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Home My WebLink About195-016By Samantha Carlisle at 3:02 pm, Jul 15, 2022 5HJJ-DPHV%2*& )URP$ODVND16$65:HOO6LWH0DQDJHUV$ODVND16$65:HOO6LWH0DQDJHUV#KLOFRUSFRP! 6HQW7KXUVGD\-XQH30 7R5HJJ-DPHV%2*& &F%URRNV3KRHEH/2*& 6XEMHFW%23(7HVW) $WWDFKPHQWV+LOFRUS$65038)%23(7HVW[OV[+,/&253SGI :ŝŵͲ ,ĞƌĞŝƐƚŚĞϱϬϬϬƉƐŝŝŶŝƚŝĂůKWƚĞƐƚĨŽƌƚŚĞϭϯϯͬϴ͛͛ƐƚĂĐŬŽŶ&ͲϮϱ͘ ^Z^D͛Ɛ ^ZͲϭZŝŐ͗ϵϬϳͲϲϴϱͲϭϮϲϲ ,ŝůĐŽƌƉůĂƐŬĂ͕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ϱϬϬϬƉƐŝŝŶŝƚŝĂůKWƚĞƐƚĨŽƌƚŚĞϭϯϯͬϴ͛͛ƐƚĂĐŬ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 6/2/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #11950160 Sundry #322-279 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:2392 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5-1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)1600 P Quantity Test Result 200 psi Attained (sec)18 P No. Valves 16 P Full Pressure Attained (sec)69 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4x2275 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:8.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 05/31/22 19:59 HRS Waived By Test Start Date/Time:6/1/2022 18:30 HRS (date) (time)Witness Test Finish Date/Time:6/2/2022 03:00 HRS BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Hilcorp Explanation for test # 2, PR Valve was not set high enough to accommidate 5000 psi test. Adjust PR Valve and continue test. Second attempt test # 2, Hose on the test pump failed. Repaired hose and continued BOPE test. Annular closure time = 29 sec. 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Ϯϯ͘ŽŶƚŝŶŐĞŶĐǇ͗;/ĨƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǁŽŶ͛ƚƉƌĞƐƐƵƌĞƚĞƐƚĚƵĞƚŽĞŝƚŚĞƌĂƉĞŶĞƚƌĂƚŽƌůĞĂŬŽƌƚŚĞWs ƉƌŽĨŝůĞŝƐĞƌŽĚĞĚĂŶĚͬŽƌĐŽƌƌŽĚĞĚĂŶĚWsĐĂŶŶŽƚďĞƐĞƚǁŝƚŚƚƌ ĞĞŽŶ͘Ϳ Ă͘ EŽƚŝĨǇKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ;,ŝůĐŽƌƉͿ͕Dƌ͘DĞůZŝǆƐĞ;K'ͿĂŶĚDƌ͘:ŝŵZĞŐŐ;K'ͿǀŝĂ ĞŵĂŝůĞǆƉůĂŝŶŝŶŐƚŚĞǁĞůůŚĞĂĚƐŝƚƵĂƚŝŽŶƉƌŝŽƌƚŽƉĞƌĨŽƌŵŝŶŐƚŚĞƌŽůůŝŶŐƚĞƐƚ͘K'ŵĂǇĞůĞĐƚ ƚŽƐĞŶĚĂŶŝŶƐƉĞĐƚŽƌƚŽǁŝƚŶĞƐƐƚĞƐƚ͘ ď͘ tŝƚŚƐƚĂĐŬŽƵƚŽĨƚŚĞƚĞƐƚƉĂƚŚ͕ƚĞƐƚĐŚŽŬĞŵĂŶŝĨŽůĚƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ Đ͘ ŽŶĚƵĐƚĂƌŽůůŝŶŐƚĞƐƚ͗dĞƐƚƚŚĞƌĂŵƐĂŶĚĂŶŶƵůĂƌǁŝƚŚƚŚĞƉ ƵŵƉĐŽŶƚŝŶƵŝŶŐƚŽƉƵŵƉ͕;ŵŽŶŝƚŽƌ ƚŚĞƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚĨŽƌůĞĂŬƐƚŽĞŶƐƵƌĞƚŚĂƚƚŚĞĨůƵŝĚŝƐŐŽŝŶŐĚŽǁŶͲŚŽůĞĂŶĚŶŽƚůĞĂŬŝŶŐ ĂŶǇǁŚĞƌĞĂƚƐƵƌĨĂĐĞ͘Ϳ Ě͘ ,ŽůĚĂĐŽŶƐƚĂŶƚƉƌĞƐƐƵƌĞŽŶƚŚĞĞƋƵŝƉŵĞŶƚĂŶĚŵŽŶŝƚŽƌƚŚĞĨůƵŝĚͬƉƵŵƉƌĂƚĞŝŶƚŽƚŚĞ ǁĞůů͘ZĞĐŽƌĚƚŚĞƉƵŵƉŝŶŐƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞ͘ Ğ͘ KŶĐĞƚŚĞKWƌĂŵĂŶĚĂŶŶƵůĂƌƚĞƐƚƐĂƌĞĐŽŵƉůĞƚĞĚ͕ƚĞƐƚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞƐǇƐƚĞŵĨŽůůŽǁŝŶŐ ƚŚĞŶŽƌŵĂůƚĞƐƚƉƌŽĐĞĚƵƌĞ;ĨůŽŽƌǀĂůǀĞƐ͕ŐĂƐĚĞƚĞĐƚŝŽŶ͕ĞƚĐ͘Ϳ Ĩ͘ ZĞĐŽƌĚĂŶĚƌĞƉŽƌƚƚŚŝƐƚĞƐƚǁŝƚŚŶŽƚĞƐŝŶƚŚĞƌĞŵĂƌŬƐĐŽůƵŵŶƚŚĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌͬWs ƉƌŽĨŝůĞͬƉĞŶĞƚƌĂƚŽƌǁŽƵůĚŶ͛ƚŚŽůĚƉƌĞƐƐƵƌĞĂŶĚƌŽůůŝŶŐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚŽŶKWƋƵŝƉŵĞŶƚ ĂŶĚůŝƐƚŝƚĞŵƐ͕ƉƌĞƐƐƵƌĞƐĂŶĚƌĂƚĞƐ͘ 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'ƵŶηϯ <ƵƉĂƌƵŬ ϭϭ͕Ϭϳϱ͛ ϭϭ͕Ϭϵϱ͛ ϳ͕ϮϬϳ͛ ϳ͕ϮϮϱ͛ ϮϬ͛ Ă͘ 'ƵŶƐŝǌĞŝƐƉƌŽũĞĐƚĞĚƚŽďĞϯͲϯͬϴ͟ϲ^W&͘EŽƚĞƚŚĂƚŐƵŶůĞŶŐƚŚƐ͕ďůĂŶŬƐ͕ĂŶĚƐǁŝƚĐŚĞƐĂƌĞ ƐƵďũĞĐƚƚŽĐŚĂŶŐĞďĂƐĞĚŽŶĨŝŶĂůKƌĞǀŝĞǁ͘ ď͘ &ůŽǁͲĐŚĞĐŬƚŚĞǁĞůůĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ Đ͘ WĞƌĨŽƌĂƚĞĚŝŶƚĞƌǀĂůƐĂƌĞŝŶƚĞƌͲŵŝǆĞĚǁŝƚŚŝŶƚŚĞ<ƵƉĂƌƵŬƐĂŶĚƐĂŶĚĂŶƚŝĐŝƉĂƚĞĚƚŽďĞƚŚĞ ƐĂŵĞƉƌĞƐƐƵƌĞĂƚ ϴ͘ϰƉƉŐ͘ ϯϲ͘ ZDKͲůŝŶĞ͘ ϯϳ͘ EŝƉƉůĞĚŽǁŶϳ͟^ŚŽŽƚŝŶŐĨůĂŶŐĞ͘ ϯϴ͘ Dh^ƉŽŽůĞƌƚŽƌƵŶ^WĐĂďůĞĂŶĚĐĂƉŝůůĂƌǇƚƵďŝŶŐ͘ Ă͘ WůĂŶƚŽƌƵŶϭͬϰ͟ĐĂƉŝůůĂƌǇƚƵďŝŶŐĨŽƌƐĐĂůĞŝŶŚŝďŝƚŽƌŝŶũĞĐƚŝ ŽŶ͘ ϯϵ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϭϬ͕ϵϯϬ͛D Ă͘ ŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶĚŝĨĨƵƐĞƌĂůŽŶŐƚŚĞĐĞŶƚƌĂůŝǌĞƌ͘ 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 ϰϬ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ;ĂƵƚŝŽŶŶŽƚƚŽĂŵĂŐĞĂďůĞŽƌĐĂƉŝůůĂƌǇƚƵďŝŶŐǁŚŝůĞůĂŶĚŝŶŐƚŚĞŚĂŶŐĞƌͿ͘ 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^ƵƌĨĂĐĞ ϴϬΖ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬEdͲϴϬ^ͬƚĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϯ͕ϰϬϱ͛ Ϭ͘Ϭϳϱϵ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϰϯϳ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵϮ ^ƵƌĨĂĐĞ ϮϬ͛ Ϭ͘ϬϬϴϳ ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ϮϬ͛ ϭϬ͕ϵϯϰ͛ Ϭ͘ϬϬϱϳϵ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϮϬ͛ yK͗ϯͲϭͬϮ͟ǆϮͲϳͬϴ͟ '>Dd/>͗DK^ŝĚĞWŽĐŬĞƚǁͬƵŵŵǇsĂůǀĞ'>D Ϯϭϯϰ͛^dϮ͗ϮͲϳͬϴ͟ǆϭ͟Ͳ /сϮ͘ϯϳϭ͟ ϯ ϭϬ͕ϲϲϵ͛^dϭ͗ϮͲϳͬϴ͟ǆϭ͟ ϰ ϭϬ͕ϴϭϮ͛ ϮͲϳͬϴ͟yEEŝƉƉůĞʹ DŝŶ/сϮ͘ϮϱϬ͟ ϱ ϭϬ͕ϴϱϰ͛ ϮͲϳͬϴ͟hϴƌĚŝƐĐŚĂƌŐĞ,ĞĂĚ&W/^ ϲ ϭϬ͕ϴϱϱ͛ WƵŵƉ͗ϭϭϵ&>yϭϬ^y ϳ ϭϬ͕ϴϳϴ͛ WƵŵƉ͗ϭϭϵ&>yϭϬ^y ϴ ϭϬ͕ϵϬϮ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'Z^&ZEZ ϵ ϭϬ͕ϵϬϱ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^ϯhdͲ^ ϭϬ ϭϬ͕ϵϭϮ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗'^ϯhd ϭϭ ϭϬ͕ϵϭϵ͛ ϱ͘ϲϮ͟KDŽƚŽƌ͗>ϱD^WϯͲϮϱϬ ϭϮ ϭϬ͕ϵϯϬ ϰͲϭͬϮ͟KtĞůů>ŝĨƚ^ĞŶƐŽƌ ϭϯ ϭϬ͕ϵϯϮ͛ ϱ͘ϴϱ͟KĞŶƚƌĂůŝǌĞƌͲƚŵΛϭϬ͕ϵϯϰ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d dǇƉĞ ĂƚĞ ^ƚĂƚƵƐ <ƵƉĂƌƵŬ ϭϭ͕ϭϮϮ͛ ϭϭ͕ϭϯϰ͛ ϳ͕Ϯϰϴ͛ ϳ͕Ϯϱϴ͛ ϭϮ ϯͲϯͬϴͬ͟ϲ^W& ϰͬϭϳͬϵϱ KƉĞŶ ϭϭ͕ϭϰϬ͛ ϭϭ͕ϭϱϰ͛ ϳ͕Ϯϲϰ͛ ϳ͕Ϯϳϲ͛ ϭϰ ϯͲϯͬϴͬ͟ϲ^W& ϰͬϭϳͬϵϱ KƉĞŶ ϭϭ͕ϭϲϲ͛ ϭϭ͕ϮϬϰ͛ ϳ͕Ϯϴϲ͛ ϳ͕ϯϭϵ͛ ϯϴ ϯͲϯͬϴͬ͟ϲ^W& ϰͬϭϳͬϵϱ KƉĞŶ 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Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-25 (PTD 195-016) MFC 05/07/2022 Please include current contact information if different from above. PTD:195-016 T36623 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.18 10:11:35 -08'00' STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing E Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: ESP Change-out Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 195-016 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22546-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT KR F-25 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL MAY 21i 2015 11.Present Well Condition Summary: Total Depth measured 11,502 feet Plugs measured N/A feek0GCC true vertical 7,575 feet Junk measured N/A feet Effective Depth measured 11,244' feet Packer measured N/A feet true vertical 7,524' feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 110' N/A N/A Intermediate 3,375' 9-5/8" 3,405' 2,975' 5,750psi 3,090psi Production 11,404' 7" 11,437' 7,446' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3#/L-80/EUE 8rd 20' 20' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 10,934' 7,0,86' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A p� Treatment descriptions including volumes used and final pressure: N/A SCANNED JAN 0 6 2017, , 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 400 0 Subsequent to operation: 284 68 527 275 273 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory❑ Development[11 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-180 17,E /0-114"--- Contact 0.114Contact Paul Chan Email pchan@hilcorp.com Printed Name Bo York Title Operations Manager Signature )' i� c..— c,--_ � , --e:1-- "ft., t�) Phone 777-8345 Date 5/25/2016 Ni RBDMS LI, MA I s 1 2016 A,, 72.4, Form 10-404 Revised 5/2015 Submit Original Only 11 • � Milne Point Unit Well: MPU F-25 SCHEMATIC Last Completed: 4/18/2013 Hacorp Alaska,LLC PTD: 195-016 Orig.KB Elev.:47'!Orig.GL Elev.:13'(N27E) TREE&WELLHEAD Tree 3-1/8"5M CIW kk 1 t 13-5/8""5M FMC w/3.5"FMC Tbg.Hanger, 4 Wellhead 20' « a f 1, EUE Lift Threads,3"CIW"H"BPV profile 4 2 OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I(Approx)in 30"Hole 7 ( PP ) 9-5/8" 678 sx PF'E',250 sx Class'E',290 sx in 12-1/4"Hole 7" 290 sx Class"G"in 8-1/2"Hole sa CASING DETAIL FP Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/N/A/N/A N/A Surface 80' N/A I 9-5/8" Surface 40/NT-80S/Btc. 8.835 Surface 3,405' 0.0759 7" Production 26/L-80/NSCC 6.276 Surface 11,437' 0.0383 95/8 31 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 Surface 20' 0.0087 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 20' 10,934' 0.00579 WELL INCLINATION DETAIL NOTE: KOP @ 800' 7"Casing Landed on Emergency Slips Max Hole Angle=60 to 62 deg.f/5,200'to 9,050' Hole Angle through perforations=30 deg. JEWELRY DETAIL No Depth Item 1 20' X0:3-1/2"x 2-7/8" GLM DETAIL:CAMCO Side Pocket w/Dummy Valve GLM 2 134' STA 2:2-7/8"x 1" -ID=2.371" 3 10,669' STA 1:2-7/8"x 1" Marker Joint: 3 4 10,812' 2-7/8"XN Nipple-Min ID=2.250" 10,753'-10,744wLM a 5 10,854' 2-7/8"EUE 8rd Discharge Head FPDIS \* IS 6 10,855' Pump:119FLEX10 SXD 4 7 10,878' Pump:119FLEX10 SXD MIN IDAbove ESP: 8 10,902' Gas Separator:GRS FER N AR 2.250"@10,811' 9 10,905' Upper Tandem Seal:GSB3DBUT-SB 5 10 10,912' Lower Tandem Seal:GSB3DBUT 11 10,919' 5.62"OD Motor: CL5 MSP3-250 ,,6&7 12 10,930 4-1/2"OD Well Lift Sensor 13 10,932' 5.85"OD Centralizer-Btm @ 10,934' 1111: 8 9&10 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Type Date Status 11,122' 11,134' 7,248' 7,258' 12 3-3/8"/6SPF 4/17/95 Open *11 Kuparuk A 11,140' 11,154' 7,264' 7,276' 14 3-3/8"/6SPF 4/17/95 Open , 11,166' 11,204' 7,286' 7,319' 38 3-3/8"/6SPF 4/17/95 Open 41 ,' ,12 Reference Log:4/15/1995 AWS GR/CCL [EHD=0.76',TTP=6.4"]/Mid-perf=7284'TVD,11,163'MD 14 '* 13 GENERAL WELL INFO API:50-029-22546-00-00 , Drilled and Cased by Nabors 27E -3/11/1995 Run ESP Completion by Nabors 4ES-11/6/1995 ESP Change-out -1998 ESP Change-out by Nabors 4ES-7/1/2000,3/9/2005,11/13/2007 Stimulate Acid Treatment-2008 ESP Change-out&Screen Replacement by Nabors 3S-12/30/2008 Stimulate Acid Treatment-2009 '' -KUP A Sands ESP Change-out&Screen Replacement by Nabors 4ES-8/5/2010 4 ESP Change-out&Screen Replacement by Doyon 16-4/18/2013 7 +.• ESP Change-out byASR#1-4/26/2016 TD=11,502'(MD)/TD=7,575'(1VD) STIMULATION SUM MARY PBTD=11,353'(MD)/PBTD=7,447'(TVD) 80,000lbs 16-20 CL ISP 4/19/1995 Kup A sand screened out. Revised By:TDF 5/25/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-25 ASR#1 50-029-22546-00-00 195-016 4/15/16 4/24/16 Daily Operations: 4/13/2016-Wednesday No activity to report. 4/14/2016-Thursday No activity to report. 4/15/2016- Friday Dig out Rig Locate Equipment/ Install Landing for stairs on Well Cover, Roads & Pads remove snow from F Pad for Rig access. 4/16/2016-Saturday Rig up Crane, Spot Well cover up to Rig, Lift Rig floor&set on well cover, install X Box on Rig floor. Continue digging out Rig, Cover 13 -5/8" BOP and heat at F-Pad. Installed Pressure washer Tank in Mud Pit module, Install cables for X box to Rig floor. Electricians test fire and gas system. Fit the Derrick with the Rig floor, install stairs on off drillers side. Pro Star Installing electronics components for Jack install. 4/17/2016-Sunday Mounted operator side stairs, modified mounting bracket, Modified Rig floor Operator side door. Welded down D rings & Tool Rack on Rig floor&Absorb roll holder, Worked on &Troubleshoot gas alarms, Install Tong Rack on Derrick, Install brackets and valves for jacking system, Install Electrical for jacking system, added brushes to Rig floor. Started fabrication of alignment bars for well house to mud boat. Circ. MP F-25. Finish Well Kill Operations on MP F-25, Rig Down Little Red Services, Break Down & Remove Hard Lines Down From Well, Install Horseshoe scaffolding around wellhead. Well Head Rep Install BPV in TBG Hanger(Notified AOGCC for 24 hour notice of right to witness BOP test @ 19:41 Hrs. on 4-17-16). Nipple down Tree, Greg Ruge well Head rep check Travel on Lock Down Screws, & Checked Hanger Threads 3.5 NSTC 9 RDS, Nipple up Bop. Set Matting Boards around well Head, Hauled Rig, Mud Boat, Rig Equipment, Peak Hauled CO,Man Trailer& Change, House, Well House & Rig Floor,to F-Pad. 4/18/2016- Monday Spot BOP Enclosure & Install Rig floor with crane, Back Rig in on Mud Boat, raise Derrick, Secure Derrick. Spot Mud tank module,Torque up BOP connections. Install Genset to mud pits, Connect and test gas detection system. Held Meeting with ASR crews and reviewed F-25 ESP change out procedure. Electrician Branden Tested (Combustible Gas & Methane Detector Alarms) in ASR-1 Cellar& Drill Floor, mud Pit Trailer, Generator Room, Mud Pump Room, Choke Room,Tested H2S Detector @ (20 ppm)Alarms in Mud Trailer, Mud Pump Room,ASR-1 Cellar. Rig up Hydraulic Fittings and Hoses to Bop Stack, Rig up Cat Walk and Stairs to Rig, Pumping and Thawing Covered Hydraulic Lines with Glycol Circulation Lines and Install Blankets on Lines. Recieved 40 bbl Fresh Water for Testing. Hang ESP Shieve in Derrick and Spot ESP Spooling Unit. tpr Well Support Greased Choke Manifold Valves and HCR and Kill Line Valves on Bop Stack, Function Test Blind Rams, Run 2- ./. ft 7/8"Test Joint into Stack Function Test Pipe Rams and Annular HCR and Kill Line Valves on Stack. Pull BPV and Installed TWC in Tbg Hanger(Bob Noble AOGCC was Called 2 Hours Prior Notification Start of Bop Test). Installed 13-5/8" Spacer Spools on top of Annular, Spotted Drill Cuttings Tank. Testing Bop,Test all valves & Rams to 250 psi low/2,500 psi high.Test Annular @ 250 psi low/1,500 psi high. Gas Alarms bump tested per AOGCC Rep. (Bob Noble with AOGCC witnessed Bop Test). 4/19/2016-Tuesday • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-25 ASR#1 50-029-22546-00-00 195-016 4/15/16 Future Daily operationsr ' 4'41°' 4/20/2016-Wednesday Break& Lay down ESP Assembly&Screens. Recovered 187 Cross collar clamps,5 Protectalizers, 3 Flat guards. 342 Joints. Rig Service, Check all fluids on Equipment. Repair cable on Pipe skate& Repair Rocker on Power swivel with Pro Star hand. Make up Bit &Casing Scraper&XO,TIH with 2-7/8"Tubing. Rig Service, Check all fluids on Equipment.TIH with 2-7/8" Tubing and 7" Casing Scraper to 11,027 ft. Circulate Bottoms up Pump Rate& Pressure=1,000 psi @ 181 stks-4bpm FCP=950 Total stks pumped=17,100 Total bbl. loss=30 bbl. POOH L/D 2-7/8" Tubing. 4/21/2016-Thursday Service Rig, Check Fluids in all equipment. Continue to TOOH laying down 2-7/8" Tubing, Lay down Bit &7" Casing scraper. Make up Halliburton 7" Champ Packer.TIH with Champ Packer on 2-7/8"Tubing to 3,000 ft. Service Rig, Check Fluids in all equipment. TIH with Champ Packer on 2-7/8"Tubing From 3,000'to 11,008'. Packer Set @ 10,995'. C/O/L P/U=52K S/O=29K Pick to 52k Rotate TBG 4 Turns to the right. Slacked off to 5k. Fill back side. Close Pipe Rams attempt to Test Casing @ 8 bbl pumped away. Unable to get Casing Test,Open Pipe Rams POOH L/D 1 Single. Packer set @ 10,965'. C/O/L Attempt to Catch Pressure at 80 spm 200psi with 10 bbl pumped away. Unable to Get Casing Test L/D 1 Single. Packer set @10,939. C/O/L Attempt to Catch Pressure at 80 spm 200psi with 10 bbl pumped away Unable to Get Casing Test, L/D 1 Single, set Packer @ 10909, attempt to test, no test. 4/22/2016-Friday, Set Packer @ 10,878'. Attempt to Test, No test.TOOH, lay down 40 joints to 9,598'. Set Packer,Attempted to Test casing, no test.TOOH laying down Tubing to 8,000',Set Packer @ 8,010 Center of Element &attempted to Test casing, no test. TOOH, Laying down 2-7/8"Tubing (JSA) Lay down 7' Champ Packer no Visual Signs of Defect on Packer Rubber Elements in Good Shape. Service Rig, Check Fluids in all equipment (JSA). Pick up 7' RTTS Packer& 4-3/4" Drill Collars.TIH 2-7/8" Tubing 7" RTTS Packer to 5,500 ft. Work on Proximity Sensor for Derrick pins. 4/23/2016-Saturday Service Rig, Check all fluids in equipment. Continue to TIH with RTTS Packer on 2-7/8"Tubing. Set Packer @ 11,005'Center of element.Attempt to Test casing on backside, unable to get a test. Release Packer, Notify Work over Engineer. Pull up hole, lay down 3 joints, set Packer @ 10,910 Center of Element, unable to get a test, Release Packer.TOOH to 7,589'. Set Packer @ 7,574' Center of element,Attempt to Test casing on backside, unable to get a test. Service Rig, Check all fluids in equipment (JSA). Trip out of the hole L/D 80 Joints to 5,046 ft. Center of element,Attempt to Test casing on backside, unable to get a test.Trip out of the hole L/D 16 joints to 4,531' Center of element,Attempt to Test casing on backside, unable to get a test.Trip out of the hole L/D 70 joints to 2,306' Center of element, Fill Back Side Test casing on backside, Tested Good. Sent Notice to AOGCC of Bop Test with 3.5"Test joint.Trip out of the with 2-7/8 Tubing (JSA) L/D 4.75 Drill Collars • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-25 ASR#1 50-029-22546-00-00 195-016 4/15/16 Future Daily Operations; 4/24/2016-Sunday Lay down BHA&Test Packer. Install Test plug, RILDS,Test 3.5"Test joint to 250 psi Low/2,500 psi high, lay down test joint & pull test plug& lay down.AOGCC,Jeff Jones waived right to witness Ram test. Load 3.5" Work string, make up RTTS& DCs. Change Elevators &slip inserts to 3.5". Trip in the hole with RTTS Packer on 3.5" CS Hydril work string to 1,000'. Set Packer @ 1,022' Center of Element,Test casing to_1,000psi for 5 minutes. Good Test. Continue to TIH with RTTS on 3.5" Work string to 3,000 ft. Service Rig, Check all fluids in equipment. (JSA) Load &Tally 3.5 CS Hydrill pipe on rack TIH From 3,000'to 10,044' (JSA)Set Packer @ 10,037' C/O/E. P/U=80K S/0=37K. 4 Turns to the right set 16k on PKR. Fill Backside. Closed Pipe Rams (JSA).Test Casing.from 10,037'to Surface 2 500psi 30min Charted Bleed Pressure,off Open Pipe Rams Release Packer. POOH, Laying down 3.5" Workstring. 467 4/25/2016- Monday Service Rig, Check fluids in all equipment. Continue to TOOH laying down 3.5"Work String. (Notified AOGCC of Right to witness BOP test if completion not landed by 7 day requirement @ 11:38 AM on 4-25-16). Lay down 4-3/4" Drill Collars & Halliburton Test packer.Service Rig, Check fluids in all equipment. (Jeff Jones with AOGCC waived right to witness BOP Test @ 18:39 PM on 4-25-16) (JSA). Load Pump Assembly and GLM's on Cat walk, Load 2-7/8 Completion Tubing on Pipe Rack and Tally. (JSA) Make up and Service ESP Pump Assembly.TIH with 2-7/8"Tubing & ESP Pump Assembly to 3,000'. 4/26/2016-Tuesday Service Rig, Check fluids in all equipment. Continue to TIH with ESP Assembly&2 7/8"Tubing.Test cable every 3,000'. Make Reel to Reel splice on ESP Cable @ 9,200'. (JSA)TIH with ESP Assembly& 2 7/8"Tubing. Service Rig, Check fluids in all equipment. (JSA)TIH with ESP Assembly& 2 7/8"Tubing. (JSA)Well Head Rep Made up and Aligned Tubing Hanger. (JSA) Centrilift Rep Made up Field Connector to Penetrator and install on Tubing Hanger. (JSA) Landed Tubing Hanger RILDS P/U=76K 5/0=30K(Ran 343 Joints)(2-GLMS)(1-XN Nipple)(186 Collar Clamps) (2 Flat Guards)(2 Pump Clamps)(5 Protectolizers). (JSA) Unscrew Landing Joint Break out TIW Valve and XO Sub & Lay Down. (JSA)Well Head Rep Tee Bar BPV in Tubing Hanger. Electrician Disconnected Generator and Alarms From Pits, Rig Floor, Cellar, Roads and Pads Hauled off 260 bbls From Pits, Drill Cutting Tank, Flow Back Tank, Mud Boat, Rig Down Power Tongs and 2-7/8" Handling Equipment From Rig Floor, Rig Down Tubing Spools From top of Annular. Disconnected Koomey Lines from Bope Stack, Cat Walk, Disconnected and Blow Down, Kill and Choke lines From Pits and Bope Stack, Bend & Lower Derrick, Driver Rig Off Mud Boat • • 4 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-25 ASR#1 50-029-22546-00-00 195-016 4/15/16 4/27/16 Daily Operations: 4/27/2016-Wednesday Rig down, Remove Rig floor, ND BOP. Nipple up Tree,Test adapter to Flange & Hanger void to 500psi low/5,000psi high. Well Head Rep Installed BPV in Hanger. 4/28/2016-Thursday No activity to report. 4/29/2016-Friday No activity to report. 4/30/2016-Saturday No activity to report. 5/1/2016-Sunday No activity to report. 5/2/2016- Monday No activity to report. 5/3/2016-Tuesday No activity to report. • • oF 91,P I%%y'.•• THE STATE Alaska Oil and Gas ti�,�;,-i-��1, ofALASKA Conservation Commission #tsirt2 333 West Seventh Avenue kms" ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �h -•�� Main: 907.279.1433 OF ALA �� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 OEi 01;'-‘,1 ;i 2111F, Anchorage,AK 99503 Re: Milne Point Field,Kuparuk River Oil Pool, MPU KR F-25 Permit to Drill Number: 195-016 Sundry Number: 316-180 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, a7- Cathy . Foerster Chair DATED this / ,day of March, 2016. RBDMS 1,1i Ws? 11 2016 • • RECEIVED STATE OF ALASKA MAR 0 7 2 1F ALASKA OIL AND GAS CONSERVATION COMMISSION 00.—.S 3 ,�oVry APPLICATION FOR SUNDRY APPROVALS AO(., , 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑✓ • Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out❑- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 195-016 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr Suite 1400 Anchorage,AK 99503 50-029-22546-00-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 1 MILNE PT UNIT KR F-25 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0355018 • MILNE POINT/KUPARUK RIVER OIL , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,502' 7,575' 11,244' 7,254' 2,057 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 80' N/A N/A Intermediate 3,375' 9-5/8" 3,405' 2,975' 5,750psi 3,090psi Production 11,404' 7" 11,437' 7,442' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: 3-1/2" 9.3#/L-80/EUE 8rd 26' See Attached Schematic . See Attached Schematic 2-7/8" 6.5#/N-80/EUE 8rd 10,978' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Cup Packer and N/A • 10,926(MD)/7,079(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic ❑ Development E - Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 3/21/2016 Commencing Operations: OIL El - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan@hilcorp.com egie-4„,Printed Name Bo York Title Operations Manager Signature OsteirI4 - "o ICA,- Phone 777-8345 Date 3/4/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number., - G Plug Integrity ❑ BOP Test g Mechanical Integrity Test ❑ Location Clearance ❑ Other: it Z J t;;c-' ,,p-.-..:.. &D P rte f - Post Initial Injection MIT Req'd? Yes ❑ No ❑ RR g Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: 1 O. j 6,,` RBL�IVIS l/V MHR 1 1 2016 /9 ///111 APPROVED BY Approved by: / f,,1/4./.147/0 � 4,......_ COMMISSIONER THE COMMISSION Date: 3 _ to _/ R Submit Form and Form 10-403 Revised 11/2015okoieGiii4Atid for 12 months from the date of apprpval. Attachments in Duplicate • Well Prognosis Well: MPU F-25 Hilcarp Alaska,LLI Date:3/4/2016 Well Name: MPU F-25 API Number: 50-029-22546-00 Current Status: SI Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: March 17th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-016 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) Current Bottom Hole Pressure: 2,757 psi @ 7,000' TVDss (SBHPS 02/29/2016/7.57 ppg EMW) Maximum Expected BHP: 2,757 psi @ 7,000' TVDss (No new perfs being added) ✓ MPSP: 2,057 psi / (0.10 psi/ft gas gradient) P �;3l6` Brief Well Summary: 8�;� tF4Y4- MPU F-25 was drilled in February/March 1995, fracture stimulated in April and completed with an ESP in November 1995. The well has had multiple ESPs installed: November 1995 (initial), August 1996, July 2000, March 2005, November 2007, December 2008, August 2010, and April 2013. The ESP has failed. Notes Regarding Wellbore Condition • Casing tested to 11,353' PBTD on 3/10/1995 (pressure test after cementing operations). Objective: Pull failed ESP, pressure test casing, and run a new ESP. / Brief RWO Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 13-5/8" BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. • S Well Prognosis Well: MPU F-25 Hilcorp Alaska,LU Date:3/4/2016 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/ 1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. 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. 'r f 4/ 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. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. /14—` _ ekes° 15. MU landing joint or spear and recover the tubing hanger. ?Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion Ltubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 2-7/8" tubing. Tubing may be re-used. Lay down failed ESP. Replace bad joints of tubing as necessary. 17. RIH with scraper assembly to 11,025' MD on 2-7/8" tubing. Circulate the well clean. Note:The well may need a cleanout through the perforated interval depending upon the condition of the screen. If needed, spot sized salt pill to control losses. POOH and LD tubing. 18. PU test packer and RIH to 10,995' MD. Pressure test casing to 2,500 psi for 30 charted minutes. ndr POOH and LD test packer and tubing. 19. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at± 10,935' MD. Conti�ngeplc_y: A cup packer and screens may be run on the bottom of the ESP depending upon K� the condition of the pulled cup packer/screen assembly OR retrievable packer with screens set above the perforated interval. 20. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 21. Set BPV. I S Well Prognosis Well: MPU F-25 Hilcorp Alaska,LU Date: 3/4/2016 Post-Rig Procedure: 22. RD mud boat. RD BOPE house. Move to next well location. 23. RU crane. ND BOPE. 24. NU existing 3" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 25. RD crane. Move 500 bbl returns tank and rig mats to next well location. 26. Replace gauge(s) if removed. 27. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. 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 H . • Milne Point Unit Well: MPU F-25 SCHEMATIC Last Completed: 4/18/2013 Hilcorp Alaska,LLC PTD: 195-016 TREE&WELLHEAD Orig.KB Elev.:47'/Orig.GL Elev.:13'(N27E) Tree 3-1/8"5M CIW A 'a 1r Wellhead 13-5/8""5M FMC w/3.5"FMC Tbg.Hanger, 20 rt EUE Lift Threads,3"CIW"H"BPV profile �* ,„ OPEN HOLE/CEMENT DETAIL 2 ,tea [ 20" 250 sx of Arcticset I(Approx)in 30"Hole 1 4 9-5/8" 678 sx PF'E',250 sx Class'E',290 sx in 12-1/4"Hole ! A 7" 290 sx Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/N/A/N/A N/A Surface 80' N/A 9-5/8" Surface 40/NT-80S/Btc. 8.835 Surface 3,405' 0.0759 7" Production 26/L-80/NSCC 6.276 Surface 11,437' 0.0383 9-5/8" TUBING DETAIL 1, 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 Surface 26' 0.0087 i' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 26' 10,978' 0.00579 ' WELL INCLINATION DETAIL KOP @ 800' Max Hole Angle=60 to 62 deg.f/5,200'to 9,050' Hole Angle through perforations=30 deg. JEWELRY DETAIL No Depth Item 1 26' XO:3-1/2"x 2-7/8" 2 141' STA 2:GLM-2-7/8"x 1"KBMM w/DSOV E 3 10,677' STA 1:GLM-2-7/8"x 1"KBMM w/Dummy Valve 4 10,824' 2-7/8"XN-Nipple(2.250 No-go ID) MIN ID.bove ESP._•• 3 5 10,865' Discharge Head:GPDIS 2.250"@10,824' 6 10,866' Pump:SXD 137-P17 CTD STGS Marker Joint: *"*"....4r 1 7 10,885' Gas Separator:GRSFTX AR H6(400 internals) 10,753'-10,744 WLM ,r 4 8 10,890' Upper Tandem Seal:GSB3DBUTSB/SB PFSA ] 9 10,897' Lower Tandem Seal:GSB3DBLT SB/SB PFSA CL5 g; 'I 10 10,903' CL5 Motor:168HP,3,460 Volt,30 amp 5 11 10,917' Sensor:WeIILift MGU a� i 12 10,919' XO:2-7/8"EUE 8rd x 2-3/8"-ID=1.99" 6 13 10,921' Shear Type Safety Jt-Pinned25K# v' 14 10,924' 2-7/8",6.4#,L-80,EUE 8rd Ported Tubing it III 7 15 10,926' 7",26#,Cup Packer Assy 1,500psi Disk 8&9 16 10,934' XO:2-7/8"EUE Box x 4-1/2"LTC Pin s v 17 10,935' 4-1/2"Duragrip 500 Micron Screen p 18 10,978' 4-1/2"Bull Plug-Bottom @ 10,978' t Po 10 PERFORATION DETAIL L" Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Type Date Status • \...., *12,13&14 11,122' 11,134' 7,248' 7,258' 12 3-3/8"/6SPF 4/17/95 Open 15 L P & KuparukA 11,140' 11,154' 7,264' 7,276' 14 3-3/8"/6SPF 4/17/95 Open 1 16 xAs.k+^ 11,166' 11,204' 7,286' 7,319' 38 3-3/8"/6SPF 4/17/95 Open !i!