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ηϱϬϱ͕ŶŽƚĞĚŽŶĨŝŶĂůƚĂůůǇ͘ŽŶΖƚZ/,ǁͬϮͲϳͬϴhĂŶĚ^W͘dĞƐƚĐĂďůĞĞǀĞƌǇϮϬϬϬΖ͘ĂĚĚŝŶŐĂĐůĂŵƉŽŶĞǀĞƌǇŽƚŚĞƌĐŽŶŶĞĐƚŝŽŶ ĨƌŽŵηϰϭϲ͘ƉƵŵƉŝŶŐϱW,ǁŚŝůĞZ/,͘Z/,dͬϭϳ͕ϬϱϰΖ͘DͬhůĂŶĚŝŶŐ:dΘŚĂŶŐĞƌ͘WĞŶĞƚƌĂƚŽƌŶŽƚĐŽŵƉĂƚŝďůĞǁŝƚŚŚĂŶŐĞƌ͘tĂŝƚ ŽŶ^WƌĞƉ͘ƚŽŵŽďŝůŝǌĞƉƌŽƉĞƌĞƋƵŝƉŵĞŶƚĨƌŽŵĐŽůĚƐƚŽƌĂŐĞ͘WƵŵƉϱW,ĚƵƌŝŶŐŽƉƐ͘dĞƌŵŝŶĂƚĞ^WĐĂďůĞƚŚƌŽƵŐŚŚĂŶŐĞƌ͕ ƚĞƐƚĐĂďůĞ;ŐŽŽĚƚĞƐƚͿDŽŶŝƚŽƌĐĂďůĞǀŝĂƵŵďŝůŝĐĂůǁŚŝůĞůĂŶĚŝŶŐŚĂŶŐĞƌΘZ/>^͘WͬhtdсϭϬϯŬ^ͬKtdсϯϬ<͘^ĞƚϯϬŬŽŶ ŚĂŶŐĞƌ͘WsŝŶƐƚĂůůĞĚŝŶŚĂŶŐĞƌ͘WƵŵƉϱW,ŽĨƐŽƵƌĐĞǁĂƚĞƌĚƵƌŝŶŐŚĂŶŐĞƌŝŶƐƚĂůů͘ůŽǁĚŽǁŶůŝŶĞƐΘĚƌĂŝŶŐĂƐďƵƐƚĞƌ͘ůĞĞĚ ĚŽǁŶĐĐƵŵƵůĂƚŽƌ͕^ĞĐƵƌĞĐĞůůĂƌΘǁĞůůŚĞĂĚ͘ZŝŐĚŽǁŶĂƚǁĂůŬ͕ĐůĞĂƌĨůŽŽƌŽĨƚƵďŝŶŐŚĂŶĚůŝŶŐƋƵŝƉŵĞŶƚ͘ ϭϬͬϴͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϭϭͬϮϬϮϮͲdƵĞƐĚĂǇ ϭϬͬϵͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϭϬͬϮϬϮϮͲDŽŶĚĂǇ 1 Regg, James B (OGC) From:Russell Gallen - (C) <Russell.Gallen@hilcorp.com> Sent:Friday, October 7, 2022 4:43 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:MPU F-38 Test BOPE Report Attachments:F-38 BOPE test report (initial ).xlsx Thank you, Phoebe. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Some people who received this message don't often get email from russell.gallen@hilcorp.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit F-38 PTD 1951680 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:10/5/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1951680 Sundry #322-541 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2484 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR 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"P Pressure After Closure (psi)1800 P Check Valve 0 NA 200 psi Attained (sec)10 P BOP Misc 0 NA Full Pressure Attained (sec)50 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2300 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 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 10/04/22 17:40 Waived By Test Start Date/Time:10/5/2022 14:00 (date)(time)Witness Test Finish Date/Time:10/5/2022 18:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp C.Pace / J. Werlinger Hilcorp Alaska LLC A.Haberthur/ R. Gallen MPU F-38 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2022-1005_BOP_Hilcorp_ASR1_MPU_F-38         J. Regg; 11/15/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOPE - Hilcorp ASR1 Date:Tuesday, November 15, 2022 4:12:21 PM Attachments:2022-1005_BOP_Hilcorp_ASR1_MPU_F-38.pdf MPU F-38 (PTD 1951680) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220930 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU I-17 500292321200 204098 3-Aug-22 READ CaliperSurvey MPU B-24 500292264200 196009 7/19/2022 READ CaliperSurvey MPU F-38 500292261400 195168 9/19/2022 READ CaliperSurvey MPU F-73A 500292274401 200198 7/31/2022 READ CaliperSurvey MPU I-01 500292206500 190090 8/31/2022 READ CaliperSurvey MPU I-30 500292371000 222023 7/12/2022 READ Inj_Profile MPU J-27 500292355700 215153 8/11/2022 READ CaliperSurvey MPU L-47 500292355000 215117 7/23/2022 READ CaliperSurvey Please include current contact information if different from above. 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sŽůƵŵĞƐ͗dďŐʹϵϳ͘ϭďďůƐƚŽ'>DηϮͬ/ʹϱϮϭďďůƐƚŽƚŽƉƉĞƌĨ;ĐŽŶƐĞƌǀĂƚŝǀĞůǇĂƐƐƵŵŝŶŐ^W ŝƐŽŶůǇϮͲϳͬϴ͟KͿ ϲ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌŝĨĨƌĞĞǌĞƉƌŽƚĞĐƚŝŽŶŝƐŶĞĞĚĞĚĚĞƉĞŶĚŝŶŐŽŶ ^ZĂƌƌŝǀĂů͘ ϳ͘ Z>ŝƚƚůĞZĞĚ^ĞƌǀŝĐĞƐĂŶĚƌĞǀĞƌƐĞŽƵƚƐŬŝĚ͘ ϴ͘ ^ĞƚWs͘EƚƌĞĞ͘ ƌŝĞĨZtKWƌŽĐĞĚƵƌĞ͗ ϵ͘ D/Zh^Z͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐ͘ ϭϬ͘ ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŝĨϬƉƐŝ͘/ĨŶĞĞĚĞĚ͕ďůĞĞĚŽĨĨĂŶǇƌĞƐŝĚƵĂůƉƌĞƐƐƵƌĞŽĨĨƚƵďŝŶŐĂŶĚĐĂƐŝŶŐ͘/Ĩ ŶĞĞĚĞĚ͕ŬŝůůǁĞůůǁͬƉƌŽĚƵĐĞĚǁĂƚĞƌŽƌƐŽƵƌĐĞǁĂƚĞƌ͘^Ğƚd^WůƵŐ͘ ϭϭ͘ EhKW͘ ϭϮ͘ dĞƐƚKWƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ Ă͘ EŽƚŝĨǇƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ dĞƐƚƵƉƉĞƌϮͲϳͬϴ͟ǆϱ͟ƌĂŵƐǁŝƚŚƚŚĞϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐǁŝƚŚƉƉƌŽǀĞĚ^ƵŶĚƌǇ͘ Ě͘ ŶƐƵƌĞƚŽŵŽŶŝƚŽƌƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐĂŶĚĂŶŶƵůƵƐǀĂůǀĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƚŽĞŶƐƵƌĞ ŶŽƉƌĞƐƐƵƌĞŝƐƚƌĂƉƉĞĚƵŶĚĞƌŶĞĂƚŚƚĞƐƚƉůƵŐ͘ Ğ͘ KŶĐĞKWƚĞƐƚŝƐĐŽŵƉůĞƚĞ͕ƐĞŶĚĂĐŽƉǇŽĨƚŚĞƚĞƐƚƌĞƉŽƌƚ;ϭϬͲϰϮϰĨŽƌŵͿƚŽK' ĂŶĚƚŽǁŶĞŶŐŝŶĞĞƌ͘ ϭϯ͘ ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůd^ƉůƵŐĂŶĚWs͘<ŝůůǁĞůůǁŝƚŚ ƉƌŽĚƵĐĞĚǁĂƚĞƌŽƌƐŽƵƌĐĞǁĂƚĞƌĂƐŶĞĞĚĞĚ͘ ϭϰ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ dŚĞWhǁĞŝŐŚƚĚƵƌŝŶŐƚŚĞϮϬϮϬǁŽƌŬŽǀĞƌǁĂƐϱϴ<ƚŽƵŶƐĞĂƚƚŚĞŚĂŶŐĞƌĂŶĚϭϯϭ< ůďƐƚŽƐŚĞĂƌƚŚĞƌĞƚƌŝĞǀĂďůĞƉĂĐŬĞƌĨƌĞĞƉŝƉĞ͘ ď͘ dŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶǁĂƐůĂŶĚĞĚǁŝƚŚĂWhtŽĨϭϬϲ<ĂŶĚϮϳ<ƐůĂĐŬŽĨĨǁƚ͘ ϭϱ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ ϭϲ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘EƵŵďĞƌĂůůũŽŝŶƚƐ͘dďŐǁŝůůďĞƐŽƌƚĞĚďĂƐĞĚŽŶƚŚĞ ƚƵďŝŶŐĐĂůŝƉĞƌƌĞƐƵůƚƐ͘'ŽŽĚũŽŝŶƚƐǁŝůůďĞďƌŽƵŐŚƚƚŽŝŶǀĞŶƚŽƌǇƵŶůĞƐƐĚĂŵĂŐĞŽƌŽƚŚĞƌ ŽďƐĞƌǀĂƚŝŽŶƐĂƌĞƐĞĞŶǁŚŝůĞƉƵůůŝŶŐ͘>ĂǇĚŽǁŶĨĂŝůĞĚ^W͘ Ă͘ ŽŶƚĂĐƚKĨŽƌĐĂůŝƉĞƌƌĞƐƵůƚƐŝĨŶŽƚƉƌĞǀŝŽƵƐůǇƉƌŽǀŝĚĞĚ͘ ď͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐĂŶĚŵĂƌŬĨŽƌĚŝƐƉŽƐĂů͘ Đ͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐĂ ŶĚũƵŶŬƚŚĞŵ͘ $VVXUHQRSUHVVXUHRQ%39/XEULFDWHRXWLIULVNRISUHVVXUH ^W^ǁĂƉ tĞůů͗DWh&Ͳϯϴ ĂƚĞ͗ϬϵͬϭϮͬϮϬϮϮ Ě͘ ůůĐůĂŵƉƐĂŶĚũĞǁĞůƌǇǁŝůůďĞĐůĞĂŶĞĚĂŶĚƉƵƚŝŶƚŽŝŶǀĞŶƚŽƌǇ ĨŽƌƌĞͲƵƐĞ͘ Ğ͘ ůůĐĂďůĞŝƐƚŽďĞƐĂůǀĂŐĞĚĂŶĚƐĞŶƚƚŽĂŬĞƌĨŽƌŝŶƐƉĞĐƚŝŽŶĂŶĚƚĞƐƚŝŶŐĨŽƌƉŽƐƐŝďůĞ ƌĞͲƵƐĞ͘ &URVVFROODUFODPSV 3URWHFWROL]HU&ODPSV )ODW*XDUG&ODPSV 0RWRU &ODPSV ϭϳ͘ Dh^ƉŽŽůĞƌƚŽƌƵŶ^WĐĂďůĞ͘ ϭϴ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϭϳ͕Ϭϰϳ͛D 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 ϭϵ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌĂŶĚůĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘EŽƚĞWh;WŝĐ ŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶ ƚĂůůǇ͘ ϮϬ͘ ^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&ϭϬͬϭϯͬϮϬϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&Ͳϯϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϭϭͬϮϬϮϬ Wd͗ϭϵϱͲϭϲϴ dс ϭϳ͕ϱϴϴ͛ ;DͿͬdсϳ͕ϲϳϬ͛;dsͿ ϮϬ´ Z<͗'>сϰϱ͘ϰϲ͛ͬ'>ůĞǀ͘сϭϮ͘Ϯ͛ͬZdƚŽdďŐ͘ ^ƉŽŽůсϯϯ͘Ϯϲ͛;EϮϳͿ ϳ͟ ϵͲϱͬϴ͟ ϳ͟ĂƐŝŶŐƐŚŽƌƚ ũŽŝŶƚƐĨƌŽŵϭϲ͕ϵϰϳ͛ ƚŽϭϲ͕ϵϲϳ͛ $6DQGV 0LQ,'´ # Wdс ϭϳ͕ϰϴϮ͛;DͿͬWdсϳ͕ϱϴϴ͛;dsͿ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ĂƉĂĐŝƚǇ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬEdͲϴϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϬΖ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƵƚƚ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϴ͕ϱϲϭΖ Ϭ͘Ϭϳϱϴ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƵƚƚ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϭϳ͕ϱϲϴΖ Ϭ͘Ϭϯϴϯ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϯϰϳ ^ƵƌĨĂĐĞ ϭϳ͕Ϭϰϳ͛ Ϭ͘ϬϬϱϴ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϵϭ͛ ^dηϮ͗ϮͲϳͬϴΗǆϭ͟W^Ksǁͬ<Ϯ>ĂƚĐŚ Ϯ ϭϲ͕ϳϱϰ͛ ^dηϭ͗ϮͲϳͬϴΗǆϭ͟'>DǁͬƵŵŵǇ'>sǁͬ<Ϯ>ĂƚĐŚ ϯ ϭϲ͘ϴϳϱ͛ ϮͲϳͬϴ͟yEEŝƉƉůĞ͕Ϯ͘ϮϬϱ͟EŽͲ'Ž ϰ ϭϲ͕ϵϲϬ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ͬKWDWϱϭϯϮͲϳͬϴyϴhϭϬϰϬ ϱ ϭϲ͕ϵϲϭ͛ ĞŶŝƚŚWŽƌƚĞĚ^Ƶď͗^ͬͬKWZ^^WKZdϱϭϯͬϱϯϴWWDW ϲ ϭϲ͕ϵϲϮ͛ WƵŵƉϮ͗WD^y,ϲϴϮ^d'ϱϯϴ&>yϮϳ ϳ ϭϲ͕ϵϴϵ͛ WƵŵƉϭ͗WD^y,ϲϭϯϱ^d'ϱϯϴ&>yϮϳ ϴ ϭϳ͕ϬϬϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'^D^dZydZDϱϯϴ'^sKZdy ϵ ϭϳ͕ϬϭϮ͛ hƉƉĞƌdͲ^ĞĂů͗'^,>,ϲ^ͬ^W&^ ϭϬ ϭϳ͕Ϭϭϵ͛ >ŽǁĞƌdͲ^ĞĂů͗'^,>,ϲ^ͬ^W&^ ϭϭ ϭϳ͕ϬϮϲ͛ DŽƚŽƌ͗ ϱϲϮyWϮϱϬ,ƉͬϮ͕ϱϬϱsͬϲϭ ϭϮ ϭϳ͕ϬϰϮ͛ 'ĂƵŐĞĂŶĚĞƚƌĂůŝǌĞƌ͗E/d,ϳʹ ƚŵΛϭϳ͕Ϭϰϳ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘^ĂŶĚƐ ϭϳ͕ϭϵϵ͛ ϭϳ͕Ϯϰϯ͛ ϳ͕ϯϳϯΖ ϳ͕ϰϬϲΖ ϰϰΖ ϮͬϮϰͬϭϵϵϲ KƉĞŶ ϭϳ͕ϮϱϬ͛ ϭϳ͕ϮϵϬ͛ ϳ͕ϰϭϭ͛ ϳ͕ϰϰϭ͛ ϰϬΖ ϭϭͬϭϲͬϮϬϬϰ KƉĞŶ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐŬƐŝŶϯϬ͟,ŽůĞʹdKΛ^ƵƌĨĂĐĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϴϴϬƐŬƐŝŶϭϮͲϭͬϰ͟,ŽůĞͲdKΛ^ƵƌĨĂĐĞ ϳ͟ ŵƚǁͬϮϭϳƐŬƐŝŶϴͲϭͬϮ͟,ŽůĞʹdKĐĂůĐƵůĂƚĞĚΛϭϱ͕Ϯϰϳ͛ t>> /E>/Ed/KE d/> <KWΛϱϱϬ͛ DĂǆ,ŽůĞŶŐůĞсϳϰƚŽϳϴĚĞŐ͘Ĩͬϰ͕ϯϬϬ͛ƚŽϭϱ͕ϭϬϬ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϰϮĚĞŐ͘ t>>^d/Dh>d/KEd/> ϯͬϭͬϵϲʹϰϮ͘ϴϱDůďƐ͘ϭϲͬϮϬĂƌďŽůŝƚĞƉƌŽƉ͘^ĐƌĞĞŶĞĚŽƵƚǁͬϴƉƉŐŽŶƉĞƌĨƐ ϯͬϭϮͬϵϲʹϭϭϱDůďƐ͘ϭϲͬϮϬĂƌďŽůŝƚĞƉƌŽƉ͘:ŽďǁĞŶƚƚŽĨůƵƐŚ dZΘt>>, dƌĞĞ ϯͲϭͬϴ͟ʹϱDĂŵĞƌŽŶ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶ͘ϱĂǁͬϯͲϭͬϮ͟&DdďŐ͘,ŶŐ͘ϰ͟>,ĐŵĞ ƚŽƉǆϯͲϭͬϮ͟hϴƌĚďŽƚƚŽŵ͕ϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϭϰͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϳͲϭϮͬϰͬϭϵϵϱ ŽŵƉůĞƚĞĚǁŝƚŚ^WďǇEĂďŽƌƐϰ^ʹϯͬϮϮͬϭϵϵϱ ^WZtKEĂďŽƌƐϰ^ʹϭϬͬϮϬͬϭϵϵϵ ^WZtKEĂďŽƌƐϰ^ʹϭϭͬϭϴͬϮϬϬϰ ^WZtKEĂďŽƌƐϰ^ʹϲͬϰͬϮϬϬϱ ^ZŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉͬ'ĂƐ>ŝĨƚʹϭϮͬϱͬϮϬϭϲ ^Z/ŶƐƚĂůů^WʹϵͬϭϭͬϮϬϮϬ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϵͬϭϮͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&Ͳϯϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϭϭͬϮϬϮϬ Wd͗ϭϵϱͲϭϲϴ dс ϭϳ͕ϱϴϴ͛ ;DͿͬdсϳ͕ϲϳϬ͛;dsͿ ϮϬ´ Z<͗'>сϰϱ͘ϰϲ͛ͬ'>ůĞǀ͘сϭϮ͘Ϯ͛ͬZdƚŽdďŐ͘ ^ƉŽŽůсϯϯ͘Ϯϲ͛;EϮϳͿ ϳ͟ ϵͲϱͬϴ͟ ϳ͟ĂƐŝŶŐƐŚŽƌƚ ũŽŝŶƚƐĨƌŽŵϭϲ͕ϵϰϳ͛ ƚŽϭϲ͕ϵϲϳ͛ $6DQGV 0LQ,'´ # Wdс ϭϳ͕ϰϴϮ͛;DͿͬWdсϳ͕ϱϴϴ͛;dsͿ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ĂƉĂĐŝƚǇ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬEdͲϴϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϬΖ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƵƚƚ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϴ͕ϱϲϭΖ Ϭ͘Ϭϳϱϴ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƵƚƚ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϭϳ͕ϱϲϴΖ Ϭ͘Ϭϯϴϯ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϯϰϳ ^ƵƌĨĂĐĞ цϭϳ͕Ϭϰϳ͛ Ϭ͘ϬϬϱϴ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϵϭ͛ ^dηϮ͗ϮͲϳͬϴΗǆϭ͟W^Ksǁͬ<Ϯ>ĂƚĐŚ Ϯ цϭϲ͕ϳϱϰ͛ ^dηϭ͗ϮͲϳͬϴΗǆϭ͟'>DǁͬƵŵŵǇ'>sǁͬ<Ϯ>ĂƚĐŚ ϯ цϭϲ͘ϴϳϱ͛ ϮͲϳͬϴ͟yEEŝƉƉůĞ͕Ϯ͘ϮϬϱ͟EŽͲ'Ž ϰ цϭϲ͕ϵϲϬ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϱ цϭϲ͕ϵϲϭ͛ ĞŶŝƚŚWŽƌƚĞĚ^Ƶď͗ ϲ цϭϲ͕ϵϲϮ͛ WƵŵƉϮ͗ ϳ цϭϲ͕ϵϴϵ͛ WƵŵƉϭ͗ ϴ цϭϳ͕ϬϬϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϵ цϭϳ͕ϬϭϮ͛ hƉƉĞƌdͲ^ĞĂů͗ ϭϬ цϭϳ͕Ϭϭϵ͛ >ŽǁĞƌdͲ^ĞĂů͗ ϭϭ цϭϳ͕ϬϮϲ͛ DŽƚŽƌ͗ ϭϮ цϭϳ͕ϬϰϮ͛ 'ĂƵŐĞĂŶĚĞƚƌĂůŝǌĞƌ͗ʹƚŵΛцϭϳ͕Ϭϰϳ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘^ĂŶĚƐ ϭϳ͕ϭϵϵ͛ ϭϳ͕Ϯϰϯ͛ ϳ͕ϯϳϯΖ ϳ͕ϰϬϲΖ ϰϰΖ ϮͬϮϰͬϭϵϵϲ KƉĞŶ ϭϳ͕ϮϱϬ͛ ϭϳ͕ϮϵϬ͛ ϳ͕ϰϭϭ͛ ϳ͕ϰϰϭ͛ ϰϬΖ ϭϭͬϭϲͬϮϬϬϰ KƉĞŶ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐŬƐŝŶϯϬ͟,ŽůĞʹdKΛ^ƵƌĨĂĐĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϴϴϬƐŬƐŝŶϭϮͲϭͬϰ͟,ŽůĞͲdKΛ^ƵƌĨĂĐĞ ϳ͟ ŵƚǁͬϮϭϳƐŬƐŝŶϴͲϭͬϮ͟,ŽůĞʹdKĐĂůĐƵůĂƚĞĚΛϭϱ͕Ϯϰϳ͛ t>> /E>/Ed/KE d/> <KWΛϱϱϬ͛ DĂǆ,ŽůĞŶŐůĞсϳϰƚŽϳϴĚĞŐ͘Ĩͬϰ͕ϯϬϬ͛ƚŽϭϱ͕ϭϬϬ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϰϮĚĞŐ͘ t>>^d/Dh>d/KEd/> ϯͬϭͬϵϲʹϰϮ͘ϴϱDůďƐ͘ϭϲͬϮϬĂƌďŽůŝƚĞƉƌŽƉ͘^ĐƌĞĞŶĞĚŽƵƚǁͬϴƉƉŐŽŶƉĞƌĨƐ ϯͬϭϮͬϵϲʹϭϭϱDůďƐ͘ϭϲͬϮϬĂƌďŽůŝƚĞƉƌŽƉ͘:ŽďǁĞŶƚƚŽĨůƵƐŚ dZΘt>>, dƌĞĞ ϯͲϭͬϴ͟ʹϱDĂŵĞƌŽŶ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶ͘ϱĂǁͬϯͲϭͬϮ͟&DdďŐ͘,ŶŐ͘ϰ͟>,ĐŵĞ ƚŽƉǆϯͲϭͬϮ͟hϴƌĚďŽƚƚŽŵ͕ϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϭϰͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϳͲϭϮͬϰͬϭϵϵϱ ŽŵƉůĞƚĞĚǁŝƚŚ^WďǇEĂďŽƌƐϰ^ʹϯͬϮϮͬϭϵϵϱ ^WZtKEĂďŽƌƐϰ^ʹϭϬͬϮϬͬϭϵϵϵ ^WZtKEĂďŽƌƐϰ^ʹϭϭͬϭϴͬϮϬϬϰ ^WZtKEĂďŽƌƐϰ^ʹϲͬϰͬϮϬϬϱ ^ZŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉͬ'ĂƐ>ŝĨƚʹϭϮͬϱͬϮϬϭϲ ^Z/ŶƐƚĂůů^WʹϵͬϭϭͬϮϬϮϬ 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 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Change Jet Pump to ESP Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,588 feet N/A feet true vertical 7,670 feet N/A feet Effective Depth measured 17,482 feet N/A feet true vertical 7,588 feet N/A feet 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 17,047' 7,260' 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): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi Burst N/A 5,750psi 7,240psi 777-8333 20" 9-5/8" 7" 4,475' 7,655' 5,410psi Casing Conductor Length 80' 8,525' 17,535' Surface Production MPU F-38 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 229 Gas-Mcf 2,967 Casing Pressure Tubing Pressure 296 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-278 359 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 400 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-168 50-029-22614-00-00 Plugs ADL0025509, ADL0355016 & ADL0355018 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 189 Representative Daily Average Production or Injection Data 357561 930 Oil-Bbl measured true vertical Packer Size N/A WINJ WAG 193 Water-Bbl MD 110' 8,561' 17,568' TVD 110' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:38 am, Oct 14, 2020 Chad A Helgeson 2020.10.14 12:22:43 -05'00'MGR15OCT2020 SFD 10/15/2020 DSR-10/15/2020 RBDMS HEW 11/25/2020 _____________________________________________________________________________________ Revised By: TDF 10/13/2020 SCHEMATIC Milne Point Unit Well: MPU F-38 Last Completed: 9/11/2020 PTD: 195-168 TD =17,588’ (MD) / TD = 7,670’(TVD) 20” RKB: AGL =45.46’/ GLElev.= 12.2’/RT to Tbg. Spool = 33.26’ (N27E) 7” 4 5 6 7 8 9 9-5/8” 2 3 7” Casing short joints from 16,947’ to 16,967’ A Sands Min ID 2.205” @ 16,875 PBTD = 17,482’ (MD) / PBTD = 7,588’(TVD) 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm Capacity 20" Conductor 91.1 / NT-80 / N/A N/A Surface 110' N/A 9-5/8" Surface 40 / L-80 / Butt 8.679 Surface 8,561' 0.0758 7" Production 26 / L-80 / Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface ±17,050’ 0.0058 JEWELRY DETAIL No Depth Item 1 191’ STA #2: 2-7/8" x 1” DPSOV w/ BK 2 Latch 2 16,754’ STA #1: 2-7/8" x 1” GLM w/ Dummy GLV w/ BK 2 Latch 3 16.875’ 2-7/8” XN Nipple,2.205” No-Go 4 16,960’ Discharge Head: B/O PMP 513 2-7/8X8 EUE1040 5 16,961’ Zenith Ported Sub: S/A B/O PRESS PORT 513/538P PMP 6 16,962’ Pump 2: PMSXD H6 82 STAGE 538 FLEX 27 7 16,989’ Pump 1: PMSXD H6 135 STAGE 538 FLEX 27 8 17,007’ Gas Separator: GAS MASTER EXTREME 538 GS VORTEX 9 17,012’ Upper T-Seal: GSBEDB HL H6 SB/SB PFSA 10 17,019’ Lower T-Seal: GSBEDB HL H6 SB/SB PFSA 11 17,026’ Motor: 562 XP 250Hp/ 2,505V/ 61A 12 17,042’ Gauge and Cetralizer: ZENITH E7 –Btm @ 17,047’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 17,199’ 17,243’ 7,373' 7,406' 44' 2/24/1996 Open 17,250’ 17,290’ 7,411’ 7,441’ 40' 11/16/2004 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks in 30” Hole – TOC @ Surface 9-5/8" Cmt w/ 1,880 sks in 12-1/4” Hole - TOC @ Surface 7” Cmt w/ 217 sks in 8-1/2” Hole – TOC calculated @ 15,247’ WELL INCLINATION DETAIL KOP @ 550’ Max Hole Angle = 74 to 78 deg. f/ 4,300’ to 15,100’ Hole Angle through perforations = 42 deg. WELL STIMULATION DETAIL 3/1/96 – 42.85 M lbs. 16/20 Carbolite prop. Screened out w/ 8ppg on perfs 3/12/96 – 115 M lbs. 16/20 Carbolite prop. Job went to flush TREE & WELLHEAD Tree 3-1/8” – 5M Cameron Wellhead 11” 5M FMC Gen. 5a w/ 3-1/2” FMC Tbg. Hng. 4” LH Acme top x 3-1/2” EUE 8rd bottom, 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E - 12/4/1995 Completed with ESP by Nabors 4ES – 3/22/1995 ESP RWO Nabors 4ES – 10/20/1999 ESP RWO Nabors 4ES – 11/18/2004 ESP RWO Nabors 4ES – 6/4/2005 ASR Convert to Jet Pump/Gas Lift – 12/5/2016 ASR Install ESP – 9/11/2020 Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 LRS/ ASR#1 50-029-22614-00-00 195-168 9/6/2020 9/11/2020 No operations to report. 9/5/2020 - Saturday Held PJSM and discussed plan forward. Checked fluids and serviced rig. PU BOPE Testing equipment and prepared for the Shell Test. Preformed Shell Test 250/3,000psi good test. Preformed BOPE Test w/ 2-7/8" and 3-1/2" test joint as following: Annular 250-2,500psi, Rams 250-3,000psi, Valves 250-3,000psi, gas detection and performed Koomey draw down. 1 F/P was recorded on C-1. AOGCC witness waived by Jeff Jones. Blew lines dry and L/D BOP testing equipment. Off loaded 541jts of 2- 7/8" EUE 8rd tbg. Bled off Gas Head from the Tbg through the BPV. Pumped 20 bbls of source water down tbg @ 3bpm/50psi. SD pump and tbg was on a vacuum. Pulled BPV monitored well. Tbg started venting gas after pulling BPV. Opened tbg to the pits and bled off remaining gas head. PU 3-1/2" EUE Landing jt and MU 3-1/2" EUE x 4-1/4" LH Acme crossover for hanger. MU Landing joint to hanger. Pulled hanger off seat at 58k and packer sheared free at 131k. Lower and reseat Hanger. RILDS. Bullhead 60 bbls of Source Water down IA at 3.8 BPM and 220psi. Bullhead 25 bbls of Source Water down Tubing at 3.5 BPM and 200psi. Conduct Fluid checks on Rig. M/U Spacer Spools atop the Annular Preventer. BOLDS. Tubing on a vac. IA is static. Pull Hanger and fluid level in Stack drops quickly. Pull Hanger to Rig Floor. Break Cap Tube and Tech Wire at Hanger. R/U two spoolers and Sheave. L/D Hanger and Landing Joint. Break TIW. Pump 5 bbls of Source Water down well. Pressure up cap string to 4,000psi to keep SSSV open while POH. POH with 3-1/2" 9.3# L-80 EUE 8rd Tubing while spooling TEC Wire and Cap String. Pumping double displacement every 15 joints. Bleed off control line and disconnect from Halliburton TRSSSV. Break and L/D TRSSSV. Lower control line off Rig Floor to ground. POH with 3-1/2" 9.3# L-80 EUE 8rd Tubing while spooling TEC Wire. Pumping double displacement every 15 joints. 105 joints total removed during shift. 9/6/2020 - Sunday MIRU LRS and return tank. Pressured PT lines to 2,500psi. SITP 500psi/IA 300psi/OA 0psi. Bled off Tbg and IA to 0psi. Returns were all gas. Started pumping dn IA with tbg opened @ 4bpm/0psi. Pumped away 137bbls never broke circulation. SD pump, IA on a vac and tbg static. Closed IA and started pumping down tbg @ 4bpm/0psi. Pumped away 132bbls, SD pump monitored well TBG and IA on Vac. Set the BPV. RDMO LRS. Mobed ASR and equipment from A pad to F-pad and staged for RU. Removed the rig mats in front of the well and filled in low area with gravel and leveled pad. Changed out multi rams while waiting on R&P's to level pad. MIRU crane, ND the production Tree, Inspected lifting threads and verified 4.25" LH Acme XO. Lift and place BOPE on wellhead. Hammer up BOPE. Lift and place Well Hut. Lift and place Rig Floor. MIRU rig components. Bleed IA pressure from 50psi to 0psi. All gas bled, no fluid. IA remains at 0psi. Conduct GrayLoc training while making up lines. Load Pit #1 with fresh water for BOP Test. M/U hydraulic lines to BOPE. Lift 3-1/2" Test Joint to Rig Floor. 9/7/2020 - Monday 9/4/2020 - Friday No operations to report. 9/2/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/3/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 LRS/ ASR#1 50-029-22614-00-00 195-168 9/6/2020 9/11/2020 Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM and discussed daily activities. Checked fluids and serviced rig. Continued POOH w/ 3-1/2" L-80 EUE 8rd completion with no overpull or drag f/ 12,068'md t/ 8,332'md pumping double displacement every 15 joints. On joint number 275 (8,332'md) swapped reels for the Techwire. Continued POOH w/ 3-1/2" L-80 EUE 8rd completion with no overpull or drag f/ 8,332'md t/ 4500'md pumping double displacement every 15 joints. Continued POOH w/ 3-1/2" L-80 EUE 8rd completion with no overpull or drag f/ 4,500' pumping double displacement every 15 joints. Noticed 5k-lb overpull at 3,400'. Well no longer taking double displacement at 22:20. Well fluid packed to surface. Appear to be swabbing as POH. Shut down and monitor well. Notice small of gas percolating up to surface. Fluid level remaining the same. RIH with completion and FL drops. Attempt to circulate down tubing by pumping 20 bbls of Source Water at 1.5 BPM and 100psi. No returns seen out IA. Attempt to bullhead down IA but IA quickly pressures up. Clear evidence that element on Packer has rolled. Monitor well. FL static. No gas seen percolating to surface. Change out back up dies on Tongs. Continued POOH w/ 3-1/2" L-80 EUE 8rd completion from 1,000' while monitoring FL as POH. 5k-8k lb overpull seen as Packer passes each casing collar. At 520', FL drops dramatically. Pump 2 bbls and FL is not visible. Continue to POH. M/U ESP. Load and strap 2-7/8" Tubing. 9/8/2020 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 LRS/ ASR#1 50-029-22614-00-00 195-168 9/6/2020 9/11/2020 9/11/2020 - Friday Continued RDMO ARS. Crane ops suspended due to high wind. Started crane ops. Fly off Rig floor and cellar. ND BOP stack NU PT. Tested tree to 5,000psi. Pulled the BPV. 9/9/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM and discussed daily activities. Continued MU and servicing New ESP Assembly. Complete final service checks. Filling hole 3 bph with 8.3 Source Water. RIH w/New ESP on 2-7/8" 6.5# L-80 EUE 8rd PU X-N Nipple 2.205 No-Go - 2.313 ID, Lower GLM w/ Dummy installed 1" valve- BK2- Latch continued RIH. On jt #13 (553') while slacking off the clamp hung up on top of the BOP stack and separated 3" of armor. Inspected and found no damage to the jacket around the wires. Wrapped area with new armor and sealed. Test on cable showed good electrical integrity. After investigating the incident found whipper plate was not center over the hole. Continued RIH w/2-7/8" ESP Completion f/553' T/8,150'. Clamping cable every joint and testing cable the 1st 1,000' and every 2,000' thereafter. Pumping 3bph of 8.3# source water while RIH. Prepare to swap ESP cable reel and splice new reel. Perform kick while tripping drill with crew and perform After Action Review. Good drill and captured minor improvements with crew. Pump 10 bbl of source water before splicing activity. Complete and test splice. Continue RIH with ESP completion. 9/10/2020 - Thursday Held PJSM and discussed daily activities. Checked fluid and serviced rig. Continued RIH w/2-7/8" ESP Completion f/9,600' T/16,000'. Clamping cable every joint and testing cable the 1st 1,000' and every 2,000' thereafter. At on jt 409 started clamping cable every other joint. Filling hole 3bph of 8.3# source water while RIH. Swapped spools and performed cable splice. No operations to report. No operations to report. 9/12/2020 - Saturday No operations to report. 9/15/2020 - Tuesday 9/13/2020 - Sunday No operations to report. 9/14/2020 - Monday Wu F 3G Pm 1,4,�rioo Regg, James B (CED) From: Regg, James B (CED) Sent: Monday, August 10, 2020 2:50 PM To: David Gorm Subject: RE: F-38 (PTD: 195-168) No Flow test requirements Per our phone conversation: removing step 6 from the procedure and this test procedure is acceptable; Steps 1-5 (Pressure discharge method) does not need to pass through a meter; make sure offset injectors — if any — supporting F-38 are online and injecting; evidence of such should be available for the AOGCC Inspector witnessing the test. Thank you for sending the procedure for review. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITYNOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: David Gorm <dgorm@hilcorp.com> Sent: Monday, August 10, 2020 1:24 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: F-38 (PTD: 195-168) No Flow test requirements Mr. Regg, Please find attached our proposed no flow test procedure for MP F-38 and the wells current schematic. We are prepared to set up a witnessed no -flow test on F-38 and would like to review our current no flow procedure. We are looking to ensure we are meeting the requirements of 20 AAC 25.265 with our proposed procedure. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. Wellwork Request Form A ell: MPU F-38 API #: 50-029-22614-00 2nd Call OE: Date: 8/10/2020 ops Engr: P g David Gorm 907-777-8333 Office Ph: Cost Est: Office Ph: Cell: 505-251-2819 Cell: PO or AFE: PO 77° @ 4,654' MD Last Tag: 15,159' MD (JP Set) Max Dev: Min ID: N/A Last SITP: Notes On Well Condition: II is currently online as a JP Producer. Complete a 3 hr shut in pressure build up. Bleed the well pressure down recording the fluid rate and gas rate with AOGCC witness for a no -flow test. Wellwork Procedure: i Shut the well in, RU line to a flowback tank to Vent the well 3 Notify AOGCC 24 hrs to Witness No flow test 4 Shut in bleed to tank for three-hour pressure build-up period. Document TBG and IA pressures. 5 Bleed the TBG and IA pressure down through a 2" line to the bleed tankcumentureeis'discha gleed down the 3 hour build up pressure. (NOTE: 20 AAC 25.265 (1)(1) (B) wepress not later than 5 minutes after a 3 hour charted pressure build-up period.) 6 After the well has blown down, document volume of fluid bled back and any steady-state fluid flow flow rate through rate through the 2" bleed line after 5 minutes. Then document any steady-state gas the 1/2" flow meter for 5 minutes recording the gas flow rate at the end of the 5 minutes. note: 20 AAC 25.265 (1)(1): no -flow test requires measured liquid production is not greater than 6.3 gallons per hour and the measured gas production is not greater than 900 cubic feet per hour; or (B) Thheiod. well pressure is discharged not later than 5 minutes after a 3 hour charted pressure build-up p 25 Flow rate test (contingency if STEP 5/6 test fails): a. With well bleed open, align well bleed through flow meter to apressures oristart of tic tank d close bypass. b. Record tubing (T), inner annulus (IA), and outer annulus (OA) c. Shut in well bleed and monitor pressure build up — record T, IA and OA pressures every 15 minutes for 1 hour. er d. After 1 hour open flow through the metand document the flow rates and associated pressures rate declines below allowed rates, not to exceed 30 (T, IA and OA) every 5 minutes until the flow minutes. Repeat at 2 and 3 hours. e. the fduct on is notdgliquid reaterproduction greater ns per ur, and the 900 standard procubic feet per houlrr,, the test ois a PASS. Rig downed gas P Notes: Hilrorp rUa.ka, Idd: RKR- AGL = 45.46'/ GL Elev.=12.2'/RT to Thg. 'Ids TD =17,588' (MD) / TD = 7,670'(TVD) PBTD =17,482' (MD) / PBTD = 7,588' (TVD) Milne Point Unit Well: MPU F-38 SCHEMATIC Last Completed: 12/5/2016 PTD: 195-168 TREE & WELLHEAD Tree 3-1/8"—SM Cameron 11" 5M FMC Gen. 5a w/ 3 1/2" FMC Tbg. Hng. 4" LH Acme Wellhead top x 3-1/2" EUE 8rd bottom, 3" CIW H BPV Profile OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks in 30" Hole —TOC @Surface 9-5/8" Cmt w/ 1,880 sks in 12-1/4" Hole - TOC @ Surface 247 7" Cmt w/ 217 sks in 8-1/2" Hole —TOC calculated @ 15, CASING DETAIL WELL STIMULATION DETAIL �h� 3/1/96 —42.85 M lbs. 16/20 Carbolite prop. Screened out w3/12/96 —115 M Ibs.16/20 Carbolite prop. lob went to flu GENERAL WELL INFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E - 12/4/1995 Completed with ESP by Nabors 4ES — 3/22/1995 ESP RWO Nabors 4ES — 10/20/1999 ESP RWO Nabors 4ES— 11/18/2004 ESP RWO Nabors 4ES— 6/4/2005 ASR —Convert to jet Pump/Gas Lift —12/5/2016 F-38 Passed AOGCC witnessed NO FLOW TEST 03/09/2017 Status Revised BY; BK 6-16-19 Wt/ Grade/ Conn Drift ID Top Btm Capacity S ze 20" Type Conductor 91.1 / NT -80 / N/A N/A Surface 110' N/A Surface 8,561 0.0758 9-5/8" Surface 40 / L-80 / Butt 8.679 6.151 Surface 17,568' 0.0383 7" Production 26 / L-80 / Butt TUBING DETAIL Surface 17,090' 0.00592 31/2 Tubing 9.3 / L-80 %EUE 8rd � 2.992 I WELL INCLINATION DETAIL wzi erforations JEWELRY DETAIL No Depth Item 2,003' 3.5" NE TRSV w/ 2.813 X. TC -II BXP 1 2 181' GLM 42: 3.5° x 1" SPMO GLM "i)v 2 3,701' GLM #1: 3.5" x 1" SPMO GLM +, d; 1 1 3 3-1/2" XD Slidin Sleeve 9Cr-1Mo 6,443' g q 5 15,159'3-1/2" XD Sliding Sleeve 9Cr-1Mo .:. 16,490' 3-1/2" ROC gauge (TCI BxP) 6 7 16,979' Baker 7" x 3 1/2" FHL Packer Box x Pin fill Sub, 3.5" 9.2# L-80 Vam Top g 17,005' Auto 17,007' Mirage Plug, 3.5" 9.2# 9Cr-1Mo Vam Top Box x Pin 9 17,033' 3 1/2" XN Nipple (2.813 wl 2.75" No -Go) 10 11 17,087' 3-1/2" WLEG PERFORATION DETAIL Sand�11 Top (TVD) Btm (TVD) FT Date op (MD) Btm (MD) 44' 2/24/1996 17,199' 17,243' 7,373' 7,406' 7,441' 40' 11/16/2004 Kup. A S 250' 17,290' 7,411' WELL STIMULATION DETAIL �h� 3/1/96 —42.85 M lbs. 16/20 Carbolite prop. Screened out w3/12/96 —115 M Ibs.16/20 Carbolite prop. lob went to flu GENERAL WELL INFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E - 12/4/1995 Completed with ESP by Nabors 4ES — 3/22/1995 ESP RWO Nabors 4ES — 10/20/1999 ESP RWO Nabors 4ES— 11/18/2004 ESP RWO Nabors 4ES— 6/4/2005 ASR —Convert to jet Pump/Gas Lift —12/5/2016 F-38 Passed AOGCC witnessed NO FLOW TEST 03/09/2017 Status Revised BY; BK 6-16-19 MEMORANDUM TO: Jim Regg P. I. Supervisor FROM: Matt Herrera State of Alaska Alaska Oil and Gas Conservation Commission T,�� 7/ZZIZp4, DATE: Petroleum Inspector SUBJECT: 7/13/2020 No Flow Test MPU F-38 Hilcorp Alaska LLC PTD 1951680; Sundry 320-278 7/13/2020: Traveled to Milne Point and met with Well Ops Coordinator Josh McNeal (Hilcorp) and went over the set up for a no -flow test on MPU F-38. This well is slated for a Jet Pump to ESP conversion and has an existing SSSV despite a previous passing no -flow test (3/9/2017). F-38 had 2 -inch hard line tied into the tree cap over to a 110% bleed tank. The in-line test manifold was equipped with a pressure gauge and new Armor Flo meter with full bore 1/4 -turn ball valves. Specs on the Armor Flo meter: Model 3461-0210-33; Serial # 152157 ' 0-1000 SCFH 0-400 psi 80-250 degrees F MPU F-38 was bled down prior to my arrival with minimum gas pressure and no liquids present when opened to the test manifold. At 1.5 hours into shut in pressure build-up monitoring period, the pressure gauge was observed to be over -pressured and "wrapped". The new gauge installed did not have sufficient range to determine the current pressure. A third gauge was installed (500 psi calibrated analog type) and showed 210 psi on the well (previous reading was 6.5 psi). It appeared something catastrophic occurred down hole causing the wellbore pressure to rapidly increase. After the 3 -hour buildup it took 35 minutes of de -pressuring the well, showing 600 SCFH (no liquids produced to surface) and approximately 10 psi before being shut in. MPU F- 38 pressures were monitored for an additional 1 hour then opened to flow, taking 8 minutes to bleed from 50 psi to 0.5 psi and a gas flow rate of 300 SCFH. The general consensus decision was to not continue with the no -flow test — the same crew was slated to do a P&A tag on different drill site with wireline waiting. It is my determination from this test that MPU F-38 can produce without the assistance of artificial lift and therefore requires a SSSV. The following table shows test details: 2020-0713—No-Flow—MPU—F-3 8_mh.docx Pagel of 2 Time Pressures' (psi) Flow Rate' Gas — scf/hr Liquid — Remarks al/hr 13:10 0.25/100/90 50 0 Firstpressure/flow reading 13:40 2.9/100/90 Monitor pressure buildup 14:10 6.5/100/90 Monitor ressure buildup 14:40 210/100/20 Downhole incident? Change pressure gauge 15:10 230/100/20 Monitor pressure buildup 15:40 250/100/20 >1000 0 Oen well to flow 16:15 10/100/20 600 0 Shut in 16:45 40/100/20 17:15 45/100/20 17:45 50/100/20 >1000 - 0 Oen well to flow 17:53 0.5/100/20 300 0 End test ' Pressures are T/IA/OA ' Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Inspection Supervisor Note: Test is deemed inconclusive Attachments: none 2020-0713_No-Flow_MPU_F-3 8_mh. doex Page 2 of 2 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Change Jet to ESP 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 17,588'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dgorm@hilcorp.com Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing MD (ft):Perforation Depth TVD (ft): COMMISSION USE ONLY Authorized Name: Authorized Title: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355016 195-168 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22614-00-00 MILNE POINT / KUPARUK RIVER OIL Hilcorp Alaska LLC Length Size 7,670' 17,482' 7,588' C.O. 432D PRESENT WELL CONDITION SUMMARY 2,522 MPU F-38 N/A 110' 110' 9.3 / L-80 / EUE 8rd TVD Burst 17,090' MD N/A Tubing Grade: 5,750psi 7,240psi 4,475' 7,655' 8,561' 17,568' DavidGorm Baker 7" x 3-1/2" FHL and 3.5" NE TRSV 16,979 MD/ 7,210 TVD and 2,003 MD/ 1,969 TVD See Schematic 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 80'20" 9-5/8" 7" 8,525' 17,535' Authorized Signature: 8/1/2020 3-1/2" Perforation Depth MD (ft): See Schematic Tubing Size: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 2:27 pm, Jun 26, 2020 320-278 Chad A Helgeson 2020.06.26 11:20:18 -08'00' DLB casing jacks ASR 1 gls 7/27/20 ADL0025509 X *3000 psi BOPE test DLB 06/26/2020 ADL0355018 10-404 DSR-6/26/2020 X 7/28/2020 RBDMS HEW 7/29/2020 ESP Change-Out Well: MPU F-38 Date: 06/25/2020 Well Name:MPU F-38 API Number: 50-029-22618-00 Current Status:JP Producer [ONLINE]Pad:F-Pad Estimated Start Date:August 1st, 2020 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg.Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:195-168 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:JP to ESP Conversion Current Bottom Hole Pressure:2,529 psi @ 7,373’ TVD 3-day PBU (6/6/2020) |6.60 PPG Maximum Expected BHP:3,259 psi @ 7,373’ TVD 30-day PBU EST.8.5 PPG MPSP:2,522 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 77° @ 4,654’ MD | Greater than 70° from 3,320’ to 15,360’ MD Max Dogleg:3.5°/100ft @ 3,523’ MD BPV Profile:3” CIW Type H Brief Well Summary: MPU F-38 was originally drilled in December 1995 and completed in March 1996 as a Kuparuk River formation producer. F-38 has only had 4 ESPs installed in its 21 year life from 1996 to 2016. The ESP failure in 2016 was due to a motor failure after an 11 year run life. MPU F-38 was recompleted in 2016 to a production string that allowed for jet pump and gas lift service. For the last four years, the well has operated a higher flowing bottom- hole pressure, and consequently a lower oil production rate. To complicate matters, the power fluid requirements and limitation of the F-pad water injection system have led to less than optimal oil production. Due to these factors, a conversion to ESP artificial lift will result in lower flowing bottom-hole pressure, less hydraulic back-out, and more water available for water injection. A few ESP design changes will be implemented to allow the well to reach a target of 700 psig FBHP. Notes Regarding Wellbore Condition x The 7” production casing passed an MIT to 3,500 psig on 12/4/2016 x A 7” casing scraper was run to 17,150’ on 11/28/2016 without issue. x The reservoir pressure is expected to build close to an 8.5 ppg gradient. A successful no-flow test was completed on February 17, 2017. x Supporting Injectors: o F-30: Online, Injecting 2,000 BWPD o F-92: Online, Injecting 1,000 BWPD Objective: x Pull 3-1/2” JP Completion. o All equipment will be saved for future use. x Install new 2-7/8” Tubing with ESP Completion x Pre-rig Slickline work o Pull jet pump o Complete tubing caliper Pre-Rig Procedure: 1. RU LRS and PT lines to 3,500 psi. 2. Order heated 8.9 NaCl Brine kill fluid to location. 3. Bleed gas off of tubing and IA. @ 15159ft * Packer waived per CO 390A ESP Change-Out Well: MPU F-38 Date: 06/25/2020 4. Circulate 595 bbls of 8.9 NaCl Brine down tubing while taking take returns up IA. (Well Capacity 580 bbls) 5. Pump 60 bbls of 8.9 NaCl Brine down tubing to formation. Observe tubing and IA pressures and pump additional fluids down tubing to formation if necessary to kill well. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services. 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RD well house and flowlines. Clear and level area around well. 10. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 11. NU BOPE. RD Crane. 12. NU BOPE house. Spot mud boat. Brief RWO Procedure: 13. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 14.Rig up casing jacks to allow for higher pick up weight on initial completion pick up and packer release. 15. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/8.9 ppg NaCl Brine prior to pulling BPV. 16. Set TWC. 17. Test BOPE to 250 psi Low/ 3,000 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. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. 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. 18.Contingency: If BOPE test fails 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 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 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. BOPE test to 3000 psi NU BOPE. Casing jacks rigged up. ESP Change-Out Well: MPU F-38 Date: 06/25/2020 19. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.9 ppg NaCl Brine as needed. 20. Ensure a 3-1/2”Intrinsically Safe Mechanical pipe cutter is on location for Baker-locked threads below the packer. 21. Rig up spoolers for 1/4” gauge tech-wire and 1/4” control line. a. 16,490’ of tech-wire was installed in the completion. b. 2,008’ of control-line installed in the completion. 22. MU 3-1/2” landing joint, BOLDS and PU on the tubing hanger. a. The PU weight = 106K and SO = 34K when landed and prior to packer set by ASR#1 in 2016. b. Baker Hughes FHL packer was pinned for 30K straight pull to release. 23. Release FHL packer and allow the packer elements to relax for 30-60 minutes prior to pulling out of the hole. 24. Circulate out any gas that may be trapped below the packer. a. IA volume to the packer is 448 bbls. b. Tubing volume to lower sleeve circulation point is 132 bbls. 25. Lay down the landing joint and tubing hanger. a. Evaluate pulled tubing hanger for damage. 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. 26. POOH and lay down the 3-1/2” tubing while spooling tech-wire and capillary tubing. a. Note any corrosion, sand, scale or damage on the tubing or jewelry. Look for over-torqued connections from previous tubing runs. i. Dispose of any damaged tubulars b. Note that the 113’ of completion below the packer is suspect to have been baker-locked. A Mechanical pipe cutter may be necessary to break up the pulled completion once the packer is on surface. c. The completion has the following amount of clamps/guards/cap-string: Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Visually inspect on site then re-stock ¼” Capillary Tubing Junk ¼” Techwire Visually inspect on site and re-stock for I-pad Injectors. Halliburton TRSV Visually inspect on site and re-stock in Fire-hall Gaslift Mandrels (2)Visually inspect on site then re-stock for I-pad New-Drills XD Sliding Sleeves (2)Visually inspect on site then re-stock for I-pad New-Drills Halliburton Gauge Visually inspect on site and send to Halliburton for Refurb Baker FHL Packer Send to Baker Hughes Dead-horse to re-dress. XN Nipple Visually inspect on site then re-stock for I-pad New-Drills WLEG Visually inspect on site then re-stock for I-pad New-Drills Cross Collar clamps (550)Visually inspect on site then re-stock Mid-Joint Clamps (10)Visually inspect on site then re-stock (verify max hydraulic pressure on Casing jack prior to pulling hanger) ESP Change-Out Well: MPU F-38 Date: 06/25/2020 27. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’. a. Base of ESP centralizer @ ± 17,050’ MD b. Motor gauge c. 250 HP Baker Hughes 562SP Motor d. Gas Separator e. Baker Hughes 222stage Flex-27 ESP f. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech-wire. g. 2 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing h. 2-7/8” XN (2.205” No-Go) Nipple i. 3 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing j. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV k. ± 533 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing l. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV m. ± 4 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 28. PU and MU a new 2-7/8” tubing hanger with landing joint. Make the final splice of the ESP cable to the penetrator. Plug off any additional control line ports if present. 29. Land the tubing hanger with extreme caution and ensure centralization to avoid damaging the ESP cable. a. Note pick-up and slack-off weights on tally. b. RILDS. Lay down landing joint. 30. Set TWC. 31. RDMO ASR. Post-Rig Procedure: 32. RD mud boat. RD BOPE house. Move to next well location. 33. RU crane. ND BOPE. 34. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 35. Pull TWC. 36. RD crane. Move returns tank and rig mats to next well location. 37. Replace gauge(s) if removed. 38. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic PU and run New ESP _____________________________________________________________________________________ Revised By: BK 6-16-19 SCHEMATIC Milne Point Unit Well: MPU F-38 Last Completed: 12/5/2016 PTD: 195-168 F-38 Passed AOGCC witnessed NO FLOW TEST 03/09/2017 TD = 17,588’ (MD) / TD = 7,670’(TVD) 20” RKB: AGL = 45.46’/ GL Elev.= 12.2’/RT to Tbg. Spool = 33.26’ (N27E) 7” 4 5 6 7 8 9 10 11 9-5/8 ” 2 3 7” Casing short joints from 16,947’ to 16,967’ A Sands PBTD = 17,482’ (MD) / PBTD = 7,588’(TVD) 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm Capacity 20" Conductor 91.1 / NT-80 / N/A N/A Surface 110' N/A 9-5/8" Surface 40 / L-80 / Butt 8.679 Surface 8,561' 0.0758 7" Production 26 / L-80 / Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.992 Surface 17,090’ 0.00592 JEWELRY DETAIL No Depth Item 1 2,003’ 3.5" NE TRSV w/ 2.813 X. TC-II BXP 2 2,181’ GLM #2: 3.5" x 1” SPMO GLM (Dummy set 6-15-19 ) 3 3,701’ GLM #1: 3.5" x 1” SPMO GLM (Dummy set 6-15-19 ) 4 6,443’ 3-1/2” XD Sliding Sleeve 9Cr-1Mo closed 6-16-19 5 15,159’ 3-1/2” XD Sliding Sleeve 9Cr-1Mo (open 6-15-19) 12A JP 6 16,490’ 3-1/2” ROC gauge (TCII BxP) 7 16,979’ Baker 7" x 3 1/2" FHL Packer 8 17,005’ Auto fill Sub, 3.5" 9.2# L-80 Vam Top Box x Pin 9 17,007’ Mirage Plug, 3.5" 9.2# 9Cr-1Mo Vam Top Box x Pin 10 17,033’ 3 1/2" XN-Nipple (2.813 w/ 2.75" No-Go) 11 17,087’ 3-1/2” WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 17,199’ 17,243’ 7,373' 7,406' 44' 2/24/1996 Open 17,250’ 17,290’ 7,411’ 7,441’ 40' 11/16/2004 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks in 30” Hole – TOC @ Surface 9-5/8" Cmt w/ 1,880 sks in 12-1/4” Hole - TOC @ Surface 7” Cmt w/ 217 sks in 8-1/2” Hole – TOC calculated @ 15,247’ WELL INCLINATION DETAIL KOP @ 550’ Max Hole Angle = 74 to 78 deg. f/ 4,300’ to 15,100’ Hole Angle through perforations = 42 deg. WELL STIMULATION DETAIL 3/1/96 – 42.85 M lbs. 16/20 Carbolite prop. Screened out w/ 8ppg on perfs 3/12/96 – 115 M lbs. 16/20 Carbolite prop. Job went to flush TREE & WELLHEAD Tree 3-1/8” – 5M Cameron Wellhead 11” 5M FMC Gen. 5a w/ 3-1/2” FMC Tbg. Hng. 4” LH Acme top x 3-1/2” EUE 8rd bottom, 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E - 12/4/1995 Completed with ESP by Nabors 4ES – 3/22/1995 ESP RWO Nabors 4ES – 10/20/1999 ESP RWO Nabors 4ES – 11/18/2004 ESP RWO Nabors 4ES – 6/4/2005 ASR – Convert to Jet Pump/Gas Lift – 12/5/2016 Jet pump _____________________________________________________________________________________ Revised By: DH 6-18-20 PROPOSED Milne Point Unit Well: MPU F-38 Last Completed: 12/5/2016 PTD: 195-168 TD =17,588’ (MD) / TD = 7,670’(TVD) 20” RKB: AGL =45.46’/ GL Elev.= 12.2’/RT to Tbg. Spool = 33.26’ (N27E) 7” 4 5 6 7 8 9 9-5/8” 2 3 7” Casing short joints from 16,947’ to 16,967’ A Sands PBTD = 17,482’ (MD) / PBTD = 7,588’(TVD) 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm Capacity 20" Conductor 91.1 / NT-80 / N/A N/A Surface 110' N/A 9-5/8" Surface 40 / L-80 / Butt 8.679 Surface 8,561' 0.0758 7" Production 26 / L-80 / Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface ±17,050’ 0.0058 JEWELRY DETAIL No Depth Item 1 ±2,00’ STA #2: 2-7/8" x 1” Side pocket GLM with 0.25” OV 2 ±16,831’ STA #1: 2-7/8" x 1” GLM with Dummy GLV 3 ±16,931’ 2-7/8” XN Nipple, 2.205” No-Go 4 ±16,995’ Discharge Gauge 5 ±16,995’ Baker 222 stage Flex-27ESP 6 ±17,013’ Gas Separator 7 ±17,030’ Baker 250 HP 562SP Motor 8 ±17,047’ Motor Gauge 9 ±17,050’ Centralizer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 17,199’ 17,243’ 7,373' 7,406' 44' 2/24/1996 Open 17,250’ 17,290’ 7,411’ 7,441’ 40' 11/16/2004 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks in 30” Hole – TOC @ Surface 9-5/8" Cmt w/ 1,880 sks in 12-1/4” Hole - TOC @ Surface 7” Cmt w/ 217 sks in 8-1/2” Hole – TOC calculated @ 15,247’ WELL INCLINATION DETAIL KOP @ 550’ Max Hole Angle = 74 to 78 deg. f/ 4,300’ to 15,100’ Hole Angle through perforations = 42 deg. WELL STIMULATION DETAIL 3/1/96 – 42.85 M lbs. 16/20 Carbolite prop. Screened out w/ 8ppg on perfs 3/12/96 – 115 M lbs. 16/20 Carbolite prop. Job went to flush TREE & WELLHEAD Tree 3-1/8” – 5M Cameron Wellhead 11” 5M FMC Gen. 5a w/ 3-1/2” FMC Tbg. Hng. 4” LH Acme top x 3-1/2” EUE 8rd bottom, 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E - 12/4/1995 Completed with ESP by Nabors 4ES – 3/22/1995 ESP RWO Nabors 4ES – 10/20/1999 ESP RWO Nabors 4ES – 11/18/2004 ESP RWO Nabors 4ES – 6/4/2005 ASR – Convert to Jet Pump/Gas Lift – 12/5/2016 Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: June 25, 2020Subject: Changes to Approved Sundry Procedure for Well F-38Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUL 16 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Ll Pull Tubing Li Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to JP 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 195-168 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22614-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0355016 MILNE PT UNIT KR F-38 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 17,588 feet Plugs measured N/A feet true vertical 7,670 feet Junk measured N/A feet Effective Depth measured 17,482 feet Packer measured 16,979 feet true vertical 7,588 feet true vertical 7,210 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 110' N/A N/A Surface 8,525' 9-5/8" 8,561 4,475' 5,750psi 3,090psi Production 17,535' 7" 17,568' 7,655' 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) 3-1/2" 9.3 / L-80 / EUE 8rd 17,090' 7,292' Packers and SSSV (type, measured and true vertical depth) Baker 7" x 3-1/2" FHL 3.5 NE TRSV 16,979' / 7,210' 2,003' /1,969- 1,969'12. 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: 1 97 1,544 256 1,089 390 Subsequent to operation: 1 79 1,131 235 3,296 436 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations ❑Q Exploratory[] Development 0 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email:dhaakinson(cbhilcom.com Authorized Signature: '� I�oa.C(pos— Dat, 7/11/2019 Contact Phone: 777-8343 V. V /,# ` �lln BDMS1LWJUL 1 82019 Form 10-404 Revised 4/2017 Submit Original Only n Flile AI. Lk LLC RIB: AGL=45.48/ GL Bev. 12.2'/Rf toThg. 9-5/8" 7' CWrigshon )ants from 16,947 to 16,%7' IN �ASands TD= 17,50 (ND) /TD =7,670'(M) PBTD=17,482' (ND) / PB1D=7,510MM) SCHEMATIC Milne Point Unit Well: MPU F-38 Last Completed: 12/5/2016 PTD: 195-168 TREE & WELLHEAD Tree 5M Cameron Wellhead 11" SM FMC Gen. Sa w/ 3-1/2" FMC Tbg. Hng. 4" LH Acme top x 3-1/2" EUE 8rd bottom, 3" CI W H BPV Profile OPEN HOLE/ CEMENT DETAIL 20" Cmtw/260sksin 30"Hole—TOC@Surface 9-5/8" _ Cmtw/1,880sksin l2-1/4"Hole-TOC @Surface 7" 1 Cmt w/ 217 sks in 8-1/2" Hole—TOC calculated @ 15.247' CASING DETAIL Size Type Wt/Gmde/Conn Drift ID Top Btm Capacity 20" Conductor 91.1 / NT -80 / N/A N/A Surface 110' N/A 9 -5/8" Surface 40/L-80/Butt 8.679 Surface 8,561' 0.0758 7" Production 26 / L-80 / Butt 6.151 Surface 17,568' 0.03833 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 /EUE 8rd 2.992 Surtace 17,090' 0.00592 WELL INCLINATION DETAIL KEEL Hole Angle = 74 to 78 deg. f/ 4,300' to 15,100' Hole Angle through perforations= 42 deg. JEWELRY DETAIL No Depth Item 1 2,003' 3.5" NE TRSV w/ 2.813 X. TC -II BXP 2 2,181' GLM#2: 3.5"xl"SPMOGLM(Dummyset6-15-19) 3 3,701' GLM #1: 3.5" x 3" SPM. GLM (Dummy set 6-15-19) 4 6,443' 3-1/2" XD Sliding Sleeve 9Cr-lMo closed 6-1619 5 15,159' 3-1/2" XD Sliding Sleeve 9Cr-1Mo(opee 6-15-19)121 JP 6 16,490' 3-1/2" ROC gauge (TCII BxP) 7 16,979' Baker 7" x 3 1/2" FHL Packer 8 17,005' Auto fill Sub,3.5"9.2#L-80 Vam Top Box x Pin 9 17,007' Mirage Plug, 3.5" 9.2# 9Cr-1Mo Vam Top Box z Pin 10 17,033' 1 31/2"XN-Nipple(2.813w/2.75"No-Go) 11 17,087' 1 3-1/2" WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm(TVD) FT Date StaW5 Kup. ASands 17,199' 17,243' 7,373' 7,406' 44' 2/24/1996 Open 17,250' 1 17,290' 1 7,411' 1 7,441' 1 40' 1 11/16/2004 Open WELL STIMULATION DETAIL 3/1/96 —42.85 M lbs. 16/20 Carbolite prop. Screened out w/ Sppg on perfs 3/12/96 —115 M lbs. 16/20 Carbolite prop. Job went to flush GENERAL WELL INFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E -12/4/1995 Completed with ESP by Nabors 4ES-3/22/1995 ESP RWO Nabors 4ES —10/20/1999 ESP RWO Nabors 4ES-11/18/2004 ESP RWO Nabors 4ES-6/4/2005 ASR — Convert to Jet Pump/Gas Lift -12/5/2016 F-38 Passed AOGCC witnessed NO FLOW TEST 03/09/2017 Revised By: SK 616-19 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP Fn Slick Line 51-029-22614-00-00 195-168 6/14/2019 6/16/2019 Daily Operations. s. 6/12/2019- Wednesday No operations to report. 6/13/2019 -Thursday No operations to report. 6/14/2019 - Friday WELL S/I UPON ARRIVAL, NOTIFY PAD -OP, PT PCE W/ LRS 250L/3500H (good). ATTEMPT TO EQUALIZE GL -SLEEVE IN XD -SS @ 6443' MD, S/D ON ICE BRIDGE @ 67' SUM, TOOLS COVERED IN HYDRATES. HAVE LRS PUMP PUMP 10bbls OF NEET FOLLOWED BY 35bbls DIESEL OWN TBG. EQUALIZE GL -SLEEVE IN XD -SS @ 6443' MD, SEE PRESSURE CHANGE. PULL GL - SLEEVE FROM XD -SS @ 6441' SLM/ 6443' MD. SHIFT XD -SSD W/ 3-1/2"" 42 -BO @ 6443' MD CLOSED. WELL S/I UPON 6/15/2019 -Saturday WELL 5/1 UPON ARRIVAL, PT PCE 25oL/32500H (good). SET XX -PLUG BODY (catcher, no packing) IN XD -SS AT 6443' MD. PULLED BK-LGLV FROM STA#1 AT 3701' MD_SET BK-DGLV IN STA#1 AT 3701' MD. PULLED BK-LGLV FROM STA#2 AT 2181' MD—SET BK-DGLV IN STA#1 AT 2181' MD. PULL CATCHER IN XD -SS AT 6443' MD, EMPTY. BEGIN IA DRAW DOWN TEST, STARTING PRESSURES TBG:1100# IA:1100. DRAW DOWN TEST PASS, BLEED 500# OFF IA AND MONITORED FOR 30 min, TBG HELD @ 1100#. SHIFT XD -SSD W/ 3-1/2""42-130 @ 6443' MD, OPEN. SHIFT XD -SSD W/ 3-1/2"" 42 -BO @ 15159' MD, OPEN. LRS PUMPED 151bbls OF PRODUCED WATER TO ASSIST IN OPENING LOWER SLEEVE. FREEZE PROTECT TBG WITH 40bbls OF DIESEL. WELL S/I UPON DEPARTURE. 6/16/2019 -Sunday WELL S/I UPON ARRIVAL, NOTIFY PAD -OP, PT PCE W/ LRS 250L/2,500H (good). SHIFT XD -SSD W/ 3-1/2" 42 -BO @ 6,443' MD CLOSED. SET 3" JET PUMP (SER #: HC -0009, RATIO 12A, SCREEN, OAL=70"") TO LOWER XD SSD @ 15,169'SUM / 15,159' MD, GOOD SET. LRS PUMPED bbls OF PRODUCED WATER TO ASSIST IN SETTING JET PUMP. WELL S/I UPON DEPARTURE. 6/17/2019 - Monday No operations to report. 6/18/2019 -Tuesday No operations to report. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 19 2019 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate L1 Pull Tub: i n Li Performed: Suspend ❑ Perforate ❑ Other Stimulate I—I Alter Casing L) Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ,_ ..a -enter Susp Well ❑ Other: Convert to GL ❑� 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: t+ o Name: Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 195-168 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22614-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0355016 MILNE PT UNIT KR F-38 ` 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 'f J S -r j N/A MILNE POINT/ KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 17,588 feet Plugs measured N/A feel true vertical 7,670 feet Junk measured N/A feet Effective Depth measured 17,482 feet Packer measured 16,979 feet true vertical 7,588 feet true vertical 7,210 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 110' N/A N/A Surface 8,525' 9-5/8" 8,561' 4,475' 5,750psi 3,090psi Production 17,535' T' 17,568' 7,655' 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) 3-1/2" 9.3 / L-80 / EUE 8rd 17,090' 7,292' Packers and SSSV (type, measured and true vertical depth) Baker 7" x 3-1/2" FHL 3.5 NE TRSV 16,979' / 7,210' 2,003' / 1,969' 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: 152 44 4,625 3,415 232 Subsequent to operation: I55 527 1,546 1,305 219 14. Attachments (required per 20 MC 25.070, 25.071, &25,283) 15. Well Class after work: Daily Report of Well Operations El Exploratory El Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil E Gas Li WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact EmailAhaakinsonAhilcoro.com Authorized Signature: Dad 4/18/2019 Contact Phone: 777-8343 11G 1(•j,�496MSL6"APR 2 2 2019 Form 10-404 Revised 4/2017 o Submit Original Only Tom Fouts From: David Haakinson Sent: Tuesday, April 16, 2019 10:33 AM To: guy.schwartz@alaska.gov' Cc: Tom Fouts Subject: MPU F-38 (PTD: 195-168) Artificial Lift Conversion Guy, We are planning to convert producer MPU F-38 from gas lift to surface power fluid jet pump service. In my research, found that the well was converted to gas lift service in August 2017 without follow-up correspondence of a 10-404 indicating the change. It appears that our last documented correspondence for producer MPU F-38 was that the well was approved for jet -pump lift in January 2017. The well was converted to gas lift in August 2017 due to water handling constraints. We are seeking to convert this well back to jet pump for a —100 801313 rate add. I am self -reporting this error in good faith and would like clarification of what may be needed prior to carrying out future work. Prior to converting back to jet -pump, can you please confirm as to whether you would like us to submit another 10-404? Point forward: This will require two days of slick -line work to dummy off the gas lift mandrels, shift open a sleeve, and set the jet -pump. There will be no other downhole mechanical work required. A MIT -IA to 3,500 psig was completed on 12/4/16 at the time the well was original put on jet pump lift Please reach out if you have any further questions, and I can stop by today to discuss further if necessary. David Haakinson Operations Engineer I North Slope Asset Team Hilcorp Alaska, LLC Office: (907) 777-8343 ( Cell: (307) 660-4999 dhaakin sonahi Ick. com K .o Alaska. LLC RKB: AGL=45.46/ GL Bev. 12.2 /RTto Tbg. TD=17,588' (MD)/TD=7,67(Y(M) PBTD=17,482' (MD) / PBTD = 7,5WaVD) SCHEMATIC Milne Point Unit Well: MPU F-38 Last Completed: 12/5/2016 PTD: 195-168 TREE & WELLHEAD Tree 3-1/8"—SM Cameron Wellhead 11" 5M FMC Gen. 5a w/3-1/2" FMC Tag. Hng. 4" LH Acme 7" top x 3-1/2" EUE 8rd bottom, 3" CIW H BPV Profile OPEN HOLE / CEMENT DETAIL 20" Cmtw/260 sks in 30" Hole —TOC @Surface 9-5/8" Cmt w/1,880 sks in 12-1/4" Hole - TOC @Surface 7" Cmt w/ 217 sks in 8-1/2" Hole—TOC calculated @ 15,247' CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Capacity 20" Conductor 91.1/NT-80/N/A N/A Surface 110' N/A 9-5/8" Surface 40/L-80/Butt 8.679 Surface 8,561' U758 T. Production 26/L-80/Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL 3-1/2" Tubing I 9.3/L-80/EUE8rc1 1 2.992 1 Surface 17,090' 0.00592 WELL INCLINATION DETAIL KOP a 550 Max Hole Angle = 74 to 78 deg. f/ 4,300' to 15,100' Hole Angle through perforations =42 deg. JEWELRY DETAIL No Depth Item 1 2,003' 3.5" NE TRSV w/2.813 X. TC -II BXP 2 2,181' GLM#2:3.5"xI"SPMO GLM (BK3/161 TRO 1124 psi) 3 3,701' GLM #1: 3.5" x 1" SPMO GLM (BK 3/16 ITRO 1106 psi) 4 6,443' 3-1/2" XD Sliding Sleeve 9Cr-11v10(GL Sleeve -OV) 5 15,159' 3-1/2" XD Sliding Sleeve 9Cr-1Mo(Closed) 6 16,490' 3-1/2" ROC gauge (TCI I BXP) 7 16,979' Baker 7" x 3 1/2" FHL Packer 8 17,005' Auto fill Sub, 3.5" 9.2# L-80 Vam Top Box x Pin 9 17,007' Mirage Plug, 3.5" 9.2# 9Cr-IMo Vam Top Box x Pin 10 17,033' 1 3 1/2" XN-Nipple (2.813 w/ 2.75" No -Go) 11 17,087' 1 3-1/2" WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 17,199' 17,243' 1 7,373' 7,406' 1 44' 2/24/1996 Open Kup. A Sands 17,250' 17,290' 1 7,411' 7,441' 1 40' 11/16/2004 Open WELL STIMULATION DETAIL 3/1/96-42.85 M lbs. 16/20 Carbolite prop. Screened out w/ 8ppg on perfs 3/12/96-115 M Ibs. 16/20 Carbolite prop. Job went toflush GENERALWELLINFO API: 50-029-22614-00-00 Drilled and Cased by Nabors 27E -12/4/1995 Completed with ESP by Nabors 4ES-3/22/1995 ESP RWO Nabors 4ES-10/20/1999 ESP RWO Nabors 4ES — 11/18/2004 ESP RWO Nabors 4ES — 6/4/2005 ASR — Convert to Jet Pump/Gas Lift —12/5/2016 F-38 Passed AOGCC witnessed NO FLOW TEST 03/09/2017 Revised By: DH 4-10-19 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 ASR#1 50-029-22614-00-00 195-168 8/23/17 8/31/19 Daily Operations: 8/23/2017- Wednesday WELL 5/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. ATTEMPT TO PULL JET FROM XD SLIDING SLEEVE AT 6,443' MD (unable to pass 6,200' SLM). L/D FOR THE NIGHT, NOTIFY PAD -OP. 8/24/2017 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. PULL 3" JET PUMP (serial #BP -1063, ratio: 13A) FROM XD -SS AT 6,443' MD. SET XX -PLUG BODY (catcher, no packing) IN XD -SS AT 6,443' MD. PULLED BK-DGLV's FROM STA#1 AT 3,701' MD AND STA#2 AT 2,181' MD. SET BK-LGLV (12/64 ports, TRO 1,124psi) IN STA#2 AT 2,181' MD. RDMO, NOTIFY PAD -OP. 8/25/2017 - Friday No activity to report. 8/26/2017 -Saturday No activity to report. 8/27/2017 -Sunday No activity to report. 8/28/2017 - Monday No activity to report. ray j e Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 ASR#1 50-029-22614-00-00 195-168 8/23/17 8/31/19 Daily Operations' 8/30/2017- Wednesday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. SET BK-LGLV (12/64 ports, TRO 1106psi) IN STA#1 PULL CATCHER FROM XD -SS AT 6,443' MD (empty). SET 3-1/2" GL -SLEEVE (OAL=54" w/lock open, EQ devise w/8x1/8" ports) IN XD -SS AT 6,443' MD. 8/31/2017 - Thursday WELL 5/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. PULL TOOLSTRING WITH GL SLEEVE ATTACHED FROM 6,400' SLIM. SET 3-1/2" GL -SLEEVE (OAL=54" w/lock open, EQ devise w/8x1/8" ports) IN XD -SS AT 6,443' MD. RDMO, TAG WELL & NOTIFY PAD -OP. 9/1/2017 - Friday No activity to report. 9/2/2017 -Saturday No activity to report. 9/3/2017 -Sunday No activity to report. 9/4/2017 - Monday No activity to report. S vOFTb ywI vj, THE STATE Alaska Oil and Gas OfA Ac A Conservation Commission C333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov March 14, 2017 Mr. John Barnes Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow 3 g Verification SCANNED A PR 0 7MPU F PTD 1951680 Dear Mr. Barnes: On February 17, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Milne Point Unit F-38. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate the well. Tubing, inner annulus,and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing, the flow meter recorded an initial gas flow rate of 100 SCF per hour which fell to an indiscernible gas flow rate within one minute. Well pressures bled to zero in less than 9 minutes. There was no liquid flow to surface during the test. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Milne Point Unit F-38 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, James B. Regg r / Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 314/ DATE: 3/09/17 P. I. Supervisor FROM: Guy Cook/Adam Earl SUBJECT: No Flow Test Petroleum Inspector MPU F-38 - Hilcorp Alaska PTD 1951680 -- 3/09/17: 3/09/17: No Flow Test due to using power fluid and a jet pump instead of gas lift. The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 13:20 0/0/2 • N/A N/A Shut in. 14:20 1/1/2.5 - N/A N/A Record well pressures 15:20 r 2/2/2 - N/A N/A Record well pressures 16:20 2.5/2.5/2 ' 100 0 - Record well pressures and open to bleed. 1 Pressures are T/IA/OA Summary: After a three-hour build-up the tubing and IA, the well was opened to bleed and bled to zero in eight and a half minutes. The flow meter registered 100 SCEs upon -. opening the well to bleed, but immediately fell to zero. `No fluids were produced during the bleeding process. I believe this well exhibits an inability to flow to surface - unassisted. Attachments: Photos (3) SCANNED APR 201z Well Schematic Test Gauge Calibration Certificates 2017-0309_No-Flow_MPU_F-3 8_gc.docx Page 1 of 3 • • 1 t t o , t ;:: ; ; r I f . , r �' � I a ';',1 4‘ 4l(J ' Y ' • f f , t , / • / 7II " I / LLL II k r 'tea t " I • f � � I rn • I g fs f nt': I Ili,/ M iji * •' , 2. 1 I a o f ! O g 0 Z a- , 00r. co , i'[.7 . , , 0 r a o c _.... . . • . ,.. , co— o E MI5 a � h V a z . • M 0) Q W k "-to (4 LL Q �....r� fit_, C :4 ' W -..e 4 , I, , • 1, u0 -- , H Q :s anti , t . O Oo a1 ! 1 i LL O N 1 • { I t Ott ......,1„.....,-.+ t Z CL CO 0 • ilt . . , \1. H r _� 9 4 0 tij$ § \/ � a\ \ \ § qa ' c0 \ 2 Ir e 4 c ©- ~ ° ° cc (1) o / Af � t , �25 ® E � � w ) ° 2222 \ 1 z 10 0@ \�9 ( g) � A �-� \ ;,..- 0a0 �) ' 2 . u�U- & `tea �= \ k/\� / §0S «( / w2q ■ j \ �_ L,§ .. . ...- . . a , '*46 4W \ ,.. . / w <: < » N. « \« \ } \ ± ^ « \ » . 0 0 t Q ,, -----) Co 1\0 . .„ ,.....1... _ ._. .. c 09 — m 00 c 0,1 CO 0 m tos a a) z .0 a) 0 T S141111 'F.. 06' OC 0 4-Ii13 .2 "5 LD ,"- ,,,„, To •... 64 NI 0 to 0 .