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Home My WebLink About195-125CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPF-69 (PTD: 1951250) Date:Tuesday, September 2, 2025 2:44:55 PM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Tuesday, September 2, 2025 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: NOT OPERABLE: MPF-69 (PTD: 1951250) Mr. Wallace, PWI MPF-69 (PTD # 195125) is currently shut in and was not brought online for its scheduled 4 year MIT-IA that was due in August. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank You. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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ϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/;ƉƉƌŽǆͿŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗ ϭ͕ϭϮϱƐǆW&͕͟͞ϮϱϬƐǆ͞'͕͟ϮϱϬƐǆW&͕͟͞ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϮϰϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϱƚŽϱϳĚĞŐ͘Ĩͬϯ͕ϵϬϬ͛ƚŽϴ͕ϲϬϬ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϯϱ͘ϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϯͲϭͬϴ͟ϱD/t tĞůůŚĞĂĚ ϭϭ͟ǆϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϯͲϭͬϮ͟E^ddďŐ͘,ŶŐƌ͘ dďŐ,ŶŐƌ ϯ͘ϱ͟E^dƚŽƉΘďŽƚƚŽŵǁͬǆͲŽǀĞƌƚŽϮͲϳͬϴ͟h/t,ͲWƌŽĨŝůĞϯ͟ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϱϴϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰ^Ͳϵͬϭϭͬϭϵϵϱ /ŶŝƚŝĂůŽŵƉůĞƚŝŽŶΘWĞƌĨŽƌĂƚŝŽŶƐʹϮͬϮϳͬϭϵϵϲ ^WZtKǁͬEĂďŽƌƐϰ^ʹϳͬϭϮͬϭϵϵϳ͕ϯͬϮϳͬϮϬϬϭΘϰͬϭϲͬϮϬϬϰ ^WZtKǁͬEĂďŽƌƐϯ^ʹϭϮͬϭϮϬϬϲ ŽŶǀĞƌƚƚŽ/ŶũĞĐƚŽƌǁͬ^ZʹϴͬϭϮͬϮϬϮϭ ^d/Dh>d/KE^hDDZz &ƌĂĐʹϭϬϳ͕ϬϬϬηŽĨϭϲͬϮϬĐĂƌďŽůŝƚĞďĞŚŝŶĚƉŝƉĞ͘ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗ddtϬϳͬϭϰͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&Ͳϲϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϴͬϭϮͬϮϬϮϭ Wd͗ϭϵϱͲϭϮϱ dс ϭϬ͕ϰϯϱ;DͿͬdсϳ͕ϰϳϳ ;dsͿ ϮϬ´ KƌŝŐ͘<ůĞǀ͗͘ϰϳ͘ϳϯ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϮ͘ϱ͛ Kƌŝ Ő͘&ůĞǀ͗͘ϰϲ͘Ϯϯ͛;EĂďŽƌƐϰ^Ϳ ϳ͟ ϵͲϱͬϴ͟ .836DQGV WdсϭϬ͕ϯϮϰ͛;DͿͬWdсϳ͕ϯϴϯ͛;dsͿ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϬΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϱ͕ϳϳϴ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚĐ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϬ͕ϰϬϴ͛ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵϮ ^ƵƌĨĂĐĞ ϵ͕ϴϴϯ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕Ϯϴϵ͛ ϯͲϭͬϮ͟yͲEŝƉƉůĞ;Ϯ͘ϴϭϯ͟/Ϳ Ϯ ϵ͕ϳϮϵ͛ ϯͲϭͬϮ͟yͲEŝƉƉůĞ;Ϯ͘ϴϭϯ͟/Ϳ ϯ ϵ͕ϳϴϭ͛ ϯͲϭͬϮ͛ǆϳ͟ĂŬĞƌWƌĞŵŝĞƌWƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϰ ϵ͕ϴϰϭ͛ ϯͲϭͬϮ͟yEͲEŝƉƉůĞǁͬZ,/ŶƐƚĂůů;Ϯ͘ϴϭϯ͟/Ϳ ϱ ϵ͕ϴϱϮ͛ t>';dDĂƚϵ͕ϴϴϯ͛Ϳ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ƐŝůƚƐ цϵ͕ϵϯϲ͛ цϵ͕ϵϲϰ͛ цϳ͕ϬϲϮ͛ цϳ͕Ϭϴϱ͛ Ϯϴ &ƵƚƵƌĞ &ƵƚƵƌĞ <ƵƉ͘ƐŝůƚƐ ϵ͕ϵϱϰ͛ ϵ͕ϵϲϰ͛ ϳ͕Ϭϳϳ͛ ϳ͕Ϭϴϱ͛ ϭϬ ϭͬϭϳͬϭϵϵϲ KƉĞŶ <ƵƉ͘ƐŝůƚƐ цϵ͕ϵϳϭ͛ цϵ͕ϵϴϱ͛ цϳ͕Ϭϵϭ͛ цϳ͕ϭϬϮ͛ ϭϰ &ƵƚƵƌĞ &ƵƚƵƌĞ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϬϬϵ͛ ϭϬ͕Ϭϵϵ͛ ϳ͕ϭϮϭ͛ ϳ͕ϭϵϱ͛ ϵϬ ϭͬϭϳͬϭϵϵϲ KƉĞŶ ϭϬ͕ϬϵϬ͛ ϭϬ͕ϭϭϬ͛ ϳ͕ϭϴϳ͛ ϳ͕ϮϬϰ͛ ϯϬ ϭϭͬϮϵͬϮϬϬϲ KƉĞŶ цϭϬ͕ϭϭϬ͛ цϭϬ͕ϭϯϱ͛ цϳ͕ϮϬϰ͛ цϳ͕ϮϮϱ͛Ϯϱ &ƵƚƵƌĞ &ƵƚƵƌĞ ϵ͕ϵϱϰ͛ƚŽϵ͕ϵϲϰ͛ΘϭϬ͕ϬϵϬ͛ƚŽϭϬ͕ϭϭϬ͛^ŚŽƚǁͬϰ͘ϱ͟ 'ƵŶƐϱ^W&ͬͬϭϬ͕ϬϬϵ͛ƚŽϭϬ͕Ϭϵϵ͛^ŚŽƚǁͬϯ͘ϱ͟'ƵŶƐϲ^W& KWE,K>ͬDEdd/> ϮϬΗ ϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/;ƉƉƌŽǆͿŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗ ϭ͕ϭϮϱƐǆW&͕͟͞ϮϱϬƐǆ͞'͕͟ϮϱϬƐǆW&͕͟͞ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϮϰϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϱƚŽϱϳĚĞŐ͘Ĩͬϯ͕ϵϬϬ͛ƚŽϴ͕ϲϬϬ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϯϱ͘ϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϯͲϭͬϴ͟ϱD/t tĞůůŚĞĂĚ ϭϭ͟ǆϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϯͲϭͬϮ͟E^ddďŐ͘,ŶŐƌ͘ dďŐ,ŶŐƌ ϯ͘ϱ͟E^dƚŽƉΘďŽƚƚŽŵǁͬǆͲŽǀĞƌƚŽϮͲϳͬϴ͟h/t,ͲWƌŽĨŝůĞϯ͟ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϱϴϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰ^Ͳϵͬϭϭͬϭϵϵϱ /ŶŝƚŝĂůŽŵƉůĞƚŝŽŶΘWĞƌĨŽƌĂƚŝŽŶƐʹϮͬϮϳͬϭϵϵϲ ^WZtKǁͬEĂďŽƌƐϰ^ʹϳͬϭϮͬϭϵϵϳ͕ϯͬϮϳͬϮϬϬϭΘϰͬϭϲͬϮϬϬϰ ^WZtKǁͬEĂďŽƌƐϯ^ʹϭϮͬϭϮϬϬϲ ŽŶǀĞƌƚƚŽ/ŶũĞĐƚŽƌǁͬ^ZʹϴͬϭϮͬϮϬϮϭ ^d/Dh>d/KE^hDDZz &ƌĂĐʹϭϬϳ͕ϬϬϬηŽĨϭϲͬϮϬĐĂƌďŽůŝƚĞďĞŚŝŶĚƉŝƉĞ͘ MEMORANDUM TO: Jim Regg P.1. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name MILNE PT UNIT F-69 Insp Num: mitBDB210825090105 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September I, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC F-69 MILNE PT UNIT F-69 Sre: Inspector Reviewed 8�� P.I. Suprv---F Comm API Well Number 50-029-22586-00-00 Inspector Name: Brian Bixby Permit Number: 195-125-0 Inspection Date: 8/22/2021 Packer Depth Well F69 Type Inj l W -TVD 6925 PTD 1 1951250 Type Test SPT. Test psi 1731 BBL Pumped: 3.2 BBL Returned: 3 Interval INITAL P/F P Notes: Initial MITIA as per SUNDRY #320-355 to 2000 psi. v, Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 537 540 540 542 IA 0 2212 2147 - 2132 OA 8 20 20 20 Wednesday, September 1, 2021 Page I of 1 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1951250 Type Inj N Tubing 537 540 540 542 Type Test P Packer TVD 6937 BBL Pump 3.2 IA 0 2212 2147 2132 Interval I Test psi 1734 BBL Return 3.0 OA 8 20 20 20 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska LLC Milne Point / MPU / F Brian Bixby Jon Arend 08/22/21 Notes:Convert to Injector sundry 320-355 Notes: Notes: Notes: F-69 Form 10-426 (Revised 01/2017)MIT MPU F-69 8-22-21 initial 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to water injector Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,435 feet N/A feet true vertical 7,477 feet N/A feet Effective Depth measured 10,324 feet 9,781 feet true vertical 7,383 feet 6,937 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 9,883' 7,019' Packers and SSSV (type, measured and true vertical depth)Premier Production N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name Contact Name: Authorized Title: Contact Email: Contact Phone: 2,180 Chad Helgeson Operations Manager 0 Water-Bbl MD 110' 5,778' 10,408' TVD 110' measured true vertical Packer Size N/A Casing Conductor Length 110' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Plugs ADL0355018 N/A measured 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 3000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-125 50-029-22586-00-00 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-355 755 Authorized Signature with date: David Gorm dgorm@hilcorp.com 200 MILNE PT UNIT F-69 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 380 Casing Pressure Tubing Pressure 0 5,741' 10,375' Surface Production Oil-Bbl 7,240psi 777-8333 20" 9-5/8" 7" 4,547' 7,454' 5,410psi WINJ WAG Hilcorp Alaska LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 520psi 3,090psi Burst 1,530psi 5,750psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:01 pm, Aug 31, 2021 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2021.08.31 11:49:02 -08'00' Chad Helgeson (1517) , ADL 025509 SFD 9/1/2021DSR-8/31/21 RBDMS HEW 8/31/2021 SFD 9/1/2021 MGR01SEP2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-69 ASR 50-029-22586-00-00 195-125 8/4/2021 8/12/2021 8/4/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Spotted ARS, raised mast and secured rack pins. Spotted and leveled pits, took on 30bbls of FW for BOP testing. Spotted company man and changeout shacks. VMS repaired 2 coolant leaks on rig. Connected Kill/Choke lines and control lines for the BOP stack. Warmed up Koomey Unit, checked pre charge and functioned BOP's. Spotted rig pump and hooked up the circulating lines. Set containment and RU Catwalk, Organized and cleaned rig floor. Greased and serviced equipment as needed. PU BOP Testing equipment, Repaired butterfly valve on pit that froze up, flooded equipment and stack and worked out air. Performed Shell test to 2,500psi. Tested BOPE both rams and annular to 250 psi low and 2,500 psi high as per the Sundry notice, tested with both 2 7/8" and 3 1/2" test jts. Greased valves as needed and replaced 2 valves on choke manifold that failed to test. Performed draw down test and Adam Earl with AOGCC witnesses the test. Removed and reinstalled outer Kill wing valve and HCR valve that failed during BOP test. 8/5/2021 - Thursday After replacing K2 and HCR Choke valves tested 250-2500psi-good test. 4 f/p were recorded, total BOP test time was 10.5hrs. Witness by State Inspector Adam Earl. Blow lines dry and L/D BOPE Testing equipment. Installed wrapping on service loop cable. Hung Elephant trunk and powered up cable spooler, pulled rope thru sheave, Swapped out handling tools to pull completion. Simop: Replaced valves on the Accumulator pump, cleaned y screens and circulated fluid thru a filter unit. Function tested Accumulator all good. Checked IA static, Pulled dart valve and found trapped pressure under the BPV. Pumped 10bbls thru BPV and monitored tbg on a vac. Pulled BPV. PU/MU 2-7/8" Landing jt w/FOSV installed. BOLDS, opened IA on vac . Picked up to 110k with no movement, hanger did not come off seat (calculated PUW ~60k). Doubled checked LDS and verified they were all backed out. Pulled up to 110k still no movement. Call OE and discussed plan forward. BO/LD 2-7/8" Landing jt, PU/MU 3-1/2" landing jt. Picked to 112k and hanger came off seat continued picking up and working string to 116k, was able to move up hole 4'. Called OE and decided to make max pull to 130k. Worked string up to 130k was able to make 6' of hole. Landed hanger and secured well. SD rig due to a hydraulic leak coming from the power pack. Found a O-ring blowout on the Packer Valve. Simop: mixed 20bbl pill on NXS lube. Pumped 20 bbl lube pill while cont. to work string between 90k to 130k up wt with no change, pumped remaining 5 bbl lube pill, slowly increased the up wt. to 140k while slacking off periodically to the hanger with a slack off wt. off 55k. Mixed and pumped 2nd 25bbl lube pill while working string and no change. Note: From landing point to 140K up wt had 7'11" stick up. The Distance between 130K up wt to 140K was 14". Held PJSM with AK E-line and rig crew, RD Elephant trunk and ESP cable sheave, RU E-line quip. and Free pt. tool string. Running Free Pt tool, RIH checking string, free pipe found down to 7,000', RIH to 8,000' and was showing 50% free while picking up to max up wt of 140k. RIH to 9,000' and showed no movement. RIH to mandrel at 9,706' and correlated tool on depth, then POOH to 9,500' no movement, POOH to 8,800, very little movement. POOH with Free pt. tool. Well Name Rig API Number Well Permit Number Start Date End Date MP F-69 ASR 50-029-22586-00-00 195-125 8/4/2021 8/12/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/6/2021 - Friday POOH with EL. Sent free point log to town for review. Deepest pipe movement recorded was @ ~8,800'. L/D tools and RDMO EL, released unit. Lined up and pumped 50bbl NXS lube pill down IA @ 2bpm spotted pill @ 6000'. Out of pumpable fluid. Waiting on vac truck to arrive from Prudhoe. Worked string up to 130k with no movement while waiting on vac truck to arrive from Prudhoe. Simop: Called SLB to build 20bbl 15% HCL pill. ETA on location is 10pm-midnight. Parked with 110k pulled into string and monitored no movement. Vac truck arrived and off loaded 290bbls of 8.6ppg KCL, Held 110k on string with elevators and SI tubing. Pumped lube pill down IA and spotted 50bbl pill @ 8354'-9950'. Observed string weight decreased from 110k to 101k. SD pump and monitored well IA static. Tbg slight blow. Sent vac truck to round trip 1 more load of KCL for the acid job. Opened bag and pulled 140k on string, 8' gained from pervious mark. Total movement of 8'9" @ 140k pick up weight. Slacked off and parked with 130k pulled into string. Monitoring for movement. Simop: Built containment for 3-1/2" workstring. Shot a fluid level on IA @ 2031'. Pumped 57bbls of 40deg FW down tubing. Parked at 130k. Pulled into the string. Monitoring for movement, no change, cont. to work st. up to 130k and landing off every 15 min with no change while W.O SLB to perform acid job. Landed tbg hanger and RU to tbg string and pumped 65 bbls of 8.6ppg 2% KCL to displace out 8.3 water in tbg and displaced to the top of perfs. Pumped at 3bpm and caught pressure after 45bbls, final press. was 310psi. Shut down and well went to -0-. Held PJSM with SLB and rig crew on upcoming acid job. RU SLB to IA and press. Tested lines to 2,500 psi. Troubleshooting pump issues with SLB. Pumping acid job at report time. Continued pumping acid job per design, Pumped 20bbls of 15% HCL Acid, swapped to 8.6 KCL and cont pumping 4.5bpm/100psi, SD pump after 75bbls away, IA on vac, P/U on hanger above mud cross with 107k pulled on tbg. Continued displacing an additional 185bbls @ 4.5bpm/1000psi. S/D pump and let acid soak across ESP assembly for 15mins. Displaced acid by pumping 1bpm. Observed hanging weight fall from 100k to 64k and pump pressure from 1000psi to 0psi. S/D pumps, monitored well on vac. Total acid job volumes: 20bbls of 15% HCL Acid, 300bbls of 8.6ppg KCL for displacement. RDMO SLB equipment,Tbg free, Pulled Hanger to rig floor with PUW @ 75k. De-completed hanger and L/D landing jt and hanger. Sent tbg hanger to well head shop. Hung sheave and elephant trunk. L/D 1 jt and threaded cable thru sheave to spooler. POOH L/D 2- 7/8" ESP Completion f/9912' t/8,300'' while spooling cable and removing clamps, filling hole with single pipe displacement every 15 jts out. Observed 1-3k drag pulling off bottom (9912'-9820'), smooth PUW thereafter. Crew eat lunch. PUW 64k @ 8,300'md, Continued POH L/D 2-7/8" ESP Completion f/8300' t/4,800' while spooling cable and removing clamps, filling hole with single displacement every 15 jts. Started seeing scale buildup on the tbg collars with clamps @ 5,200'md. Total 167 joints L/D,PUW 42k @ 4,800'md, Continued POH L/D 2-7/8" ESP Completion f/4,800' t/3500' while spooling cable and removing clamps, filling hole with single displacement every 15jts. Kickout Jts 92,93,168, 178, 183. Held discussion with crew about tripping drill and discussed their roles and responsibilities. PUW 30k at 3500' Issues with tongs and damaged jt. 202, broke out jt. & LD, repaired tongs. Continued POH L/D 2-7/8" ESP Completion f/3,500' t/3,345' while spooling cable and removing clamps. Kicked out Jts 202 & 203, Crew eat lunch, PUW 29k at3,345', Continued POH L/D 2-7/8" ESP Completion f/3,345' to 206' while spooling cable and removing clamps, filling hole with single displacement every 15jts. C/O spools on ESP cable. Kicked out Jts 242,423, 263,264, 285,286. 8/7/2021 - Saturday Well Name Rig API Number Well Permit Number Start Date End Date MP F-69 ASR 50-029-22586-00-00 195-125 8/4/2021 8/12/2021 Hilcorp Alaska, LLC Weekly Operations Summary Continued RIH the 7" Scg Scraper f/9,500' t/9921', Reciprocated Scraper f/9,750'md t/9,850'. Lined up valves to pump down tbg, displaced tubing with 60bbls of 8.6% KCL @ 3.5bpm/500psi. SD pump and lined up to the IA, SI TIW and displaced IA with 300bbls of 8.6ppg KCL @ 3.5bpm/500psi. SD monitored well, Transferred remaining fluid from vac truck to pit, prep Rig floor to POH. POOH w/ Csg Scraper BHA L/D 2-7/8" EUE f/9921' t/8070'. Pumping single displacement every 15jts out. No drag or over pulls while tripping. PUW of bottom 50k, crew eat lunch, POOH w/ Csg Scraper BHA L/D 2-7/8" EUE f/9921' to surface LD 7" Csg scraper. Pumping single displacement every 15jts out. (LD a total of 313 jts 2 7/8" tbg). Changed out handling equip. from 2 7/8" to 3 1/2" and laid out a row of 3 1/2" 9.3# L-80 EUE 8rd tbg onto the pipe rack and strapped same. Held PJSM, then PU & MU 3 1/2" Mule shoe, XN assy, 1-jt. of 3/12" 9.3# L-80 tbg, Baker 7" Premier Production pkr, 1-jt of 3 1/2" tbg and X-nipple assy. RIH to 133'. MU Pkr per Baker Rep. Began RIH with 7" Inj. Pkr on 3 1/2" 9.3# L-80, 8rd tbg from 133' to 685'. (running speed 90'/min/ per Baker), Crew eat lunch, Cont. RIH with 7" Inj. Pkr on 3 1/2" 9.3# L-80, 8rd tbg, picking up and drifting tbg from 685' to 1,265', (12k st wt down). Repaired leaking seal on the Backup ram on the rig tongs. Cont. RIH with 7" Inj. Pkr on 3 1/2" 9.3# L-80, 8rd tbg, picking up and drifting tbg from 1,265' to 3,450'. (running speed 90'/min/ per Baker) (23k st wt down). 