-f`� Reference Log:4/15/1995 AWS GR/CCL [EHD=0.76',TTP=6.4"]/Mid-pert=7284'TVD,11,163'MD 17 k GENERAL WELL INFO API:50-029-22546-00-00 14, 18 I Drilled and Cased by Nabors 27E -3/11/1995 i1Run ESP Completion by Nabors 4ES-11/6/1995 ESP Change-out -1998 11 F *2 ESP Change-out by Nabors 4ES-7/1/2000,3/9/2005,11/13/2007 KUPA Sands Stimulate Acid Treatment-2008 i ESP Change-out&Screen Replacement by Nabors 35-12/30/2008 7" ,' - '• Stimulate Acid Treatment-2009 TD=11,502'(MD)/TD=7,575'(TVD) ESP Change-out&Screen Replacement by Nabors 4ES-8/5/2010 PBTD=11,353'(MD)/PBTD=7,447'(TVD) ESP Change-out&Screen Replacement by Doyon 16-4/18/2013 STIMULATION SUMMARY 80,000lbs 16-20 CL ISP 4/19/1995 Kup A sand Revised By:TDF 3/3/2016 screened out. H . • Milne Point Unit Well: MPU F-25 PROPOSED Last Completed: 4/18/2013 Hilcora Alaska,LLC PTD: 195-016 TREE&WELLHEAD Orig.KB Elev.:47'/Orig.GL Elev.:13'(N27E) Tree 3-1/8"5M CIW 1 13-5/8""5M FMC w/3.5"FMC Tbg.Hanger, t4illr Wellhead EUE Lift Threads,3"CIW"H"BPV profile 20 ,,, OPEN HOLE/CEMENT DETAIL 4 ii 20" 250 sx of Arcticset I(Approx)in 30"Hole 4 +a 9-5/8" 678 sx PF'E',250 sx Class'E',290 sx in 12-1/4"Hole 7" 290 sx Class"G"in 8-1/2"Hole 1 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF _g 5 20" Conductor 91.1/N/A/N/A N/A Surface 80' N/A 1 9-5/8" Surface 40/NT-80S/Btc. 8.835 Surface 3,405' 0.0759 fi 7" Production 26/L-80/NSCC 6.276 Surface 11,437' 0.0383 9-5/8" "6 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 Surface ±30' 0.0087 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 ±30' ±10,980' 0.00579 WELL INCLINATION DETAIL KOP@800' Max Hole Angle=60 to 62 deg.f/5,200'to 9,050' Hole Angle through perforations=30 deg. 2-- 7// /A 4_e JEWELRY DETAIL ✓ No Depth Item [ ( S�f2e.. 1 ±30' XO:3-1/2"x 2-7/8" 00'4 2 ±140' STA 2:GLM-2-7/8"x 1"KBMM w/DSOV 0 V 3 ±10,677' STA 1:GLM-2-7/8"x 1"KBMM w/Dummy Valve 4 ±10,824' 2-7/8"XN-Nipple(2.250 No-go ID) MIN ID Above ESP: 2.250"@10,824' 3 5 ±10,865' Discharge Head 6 ±10,866' Pump Marker Joint: -***----# 411 7 ±10,885' Separator 10,753'-10,744WLM #Mb 4 4 8 ±10,890' Seal 1 9 ±10,897' Seal 10 ±10,903' Motor 6 11 ±10,917' Gauge Ci 1 12 ±10,919' XO(Contingency) 6 13 ±10,921' Shear Type Safety Joint(Contingency) k;' ;*N 14 ±10,924' 2-7/8"Ported Tubing Jt(Contingency) IIIA 1 7 15 ±10,926' Cup Packer Assy(Contingency) 4 8&9 16 ±10,934' XO(Contingency) V, ISf s 17 ±10,935' Screen(Contingency) a 's 18 ±10,978' Bull Plug(Contingency) 110 PERFORATION DETAIL �� Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Type Date Status 11,122' 11,134' 7,248' 7,258' 12 3-3/8"/6SPF 4/17/95 Open t 1513&14 KuparukA 11,140' 11,154' 7,264' 7,276' 14 3-3/8"/6SPF 4/17/95 Open 1[ 16 1 11,166' 11,204' 7,286' 7,319' 38 3-3/8"/6SPF 4/17/95 Open Reference Log:4/15/1995 AWS GR/CCL [EHD=0.76',TTP=6.4"]/Mid-perf=7284'TVD,11,163'MD 17 V, GENERAL WELL INFO it API:50-029-22546-00-00 18 .,,,t,, Drilled and Cased by Nabors 27E -3/11/1995 r Run ESP Completion by Nabors 4ES-11/6/1995 ESP Change-out -1998 10"0 V t *.:- ESP Change out by Nabors 4ES-7/1/2000,3/9/2005,11/13/2007 KUPASands Stimulate Acid Treatment-2008 * ESP Change-out&Screen Replacement by Nabors 3S-12/30/2008 7" TM1- Stimulate Acid Treatment-2009 1D=11,502'(MD)/TD=7,575'(TVD) ESP Change-out&Screen Replacement by Nabors 4ES-8/5/2010 PBTD=11,353'(MD)/PBTD=7,447(TVD) ESP Change-out&Screen Replacement by Doyon 16-4/18/2013 STIMULATION SUMMARY 80,000Ibs 16-20 CL ISP 4/19/1995 Kup A sand Revised By:PC 3/7/2016 screened out. fit • • Milne Point ASR 13-5/8" BOP 03/07/2016 riga,„rt, 11.,.k,.1.r.c r 1 O O i Hydril 13 5/8” 5M if II [11-1 art rizt I I "I gni Brian i I Spacer Spool 13 5/8" 10M x 13 5/8" 5M 1I1.1I I.I1I.II I.I IC I / \ r Shaffer — ®® 2 7/8"x 5"VBR Rams -. f3 r 13 5/8" 5M Blinds 2 1/16" 5M Kill Valves ".91' / 2 1/16" 5M Choke Valves Manual and Manual ._ .�. Manual and HCR irt,PLP .. .,..--- ---)ir 9,( e ii t *soII)U0 . • . BHTA,Otis,3 1/8"5M MPF-25 FMC New standard Big Bore Tubing hanger,FMC 13 Valve,Swab,WKM 3 1/8" ,@� 6, `J 5/8"X 3 1/2"3"'type H HWO =+ `)1 ,, BPV profile / iiii. ..1/2''',.. 17)1 t(,.._..-z, Gd4.P Valve SSV WKM �% 3 1/8" Baker oper �o,fo /2 b :•,._ _...--2, ' 0r �Z/gyp. Valve,Master WKM 3 1/8" HWO ) ) ' 1-3/8 Adapter, FMC 13 5/8"5M rot flg btm X Control line - 3 1/8 5M stdd top, ? � ali — 1 Tubing head j , NAll 13 5/8'SM btm x N 13 5/8"5M Top,w/2 _l •d i� �_ 2 1/16 5M HWO valves + ® Illi I ___1.,...„„ �-_, �, I, O �I��I �= 0 ilz.„•---11 -F-i=-----, -- *.iioldr. 2 Casing head,FMC — = 13 5/8 SM,w/2-2 1/16 _l I w n L - s_ is HWO valves �,' r Iii r - INOF a 0 i • • 0 = m ,.. /\« $ � ; a , c / § ; - !\ ) j / \ — e= c, \ ) 3 2 r } } / .... § e/ I ■ X /DO § .... ■` ai & OOTD 9 ` 9 % \ ) / {•, §I \ \ \ \ ) ) ; k / 2 ► ƒ / / ) ) \ \ / §K A ra cooo 0 o an o o < � §� C g9 4__.< \ : : 1 < § &t § \ \ nomii /u: to _ [4140� . 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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 TO RE-SCAN Vincent Nathan Lowell Date: ¢}" 0¢2,~/si/~%,- Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA E r ,- ; • / SKA OIL AND GAS CONSERVATION CcMISSION , REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. • ❑ Exploratory ❑ Stratigraphic 195 416 . 3. Address: • ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22546 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025509 & 355018 MPF -25 ' 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands • 11. Present well condition summary: Total depth: measured 11502' feet ' Plugs:(measured) N/A feet true vertical 7575' feet Junk: (measured) N/A feet Effective depth: measured 11333' feet Packer: (measured) 10926' & 10935' feet true vertical 7430' feet Packer: (true vertical) 7079' & 7087' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 32' - 110' 32' - 110' Surface 3375' 9 -5/8" 31' - 3406' 31' - 2975' 5750 3090 Intermediate Production 11407' 7" 30' - 11437' 30' - 7520' 7240 5410 Liner SCANNED JUL 2 2 2013 Perforation Depth: Measured Depth: 11122' - 11204' feet True Vertical Depth: 7248' - 7319' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# N -80 10978' 7124' Packers and SSSV (type, measured and true vertical depth): Baker 7 ", 26# Cup Packer Assembly & 10926' & 10935' 7079' & 7087' 4 -1/2" Duragrip 500 Micron Screen w /Bull Plug 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 387 120 415 280 223 Subsequent to operation: 370 129 406 280 274 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ' ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: . Oil ❑ Gas ❑ WDSPL Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Noel Nocas, 564 -4667 N/A Email: Noel.Nocas @bp.com Printed N - - Joe Las a Title: Drilling Technologist Signature: ik Phone: 564 -4091 Date: S 45/I3 Form 10-404 Re - - • 10/2012 7/ f � 3 /`� • mit Original Only l �� FIE3DMS MAY 17 201A • • r+irir Sutnria0 Report Common Well Name: MPF -25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: X4 OOXL3 E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @45.40usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 4/13/2013 10:00 - 12:00 2.00 MOB P PRE RIG WAS RELEASED FROM WELL MPC -14 AT 10:00. PREP TO PULL OFF THAT WELL. 12:00 - 18:30 6.50 MOB P PRE PULL RIG OFF WELL AND SET DOWN ON THE EDGE OF THE PAD. BREAK BOP STACK APART TO CHANGE TO A 4- PREVENTER STACK 18:30 - 20:30 2.00 MOB P PRE MAKE UP 4 PREVENTER STACK - MAKE UP MUD CROSS AND SINGLE GATE TO DOUBLE GATE - SECURE TO STAND FOR TRANSPORT - BRIDLE UP TO LAY DERRICK DOWN 20:30 - 00:00 3.50 MOB P PRE - PJSM FOR RIG MOVE TO MPF -25 - BRIDLE UP AND LAY DERRICK OVER - NOTIFY PAD OPERATOR - PULL OFF OF MPC PAD AND MOVE TO MP F PAD 4/14/2013 00:00 - 02:00 2.00 MOB P PRE PRE -TOUR MEETING, SPCC CHECKS - CONTINUE MOVE FROM MP C PAD TO MP F PAD - RIG MOVING DOWN MP L & F PAD ACCESS ROAD 02:00 - 03:00 1.00 MOB P PRE ARRIVE MP F -PAD - PULL ON TO MPF -PAD - LAY MATS AND PREP TO BACK OVER WELL - INSTALL BOP STACK ON STUMP IN CELLAR 03:00 - 06:00 3.00 MOB P PRE BACK OVER MP F -25 - WSLAND NIGHT TOOLPUSHERS PRESENT, PAD OPERATOR NOTIFIED 06:00 - 07:00 1.00 MOB P PRE SET RIG DOWN, CLOSE CELLAR DOORS. SHIM RIG AND PLUG OPENINGS IN CELLAR DOORS. PJSM THEN RAISE AND PIN DERRICK 07:00 - 10:00 3.00 MOB P PRE RIG DOWN BRIDAL LINES. RIG UP CIRC SKID IN CELLAR. TAKE ON FLUID IN PITS, 9.9 PPG, 108 DEG. ACCEPT DOYON 16 ON MPF -25 AT 0800 HRS ON 4/14/2013 10:00 - 10:30 0.50 MOB P PRE RIG EVAC DRILL AND AAR. 10:30 - 12:30 2.00 WHSUR P DECOMP FILL SURFACE LINES, INSTALL SAFETY CABLES. PREP TO PT LINES. 12:30 - 13:30 1.00 WHSUR P DECOMP PRESSURE TEST CIRC OUT LINES TO FLOWBACK TANK, 250 / 3500 PSI, GOOD. 13:30 - 14:00 0.50 WHSUR P DECOMP RIG EVAC DRILL WITH DAY CREW AND AAR. 14:00 - 16:30 2.50 WHSUR j P DECOMP PJSM, PU DSM LUBRICATOR. RU TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. - PULL BPV AND UD LUBRICATOR Printed 4/29/2013 11:56:37AM Operation Summa Re ort Common Well Name: MPF -25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: IX4 -00XL3 -E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @45.40usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 16:30 - 17:30 1.00 WHSUR P DECOMP PJSM, WELL KILL WITH 9.9 PPG BRINE AT -130 F - DAY WSL / TOOL PUSHER PRESENT ' DURING OPERATION - WSL & TOOL PUSHER CONFIRM VALVE ALIGNMENT - SITP = 600 PSI, SICP = 550, SIOA = 0 PSI - BLEED GAS FROM IA F/ 550 PSI T/ 0 PSI IN 10 MIN. SITP = 200 PSI _ - GAS AND FLUID RETURNS. 17:30 - 21:30 4.00 WHSUR ! P DECOMP - PUMPED 62 BBLS 9.90 PPG HEATED BRINE AT 3 BPM WITH 410 PSI DOWN THE TBG ! THROUGH CHOKE SKID TO FLOW BACK TANK. - AT 40 BBLS AWAY , PUMP LOST PRIME, SHUT DOWN FOR 10 MINS - RESTART PUMPING AT 3 BPM & 750 PSI - ICP =410 PSI -FCP =700 PSI - BULL HEAD ON THE FLY, 17 BBLS KWF DOWN THE TBG AT 3 BPM / 700 PSI. PUMPED HEATED 9.9 PPG HEATED BRINE AT 1 5 BPM DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. -ICP= 5 BPM /2000 PSI. - PUMPED 350 BBLS KWF AT 5 BPM AND SHUT PUMP OFF I - SHUT -IN WELL WHILE VACUUM OUT FLOW BACK TANK. RECOVERED 300 BBLS PRODUCED WATER & CRUDE. - OPEN WELL - CONTINUE PUMPING THE REMAINING 136 BBLS KWF - ICP = 5 BPM / 1700 PSI - FLUID RETURNS = 9.9 PPG AT 423 BBLS PUMPED - SHUT DOWN PUMP AFTER 5745 STROKES / 486 BBLS MONITOR 30 MINUTES. - TBG AND IA IMMEDIATELY ON A VACUUM. - TOTAL LOSSES DURING WELL KILL 111 BBLS KWF 21:30 - 22:30 1.00 WHSUR P DECOMP RIG DOWN KILL MANIFOLD - BLOW DOWN LINES - RIG DOWN CIRCULATING LINES & KILL MANIFOLD - R/U SECONDARY KILL LINE 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND 3500 PSI LOW FOR 5 MINS EACH , CHARTED - SET TWC - LAY DOWN LUBRICATOR CONTINUOUS HOLE FILLAT -20 BPH OF 9.9 PPG KWF 24 HR LOSSES = 111 BBLS _ Printed 4/29/2013 11:56:37AM • . . ,„ . • ()Oration Summary R8p0 Common Well Name: MPF -25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: X4- 00XL3 -E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @45.40usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/15/2013 00:00 - 02:30 2.50 WHSUR P DECOMP WEEKLY SAFETY MEETING WITH 'D' CREW, SPCC CHECKS , PRE -TOUR MEETING PRESSURE TEST TWC - PERFORM 500 PSI ROLLING TEST BELOW TWC. - PUMP DOWN IA @ 2.5 BPM AND 500 PSI FOR 10 MINS, CHARTED MIN. (28 BBLS KWF PUMPED) - LESS THAN 1 BBLS BLED BACK. - TEST TWC FROM ABOVE 250 PSI LOW & 3500 PSI HIGH FOR 5 MINS EACH , CHARTED. - FMC, AND MP WELL SUPPORT VERIFY REFERENCE MARKS FOR POST RIG TREE I ALIGNMENT. 02:30 - 04:00 1.50 WHSUR P DECOMP PJSM TO DRAIN AND NIPPLE DOWN TREE & N/U BOPE - NIPPLE DOWN FMC ADAPTER FLANGE & 2 9/16" , 5 M TREE - FMC REP CLEAN AND INSPECT 3 -1/2" NSCT HANGER THREADS - CONFIRM 8 TURNS BY HAND. 04:00 - 11:00 7.00 BOPSUR P DECOMP PJSM, RIG UP BOPE - N/U 13 -5/8" 5M , 4 PREVENTER BOP STACK - INSTALL 13 -5/8" x 13 -5/8" SPACER SPOOL - INSTALL TURNBUCKLES AND FLOW NIPPLE. - INSTALL VBRS & BLINDS INTO RAM BODIES - RE- ENERGIZE ACCUMULATOR SYSTEM. - R/U RISER. BOP CONFIGURATION: ANNULAR PREVENTER 2 -7/8" x 5" VBR BLIND SHEAR MUD CROSS W/ KILL AND CHOKE LINES 2- 7 /8 "x5'VBR 11:00 - 13:00 2.00 BOPSUR P DECOMP START BOP TEST. - TEST FOUR PREVENTER BOP AND RELATED EQUIPMENT - AOGCC INSPECTOR CHUCK SCHEVE HAS WAIVED WETNESS TO THE TEST. I- FILL BOPS WITH FRESH WATER AND SHELL TEST AGAINST TWC. - FIND LEAK ON BLIND RAM DOOR SEAL. 13:00 - 14:00 1.00 BOPSUR N ! RREP DECOMP GET NEW DOOR SEAL FROM PARTS STORAGE AT DOYON CAMP. REPLACE DOOR SEAL AND PRESSURE TEST, GOOD. Printed 4/29/2013 11:56:37AM • • ;„„„ .; ,,„ .• . (V: • • • „r• , '"' - : thin - , . Common Well Name: MPF-25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: X4-00XL3-E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM , Rig Release: Rig Contractor: DOYON DRILLING INC. Active datum: Kelly Bushing / Rotary Table ©45.40usft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 20:00 6.00 BOPSUR P DECOMP CONTINUE BOP TEST. - TEST BOP ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST LOWER AND UPPER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, CHARTED TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - COMPLETE ACCUMULATOR DRAW DOWN TEST. - NO FAILURES THROUGH OUT BOP TEST - BLOW DOWN LINES - RIG DOWN TEST EQUIPMENT - SUCK OUT STACK 20:00 - 22:30 2.50 WHSUR P DECOMP PJSM, PU DSM LUBRICATOR / OFFSET EXTENSION. 1- CLOSE ANNULAR AND PRESSURE TEST LUBRICATOR TO 250 / 3500 PSI AND CHART FOR 5 MINUTES EACH. - PULL TWC AND R/D DSM LUBRICATOR AND EXTENSION. - WSL VERIFY WELL IS ON VAC - LAY DOWN LUBRICATOR - LAY DOWN OFFSET EXTENSION 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM ON PULLING 3-1/2" NSCT TBG HANGER TO FLOOR. - WSL, TOOLPUSHER, FMC REP, RIG CREW IN ATTENDANCE. - DISCUSSED WELL CONTROL, CONTINUOUS HOLE FILL, DISCONNECTING ESP CABLE FROM PENETRATER. - MU LANDING JOINT WITH FOSV TO TBG HANGER. BOLDS PER FMC REP. - PULL TBG HANGER OFF SEAT @ 125K INCLUDES 40K TOP DRIVE WT. - PULLUP TO FIRST FULL JOINT, UP WT= 115K - CUT ESP CABLE. - POSITION SLICK JOINT ACROSS STACK CONTINUOUS HOLE FILL AT -17 BPH OF 9.9 PPG KWF 24 HR LOSSES = 271 BBLS 4/16/2013 00:00 - 01:00 1.00 PULL P DECOMP SPCC CHECKS , PRE-TOUR MEETING - CLOSE ANNULAR AND PUMP 62 BBLS OF 9.9 PPG BRINE, DOWN TUBING AT 4 BPM / 1380 PSI. - TAKE RETURNS THROUGH GAS BUSTER - SHUT DOWN PUMP - MONITOR WELL - HANG ESP SHEAVE IN DERRICK - HANG SPILL CONTAINMENT TRUNK - WSL / DRILLER VERIFY VACUUM AND NO TRAPPED PRESSURE - OPEN ANNULAR Printed 4/29/2013 11:56:37AM • " • Operation S mma r Common Well Name: MPF -25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: X4 -00XL3 -E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: _ Active datum: Kelly Bushing / Rotary Table @45.40usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations _ — (hr) (usft) 01:00 - 01:30 0.50 PULL 1 P DECOMP LAY DOWN LANDING JOINT - BREAK DOWN CROSSOVER - LAY DOWN HANGER - BLOW DOWN LINE 01:30 - 02:30 1.00 PULL P DECOMP POOH WITH 2 -7/8" EUE 8RD TUBING - PULL 1 STAND - RESTRING ESP CABLE OVER SHEAVE USING DRILL LINE SNAKE ANCHORED TO ESP CABLE. - HAND PULLED OVER SHEAVE INTO TRUNK. - ATTACH ESP TO REEL IN SPOOLING UNIT. 02:30 - 03:00 0.50 PULL P DECOMP 1 AAR ON PULLIING ESP CABLE THROUGH SHEAVE - CREW, CENTRILIFT, TOOL PUSHER , AND WSL PRESENT 03:00 - 04:30 1.50 PULL P DECOMP POOH WITH 2 -7/8" EUE 8RD TUBING, ESP , & CUP PACKER ASSEMBLY - POH WITH TUBING & ESP CABLE FROM 10,825' MD - LASALLE CLAMP EVERY OTHER JOINT - MAINTAIN -17 BPH HOLE FILL W/ 9.9 PPG 'BRINE 04:30 - 05:00 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL AAR: - USED 5 FT SECTION OF OLD ESP CABLE TO CUT - CUTTING CABLE & TYING IT OFF UNDER STRESS WAS A GOOD LESSON LEARNED - GOOD REACTION AND STATION PLACEMENT BY CREW 05:00 - 06:00 1.00 PULL j P DECOMP 'POOH WITH 2 -7/8" EUE 8RD TUBING, ESP , & CUP PACKER ASSEMBLY - POH WITH TUBING & ESP CABLE FROM -800' MD - LASALLE CLAMP EVERY OTHER JOINT 06:00 - 13:30 7.50 PULL P DECOMP [ CONTINUE POOH WITH WITH 2 -7/8" EUE 8RD j TUBING ESP COMPLETION 1- STAND BACK IN DERRICK 13:30 - 15:30 2.00 PULL P DECOMP PULL LOWER GLM UP TO RIG FLOOR. MONITOR WELL FOR 10 MIN, ENSURE FLUID IS DROPPING. PULL OUT GLM, LAY DOWN. STAND BACK LAST STAND THEN PULL ESP 1 MOTOR AND PUMP TO RIG FLOOR. BREAKAPART MOTOR, PUT IN PIPE SHED. RUN CABLE OUT TO SPOOLING UNIT, SECURE IT ON THE REEL. 15:30 - 16:30 1.00 PULL P DECOMP PULL SCREENS TO RIG FLOOR, LAY DOWN. - CLAMPS RECOVERED: 5 PROTECTOLIZERS, 3 FLAT GUARDS, 188 LASSALE CLAMPS 16:30 - 18:30 2.00 PULL P DECOMP , CLEAR / CLEAN RIG FLOOR - R/D ESP TRUNK - REMOVE SCREENS, OLD PUMP AND MOTOR ASSY FROM PIPE SHED Printed 4/29/2013 11:56:37AM • ",?,' • , ; , " ' ." `W'A fwg; r.e4,;*4•tc OperatiOn « pot •;* 7 Common Well Name: MPF-25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: X4-00XL3-E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @45.40usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 18:30 - 23:00 4.50 RUNCOM P RUNCMP PJSM ON MAKING UP NEW SCREENS AND CUP PACKER ASSY AND STRINGING NEW ESP CABLE OVER SHEAVE - M/U AND SERVICE NEW PUMP AND MOTOR ASSY, AND CUP PACKER PER RUNNING ORDER - INSTALL PROTECTOLIZERS AND FLAT GUARDS - TEST CENTRILIFT ESP CABLE CONDUCTIVITY 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM, RIH WITH 2 7/8" EUE 8 RD ESP COMPLETION - FROM SURFACE TO 339' - OA = 135 PSI - LOSS RATE = 14 BPI-I - 24 HOUR FLUID LOSS = 375 BBLS 9.8 PPG BRINE 4/17/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SERVICE RIG INSPECT DRAW WORKS - PJSM WITH CENTRILIFT REP TO RUN ESP COMPLETION 00:30 - 08:00 7.50 RUNCOM P RUNCMP CONT. RIH WITH 2-7/8" EUE 8RD TUBING, ESP ,& CUP PACKER ASSEMBLY FROM DERRICK - FROM 339' TO 7653' MD '-TUBING TORQUE = 2300 FT/LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR ON THE FIRST 9 JOINTS, THEN EVERY OTHER JOINT THEREAFTER - INSTALL CLAMPS ON EVERY COLLAR WITH GREATER THAT 4 DEG DLS AT 1550-1650, 2450-2550, 4730-4830, 5200-5300 - CHECK CONDUCTIVITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM EVERY 2000 FT. 2000 FT 0.5 BPM = 490 PSI, 4000 FT 0.5 BPM = 500 PSI, 6000 FT 0.5 BPM = 460 PSI, 7653 FT 0.5 BPM = 430 PSI. 08:00 - 10:30 2.50 RUNCOM P RUNCMP CENTERLIFT PERFORM CABLE TO CABLE SPLICE IN SPOOLING UNIT. 10:30 - 14:00 3.50 RUNCOM P RUNCMP CONTINUE RUNNING ESP COMPLETION. - FROM 7653' TO 10978' MD 14:00 - 17:00 3.00 RUNCOM 1 P 1 RUNCMP PICK UP HANGER. TERMINATE ESP CABLE IN HANGER. 17:00 - 18:00 1.00 RUNCOM P RUNCMP LAND HANGER, UP WT IS 115K, SLACK OFF IS 77K. BLOCKS ARE 40K. RUN IN LDS. 118:00 - 19:30 1.50 RUNCOM P RUNCMP M/U RUNNING TOOL AND SET TWC -PERFORM ROLLING TEST FROM BELOW, 500 PSI, 10 MIN, CHARTED, 2 BPM = 500 PSI, 28 BBLS PUMPED AWAY - TEST FROM ABOVE 250 / 3500 PSI, 5 MIN CHARTED 19:30 - 20:00 0.50 BOPSUR P RUNCMP PJSM FOR N/D BOPE, N/U TREE - BLOW DOWN ALL LINES AND SUCK OUT STACK - R/D TEST EQUIPMENT 20:00 - 21:30 1.50 BOPSUR P RUNCMP N/D BOPE AND RISER - CENTRILIFT MAKE FINAL ESP CONDUCTIVITY CHECKS Printed 4/29/2013 11:56:37AM is - /"�, - y^� »;,:�,. • :, ;�<;;v " ✓- .'ii % :2,.,�,,, . /. . , yyyy � f 'r� O k'hlal Common Well Name: MPF -25 AFE No Event Type: WORKOVER (WO) Start Date: 4/13/2013 End Date: X4 -00XL3 -E:RIG (1,700,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/29/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @45.40usft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 121:30 - 00:00 2.50 WHSUR P WHDTRE N/U FMC GEN 5 11" X 3 1/8" 5K ADAPTOR FLANGE N/U 3 1/8" 5000 WKM TREE -TEST ADAPTER VOID, 5000 PSI, 30 MIN 4/18/2013 00:00 - 00:30 0.50 WHSUR P r WHDTRE TEST FMC TREE ADAPTER FLANGE VOID — - 5000 PSI HIGH, 30 MINUTES rt— 00:30 - 02:00 1.50 WHSUR P WHDTRE TEST TREE WITH DIESEL - 250 / 5000 SPI, 5 MIN, CHARTED, GOOD TEST 02:00 - 04:30 2.50 WHSUR P WHDTRE M/U DSM LUBRICATOR TO TOP OF TREE - TEST 250 / 3500 PSI, 5 MIN, CHARTED - PULLTWC - TEST LUBRICATOR AGAIN - SET BPV - R/D DSM LUBRICATOR 04:30 - 05:00 0.50 WHSUR P WHDTRE !PERFORM ROLLING TEST FROM BELOW BPV 1- 2 BPM = 500 PSI, 10 MIN, CHARTED, 34 BBLS -- — — — PUMPED AWAY - 05:00 - 08:30 l 3.50 WHSUR P WHDTRE BREAK DOWN CELLAR LINES AND START RIGGING DOWN, PREP TO MOVE OFF WELL. OFFLOAD REMAINING BRINE, VAC OUT PITS AND CUTTINGS BOX. MEANWHILE HOLD PJSM, R/U LITTLE RED SERVICES AND TEST LINES. - PUMP 75 BBLS OF DEAD CRUDE FREEZE PROTECT DOWN IA, 2 BPM © 1500 PSI. FP TO 2500 FT. - PUMP 15 BBLS OF DIESEL DOWN TUBING, 0.75 BPM @ 1700 PSI. FP TO 2500 FT. I , I � * ** RELEASE RIG AT 0830. ALL FURTHER ENTRIES ON WELL F -57 * ** Printed 4/29/2013 11:56:37AM r r. r ' Tree: 3 1/8"" - 5M • M P F -2 5 Orig. .elev = 45.5' Wellhead: 11" 5M FMC Orig. GL Elev. = 13.0' w/ 3.5" FMC Tubing Hanger , EUE OKB to Base Flange. = 33.46' lift threads, 3" CIW H BPV profile 20 ", 91.1 ppf 80' Camco 2 7/8" x 1" 141' v' KBMM GLM KOP @ 800' Max. Hole Angle = 60 to 62 deg. f/ 5200' - 9050' NOTE: 7" Casing Landed on Hole angle thru' perfs = 30 deg. Emergency slips 9 5/8 ", 40 # /ft, 3405' MD , ■ NT-80S Btrs. )) Camco 2 7/8" x 1" 10677' KBMM GLM 2 -7/8 ", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) 7" 26 #, NT-80S NSCC Casing 2 - 7/8" HES XN nipple 10824' (cap. = 0.0383 bpf) ( 2.250" No -Go ID ) Discharge Head 10865' (cap w/ 2 7/8" tubing inside = 0.02758) , Centrilift Pump 10866' , ° 137- P17,PM SXD Stages Gas Separator 10885' 7" x 21' casing marker joint —X "'„4 GRSFTXAR H6 10,753- 10,774' wlm ! -_; ^ Intake TVD 7043' `* Centrilift Tandem Seal Section p . GSB3DBUT UT /LT SB /SB PFSA CL5 10890' Stimulation Summary Centrilift MSP1 -259 Motor 80 M Lbs. 16 -20 CL ISP 4/19/95 ismagr iii numwt 168 HP 3460 v / 30 A Kup "A" Sand - Screened out 10903' WeIILift MGU w/ 6 Fin Central- 10917' Perforation Summary izer REF LOG: 4/15/95 AWS GR /CCL Gauge TVD 7076' BOT Safety Shear Sub (25k) 10921' Gun SPF Interval (TVD) 3 3/8" 6 11,122'- 11,134' (7247'- 7258) 2 7/8" Ported Tbg Jt. 10924' 3 3/8" 6 11,140'- 11,154' (7262'- 7275') BOT 7" Cup Packer 10926' 3 3/8" 6 11,166' - 11,204' (7285'- 7318') 4.5" duragrip 500 Micron 10935' Screen w/ bull plug EHD = 0.76 ", TTP = 6.4" mid -perf = 7284' tvd 11163' and — Fill cleaned out to 11,244' on 12/31/08 ORIG. PBTD 11, 353' M D t, 7" 26 #, NT-80S NSCC 11,437' MD DATE REV. BY COMMENTS MILNE POINT UNIT 08 /19/96 MDO ESP RWO 4ES 07/02/00 .IWS FSP RWO 4FS WELL F -25 03/09/05 Lee Hulme ESP RWO 4ES API NO: 50 -029 -22546 11/13/07 Lee Hulme ESP RWO 4ES 12/31/08 Lee Hulme Replace ESP and install Pkr /Screens Nabors 3S 8/5/10 Lee Hulme Replace ESP and Pkr /Screens Nabors 4ES 4 -20 -13 AAR Doyon 16 ESP Changeout BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 • ' Y December 30, 2011 Mr. Tom Maunder 0j�— 0 l 6 Alaska Oil and Gas Conservation Commission I 333 West 7 Avenue Anchorage, Alaska 99501 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 (10 -404) 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 gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 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 02 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 -40- MPF -25 1950160 50029225460000 0.3 N/A 0.3 WA 6.8 10/29/2011 MPF -26 1970840 50029227870000 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 8/92011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/52011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 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 8/12011 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-01 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 8/42011 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 12 N/A 13.6 8/3/2011 MPF -840 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 12 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 ALAS IL AND GAS CONSERVATION COMMI N REPO~OF SUNDRY WELL OPERA ONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5:- Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-016 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~~ 50-029-22546-00-00 7. Property Designation: '*~ 8. Well Name and Number: .,~ ADL 355018 MPF-25 9. Field /Pool(s): "~ Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 11502 feet true vertical 7575 feet Plugs (measured) N/A Effective depth: measured 11333 feet Junk (measured) N/A true vertical 7430 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' Surface 3375' 9-5/8" 3406' 2975' 5750 3090 Intermediate Production 11407' 7" 11437' 7520' 7240 5410 Liner ti ~- 3 Perforation Depth: Measured Depth: 11122' - 11204' True Vertical Depth: 7248' - 7319' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 10981' 7126' Packers and SSSV (type, measured and true vertical depth): Baker 7", 26# Cup Packer Assembly 10936' 7088' 4" Excluder Screen with Bull Plug 10939' - 10981' 7090' - 7126' 11. Stimulation or cement squeeze summary: 4 Intervals treated (measured): Treatment description including volumes used and final pressure: i~li'~f .?t 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 196 53 1009 324 370 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ` ^ Exploratory ®Development ^ Service erations ® D il R f Well O rt y p a epo o ® Well Schematic Diagram 15. Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si~nature ~ Phone 564-4750 Date© ~`~ Sondra Stewman, 564750 Form 10-404 Revised 07/2009 ~ ~~ Submit Original Only Tree: 3 1/8"" - 5M M P F-25 Orig. DF e~ 45.5' Wellhead: 11" 5M FMC Orig. GL Elev. = 13.0' w/ 3.5" FMC Tubing Hanger ,EUE OKB to Base Flange. = 33.46' lift threads, 3" CIW H BPV profile 20", 91.1 ppf 80' KOP C~ 800' Max. Hole Angle = 60 to 62 deg. f/ 5200' - 9050' Hole angle thru' perfs = 30 deg. 9 5/8", 40#/ft, 3405' MD NT-80S Btrs. 2-7/8", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) 7" 26#, NT-80S NSCC Casing (cap. = 0.0383 bpf) (cap w/ 2 7/8" tubing inside = 0.02758) 7" x 21' casing marker joint - 10,753-10,774' wlm Stimulation Summary 80 M Lbs. 16-20 CL ISP 4/19/95 Kup "A" Sand -Screened out Perforation Summary -REF LOG: 4/15/95 AWS GR/CCL Gun PF Interval (TVD) 3 3/8" 6 11,122'-11,134' (7247'-7258' 3 3/8" 6 11,140'-11,154' (7262'-7275' 3 3/8" 6 11,166'-11,204' (7285'-7318' EHD = 0.76", TTP = 6.4" mid-perf = 7284' tvd 11163' and Camco 2 7/8" x 1" 139` KBMM GLM NOTE: 7" Casing Landed on Emergency slips Camco 2 7/s" x 1 " 10707' KBMM GLM 2-7/8" HES XN nipple 10853' ( 2.250" No-Go ID ) Discharge Head 10864' Centrilift Pump 10865' 137-P17, SXD Gas Separator 10884' ~ ' ~ GRSFTX AR H6 Intake TVD 7043' a Centrilift Tandem Seal Section ' GS63D6 UT/LT SB/SB PFSA 10889 Centrilift 562 series Motor (rerated) 195 HP KMH 2415 V / 52 A KME-1 10902' PumpMate XTO Sensor w/ 6 10922' Fin Centralizer Gauge TVD 7076' BOT Safety Shear Sub (36k) 10925' _ 2 7/8" Ported Tbg Jt. 10929' BOT 7" Cup Packer 10931' BOT Excluder Screen w/ 10941-80' bull plug -Fill cleaned out to 11,244' on 12/31/08 i1333'm ORIG. PBTD MD 7" 26#, NT-80S NSCC 1 43T MD DATE REV. BY 11/06/95 08 /19/96 JBF MDO 07/02100 03(09!05 JWS Lee Hulme 11!13/07 12/31/08 Lee Hulme Lee Hulme 8!5/10 Lee Hulme COMMENTS ESP RWO 4ES replace ESP and install Pkr/Screens Nabors 3S Replace ESP and Pkr(Screens Nabors 4ES MILNE POINT UNIT WELL F-25 API NO: 50-029-22546 BP EXPLORATION • North Amarica -ALASKA - BP Page i of i ©peration Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 7/28/2010 End Date: X4-0009E-E (50,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:OO:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: RIG KELLY BUSHING @45.4ft (above Mean Sea Active Datum: O Level) Date _ _ From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/28/2010 18:00 - 00:00 6.00 MOB P PRE RIG PREP OF MOBILIZATION TO MPF-25 -PJSM WITH PEAK TRUCK DRIVERS AND RIG CREW. -PRE SETTING EXTRA MATS AROUND WELL " -SETTING EQUIPMENT BEHIND WELL PRIOR TO SPOTTING SUB MOVING RIG 7/29/2010 00:00 - 06:00 6.00 MOB P PRE ' SPOTTING RIG OVER MPF-25 -PRE SETTING EXTRA MATS AROUND WELL -SETTING EQUIPMENT BEHIND WELL PRIOR TO SPOTTING SUB 06:00 - 17:00 11.00 MOB P PRE SPOT SUB BASE, PITS, AND PIPE SHED. -JACK UPAND LEVEL ALL THREE MODULES - 2 MATTS HIGH AND'HIGH-JACKED TO ACCOMIDATE TBG SPOOL HEIGHT AND DOUBLE GATE. CLEAN-WP AROUND MPF-93, REMOVE " HERCULITE,-RIG UP MUD LINES, LEVEL RIG & PIPE SHED -SHORE UP ALL STAIRS, RIG ACCEPTED 15:00 HRS, 07/29/2010. Printed 8/26/2010 1:44:46PM • North America -ALASKA - BP Page ~ of Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-0009E-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29!2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUS HING @45.4ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/29/2010 17:00 - 21:00 4.00 KILLW P DECOMP TAKE ON BRINE, TEST SURFACE LINES. -CHECK FOR GAS ON TBG & I/A, VERY LITTLE GAS -SET OUT GAS VENTING SIGNS AND NOTIFY MILNE BASE OF IMPENDING OPERATION -TAKE ON 3 TRUCKS 9.1 PPG BRINE TO PITS. VARIFY WT AND TEMP. 21:00 - 21:30 0.50 KILLW P DECOMP PJSM: PJSM WITH TRUCK DRIVERS AND RIG `CREWS'FOR WELL KILL OPERATIONS. -M/U'i1UBRICATOR, TEST TO 500 PSI, OK. PULL.BPV. -RECORD,PRESSURES,SITP-530 SICP-620 21:30 - 00:00 2.50 KILLW P DECOMP WELL KILL OPERATIONS: CIRCULATE 62 BBLS OF 9.1 PPG BRINE TO DISPLACE TUBING. BULL HEAD 35 BBLS TO FORMATION. CIRCULATE 325 BBLS DOWN .TUBING UP THROUGH THE CHOKE OUT TO THE TIGER TANK ,UNTIL RETURNS WERE CLEAN. -9.1 PPG IN AND OUT. -CIRCULATE AT 3-BPM WITH 770 PSI PUMP PRESSURE. -SHUT DOWN AND MONITORED WELL, HAD SMALL AMOUNT OF GAS BREAKING OUT. LINED UP TO PUMP THROUGH THE CHOKE TO THE GAS BUSTER BACK TO THE PITS. PUMPED ANOTHER 100 BBLS. -SHUT DOWN AND MONITORED WELL -WELL IS STATIC (0) PSI ON BOTH THE TUBING AND LA. ,WELL ON A SLIGHT VAC -TOTAL LOSS DURING KILL - 153 BBLS 7/30/2010 00:00 - 04:00 4.00 KILLW P DECOMP WELL KILL OPERATIONS: -WELL KILL. CIRCULATE 62 BBLS OF 9.1 PPG BRINE TO DISPLACE TUBING. BULL HEAD 35 BBLS TO FORMATION. CIRCULATE 325 BBLS DOWN TUBING UP THROUGH THE CHOKE OUT TO THE TIGER TANK ,UNTIL RETURNS WERE CLEAN. -9.1 PPG IN AND OUT. -CIRCULATE AT 3-BPM WITH 770 PSI PUMP PRESSURE. -SHUT DOWN AND MONITORED WELL, HAD SMALL AMOUNT OF GAS BREAKING OUT. LINED UP TO PUMP THROUGH THE CHOKE TO THE GAS BUSTER BACK TO THE PITS. PUMPED ANOTHER 100 BBLS. -SHUT DOWN AND MONITORED WELL -WELL IS STATIC (0) PSI ON BOTH THE TUBING AND I.A. , WELL ON A SLIGHT VAC -TOTAL LOSS DURING KILL ~ 153 BBLS 04:00 - 06:30 2.50 BOPSUR P DECOMP INSTALL AND TEST TWC -TEST TO 3500 PSI FROM ABOVE AND A ROLLING TEST FROM BELOW TO 500 PSI FOR TEN CHARTED MIN. Printed 8/26/2010 1:44:56PM ~orth America -ALASKA - BP ~ Page 2 of ~ Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6!2010 X4-0009E-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUS HING @45.4ft (above Mean Se_a Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 08:00 1.50 BOPSUR P DECOMP ND 3 V8" 5M TREE AND ADAPTER FLANGE.,, -SINGLE BARRIER DISPENSATION IN PLACE FOR MILNE PT WELL -BARRIER IN PLACE: IS A TESTED 3" CIW (H) STLYE TWC *'*JEFF JONES W/ AOGCC CALLED AND WAIVED THE RIGHT TO WITNESS THE BOP TEST ON MPF-25*** @ 07:15 08:00 - 14:30 6.50 BOPSUR P DECOMP NU 135/8" 5M BOP STAC~FROM TOP TO BOTTOM: -1'3 5/8" HYDRIL'GK' ANNULAR PREVENTER -2 7/8" X 5'' VBR -BLIND/SHEAR RAMS' -MUD CROSS -2 7/8" X 5" VBR 14:30 - 16:30 2.00 BOPSUR P DECOMP FUNCTION TEST BOP STACK. -FUNCTION AND VERIFY RAM OPERATION IN BOP STACK. -FILL STACK AND CHOKE LINES WITH WATER... -WORK AIR OUT OF SYSTEM AND LOOK FOR LEAKS. 16:30 - 00:00 7.50.... BOPSUR N SEAL 00 DECOMP CHOKE LINE LEAK WHILE FILLING LINES. -FOUR WAY CROSS BLOCK FOUND TO BE WASHED OUT. -PARTS HAVING TO COME FROM DEAD HORSE 7/31/2010 00:00 - 01:00 1 00 BOPSUR N SFAC DECOMP CHOKE LINE LEAK 1(~HILE FILLING ~, N~. FyS_, , . -FOUR WAY CROSS BLOCK FOUND TO BE WASHED OUT. -PARTS HAVING TO COME FROM DEAD HORSE 01:00 - 08:30 7.50 BOPSUR P DECOMP STA T D T 13-5/8" HYDRILL 5M BOP TEST AS FOLLOWS TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. -AOGCC WITNESSING OF TEST WAIVED BY JEFF JONES @ 07:15 7-30-2010 -TEST WITNESSED BY BP WSL, NABOR'S TOOL PUSHER & NABORS DRILLER -PERFORM KOOMEY DRAW DOWN TEST -200 PSI BUILD UP TO 1775 PSI FROM 1575 PSI = 55 SECONDS. -FULL BUILD UP TO 3000 PSI = 210 SECONDS. -4 BOTTLES x 2050 PSI. 08:30 - 09:30 1.00 BOPSUR P DECOMP LAY DOWN BOP TEST EOPT -LD TEST JNT, DRAIN BOP STACK, -RU DUTCH RISER 09:30 - 11:00 1.50 BOPSUR P DECOMP PU & MU LUBRICATOR -PRESSURE TEST LUBRICATOR TO 500 PSI, GOOD TEST -MILNE PT WELL SUPPORT PULLED TWC, -RD & LD DUTCH RISER Printed 8/26/2010 1:44:56PM .North America -ALASKA - BP ~ Page s of 5 Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-0009E-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud DatelTime: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: ORIG KELLY BUS Active Datum : HING @45.4ft (above Mean Sea Level) _ _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:30 1.50 BOPSUR P DECOMP PU AND MAKE UP LANDING NT WITH 3-1/2" IF BY 3-1/2" NSTC X-OVER TO THE TUBING HANGER -PULL 11" FMC HANGER TO THE FLOOR AND lAY DOWN -PUW TO LIFT HANGER 80K. 12:30 - 15:00 2.50 BOPSUR P DECOMP CIRCULATE BOTTOMS UP: =SPR , 1-BPM @ 100 PSI. CIRCULATE BOTTOMS UP W/ 3 BPM @ 620 PSI -PUMPED TOTAL OF 325 BBLS DURING CIRCULATION. 15:00 - 23:30 8 50 BOPSUR P QECOMP pOH WITH2-7/8" ESP COMPLETION. , . STANDING BACK 2-7/8" EUE 8RD TBG IN 'DERRICK. -WELL WAS SWABBING SLIGHTLY IN BEGINING, SLOWED DOWN PULLING SPEED AND ALL SWABBING STOPPED -MAINTAINING SLOW TRIP SPEED TO AVOID SWABBING ;AVG 12-15 MIN PER STAND - -TRIP SHEET SHOWS THE WELL IS LOSING ~3 BPH OVER DISPLACEMENT 23:30 - 00:00 0.50 BOPSUR P DECOMP WELL CONTROL DRILL: (D1) KICK WHILE DRILLING -DRILL WHILE POOH WITH 2-7/8" ESP COMPLETION: -DRILLER CALLED OUT THE DRILL, DRILLER PULLED UP ONE FULL JOINT THE CREW CUT AND SECURED THE ESP CABLE. DRILLER CAME BACK DOWN IN THE SLIPS. THE CREW INTALLED THE OPEN TIW VALVE. DRILLER SIMULATED OPENING THE HCR VALVE AND CLOSING THE ANNUAR. -TIME ELAPESED TO SECURE THE WELL WAS 2 MIN 47 SEC. ** WE WERE ABLE TO TAKE ADVANTAGE OF A ESP CABLE REEL TO REEL CHANGE OUT. NORMALY WE WOULD CUT THE ESP CABLE DOWN IN THE SPOOLING UNIT. FOR THE DRILL WE WERE ACTUALLY ABLE TO GET A FEEL FOR HOW IT IS TO PULL AND CUT THE ESP CABLE TO SECURE THE WELL. AAR: -WE DISCUSSED THE DRILL, WHAT WENT WELL AND WHAT COULD WE HAVE DONE BETTER? -CREWS APPRECIATED THE VALUE OF BEING ABLE TO CUT THE ESP CABLE TO SECURE THE WELL, RATHER THAN JUST TALKING ABOUT AND SIMULATING IT. IT GAVE A BETTER UNDERSTANDING OF WHAT IT TAKES TO SECURE A WELL WHILE PULLING AN ESP COMPLETION. 8/1/2010 00:00 - 01:00 1.00 PULL P DECOMP RUN ESP CABLE DOWN TO THE SPOOLER. -CHANGE OUT SPOOLS 01:00 - 02:30 1.50 PULL P DECOMP CIRCULATE BOTTOMS UP -CIRCULATE 3 BPM AT 550-630 PSI. -CLEAN AND CLEAR RIG FLOOR Printed 8/26/2010 1:44:56PM .North America -ALASKA - BP • Page a of Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-0009E-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUS HING @45.4ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 06:00 3.50 PULL P DECOMP POH WITH ESP COMPLETION, STANDING BACK 2-7/8" EUE 8RD TBG IN DERRICK. -PULLING OUT VERY SLOWLY ,AVG 12-15 MIN PER STAND, FILLING EVERY FIVE STANDS -AVG LOSS RATE OVER DISPLACEMENT= ~ 2 BPH FOR EVERY 5 STANDS. 06:00 - 07:00 1.00 PULL P DECOMP PTSM: -CONVERSATION FOCUS AROUND WELL CONTROL WITH REGUARDS TO ESP CABLE iN THE.HOLE -ENVIRONMENTAL WALK AROUNDS. 07:00 - 22:00 15.00 PULL P DECOMP POH`WITH 2-7/8" ESP COMPLETION, STANDING BACK 2-7/8" EUE 8RD TBG IN DERRICK: =PULLING OUT VERY SLOWLY ,AVG 12-15 MIN PER STAND, FELLING-EVERY FIVE STANDS -AVG LOSS RATE ~ 3 BPH, -LD 3 SINGLES LD 2 GLM'S AND 4 PUP JNTS. -POH ON 113 STANDS AND THREE SINGLES -REPLACED TWO COLLARS AND ONE FULL JOINT OF 2-7/8" ,6.5# 8RD EUE -THREDS ON THE XN NIPPLE WERE GALLED ALONG WITH THE 6' PUP, WE REPLCED BOTH. THE XN WAS REPLACED WITH USED 2.25" LD. ,THE PUP WAS REPLACED WITH A NEW J NT. 22:00 - 00:00 2.00 PULL ` P DECOMP BREAK OUT AND lAY DOWN ESP BHA, CUP TYPE PACKER ANDS REENS TO THE PIPE SHED -DETACH ESP CABLE FROM MOTOR. -CENTRILIFT DISASSEMBLED ESP BHA SECTION BY SECTION INSPECTING EACH ASSY. CENTRILIFT REP WITNESSED SOME CORROSION AROUND THE GAS SEPERATOR PORT. -SPOOLED UP CABLE INTO CABLE SPOOLER. -RECOVERED 181 LASALLE CLAMPS, 3 FLAT GUARDS, 4 PROTECTOLIZERS -ESTABLISHED STATIC LOSS RATE AFTER PULLING CUP PACKERS. -(8) BPH STATIC LOSS RATE. RIG IS MAINTAINING CONTINUOUS HOLE FILL DURING COMPLETION ASSY BREAK DOWN. -MILNE PT WELLS GROUP CAME OUT AND REDRESSED THE GLM'S Printed 8/26/2010 1:44:56PM .North America -ALASKA - BP ~ Page 5 of y Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-0009E-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @45.4ft (above Mean Sea Level) __ _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/2/2010 00:00 - 01:00 1.00 PULL P DECOMP BREAK OUT AND LAY DOWN ESP BHA, CUP TYPE PACKER AND SCREENS TO THE PIPE SHED -DETACH ESP CABLE FROM MOTOR. -CENTRILIFT DISASSEMBLED ESP BHA SECTION BY SECTION INSPECTING EACH ASSY. CENTRILIFT REP WITNESSED SOME CORROSION AROUND THE GAS SEPARATOR 'PORT. " -SPOOLED UP CABLE INTO CABLE SPOOLER. -RECOVERED 181 LASALLE CLAMPS, 3 FLAT GUARDS; 4 PROTECTOLIZERS -ESTABLISHED STATIC LOSS RATE AFTER PULLING CUP PACKERS. -(8) BPH STATIC LOSS RATE. RIG IS MAINTAINING CONTINUOUS HOLE FILL DURING COMPLETION ASSY. -MtLNE PT WELLS GROUP CAME OUT AND REDRESSED THE GLM'S 01:00 - 05:00 4.00 CLEAN P RUNCMP CLEAN AND CLEAR RIG FLOOR. -REMOVE COMPLETIONS ASSEMPLIES FROM PIPE SHED. 'PREP RIG TO RUN ESP ASSEMBLY, CUP PACKER & SCRENS -BREAK AND LAY DOWN KELLY FOR INSPECTION -CONTINUOUS HOLE FILL FOR WELL - CONTROL MEASURES -NEW ESP SPOOL LOADED IN THE SPOOLER. -LOAD NEW ESP EQUIPMENT CUP PACKER ASSY AND SCREENS IN PIPE SHED. 05:00 - 08:30 3.50 RUNCOM P RUNCMP PU & MU ESP COMPLETION. -ESP COMPLETION ASSEMBLY DIRECTED BY CENTRILIFT REP 08:30 - 18:00 9.50 RUNCOM P RUNCMP RIH W/ ESP ON 2-7/8", 6.5# L-80, EUE 8RD PIPE. - RIH ON STANDS FROM THE DERRICK -CANNON CLAMPS ON FIRST 9 JNTS AND THEN EVERY OTHER JOINT. - FILL TUBING AND CHECK ESP CABLE EVERY 2000'. RIH WITH 60 STANDS ,CENTRILIFT MEG TESTING CABLE -TEST NOT CONCLUSIVE, TROUBLE SHOOTING, POSSIBLE BAD MEGGER TEST UNIT. - RE-RAN TEST WITH DIFFERENT TESTER. - BOTH TEST UNITS COMING UP WITH A BAD TEST, RELIEVING A BAD TEST FOR THE MOTOR TEMP READING. 18:00 - 18:30 0.50 RUNCMM N DEAL RUNCMP MILNE POINT WELLS MANAGMENT TEAM MADE THE DECISION TO POOH TO REPLACE SENSOR. - WSL CALLED RWO TEAM ENGINEER IN ANCHORAGE, CALLS WERE MADE TO THE RWO MAGAGMENT TEAM TO INFORM THEM OF THE CHANGE OF SCOPE. 18:30 - 21:30 3.00 RUNCOM N RUNCMP RIG CREW DOING PRE TOUR INSPECTIONS. - PREPING RIG FOR TOH WITH FAILED ESP CABLE AND ESP COMPLETION Printed 8/26/2010 1:44:56PM ~orth America -ALASKA - BP • Page s of y Operation Summary Report - - -__ Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-OOQ9F-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUS HING @45.4ft (above Mean Sea Level) _ __ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 22:00 0.50 RUNCOM N RUNCMP PJSM WITH CREW - MEETING DISCUSSION AROUND WELL CONTROL FOR TOH WITH NEW CUP PACKERS. -TRIPPING SPEEDS TO BE MONITORED CLOSELY FOR SWABBING ACCURATE TRIP SHEETS, VOLUMES OF STRAPS AND LOSSES TO BE CALLED OUT .CLEARLY. 22:00 - 23:30 1 50 RUNCOM N RUNCMP TaRTFn ~~ 1T nF THE HOLE W/THE ESP . COMPLETION ON 2-7/8",6.5# L-80 EUE TUBING - FIRST FIVE STANDS OUT OF THE HOLE , NO SWABBINGDETECTED. -LOSS RATE ~ 1 ~5 BBLS OVER DISPLACEMENT. ` - HAD TO SHUT DOWN TO TROUBEL SHOOT THE GERANAMO LINE. 23:30 - 00:00 0.50 RUNCOM N RUNCMP RIG EVACUATION DRILL: -TOUR PUSHER CALLED THE DRILL OVER THE'LOUD SPEAKER -DRILLER SIMULATED ACTIVATING THE ESP SWITCH, LOADER HAND BLOCKED THE . .ENTRANCE TO THE LOCATION. RIG HANDS MUSTERED AT THE ENTRANCE OF LOCATION DUE THE WIND THE ENTRANCE TO LOCATION WAS PREFERED OVER THE MECHANIC SHOP. - ROUGH NECK TRAINER GRABBED THE NABORS ROSTER & SIGHN IN SHEET TO VERIFY EVERYONE WAS ACCOUNTED FOR. AAR: - WAS FOUND THERE WAS SOME QUESTION TO WEITHER OUR NIGHT MECHANIC WAS ON THE ROSTER. ROUGH NECK TRAINER COULD NOT REMEMBER. -AFTER DOUBLE CHECKING THE ROSTER, IT WAS DISCOVERED THAT THE MECHANIC WAS ON THE ROSTER. -ACTION TO BE TAKEN, WSL OR TOOL PUSHER WILL ASSUME CONTROL OF ROSTERS AND SIGN IN SHEETS AND CALL OUT LOUD TO ENSURE ALL PERSONEL IS ACCOUNTED FOR. 8/3/2010 00:00 - 03:30 50 3 RUNCOM N RUNCMP (`ONTINtIE TOH WITH FAILED Fcp rani F nN . 2-7/8",6.5# L-80 TUBING FROM THE DERRICK - PULLING SLOWLY ,WATCHING CLOSELY FOR ANY SWABBING. NO SWABBING ACCURING. -AVG LOSS RATE ~ 2 BPM OVER DISPLACEMENT -TOH WITH 30 STNDS, NOTICED THE TRIP GETTING INCREASINGLY WET. -STOPPED TO PUMP A SLUG 03:30 - 04:00 0.50 RUNCOM N RUNCMP MIXED A 15 BBL SLUG WITH 5 SXS OF SALT. -PUMPED AT LESS THAN A BPM 1500 PSI. Printed 8/26/2010 1:44:56PM ~orth America -ALASKA - BP ~ Page ' of 9 Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-OOQ9F-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @45.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 06:00 2.00 RUNCOM N RUNCMP CONTINUE TOH WITH FAILED ESP CABLE ON 2-7/8",6.5# L-80 TUBING FROM THE DERRICK - PULLING SLOWLY ,WATCHING CLOSELY FOR ANY SWABBING. NO SWABBING ACCURING. -PULLED AN AVG OF _ 30' PER MIN -AVG LOSS RATE ~ 2 BPM ABOVE DISPLACEMENT -TOH' 60 STANDS TO THE TOP OF THE ESP PUMP. 06:00 - 08:30 2.50 RUNCOM N RUNCMP BREAK AND LAY DOWN ESP PUMP ASSEMBLY, SEAL ASSEMBLY AND MOTOR MOTOR.' -PULL OUT AND STAND BACK CUP PACKER ASSEMBLY AND 40' SCREEN ASSEMBLY - CENTRILIFT CHANGED OUT THE MOTOR AND SENSOR -CHANGE'OUT'SPOOLS IN SPOOLER. 08:30 - 10:30 2.00 RUNCOM N RUNCMP PJSM: FOR PICKING UP MOTOR AND PUMP ASSEMBLIES -PU MU ESP MOTOR AND PUMP ASSEMBLIES PER CENTRILIFT REP. 10:30 - 17:00 6.50 RUNCOM N RUNCMP RIH W/ ESP ON 2-7/8" 6.5# L-80, EUE 8RD - RIH ON STANDS FROM THE DERRICK -CANNON CLAMPS ON FIRST 9 JNTS AND THEN EVERY OTHER JOINT. - FILL TUBING AND CHECK ESP CABLE EVERY 2000'. RIH WITH 60 OF 342 STANDS BACK TO WHERE WE PULLED OUT FOR THE FAILED MOTOR SENSOR. 17:00 - 19:00 2.00 RUNCOM P RUNCMP RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING STANDS OUT OF DERRICK. - USING BEST O LIFE 2000 PIPE DOPE, TORQUING TUBING T02300 FT/LBS. - CHECKING CONDUCTIVITY AND PUMPING 10 BBLS DOWN TUBING EVERY 20 STANDS - RIH W/ 79 OF 342 JNTS OF 2-7/8", 6.5# L-80, EUE 8RD PIPE. -MAINTAINING CONT HOLE FILL DURING TRIP IN HOLE -AVG LOSS RATE - 3 BPH 19:00 - 23:00 4.00 RUNCOM P RUNCMP REEL TO REEL SPLICE. - FIELD SPLICE OPERATION PERFORMED BY CENTRILIFT REP. - CONT HOLE FILL WAS MAINTAINED FOR WELL CONTROL DURING SPLICE OPERATIONS 23:00 - 00:00 1.00 RUNCOM P RUNCMP WEEKLY HSE MEETING WITH CREW: -REVIEWED ADW WEEKLY HSE PUBLICATION -REVIEWED IADCE ALERTS -DISCUSSED UPCOMING SUMMER SHUT DOWN AND HOW WE WOULD IMPLIMENT OUR DROPPED OBJECTS MANAGMENT PROGRAM. Printed 8/26/2010 1:44:56PM North America -ALASKA - BP ~ Page 8 of 9 Operation Summary Report Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-OOQ9F-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY B_U_S_ H_ING @45.4ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/4/2010 00:00 - 03:30 3.50 RUNCOM P RUNCMP RIH W! 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING STANDS OUT OF DERRICK. - USING BEST O LIFE 2000 PIPE DOPE, TORQUING TUBING TO 2300 FT/LBS. - CHECKING CONDUCTIVITY AND PUMPING t0 BBLS DOWN TUBING EVERY 20 STANDS .MAINTAINING CONT HOLE FILL DURING TRIP IN HOLE - AVG_LOSS RATE ~ 3 BPH 04:00 - 04:30 0.50 RUNCOM P RUNCMP PJSM: -PICK UP AND MAKE UP TUBING HANGER , A DfNG J INT. -MU PENETRATOR IN TBG HANGER 04:30 - 05:30 1.00 RUNCOM P RUNCMP. CENTRILIFT -MAKE UP FIELD CONNECTION PENETRATOR SLICE. -CONDUCTIVITY TESTS -INSTALLBRASS SHIPPING CAP -LD ESP CABLE:THROUGH THE SHEAVE 05:30 - 06:30 1.00 RNTBHG P TUBHGR LAND TUBING HANGER AND 2-7/8" ESP COMPLETION. RUN IN LOCK DOWN SCREWS. -342 JOINTS OF 2-7/8" TUBING, MU TORQUE _ .2,300 FT-LBS. -PU WT = 72K LBS, SO WT = 45K LBS. - 189-LASALLE CLAMPS , 3- FLAT GUARDS , 5- PROTECTOLIZERS 06:30 - 09:00 2.50 RNTBHG P TUBHGR FMC REP SET TWC -FILL BOP STACK AND PRESSURE TEST TO 3,500 PSI -FOR 10 CHARTED MINUTES FROM ABOVE. -PERFORM A ROLLING TEST FROM BELOW TO 500 PSI - FOR 10 CHARTED MINUTES. (1.88 BPM). 09:00 - 13:00 4.00 BOPSUR P RUNCMP PJSM- FLUSH BOP STACK, BLOW DOWN LINES, SUCK-OUT STACK -REMOVE VBR AND BLIND SHEAR RAMS FROM BOP 13:00 - 22:00 9.00 BOPSUR P RUNCMP_. ._.. - - ND 13-5/8" BOP W/ (4) RAM CONFIG. -FINISH ND LOWER SINGLE GATE FROM MUD CROSS. -RU TO PICK ANNULAR, DOUBLE GATE, AND MUD CROSS. -ND LOWER SINGLE GATE FROM DSA AND REMOVE FROM CELLAR -ALL EOPT PREPED FOR TRANSPORT TO NABORS YARD FOR ANNUAL PM INSPECTION. -LAY DOWN RIG TONGS, HAND SLIPS AND OTHER RIG EQPT FOR INSPECTION AT TUBOSCOPE. 22:00 - 00:00 2 00 BOPSUR P RUNCMP NIPPLE UP A APTFR FI ANGE AND 3-1/8" . TREE. -ORIENT TREE, PER FMC REP 8/5/2010 00:00 - 02:00 2.00 WHSUR P WHDTRE NIPPLE UP ADAPTER FLANGE AND 3-1/8" TREE. -ORIENT TREE. -PRESSURE TEST HANGER VOID TO 5000 PSI FOR 30 CHARTED MIN BY FMC REP, GOOD TESTS Printed 8/26/2010 1:44:56PM ~orth America -ALASKA - BP ~ Page g of Operation Summary Report __ -_ ___ Common Well Name: MPF-25 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2010 End Date: 8/6/2010 X4-0009E-E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/29/2000 12:0O:OOAM Rig Release: 8/5/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY_B_US_ H_I_NG @45.4ft (above Mean Sea Level) _ _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 03:00 1.00 WHSUR P WHDTRE -TEST ADAPTER FLANGE AND TREE TO 5000 PSI WITH DIESEL FOR 5 CHARTED MIN - GOOD TEST. 03:00 - 05:00 2.00 WHSUR P WHDTRE PJSM: -RU LUBRICATOR AND TEST W/ DIESEL TO 500 PSI. -WELL SUPPORT TO PULL TWC AND INSTALL " BPV -TEST BPV FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES BY ROLLING THE PUMPS: -PUMPED AT 2-1/2 BPM @ 650 PSI. TOTAL PUMPED-23'BBLS 05:00 - 06:00 1.00 WHSUR P WHDTRE. -CENTRILIFT PERFORMED FINAL CHECKS. -6HP = 3347 PSI, MOTOR TEMP = 179 F, INTAKE TEMP= 181`F -4.O PHASE TO PHASE, 383MG PHASE TO GROUND. LAY-DOWN LUBRICATOR -SECURE WELL AND CELLAR ""` RIG RELEASED AT 06:00 "" Printed 8/26/2010 1:44:55PM STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~' AC1D Pertormed: Alter Casing ~ Pull Tubing~ Perforate New Pool ~ Waiver~ Time Extension~ TREATMENT Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory ^ 195-0160 / 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage,AK 99519-6612 50-029-22546-00-00 ~ 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-355018 ~/ MPF-25 / 10. Field/Pool(s): MILNE POIN7 FIELD / KUPARUK RIVER SANDS OIL POOL / 11. Present Well Condition Summary: Totai Depth measured 11502 ~ feet Plugs (measured) None feet true vertical .7-~~~ feet Junk (measured) None feet ~~~ ~~~~~~ Effective Depth measured 11333 feet Packer (measured) 10936' true vertical 7430 feet (true vertical) 7088' Casing Length Size MD ND Burst Collapse Structural Conductor 78 20" SURFACE - 110 SURFACE - 110 Surface 3375 9-5/8" 40# NT-80S SURFACE - 3406 SURFACE - 2975 5750 3090 Intermediate Production 11407 7" 26# NT-80S SURFACE - 11437 SURFACE - 7520 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 SURFACE - 10981' SURFACE - 7126' Packers and SSSV (type, measured and true vertical depth) 7" CUP PAKER 10936' 7088' 12. Stimulation or cement squeeze summary: Intenrals treated (measured): , ' y m _ `;~ ( t:~' r s, , , y ~ ~. , , Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 198 28 507 292 Subsequent to operation: 196 28 522 305 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl TiUe Data Management Engineer Signature Phone 564-4944 Date 9/14/2009 Form 10-404 R~sed 7/2009 ,,~ ~r~ ~~~~ ~~~ ,~ S~ ~ Submit Original Only ~ , f ~U., ~dl ~~~ ~fy~ . M PF-25 195-016 PERF ATTACHMENT n ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-25 4/17/95 PER 11,122. 11,134. 7,248.02 7,258.41 MPF-25 4/17/95 PER 11,140. 11,154. 7,263.6 7,275.73 MPF-25 4/17/95 PER 11,166. 11,204. 7,286.12 7,319. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PQCK, OPEN OH OPEN HOLE • . • MPF-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/10/2009jT/I/0=400/340/180 Acid Treatment Pumped 10 bbls crude, 19 bbls 10% DAD iAcid, 3 bbls 60/40 methanol, 38 bbls crude & 3.7 bbls 60/40 methanol down ~Tbg to displace Tbg. DSO notified swab wing ssv shut, master ia oa open. ; FWHP's=450/440/180 FLUIDS PUMPED BBLS 19 10% DAD ACID 6.7 60/40 METH 10 CRUDE 35.7 TOTAL STATE OF ALASKA ~ '~~ ~'i~ AL•CA OIL AND GAS CONSERVATION CO,,,„, ~~~" , ~' ;~~ KEPORT OF SUNDRY WELL OPERATION ~ 2009 /~ ~G~o9 1. Operations Performed: ' ~ ~ ~~ ~8S (15. COfT1fT1~SSItJ1't C~ ~~ ^ Abandon ®Repair Well ^ Plug Perforations 15L e ~O~h~~-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ®Other ,, ^ Change Approved Program ^ Operation Shutdown Change Out ESP & Install ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 195-016 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22546-00-00 - 7. KB Elevation (ft): 45 7' ~ 9. Well Name and Number: MPF-25 - 8. Property Designation: 10. Field /Pool(s): ADL 355018 - Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11502 -feet true vertical 7575 feet Plugs (measured) N/A Effective depth: measured 11333 feet Junk (measured) N/A true vertical 7430 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' t10' Surface 3375' 9-5/8" 3406' 2975' 5750 3090 Intermediate Production 11407' 7" 11437' 7520' 7240 5410 Liner Perforation Depth MD (ft): 11122' - 11204' Perforation Depth TVD (ft): 7248' - 7319' 2-7/8", 6.5# L-80 10981' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker 7", 26# Cup Packer Assembly 10936' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 105 11 40 250 269 Subsequent to operation: 242 28 99 300 239 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 1 W II Status after work: ® Well Schematic Diagram (Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Howard West, 564-5471 N/q Printed Name Sondra Stewman ~- Title Drilling Technologist ,, i nature ii Prepared ey Name/Number: Phone 564-4750 Date(~I 'Z[;~G~~ Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~j~ g~ ~ Submit Original Onty Tree; 3 1/8"" - 5M - Wellhead: 11" 5M FMC w/ 3.5" FMC Tubing Hanger ,EUE lift threads, 3" CIW H BPV profile 20", 91.1 ppf, 80' NT80LHE KOP Q 800' Max. Hole Angle = 60 to 62 deg. f/ 5200' - 9050' Hole angle thru' perfs = 30 deg. 9 5/8", 40#/ft, 3405' MD NT-80S Btrs. 2-7/8", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) 7" 26#, NT-80S NSCC Casing (cap. = 0.0383 bpf) (cap w/ 2 7/8" tubing inside = 0.02758) M P r X25 Orig. ~lev = 45.5' Orig. GL Elev. = 13.0' OKB to Base Flange. = 33.46' 7" x 21' casing marker joint - 10,753-10,774' wlm Stimulation Summary 80 M Lbs. 16-20 CL ISP 4/19/95 Kup "A" Sand -Screened out I Perforation Summary I REF LOG: 4/15/95 AWS GR/CCL ~~ Gun ~.SPF~ Interval ~ (TVD} I 3 3/8" 6 11,122'-11,134' (7247'-7258' 3 3/8" 6 11,140'-11,154' (7262'-7275' 3 3/8" 6 11,166'-11,204' (7285'-7318' EHD = 0.76", TTP = 6.4" mid-perf = 7284' tvd 11163' and DATE IREV. BY 1 COMMENTS 08 /19/96 MDO ESP RWO 4ES 07/02!00 JWS ESP RWO 4ES 03/09/05 Lee Hulme ESP RWO 4ES 11/13/07 Lee Hulme ESP RWO 4ES 12/31!08 Lee Hulme Replace ESP and install Pkr/Screens Nabors 3S Camco 2 7/8" x 1 " 141 ` KBMM GLM NOTE: 7" Casing Landed on Emergency slips Camco 2 7/8" x 1" 10,614' KBMM GLM 2-7(8" HES XN nipple 10729' ( 2.250" No-Go ID ) Discharge Head 10875' Centrilift Pumps 10876, 160-P11, SXD Gas Separator 10893' GRSFTX AR H6 Intake TVD 7051' Centrilift Tandem Seal Section GSB3DB UT/LT SB/SB PFSA 10898' Centrilift 562 series Motor 152 HP KMH 2345 V / 40 A 10912' PumpMate XTO Sensor w(6 ' Fin Centralizer 10926 Gauge TVD 7079' BOT Safety Shear Sub 10930' 2 7/8" Ported Tbg Jt. 10933' BOT 7" Cup Packer 10936' BOT Excluder Screen w/ 10940-81' bull plug -Fill cleaned out to 11,244' on 12/31/08 ORIG. PBTD 11,353' MD 7" 26#, NT-80S NSCC 1 437' MD MILNE POINT UNIT WELL F-25 API NO: 50-029-22546 BP EXPLORATION Start: 12/23/2008 Rig Release: 12/30/2008 Rig Number: BP AMOCO Operations Summary Report Legal Well Name: MPF-25 Common Well Name: MPF-25 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date !~ From - To Hours I, Task Code NPT 12/24/2008 115:00 - 00:00 9.00 MOB P 12/25/2008 00:00 - 20:30 20.50 MOB P 20:30 - 22:30 2.00 MOB P 22:30 - 00:00 1.50 MOB P 12!26/2008 00:00 - 01:30 1.50 MOB P 01:30 - 06:00 4.50 RIGU P 06:00 - 10:30 ~ 4.50 ~ RIGU ~ P 10:30 - 13:00 2.50 RIGU P 13:00 - 18:00 5.00 RIGU P 18:00 - 19:30 1.501 RIGU ~ P 19:30 - 21:30 2.00 W HSU R P 21:30 - 23:30 ~ 2.00 ~ KILL ~ P 23:30 - 00:00 I 0.50 I KILL I P 12/27/2008 100:00 - 01:30 1.501 KILL ~ P 01:30 - 02:30 ~ 1.00 ~ KILL ~ P 02:30 - 05:00 I 2.501 KILL I P Phase. `J Page 1 of 3 Spud Date: 6/29/2000 End: 12/30/2008 Description of Operations PRE Rig released ~ 12:00 from MPC-43. Prep for Rig move. C/O Kelly hoses on rig floor. Inspect Pit #2 for leaks. Wait for trucks. PRE Wait on trucks from Peak to be released after Doyon rig move. PRE Trucks on location. Move rig off well with pad-op witness. Move all rig modules to edge of pad and notifiy Milne Pt of rig move to F-25. PRE Move rig from C-pad to F-pad access road. PRE Move rig to F-pad. PRE Rig on location at 0130 hrs. Spot mats around well and lay herculite. Spot camp module and toolhouse. Spot carrier over well with pad-op witness. Jack up rig on mats, spot pipe shed !, and pits and jack up into position. PRE Rig not properly positioned. Call for PEAK Sow to return. Jack down modules, move and re-position Rig. PRE Connect all Rig modules. Raise and scope Derrick. PRE Work to identify and repair leak in pits. Fill pits and monitor for 1 hr to verify no leaks. Pits are not leaking. Call CH2 dispatch for 3 loads of SW. ""Ri acce ted at 18:00 hrs on 12-26-08"' PRE RU kill manifold to tree. RU Tiger Tank and downstream line. Connect all lines to pits and choke. Spot LRS on pit side next to upright tank. DECOMP RU lubricator and pressure test to 500 psi with diesel. Pull BPV. Shut in pressures: TBG = 320 psi, IA = 520 psi, OA = 250 psi. 1st vac truck on location at 21:00 hrs, take on fluid to pits. DECOMP RU LRS to kill manifold. Blow down lines with steam. Re-check hammer unions. Pressure test lines to 3000 psi, pressure test downstream line to Tiger tank to 500 psi. Blow down lines with air. Take on fluid from second vac truck to upright. DECOMP Conduct safety meeting with rig crews, LRS and vac truck drivers. Discuss kill procedure, egress and establish communication standards. Call Milne Pt. to notify gas venting in progress. DECOMP Bleed IA pressure thru choke from 520 psi to 40 psi. Bleed tubing pressure thru choke from 250 psi to 30 psi. Fluid weight in pits = 8.5 ppg / 100 degF. Break circulation down tubing taking returns thru choke to tiger tank at 1 BPM / 20 psi, returning all gas. Caught fluid 20 bbls into circulation. Circulate 65 bbls at 3.5 BPM / 880 psi, returned 21 bbls back to tiger tank. Tubing pressure fell to 0 psi. DECOMP Bullhead 21 bbls down tubing at 3 BPM / 1040 psi on final pump pressure. IA increased from 230 to 880 psi during bullhead. Monitor well for 15 min. Tubing went on vac and IA fell to 90 psi. Take on additional fluid in pits, 8.5 ppg / 100 degF. DECOMP Open well and break circulation down tubing taking returns thru choke to tiger tank at 1 BPM / 70 psi. Circulate 348 bbls at 3.5 BPM / 960 psi of 8.5 ppg / 100 degF until returns were 8.4+ and clean. Tubing on vac and 30 psi on IA. Monitor for 15 min and allow well to u-tube. Blow down lines to tiger tank. Well rnrnea: v~zuua n:iu:ioHm BP AMOCO Operations Summary Report Legal Well Name: MPF-25 Common Well Name: MPF-25 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date 12/27/2008 Start: 12/23/2008 Rig Release: 12/30/2008 Rig Number: From - To Hours Task Code NPT Phase. 