-- -- 44. CD I— , a < o Li o A i r 2 3 0 0 0 0 49 c cn ce 0 w (NI '0 0 t-.. • pt Pt,k 0 ----,--------,,-- . Alaska Metrology and Calibration Services, inc. , - ,,,,,, .. i - ,,,,,.......,.... 224 East 54th Avenue i , . (907)929,-9361 ) Certificate No: IVILAB170760 Certificate of Calibration ...._ .._,.._ - For Instrument; Ashcroft 4-5207z1SDO4L5000# Cal Dile: 06 March 2018 Description: Digital Pressure Gauge Asset Number: M1>(12915 Serial Number: 1082915 ("CUSTOMER INFORMATION _ I. s HI LCORP ALASKA LLC Customer Account Number:HIL001 3800 Centerpoild Dr. Anchorage,AK 99503 Customer Purchase Order:MR17Q0206161 Customer Shop Location:MILNE.PT WELLS SUPPORT I...._.--- _ CA LIBRA I ION IN FORMATION ., alibunaoa Li di Nticel!06,.',.n1-; Calibration Laboratory:MLAR - Calibration Procedme:A tit.S-CAL Hydraulic Gauge Verification: Temperature: 19.00'C Humidity:5%RI Specifications I Ltd:Maim i itei OM SpeciticOtiOn: As-Folio('Condition: As-Left Condition: i Calibrotion Measurement Results: la Tolerance Calibration Measurement Results: In Tolerance : ''- -- ' --- --- -- ------- — .-----. - Certification: his certificate is issued as a statement of the tact that the Instrument described above,met or exceeded the Specifications Used(listed above)at the time of Calibration. [lie calibration activities described by this document were performed in compliance with ISO/1EC 17025:2005(E)and ANSUNCSL1540-1. 'Ibe calibration results recorded herein arc applicable only to the instrument identified above. No statement or opinion regarding the applicability to any other instrument is expressed or implied. „This report shall not be reproduced without the written permission of Alaska Metrology&Calibration Services,Inc. Standards Used for Calibration: Alaska Metrology&Calibration Services maintains calibration programs for all equipment used lbr calibrations that have a significant effect on the accuracy andlor validity of measurements. Traceability of'Measurements: 1 he calibration tests described by this certificate were conducted using Standards whose accuracies were calibrated by laboratories that can demonstrate traceability to the National Institute of Standards and'technology(N1S'n and to the International System of Units(SI). 'Uncertainty of Standard Applied/Reading: As per MST Tiwholool Now 1297,OuidelinesPr f;valllating aha!Elypressing the Uncertainty of NIST Afewcurement Rea/t .the total expanded uncertainty(U)of the Standard Applied/Reading is the product of the Root-Sum-Squared value of the individual uncertainties of the Standards Used for Calibration(tic)and a coverage factor(k). Using k=2 provides a 95%level of confidence:. As per Alaska Metrology&Calibration Services policy, the ratio of the expanded uncertainty(U)a!'all Standard Applied/Readings to the Specifications the Customer's equipment is calibrated is greater than or equal to 4:1 (unless otherwise noted on the Certificate of Calibration). IST.41NDARDS USED FOR CALIBRATION ID Number M fg Model Description Cal Due Date AMCS62S5 Cie Sensing 2456-LEM Laboratory Environment Monitor 6/912017 AMCS5410 Ritska 2465-799 Mass Set 6/18/2017 AMCS.1383 ' Rusks 2485-983 Piston,Hydraulic 11)1812017 Page I of 2 • • Fra Alaska Metrology and CalibrationServices Inc -,5 ;A 224 k a=t 54th Avenue Anchorage',AK 99518 (907)929-8052FAX:(9017)929-9361 Certificate No: I LAB 70 762 I Certificate of llibratio to t?or Instrument: Ashero1C 4520741SD04L5000# a l i�ut:: 06 March 2018 Description: Digital Pressure Gauge ._,_._. ._..._�...�_ . Asset Number: MI'U80018 Serial Number: 61080018 • (.`La`aTOt1<l la I2 INFORM A 3 ION r .. ri HILCORI'ALASKA LI X.` Custoaner Account Number:i-ill;0111 350€I Centorpoint Dr. Anchorage,AK 09503 Customer l'urclaseOrder:MRbQI}?01,161 Customer Shop Location:MILNE PT WELLS SUPPORT 4;'rtL IItIZ:•1'PIC)N INFORMATION ___. ;alihrsata,a3l,zate.yl,€,1i 01 Calibration Laboratory: MLA ''Calibration Procedure:AN/ICS-CAI.Ilydr tilic Gauge Verification: Temperature: 19.00'C Humidity:5%RI I Specifications Used:Manufacturer Specifications Foumm<t Condition As-I,eft Condition: Calibration Measauanion fftesntts: In Tolerative Calibration hIeastn,cnaoot Results: In Tolerance Certification: .�.��.,_ .�..��.. ...�.��._..�....� . . �.., ,�.� .....� .�. � This certificate is issued as a statement of the fact that the Instrument closet ibed above,met or esceeded the Specilic£ttiuo Used(listed above)at the time orCalihrntion. The calibration activities described by this document were performed in compliance with ISO/iEC 17025:2005(E)and AN517NCSL 2540-1. The calibration results rticorded herein are applicable only to the instrument identified above. No statement or opinion regarding the applicability to any other instrument is expressed or implied, tt his report shall not be reproduced without the written permission of Alaska.Metrology&Calibration Services-Inc. standards Used for Calibration: Alaska Metrology°& Calibration Services maintains calibration programs ror all equipment used for calibrations that have a significant effect on the • ;accuracy and/or validity of measurements. Traceability of Measurements: The calibration tests described by this certificate were conducted using Standards whose accuracies were calibrated by laboratories that can demonstrate traceability to the National Institute of Standards and Technology(NISI)and to the International System of CUts(Si). tIncertstiuty of Standard Applied/Reading: As per tv=FSI fee/lnicul Note 1291,Guide/limesline8 for Evriiuoiing and apressingthe Uncertainty ,lNIST Measurement Results,the total expanded uacemluinty(1-11 of die Standard Applied/Reading is the product oftlte Root-Suits-Squared value of die individual uncertainties ol'the Standards Used for Calibration(tic)and a coverage t<twior(ic). Using k=2 provides a 95%level of confidence. As per Alaska Metrology&Calibration Services policy, the ratio of the expanded uncertainty(U)of;all Standard Applied/Readings to the Specifications the Customer's equipment is calibrated is greater than or equai to 4: (unless otherwise noted on the Certiiicate of Calibration). [e.TANI)AI21)S USED FOR CALIBRATION ��r�.-+sxtx� _m°� t "'cs 'x+ um�wry a, _... ce+:uncy... .—.•s., „r.`,�`.."",.,pt ,;: �m€rzv,� ID Number Mfg Model Description Cal Due Date AMCS62S3 Go Seniors 2456-LEM Laboratory Environment.Monitor 6/9/2017 AMCS54t t1 Ituskaa 2465-799 Mass Set 6/18/2017 AMCSJ3833 Ituska 2485-983 Piston,I lydriulic 10/4/2017 Page 1 of 2 Milne PointPUF FU3n111 8 Well: M SCHEMATIC Last Completed: 12/5/2016 1Iilciarp Alaska,LLC PTD: 195-168 RKB:AGL=45.46'!GLEIev.=12.2'/RT to Tbg. TREE&WELLHEAD Spool=33.26'(N27E) Tree 3-1/8"—5M Cameron A Wellhead 11"SM FMC Gen.Saw/3-1/2"FMC Tbg.Hng.4"LH Acme top x 3-1/2"EUE 8rd bottom,3"CIW H BPV Profile 20 OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sks in 30"Hole—TOC @ Surface k 9-5/8" Cmt w/1,880 sks in 12-1/4"Hole-TOC @ Surface 1 7" Cmt w/217 sks in 8-1/2"Hole—TOC calculated @ 15,247 ffi a CASING DETAIL 21 A Size Type Wt/Grade/Conn Drift ID Top Btm Capacity 20" Conductor 91.1/NT-80/N/A N/A Surface 110' N/A 9-5/8" Surface 40/L-80/Butt 8.679 Surface 8,561' 0.0758 s 7" Production 26/L-80/Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL Xi 0 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 Surface 17,090' 0.00592 WELL INCLINATION DETAIL +o, i 3 ', KOP @ 550' 1 Max Hole Angle=74 to 78 deg.f/4,300'to 15,100' Hole Angle through perforations=42 deg. l JEWELRY DETAIL I 9-5/8" No Depth Item 1 2,003' 3.5"NE TRSV w/2.813 X. TC-Il BXP 2 2,181' GLM#2: 3.5"SOV Drift 2.867 3 3,701' GLM#1: 3.5"SOV Drift 2.867 ••• 4 Sands 4 6,443' 3-1/2"XD Sliding Sleeve 9Cr-1Mo 3"JP,ratio:13A 5 15,159' 3-1/2"XD Sliding Sleeve 9Cr-1Mo 6 16,490' 3-1/2"ROC gauge(TCII BxP) 7 16,979' Baker 7"x 3 1/2"FHL Packer 8 17,005' Auto fill Sub,3.5"9.2#L-80 Vam Top Box x Pin 9 17,007' Mirage Plug,3.5"9.2#9Cr-1Mo Vam Top Box x Pin 10 17,033' 3 1/2"XN-Nipple(2.813 w/2.75"No-Go) 11 17,087' 3-1/2"WLEG PERFORATION DETAIL Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 17,199' 17,243' 7,373' 7,406' 44' 2/24/1996 Open Kup.A Sands 17,250' 17,290' 7,411' 7,441' 40' 11/16/2004 Open p7 ••• 5 €t WELL STIMULATION DETAIL 3/1/96—42.85 M lbs.16/20 Carbolite prop. Screened out w/8ppg on perfs i':" 3/12/96—115 M lbs.16/20 Carbolite prop. Job went to flush GENERAL WELL INFO 6 itk API:50-029-22614-00-00 °te, d Na4/ Completed with ESPby by Nabo4ES 12/-3/2199595 2/19 7"Casing shortjoints ESPDrilled RWOanNabors Cased 4ES—10/20bors /27Ers1999- from 16,947 to ,, ESP RWO Nabors 4ES—11/18/2004 16,967 rr� ESP RWO Nabors 4ES—6/4/2005 f ASR—Convert to Jet Pump/Gas Lift—12/5/2016 4 A � • 7 �� 89 9 it 40 10 44 11 !: 4 r.-A Sands rs ` TD=17,588'(MD)/TD=7,670'(TVD) PBTD=17,482'(MD)/PBTD=7,588'(TVD) Revised By:PC 1/12/2017 STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COMFSION JAN 12 2017 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf PlugPerforations AOGCC L) L) Fracture Stimulate L) Pull Tubing Lf Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑J Re-enter Susp Well❑ Other: Convert to Jet Pump❑� 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: (Hilcorp Alaska LLC Development EExploratory 1=1195-168 kr` ES�� 3.Address: Stratigraphic 111 Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22614-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355016 MILNE PT UNIT KR F-38 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 17,588 feet Plugs measured N/A feet true vertical 7,670 feet Junk measured N/A feet Effective Depth measured 17,482 feet Packer measured 16,979 feet true vertical 7,588 feet true vertical 7,210 feet Casing Length Size MD ND Burst Collapse Conductor 80' 20" 110' 110' N/A N/A Surface 8,525' 9-5/8" 8,561' 4,475' 5,750psi 3,090psi Production 17,535' 7" 17,568' 7,655' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic SCANNED A�,,i Y, )2 r ", f� G True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3/L-80/EUE 8rd 17,090' 7,292' Packers and SSSV(type,measured and true vertical depth) Baker 7"x 3-1/2"FHL 3.5 NE TRSV 16,979'/7,210' 2,003'/1,969' 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 1,200 0 Subsequent to operation: N/A N/A N/A N/A 211 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-580 Contact Paul Chan Email pchan@hilcorp.com Printed Name il°414\-44Bo York Title Operations Manager SignaturesdA--"E •------.j.__ Phone 777-8345 Date 1/12/2017 - e)4.) a- 7-i7 AP ,24/;:7 Form 10-404 Revised 5/2015 RBDMSSubmit Original Only JAN 2 5 2017 9 • 0 • Milne Point Unit Well: MPU F-38 SCHEMATIC Last Completed: 12/5/2016 PTD: 195-168 lli!carp Alaska,LLC RKB:AGL=45.46/GLElev.=12.2'/RT to Tbg. TREE&WELLHEAD Spool=33.26'N27E) Tree 3-1/8"-5M Cameron 11"5M FMC Gen.5a w/3-1/2"FMC Tbg.Hng.3-1/2"EUE 20"J ,.. I 8rd top and Bottom,3"CIW H BPV Profile Wellhead OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sks in 30"Hole-TOC @ Surface 9-5/8" Cmt w/1,880 sks in 12-1/4"Hole-TOC @ Surface I. 1 7" Cmt w/217 sks in 8-1/2"Hole-TOC calculated @ 15,247' CASING DETAIL ,; 2 Size Type Wt/Grade/Conn Drift ID Top Btm Capacity ,f+ 20" Conductor 91.1/NT-80/N/A N/A Surface 110' N/A 7 9-5/8" Surface 40/L-80/Butt 8.679 Surface 8,561' 0.0758 7" Production 26/L-80/Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL ' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 Surface 17,090' 0.00592 WELL INCLINATION DETAIL , 3 KOP @ 550' ' Max Hole Angle=74 to 78 deg.f/4,300'to 15,100' i Hole Angle through perforations=42 deg. JEWELRY DETAIL 9-5/8" 1 a No Depth Item 1 2,003' 3.5"NE TRSV w/2.813 X. TC-Il BXP 2 2,181' GLM#2: 3.5"SOV Drift 2.867 3 3,701' GLM#1: 3.5"SOV Drift 2.867 .E's' 4 4 6,443' 3-1/2"XD Sliding Sleeve 9Cr-1Mo 5 15,159' 3-1/2"XD Sliding Sleeve 9Cr-lMo 6 16,490' 3-1/2"ROC gauge(TCII BxP) 7 16,979' Baker 7"x 3 1/2"FHL Packer 8 17,005' Auto fill Sub,3.5"9.2#L-80 Vam Top Box x Pin 9 17,007' Mirage Plug,3.5"9.2#9Cr-lMo Vam Top Box x Pin 10 17,033' 3 1/2"XN-Nipple(2.813 w/2.75"No-Go) 11 17,087' 3-1/2"WLEG PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A Sands 17,199' 17,243' 7,373' 7,406' 44' 2/24/1996 Open • 17,250' 17,290' 7,411' 7,441' 40' 11/16/2004 Open 0 s WELL STIMULATION DETAIL 3/1/96-42.85 M lbs.16/20 Carbolite prop. Screened out w/8ppg on perfs 3/12/96-115 M lbs.16/20 Carbolite prop. Job went to flush GENERAL WELL INFO 6 API:50-029-22614-00-00 dw Drilled and Cased by Nabors 27E -12/4/1995 Loo w Completed with ESP by Nabors 4ES-3/22/1995 7"Casing short joints' ESP RWO Nabors 4ES-10/20/1999 from 16,947'to ESP RWO Nabors 4ES-11/18/2004 16,967' R ESP RWO Nabors 4ES-6/4/2005 ASR-Convert to Jet Pump/Gas Lift-12/5/2016 ,. ,%1 � : 7 v 8 y' • i 9 10 41 11 W 11 i A Sands 7 TD=17,588'(MD)/TD=7,670'(TVD) PBTD=17,482'(MD)/PBTD=7,588'(TVD) Revised By:PC 1/12/2017 s o Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 ASR#1 50-029-22614-00-00 195-168 11/24/16 12/4/16 Daily Operations: 11/23/26/2016-Wednesday No activity to report. 11/24/2016-Thursday Continue to RU on F-38: Spot Mud Boat. Install VR plug in wellhead to allow for setting Wellhouse. Remove annulus valve. Bring in crane, Spot Mud Boat center of well, Spot Pit Module,Alaska Crane Assisted in Nipple down and Removal of Production Tree. Well head rep Inspected Hanger Lifting Threads and Travel of Lock down Screws, Nipple up Bope Stack. 11/25/2016- Friday Spot Doghouse and WSM Trailers. Set Wellhouse and Rig Floor w/Crane. Spot Pits and install stairs & Hand rails. Spot Rig on Mud Boat. raise derrick& install guide wires. Lay Herculite for catwalk and spot same. hook up skate &accumulator lines.Transfer 9.8 ppg brine f/upright to pits. Offload 70 bbls of 140° seawater into pits to bring MW down to 9.4+ ppg. Lay Herculite for pipe racks. Hold Sundry meeting w/rig crew.Torque BOP bolts. Function valves. Spot cuttings tank& parts Conex. Continue to RU heat trailers, lines, etc. Wellhead Rep. Pull BPV and install TWC. Fill stack w/water. (Accept Rig at 15:00hrs.) RU to test BOPE. Shell test BOPE. OK,Test BOPE per Sundry#316-580 and ASR-1 procedure.Test all Valves and Rams to 250/3,000psi 5 min each,Tested 2-7/8" and 3-1/2"Tests Joints,Tested Annular 250/2,500psi 5 min each Recorded Accumulator Pre-Charge Pressures and Charted Tests Changed out K-1 and K-2 Manual Valves on mud Cross ( AOGCC Rep. Lou Grimaldi waived witness of test at 18:00 hrs. on 11/23/16) Rig Down Test Equipment Held Safety Sundry Meeting with Crew on F-38 Procedure Well Head Rep Tee bar Removed TWC Valve Rigged up Pump 110 bbl. down the Tubing Taking Returns back to the Flow back Tank with a Pump Rate 3BPM at 650psi (Total 90 bbls in Flow tank) Fluid Loss 20 bbl. Blow down all lines, Hang ESP Sheave E-Trunk and Drain Hose in Derrick Make up landing joint screw into hanger BOLDS Check IA Pressure=0 unseat Hanger at 50k Max Pull 120k Free Pull 100k Center Bop Stack, Break out Lay down Landing Joint and Tubing Hanger,Tie ESP Cable to Spooler. • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 ASR#1 50-029-22614-00-00 195-168 11/24/16 12/4/16 Daily Operations: 11/26/2016-Saturday POH LD 2-7/8" completion f/ 16,678' to ±8,100'. Fill hole w/double displacement. Service Rig Check Fluid Levels Continued POH LD 2-7/8" completion F/±8,100' to surface. Fill hole w/double displacement. (Total Joint 522) Break and Lay down ESP Pump Assembly(Noticeable Damage on Pump MLE Cable Damage and Burned up Motor). 11/27/2016-Sunday RD Centrilift equipment. Clean/Clear Rig Floor. Load &Strap 290 joints of 2-7/8" PH6 work string.TIH W/7' 26#CSG Scraper and 2-7/8"Tubing to 3,744 ft.Service Rig Check Fluid Levels Continued TIH W/7' 26#CSG Scraper and 2-7/8" Tubing F/3,744'to 9,027'. Change Over Handing Equipment to 3-1/2", Load and Tally 280 Joints 3-1/2" CS-Hydril Work/ String on Pipe Racks. 11/28/2016- Monday RIH w/3 1/2" CS-Hyd workstring f/9,028' to 11,911'. Kick while Tripping Drill. Secure well. Discuss results w/crew afterward. Re-Gen Rig engine after resetting error codes. Pro-Star Rep on location. Allow to take parameter readings after Re-Gen. Crew Change out day- Hold PJSM &Sundry with meeting with incoming crew. Continue to RIH w/7" casing scraper assembly on 2-7/8" PH6 & 3-1/2" RTS-8 work/string f/ 11,911' to 15,275'. Rig Service Check Fluid Levels Hold PJSM &Sundry meeting with incoming crew. Continue to RIH w/7" casing scraper assembly on 2-7/8" PH6& 3-1/2" RTS-8 work string F/ 15,275'to 17,150 ft. Reciprocate CSG Scraper across PKR setting Depth at 17,100' 3 Times with a P/U/W=105K S/O/W=28K Rig up to Circulate BTMS up Taking Returns back to the pits, with a pump Rate of 3.5 BPM at 2030psi (42 bbl to Fill hole,) (Total Fluid Loss 60 bbls.) Continue to TOOH w/7" casing scraper assembly on 3-1/2" RTS-8 work/string F/ 17,150'to 15,365' (60 jts. out). 11/29/2016-Tuesday Trouble shoot Derrick locking pin sensor. Sensor showing that the locking pins are disengaged and not allowing movement of the blocks.Visually inspect pins and verify that they are engaged (Good). Pro-Star contacted and bypassed the sensor to allow blocks come down. Clean sensor"eye's".Take System off of Bypass. POH LD 1 joint to verify(OK). Service rig.;Continue to POH LD 3-1/2" WS f/ 15,365'to 9,028'. Change handling equipment to 2 7/8". POH LD 2-7/8" PH6 workstring f/9,028'to ±8,000'. Service Rig Check Fluid Levels. POH LD 2-7/8" PH6 work string f/±8,000' to Surface Lay down 7' 26#CSG Scraper. Rig Service Change Engine oil and Filters. ® • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 ASR#1 50-029-22614-00-00 195-168 11/24/16 12/4/16 Daily Operations: 11/30/26/2016-Wednesday Continue to service rig. Change oil, filters in equipment. PU 7" RTTS per HES Rep. RIH PU 2-7/8" PH6 workstring to 6,385' (205 jts). Service Rig Check Fluid Levels, Continued TIH W/7" RTTS PKR and 2-7/8" PH6 work string to F/6,385ft.'to 9,020'. Load (272)Joints of 3-1/2 RTS-8 Work string on Pipe Racks, Change over Handling Equipment to 3-1/2", Continued TIH W/ 7" RTTS PKR and 3-1/2" RTS-8 work string to F/9,020'to 13,800'. 12/1/2016-Thursday Continue to RIH w/7" RTTS f/ 13,800'to 17,125'. Obtain parameters. PUW 90k-SOW 29k. (AOGCC was notified of upcoming BOP Test if needed before completion is landed on 12-1-16 @ 06:41 AM, Witness was waived by AOGCC Bob Noble @ 07:38 AM on 12-1-16). Spot RTTS C.O.E. at 17,100'. Set Packer per HES Rep. Fill hole w/5 bbls. Close Rams &Test Casing to 2,500psi charted for 30 minutes. Bleed pressure, open Rams& Release RTTS, Monitor wellbore.TOOH laying down 3.5" Work string to 13,000'. Service Rig Check Fluid Levels. Continued POOH, laying down 3.5" Work string f/ 13,000' to 9,028'. Change over Handling Equipment F/3-1/2 to 2-7/8,Continued POOH, laying down 2-7/8" Work string F/9,028' to 3,000'. 12/2/2016- Friday Service Rig, Check fluids in Equipment. Continue to TOOH laying down 2-7/8" work string F/3,000'to surface, Lay down Halliburton RTTS packer. Load Completion Jewelry on Cat walk, Load &Tally 300 Joints of 3.5" L-80 9.3#Completion Tubing, Make up 3.5" completion assembly&TIH with 3.5" 9.3# EUE 8 Round Tubing to 600' Pick up Halliburton ROC Gauge mandrel &Tie in &Test. Continue to TIH with Completion & 3.5" 9.3# EUE 8 Round Tubing per completion Tally F/600'TI 1,200'. Service Rig, Check fluids in Equipment. Continue to TIH with Completion & 3.5" 9.3# EUE 8 Round Tubing per completion Tally F/ 1,200'to 6,065'. 12/3/2016-Saturday Service Rig, Check all fluid levels. Continue to TIH with Completion & 3.5" 9.3# EUE 8 Round Tubing per completion Tally F/6,065'T/9,507',Load &Tally 240 joints of 3.5" Completion Tubing on Racks. Continue to TIH with Completion & 3.5" 9.3# EUE 8 Round Tubing per completion Tally F/9,507'T/ 11,430' ( Well Kill Operations on F-29),Service Rig, Check all fluid levels. Continue to TIH with Completion & 3.5" 9.3# EUE 8 Round Tubing per completion Tally F/ 11,430' to 17,087'. (Total Jts 539) ( Well Kill Operation on F-29),P/U Landing Joint and Make up into Tubing Hanger, Splice Tec Wire Through Hanger, Make up control line to Hanger& Pressure up to open SSV. Land Tubing Hanger P/U/W= 106K S/O/W= 29 K. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-38 ASR#1 50-029-22614-00-00 195-168 11/24/16 12/4/16 Daily Operations: 12/4/2016-Sunday Run in Lock Down Screws on Tubing Hanger, Rig up & Reverse Circulate 400 bbls of Brine water&Seawater with corrosion inhibitor 3 bpm @ 650psi. Rig up Little Red Services,Test lines, Reverse Circulate with 55 bbls of Diesel @ 3 bpm @ 525psi. for Freeze protect 3.5" x 7". Rig up Little Red on 3.5" Tubing, Pressure test lines, Pressure up to 500psi. hold for 5 minutes, continue to pressure up to 3,500psi &set Packer and Test tubing, charted for 30 minutes. bleed pressure off tubing to 1,600psi. Rig up Little Red on 3.5" x 7" Annulus, Pressure test lines, Pressure test to 3,50si charted for 3Q.min.Bleed Annulus&tubing pressure off, Rig up on Tubing, Pressure test lines to 4,800psi. Pressure up on tubing to 4,200psi for 5 minutes, increase pressure to 4,400psi to blow Mirage plug out. Back out Landing joint, Install BPV, re install landing joint, bullhead 17 bbls of diesel through BPV down tubing for freeze protect. Lay down landing joint. Rig Little Red down. Service Rig Check Fluids. Nipple down BOP Stack to Four Bolts, Blow Down and Disconnect all Service Lines, Disconnect Hydraulic lines to BOP Stack, Prep Rig Floor, Un pin Top Section of Derrick and Lower, Electricians Disconnected fire and Gas Alarms. Removed Rig Floor and Well House, Finished N/D Bop Stack and Equipment onto Trailer, Clean up Cellar and Well Head, Move Well site Trailer to F-29 (Well Head rep was on Doyon 14 and was unable to be on location to N/U and install Tree, ),Moved Alaska Crane over to F-29 Hoisted and Installed Well House, Hoisted and Nipple up Bop stack and Equipment. 12/5/2016- Monday No activity to report. 12/6/2016-Tuesday No activity to report. Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday,January 10, 2017 8:52 AM To: Paul Chan Cc: Julianne Dickerson;Alaska NS- Milne - Field Foreman;John Barnes; Bo York;Wyatt Rivard Subject: RE: MP F-38 (PTD 195-168/Sundry 316-580)Variance request Paul, You have approval to operate the well as proposed (reverse Jet Pump)with the SVS system in place as shown. (granted under variance to 20 AAC25.200(d)). A functional/performance test of the SVS system(production and powerfluid side)should be done as soon as possible and results reported to the AOGCC. This approval is valid for 2 months of production ... additional time to flow well as a "Flow to surface" jet pump will have to be requested at that time if the well is not converted to Gas lift by then. Regards, Guy Schwartz Sr. Petroleum Engineer SCANNED JAN 1 201ZAOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Paul Chan [mailto:pchan@hilcorp.com] Sent: Friday,January 06,2017 5:06 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Julianne Dickerson<jdickerson@hilcorp.com>;Alaska NS-Milne-Field Foreman<AlaskaNS-Milne- FieldForeman@hilcorp.com>;John Barnes<jbarnes@hilcorp.com>; Bo York<byork@hilcorp.com>;Wyatt Rivard <wrivard@hilcorp.com> Subject: MP F-38(PTD 195-168/Sundry 316-580)Variance request Guy Please see our reply highlighted in red: Please forward additional SVS system info such as how the power fluid is shut down when the surface SSV is tripped. • Attached is the F-38 P&ID's. Page two shows XV valve 24438 that will actuate if the surface SSV is tripped as shown on the cause and effect document: II-MF-CE-724038-001-01A DC 46120601 (also attached). Is there a pilot associated with the PF side in case of a line break? • There are two pilots on the Water Injection Header that supply power fluid to the well The low pressure pilot is activated at 500 psi (PAL 2442)and the high pressure pilot is activated at 3600 psi (PAH 2442) as shown on the 1 Water Header P&ID document. If either pilot is activated,the source water wells are shut down, stopping power fluid flow to the well. What is your max IA pressure for the power-fluid side? • The maximum IA pressure for the power fluid side is 3500 psi,which is the current discharge pressure from the booster pumps. With friction losses,the power fluid header at F-pad is currently at 3460 psi. Are your long term plans to stay on jet pump or go to Gas lift? • We are currently discussing the benefits of placing this well on gas lift this summer. Sincerely Paul than Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, December 30, 2016 9:00 AM To: Paul Chan<pchan@hilcorp.com> Cc:John Barnes<ibarnes@hilcorp.com>; Bo York<byork@hilcorp.com> Subject: RE: MP F-38(PTD 195-168/Sundry 316-580) Paul, Since this is a potential "flow to surface well"a variance to 20 MC 25.200(d) is required as jet pump completions by design have a pathway through the tubing to the tbg x casing annulus. (in this case you are using a reverse jet pump configuration..pumping powerfluid(PF)down IA with production up tubing). Please forward additional SVS system info such as how the power fluid is shut down when the surface SSV is tripped. Is there a pilot associated with the PF side in case of a line break? What is your max IA pressure for the power-fluid side? Can issue variance once I have this information. Are your long term plans to stay on jet pump or go to Gas lift? Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 2 From: Paul Chan [mailto:pchan@hilcorp.com] Sent:Thursday, December 29,2016 11:56 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:John Barnes<jbarnes@hilcorp.com>; Bo York<byork@hilcorp.com> Subject: MP F-38(PTD 195-168/Sundry 316-580) Guy MP F-38 sundry was approved by the AOGCC to convert this well from ESP to gas lift. Work began on the gas lift line November 19th(-5 days prior to rig arrival) by re-purposing an adjacent gas line that had previously been used on a WAG well. As part of the work,the gas line to F-pad was to be pigged to clear the line of any liquid that may have accumulated. During this operation (depressurizing the gas line),the pressure did not drop as expected at F-pad. Subsequent operations discovered that an ice plug had formed in the gas line/header. Thawing operations commenced but were unable to be completed due to dropping temperatures and rising winds after the MP F-38 well was completed. As this completion was setup with sliding sleeves and the gas lift line is not operational, Hilcorp Alaska respectfully requests a variance to 20 MC 25.200(d)to allow this well to be produced by jet pump(instead of gas lift). The casing has been tested to 3500 psi down to the production packer at 16,979' MD. 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T m a yof 71 1, THE STATE Alaska Oil and Gas ofAT jsKAL Conservation Commission 333 West Seventh Avenue Alaska 99501-3572+L Anchorage,GOVERNOR BILL WALKER g Main: 907.279.1433 of -*P' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager hAR t �? Hilcorp Alaska, LLC SCS 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field,Kuparuk River Oil Pool,MPU KR F-38 Permit to Drill Number: 195-168 Sundry Number: 316-580 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, Daniel T. Seamount, Jr. Commissioner DATED this J5 day of November,2016. RBDMS L,t' NOV 1 6 2016 • V RECEIVED STATE OF ALASKA NOV 0 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCO 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations El Fracture Stimulate ❑ Repair Well ❑., Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: Convert to GL❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC . Exploratory ❑ Development Q • 195-168 . 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ElService ❑ 6.API Number: Anchorage Alaska 99503 50-029-22614-00-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D t Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT KR F-38 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355016 ' 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): f Plugs(MD): Junk(MD): 17,588' - 7,670' .. 17,482' - 7,588' 2,636 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 110' N/A N/A Surface 8,525' 9-5/8" 8,561' 4,475' 5,750psi 3,090psi Production 17,535' 7" 17,568' 7,655' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic ' See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 16,680 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 ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory El Stratigraphic El Development El ' Service El 14.Estimated Date for 15.Well Status after proposed work: 11/21/2016 Commencing Operations: OIL El. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan(a�hilcorp.com Printed Name // /' Bo York Title Operations Manager Signature .� '-` Phone 777-8345 Date t.NA .i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity El BOP Test E Mechanical Integrity Test El Location Clearance ❑ Other: 8,,,,,, ,,,,A•,,,c- ,,,e., , ._ S:� !�G s C o e, e C arc- ... ) Ae 3c�o0 /as�,. d1�CS -1::_ Post Initial Injection MIT Req'd? Yes ❑ No ❑ , t‘ 1 (( Spacing Exception Required? Yes ii N. Subsequent Form Required: `a 41 oG( RBDMS Lt NOV 1 6 2016 APPROVED BY Approved by: , / I COMMISSIONER THE COMMISSION Date:/ (�s//,6 fik6 11/10//c. 46 DRlipaiNSubmit Farm and Form 10-403 Revised 11/2015 12 months from the date of approval. Attachments in Duplicate • Well Prognosis • Well: MPU F-38 Hileorp Alaska,LL' Date:11/07/2016 Well Name: MPU F-38 API Number: 50-029-22614-00 Current Status: SI Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: November 21st, 2016 Rig: ASR 1 IV Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-168 First Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: Jobi'ype: Convert to GG Current Bottom Hole Pressure: 3,336 psi @ 7,000' TVD (SBHPS 10/18/2016/9.18 ppg EMW) Maximum Expected BHP: 3,336 psi @ 7,000' TVD (No new perfs being added) ✓ MPSP: 2,636 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-38 was originally drilled in December 1995 and completed in March 1996 as a Kuparuk River formation producer. F-38 has only had 4 ESPs installed in its 21 year life (initial installation in March 1995, October 1999, November 2004, and June 2005). The ESP has failed. A replacement ESP is not recommended for this well as the reservoir pressure of 9.18 ppg EMW requires an ESP packer that will introduce significant mechanical risk due to the depth and deviation of this well. The well will be converted to gas lift. Objective: Convert the well from ESP to gas lift. ✓ / c-,15 ati C> r /1w 14 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 ±9.4 ppg NaCI/KCI 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. 