8/8/2021 - Sunday L/D ESP assembly, there was some scale around the clamps and assembly connection. No visual pitting or corrosion. Clamps Recovered: Lasalle = 162 (2006 Install report shows 172 used), Portectectolizers = 6, Armsterguards = 3. R/D cable sheave and elephant trunk, cleaned and cleared rig floor. RDMO Spooler Unit and hauled back to A-pad. Emptied return tank and hauled to G&I. Pumping 5bph hole fill. MIRU Ak E-line Unit. RIH with CBL/CCL tied in with short joint @ 9800'. Logged f/9954'md t/9000'. POOH . TOC 9,214' md sent log to OE for review. RDMO Ak E-line Unit. Tallied 1st row of 2-7/8" EUE and Scraper BHA, P/U 2-7/8" muleshoe, 7" 26# Csg Scraper xo to 2-7/8" EUE, attempted to RIH but could not get the top blades of the scraper to go thru the wellhead. Tried lubing and hammering on the blades with the results. Called yellow jacket to troubleshot issue. Waiting on Yellow Jacket to bring out a new scraper, L/D Scraper BHA. Crew cleaning and organizing tent and c-cans. MU new 7" 26# csg scraper with mule shoe and XO back to 2 7/8" tbg and began RIH PU and drifting tbg RIH to 4,790' (150 jts PU) PU Wt 26K, S/O 20K. Crew ate lunch. Cont. RIH with 7" Scraper on 2 7/8" Tbg from 4,790' to 9,500' . At 6,373', PU Wt. 33k, S/O 24K. At 7,944, PU Wt. 40K, S/O 27K. 8/9/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-69 ASR 50-029-22586-00-00 195-125 8/4/2021 8/12/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/11/2021 - Wednesday Cleaned and cleared Rig Floor, Moveout pipe racks, catwalk and C-cans, emptied pit, and R/D pump and circulating lines. RDMO ASR and Mudboat,Began crane work, Fly off rig floor and wellhouse. ND/BOP's, NU/tree tested void to 250-5000psi for 5mins good test. Pulled BPV secured well. 8/12/2021 - Thursday WELL SHUT-IN ON ARRIVAL, PT PCE 250L / 3000H. PULL BALL & ROD, 3-1/2" RHC PLUG BODY FROM XN-NIPPLE AT 9,820' MD. SET 3-1/2" MCX(ser# - MP3-02, bean - .725") IN X-NIPPLE AT 2,300' MD. WELL SHUT-IN ON DEPARTURE, NOTIFIED PAD OP. Checked fluids and serviced rig as needed. Continued RIH w/ 3-1/2" Water Injection Completion f/3,500' t/5300', SD secured well, lost all communication in the Xbox. Troubleshot issues and found a broken Ethernet cable going into the Xbox (operators console), spliced cable and tested good. Operated the Rig for 15 to ensure its operating properly. Filled hole with 15bbls of 8.6% KCL, monitored well on vac. Continued RIH w/ 3-1/2" Water Injection Completion f/5,300' t/7,595'. SD to Troubleshot rig. Troubleshoot rig...….found hydraulic hoses loose on the high pressure filters, tightened same and checked ok. Cont. RIH with 3 1/2" water injection completion from 7,595' to 9,828', St wt up 74k, Down wt. 47K, ( ave MU torque 3100ft/lbs) ( ran a total of 316 jts 3 1/2", 9.3#, L-80 8rd tbg). MU 3 1/2" Landing jt to TC-1A-EMS 3 1/2" x 11" tbg hgr, RIH and landed out RILDS. With TIW shut on the tbg, RU on the IA and with the rig pump, pumped down 200bbls of source water with corrosion inhibitor, initial rate 5bpm, ave. 4bpm, ICP 300 psi, FCP 600psi. RU Little Red on the IA and pumped 75bbls diesel down the IA for freeze protection. ave 2 bpm at 500 psi. Set 7" Baker Premier Pkr at 9,781', Dropped 1/14" rod and ball and pumped 13bbls diesel and pressured up to 2,850 psi and set pkr and held same for 15min, good test. With tbg shut in, LRS pumped 23bbls diesel to catch pressure and pressured up on IA to 2000 psi and performed MIT for 30min. Good test. Bled off pressure. Set the BPV. 8/10/2021 - Tuesday _____________________________________________________________________________________ Revised By: DH 8/30/2021 SCHEMATIC Milne Point Unit Well: MP F-69 Last Completed: 8/12/2021 PTD: 195-125 TD = 10,435(MD) / TD =7,477 (TVD) 20” Orig. KB Elev.: 47.73’/ Orig. GL Elev.: 12.5’ Ori g. DF Elev.:46.23’ (Nabors 4ES) 7” 4 9-5/8” 1 3 KUP Sands PBTD =10,324’(MD) / PBTD =7,383’(TVD) 5 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btc. 8.835 Surface 5,778’ 7" Production 26 / L-80 / Btc 6.276 Surface 10,408’ TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.992 Surface 9,883’ JEWELRY DETAIL No Depth Item 1 2,289’ 3-1/2” X-Nipple (2.813” ID) 2 9,729’ 3-1/2” X-Nipple (2.813” ID) 3 9,781’ 3-1/2’x7” Baker Premier Production Packer 4 9,841’ 3-1/2” XN-Nipple w/RHC Install (2.813” ID) 5 9,852’ WLEG (BTM at 9,883’) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. B Sands 9,954’ 9,964’ 7,077’ 7,085’ 10 1/17/1996 Open Kup. A Sands 10,009’ 10,099’ 7,121’ 7,195’ 90 1/17/1996 Open 10,090’ 10,110’ 7,187’ 7,204’ 30 11/29/2006 Open 9,954’ to 9,964’ & 10,090’ to 10,110’ Shot w/ 4.5” Guns 5SPF // 10,009’ to 10,099’ Shot w/ 3.5” Guns 6SPF OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 1,125 sx PF “E”, 250 sx “G”, 250 sx PF “E”, in 12-1/4” Hole 7” 240 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 55 to 57 deg. f/ 3,900’ to 8,600’ Hole Angle through perforations = 35.5 deg. TREE & WELLHEAD Tree 3-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5, w/ 3-1/2” NSCT Tbg. Hngr. Tbg Hngr 3.5” NSCT top & bottom w/ x-over to 2-7/8” EUE CIW H-Profile 3” GENERAL WELL INFO API: 50-029-22586-00-00 Drilled and Cased by Nabors 4ES - 9/11/1995 Initial Completion & Perforations – 2/27/1996 ESP RWO w/ Nabors 4ES – 7/12/1997, 3/27/2001 & 4/16/2004 ESP RWO w/ Nabors 3S – 12/1 2006 Convert to Injector w/ASR – 8/12/2021 STIMULATION SUMMARY Frac – 107,000# of 16/20 carbolite behind pipe. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: MPU F-69 Free Point log (PTD 195-125) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 9:09 am, Aug 26, 2021 STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry �'i I" ze)q BOPE Test Report for: MILNE PT UNIT F-69 Comm Contractor/Rig No.: Hilcorp ASR 1 PTD#: 1951250 - DATE: 8/5/2021 - Inspector Adam Earl - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Hudgens/Wilson Rig Rep: Beshea/Haberthur Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopAGE210807084536 Rams: Annular: Valves: MASP: Type Test: NIT 320-355 - —— -- - 9 -- Related Ins No: 250/2500 ' 250/2500 0 - 250/2500 ' 18892 - p TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Quantity P/F Quantity Size Visual Alarm Time/Pressure P/F Location Gen.: -_P _- Trip Tank NA NA System Pressure 3000 P Housekeeping: P Pit Level Indicators _P _ P Pressure After Closure 1750 P " PTD On Location P Flow Indicator NA NA 200 PSI Attained 43 P " Standing Order Posted P Meth Gas Detector _-P P Full Pressure Attained 172 P Well Sign P H2S Gas Detector P P Blind Switch Covers: All Stations P ' Drl. Rig P_ MS Misc - 0 NA Nitgn. Bottles (avg): 4�a, 2350 - P" Hazard Sec. P 0 NA ACC Misc 0 NA Misc NA P HCR Valves FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Quantity P/F Quantity Size P/F Upper Kelly __ -0 NA Stripper 0 NA Lower Kelly 0_ ' NA' Annular Preventer 1 11 P Ball Type 1 P #1 Rams 1 2 7/8 X 5 P' Inside BOP 1 P #2 Rams 1 Blind P FSV Mise 0 NA #3 Rams 0 NA #4 Rams --0 - NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 21/16 P HCR Valves 1 21/16 - FP Kill Line Valves 3 2 1/16 FP - Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 15 FP Manual Chokes 1 ___ P " Hydraulic Chokes --I - P CH Mise 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 4 Test Results Test Time 10.5 Remarks: HC pd and outside Kill failed both replaced. C-9 & C-12 FP. Koomy needed some filtering and pump work It was completed before work started. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Water Injector 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,435'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: 8/11/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Authorized Signature: 9/20/2020 2-7/8" N/A and N/A See Schematic Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. dgorm@hilcorp.com N/A and N/A 5,778' 10,408' 6.5# / L-80 / EUE 8rd Tubing MD (ft):Perforation Depth MD (ft): See Schematic 110' 20" 9-5/8" 7" 5,741' 10,375' TVD Burst 9,917' MD N/A 5,750psi 7,240psi 4,547' 7,454' Tubing Size: Hilcorp Alaska LLC C.O. 432D MILNE PT UNIT F-69 Length Size PRESENT WELL CONDITION SUMMARY 7,477'10,324'7,383'1,892 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 MILNE POINT / KUPARUK RIVER OIL 3800 Centerpoint Dr, Suite 1400 195-125 Anchorage Alaska 99503 50-029-22586-00-00 N/A COMMISSION USE ONLY Authorized Name: Tubing Grade: 110'110' Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate Chad A Helgeson 2020.08.25 16:11:41 -08'00' By Samantha Carlisle at 9:22 am, Aug 26, 2020 320-355 DLB 08/26/2020 MIT - IA to 2000 psi. 10-404 BOPE Test to 2500 psi. Annular test to 2500 psi. Cement Bond Log to AOGCC for review before POI. X DSR-8/27/2020MGR27AUG2020 Required? Yes 8/31/2020 JLC 8/28/2020 RBDMS HEW 8/31/2020 WINJ Conversion Well: MPU F-69 Date: 8-11-20 Well Name:MPU F-69 API Number: 50-029-22586-00 Current Status:Shut-in ESP Producer Pad:F-Pad Estimated Start Date:Sep. 20th, 2020 Rig:ASR Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:1951250 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Well EZ Entries Required Yes Current Bottom Hole Pressure:2,592 psi @ 7,000’ TVD SBHPS on 6/4/2020:7.2 PPG Maximum Expected BHP:2,592 psi @ 7,000’ TVD SBHPS on 6/4/2020:7.2 PPG MPSP:1,892 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 55-57° @ 3,900’-8,600’ MD Min ID:2.205” ID XN at 9,787’ MD Brief Well Summary: MPU F-69 is an existing ESP producer completed to the Kuparuk A and B sands. The well is high WC and has remained SI with a failed ESP since June 2017. F-69 is in an optimal location to support producer MPU F-37 as a water injector. Notes Regarding Wellbore Condition x The 7” production casing last tested to 1,500 psi test against an RBP set at 9,600’MD on 2/9/1996. Objective: x Pull existing ESP completion. x Install new 3-1/2” water injection completion. Area of Review (PTD#1951250) Prior to the conversion of F-69 from Kuparuk production to Kuparuk Injection, an Area of Review (AOR) was conducted. This AOR found no other wells within ¼ mile (1,320’) of F-69’s entry point into the Kuparuk Formation, however MPL-24 is 1,395 ft. away and was also included in the review. See attached table Area of Review MPU F-69 for annulus integrity and zonal isolation of all wells within the AOR. Sundry Procedure (Approval Required to Proceed) Pre-Rig Procedure 1. RU hot oil and PT lines to 2,500 psi. 2. Circulate at least 1 wellbore volume (~360 bbls) with 8.3 ppg source water down tubing and taking returns up IA to 500 bbls returns tank. a. Tubing Volume = .00579 bpf * 9900’ = 57 bbls b. Annular Volume = .0302 bpf * 9900’ + .0383*100’ = 303 bbls 3. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. WINJ Conversion Well: MPU F-69 Date: 8-11-20 4. RD hot oil truck. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 8. NU BOPE. RD Crane. 9. Spot mud boat. RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 11. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/8.3 ppg source water prior to pulling BPV. 12. Set TWC. 13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “ASR 1 BOP Test Procedure” dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14.Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing. Pull TWC. Kill well w/8.3 ppg source water as needed. 16. Rig up spoolers for ESP #1 cable. a. Baker Hughes representative should be onsite for ESP pull. 17. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. The PUW =55 K + blocks, SOW = 33K + blocks when landed by Nabors 3S in November 2006 b. ~9,900’ of 6.5 # 2-7/8” tubing weighs ~ 65Klbs(dry) or 57Klbs(buoyed by 8.3 ppg fluid) c. If needed, circulate (long or reverse) pill with lubricant, source-water, and/or baraclean pill prior to laying down the tubing hanger. WINJ Conversion Well: MPU F-69 Date: 8-11-20 18. Lay down tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 2-7/8” tubing while spooling # 1 cable. Lay down ESP and motor. a. Note any sand or scale inside or on the outside of the ESP in WSR. b. The completion has the following amount of clamps/guards/cap-string: i. 172 Lasalle Clamps ii. 3 Armsterguards iii. 6 Protectolizers Pulled Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Junk ESP Cable Junk GLMS Visually inspect on site then re-stock ESP Equipment Visually inspect on site then provide to Baker for scrap Clamps Visually inspect on site then re-stock XN Nipple Visually inspect on site then re-stock 20. Pump 70 BBL source water down the 7” CSG. 21. RU Lubricator and E-Line 22. RIH CBL/CCL and run CBL from 10,435’ MD to 9,200’ MD. Send Copy of the CBL to the Operations Engineer to confirm results before moving to the next step. 23. PU 7” casing scraper BHA and RIH to 9,900’ MD 24. Pull up-hole and reciprocate/circulate from 9,650’ MD to 9,900’ MD 25. POOH and lay down casing scraper. 26. PU and RIH w 3.5” 9.3# L-80 injection completion and packer. Ensure 3-1/2” RHC plug body installed in lower X nipple prior to running. 27. Proposed Running Order a. WLEG at 9860’ MD b. 1 joint of 3-1/2”, 9.3# tubing c. 3-1/2” X Nipple (2.813” ID) @ ±9,820’ MD d. 1 joint of 3-1/2”, 9.3# tubing e. 3-1/2”x7” Hydraulic Set Packer @ ±9,780’MD f. 1 joint of 3-1/2”, 9.3# tubing g. 3-1/2” X Nipple (2.813” ID) @ ±9,740’ MD h. ~ 240 jts of 3-1/2”, 9.3# tubing i. 3-1/2” X Nipple (2.813” ID) @ ±2,300’ MD j. ~ 74 jts of 3-1/2”, 9.3# tubing WINJ Conversion Well: MPU F-69 Date: 8-11-20 28. Circulate 250 bbls clean source water w/corrosion inhibitor and 70 bbls diesel freeze protect down the IA prior to setting the packer a. Freeze protect annular volume = .026bpf*2,500’ = 66 bbls. 29. Space out to set packer at ±9,780’ and land the tubing into the hanger. RILDS. Lay down landing joint. a. Packer must be set within 200’ MD of the upper perfs at 9954’ MD. b. Note PU (Pick Up) and SO (Slack Off) weights on tally. 30. Test tubing hanger to 250psi low/ 5,000psi High. 31. Drop ball and rod and hydraulically set the packer per manufacturer’s setting procedure. 32. Conduct MIT-IA to 2,000psi (0.25 psi/ 7,477’ Shoe TVD). i. Notify AOGCC at least 24 hours prior to performing Pre Injection MIT-IA ii. Submit completed Pre-Injection MIT-IA on 10-426 form 33. Set TWC. Post-Rig Procedure: 34. RD mud boat. RD BOPE house. Move to next well location. 35. RU crane. ND BOPE. 36. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 37. Pull TWC. 38. RD crane. Move returns tank and rig mats to next well location. 39. Replace gauge(s) if removed. 40. Turn well over to production. RU well house and flowlines. E-line Perforations 41. Spot E-Line unit to well and RU unit. 42. Pressure test lubricator to 300psi low and 2,000psi high. 43. MU perforating tool string with 2” to 2-1/2”, 6spf guns with deep penetrating charges and RIH. 44. RIH and gamma ray correlate to Gamma Ray / CCL Perf Record dated 11/12/1995. Contact OE prior to shooting for final approval of tie in. 45. Perforate 1 st gun run per table below (specific interval subject to change, confirm with signed final perforation sheet from geologist). 1. Note TxIA pressure change in WSR. Gun Run # Perf Top Perf Bottom Perf Length 1 ±9,939’ ±9,953’ 14’ 2 ±9,965’ ±9,985’ 20’ 3 ±10,110’ ±10,130’ 20’ Total 54’ Table 1: F-69 Proposed Kuparuk C Perf Gun Runs Note: Final depths to be confirmed in “Final Approved Perf Sheet” 46. Repeat steps 43-45 for Gun Runs #2-#3 per table above. 47. POOH. RD E-Line. Slickline WINJ Conversion Well: MPU F-69 Date: 8-11-20 48. RU SL, PT PCE to 250 psig low / 2,500 psig high. 49. RIH and set MCX injection valve in X-Nipple @ ~2,300 MD. 50. RDMO Slickline Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form 5. Area of Review Map DAT E REV. BY COMMENTS Orig. KB Elev. = 47.7’ (N 27E) Orig. GL Elev. = 12.50' RT to Tbg Spool= 32.78' (N 27E) Tr ee : Wellhead :11" x 11" FMCGen.55M M ILNE POI N T U NI T W ELL F -69 API NO :5 0 -0 2 9-2 2586 9 5/8", 40 ppf, L-80 Btrc. Pe r f o r a t io n Su mmary Ref lo g:9/22 /9 5 GR/CCL Size SPF Interval (TVD) BP EXPLORATION (AK) 7" float collar (PBTD) KOP@ 500' Max. hole angle = 55 to 57deg. f/ 3900' to 8,600' Hole angle thru' perfs = 35.5 deg. 7" float shoe 20" 91.1 ppf, H-40 MPUF-69 113' Sti mu lat io n Su mmar y 7" 26 ppf, L-80, Btrc.prod. casing, ( drift ID= 6.151", cap. = 0.0383 bpf ) 2-7/8", 6.5#, L-80 8rd,EUE (2.441" ID, Cap. .00579 bbls/ft.) 5778' 0 X 'A' Sands 1 /3 /9 6 -Kup ‘a ’s a nd,12 2 m#16-20 7” x 21’ Short Jt from 9800’-9821’. 