02:30 - 05:00 2.50 KILL P 05:00 - 06:00 I 1.00 KILL ~ P 06:00 - 07:00 ~ 1.00 ~ WHSUR ~ P 07:00 - 09:00 2.00 ~ WHSUR ~ P 09:00 - 14:00 ~ 5.00 ~ BOPSUFj P 14:00 - 15:00 1.00 BOPSUF±P 15:00 - 16:30 1.50 BOPSU P 16:30 - 22:30 ~ 6.00 ~ BOPSUFj P 22:30 - 00:00 1.50 BOPSU P i 12/28/2008 00:00 - 01:00 1.00 BOPSU P 01:00 - 02:30 I 1.501 PULL I P 02:30 - 03:00 0.501 PULL ~ P 03:00 - 04:00 ~ 1.00 ~ PULL ~ P 04:00 - 06:00 ~ 2.00 ~ PULL ~ P 06:00 - 07:00 1.00 PULL P 07:00 - 08:00 1.00 PULL P 08:00 - 10:30 2.50 PULL P 10:30 - 18:00 7.50 PULL P Page 2 of 3 ~ Spud Date: 6/29/2000 End: 12/30/2008 Description of Operations DECOMP not static or on vac. Line up to circulate back to pits. Tota ui circ uateci on well kill = 417 bbls Total returns = 325 bbls Total losses = 92 bbls lost Burin circulation. DECOMP Circulate 50 bbls down the tubing at 3.5 BPM / 480 psi thru choke back to pits. Shut in well and monitor for 15 min. Tubing and IA on vac. Lost 7 bbls during circulation. Blow down lines. DECOMP Tb and IA on vacuum. D rod TWC. Test to 3500 si from above and chart for 10 minutes. RU LRS to IA, test lines to 2500 psi, bullhead 50 bbls in IA. DECOMP Bleed tubing hanger void. ND tree. Check top hanger threads with 3-1/2" NSCT XO - 7-1/2 turns. DECOMP NU 13-5/8" BOPE, with 2-7/8" x 5" VBR. Connect Koomey lines, choke and kill. Function test components. Full body test to 3500 si. Test all alarms and sensors. DECOMP Work on Koomey unit. Replace bad KR valves. DECOMP Call AOGCC for witness of Test. While waiting, RU shieve, elephant trunk and floor for pulling completion. DECOMP AOGCC rep Jeff Jones on location. Test BOPE 250 psi low / 3500 psi high. Test with 2-7/8" test joint. Complete Koomey draw down test. Test witnessed by BP WSL, NAD Toolpusher and AOGCC rep. Use LRS to gravity feed backside during test at 20 BPH. RD test equipment, blow down lines. DECOMP RU Opso-Lopso and lo-torque valve. MU polish rod and lubricator to Opso. Pressure test with diesel to 500 psi. Pull TWC. Monitor well. DECOMP Monitor and allow well to stabilize. Tubing and IA on vac. RD lubricator and Opso-Lopso. Clear rig floor. DECOMP PJSM. MU XO to landing joint, MU TIW valve and head pin. Screw into hanger, FMC rep BOLDS. Pull hanger off seat with 90K PUW. DECOMP Break circulation down tubing taking returns to pits to ensure no trapped gas. Circulate 70 bbls at 3 BPM / 530 psi. Crude on top then cleaned up thru circulation. Lost 8 bbls during circulation. DECOMP Pull hanger to floor. Disconnect ESP cable from hanger and cut tail above LaSalle clamp as per Centralift rep. Secure pig tail above clamp with 2 bands. LD landing joint and tubing hanger. DECOMP PJSM. RU to run 2-7/8" tubing. RIH from shed 1x1 from 10,840'. Circulate across the top while RIH. Loss rate = 10 BPH. Tag fill C~3 11,244' (40' of rathole). DECOMP aying own 14 singles used to tag fill. DECOMP RU to pull completion, get air slips. Tie ESP cable onto rope. Monitor well, out of balance. DECOMP MU single and band ESP cable. RIH to space out across stack. MU head pin and break circulation down tubing, circulate 400 bbls at 4 BPM / 950 psi. 34 bbls loss during circulation. Clean returns with out gas. DECOMP Shut down operations as per RWO Superintendent. Clean and maintenance rig. Pump across top of the hole, loss rate is 10 BPH. Prirnea: vsizuua 11:1tlab HM BP AMOCO Page 3 of 3 Operations Summary Report Legal Well Name: MPF-25 Common Well Name: MPF-25 Spud Date: 6/29/2000 Event Name: WORKOVER Start: 12/23/2008 End: 12/30/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/30/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code II, NPT I Phase '~ Description of Operations 12/28/2008 18:00 - 18:30 0.50 PULL P DECOMP Crew change. Check PVT, derrick inspection and walkaround. 18:30 - 00:00 5.50 PULL P DECOMP POH standing back ESP completion. Change spools after 3000' of cable spooled out of hole, continue POH. 12/29/2008 00:00 - 06:00 6.00 PULL P DECOMP Continue POH with 2-7/8" ESP com letion. Loss rate = 10 BPH. LD 8 bad jts between top and bottom GLM, took straps 06:00 - 06:30 0.50 PULL P 06:30 - 09:30 3.00 PULL P 09:30 - 12:30 3.00 PULL P 12:30 - 13:30 1.00 PULL P 13:30 - 14:00 0.50 PULL P 14:00 - 18:00 4.00 BUNCO 18:00 - 00:00 6.00 BUNCO 12/30/2008 00:00 - 04:00 4.00 BUNCO 04:00 - 08:00 4.00 BUNCO 08:00 - 08:30 0.50 BUNCO 08:30 - 11:30 3.00 BUNCO 11:30 - 12:30 12:30 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 19:30 19:30 - 22:30 22:30 - 00:00 1.00 BUNCO 2.00 BUNCO 0.50 BUNCO 1.00 RUNCOI~P 2.00 BOPSU P in pipe shed. DECOMP Service rig and perform daily inspections. DECOMP Continue POH with 2-7/8" ESP completion. Loss rate = 10 BPH. 339 joints Total. DECOMP Lay down ESP pump assy. No scale or sand found in ES_P. (177 LaSalle clamps, 6 protectolizers, and 3 flat guards recovered). DECOMP Clear and clean rig floor and swap equipment to run in hole. DECOMP Rig down elephant trunk and string rope through sheave. Redress GLM's in pipe shed. RUNCMP PU excluder screen, Baker cu aaker and ESP. MU as per Centralift rep. Tie in ESP cable from spooling unit. RUNCMP PJSM. RIH with 2-7/8" tubing as per tubing detail. Check conductivity every 2000', flush pump with 10 bbls at .5 BPM / 1000 psi. Loss rate = 6 BPH. RUNCMP Continue running 2-7/8" ESP completion as per tubing detail. Check conductivity every 2000', flush pump with 10 bbls at .5 BPM / 1000 psi. RUNCMP Centralift make cable splice. 118 stands in the hole at 04:00 hrs. Monitor well, static losses = 5 BPH. RUNCMP RIH to stand 120. Test cable while submerged in fluid. RUNCMP Continue running 2-7/8" ESP completion as per tubing detail 342 joints Total. Check conductivity every 2000', flush pump with 10 bbls at .5 BPM / 700 psi. Ran 179 La Salle clamps, 4 Protectolizers, and 3 flat guards. RUNCMP PUMU UJ and hanger install penetrator and orient. RUNCMP Make up penetrator pig tail. RUNCMP Land tubin han er and RILDS and torque to 450 ft. lbs. Back out UJ and lay down. RUNCMP D rod in TWC and test from above to 3500 si for 1 charted minutes. RUNCMP Drain stack and blow down lines. Bleed koomey and remove lines. 1.50 BOPSU P RUNCMP N/D BOPE and set in craddle. 3.00 BOPSU P RUNCMP N/U adapter flange and tree. Test adapter void to 5000 psi for 30 min. (Witnessed by WSL). Test tree to 5000 psi for 5 charted minutes. 1.50 BOPSU P RUNCMP P/U lubricator and test to 500 si. Pull TWC tubin on vac . Set BPV andclean pits. Normal up tree and cellar. R~ Printed: 1/5/2009 11:18:15 AM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMM ISSION BOPE Test Report Submit to: i~~n,r_e+~g_ ~~sf~:~_~z;>~% c~tSc.an f;C. E;3~~':3r'.I:~cl;' ~c,iclSlsci,t~t3+f Contractor: Nabors Rig No.: 3S DATE: 12/27/2008 Rig Rep.: R. Bjorhus/ E.Potter Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J. Menke/V.Volpe Field/Unit & Well No.: MP F-25 PTD # 1950160 Operation: Drlg: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind/Shear P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8-2 1/16" P Kill Line Valves 1 2 1/16" 5000 P Check Vaive 0 NA Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 FP Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2950 P Pressure After Closure 1700 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 43sec P Trip Tank P P Full Pressure Attained 3 min P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 2000psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 3 Test Time: 5.5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: "iW:.~ eg ~ ~i~s>ta.~ uv Remarks: Tested a ainst 2 wa check tested w!2 7/8" test 'nt. 1 Flan a leaked betweeen #7CV &HCR ti htened & passed R/T. 2) #12 CV failed, greased and worked & passed R/T. 3) Outer valve on test spool leaked, reased & assed R/T. 24 HOUR NOTICE GIVEN YES X NO Waived By Date 12/26!08 Time 11:30 hrs Witness Jeff Jones est start 16:30 hrs Finish 22:00 hrs BOP Test (for rigs) ~ ~,~.~-. f kt ~ ?~~ j BFL 11 /14/07 Nabors 3s BOP Test MP F-25 12-27-2008.x1s STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS _~e~~.~- io ao-d~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ .Stimulate Q Other ~ ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ - Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~'' ~ Exploratory 195-0160 ~ 3. Address: P.O. Box 196612 Stratigraphic '" Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-22546-00-00 7. KB Elevation (ft): 9. Well Name and Number: 45.7 KB MPF-25 ~ 8. Property Designation: 10. Field/Pool(s): ADLO-355018 ~ MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11502 ~ feet Plugs (measured) None true vertical 7575.42 feet Junk (measured) None Effective Depth measured 11333 - feet true vertical 7430 feet Casing Length Size MD TVD ,Burst Collapse Conductor 78' 20" 91.1# NT80LHE Surface - 80' Surface - 80' Surface 3375' 9-5/8" 40# NT-80S Surface - 6405' Surface - 2975' 5750 3090 7240 5410 Production 11407' 7" 26# NT-80S Surface - 1143 Surf ce - 7520' 7 ' a a ••.~,##~yy~~{' y ~ ~ r/~p~ ~ f j Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 10846' 0 0 - Packers and SSSV (type and measured depth) N/A 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 278 37 165 259 Subsequent to operation: 282 37 166 255 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development `' ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG GINJ ~ WINJ ~ WDSPL 17. 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 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/8/2008 Form 10-404 R ised 04/2006 ~' ~ ~~ Q~~ ~ ~OD~ Submit Original Only ~~~ MPF-25 195-016 PERF ATTACI-IMENT C7 Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-25 4/17/95 PER 11,122. 11,134. 7,248.02 7,258.41 MPF-25 4/17/95 PER 11,140. 11,154. 7,263.6 7,275.73 MPF-25 4/17/95 PER 11,166. 11,204. 7,286.12 7,319. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS _ _ SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE MPF-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY `` ACTIVITYDATE ~ SUMMARY 10/4/2008 T/I/0=300/300/220 Acid Treatment (ESP) -Pumped tbg w/20 bbls crude, 15 ', bbls 7.5% DAD acid, 4 bbls 60/40 methanol & 43 bbls crude for displacement. ', IA/OA, ssv & master open. Wing & swab closed. Turn well over to operator for .soak/ESP run. Final WHP's=350/400/220 FLUIDS PUMPED BBLS 63 CRUDE 4 60/40 METH 15 7.5% DAD ACID 82 TOTAL STATE OF ALASKA ~ • ALASKA OIL AND GAS CONSERVATION COM~SION R~~~C1'V ~LV~k`'.~r~ DEC ~ 7 REPORT OF SUNDRY WELL OPERATI~~a Oi[ & Gas Cons. Commission Anrhnr~na 1. Operations Performed: ^Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-016 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-22546-00-00 7. KB Elevation (ft): 45 7' 9. Well Name and Number: MPF-25 - 8. Property Designation: 10. Field /Pool(s): ADL 355018 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11502- feet true vertical 7575 • feet Plugs (measured) N/A Effective depth: measured 11333 feet Junk (measured) N/A true vertical 7430 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' Surface 3375' 9-5/8" 3406' 2975' 5750 3090 Intermediate Production 11407' 7" 11437' 7520' 7240 5410 Liner ~~;~ D E C ~. 3 2007 Perforation Depth MD (ft): 11122' - 11204' Perforation Depth TVD (ft): 7248' - 7319' 2-7/8", 6.5# L-80 10846' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 115 58 133 320 289 Subsequent to operation: 282 146 455 310 282 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations ell Status after work: ® Well Schematic Diagram Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: Sig ture Phone 564-4750 Date ~a-dfl~~ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 Submit Original Only S ~- I)E~.:~ ~. 2007 ~a < <~ Tree: 3 1 /8"" - 5M M P F -2 5 Orig. I~ev = 45.5' Wellhead: 11" 5M FMC Orig. GL Elev. = 13.0' w/ 3.5" FMC Tubing Hanger ,EUE OKB to Base Flange. = 33.46' lift threads, 3" CIW H BPV profile 20", 91.1 ppf, 80' NT80LHE KOP @ 800' Max. Hole Angle = 60 to 62 deg. f/ 5200' - 9050' Hole angle thru' perfs = 30 deg. 9 5/8", 40#/ft, 3405' MD NT-80S Btrs. 2-7/8", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) 7" 26#, NT-80S NSCC Casing (cap. = 0.0383 bpf) (cap w/ 2 7/8" tubing inside = 0.02758) 7" x 21' casing marker joint - 10,753-10,774' wlm Stimulation Summary 80 M Lbs. 16-20 CL ISP 4/19/95 Kup "A" Sand -Screened out Perforation Summary REF LOG: 4/15/95 AWS GR/CCL Gun PF Interval (TVD) 3 3/8" 6 11,122'-11,134' (7247'-7258' 3 3/8" 6 11,140'-11,154' (7262'-7275' 3 3/8" 6 11,166'-11,204' (7285'-7318' EHD = 0.76", TTP = 6.4" mid-pert = 7284' tvd 11163' and DATE ~2EV. BY I COMMENTS Camco 2 7/8" x 1" 139 KBMM GLM NOTE: 7" Casing Landed on Emergency slips Camco 2 7/8" x 1" 10,611' KBMM GLM 2.313" XN Nipple 10,726 (2.250 no-go ID) Discharge Head 10,779' Centrilift Tandem Pump ' 160P11 PSXD / 18P75 SXD 10,7$0 Centrilift Gas Separator 10 804' ~ GRSFTX AR H6 (400 INTERNALS) Centrilift Tandem Seal Sectio n 10 $09• GS63DB UT/LT PFSA/FSA CL5 , Motor KMH, Rerated to KME- 1 10 $23' 195 HP, 52 Amp, 2145 Volt , Phoenix XTO Sensor w/ $42' 10 6 fin centralizer , XTO Sensor = 7007' tvd /Fill cleaned out to 11,333' on 11 /5/95 ORIG. PBTD 11,353' MD - 7" 26#, NT-80S NSCC 11,437' MD ~ 07/02/00 I JWS 1 ESP RWO 4ES 1 03/09/05 I Lee Hulme I ESP RWO 4ES 11/13/07 Lee Hulme ESP RWO 4ES MILNE POINT UNIT WELL F-25 API NO: 50-029-22546 BP EXPLORATION ' • • BP AMOCO Page 1 of 3 Operations Summary Report Legal Well Name: MPF-25 Common Well Name: MPF-25 Spud Date: 6/29/2000 Event Name: WORKOVER Start: 11/7/2007 End: 11/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11!13/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/7/2007 12:00 - 15:00 3.00 RIGD P PRE PJSM Scope & lay down derrick, Rig down rig components 15:00 - 00:00 9.00 MOB P PRE PJSM Move Rig & all rig components from MPW-40i to MPF-pad 11/8/2007 00:00 - 07:00 7.00 MOB P PRE PJSM Contuine move rig from MPW -Pad to MPF -Pad 07:00 - 11:00 4.00 MOB P PRE PJSM R/U on MPF - 25, scope derrick, and R/U rig components. Rig accepted @ 11:00 hrs, 11/08/2007. 11:00 - 14:00 3.00 KILL P DECOMP PJSM. Take on heated seawater to pits. Spot Milne Pt tiger tank. Notice damaged line on tiger tank due to heavy valve hanging off it with no support. Assess damage, opt to get another tank. Rig up lubricator, pressure test lubricator, OK. _Pull BPV. SITP = 300 psi, SICP = 600 psi, OJA = 700 psi. 14:00 - 16:00 2.00 KILL P DECOMP Wait on tiger tank, prep for well kill. 16:00 - 17:00 1.00 KILL P DECOMP PJSM. Spot replacement tank, rig up lines, test lines to 3500 psi, OK. 17:00 - 17:30 0.50 KILL P DECOMP Pre kill safety meeting. Highlight placement of gas venting signs, notifying Milne Pt of intent to vent gas. Highlight spill prevention awareness and overall scope of the operation. 17:30 - 23:00 5.50 KILL P DECOMP Bled tubing pressure from 180 psi to 30 psi. Bled annulus pressure from 610 psi to 50 psi. Bled gas off tubing thru choke to tiger tank, shut in and lined up to pump down the tubing, taking returns up the l/A thru the choke and to the tiger tank. Pumped 62 bbls heated seawater down tubing 3-4 bpm, 900-1200 psi. Caught fluid at 7 bbls pumped. At 4 bpm, returns were 3.1 bpm per micro motion meter. Closed choke, attempted to bullhead down tubing at 1-1/2 bpm. Pressure increased to 2500 psi within 10 bbls. Bled tubing pressure, opened choke and circulated the long way a total of 532 bbls. OA pressure increased from 600 psi to 750 psi during circulation. Had seawater to surface at about 450 bbls pumped. Shut down oumo and mnnitnrarf wall• 4„hinn~ annulus pressures 0 psi Broke circ lin ink nnnn y~m_ 23:00 - 00:00 1.00 WHSUR P DECOMP Set TWC. RU to test TWC from above and below. Tested TWC from above to 3500 psi for 30 minutes. 11/9/2007 00:00 - 00:30 0.50 WHSUR P DECOMP Tested TWC from below to 1000 psi. RD and blew down lines. 00:30 - 02:00 1.50 WHSUR P DECOMP Bled void and ND tree. Checked lock down screws. 3-1/2" tubing hanger threads turned out to be NSCT rather than EUE. 02:00 - 04:30 2.50 BOPSU P DECOMP PJSM, NU BOPE. Serviced valves on mud cross. RU to test BOPE. 04:30 - 11:30 7.00 BOPSU P DECOMP Test BOPE to 250 osi low / 3500 osi high per BP and AOGCC requirements. BOPE test witness waived by C. Scheve, AOGCC @ 02:30 hrs 11/9/2007. 2-7/8" x 5" variable & blindshear rams in stack. 11:30 - 14:00 2.50 WHSUR P DECOMP PJSM MU & test lubicator @ 500 psi, pull TWC & RD same 14:00 - 16:00 2.00 WHSUR P DECOMP PJSM MU landing jt w/FOSV, screw into tbg hngr, BOLDS pull free 97K, up wt. 87K. Observe well. LD tbg hngr. Fluid level at tubing spool. 16:00 - 18:00 2.00 CLEAN P DECOMP PJSM. Secure ESP cable to tubing, RIH & tag fill (c~ 10.996'. G,~ f;~t tc.. LD 5 jts. Pulled sheave rope to floor. ~~~ 18:00 - 19:00 1.00 PULL P DECOMP Held crew change and performed pre-tour checks. Pulled ESP cable over sheave and attached to spooler. 19:00 - 20:30 1.50 PULL P DECOMP TOH and stood back 2-7/8" tubing. Added pipe displacement to well while TOH. Cable splice at stand #30. 20:30 - 21:30 1.00 PULL P DECOMP Cut ESP cable at splice and removed cable spool. Printed: 72/4/2007 8:40:04 AM • • BP AMOCO Page 2 of 3 Operations Summary Report Legal Well Name: MPF-25 Common Well Name: MPF-25 Spud Date: 6/29/2000 Event Name: WORKOVER Start: 11!7/2007 End: 11/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/13/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~i 11/9/2007 21:30 - 00:00 2.50 PULL P DECOMP Continued TOH and standing back 2-7/8" tubing. 78 stands out @ 00:00 hrs. Well fluid level stable. 11/10/2007 00:00 - 03:30 3.50 PULL P DECOMP Continued TOH, standing back 2-7/8" tubing. Added pipe displacement plus about 4 bbls seawater to fill well. 03:30 - 06:30 3.00 PULL P DECOMP LD ESP assembly. Components below 10' pup it on top of clamps, 3 flat guards, 6 protectalizers. 06:30 - 08:00 1.50 PULL P DECOMP PJSM. Service rig, clean & clear rig floor. 08:00 - 09:00 1.00 EVAL P DECOMP Remove flow-line nipple, NU shooting flange, RD E-trunk and string rope over sheave. 09:00 - 12:00 3.00 EVAL P DECOMP PJSM with all hands, spot E-line equip. RU USIT logging tools & lubricator to shooting flange and tested to 400 psi. 12:00 - 13:00 1.00 EVAL P DECOMP E-line RIH with USIT logging tool to 10980' WLM. E-line had power failure. POH for repair. 13:00 - 15:30 2.50 EVAL N DFAL DECOMP POH with USIT assembly. Had electrical short; reheaded tools. 15:30 - 18:00 2.50 EVAL P DECOMP RIH with USIT to 10,980' WLM. Logged up to 9950'. 18:00 - 20:30 2.50 EVAL P DECOMP Held crew change and performed pre-tour checks. POH with USIT. RD E-line service. 20:30 - 21:30 1.00 EVAL P DECOMP ND shooting flange. NU flow riser. 21:30 - 22:30 1.00 CLEAN P CLEAN RU to TIH with mule shoe on 2-7/8" tubing. installed wear ring. 22:30 - 00:00 1.50 CLEAN P CLEAN MU mule shoe assembly on 2-7/8" tubing. TIH from derrick to clean out fill 11/11/2007 00:00 - 04:00 4.00 CLEAN P CLEAN Continued TIH with mule shoe on 2-7/8 tubing. Running stands from derrick. Tagg_ed fill C1 1.0,960'. 04:00 - 05:00 1.00 CLEAN P CLEAN RU to circulate. Had gas in returns. Circulated oas out. Iona way 4 bpm, 720 psi. 05:00 - 14:00 9.00 CLEAN P CLEAN PJSM. Wash &Revc. from 10960' to (work spot @ 11016' ) Wash &Revc. from 11016' to 11047', pumped 50 bbl Hi-Vis sweep. Wash &Revc, f/ 11047' to 11110' pumped 37 bbl Hi-Vis sweep. Wash &Revc. f/ 11110' to hard spot Ca) 11245' NO O. Up wt. 72 K dn. wt. 35 K 4 bpm @ 600 - 760 psi Recover some Perf. junk with sweep) 14:00 - 16:00 2.00 CLEAN P CLEAN Pumped 40 bbl Hi-Vis sweep, revc. 5.5 bpm @ 800 psi and work pipe, till clean. 16:00 - 18:00 2.00 CLEAN P CLEAN Held PJSM. LD 19 work joints 2-7/8" tubing. TOH, standing back remainder of tubing. 18:00 - 22:00 4.00 CLEAN P CLEAN Held crew change and performed pre-tour checks. Continued TOH with 2-7/8" tubing. LD mule shoe. 22:00 - 00:00 2.00 RUNCO RUNCMP Held PJSM. Pulled wear ring. Cleared and cleaned rig floor. RU to run 2-7/8" ESP completion. 11/12/2007 00:00 - 03:30 3.50 RUNCO RUNCMP MU and serviced new ESP assembly. Pulled multi-lead extension over sheave. Plugged in to pump motor and tested. 03:30 - 06:00 2.50 RUNCO RUNCMP Attached 3 flat guards and 5 protectolators to 2-7/8" tubing. TIH with tubing from derrick and ESP ass'y. 17 stands in hole @ 05:30 hrs. 06:00 - 06:30 0.50 RUNCO RUNCMP PJSM Pre-tower checks & inspection, service rig. 06:30 - 10:30 4.00 RUNCO RUNCMP Con't TIH with 2-7/8 tbg. from derrick and ESP assb'y. Test cable & flush every 2000 ft. 10 spm @ 1700 - 1750 psi. 81 std in hole. 10:30 - 14:00 3.50 RUNCO RUNCMP PJSM. M/U ESP reel to reel splice, Flush pump 10 spm @ 1700 psi. 14:00 - 16:30 2.50 RUNCO RUNCMP PJSM. Continue in hole w/ 2 7/8" ESP completion string. Printed: 12/4/2007 8:40:04 AM $P AMOCO Page 3 of 3 Opell•atiolns Summary .Report Legal We{{ Name: MPF-25 Common Well Name: MPF-25 Spud Date: 6/29/2000 Event Name: WORKOVER Start: 11/7/2007 End: 11!13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/13/2007 Rig Name: NABORS 4ES Rig Number: Date I From - To I Hours I Task I Code I NPT Phase Description of Operations 11/12/2007 116:30 - 18:00 I 1.501 RU 18:00 - 20:00 2.00 RUNCO 20:00 - 21:00 1.00 RUNCO 21:00 - 22:00 1.00 WHSUR P 22:00 - 00:00 2.00 BOPSU P 11/13/2007 00:00 - 02:00 2.00 WHSUR P 02:00 - 06:00 4.00 WHSUR P RUNCMP PJSM. M/U landing joint & tubing hanger. Install penetrator. Up wt = 88K, down wt = 43K. Installed 178 La Salle clamps, 3 flat guards and 6 protectrolizers. RUNCMP Held crew change. Performed pre-tour checks. Attached field connector. Plugged in to penetrator and tested. RUNCMP Landed tubing hanger and RILDS. LD landing joint. RUNCMP Set TWC. Tested TWC from above to 1000 psi for 10 minutes. Tested from below to 800 psi. RUNCMP ND BOPE. RUNCMP NU tree. Tested tree and hanger void to 5000 psi. Performed final ESP check. RUNCMP RU lubricator and tested to 500 psi. Pulled TWC and set BPV. LD lubricator. Attempted to test BPV. Pumped 3 bpm @ 600 psi. Pumped 26 bbls. Secured tree and cellar. Released rig @ 06:00 hrs 11/13/2007. Printed: 12/4/2007 8:40:04 AM 11!21 /07 Schlumb~rg~r Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall Inh it ~'~.G`6D'C9yt~L~ IYQ N Kr ~ 207 :.... n..~~.:..a:.... NO. 4509 Company: State of Alaska Alaska Oil & Gas Cons Comm / tY~ Attn: Christine Mahnken (!~ `GJ 333 West 7th Ave, Suite 100 E/~y Anchorage, AK 99501 Field; P.Bay, Milne Pt., Endicott n.-a.. Z-10 11676974 GLS '"~,=° - "; ' 11/11/07 1 06-16 11686797 PPROF &RST "~ ~ __ ,~ `:r- s 11/15/07 1 MPL-33 11661179 MEM INJECTION PROFILE ;;7 r ~ ? p r.. - 11113!07 1 MPF-25 11846827 USIT / ~~ ~~ --,~. '°, !' 1:~, _ 11/10/07 1 GNI-04 11846828 USIT ~-,-i~a't"mot-,... ^; ° 1. 11111/07 1 OWDW-SW 11626128 RST j) z°~ ~~-.,"•,..~ - 10/10/07 1 1 3-351E-36 11630502 RST s ~':"..f. d ~ 'i_i'`; - ~ , ;, 09/09/07 1 1 15-266 11661165 MCNL ,.r r~ s '~ ~ i~ ~ ~ r~ fir'' 08/24/07 1 1 05-36A 10928638 MCNL i ~4 ~`~;"~ - rs'~t_ ~' > "~` ? '" I. ! ''"~ 06/11/05 1 1 07-16A 11216211 MCNL -' „3 - ~'-j-, '~y~ '-,a,~ 08/27/06 1 1 2-286/0-19 11638650 RST )~'4~ . s,~yt, `- ~-~"- `) ",`i 07/05/07 1 1 07-02A 11649983 MCNL ~! t ". O ~C`~ I~ - ~- , f) 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT ,-~~7 ! ,_P/7 ',! °-• , ~ #. ~ 09/11/07 2 1 rLLMJC Mlif~IYV YYLCUVC RCliGlrl or J1~71YInIV NIYU RCIUKn111VV Vnl t..UVYE~==5HGF1 IIJ: BP Exploration (Alaska) Inc. I, Petrotechnical Data Center LR2-1 ' 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~~(~~~ ~ ~ `~()s~! Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283; ATTN: Beth ~~ i ~ ~ ~ ; ~ %, Received bya ,Mx, /' ,,,, • ) STATE OF ALASKA -, ALASKA LJIL AND GAS CONSERVATION COh..JlISSIO~J::rEI\/ED REPORT OF SUNDRY WELL OPERATI~",' ,... ,,~~ APR 1 9 Z005 ,:\I 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program DI Repair Well 0 Plug Perforations DI Pull Tubing 0 Perforate New Pool o Operation Shutdown 0 Perforate " Çhª-nge gµh E~lJmmi.&iOQ o Stimulate A'..aka Ou ~~~~. I~J~~h' ., . . ..' . If a . . o Waiver Ime xtenslon o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6,612 45.7' 8. Property Designation: ADL 355018 4. Current Well Class: DI Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 195-016 6. API Number: 50-029-22546-00-00 9. Well Name and Number: M PF-25 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 11502 feet true vertical 7575 feet Plugs (measured) N/A Effective depth: measured 11333 feet Junk (measured) N/A true vertical 7430 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' Surface 3375' 9-5/8" 3406' 2975' 5750 3090 Intermediate Production 11407' 7" 11437' 7520' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 11122' - 11204' 7248' - 7319' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): c:¡ \~' 2005 SCANNED APR t! J .' ,'. 2-7/8" 6.5# L-80 10847' N/A Treatment description including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: 344 Subsequent to operation: 354 14. Attachments: 0 Copies of Logs and Surveys run DI Daily Report of Well Operations DI Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure 159 289 400 156 246 430 TubinQ Pressure 334 350 15. Well Class after proposed work: o Exploratory DI Development 0 Service 16. Well Status after proposed work: DI 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 ."--<'l /l/'~+M ," Slgnat!:lr~... ..)..('; \"t~ ((~?'\. ~:;v--v:....\,.J.f'./·v Form 10-404 Revised 04/2004"'--'" Title Technical Assistant Phone r' /"'¡, i '¡ I ç ~. Prepared By Name/Number: 564-4750 Date()":'" ~ 01)~ Sondra Stewman, 564-4750 ~Jjfti15 ~··I Ð~Wriginal Only -" ) MPF-25 Orig. þlev = 45.5' Orig. GL" Elev. = 13.0' OKB to Base Flange. = 33.46' Tree: 3 1/8"" - 5M Wellhead: 11" 5M FMC wi 3.5" FMC Tubing Hanger, EUE lift threads, 3" CIW H BPV profile 20", 91.1ppf, NT80LH E . 