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/±9.4 ppg NaCI/KCI prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/3,000 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. s • Well Prognosis • n Well: MPU F-38 Ililcon)Alaska.Lb Date: 11/07/2016 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 CO��,� c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor 5r the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking G anywhere at surface.) zf` �,S.�3 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/±9.4 ppg NaCI/KCI as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The initial PU weight during the 2005 ESP swap was 130K lbs. (block weight not noted) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. c. Contingency Casing Jack Procedure: If the tubing hanger will not come off seat after circulating lubricant, RU casing jacks as follows: i. PU Casing Jacks via the beaver slide and Tugger winches to rig floor (A.- ,in ii. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and �,cti function test same. 3 iii. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point iv. 100%Yield strength of 2-7/8", 6.4#, L-80145K I "f v. Cycle jacks up and down to ensure proper unc on (dry run without being connected to hanger). 16. Recover the tubing hanger. ;F. 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 l be scrapped. `-'/' 18. PU & RIH with 7" 26#scraper assembly to—17,150' MD on 3-1/2"workstring. Reciprocate scraper across packer setting depth of 17100' MD. Circulate the well clean. 19. POOH. L/D scraper assembly and 3-1/2" workstring. . Well Prognosis • Well: MPU F-38 flilcor')Alaska,LL Date: 11/07/2016 20. RU Tec wire spooling unit. PU packer and tailpipe. MU gauge and terminate TEC wire. 21. RIH on new 3-1/2" tubing. Place Tec wire clamp on every collar. a. GLM #2 @ ±2,198' MD w/DGLV b. GLM #1 @ ±3,711' MD w/shear valve c. Halliburton XD sliding sleeve @ 6,449' MD d. Halliburton XD sliding sleeve @ 15,175' MD e. 3-1/2" Halliburton ROC Gauge @ ±16,500'MD f. Baker 7" x 3-1/2" FHL Packer set @ ± 17,020' MD g. 3-1/2" Halliburton Mirage Plug/Auto-Fill sub h. 3-1/2" XN Nipple @ ±17,060'MD i. 3-1/2" WLEG @ ±17,100'MD 22. MU tubing hanger and landing joint. 23. Reverse circulate the well with 100 bbl of seawater and 350 bbl seawater w/corrosion inhibitor at 3 BPM. 24. Terminate TEC wire in tubing hanger. 25. Land hanger, RILDs and test hanger. 26. Perform a low pressure tubing test to 500 psi. 27. With annulus open, pressure up on tubing to close Autofill sub. Confirm calculated closing pressure. Confirm Autofill sub is closed. 28. Continue pressurizing the tubing and set the packer. Test the tubing to 3500 psi for 30 minutes. Bleed off the tubing pressure to 1500- 1700 psi. Test the annulus to 3,000 psi for 30 min. C' li,L,i ' 29. Bleed off the tubing pressure and shear the valve in GLM #1. 30. RU hot oil pump and freeze protect the tubing and IA to '2500' MD with diesel. Allow freeze protect to U-tube down tubing. 31. Set BPV. RDMO ASR#1. Post-Rig Procedure: 32. RD mud boat. RD BOPE house. Move to next well location. 33. RU crane. ND BOPE. 34. NU 3-1/8"" 5,000#tree/adapter flange. Pull BPV and set TWC. Test to 500 psi low/5,000 psi high. Pull TWC. 35. RD crane. Move 500 bbl returns tank and rig mats to next well location. 36. Replace gauge(s) if removed. 37. Turn well over to production. RU well house and flowline. 38. Hookup gas lift line. Hookup HAL ROC gauge. 39. RU SL. Drift tubing to maximum deviation. 40. Open HAL sliding sleeve at 6,449' MD 41. Set X-lock with gas lift carrier in SS at 6,449' MD. 42. RD SL. . • Well Prognosis Well: MPU F-38 Ilitcorp Alaska.LLQ Date: 11/07/2016 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Existing Tree/Wellhead 4. BOPE Schematic 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form 14 • . Milne Point Unit • Well: MPU F-38 SCHEMATIC Last Completed: 3/22/1995 Hilcorp Alaska,LLC PTD: 195-168 RKB:AGL=45.46GLEIev.12.2'/RT toTl�g. TREE&WELLHEAD '! 5000��3 .'(1\47E) Tree 2-9/16"—5M FMC t* Wellhead 11"5M FMC Gen.5a w/2/78"FMC Tbg.Hng.2-7/8"EUE r 8rd top and Bottom,2.5"CIW H BPV Profile 20' 0 r„, OPEN HOLE/CEMENT DETAIL 1 64 20" Cmt w/260 sks in 30"Hole—TOC @ Surface h 9 5/8" Cmt w/1,880 sks in 12-1/4"Hole TOC @ Surface tt Y 7" Cmt w/217 sks in 8-1/2"Hole—TOC calculated @ 15,247' Lthl CASING DETAIL 44 Size Type Wt/Grade/Conn Drift ID Top Btm Capacity 20" Conductor 91.1/NT-80/N/A N/A Surf 110' N/A 14 0 o. 9-5/8" Surface 40/L-80/Butt 8.679 Surf 8,561' 0.0758 7" Production 26/L-80/Butt 6.151 Surface 17,568' 0.0383 k 1 TUBING DETAIL ot 2-7/8" Tubing 6.5/L-80/8RD EUE 2.347 Surf 16,678' 0.00592 4 WELL INCLINATION DETAIL '4 KOP @ 550' :4 4 Max Hole Angle=74 to 78 deg.f/4,300'to 15,100' ti Hole Angle through perforations=42 deg. 9-5/8"4 III► JEWELRY DETAIL No Depth Item 1 137' Camco 2-7/8"KBMM GLM 2 2 16,557' 2-7/8"KBMM GLM 3 16,602' 2-7/8"HES XN-Nipple(2.205 no-go ID) 4 16,617' Pump GC2200 ESP,513 series,GMPTAR 1:1 122 STG to) 3 5 16,638' Tandem Gas Separator GRSFTXAR y 1 6 16,643' Tandem Seal Section GSB#DBUT/L TILH6PFSAFLAS/HSN 7 16,657' Motor,19OHP,KNH,2415 Volt,48 AMP 8 16,674' Phoenix Multi Sensor w/6 fin centralizer 9 16,947 7"Short Joints 16,947 to 16,967' 4 PERFORATION DETAIL lies Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status ` 17,199' 17,243' 7,373' 7,406' 44' 2/24/1996 Open «g Kup.A Sands 17,250' 17,290' 7,411' 7,441' 40' 11/16/2004 Open WELL STIMULATION DETAIL of 7 3/1/96-42.85 M lbs.16/20 Carbolite prop. Screened out w/8ppg on perfs V. V, 3/12/96—115 M lbs.16/20 Carbolite prop. Job went to flush - GENERAL WELL INFO F 1,41 8 ' API:50-029-22614-020-00 Drilled and Cased by Nabors 27E -12/4/1995 OF viii " Completed with ESP by Nabors 4ES—3/22/1995 9 ESP RWO Nabors 4ES—10/20/1999 '' ESP RWO Nabors 4ES—11/18/2004 ESP RWO Nabors 4ES—6/4/2005 4. ` 0 f r A Sands V 1 FWW: J A: 7" le TD=17,588'(MD)/TD=7,670'(TVD) PBTD=17,482'(MD)/PBTD=7,588'(ND) Revised By:PC 11/07/2016 • Milne Point Unit H ii Well: MPU F-38 • PROPOSED Last Completed: 3/22/1995 Eiileoru Alaska,LLC PTD: 195-168 RKB:AGL=45.46GLEIev.=12.2'/RT toTbg. TREE&WELLHEAD '! 5000L=33 2 ' N?7Ej Tree 2-9/16" 5M FMC 11"5M FMC Gen.5a w/2/78"FMC Tbg.Hng.2-7/8"EUE ,4 Wellhead 8rd top and Bottom,2.5"CIW H BPV Profile 20" !' OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sks in 30"Hole—TOC @ Surface 9-5/8" Cmt w/1,880 sks in 12-1/4"Hole-TOC @ Surface 7" Cmt w/217 sks in 8-1/2"Hole—TOC calculated @ 15,247' CASING DETAIL 1 Size Type Wt/Grade/Conn Drift ID Top Btm Capacity 20" Conductor 91.1/NT-80/N/A N/A Surface 110' _ N/A 9-5/8" Surface 40/L-80/Butt 8.679 Surface 8,561' 0.0758 7" Production 26/L-80/Butt 6.151 Surface 17,568' 0.0383 TUBING DETAIL ' '' 3-1/2" Tubing 9.2/L-80/EUE 8rd 2.992 Surface ±16,678' 0.00592 WELL INCLINATION DETAIL 2 KOP@550' Max Hole Angle=74 to 78 deg.f/4,300'to 15,100' Hole Angle through perforations=42 deg. JEWELRY DETAIL 9-5/8"-& 6 No Depth Item 1 ±2,198' 3-1/2"x 1"GLM l tC5 2 ±3,711' 3-1/2"x GLM E. 3 )t _ 1"• 3 ±6,449' 3-1/2"Sliding Sleeve Al eq" 4 ±15,175' 3-1/2"Sliding Sleeve 5 ±16,500' 3-1/2"Gauge Carrier 6 ±17,020' 7"x 3-1/2"Retrievable Packer 7 ±17,060' 3-1/2"XN-Nipple 8 ±17,100' 3-1/2"WLEG PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A Sands 17,199' 17,243' 7,373' 7,406' 44' 2/24/1996 Open 17,250' 17,290' 7,411' 7,441' 40' 11/16/2004 Open WELL STIMULATION DETAIL 3/1/96—42.85 M lbs.16/20 Carbolite prop. Screened out w/8ppg on perfs •fir 4 3/12/96—115 M lbs.16/20 Carbolite prop. Job went to flush GENERAL WELL INFO API:50-029-22614-020-00 Drilled and Cased by Nabors 27E -12/4/1995 \ y 5 Completed with ESP by Nabors 4ES—3/22/1995 . ESP RWO Nabors 4ES—10/20/1999 ESP RWO Nabors 4ES—11/18/2004 ESP RWO Nabors 4ES—6/4/2005 7"Casingshortjoints from 16,947'to j ' 16,967' '! IAej 6 P 8 k; * 1 A Sands 7'J I , J TD=17,588'(MD)/TD=7,670'(TVD) PBTD=17,482'(MD)/PBTD=7,588'(TVD) Revised By:TDF 11/8/2016 • 1111 Milne Point ASR Rig 1 BOPE Il itrorp.41ar4aa.1.1.6 11" BOPE Stripping Head 3.98' ' *Shaffer ° 11" - 5000 III lil itI liiI11 1 .1 iii l_ 1 IIII III CI i —� BUM' 4.54' f '® VBR or Pipe Rams • 1 11'-5000 r®® 11..= Blind CSI i11 ir-] ill 2 1/16 5M Kill Line Valves 21/16 5M Choke Line Valves . ,L-11 ITT it I'll IT, 2.00' .(o)i a ao i fro Manual Manual Manual HCR Updated 8/19/2015 0 r ,isg aI )1 § 1-3%*6 R act - CY C i J t c:-8, ; O 3 V ._O F' c• _ G.LL F m C x OiJ 41J s Q. a a U F, o V J s L1 g " i > u C7 z 2" l0•L ., « W > u O V r Z • •, ► •••Col-004 ; . .W.1 w > c7 m a a z Y ZJ U 6J TTJ dyy1ut mens ^'�enf } l7 _ . == u v u!S m c u u d1, '- .-- - m O o a a o m § a .06 . 8J 0 o Q �� vi �. n v; u vl II o II II II a gll 3 3 3 3 3 I T ,,, 707 c :,.. 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O o °� 0 css a CO c U 13 0 L co d V ; O Q II cd cx. d a. G. 'Es To- U • C U > L 0 o cin cin Q m Q a` 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 Complete RESCAN Color items - Pages' Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ • • P BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder � — bq Alaska Oil and Gas Conservation Commission I L `" 333 West 7 Avenue p F .. 3 Anchorage, Alaska 99501 r 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 • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) MPF -Pad 10/29/2011 Corrosion 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 8/72011 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 8/2/2011 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 8/6/2011 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 2010820 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 WA 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 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 NA/ 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 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 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 7/31/2011 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 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -848 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 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 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 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 8/13/2011 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 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 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 ) ALASKA 01L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355016 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): Change Out ESP o Suspend 0 Operation Shutdown 0 Perforate 181 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 45.50' 17588 7670 17472 7580 110' 8525' 17535' 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 195-168 6. API Number: 50-029-22614-00-00 99519-6612 9. Well Name and Number: M PF-38 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) feet Junk (measured) feet Size MD 20" 110' 9-5/8" 8561' 7" 17568' NIA NIA TVD Burst Collapse 110' 4475' 1490 5750 470 3090 7655' 7240 5410 SCANNEC. .rUI... 0 7 2005 rl, .,""," ~t'"rrß ~...- ~1:;':'¡'ITóII 1,,_. JUN 2 ~¡¡ 2005 17199' - 17290' 7373' - 7441' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n¡~ B\ 2-7/8",6/5# L-80 16680' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None Treatment description including volumes used and final pressure: RBDMS BFL JUN 3 0 2005 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure 329 453 400 346 373 350 Oil-Bbl Prior to well operation: 1114 Subsequent to operation: 1109 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Tubinq Pressure 363 314 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 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 Si9~~~~' Form 10-404 Revised 04/2004 Title Technical Assistant Phone Prepared By Name/Number: Date ð tow zg -q;~ndra Stewman, 564-4750 Submit Original Only 564-4750 Tree: 2 9/16" - 5M FMC ) Wellhead: 11" 5M FMC Gen. 5a wi 2 7/8" FMC Tbg. hng., 2 7/8" EUE 8rd top and bottom, 2.5" CIW H BPV profile I 20",91.1 ppf, NT80 csg.1 115' I KOP @ 550" Max. hole angle = 74 to 78 deg. fl 4300' to 15,100' Hole angle thru' perfs. = 42 deg. 9 5/8", 40 ppf, L-80 Btrc. surface csg. I 8561' mdl j 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary 03/01/96 - 42.85 M Ibs. 16/20 Carbolite prop behind pipe. Screened out wi 8 ppg on perfs.. 03/12/96 - 115 M Ibs. 16/20 Carbolite prop. behind pipe. Job went to flush. Perforation Summary Ref log: Perf Record 02/24/96 Size SPF Interval (TVD) Kup. 'A' Sand 3 3/8" 6 17199'-17,243' (7352'-7405') 22 gm. JumboJet charges ( EHD=0.76",TTP=6.4") 60 deg. phasing. MPU F-38 Orig., )Iev. = 45.46' (N 27E) GL Elev. = 12.2' RT To Tbg. Spool = 33.26' (N 27E) I . Cameo 2 7/8" x 1" 137' KBMM GLM i 2 7/8" KBMM GLM 16,557' I 2 7/8" HES XN Nípple I 16,603' I (2.205 no-go ID) Pump GC2200 ESP, 513 series, GPMTAR 1:1 12~ Stg 16,618' Tandem gas separator GRSFTXAR H6 16,638' Tandem Seal Section GSB3DBUT AB/HSN PFSA CL5 16,643' GSB3DBL T AB/HSN FSA CL5 Motor, 266 HP, KMH, 2345 VOlt 69 AMP Note :Re-Rated 16,657' 195 hp 2177 v. /53 amp. Phoenix MultiSensor w/ 6 fin I 16,678' centralizer v ~ 7" short joints from 16,947' to 16,967' I ~IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII~ 7" Float collar (PBTD) 7" Float shoe 7507' tvd 117,482' md I 117,568' mdl DATE REV. BY COMMENTS MILNE POINT UNIT 1 2 / 04 / 95 JBF Drilled and Cased by Nabors 27E WELL F-38 03 / 22 / 95 JBF Initial ESP Completion by Nabors 4ES API NO: 50-029-22614 1 0/20/99 M. Linder RWO Nabors 4-ES / 11/18/04 06/04/05 MDO ESP RWO Nabors -4es BP EXPLORATION (AK) ) ) BP EXPLORATION Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/1/2005 6/2/2005 6/3/2005 6/4/2005 MPF-38 MPF-38 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/1/2005 Rig Release: 6/4/2005 Rig Number: Spud Date: End: 6/4/2005 From - To Hours Task Code NPT Phase Description of Operations 18:00 - 19:30 1.50 RIGD P PRE Scope & lower derrick 19:30 - 20:30 1.00 RIGD P PRE Prep rig to move. Move camp & spool 20:30 - 23:00 2.50 RIGD P PRE Move rig to MPF-38 23:00 - 00:00 1.00 P PRE Raise & scope rig Rig accepted @ 00:00 hrs 00:00 - 01 :00 1.00 KILL P DECOMP R/U lines to tree & annulus to circulate, Load pits with produced water 01 :00 - 01 :30 0.50 KILL P DECOMP R/U lubricator-Pull BPV- Lay down Lubricator 01 :30 - 02:30 1.00 KILL P DECOMP Continue to R/U Tree to circulate. Take on 8.3+ water 02:30 - 03:00 0.50 KILL P DECOMP PJSM Test lines to 3500 psi R/U Choke line Test Open well TBG = 720 Annulus = 710 psi 03:00 - 05:30 2.50 KI LL P DECOMP Circ. 100 bbls hot 8.5 ppg sea water 2.5 bbm 1200 psi Bull head 50 bbls Circ 50 bbls, Bleed down and shut in to monitor. 05:30 - 06:00 0.50 KILL P DECOMP SITP = 220 psi after 1/2 hour, & staballized. 06:00 - 07:30 1.50 KILL P DECOMP Send truck for load of 9.9 ppg brine @ MP D pad. Continue circulating, following heated seawater wi processed water, to empty pits. WI 8.3 ppg processed water. 07:30 - 08:00 0.50 KILL P DECOMP Monitor well. After 1/2 hour, 340 psi on the tubing, 610 psi on the II A & 700 psi on the 01 A. 08:00 - 16:30 8.50 KILL P DECOMP PJSM. Take on 9.9 ppg fluid & water back to 9.5 ppg. Pump down tubing, taking returns thru choke to tiger tank. Pump rate = 4 bpm @ 500 psi with pump pressure gradually rising to 1450 psi as weighted brine turns the corner. With 750 bbls pumped, seeing 9.4 ppg coming back, shut down & monitor well, both sides on vacuum. 16:30 - 17:30 1.00 WHSUR P DECOMP Set TWC and test to 3500psi Bleed void and N/D Tree 17:30 - 19:30 2.00 BOPSUR P DECOMP PJSM Nipple up B.O.P.E. 19:30 - 23:00 3.50 BOPSUR P DECOMP Pressure test BOPE as per BP/AOGCC requirements LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones w/AOGCC. Test witnessed by Nabors Tour Pusher Randall Henderson & BP Rep Danny Felder. 23:00 - 00:00 1.00 PULL P DECOMP PJSM R/U Lubricator pull TWC, UD Lubricator 00:00 - 01 :00 1.00 PULL P DECOMP PJSM Pull hanger to floor, broke free at 130K, stable up wt. 100K. Test and UD hanger 01 :00 - 06:00 5.00 PULL P DECOMP Fill hole 25 bbls of 9.4ppg POOH w/2 7/8" ESP completion string 06:00 - 07:30 1.50 PULL P DECOMP Coninue OOH wi 2 7/8" ESP completion. 07:30 - 09:00 1.50 PULL P DECOMP Change out reel. Circulate 160 bbls 9.5 brine around to clean up hole wi swapping reels, taking dirty returns to tiger tank. 09:00 - 15:00 6.00 PULL P DECOMP Continue to POOH wi 27/8" completion string. 15:00 - 18:00 3.00 PULL P DECOMP PJSM. UD pump assembly. Prep to RIH wi new ESP. Clear I clean rig floor. Upper pump locked up, motor imbalanced. 18:00 - 20:00 2.00 RUNCOrvP RUNCMP Make up and service pump assembly. Test motor, route cable through 54" sheave. Attach and secure cable and sensor line 20:00 - 21 :00 1.00 RUNCOrvP RUNCMP Make up 2.205 XN Nipple with pup, 1 Jt of 2-7/8" 6.5# L-80 Tbg, KBMM GLM with 1" Dummy 21 :00 - 00:00 3.00 RUNCOrvP RUNCMP TIH by stands 2-7/8" 6.5# L-80 Tbg. Pump and record pressure & test cable every 20 stds 00:00 - 01 :30 1.50 RUNCOM RUNCMP TIH with ESP on 2-7/8" 6.5# L-80 Tbg by stands Pump & record pressure & test cable every 20 Stds 01 :30 - 05:00 3.50 RUNCOM RUNCMP 8000' Cable splice at 80 stands. Fill hole. Cut and slip Drill Line. Test Cable 05:00 - 09:00 4.00 RUNCOM RUNCMP Continue run Esp Completion 09:00 - 12:00 3.00 RUNCO, I RUNCMP PJSM. Make reel to reel splice. Printed: 6/6/2005 11 :22:20 AM ') ) BP EXPLORATION Operations· Summary Report Page 2012 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-38 MPF-38 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/1/2005 Rig Release: 6/4/2005 Rig Number: Spud Date: End: 6/4/2005 6/4/2005 12:00 - 13:30 1.50 RUNCOM RUNCMP PJSM. Run last (2) stands & M/U hanger. Wrong penetrator sent out, call for new one & hot test @ shop. 13:30 - 14:30 1.00 RUNCOM RUNCMP Make field connection & test, OK. land tubing & RILDs. Set two way check valve. 14:30 - 15:30 1.00 BOPSUP RUNCMP PJSM. N/D BOPE. 15:30 - 17:00 1.50 WHSUR RUNCMP PJSM. N/U & test tree & void @ 5000 psi, OK. Make final test on ESP cable, OK. 17:00 - 18:00 1.00 WHSUR RUNCMP PJSM. Transfer fluid to tiger tank. P/U lubricator, pull 2 way check, set BPV. Rig released @ 18:00 hrs, 06/04/2005. Printed: 6/6/2005 11 :22:20 AM ) STATE OF ALASKA'\ ALASKA UIL AND GAS CONSERVATION COfl,,,,¡fISSION - .QECEtV. E.-. D REPORT OF SUNDRY WELL OPERATIONS' DEC 2 1 2004 ÞJ~$ì~ul1!lW1!lE{~ göftS. Commtlliol 181 ~~orage 0 Time Extension 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 45.50' 8. Property Designation: ADL 355016 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 181 Perforate 0 Re-Enter Suspended Well 17588 7670 17472 7580 110' 8525' 17535' 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 195-168 6. API Number: 50-029-22614-00-00 9. Well Name and Number: MPF-38 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 110' 110' 9-5/8" 8561' 4475' 5750 3090 7" 17568' 7655' 7240 5410 SCANNED DEe 2 7 2004 17199' - 17290' 7373' - 7441' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 2-7/8",6/5# L-80 16679' Treatment description including volumes used and final pressure: RBDMS BFL DEC 2 2 1004 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 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 Title Technical Assistant Phone ;"~' '.; ,i">. .~\¡ i\. /2 l . ,~~ Prepared By Name/Number: ;"~~4f~~5Þ(,\1 /~\ bate- -r-Urondra Stewman, 564-4750 Submit Original Only Tree: 2 9/16" - 5M FMC ) Wellhead: 11" 5M FMC Gen. Sa wi 2 7/8" FMC Tbg. hng., 2 7/8" EUE 8rd top and bottom, 2.5" CIW H BPV profile 20",91.1 ppf, NT80 csg.1 110 I. KOP @ 550" Max. hole angle = 74 to 78 deg. fl 4300' to 15,100' Hole angle thru' perfs. = 42 deg. 9 5/8", 40 ppf, L-80 Btrc. surface csg. I 8561' md I j 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift 10 ::::: 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary 03/01/96 - 42.85 M Ibs. 16/20 Carbolite prop behind pipe. Screened out w/ 8 ppg on perfs.. 03/12/96 - 115 M Ibs. 16/20 Carbolite prop. behind pipe. Job went to flush. Perforation Summary Ref log: Perf Record 02/24/96 Size SPF (TVD) Interval Kup. 'A' Sand 33/8" 6 17199'-~ (7352~.- 7~1J¡ C> . -'/I.tt..ll', ~ 22 gm. JumboJet charges ( EHD=0.76",TTP=6.4") 60 deg. phasing. ,- MPU F-38 Orig. [')ev. = 45.46' (N 27E) GL Elev, = 12.2' RT To Tbg, Spool = 33.26' (N 27E) " Camco 2 7/8" x 1" KBMM GLM 135' ~ 2 7/8" KBMM GLM 16554' I 27/8" HES XN Nipple (2.205 no-go ID) 16602' I Pump GC2200 ESP, 513 I ' I series, GMPTAR 1:1 122 Stg 16617 6950' tvd Tandem gas separator GRSFTXAR 16638' I Tandem Seal Section I I GSB3DBUT/L TILH6PFSAFLAS/HSN 16643' Motor, 190 HP, KMH, 2415 VOlt 16657' I 48 AMP Phoenix MultiSensor wi 6 fin I 16674' I centralizer 6990' tvd v ~ 7" short joints from 16,947' to 16,967' $; ~~( f I % I I "Wllllllllllmllllllllllllllllllllllll.. 7" Float collar (PBTD) 7" Float shoe 7507' tvd 117,482' md 117,568' mdl 12 / 04 / 95 03 / 22 / 95 1 0/20/99 11/18/04 JBF JBF M. Linder Lee Hulme COMMENTS Drilled and Cased by Nabors 27E Initial ESP Completion by Nabors 4E5 RWO Nabors 4-ES RWO Nabors 4ES DATE REV. BY MILNE POINT UNIT WELL F-38 API NO: 50-029-22614 BP EXPLORATION (AK) ) ) BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-38 MPF-38 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/12/2004 Rig Release: 11/18/2004 Rig Number: Spud Date: End: Date From - To Ho u rs Task Code NPT Phase Description of Operations 11/12/2004 10:00 - 14:00 4.00 RIGD P PRE Lower & scope down derrick. RD & prepare to move from MPI -6 to MPF -38. 14:00 - 19:30 5.50 MOB P PRE Move from MPI -06 tp MPF-38. Moved sub & camp 1st. 19:30 - 21 :00 1.50 RIGU P PRE Spot & berm Rig sub over MPF-38. 21 :00 - 22:30 1.50 RIGU P PRE Raise & scope up derrick. R/U rig. 22:30 - 00:00 1.50 RIGU P PRE Spot in pipe shed & level. Spot in pits & R/U to lines to sub. ACCEPTED RIG @ 00:01 hrs, 11/13/2004. 11/13/2004 00:00 - 01 :30 1.50 PULL P DECOMP R/U lines to tiger tank & X-mas tree. Take on seawater. 01 :30 - 02:00 0.50 WHSUR P DECOMP P/U lubricator & pull BPV. UD lubricator. 02:00 - 02:30 0.50 WHSUR P DECaMP Pressure test lines to tree to 3500 psi, OK. Test lines to tiger tank. 02:30 - 03:00 0.50 KILL P DECOMP Hold PJSM & Pre-spud meeting wi all hands. 03:00 - 06:00 3.00 KILL P DECOMP Open & begin killing well. SITP 1380 psi. SICP 1440 psi. Pump I @ 3 BPM1100 psi. Pump tbg vol (96 bbls). SI & bullhead 30 bbls to perfs.. check SI pressures, tbg went to 0 psi. Con't to circulate & kill well. 3 BPM @ 1300 psi. 06:00 - 07:30 1.50 KILL P DECOMP PJSM. Continue to circulate well wi 120 degree 8.5 ppg seawater. See seawater returns back after pumping 620 bbls. I Bring rate up to 4 bpm I 1400 psi. Pump total of 11,000 stks or 650 bbls. ! 07:30 - 08:00 0.50 KILL P DECOMP PJSM. Bleed off both sides & shut in to observe. See pressure I stabalize @ 200 psi on tubing & 200 psi on casing. Order out I kill wt brine.... (9.2+ - 9.3 ppg). 08:00 - 14:30 6.50 KILL P DECaMP PJSM. Monitor well & circulate remaining 8.5 ppg seawater around while mud plant mixes & trucks out 9.3 ppg brine. SITP & SICP after circulatring & shutting in = 210 psi. 14:30 - 18:00 3.50 KILL P DECOMP PJSM. Take on 9.3 ppg brine & commence circulating around @ 4 bpm 11500 psi, 625 bbls. SID monitor well. Well dead. 18:00 - 19:00 1.00 WHSUR P DECOMP Blow down & RID lines. Install TWC. 19:00 - 20:30 1.50 WHSUR P DECOMP RID HCR valve. N/D tree & adapter flange. Inspect hanger threads. 3" LH Acme, OK. 20:30 - 23:00 2.50 BOPSUP P DECOMP N/U BOPE & test equip. 23:00 - 00:00 1.00 BOPSUP P DECOMP Test BOP equip as per AOGCC/BP requirements. LP 250 psi. H P 3500 psi. 11/14/2004 00:00 - 02:30 2.50 BOPSUP P DECOMP Finish testing BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Sheve wi AOGCC. RID test equip. 02:30 - 03:00 0.50 WHSUR P DECOMP R/U lubricator & pull TWC. UD lubricator.. 03:00 - 03:30 0.50 WHSUR P DECOMP M/U landing jt in hanger. BOLDS. P/U & pull hanger free @ 70K, Con't to pull to 112K & tubing coming out of hole. Pull hanger to floor. Much drag. 03:30 - 06:00 2.50 PULL P DECOMP Circulate bottoms & work pipe. 4 BPM @ 1700 psi. 06:00 - 08:00 2.00 PULL P DECOMP PJSM. POOH wi 2 7/8" ESP completion, standing back tubing. WI 23 stands out, note hole fill less than it should be. Very slight flow. 08:00 - 14:30 6.50 KILL N DPRB DECaMP PJSM. Weight up 9.3 ppg brine to 9.6 ppg brine & circulate tbg volume @ 4 bpm I 1400 psi. Bullhead 100 bbls @ 3 bpm I 1800 psi, final bullhead pressure @ 2 bpm I 1900 psi. Resume circulating & weighting up, circulating 9.6 ppg brine around @ 4 bpm I 1400 psi, to clean 9.6 ppg brine returns. 14:30 - 15:00 0.50 KILL N DPRB DECOMP Monitor well, well on a slight drink on tubing & IIA. 15:00 - 15:30 0.50 PULL P DECOMP PJSM. POOH wi 2 7/8" ESP completion. 15:30 - 17:00 1.50 PULL P DECOMP PJSM. Swap reels. Printed: 11/22/2004 10:20:59 AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-38 MPF-38 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/12/2004 Rig Release: 11/18/2004 Rig Number: Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2004 17:00 - 22:30 5.50 PULL P DECOMP Continue to POOH wi 2 7/8" ESP completion, well stable. Pulled 101 stands. replaced 1 jt for galled threads. 22:30 - 23:00 0.50 PULL P DECOMP Change out spools in spooling unit. 23:00 - 00:00 1.00 PULL P DECOMP Con't to POOH wi ESP completion. pulled 125 stands. 11/15/2004 00:00 - 03:30 3.50 PULL P DECOMP Con'to POOH wi ESP completion. Pulled &stood back 174 stands. 03:30 - 05:00 1.50 PULL P DECOMP Drain, break, inspect & LID ESP. 05:00 - 06:00 1.00 PULL P DECOMP Clear & clean rig floor. Prepare to RIH. 06:00 - 07:00 1,00 PULL P DECOMP Lubricate & service rig. 07:00 - 15:00 8.00 CLEAN P CLEAN PJSM. M/U mule shoe & RIH wi 2 7/8" EUE tbg from derrick. PIU singles & single in. See no fill. 90K up wt, 27K down wt. M/U head pin on jt #553. 15:00 - 16:30 1 .50 CLEAN P CLEAN PJSM. Attempt to break circulation, plugged up. Lay down #553 & make up headpin on #552. Work pipe wi 1700 psi on tbg, broke free, Circulate down & M/U head pin on #553. Circulate down & tag PBTD 11' in on #553 @ 17485'. 16:30 - 18:00 1 .50 CLEAN P CLEAN Close bag & reverse circulate @ 6 bpm I 1600 psi. See gravel I frac sand back over shaker. Estimate there was 15' (+ -) of fill. Reverse circulate to clean returns. 18:00 - 23:00 5.00 CLEAN P CLEAN Monitor well. Well flowing slightly. Mix salt & weight up system to 9.8 ppg. SID & monitor well. well dead. 4112 BPM @ 1900 psi. Pumped 680 bbls. 23:00 - 00:00 1.00 CLEAN P CLEAN POOH w/2 7/8" tubing. 11/1 6/2004 00:00 - 06:00 6.00 CLEAN P CLEAN Con't to POOH & stand back 2 7/8" tubing string. LID 28 jts of excess 2 7/8" tbg. 06:00 - 12:00 6.00 PERFOB P OTHCMP PJSM. Rig up to perforate. N/D flow nipple, NIU shooting flange. Rig up Schlumberger E Line lubricator extension & BOPE. Test against blind rams to 500 psi, OK. 12:00 - 15:30 3.50 PERFOB P OTHCMP PJSM. Pick up 20' of 3 3/8" hollow carrier perf gun loaded wi 6 spf, Powerjet charges. RIH on E Line. Tie in to Atlas GR/CCL log, (+56' correction). Tag depth @ 17,487' after correction. Pull up to firing depth to perf from 17,270' - 17,290'. Fill hole, (15 bbls). Go through firing sequence several times with no good indication of shots fired. Indication is an open circuit. 15:30 - 17:00 1.50 PERFOB P OTHCMP POOH wi perf assembly. 17:00 - 19:00 2.00 PERFOB N MISC OTHCMP PJSM. Lay down & disarm perf gun. Trouble shoot same. Replace firing head. 19:00 - 21 :00 2.00 PERFOB P OTHCMP RIH wi 3-3/8" Hollow Carrier perf guns wi 6 Powerjet SPF on changed-out firing head. Tie-in to GR-CCL as noted above and fire guns from 17,270' to 17,290'. Fill casing w/8 Bbls 9.8 brine. Initiate firing sequence wi good indication of firing. Monitor hole for 10 minutes. 21 :00 - 22:00 1.00 PERFOB P OTHCMP POH wi perf assy. Hold PJSM to prepare for changing out fired guns for 2nd 20' section of 3-3/8" HC gun. 22:00 - 23:00 1.00 PERFOB P OTHCMP Breakout and LID 1 st 20' section of HC perf guns. All guns fired; formation crude oil dribbling out of fired gun cavities. 23:00 - 23:30 0.50 PERFOB P OTHCMP M/U 2nd 20' section of 3-3/8" HC perf guns. 23:30 - 00:00 0.50 PERFOB P OTHCMP RIH wi 2nd 20' section of 3-3/8" HC perf guns. 11117/2004 00:00 - 01 :00 1.00 PERFOB P OTHCMP RIH wi 2nd 20' section of HC perf guns. Correlate and repeat to spot guns across 17250' to 17270'. Fill casing wi 12 Bbls 9.8 brine. Fire guns, resulting wi good surface indication. Monitor well for 10 minutes. 