09/13/95 02/27/96 05/23/96 JBF JBF Drill and case Nabors 27-E Inital completion Nabors 4-ES RWO 4-ES 3-3/8”6 10009’-10099’ 7124’-7200’ ‘B’Sands 4.5” 5 9954’-9964’7078’-7088’ 10326’ 10408’ mid -perf = 7139’ t vd 10026 ’md X-Over 2-7/8” 8RD EUEx 3-1/2” STL X-over joint (29’) 2,541‘ Camco 2 7/8" x 1" sidepocket KBMM GLM 2-7/8” XN Nipple 2.205”ID 3-1/8“ 5M CIW Camco27/8"x1" sidepocket KBMM GLM 7/13/97 , 3/30/01 04/15/04 MDO ESP RWO 4-ES 9,912‘Centrilift Pumpmate Centrilift Motor HP 304 / KMH V. 2290 / 81 Amps 9,887‘ Centrilift Tandem Seal Section GSB3DBUT SB/SBPFSA GSB3DBLT SB/SB PFSA CL5 Centrilift Tandem Gas Section GRSFTXBARH6 9,873‘ 9,868‘ Centrilift Tandem Pump Section GPMTAR 1:1 74/82 GC3500 9,835‘ 9,787‘ 9,706‘ 164‘ 21‘ 3.5“eue 8rd. x 2-7/8” eue 8rd. 3.5“ NSCT Top & Btm. w/ x-over to 2-7/8” eue CIW H-Profile 3“ ‘A’ Sands 4.5“5 10090‘ - 10110’ Camco 2 7/8" x 1" sidepocket KBMM GLM 2012‘ 7187‘-7204’ 12/09/06 REH ESP RWO/ ADD PERFS -NABORS 3S DGLV pulled on 1/12/20 ***LEFT EMPTY*** Set DGLV on 1/12/20 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] 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 scanned by: ~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 . Post Office Box 196612 r= Anchorage, Alaska 99519 -6612 December 30, 2011 t,, FE ' Z � Mr. Tom Maunder s� 5 Alaska Oil and Gas Conservation Commission •Q 4- 333 West 7 Avenue _ Anchorage, Alaska 99501 f � 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 extemal 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 0 • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion 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 822011 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 822011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 822011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/12011 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 8/12011 MPF -33 2010620 50029226890000 23 Need top Job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/12011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 _ MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/112011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF -49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/12011 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 1.2 N/A 13.6 8/3/2011 MPF -84B 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 9/12011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF-88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/32011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/132011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 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 9/12011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 \. STATE OF ALASKA ! ~'~RECEIVED ALAS~OIL AND GAS CONSERVATION COMM~ONP REPORT OF SUNDRY WELL OPERATIONS DEC 1 8 2006 AI:Jsko Oil & &as CðdS. Comlhis~'on o Re-Ente~6bp~d Well ~ Other Change Out ESP 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): ~ Repair Well . 0 Plug Perforations 0 Stimulate ~ Pull Tubing . 0 Perforate New Pool 0 Waiver o Operation Shutdown ~ Perforate 0 Time Extension KBE = 46' 10435 7477 10324 7383 72' 5742' 10375' 99519-6612 4. Well Class Before Work: ~ Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 195-125 6. API Number: 50-029-22586-00-00 9. Well Name and Number: MPF-69 10. Field I Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 9-5/8" 5778' 4546' 5750 3090 7" 10408' 7454' 7240 5410 SCANNED DEC 2 62006 9954' -10110' - 7077' - 7204' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl 2-7/8",6.5# L-80 9917' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None None Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory ~ Development 0 Service ~ Daily Report of Well Operations 16. Well Status after proposed work: ~ Well Schematic Diagram ~ 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 Frank Roach, 564-4373 Printed Name Sondra Stewman Si~ Form 10-404 Revised 04/2006 nRlh(f\IAI Title Technical Assistant Prepared By Name/Number: 564-4750 Date) L- t )~-[X¡;Sondra Stewman, 564-4750 , BFL. [1![[, 2 6 2006, Submit Original Only Phone .Iœe.;. 3-1/8" 5M CIW Wellhead : 11" x 11" RvC Gen. 55M 3.5" NSCT Top & Btm. wI x-over to 2-7/8" eue CIW H-Profile 3" 20" 91.1 ppf, H-40 1 113' I' KOP@ 500' Max. hole angle = 55 to 57deg. fl 3900' to 8,600' Hoe angle thru' perfs = 35.5 deg. 95/8",40 ppf, L-80 Btrc. 1 5778' 1 ' j 2-7/8",6.5#, L-80 8rd,BJE (2.441" ID, C:lp. .00579 bbls/ft.) 7" 26 ppf, L-80, Btrc.prod. casing, ( drift ID = 6.151", cap. = 0.0383 bpf ) Stimulation Summary 1/3/96 - Kup 'a' sand, 122m #16-20 mid -perf = 71 39' tvd 10026'md Perforation Summary PP-f loc;¡: 9/22/95 GRlCC' Size SPF Interval (TVD) 'B' Sands 4.5" 5 9954'-9964' 7078'- 7088' 'A'Sands 3 - 3/8" 6 10009'-10099' 7124'-7200' 'A' Sands 4.5" 5 10090' -10110' 7187'-7204' MPU F-69 , I ; , , , , , , , , , , , , , , , , , , , , , I , , , , , , , , , , , , , , , , , , ; , ,-' ? , Org. KB Eev. = 47.7' (N 27E) arg. GL Eev. = 12.50' RTto Tbg SPOOF 32.78' (N 27E) 3.5"eue 8rd. x 2-7/8" eue 8rd. , X-Over I 21' I C:lrrco 2 7/8" x 1" sidepocket KBrvtv1 GLM C:lrrco 2 7/8" x 1" sidepocket KBfvfv1 GLM ) 2-7/8" 8RDBJEx 3-1(2" STL X-over joilt (29') . 12,541' I C:lrrco 2 7/8" x 1" sidepocket KBfvfv1 GLM 2-7/8" XN Nipple 2.205" ID I 164' I 1 2012'1 19,706' I 19,787'1 Centrilift Tandem Pump Section 1 9,835'1 GPMT AR 1: 1 74/82 GC3500 Centrilift Tandem Gas Section GRSFTXBARH6 1 9,868' I Centrilift Tandem Seal Section GSB3DBUT SB/SBPFSA GSB3DBL T SB/SB PFSA CL5 Centrilift Motor HP 304/ KMH V. 2290/81 Amps Centrilift Pumpmate 19,873' 1 19,887'1 19,912' I X 7" x21' Short Jt from 9800'-9821'. '.~,- *," ] ~~ g: 7" float colar (AHD) 7" float shoe I 10326' I I 10408' I DATE REV. BY COMM ENTS Mil NF POINT UNIT 09/13/95 JBF Drill and case Nabors 27-E WF F-69 0?1?7/96 JBF Inital completion Nabors 4-FS API NO: 50-079-.77586 OS/23/96 RWO 4-ES 7/13/97,3/30/01 04/15/04 MOO ESP RWO 4-ES BP EXPLORATION (AK) 12/09/06 REH ESP RWOI ADD PERFS -NABORS 3S '~ "- j Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/20/2006 20:00 - 00:00 4.00 MOB P PRE Move rig from NOC-Deadhorse to MPf~69. 11/21/2006 00:00 - 15:00 15.00 MOB P PRE Move rig from NOC-Deadhorse to MPF-69. 15:00 - 19:30 4.50 MOB P PRE Lay down Herculite and position rig components for Rig Up. Move rig over well and line up to tree. 19:30 - 00:00 4.50 MOB P PRE RIU rig components. 11/22/2006 00:00 - 06:30 6.50 RIGU P PRE Continue with RIU rig components. Rig accepted at 0400-hrs. Crew change at 0600-hrs. 06:30 - 07:30 1.00 RIGU P PRE Convene the day crew inside the Shop for their Authority To Proceed (A TP) put on by John Buford and Mark O'Malley from MPU Operations. 07:30 - 10:00 2.50 KILL P DECOMP Test line to Tiger Tank with air. Adjust Pipe skate extension. P/U BPV pulling tool and M/U to tree and pull BPV. Tubing pressure under the BPV was 875-psi. SII tree and remove BPV pulling tool. Check all valve alignments to prepare for well kill operations. Pump open the SSV and Wing valve actuators and install fusible caps on same. 10:00 - 10:30 0.50 KILL P DECOMP Hold PJSM for well kill operations with rig crew, Veco drivers, and WSL. 10:30 - 12:30 2.00 KILL P DECOMP Bleed down well to Tiger Tank; SITP 910-psi, SICP 730-psi. Bleed down to TP = 480-psi, CP = 250-psi and start Mud Pump and circulate 120-F seawater; bring pump up to 2-1/2 BPM. Continue to open Choke and increase pump to 3-BPM and pump a total of 70-Bbls. S/I to prepare to Bullhead 60-Bbls into formation. Instantaneous SITP 250-psi, SICP 270-psi. Gauge Tiger Tank and recover 151-Bbls of diesel and crude oil. 12:30 - 13:30 1.00 KILL P DECOMP Bullhead 60-Bbls of 120-F seawater into formation, max rate 3-BPM @ 1,OOO-psi. 13:30 - 15:30 2.00 KILL P DECOMP Circulate 120-F seawater through well bore, bringing pump up to 4-BPM @ 950-psi TP and 200-psi CPo With 175-Bbls pumped TP :: 950-psi, CP = 120-psi. SID to gauge Tiger Tank. Haul off 290-Bbls and have 165-Bbls in TT. Continue pumping at 4-BPM; TP = 870-psi, CP = 100-psi. S/I when returning fluid cleans up after pumping 419-Bbls. Haul off 290-Bbls and have 128-Bbls remaining in TT. Total fluid recovered:: 708-Bbls and total fluid pumped = 552-Bbls. 15:30 - 21:15 5.75 KILL P DECOMP S/I for pressure build-up to calculate Well Kill fluid weight. fluid weight in Pits:: 8.4-ppg, fluid weight of sample out of well = 8.4-ppg. Instantaneous SITP :: 340-psi. 1530-hrs: SITP 380-psi, SICP 360-psi. 1700-hrs: SITP 460-psi, SICP 440-psi. 1800-hrs: SITP 470-psi, SICP 450-psi. 1900-hrs: SITP 480-psi, SICP 460-psi. 1930-hrs: SITP 490-psi, SICP 470-psi. 2000-hrs.: SITP 490-psi, SICP 470-psi. 2030-hrs. SITP-490-psi, SICP 470-psi. 2100-hrs. SITP 490-psi, SICP 480-psi. Ordered 580-Bbls. 120F NaCl/NaBr 10.3-ppg kill weight brine filtered to 3 microns and 60 NTU from MI mudplant at 2115-hrs. Haul off 125-Bbls. returns from TT to disposal. 3-Bbls remaining in TT. 21 :15 - 00:00 2.75 KILL P DECOMP Waiting on kill weight brine to arrive. 11/23/2006 00:00 - 08:30 8.50 KILL P DECOMP Monitor well. 500-psi on tubing and 490-psi on casing. Wait on Kill weight fluid. Clear and clean Rig Floor. Empty Pits to Tiger Tank and blowdown hard line to Tiger Tank. Continue to monitor well. Pressures at 0830-hrs: SITP 510-psi, SICP 490-psi. Printed: 12/4/2006 10:08:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/23/2006 08:30 - 09:30 1.00 KILL P DECOMP Hold PJSM with rig crew, Veco drivers, Toolpusher and WSL to discuss the order of activities for the wellbore displacement with hot 10.3-ppg NaCI/NaBr. Every person in the PJSM was asked for and gave their input with respect to HSE concerns. Derrickman took samples of the fluid in the pits and from the second truck. Both were found to be at 10.2-ppg, so MI was contacted and the assigned Mud Engineer was sent to N-3S. 09:30 - 11 :30 2.00 KILL P DECOMP Wait on MI Mud Engineer. 11 :30 - 12:30 1.00 KILL P DECOMP Load MI NaBr into mud pit room and mix brine to attain 10.3-heavy brine. SITP at 1130-hrs 530-psi. 12:30 - 13:00 0.50 KILL P DECOMP Circulate 62-Bbls of hot 10.3-ppg NaCI/NaBr brine into well and take 93-Bbls of returns to Tiger Tank. Max circulation rate 4-BPM @ 900-psi TP, and 140-psi CPo TP dropped to 650-psi, with CP @ 140-psi when pump was SID to close in annulus to Bullhead into formation. 13:00 - 13:30 0.50 KILL P DECOMP SII annulus, blowdown flowline to Tiger Tank and start bull heading into formation. SITP 10-psi and SICP 440-psi before starting pump. Bullhead 60-Bbls of hot 10.3-ppg NaCI/NaBr at 3-BPM, 1060-psi TP, 1130-psi CPo SID pump and SITP quickly drops to 10-psi, SICP drops to 440-psi. 122-Bbls of 10.3-ppg NaCl/NaBr brine pumped; 60-Bbls pumped into formation; 93-Bbls of returns to Tiger Tank. Vac Truck pulled 93-Bbls of well bore returns and 53-Bbls of Pits returns from Tiger Tank. 13:30 - 15:00 1.50 KILL P DECOMP Open annulus and take returns to Tiger Tank. Start pump and bring rate up to 4-BPM; TP 590-psi, CP 160-psi. First sample with 350-Bbls (total wellbore vol = 354-Bbls) pumped around was 10.27-ppg. Continue taking samples and get 10.28 to 10.30-ppg after pumping 372-Bbls. An additional 60-Bbls had been Bullheaded during the second stage of pumping. Vac truck pulled an additional 144-Bbls from Tiger Tank. 15:00 - 17:30 2.50 KILL P DECOMP SID pump and monitor well. Tubing and casing on slight vacuum. Have Wells Support personnel shoot fluid levels and find fluid at -200' below Tree on first shot at 1545-hrs. Second shot at 1550-hrs has fluid slightly lower. Third shot at 161 O-hrs shows fluid slightly higher than the first shot, but tubing is on vacuum, so well is U-tubing. FIL shot at 1625-hrs is -180'. Will SII and monitor while awating FMC to install TWC. 170-Bbls of returns taken from Tiger Tank for total returns of 246-Bbls + 170-Bbls = 416-Bbls versus the circulated volume of 372-Bbls of 10.3-ppg NaCl/NaBr brine. Well dead with static fluid level at -180' to 200' below the tree. 17:30 - 19:00 1.50 KILL P DECOMP RIU to prepare to set and test TWC. Make crew change. Hold MPU ATP meeting in the Shop at 1830-hrs for the Night Crew. 19:00 - 20:30 1.50 WHSUR P DECOMP FMC wellhead technician dry rod set TWC. PIT TWC from above to 3500-psi for 10 charted minutes. Good test. PIT TWC from below - bullheading into formation at 3.0-BPM at 500-psi to 650-psi. Chart test and bullhead 30-Bbls. into formation. Good test. 20:30 - 22:30 2.00 WHSUR P DECOMP ND Tree. FMC verify top Tubing Hanger thread condition O.K. 22:30 - 00:00 1.50 BOPSUP P DECOMP NU BOPE. 11/24/2006 00:00 - 09:00 9.00 BOPSUR P DECOMP NU BOPE. Install blind shear rams and 2-7/8" x 5-1/2" VBR's. Retorque all flange breaks in BOP stack. Connect kill, choke Printed: 12/4/2006 10:08:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/24/2006 00:00 - 09:00 9.00 BOPSUP P DECOMP and Koomey lines. Grease choke manifold valves. Fill hole with 35-Bbls. at 0300-hrs. Fluid calculated to be 1,159' from surface. Called AOGCC at 0600-hrs to alert them of impending BOPE test start at 0900-1000-hrs. Lou Grimaldi requested that we allow him time to get to MPF pad from Endicott, but he thought he would not be leaving Endicott untill 1000-hrs. 09:00 - 10:00 1.00 BOPSUP. P DECOMP Perform function tests on rams and body pressure test to 3,500-psi. 10:00 - 13:30 3.50 BOPSUP P DECOMP Wait on AOGCC Inspector to perform BOPE tests. 13:30 - 23:30 10.00 BOPSUP P DECOMP PJSM to discuss the BOPE testing procedure. Test and record 250-psi low and 3,500-psi. First test with the Dart Valve and TIW valve (3-1/2" IF) failed. Replace TIW valve and resume testing. The Flow Cross flanges were found leaking and all bolts on the cross were tightened. The second TIW valve leaked through the valve stem. Replace this valve with a 3-112" IF TIW valve and XO. The hole fills show a fluid loss to the formation of 10-11 Bbls per hour. Continue BOPE testing. Completed BOPE testing at 2300-hrs. Ordered 290-bbls. 10.3-ppg NaCl/NaBr brine at 2200-hrs.for a 1330-hrs. delivery on 11-25-2006. 23:30 - 00:00 0.50 BOPSUP P DECOMP Fluid losses continue at 10-BPH. UD test jt. Safety standdown per tourpusher request. Convene all crew and support personnel on rig floor to discuss recent spate of near misses and accidents on Nabors Rigs 3S, 33E and 2ES. 11/25/2006 00:00 - 00:15 0.25 PULL P DECOMP PJSM - pull TWC. Reviewed process for PUMU Lopso-Opso and lubricator and PUMU single jts. tubing for planned fill tag with ESP. 00:15 - 01 :30 1.25 PULL P DECOMP Rig up floor and skate extension. Thaw out traveling block swivel w/steam hose and unlock same. Load 15-jts. 2-7/8" 8-rd. tubing in pipe shed. Drain BOP stack. Offload remaining 60-Bbls. 10.3-ppg brine into pits. Release vac truck. 01 :30 - 02:00 0.50 PULL P DECOMP PUMU Lopso-Opso and break out 3-1/2" 8-rd. x 2-7/8" 8-rd. XO. Make up 3-1/2" 8-rd. x 3-1/2" NSCT BxP XO to Lopso-Opso. Screw Lopso-Opso into Tubing Hanger. PUMU lubricator and lubricator rod extensions. MU lubricator to Lopso-Opso. Gravity feeding brine into IA. Line up BOP stack and Bell Nipple to the vertical. 02:00 - 03:00 1.00 PULL P DECOMP Pull TWC. LD lubricator and Lopso-Opso. 03:00 - 03:30 0.50 PULL P DECOMP PUMU 3-1/2" NSCT landing jt. with floor safety valve. Screw landing jt. into Tubing Hanger 8-3/4-turns. 03:30 - 04:30 1.00 PULL P DECOMP BOLDS. Unland Tubing Hanger. PUW to unland Tubing Hanger = 85K. After Tubing Hanger unlanded, PUW = 72K, SOW = 40K. Breakout and UD Tubing Hanger, 3-1/2" NSCT x 3-1/2" 8-rd. XO, 3-1/2" 8-rd. x 2-7/8" 8-rd. XO and 4' 2-7/8" L-80 8-rd. Tubing Pup. Centrilift test downhole cable. 04:30 - 05:00 0.50 PULL P DECOMP POH to bottom of 1 st full joint Tubing. Cut ESP Cable 18" above top of 2nd full joint Tubing. Leave ESP cross-coupling Cable Clamp attached at coupling on top of 2nd full joint Tubing. Attach ESP Cable above cross-coupling Cable Clamp to Tubing with 8 steel Cable Bands. Rig up hydraulic Tubing Tongs. 05:00 - 05:30 0.50 PULL P DECOMP PUMU 2-7/8" 8-rd. Tubing 1x1 from Pipe Shed and RIH to tag fill. PUW = 64K, SOW = 40K. Soft tag fill at 15' in on Joint #5 Printed: 12/4/2006 10:08:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/25/2006 05:00 - 05:30 05:30 - 06:00 0.50 PULL P 0.50 PULL P DECOMP (10,047.51') with 5K down weight. DECOMP POH UD 3 Joints Tubing 1 x1 through Pipe Shed. Fluid losses = 10-BPH. Pit volume = 204-Bbls. DECOMP Clear and clean Rig Floor; prepare for POH with ESP completion. Bleed down choke hose to Rig Floor. Hang Centrilift Sheave and pull rope over Sheave from Elephant Trunk. Pull ESP cable over Sheave. POH with ESP completion and SIB doubles in Derrick. POH 32-stands at 1230-hrs. Cut ESP Cable at splice and secure to spool. Remove spool from Centrilift Spooling Unit and move second spool forward to resume POH with ESP. Resume POH and SIB 2-7/8" tubing in Derrick, spooling up ESP cable. 