80' KOP @ 800' Max. Hole Angle = 60 to 62 deg. fl 5200' - 9050' Hole angle thru' perfs = 30 deg. 9 5/8", 40#/ft, NT-80S Btrs. 13405' MDI j 2-718", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) 7" 26#, NT-80S NSCC Casing (cap. = 0.0383 bpf) (cap wi 2718" tubing inside = 0.02758) 7" X 21' casing marker joint -% 10,753-10,774' wlm Stimulation Summary 80 M Lbs. 16-20 CL ISP 4/19/95 Kup "A" Sand - Screened out perforation Summary REF LOG: 4/15/95 AWS GR/CCL Gun SPF Interval 3 3/8" 6 11 ,122'-11 ,134' 3 3/8" 6 11 ,140'-11 ,154' 3 3/8" 6 11,166'-11,204' (TVD) (7247'-7258': (7262'-7275': (7285'-7318': EHD = 0.76", TIP = 6.4" mid-perf = 7284' tvd 11163' md DATE REV. BY COMMENTS 11/06/95 JBF =SP Completion by N 4ES 08 /1 9/96 MDO ESP RWO 4ES 07/02/00 JWS ESP RWO 4ES 03/09/05 Lee Hulme ESP RWO 4ES I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ,I ~ ~ ~ ~ ~ ~ ~ ~ ~li (1' i"':I· IU~'.;:;:l;;~' :;::,,:::::~ Cameo 2 7/8" x 1" KBMM GLM 1381 NOTE: 7" Casing Landed on Emergency slips t Cameo 2 7/8" x 1" KBMM GLM 2.313" XN Nipple (2.250 no-go 10) MS-1 Pressure Head MS-1 PSI Head = 6958' tvd Centrílift Tandem Pump 1 S9GC 1150 / 19GC8200 GPMTAR 1:1 Centrilift Gas Separator GRSFTX AR H6 (400 INTERNALS) 110,6111 I 110,7301 I 110,784' I 11Ò,785~ I 110,8091 I Centrílift Tandem Seal Section I 10 8141 GSB3DB UT/L.T AB/HSN F'/FSA CL5 ' Centríli'ft KMH 562 Series 171 HP, 44 Amp, 2390 Volt 110,8281 I 110,8431 I Phoenix MS-1 Sensor wi 6 fin centralizer MS-1 Sensor = 7008' tvd I / Fill cleaned out to 11 ,333' on 11/5/95 ~ - ORIG. PBTD 111,353' MD I -7" 26#, NT-80S NSCC 111 ,437' MD I MILNE POINT UNIT WELL F-25 API NO: 50-029-22546 BP EXPLORATION (AK) ) ) SÞAMQC:Q Oiperªtions ..SLlI11I'1'1ªryR~port PJSM. Scope down & layover derrick. Rig down rig components. PJSM. Begin moving rig components from MPF-54 to MPF-25. PJSM. Continue moving rig and rig components from MPF-54 to MPF-25. PJSM. Rig up on MPF-25. Raise & scope up derrick. Rig accepted @ 06:00 hrs. Take on heated seawater. Nipple up secondary annulus valve. Test lines, OK. Pull BPV. Tubing = 0 psi. I/A = 370 psi. PJSM. Commence pumping down tubing @ 4 bpm, catch fluid @ 6000'. II A bled to 0 psi in short order. Pump down tubing 2000 stks, (20 bbls). No returns while circulating down tbg. Line up & bullhead 350 bbls heated seawater down II A @ 5 bpm 111 00 psi. Monitor well, well dead. PJSM. Set two way check valve. Bleed void & nipple down tree. PJSM. N/U 13 5/8" x 5M BOPE. Install secondary annulus valve. PJSM. Conduct full BOPE test as per AOGCC & BP requirements. Witnessing of test waived by AOGCC rep John Crisp. Test witnessed by Nabors Toolpusher & BP Company Man. P/U lubricator Pull TWC. UD lubricator. M/U landing jt into hanger. BOLDS. Pull hanger to floor wI 90K P/U wt. Unplug connector. UD hanger & landing jt. POOH & stand back 2 7/8" tubing. Pulled 42 stands. Cut splice. Change out reels in spooling unit. Con't to POOH & stand back tubing. Con't to POOH & stand back tubing. pulled total of 113 stands. Drain, break out & UD ESP. Clear I clean rig floor. Lubricate rig. PJSM. Rig up to run ESP completion. Pick up & service pump assembly. Install Phoenix sensor & test, OK. PJSM. RIH w/2 7/8" ESP completion. Test ESP cable & pump (10 bbls @ 1 bpm I 800 psi every 2000', OK. PJSM. wi 80 stands in @ 7710', make reel to reel splice. Continue in hole testing cable & pumping down tubing every 2000', OK. PJSM. Pick up landing joint & make up hanger. PJSM. Make field connector splice, attach & test, OK. PJSM. 89K up wt, 40K down. Land hanger & RILDs. 450 ft/lbs torque on LDs. UD landing joint, set 2 way check valve. PJSM. NID BOPE. PJSM. N/U tree. Conduct final test on penetrator, OK. NOTE: Wellhead hand's truck broke down on the way to Milne. Phase III weather set in & he is camped out @ Nabors 7ES, waiting on weather. Unable to test tree at this time. WAIT RUNCMP Phase III weather for Milne called @ 06:24 hrs. Wait on weather. Phase II call1ed for main roads in Milne @ 13:25 hrs. Wait on wellhead hand to arrive & test tree. RUNCMP PJSM. Test tree & void to 5000 psi, OK. PJSM. P/U lubricator, pull two way check valve, set BPV. Secure well & release rig @ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-25 MPF-25 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES pate' From.; To Hours Task Code NPT : Phase 3/6/2005 20:00 - 23:00 3.00 RIGD P PRE 23:00 - 00:00 1.00 MOB P PRE 3n 12005 00:00 - 03:00 3.00 MOB P PRE 03:00 - 06:00 3.00 RIGU P PRE 06:00 - 08:00 2.00 KILL P DECOMP 08:00 - 09:00 1.00 KILL P DECOMP 09:00 - 10:30 1.50 KILL P DECOMP 10:30 - 11 :00 0.50 BOPSUPP DECOMP 11 :00 - 15:30 4.50 BOPSUP. P DECOMP 15:30 - 19:00 3.50 BOPSUP P DECOMP 3/8/2005 19:00 - 19:30 0.50 WHSUR P DECOMP 19:30 - 20:30 1.00 WHSUR P DECOMP 20:30 - 23:00 2.50 PULL P DECOMP 23:00 - 23:30 0.50 PULL P DECOMP 23:30 - 00:00 0.50 PULL P DECOMP 00:00 - 04:00 4.00 PULL P DECOMP 04:00 - 07:30 3.50 PULL P DECOMP 07:30 - 08:30 1.00 PULL P DECOMP 08:30 - 12:30 4.00 RUNCOMP RUNCMP 12:30 - 17:30 5.00 RUNCOMP RUNCMP 17:30 - 20:30 3.00 RUNCOrvP RUNCMP 20:30 - 23:00 2.50 RUNCOrvP RUNCMP 23:00 - 00:00 1.00 RUNCOMJ RUNCMP 00:00 - 01 :30 1.50 RUNCOrvP RUNCMP 01 :30 - 02:30 1.00 RUNCOrvP RUNCMP 02:30 - 04:00 1.50 BOPSUP. P RUNCMP 04:00 - 06:00 2.00 WHSUR P RUNCMP 3/9/2005 06:00 - 16:00 10.00 WHSUR N 16:00 - 18:00 2.00 WHSUR N Start: 3/7/2005 Rig Release: 3/9/2005 Rig Number: Spud Date: 6/29/2000 End: 3/9/2005 Desciiption:of Operations Printed: 3/14/2005 1 :42:50 PM ) ') BP ;AMOCO Operat... i. b..ns ...·.$u. m.\·,.:,:.. m...·.···.¡aryReP. ort· . .. . . . .. . .. . . . .. . . .. . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-25 MPF-25 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 3/9/2005 16:00 - 18:00 From-To Hours Task Code NPT 2.00 WHSUR N Date Start: 3/7/2005 Rig Release: 3/9/2005 Rig Number: RUNCMP 18:00 hrs, 03/09/2005. Spud Date: 6/29/2000 End: 3/9/2005 Description of Operations Printed: 3/14/2005 1 :42:50 PM ANNULAR INJECTION DATA ENTRY SCREEN ~ Asset Uilr~.e. .......................................... Legal Desc .I..8.§.7.'.[~.[,,..~.~.~.~.'.~,[,,..~.fLq..§,.T..1.:~,..E[.I.QE .................................... Research Rig Name ~.~b.~.r.~..;~.7.F,, ............................. · ................................................................................................................................................................................................................................ Inj Well Name M..P...F..-2..5. ..................................... Permit Start ........ .3J..1.0.~/.9.~ ........ Permit End ....... ].~.:~.1/~.5. ....... Sur Csg Dep :~.4..(}.,5. ................ · ............................................................. .............................................................. ~...., ~ ~:,,, Cumulative Data *Permit Expires in 30 Days or Less* ............ Rig completion Formation Intermittant Final Well Total Uud/Ctg Wash Fluids FlUids Freeze Freeze ......... ~.J~.~.7. .................. .9.,.3.~iZ .................... 25.0. .................................................................................. ~2~ ....................... ~.5. ............ · ' /.t~k~:~' ' --"'-',' . .. Daily Data Mud, Ctgs, Crrti I ~ Dated ~nated RigWash ~ F~ ,Freeze Freeze DaJy Amul~ ~>'¢"~'" ........... ~'~ ............ ~ I ..................................... 1 ........................................................................... / .......................................... ]~ ........................ ~--~ ............... ~'~ ............. 1'~ .............................. 1''~'~'~' ............ :; ............................. '1 ......................., ~1~'~--'-'1 ......................... ;~- .............................................................................. u..-~. I~~ ..I~ I ..1 ,1 -.1--1 ~"'~:~ ....................... i:~'-~'~ .................. 'i]'~'~'~' ...................................... I .......................................... ] ..................................... 't .................................. iiiiii, ii.I .................... 'i.;.L-.I ................................ ;.;i.1........... ~-~'~ ......................................................................................................................................................................................................... ....................... I'~''~'~'~'~'~ ................. .]'~ ........................................ '1 ............................................. ] ...................... ....................... i1 ...................................... ii;.ii']''~ .............................. ii'iii'iiiiiiii1 ........................................... "~'~'~ ..................................................................................................................................................................................................................................... I~'~'~:-~ ....................... 1'~'~ ................. ']'~'~'~' ....................................... I ............................................ '.] ...................... ~ ..................... '.1 ................ .................. 'i. ii.ii;.i1'"' ....................... iiiiiiiiiii, ii.I ...................................... ''''''~IIII,III'~'~'''''''": ......................................................................................................................................................................................................... ~i~""~ ...................... ~'~'~'~'~'~ .................. "]'~:"~"~ ................................ / .............................................. ""1 ................................................ '1 ...................................... ~'~.'~'~] ............... ~..."..~.`~...........~.~...~..~.~.~]....~............................~.........`..............~]..~..~.]..~................L.....`...- ........................................................................................................................................................... ~ .............................. ~~'~ ..................... 1''~'~'~'~ ................. ','~'~ ..................................... ~ .......................................... '~.~.] ............................................... 'I ................................ '~.'L1 ....................... ......'~.'.~.'~.'~] ........... ............. ....'~.)~ ~ ........................................................................................................................... ~ .................................................... ,, ~:~'~ ....................... ~..~.~.~.~.~........ ............ ~, ................................................................................................................................................................................................. ~..~ ......................................................................................... .~.~..~ .............................................................................................................................................................................................................................. -. ......................................................................................................... .1 ....................................................... J ............................................ ....J ................................................. .~ ...................................... .,,,,,,.,.,~ ................................... ,.,,,,.,,.,..,,1 .......................................... ,,,..1 MPF-25 01/02/96 ~335 12 347 MPF-25 ~/03/96 ~'~ ..................... 987 .................................................. MPF-25 01/04/96 /640 ~'-- 640 MPF-25 ~'~ ..... -~'~'~ ........................................ 260 MPF-25 01/06/96 175 5 180 .................................................................................................................................................... MPF-25 01/07/96 260 8 268 .......................................................................................................................................................................................................... MPF-25 01/08/96 70 10 80 ....................................................................................................................................................................................................................... ~ ............... , ............................................................................................................................................................... MPF-25 01/09/96 ~120 10 130 ....................................................................................................................................................................................................................................................................................................................................................................... ............... , .......................................... , ........................................................................................................................... MPF-25 01/10/96 75 10 85 .................................................................................................................................................................................................................................................................................................................................... , ................................ ~ .................................................................................................................. MPF-25 01/11/96 220 10 230 ~'~:~ ....................... ~"~"~'~'~'~ .................... ~'~ .......................................... ~ ................................................. ~ ................................................ ~ .......................................... ] ........................................... ] ....................................... '~'~'~ .............................. 1 .... ................... .................... ? .................................. .................................................. ................................................. ................... .......... .................................................. i ....................................... ................................. , ..................................................................................................................... ...................... .................................................. re. d rvloes 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 DEC 141998 Dear Ms. Mahan: Naska 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, 1-65/31-25, 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 & ~2, 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, 1542, 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- l/Q-20, -40/S-22 · Exploration well S~.u. rdoueh #3 - ~' o o ~ · - Miln ' ~ :- o ~. ~- '~ 8 ~s'. ils' / q4- i Lb · e Point wells F-06 ~ ' ' - · individual logs are provided to ~$~js~'~ ~_.~o~ -~,.~. , ~ S-33- ~-~o~ y xux these lOgS ~ Well. · 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 1998 Maska Oil & ~as Cons. Commissio,~ Anchorage ~ar(id SerVice Drilling ~nO~ar Injection Volumes ly 25, 1995 until December 1998 ~mulative Report Surface Casing ' Inj Well Depth Legal Desc licott on 15 1-19/I-18 5000 on 15 1-23/O- 15 4246 on 15 1-33/M-23 5013 Cum Total Cum Mud & Ctgs Cum Rig Wash Sec. 36, T12N, R16E 8,960 7,848 992 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 1,160 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 150 Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Fluids Fluids .F[eeze .. Freeze Start End Status 120 12/5/95 12/5/96 Open 200 120 9/30/95 12/31/95 Open 8/31/95 12/31/95 Broached on. 15 1-61/Q-20 4236 . 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open ; an.!5. ...... 2:.4..(?S72.? ....... 4..5~31 .............. ~0..2...0, F. _N L,..._2289.'..F'. E..~.,....S .e.c..~6, .T ! 2..N L R..] 6~E ............. 3.!_,..1....95 .......... 2..9.,.9.5_2. ................ !. ,.o_6~._3 ......................................................................... 1_2_o. ................ 60 7/25/95 12/31/95 'open ~ , ~n 14 15,47 3515 3648'NSL 4956'WEL Sec 22 T11N R14E 3 002 903 2 009 90 11/7/95 12/31/95 . Open ~ ....................................... ........'. ........................ .'. ...................... '. .,. .................................................................................................... ~ ............................................................................................................................................................................................................................................................................................................................................................................................ 3n 14 DS 15-45 3829' 4749' NSL, 5180' WEL, Sec. 22, T11N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached ~n 1'4 . . DS 15-48 . 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open )n 14 DS 15-49 3667 4676' NSL,. 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open )n 9 18-30 3930 '1499'SNL 26'WEL Sec 24 T11N R14E 2 266 936 380 800 150 7/25/95 12/31/95 Open )n 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R14E 6,086 2,250 1,100 2,565 171 7/26/95 12/31/95 Open )n 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,i00 150 8/24/95 12/31/95 Open )n 9 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open )rs 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open )rs 18E 12-36 3452 63'FSL 899'FEL Sec 18 T10N R15E 4 002 1 961 50 1,871 120 10/13/95 12/31/95 Open .'. ................................... : ............................. '. ................... .'. ........................................................................... '. ................................................. .'. ....................................................................................................................................................................... ............................................................................................................................... : ......................................................................................................................... !.~.s.....?.,E. ....................... !...3.:..3..6. ........................................ .3...4...3...! ................................. !..5.~.s..?.S..L.:_s_..!.~.7..'....W..E_.L.:..~.?..c..!.3_,.T_?_N_,_..R..!.4..~ ........................... .4..,.j...3..7.. ......................... ?,_5..2_3_ ................ .4_._6_4_ ............................................... !6_0__1_0.(.2_79_s_ ........ ~_~_3__1/~S_ ...... O_.p_e?.. .... !r.~.].._8.E. ..................... !.~:.!~ ................................... .~2.~ ................................. 2`.?.~...N.`s..L.~..1.-6.~..7.~...w..E...L.`~.....`s`.e?-..9-:.T1-~-N..~....R...~iE. .......................... ~i..9..7.~ ............................... .2..,...3...!_9- ................ 1,535 120 8/17/95 12/31/95 open oration 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed B ~ MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 . Open ,.?._2_~.E ................... M.~_C. z2...3 ........................... ..4..9..4...! ............................. !...0_3_8.._N..s_..L.,_ .2_4.0..4_ .w_ E_.L.,.....S_e_c._.! .0.,- I~N_ .................... _2_,0__6_0_ ..................... _1_,_8._0_0. ............. !37 ................................................................... 1_.30___.._1_/2_5!9_6_ ......... !_/.25/___~9.7_ ........... _o_p. e_~n ........ ,rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, RIOE 1,905 1,465 300 140 1/5/96 1/5/97 Open __ ,rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open ,rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 .DEC 1 4 t998 ;ha..r,,~d oervice DHIling ,nn~l'ar Injection Volumes uly 25, 199§ until December 1998 'umulative Report Sudace Casing g Inj Well Depth ibors 22E MPF-06 8766 ~bors 22E MPF-14 6690 ~bors 22E MPF-70 7919 ~bors 22E MPH-05 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze .... Ereeze Start . End S1atus Sec.?6~T13N, R10E ............. !.~9~.7. .... ~'73`.1 ' ............... !..96 !/25!96 1!25!97 OPer~ Se~.06,.T13N, R lOE. ~a ..... . ................. 1..8t~ !.~ .....17~ ?7 ..... !..'.._27 ~..0..' 6/3/96 ...... 6!3!? .... ~.~er~ ......... 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 . 190 56 6/17/96 6/17/97 Open 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open ~bors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R 10E 8,515 8,335 180 8/5/95 12/31/95 Open .bors 22E MPI-07 2680 2339'NSL 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 ' 70 9/21/95 12/31i95 .Open .bors 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 Open bors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 Open bors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 . 1/25/96 1/25/97 OPen bors 27E MpF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open bors 27E MPF-25 3405 1857'NSL, 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 225 65 12/26/95 12/26/96 Open bors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open bors 27E MPF-38 8561 1994'NSL, 2731'WEL Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 12/31/95 Open bors 27E MPF-45 6678 1979'NSL 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open bors 27E MPF-53 6750 2028'NSL 2572'WEL,.Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open bors 27E MPF-61 6585 2077'NSL, 526'WELl Sec 31,T14N R10E 5 732 5 657 75 8/31/95 12/31/95 Open ~3ors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open 3ors 27E MPF-78 7085 2237'NSL 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Opon ~ors 27E MPL-24 6515 3654'NSL 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31/95 Open )A : F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open ! ~:..3..~ ....................................... ..3`6..?.! .................................. 2..6..4...2.?..S.~...~?.E.....L.,....~.~?.~.~.!..?.~....~_?.~ .................................. ~.,..~.6....3.....i .......................... !..,?..9..~ .............................. ?.9_ ................... 3`~.~.7...!. !3..5.. ........... !??..~/9.~ ................. !.2~Ls..,/.~ ..................... ?.p.~.e..?. ~on 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open ~on 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96 4/10/97 Open ~on 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open , )ors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R 12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN Page 2 Shared Se'i~vice Dr..illing ~,nn'~i~'r injeCtion Volumes July 25, 1995, until December 1998 3umulative Report Surface Casing {ig Inj Well Depth labors 28E B-33 3504' labors 28E E-34 3664 ..... labors 28E E-36 3648 ,. labors 28E E-37 3810 labors 28E , labors 28E !ab~s,2,8,,,E~ ............... E-39 . , . Legal Desc 969'SNL, 1898'EWL, Sec 31,111 N, R 14E 3,974 2,842 857 168'SNL, 500'WEL, Sec 6,111N, R14E 9,656 7,228 1,420 858 1706'SNL, 822'WEL, Sec'6,T11N, R14E 9,271 4,417 1,293 3,096 3391 'NSL, 881 'WEL, Sec 6,111 N, R 14E 4,695 4,241 374 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End Status 195 80 5/1/96 12/31/96 Broached 40 110 8/23/95 12/31/95 Open' 365 100 7/25/95 12/31/95 Open 80 9/16/95 12/31/95 Open 80 8/28/95 ...... !2/3!!9,5 ............... ~,p.~? 3638 , 3358~NSL, 501'WEL, Sec 6,111N, R14E 2,250 , 928 220 1,022 G-O4A 3509 2917'NSL, 1974'WEL, Sec 12,111N, R13E 5,937 1 798 1,824 2,315 10/20/95 12/31/95 ' Open 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 labors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,112N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open abors 28E S-41 3331 4152' NSL 4504' WEL, Sec 35,112N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 Open abors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open 20 80 10/26/95 2/31/95 abors 2ES . H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, R13E 4,860 3,725 ,555 480 ' 1 Open abors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,111N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open Page 3 red TO: FROM: DATE: SUBJECT: Blair Wondzell Chris West October 27, 1995 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 MATE~4L tmO~ ~:n~s COV~ nAS ON. OR BEFORE P E A_ T E _ '--_ !AL UNDER TH 18 M ARK ER ~ .. STATE OF ALASKA ~_~ ALAStO L AND GAS CONSERVATION COM[ SION REPORT OF SUNDRY WELL OPERATION~ 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 45.7' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number MPF-25 1858' NSL, 2695' WEL, Sec. 06, T13N, R10E, UM 9. Permit Number/ Approval No. At top of productive interval 195-016 2737' NSL, 1844' WEL, Sec. 36, T14N, R09E, UM 10. APl Number At effective depth 50-029-22546-00 2830' NSL, 1901' WEL, Sec. 36, T14N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2904' NSL, 1945' WEL, Sec. 36, T14N, R09E, UM Sands 12. Present well condition summary Total depth: measured 11502 feet Plugs (measured) true vertical 7575 feet ~__? Effective depth: measured 11333 feet Junk (measured) "'~' ~ true vertical 7430 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arctic Set I (Approx.) 110' 110' Surface 3375' 9 5/8" 678 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 3406' 2975' Intermediate Production 11407' 7" 290 sx Class 'G' 11437' 7520' Liner ::"'.,', :':' :" ~:. "i '~'"' :.: ': ~".,:' :' "', ,->' ~..: .,: :~. . ..'> ..... Perforation depth: measured 11122'-11134', 11140'- 11154', 11166'- 11204' ' :" ~'-"' '-'-: "' ' ~ ~. ~'~ ;~ ¢!,'~,.-'.,' true vertical 7248'- 7258', 7264' - 7276', 7286' - 7319 .... ~ ...,':--., ....." ':-:!:::;.t:!'-,."t : ;" :. : ::-: ' ~:'~:',- · Tubing (size, grade, and measured depth) 2-7/8". 6.5#, L-80 to 10912' .~._..i~..i...~::~:~:;;:: · Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary ESP Replacement Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily ,~verage Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerdeHubble ~ ~ Title TechnicalAssistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate'~ Form 10-404 Rev. 06/15/88 operatiOns:SUmmary Report Page 1 of 1 Legal Well Name: MPF-25 Common Well Name: MPF-25 Event Name: WORKOVER Start: 6/29/2000 Contractor Name: NABORS Rig Release: 7/1/2000 Rig Name: NABORS 4ES Rig Number: ~i:: :Date: ~ :From ~ To: !~;Hours iActivityiCode~ ~Phase ~ ~ Description of Operations :: :: : : i :; : i : : i ;:;: { Spud Date: 6/29/2000 End: 7/1/2000 Group: RIG 6/29/2000 18:00 - 21:00 3.00: KILL DECOMP 6/30/2000 7/1/2000 21:00 - 23:30 2.50 KILL DECOMP 23:30 - 23:59 0.48, KILL DECOMP 00:00 - 00:30 0.50 WHSUR DECOMP 00:30 - 01:00 0.50 WHSUR DECOMP 01:00 - 02:00 1.00 BOPSUR DECOMP 02:00 - 03:30 1.50 BOPSUR DECOMP 03:30- 05:30 2.00 PULL DECOMP 05:30- 15:30 10.00 PULL DECOMP 15:30- 18:00 2.50 RIGU COMP 18:00 - 21:00 3.00 RIGU 21:00 - 23:59 2.98: RUNCOM 00:00 - 08:30 8.50 RUNCOM 08:30- 12:00 3.50 WHSUR. 