01 :00 - 02:00 1.00 PERFOB P OTHCMP POH wi 2nd section of guns. B/O and LID same. All charges Printed: 11/22/2004 10:20:59 AM ~ ) ) Page 3 of 3 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPF-38 MPF-38 WORKOVER Start: 11/12/2004 NABORS ALASKA DRILLING I Rig Release: 11/18/2004 NABORS 4ES Rig Number: From - To I Hours Task Code NPT Phase 11/17/2004 01 :00 - 02:00 1.00 PERFOB P OTHCMP 02:00 - 03:30 1.50 PERFOB P OTHCMP 03:30 - 04:30 1.00 PERFOB P OTHCMP 04:30 - 06:00 1.50 PERFOB P OTHCMP 06:00 - 16:00 10.00 RUNCOMP RUNCMP 16:00 - 18:30 2.50 RUNCOMP RUNCMP 18:30 - 23:30 5.00 RUNCOMP RUNCMP 23:30 - 00:00 0.50 RUNCOMP RUNCMP 11/18/2004 00:00 - 03:00 I 3.00 RUNCOMP RUNCMP 03:00 - 04:00 I 1.00 RUNCOMP RUNCMP I 04:00 - 04:30 0.50 RUNCOMP RUNCMP 04:30 - 06:30 2.00 RUNCOMP RUNCMP 06:30 - 07:00 0.50 RUNCOMP RUNCMP 07:00 - 07:30 0.50 WHSUR P RUNCMP 07:30 - 08:30 1.00 BOPSUR P RUNCMP 08:30 - 10:00 1.50 WHSUR P RUNCMP 10:00 - 11 :00 1.00 I WHSUR P RUNCMP I I I Spud Date: End: Description of Operations fired, wi crude oil oozing from wounds. RID SWS E-Line unit and sheaves. NID perforating flange, E-Line lubricator extension, and BOPE. N/U flow nipple and riser pipe. P/U and M/U ESP Assy. PJSM. Continue making up ESP assembly & RIH on 2 7/8", 6.5#, L-80, EUE 8 rnd tubing. Check cable every 2000'. PJSM. Make splice in ESP cable. Continue RIH w/ new ESP completion. Check cable every 2000'. PJSM. Start reel-to-reel splice wi 165 stands of 2-7/8" tbg in the hole, 9 remaining in the derrick. Make reel-to-reel cable splice. Complete RIH wi ESP completion on 9 stds 2-7/8" from derrick. Checked cable every 2000'. Utilized: 5 Protectolizers, 3 Flat Guards, & 269 LaSalle Clamps. M/U hanger & landing jt. P/U wt = 109K; S/O wt = 20K. Install penetrator & make Lower Connector field splice. Check same. Good. Land hanger, RILDS. UD landing joint. Set TWC and test to 1000 psi. N/D BOPE. N/U Tree and test to 5000 psi. Final ESP test--good. P/U lubricator and pull TWC, set BPV. Secure tree and cellar. Release rig_11 00 hours. Printed: 11/22/2004 10:20:59 AM A hCa_red ices rii.ljjn TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20' AAC 25.110. As discussed this morning we propose Setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8,' x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if i maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 SCANNED $ 2002 ANNULAR INJECTION DATA ENTRY SCREEN Asset Uilr}.e. .......................................... Rig Name ~.¢ll~.Qr~..~.7..F,, ............................. Inj Well Name M..P...F.r.~.~. ..................................... Sur Csg Dep ~.~.(~.1 ................. CumulatiVe Data Legal Desc .I..9.~.~.'.~.~.;~.?.:3.1.'.~.F,,L,..~.e~..§,.T..1.:3~,..B.1.QE .................................... Permit Start ......... 1.~/.6.~/.~.5 ........ Permit End .......~.~.:~.1/.~t.5. ....... *Permit Expires in 30 Days or Less* Cor on Formation Final ., Fluids Freeze Rig Well Total MUd/Ctg Wash: ..... :..~,:~.3.:~....; ............. ~,.1.5Z ........................................................................................................................................... :7.5. .......... :. Daily Data .................. Mi~I,~,C~ ................................................................................ I~ ......... F'r~ .... Souce Date of C(xtan-inatedRig Wash ~ F~ Freeze Freeze Daly Well InjeclionDflg Mud Ruids Fluids' Fluids ~ Proledion Tolai MPF-30i 2/06/95 205 205 MPF-30i 2/07/95 110 110 MPF-30i 2/08/95 300 300 MPF-30i 2/09/95 620 ................. 620 . MPF-30i 2/10/95 300 300 MPF-30i 2/11/95 2,260 2,260 MPF-30i 12/12/95 210 210 MPF-30i 12/13/95 490 490 --,'~"'"""1~',30i .................... 12/14/95 450 . 450 j~L30i 'i"~'i"~)~'~ ...................... §~ ......................................................................................................................................................................................................................................................................................................... §'~'i~ .................................. is'i~':§6i ....................... i'~/'~'i~?[i~ .................... '6'6'6 ....................................................................................................................................................................................................................................................................... ~'~ .......................... [vi~:§i~i ........ i~Ji'~/~ .......... ~ ................................................................................................................ §i~ ' Open 1995 Year End Summary , MPF-30i MPF-30i MPF-30i MPF-30i MPF-30i MPF-30i 12/18/95 135 135 12/19/95 120 120 12/20/95 240 240 12/21/95 150 150 , __ 12/22/95 1,027 1,027 '!~.~?~.~ii i'.ii?~ ............................. /. ................................................................................................ -~- .............. ~'~ ....................... ,, eared rvices rilling 900 East Benson Boulevard, MB 8'1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 141998 Alaska 0il & Gas Cons, Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular' Disposal Records from July 25, 1995 through preSent time. We compared your list with Our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the ssD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are proVided to yOu in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & ~$v2, K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because 'the waste materials generated, from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disPosal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular dispoSal: ,Annular Disposal Letter 12/14/98 ! · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdough #3 - ~L~° ~4 ,~ ' · M11nePointwellsF-06,~-05,/-I-06, J'13, L-24 - · PBU wells-18-30, 18-31, 14z~A,.S_~-43, E-34, E-36, G-04A, and S-33- · Individual logs are provided to ~ou fof tl~es~ ~'ogs/ts we~l. · Finally, our records show that the B-24 outer annulus was left Open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, . Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED oEc !4. 1998-. Alaska Oil & 6as Cons, ¢oommissio~ Anchora,ge uedo' /.6/8 Lit, 96/8 I./t, 00 L G89 98~ 859'8 I. 809'61. =11. I. 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'N I. 1.1 '~ 'oeS '"F:I/~ ,08 I.g "]SN ,6t,/_.t, 6~88 9t'-S I. SO t' I. uo,~ uedo g6/LS/-&l. ~6//.J1.1. 06 600'~ 806 ~00'8 3t, H:I 'N1.1.1'~;~ oes '93~,996*1;, '"ISN,St,98 G I.(:J8 L'l;,-cJ 1. t'l. uo~ VI .... U'~d0 ............ 96i~1. ...... 96/g/~1~ 09 ~/.~'1. ..... 8[~;~ 6/-8,~~ 8~'g~ ' :1911-1 'N~;~1. ~S peqoeoJ8 g6/LS/~ g6/1.8/8 0gl. 6~/.'6 6/_8'6 39LH 'N~1.1'98 oas "13M, t'1. L~ '-ISN,/- 1.~ 81.09 g~-~/88-1, gt UO~, Uedo ..... 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Nabors 28E E-39 3638 3358'NSL 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A 3509 2917'NSL 1974'WEL, Sec 12.T11N, R13E 5,937 1,798 1.824 2,315 10/20/95 12/31/95 Open Nabors 28E G-21 3509 2911'NSL, 2368'WEL, Sec 12,T11N, R14E 11,430 3,956 3,072 4,270 70 '62 9/8/95 12/31/95 Open Nabors 28E S-24 2750 ' 1633'SNL, 4228'WEL, Sec 35.T12N, R12E 20.261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open Nabors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open Nabors 28E S-41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 Open Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open ...N..?..b...o.r.s..~...E..s- ..................... ..H.~..3..5 .......................................... _3..1....5....7. ........................... ~ ~ ~?..s...L_,,...?..6..6_'...W...E_ L..,....~ e....c_.2..!.., .T..!_ !,...N_,.....R_I., .3~ ............ _4,_8_60 ........................ 3,7_2.5. .................... .52.5- 480 20 80 10/26/95 12/31/95 Open N.a~b.O.~..~.E.? .............. !"!;~3~ .................................. ~..5.? ........................... ~ .4...-~.87.~!:,....!.~65.,.~..E...L.L.S.~c....2.!..,.'[ !_.!..N.,_R.!..3.E. ....................... !.L4...5..~ ....................................... 8..5..7.. ................................... !..o....o. .................................. _4..!..o. .................................................................................................................................... $C^NNF. D t OV 1 $ 200 Page 3 T~ ON P E M A_ ~ E IA L U N D~W T H ~S M A R K £ R C:LORI~:HLM. DOC . ~~'"'"~"'--'~"~'~ .... STATE OF ALASKA ALASK/-,, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 []Operation Shutdown []Stimulate [] Pull Tubing l--lAIter Casing [] Repair Well [] Other 5. Type of well:, . I~ Development I--I Exploratory [] Stratigraphic [] Service 4. Location of well at surface 1994' NSL, 2731' WEL, SEC. 6, T13N, R10E At top of productive interval 170' NSL, 3852' WEL, SEC. 19, T14N, R10E At effective depth 352' NSL, 3807' WEL, SEC. 19, T14N, R10E At total depth 423' NSL, 3870' WEL, SEC. 19, T14N, R10E [] Plugging [] Perforate 6. Datum Elevation (DF or KB) KBE: 45.46' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-38 9. Permit Number / Approval No. 95-168 10. APl Number 50-029-22614 11. Field and Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 17588 feet Plugs (measured) 7671 feet 17472 feet Junk (measured) 7582 feet Length Size 110' 20" 8525' 9-5/8" 17535' Cemented 260 sx Arctic Set (Approx.) 1630 sx PF 'E', 250 sx 'G', 200 sx PF 'C' 217 sx Class 'G' MD TVD 110' 110' 8561' 4475' 17568' 7655' Perforation depth: measured true vertical 17199'-17243' 7373'-7406' ORigINAL Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 16747' Packers and SSSV (type and measured depth) None RECEIVED OCT 2 3 ' 999 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0il & Gas 00ns, Commission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [~ Oil [] Gas I--I Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ Terrie Hubble, Title Technical Assistant III Prepared By Name/Number: Date 10'2'7-¢? Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility M Pt F Pad Progress Report Well MPF-38 Page 1 Rig Nabors 4ES Date 27 October 99 Date/Time 15 Oct 99 16 Oct 99 17 Oct 99 18:00-02:00 18:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00 06:00-09:00 06:00-09:00 09:00 09:00-17:00 09:00-17:00 17:00 17:00-19:00 17:00-19:00 19:00 19:00-22:30 19:00-22:30 22:30 22:30-01:30 22:30-01:30 01:30 01:30-02:30 01:30-02:30 02:30 02:30-06:00 02:30-06:00 06:00 06:00-16:00 06:00-10:30 10:30 10:30-16:00 16:00 16:00-22:30 16:00-17:00 17:00 17:00-19:30 Duration 8hr 8hr 4hr 4hr 3hr 3hr 8hr 8hr 2hr 2hr 3-1/2 hr 3-1/2 hr 3hr 3hr lhr lhr 3-1/2 hr 3-1/2 hr 10hr 4-1/2 hr 5-1/2 hr 6-1/2 hr lhr 2-1/2 hr Activity Move rig Rig moved 100.00 % rig leveled & bermed & safed out. At well location - Slot Wellhead work Removed Hanger plug Rig lines to thrash tank & rig lub & pull bpv & take on sea he0 Equipment work completed Wellhead work (cont...) Rigged up Accessories Continue rigging lines to tree & Tiger Tank. Equipment work completed Well control Circulated closed in well at 16749.0 ft Well control risk assessment & metigation. & test lines to 3000 psi. & displace well bore fluids with 9.4 ppg. brine & sitp=110, psi. raise brine wt. to 9.9 ppg. & kill & monitor well static. Influx Out of hole Wellhead work Rigged down Xmas tree set twc & test to 2500 psi. & rig dn tree. Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Test waived by John Spaulding with AOGC Wellhead work Removed Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 0.0 ft Rig floor & attempt to pull hanger to floor & observed drag work pipe & prepare to spot lube tex to metal to metal wetting agent, to give Observed 18.00 klb overpull Pull Single completion, 2-7/8in O.D. (cont...) Worked stuck pipe at 16749.0 ft Work tbg. & pump E-P lube & Lube tex to free pump & tbg. Pipe came free Pulled Tubing in stands to 9873.0 ft lay dn hanger & pull completion. Began precautionary measures Wellhead work Set Retrievable packer at 84.0 ft with 0.0 psi Make up baker storm packer on tbg. string & set @ 84' rt- & test to 1000 psi. Packer set at 84.0 ft Removed BOP stack Facility Date/Time 18 Oct 99 19 Oct 99 M Pt F Pad Progress Report Well MPF-38 Page 2 Rig Nabors 4ES Date 27 October 99 19:30 19:30-22:30 22:30 22:30-00:00 22:30-00:00 00:00 00:00-01:00 00:00-01:00 01:00 01:00-02:00 01:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00 06:00-11:30 06:00-11:30 11:30 11:30-17:00 11:30-17:00 17:00 17:00-06:00 17:00-06:00 06:00 06:00-13:30 06:00-13:30 13:30 13:30-15:00 13:30-15:00 15:00 15:00-06:00 15:00-18:00 18:00 Duration 3hr 1-1/2 hr 1-1/2 hr lhr lhr lhr lhr 4hr 4hr 5-1/2 hr 5-1/2 hr 5-1/2 hr 5-1/2 hr 13hr 13hr 7-1/2 hr 7-1/2 hr 1-1/2 hr 1-1/2 hr 15hr 3hr Activity Equipment work completed Installed Tubing head spool ND TBG. SPOOL & CHANG PACKOFF & NU GEN5A TEST TO 5000 PSI. Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack SET PLUG & TEST BOP TO 250 LOW & 3500 HIGH. Pressure test completed successfully - 3500.000 psi 3-1/2in. Drillpipe workstring run Ran Drillpipe to 84.0 ft (3-1/2in OD) RIH & EQUALIZE & MONITOR FOR PSI. & RELEASE & STORM PKR TO FLOOR & LAY DN SAME. Completed run with Other sub-surface equipment to 84.0 ft Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 6500.0 ft Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Pulled Tubing in stands to 0.0 ft POOH & LAY DN ESP & LOST 2-BANDS IN HOLE. Completed operations Slickline wireline work Conducted slickline operations on Slickline equipment - Retrival run RIG HES & RECOVER LOST BAND WITH RUN TO 4400' GR/JB Completed run with Junk basket/gauge ring from 0.0 ft to 4400.0 ft Run Single completion, 2-7/8in O.D. Pulled Tubing in stands to 14000.0 ft MU & SERVICE ESP. & RIH WITH SAME AND MAKE MIDLINE SPLICE & FLUSH PUMP Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 16746.0 ft Ran comp. & make mid-line splice & make up hanger & landing jt. & connector to hanger. Hanger landed Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test same to 5000 psi. & pull twc & set bpv. & secure tree. & cellar. Equipment work completed PERMIT AOGCC Individual Well GeoloGical Materials Inventory DATA T DATA PLUS PaGe: Date: RUN 1 03/12/98 RECVD 95-168 04/o9/96 95-168 95-168 95-168 95-168 95-168 CDR- TVD c~'E P IA CDN- T~ ~' SEPIA CDR-MD ~ SEPIA CDN-MD ~ SEPIA 7201 ~'~ CDR/CDN 04/04/96 04/04/96 04/04/96 04/04/96 04/04/96 95-168 7261 L/T~ MWD - SPERRY 1,2 05/29/96 95-168 DGR/EWR - MD ~L~ SEPIA t ~-' ~ ~O 1,2 06/04/96 95-168 DGR/EWR - TVD ~'SEPIA (~ _ c/~/~ ? 10-407 ~ COMPLETION DATE ~/P&/?(~ / ~A~LY WEUL O~S ~ ~ /~/~? TO ;~ ~/ Are dry ditch samples re~ired? yes ~ ~d received? Was the well cored? yes ~. ~alysis & description received? required? yes ~o Received? y~,~--,n~, ,~ Are well tests Well is in compliance ~ Initial COMMENTS 1,2 06/04/96 T STATE OF ALASKA - ALASI".,-. OIL AND GAS CONSERVATION C~,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-168 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1'~~'.~'~ 50-029-22614 4. Location of well at surface ~--~'- .'-~':~ :~ ~:--~"~?~"~'"---'~ ~"" ""'!~ ~ff:¢,~, i 9. Unit or Lease Name 1994'. NSL, 2731' WEL, SEC. 6, T13N, R10E Milne Point Unit At top of productive interval i .~./~.?~"~~. ~ i~ 10. Well Number .s., w.., s.c. 19, Ti ., .10.--- i At total depth _ ~j¢.~'"'-'_/'-.¢ -----~---"~'"' '~'~ ~-' ~" ~! .... 11. Field and Pool 423' NSL, 3870' WEL, SEC. 19, T14N, R10E Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate' KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE - 45.46'I ADL 355016 i12. Date Spudded11/12/95 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' water depth' if OffshOre 116' NO' Of COmpletiOns11/26/95 03/22/96 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey 20. Depth where SSSV set~21. Thickness of Permafrost 17588 7671 FT 17472 7582 F'r] [] Yes [] No N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, Gyro, GR, RES, NED, DEN 23. CASING, LINER AND CEMENTING RECORD CASING SE'FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT80LHE Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 36' 8561' 12-1/4" 1630 sx PF 'E', 250 sx 'G', 200 sx PF 'C' 7" 26# L-80 33' 17568' 8-1/2" 217 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 16750' MD TVD MD TVD 17199' - 17243' 7373' - 7406' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 17199' - 17243' Frac'd w/42,850# 16/20 Carbolite Behind Pipe 17199' - 17243' Frac'd w/115,000# 16/20 Carbolite Behind Pipe Freeze Protect with 85 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) May 18, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED II~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE BAT_A...~ ~~_-- Brief description of lithology, porosity, fractures, apparent dips and pr~ser1~s~r~w~ l~bmit core chips. SEP ~ 0 '~996 Alaska 0ii & G;~s Cons, Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate "' Geologic Mark ~ 30. Formation Tests ,,, Measured True Vertical Include interval tested, pressure data, ali fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Kuparuk D 17022' 7242' Kuparuk C 17132' 7323' Kuparuk B 17132' 7323' Kuparuk A 17170' 7351' Kuparuk A3 17174' 7354' Kuparuk A2 17192' 7367' Kuparuk A1 17222' 7390' Miluveach 17308' 7455' "31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is trueland cor,~e~t to the best of my knowledge Signed ~ ~'~ ~~.~ Senior Date Tim Schofield Title Drilling Engineer ,. Prepared By Name/Number: Terrie Hubbl¢, 56~1-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage 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 CsgDep 16678 Su~ I Well Cum Total Cum Mud/Ctg AININ JILA I ATA ASE ILO Cum Water Cum Dies/FP Cum Brine Legal Desc (Sec, T, R) VOLUME (BBLS' ~,lethod of displosal=pumping down outer annulus SOURCE WELL DATE OF DIESEL/FREEZE I Daily Cum. Total COMPLICATIONS, COMMENTS NUMBER INJECTION MUD/CTGS BRINE WATER PROT. I UP F-38 1 1/1 3/95 200.00 MP F-38 11/14/95 274.00 M P F-38 1 1 / 1 5 / 9 5 200.00 MR F-38 1 1/16/95 650.00 MP F-38 11/1 7/95 310.00 a P F-38 1 1 / 1 9 / 9 5 320. 00 UP F-38 1 1/20/95 181.00 MP F-38 1 1/21/9 5 665.00 UP F-38 11/23/95 675.00 ?F-38 11/24/95 4~.00 MP F-38 1 1/25/95 271.00 MP F-38 1 1/26/95 167.00 UP F-38 1 1 / 2 7 / 9 5 385.00 ~[~?~?~?~[~?:~[~?~ ~[~:~ ~ M P F-38 1 1 / 2 8 / 9 5 477.00 U P F-38 1 1 / 3 0 / 9 5 260.00 MP F-38 12/1/95 315.00 MP F-38 1 2/2/95 1346.00 75.001~?,~{~ I BP/AAI SHARED SERVICE DAILY OPERATION~ PAGE: 1 WELL: MPF-38 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/11/95 08:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 27E WO/C RIG: NABORS 27E 11/12/95 ( 1) TD: 110'( 0) 11/13/95 (2) TD: 1140' (1030) 11/14/95 ( 3) TD: 3750' (2610) 11/15/95 ( 4) TD: 5740' (1990) 11/16/95 ( 5) TD: 7190' (1450) 11/17/95 ( 6) TD: 8580' (1390) 11/18/95 ( 7) TD: 8580' ( 0) MAKE UP STANDS OF DP MW: 0.0 VIS: 0 MIRU. MOVE FROM MPF-62I TO MPF-38. RIG ACCEPTED @ 2000 HRS., 11/11/95. SPOT TESCO POWER UNIT & BERM UP. TAKE ON WATER IN PITS. NU DIVERTER SYSTEM. MIX MUD. MU STANDS OF DP & STAND BACK IN DERRICK. DRILLING MW: 0.0 VIS: 0 MU DP & STAND BACK IN DERRICK. INSPECT & FUNCTION TEST DIVERTER. WITNESSED BY JOHN SPAULDING. MU STDS OF DP. BRING BHS TO FLOOR. MU BHA. 45 DEGREE ELBOW PUT BETWEEN ROTARY HOSE & TOP DRIVE. DRILL T/ll0' T/272'. POOH, PU REST OF DC & STAB. DRILL F/272' T/l140' DRILLING MW: 0.0 VIS: 0 DRILL F/1140' T/3162'. PUMP LO-HI VIS SWEEP, CIRC HOLE CLEAN. MONITOR WELL. POOH T/l140'. RIH, TOOK WEIGHT @ 2373, WORKED PIPE, WENT AWAY. NO FILL. DRILL F/3162' T/3750' TRIP FOR BIT MW: 0.0 VIS: 0 DRILL F/3750' T/5017'. PUMP LO-HI VIS SWEEP. CIRC HOLE CLEAN_ SHORT TRIP T/3537'. NO FILL. DRILL F/5017' T/5740'. PUMP LO-HI VIS SWEEP. CIRC HOLE CLEAN. CHECK FOR FLOW. BLOW DOWN LINES. POOH FOR BIT. DRILLING MW: 0.0 VIS: 0 FINISH POOH FOR BIT. CHANGE BIT & ORIENT. DOWNLOAD MWD. CHANGE OUT MPT & ORIENT. CHANGE TOP STAB BLADE. PU SINGLES OF PIPE, RIH. CHECK SHOT @ 5204' RIH T/5679' REAM F/5679' T/5740'. DRILLED F/5740' T/7190'. PREP FOR SHORT TRIP MW: 0.0 VIS:0 DRILLING F/7190' T/7472'. CIRC LO-HI VIS SWEEP. MONITOR. PUMP DRY JOB. BLOW DOWN LINES. SHORT TRIP. DRILLING F/7472' T/8580'. CIRC LO-HI VIS SWEEP. MONITOR WELL. PUMP DRY JOB. BLOW DOWN LINES. RUNNING CASING MW: 0.0 VIS: 0 FINISH CIRC HOLE CLEAN. MONITOR WELL. OK. SHORT TRIP OUT TO HWDP. SLIP & CUT DRILL LINE. RIH. CIRC & COND TO RUN CASING. MONITOR. OK. PUMP DRY JOB. POOH. MONITOR WELL @ HWDP & DC. LD BHA. DOWNLOAD MWD. CLEAR FLOOR TO RUN 9-5/8" CASING. RUN 9-5/8" CASING. RECEIVED S EP 5 0 199G Alaska Oil & Gas Cons. Commission Anchorage WELL : MPF-38 OPERATION: RIG : NABORS 27E PAGE: 2 11/19/95 ( 8) TD: 8580' ( 0) 11/20/95 (9) TD: 9341' ( 761) 11/21/95 (10) TD:10576' (1235) 11/22/95 (11) TD:12999' (2423) 11/23/95 (12) TD:14893' (1894) 11/24/95 (13) TD:16140' (1247) PREP TO PU BHA MW: 0.0 VIS: 0 FINISH RUNNING CASING. MU HANGER & LAND CASING. FS @ 8561', FC @ 8482'. RU CEMENT HEAD & LINES. CBU. TEST LINES. CEMENT & DISPLACED WITH WATER. BUMP PLUG. FLOATS HELD. CIP @ 1400 HRS., 11/18/95. RD HOWCO. BACK OUT & LD LANDING JT. ND DIVERTER. FLUSH BAG, VALVES & LINES WITH WATER. PERFORM TOP JOB. GOOD CEMENT TO SURFACE. INSTALL WH. NU BOPE. CHANGE OUT HYDRIL RUBBER. NU RISER & FLOWLINE. TEST BOPE & ANNULAR. OK. WITNESSING WAIVED BY LOU GRIMALDI WITH AOGCC. RD TEST EQUIP. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 LD 15' BAILS. CHANGE DIES IN GRABBER. RU TOP DRIVE F/DRILLPIPE. STRAP & CALIPER BHA. PLUG IN & LOAD SOURCES. SOURCE WOULD NOT SEAT IN CDN TOOL. POOH. BREAK DOWN CDN. STEAM ICE OUT OF TOOL BODY. PU SINGLES & STAND BACK. RUN 'G' PIPE IN HOLE. ADD EXTENSION BETWEEN TOP DRIVE GOOSE NECK & KELLY HOSE TO KEEP IT OFF TOP DRIVE BODY. FILL PIPE. RIH T/8466'. TEST CASING. OK. TAG PLUGS ON FC. DRILL PLUGS, FC & 30' CEMENT. RE-TEST CASING. OK. DRILL CEMENT, SHOE, RATHOLE & 10' NEW HOLE T/8590'. CBU. PERFORM LOT TO EMW. DRILLING F/8590' T/9341'. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILLING F/9341' T/10546'. CIRC LO-HI VIS SWEEP AROUND. MONITOR WELL. OK. PUMP DRY JOB. SHORT TRIP TO CASING SHOE. SERVICE TOP DRIVE. RIH. CIRC LO-HI VIS SWEEP AROUND. LD HYD ELEVATORS & SHORT BALLS. PU 15' BALLS & REGULAR ELEVATORS. NEEDED ADDITIONAL CLEARANCE FOR WIRELINE PACKOFF. RU ATLAS WIRELINE. PUMP DOWN GYRO T/4830'. RD WIRELINE. RU TESCO BALLS & ELEVATORS. RIH. NO FILL. DRILLING F/10546' T/10576' DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL F/10576' T/12621'. PUMP LO-HI SWEEP WHILE DRILLING BEFORE ST. MONITOR. OK. PUMP DRY JOB. BLOW DOWN LINES. SHORT TRIP. NO FILL. DRILLING F/12621' T/12999' DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILLING F/12999' T/13568'. CHANGE SWAB IN #2 PUMP. DRILLING F/13568' T/14517'. STARTED LOSING MUD WHILE DRILLING. STOP PUMPS & MONITOR WELL. HOLE GIVING FLUID BACK. CIRC LO-HI VIS SWEEP AROUND UNTIL CLEAN RETURNS. MONITOR WELL. FLOWED BACK & DIED. SHORT TRIP, PULLED SLOW. RIH SLOW. NO FILL, NO PROBLEMS. CIRC & COND MUD. DRILLING F/14517' T/14893' DRILLING MW: 0.0 VIS: 0 DRILLING F/14893' T/15270'. CHANGE SWAB IN #2 PUMP. DRILLING F/15270' T/16019' FINISH CIRC SWEEP OUT. MONITOR WELL. OK. DRY JOB. BLOWDOWN MUD LINE. SHORT TRIP. PRECAUTIONARY REAM TO BOTTOM. DRILLING F/16019' T/16140' RECEIVED SEP 3 0 99G Alaska Oil & (3as Cons. Commission Anchorage WELL : MPF-38 OPERATION: RIG : NABORS 27E PAGE: 3 11/25/95 (14) TD:16955' ( 815) 11/26/95 (15) TD:17426' ( 471) 11/27/95 (16) TD:17588' ( 162) 11/28/95 (17) TD:17588' ( 0) 11/29/95 (18) TD: 0 PB: 0 WEIGHT UP MUD SYSTEM MW: 0.0 VIS: 0 DRILLING F/16019' T/16405'. DRILLING F/16405' T/16525'. WO GUZZLER. DRILLING F/16525' T/16955'. WEIGHT UP MUD SYSTEM SLOWLY. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 CIRC & FINISH WEIGHT UP. MONITOR WELL. OK. DRY JOB. SHORT TRIP. NO FILL. WEIGHT MUD UP, STARTING LOSING MUD @ SURFACE. REDUCE PUMP RATE & STARTED LCM. AS LOSSES DEMINISH, INCREASE PUMP RATE. MUD WEIGHT LEVELED OUT. FULL RETURNS. DRILLING F/16955' T/17426' SHORT TRIP TO CSG SHOE MW: 0.0 VIS: 0 DRILLING F/17426' T/17588'. MONITOR WELL, GAINED MUD. CIRC LO/HI VIS SWEEP AROUND & COND HOLE WITH LCM. PUMP DRY JOB. BLOW DOWN LINES. POOH, SLOW. HOLE NOT TAKING CORRECT FILL. MONITOR WELL, NO FLOW. RIH. CBU. NO INDICATION OF OIL OR GAS AT SURFACE WITH BU. MONITOR WELL, GAINED & DIED. POOH SLOW. FILLING PIPE THRU TOP DRIVE. POOH TO LD BHA MW: 0.0 VIS: 0 BOPE TEST WAIVED BY DOUG AMOS WITH AOGCC. FINISH PULL INTO SURFACE SHOE. FILLING HOLE WITH TOP DRIVE. CIRC WHILE CUT & SLIP DRLG LINE. RIH SLOW. NO FILL. CIRC & COND MUD. PUMP & BACK REAM F/17588' T/16798'. POOH T/15270'. TRY TO BREAK CIRC. POOH T/14326'o TIGHT SPOT, HOLE SWABBING. TRY TO CIRC. CONT POOH TO CASING SHOE @ 8561'. SPOT DOWN SAPP PILL, ALLOW TO SOAK. CIRC ABOUT THE SAME. CONT TO POOH, HOLE PARTIALLY SWABBING. CIRC & COND MUD MW: 0.0 FINISH POOH WITH DP. LD BHA, UNLOAD LWD SOURCES. PULL WEAR RING. TEST BOPE. WITNESSING WAIVED BY DOUG AMOS WITH AOGCC. BLOW DOWN LINES, SET WEAR RING. MU BHA #4. START RIH. SLM & RABBIT. CIRC & COND MUD @ 4263' ROTATE & RECIP. CONT RIH T/8535'. CIRC & COND MUD. DROP LCM & WEIGHT. ROTATE & RECIP. RIH T/9581'. CIRC & COND MUD. DROP LCM & WEIGHT. ROTATE & RECIP. WELL : MPF-38 OPERATION: RIG : NABORS 27E PAGE: 4 11/30/95 (19) TD: 0 PB: 0 12/01/95 (20) TD: 0 PB: 0 12/02/95 (21) TD: 0 PB: 0 12/03/95 (22) TD: 0 PB: 0 SHORT TRIP TO RUN CSG MW: 0.0 CONT COND MUD. RIH T/10712'. SLM & RABBIT DP. CONT CIRC & COND MUD. ROTATE & RECIP. RIH T/11843'. SLM & RABBIT DP. CONT CIRC & COND MUD, ROTATE & RECIP. RIH T/12974'. SLM & RABBIT DP. CONT CIRC & COND MUD, ROTATE & RECIP. RIH T/14112' SLM & RABBIT DP. CONT CIRC & COND MUD, ROTATE & RECIP. RIH T/15245' SLM & RABBIT DP. CONT CIRC & COND MUD, ROTATE & RECIP. WASH DOWN T/16367'. SLM & RABBIT DP. CONT CIRC & COND MUD, ROTATE & RECIP. WASH DOWN T/17000'. WASH & REAM T/17588'. OK. SLM & RABBIT. PUMO LO-HI SWEEP. CIRC. MONITOR WELL. SHORT TRIP, PULLED TIGHT @ 17118'. REAM THROUGH, OK. RUN 7" CASING MW: 0.0 CIRC & COND HOLE FOR CASING. MONITOR WELL. POOH SLOW. PUMP DRY JOB. POOH, LD BHA. PULL WEAR RING. RU TO RUN CASING. RUN 7" CASING. LD CASING TOOLS MW: 0.0 RUN 7" CASING SLOWLY, HOLE TAKING FLUID. FILL EVERY JT. CIRC @ 9-5/8" CASING SHOE. CONT RUN CASING. MU HANGER & LANDING JT. LAND CASING. BREAK CIRC. PERFORM CEMENT JOB, DISPLACE WITH RIG PUMP. PRESSURE INCREASE WHEN PLUG BUMPED & CALC STROKES. BLEED OFF, CHECKED FLOATS. ANNULUS FLOWING, SHUT WELL IN, SIP BUILT T/340 PSI. BLEED OFF THRU CHOKE. PRESSURE CONTINUED TO DROP. ND BOPE MW: 0.0 LD CASING TOOLS. MONITOR ANNULUS. LD DP IN MOUSE HOLE. BLEED OFF ANNULUS. DRAIN STACK, WASH DOWN, LD LANDING JT, INSTALL 7" PACKOFF & TEST. INSTALL TUBING HANGER WITH 2-WAY CHECK INSTALLED. ND BOPE. RIG RELEASED @ 1200 HRS., 12/03/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED SEP 3 0 !996 Alaska Oil & G~s Con~. Commission Anchorzg~ gyro/data B.P. EXPLORATION F-PAD WELL NO. MPF-38 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Of 5.5" Drillpipe Survey date · 21 November 1995 Job number' AK1195G307 RECEIVED SEP 3 0 1996 Alaska 0il & AnChorage SR307.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 December 6, 1995 B.P. Exploration Petrotechnical Data Center, MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Re: F-PAD, WELL #MPF-38, MILNE POINT FIELD, AK Enclosed please find one (1) original (6) copies and (1) disk of the completed smwey of Well #MPF-38 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Robert J. Shoup Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK1195G307 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL. EQUIPMENT AND CHRONOLOGICAL REPORT SR307.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR307.DOC gyro/data DISCUSSION JOB NUMBER · AK1195G307 Tool 080 waS run in MPF-38 on ATLAS 5/16" Wireline inside 5.5 inch drillpipe. The survey was run without problems. SR307.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER · AK1195G307 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited: This report represents a directional survey of this well based on the original data obtained at the well site. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR307.DOC gyro/data 2. SURVEY DETAILS SR307.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK1195G307 CLIENT: B.P. EXPLORATION RIG: F-PAD LOCATION: MILNE POINT FIELD WELL: MPF-38 LATITUDE: 70.5050 N LONGITUDE: 149.5 W SURVEY DATE: 21-November 1995 SURVEY TYPE : MULTISHOT IN 5.5" drillpipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 44.7 feet 4830' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 100' from 0 feet to 1400 feet. 50' from 1400 feet to 3800 feet. 100' from 3800 feet to 4700 feet. 50 ' from 4700 feet to 4800 feet. UTM CO-ORDINATES: TARGET DIRECTION: 355.250 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR307.DOC gyro/data 3. OUTRUN SURVEY LISTING SR307.DOC A Gyro da t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AKl195G307 Run Date: 21-Nov-95 21:25:00 Surveyor: T.S. Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 355.250 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i r e c t i o n a I Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0o0 0.00 0.00 0.0 0.0 -44.7 0.00 0.0 0.0 0 - 4830 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALI, DEPTHS REFERENCE TO F-PAD R.K.B. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .20 179.14 100.0 -.2 55.3 .20 200.0 .28 195.80 200.0 -.6 155.3 .11 300.0 .36 215.37 300.0 -1.1 255.3 .13 400.0 .41 197.70 400.0 -1.6 355.3 .13 500.0 .32 179.31 500.0 -2.2 455.3 .14 600.0 1.89 355.76 600.0 -.9 555.3 2.22 700.0 4.98 2.24 699.8 5.1 655.1 3.10 800.0 5.75 4.73 799.3 14.3 754.6 .81 900.0 6.10 2.92 898.8 24.6 854.1 .40 1000.0 6.65 348.77 998.2 35.6 953.5 1.66 1100.0 6.98 .38 1097.5 47.4 1052.8 1.41 1200.0 9.00 3.21 1196.5 61.2 1151.8 2.06 1300.0 10.52 5.97 1295.1 77.9 1250.4 1.58 1400.0 11.13 5.28 1393.3 96.4 1348.6 .63 1450.0 11.88 359.64 1442.3 106.2 1397.6 2.71 1500.0 12.60 359.66 1491.2 116.8 1446.5 1.44 1550.0 13.05 359.07 1539.9 127.9 1495.2 .93 1600.0 14.27 357.73 1588.5 139.7 1543.8 2.53 1650.0 16.01 353.05 1636.8 152.7 1592.1 4.25 1700.0 17.60 347.18 1684.6 167.1 1639.9 4.65 .2 179.1 .6 186.0 1.1 196.0 1.8 199.7 2.4 197.1 1.2 221.6 5.1 351.3 14.4 359.2 24.7 1.1 35,7 359.4 47.4 358.2 61.3 359.1 78.2 .3 96.9 1.3 106.9 1.4 117.5 1.3 128.6 1.1 140.4 .9 153.3 .4 167.6 359.5 .18 S .00 E .59 S .06 W 1.08 S .31 W 1.68 S .60 W 2.30 S .70 W .93 S .82 W 5.05 N .78 W 14.38 N .19 W 24.68 N .49 E 35.67 N .37 W 47.42 N 1.45 61.31 N .98 78.20 N .41 96.88 N 2.25 106.84 N 2.66 117.44 N 2.59 E 128.54 N 2.47 E 140.34 N 2.13 E 153.34 N 1.05 E 167.56 N 1.46 W A Gyroda t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 1750.0 18.56 349.57 1732.2 1800.0 18.37 350.18 1779.6 1850.0 19.19 351.79 1826.9 1900.0 19.80 351.08 1874.1 1950.0 20.97 354.33 1920.9 182.5 198.3 214.3 231.0 248.4 1687.5 2.42 182.8 358.6 1734.9 .54 198.5 357.9 1782.2 1.94 214.5 357.4 1829.4 1.32 231.1 356.9 1876.2 3.25 248.4 356.6. 