50-stands POH @ 1445-hrs, for 10-stands per hour average. 106-stand POH @ 2130-hrs. Coupling connections very tight. Joint #210 bent during breakout. UD Joint #210. DECOMP Continue POH and SIB 2-7/8" tubing in Derrick, spooling up ESP cable. Maintaining hole fill with double steel displacement plus 10-Bbls. every hour. 130-stds. POH @ OOOO-hrs. Fluid losses = 8-BPH. DECOMP 308 joints Tubing POH @ 0300. DECOMP B/O UD ESP assembly through pipeshed. Outside of ESP assembly free of scale and corrosion. Pit volume = 185-Bbls. 125-Bbls. brine left on vac truck to unload. Fluid losses @ 8-BPH. Clear and clean Rig floor and prepare to RIH with the Muleshoe. RIH with Muleshoe on 2-7/8" tubing doubles, strapping in from Derrick. At 1315-hrs, stand #75 of 152-stands. Stand #125 @ 1630-hrs. Stand #152 RIH @ 1800-hrs. PUMU single joints 2-7/8" 8-rd. 1x1 from pipeshed to tag fill. Mix 25-Bbl. sweep with "Flo-Vis L". Tag @ 18' in on joint #14 (10,037'). Hook up circulating lines for conventional and reverse circulation. DECOMP Break circulation at 3.0-BPM at 600-psi. Increase rate to 4.0=BPM @ 980-psi. Pump #1 25-Bbl. sweep away at 4.0-BPM at 980-psi. Losses = 8-BPH. Wash down to 10,051' with never more than 500# downweight. Pick up to 10,037' and wash down again to 10,051'. Circulate 25-Bbls. and SID pump and break off circulating lines. PUMU single joint and reconnect circulating lines. Break circulation at 4.0-BPM and wash down to 10,082' work pipe up to 10,051' and back to 10,082' with never more than 500# downweight. 2120-hrs: Close annuluar preventer and start reverse circulation at 4.0-BPM at 450-psi. Losses = 2.5-BPM. Decrease rate to 3.0-BPM at 380-psi. with losses at 2.0-BPM. Pumped away 20-Bbls. Pit volume = 190-Bbls. Round trip vac truck for load of 10-3-ppg brine. SID pumping and switch back to circulating long way. Pump #2 25-Bbl. Flo-Vis "L" sweep @ 4.0-BPM. Work pipe while circulating and waiting for sweep to come around. Losses = 8.0-BPH. Sweep returned to surface. Pumped hole volume (370-Bbls). Small amount of cuttings in hi-vis sweep. SID pump and break off circulating lines. 06:00 - 09:30 3.50 PULL P 09:30 - 12:30 3.00 PULL P DECOMP 12:30 - 13:30 1.00 PULL P DECOMP 13:30 - 21 :30 8.00 PULL P DECOMP 21 :30 - 00:00 2.50 PULL P 11/26/2006 00:00 - 03:00 03:00 - 06:00 3.00 PULL P 3.00 PULL P 06:00 - 07:30 1.50 PULL P DECOMP 07:30 - 18:00 10.50 CLEAN P DECOMP 18:00 - 20:00 2.00 CLEAN P DECOMP 20:00 - 23:45 3.75 CLEAN P Printed: 12/4/2006 10:08:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/26/2006 23:45 - 00:00 0.25 CLEAN P DECOMP PUMU single joint and resume circulating long way @ 3.0-BPM at 41 O-psi. Fluid losses = 1.0-BPM 11/27/2006 00:00 - 02:15 2.25 CLEAN P DECOMP Wash down to 10,113'. Reciprocating pipe while circulating. Pump #3 sweep at 4.0-BPM at 780-psi. Pump hole volume surface to surface (370-Bbls.) Formation sand in returns. Slowed circulation rate to 3.0-BPM to keep from over running shaker screen. Sweeps recovered. Increase rate to 4.0-BPM at 700-psi. 0200-hrs. - Vac truck wlload of 10.3-ppg brine arrived on pad. Second load of brine ordered. 02:15 - 04:45 2.50 CLEAN P DECOMP PUMU single joint connection. Circulating at 4.0-BPM. Pump #4 25-Bbl. sweep away at 4.0-BPM at 700-psi. Wash down to 10,143' and reciprocate pipe while mixing #5 sweep. Pump away #5 25-Bbl. sweep. Chasing sweep at 4.0-BPM at 700-psi. Reciprocating pipe while pumping sweeps around to surface. 0330-hrs. Fluid losses = 60-BPH. #4 sweep recovered to pits @ 0400-hrs. Moderate amount of solids recovered. 0430-hrs. Recovered #5 sweep with small amount of formation sand recovered. SID pumping. 04:45 - 10:30 5.75 CLEAN P DECOMP Line up circulating lines for reverse circulating. Start reversing at 3.0-BPM at 450 psi. Fluid losses = 1.0-BPM. A large slug of formation sand and frac sand and formation solids plugged off the flow line and back-flowed into the void above the closed hydril bag. Flow line was cleared from the flow nipple to the shakers and void was cleaned when the returns from rev circulating cleaned up. 10:30 - 12:00 1.50 CLEAN P DECOMP POH and UD 5-single joints and SIB remaining tubing in Derrick. When the 5th stand was in the derrick and the Driller started the pump to give the well a drink, the fluid level was found to be slowly rising in the annulus. Monitored the flow for 15-minutes, called ADW Mgr and engineer, then SII the well for an hour. Installed 300-psi gages on the tubing and on the casing. At 1300-hrs SITP 12-psi, SICP 19-psi. Decided to increase Kill Weight 0.2-ppg to 10.5-ppg. 12:00 - 16:00 4.00 CLEAN P DECOMP Cleaned Mud Pits due to the volume of carry-over sand in the Pits from the Reverse Circulation operations. Had 520-Bbls of 10.3-ppg in two trucks on location from which to build the 10.5-ppg NaCI/NaBr. Pumped all Pit fluid to the Tiger Tank and used Super Sucker to clean sand out of Pits. 16:00 - 19:30 3.50 KILL P DECOMP Killing well, mixing brine and flowing back to Tiger Tank all discussed in pre-tour meeting with all crew. Take on 10.3-ppg brine to Pits, then batch add NaBr at 12-lbs per Bbl of brine to bring up to 10.5-ppg. H/U circulating lines on rig floor. 19:30 - 20:45 1.25 KILL P DECOMP Prepare to circulate 10.5-ppg NaCl/NaBr into wellbore. SITP = 60-psi., SICP = 22-psi. Line up and Open choke 50% to Tiger Tank. Well flowing slightly. Open TIW valve and establish pumping parameters @ 1.0-BPM @ 110-psi. taking returns to Tiger Tank. Increase rate to 3.0-BPM @ 410-psi. Open choke 100%. Circulate 203-Bbls. 10.5-ppg brine. with 170-Bbls returned. Losses to formation - 33-Bbls. or 19.4% of total volume pumped. SID pumping and shut well in. 2045-hrs.-- Haul 290-Bbls. returns from Tiger Tank to disposal at Pad 3. 20:45 - 22:00 1.25 KILL P DECOMP Load pits with 10.3-ppg brine. Weight up 10.3-ppg brine to 10.5-ppg with 12-ppg NaBr. Printed: 12/4/2006 10:08:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/27/2006 22:00 - 00:00 2.00 KILL P DECOMP SITP = O-psi, SICP = Vacuum. Resume circulating 10.5-ppg NaCIINaBr brine into well taking returns to Tiger Tank @ 3.0-BPM @ 530-psi. SID circulating. Circulated 239-Bbls. brine with 202-Bbls. returned to Tiger Tank. Losses = 18.3% of volume pumped. Brine weight in returns = 10.4-ppg. 75-Bbls. of 10.3-ppg brine remaining in pits. Weight up brine to 10.5-ppg. 11/28/2006 00:00 - 05:00 5.00 KILL P DECOMP Monitor well. 0430-hrs. Circulate remaining 75-Bbls. brine @ 3.0-BPM/530-psi. Returns to Tiger Tank achieved after pumping 4-Bbls. Returned brine wieght - 10.5-ppg. Waiting on truck load of 10.5-ppg brine from MI mudplant. Truck departed MI mud plant at 04:45-hrs. Shut in well. Monitor same. Tubing and IA on vacuum. 05:00 - 07:00 2.00 CLEAN P DECOMP RIH 5-stands of tubing from Derrick and pick up 4singlejoints of tubing from Pipe Shed. Tag fill @ 10,140' MD. Perform 100-Bbls circulation to ensure 10.5-ppg is all the way around. 07:00 - 08:30 1.50 CLEAN P DECOMP Take on new 10.5-ppg NaCl/NaBr brine to Pits (sample from truck 10.5-ppg) then circulate 100-Bbls taking returns to Pits @ 4-BPM/900-psi. Took 8-Bbls to fill hole after starting rig pump. Formation loss during circulation was O.4-BPM. 08:30 - 10:00 1.50 CLEAN P DECOMP Add rebuilt backup tongs to bottom of hydraulic tongs to improve efficiency and safety. 10:00 - 17:30 7.50 CLEAN P DECOMP POH and stand back all tubing in derrick. 17:30 - 19:30 2.00 CLEAN P DECOMP PJSM wI SLB TCP hands and rig crew. P/U and M/U SLB TCP guns (Bottom Nose, 20' of 4-1/2" Power Jet 5 spf perf gun, Safety Spacer, CBF Firing Head, Baker Disconnect). 19:30 - 00:00 4.50 CLEAN P DECOMP RIH wi Perf Guns on 2-7/8" EUE 8rd Tubing to @ 4700' MD. Run two pup joints, one wi RA Collar, above Guns in order to tie in with E-Line. Losses @ -13 Bbls/Hr. 11/29/2006 00:00 - 04:00 4.00 PERF P DECOMP Continue RIH wI Perf Guns on 2-7/8" EUE 8rd TBG to 10,110' MD. Losses @ -13 BPH during trip. 04:00 - 09:00 5.00 PERF P DECOMP RD ESP sheaves and equipment to RU rig floor for SWS E-line unit wI Stripper head & Pump-in sub. XIO from 2-7/8" EUE 8rd TBG to 3-1/2" IF TIW valve to 4-1/2" IF Pump-in sub. 11 :30 - 13:00 1.50 PERF P DECOMP RIH wI SLB E-Line GRlCCL to 10,040' MD. Log 3 repeat passes from 9,850' MD to 10,040' MD. Located RA Tag @ 9,985' MD. RA Tag needs to be @ 9,962' MD for guns to be on depth. POH and RID E-Line. DECOMP POH 23' wI Perf Guns on 2-7/8" EUE 8rd TBG putting the RA tag at 9,962' MD ( the correct depth for perforating). 4-1/2" PJ 5 spf Perf Guns @ 10,090' MD - 10,110' MD. Drop ball and RlU line to pressure up on tubing. Pressure up to 2800 psi on tubing. Guns fired. Good visible indication of detonation. POH 30' and monitor well. Well is losing fluid (- 1 BPH). 09:00 - 11 :30 2.50 PERF P Printed: 12/4/2006 10:08:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 11/17/2006 Rig Release: 12/1/2006 Rig Number: N3S Spud Date: 8/31/1995 End: 12/1/2006 11/29/2006 13:00 - 15:00 2.00 PERF P DECOMP Circulate 280 Bbls of 10.5 ppg brine @ 3 BPM. Shut down and monitor well. Well is still taking fluid. Gas is bubbling to surface. Circulate an additional 75 Bbls of 10.5 ppg brine. Well is static. 15:00 - 00:00 9.00 PERF P DECOMP POH wI Perf Guns on 2-7/8" Tubing. SIB Tubing in Derrick. UD pup joints, single joint, RA Collar, and Perf Guns. SLB onsite to supervise the guns coming to surface. Losses @ 6 BPH. 11/30/2006 00:00 - 01 :00 1.00 PERF P DECOMP Continue POOH wI TBG Conveyed Perf Guns on 2-7/8" 8rd TBG. UD pup joints, single joint, B/O RA Collar and Perf Guns. SLB on site to supervise Perf Guns coming OOH. Losses 6 BPH. 01 :00 - 03:30 2.50 RUNCOMP RUNCMP RIU rig floor wI ESP sheaves. RU Centrilift spooling unit. 03:30 - 08:00 4.50 RUNCOMP RUNCMP PU ESP BHA. Verify horsepower and SIO control cable. Install Centrilift Spooling Unit and MU ESP. 08:00 - 00:00 16.00 RUNCOMP RUNCMP RIH wI new Centrilift ESP completion using Best-O-Life Pipe Dope and Optimum Torque of 2,300 ft-Ibs on all connections. Test electrical integrity of ESP cable and downhole ESP unit each 2000' ran in hole. Break circulation every 2000 ft. and pump 10 bbls through ESP per program. Avg. = 10 stands/hr. Losses wI RIH @ 4-6 BPH. LaSalle Clamps used- 172, Flat Guards used- 3, Protectolizers used- 6. P/U Wt- 55K plus blocks, SIO Wt- 33K plus blocks. 12/1/2006 00:00 - 01 :30 1.50 RUNCOMP RUNCMP PU and MU TBG Hanger. Install brass-shipping cap on ESP penetrator. 01 :30 - 04:00 2.50 RUNCOMP RUNCMP Splice ESP cable to HGR and test same. 04:00 - 04:30 0.50 RUNCOMP RUNCMP Land ESP completion with extreme care and RILDS. 04:30 - 06:00 1.50 RUNCOMP RUNCMP Set twc. Test from above and below to 1000 psi for 5 minutes each and chart. Test from below was not good due to losing fluid to formation. Test from above held steady. 06:00 - 13:00 7.00 BOPSUPP POST N/D BOPE. Reposition tree within cellar in order to lift Stack safely. 13:00 - 16:30 3.50 WHSUR P POST N/U Tree. Pressure test Tree and Tubing Head Adapter to 5000 psi and chart. 16:30 - 17:00 0.50 WHSUR P POST Pull TWC wI Lubricator and install BPV. 17:00 - 00:00 7.00 WHSUR P POST Safety Stand Down. Release Rig 24:00 hrs. RDMO Printed: 12/4/2006 10:08:32 AM o~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: JIm regg@admín.state.ak.us aogcc prudhoe bay@adm;n.s.tate.ak.us bob f;eckenste;n@admín.state.ak.us Rig No.: 3S DATE: 11/24/2006 Rig Phone: 670-3483 Rig Fax: 670-3236 Op. Phone: 670-3366 Op. Fax: 670-3236 1/28/04 Contractor: Nabors Rig Rep.: Greco/ Fritts Operator: BPX Rep.: Rooney/Hefley Field/Unit & Well No.: MPU-F-69 Location: Section: Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 Well Sign Dr!. Rig Hazard Sec. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Size 13 5/8 2-7/8x5 1 1 2 1 o shear 3 1/8" 3 1 /8" , 2-1/16 2-1/16" MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm Test P P P P P PTD # 1951250 Township: Workover: X Weekly: Annular: 250/3500 TEST DATA Test Result P p P Test Result FP P NA P P P P NA ~ Meridian: Range: Explor.: Other: Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type 1 FP Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3100 P Pressure After Closure 1400 P 200 psi Attained 41 sec P Full Pressure Attained 2min 29 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 1900 psi Test Results Number of Failures: §. Test Time: 10 Hours Components tested ALL Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Jjm.Jegg@admín.statf-:,ak.us Remarks: 2ea. 3 1/2 floor safety valves failed - dsa on choke and kill lines leaked- flanqe on choke manifold between valves 5 & 9 leaked - floor valves will be repaired & retested - flanqes were tiqhtened up and retested. 24 HOUR NOTICE GIVEN YES X NO Date 11/24/06 Test start 13:30 Time Finish Waived By 11/24/2006 23:30 6ÇANNED NOV 2 7 2005 Witness Lou Grimaldi ~ STATE OF ALASKA "'-", ALASKA ~L AND GAS CONSERVATION COlvllv1ISSION REPORT OF SUNDRY WELL OPERATIONS '. 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 46' 0 Suspend 181 Repair Well 181 Pull Tubing 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 72' Surface 5742' Intermediate Production 10375' Liner 10435 7477 10324 7383 Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Waiver 181 Other 0 Time Extension Change Out ESP 0 Annular Disposal 5. Permit To Drill Number 195-125 6. API Number: 50-029-22586-00 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic Test 0 Service 9. Well Name and Number: MPF-69 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 9-5/8" 5778' 4546' 7" 10408' 7454' 9954' - 10099' 7077' - 7195' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8", 6.5# L-80 9916' None None Oil-Bbl RE(;I::IVED MAY 14 2004 Alaska Oil & Gas Cons. Commission Anrhor2gø Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure Tubino Pressure Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations IBI Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Sign~--c""~- Form 1 0-404 Revised 12/2003 Title Technical Assistant 0 RiG I NAr I"'\S- [I 1 £. Prepared By NamelNumber: Datev~ "14) \ Sandra stewmi lri.61í\ -- Bfl "* ~ ~ /"\ .. 