12:00 - 13:30 1.50 BOPSUR 13:30- 16:00 2.50 WHSUR 16:00 - 19:00 3.00 CLEAN COMP COMP COMP COMP COMP COMP COMP Rig lines to tree from tiger tank through choke & test to 2500 psi. & rig lubricator & pull bpv. Circ. 8.5 PPg. sea h20 & remove influx from well bore. Monitor well bore pressure O set twc & test same. Nipple down tree. Nipple up bop's test bop to 250-1ow & 3500 high. (test waived by John Spaulding. MU landing joint & pul hanger to floor & lay dn same. Pull out of hole with esp completion & lay dn same. Make up esp and service same (Note: damage flat lead connector while attempt to pull over sheave. repair & re-install esp connector to flat lead. rih with esp completion. Rih with esp completion to 10911' MU HANGER & ALIN SAME & MAKE EFT CONNECTOR & TEST & INSTALL TO HANGER & LAND HANGER & RILDS. & SET TWC & TEST. NIPPLE DOWN BOP NU TREE & TEST TO 5000 PSI. & PULL TWC & SET BPV SECURE CELLAR AREA & CLEAN PITS OF OIL & SALT. Printed: 8/10/2000 11:17:19 AM STATE OF ALASKA ALASK/-~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1858' NSL, 2695' WEL, Sec. 6, T13N, R10E At top of productive interval 2747' NSL, 1845' WEL, Sec. 36, T14N, R9E At effective depth 2839' NSL, 1909' WEL, Sec. 36, T14N, R9E At total depth 2913' NSL, 1955' WEL, Sec. 36, T14N, R10E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE -- 47' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-25 9. Permit Number / Approval No. 95-16 10. APl Number 50- 029-22546 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 11502' feet true vertical 7578' feet Effective depth: measured 11333' feet true vertical 7433' feet Casing Length Size Structural Conductor 78' 20" Surface 3375' 9 5/8" Intermediate Production 11407' 7" Liner Plugs (measured) Junk (measured) ORIGINAL Cemented 250 sx Arctic Set I (Approx.) 678 sx PF 'E', 250 sx 'G', 250 sx 290 sx Class 'G' MD TVD 110' 110' 3460' 2761' 11437' 7574' Perforation depth: measured 11122'-1134', 11140'-11154', 11166'-11204' true vertical 7251'-7261', 7266'-7278',7288'-7321' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 10878' Packers and SSV (type and measured depth) None APR 2 0 t998 .~t311&Ga,~. C~mmis,)c,~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr 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 [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ,~~(~ ~ Title Engineering Supervisor Form 10-404 Rev. 06/15/88 Date Prepared By Name/Number: Mary Youngers 564-5242 Submit In Duplicate~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MP F-25 Rig Name: N-4ES AFE# 339022 Accept Date: 8/18/96 Spud Date: - Release Date: 8/19/96 AUGUST 18, 1996 RIG ACCEPTED @ 0600 HRS. MOVE IN, RIG UP, RAISE, LEVEL, BERM & SAFE OUT EQUIPMENT PREPARE TO TAKE ON SEA WATER & KL-WL. AUGUST 19, 1996 LOAD PITS W/8.4 PPG SEAWATER, NU TO TREE, TANK, TEST LINES TO 3000 PSI. PULL BPV, TBG = 310 PSI ANNULUS - 320 PSI. DISPLACE OIL & GAS IN WELL BORE W/8.4 PPG SEAWATER (SPOT 2 LCM PILLS & INSTALL TWC). ND TREE & NU BOP'S. TEST BOP'S TO 250 LOW & 5000 HIGH TEST WAIVED BY BOBBY FOSTER OF AOGCC PULL TWC & INSTALL LANDING JT & PULL HANGER TO FLOOR & CHECK POOH W/ESP COMPLETION. CHANGE OUT SPOOL IN SPOOLING UNIT @ 8500' CONT. TO POOH W/ESP COMP. TOH W/ESP COMPLETION & LD ESP EQUIP. RIG UP FLOOR & SPOOLING UNIT. PU & SERVICE ESP. RIN W/ESP ASSY. LOAD NEW SPOOL & SPLICE ESP LINE. CONT. TO RIH W/ESP ASSY. SPLICE ESP LINE @ HANGER. LAND TBG RILDS-LD LANDING JT SET TWC. ND BOP'S & NU TREE-TEST HANGER & TREE TO 5000 PSI. PULL TWC & SET BPV FREEZE PROTECT TBG & ANNULUS W/70 BBL DIESEL BLOW DOWN LINES & SECURE WELLHEAD & INSTALL BLIND FLG ON WING. RIG RELEASED @ 0600 HRS. Page 95 .... 0 'i 6 95--01iS 95-'016 95--'- 0 i 6 95--0 'i 6 G e o '1 o cj -¥ c ,s i i','i a t e r- ~' a 'J :: I n v ,:..s n 't o r' y DATA T DATA__F'LUS D G F,:/' C i'..l O/S L D ~ 'i 'i 9 ,~ i i S 0 jvi D D,SR/CNO/SL.D ~,~L 'i 19 ....7578 "F'VD · DGR/EWR/, ~ i '19--7 57 ~ T'VD DGF~/'EWE4. ~ ii9 .... i'i502 GR/'CCL FINAL ~ 'i0650-i 1 PF'C/'PERF ~'i0700 ..... i'i~0 7/4. i 'i ~ Ar"e dr'y Was the A r" e v,.,' e 'l 'l We '1 'i ::] O H H E i'q T S 10---4o? ~ COi'4PLETZC, i',~ DATE ~'1/' 6 /¢__/~,,... DAILY WELL C, PS R ~/"l~/'~j~" TO i'11."d~/'¢¢/" d~"t:ch samp'ies r'equ'i'r'ed2 yes (~__~And r'ece'¥ved? wei'i cor"ed? y e s ._.~______~'~ a 'i y s '¥ ::.~ &. d e s c r' '¥ p i: i' o n r' e c e "~ ~ Rec:e'¥ved? 0 !::t I I_1-- I IM G S ~::: I:t L/I r' ~ S WELL LOG TRANSMII~AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 September 03, 1996 RE: MWD Formation Evaluation Logs - MPF-25, AK-MM-950210 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 Dfi~g Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-25: 1 LDWG formatted LIS tape with verification listing. API~: 50-029-22546-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industr/es, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMP LETION 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 95-16 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5 o- 029-22546 4. Location of well at surface 9. Unit or Lease Name Unit 2747' NSL, 1854' WEL, SEC. 36, T14N, R9E i ~ .... 'i 11. Field and Pool At Total Depth~ Milne Point/Kuparuk Sands 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE = 47' I ADL 355018 12. Date Spudded 113. DateT. D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 02/20/95 03/06/95 11/06/95I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD)19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafros t 11502'MD/?578"I-VD 11533'MD/7433'TI/D ~ [] ~0 [] N/A feet MD 1800'(Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, CCL/~R 23. CASING, LINER AND CEMENTING RECORD SETRNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI-OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT8OLHE 32' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 3406' 12-1/4" 6z~ sx PF 'E', 250 sx 'G', 250 sx PF 'E' 7" 26# L-80 30' 11437' 8-1/2" 290 SX Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET/MD) PACKER SET (MD) 3-3/8" gun diameter, 6 spf 2- 7/8", L-80 10881' N/A MD TVD 11122'- 11134' 7251 '-7261' 26. ACID, FRACTURE, CEMENT SQ UFI=-/F, ETC. 11140'-11154' 7266'-7278' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11166'-11204' 7289'-7321' Freeze protect w/ 60 bbls diesel Fractured Kuparuk A w~ 154000# 16/20 carbolite 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 12/17/95 I ESP Date of Test Hours Tested =REDUCTION FOR !OIL-BBL GAS-MCF WATER-BBL CH OKESlZE IGAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ORIGINAL RECEIVED JUN 2 5 1996 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP F-25 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/18/95 12:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 27E WO/C RIG: NABORS 4ES 02/17/95 ( 1) MIRU TD: 0'( 0) 02/18/95 (2) TD: 0'( 0) 02/19/95 (3) TD: 0' ( 0) 02/20/95 (4) TD: 0' ( 0) 02/21/95 ( 5) TD: 1845' (1845) 02/22/95 (6) TD: 3425' (1580) MW: 0.0 VIS: 0 WAIT ON WEATHER T/SETTLE DOWN & THE ROADS T/CLEAR. EQUIPMENT ON @24:00 HRS. SET OUT PIPE SHEDS, PITS, GENERATOR MODULE. MOVING SUB OFF THE WELL @06:00 MIRU MW: 0.0 VIS: 0 L/D DERRICK. REMOVE BOARD. RAISE AND REPIN WINDWALLS. UNBRIDLE. UNSPOOL DRLG LINE. UNPIN DERRICK & LOAD ON TRUCKS. INSTALL FROG IN SUB. UNPIN GOOSE NECKS, MOVE IN & REPIN. MOVE SUB F/L-PAD TO F/PAD. MOVE & SPOT MTRS ON F-PAD. MOVE WHEELS OUT. REMOVE FROG. PIN DERRICK TO SUB. MIRU MW: 0.0 VIS: 0 PIN DERRICK TO SUB. BRIDLE UP. STRING DRLG LINE. INSTALL DERRICK BOARD. 'LOWER WIND WALLS. RAISE DERRICK. INSTALL SHUTE. SET SUB MATS. SPREAD HERCULITE. CPOT SUB & MTR COMPLEX. SET MUD PITS AND PIPE SHEDS. RIG UP FLOOR. HANG BRIDLE LINE IN DERRICK. RIG UP DERRICK. DRLG MW: 0.0 VIS: 0 PICK UP KELLY. MU STAND PIPE. PUT UP LINE GUIDE ROLLERS. IN STALL LIGHTS. SET 20" HYDRIL, PICK UP RISER, TAKE MEASUREMENTS, LAY BACK DOWN. TAKE TO WELDING SHOP AND ETEND 9" BETWEEN FLANGE AND FLOWLINE NIPPLE. HOOK UP DIVERTER LINE. FUNCTION TEST. OK. WAIVED BY DOUG AMOS. RIG UP MOUSE HOLE, BERM RIG. NIPPLE UP RISER & FLOW LINE. CLEAN UP. STRAP BHA. PICK UP MTR & MWD, ORIENT, FILL HOLE TEST BHA. TEST LINES. DRIL F/Il0-200'. DRILLING MW: 0.0 VIS: 0 DRILL F/200-1845'. SHORT TRIP TO 300. NO PROBLEMS. SLIDE & ROTATE F/1785-1845'. SHORT TRIP MW: 0.0 VIS: 0 DRILL F/1845-2984'. CHECK FOR FLOW. SHORT TRIP TO 1920' NO PROBLEMS. DRILL F/2984-3425'. CBU. PUMP PILL. CHECK FLOW. SHORT TRIP TO 1900' SLM. NO PROBLEMS. RECEIVED JUN 2 5 199f; Alaska Oil & Gas Cons Anchorage WELL : MP F-25 OPERATION: RIG : NABORS 27E PAGE: 2 02/23/95 (7) TD: 3425' ( 0) 02/24/95 (8) TD: 3425' ( 0) PREPARE FOR TOP JOB MW: 0.0 VIS: 0 CIRC LOW AND HIGH VISC SWEEP WHILE ROTATE AND RECIPROCATE. PUMP DRY JOB, SET BACK KELLY, FLOWCHECK WELL. OK. POOH. NO PROBLEMS. LD 8" BHA TO MWD. DOWNLOAD MWD. FINISH .D BHA. CLEAR FLOOR. RU TO RUN 9-5/8" CSG. PU LANDING JT AND ADD 6' PUP JT. LD SAME. RIH WITH 9-5/8" CSG. CSG WENT IN HOLE WITHOUT INCIDENT. CIRC AND COND HOLE FOR CMT. TEST LINES 3000 PSI. OK. PUMP 75 BBL FRESH WATER SPA~ER, FOLLOWED BY 262 BBL TYPE 'E' PERMAFROST CMT, FOLLOWED BY 51 BBL PREMIUM 'G' WITH 0.2% CFR-3+ 2.0% CACL2. DISPLACED CMT WITH RIG PUMPS AT 11 BPM. BUMP PLUG AT CALCULATED STROKES. PRESSURE UP TO 2000 PSI. AT 2000 PSI PRESSURE BREAK BACK TO 700 PSI. ATTEMPT TO BRING BACK TO 2000 PSI. ROLLING PUMP OVER INJECTING AWAY AT +-750 PSI. SHUT DOWN. ISOLATE SURFACE EQUIP. TEST TO 2000 PSI. OK. CHECK FLOATS. OK. HAVE PUMPED ADDITIONAL 15 STROKES SINCE BUMP PLUG. SHUT DOWN. DETERMINE EITHER PLUGS NOT HOLDING, LEAK IN CSG, OR RUNNING TOOL SEAL BLOWN. CONTACT DRLG SUPT. DISCUSS OPTIONS. DECIDE TO ND DIVERTER SYSTEM. ONCE CMT ROUNDED CORNER STEADY INCREASE IN PRESSURE. FULL RETURNS THROUGHOUT JOB. PLUG DID BUMP THOUGH DID NOT HOLD. FLOATS HELD. BACKOUT LANDING JT. SEAL RING HAD SMALL CUT WHICH DOES NOT APPEAR THAT IT WOULD HAVE BEEN ENOUGH. TO CAUSE PROBLEM. ND DIVERTER SYSTEM. RE-RUN LANDING JT/RUNNING TOOL. RUN SAME T~RU ROTARY TABLE AND MU INTO HANGER. FILL LANDING JT. PRESSURE UP ON SAlViE. PRESSURE UP TO 2000 PSI. HOLD SOLID. TEST CSG MW: 0.0 VIS: 0 HOLD 2000 PSI ON 9-5/8", 40#, L-80, BTC CSG. HOLD SOLID. BLEED OFF PRESSURE. BLOW DOWN MUD LINES. RIG DOWN CMT HEAD AND LJ. RU AND PERFORM TOP JOB. RIG DOWN HALLIBURTON CEMENTERS. MOVE SPEED HEAD INTO CELLAR. SET BACK 20" HYDRIL. INSTALL SPEED HEAD AND TEST TO 500 PSI. INSTALL TEST PLUG. CLEAR FLOOR OF CSG EQUIP. NU BOPE. LD FLOW NIPPLE AND WELD ON EXTENSION DUE TO STARTING HEAD SET 9" LOWER ON NEW PAD (PAD TO BE COMPACTED 9" THIS SUMMER). HOOK UP CHOKE LINE AND TURNBUCKLES. NIPPLE UP FLOW LINE. FULL BLOWN BOPE TEST (TEST FORM FAXED IN 24 FEB 95 0500 HRS). STATE WITNESSING WAIVED BY BOBBY FOSTER (AOGCC) 23 FEB 95. INSTALL WEAR FUSHING. STRAP, PU, AND MU BHA (1 HR TURBINE, 1 HR MWD). RIH W/HWDP AND DP. LD 4 SINGLES. FILL PIPE AND WASH TO FLOAT COLLAR. RU AND TEST 9-5/8", 40#, L-80, BTC CSG TO 3500 PSI F/30 MIN. GOOD TEST. BLEED OFF PRESSURE. WELL : MP F-25 OPERATION: RIG : NABORS 27E PAGE: 3 02/25/95 (9) TD: 4443' (1018) 02/26/95 (10) TD: 5121' ( 678) 02/27/95 (11) TD: 5438'( 317) 02/28/95 (12) TD: 7145' (1707) 03/01/9.5 ( 13) TD: 7253' ( 108) DRLG @ 4443' MD MW: 0.0 VIS: 0 BLEED OFF PRESSURE. CSG TEST TO 3500 PSI GOOD. DRILLOUT PLUGS AND FLOAT COLLAR (IT IS FELT THAT PLUGS FAILED DURING ORIGINAL CMT JOB. WAS NON ROTATING FLOAT EQUIP. SHOULD HAVE TAKEN 15 MIN TO 1 HR TO DRILLOUT. ONCE DRILLED OUT NO CMT BELOW COLLAR UNTIL APPROX 20' ABOVE SHOE WHICH MATCHES UP WITH OVERDISPLACED STROKES DURING JOB). HELD STRIPPING DRILL. GOOD DRILL. LEARNED-ALOT. DRILL REMAINING C~T, FLOAT SHOE, AND 10' OF NEW HOLE. PERFORM LEAKOFF TEST. DETERMINED 13.7 PPG EMW F/LEAKOFF PRESSURE. DIRECTIONAL DRLG TO 4379' MD. SHORT TRIP 12 STANDS. NO PROBLEMS. DIRECTIONAL DRLG F/4379-4443' MD. FROM 3425-4394' MD ART 2.71 HRS AST 2.36 HRS. POOH MW: 0.0 VIS: 0 DRLG FROM 4443-5121' ART 3.25 HRS, AST 3.5 HRS. BLOWDOWN/SETBACK KELLY. FLOWCHECK WELL. SHORT TRIP TO 4300' MD. RIH. NO PROBLEMS. CBU. RU ATLAS WL/GYRO DATA. WLIH AND RUN IN HOLE REFERENCE GYRO. RD ATLAS WL/GYRO DATA. PU/MU KELLY. ATTEMPT TO REAM BACK TO BOTTOM. COULD NOT GET PAST 5089' MD. SET BACK KELLY. BEGIN POOH. GET SVYS AT 4450' MD AND 4350' MD. CONTINUE POOH TO CHECK BIT, TURBINE AND REMAINING BHA. DRLG MW: 0.0 VIS: 0 CONTINUE POOH. DOWNLOAD MWD. LD BIT-TURBINE. PDC BIT RINGED OUT. MU NEW BIT AND 5/6STAGE F2000S DYNADRIL. UPLOAD MWD. RIH TO 4430' MD. PU KELLY AND CHECK SVYS AGAINST IN -HOLE REFERENCE GYRO. SET BACK KELLY. CONTINUE RIH. MAD PASS F/5078-5121' MD. DRL F/5121-5374'. MD. CIRC AND RECIPROCATE WHILE WORK ON HYDRAULIC PUMP. GENERATED 7.8 DEG DOGLEG. LD 6 JTS AND ATTEMPT TO REAM OUT SAME. NO CHANGE. LD DOWN 4 JTS. ORIENT AT 180 DEG AND REAM. NO CHANGE. (HAD BEEN SLIDING AT 0 DEG AND SVY EVERY 15' WHEN GENERATED DOGLEG. CIRC BEFORE POOH F/PDC BIT MW: 0.0 VIS: 0 DRILLING FROM 5438-6387'. DRILLING FROM 6387-7140 CIRC SWEEP AROUND BEFORE POOH F/PDC AND TURBINE. BIT #~: FROM 5121-7145' REPLACE KELLY HOSE MW: 0.0 VIS: 0 PUMP LO-HIGH VISC SWEEP AROUND. FLOWCHECK WELL 10 MIN. OK. PUMP DRY JOB. POOH TO MW/). DOWNLOAD SPERRY MWD & SOURCES. L/D BHA #3. CLEAR/CLEAN FLOOR. SAFETY MTG W/CO. REP, TOOLPUSHER, AND ALL PERSONNEL. DISCUSSED PERFORMANCE TO DATE, RECENT VEHICLE ACCIDENT AT MILNE POINT, MP BASE CAMP REQUIREMENTS. PU, MU BHA #4 (PDC BIT AND TURBINE). CHANGE OUT PULSER, LOAD NEW BATTERY PACK, UPLOAD SOURCES. RIH TO 4430' MD. TAKE BENCHMARK SVYS. OK. REPAIR IRONROUGHNECK. RECEIVED JUN 2 5 1996 Alaska Oil & Gas Cons. Oom~ml~um Anchorage WELL ' MP F-25 OPERATION: RIG : NABORS 27E PAGE: 4 03/02/95 (14) TD: 8295' (1042) 03/03/95 (15) TD: 9436' (1141) 03/04/95 (16) TD:10602' (1166) DRILLING MW: 0.0 VIS: 0 CHANGE OUT KELLY HOSE. CHANGE OUT FITTINGS ON KELLY GOOSENECK. WAIT ON NEW HOSE FROM 28E. WELD NIPPLE ON NEW HOSE. INSTALL NEW HOSE AND TEST. TRIP IN HOLE TO 7253'. DRILL F/ 7253 - 8138'. CHANGE OUT WASH PIPE ON SWIVEL. DRILL F/ 8138 - 8295'. DRILLING MW: 0.0 VIS: ~ DRILL F. 8295 - 9325'. 7 STAND SHORT TRIP WHILE MAKEING UP HOSES TO CIRCULATE WITH HEAD PIN WHILE WELDING UP SWEEP IN MUDLINE. PUMP SWEEP. CIRCULATE BOTTOMS UP. MONITOR WELL. SHORT TRIP TO 6275' DRILL F/ 9325 - 9436'. SLIDING DRIL F/ 9436 - 10602'. MW: 0.0 VIS: 0 03/05/95 (17) TD:10890' ( 288) 03/06/95 (18) TD:l1075' ( 185) 03/07/95 (19) TD:l1502' ( 427) 03/08/95 (20) TD:l1502' ( 0) TEST BOPE MW: 0.0 VIS: 0 DRLG F/ 10602 - 10890' PUMP SWEEP. CONDITION MUD. CHECK FOR FLOW. PUMP DRY JOB. SET BACK KELLY. POH TO MWD. CHECK FOR FLOW @ SHOE. DOWN LOAD MWD. STAND BACK BHA #4, LAY DOWN TURBINE. CLEAR FLOOR. PULL WEAR BUSHING. RIG UP AND TEST BOPE. DRILLING MW: 0.0 VIS: 0 TEST BOPE. PULL TEST PLUG. INSTALL WEAR BUSHING. REPAIR LEAK IN BLIND RAM HYDRAULIC LINE. MU BIT, NB STAB, NMDC. CHECK FLOAT. CHANGE BATTERY IN MWD. LOAD SOURCE, FINISH MU BHA. RIH TO 3350'. BOP DRILL, CUT AND SLIP LINE, ADJUST BRAKES. RIH TO 10842'. BREAK CIRC AND CHECK MOTOR @ 3350'. FILL @ 4481' AND 8247'. KELLY UP @ 10842' WASH TO 10890' DRILL F/ 10890 - 11075' SHORT TRIP MW: 0.0 VIS: 0 DRILL F/ 11075 - 11502' PUMP LO/HI VIS SWEEP. CONDITION MUD. MONITOR WELL. PUMP DRY JOB, SET BACK KELLY. SHORT TRIP TO 9 5/8" SHOE. MONITOR WELL @ SHOE. OK. RIH, NO PROBLEMS. RUN 7" CSG MW: 0.0 VIS: 0 RIH TO 113346. WASH F/11346-11502 NO PROBLEMS. PUMP SWEEP CIRC & COND MUD @0900 SHUT WELL IN NO BUILD UP.OPEN RAMS MONITOR WELL CIRC OUT AIRED UP MUD @ REDUCED RATE. CONTINUE TO CIRC & COND MUD. SAFETY MTG LAY DOWN DRILL PIPE & BHA. DOWNLOAD MWD. FINISH LAY DOWN BHA CLEAR FLOOR. PULL WB CHANGE RAMS TO 7" TEST BOPE. RIG UP TO RUN CSG. RUN 7" 26# L-80 CSG. RECEIVED JUN 2 S 199G Alaska Oil & Gas Cons. Commi$t~Jon ,Anchorage WELL : MP F-25 OPERATION: RIG : NABORS 27E PAGE: 5 03/09/95 (21) TD:l1502 PB: 7578 03/10/95 (22) TD:l1502 PB: 7578 03/11/95 (23) TD:l1502 PB: 7578 10/31/95 (24) TD:11437 PB:11353 DISPLACE CMT MW: 0.0 CIRCULATE 7". CIRC BOTTOMS UP @ 7175'. RUN 7" CSG, BREAK CIRC @ 225 JTS. BREAK CIRC @ 251 JTS, RUN 24 JTS 7". MU CIRC HEAD, CIRC DOWN # 276, 277 AND 20' PUP. MU HGR AND LDG JT. CSG STUCK. LAY DOWN LDG JT AND HGR. MU CIRC HEAD ON CSG, BREAK CIRC. WORK STUCK PIPE WHILE WAITING ON SOURCE WATER. PUMP 5 BBL H20, TEST LINES, PUMP 15 BBL H20, 100 BBL MUD LOST. CIRC UP TO START POURING CMT. PUM~ 80 SAX CLASS 'G', 15.8# CMT. RELEASE BTM PLUG, RELEASE TOP PLUG. SWITCH TO RIG PUMPS. DISPLACE W. 433.6 BBL SOURCE WATER. FREEZE PROTECT WELL MW: 0.0 DISPLACE CMT W/ SOURCE WATER. CHECK FLOATS. PRESSURE UP TO TEST CSG.. XO LEAKING, LAY DOWN CMT HEAD, MU SWAGS, TEST CSG, OK. BLOW DOWN LINES. LAY DOWN CSG TOOLS. CLEAR FLOOR. SERVICE ROTARY TABLE, DWKS, CHANGE OUT PIPE SPINNER. PUMP DOWN ANNULUS. BLEED OFF. PREP STACK TO PICK UP. NIPPLE DOWN STACK. PICK UP STACK. SET SLIPS. CUT OFF 7" CSG. MAKE FINAL CUT. INSTALL PACKOFF. NIPPLE UP STACK, TEST. LAY DOWN SPIDER, BREAK, CUT OFF OUT OF 20' PUP. RETRIEVE RBP. CHANGE RAMS TO 3 1/2". INSTALL WB. PICK UP 3 1/2" TO 2100' FREEZE PROTECT 7" TO-2100' RELEASE RIG MW: 0.0 NIPPLE UP MOUSE HOLE, LAY DOWN 69 JTS 3 1/2" DP IN MOUSEHOLE. WASH EA JOINT. PULL WEAR RING, CHANGE RAMS TO 5" NIPPLE DOWN FLOWLINE, MOUSEHOLE, RISER. NIPPLE DOWN BOPE STACK. NIPPLE UP ADAPTER SPOOL, MASTER VALVE AND TREE CAP. FILL W/ DIESEL. RELEASE RIG @ 1800 HRS ON 03/10/95. RIG MOVE MOVE IN, RIG UP. MW: 0.0 11/01/95 (25) TD:11437 PB:11353 RIH WITH TUBING MW: 0.0 SPOT & BERM RIG ON MPF-25. RAISE & SCOPE DERRICK. RIG ACCEPTED @ 1200 HRS., 10/31/95. ND XMAS TREE. NU BOP'S. BOLDS, PULL HANGER. INSTALL TEST PLUG & TEST BOP'S. LEAK ON TUBING FLANGE. ATTEMPTE TO TIGHTEN. DRAIN STACK, RAISE BOP, CHANGE API RING & NU. TEST BOPE. IWR. RU FLOOR, MU BAKER RETRIEVE TOOL & RIH WITH TUBING TO ICE @ 235'. CIRC THRU ICE F/235' T/300'. DISPLACE OUT DIESEL. RIH WITH 2-7/8" TUBING. RECEIVED JUN 2 5 1996 ~aska Oil & Gas Cons. Commission Anchorage WELL : MP F-25 OPERATION: RIG : NABORS 27E PAGE: 6 11/02/95 (26) TD:11437 PB:11353 11/03/95 (27) TD:11437 PB:11353 11/04/95 (28) TD:11437 PB:11353 11/05/95 (29) TD:11437 PB:t1353 11/06/95 (30) TD:11437 PB:11353 11/07/95 (31) TD:11437 PB:11353 RIH THRU ANNUL PREVENTER MW: 0.0 PU TUBING & RIH WITH SAME T/10805' WITH BAKER RETRIEVE TOOL. DISPLACE WELL WITH BRINE. TIH & CIRC TO BRIDGE PLUG @ 10941' & RELEASE SAME. CBU & MONITOR WELL. POOH T/1081' & CHECKED FOR CORRECT FILL. WELL FLOWING. SHUT WELL IN & MONITOR PRESSURES. ATTEMPT TO CIRC OIL & GAS INFLUX. RU & BEGIN TO STRIP TO BOTTOM. CIRC. % REV CIRC SAND F/7" CSG MW: 0.0 CIRC & DISPLACE CRUDE & GAS @ 4870'. TIH WITH 2-7/8" TUBING T/6385'. CIRC & DISPLACE CRUDE & GAS @ 6385' TIH T/10955' BUILD VOLUME WEIGHT & KILL WELL @ 10932'. MONITOR. POOH & LD BAKER RBP. MU BHA %2 & RIH T/10959'. TAG SAND. REV CIRC FRAC SAND FROM 7" CASING F/10959' T/10989'. PU 4-1/2" TBG FOR CLN-OUT MW: 0.0 REV FRAC SAND FROM 7" CASING F/10989' T/11147'. TOH T/957' & MONITOR WELL. CBU & MONITOR. TOH WITH 2-7/8" TUBING & LD BHA #2. PULL WR & SET TEST PLUG & CHANGE RAMS TO 4-1/2" & TEST. PU 4-1/2" TUBING. CUT & SLIP DRILL LINE. PU TUBING. LD 4-1/2" TUBING MW: 0.0 PU 4-1/2" TUBING T/11133'. REV CIRC & WASH SAND FROM 7" CASING F/11133' T/11309'. REV CIRC XANVIS SWEEP. REV CIRC & WASH F/11309' T/i1333' & REV CIRC XANVIS SWEEP. MONITOR. OK. CIRC LONG WAY. CIRC & FILTER BRINE. MONITOR. POOH T/il061'. CBU & FILTER BRINE. PULL TUBING. CHECK DISPLACEMENT & MONITOR WELL. OK. LD 4-1/2" TUBING. SPLICE CABLE @ HANGER MW: 0.0 LD TUBING. PULL WR & CHANGE RAMS IN BOP'S & TEST. RIG FLOOR TO RUN ESP ASSY & TEST. RIH WITH ESP ON 2-7/8" TUBING. REPAIR CENTRILIFT SPOOLING UNIT. CONT TIH WITH ESP. SPLICE ESP CABLE. CONT TIH WITH ESP. SPLICE ESP CABLE AT HANGER. RIG MOVE TO MPF-37 MW: 0.0 MAKE ESP LINE AT HANGER. LAND TUBING, RILDS & LD LANDING JT. SET TWC. ND BOP'S. NU TREE & TEST HANGER, ADAPTER FLANGE & TREE. PULL TWC & SET BPV. FREEZE PROTECT WELL DOWN TUBING & ANNULUS. RD FREEZE PROTECT LINES & SECURE WELL. RIG RELEASED @ 1500 HRS., 11/06/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED dUN 2 5 1996 Alaska Oil & Gas Cons. Commission SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/95 DATE OF SURVEY: 030695 MWD SURVEY JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -47.00 0 0 159 159.06 112.06 0 15 253 253.29 206.29 0 18 343 343.38 296.38 0 18 433 433.83 386.83 0 33 N .00 E .00 .00N .00E .00 N 41.38 W .16 .26N .23W .34 N 60.36 W .11 .54N .58W .77 N 71.11 W .06 .73N 1.01W 1.18 S 64.86 W .44 .62N 1.62W 1.44 522 522.69 475.69 616 616.60 569.60 705 705.35 658.35 795 795.26 748.26 883 883.74 836.74 0 37 0 48 0 55 1 21 1 52 N 75.27 W .45 .56N 2.48W 1.88 N 69.03 W .22 .93N 3.59W 2.82 N 68.12 W .13 1.42N 4.83W 3.93 N 69.33 W .49 2.07N 6.50W 5.42 N 49.22 W .86 3.38N 8.59W 7.69 974 974.66 927.66 1065 1064.80 1017.80 1158 1157.50 1110.50 1254 1252.89 1205.89 1349 1346.34 1299.34 3 7 4 24 6 18 8 20 9 25 N 34.10 W 1.53 6.41N ii.iOW 11.62 N 26.66 W 1.52 11.55N 14.04W 17.51 N 21.18 W 2.11 19.52N 17.50W 26.03 N 21.25 W 2.11 30.95N 21.93W 37.94 N 29.28 W 1.74 44.10N 28.21W 52.31 1443 1439.42 1392.42 1535 1528.79 1481.79 1632 1621.08 1574.08 1722 1707.44 1660.44 1819 1797.92 1750.92 12 0 15 57 16 55 19 6 21 26 N 36.04 W 3.02 58.85N 37.81W 69.89 N 35.30 W 4.29 76.94N 50.77W 92.15 N 35.27 W_ 1.01 99.18N 66.51W 119.39 N 34.18 W 2.43 122.27N 82.49W 147.48 N 31.94 W 2.55 150.30N 100.70W 180.88 1914 1886.30 1839.30 2009 1974.21 1927.21 2103 2058.70 2011.70 2199 2143.93 2096.93 2294 2225.48 2178.48 21 6 24 21 26 21 29 4 32 20 N 32.55 W .43 179.40N 119.05W 215.24 N 34.65 W 3.52 210.04N 139.46W 252.05 N 34.19 W 2.14 243.07N 162.09W 292.09 N 34.68 W 2.83 279.99N 187.41W 336.85 N 33.08 W 3.56 320.22N 214.39W 385.28 2389 2304.43 2257.43 2483 2379.62 2332.62 2577 2451.09 2404.09 2671 2518.96 2471.96 2764 2584.42 2537.42 35 4 38 59 42 33 44 35 45 38 N 33.38 W 2.88 364.29N 243.26W 437.94 N 33.71 W 4.16 411.57N 274.62W 494.65 N 33.69 W 3.78 462.84N 308.81W 556.27 N 33.31 W 2.19 516.71N 344.46W 620.84 N 33.60 W 1.14 571.55N 380.70W 686.55 2860 2650.16 2603.16 48 2 2955 2712.56 2665.56 50 7 3051 2772.24 2725.24 52 24 3144 2828.24 2781.24 53 38 3238 2883.24 2836.24 55 23 N 32.86 W 2.56 N 32.21 W 2.24 N 33.51 W 2.62 N 34.88 W 1.78 N 34.80 W 1.85 630 . 19N 419 . i0W 756 . 61 690 . 88N 457 . 81W 828 . 53 753 . 36N 498 . 19W 902 . 87 814 . 86N 539 . 98W 977 . 22 JUN 2 5 1996 Alaska 011 & Gas Cons, Commission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/95 DATE OF SURVEY: 030695 MWD SURVEY JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 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. 3333 2936.37 2889.37 3457 3005.24 2958.24 3552 3058.83 3011.83 3647 3113.07 3066.07 3741 3167.62 3120.62 56 34 N 35.00 W 1.27 942.75N 629.10W 55 45 N 35.67 W .81 1026.56N 688.52W 55 27 N 36.42 W .73 1089.84N 734.57W 55 3 N 36.14 W .48 1152.88N 780.84W 53 50 N 36.62 W 1.37 1214.33N 826.11W 1133.10 1235.84 1314.09 1392.27 1468.57 3835 3223.33 3176.33 3931 3279.91 3232.91 4024 3333.09 3286.09 4119 3385.63 3338.63 4214 3436.50 3389.50 53 9 N 36.72 W .74 1274.71N 871.07W 54 34 N 37.12 W 1.52 1336.65N 917.61W 56 5 N 36.51 W 1.71 1398.21N 963.68W 56 46 N 34.82 W 1.65 1462.54N 1009.84W 58 16 N 35.24 W 1.63 1528.00N 1055.73W 1543.81 1621.25 1698.09 1777.27 1857.21 4307 3484.96 3437.96 4401 3533.12 3486.12 4496 3581.87 3534.87 4593 3632.19 3585.19 4688 3683.74 3636.74 59 8 N 34.88 W .98 1593.26N 1101.53W 59 15 N 34.64 W .25 1659.64N 1147.60W 59 9 N 35.61 W .88 1726.55N 1194.66W 57 48 N 35.84 W 1.42 1793.18N 1242.59W 56 47 N 35.70 W 1.08 1858.32N 1289.52W 1936.94 2017.74 2099.54 2181.61 2261.89 4783 3734.28 3687.28 4877 3783.01 3736.01 4972 3833.24 3786.24 5069 3886.00 3839.00 5165 3938.92 3891.92 58 30 N 37.28 W 2.30 1922.46N 1336.97W 59 20 N 36.50 W 1.14 1987.15N 1385.52W 56 55 N 35.94 W 2.59 2052.34N 1433.28W 56 52 N 36.06 W .12 2117.82N 1480.85W 56 7 N 34.70 W 1.41 2183.00N 1527.14W 2341.64 2422.48 2503.28 2584.20 2664.14 5259 3987.21 3940.21 5354 4032.45 3985.45 5448 4078.20 4031.20 5543 4123.30 4076.30 5638 4168.48 4121.48 62 24 N 30.31 W 7.74 2251.50N 1570.67W 60 22 N 33.38 W 3.56 2321.95N 1614.40W 61 25 N 32.24 W 1.54 2391.04N 1658.94W 61 59 N 31.79 W .72 2462.09N 1703.36W 61 34 N 32.64 W .89 2533.33N 1748.25W 2745.22 2828.01 2910.16 2993.84 3077.94 5733 4213.53 4166.53 5829 4259.13 4212.13 5925 4305.09 4258.09 6020 4350.60 4303.60 6114 4395.87 4348.87 61 47 N 32.23 W .45 2603.93N 1793.11W 61 22 N 32.90 W .76 2674.96N 1838.47W 61 12 N 32.04 W .81 2745.74N 1883.52W 61 27 N 32.16 W .29 2816.26N 1927.76W 61 21 N 33.40 W 1.16 2886.10N 1972.73W 3161.50 3245.71 3329.53 3412.68 3495.68 6209 4441.08 4394.08 6303 4485.52 4438.52 6398 4530.39 4483.39 6493 4574.98 4527.98 6588 4620.06 4573.06 61 42 N 32.81 W .66 2955.94N 61 45 N 32.40 W .39 3025.58N 61 59 N 33.44 W .99 3096.04N 61 56 N 32.82 W .58 3166.17N 61 30 N 32.14 W .78 3236.85N 2018.27W 3579.01 2062.81W 3661.60 2108.43W 3745.49 2154.19W 3829.19 JUN 2 $ 1996 Alaska 011 & Gas Cons. Commission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/9 DATE OF SURVEY: 030695 MWD SURVEY JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6682 4664.96 4617.96 6777 4710.71 4663.71 6871 4757.21 4710.21 6966 4804.27 4757.27 7060 4851.64 4804.64 61 23 N 30.62 W 1.43 3307.28N 2242.15W 60 43 N 31.44 W 1.04 3378.16N 2284.79W 60 8 N 33.45 W 1.95 3447.32N 2328.75W 60 16 N 32.84 W .58 3516.14N 2373.69W 59 41 N 33.05 W .65 3584.96N 2418.28W 3995.23 4077.75 4159.62 4241.77 4323.72 7154 4898.67 4851.67 7247 4945 . 95 4898 . 95 7342 4994.23 4947.23 7437 5042 . 06 4995 . 06 7533 5089.85 5042.85 59 36 N 33.23 W .19 3652.22N 2462.20W 59 31 N 33.80 W .53 3719.32N 2506.63W 59 34 N 34.44 W .58 3787.32N 2552.71W 59 56 N 33.34 W 1.07 3855.44N 2598.46W 60 12 N 32.92 W .47 3924.95N 2643.83W 4404.00 4484.46 4566.59 4648.64 4731.60 7627 5136.43 5089.43 7722 5183.47 5136.47 7817 5230.10 5183.10 7910 5276.00 5229.00 8003 5322.04 5275.04 60 18 N 33.57 W .61 3993.12N 2688.52W 60 25 N 32.92 W .61 4062.28N 2733.85W 60 44 N 30.40 W 2.33 4132.67N 2777.25W 60 20 N 32.75 W 2.23 4201.89N 2819.79W 60 18 N 35.72 W 2.78 4268.68N 2865.24W 4813.07 4895.73 4978.28 5059.39 5140.17 8098 5368.69 5321.69 8193 5415.28 5368.28 8289 5461.68 5414.68 8384 5507.29 5460.29 8480 5553.92 5506.92 60 41 N 35.38 W .51 4335.77N 2913.19W 60 54 N 36.33 W .90 4403.33N 2962.01W 61 7 N 34.96 W 1.27 4471.41N 3010.83W 61 17 N 34.20 W .72 4539.74N 3057.93W 60 46 N 36.34 W 2.02 4608.52N 3106.57W 5222.63 5305.97 5389.73 5472.73 5556.97 8575 5600.33 5553.33 8669 5647.21 5600.21 8765 5694.16 5647.16 8860 5741.26 5694.26 8954 5787.96 5740.96 60 20 N 37.06 W .81 4674.45N 3155.71W 60 20 N 37.57 W .47 4739.94N 3205.63W 60 30 N 38.17 W .57 4805.23N 3256.40W 60 31 N 39.00 W .76 4870.35N 3308.36W 60 0 N 37.84 W 1.21 4934.41N 3359.17W 5639.16 5721.44 5804.04 5887.18 5968.80 9050 5835.71 5788.71 9144 5883.63 5836.63 9238 5931.61 5884.61 9334 5980.40 5933.40 9430 6030.01 5983.01 59 48 N 38.47 W .61 4999.18N 3410.06W 59 8 N 39.84 W 1.44 5062.20N 3461.37W 59 31 'N 39.82 W .41 5124.33N 3513.19W 59 20 N 37.89 W 1.74 5188.66N 3565.02W 58 16 N 39.03 W 1.51 5252.84N 3615.99W 6051.05 6132.10 6212.71 6295.14 6376.94 9525 6081.29 6034.29 9619 6133.75 6086.75 9715 6189.54 6142.54 9810 6247.26 6200.26 9905 6306.89 6259.89 56 35 N 40.01 W 1.97 5314.78N 3667.08W 55 13 N 38.50 W 1.98 5374.78N 3716.12W 53 35 N 37.96 W 1.75 5436.01N 3764.36W 52 18 N 36.86 W 1.63 5496.75N 3810.82W 49 58 N 37.47 W 2.51 5555.73N 3855.52W RECEIV 6456.98 6534.25 6612.08 6688.48 6762.44 £D JUN 2 5 1996 Alaska Oil & ~as Cons. Comm~sslor~ Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/9 DATE OF SURVEY: 030695 MWD SURVEY JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10000 6368.97 6321.97 47 55 N 36.91 W 2.21 5612.50N 3898.61W 6833.65 10095 6433.98 6386.98 46 16 N 35.85 W 1.90 5668.82N 3940.11W 6903.59 10191 6500.36 6453.36 45 10 N 35.27 W 1.25 5724.20N 3979.70W 6971.66 10285 6567.99 6520.99 43 40 N 35.50 W 1.59 5778.24N 4018.08W 7037.94 10379 6637.39 6590.39 41 18 N 35.93 W 2.53 5829.86N 4055.19W 7101.51 10473 6709.12 6662.12 39 15 N 36.42 W 2.22 5878.93N 4091.06W 7162.28 10567 6782.46 6735.46 36 49 N 36.68 W 2.60 5925.03N 4125.23W 7219.64 10663 6859.98 6812.98 35 21 N 35.02 W 1.84 5970.82N 4158.34W 7276.15 10756 6937.62 6890.62 32 57 N 35.97 W 2.63 6013.71N 4188.91W 7328.81 10856 7021.51 6974.51 31 42 N 33.29 W 1.91 6057.38N 4219.10W 7381.90 10949 7101.32 7054.32 30 41 N 34.84 W 1.39 6097.42N 4246.16W 7430.22 11042 7181.22 7134.22 30 24 N 32.52 W 1.31 6136.66N 4272.31W 7477.36 11137 7263.80 7216.80 29 57 N 31.91 W .57 6177.29N 4297.92W 7525.33 11233 7346.26 7299.26 30 12 N 31.23 W .44 6217.99N 4322.93W 7573.02 11327 7427.98 7380.98 30 47 N 32.75 W 1.02 6258.82N 4348.43W 7621.10 11411 7499.82 7452.82 30 46 N 30.26 W 1.52 6295.30N 4370.79W 7663.81 11502 7577.55 7530.55 30 46 N 30.26 W .00 6335.28N 4394.12W 7709.93 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7710.00 FEET AT NORTH 34 DEG. 44 MIN. WEST AT MD = 11502 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 325.02 DEG. RECEIVED SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/95 DATE OF SURVEY: 030695 JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 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 -47.00 .00 N .00 E .00 1000 999.79 952.79 7.54 N 11.87 W .21 2000 1965.42 1918.42 206.79 N 137.23 W 34.58 3000 2740.97 2693.97 719.65 N 475.94 W 259.03 4000 3319.39 3272.39 1381.83 N 951.56 W 680.61 .21 34.36 224.46 421.58 5000 3848.13 3801.13 2070.86 N 1446.70 W 1151.87 6000 4340.87 4293.87 2801.12 N 1918.23 W 1659.13 7000 4820.99 4773.99 3540.75 N 2389.57 W 2179.01 8000 5320.18 5273.18 4266.04 N 2863.35 W 2679.82 9000 5810.51 5763.51 4965.25 N 3383.13 W 3189.49 471.26 507.26 519.89 500.80 509.67 10000 6368.67 6321.67 5612.24 N 3898.41 W 3631.33 11000 7144.80 7097.80 6118.63 N 4260.82 W 3855.20 11502 7577.55 7530.55 6335.28 N 4394.12 W 3924.45 441.84 223.87 69.25 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RECEIVED SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/95 DATE OF SURVEY: 030695 JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 OPERATOR: BP EXPLORATION FT. 