182.75 N 4.58 W 198.34 N 7.36 w 214.24 N 9.88 230.73 N 12.36 W 248.00 N 14.56 W 2000.0 21.99 352.21 1967.5 2050.0 22.84 349.98 2013.7 2100.0 24.62 351.46 2059.4 2150.0 25.75 351.29 2104.7 2200.0 27.50 351.94 2149.4 266.7 285.7 305.7 327.0 349.3 1922.8 2.57 266.7 356.4 1969.0 2.40 285.7 356.1 2014.7 3.76 305.7 355.7 2060.0 2.26 327.0 355.4 2104.7 3.53 349.3 355.2 266.18 N 16.71 W 285.01 N 19.67 W 304.87 N 22.91 W 325.91 N 26.10 W 348.08 N 29.36 W 2250.0 28.76 355.96 2193.5 2300.0 30.52 354.54 2236.9 2350.0 31.67 356.85 2279.8 2400.0 33.36 356.87 2321.9 2450.0 34.68 357.33 2363.4 372.9 397.6 423.4 450.3 478.2 2148.8 4.56 372.9 355.1 2192.2 3.79 397.6 355.1 2235.1 3.32 423.4 355.1 2277.2 3.39 450.3 355.3 2318.7 2.69 478.2 355.4 371.51 N 31.83 W 396.15 N 33.88 W 421.89 N 35.81 W 448.73 N 37.29 W 476.67 N 38.70 W 2500.0 35.59 357.17 2404.2 2550.0 36.51 357.63 2444.7 2600.0 37.23 357.70 2484.7 2650.0 38.25 357.05 2524.2 2700.0 39.51 357.84 2563.1 507.0 536.4 566.4 597.0 628.3 2359.5 2400.0 2440.0 2479.5 2518.4 1.82 507.0 355.5 1.92 536.4 355.6 1.44 566.4 355.7 2.19 597.0 355.8 2.71 628.3 355.9 505.41 N 40.08 534.80 N 41.41 564.78 N 42.63 W 595.35 N 44.04 W 626.70 N 45.43 W 2750.0 39.19 358.26 2601.8 2800.0 39.65 357.86 2640.4 2850.0 40.34 358.09 2678.7 2900.0 41.49 356.89 2716.5 2950.0 42.69 357.26 2753.6 660.0 691.7 723.8 756.5 790.0 2557.1 .82 660.0 356.0 2595.7 1.05 691.8 356.1 2634.0 1.41 723.9 356.1 2671.8 2.78 756.6 356.2 2708.9 2.44 790.1 356.2 658.39 N 46.51 W 690.12 N 47.59 W 722.24 N 48.72 W 754.95 N 50o16 W 788.42 N 51o86 W A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet sUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. Page 3 HORIZONTAL COORDINATES feet 3000.0 43.69 356.65 2790.1 3050.0 45.44 356.06 2825.7 3100.0 45.76 356.69 2860.7 3150.0 47.52 355.33 2895.0 3200.0 48.11 356.23 2928.6 824.2 859.3 895.0 931.4 968.4 2745.4 2781.0 2816.0 2850.3 2883.9 2.18 824.3 '356.3 3.59 859.4 356.3 1.10 895.2 356.3 4.04 931.5 356.3 1.78 968.6 356.2 822.60 N 53.68 W 857.61 N 55.92 ~'~ 893.26 N 58.17 929.53 N 60.71 W 966.47 N 63.43 W 3250.0 50.28 354.90 2961.2 3300.0 50.67 354.58 2993.1 3350.0 51.65 353.81 3024.4 3400.0 52.34 353.74 3055.2 3450.0 54.81 354.04 3084.9 1006.2 1044.8 1083.8 1123.1 1163.4 2916.5 2948.4 2979.7 3010.5 3040.2 4.79 1006.4 356.2 .93 1044.9 356.2 2.30 1083.9 356.1 1.37 1123.2 356.0 4.97 1163.4 355.9 1004.20 N 66.36 W 1042.61 N 69.90 W 1081.35 N 73.84 W 1120.52 N 78.11 W 1160.52 N 82.39 W 3500.0 56.61 352.88 3113.1 3550.0 57.96 353.12 3140.1 3600.0 59.23 352.78 3166.1 3650.0 60.40 353.25 3191.3 3700.0 61.45 352.62 3215.6 1204.6 1246.7 1289.3 1332.5 1376.2 3068.4 3095.4 3121.4 3146.6 3170.9 4.07 1204.7 355.9 2.74 1246.7 355.8 2.60 1289.3 355.7 2.48 1332.5 355.6 2.36 1376.2 355.5 1201.55 N 87.10 W 1243.31 N 92.22 W 1285.66 N 97.46 W 1328.55 N 102.72 W 1371.92 N 108.10 W 3750.0 63.51 352.22 3238.7 3800.0 64.61 353.36 3260.6 3900.0 67.97 352.40 3300.8 4000.0 70.85 350.90 3335.9 4100.0 73.85 351.24 3366.2 1420.4 1465.4 1556.8 1650.2 1745.3 3194.0 3215.9 3256.1 3291.2 3321.5 4.20 1420.4 355.4 3.00 1465.4 355.3 3.47 1556.8 355.2 3.20 1650.3 355.0 3.01 1745.3 354.8 1415.87 N 113.94 ". 1460.48 N 119.58 v~' 1551.32 N 130.95 W 1643.92 N 144.55 W 1738.05 N 159.34 W 4200.0 73.31 351.89 3394.5 4300.0 73.00 354.65 3423.5 4400.0 75.68 354.36 3450.5 4500.0 75.54 354.74 3475.3 4600.0 75.14 354.58 3500.6 1841.0 1936.6 2032.9 2129.8 2226.5 3349.8 3378.8 3405.8 3430.6 3455.9 .82 1841.1 354.6 2.66 1936.8 354.5 2.70 2033.1 354.5 .39 2129.9 354.5 .42 2226.7 354.5 1832.94 N 173.42 W 1927.97 N 184o64 W 2023.81 N 193o86 W 2120.24 N 203.06 W 2216.56 N 212.07 W A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA Page MEASURED I DEPTH feet N C L AZIMUTH VERTICAL DEPTH dego deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4700.0 77°95 353.65 3523.9 4750.0 77o10 355.75 3534.7 4800.0 76.59 355.42 3546.1 4830.0 76.81 356.46 3553.0 2323.7 3479.2 2.95 2323.9 354.5 2372.5 3490.0 4.45 2372.7 354.5 2421.2 3501.4 1.20 2421.4 354.5 2450.4 3508.3 3.47 2450.6 354.6 2313.29 N 2361.90 N 2410.44 N 2439.56 N 222.05 W 226.56 T,~ 230.31 232.37 W Final Station Closure: Distance: 2450.61 ft Az: 354.56 deg. A Gyr oda t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AKl195G307SS Run Date: 21-Nov-95 21:25:00 Surveyor: Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 355.250 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet -44.7 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0.0 N 0.0 E 0 - 4830 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALI, DEPTHS REFERENCE TO F-PAD R.K.B. 100.0 .24 186.59 144.7 -.4 .16 200.0 .32 204.55 244.7 -.8 .12 300.0 .38 207.47 344.7 -1.3 .13 400.0 .37 189.48 444.7 -1.9 .14 500.0 1.03 258.21 544.7 -1.6 1.07 600.0 3.28 358.66 644.7 1.8 2.61 700.0 5.32 3.37 744.7 9.3 2.07 800.0 5.91 3.91 844.7 19.0 .62 900.0 6.35 356.39 944.7 29.6 .98 1000.0 6.81 354.21 1044.7 41.1 1.54 1100.0 7.94 1.73 1144.7 54.0 1.72 1200.0 9.74 4.56 1244.7 69.4 1.83 1300.0 10.82 5.62 1344.7 87.2 1.10 1400.0 11.92 359.64 1444.7 106.8 2.65 1500.0 13.17 358.94 1544.7 129.1 1.08 1600.0 16.27 352.07 1644.7 155.1 4.31 1700.0 18.51 349.73 1744.7 186.7 1.92 1800.0 19.42 351.53 1844.7 220.6 1.70 1900.0 21.49 353.24 1944.7 257.7 2.90 2000.0 24.05 350.98 2044.7 299.3 3.32 .6 182.2 1.1 190.5 1.8 197.7 2.4 198.5 1.2 208.0 5.1 279.7 14.4 354.9 24.7 .1 35.7 .3 47.4 358.9 61.3 358.6 78.2 359.7 96.9 .8 117.5 1.4 140.4 1.1 167.6 .2 198.5 358.4 231.1 357.2 266.7 356.5 305.7 355.8 .4 S .OW .8 S .2 W 1.3 S .4 W 2.0 S .6 W 1.7 S .8 W 2.8 N .8 W 9.3 N .5 W 19.1 N .3 E 29.8 N .4 W 41.2 N .9 W 54.0 N 1.2 W 69.6 N .7 E 87.6 N 1.3 E 107.4 N 2.7 E 129.7 N 2.4 E 155.7 N 1.1 W 186.9 N 5.3 W 220.5 N 10.8 W 257.3 N 15.7 W 298.5 N 21.9 W A Gyrodat a D i re c t i on a i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307SS ALASKA Page SUBSEA 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 2100.0 27.31 351.87 2144.7 2200.0 30.73 354.96 2244.7 2300.0 34.09 357.12 2344.7 2400.0 36.51 357.63 2444.7 2500.0 38.91 357.47 2544.7 347.0 3.40 349.3 355.2 402.3 3.70 423.4 355.1 465.6 3.00 478.2 355.3 536.4 1.92 566.4 355.6 613.5 2.46 628.3 355.8 345.8 N 29.0 W 400.8 N 34.2 W 464.1 N 38.1 W 534.8 N 4]..4 W 611.9 N 44.8 W 2600.0 39.73 357.89 2644.7 2700.0 42.40 357.18 2744.7 2800.0 45.62 356.41 2844.7 2900.0 49.18 355.57 2944.7 3000.0 52.10 353.76 3044.7 695.3 1.09 723.9 356.1 782.0 2.53 790.1 356.2 878.7 2.24 895.2 356.3 987.1 3.26 1006.4 356.2 1109.7 1.69 1123.2 356.0 693.7 N 47.7 W 780.4 N 51.5 W 877.0 N 57.1 W 985.1 N 64.9 W 1107.1 N 76.7 W 3100.0 58.18 353.06 3144.7 3200.0 63.82 352.53 3244.7 3300.0 71.72 351.00 3344.7 3400.0 75.11 354.42 3444.7 3500.0 76.65 355.46 3544.7 1254.2 2.71 1289.3 355.7 1432.8 3.87 1465.4 355.4 1677.8 3.15 1745.3 354.9 2012.3 2.69 2033.1 354.5 2415.4 1.59 2421.4 354.5 1250.8 N 93.1 W 1428.1 N 115.5 W 1671.2 N 148.8 W 2003.3 N 191.9 W 2404.6 N 229°9 W 3508.3 76.81 356.46 3553.0 2450.4 3.47 2450.6 354.6 2439.6 N 232.4 W ~ Final Station Closure: Distance: 2450.61 ft Az: 354.56 deg. A Gyroda t a D i r e c t i on a i Survey for B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AKl195G307 Run Date: 21-Nov-95 21:25:00 Surveyor: Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction- 355.250 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet -44.7 0o00 0.00 0.0 0.0 0.00 0.0 ' 0.0 0.0 N 0.0 E 0'- 4830 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL DEPTHS REFERENCE TO F-PAD R.K.B. 55.3 .20 179.14 100.0 -.2 .20 155.3 .28 195.80 200.0 -.6 .11 255.3 .36 215.37 300.0 -1.1 .13 355.3 .41 197.70 400.0 -1.6 .13 455.3 .32 179.31 50'0.0 -2.2 .14 555.3 1.89 355.76 600.0 -.9 2.22 655.1 4.98 2.24 699.8 5.1 3.10 754.6 5.75 4.73 799.3 14.3 .81 854.1 6.10 2.92 898.8 24.6 .40 953.5 6.65 348.77 998.2 35.6 1.66 1052.8 6.98 .38 1097.5 47.4 1.41 1151.8 9.00 3.21 1196.5 61.2 2.06 1250.4 10.52 5.97 1295.1 77.9 1.58 1348.6 11.13 5.28 1393.3 96.4 .63 1397.6 11.88 359.64 1442.3 106.2 2.71 1446.5 12.60 359.66 1491.2 116.8 1.44 1495.2 13.05 359.07 1539.9 127.9 .93 1543.8 14.27 357.73 1588.5 139.7 2.53 1592.1 16.01 353.05 1636.8 152.7 4.25 1639.9 17.60 347.18 1684.6 167.1 4.65 .2 179.1 .6 186.0 1.1 196.0 1.8 199.'7 2.4 197.1 1.2 221.6 5.1 351.3 14.4 359.2 24.7 1.1 35.7 359.4 47.4 358.2 61.3 359.1 78.2 .3 96.9 1.3 106.9 1.4 117.5 1.3 128.6 1.1 140.4 .9 153.3 .4 167.6 359.5 .2 S .0 E .6 S .1 W 1.1 S .3 W 1.7 S .6 W 2.3 S .7 W .9 S .8 W 5.1 N .8 W 14.4 N .2 W 24.7 N .5 E 35.7 N .4 W 47.4 N 1.5 W 61.3 N 1.0 W 78.2 N .4 E 96.9 N 2.2 E 106.8 N 2.7 E 117.4 N 2.6 E 128.5 N 2.5 E 140.3 N 2.1 E 153.3 N 1.1 E 167.6 N 1.5 W A Gyr oda t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 1687.5 18o56 349.57 1732.2 1734.9 18.37 350.18 1779.6 1782.2 19.19 351.79 1826.9 1829.4 19o80 351.08 1874.1 1876.2 20.97 354.33 1920.9 182.5 198.3 214.3 231.0 248.4 2.42 .54 1.94 1.32 3.25 182.8 3'58.6 198.5 357.9 214.5 357.4 231.1 356.9 248.4 356.6 182.8 N 4.6 W 198.3 N 7.4 W 214.2 N 9.9 W 230.7 N 12.4 W 248.0 N 14.6 W 1922.8 21.99 352.21 1967.5 1969.0 22.84 349.98 2013.7 2014.7 24.62 351.46 2059.4 2060.0 25.75 351.29 2104.7 2104.7 27.50 351.94 2149.4 266.7 285.7 305.7 327.0 349.3 2.57 2.40 3 .76 2.26 3.53 266.7 356.4 285.7 356.1 305.7 355.7 327.0 355.4~ 349.3 355.2 266.2 N 16.7 W 285.0 N 19.7 W 304.9 N 22.9 W 325.9 N 26.1 W 348.1 N 29.4 W 2148.8 28.76 355.96 2193.5 2192.2 30.52 354.54 2236.9 2235.1 31.67 356.85 2279.8 2277.2 33.36 356.87 2321.9 2318.7 34.68 357.33 2363.4 372.9 397.6 423.4 450.3 478.2 4.56 3.79 3.32 3.39 2.69 372.9 355.1 397.6 355.1 423.4 355.1 450.3 355.3 478.2 355.4 371.5 N 31.8 W 396.1 N 33.9 W 421.9 N 35.8 W 448.7 N 37.3 W 476.7 N 38.7 W 2359.5 35.59 357.17 2404.2 2400.0 36.51 357.63 2444.7 2440.0 37.23 357.70 2484.7 2479.5 38.25 357.05 2524.2 2518.4 39.51 357.84 2563.1 507.0 536.4 566.4 597.0 628.3 1.82 1.92 1.44 2.19 2.71 507.0 355.5 536.4 355.6' 566.4 355.7 597.0 355.8 628.3 355.9 505.4 N 40.1 W 534.8 N 41.4 W 564.8 N 42.6 W 595.4 N 44.0 W 626.7 N 45.4 W 2557.1 39.19 358.26 2601.8 2595.7 39.65 357.86 2640.4 2634.0 40.34 358.09 2678.7 2671.8 41.49 356.89 2716.5 2708.9 42.69 357.26 2753.6 660.0 691.7 723.8 756.5 790.0 .82 1.05 1.41 2.78 2.44 660.0 356.0 691.8 356.1 723.9 356.1 756.6 356.2 790.1 356.2 658.4 N 46.5 W 690.1 N 47.6 W 722.2 N 48.7 W 755.0 N 50.2 W 788.4 N 51.9 W A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg. / 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2745.4 43.69 356.65 2790.1 2781.0 45.44 356.06 2825.7 2816.0 45.76 356.69 2860.7 2850.3 47.52 355.33 2895.0 2883.9 48.11 356.23 2928.6 824.2 859.3 895.0 931.4 968.4 2.18 3.59 1.10 4.04 1.78 824.3 356.3 859.4 356.3 895.2 356.3 931.5 356.3 968.6 356.2 822.6 N 53.7 W' 857.6 N 55.9 W 893.3 N 58.2 W 929.5 N 60.7 W 966.5 N 63.4 W 2916.5 50.28 354.90 2961.2 2948.4 50.67 354.58 2993.1 2979.7 51.65 353.81 3024.4 3010.5 52.34 353.74 3055.2 3040.2 54.81 354.04 3084.9 1006.2 1044.8 1083.8 1123.1 1163.4 4.79 .93 2.30 1.37 4.97 1006.4 356.2 1044.9 356.2 1083.9 356.1 1123.2 356.0 1163.4 355.9 1004.2 N 66.4 W 1042.6 N 69.9 W ' 1081.4 N 73.8 W 1120.5 N 78.1 W 1160.5 N 82.4 W 3068.4 56.61 352.88 3113.1 3095.4 57.96 353.12 3140.1 3121.4 59.23 352.78 3166.1 3146.6 60.40 353.25 3191.3 3170.9 61.45 352.62 3215.6 1204.6 1246.7 1289.3 1332.5 1376.2 4.07 2.74 2.60 2.48 2.36 1204.7 355.9 1246.7 355.8 1289.3 355.7 1332.5 355.6 1376.2 355.5 1201.6 N 87.1 W 1243.3 N 92.2 W 1285.7 N 97.5 W 1328.6 N 102.7 W 1371.9 N 108.1 W 3194.0 63.51 352.22 3238.7 3215.9 64.61 353.36 3260.6 3256.1 67.97 352.40 3300.8 3291.2 70.85 350.90 3335.9 3321.5 73.85 351.24 3366.2 1420.4 1465.4 1556.8 1650.2 1745.3 4.20 3.00 3.47 3 .20 3 .01 1420.4 355.4 1465.4 355.3 1556.8 355.2 1650.3 355.0 1745.3 354.8 1415.9 N 113.9 W 1460.5 N 119.6 W 1551.3 N 130.9 W 1643.9 N 144.5 W 1738.1 N 159.3 W 3349.8 73.31 351.89 3394.5 3378.8 73.00 354.65 3423.5 3405.8 75.68 354.36 3450.5 3430.6 75.54 354.74 3475.3 3455.9 75.14 354.58 3500.6 1841.0 1936.6 2032.9 2129.8 2226.5 .82 2.66 2.70 .39 .42 1841.1 354.6 1936.8 354.5 2033.1 354.5 2129.9 354.5 2226.7 354.5 1832.9 N 173.4 W 1928.0 N 184.6 W 2023.8 N 193.9 W 2120.2 N 203.1 W 2216.6 N 212.1 W A Gyro da t a D i r e c t i ona i Survey B.P. EXPLOP~ATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, Job Number: AKl195G307 ALASKA Page SUBSEA 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 3479.2 77.95 353.65 3523.9 3490.0 77o10 355.75 3534.7 3501.4 76.59 355.42 3546.1 3508.3 76.81 356.46 3553.0 2323.7 2.95 2323.9 354.5 2372.5 4.45 2372.7 354.5 2421.2 1.20 2421.4 354.5 2450.4 3.47 2450.6 354.6 2313.3 N 222.0 W 2361.9 N 226.6 W 2410.4 N 230.3 W 2439°6 N 232.4 W Final Station Closure: Distance: 2450.61 ft Az: 354.56 deg. gyro/data 4. QUALITY CONTROL SP,307.DOC Quality Control Comparisons B.P. EXPLORATION WELL: MPF-38, 5.5 Location: F PAD, MILNE POINT FIELD, ALASKA Job Number : AKl195G307 / AKl195G307 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN Depth Inc Inc Delta Az 1000.0 6.61 6.65 -.045 348.82 2000.0 21.94 21.99 -.052 352.66 3000°0 43.99 43.69 .295 356.78 4300.0 72.97 73.00 -.033 354.07 4700.0 78.04 77.95 ..084 354.15 4800.0 76.59 76.59 .001 356.08 For Inclinations Greater than 1 degrees: Average Inclination Difference = .04159 deg. Average Azimuth Difference = .20177 deg. OUTRUN Az 348.77 352.21 356.65 354.65 353.65 355.42 Delta .047 .451 .132 -.575 .495 .660 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK1195G307 TOOL NUMBER: 080 MAXIMUM GYRO TEMPERATURE: 74.75 C MAXIMUM AMBIENT TEMPERATURE: 40.1 C MAXIMUM INCLINATION: 78.04 deg AVERAGE AZIMUTH: 354.5368 WIRELINE REZERO VALUE: 0 Feet REZERO ERROR / K: .003 CALIBRATION USED FOR FIELD SURVEY: 1243 CALIBRATION USED FOR FINAL SURVEY: 1243 PRE JOB MASS BALANCE OFFSET CHECK: -.20 POST JOB MASS BALANCE OFFSET CHECK] · CONDITION OF SHOCK WATCHES -.25 USED -.25 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 4830.0 76.81 356.46 3553.0 2439.76N 231.37W FINAL SURVEY 4830.0 76.81 356.46 3553.0 2439.56N 232.37W SR307.DOC gyro/data SR307.DOC gyro/data FUNCTION TEST JOB NUMBER: AK1195G307 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 3000 43.69 43.69 43.70 43.70 43.70 AZIMUTH M.D. ft 1 2 3 4 5 3000 356.65 356.86 356.80 356.86 356.88 SR307.DOC gyro/data 5..EQUIPMENT AND CHRONOLOGICAL REPORT SR307.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK1195G307 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0080 DATA SECTION C0031 POWER SECTION C0006 COMPUTER POWER SUPPLY PRINTER INTERFACE A0213 A0085 A0029 A0035 BACKUP TOOL No. 713 GYRO SECTION A0035 DATA SECTION C0058 POWER SECTION C0016 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0055 A0079 A0071 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: 18 feet MAXIMUM O.D.: 2.5 INCHES TOTAL WEIGHT OF TOOL: 220Lbs SR307.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK1195G307 11/21/95 1900 2030 230O 2325 11/22/95 0000 0200 O4OO 0445 0630 ENROUTE TO MILNE POINT ARRIVED IN LOCATION RIG UP ATLAS PICK UP TOOL, START RUN PUMP TOOL TO 4800 SURVEYING OUT LAY DOWN TOOL PROCESSING SURVEY. RETURN TO ATLAS. CLEANED & PACKED TOOLS. SR307.DOC BP EXPLORATION (ALASKA) INC MILNE PT/MPF-38 500292261400 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 111795 MWD SURVEY JOB NUMBER: AK-MM-951158 KELLY BUSHING ELEV. = 45.46 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGLrLAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -45.46 193 193.60 148.14 239 239.16 193.70 328 328.06 282.60 416 416.92 371.46 0 0 N .00 E .00 .00N .00E .00 0 27 S 26.20 W .23 .68S .34W -.65 0 27 S 4.06 W .38 1.03S .43W -.99 0 40 S 14.51 W .26 1.88S .58W -1.83 0 48 S 10.46 W .17 3.01S .83W -2.93 508 508.57 463.11 596 596.67 551.21 685 685.35 639.89 775 775.28 729.82 869 868.85 823.39 0 54 S 20.91 W .20 4.31S 1.20W -4.20 '0 21 S 2.77 E .67 5.24S 1.44W -5.10 2 11 N 1.04 E 2.87 3.82S 1.39W -3.69 4 52 N 2.91 E 2.98 1.72N 1.17W 1.81 5 19 N 2.90 E .49 10.06N .74W 10.09 966 964.98 919.52 1060 1059.13 1013.67 1154 1152.25 1106.79 1249 1245.51 1200.05 1344 1339.15 1293.69 6 23 N 2.57 E 1.10 19.92N .27W 19.87 6 49 N 2.43 E .45 30.81N .20E 30.69 8 30 N 1.52 E 1.79 43.32N .62E 43.12 10 6.~ N_. 4.61 E 1.78 58.58N 1.47E 58.25 10 49 N 5.55 E .77 75.80N 3.01E 75.29 1436 1429.50 1384.04 1534 1524.72 1479.26 1629 1616.46 1571.00 1721 1704.67 1659.21 1818 1796.68 1751.22 12 6 N 1.07 E 1.69 94.08N 4.03E 93.42 13 3 N .80 W 1.07 115.32N 4.06E 114.59 15 34 N 6.02 W 2.99 138.67N 2.58E 137.98 18 40 N 9.23 W 3.51 165.60N 1.09W 165.12 18 56 N 9.95 W .36 196.50N 6.31W 196.35 1912 1884.98 1839.52 2007 1973.19 1927.73 2101 2059.46 2014.00 2197 2145.35 2099.89 2293 2229.28 2183.82 20 27 N 7.26 W 1.89 227.75N ll.02W 227.88 22 34 N 5.96 W 2.29 262.~1N 15.00W 262.65 25 19 N 5.78 W 2.91 300.43N 18.92W 300.97 27 42 N 5.80 W 2.47 343.06N 23.24W 343.81 30 40 N 3.05 W 3.39 389.80N 26.80W 390.68 2388 2309.63 2264.17 2484 2388.65 2343.19 2579 2464.67 2419.21 2673 2538.61 2493.15 2769 2612.15 2566.69 33 34 N 3.53 W 3.07 440.16N 29.71W 441.10 35 50 'N 2.98 W 2.38 494.79N 32.81W 495.81 37 21 N 3.11 W 1.61 551.17N 35.81W 552.24 39 30 N 2.35 W 2.33 609.78N 38.59W 610.88 39 32 N 1.79 W .38 670.42N 40.79W 671.49 2863 2684.21 2638.75 2957 2753.80 2708.34 3051 2820.78 2775.32 3147 2886.44 2840.98 3242 2948.74 2903.28 40 58 N 2.05 W 1.54 731.40N 42.83W 732.44 43 28 N 2.36 W 2.67 794.53N 45.27W 795.55 45 42 N 3.38 W 2.48 860.47N 48.58W 861.54 47 27 N 3.67 W 1.86 929.72N 52.85W 930.91 50 25 N 4.66 W 3.23 1001.05N 58.06W 1002.42 RECEIVED $£P ,.3 0 1996 Alaska OJJ & Gas Cons. Commission Anchorage SPE~...Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPF-38 500292261400 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 111795 MWD SURVEY JOB NUMBER: AK-MM-951158 KELLY BUSHING ELEV. = 45.46 OPERATOR: BP EXPLORATION FT. 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 VERT. SECT. 3335 3007.26 2961.80 3428 3062.48 3017.02 3523 3115.44 3069.98 3615 3162.96 3117.50 3711 3208.48 3163.02 52 8 54 34 57 48 60 12 62 48 N 5.53 W 1.97 1073.77N 64.55W N 5.09 W 2.66 1147.69N 71.42W N 6.22 W 3.53 1226.41N 79.23W N 6.39 W 2.60 1305.04N 87.92W N 6.23 W 2.73 1388.40N 97.13W 1075.43 1149.66 1228.75 1307.84 1391.68 3806 3249.68 3204.22 65 43 3900 3286.46 3241.00 68 28 3995 3318.97 3273.51 71 15 4086 3346.72 3301.26 73 33 4182 3373.38 3327.92 73 54 N 6.71 W 3.11 1473.36N 106.77W N 8.05 W 3.19 1559.72N 117.97W N 8.24 W 2.94 1647.50N 130.53W N 8.43 W 2.51 1734.06N 143.21W N 7.05 W 1.44 1824.52N 155.51W 1477.14 1564.14 1652.65 1739.96 1831.13 4278 3400.67 3355.21 4372 3426.24 3380.78 4467 3449.88 3404.42 4561 3473.47 3428.01 4654 3495.53 3450.07 73 9 75 27 75 44 74 57 77 39 N 4.91 W 2.27 1916.31N 165.13W N 5.39 W 2.48 2006.97N 173.30W N 4.57 W .89 2098.71N 181.29W N 3.64 W 1.28 2188.68N 187.75W N 4.05 W 2.93 2279.06N 193.83W 1923.40 2014.43 2106.52 2196.71 2287.28 4747 3515.97 3470.51 76 57 4843 3537.96 3492.50 76 32 4935 3559.91 3514.45 75 47 5032 3584.09 3538.63 75 26 5127 3608.16 3562.70 75 13 N 3.38 W 1.03 2369.64N 199.71W N 3.44 W .44 2462.87N 205.27W N 3.24 W .84 2551.86N 210.46W N 3.54 W .46 2645.99N 216.04W N 3.07 W .54 2737.80N 221.34W 2378.04 2471.41 2560.52 2654.79 2746.73 5219 3632.12 3586.66 5313 3655.87 3610.41 5408 3678.90 3633.44 5504 3702.84 3657.38 5598 3727.27 3681.81 74 35 76 2 75 52 75 13 74 49 N 2.83 W .72 2826.56N 225.91W N 3.37 W 1.63 2917.07N 230.82W N 2.73 W .68 3009.03N 235.72W N 3.67 W 1.16 3101.76N 240.90W N 4.39 W .85 3192.90N 247.32W 2835.56 2926.16 3018.21 3111.06 3202.41 5693 3751.75 3706.29 75 18 5789 3776.25 3730.79 74 59 5883 3800.39 3754.93 75 24 5979 3824.19 3778.73 75 51 6071 3847.47 3802.01 74 43 N 3.80 W .78 3284.45N 253.87W N 4.17 W .50 3376.57N 260.29W N 3.85 W .55 3467.72N 266.68W N 3.94 W .48 3560.47N 272.99W N 3.48 W 1.32 3648.95N 278.73W 3294.19 3386.53 3477.90 3570.84 3659.50 6166 3871.68 3826.22 6258 3893.61 3848.15 6354 3916.42 3870.96 6448 3940.44 3894.98 6543 3964.36 3918.90 75 43 76 38 75 50 74 40 76 2 N 4.05 W 1.19 3740.55N 284.76W N 4.20 W 1.01 3829.48N 291.18W N 3.99 W .86 3922.41N 297.83W N 4.29 W 1.28 4013.41N 304.42W N 4.76 W 1.53 4104.66N 311.64W 3751.29 3840.44 3933.60 4024.83 4116.37 SPE~,~,Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPF-38 500292261400 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 111795 MWD SURVEY JOB NUMBER: AK-MM-951158 KELLY BUSHING ELEV. = 45.46 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 6637 3987.32 3941.86 75 52 N 4.47 W .35 4196.14N 319.02W 6729 4010.15 3964.69 75 24 N 4.19 W .59 4285.04N 325.75W 6825 4034.23 3988.77 75 24 N 5.56 W 1.39 4377.18N 333.61W 6919 4058.05 4012.59 75 24 N 6.25 W .71 4468.19N 343.03W 7015 4082.31 4036.85 75 18 N 6.48 W .26 4560.48N 353.32W 7111 4106.89 4061.43 74 48 N 6.24 W .58 4651.97N 363.52W 7204 4130.78 4085.32 75 32 N 6.85 W 1.01 4741.59N 373.80W 7300 4154.08 4108.62 76 27 N 7.04 W .97 4834.37N 385.10W 7392 4176.16 4130.70 75 45 N 7.28 W .81 4922.90N 396.22W 7488 4200.43 4154.97 74 57 N 6.92 W .90 5015.06N 407.71W 7582 4223.42 4177.96 76 37 N 6.88 W 1.78 5105.25N 418.62W 7677 4245.72 4200.26 76 17 N 7.30 W .56 5197.13N 430.05W 7772 4269.18 4223.72 75 10 N 8.20 W 1.49 5288.54N 442.49W 7867 4292.79 4247.33 75 54 N 6.39 W 2.01 5379.35N 454.11W 7961 4316.13 4270.67 75 20 N 6.07 W .68 5469.91N 463.99W 8057 4341.27 4295.81 74 19 N 4.87 W 1.61 5562.22N 472.84W 8152 4366.67 4321.21 74 44 N 4.58 W .53 5653.71N 480.40W 8247 4392.07 4346.61 74 1 N 4.27 W .82 5744.29N 487.41W 8342 4417.81 4372.35 74 37 N 4.44 W .64 5835.75N 494.37W 8434 4441.45 4395.99 75 39 N 4.26 W 1.13 5924.58N 501.13W 8501 4458.73 4413.27 74 37 N 4.08 W 1.54 5989.54N 8580 4479.41 4433.95 74 37 N 4.08 W .00 6064.57N VERT. SECT. 4208.15 4297.30 4389.77 4481.25 4574.07 4666.09 4756.25 4849.66 4938.80 5031.60 5122.38 5214.90 5307.02 5398.48 5489.54 5582.27 5674.07 5764.92 5856.65 5945.73 505.87W 6010.86 511.22W 6086.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6086.08 FEET AT NORTH 4 DEG. 49 MIN. WEST AT MD = 8580 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 355.25 DEG. SPE .... Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPF-38 500292261400 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 111795 JOB NUMBER: AK-MM-951158 KELLY BUSHING ELEV. = 45.46 OPERATOR: BP EXPLORATION FT. 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 0 .00 -45.46 .00 N .00 E .00 1000 998.66 953.20 23.68 N .11 W 1.34 2000 1966.55 1921.09 259.56 N 14.71 W 33.45 3000 2784.52 2739.06 823.64 N 46.47 W 215.48 4000 3320.54 3275.08 1652.07 N 131.19 W 679.46 1.34 32.11 182.03 463.98 5000 3575.91 3530.45 2614.53 N 214.09 W 1424.09 6000 3829.12 3783.66 3579.99 N 274.34 W 2170.88 7000 4078.28 4032.82 4545.22 N 351.59 W 2921.72 8000 4325.87 4280.41 5506.97 N 467.93 W 3674.13 8580 4479.41 4433.95 6064.57 N 511.22 W 4100.59 744.63 746.78 750.84 752.41 426.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE.~.Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPF-38 500292261400 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 111795 JOB NUMBER: AK-MM-951158 KELLY BUSHING ELEV. = 45.46 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 0 .00 -45.46 45 45.46 .00 145 145.46 100.00 245 245.46 200.00 345 345.46 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .34 S .17 W .00 .00 .08 S .43 W .00 .00 .08 S .63 W .01 .01 445 445.46 400.00 545 545.46 500.00 645 645.46 600.00 745 745.46 700.00 845 845.46 800.00 3.40 S .90 W 4.84 S 1.40 W 5.31 S 1.42 W .56 S 1.28 W 7.88 N .85 W .02 .01 .03 .01 .04 .01 .16 .12 .52 .36 946 945.46 900.00 1047 1045.46 1000.00 1147 1145.46 1100.00 1249 1245.46 1200.00 1351 1345.46 1300.00 17.73 N .37 W 1.01 .49 29.17 N .13 E 1.66 .65 42.31 N .59 E 2.53 .87 58.57 N 1.47 E 3.86 1.33 77.00 N 3.13 E 5.56 1.70 1453 1445.46 1400.00 1555 1545.46 1500.00 1659 1645.46 1600.00 1764 1745.46 1700.00 1870 1845.46 1800.00 97.50 N 4.09 E 7.65 2.09 120.25 N 3.93 E 10.21 2.56 146.98 N 1.61 E 13.76 3.55 179.22 N 3.31 W 18.95 5.19 213.21 N 9.12 W 24.74 5.78 1977 1945.46 1900.00 2086 2045.46 2000.00 2197 2145.46 2100.00 2312 2245.46 2200.00 2431 2345.46 2300.00 250.84 N 13.80 W 31.70 6.96 293.93 N 18.26 W 40.69 8.99 343.13 N 23.25 W 52.27 11.58 399.52 N 27.33 W 67.17 14.90 463.98 N 31.17 W 86.22 19.05 2555 2445.46 2400.00 2682 2545.46 2500.00 2812 2645.46 2600.00 2946 2745.46 2700.00 3087 2845.46 2800.00 536.52 N 35.01 W 109.84 23.62 615.42 N 38.83 W 137.30 27.46 697.97 N 41.65 W 167.00 29.70 786.62 N 44.94 W 200.70 33.71 885.72 N 50.08 W 241.61 40.91 3237 2945.46 2900.00 3398 3045.46 3000.00 3580 3145.46 3100.00 3795 3245.46 3200.00 4082 3345.46 3300.00 997.13 N 57.75 W 291.55 49.94 1123.87 N 69.29 W 353.44 61.89 1274.66 N 84.51 W 435.09 81.65 1464.17 N 105.70 W 550.49 115.41 1729.82 N 142.59 W 736.99 186.50 SPE~_,,~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPF-38 500292261400 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 111795 JOB NUMBER: AK-MM-951158 KELLY BUSHING ELEV. = 45.46 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4449 3445.46 3400.00 2081.36 N 179.91 W 1004.52 4875 3545.46 3500.00 2494.14 N 207.15 W 1330.17 5270 3645.46 3600.00 2875.59 N 228.40 W 1625.10 5669 3745.46 3700.00 3260.52 N 252.28 W 1923.56 6063 3845.46 3800.00 3641.62 N 278.29 W 2218.42 267.52 325.65 294.94 298.45 294.87 6467 3945.46 3900.00 4031.68 N 305.79 W 2522.07 6869 4045.46 4000.00 4420.11 N 337.84 W 2824.47 7263 4145.46 4100.00 4798.83 N 380.72 W 3118.52 7676 4245.46 4200.00 5196.08 N 429.91 W 3431.13 8073 4345.46 4300.00 5577.10 N 474,10 W 3727.62 303.65 302.40 294.05 312.61 296.48 8450 4445.46 4400.00 5940.20 N 502.29 W 4005.31 8480 4452.91 4407.45 5968.39 N 504.36 W 4027.09 277.69 21.79 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D FI I Cl--I Itl G WELL LOG TRANSMITTAL To: State of Alaska May 31, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. ! ? MWD Formation Evaluation Logs - MPF-38, AK-MM-951158 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of 2 Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 /-~' 2"x 5" MD Resistivity and Gamma Ray Logs: ~2" x 5" TVD Resistivity and Gamma Ray Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri I::t I I__1__ I N G S I:: F! ~J I I-- ~::: S WELL LOG TRANSMITYAL To: State of Alaska May 24, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs- MPF-38 AK-MM-951158 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-38: 1 LDWG formatted LIS tape with verification listing. APl#: 50-029-22614-00 i C i=ivl=O 29 1996 Anchorage 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 March 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS ECC No. Run # 1 6603.00 Run # 1 6609.00 Run # 1 6616.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging SerVices 5600 B Street Suite 201 Anchorage, AK 99518 Received by/r/'// )~ / ' \, Date: 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) April 4, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth shifted CDR/CDN,CDR/CDN TVD'S for well MPF-38 Job # 95388 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth shift display State of Alaska Alaska Oil & Gas Conservation Comm. Attn' Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 -, 1 OH L!S Tape 1 Blueline each 1 RF Sepia each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 404 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courie Date Delivered: SCHLUMBERGER GEOQUEST . -. 500 WEST INTERNATIONAL AIRP. OI~.-T,..R.~O_AD~ ANCHORAGE, A I_~,'S I~A-- 995i8- i '~ 99 Received'Byl .... ·.:: . :~: · . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J oh_~n, DATE: Chairm,~m'~' : March 18, 1996 THRU: FILE NO: Blair Wondzell, ~~ P. !. Supervisor_ r= FROM: Bobby Foste~\ SUBJECT: Petroleum ins~ector AWPICRDD.doc BOPE Test- Nabors 4ES BPX - MPU - MPF-38 PTD # 95-0168 Milne Point Field Monday, . March 1.8, !996: i traveled this date to BPX's MPU well MPF-38 being worked over by Nabors rig 4ES and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows the test went very good and there were no failures of the equipment tested. The rig was in good shape and all equipment seemed to be in good working order. Summary: I witnessed the weekly BOPE test on Nabors dg 4ES working over BPX's MPU well MPF-38 - test time 3 - no failures. Attachment: AWPICRDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: · Workover: X , , Drig Contractor:· r r ..... .~NABORS . Rig No. Operator: BPX Well Name: MPF-38 Casing Size: 7'Xg,625" Set @ 17,56'1' Test: initial~ Weekly X~ Other 4ES PTD# 95-0168 . , . Rep.: DATE: 3/18~6 Rig Ph.# 059-4154 RANDAL ANDERSON Rig Rep.: GENE SWEET T. 'I3N R. fOE Meridian Urn. Location: Sec. 6 ~ -. Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: 0K' (Gen) PTD On Location ~ES Standing Order Posted YES Well Sign YES Drt. Rig YES Hazard Sec. YES FLOOR SAFETY VALVES: Ouan. Upper Kelly t IBOP f. ! BailL°wer Kelly / IBOPType ' 11"! Inside BOP . .~. I Pressure 500/5,000 500/5,000 5oo ,o _oo 500/5,000 P/F BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 'Test Press. PiF [ p 5oo/5.000 'P ..500/5,000 'P 500/5,0O0. P CHOKE MANIFOLD: No. Valves 10 No. Flanges 20 Manual Chokes ' 1 _ . Hydraulic Chokes 1 · Test Pressure 500/5,000 Functioned Functioned PIF N /A 3,000 [ P · 1,~'~0 ....{ P' MUD SYSTEM: V*sual Alarm minutes 31 Trip Tank YES YES minutes 10 Pit Level Indicators YES YES YES Rem0t~: Flow Indicator YES YES 4 i~, 2000 Avf~> Ueth Gas Detector "'YES '~/Es...... Psig. H2S Gas Detector YES YES ! . , ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btrs: sec. sec. YES 'Number of Failures: .0 ' ",T~st Tii;~ie(~'OU'm, ..... NU'i~'ber°fvalveStested' ' f8 'Re~ir:or'Repla~e'~'nt"~f-~aii'~ Equipment will be made within 0 N~ffyys. Notify the Inspector and follow with' Written or Faxed verification to the AOGCC Commissi'on Office ~; F_ax__ No. 276-7_,54~_~ lnspe~or North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P, L Supervisor at 279,1433 . IIII .I I I II I II II I I I I II ] II I I .1111! I . II II I REMARKS: Distribution: orig-Well File c ~ Oper./Rig c - Database c -Tdp Rpt File c - Inspector sTATE WI¥1{JE~I!i~REQUI'RED? ' Waived By: YES X NO ~arrtnessed By: 24 HOUR NOTICE GIVEN YES NO X BOBBY D. FOSTER F1-021L (Rev, 12/94) AWPICRDD.XL$ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: MPF-38 MILNE POINT / KUPARUK NORTH SLOPE, AK Date: RE: 28 February 1996 Transmittal of Data ECC #: 6603.00 Sent by: HAND CARRY Data: PLS Enclosed, please find the data as described below: Prints/Films: 1 PLS FINAL BL+RF Run # 1 1 PFC/PERF FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson ._~.