'iB¡D EXRLOP\ÅTI~.N '. '." " .;', .,;", .,~..' . " ,.,t,\Jøn~ 'Sul\11niå~Y',R~port .",' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date .. . From - To Hôúrs; ifask>+ Ôód~ ." NPT . Pþase " ';;v, ,ii, "',' , 4/13/2004 00:00 - 02:00 2.00 MOB P PRE 02:00 - 04:00 2.00 RIGU P PRE 04:00 - 06:00 2.00 KILL P DECOMP 06:00 - 07:30 1.50 KILL P DECOMP 07:30 - 09:30 2.00 KILL DECOMP P 09:30 - 14:30 5.00 KILL P DECOMP 14:30 - 20:00 5.50 KILL P DECOMP 20:00 - 22:30 2.50 KILL P DECOMP 22:30 - 00:00 1.50 KILL P DECOMP 4/14/2004 00:00 - 02:00 2.00 KILL P DECOMP 02:00 - 02:30 0.50 WHSUR P DECOMP 02:30 - 04:00 1.50 WHSUR P DECOMP 04:00 - 06:00 2.00 WHSUR P DECOMP 06:00 - 06:30 0.50 WHSUR P DECOMP 06:30 - 07:30 1.00 WHSUR P DECOMP 07:30 - 08:30 1.00 WHSUR P DECOMP 08:30 -11:00 2.50 PULL P DECOMP 11 :00 - 16:30 5.50 PULL P DECOMP 16:30 -18:30 2.00 PULL P DECOMP 18:30 - 22:30 4.00 PULL P DECOMP 22:30 - 00:00 1.50 PULL P DECOMP 4/15/2004 00:00 - 01 :30 1.50 PULL P DECOMP 01 :30 - 03:00 1.50 PULL P DECOMP 03:00 - 06:00 3.00 RUNCOMP COMP 06:00 - 07:00 1.00 RUNCOMP COMP 07:00 - 07:30 0.50 RUNCOMP CaMP 07:30 - 13:30 6.00 RUNCOMP CaMP ,. Start: 4/13/2004 Rig Release: 4/16/2004 Rig Number: 4ES Spud Date: 8/31/1995 End: 4/16/2004 , . Descr!piïón of' Op~(fitions' Complete move from F-45. Rig released from F-45 at 18:00 on 04/12/2004. RIG ACCEPTED @ 02:0004/13/2004 on F-69. RU to circulate well. PT lines to 3500 psi. Blow down lines. Pull BPV. SITP = 1100 psi; SICP = 1430 psi. Well lined up to circulate wlhot seawater. Start bleeding gas off tubing thru choke to tiger tank. Tubing and casing bled down together to -500 psi. Come on line with hot seawater down the tubing with choked returns from casing. Work rate up to 4 bpm @ 1000 psi once tbg full of heated seawater. Casing press = 240 psi. Returns are mostly liquid. Finish circulating w/265 bbls pumped. Shut-in returns. Tiger tank nearly full. Bullhead 50 bbls heated seawater into formation at 2 bpm, shut-in and record SITP. SITP = 860 psi, SICP = 870 psi. Complete eire-out with heated seawater (bottoms-up). Ordered out 11.1 ppg NaCUNaBr brine from MI. Load pits w/11.1 (heavy) ppg, ship remaining 8.5 seawater to Tiger Tank. Circulate 11.1 (hvy) ppg brine 3 BPM @ 225-250 psi for 370 Bbls. SI, monitor pres, TP 50, CP 40. Open both sides, check gains, 5.1 Bbls in 10 mins. SI 10 mins, TP20, CP 20. Open both sides 10 mins, gains 4 Bbls. Sl 20 mins, TP 10, CP 10. Open both sides, gain 2-1/2 Bbls in 10 mins. Recalculate kill fluid weight to 11.37 ppg with 75 psi over-balance. Mix 11.4 ppg fluid and resume circulation at 3 BPM, 600 psi. Circulated 11.4 ppg brine to kill well. P/U and Install TWC, blow down lines. N/D tree and prepare to N/U BOPE. N/U and test BOPE, short test 250/3500 psi. AOGCC witness waived by Jeff Jones. RID test equipment. P/U Lubricator & extension, pull TWC and UD. M/U landing joint, BOLDS. Lubricate rig. RlU to UD 3-1/2" STL, flush-joint tubing. Pull hanger wI 95K, wt fell back to 85K. UD landing joint and hanger. Pull ESP line over sheave. Fill tubing w/ 15 Bbls brine. POH and UD 83 jts 3-1/2" STL tubing using lift nubs and collar clamp. R/U to pull and Stand Back 2-7/8", L-80, EUE 8 rd tubing. C/O ESP spools. Adjust Beaver Slide chocks and level rig. POH and SIB 2-7/8" tbg and tally out of hole: 74 stands and 4 jts. Recovered all LaSalle Clamps (159), all bands (252), all Protectolizers (5), and all flat clamps (2). Break out and UD ESP completion. Break-out and UD ESP completion. cIa spools in cable building. RlU equipment for handling new ESP completion. M/U and service new ESP completion equipment. Run cable over sheave. Connect ESP cable to pump, secure and test. Fill hole w/15 Bbls brine. Lubricate rig. RIH wI 2-7/8", L-80, EUE 8 rd tubing string (74 stands from Printed 511712004 1033:47 AM ~, /""""., .. " .' . , ,§~::~~Þh Oft1\> T ION 0 pe~~t,!:~Q~:/~ilfh mary Bepo rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-69 MPF-69 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date Froni.iTo, "'Bourg' "Tàsk' ,Code,è~p:p ','Phàsè '...'{' <, 4/15/2004 07:30 - 13:30 6.00 RUNCOMP COMP 13:30 - 14:30 1.00 RUNCOMP COMP 14:30 - 17:00 2.50 RUNCOMP CaMP 17:00 - 20:00 3.00 RUNCOMP COMP 20:00 - 21 :00 1.00 RUNCOMP COMP 21 :00 - 22:30 1.50 RUNCOMP CaMP 22:30 - 00:00 1.50 RUNCOMP COMP 4/16/2004 00:00 - 01 :00 1.00 RUNCOMP COMP 01 :00 - 02:00 1.00 RUNCOMP CaMP 02:00 - 02:30 0.50 BOPSUF P COMP 02:30 - 04:00 1.50 BOPSUF P COMP 04:00 - 06:00 2.00 WHSUR P CaMP Page. 2 of 2 Start: 4/13/2004 Rig Release: 4/16/2004 Rig Number: 4ES Spud Date: 8/31/1995 End: 4/16/2004 DescriptlonpfOperations: derrick); 2-GLMs, bottom one open; XN nipple wi plug; new ESP wI tandem pumps. LaSalle Clamp on each collar to 3000'. Test cable conductivity each 2000'. Cant. TIH wI used, inspected tbg from MPE-20: 18 its 2-7/8", L-80, EUE 8 rd. Make and test reel-to-reel cable splice @ 7600'. Continue TIH wI remaining 65 its of inspected 2-7/8" tubing from MPE-20; add 4.02' pup below hanger XO's to allow for cable clamp. M/U landing jt and new hanger and prepare for EFT connection. Check string weights: P/U wt = 64K, SIO wt = 45K. New Tubing Hanger had only an ESP penetration port, whereas the existing tree adaptor flange had two ports: an ESP port and a Heat Trace port. Replacement adaptor flange coming from Stores. M/U EFT connection. M/U EFT connection and test. P/U and land tubing hanger. Pump bottom centralizer landed @ 9916'. RILDS. P/U and install and test TWC. Drain BOPE. NID BOPE. Remove existing "two-port" tree adaptor flange from tree and install single port adaptor flange. N/D BOPE and set back on stump. N/U tree wI new single port (ESP) adaptor and test. Pull TWC. Install BPV. Perform final ESP check. Release Rig at 06:00 hrs. ..04/16/2004. Printed, 511712004 10'3347 AM ~ IrE 3-1/8" 5M CIW Wellhead: 11" x 11" FIVC Gen. 5 5M 3.5" NSCT Top & Btm. wI x-over to 2-7/8" eue CIW H.Profile 3" 20" 91,1 ppf, H-40 I 113' I' KOP@ 500' r-Iax. hole angle = 55 to 57OOg. fl 3900' to 8,600' roe angle thru' perfs = 35.5 deg. 95/8",40 ppf, L-80 Btrc, I 5778' I'" 2- 7/8",6.5#, L-80 8rd,8JE (2.441" ID, Cap. ,00579 bblslft.) ì' 26 ppf, L-80, Btrc.prod. casing, (drift ID= 6.151", cap. = 0.0383 bpf) Stimulation Summary 1/3/96 - Kup 'a' sand, 122m #16.20 mid-perf = 7139' tvd 10026'md Perforation Summary Ref log: 9/??195 GRlCCL Size SPF Interval 'B'Sands 4.5" 5 9954'-9964' 'A'Sands 3-3/8' 6 10009'-10099' (TVD) 7078'- 7088' 7124'-7200' ~ MPU F -69 - ... /~. Org. KB Elev. =47.ì(N27E) Org, GL Eev = 12 50' Rr to lbg SpooÞ 32 78' (N 27E) 3.5"eue 8rd. x 2-7/8" eue 8rd. . X-Over OI:J Carrco 2 7/8" x 1" sidepocket KI3M'v1 GLM 1134' I ) 2-7/8"8RDBEx3-112" STL X-over jont (29') 12,541' I Carrco 2 7/8" x 1" sidepocket KBrvfv1 GLM I 9,707' I 19,788' I 2-7/8" XN Nipple 2.205" ID Centrilift Tandem Pump Section I 9 836' I GPMTAR 1/1 44/97 GC3500 , Centrilift Tandem Gas Section I I GRSFTXARH6 9,866' Centrilift Tandem Seal Section I GSB3DBUTILH6PFSI GSB3DBLTH6 I 9,871 ' Centrilift Motor HP 3041 KMH I 9,885' I V. 2290 I 81 Amps . Centrilift Pumpmate I 9,910' I X T'x21'ShortJtfrom9800'-9821'. ] ì'floatcolar(PBTD) ì' float shoe 1 10326' I 110408' I DATE REV. BY COMMENTS ,MILNF POINT UNIT 09/13/95 JBF Drill and case Nabors 27-E WELL F-69 02/27/96 JBF Inital completion Nabors 4-ES API NO: 50-029-22586 OS/23/96 RWO 4-ES 7/13/9F, 3/30/01 04/15/04 MOO ESP RWO 4-ES BP EXPLORATION (AK) .. L ~c;;. .' -. ... $ ~"ATE OF ALASKA .... ALASKA t~L AND GAS CONSERVATION COMM~,.._.-JON REPORT OF SUNDRY WELL OPERATIONS 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 = 46' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Maine Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2124' NSL, 2502' WEL, Sec. 6, T13N, R10E, UM MPF-69 At top of productive interval 9. Permit Number / Approval No. 195-125 2916' NSL, 2589' WEL, Sec. 31, T14N, R10E, UM 10. APl Number At effective depth 50-029-22586-00 3134' NSL, 2602' WEL, Sec. 31, T14N, R10E, UM 11. Field and Pool At total depth Maine Point Unit / Kuparuk River 3177' NSL, 2604' WEL, Sec. 31, T14N, R10E, UM Sands 12. Present well condition summary Total depth: measured 10408 feet Plugs (measured) true vertical 7454 feet Effective depth: measured 10326 feet Junk (measured) true vertical 7384 feet Casing Length Size Cemented MD TVD Structural Conductor 72' 20" 250 sx Arcticset (approx.) 110' 110' Surface 5742' 9 5/8" 1375 sx PF 'E', 250 sx 'G' 5578' 4429' Intermediate Production 10375' 7" 250 sx Class 'G' 10408' 7454' Liner Perforation depth: measured 9954'-9964' (B sands), 10009'-10099' (A sands) ~ E C true vertical 7077'-7085', 7121 '-7195' ;/~/... 0 2007 Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9908' ,'~!aska 0il & Gas uuiis, /''' ' ' ,,0rn~r~ss~0r; Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure % .... ; 14. Representative Daily Average Production or Iniection Data 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 [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ne~~w?~p._.~;(~~f--~.%,y¥~.~__~Title Technical Assistant Date Prepared By Name/Number: Sondra Stewrnan, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPF-69 Common Well Name: MPF-69 Spud Date: 8/31/1995 Event Name: WORKOVER Start: 3/23/2001 End: 3/27/2001 Contractor Name: NABORS Rig Release: 3/27/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: Date ~ ~From - To~ ~Hours ~ Task ~ode~Phase~ ~!~?~:,: :; Description of .... ~- '-~?:~--~ ..... l~!asK./~:~e - ._7__ ~ ~ :; OPerations 3/23/2001 07:30 - 10:00 2.50 MOB PRE SET MA~ING. MOVE RIG ON FROM MPF-33 TO MPF-69. 10:00 - 12:00 2.00 RIGU PRE ~ISE & SCOPE DERRICK. ~U. ACCEPTED RIG ~ 1200 HRS, 3-23-01. 12:00 - 14:00 2.00 RIGU PRE SPOT & BERM TIGER TANK. MAKE UP KILL LINE TO WELLH~D. 14:00 - 15:00 1.00 WHSUR DECOMP ~U LUBRICATOR & PULL BPV. ~D LUBRICATOR. 15:00 - 18:00 3.00 WHSUR DECOMP FINISH ~U HARD LINES. PRESSURE TEST TO 3500 PSI, OK. TAKE ON 13 PPG KILL FLUID. 18:00 - 20:30 2.50 KILL i DECOMP HOLD PJSM. OPEN WELL. SITP 2040 PSI, SICP 2690 PSI. START KILL CPS. PUMP IN ~ 1 BPM. PUMPED TOTAL OF 18 BBLS. TBG PRESSURE IN CR~SED TO 2700 PSI. PUMP PLUGGED. S/D & BLOW LINES. 20:30 - 21:30 1.00 KILL DECOMP ~U HB&R A~EMPT TO PUMP DIESEL DOWN TBG ~ 1/4 BPM. PRESSURE INCR~SED TO 3500 PSI. S/D & ~D HB&R. 21:30 - 00:00 2.50 KILL DECOMP WAIT ON E-LINE TO PERF TBG. 3/24/2001 00:00 - 03:00 3.00 KILL DECOMP WAIT ON SCHLUMBERGER E-LINE. 03:00 - 08:00 5.00 KILL DECOMP HELD PJSM, ~U SCHLUMBERGER. TEST LUBRICATOR TO 3000 PSI. 08:00 - 10:00 2.00 KILL DECOMP RIH & PERFO~TE TBG ~ 9622' W/8 SHOTS. POOH, TOOL STUCK IN WELLHEAD. 10:00 - 12:30 2.50 KILL DECOMP PUMP TOOL FREE & GIRO TO CLEAN UP. PULL TOOL UP INTO LUBRICATOR. 12:30 - 15:30 3.00 KILL DECOMP KULL WELL W/13 PPG FLUID ~ 4 BPM. WELL DEAD. MONITOR WELL. 15:30 - 17:00 1.50 KILL DECOMP BR~K OFF LUBRICATOR. RECOVER TOOLS & ~D SCHLUMBERGER. 17:00- 17:30 0.50 KILL DECOMP INSTALL ~C IN TBG HGR. 17:30 - 18:00 0.50 KILL DECOMP ~D HARDLINE TO TREE & HCR VALVE. 18:00 - 19:00 1.00 WHSUR DECOMP N/D X-~S TREE. 19:00 - 21:30 2.50 BOPSUF DECOMP N/U BOPE. 21:30 - 00:00 2.50 BOPSUF DECOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI. TEST WITNESSED BY JEFF JONES W/AOGCC. 3/25/2001 00:00 - 01:00 1.00 BOPSUF DECOMP FINISH TESTING BOPE. 01:00 - 01:30 0.50 BOPSU~ DECOMP ~D TEST EQUIP. D~IN LINES. 01:30 - 02:30 1.00 PULL DECOMP P/U LUBRICATOR PULL ~C & ~D SAME. 02:30 - 03:30 1.00 PULL DECOMP M/U ~NDING JT. BOLDS. PULL HANGER W/82K. UD ~NDING JT. 03:30 - 06:00 2.50 PULL DECOMP MOITOR WELL. SL GAS BLOW. NO FLOW. POOH W/2 7~8" COMPLETION (SLM) 06:00 - 06:30 0.50 PULL DECOMP CHANGE ESP CABLE SPOOL. 06:30 - 11:00 4.50 PULL DECOMP POOH W/2 7/8" COMPLETION. 11:00 - 13:00 2.00 PULL DECOMP HOLE NOT TAKING PROPER FILL. ClRCU~TE & MONITOR WELL. WELL HAD SLIGHT FLOW. 13:00 - 16:00 3.00 PULL DECOMP CUT ESP CABLE & TRIP BACK IN HOLE. 16:00 - 00:00 8.00 PULL DECOMP ClRCU~TE & CONDITION MUD. WEIGHT DROPPED TO 12 PPG ON BOSOMS UP. ~ BACK UP TO 12.9 PPG. S/D & MONITOR WELL. WELL DEAD. 3/26/2001 00:00 - 09:00 9.00 PULL DECOMP POOH W/2 7~8" COMPLETION STRING. UD 80 JTS OF 2 7~8" TBG. 09:00 - 10:30 1.50 PULL DECOMP UD ESP. 10:30 - 11:30 1.00 RUNCO~ COMP CL~R FLOOR. ~U TO RUN NEW COMPLETION. 11:30 - 17:00 5.50 RUNCO~ COMP M/U & SERVICE NEW ESP. TEST SAME. 17:00 - 22:00 5.00 RUNCO~ COMP RIH W/2 7~8" COMPLETION TBG. 22:00 - 00:00 2.00 RUNCO~ COMP SPLICE ESP CABLE.~ 6950'. 3/27/2001 00:00 - 01:00 1.00 RUNCO~ 4 COMP SPLICE ESP CABLE & TEST SAME. 01:00 - 01:30 0.50 RUNCOM COMP RIH W/2 7~8" TBG STRING TO 7340'. Printed: 4/12/2001 9:35:34AM Legal Well Name: MPF-69 Common Well Name: MPF-69 Spud Date: 8/31/1995 Event Name: WORKOVER Start: 3/23/2001 End: 3/27/2001 Contractor Name: NABORS Rig Release: 3/27/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: ~Date ~ ~From -:To~Heurs~ Tas~c~o-d-e ~Bhase ~? :~ ~, Description of Operations :3/27/2001 01:30 - 02:00 0.50 RUNCOI~ COMP CLEAR FLOOR & R/U HANDLING TOOLS F/3 1/2" TBG. M/U X-OVER JT. 02:00 - 08:00 6.00 RUNOOI~ COMP RIH W/83 JTS 3 1/2" TBG. 08:00 - 11:30 3.50 RUNOOI~ COMP MU HANGER & SPLICE ESP OONECTOR TO HANGER & LAND SAME. & 8ET TWO. & TEST. 11:30 - 13:30 2.00 BOPSUF COMP NIPPLE DN BOP 13:30 - 16:30 3.00 WHSUR COMP NIPPLE UP TREE & TEST SAME TO 5000 PSI. 16:30 - 18:30 2.00 CLEAN COMP CIRC. 13.0 PPG. BRIINE FROM WELL BORE. 18:30 - 20:00 1.50 CLEAN COMP FREEZE PROTECT WELL WITH DEAD CRUDE. 80-BBL. 20:00 - 00:00 4.00 CLEAN COMP SET BPV & CLEAN PITS & RELEASE RIG @ 00:00--hRS. 3/27/2001 . Printed: 4/12/2001 9:35:34AM ~ALASKA~ ieare.d rvloes rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: February 26, 1999 From: Subject: Terrie Hubble Technical Assistant Miscellaneous Surveys Enclosed, in duplicate, are a number of directional surveys that I have come across while clearing out Ms. Campoamor's desk. I have verified that these surveys do not affect the previously calculated TVD's and below surface locations of these wells, so it was not necessary to correct the 10-407's. They are simply being submitted for your records. If they are duplicates, please discard them. Thank you. /tlh Endicott MPI 1-09A/L-21 Milne Point MPC-09 Milne Point MPF-21 Milne Point MPF-37 Milne Point MPF-45 Milne Point MPF-69 Milne Point MPF-79 Permit #97-29 Permit #85-36 Permit #96-135 Permit #96-25 Permit #95-58 Permit #95-125 Permit #97-180 gyro/data B.P. EXPLORATION WELL NO: MPF-69 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Of 7" Casing Survey date · 22 MAY 1996 Job number' AK0596G343 SR343DOC gyro/data i I I Gyrodata Incorporated RO. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 June 21, 1996 B.P. Exploration Petrotechnical Data Center, MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Re: · F-PAD, WELL #MPF-69, MILNE POINT, AK Enclosed please find one (1) original, six (6) copies and one (1) disk of the completed survey of Well #MpF-69 We would like to take this opportunity to thank you for.using Gyrodata and we look forward to serving you in the future. Sincerely, /~ , S od Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK0596G343 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR343DOC gyro/data DISCUSSION , SURVEY CERTIFICATION SHEET SR343DOC gyro/data DISCUSSION JOB NUMBER' AK0596G343 Tool 743 was run in well# MPF-69 on ATLAS 5/16" Wireline inside casing. The survey was run without problems. SR343DOC gyro/data SURVEY CERTIFICATION SHEET JOB .NUMBER' AK0596G3.43 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR343DOC gyro/data 2. SURVEY DETAILS SR343DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0596G3.43 CLIENT: B.P. EXPLORATION RIG: NABORS LOCATION: MILNE POINT, ALASKA WELL: LATITUDE: MPF-69 70.505 N. LONGITUDE: 149.5 W. SURVEY DATE: 22 MAY 96 SURVEY TYPE : MULTISHOT IN 7" CASING DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 49.7 FT.. 10262 SURVEY TIED ONTO: NA SURVEYINTERVAL: UTM CO-ORDINATES: 100 FT. FROM '100 - 4000 50 FT. FROM 4000 - 10262 TARGET DIRECTION: 358.83 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD SR343DOC gyro/data. 3. OUTRUN SURVEY LISTING SR343DOC A Gyrodat a Di re c t i onal Survey for B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, ALASKA Job Number: AK0596G343 Run Date: 22-May-96 11:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 49.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 358.830 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata B.P. EXPLORATION WELL: F PAD, MPF-69, Location: NABORS 4ES, Job Number: AK0596G343 7 I! MILNE POINT, ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 0.0 0.00 0.00 0.0 0.0 Directional Survey SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. -49.7 0.00 0.0 0.0 O.O - 10262 FT. GYRO MULTISHOT RUN IN 7" CASING MEASURED DEPTHS ARE REFERENCED TO THE POOL 4ES R.K.B. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .71 342.02 100.0 .6 50.3 200.0 .76 334.13 200.0 1.8 150.3 300.0 .75 329.70 300.0 3.0 250.3 400.0 .79 345.39 400..0 4.2 350.3 500.0 1.02 337.37 500.0 5.7 450.3 600.0 1.34 342.60 599.9 7.7 550.2 700.0 1.86 343.05 699.9 10.3 650.2 800.0 2.21 342.17 799.8 13.8 750.1 900.0 2.44 341.75 899.8 17.6 850.1 1000.0 2.96 22.20 999.7 22.0 950.0 1100.0 4.64 30.38 1099.4 27.9 1049.7 1200.0 5.18 27.02 1199.1 35.3 1149.4 1300.0 5.71 26.19 1298.6 43.7 1248.9 1400.0 6.93 18.09 1398.0 53.8 1348.3 1500.0 7.17 16.44 1497.2 65.4 1447.5 1600.0 7.04 14.61 1596.5 77.3 1546.8 1700.0 7.79 11.67 1695.6 89.8 1645.9 1800.0 8.50 6.09 1794.6 103.7 1744.9 1900.0 9.40 5.77 1893.4 119.2 1843.7 2000.0 11.91 2.94 1991.7 137.6 1942.0 .71 .11 .06 .21 .27 .33 .51 .35 .24 1.93 1.76 .62 .54 1.51 .32 .26 .84 1.06 .91 2.56 .6 342.0 .59 N .19 W 1.9 339.3 1.78 N .67 W 3.2 336.3 2.94 N 1.29 W 4.5 336.7 4.18 N 1.80 W 6.1 337.8 5.67 N 2.32 W 8.2 338.4 7.61 N 3.01 W 11.0 339.5 10.27 N 3.83 W 14.5 340.3 13.66 N 4.89 W 18.6 340.6 17.51 N 6.15 W 22.7 345.1 21.93 N 5.84 W 27.9 35.3 44.2 54.9 67.1 79.4~ 92.3 106.4 121.9 140.3 354.2 27.80 N 2.83 W 2.1 35.31 N 1.27 E 7.2 43.80 N 5.52 E 10.1 54.01 N 9.59 E 11.4 65.73 N 13.23 E 12.0 12.2 11.7 11.0 10.1 77.65 N 16.55 E 90.22 N 19.46 E 104.21 N 21.62 E 119.68 N 23.22 E 138.11 N 24.57 E A Gyrodata B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, Job Number: AK0596G343 ALASKA Directional Survey Page 2 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. HORIZONTAL COORD I NATE S~ feet 2100.0 14.18 1.55 2089.1 2200.0 17.55 5.26 2185.3 2300.0 21.11 4.72 2279.6 2400.0 24.45 5.49 2371.8 2500.0 27.46 7.03 2461.7 2600.0 30.40 4.64 2'549.2 2700.0 34.10 4.26 2633.8 2800.0 36.35 1.61 2715.5 2900.0 38.68 .74 2794.8 3000.0 40.35 358.22 2871.9 3100.0 42.20 357.11 2947.1 3200.0 44.53 355.80 3019.8 3300.0 46.56 354.52 3089.8 3400.0 48.66 353.