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 -47.00 47 47.00 .00 147 147.00 100.00 247 247.00 200.00 347 347.00 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .22 N .19 W .00 .00 .52 N .55 W .00 .00 .74 N 1.03 W .00 .00 447 447.00 400.00 547 547.00 500.00 647 647.00 600.00 747 747 . 00 700 . 00 847 847.00 800.00 .57 N 1.74 W .63 N 2.73 W .08 N 3.99 W .68 N 5.48 W .60 N 7.67 W .01 .00 .01 .01 .02 .01 .03 .01 .06 .03 947 947.00 900.00 1047 1047.00 1000.00 1147 1147.00 1100.00 1248 1247.00 1200.00 1349 1347.00 1300.00 5.16 N 10.26 W 10.32 N 13.42 W 18.44 N 17.08 W 30.15 N 21.62 W 44.21 N 28.28 W .13 .07 .32 .19 .73 .41 1.53 .80 2.75 1.21 1451 1447.00 1400.00 1554 1547.00 1500.00 1659 1647.00 1600.00 1764 1747.00 1700.00 1872 1847.00 1800.00 60.20 N 38.79 W 81.19 N 53.78 W 105.62 N 71.06 W 133.71 N 90.22 W 166.60 N 110.89 W 4.57 1.83 7.87 3.30 12.25 4.38 17.89 5.64 25.18 7.29 1979 1947.00 1900.00 2090 2047.00 2000.00 2202 2147.00 2100.00 2319 2247.00 2200.00 2441 2347.00 2300.00 200.12 N 132.68 W 238.28 N 158.83 W 281.42 N 188.39 W 331.80 N 221.94 W 390.26 N 260.44 W 32.88 7.70 43.09 10.20 55.95 12.86 72.86 16.92 94.96 22.09 2572 2447.00 2400.00 2710 2547.00 2500.00 2855 2647.00 2600.00 3009 2747.00 2700.00 3175 2847.00 2800.00 459.77 N 306.76 W 125.29 30.34 539.83 N 359.66 W 163.92 38.62 627.24 N 417.20 W 208.69 44.77 726.11 N 480.18 W 262.80 54.12 835.76 N 554.56 W 328.83 66.02 3353 2947.00 2900.00 3531 3047.00 3000.00 3706 3147 . 00 3100 . 00 3874 3247.00 3200.00 4049 3347.00 3300.00 955.94 N 638.34 W 1076.02 N 724.37 W 1191.69 N 809.29 W 1300.03 N 889.96 W 1414.84 N 976.00 W 406.22 77.40 484.61 78.39 559.52 74.91 627.58 68.06 702.49 74.91 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/95 DATE OF SURVEY: 030695 JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANG~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4234 3447.00 3400.00 4428 3547.00 3500.00 4621 3647.00 3600.00 4807 3747.00 3700.00 4997 3847.00 3800.00 1541.87 N 1678.84 N 1812.25 N 1938.98 N 2069.46 N 1065.54 W 787.32 84.83 1160.86 W 881.87 94.55 1256.36 W 974.02 92.15 1349.55 W 1060.46 86.44 1445.68 W 1150.93 90.47 5179 3947.00 3900.00 5383 4047.00 4000.00 5593 4147.00 4100.00 5804 4247.00 4200.00 6012 4347 . 00 4300 . 00 2193.13 N 2343.32 N 2499.84 N 2656.30 N 2810.66 N 1534.06 W 1232.89 81.96 1628.48 W 1336.62 103.72 1726.85 W 1446.81 110.20 1826.40 W 1557.50 110.68 1924.23 W 1665.83 108.33 6222 4447.00 4400.00 6434 4547.00 4500.00 6645 4647.00 4600.00 6851 4747.00 4700.00 7051 4847.00 4800.00 2965.19 N 3122.10 N 3278.95 N 3432.48 N 3578.31 N 2024.23 W 1775.31 109.48 2125.64 W 1887.22 111.91 2225.38 W 1998.29 111.08 2318.94 W 2104.05 105.76 2413.96 W 2204.79 100.73 7249 4947.00 4900.00 7447 5047.00 5000.00 7648 5147.00 5100.00 7851 5247.00 5200.00 8054 5347.00 5300.00 3720.81 N 3862.56 N 4008.56 N 4158.68 N 4304.31 N 2507.63 W 2302.48 97.69 2603.15 W 2400.52 98.04 2698.77 W 2501.67 101.15 2792.51 W 2604.99 103.33 2890.83 W 2707.22 102.23 8259 5447.00 5400.00 8466 5547.00 5500.00 8669 5647.00 5600.00 8872 5747.00 5700.00 9072 5847.00 5800.00 4449.59 N 4598.55 N 4739.65 N 4878.24 N 5014.38 N 2995.57 W 2812.35 105.13 3099.24 W 2919.58 107.22 3205.41 W 3022.51 102.94 3314.75 W 3125.41 102.90 3422.14 W 3225.58 100.17 9268 5947.00 5900.00 9462 6047.00 6000.00 9642 6147.00 6100.00 9810 6247.00 6200.00 9967 6347.00 6300.00 5144.42 N 5274.18 N 5389.71 N 5496.48 N 5593.05 N 3529.94 W 3321.88 96.30 3633.29 W 3415.60 93.72 3727.99 W 3495.40 79.80 3810.62 W 3563.43 68.03 3884.00 W 3620.67 57.24 10114 6447.00 6400.00 10256 6547.00 6500.00 10392 6647.00 6600.00 10522 6747.00 6700.00 10647 6847.00 6800.00 5679.86 N 5761.92 N 5836.69 N 5903.71 N 5963.28 N 3948.08 W 3667.80 47.13 4006.45 W 3709.73 41.93 4060.14 W 3745.68 35.95 4109.36 W 3775.75 30.07 4153.06 W 3800.09 24.34 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-25 500292254600 MILNE POINT FIELD COMPUTATION DATE: 3/15/95 DATE OF SURVEY: 030695 JOB NUMBER: AK-MM-950210 KELLY BUSHING ELEV. = 47.00 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 10768 6947.00 6900.00 6018.64 N 4192.49 W 3821.03 20.94 10886 7047.00 7000.00 6070.54 N 4227.74 W 3839.10 18.07 11002 7147.00 7100.00 6119.72 N 4261.51 W 3855.55 16.45 11118 7247.00 7200.00 6169.07 N 4292.80 W 3871.37 15.82 11233 7347.00 7300.00 6218.36 N 4323.15 W 3886.92 15.55 11350 7447.00 7400.00 6268.36 N 4354.57 W 3903.05 16.14 11466 7547.00 7500.00 6319.57 N 4384.95 W 3919.44 16.39 11500 7575.83 ~7528.83 6334.40 N 4393.60 W 3924.17 4.72 THE CALCUlaTION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS gyro/data MILNE POINT FIELD, WELL NO. MPF-25 NORTH SLOPE, ALASKA Gyro Multishot Survey in 5.5" drill pipe Survey date :25 February, 1995 Job number' AK0295G253 RECEIVED JUN 2 5 1996 SR253.DOC gyrodat Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 7131461-3146 Fax: 7131461-0920 March 7, 1995 Ms. Marian Sloan B.P. Exploration Pmdhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 Re: Dear Ms. Sloan, Milne Point Field, Well No. MPF-25 North Slope, Alaska Enclosed please find one (1) original and four copies (4) of the completed survey of Well #MPF-25 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 Shoup Assistant Operations Manager RS/gr Sec,,ing the Worldwide Energy Industry with Precision Survey Instrumentation gym/data CONTENTS JOB NUMBER ' AK0295G253 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR253.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR253.DOC gym/data DISCUSSION JOB NUMBER' AK0295G253 Tool 046 was run in MPF-25 on ATLAS 15/32" Wireline inside 5.5" drill pipe. The survey was run without problems. SR253.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER' AK0295G253 The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Gyrodata Limited, and are 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 true arid correct directional survey of this well based on the original data obtained at the well site. Checked by · ROB SHOUP OPERATIONS ENGINEER SR253.DOC gyro/data 2. SURVEY DETAILS SP,253.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0295G253 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MILNE POINT WELL: MPF-25 LATITUDE: 70.515 N LONGITUDE: 149.5 W SURVEY DATE: 25 FEBRUARY, 1995 SURVEY TYPE : MULTISHOT IN 5.5" drill pipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 46.7 ASL 4830' SURVEY TIED ONTO: N/A SURVEY INTERVAL: UTM CO-ORDINATES: 100' 30' in open hole TARGET DIRECTION: 325.02 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR253.DOC gyro/data 3. OUTRUN SURVEY LISTING SR253.DOC A Gyroda t a D i re c t i ona i Survey for B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, NORTH SLOPE, ALASKA Job Number: AK0295G253 Run Date: 25-Feb-95 19:55:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.515000 deg. N Sub-sea Correction from Vertical Reference: 46.7 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 325.020 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A' G y r o d a t a D i r e c t i o n a i S u r v e. y B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, Job Number: AK0295G253 NORTH SLOPE, 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. 0.0 0.00 0.00 0.0 0.0 -46.7 0.00 0.0 0.0 0 - 4830 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL MEASURED DEPTHS REFERENCED TO F PAD R.K.B..OF 46.7 FT. ABOVE SEA LEVEL Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .19 291.01 100.0 .1 53.3 .19 .2 291.0 200.0 .34 279.76 200.0 .5 153.3 .16 .6 285.7 300.0 .27 276.24 300.0 .8 253.3 .07 1.2 282.2 400.0 .36 275,00 400.0 1.2 353.3 .09 1.7 280.1 500.0 .39 271.95 500.0 1.6 453.3 .04 2.4 278.2 600.0 .53 291.46 600.0 2.2 553.3 .21 3.1 279.5 700.0 .80 287.60 700.0 3.1 653.3 .27 4.3 282.1 800.0 1.35 295.76 800.0 4.7 753.3 .57 6.1 285.3 900.0 2.02 312.15 899.9 7.5 853.2 .82 8.9 291.8 1000.0 3.32 325.03 999.8 12.1 953.1 1.42 13.2 301.4 1100.0 5.12 335.79 1099.5 19.4 1052.8 1.96 19.9 312.1 1200.0 6.99 339.71 1199.0 29.6 1152.3 1.92 29.7 321.0 1300.0 8.78 334.82 1298.0 43.0 1251.3 1.91 43.0 326.0 1400.0 11.03 326.67 1396.5 60.1 1349.8 2.65 60.2 327.3 1500.0 15.17 325.09 1493.9 82.8 1447.2 4.16 82.8 326.8 1600.0 16.53 323.31 1590.1 110.1 1543.4 1.45 110.1 326.2 1700.0 18.74 325.14 1685.4 140.4 1638.7 2.27 140.4 325.8 1800.0 20.61 328.76 1779.6 174.0 1732.9 2.23 174.0 326.0 1900.0 20.92 328.64 1873.1 209.4 1826.4 .32 209.4 326.5 2000.0 24.27 326.53 1965.4 247.8 1918.7 3.44 247.9 326.6 .06 N .15 W .17 N .60 W .25 N 1.13 W .30 N 1.68 W .34 N 2.33 W .52 N 3.11 W .90 N 4.20 W 1.62 N 5.92 W 3.31 N 8.29 W 6.87 N 11.25 W 13.31 N 14.74 W 23.08 N 18.68 35.70 N 24.04 ,, 50.60 N 32.54 W 69.34 N 45.29 W 91.48 N 61.29 W 116.07 N 78.97 W 144.30 N 97.28 W 174.59 N 115.70 W 206.99 N 136.33 W k Gyro da t a D i r e c t i ona i S u rve. y B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, Job Number: AK0295G253 NORTH SLOPE, ALASKA Page MEASURED I DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 2200.0 2300.0 2400.0 2500.0 26 29 32 35 40 .57 325.85 2055.7 .49 324.33 2144.0 .42 324.86 2229.7 .31 327.75 2312.7 .09 328.36 2391.8 290.7 337.7 389.1 444.8 505.8 2009.0 2.32 290.8 326.6 2097.3 3.00 337.7 326.4 2183.0 2.95 389.2 326.1 2266.0 3.30 444.9 326.2 2345.1 4.80 506.0 326.4 242.65 N 160.22 W 281.16 N 187.14 W 323.09 N 216.93 -' 369.46 N 247.78 421.34 N 280.12 W 2600.0 2700.0 2800.0 2900.0 3000.0 43 45 46 49 5O .02 326.72 2466.7 .41 326.45 2538.3 .83 325.33 2607.6 .17 326.62 2674.6 .99 328.39 2738.7 572.1 641.8 713 . 8 788.1 864.7 2420.0 3.13 572.3 326.5 477.28 N 315.73 W 2491.6 2.40 642.0 326.5 535.49 N 354.13 W 2560.9 1.63 714.1 326.5 595.16 N 394.56 W 2627.9 2.53 788.4 326.4 656.75 N 436.13 W 2692.0 2.27 865.0 326.5 721.44 N 477.31 W 3100.0 3200.0 3300.0 3400.0 3500.0 52 54 56 56 55 .91 325.42 2800.4 .36 325.81 2859.7 .33 325.67 2916.5 .61 323.90 2971.8 .74 323.20 3027.4 943.4 1023.9 1106.2 1189.5 1272.6 2753.7 2813.0 2869.8 2925.1 2980.7 3.02 943.8 326.5 1.48 1024.3 326.5 1.98 1106.5 326.4 1.50 1189.8 326.3 1.05 1272.8 326.1 787.38 N 520.32 W 853.83 N 565.79 W 921.80 N 612.10 W 989.90 N 660.17 W 1056.73 N 709.52 W 3600.0 3700.0 3750.0 3780.0 3810.0 55 54 53 53 53 .21 326.50 3084.1 .40 323.28 3141.8 .52 322.54 3171.2 .66 321.37 3189.0 .25 320.41 3206.9 1355.0 1436.7 1477.1 1501.2 1525.2 3037.4 3095.1 3124.5 3142.3 3160.2 2.76 1355.2 326.0 2.75 1436.9 326.0 2.14 1477.2 325.9 3.16 1501.3 325.8 2.92 1525.3 325.8 1124.07 N 756.94 W 1190.91 N 803.93 1223.16 N 828.31 ,, 1242.17 N 843.19 W 1260.87 N 858.39 W 3840.0 3870.0 3900.0 3930.0 3960.0 53 53 53 54 55 .16 320.39 3224.8 .53 320.74 3242.8 .94 321.27 3260.5 .99 321.88 3277.9 .38 322.46 3295.1 1549.1 1573.1 1597.3 1621.6 1646.2 3178.1 3196.1 3213.8 3231.2 3248.4 .31 1549.2 325.7 1.55 1573.2 325.6 1.98 1597.3 325.5 3.87 1621.7 325.5 2.04 1646.3 325.4 1279.38 N 1297.97 N 1316.77 N 1335.89 N 1355.35 N 873.70 W 888.99 W 904.21 W 919.38 W 934.49 W A Gyroda t a D i r e c t i on a i S u rve~y B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, Job Number: AK0295G253 NORTH SLOPE, 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 3990.0 55.57 322.93 3312.1 4020.0 56.13 322.89 3328.9 4050.0 56.02 323.26 3345.7 4080.0 56.33 323.24 3362.4 4110.0 56.83 323.71 3378.9 1670 1695 1720 1745 1770 .9 .7 .6 .5 .6 3265.4 3282.2 3299.0 3315.7 3332.2 1.44 1671.0 325.4 1.86 1695.8 325.3 1.09 1720.6 325.3 1.03 1745.6 325.3 2.11 '1770.6 325.3 1375.01 N 949.47 W 1394.81 N 964.44 W 1414.71 N 979.39 ", 1434.68 N 994.31 ~) 1454.80 N 1009.21 W 4140.0 57.34 324.06 3395.2 4170.0 57.68 324.30 3411.3 4200.0 58.10 324.42 3427.2 4230.0 58.42 324.66 3443.0 4260.0 58.86 324.77 3458.6 1795 1821 1846 1872 1897 .7 .0 .5 .0 .6 3348.5 3364.6 3380.5 3396.3 3411.9 1.97 1795.8 325.2 1.31 1821.1 325.2 1.45 1846.5 325.2 1.28 1872.0 325.2 1.50 1897.6 325.2 1475.14 N 1024.05 W 1495.66 N 1038.86 W 1516.31 N 1053.67 W 1537.09 N 1068.47 W 1558.01 N 1083.27 W 4290.0 59.09 324.71 3474.1 4320.0 59.76 324.37 3489.4 4350.0 59.95 324.22 3504.4 4380.0 59.34 323.74 3519.6 4410.0 59.36 323.53 3534.9 1923 1949 1975 2000 2026 .3 .1 .1 .9 .7 3427.4 3442.7 3457.7 3472.9 3488.2 .78 1923.3 325.2 2.43 1949.1 325.2 .78 1975.1 325.2 2.47 2001.0 325.1 .62 2026.8 325.1 1579.00 N 1600.04 N 1621.10 N 1642.04 N 1662.83 N 1098.11 W 1113.09 W 1128.23 W 1143.46 W 1158.76 W 4440.0 59.11 323.33 3550.2 4470.0 58.91 323.12 3565.7 4500.0 59.11 322.78 3581.1 4530.0 59.01 322.75 3596.5 4560.0 58.17 322.40 3612.2 2052 2078 2103 2129 2155 .5 .2 .9 .6 .2 3503.5 3519.0 3534.4 3549.8 3565.5 1.01 2052.5 325.1 .88 2078.2 325.1 1.16 2103.9 325.1 .38 2129.6 325.0 2.96 2155.2 325.0 1683.53 N 1704.13 N 1724.66 N 1745.14 N 1765.47 N 1174.12 W 1189.52 1205.01 ~ 1220.58 W 1236.14 W 4590.0 57.75 322.19 3628.1 4620.0 57.32 322.36 3644.2 4650.0 56.92 322.54 3660.5 4680.0 56.69 322.27 3676.9 4710.0 57.60 322.36 3693.2 2180 2205 2231 2256 2281 .6 .9 .1 .1 .3 3581.4 3597.5 3613 .8 3630.2 3646.5 1.52 2180.6 325.0 1.49 2205.9 324.9 1.45 2231.1 324.9 1.07 2256.2 324.9 3.05 2281.3 324.9 1785.59 N 1805.61 N 1825.59 N 1845.48 N 1865.43 N 1251.69 W 1267.18 W 1282.53 W 1297.85 W 1313.26 W A Gyro d a t a D i r e c t i o n a i S u r v e-y B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, Job Number: AK0295G253 NORTH SLOPE, 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 4740.0 57.52 322.77 3709.3 4770.0 58.19 322.88 3725.2 4784.0 58.66 324.05 3732.6 4830.0 58.97 323.59 3756.4 2306.6 2332.0 2343.9 2383.3 3662.6 3678.5 3685.9 $709.7 1.18 2306.6 324.8 2.22 2332.0 324.8 7.90 2343.9 324.8 1.10 2383.3 324.8 1885.53 N 1328.65 W 1905.77 N 1344.00 W 1915.35 N 1351.10 ". 1947.12 N 1374.33 ~ Final Station Closure: Distance: 2383.28 ft Az: 324.78 deg. A Gyroda t a D i r e c t i ona i Survey for B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE F PAD, MILNE POINT, NORTH SLOPE, ALASICA gob Nu. mbe~.~.': A]<0295G253SS Run Date: 25-Feb-95 19:55:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.515000 deg. N Sub-sea Correction from Vertical Reference: 46.7 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 325.020 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 S u rve, y B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, Job Number: AK0295G253SS NORTH SLOPE, ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -46.7 0.00 0.00 0,0 0.0 0.00 0.0 0.0 0.00 N 0.00 E 0 - 4830 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL MEASURED DEPTHS REFERENCED TO F PAD R.K.B.~OF 46.7 FT. ABOVE SEA LEVEL 100.0 .26 285.76 146.7 .3 .18 .6 288.5 200.0 .31 278.11 246.7 .7 .12 1.2 284.1 300.0 .31 275.66 346.7 1.0 .08 1.7 281.2 400.0 .38 273.58 446.7 1.4 .07 2.4 279.2 500.0 .46 281.07 546.7 1.9 .12 3.1 278.8 600.0 .66 289.66 646.7 2.6 .24 4.3 280.7 700.0 1.05 291.41 746.7 3.9 .41 6.1 283.6 800.0 1.66 303.42 846.7 6.0 .69 8.9 288.3 900.0 2.63 318.18 946.7 9.6 1.10 13.2 296.3 1000.0 4.16 330.09 1046.7 15.5 1.68 19.9 306.4 1100.0 6.01 337.65 1146.7 24.2 1.94 29.7 316.3 1200.0 7.85 337.35 1246.7 36.1 1.91 43.0 323.4 1300.0 9.89 330.79 1346.7 51.5 2.27 60.2 326.6 1400.0 13.16 325.86 1446.7 71.8 3.42 82.8 327.0 1500.0 15.92 324.11 1546.7 97.8 2.67 110.1 326.5 1600.0 17.84 324.40 1646.7 128.1 1.94 140.4 325.9 1700.0 19.96 327.50 1746.7 162.3 2.25 174.0 325.9 1800.0 20.83 328.67 1846.7 199.4 .86 209.4 326.3 1900.0 23.59 326.96 1946.7 240.0 2.81 247.9 326.6 2000.0 26.34 325.91 2046.7 286.4 2.43 290.8 326.6 .11 N .36 W .20 N .85 W .27 N 1.38 W .32 N 1.98 W .42 N 2.69 W .70 N 3.62 W 1.24 N 5.01 W 2.41 N 7.03 W 4.98 N 9.68 W 9.89 N 12.89 W 17.94 N 16.61 W 29.16 N 21.26 W 43.06 N 28.24 W 60.25 N 39.11 W 81.49 N 54.07 W 106.08 N 71.79 W 134.45 N 90.89 W 166.05 N 110.50 W 200.44 N 132.16 W 239.10 N 157.84 W .- A' G y r o d a t a D i r e c t i o n a'l S u r v e~ y B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, Job Number: AK0295G253SS NORTH SLOPE, ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. VERTICAL VERTICAL DOGLEG CLOSURE DEPTH SECTION SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 29.58 324.35 2200.0 33.01 325.45 2300.0 37.36 328.01 2400.0 42.24 327.16 2500.0 45.58 326.32 2146.7 339.3 3.00 389.2 326.3 2246.7 400.5 3.02 444.9 326.1 2346.7 471.0 3.94 506.0 326.3 2446.7 554.4~ 3.57 572.3 326.5 2546.7 650.5 2.31 714.1 326.5 282.50 N 188.09 W 332.58 N 223.24 W 391.73 N 261.67 W 462.36 N 306.23 W 542.69 N 359.01 W 2600.0 48.19 326.08 2700.0 51.24 328.01 2800.0 54.04 325.72 2900.0 56.48 324.70 3000.0 55.56 324.32 2646.7 757.2 2.16 788.4 326.4 2746.7 874.9 2.37 943.8 326.5 2846.7 1006.3 1.82 1024.3 326.5 2946.7 1151.7 1.72 1].,89.8 326.4 3046.7 1300.6 1.63 1355.2 326.1 631.11 N 418.82 W 729.96 N 482.87 W 839.29 N 555.84 W 958.99 N 638.35 W 1079.59 N 725.62 W 31.00.0 54.26 323.1.5 3200.0 53.62 320.86 3300.0 56.04 323.26 3400.0 58.53 324.68 3500.0 59.17 323.37 3].46.7 1,443.4 2.65 ].477.2 326.0 3246.7 1578.5 1.65 1597.3 325.6 3346.7 1722.2 1.08 1745.6 325.3 3446.7 1878.0 1.33 1897.6 325.2 3546.7 2046.6 .92 2052.5 325.1 1196.30 N 808.00 W 1302.14 N 892.37 W 1415.96 N 980.33 W 1542.02 N 1071.96 W 1678.78 N 1170.60 W 3600.0 57.26 322.39 3700.0 58.84 323.78 3709.7 58.97 323.59 3646.7 2209.8 1.48 2231.1 324.9 3746.7 2367.3 3.86 2383.3 324.8 3756.4 2383.3 1.10 2383.3 324.8 1808.69 N 1269.55 W 1934.21 N 1364.89 W 1947.12 N 1374.33 W Final Station Closure: Distance: 2383.28 ft Az: 324.78 deg. gY~ /data 4. QUALITY CONTROL SR253.DOC Quality Control Comparisons B.P. EXPORATION WELL: MPF-25, 5.5" DRILL PIPE Location: F PAD, MILNE POINT, NORTH SLOPE, ALASKA Job Number : AK0295G253 / AK0295G253 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 1000.0 3.52 3.32 .206 2000.0 24.12 24.27 -.146 3000.0 50.87 50.99 -.118 4830.0 58.97 58.97 .000 INRUN Az 327.18 328.02 328.80 323.66 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.0880 deg. Average Azimuth Difference = .65737 deg. OUTRUN Az 325.03 326.53 328.39 323.59 Delta 2.152 1.486 .407 .079 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0295G253 TOOL NUMBER: O46 MAXIMUM GYRO TEMPERATURE: 78.1c MAXIMUM AMBIENT TEMPERATURE: 31.0 c MAXIMUM INCLINATION: 60.1 AVERAGE AZIMUTH: 324.77 WlRELtNE RE-ZERO VALUE: NO CORRECTION RE-ZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 21-JANUARY-95 1060 CALIBRATION USED FOR FINAL SURVEY: 21-JANUARY-95 1060 PRE JOB MASS BALANCE OFFSET CHECK: -.35,-.19,-.33 POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES USED -.35 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISONS M.D. 1NC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 4830 FINAL SURVEY - .:'~' 4830 58.97 323.59 3756.0 1946.91 -1374.19 58.97 323.59 3756.4 1947.12 -1374.33 SR253.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0295G253 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 2700 45.41 45.41 45.41 45.41 45.41 AZIMUTH M.D. ff 1 2 3 4 5 2700 326.11 326.45 326.46 326.50 326.47 SR253.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR253.DOC EQUIPMENT REPORT JOB NUMBER: AK0295G253 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 046 GYRO SECTION A0083 DATA S ECTI ON A0025 POWER SECTION A0027 BACKUP TOOL No. 710 GYRO SECTION A0083 DATA SECTION A0032 POWER SECTION B0053 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0032 A0079 A0071 A0252 A0074 A0029 A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16" RUNNING GEAR 2 1/4" System using 2 1/4 "eccentric weight bar TOTAL LENGTH OF TOOL: 24.5 feet MAXIMUM O.D.: 2.25 inches TOTAL WEIGHT OF TOOL: 250 lbs SR253.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0295G253 2/25/95 O63O ALASKA AIR TO SLOPE 1000 FAIR BANKS. ALASKA AIR DOWN FLY MARK AIR. 1130 ARRIVE DEADHORSE. 13OO CHECK 046. OK. 1315 LEAVE FOR MILNE POINT 1445 ARRIVE LOCATION, MU TOOL. 16OO STANDBY 1915 PU TOOL. MU PUMP DOWN SUB. START INRUN SURVEY. 2025 2110 4830 START OUTRUN SURVEY. 5200 CASING. 2245 LD AND BD TOOL. 2/26/95 0130 RTN TO ATLAS. O530 POST RUN CHECK. TOOL DOWN. 1000 RECHECK 046. TOOL DOWN GYRO, RECHECK SWIVEL. 2100 MARK AIR TO ANCHORAGE. SR253.DOC WELL LOG TRANSMITTAL To: State of Alaska .. Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 August 11, 1995 RE: MWD Formation Evaluation Logs - MP F-25, AK-MM-950210 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 2" x 5" MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs: 1 Folded Sepia 1 Blueline 1 Folded-Sepia 2" x 5" MD Neutron and Density Logs: 1 Blueline 1 Folded Sepia / x 5" TVD Neutron and Density J~s: 1 Blueline r~ 1 Folded Sepia ' "b/Pc,, I/I P I ~ C~/~s .- ~ u I '.,~vo:~go. c~%~i~io0' 5631 Silverado Way, Suite G · Anchorage, Alaska 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: 24 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 6406.01 Run # 1 6409.01 Run # 1 6410.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return to~ PetrotechnicaZ' Data Cente~ BP Exploration (Alaska) In~ 900 East Benson BoUleVard Anch~orage, Al~_ska 99508 IVED MAY 0 4 1995 _ , Nas~ 0il & 6as C(~ns. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 27 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL 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 6408.00 Run # 1 6409.00 Run # 1 6410.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s~[gn ~nd ~e2tl~n ~; ~- trotechnical Da%a Cente~ ~P EXploration {Alaska) 90~n'ast ~ 22Z,~ ' ~nson~Boulevard Da~ ...... --~.~~ 1995 .... ~,~ ~/~1 ~ ~ C.o~s. Commission BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johston, Chairman Date: April 28, 199! ;COM~ i'co COMM RES ENG SR EN~ SR F_Ne ENG ASST ENG ASST SR GEOL GEOL ASSTI GEOL ASSTI,' :_STAT TEC.,H Subject: Milne Point Unit Drillinq Operations - Clarification Per our conversation with Blair Wondzell on April 26, we would like to clarify our drilling operations at Milne Point unit F and L pads. MPL-17 (Permit # 94-169). Drilled surface hole and set 9-5/8" surface casing at 3650'. Drilled to 8788' MD and set 7" casing across the Kuparuk sands. The well was suspended with source water in the casing and a 7" retrievable bridge plug set at 3025'. The well will be perforated, hydraulically sand frac'd and cleaned out with coiled tubing without a rig on the well. The well will be completed by a rig as an ESP completion with 2-7/8" tubing at a later date. MPL-29 (Permit # 95-009). Drilled surface hole and set 9-5/8" surface casing at 7676' in January, 1995. The well was suspended with a dry hole tree in order to move N27E to the newly set MPF-pad and drill several development wells before break-up and pad compacting operations commenced. N27E will be moving back to MPL-29 in early May to complete drilling operations on this well. The well will be completed with 3-1/2" tubing by N27E as a Kuparuk water injection well. MPF-25 (Permit # 95-16). Drilled surface hole and set 9-5/8" surface casing at 3425'MD. Drilled to 11502'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. MPF-13 (Permit # 95-27). Drilled surface hole and set 9-5/8" surface casing at 3968'MD. Drilled to 10975'MD and set 7" casing across the Kuparuk sands, The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing, The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. REEEIVED MAY -2 1995 0il & Gas Cons. Commission Anchorage MPF-37 (Permit-~ 95-25). Drilled surface hole and set 9-5/8" surface casing at 6621'MD. Drilled to 12915'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. MPF-01 (Permit #95-45). Drilled surface hole and set 9-5/8" surface casing at 7124'MD. Drilled to 12941'MD and set 7" casing across the Kuparuk sands. The well will be perforated and hydraulically sand frac'd without a rig and then cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. Yours Sincerely, "~ Adrian Clark Drilling Engineer Supervisor cc. Well file RECEIVED MAY-2 1995 Alaska 0il & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION GR/CCL FINAL BL+RF GR/CCL FINAL BL+RF GR/CCL FINAL BL+RF ECC No. Run # 1 6408.00 Run # 1 6409.00 Run # 1 6410.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, -AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return to; Petrotechnlcal Data Cente~ BP Exploration (Alaska) In~ 9.00 East Benson Boulevard ,~~O~aska ~9508 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM TO: David John, Chairmah_,,~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 21, 1995 THRU: Blair Wondzeil, ~ P. I. Supervisor c/z8 FROM: Bobby Fos~ SUBJECT: Petroleum Inspector FILE NO: EWQIBCD.doc Diverter Inspection BPX - MPU - F-25 PTD # 95-0016 Kuparuk River Field Tuesday, February 21, 1995: I traveled this date to BPX's Miine Point field and inspected the diverter on Nabors rig 27 E. The diverter system was rigged up properly and in compliance with AOGCC regulations concerning diverters. The system was not function tested due to an inspector not being able to get to the location before drilling had started and was in progress when i arrived. The only thing I found wrong was the lines were not tied down properly, but this was corrected before left the location. The rig was clean and ali equipment seemed to be in good working order. The- location was clean and all extra equipment and drilling supplies were stored properly. Summary: ! inspected the acceptable diverter system on Nabors 27E rigged up on BPX's Miine Point Unit well F-25. Attachment: EWQIBUCD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIt~$1ON Diverter Systems Inspection Report Operation: Drlg Contractor: Nabors Alaska Drilling, Inc. Rig No. Operator: BPX MPU Oper. Rep.: Well Name: MP F-25 Rig Rep.: Location: Sec. 6 T. 13N R. 10E Date: 2/21/95 Development X Exploratory: 27E PTD# 95-0016 Rig Ph.