~_ Western Atlas Logging Services 5600 B Street Anchorage, AK 99518 ~a- Or FAX to (907) 563-7803 ~?~$~.A MEMORANDUM TO: David JohnSon, Chairrr~ THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 12, 1995 FILE NO: ewqlklcd.doc FROM: John Spauiding,?,~.,. SUBJECT: Petroleum lnsp. Diverter Function Test BPX MPU Nabors 27E Kuparuk River Field PTD 95-168 (F-38) Sunday November 12, 1995: I traveled to BPX's MPU to witness the Diverter Function Test on Nabors 27E, well F-38. The AOGCC Diverter Function Test report is attached for reference. The rig was in good shape and all equipment functioned very well, with no failures. The pad area is very small and is being shared with other simultaneous operations; electric wireline and construction. Two electric line units were located near the end of the vent line (+- 100'). These "E" line units were not directly inline with the vent line - see attached. I spoke to Jim Fox and Larry Niles BPX prod. supervisors about the apparent lack of communications between drilling and production. Jim and Larry acknowledged that there has been a lack of communications and an effort will be made in the future to correct this problem. Summary:. I witnessed the successful Diverter Function Test on Nabors 27E, no failures. Attachments: Drlg Contractor: Operator: Well Name: Location: Sec, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Nabors BPX MPF-38 6 T. 13N. R. Operation: Development Rig No. 27E PTD # Oper. Rep.: Rig Rep.: 10E. Merdian Umiat X Exploratory: 95-168 Rig Ph. # Jim Gafney Brian Busby 659-4373 TEST DATA MISC. INSPECTIONS: Location Gen.: OK Well Sign: OK Housekeeping: OK (Gen.) Drlg. Rig: OK Reserve Pit: OK Flare Pit: NA DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: 20 in. yes yes 10 105 yes yes yes yes in. ACCUMULATOR SYSTEM: Systems Pressure: 3000 psig Pressure After Closure: 1900 psig 200 psi Attained After Closure: min. 14 sec. Systems Pressure Attained: 1 min. 3 sec. Nitrogen Bottles: 2200, 2400, 2300, 2400 2300, 2450, 2200, 2300 psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: ok ok Mud Pits: ok ok Flow Monitor: ok ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok DIVERTER SCHEMATIC Constuction Facilities Pipe Shed / 2~0' + - between fac. and v. lin~ Prod. Facilities Motors & Pits wells vah)es'~; ~ Wire line Unit Wire line Unit Access *west facing vent line normally closed * 100' +- from west facing vent to E-line unit Rig Shop North Wind ~... Direction Flowlines Rig Camp Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c o Inspector AOGCC REP.: OPERATOR REP.: John H. Spaulding Jim Gafney F1-022 EWQLKLCD.XLS ALASK OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 26, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF,38 BP Exploration (Alaska), Inc. Permit No 95-168 Surf Loo. 1994'NSL, 2731'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc. 455'NSL, 3865'WEL, Sec. 19, T14N, R10E, UM Dear Mr. Schofield: 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 petroleum field inspector 659-3607. David W.'~Otmston \ Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 Re-Entry [] DeepenFII 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 RTE = 45.2 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. ©. Box 196612, Anchorage, Alaska 99519-6612 ADL 355016 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1994' NSL, 2731' WEL, SEC 06, T13N, RIOE Milne Point Unit At top of productive interval .8. Well number Number 165' NSL, 3850' WEL, SEC 19, T14N, RIOE MPF-38 2S100302630-277 At total depth 9. Approximate spud date Amount 455' NSL, 3865' WEL, SEC 19, T14N, RIOE 10/30/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (UD and TVS) 3roperty line ADL355018 455 feet NoCIoseApproach feet 5071 17591'MD/7625'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle z5 o Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NTSOLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 8516' 31' 31' 8547' 4497' 1638 sx PF 'E', 250 sx 'G; 250 PF 'E' 8-1/2" 7" 26# L-80 Btm 17561' 30' 30' 17591' 7625' 217 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. F~. t...., ~., , r.. P Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet 0CT 2~ 1995 Effective depth: measured feet Junk (measured) A_~a~.~il .& Bas Cons. Co_mfflissi~.n true vertical feet .... '. ~fflchoi'a~]Q" Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis F-I Seabed report[] 20 AAC 25.050 requirements[] ..... the foregjoing is ~rg.e and correct to the best of my knowledge / / 21. I hereby certify that · -' · S~gned /,.~ Title SeniorDrillin~ Engineer Date Commission Use Only IA5P0 'h~___.e~ Approval date See cover letter Permit Number I. 2_ ~ ~' ,/z'// ,,/¢ -,~ ~, ..- ~'~ for other requirements - Con~lit~ns 'of approval Samples required [] Yes J~No Mud Icg required []Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; 1~5M; I-IIOM; []15M; Other: Original Signe~ By by order of // Approved by David W, Johnston Commissioner ~ne commission Date/~/.z_c,~.?~ Form 10-401 Rev. 12-1-85 Submit in ,licate I Well Name: I MPF-38 [ Well Plan Summary ]Type of Well (producer or injector): [Kupamk Producer I Surface Location: 1994' FSL 2731' FEL Sec 06 T13N R10E UM., AK. Target Location: 165' FSL 3850 FEL Sec 19 T14N R10E UM., AK. Bottom Hole 455' FSL 3865' FEL Sec 19 T14N R10E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. [AFE Number: [330202 ] [Rig: [Nabors 27E [ IEstimated Start Date: ]Oct 30, 1995 '[ IOperating days to drill and case: IMD: I17591' I I TVD: 17625'BKB I IKBE: I46' I IWell Design (conventional, slimhole, ] Ultra Slimhole, 7" Longstfing etc.): I Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1815' 1795' n/a NA (Top .Schrader) 6530' 3975' 1653 psig / 8.0 ppg CA ' ' 1744 psig / 8.0 ppg Base Schrader Bluff 8346' 4445' 1848 psig / 8.0 ppg Top HRZ' 16625' 6965' n/a Base HRZ ' ' n/a Kupark D Shale 16969' 7185' n/a Kuparuk C ' 7209' 3598 psig / 9.6 ppg Target KUP A3 17181' 7335' 3616 psig / 9.6 ppg Total Depth 17591' 7625' n/a Casing/Tubin.. g Prol, ram: Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MDfEVD MDfrVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 i2 1/4" 9 5/8" 40# L-80 btrc 8516' 31/31 8547/4497 8 1/2" 7" 26# L-80 btrc 17561' 30/30 17591/7625 N/A (tbg) 2-7/8" 6.5# L-80 EUE 17052' 29/29 17081/7410 8rd 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 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. Logging Prol I Open Hole Logs: Surface Intermediate Final ICased Hole Logs: ,ram. LWD GR/Resistivity None LWD GR/Resistivity/Neutron/Density None OCT 2 Al~.~k~ Oil & fin.et Annht , ,, Ei.) :0ns. Commission rage A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. API# 50- October 20, 1995 Mud Program: Special design considerations LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 , , to to to to to to to T 9.6 100 35 15 30 10 15 ,,, Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) .Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.2 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1600' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 75 degrees <_ 4 degrees 45 De~rees No - See Traveling Cylinder report There are no close approach wells for drilling MPF-38. There are other well in the area but do not enter a close approach condition . The well path should be followed as close as possible to ensure we do not compromise the proximity toleranxces. Alaska Oil & Gas Cons..Commission Anchorage AP1 # 50- October 20, 1995 Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Miln¢ Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Re quest to AOGCC for Annular Pumping Approval for MPF-38: Approval is requested for Annular Pumping into the MPF-38, 9-5/8" x 7" casing annulus. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order ~2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 8547' md (4497' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2302 psi for a 10.4 ppg fluid in this well. MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permiability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) ,, Milne Point F-1 0 35,000 1/1/95 - 12/31/95 Milne Point F-13 684 35,000 1/1/95 - 12/31/95 , Milne Point F-25 ' ' 230 35,000 1'/1/95 - 12/31/95 ,, Milne Point 'F-37 0 35,000 1/1/95 - 12/31/95 Milne Point F-45 0 35,000 1/1/95 - 12/31/9,~ Milne Point F-53 0 35,000 1/1/95 - 12/31/95 Miln~' ISoint F-61 0 35,000 1/1/95 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. Alaska Oil & Gas Corm. Commission Anchorage API# 50- October 20, 1995 DRILLING HAZARDS AND RISKS: See both the updated Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the BHA, rather than formation drilling problems. The MPU PE group will 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. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F- pad. The max mud weight re~.ched on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells F-69, F-61, AND F-53 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. 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. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.2 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3594 psi @ 7200' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. API# 50- October 20, 1995 MP F-38 Proposed Summary of Operations o Drill and Set 20" Conductor. conductor. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. o Drill a 12-1/4" surface hole to 8547' md (44497' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. . . ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well f'fle. 10. Drill 8-1/2" hole to TD at 17591' MD (7625' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). 11. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. 12. ND BOPE and NU dry hole tree. Release rig to MPF-30i. Note: This well will be perforated, hydraulically fractured and cleaned out with a completion rig and prior to running the injection completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine in the wellbore. 13. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. 14. PU and RIH with 2-7/8" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. 15. R/H with Electric Submersible Pump 0ESP) completion on 2-7/8" EUE 8rd tubing. 16. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. 17. RDMO with workover/completion rig. POST RIG WORK Alaska 0il & Gas Cons. Commission gnch0rag~, 1. Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. . . , A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. The rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. API# 50- October 20, 1995 MPF.38 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CE..M_ENT JOB ACROSS THE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST 170 deg F at 7260' TVDSS. SPACER: 20 bbl~ 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: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 217 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8"" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 17 joints of 7" Casing (34 total). Use stop collars to fasten centralizers to casing joints. This will cover 300' above the top of the Kuparuk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator a minimum of 60 feet inside the 9- 5/8"casing shoe to avoid hanging up on the shoe. This centralizer may be attached across a casing collar connection. 3. Total 7-1/8"" x 8-1/4" Straight Blade Turbulators needed is 35. 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 until the plug .bumps, but not more than to displace cement just above the production zone. Batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kuparuk Sands with 30% excess over a guage hole. OCT Oil & Gas Cons. Corrm~ission API# 50- October 20, 1995 BPX-Sh~ed Services Z)~illlng Alaska ~te Plane: Zone4 Milne P~c', MPF HPF-38 As-BuiL-t MPF-38 ~/pl VERTICAL VIEW SCALE 5(X] f'-t. / DIVISION TVD REF: WELLHEAD VERTICAL SECTI[]q REF: WE]]_.HEAD CRITICAL POINT DAI'A MD TIE IN 0 KOP / START []F BUILD 8 1.DO/1CX~ ST~T ~ ~ILD ST~T ~ ~ILD ST~T ~ ~ILD 8 E,,~/IOO C% END DF' BUILD 17E'D B. PermaFrost 1815 START JIF BUILD 1~0 8 8,50/10D ~'t END OF BUILD 4160 START JIF 5160 CURVE e 8,50/1 [II Ft END OF CURVE 5164 NA Son c~s 6530 Inc Azi, TVD N/S E/W O.[D ~,[~] 0 0 N 0 E O.DO 355.00 6DO 0 N 0 E 3.OD ~.[~3 ~DO 8 N 1 W 7.50 ~.[D 11~ 35 N 3 W 13.5.50 355.00 1493 ~ N 8 W lg.~ ~,~ 1~4 151 N 13 W lg,~ ' ~,~ 17~ 182 N 16 W lg.~ ~.~ 1~4 ~16 N lg W ~.~ 3~,~ 3~1 1784 N 1~ W ~.~ ~.~ 3~ 8746 N 840 W 75.0D 355.11 36~1 8750 N 841 W 75,00 355,11 3975 4065 N 353 W 75.[]0 355.11 4445 5812 N 503 W B, Sch~ ader 8346 Casno 8547 75.00 3~,11 4497 ~ N 519 W ST~ 151E3 75.~ ~.11 61~ 1E334 N 1~1 W ~E ~ END ~ ~VE t66B5 45,~ ~,~ 6~ ~36~7 N ~53 ~ TKO3 ~7~8~ 45.~ ~.~ 7~5 t4~ N ~74 ......... T~t 10/1/~ ~ 14010 N 1174 W ~ ~49448 J ~INT DATA 9 5/8 In 8547 75,~ ~,11 4497 ~ N 519 7 in 17591 45,~ 357,~ 7625 l~ N 1189 0 5eX] 10[I] 1500 E~]O0 I I I 7185 14348 WELLPLAN FEASIBILITY STUDY This plan is for feasibility purposes only it has not yet been certifi~dl 850D g[X]O 9500 10(]OD 105(][] liOOD 1150D 1EOCO IL:~DCD 13DCD 135[I] 14[]OD 145(1I] 150[I] VERTICAL SECTEiN PL/N",E: 355.B5 10/E0/95 11;41 HORIZONTAL V!_~ (T~,.,E NO~TH) SCALE 1030 ~z / DiVlSiLN SURVEY REF: WELLhF_~'D 6739 ' 6563 6413 150CC 35~00 356.51_ 356.0~ 355,73 355.40 355.11 L--!arJCC :J ' I : 1000 0 1Q33 ag30 Halliburton Energy Services - Drilling Systems PSL Proposal Report Date: 10£z Time: 11:48, Welipath ID: MPF-38 Wp, Last Revision: 10/20/95 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.30.28 N - Long. 149.39.28 W Refexence GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6035446.44 N 541831.37 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2. I.B Vertical Section Plane: 355.25 deg. WELLPLAN FEASIBILITY STUDY This plan is for feasibility purposes only it has not yet been certifiedl BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-38 As-Built MPF-38 Wpl Measured lnci Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (fi) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum_ Expected Total Max Hot Min Hot Dir. Vest Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (fi) (ft) (fi) (deg.) (ft) Survey Tool TrEIN 0.00 0.00 0.00 -44.70 0.00 0.00 0.00N KOP I START OF BUILD @ 1.00 deg/100 ft 600.00 0.00 0.00 555.30 600.00 600.00 0.00N 700.00 1.00 355.00 655.29 699.99 100.00 0.87N 0.00E 6035446.44 541831.37 0.00 E 6035446.44 541831.37 0.0~N 6035447.31 541831.29 0.~@ 0.~ 0.~ 0.~ 0.~ 0.~@ 0.~ 0.~ 0.~ 0.~ 0.87@355.00 0.87 1.00 0.00 0.00 0.0 0.00N 0.00 0.0 0.00N 1.00 1.0 0.87N 0.00 E 0.00 0.00 0.00 0.00 MWD 0.00 E 2.47 2.47 0.00 0.83 BPHM-PBD 0.0~W 2.64 2.63 85.00 0.98 B PI-fM-PBD 8(X).00 2.00 355.00 755.26 799.96 100.00 3.48N START OF BUILD @ 1.50 deg/100 fl 900.00 3.00 355.00 855.16 899.86 100.00 7.82N 1000.00 4.50 355.00 954.95 999.65 100.00 14.34N 1100.00 6.00 355.00 1054.52 1099.22 100.00 23.45N START OF BUILD @ 2.00 deg/100 ft 1200.00 7.50 355.00 1153.83 1198.53 100.00 35.16N 1300.00 9.50 355.00 1252.72 1297.42 100.00 49.89N 0.3CW 6035449.92 541831.04 3.49@355.00 3.49 0.&%V 6035454.26 541830.64 7.85@ 355.00 7.85 1.2_%V 6035460.77 541830.03 14.39@ 355.00 14.39 2.05W 6035469.88 541829.18 23.54@ 355.00 23.54 3.0~k' 6035481.58 541828.09 35.30@ 355.00 35.30 4.3Ohr 6035496.30 541826.72 50.08@ 355.00 50.08 1.00 0.00 1.00 0.00 1.50 0.00 1.50 0.00 1.50 0.00 2.00 0.00 1.00 2.0 3.48N 1.00 3.0 7.82N 1.50 4.5 14.34N 1.50 6.0 23.45N 1.50 7.5 35.16N 2.00 9.5 49.88N 0.31W 2.82 2.81 85.00 1.13 BPHM-PBD 0.6~V 3.02 3.00 85.00 1.29 BPHM-PBD 1.2ON 3.27 3.20 85.00 1.45 BPHM-PBD 2.0c'W 3.56 3.41 85.00 1.61 BPHM-PBD 3.1CW 3.91 3.63 85.00 1.77 BPHM-PBD 4.4CW 4.35 3.86 85.00 1.96 BPHM-PBD 1400.00 11.50 355.00 1351.04 1395.74 100.00 68.04N 5.9_%V 6035514.44 541825.03 68.30@355.00 68.30 START OF BUILD @ 2.50 deg/100 ft 1500.00 13.50 355.00 1448.67 1493.37 100.00 89.60N 7.84W 6035535.99 541823.03 89.94@ 355.00 89.94 1600.00 16.00 355.00 1545.37 1590.07 100.00 114.96N 10.0c'W 6035561.33 541820.66 115.40@355.00 115.40 2.00 2.50 0.00 0.00 2.00 11.5 68.03N 6.01W 4.90 4.09 85.00 2.15 BPI-IM-PBD 2.00 13.5 89.59N 7.97N 5.58 4.34 85.00 2.35 BPHM-PBD 2.50 16.0 114.95N 10.1~V 6.40 4.60 85.00 2.58 BPHM-PBD 1700.00 18.50 355.00 1640.86 1685.56 100.00 144.50N 12.64W 6035590.86 541817.91 145.05@355.00 145.05 END OF BUILD 1720.00 19.00 355.00 1659.80 1704.50 20.00 150.90N 13.2CRV 6035597.26 541817.32 151.48@355.00 151.48 B. Permafrost 1815.40 19.00 355.00 1750.00 1794.70 95.40 181.84N 15.91W 6035628.18 541814.44 182.54@355.00 182.54 2.50 2.50 0.00 0.00 0.00 0.00 2.50 18.5 144.48N 12.83V 7.37 4.86 85.00 2.84 BPHM-PBD 2.50 19.0 150.89N 13.3~V 7.58 4.92 85.00 2.89 BPHM-PBD 0.00 19.0 181.82N 16.1_~6/ 8.58 5.23 85.00 3.06 BPI-[M-PBD START OF BUILD @ 2.50 deg/100 ft 1920.00 19.00 355.00 1848.90 1893.60 104.60 215.77N 18.8LzW 6035662.08 541811.28 216.59@355.00 216.59 2020.00 21.50 355.00 1942.71 1987.41 100.00 250.25N 21.85W 6035696.54 541808.07 251.2(]0~355.(X) 251.20 0.00 2.50 0.00 0.(~) 0.00 19.0 215.74N 19.1~V 9.70 5.59 85.00 3.25 BPHM-PBD 2.50 21.5 250.21N 22.27W 10.92 5.89 85.00 3.55 BP[IM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Date: lb, Wellpath ID: MPF-38 Measured Incl Drift Subsea TVD Course T 0 T A L Depth Dir. Depth Length Rectangular Offsets (fi) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. ' Expected Total Max Hor Min Hot Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (It) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2120.00 24.00 355.00 2034.93 2079.63 100.00 288.77N 25.2Ohr 6035735.04 541804.48 289.87@355.00, 289.87 2.50 0.00 2220.00 26.50 355.00 2125.37 2170.07 100.00 331.26N 28.9~V 6035777.50 541800.53 332.52@ 355.00 332.52 2.50 0.00 2320.00 29.00 355.00 2213.86 2258.56 100.00 377.64N 33.04W 6035823.85 541796.21 379.08@355.00 379.08 2.50 0.00 2.50 24.0 288.73N 25.72JW 12.28 6.20 85.00 3.87 BPI-IM-PBD 2.50 26.5 331.21N 29.5~%V 13.78 6.53 85.00 4.22 BPHM-PBD 2.50 29.0 377.58N 33.7~W 15.42 6.87 85.00 4.60 BPHM-PBD 2420.00 31.50 355.00 2300.23 2344.93 100.00 427.82N 37.43h~ 6035874.01 541791.54 429.46@ 355.00 429.45 2.50 0.00 2520.00 34.00 355.00 2384.33 2429.03 100.00 481.71N 42.14W 6035927.86 541786.52 483.55@ 355.00 483.54 2.50 0.00 2620.00 36.50 355.00 2465.99 2510.69 100.00 539.20N 47.17W 6035985.32 541781.17 541.26@355.00 541.25 2.50 0.00 2.50 31.5 427.75N 38.2 t%V 17.20 7.22 85.00 5.01 BPI-IM-PBD 2.50 34.0 481.62N 43.1_W~/ 19.11 7.59 85.00 5.45 BPHM-PBD 2.50 36.5 539.09N 48.3C'W 21.16 7.96 85.00 5.93 BPHM-PBD 2720.00 39.00 355.00 2545.05 2589.75 100.00 600.18N 52.51W 6036046.26 541775.49 602.48@355.00 602.47 2.50 0.00 2820,00 41.50 355.00 2621.37 2666.07 100.00 664.54N 58.14W 6036110.58 541769.50 667.08@ 355.00 667.08 2.50 0.00 2920.00 44.00 355.00 2694.80 2739.50 100.00 732.16N 64.06V 6036178.16 541763.20 734.96@355.00 734.95 2.50 0.00 2.50 39.0 600.06N 53.91W 23.33 8.34 85.00 6.44 BPHM-PBD 2.50 41.5 664.40N 59.77W 25.62 8.73 85.00 6,99 BPHM-PBD 2.50 44.0 732.00N 65.949/ 28.02 9.12 85.00 7.58 BPHM-PBD 3020.00 46.50 355.00 2765.19 2809.89 100.00 802.90N 70.24W 6036248.86 541756.61 805.97@ 355.00 805.96 2.50 0.00 3120.00 49.00 355.00 2832.42 2877.12 100.00 876.64N 76.7CW 6036322.55 541749.75 879.99@355.00 879.98 2.50 0.00 3220.00 51.50 355.00 2896.36 2941.06 100.00 953.22N 83.4CW 6036399.09 541742.62 956.86@ 355.00 956.86 2.50 0.00 2.50 46.5 802.71 N 72.41W 30.54 9.51 85.00 8.20 BPHM-PBD 2,50 49.0 876.42N 79.17W 33.17 9.90 85.00 8.86 BPHM-PBD 2.50 51.5 952.98N 86.1gW 35.90 10.27 85.00 9.56 BPI-IM-PBD 3320.00 54.00 355.00 2956.89 3001.59 100.00 1032.51N 90.3L:NV 6036478.33 541735.24 1036.46@ 355.00 1036.45 2.50 0.00 3420.00 56.50 355.00 3013.88 3058.58 100.00 1114.36N 97.4~hr 6036560.13 541727.62 1118.62@355.00 1118.61 2.50 0.00 3520.00 59.00 355.00 3067.24 3111.94 100.00 1198.60N 104.8eW 6036644.32 541719.78 1203.18@355.00 1203.17 2.50 0.00 2.50 54.0 1032.24N 93.47W 38.72 10.64 85.00 10.30 BPHM-PBD 2.50 56.5 1114.05N lOl.0Ohr 41.64 11.00 85.00 11.07 BPHM-PBD 2.50 59.0 1198.26N 108.7ON 44.64 11.34 85.00 11.87 BPHM-PBD 3620.00 61.50 355.00 3116.86 3161.56 100.00 1285.09N l12.4,aW 6036730.75 541711.72 1290.00@355.00 1289.98 2.50 0.00 3720.00 64.00 355.00 3162.64 3207.34 100.00 1373.64N 120.1~V 6036819.25 541703.48 1378.89@355.00 1378.88 2.50 0.00 3820.00 66.50 355.00 3204.50 3249.20 100.00 1464.10N 128.090V 6036909.66 541695.06 1469.70@ 355.00 1469.68 2.50 0.00 2.50 61.5 1284.71N 116.74W 47.72 11.67 85.00 12.71 BPHM-PBD 2.50 64.0 1373.23N 124.92W 50.87 I1.97 85.00 13.58 BPHM-PBD 2.50 66.5 1463.65N 133.2~/ 54.09 12.25 85.00 14.48 BPHM-PBD 3920.00 69.00 355.00 3242.36 3287.06 100.00 1556.30N 136.1CN 6037001.80 541686.48 1562.24@ 355.00 1562.23 2.50 0.00 4020.00 71.50 355.00 3276.15 3320.85 I00.00 1650.05N 144.3L'W 6037095.50 541677.75 1656.35@355.00 1656.34 2.50 0.00 4120.00 74.00 355.00 3305.81 3350.51 100.00 1745.18N 152.6~W 6037190.57 541668.89 1751.85@355.00 1751.83 2.50 0.00 2.50 69.0 1555.81 N 141.81W 57.37 12.50 85.00 15.40 BPHM-PBD 2.50 71.5 1649.52N 150.4~N 60.70 12.73 85.00 16.35 BPHM-PBD 2.50 74.0 1744.60N 159.3CW 64.08 12.93 85.00 17.31 BPHM-PBD END OF BUILD 4160.00 75.00 355.00 3316.49 3361.19 40.00 1783.58N 156.04W 6037228.94 541665.32 1790.39@355.00 1790.38 2.50 0.00 START OF CURVE @ 2.50 deg/100 ft 5160.00 75.00 355.00 3575.31 3620.01 I000.00 2745.83N 240.2~ 6038190.61 541575.75 2756.32@355.00 2756.29 0.00 0.00 END OF CURVE 5164.07 75.00 355.11 3576.37 3621.07 4.07 2749.75N 240.57W 6038194.53 541575.39 2760.25@355.00 2760.23 -0.05 2.59 ... · NA Sands 6530.22 75.00 355.11 3930.00 3974.70 1366.15 4064.52N 353.1ON 6039508.52 541455.46 4079.84@355.03 4079.81 0.00 0.00 B. Schrader 8345.96 75.00 355.11 4400.00 ~.70 1815.74 5811.99N 502.81W 6041254.96 541296.09 5833.70@355.06 5833.66 0.00 0.00 Casing / CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/fL 8547.00 75.00 355.11 4452.04 4496.74 201.04 6005.46N 519.3~V 6041448.32 541278.45 6027.88@355.06 6027.85 0.00 0.00 START OF CURVE @ 2.00 deg/100 ft 15122.57 75.00 355.11 6153.99 6198.69 6575.57 12333.80N I061.31W 6047772.94 540701.61 12379.38@355.08 12379.33 0.00 0.00 15222.57 73.00 355.20 6181.55 6226,25 100.00 12429.58N 1069.4_%V 6047868.66 540692.96 12475.50@355.08 12475.45 -2.00 0.10 15322.57 71.00 355.30 6212.45 6257.15 100.00 12524.35N 1077.3CW 6047963.39 540684.57 12570.60@355.08 12570.55 -2.00 0. I0 15422.57 69.01 355.40 6246.64 6291.34 100.00 12618.01N 1084.91W 6048056.99 540676.45 12664.57@355.09 12664.52 -2.00 0.10 15522.57 67.01 355.51 6284.08 6328.78 I00.00 12710.44N 1092.2C3hr 6048149.37 540668.60 12757.29@355.09 12757.24 -2.(×) 0.10 15622.57 65.01 355.62 6324.74 6369.44 I00.00 12801.52N 1099.32~V 6048240.41 540661.03 12848.64@355.09 12848.59 -2.00 0.11 2.50 75.0 1782.98N 162.85N~/ 65.44 13.01 85.00 17.70 BPHM-PBD 0.00 75.0 2744.80N 251.9gW 99.51 15.95 85.00 27.10 BPHM-PBD 2.50 75.1 2748.72N 252.3_~N 99.65 15.97 85.00 27.14 BPHM-PBD 0.00 75.1 4062.93N 371.5C'W 146.26 20.05 85.03 40.54 BPHM-PBD 0.00 75.1 5809.64N 530.0CW 208.25 25.53 85.06 58.63 BPHM-PBD 0.00 75.1 6003.03N 547.5,%V 215.11 26.14 85.06 60.64 BPHM-PBD 0.00 75.1 12328.64N 1121.349/ 439.73 46.18 85.08 126.78 BPHM-PBD 2.00 77.1 12424.38N 1129.9,%V 443.11 46.82 85.08 127.65 BPHM-PBD 2.00 79.1 12519.12N l138.2zlW 446.45 47.53 85.09 128.49 BPHM-PBD 2.00 81.1 12612.74N 1146.2/~'W 449.75 48.29 85.09 129.30 BPHM-PBD 2.00 83.1 12705.14N ! 154.0~V 452.99 49.11 85.09 130,07 BPHM-PBD 2.00 85.1 12796.19N 1161.4PN 456.19 49.97 85.10 130.80 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Date: Wellpath ID: MPF-3, Measured Incl Drift Subsea TVD Course T 0 T A L Depth Dir. Depth Length Rec~lgular Offsets (fi) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hot Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) fit) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (fi) (ft) (deg.) (ft) Survey Tool 15722.57 63.01 355.73 6368.55 6413.25 100.00 12891.15N 1106.10/4 6048329.99 540653.76 12938.52@355.10 12938.47 -2.00 15822.57 61.02 355.85 6415.47 6460.17 100.00 12979.22N 1112.59W 6048418.01 540646.79 13026.82@355.10 13026.77 -2.00 15922.57 59.02 355.97 6465.44 6510.14 100.00 13065.61N 1118.7~'W 6048504.35 540640.13 13113.42@355.11 13113.38' -2.00 0.11 0.12 0.12 2.00 87.1 12885.79N 1168.62W 459.33 50.88 85.10 131.49 BPHM-PBD 2.00 89.1 12973.83N 1175.44W 462.41 51.83 85.11 132.14 BPHM-PBD 2.00 91.1 13060.20N 1181.9~V 465.43 52.81 85.11 132.75 BPHM-PBD 16022.57 57.02 356.09 6518.40 6563.10 100.00 13150.23N 1124.65W 6048588.93 540633.79 13198.23@355.11 13198.19 -2.00 16122.57 55.03 356.22 6574.28 6618.98 100.00 13232.96N 1130.21W 6048671.63 540627.78 13281.14@355.12 13281.11 -2.00 16222.57 53.03 356.36 6633.02 6677.72 100.00 13313.72N 1135.4,%V 6048752.34 540622.10 13362.05@355.13 13362.02 -2.00 0.13 0.13 0.14 2.00 93.1 13144.80N 1188.11W 468.39 53.82 85.12 133.32 BPHM-PBD 2.00 95.1 13227.52N 1193.94W 471.27 54.86 85.13 133.85 BPHM-PBD 2.00 97.1 13308.26N 1199.42W 474.07 55.92 85.13 134.33 BPHM-PBD 16322.57 51.03 356.51 6694.54 6739.24 100.00 13392.40N 1140.35W 6048830.98 540616.76 13440.86@355.13 13440.83 -2.00 16422.57 49.04 356.66 6758.77 6803.47 100.00 13468.90N 1144.9~aW 6048907.45 540611.77 13517.47@355.14 13517.45 -2.00 16522.57 47.04 356.82 6825.63 6870.33 100.00 13543.13N 1149.15W 6048981.65 540607.13 13591.80@355.15 13591.78 -2.00 0.15 0.15 0.16 2.00 99.1 13386.92N 1204.5tSW 476.81 ~ 56.99 85.14 134.78 BPHM-PBD 2.00 101.1 13463.41N 1209.3~aW 479.46 58.07 85.15 135.18 BPHM~PBD 2.00 103.1 13537.63N 1213.74W 482.02 59.16 85.16 135.54 BPHM-PBD 16622.57 45.04 357.00 6895.05 6939.75 100.00 13615.01N 1153.04W 6049053.50 540602.85 13663.74@355.16 13663.73 -2.00 END OF CURVE 16624.72 45.00 357.00 6896.56 6941.26 2.14 13616.52N 1153.12W 6049055.01 540602.76 13665.26@355.16 13665.24 -2.00 16657.87 45.00 357.00 6920.00 6964.70 33.15 13639.93N 1154.34W 6049078.41 540601.41 13688.69@355.16 13688.67 0.00 0.17 0.18 0.00 2.00 105.1 13609.50N 1217.7~N 484.51 60.25 85.17 135.86 BPHM-PBD 2.00 105.1 13611.02N 1217.87W 484.56 60.27.. 85.17 135.87 BPHM-PBD 0.00 105.1 13634.42N 1219.14W 485.38 60.45 85.17 136.05 BPH1M-PBD TKUD 16968.99 45.00 357.00 7140.00 7184.70 311.13 13859.62N I165.8tq~/ 6049298.02 540588.69 13908.57@355.19 13908.57 0.00 TKUA3 17181.13 45.00 357.00 7290.00 7334.70 212.13 14009.42N 1173.71W 6049447.76 540580.01 14058.50@355.21 14058.50 0.00 Target 10/1/95 17181.40 45.00 357.00 7290.19 7334.89 0.28 14009.61N 1173.72W 6049447.95 540580.00 14058.70@355.21 14058.69 0.00 TMLV 17291.43 45.00 357.00 7368.00 7412.70 110.03 14087.31N 1177.75'W 6049525.62 540575.50 14136.46@355.22 14136.46 0.00 CASING POINT OD = 7 m, ID = 6.28 in, Weight = 26.00 lb/ft. 17591.43 45.00 357.00 7580.13 7624.83 300.00 14299.15N l188.863V 6049737.38 540563.23 14348.49@355.25 14348.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 105.1 13854.09N 1231.1t'W 493.10 62.15 85.20 137.79 BPHM-PBD 0.00 105.1 14003.87N 1239.3TN 498.36 63.30 85.22 138.97 BPI-IM-PBD 0.00 105.1 14004.06N 1239.3t'W 498.36 63.30 85.22 138.98 BPHM-PBD 0.00 105.1 14081.75N 1243.6CW 501.09 63.90 85.23 139.59 BPHM-PBD 0.00 105.1 14293.57N 1255.1L%V 508.53 65.54 85.26 141.27 BPHM-PBD MPF-~ WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES'Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS' 1638 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS' 100-150 cc YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP, JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 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 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. AP1 # 50- October 20, 1995 WELL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev~redrll [] aery [] ADMINISTRATION 1. 2. 3. 4. 5. 10. 11. 13. Permit fee attached .................. · N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary.. N Well located proper distance from other wells ...... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party ............... Y N Operator has appropriate bond in force ......... Y N Permit can be issued without conservation order .... Y N Permit can be issued without administrative approval. . N Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs'. ....... Y~ 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 ............ .~ N 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 .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... {=') N 26. BOPE press rating adequate; test to ~~ psig.~_ N 27. Choke manifold complies w/API RP-53 (M~y 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N /____ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... Y 33. Seabed condition survey (if off-shore) ......... V N 34. Contact name/phone for weekly progress reports ..... /Y N _ [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: HOW/jo - A:~FORMS\cheklist rev 03/94 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. Tape Subfile 2 ~s type: LIS TAPE HEADER MILNE POINT UNIT MWD/MAD OGS 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 1 6673.00 M. HANIK J. GAFFANEY MPF-38 500292261400 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 13-MAY-96 MWD RUN 2 B. ZIEMKE T. ANGLEN 6 13N 10E 1994 2731 45.46 12.