-89 3157.2 3500.0 51.51 354.55 3221.4 3600.0 52.51 353.44 3282.9 3700.0 51.94 354.08 .3344.2 3800.0 53.90 353.97 3404.5 3900.0 53.62 354.54 3463.6 4000.0 55.63 355.06 3521.5 4050.0 55.73 354.55 3549.7 4100.0 55.50 354.49 3577.9 4150.0 55.60 354.27 3606.2 4200.0 55.82 354.22 3634.4 4250.0 55.71 354.61 3662.5 160.1 187.3 220.2 258.7 302.1 350.1 403.2 460.7 521.6 585.2 651.1 719.7 791.0 864.6 941.0 1019.5 1098.3 1177.8 1258.2 1339.5 1380.7 1421.8 1462.9 1504.1 1545.3 2039.4 2.29 162.7 9.0 2135.6 3.51 189.9 8.2 2229.9 3.57 222.9 7.7 2322.1 3.36 261.6 7.4 2412.0 3.08 305.4 7.2 2499.5 3.16 353.7 7.0 2584.1 3.71 407.0 6.7 2665.8 2.72 464.6 6.2 2745.1 2.39 525.3 5.6 2822.2 2.32 588.5 5.0 2897.4 1.99 654.0 4.2 2970.1 2.50 722.1 3.5 3040.1 2.23 792.8 2.7 3107.5 2.14 865.9 2.0 3171.7 2.90 941.9 1.4 3233.2 1.33 1020.1 .8 3294.5 .76 1098.6 .3 3354.8 1.97 1178.0 359.9 3413.9 .54 1258.2 359.5 3471.8 2.06 1339.5 359.2 3500.0 .88 1380.7' 359.1 3528.2 .47 1421.8 359.0 3556.5 .42 1462.9 358.8 3584.7 .45 1504.1 358.7 3612.8 .69 1545.3 358.6 160.66 N 25.43 E 187.92 N 27.15 E ~ 220.89 N 30.01 E 259.46 N 33.48 E 302.95 N 38.28 E 351.07 N 43.16 E 404.26 N 47.28 E 461.85 N 50.20 E 522.74 N 51.44 E 586.35 N 50.84 E 652.25 N 48.14 E 720.78 N 43.88 E 791.90 N 37.84 E 865.37 N 30.37 E 941.67 N 22.66 E 1020.04 N 14.42 E 1098.61 N 5.83 E 1177.96 N 2.48 W 1258.20 N 10.56 W 1339.40 N 17.94 W 1380.52 N 21.68 W 1421.59 N 25.62 W 1462.63 N 29.66 W 1503.73 N 33.80 W 1544.87 N 37.83 W A Gyroda t a D i re c t i ona I Survey B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, ALASKA Job Number: AK0596G343 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4300.0 55.28 355.63 3690.8 4350.0 55.18 355.77 3719.4 4400.0 55.04 356.03 3748.0 4450.0 54.61 357.25 3776.8 4500.0 54.54 357.64 3805.7 1586.4 3641.1 1.88 1586.5 358.5 1627.5 3669.7 .31 1627.5 358.4 1668.4 3698.3 .52 1668.5 358.4 1709.2 3727.1 2.16 1709.3 358.3 1750.0 3756.0 .65 1750.1 358.3 1585.93 N 41.34 W 1626.88 N 44.41 W-~- 1667.79 N 47.34 W 1708.59 N 49.74 W 1749.29 N 51.56 W 4550.0 54.43 357.82 3834.8 4600.0 54.66 358.06 3863.8 4650.0 55.00 358.21 3892.6 4700.0 55.24 358.12 3921.2 4750.0 55.18 358.10 3949.7 1790.7 3785.1 .37 1790.7 358.3 1831.4 3814.1 .61 1831.5 358.3 1872.3 3842.9 .73 1872.3 358.3 1913.3 3871.5 .50 1913.4 358.3 1954.3 3900.0 .12 1954.4 358.3 1789.96 N 53.17 W 1830.66 N 54.64 W 1871.51 N 55.97 W 1912.51 N 57.28 W 1953.55 N 58.64 W 4800.0 55.19 358.20 3978.3 4850.0 55.25 358.17 4006.8 4900.0 55.32 358.14 4035.3 4950.0 5'5.38 358.05 4063.7 5000.0 55.26 358.00 4092.1 1995.4 3928.6 .16 1995.5 358.3 2036.4 3957.1 .15 2036.5 358.3 2077.5 3985.6 .14 2077.6 358.3 2118.7 4014.0 .20 2118.8 358.3 2159.8 4042.4 .25 2159.9 358.3 1994.57 N 59.96 W 2035.62 N 61.26 W 2076.70 N 62.58 W 2117.81 N 63.95 W 2158.90 N 65.36 W 5050.0 55.20 358.02 4120.6 5100.0 54.93 358.02 4149.3 5150.0 54.73 358.14 4178.1 5200.0 54.71 358.12 4207.0 5250.0 54.23 358.09 4236.0 2200.9 4070.9 .13 2201.0 358.3 2241.8 4099.6 .55 2242.0 358.3 2282.7 4128.4 .44 2282.8 358.3 2323.5 4157.3 .04 2323.6 358.3 2364.2 4186.3 .97 2364.3 358.2 2199.95 N 66.79 W 2240.92 N 68.20 W 2281.76 N 69.57 W 2322.56 N 70.91 W 2363.23 N 72.25 W 5300.0 53.75 357.78 4265.4 5350.0 54.02 357.80 4294.9 5400.0 54.72 357.78 4324.0 5450.0 55.04 357.88 4352.8 5500.0 54.88 357.88 4381.5 2404.6 4215.7 1.07 2404.8 358.2 2445.0 4245.2 .54 2445.2 358.2 2485.7 4274.3 1.40 2485.8 358.2 2526.6 4303.1 .65 2526.7 358.2 2567.5 4331.8 .33 2567.6 358.2 2403.65 N 73.71 W 2444.01 N 75.26 W 2484.62 N 76.83 W 2525.49 N 78.38 W 2566.40 N 79.89 W B.P. EXPLORATION WELL: F PAD, MPF-69, Location: NABORS 4ES, Job Number: AK0596G343 A G y r o d a t a 7 ~! MILNE POINT, ALASKA Directional Survey Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL .SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5550.0 54.71 357.80 4410.3 5600.0 54.60 357.67 4439.2 5650.0 54.29 357.55 4468.3 5700.0 54.52 357.74 4497.4 5750.0 54.47 357.62 4526.4 2608.3 2649.1 2689.8 2730.4 2771.1 4360.6 .35 2608.5 358.2 4389.5 .30 2649.3 358.2 4418.6 .65 2690.0 358.2 4447.7 .54 2730.6 358.2 4476.7 .22 2771.3 358.2 2607.22 N 81 2647.98 N 83 2688.62 N 84 2729.24 N 86 2769.91 N 88 .44 W .05 W ..... .74 W .41 W .06 W 5800.0 53.63 357.50 4555.8 5850.0 53.73 357.40 4585.4 5900.0 53.64 357.21 4615.0 5950.0 54.18 357.31 4644.5 6000.0 54.97 357.38 4673.5 2811.6 2851.9 2892.1 2932.5 2973.3 4506.1 1.69 2811.8 358.2 4535.7 .25 2852.1 358.2 4565.3 .36 2892.4 358.1 4594.8 1.08 2932.8 358.1 4623.8 1.58 2973.5 358.1 2810.35 N 89 2850.60 N 91 2890.84 N 93 2931.20 N 95 2971.90 N 97 .79 W .58 W .47 W .40 W .29 W 6050.0 54.68 357.48 4702.3 6100.0 54.59 357.31 4731.2 6150.0 54.68 357.47 4760.1 6200.0 54.72 357.47 4789.0 6250.0 55.83 357.62 4817.5 6300.0 56.21 357.43 4845.5 6350.0 55.81 357.39 4873.4 6400.0 55.73 357.29 4901.5 6450.0 55.87 357.29 4929.6 6500.0 55.84 357.29 4957.7 3014.1 3054.9 3095.6 3136.4 3177.5 3219.0 3260.4 3301.7 3343.1 3384.4 4652.6 .60 3014.4 358.1 4681.5 .33 3055.1 358.1 4710.4 .32 3095.9 358.1 4739.3 .09 3136.7 358.1 4767.8 2.24 3177.8 358.1 4795.8 .82 3219.3 358.1 4823.7 .81 3260.7 358.1 4851.8 .22 3302.0 358.1 4879.9 .27 3343.4 358.0 4908.0 .05 3384.8 358.0 3012.73 N 99 3053.46 N 100 3094.19 N 102 3134.96 N 104 3176.01 N 106 3217.44 N 108 3258.85 N 110 3300.15 N 111 3341.45 N 113 3382.79 N .115 .12 W .97 W .83 W .63 W .39 W .18 W .05 W .97 W .93 W .88 W 6550.0 56.85 357.29 4985.4 6600.0 56.80 356.95 5012.8 6650.0 56.69 356.76 5040.2 6700.0 56.62 356.65 5067.7 6750.0 56.53 356.56 5095.2 3426.1 3467.9 3509.7 3551.4 3593.1 4935.7 2.01 3426.4' 358.0 4963.1 .57 3468.2 358.0 4990.5 .39 3510.0 358.0 5018.0 .24 3551.8 358.0 5045.5 .22 3593.5 358.0 3424.36 N 3466.16 N 3507.91 N 3549.61 N 3591.26 N 117.85 W 119.96 W 122.25 W 124.65 W 127.12 W B.P. EXPLORATION WELL: F PAD, MPF-69, Location: NABORS 4ES, Job Number: AK0596G343 A Gy r o d a t a 7 i! MILNE POINT, ALASKA Direct i o n a 1 Survey 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 C 00 R D I N A.T E S feet 6800.0 56.50 356.41 5122.8 6850.0 56.33 356.30 5150.5 6900.0 56.31 356.88 5178.2 6950.0 56.21 357.08 5206.0 7000.0 56.14 357.09 5233.8 3634.8 3676.4 3718.0 3759.5 3801.0 5073 5100 5128 5156 5184 .1 .8 .5 .3 .1 .26 3635.2 358.0 .40 3676.8 357.9 .98 3718.4 357.9 .39 3760.0 357.9 .15 3801.5 357.9 3632.89 N 3674.46 N 3715.99 N 3757.52 N 3799.00 N 129.68 W 132.33 W ~' 134.80 W 136.99 W 139.10 W 7050.0 56.09 357.08 5261.7 7100.0 56.51 357.88 5289.4 7150.0 56.54 358.29 5317.0 7200.0 56.51 358.00 5344.6 7250.0 56.15 357.82 5372.3 3842.5 3884.1 3925.8- 3967.5 4009.1 5212 5239 5267 5294 5322 .0 .7 .3 .9 .6 .10 3843.1 357.9 1.58 3884.6 357.9 .69 3926.4 357.9 .48 3968.1 357.9 .78 4009.7 357.9 3840.46 N 3882.01 N 3923.70 N 3965.38 N 4006.96 N 141.21 W 143.04 W 144.43 W 145.78 W 147.29 W 7300.0 55.92 357.82 5400.2 7350.0 55.00 358.10 5428.6 7400.0 55.76 358.24 5457.0 7450.0 55.92 358.23 5485.0 7500.0 57.06 359.03 5512.6 4050.6 4091.8 4132.9 4174.3 4216.0 5350 5378 5407 5435 5462 .5 .9 .3 .3 .9 .46 4051.1 357.9 1.90 4092.3 357.9 1.53 4133.5 357.9 .33 4174.8 357.9 2.62 4216.5 357.9 4048.40 N 4089.57 N 4130.69 N 4172.05 N 4213.72 N 148.87 W 150.33 W 151.65 W 152.92 W 153.92 W 7550.0 57.11 358.62 5539.8 7600.0 56.81 358.48 5567.1 7650.0 56.85 358.28 5594.4 7700.0 56.67 358.10 5621.8 7750.0 56.69 357.93 5649.3 4258.0 4299.9 4341.7 4383.5 4425.3 5490 5517 5544 5572 5599 .1 .4 .7 .1 .6 .68 4258.5 357.9 .65 4300.4 3.57.9 .35 4342.3 357.9 .47 4384.1 357.9 .29 4425.9 357.9 4255.69 N 4297.59 N 4339.43 N 4381.23 N 4422.98 N 154.78 W 155.84 W 157.02 W 158.34 W 159.79 W 7800.0 56.42 357.88 5676.9 7850.0 56.20 357.70 5704.6 7900.0 56.09 357.47 5732.4 7950.0 55.92 357.42 5760.4 8000.0 55.75 357.27 5788.5 4467.0 4508.6 4550.1 4591.6 4632.9 5627.2 5654.9 5682.7 5710.7 5738.8 .54 4467.6~ 357.9 .54 4509.2 357.9 .44 4550.7 357.9 .36 4592.2 357.9 .41 4633.5 357.9 4464.68 N 4506.25 N 4547.73 N 4589.15 N 4630.47 N 161.31 W 162.92 W 164.67 W 166.51 W 168.43 W A Gyrodat a Di re c t i onal Survey B.P. EXPLORATION WELL: F PAD, MPF-69, Location: NABORS 4ES, Job Number: AK0596G343 7 l! MILNE POINT, ALASKA Page 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. HORIZONTAL COORDINATES feet 8050.0 55.60 357.22 5816.7 8100.0 55.52 357.22 5845.0 8150.0 56.60 357.64 5872.9 8200.0 56.72 357.86 5900.3 8250.0 56.48 357.72 5927.9 4674.2 4715.4 4756.9 4798.7 4840.4 5767.0 .31 4674.8 357.9 5795 . 3 . 17 4716 . 1 357 . 9 5823.2 2.27 4757.5 357.9 5850.6 .45 4799.3 357.9 5878.2 .55 4841.1 357.9 4671.72 N 170.41 W 4712.91 N 172.41 W 4754.34 N 174.27 W 4796.08 N 175.91 W 4837.79 N 177.52 W 8300.0 56.37 357.72 5955.5 4882.1 8350.0 56.53 359.11 5983.2 4923.7 8400.0 56.36 .21 6010.8 4965.4 8450.0 56.33 .56 6038.5 5007.0 8500.0 56.03 .54 6066.3 5048.5 8550.0 55.71 .53 6094.4 8600.0 55.61 .48 6122.6 8650.0 55.46 .49 6150.9 8700.0 55.21 .47 6179.3 8750.0 55.04 .35 6207.9 8800.0 55.05 .17 6236.6 8850.0 53.59 .67 6265.7 8900.0 52.61 .93 6295.8 8950.0 52.22 .95 6326.2 9000.0 50.64 1.38 6357.4 9050.0 50.01 1.44 6389.3 9100.0 48.53 1.91 6422.0 9150.0 47.86 1.83 6455.3 9200.0 46.19 1.31 6489.4 9250.0 45.80 1.03 6524.1 5089.9 5131.2 5172.4 5213.5 5254.5 5295.4 5336.0 5376.0 5415.6 5454.6 5493.1 5530.9 5568.1 5604.7 5640.6 5905.8 .20 4882.7 357.9 5933.5 2.33 4924.4 357.9 5961.1 1.87 4966.0 357.9 5988.8 .58 5007.6 357.9 6016.6 .59 5049.1 358.0 6044.7 .64 5090.4 358.0 6072.9 .22 5131.7 358.0 6101.2 .31 5172.9 358.0 6129.6 .49 5214.0 358.0 6158.2 .40 5254.9 358.1 6186.9 .29 5295.9 358.1 6216.0 3.04 5336.5 358.1 6246.1 2.00 5376.4 358.1 6276.5 .77 5416.0 358.1 6307.7 3.24 5455.0 358.2 6339 . 6 1 . 26 5493 . 4 358 . 2 6372.3 3.03 5531.3 358.2 6405.6 1.36 5568.5 358.2 6439.7 3.41 5605.0 358.2 6474 . 4 · 88 5640 . 9 358 . 3 4879.42 N 179.18 W 4921.07 N 180.33 W 4962.74 N 180.58 W 5004.36 N 180.29 W 5045.89 N 179.89 W 5087.28 N 179.51 W 5128.56 N 179.14 W 5169.78 N 178.80 W 5210.91 N 178.45 W 5251.92 N 178.16 W 5292.90 N 177.97 W 5333.52 N 177.67 W 5373.50 N 177.11 W 5413.11 N 176.46 W 5452.20 N 175.67 W 5490.67 N 174.72 W 5528.54 N 173.62 W 5565.79 N 172.40 W 5602.36 N 171.40 W 5638.32 N 170.66 W A Gyrodat B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, ALASKA Job Number: AK0596G343 a D i re c t i ona i Survey Page 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. HORIZONTAL COORDINATES feet 9300.0 44.27 .30 6559.4 9350.0 43.72 359.79 6595.4 9400.0 43.17 359.03 6631.7 9450.0 42.41 358.63 6668.4 9500.0 41.09 358.61 6705.7 5676.0 5710.7 5745.1 5779.0 5812.3 6509.7 3.23 5676.2 358.3 6545.7 1.31 5711.0 358.3 6582.0 1.53 5745.3 358.3 6618.7 1.60 5779.3 358.3 6656.0 2.64 5812.6 358.3 5673.69 N 170.25 W 5708.42 N 170.22 W .... ~ 5742.80 N 170.57 W 5776.76 N 171.27 W 5810.04 N 172.06 W 9550.0 40.25 358.09 6743.6 5844 9600.0 38.72 357.39 6782.2 5876 9650.0 38.40 356.98 6821.3 5907 9700.0 37.64 356.54 6860.7 5938 9750.0 37.14 356.28 6900.4 5969 .9 .7 .9 .6 .0 6693.9 1.81 5845.2 358.3 6732.5 3.19 5877.0 358.3 6771.6 .82 5908.1 358.3 6811.0 1.61 5938.9 358.3 6850.7 1.05 5969.3 358.3 5842.61 N 173.00 W 5874.38 N 174.25 W 5905.51 N 175.78 W 5936.26 N 177.52 W 5966.56 N 179.42 W 9800.0 36.59 356.39 6940.4 9850.0 36.39 356.24 6980.6 9900.0 36.32 356.02 7020.9 9950.0 36.19 356.06 7061.2 10000.0 36.06 355.75 7101.6 5998 6028 6058 6087 6117 .9 .7 .3 .8 .2 6890.7 1.11 5999.2 358.3 6930.9 .44 6029.0 358.3 6971.2 .30 6058.6 358.2 7011.5 .26 6088.1 358.2 7051.9 .45 6117.6 358.2 5996.50 N 181.34 W 6026.17 N 183.25 W 6055.74 N 185.25 W 6085.23 N 187.29 W 6114.63 N 189.40 W 10050.0 35.33 355.47 7142.2 10100.0 35.46 354.63 7183.0 10150.0 34.34 354.29 7224.0 10200.0 33.85 354.31 7265.4 10250.0 33.34 354.57 7307.0 6146.4 6175.2 6203.8 6231.7 6259.3 7092.5 1.50 6146.7 35.8.2 7133.3 1.02 6175.6 358.2 7174.3 2.29 6204.2 358.2 7215.7 .98 6232.1 358.2 7257.3 1.06 6259.7 358.1 6143.72 N 191.63 W 6172.57 N 194.13 W 6201.05 N 196.89 W 6228.93 N 199.68 W 6256.47 N 202.36 W 10262.0 33.27 354.74 7317.1 Final Station Closure: DiStance: 6265.9 6266.32 7267. ft 4 .96 6266.3~ 358.1 Az: 358.14 deg. 6263.03 N 202.97 W A Gyrodat a D i re c t i ona i Survey for B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, ALASKA Job Number: AK0596G343SS Run Date: 22-May-96 11:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 49.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 358.830 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata Direct B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, Job Number: AK0596G343SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -49.7 0.00 0.00 0.0 0.0 0.00 0.O - 10262 FT. GYRO MULTISHOT RUN IN 7" CASING MEASURED DEPTHS ARE REFERENCED TO THE POOL 4ES R.K.B. i o n a 1 CLOSURE DIST. AZIMUTH feet deg. 0.0 0.0 Survey Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .74 338.10 149.7 1.2 200.0 .76 331.93 249.7 2.4 300.0 .77 337.51 349.7 3.6 400.0 .91 341.40 449.7 5.0 500.0 1.18 339.97 549.7 6.7 600.0 1.60 342.82 649.7 9.0 700.0 2.03 342.61 749.7 12.0 800.0 2.33 341.96 849.7 15.7 900.0 2.70 1.97 949.7 19.8 1000.0 3.80 26.30 1049.7 25.0 1100.0 4.91 28.69 1149.7 31.6 1200.0 5.45 26.60 1249.7 39.6 1300.0 6.34 22.03 1349.7 48.9 1400.0 7.06 17.23 1449-.7 59.9 1500.0 7.10 15.47 1549.7 71.7 1600.0 7.44 13.03 1649.7 84.0 1700.0 8.'18 8.62 1749.7 97.4 1800.0 9.00 5.91 1849.7 112.3 1900.0 10.84 4.15 1949.7 129.7 2000.0 13.26 2.11 2049.7 151.0 .41 .09 .14 .24 .30 .42 .43 .30 1.08 1.84 1.18 .58 1.03 .89 .29 .57 .96 .97 1.85 2.40 1.9 340.7 3.2 337.8 4.5 336.5 6.1 337.2 8.2 338.1 11.0 339.0 14.5 339.9 18.6 340.5 22.7 342.9 27.9 349.7 35.3 358.2 44.2 4.7 54.9 8.7 67.1 10.8 79.4 11.7 92.3 i2.1 106.4 11.9 121.9 11.3 140.3 10.5 162.7 9.4 1.18 N .43 W 2.36 N .98 W 3.56 N 1.54 W 4.92 N 2.06 W 6.63 N 2.66 W 8.93 N 3.42 W 11.96 N 4.36 W 15.58 N 5.52 W 19.72 N 6.00 W 24.87 N 4.33 W 31.59 N 2.04 E 39.63 N 3.43 E 49.05 N 7.61 E 60.12 N 11.49 E 72.03 N 14.98 E 84.40 N 18.11 E 97.86 N 20.64 E 112.83 N 22.51 E 130.24 N 24.00 E 151.54 N 25.09 E A Gyrodata B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, Job Number: AK0596G343SS ALASKA Directional Survey 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 COORD.I NATES feet 2100.0 16.30 3.89 2149.7 2200.0 19.98 4.89 2249.7 2300.0 23.65 5.31 2349.7 2400.0 27.06 6.83 2449.7 -2500.0 30.42 4.64 2549.7 2600.0 34.54 3 74 2649.7 2700.0 37.36 1.24 2749.7 2800.0 39.87 358.94 2849.7 2900.0 42.28 357.06 2949.7 3000.0 45.40 355.25 3049.7 177.3 209.8 249.5 296.3 350.4 414.4 487.0 566.9 653.6 750.2 3.06 189.9 8.5 3.55 222.9 7.9 3.41 261.6 7.4 3.12 305.4 7.2 3.16 407.0 7.0 3.52 464.6 6.6 2.58 525.3 6.0 2.34 588.5 5.1 2.01 722.1 4.2 2.38 792.8 3.2 177.84 N 26.51 E 210.44 N 29.11 E 250.21 N 32.65 E 297.14 N 37.64 E 351.36 N 43.18 E 415.48 N 47.85 E 488.13 N 50.74 E 568.02 N 51.02 E 654.72 N 47.99 E 751.16 N 41.30 E 3100.0 48.42 353.96 3149.7 3200.0 51.97 354.04 3249.7 3300.0 52.12 354.07 3349.7 3400.0 53.68 354.40 3449.7 3500.0 55.73 354.55 3549.7 3600.0 55.76 354.43 3649.7 3700.0 55.01 356.11 3749.7 3800.0 54.55 357.94 3849.7 3900.0 55.18 358.10 3949.7 4000.0 55.35 358.10 4049.7 856.4 977.1 1105.5 1239.2 1380.7 1526.5 1670.9 1811.6 1954.3 2098.4 2.15 865.9 2.1 2.18 1020.1 1.1 .87 1178.0 .3 .88 1258.2 359.6 .88 1421.8 359.1 .58 1545.3 358.6 .62 1709.3 358.4 .49 1831.5 358.3 .12 1954.4 358.3 .17 2118.8 358.3 857.17 N 31.21 E 977.72 N 18.87 E 1105.85 N 5.52 W 1239.32 N 8.66 W 1380.53 N 21.68 W 1526.12 N 35.99 W 1670.26 N 47.49 W 1810.88 N 53.93 W 1953.53 N 58.63 W 2097.59 N 63.27 W 4100.0 54.92 358.03 4149.7 4200.0 54.01 357.95 4249.7 4300.0 55.01 357.87 4349.7 4400.0 54.49 357.63 4449.7 4500.0 53.81 357.53 4549.7 2242.4 2383.0 