# 659-4384 JIM GAFFENEY ROD KLEPZIG Merdian Umiat MISC. INSPECTIONS: Location Gen.: OK Well Sign: OK Housekeeping: OK (Gen.) Drlg. Rig: OK Reserve Pit: N / A Flare Pit: N / A DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 Vent Line(s) Length: Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: YES in. in. ACCUMULATOR SYSTEM: Systems Pressure: NOT TESTED psig Pressure After Closure: psig 200 psi Attained After Closure:~min. ~sec. Systems Pressure Attained: ~ min. ~sec- Nitrogen Bottles: 8 Bottles 2300 Ave. psig 86 & 136 ft. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide:' NT NT NOI~TFI ~ Drawing Not To Scale Prevailing Winds Non Compliance Items Remarks: Distribution orig. - Well File c - OpedRep c - Database c - Tdp Rpt File c- Inspector N.C. Mechanically ~ ! / Linked(2) 10"Knife Valves II ~-- Pipe Shed o. 54 / ! (~ ~__________~ 20,, Annular Preventer With 10" FO Hydraulic Knife Valve Mud System Motor Module Repair Items Within 0 0 The rig was found to be in good condition. AOGCC REP.: Day (s) And contact the Inspector @ 659-3607 FI-022 (Rev. 7/93 EWQIBUCD.XLS TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 14, 1995 Adrian Clark, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit MPF-25 BP Exploration (Alaska) Inc 95-16 1857'NSL, 2696'WEL, Sec 6, T13N, R10E, UM 2902'NSL, 1961'WEL, Sec 36, T14N, R9E, UM Dear Mr Clark: 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 ddlling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ¥o Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ,¢-" STATE OF ALASKA - AL/-,..,KA OIL AND GAS CONSERVATIOI~ COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrilll-lIlb. Type of well. Exploratoryr-] Stratigraphic Test [] Development Oil[] Re-Entry [] DeepenI'-]I 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. KBE = 32.5' feet Mi/ne Point Unit - Kuparuk 3. Address 6. Property Designation Sands P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 35501~ 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1857'NSL, 2696' WEL, SEC. 6, T13N, RIOE Prudhoe Bay Unit At top of productive interval 8. Well number Number 2736' NSL, 1845' WEL, SEC. 36, T14N, PgE MPF-25 2S 100302630-277 At total depth 9. Approximate spud date Amount 2902' NSL, 1961' WEL, SEC. 36, T14N, PgE 2/15/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) ~ prop~/~ line L 355023-2902' feet No close approach feet 2560 11570' MD/7613' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 6o o Maximum surface 2898 psig At total depth (TVD) 7613/3646 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 B TRC 3399' 31' 31' 3430' 3000' 678 sx PF "E"/250 sx "G"/250 sx PF"E" 8-1/2" 7" 26# L-80 BTRC 11540' 30' 30' 11570' 7613' 205 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°rnfda~Cet°r R E¢ E IV E D Intermediate Production FEB -9 1995 Liner Perforation depth: measured Ailii$~ 0il & GasC0ns. Commission true vertical ~ll~lch0r~'. ~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drillin9 fluid Time vs program/llFI depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify//_cf~?~s true and correct to the best of my knowledge __, Signed/~) '(~_.¢_./~~ Tit le Drillin¢ En~lineer Superv/sor Date,,'~/"t / ~ ,-~ Commission Use Only Permit Number 1APl number IApproval ,date See cover letter ?.¢'-,/g' 15o-o .¢ I- merits - for other require Conditions of approval Samples required [] Yes ~ No Mud log required []Yes ,1~ No Hydrogen sulfide measures [] Yes 1~ No Directional survey required ~' Yes [] No Required working pressure for DOPE,, [] 2M; []3M; 1~-5M' I-I10M. i--)15M' Other: uriginal Signed By by order of /--/ Approved by Dav[I~ W. Johristol'i Commissioner ,ne commission Date,~,///¢//'~..~- Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: l MPF-25 I Well Plan Summary I Type of Well (producer or injector): IKuparuk Producer I Target Location: Bottom Hole Location' Surface Location: 1857' FSL 2696' FEL Sec 06 T13N R10E UM., AK. 2736' FSL 1845' FEL Sec 36 T14N R9E UM., AK. 2902' FSL 1961' FEL Sec 36 T14N R9E UM., AK. [AFE Number: [ 330110 [ Estimated Start Date: I February 15, 1995 I Rig: ] Nabors 27E Operating days to drill 116 and case: I 7613' IWell Design (conventional, slimhole, etc.): Ultra Slimhole Formation Markers: Formation Tops MD TVD (ss) Formation Pressure/EMW base permafrost 17 64' 17 00' n/a MA n/a n/a n/a NA (Top Schrader) 5340' 3950' 1643 psig / 8.0 ppg OA ' 4130' 1718 psig / 8.0 ppg Base Schrader Bluff ' 4400' 1830 psig / 8.0 ppg Top HRZ truncated truncated n/a Base HRZ ........ n/a Kupark D Shale 10818' 6961' n/a Top Kuparuk C 11134' 7236' 3635 psig / 9.6 ppg Target 11163' 7260' 3646 psig / 9.6 ppg Total Depth 11570' 7 613' n/a Casing/Tubin g Pro,gram: -i- ir T Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.14/ NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 404/ L-80 btrc 3399 31/31 3430/3000 8 1/2" 7" 26# L-80 btrc 11540 30/30 11570/7613 Internal yield pressure of the 7" 26/4 casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7260' TVDSS. Maximum RECEIVED FEB -9 1995 Alaska 0il & Gas Cons. Commission gnchorage anticipated surface pressure in this case assuming a reservoir pressure of 3646 psi is 2898 psi, well below the internal yield pressure rating of the 7" casing. Logging Prol I Open Hole Logs: Surface Intermediate Final Cased Hole Logs- ,ram' None (MWD only) None LWD GR/Resistivity/Neutron/Density None A gamma ray log will be obtained from surface to TD. Mud Logging is not required. R£C£1V£D Gas Cons. Commission Anchorage Mud Program: Special design considerations None- LSND freshwater mud Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties' [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to tO tO tO tO tO 10.1 50 15 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: IKOP' [ 1000' Maximum Hole Angle' ]60 degrees Close Approach Well: None There are no close approach wells for drilling MPF-25. Disposal' Cuttings Handling: CC2A Fluid Handling: The only other well on this pad, F-46 (No. Point), has had it's annulus arctic packed making it unavailable for injection. Consequently, there will be no annuli available for annular injection. All drilling and completion fluids will have to be trucked to CC2 for processing. After cementing the 7" casing on this well, F-25, and allowing the cement to cure 6 hours the 7" x 9-5/8" annulus may be used for fluid disposal. Annular Injection: All cuttings/fluids from this well (F-25) will require trucking to CC2 for processing and disposal. The 7" x 9-5/8" annulus may be used on this well after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. RECEIVED FEB -9 1995 .~s~ gil & Gas Cons. Commi~10n AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point F-25 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. RECEIVED FEB -9 1995 Oil & Gas Cons. Commission Anchorage MP F-25 Proposed Summary of Operations X. . 3. 4. 5. o 10. 11. 12. 15. 16. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Universal Slimhole Wellhead on conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole to 3430' md (3000' tvd). 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 turbine. Test the 9-5/8" casing to 3500 psig. Drill out float equipment and 10 feet of new formation, Perform a LOT. Drill 8-1/2" hole to TD at 11570' MD (7613' TVD). Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. If the Schrader Bluff is wet as expected cement the 7" with a single stage cement job across Kuparuk only. The 7" casing will be displaced with source water. Run and test 7" pack-off to 5000 psi. Change rams to 3-1/2". RIH with 3-1/2" DP and set a retrievable bridge plug @ 3000' MD. POH to 2200' TVD and freeze protect by displacing the 7" casing to diesel. ND BOPE. NU 7-1/16" tubing head adapter, 7-1/16 valve and a tree cap. RDMO Nabors 27E drilling rig to drill MPF-17. RECEIVED FED -9 1995 Oil & (las Cons. Commission Anchora~o MPL-29 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: 678 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 hfs at 50° F. FREE WATER: 0 TOP .1OB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX NO SACKS: 250 YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 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. RECEIVED FEB -9 1995 Aiaska Oil & Gas Cons. ComrnJssion Anchora~i~ Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above 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. RECEIVED FEB -9 1995 .0il & Gas Cons. Commission Nlchora? MPF-2$ 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST CEMENT .lOB ACROSS THE 170 deg F at 7260' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 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: 205 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). This will cover 300' above the LK1. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator inside the 9-5/8"casing shoe. 3. Total 7-1/8 .... x 8-1/4" RH 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. Batch mixing is not necessary. CEMENT VOLUME' 1. The cement volume is calculated to cover 1000' md with 30% excess over a guage hole. RECEIVED FEB -9 1995 Alaska Oil & Gas Cons. Commission Anchora. ~ DRILLING HAZARDS AND RISKS: See the Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for a general recap of the original No Point well (F-46) recently drilled by BPX. There are also several BHLs drilled from L-pad that can give information relavent F-pad drilling. There will be no close approaches while drilling this well. The gravel on F-pad has only recently been laid. Although frozen the gravel has a relatively high moisture content and has not been compacted. This will force Nabors 27E to leave pad in early May so the pad can be compacted and facilities installed. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells with coiled tubing shortly after the rig drills and completes them. This will make the near rig area congested and as a result 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 the only well drilled to date on F-pad. The max mud weight reached 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 L-07, L-08, L-09 and L-11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses initially with LCM treatments. Stuck Pipe Potential' 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-il @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 45 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3646 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 (3646 psi @ 7305 TVD). There has been no injection in this region since then, only production, therefore the reservoir pressure should not exceed this estimate. RECEIVED FEB -9 1995 A!aska Oil & Gas Cons. Commission Anchora V[:R I']C. AI_ VII{. W SCAI. E 500 f't. / 1'Vi) REF: ~/Et_I_HF:AI) VIJR11CAL. SIfCI']J]N REI.': WELI.t EAD (J.(x) (~ lo(x,) ND KliP / ,~I^RI I.)l I]UIi II ~ ~?,UO/IO0 fl. 1500 [~ 16([) ~37.50 ~ ~q(X) ND 3/,50 e 8'.~[) MI) CRIII(:AL PL]INI' I)A1A MD [nc Az;. TVD N/S E/~/ lie IN 0 0,00 3~:5.08 0 0 N 0 E KElP / S1/~-?'I 1000 0.00 3~5.[]2 1000 0 N 0 E []F BUILD ~ a,50/l(x) r.t B. Perm~f'~o~ t ~764 ~9,10 385,08 END OF' [~]LI)3407 60, i6 385,08 1, Sck~'ader' 5340 60,]6 l]~uFf' [J. Sck~mder, G~]44 6[]. 16 3~,08 SIART 0" 9355 GO.16 3~.02 CLJRVE e ~.O0/l(X) [NI) ['][.' (.:U~VE 10063 X).O0 Ior'Fl(.,t ()',]] / ~11G3 30.0(} 385,C}0 7~3G0 6159 N 430g I I<l. J63 B, K~nul< ~ }~]70:.~),[)(] : .... 1750 103 N 78 8988 944 N 660 3950 L~318 N 16~'2 4400 8961 N2071 5948 5178 N36113 for'get 95E. 72260 0159 N 4:KJ9 ~/ 5375?7 6041445 47~0 e ~;C~) MI) [ k.~a:50 ii ]ex Nl] J CASI~i P[]INr DATA ' '~ J 20 ;n 1~3 O,~] O,b0 113 0 N ,0 E .... . J 9 5/8 ;n 3431 GO, lO 325.[)~ 3~)0 ~ J MD 1157035 J ............................................ ~. 60. 6 ~ (~44 MI) B ~[ h~od ,~ III ~rr / V% 77L~ 7 :),',~:1 ~ ' J N/S 6~6.14 N I ~ 54,16 ~ ~55 MP ~ 46,16 ~ 10~5 ND ~ 4~,16 B 1~35 NI) ~38.16 e 10455 ............................................... ~ ............................................... ~1[~ ~ 1~63 ND END ~' ~VE : :::::::::::::::::::::::::::::::::: .::::::z.~=~::'c::=:::=:=:~~.~c=~c~:Sf~¢~¢~o% .................... : ................................................................................................ ~ (~ ~po, '1 I ...... I ........ I l ......... I ....... I ........ I ..... ] ...... I ........... 1 ...... [ ....... I ...... 1 ...... 1 .... I~'~ [)()l) 0 500 1CX)O l[)L}(] 20(X) F~3()O 3000 3t~D 4[)()0 4500 U(XX) 5500 (~0[]0 6tX~) 7000 7[300 VIM I ICAI_ SEC 1 Il.IN PL AND ,']r_",).Or__ ') Well Plan Feasibility Studl[ This Plan is for £casibiliiy purposcs only, ii has no! ;ycl becn ccrtificd. I..ORIZ[]NI'AL VIB/ (TRUE NBRTFD SCALE 500 rt. / I)IVISIEN SURVEY REF: ~/ELL..L. IE~I] x~ 1 I 1 i f I I I 1119/95 310 ¢m --60OO 5500 --85OO --1500 5('K)O4500 40L)O 3500 30L)O L?JO0 ~]OO 15(~ lO(]O 500 0 ~]--.0 5O0 RECEIVED FEB -9 1995 Oil & Gas Cons. 6ommi~ion WELL PERMIT CHECKLIST F ELD OOL 3' J' / o WELL NAME GEOL AREA UNIT# PROGRAM: exp [] //32F dev~ redrll [] serv [] ON/OFF SHORE ~J ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N '7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING APPR D~TE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on ~onductor & surf osg. 17. CMT vol adequate to tie-in long string to surf csg · . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY APPR DATE 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 .......... ~/ N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMM~SS~ Comments/Instructions: 0 z 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. RECEIVED APR ~ o~, ~ ~ oo~. oo~~ILNE POINT Anchorage MICI OFILME Run 1' 15 - April - 1995 Marked Line GR Cased Hole 1O65O 11349 WESTERN ATLAS Logging Services Tape Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF - 25 500292254600 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 26-APR-95 6409.00 R. ECK D. ROBERTSON 6 13N 10E 1857 2696 47.00 45.50 13.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 13.325 80.0 3RD STRING 9.625 3405.0 PRODUCTION STRING 7.000 11437.0 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: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH GR/CCL Cased Hole. 54.50 40.00 29.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** THIS LOG WAS ZEROED AT THE BASE FLANGE WHICH IS USED AS THE REFERENCE POINT. THE BASE FLANGE IS 33.46' BELOW THE R.K.B. ******************** NOTICE ************************ 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 10650.0 11349.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 25 FN : MILNE POINT COUN : 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 66 264 36 0 4 4 66 264 36 0 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 17 Tape File Start Depth = 10650.000000 Tape File End Depth = 11350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4204 datums Tape Subfile: 2 113 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 10864.0 BASELINE DEPTH GRCH 10886.0 10886.0 10887.0 10886.5 10887.5 10887.5 10896.5 10896.5 10897.0 10897.5 10900.5 10901.0 10901.5 10901.5 10902.5 10902.5 10908.5 10908.0 10919.5 10919.0 10921.5 10920.5 10941.5 10940.5 10942.0 10941.5 10951.5 10950.5 10956.0 10955.0 10972.0 10972.5 10972.5 10973.0 10975.5 10975.0 10977.0 10976.5 10985.0 10984.0 10985.5 10984.5 10990.5 10990.5 10995.5 10995.0 10999.0 10998.5 11021.5 11021.5 11025.5 11025.5 11026.0 11026.5 11027.0 11027.5 11033.0 11033.0 11033.5 11033.5 11046.5 11046.0 11048.5 11048.0 11070.0 11070.5 11070.5 11071.0 11071.5 11071.5 11076.0 11076.0 11077.0 11076.5 11077.5 11077.5 STOP DEPTH 11248.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 11079 11080 11080 11081 11082 11093 11095 11097 11105 11117 11126 11126 11131 11132 11133 11133 11134 11135 11136 11136 11144 11145 11149 11150 11158 11158 11159 11160 11161 11162 11194 11204 11207 11208 $ REMARKS: .0 11079.0 .0 11079.5 .5 11080.0 .5 11080.5 .0 11081.0 .5 11093.5 .5 11095.5 .5 11097.0 .0 11104.5 .0 11116.0 .0 11125.0 .5 11126.0 .5 11131.0 .5 11131.5 .0 11132.5 .5 11133.5 .0 11134.0 .0 11134.5 .0 11135.5 .5 11137.0 .0 11144.5 .0 11145.0 .0 11149.0 .0 11149.5 .0 11157.5 .5 11158.5 .5 11159.5 .0 11160.5 .0 11161.5 .0 11162.0 .5 11194.5 .5 11206.0 .5 11209.0 .0 11209.5 PASS 2 (REPEAT PASS) . TENS SHIFTED WITH GRCH / ??MATCH2A . OUT $ CN : BP EXPLORATION WN : MPF - 25 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: API API API API Log Crv Crv Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB Size Length Typ Typ Cls Mod 4 4 66 264 36 0 4 4 66 264 36 0 * DATA RECORD (TYPE# 0) Total Data Records: 10 1014 BYTES * Tape File Start Depth = 10860.000000 Tape File End Depth = 11250.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2344 datums Tape Subfile: 3 115 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE S~Y VENDOR TOOL CODE START DEPTH GR 10649.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11360.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL SWIVEL GR GAMMA RAY CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-APR-95 FSYS REV. J001 VER. 1.1 1631 15-APR-95 11327.0 11350.0 10650.0 11349.0 1800.0 YES TOOL NUMBER 3913NA 1311XA 2321NA .OO0 11437.0 .0 DIESEL & WATER .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 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 REMARKS: PASS 1 (MAIN PASS). $ CN : BP EXPLORATION WN : MPF - 25 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 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 68 Tape File Start Depth = 10649.000000 Tape File End Depth = 11360.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21275 datums Tape Subfile: 4 141 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10864.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11248.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL SWIVEL GR GAMMA RAY CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-APR-95 FSYS REV. J001 VER. 1.1 1700 15-APR-95 11327.0 11350.0 10650.0 11349.0 1800.0 YES TOOL NUMBER 3913NA 1311XA 2321NA .000 11437.0 .0 DIESEL & WATER .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 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 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPF - 25 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 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 37 Tape File Start Depth = 10864.000000 Tape File End Depth = 11248.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11567 datums Tape Subfile: 5 110 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS 95/ 4/26 01 **** REEL TRAILER **** 95/ 4/26 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 26 APR 95 3:02p Elapsed execution time = 4.61 seconds. SYSTEM RETURN CODE = 0 _~pe Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT M D/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK MM 950210 M. HANIK J. ROBERTSON 500292254600 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 27-AUG-96 MWD RUN 3 M. HANIK J. ROBERTSON MWD RUN 4 J. STRAHAN J. GAFFANEY MWD RUN 5 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 J. STRAHAN J. GAFFANEY 6 13N 10E 1857 2696 47.00 45.50 13.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 9.625 3405.0 PRODUCTION STRING 8.500 11502.0 REMARKS: MWD - EWR4/SLD/CNP/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. ANNULAR & CRITICAL VELOCITIES CALCULATED USING THE POWER LAW MODEL. MWD RUN 1 WAS DIRECTIONAL ONLY & NO DATA IS PRESENTED. FILE HEADER FILE N-UMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP RHOB NPHI $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 3372.0 3402.0 3402.0 3402.0 BASELINE DEPTH GR 10670.5 10664.0 10674.0 10673.5 10679.0 10677.0 10680.0 10678.5 10683.0 10681.5 10686.0 10685.0 10692.5 10690.5 10708.5 10707.0 10720.0 10717.5 10725.5 10723.5 10735.0 10733.0 10765.5 10762.5 10785.5 10784.5 10794.0 10790.0 10815.5 10813.0 10850.0 10849.5 10852.0 10851.5 10855.0 10854.5 10884.0 10882.0 10890.0 10889.0 10891.5 10890.5 10893.0 10892.0 10901.0 10899.0 10906.5 10904.5 10908.0 10906.0 10910.5 10910.0 10912.5 10911.5 10915.0 10913.5 10917.0 10915.0 10943.0 10941.5 10969.0 10967.5 10985.0 10982.5 11000.5 10998.5 11022.5 11020.0 11023.5 11021.5 11030.0 11027.5 11033.0 11029.5 11076.5 11072.5 11087.5 11083.0 11099.0 11096.5 11111.5 11108.0 all bit runs merged. STOP DEPTH 11469.0 11442.0 11458.0 11449.0 (WALS, 15-APR-95) EQUIVALENT UNSHIFTED DEPTH 11121.0 11124.5 11130.5 11134.0 11138.5 11143.0 11145.5 11150.0 11157.5 11159.0 11163.5 11166.5 11172.5 11176.5 11179.5 11186.5 11190.5 11193.0 11194.0 11203.5 11239.5 11241.5 11298.0 11299.0 11308.0 11329.0 11331.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 11118.0 11120.0 11127.5 11131.5 11135.0 11140.5 11142.5 11146.5 11154.5 11157.0 11161.5 11163.0 11169.0 11173.0 11176.0 11182.5 11186.5 11188.5 11190.0 11199.0 11231.0 11233.0 11291.0 11294.0 11304.0 11330.0 11332.0 BIT RIINNO 2 3 4 5 MERGE TOP 3425.0 5121.0 7145.0 10890.0 MERGE BASE 5121.0 7145.0 10890.0 11502.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. /? ?SHIFT. OUT $ CN : BP EXPLORATION WN : MPF-25 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: (ALASKA) API API API API Log Crv Crv Name Tool Code Samples Units 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 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 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 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 781 Tape File Start Depth = 11550.000000 Tape File End Depth = 3350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 196813 datums Tape Subfile: 2 938 records... Minimum record length: Maximum record length: 62 bytes 1014 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: 2 DEPTH INCREMENT: .5000 FILE SI/MMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3370.0 5066.0 EWR4 3400.0 5039.0 SLD 3400 . 0 5054 . 0 CNP 3400 . 0 5046 . 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERS ION: 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: 26-FEB-95 2.19A 3.93 MEMORY 5121.0 3425.0 5121.0 0 53.1 59.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 3405.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : STUD 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: LSND 9.10 45.0 10.0 1700 7.2 2.600 1.831 1.900 3.200 67.0 98.0 67.0 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN) : . 000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: MWD RUN 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-25 : MILNE POINT : NORTH SLOPE : ALASKA .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 2 RPX MWD 3 RPS MWD 4 RPM MWD 5 RPD MWD 6 RHOB MWD 7 'DRHO MWD 8 PEF MWD 9 NPHI MWD 10 FET MWD 11 RO P MWD 68 1 AAPI 4 68 1 OHMM 4 68 1 OHMM 4 68 1 OHMM 4 68 1 OHMM 4 68 1 c/c3 4 68 1 G/C3 4 68 1 BN/E 4 68 1 PU-S 4 68 1 HR 4 68 1 FPHR 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 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 170 Tape File Start Depth = 5125.000000 Tape File End Depth = 3350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42613 datums Tape Subfile: 3 239 records... Minimum record length: 62 bytes Maximum record length: 1014 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5048.0 EWR4 5021.0 SLD 5038.0 CNP 5028.0 $ 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 7108.0 7081.0 7096.0 7088.0 28-FEB-95 2.19A 3.93 MEMORY 7145.0 5121.0 7145.0 0 56.1 62.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 3405.0 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: LSND 9.20 45.0 9.5 1800 6.8 2.600 1.700 1.900 3.200 67.0 106.0 67.0 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-25 : MILNE POINT : NORTH SLOPE : ALASKA .000 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 2 RPX MWD 3 RPS MWD 4 RPM MWD 5 RPD MWD 6 RHOB MWD 7 DRHO MWD 8 PEF MWD 9 NPHI MWD 10 FET MWD 11 ROP MWD 68 1 AAPI 4 68 1 OHMM 4 68 1 OHMM 4 68 1 OHMM 4 68 1 OHMM 4 68 1 G/C3 4 68 i /c3 4 · 68 1 BN/E 4 68 1 PU-S 4 68 1 HR 4 68 1 FPHR 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 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 205 Tape File Start Depth = 7150.000000 Tape File End Depth = 5000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 248426 datums Tape Subfile: 4 274 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7090.0 EWR4 7063.0 SLD 7080.0 CNP 7071.0 $ 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: MAXIMIIMANGLE: STOP DEPTH 10835.0 10808.0 10823.0 10815.0 05-MAR- 95 2.19A 3.93 MEMORY 10890.0 7145.0 10890.0 0 32.9 61.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 3405.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MI/D 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: LSD 9.60 43.0 10.0 1600 6.0 1.050 .590 1.050 1.100 78.0 145.0 74.0 80.O NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-25 : MILNE POINT : NORTH SLOPE : ALASKA .000 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 2 RPX MWD 3 RPS MWD 4 RPM MWD 5 RPD MWD 6 RHOB MWD 7 DRHO MWD 8 PEF MWD 9. NPHI MWD 10 FET MWD 11 RO P MWD 68 1 AAPI 4 68 1 OHMM 4 68 1 OHMM 4 68 1 OHMM 4 68 1 OHMM 4 68 i G/c3 4 68 1 G/C3 4 68 1 BN/E 4 68 1 PU-S 4 68 1 HR 4 68 1 FPHR 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 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 366 Tape File Start Depth = 10900.000000 Tape File End Depth = 7060.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 134786 datums Tape Subfile: 5 435 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10804.0 11470.0 EWR4 10771.0 11442.0 SLD 10792.0 11458.0 CNP 10784.0 11450.0 $ 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: 07-MAR- 95 2.19A 3.93 MEMORY 11502.0 10890.0 11502.0 0 30.0 31.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO DENSITY DGR DUAL G_~flVl~ RAY $ TOOL NI/MBER P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 P0339CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3405.0 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: LSD 10.40 42.0 10.0 1600 4.6 1.700 .770 1.300 2.600 68.0 158.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN) : . 000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-25 : MILNE POINT : NORTH SLOPE : ALASKA .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 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 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 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 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 77 Tape File Start Depth = 11550.000000 Tape File End Depth = 10750.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 267639 datums Tape Subfile: 6 146 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 96/ 8/27 01 **** REEL TRAILER **** 96/ 8/28 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 28 AUG 96 ll:02a Elapsed execution time = 6.59 seconds. SYSTEM RETURN CODE = 0