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 REMARKS: 20.000 112.0 8580.0 MWD - DGR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. AITNULAR & CRITICAL VELOCITIES CALCULATED USING THE POWER LAW MODEL. MWD RUNS 1 & 2 WERE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, & ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). PER THE CONVERSATION BETWEEN DAVE DOUGLAS OF WALS/PDC, LARRY VENDAL OF BP EXPLORATION, & ALI TURKER OF SPERRY-SUN, THE DEPTH SHIFTING OF MWD DATA TO WIRELINE GR HAS BEEN WAIVED. ti 1-i vi:D 29 Aia C I& Gas Cons. Commission Anchorage FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 110.0 8530.0 110.0 8522.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 110.0 5740.0 2 5740.0 8580.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-38 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OPHv~ 4 4 RPM MWD 68 1 OHNM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 547 Tape File Start Depth = 8584.000000 Tape File End Depth = 108.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 135625 datums Tape Subfile: 2 632 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 110.0 EWR4 110.0 $ 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: STOP DEPTH 5690.0 5682.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 15-NOV-95 ISC 2.11 / MPDS 1.22 3.94 MEMORY 5740.0 110.0 5740.0 0 .4 77.7 TOOL NUMBER P0459CGR8 P0459CGR8 12.250 112.0 SPUD 9.20 51.0 9.0 1300 9.8 2.100 1.356 2.100 2.300 68.0 109.0 63.0 68.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-38 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 365 Tape File Start Depth = 5750.000000 Tape File End Depth = 108.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 90281 datums Tape Subfile: 3 430 records... Minimum record length: Maximum record length: 38 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5665.0 EWR4 5657.0 $ 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: MAXIM UMANGLE: STOP DEPTH 8530.0 8522.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 17-NOV-95 ISC 2 . 11 / MPDS 1.22 3.94 MEMORY 8580.0 5740.0 858O.O 0 74.0 76.6 TOOL NUMBER P0459CGR8 P0459CGR8 12.250 112.0 SPUD 9.50 51.0 9.0 1200 7.8 2.100 1.240 2.100 2.300 68.0 120.0 63.0 68.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-38 : MILNE POINT : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 190 Tape File Start Depth = 8584.000000 Tape File End Depth = 5650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 182578 datums Tape Subfile: 4 255 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS 96/ 01 **** REEL TRAILER **** 96/ 5/14 O1 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 14 MAY 96 2:41a Elapsed execution time = 4.67 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF-38 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22614-00 REFERENCE NO : 95388 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF-38 FiELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22614-00 REFERENCE NO : 95388 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/ 3 ORIGIN '. FLIC REEL NAME : 95388 CONTINUATION # : PREVIOUS REEL COGENT : B.P. EXPLORATION, MILNE POINT MPF-38, API #50-029-22614-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 96/04/ 3 ORIGIN : FLIC TAPE NAME : 95388 CONTINUATION # : 1 PREVIOUS TAPE : COPff4ENT : B.P. EXPLORATION, MILNE POINT MPF-38, API #50-029-22614-00 TAPE H~ER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN 1 95388 RUMINER ANGLEN SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPF-38 500292261400 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 3-APR-96 BIT RUN 2 BIT RUN 3 6 13N iOE 1994 2731 45.46 45.46 12.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 8561 . 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 3RD STRING PRODUCTION STRING Well drilled 19-NOV through 28-NOV-95 with CDR/CDN. All data was collected in a single bit run. CDN data only collected from 14600' to 16420' due to battery and memory limitations. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION ' O01CO1 DATE : 96/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AK]M~ER: 1 EDITEDMERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SO?4MARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (M~ASUREDDEPTH) START DEPTH STOP DEPTH 8508.0 17621 . 0 BASELINE DEPTH 88888.0 17253.0 17250.5 17229.5 17213.5 17199.5 17178.0 17172.0 17162.0 17155.0 17136.5 17099.0 17084.5 17074.0 17064.0 17040.5 17005.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88921.5 17286.5 17282.5 17258.5 17239.0 17227.5 17203.5 17200.5 17189. 17185 17163 17121 17108 17098 17087 17064, 17029. LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: 16961.0 16957.0 16943.5 16920.0 8550.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 16990.5 16984.0 16966.5 16941.5 8550.0 BIT RUN NO. MERGE TOP MERGE BASE The depth adjustments shown above reflect the MWD GR to the CH GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 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 630354 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~ 630354 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: NA~E SERVUNIT SERVICE API APIAPI API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RP MWD 0H~4~I630354 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0H~630354 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~ 630354 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD. OH~I 630354 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD. FPHR 630354 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD. HR 630354 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630354 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630354 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630354 O0 000 O0 0 1 1 1 4 68 0000000000 PEF 14WD BN/E 630354 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630354 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD. PU-S 630354 O0 000 O0 0 1 1 1 4 68 0000000000 GRCHWL GAPI 630354 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 17621.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD. -999.250 ROP.MWD. 96.781 FET.MWD. GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. I4WD -999.250 NPHI.MWD. -999.250 GRCH. WL -999.250 'DEPT. 16500.000 RA.MWD 2.958 RP.MWD 3.025 VRA.MWD VRP.MWD 3.055 DER.MWD. 3.000 ROP.MWD. 92.298 FET.MWD. GR.MWD 90.004 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD. -999.250 GRCH. WL -999.250 DEPT. 15000.000 RA.MWD 3.033 RP.MWD 3.282 VRA.MWD VRP.14WD 3.317 DER.MWD. 3.185 ROP.MWD. 221.273 FET.MWD. GR.MWD 97.552 RHOB.MWD 2.356 DRHO.MWD 0.031 PEF.MWD CALN. MWD 8.500 NPHI.MWD. 30.900 GRCH. WL -999.250 DEPT. 13500.000 RA.MWD 3.277 RP.MWD 3.522 VRA.MWD VRP.MWD 3.583 DER.MWD. 3.429 ROP.MWD. 292.505 FET.MWD. GR.MWD 92.823 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD. -999.250 GRCH. WL -999.250 DEPT. 12000.000 RA.MWD 3.215 RP.MWD 3.614 VRA.MWD VRP.MWD 3.656 DER.MWD. 3.454 ROP.MWD. 193.563 FET.MWD. GR.MWD 80.662 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD. -999.250 GRCH. WL -999.250 DEPT. 10500.000 RA.MWD 6.055 RP.MWD 6.598 VRA.MWD VRP.MWD 6.598 DER.MWD. 6.445 ROP.MWD. 233.986 FET.MWD. GR.MWD 79.436 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD. -999.250 GRCH. WL -999.250 -999.250 -999.250 -999.250 3. 011 2. 732 -999. 250 2. 922 O. 417 3. 011 3.290 0.272 -999.250 3.345 0.419 -999.250 5.767 12.304 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: DEPT. 9000.000 RA.MWD VRP.MWD 3.188 DER.MWD. GR.MWD 71.581 RHOB.MWD CALN. MWD -999.250 NPHI.MWD. 3.171 RP.MWD 3.160 ROP.MWD. -999.250 DRHO.MWD -999.250 GRCH. WL 3.153 205.626 -999.250 -999.250 VRA . MWD FET.MWD. PEF. MWD DEPT. 8508.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD. -999.250 ROP.MWD. -999.250 FET.MWD. GR.MWD 35.427 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD. -999.250 GRCH. WL -999.250 3.231 0.772 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE . 96/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NU~iBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8508.0 17621 . 0 $ LOG HEADER DATA DATE LOGGED: 28 -NOV- 95 SOFTWARE: SURFACE SOFTWARE VERSION: 2.5 DOWNHOLE SOFTWARE VERSION: 4. OC LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR GR/RESIST. CDN NEUT./DENS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPfiv~) AT T~MPERATURE (DEGF) : MUD AT M~%SURED TEMPERATURE (MT): MUD AT MAX CiRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): MEMORY 17588.0 8508.0 17621.0 80 38.0 76.2 TOOL NUMBER RGS055 NDS055 8.500 8561.0 LSND 9.80 500 3. 063 70.0 2. 712 70.0 REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 8580' - 17588' HOLE ANGLE AT TD = 37.97 DEG @ 17588' RES TO BIT: 62.33 '; GR TO BIT: 72.75' NEUT TO BIT: 124.12'; DENS TO BIT: 117.14' TD WELL @ 10:00 26-NOV-95 CDN RECORDED FROM 14600' TO 16399' ONLY DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NDY, IB SAMP ELEM CODE (HEX) DEPT FT 630354 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OHMM 630354 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OHFIM 630354 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 Otff4M630354 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 630354 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW! HR 630354 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 630354 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 630354 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 630354 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW1 BN/E 630354 O0 000 O0 0 2 1 1 4 68 0000000000 CALN LW1 IN 630354 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW1 PU 630354 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 630354 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU 630354 O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW1 IN 630354 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 17588. 000 ATR.LW1 -999.250 PSR.LW1 -999.250 DER.LW1 ROPE.LW1 96.781 TABR.LW1 -999.250 GR.LW1 -999,250 RHOB.LW1 DRHO.LW1 -999.250 PEF. LW1 -999.250 CALN. LW1 -999,250 TNPH. LW1 TABD.LW1 -999.250 DPHI.LW1 -999.250 DCAL.LW1 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: DEPT. 16500. 000 ATR. LW1 ROPE. LW1 165.413 TABR. LW1 DRHO. LW1 - 999. 250 PEF. LW1 TABD.LW1 -999.250 DPHI.LW1 DEPT. 15000. 000 ATR. LW1 ROPE.LW1 301. 086 TABR.LW1 DRHO. LW1 O . 008 PEF. LW1 TABD . LW1 1.309 DPHI . LW1 DEPT. 13500. 000 ATR. LW1 ROPE. LW1 249. 609 TABR. LW1 DRHO . LW1 - 999.250 PEF. LW1 TABD.LW1 -999.250 DPHI.LW1 DEPT. 12000. 000 ATR. LWl ROPE. LW1 227.837 TABR. LW1 DRHO. LW1 - 999. 250 PEF. LW1 TABD. LW1 -999. 250 DPHI. LW1 DEPT. 10500. 000 ATR. LW1 ROPE. LW1 224. 986 TABR. LW1 DRHO . LW1 - 999.250 PEF. LW1 TABD . LW1 -999. 250 DPHI . LW1 DEPT. 9000.000 ATR.LW1 ROPE.LW1 205.626 TABR.LW1 DRHO.LW1 -999.250 PEF.LW1 TABD.LW1 -999.250 DPHI.LW1 DEPT. 8508. 000 ATR. LW1 ROPE. LW1 -999. 250 TABR. LW1 DRHO. LW1 -999.250 PEF. LW1 TABD. LW! - 999.250 DPHI. LW1 2.869 PSR.LW1 2.596 GR.LW1 -999.250 CALN. LW1 -999.250 DCAL.LW1 2. 995 PSR. LW1 O . 303 GR. LW1 3.334 CALN. LW1 14 . 600 DCAL. LW1 3. 299 PSR. LW1 O. 290 GR. LW1 -999. 250 CALN. LW1 -999. 250 DCAL. LW1 3. 175 PSR . LW1 0.411 GR. LW1 -999. 250 CALN. LW1 -999. 250 DCAL . LW1 5.338 PSR . LWl 12.374 GR. LW1 - 999. 250 CALN. LW1 -999. 250 DCAL. LW1 3.192 PSR. LW1 0. 773 GR. LW1 -999. 250 CALN. LW1 - 999.250 DCAL. LW1 -999. 250 PSR. LW1 -999. 250 GR. LW1 - 999. 250 CALN. LW1 -999. 250 DCAL. LW1 2.826 79.196 -999.250 -999.250 3.495 95.548 8.615 0.115 3.427 87.719 -999.250 -999.250 3.589 82.963 -999.250 -999.250 5.601 89.055 -999.250 -999.250 3.174 74.387 -999.250 -999.250 -999.250 35.427 -999.250 -999.250 DER. LW1 RHOB. LW1 TNPH. LW1 DER. LW1 RHOB. LW1 TNPH. LW1 DER. LW1 RHOB. LW1 TNPH. LW1 DER.LW1 RHOB.LW1 TNPH. LW1 DER. LW1 RHOB. LWI TNPH. LW1 DER. LW1 RHOB . LW1 TNPH. LW1 DER. LW1 RHOB. LW1 TNPH. LW1 2.841 -999.250 -999.250 3.284 2. 427 33. 000 3.380 -999.250 -999.250 3.422 -999.250 -999.250 5.521 -999.250 -999.250 3.180 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1996 15:24 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/ 3 ORIGIN . FLIC TAPE NAME : 95388 CONTINUATION # : 1 PREVIOUS TAPE : COf4~IENT · B.P. EXPLORATION, MILNE POINT MPF-38, API #50-029-22614-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE . 96/04/ 3 ORIGIN : FLIC REEL NAME : 95388 CONTINUATION # : PREVIOUS REEL : COGENT : B.P. EXPLORATION, MILNE POINT MPF-38, API #50-029-22614-00 MPF - 38 RECEIVED Anchorage w ' . ~, .. . ...; .... ..-) . . , l,, ,.. / /~a L~. ~, / /~~:.~.... - ---,. -.-- · ~ ~1--- ~ - i. - ~.--~ ..... ....... ~1 , . ~. -' J~ ~ '. '~ :7.:..~:::7:- : .... · ~ .. :.~--- . - ,. . :":""~::":'.':; :~;:~:~. · -',, "- .... ,'" Run ~' ............. . ..... -. - 24 - Febma~ - 1996 ~ ...... : ~...., ~.- ~-; ::::::::::::::::::::::::::::::::: ..... ~-.' ............. ~--'...,:': ..... Ma~ed Line_.,~ - ~ .. ~. ~ ~_...... ..... ...... -?"~ '"- Card Hole ........ 2~.%. ~ ........ ' ' :.~. ..~:~ ......... ~. - :..~:.~.~. . ~_?_.~_ .,.__%~t_.~_ _~. ~__ ,~i~.~._.~ ___ · ~, ....-_. ., ~ ~-%~-" ~ - ~ . ::..-- : .. ~ ..~ ..................... ~..-~ -. ..... ~ .... . .- - .m ........ _ - . ~ :; · ;?~' '--~- ... :T : '- .:: '... ...... , ~- 16900' 17380' Date WESTERN ATLAS Logging Services _ape Subfile, 2 i$ type: LIS TAPE HEADER MILNE POINT %INIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF- 38 500292261400 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 20-MAR-96 6603.00 D. BARBA J. FOX 6 13N 10E 1994 2731 45.46 12.20 OPEN HOLE ~ CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 8561.0 PRODUCTION STRING 7.000 17568.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 2 1 24-FEB-96 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: PFC/PERF. 40.00 26.00 ALL DEPTHS ARE WIRELINE DEPTHS TIED TO MARKED LINE. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 16897.0 17380.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: MAIN PASS. NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 38 FN : MILNE POINT COLIN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# Total Data Records: 0) 1014 BYTES * 12 Tape File Start Depth = 16895.000000 Tape File End Depth = 17380.000000 Tape File Level Spacing = 0.500000 Tape File De. pth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2914 datums Tape Subfile: 2 106 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NIIMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 16896.0 $ LOG HE ER DATA STOP DEPTH 17394.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): .7 BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CASING COLLAR LOC. PFC PFC GAMMA RAY WHEL WHEELS $ 24-FEB-96 FSYS REV. J001 VER. 1.1 1153 24-FEB-96 17482.0 17410.0 16900.0 17380.0 1800.0 YES TOOL NUMBER 2315NA 0722XA 9999ZZ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT) : 0.000 17568.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL P~ATIO: CHOKE (DEG): WATER/DIESEL 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 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) : - 0.0 REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : MPF - 38 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 48 Tape File Start Depth = 16896.000000 Tape File End Depth = 17394.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11971 datums Tape Subfile: 3 121 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile~4' iJ~ type: LIS 96/ 3/20 01 **** REEL TRAILER **** 96/ 3/20 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 20 MAR 96 6:18p Elapsed execution time = 1.93 seconds. SYSTEM RETURN CODE = 0 ***~***~ AF.ADR!%i, *******~ SO~LUMB~;~R ********** ********* ************************************************* C019F:'~Y SHARED SB:',VICB:', ISLe. gELL NA~ MF'F-38 LL:~TION 1 MI~ ~iN: LOCATION 2 PRUDHOE BAY., NS3~ AX MA~E~C PECLINATION 28.~! GRID CO~RGD~CE ANGLE 0~00 DA~: 16-~V-$5 ~ELL NU~ER 38 APl 50-027-226~4 JOB NO~ 3Y40Y WELL HEAD LOCATION: LAT(N/-S) 8,00 DEP(E/-W) 0,00 AZII~TH FR~ R~TA,E~' TAP, LE TO i'F)HG~ IS TIE IH F:OINT(T!F') : M-F..A£UR~, DEPTH 0+00 TRUE VERT DEPTH 0,00 T .'" ~NuLI~A.~.ON AZIMUTH 0,00 LATITUDE(~!-S) DEPARTURE (E/-W) O, O0 RECEIVED SEP 5 0 ~aska Oil & Gas Cons. Commission Anchorage ~ASUR£D !N%F-:VAL ~:T!CAL D~'?H ft' .ct ft 0,~.3 0,0 0,00 !93,60 ""' ' iYj,o !93.60 23~'.1~ 45,6 ~,O.D 4!~-,?~ 88,? 508,60 596:70 775 86'.;.' .47 :V.V,o? !2~Q~'--', !534,3 !629,04 1912,35 2007,19 2!01,~0 2!97~60 22~3,~ 2673.88 2769,~ ~ 2863,65 3051,73 3!47.~ 3335,71 34~ ~ 3523,46 371i,20 ~J~EY C-ALUu~?~uN~ ****.~***-x~** CIR~L,~R A~S .~.~HOD***.~*** TARGET STATION S~u INCU4, ft ~ 0,~ 0.00 -0,65 0,45 -0,'.29 0,46 -to&3 0,67 -2,93 0,8! 91,7 ~8,57 -4,20 8B,i 596,67 -5,10 0,36 88,7 685,37 -3,69 2,19 4 90,I ,7.,30 1,8I .,8/ '~,.9 868,87 10.09 5,33 96,6 965,00 94,3 !059,15 94,0 1152.2~ .4.~ 1245,55 95,2 1~9,18 T q'~ Ni-S deg ft 0,00 0,00 ~6,20 -0.68 184,06 -!~03 194.~1 -!,88 190,46 -3,0! 19,87 6.~ .30,69 ~ 43,13 8,50 5~,~5 10,!1 75,~ 10,82 D=~U~ DISPLAC~T at ft ft 0,00 -0,34 0,76 -0.43 1,!! -0,58 1,97 -0,83 3, !2 ~T~ ~'4 deo 0,00 206,20 202~64 197,19 195,~' DLS d~/ lOOft 0,00 0,23 0,3.5 0.26 0.17 200+9! -4,31 -!,20 4,48 195,57 0,20 177,23 -5,24 -!,44 5,43 !95,~: 0.67 1,04. -3,82 -!,39 4,07 200,0! '2,87 2,91 1,72 -I,!7 2,0~ 325,90 2,98 2,~' tO.O~ -0,74 10,09 355,78 0,49 2,~ i9,92 -O,Z7 1-'.-7,92 3_,9:2: l,;n 2,43 .30+61 0,20 30,81 0,37 0,45 ,'-,-. .,-', '-,", n,.4';', a."-,-, 33 0,82 1.7.c.' 1,2'~. -.o~-oo ...... 4+6t 58,58 1,47 58,60 !,44 !,78 5,55 75,80 3+01 ~,~, 2.~ 0,~ 92~2 1429,54 93.42 !2,10 1.07 94,08 4,03 94,!7 97,6 1524,76 114,59 13.06 359,20 1!5,33 4,'~ 115,40 94,7 !616,50 137.98 !5,58 353,9~ 138,67 92,3 ..~,,.'~n~ ~ 1A5,12. .~-8.~8. ~.~.,,~n.."~165,60 -1,09. !65,,~0 97,2 1796,72 196,35 18,94 ~0.05 !96,50 -5,31 196,60 352,74 2Z%76 -11,02 23B. ~,~*~ 3~M.04 262,32 -15.00 262,~ 354,22 300,45 -!8+92 30!,04 ~4~,-'~ '~'~ ~ 354,20 ~ ~ ' 343 - ~56,% 389,~2 -~o,& 390,7~ 93,8 1~45,03 227,89 20,46 ...~,~. 262,66 22,58 94,4 2059,52 ~DO,98 ~,33 96.0 2!45,42 343,83 27,70 96,! ~?,3~ 390,70 30,67 2,45 2.0':-' 1,07 ~.,. ~', _,.. 94,9' 2309,71 96, -! '~ 94,7 ,-m. ~,,' .., 94,4 2538,7t ~,3 2612,25 357,22 356,73 356,12 ~' 07 3~, ~!.12 33,57 356.47 440.17 4o~ A~ 35.84 3~,02 494,~2 b'52.~ 37,~ 356.~9 555.!,19 610,92 ~'+5! 357,65 609,82 67!,53 ~.54 ~8,2! 670,45 4 ~,~ A.u7 1.07 3 TM 0,36 !,89 r~ ~ 2,'-)'! 2,47 3.~ 94,4 2684~3! 732,¢B 40,99 ~4.0 ~?~ ~^ 795,61 94,1 2820,89 ~41,61 45.70 ?5,5 2886,56 ~0,98 47.46 94,? 2948.86 !002,50 50.43 -~',7! 441.17 356,14 3,07 ~..,~: 2,34 -~,8! 55_-,2,36 356,2S 1,6! -~.60 611,04 356,36 2,33 -'.,;0,,79 671,69 356,52 0.38 357,95 731,45 -,~,~o 7~,70 ~6.65 1,55"5 ~,M 794,59 -45,Z? 795,88 356,74 2,66 ,c~ ~,.,. -.~.~? 861,91 2,~ ~6,33' 9~.80 -52,86 931,30 356,~ 1,36 355.34 1001,~3 -~8,07 1002.8! ~:~ ~ 3.23. 356,56 356.~ 356,30 356,'~,~ 356,00 93,6 3007,38 !075,5! 52.14 3~.47 1073.85 -64,56 1075,79 52,5 3~52.6I 1!49,76 54,58 354,91 !147,78 -71,42 1150.01 95_,,2 3115,57/ !22,~,85 57.81 353.78 1226.50 -79,23 1229,06 o ........ ~n-.-,= .~,2! 353,61 1305,15 -q~,g9 !3~,I! ~.4 ~08,61 139!.78 62,81 353,77 !~,8,51 -97.14 1~!,90 1,97 2,66 3,53 2,60 -' 2,73 ~Ag_,.~' !NT~VAL VP-RTIC~L D~TH DEPEd ft ft 3836,12 94,~ ~9 3900,67 94,5 3~6.60 3995~i2 94J 4086.~ 91.8 3346.86 4~ ~.~ -r~ 95.1 3~73.52 4372.86 4467.74 4654,42 4747,47 4843.42 5032.~ 5!27.63 5313.39 5693.8! 578%35 58~3,86 5979,82 607!,50 6i~6~ 64~,53 6637.76 6825.35 7015,88 711!,16 7300,82 7392.73 7488,73 96,3 3400,8! 94.6 ~, oo 95,1 3450.03 93,! 35!6,12 95,9 3538, 97.3 3564.24 y z..l 3~3£,27 93.7 ~56.02 94,? 3679,06 95.9 3702,79 94,6 ~,0 3751.9! 95,5 3U6,40 94,5 3800.54 91,7 3847,62 ~.y 387[,83 91,8 3893,77 94.3 ~40,59 94,6 3964,5~ 94.6 3987,48 92,0 4010,31 95.6 -40~4,~9 94,5 4058.2! 96,0 .4082,47 95,3 4107,05, ~,3 4130,94 96.3 "~ °~ 91,9 4176,32 ?6,0 4700,59 TkE~ ~ATTON AZ~_I~H ' """~""'"'"' SECTIC+~. !~-LN, N/-S ft deg d~ ft !477.24 65.73 :353.Z;' 1473.~$ ="' ~'"' AS,4A 351,95 JO-..:~. . ._ :A52 7~ 71 25 351,76 !647,&0 1740,08 73,55 351 ,~ 1734, 183!, 2~ 73.90 ~2,95 1824,64 l,~:,Jo 73,16 ~,0. !916,44 20!4.~ 75.46 354.61 ~'07.11 2106..~, ~,74 -355.43 2098,86 2196.86 74.96 356,~ 2188.83 2287.43 77,66 355.95 2279,2! 2378.20 76.96 356,62 2369.80 a,,1 :, 76.54 356.5g 2463,03 2560.67 75,79 356,76 ~52.01 26~,95 ~,45 356,.46 2646,!5 o.:J./l 74,60 3~.17 2826,71 2?26,33 76,~ ~6,53 27~7,~ 30!B.39 ~,87 357.27 300q.19 3111.~ 75.23 356.33 3!0!.92 ~0~. ~ 74.~.~. 35.61 3~_ ~;.. ~ n~.~ 3294,36 75.3~ ~6,20 32~4,61 3386.70 74.99 3~.83 3376,73 3478.07 75,41 356.15 3467.~4 3~!,02 ~.86 356.06 3560.63 3659,~ 74.73 35,6,52 36-49,12 375..i.47 75.72 3~.95 3740.72 3840.62 76.64 ~5.80 3829,65 3~3.78 ~.84 ~, 40~.02 74.67 355.71 4012.58 44l llo,~ 76,04 355.24 4104,84 4208.34 75.87 ~.53 4196.32 4297.49 75.40 355.81 4285.22 4389.97 75,41 35-.4,44 4377.36 4¢~.~ 75,41 ~ ~ 4468.37 .~ ,- ~.1~- . 457.4.27 75. -30 353.52 4.56.0,66 ~6,29 74.80 353.76 4652.15 4,,~6.14 75.~ ~3.15 4741.77 4529,0! 75,75 352,72 4923,Cq ~0~1,81 74,96 .~.u~ 50!5,~. MF'F-3S. AZIZa,TH,.' 355,67 355.47 3~ -165~14 I9~3,54 ~.OB -173,31 20.14,58 355,06 i-i ~ 21~6" 355,06 '.O~,O£ ~'" 87 355.i0 -1~.84 2287.44 3~.14 -!~..72 ~78,20 355,18 ~.2~ 247!.57.. -2!8,05 2654,75 e.%'55,33 ~4 .. -::~.35 77aA,89 355,38 -~,92 2835.73 355,43 -230,~I 2926,35 355,47 ~ ~ 3~,52 -:~p.o. 3018.42 ~"' ,~7 31!1.27 355,56 -~..,,~ 3202.63 DLS ~e~/ 3,11 3,19 2.94 2.5! !,44 2,27 2,46 .0,89 1,28 2.~ 1.03 0.~ 0.84 0,46 0,54 .. 0./£ 1,67 0.78 1,16 0,~5 -254.C5_ 3294 . -.~"~ 355.58 u..-8 · -.,, .,-, O,J.c ,..,o&.~,, 6 3~.~c' . .J.: ,; -2~6.85 '~4~"~. 13.., , ~.~ 355,J0 0.55., -Z73,17 q~"~ '"" ~== '" 0,48 -27.A,71 3~57,~6 355,63 1,32_ 3~..34 1.19 355,65 !.01 355,66 0.86 355.66 1.28 355,~ 1,53 -~As.~'~ 3751.= -2~1,35 -298.00 39~.8~ -304,59 4025,12 -319.20 4208.44 355,65 0,35, -~.~.'.,~ 4297.60 355,65 0.59 -3~,79 4390,07 355,64 1.~ ~ ~n 44oi,2~ 355.61 0,71 -353,50 4574,34 355,57 0.26 3~.53 0.58 355.49 1.01 ~== ~ 0.97 355.40 0,81 3~.35 0,90 -363,69 4~.,.35 -373,78 4756,50 -~6,40 4939,02 -~7,88 5031.81 DEPTH DEF?H - ft ft ft 7961,48 94,0 4316,~ SL~;PJ~ CA, LCULAT., ud~ ?~T .STATION AZIMU?H'- ~T!TUDE SECTION INCLN, Nd-S ft deg deg ft 5!22,59 76..~ 353o'~: 51~,45 52!5,11 76.23 352,70 5197,~ 5337,23 75,17 "~ . 5398,70 ~,~! ~3,81 5379,~ 5'4-','3~,7775.35 353.~3 54,70,12 8342,43 9;,~ 74.62 3~,56 ~35,97 ~ 75.65 355,7a 5~4,~0 6434,60 ~2,2 444!,,.~ 5~45,~6 ,. 8501,55' 67,4 445~.~I 6011,10 74M3 3~,92 8653.~"' 15'~,~ ~~sqo,37...~ 6156,~ ~,~ ~ 3~,41 6134,32 ~ 96,8 .j~:',.~ &~,4o 35~.43 o,~,~Z '~,5 4~£,30 ~.+.~A~ ~ 75,15 .._._. 8~38,82 ._,~ o ,55 ,4,~ 353,38 ~:.-f~ ..... - MF?-38 ~/-W de?' ft ft deg lOOft -~,~3 52!5,1! 355,27 -442,6~ 52~7,23 355,22 i,49 -~54,29 539~,7i 355,17 2,01 '. -473,02 ~82,5! ,...,'..2, ~."'='-'= :4. 1,61 -480,5~ 5674,?~,.,.~ 3~.':. 4_ . ... 0,53 - .. .... :j.~_.-, .._ 0,32 -487,5;' ~/,5,17 "~ '~s ,', ,, ~ ¢tQ'-,~ ~r, . , -4~.,_u Jo>: ,.~ 355,. IL-.- 0,~'j -=-~, ,"-~ 5945,97 355,' '~o !,!3 -506,05 60i!,10 355,17 1,54 -517,04 6!56,57 355,18 0,78 '~Ot ..... 6oo9,5~ 1,28 -547,32 6431,~ 355,!2 0,27 '90~,ee ~" "~c~..,v ^ '~.,v~,70' ~ . o;~;,~v"~" "^ 7~,7A, . ~2,5~ 6499,Z7 -55~,52 6523,23 355,09 0,83 91~'.29 95,4 462~,~4 ~A15,!5 74,69 35i o~ ~ ^ .._ ,.,~ 6~9v,51 '57...'0,93 6615,19 ~.~ n= 0,66. -~8~,J. 6707,60 355,02 1,95 9225,16 95.,,? .~.~:,,,"'=' ~" ~707,54. . 74,71 :~3,87 6682,Z? ~ ~ ~ ..... 353,76 6772,3~ -~;'~1! X---,, ~v q~5.,"~ 0,48 q l~-18 94,0 4677,28 4798,11 ~' ~ .i>,,~, ....... . ~..' , - . / ~ ! '....,/ - 9~4 352 ,~ ..~.,;~ 1,~.~ · ~:~,60 95,4 4703,35 6889,84 74,02 ,~6 68.~,47 -603,~ ./,889,92 9Jv7',04 94~4 47~,!7 6~0,62 ,~,~'~ o~ ~,,~,"=' "'A0s3,~.. _. -' 69&~,71 " '"' 1,93. · . 4~,,5o 7070,66 74,30 3~,Cq 7043,36 -621,85 7070,76 354,~5 0,76 96v2,~Y 9695,90 "~ ~ .. ~ ~ ~' ~ 7132, -630,2! 71d~,53 o_~.,95 0,?3 ¢o,o 4.77.-'9,99 71A0,43 /4,0~ o.w,~o 74 o~o~ 70 96,8 ~nA,35 7253,58 74+~ 355,04 7225,49 -638,'72 7253,69 354,95 0,89 %,~ 4B31,91 74,13 7315~ -a~.~ '~"' ~* ~4,75 0,~ 998!,01 74,! ~55,03 7434,64 73,64 354,29 7.4-05,,85 -654,87 7434,74 35~,95 !,08 10073,32 92,3 4B84,40 F523,¢9 73,17 353,81 7493,34 -664,C~ 75~,20 354,94 0,71 n~, 94,2 ~4,09 -~7~, 7613,31 354,~2 0,41 1~.~7+55 4911,89 7613+19 72,90 7583,46 . . 54 I0262,!7 94,~ 4%~,'44 770~,~9 73,23 356,90 7673,69 -./40,./4. 7703,81 354,7~ 2,86 10356,16 94,0 4965,90 7793,86 74,10 356,73 ~-.&3./4 -.-.q15,65 /-'793,96 ~,,~ 0,94 10451,16 95,0 499!,47 7885,0"2 74,68 356,74 7855,0? -6'.90,87 7885,4! 35~,97 0,6I ~O~ .... ', ~ ~n~.nl ,9/4,80 74 ~.~,o. ,~, . ~sa,,o ~u40,~ 8065,59 ~, , -/u~,oz 80.5,o~ ~55_,~u 1,13 10637,97 94,0 .... 75.33.. 35'5_,.,H, 80~,9e -n~ o, x ,. ~ ..... ~ I0734,13 96,2 ~65,Z7 8158,46 74,62 ~.47' 8!Z~,~ -710,15 8!5~,54 355,01 0,73 ',. ~ ~ - ~ 10829,~4 95,5 5090,~: 8250,59 74,83 354,2! 8~lV,~o -718,43 8250,67 35'5,00 1,~' ... ~, . .~4~ ~n 355,00 !,40 !0W4,50 94,9 5114,18 8~+2,42 76,15 ~..A,38 8310,71 -727,56 ,~ ~ ~ 75,~D _ .. ~0!~,Ov 90,6 .~o,uv~' "" o~u.oo""~ ~ .~ 353.99 839A,~. _. -724,.47 84DD,42 11109,72 94,6 5!59.11 85~.07 75,75 35_,4,23 8489+~ -745,89 8522,17 354,?~ 0,35 11204.24 94,5 5!82.65 8613.59 /"5,40 353.7~ 8580,50 -7~,50 ~13,69 354,97 0,65 11~¢7,42 .~,2 5206,77 8703,56 74.~0 Z3,49 8&.'9,55 -765,53 8703,68 354,95 " F'AG£ ,.~ASUR~ !N?~:UAL -V~R?!C~ D~;'TH DEFT4 ft ft ft l~4~v,fi6 ~5,8 5~8.16 115~0.50 ?0.9 5282,39 11677.05 96,6 ~307~26 12807,98 I ~"-'~'= 9A 13090.9! lo!~0,o5 · } r5."%~ 4 A .¢ OO.., 1347O,39 13Joc,,4~ 13945.I8 I4040,--.-.. !4: 0=. 17 14796,67 '. T~..-.~ A~I~TH ~ TkI~T ~t ION ft deg 87%.40 74,J6 ~88,66 74,03 353,87 8Y7¢,~u 75,07 ~4,78 9159,65 75,78 94,0 5~3~¢5' ~?0,67 ~..48 35q,69 95_.,3 5378,08 9342,88 75,24 ~4,5~ 95,1 5402,56 9434,7i 74.92 . 353,8! 91,9 5426,77 9523,32 74,53 35_3,13 94,4 5451,03 9614,52 75..~ 354,71 94,3 5474,66 9705.81 75,30 3q'M.44 94,8- 5498,34. 9797,64 75,75 356,24 94,~ 5522,1! 9~-9,41 75,24 355,69 ~,5 5~6,17 ??7%80 74,95 3.54,82 ~,6 ~_'-571,i0 10072,14 74,~ 3~,24 MPF-3q3 IJ.i;~UuE D~'AF:TU~ ~,i.=r~.~,~m~ at ft ft ft 8762,3! -~, 12 8Y4i,c4 , z:, -801,76 91~.97 -]~,2B 9159.79 . 7~i4,69 -816,/I ~97,87 -~34,72 9434,87 9485,9'g -~,80 9523,48 ~76,65 -854,45 96!4,70 ~TT~l ,FI'H DLS deg/ lOOft 1,16 1,02 1,49 0,30 1.70 0,3! .0,80 Q~ O, ,~ 2,02 · -,.~:' 4 g' 9667,55_, -8(-3.09 9706,00 .j_,~:, yO 0,49 9/Y; ,o, 354,90 1,69 y/.;.¥,u~""'-" "" -870,55 '-":'" 98~.62 -AP,O1 '¢..,8~,,~c. 354,S'I 0,78, ..... %9,97 354,S"2 0,95 99J~.70 -884,4.¢' ';' '"' 10032,69 -892.49 .~00/Z,~ 354,92 0,43 , 94,1 55~5,0~ !0i63,!4 75...,63 355,90 I01~42 -8'~9,52 10163,30 354,92 1,08 -5'3,7 56!8,62 .09_-:-o,~6 75,L? 3~,08 ~,J,~- -9C6,07 10253,92 354,94 1,2B 94,3 5642,15 !0345,C~ 75,34 357,88 I0305,15 -E~?.O8 10345,17 354,96 1,02 '~,0 5345,68 !0436~94 75,46 357,~ 10397,08 -912,59 10437,05 354,98 0,43 ~5,9 ~,90,08 I0529,~5 ~,08 357,16 10489,77 -916,7! i052~,75 355,01 0,71 94,6 5714,72 ~'~^ °~ -921,48 10621,02 !,.,o.v,To 74,74 a~e,~=t a~~.,~,v,~,'n~n~ ,-,. ~==,02 O,4A.. 94.2 S764,i0 10~3,13 74,51 357,85 I0763,~ -92~.29 10803,1~ 355,07 0.80 93,1 578%~i...lO~=,>! 73,80 357,79 !0u.2,6o -.=,,,= 108~?,60 355,0~' 0,77 %,1 5815,7! 10984,94 74,~ 358,14 10945,~0 -934,~9 10984,96 355,12 0,88 9-:,--'iS-,,., ~l~/J.~.~ 73,¢5 35A,.,:, 11035,43 -939,0! ~ ~'~' 95,2 .-~66.27 11167,~ 75,57 ~'=:~J~,.~ ::~-~- 111-2_7,34 -943~I0 '",~ ~.~,16 2,!7 ., 1t:60,c,: 75,10 ~. ,;..~ .. ,~i 355, 1,~, · 75,,'5~iJ,.~4 1!352,18 74,83. ~.05. 113!2,"-'~:-,j,.:,.:u'~:" '~ .,.~.,.'....,-,.,..-,"""'=~ ~' 35s,l'::'- .. 0.43 ~,':Y 5939,.~ 11442,73 74.79 357,49 11402,67 -~..~,62 11442,73 ~_q55,20 0,45 ?6,6 5964.¢.~ i1536,14 75,&0 357,09 94,5 5987.95 11627,66 75,42 J.,6/ '~,~ 60!2,45 11720,28 74,96 356,19 93,3 6036,46 11810,~? ~.20 ~,73. 91,0 ~59,02 11898.56 76,10 ~4.50 1!496,04 -961,04 11536,t4 355,~ 1,I1 11567,46 -.%6,03 1!6Z7,66 35-5, ~ 0,58 · x'; 0,69 1:./~.3~2 -971,80 11720.28 355,24 -/· I-: '? ll/,t...-,,' 6 -978,78 11810,3'3' 355,25 1,33 IIAJ~,56 -986,90 11898,5'6 355,24 1,09 355,2~ 0,99 355,24 0.34 3~,24 0,84 355,24 0,50 355,23 0,59 -7¥J,.~ 11%2,37 -:v02,~5 12083,97 -iO0~.'~ I2I/-'5,36 -10!8,08 1~.56,03 -t027.05 1~58,10 96,7 60~2,41 11992,37 75,90 355,46 11951,02 94,5 6105,67 12°~-,97 75,60 355J8 12042,23 '"~9 rA 94,7 ol=.,J. !2175,56 75,16 354,90 12133.6! 95,5 6179,~ 123~8.10 74,49 3~4,15 123!5,35 PAG~ ~0, 6 MZASURD INTERVAL L~iCAL DEPTH ft ft ft 15175.3! 94,8 6205.50 15552,04 i56~$6 16016,76 6515,75 6567,47 !6~?0,72 16484,95 O_M ,., * ._-r ,t-'../ 16858,8! t6S53,05 17048,~ 17140,97 17424,70 A~m 2! 71,4 .re_, 96,0 6988,66 ~,3 705,,2: 94,1 71~,!9 94,2 7191,03 95,0 7260,64 ~,? 7329,34 95,2 ~'^~ '~ ':/5~4 7472,58 93,i .~ . -: / ~¥L, o'o ,- t · · ~c,n .... ~' TO Tg , -/:~ n ,"a% 95,4 ~96,30 7670,99 t MF'F-~ TARGET STATT'ON AZ.!~.r~H" LAT!TUD~ DEP..~]RE DISF'~CZM~T a.t AZZi~TH DLS ft d~ d.~ ft ft ft deg l~ft ~,~/ 73,~'~ 35~,52 k406,0~ !2538,06 71,67 ~4,74 12494,62 12625,29 69,74 355,88 1~81,56 -10~9,93 126~,30 355,23 2,40 · --~ ~ ~ .. ..;,.~C~-.~_-',!.i. ,.,. .- _ .~ ...... :.- ;_c:o2,7u' 61.,84 3~,01_ . 1~..18,,47 -1070,71 ~,'.~:,~:,.'.-.'~"'~ '~ .,..-= 60,w I.~,~- .. · 13044,.,-, 355,28 "'? a.~04~, .,--' o. o, v.C. · ,,-," -' 355,2.-7' 2,41 'i:iz:.,38"' ~' 57,77., 3%_q,51 z,:,uSi ,!5 -!076,72 ,~...:j,.:.:,,m'=' '~.-, ~"'",' '".' "' ~ -1079,20 ""~ - 13-60..,., 1~04,/. .....'v~. ,~'~ 54,12 357,91 355,31 1,..q2 '"~"' "' a~oz ,60 -i~2,29 1328,1,77 ~.._,_,,o~q=-' '::'" ~oz,:~,/o ~,42 ~/~,~.= ~ ~ , 1,85 13~7,20 52,64 ~8,28 13313,07 -!085,09 1~,21 355, ~'4 2,02 !~31,~ ~,4! 3~,31 1~B7~49 -1067,75 I~3!,62 355,35 2,47 l"Son ~ 48,v4. ¢o..,,~ ,34~6,3t -:uy!,89 13500,59 355,36 2,76 13~O,~ 47,74 3~,52 !3526,17 -!~'5,~ 13~0,49 355,37 1,15 13.~6,~ 4~,!0 357,~ "" .... ,~ -~. ~w.~..-. t3705,19 45,04 356,22 13660,86 -!10!,~ 13/0o,=o ~5%2o 1,42 !3~0,~ 44,52 354,,~ 13725,70 -i!07,11 13770,Z? 355,29 !,34 .......... z38o5,~? 355,~ - ~ .1._,~ ~. 1,97 l%%q~,.-,'q5 4~.0o 356,21 13790,60 -I !qj99,66 43,i2 ~8,47 13654,~ -!!15,29 13899ff0 3~,® 1,65 · ~.., "' ~== 4' 0,87 1~964,~ 42,64 3~,49 I.,z=,48 -1117,56 I~E4,~, ~o~,.= 140£o,! 3 4~,03 358,70 1...%'82,04 -~1Y,64 1~26,79 355,42 1,09 ' ' OJJ,,D i&SBY,Y8 41~31 ~.9~, ... !~45,32 -~-,~1 ao 10390,05. ~== ~ 1,27 14152,45 40,53 356,.~ .a.~- -m 14152 z~ ~.~/,/= -t125,38 ,~- 355,44 1,03 t42z2,o~ 3%67 355,45 14167,50 -1i~,67 ""I" '~' "== '~ 1,I0 !4~,42 38,96 354,79 ~42!0.37 -!133,33 1~255,50 355,44 1,22