2522.2 2663.8 2803.2 .54 2282.8 358.3 1.02 2404.8 358.2 .73 2526.7 358.2 .43 2690.0 358.2 1.38 2811.8 358.2 2241.51 N 68.22 W 2382.04 N 72.93 W 2521.13 N 78.21 W 2662.62 N 83.66 W 2801.95 N 89.43 W A Gy r o d a t a B.P. EXPLORATION WELL: F PAD, MPF-69, 7" Location: NABORS 4ES, MILNE POINT, ALASKA Job Number: AK0596G343SS Directional Survey Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH · SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 54.32 357.32 4649.7 2939.9 4700.0 54.65 357.41 4749.7 3080.9 4800.0 56.15 357.42 4849.7 3225.3 4900.0 55.85 357.29 ~ 4949.7 3372.6 5000.0 56.67 356.72 5049.7 3524.1 5100.0 56.34 356.30 5149.7 3675.3 5200.0 56.11 357.08 5249.7 3824.7 5300.0 56.44 357.97 5349.7 3975.2 5400.0 55.57 358.20 5449.7 4122.4 5500.0 57.00 358.57 5549.7 4273.2 5600.0 56.69 357.93 5649.7 4425.9 5700.0 55.98 357.44 5749.7 4575.7 5800.0 55.70 357.29 5849.7 4722.5 5900.0 56.39 357.72 5949.7 4873.3 6000.0 56.21 .55 6049.7 5023.7 6100.0 55.46 .49 6149.7 5170.6 6200.0 54.39 .40 6249.7 5313.7 6300.0 51.03 1.27 6349.7 5445.0 6400.0 47.97 1.84 6449.7 5561.9 6500.0 44.69 .50 6549.7 5666.2 6600.0 42.80 358.84 6649.7 5761.7 6700.0 40.01 357.98 6749.7 5849.9 6800.0 37.85 356.66 6849.7 5930.0 6900.0 36.54 356.36 6949.7 6005.8 7000.0 36.23 356.05 7049.7 6079.3 1.17 2973.5 358.1 · 33 3095.9 358.1 .82 3260.7 358.1 · 11 3384.8 358.0 · 34 3551.8 358.0 .40 3676.8 357.9 .12 3843.1 357.9 · 54 4009.7 357.9 1.62 4133.5 357.9 · 67 4300.4 357.9 · 29 4467.6 357.9 · 39 4592.2 357.9 · 53 4757.5 357.9 .28 4882.7 357.9 · 58 5049.1 357.9 .30 5172.9 358.0 1.53 5336.5 358.1 2.63 5455.0 358.1 1.64 5568.5 358.2 2.58 5676.2 358.3 1.56 5779.3 358.3 2.02 5877.0 358.3 1.39 5938.9 358.3 .96 6029.0 358.3 · 27 6088.1 358.2 2938.54 N 3079.49 N 3223.72 N 3371.00 N 3522.33 N 3673.32 N 3822.67 N 3973.09 N 4120.17 N 4270.88 N 4423.58 N 4573.29 N 4719.96 N 4870.65 N 5021.06 N 5168.05 N 5311.19 N 5442.52 N 5559.53 N 5663.93 N 5759.44 N 5847.61 N 5927.67 N 6003.33 N 6076.80 N 95.74 W 102.16 W 108.46 W 115.33 W 123.08 W 132.25 W 140.30 W 146.06 W 151.31 W 155.16 W 159.81 W 165.81 W 172.73 W 178.83 W 180.13 W 178.81 W 177.84 W 175.86 W 172.61 W 170.36 W 170.91 W 173.20 W 177.03 W 181.78 W 186.71 W A Gyrodat a Direc t ional Survey B.P. EXPLORATION WELL: F PAD, MPF-69, 7" ~ Location: NABORS 4ES, MILNE POINT, ALASKA Job Number: AK0596G343SS 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 C O O R D I N A T.E S feet 7100.0 35.35 355.32 7149.7 6151.7 1.41 6175.6 358.2 7200.0 34.03 354.30 7249.7 6221.1 1.47 6232.1 358.2 7267.4 33.27 354.74 7317.1 6265.9 .96 6266.3 358.1 Final Station Closure: Distance: 6266.32 ft Az: 358.14 deg. 6149.01 N 6218.36 N 6263.03 N 192.09 W 198.62 W 202.97 W gyro/data 4. QUALITy CONTROL SR343DOC Quality Control Comparisons B.P. EXPLORATION WELL: MPF-69, 7" Location: F PAD, MILNE POINT, ALASKA Job Number : AK0596G343 / AK0596G343 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN OUTRUN Depth Inc Inc Delta Az Az 4000.0 55.63 55.63 .000 354.46 354.70 7000.0 56.12 56.12 -.001 356.42 356.96 10262.0 33.27 33.29 -.019 354.74 354.74 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.0068 deg. Average Azimuth Difference = -.2598 deg. Delta -.238 -.541 -.000 gyro/data QUALITY CONTROL REPORT JOB NUMBER' AK0596G343 TOOL NUMBER' 748 MAXIMUM GYRO TEMPERATURE · 75.7C MAXIMUM AMBIENT TEMPERATURE · 18.9C MAXIMUM INCLINATION' 57.07 AVERAGE AZIMUTH ' 358.15 WIRELINE REZERO VALUE' 2 FT REZERO ERROR / K' CALIBRATION USED FOR FIELD SURVEY' 1482 CALIBRATION USED FOR FINAL SURVEY · 1482 PRE JOB MASS BALANCE OFFSET CHECK · POST JOB MASS BALANCE OFFSET CHECK~ · CONDITION OF SHOCK WATCHES -.5 USED -1.0 UPON ARRIVAL AT RIG · OK UPON COMPLETION OF SURVEY · OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 10262 33.29 354.74 7317.1 6263.11N 201.96W FINAL SURVEY 10262 33.29 354.74 7317.1 6263.11N 201.96W SR343DOC gym/data FUNCTION TEST JOB NUMBER' AK0596G343 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 10262 33.29 33.29 33.29 33.29 33.29 AZIMUTH M.D. ff 1 2 3 4 5 10262 354.74 354.74 354.74 354.74 354.74 SR343DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR343E)OC "i gyro/data EQUIPMENT REPORT JOB NUMBER: AK0596G343 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL' No. 748 GYRO SECTION A0106 DATA SECTION C0031 POWER SECTION C0046 COMPUTER POWER SUPPLY PRINTER INTERFACE A0222 A0085 A0079 A0074 BACKUP TOOL No. 705 GYRO SECTION A0082 DATA SECTION C0063 POWER SECTION C0059 COMPUTER POWER SUPPLY PRINTER INTERFACE A0246 A0107 A0029 A0071 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: 22 FEET MAXIMUM O.D.: 3.6 INCHES TOTAL WEIGHT OF TOOL: 25O POUNDS SR343DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER' AK0596G343 05/22/96 0900 11:00 1500 05/22/96 05:30- TO LOCATION 07:20 09:30 07:45 11:00 16:15 16:45 18:30 21:30 TO DEADHORSE ARRIVED AT ATLAS CHECK TOOLS O.K. ARRIVE LOCATION . MU TOOL, STANDBY RU ATLAS START INRUN SURVEY05/30/96 GYROCOMPASS OUT LD TOOL. RD ATLAS. PROCESS SURVEY. PROCESS SURVEY RETURN TO RIG WITH SURVEY. SR343DOC red rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 14 1998 Naska 0ii & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with Our records and are able to provide you with the following data: Individual Annular DisPosal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The~SSD records are proVided to you.in the. same order as listed on your log. There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1.65/N-25, 1-59/0-24 · EXploration well Pete's Wicked #1 : · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #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, 15'42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection, logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be Permitted with a SUndry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide .you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: ..Annular Disposal Letter 12/14/98 I ! · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - · ~.-o~.],~__.,_. ~ ~-ny / ~ - · Mflne Point wells F-06, H-05, H-06, J-13, L-24 - · PBU wells-18-30, 18-31, 14~,~43, ~-34, E-36, G-04A, and S-33- · Individufl logs me provided to ~ou for these ~ogs as we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED oEc !4 Masks Oil & ~as Cons. oommissior~ A,nchorase ANNULAR INJECTION DATA ENTRY SCREEN Asset UilD.e. .......................................... Rig Name N.~b.Qr.~..~.-LE ............................. Inj Well Name M...P...F.r~.c':':J. ..................................... Sur Csg Dep ~.7..7..~ ................ Legal Desc ~.l'~.5.'.~I~.L.~.5.02,,:W. EL,..S.e.c..§,.T..13N,.B.tQE .................................... Permit Start ........ .8/..~J.L~.$ ........ Permit End ....... 'l~.:~.l/.[~.~..: ..... Cumulative Data : .Rigi~ :. ComPletion Formation :. intermittant Final WelITotal MUd/Ctg WaSh:: ~ Fi~ids :. ~j~i~s: :: : ::Freeze: FreeZe . !: . 1:: · . ' .: }~1: :': i - - . . Research Daily Data 110 25O 200 350 !443 ,582 ' 1,790 307 525 53O 586 632 125 24O 130 1,815 _~i:'~_?_'_i'/ ..... Open Sharrd SerVice Drilling Anna;Tar Injection Volumes July 25, 1995 until December 1998 Cumulative Report Rig 'lnj Well Endicott Doyon 15 1-19/I;18 Doyon 15 1-23/O- 15 Doyon 15 1-33/M-23 Surface Casing Depth Legal Desc Cum Total 5000 Sec. 36, T12N, R16E 8,960 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 Cum Mud Cum Rig & Ctgs Wash 7,848 992 _. 30,604 1,160 9,729 150 Cum Compl Cum Form Cumlnterm Cum Final Disposal Period Annulus Fluids Fluids Freeze Freeze Start End Slalus . ._ 120 12/5/95 12/5/96 Open 200 120 g/30/95 12/31/95 Open 8/31/95 12/31/95 Broached Doyon 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 ::)oyon 15 2-40/S-22 4531 2020'FNL 2289'FEL Sec 36 T12N R16E 31 195 29 952 1,063 ....... . ................................. ,_ .........._, ....... ~ .....: ............ ·.,. _ ...........~ v_ _ .... --oA ::)oyon 14 15-47 3515 3648'NSL, 4956'WEL~ Sec 22,T11N, R14E 3,002 903 2,009 1,176 60 12/5/95 12/5/96 Open 120 60 7/25/95 12/31/95 Open 90 11/7/95 . 12/31/95 Open )oyon 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 3,385 216 820 2,283 66 12/21/95 )?_yo_n__l_4_ .... DS 15-48 . 3548 )oyon 14 . DS 15-49 3667 Sec. 22, T11N, R14E 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 )oyofl g 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open )oyon 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 )oyon 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,100 150 8/24/95 12/31/95 Open )oyon 9 18-33 4140 36g0'NsL, 56'WEL, Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open labors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 g/1/95 12/31/95 Open labors 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 labors 18E 13-36 3431 1585'NSL, 5187~NEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open 'abors 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open xploration ool 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, TgN, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed !line 27E MPK-17 3508 3648'NSL,2100~CVEL, Sec.03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open abors 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open abors 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open abors 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/lg/96 Open ~bors 22E MPC-28 5405 : Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open 12/21/96 Open 2/21/97 Open Page 1 .DB 1 4. 1998 ~chomgo . Sha~..d Service Drilling Annular Injection Volumes July 25, 199~ until December 1998 Cumulative Report Rig Inj Wel! Nabors 22E MPF-06 Nabors 22E MPF-14 Nabors 22E MPF-70 Nabors 22E MPH-05 Sudace Casing Cum Mud Cum Rig CumCornpl Cum Form Cum Interm Cum Final Depth Lega! Desc Cum Total & Ctgs Wash Fluids Fluids Freeze.. Freeze 8766 Sec 06,T13N, R10E 1,927 ~,731. . ......... 196 . _ . 6690 Sec'06,T13N, R10E UM 18,717 17,107 1,270 ............. .3_4._0 7919 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 ....... 735 _ ... 190 .56 . 5335 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190__ 180 8/5/95 Disposal Period Start End 1/25/96 1/25/97 6/3/96 6/3/97 .. 6/17/96 6/17/97 8/19/95 12/31/95 Annulus Stalus Open Open ... Open Open 12/31/95 Open Nabors 22E MPH-06 _. Nabors 22E MPI-07 _ ._ Nabors 22E MPJ-13 Nabors 22E MPJ-16 Nabors 27E B-24 7304 2824'NsL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 ................ .... 8_0_.~ ...... 7_0__ ............. 9/21/95 12/31/95 ............. Open 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10117/95 ................. 12/31/95 Open 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 70 11/12/95 12/31/95 1/25/96 1/25/97 Open Open Nabors 27E . . Nabors 27E MPF-22 12/12/95 Open 12/26/95 Open 8841 Sec 06,T13N, R10E UM 6,536 6,466 7O 12/12/96 MPF-25 3405 i 857'NSL, 2696'WEL, sec 6,T13N, R 10E ' 9,897 9,357 250 225 65 1 2/26/96 Nabors 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 Nabors 27E MPF-38 8561 1994'NSL, 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6_/9_5_ _ __1.~.3.1_/9~5 ......_O__p_e.n__ ..... Nabors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 Open Nabors 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 --- 75 8/31/95 1 2/31/95 Open Nabors 27E MPF-61 6585 2077'NSL, 526'WEL; Sec 31,T14N, R10E 5,732 5,657 Nabors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open Nabors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 75 8/31/95 12/31/95 Open Nabors 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 Open Nabors 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 woA 18E F-33 3570 3332'NSL, 2174~NEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open 18E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 135 12/18/95 12/18/96 Open 3oyon 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 ~)oyon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96 4/10/97 Open ;)oyon 9 D-33 3P2:~ 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/g6 2/21/97. Open qabors 18E S-43 3121' 4211'NSL,4503'WEL, SEC35,T12N,R12E 5,943 2,636 1,716 1,511. 80 5/7/97 5/7/98 OPEN Page 2 Shared` S, ei~ice Dr..illing Ann1~l~r Injection' Volumes July 25, 1995. until December 1998 Cumulative Report Sudace Casing Rig Inj Well Depth Nabors 28E B-33 3504' . . Nabors 28E E-34 3664 Nabors 28E E-36 3648 . Nabors 28E E-37 3810 Cum Mud Legal Desc .. cu~m Tota! & Ctgs 96g'SNL, 1898'EWL. Sec 31, T11N, R14E 3,974 2,842 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 Cum Rig Cum Compl Cum Form Wash Fluids Fluids . .. 857' 1,420 858 1,293 3,096 374 Cum Interm Cum Final Disposal Period Annulus 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 Nabors 28E E-39 3638 3358'NSL, 501'WEL. Sec 6.T11N. R14E Nabors 28E G-04A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E Nabors 28E G-21 3509 2911'NSL. 2368'WEL, Sec 12,T11N, R14E Nabors 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E Nabors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 2,250 928 ' 220 1,022 5,937 1,798 1,824 2,315 11,430 3,956 3,072 4,270 20,261 11,773 2,177 5,751 18,014 6,613 2,431 8,392 80 8/28/95 12/31/95 Open . 10/20/95 12/31/95 Open 70 62 9/8/95 12/31/95 Open 275 285 12/9/95 12/9/96 Open 270 308 12/1/95 12/1/96 Open Nabors 28E S-41 3331 4152; NSL, 4504' WEL, Sec 35,T12N, Nabors 28E S-42 3077 Sec 35, T12N, R12E 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 3/13/96 3/13/97 168 100 68 Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, ~R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 Open Nabors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21 ,T11N, R13E 1,452 857 100 410 85 10/~6/9_5 __ .~1._2/31/95 Open .. Open Open SCANNED NOV I 3 2002 Page 3 8red .cos rilling TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 l~7~TuI S~N~BK4OD ~ou~TIdmOO uT sT II~M _~--.eA ZpeATeOe~ UOTqdT~osep ~ STSXietnf~-~ sea Zpe~oo IIem eqq SeM £0P-0I 96/I5/90 96/80/~0 I 96/80/~0 I 96/9t/~0 -~ S6/8~/60 I ~6/~0/0z z s6/~0/0z z 96/~/~o 96/£~/~0 96/£~/E0 96/£~/~0 96/SI/S0 ~/~ O_ADZH Z~ 86/£I/S0 :~ L896-S9~6 ~IdZS~l~ MMM~/~DD SET-S6 ~i~s~ .~.~/~oo/~s S~T-S6 SET-S6 SET-S6 9I£01-00£6 ~ % '~, ~ S~ICT~ SCT-S6 9I£01-00~6/D ~DD/~D SET-S6 -- X~oqu~uI sI~;eN IeD~6oIo~ II~M Ienp~puI DD~O~ ~m - ~s/~a ~- ~s/~a cL~m - CE4 - SNZ~/ND 580£ SETiS6 SE:T-S6 SET-S6 SCTiS6 S~T-S6 STATE OF ALASKA ALASIkJ-,, 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 Exchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2124' NSL, 2502' WEL, Sec. 6, T13N, R10E, UM At top of productive interval 2915' NSL, 2613' WEL, Sec. 31, T13N, R10E, UM At effective depth 3132' NSL, 2627' WEL, Sec. 31, T13N, R10E, UM At total depth 3176' NSL, 2629' WEL, Sec. 31, T13N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE - 49' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-69 9. Permit Number / Approval No. 95-125 10. APl Number 50-029-22586 11. Field and Pool Milne Point Unit / Kuparuk River Sands 10408' feet 7454' feet 10326' feet 7385' feet Length Size 72' 20" 5542' 9 5/8" 10375' 7" Plugs (measured) Junk (measured) Cemented MD TVD 9954'-9964'(B sands),10009'-10099' 7078'-7088',7124'-7200' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9741' Packers and SSV (type and measured depth) None 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 In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] 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 Date ~ f'C(.P~J ./ v Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Dup!icate~ 250 sx Arcticset (approx.) 11 O' 11 O' 1125 sx PF 'E', 250 sx 'G' 5578' 4430' 250 sx PF 'E' 250 sx Class 'G' 10408' 7454' SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING- BPX ! ARCO Well Name: MPF-69 Rig Name: N-4ES AFE# 339049 Accept Date: 07/08/97 Spud Date: . Release Date: 07/11/97 JULY 09, 1997 RIG ACCEPTED @ 20:00 HRS 07/08/97 RD & MOVE TO F-69 SPOT RIG ON WELL & RAISE DERRICK RU MUD & FLOW LINES ACCEPT RIG SPOT & BERM TIGER TANK. RU KILL LINES PULL BPV W/LUB TEST LINES TO 2000 PSI GOOD OPEN WELL TP=600 PSI CP=640 PSI BLEED GAS DISP WELL TO SW TAKE RETURNS TO TIGER TANK. LET PRESSURE STABILIZE & MONITOR WHP 180 PSI ORDER OUT 9.2# BRINE FROM BAROID PLANT CONT TO CIRC WELL W/EXTRA SW RETURN TO TT, WO BRINE MONITOR WELL (AGAIN STABILIZED W/WHP @ 180 PSI) SERVICE RIG. JULY 10, 1997 MONITOR WELL & FILL PITS W/9.2 PPG BRINE KILL WELL W/9.2 PPG BRINE SAFETY FOCUS SHUT DOWN INSTALL TWC & ND TREE & NU BOP'S TEST BOP'S TO 250 LOW & 5000 HIGH MU LANDING JT & PULL HANGER TO FLOOR & LD SAME CIRC OIL & GAS OFF TOP OF WELL THROUGH CHOKE & RAISE WT TO 9.3 PPG & MONITOR SAME TOH & DRIFT TBG SAFETY FOCUS SHUT DN POOH W/ESP COMPLETION, JULY 11, 1997 CONT POO & LD ESP ASSY RIH HES & RIH W/3.75" SWEDED TO 10147' (WLM) MU ESP ASSY & SERVICE (WELL STARTED FLOWING) SHUT WELL IN & MONITOR & MU 150 BBL 9.9 PPG BRINE (30 PSI SIP) BULLHEAD 150 BBL 9.9 BRINE (30 PSI SIP) BULLHEAD 150 BBL 9.9 TO 3500' (TVD) & MONITOR WELL. MU CABLE & ATTACH TO ESP ASSY & RIH TO 7800' CHG CABLE SPOOLS & SPLICE SAME CONT TIH & MU HANGER & LANDING JT. MU PIGTAIL & SPLICE @ HANGER & CIRC OUT WELL BORE INFLUX BY CHOKE (WELL STARTED FLOWING AS HANGER WAS BEING MU). JULY 12, 1997 CONT TO CIRC OUT GAS & OIL & SPOT 30 BBL 9.9 IN TBG CONNECT ESP CABLE TO PENETRATOR & LAND HGR & RILDS & INSTALL BPV. ND BOP'S & NU TREE TEST TREE TO 5000 PSI AGAINST TWC FREEZE PROTECT WELL TO 2000' W/DIESEL RIG DOWN LINES TO TREE & SECURE SAME BPV SET, RIG RELEASED @ 1500 HRS 07/11/97. Page 1 of 1 STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPE~IDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc 95-125 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5 o- 029-22586 4. Location of well at surface 9. Unit or Lease Name ] ~i 10.Miine P°int Unitwell Number 2124' NSL, 2502' EEL, SEC. 6, T13N, RIOE ~'"':!~i~.~;~i~:}:.~' i At Top Producing Interval ! i ;q'i; ~ .J~ ~,,.,'i 2915' NSL, 2613' WEL, SEC. 31, T,,N, R,OE ~ w-".:.,~"~' i '~i 11. Field and '001 At Total Depth .~_~_______~ ..... ~~~ Milne Point / Kuparuk River 3190' NSL, 2630' WEL, SEC. 31, T14N, RIOE ......... ~, ...... ~;~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 49' ADL 355018 .. 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 08/31/95 09/08/95 05/23/96I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10435'MD/7477'TVD 10324'MD/7383'TVD YES [] NO [] N/A feet MD 1800'(Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, GR/RES/NEU/DEN, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SE'ITING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT8OLHE 38' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 5778' 12-1/4" ~ 125 sx PF 'E; 250 sx 'G', 250 sx PF 'E' 7" 26# L-80 33' 10408' 8-1/2" 250 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 9726' N/A MD TVD 10009'- 10099' 7122;7195' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4-1/2" Gun Diameter, 5 spf - Add perfs 01/17/96 Freeze protect w~ 70 bbls diesel to 2000' MD TVD Frac'd 10009 '- 10099' 107000# 16/20 Carbolite behind pipe 9954'-9964' 7077;7085' .. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 05/25/96 ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE 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 ]~' P ~' ~ .J~ ~ ~ ! I" I~ 28. CORE DATA '' ~' ~'' iL, ! ~¢ [~ U Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core ~i~s~ 7-~} ~vO~q~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEFTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) .. Top Kuparuk 'B' 9938' 7018' Top Kuparuk 'A ' 10004' 7071' Top Kuparuk A3 10015' 7080' Top Kuparuk A2 10033' 7095' Top Kuparuk A 1 10064' 7120' $1. LIST OF A'I-f'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~"¢~~- T,tle$on[orDdlling~n~]n~r Date / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show 'the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 oP/AAI SHARED SERVICE DAILY OPERATIONL PAGE: 1 WELL: MPF-69 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/01/95 12:01 SPUD: RELEASE: 09/10/95 11:59 OPERATION: DRLG RIG: NABORS 27E WO/C RIG: 09/01/95 ( 1) TD: 746'( 0) 09/02/95 (2) TD: 2950' (2204) 09/03/95 (3) TD: 4710' (1760) 09/04/95 (4) TD: 5810' (1100) 09/05/95 (5) TD: 5810' ( 0) DRILLING MW: 0.0 VIS: 0 MOVE RIG IN AND SET UP. P/U BHA, KELLY UP. TAG UP AT 89'. BREAK CIRC, CHECK FOR LEAKS. MU MWD, ORIENT, PICK BHA. DRILL F/Il0' TO 746' DRILLING MW: 0.0 VIS: 0 DRILL F/746' TO 2197' CLEAN SUCTION SCREENS ON MUD PUMPS. PLUGGING W/MUD ADDITIVES. DRILL F/2197' TO 2762'. PUMP HI-LO VIS SWEEP. CIRCULATE HOLE CLEAN. MONITOR WELL. SHORT TRIP TO 1646'. NO PROBLEMS, NO FILL. DRILL F/2762' TO 2950'. SHORT TRIP MW: 0.0 VIS: 0 DRILL F/2197' TO 3673' CIRC HI-LO SWEEP, MONITOR WELL, PUMP DRY JOB. POOH TO MWD. CHANGE CHOKE IN PULSER, DOWNLOADING MWD, INSPECT FLOAT. CHANGE BIT, RIH TO HWDP. RIH T/3630', BREAK CIRC, REAM 43' T/3673'. NO PROBLEMS, NO FILL. DRILL F/3673' TO 4710' CIRCULATE HI-LO VIS SWEEP, MONITOR WELL, PUMP DRY JOB. POOH T/3600'. POOH TO RUN 9-5/8" CASING MW: 0.0 VIS: 0 SHORT TRIP T/3600', NO PROBLEMS, NO FILL. DRILL 4710' TO 5810'. HIT HARD SPOT OR BALLED UP AT 5247'. CIRC LO-HI VIS SWEEP. MONITOR WELL, PUMP DRY JOB. SHORT TRIP TO HWDP SLM, NO CORR, NO PROBLEMS, NO FILL. PUMP LO-HI VIS SWEEP. CIRC UNTIL HOLE CLEAN. MONITOR WELL, PUMP DRY JOB. POOH TO RUN 9-5/8" CASING. TEST BOPE MW: 0.0 VIS: 0 POOH TO TUN 9-5/8" CASING. OK. LD BHA. DOWNLOAD MWD. RU TO RUN 9-5/8" CASING. RUN 141 JTS CASING. MU LANDING JT HANGER & CEMENT HEAD. BREAK CIRC, INCREASE RATE TO 12 BPM, 400 PSI. OK. DISPLACE CEMENT WITH RIG @ 12 BPM, ICP 400 PSI,RCP 1550 PSI,BUMP PLUG W/1200 PSI,HELD FOR 5 MIN. CHECKED FLOATS. OK. NO CEMENT TO SURFACE. RU & DO 50 BBL TO JOB. RD FLOWLINE,DIVERTER LINE,MOUSE HOLE. LD LANDING JT. SET BACK HYDRIL. PREP CELLAR TO NU FMC WELLHEAD. NU CASING HD & TBG SPOOL. TEST W/1000 PSI. NU XO'S & BOPE. INSTALL RISER, MOUSEHOLE,FLOWLINE,FILL UP,CHOKE & KILL LINES. TEST BOPE & SAFETY VALVES F/250 PSI T/5000 PSI. WAIVED BY JERRY HERING. ,~ELL : MPF-69 OPERATION: RIG : NABORS 27E PAGE: 2 09/06/95 (6) TD: 7170'(1360) 09/07/95 ( 7) TD: 8830'(1660) 09/08/95 (8) TD:10047' (1217) 09/09/95 (9) TD:10435' ( 388) 09/10/95 (10) TD:10435' ( 0) 09/11/95 (11) TD:10435' ( 0) DRILLING MW: 0.0 VIS: 0 INSTALL WEAR RING. MU BHA, ORIENT MWD & MOTOR. LOAD SOURCES. RIH T/4762'. TEST CASING W/3000 PSI FOR 30 MIN. OK. PERFORM STRIPPING DRILL. RIH T/5612'. KELLY UP,BREAK CIRC. WASH T/5691'. DRILL FLOAT COLLAR, 82' CEMENT, SHOE, 10' NEW HOLE T/5820'. CIRC PERFORM LOT. DRILL F/5820' T/7170'. DRILLING MW: 0.0 VIS: 0 SWEEP HOLE. CIRC UNTIL HOLE CLEANS UP. FLOWCHECK WELL. OK. PUMP DRY JOB. SHORT TRIP T/7205' MD TO 9-5/8" SHOE AT 5778' MD. RIH. OK. NO FILL. DRILLING F/7205' MD T/8789' MD. SWEEP HOLE. CIRC UNTIL HOLE CLEANS UP. FLOWCHECK WELL. OK. PUMP DRY JOB. SHORT TRIP F/8789' MD T/7200' MD. RIH. OK. NO FILL. HOLE IN GOOD SHAPE. DRILLING F/8789' MD T/8830' MD. DRILLING MW: 0.0 VIS: 0 DRILLING F/8830' MD T/10047'. ESTIMATE TOP OF KUPARUK 'C' SAND @ 9937'MD. CIRC/COND B4 POOH LDDP MW: 0.0 VIS: 0 DRILLING F/10047' MD T/10203' MD. DRILLING F/10203' MD T/10230' MD. SLIGHT INCREASE IN FLOW. MONITOR WELL. WELL NOT FLOWING. SOME OIL IN MUD AT SHAKERS. ENCOUNTERED SMALL DRILLING BREAK 10212' MD TO 10219' MD. CBU. MUD WEIGHT AT BOTTOMS UP 10.1 IN & OUT. MONITOR WELL. STABLE. DRILLING F/10230' MD T/10435' MD. CIRC & COND MUD FOR SHORT TRIP TO SHOE. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. POOH W/10 STDS. LD 9 SINGLES. CONT POOH TO 9-5/8" SHOE. RIH T/10128' MD. FILL DP. PRECAUTIONARY REAM F/10128' MD T/10435' MD. TRIP GAS TO SURFACE AT BOTTOMS UP. MONITOR WELL. NO FLOW. WELL STABLE. CIRC & COND WELL BEFORE POOH LDDP. RIH W/7" CASING MW: 0.0 VIS: 0 FLOWCHECK WELL. PUMP DRY JOB. SET BACK KELLY. POOH LDDP AND LD HWDP. DOWNLOAD MWD AND SOURCES. PULL WEAR RING. INSTALL TEST PLUG. CHANGE RAMS. TEST DOOR SEALS. RU TO RUN CASING. RIH W/7" CASING. RIG RELEASED MW: 0.0 VIS: 0 CONTINUE RIH W/7" CASING. LAND CASING. CIRCULATE. BUMPED PLUG. INSTALL AND TEST PACKOFF. CHANGE RAMS TO 5". ND FLOWLINE, FLOW NIPPLE, BOPE. INSTALL TUBING HANGER AND RILDS. NU ADAPTER FLANGE AND TREE. TEST TREE. FREEZE PROTECT WELL. RELEASE RIG 2400 HRS 09/10/95. SIGNATURE: (drilling superintendent) DATE: SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-69 Rig Name: 4ES AFE: 330184 Accept Date: 02/22/96 Spud Date: Release Date: 02/27/96 Feb 23 1996 MIRU. Rig lines to tree & test against plug. OK. ND tree & NU BOP's. RU & test BOP's. Test waived by Bobby Foster w/AOGCC. Rig floor, etc. MU Baker retrieving tool & RIH w/same picking up 3-1/2" DP. Rig accepted 02/22/96 @ 1500 hrs. Feb 24 1996 Displace freeze protection. Cont PU 3-1/2" DP t/9578'. Drift & SLM same. Cond brine & add Zanvis & liquid casing. Wash down & tag plug @ 9599' & equalize & monitor well & release same & RIH t/9606'. CBU & monitor well. POOH with plug. MU BHA & RIH with same. Feb 25 1996 Cont to RIH t/9617'. Wash frac sand out of 7" casing with viscosified brine. Had difficulties while going through perf sections with 6" mill. Wash to plug back TD. Rev circ well bore clean of sand - lost circ material. Feb 26 1996 Cont to perform casing wash at 9750'. POOH, LD DP. Pull WR & set test plug. Change rams to 2-7/8" & test. RU to run ESP & MU ESP assy & RIH with same. Feb 27 1996 Cont to RIH with ESP completion. MU tubing hanger, splice ESP cable & land tubing. RILDS & set TWC. ND BOP & NU tubing flange & tree & test same. Mix & pump Xanvis sweep & follow with source water to recover brine. Release rig 02/27/96 @ 0600 hrs. Page SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO .. Well Name: MPF-69 Rig Name: 4ES AFE: 3301 84 Accept Date: 05/20/96 Spud Date: Release Date: 05/23/96 May 21 1996 MIRU. Berm & raise & level derrick & rig floor. Rig accepted 05/20/96 @ 1100 hrs. Take on brine & pull BPV & rig hard lines & test for leaks. Circ out oil & gas influx to t/tank with brine. Monitor well. Spot liquid casing pill & cut weight. Well still not acting right. Gas & oil influx working to top. Rig Camco & RIH & pull & re-set dummy valve in GLM. Circ wellbore with brine. Well acting more like it should. Monitor well bore well stable with small loss. RU to set TWC & NU. May 22 1996 ND tree & NU BOP's. Repair test pump RU & test BOP's. Test waived by Doug Amos. Circ oil & gas influx out through choke until clean. Open annulus & circ & spot LCM pill liquid casing & Zanvis. PI hanger to floor & meg. Monitor. LD hanger & monitor. Circ .. LCM pilll out of tubing. POOH w/ESP completion. May 23 1996 POOH with ESP completion. ND riser & flowline & NU perf flange & Atlas lub & test. Rig Atlas & RIH w/Gyro t/10259'. Survey t/4000', log failed. Change out Gyro & survey f/4000' to surface. RD Atlas. ND perf flange. NU flowline. MU & service ESP. Make pigtail splice. RIH w/ESP completion. May 24 1996 Cont to RIH w/ESP completion. MU hanger & landing jt. MU splice in hanger. Land tbg. RILDS & LD landing jr. ND flowline riser & BOP's. NU tree & test & hanger flange & pull 'TVVC. Freeze protect tbg & annulus t/2000' & set BPV. Secure wellhead & blow down diesel lines. Release rig 05/23/96 @ 1500 hrs. Page S RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE J EXPLORATION (ALASKA) INC .4ILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 MWD SURVEY JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -47.73 162 162.53 114.80 253 253.63 205.90 342 342.00 294.27 432 431.99 384.26 0 0 N .00 E .00 .00N .00E 0 48 N 25.87 W .49 1.02N .50W 1 47 N 24.07 W 1.10 2.90N 1.36W 0 26 N 18.56 W 1.54 4.49N 2.03W 0 56 N 28.89 W .57 5.46N 2.50W .00 1.03 2.93 4.53 5.51 518 518.91 471.18 608 608.74 561.01 696 696.25 648.52 787 787.76 740.03 883 882.77 835.04 1 16 N 26.10 W .40 6.96N 3.27W 1 34 N 15.04 W .45 9.06N 4.03W 1 46 N 18.54 W .25 ll.50N 4.78W 2 15 N 20.84 W .53 14.53N 5.86W 2 35 N 23.10 W .38 18.25N 7.37W 7.02 9.14 11.60 14.64 18.40 982 982.27 934.54 1079 1079.22 1031.49 1173 1172.72 1124.99 1267 1266.02 1218.29 1363 1362.05 1314.32 2 42 N 27.35 E 2.27 22.42N 7.18W 4 20 N 31.92 E 1.70 27.58N 4.18W 5 3 N 25.96 E .92 34.31N .50W 5 1 N 25.14 E .08 41.72N 3.05E 6 46 N 18.89 E 1.93 50.93N 6.69E 22.57 27.66 34.31 41.65 50.79 1457 1454.95 1407.22 1552 1549.13 1501.40 1647 1643.74 1596.01 1741 1736.30 1688.57 1835 1830.13 1782.40 7 8 N 17.99 E .41 61.68N 10.27E 6 30 N 15.32 E .74 72.48N 13.51E 7 25 N 13.65 E .98 83.67N 16.39E 8 18 N 6.98 E 1.35 96.23N 18.63E 8 16 N 5.52 E .22 109.82N 20.12E 61.46 72.19 83.32 95.83 109.38 1930 1923.54 1875.81 2026 2017.51 1969.78 2121 2109.46 2061.73 2214 2199.43 2151.70 2309 2289.05 2241.32 10 11 N 4.50 E 2.03 124.95N 21.43E 12 36 N .15 W 2.70 143.87N 22.07E 14 38 N 5.16 E 2.53 166.12N 23.12E 17 43 N 7.22 E 3.34 192.07N 25.98E 20 52 N .04 W 4.16 223.35N 27.79E 124.48 143.39 165.61 191.50 222.73 2404 2376.46 2328.73 2497 2460.51 2412.78 2591 2543.37 2495.64 2684 2622.34 2574.61 2781 2702.20 2654.47 24 27 N 6.20 E 4.56 259.73N 29.89E 26 55 N 5.63 E 2.66 299.96N 34.05E 30 1 N 5.98 E 3.29 344.68N 38.61E 33 4 N 4.51 E 3.38 392.96N 43.01E 36 17 N 1.52 E 3.75 448.12N 45.86E 259.07 299.20 343.82 392.00 447.09 2877 2777.93 2730.20 2971 2850.74 2803.01 3065 2922.01 2874.28 3159 2991.07 2943.34 3254 3057.98 3010.25 38 26 N .05 E 2.44 505.95N 46.63E 39 57 N 1.51 W 1.92 565.30N 45.86E 41 37 N 2.37 W 1.87 626.75N 43.77E 44 9 N 3.88 W 2.91 690.80N 40.26E 45 47 N 4.99 W 1.91 757.45N 35.08E 504.89 564.25 625.73 689.84 756.57 ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE P EXPLORATION (ALASKA) INC MILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 MWD SURVEY JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3348 3122.40 3074.67 3441 3183.79 3136.06 3535 3242.24 3194.51 3596 3279.12 3231.39 3691 3337.38 3289.65 47 47 50 28 52 28 52 21 51 48 N 5.48 W 2.17 825.75N 28.81E N 5.73 W 2.85 896.37N 21.88E N 5.42 W 2.16 969.44N 14.75E N 5.13 W .43 1017.17N 10.35E N 4.68 W .69 1091.68N 3.95E 824.99 895.74 968.93 1016.74 1091.37 3784 3393.46 3345.73 53 54 3879 3449.75 3402.02 53 27 3972 3504.30 3456.57 55 5 4066 3557.76 3510.03 55 32 4159 3610.43 3562.70 55 27 N 5.22 W 2.31 1165.45N 2.45W N 4.50 W .78 1241.74N 8.93W N 4.99 W 1.81 1317.31N 15.21W N 4.77 W .52 1394.29N 21.78W N 5.20 W .39 1470.62N 28.44W 1165.26 1241.67 1317.35 1394.44 1470.89 4252 3663.23 3615.50 55 29 4347 3717.37 3669.64 55 2 4443 3772.75 3725.02 54 11 4538 3828.75 3781.02 54 7 4632 3883.33 3835.60 54 39 · N 5.22 W .05 1547.04N 35.41W N 4.05 W 1.11 1624.87N 41.72W N 1.03 W 2.73 1702.76N 45.19W N 1.92 W .76 1780.25N 47.18W N .79 W 1.13 1856.42N 48.98W 1547.44 1625.39 1703.33 1780.84 1857.03 4729 3939.28 3891.55 55 1 4823 3993.04 3945.31 55 0 4918 4047.63 3999.90 55 8 5013 4101.61 4053.88 55 7 5107 4156.00 4108.27 54 46 N 1.44 W .67 1935.83N 50.53W N .92 W .45 2012.65N 52.11W N 1.52 W .53 2090.82N 53.77W N 1.95 W .37 2168.25N 56.12W N 1.16 W .78 2245.78N 58.23W 1936.46 2013.29 2091.48 2168.95 2246.50 5202 4210.60 4162.87 5297 4266.36 4218.63 5390 4320.96 4273.23 5485 4375.62 4327.89 5580 4431.03 4383.30 54 28 53 44 54 47 54 36 54 23 N 1.07 W .34 2322.66N 59.72W N 1.43 W .83 2399.69N 61.40W N 1.57 W 1.13 2475.55N 63.39W N 1.91 W .35 2552.70N 65.73W N 1.29 W .58 2630.36N 67.90W 2323.40 2400.44 2476.33 2553.51 2631.20 5675 4486.42 4438.69 5734 4520.84 4473.11 5834 4580.08 4532.35 5930 4636.93 4589.20 6024 4692.47 4644.74 54 4 54 7 53 37 53 9 54 45 N 2.27 W .90 2707.21N 70.29W N 1.43 W 1.16 2754.74N 71.82W N 1.81 W .58 2835.86N 74.12W N 1.96 W .50 2912.33N 76.63W N 1.83 W 1.70 2988.62N 79.16W 2708.08 2755.64 2836.78 2913.29 2989.61 6120 4747.77 4700.04 6213 4802.27 4754.54 6308 4856.36 4808.63 6402 4909.50 4861.77 6497 4963.48 4915.75 54 24 54 32 55 46 55 28 55 22 N 1.85 W .38 3066.35N 81.65W N 1.40 W .42 3142.65N 83.82W N 1.25 W 1.31 3220.35N 85.61W N .43 W .79 3298.03N 86.75W N 1.60 W 1.02 3376.32N 88.14W 3067.38 3143.71 3221.42 3299.11 3377.42 ,~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE J EXPLORATION (ALASKA) INC .4ILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 MWD SURVEY JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 OPERATOR: BP EXPLOP. ATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORD DEGREES DG/100 NORTH/SOUTH EAST INATES /WEST VERT. SECT. 6593 5017.32 4969.59 6687 5069.40 5021.67 6782 5121.89 5074.16 6876 5174.35 5126.62 6970 5227.18 5179.45 56 27 56 21 56 16 55 50 55 57 N 2.47 W 1.35 3455.86N 90 N 1.34 W 1.01 3534.22N 93 N 2.25 W .81 3612.93N 96 N 2.96 W .77 3690.80N 99 N 2.51 W .41 3768.74N 103 .97W .58W .04W .59W .31W 3457.00 3535.39 3614.14 3692.07 3770.07 7066 5281.10 5233.37 55 35 7160 5334.17 5286.44 55 51 7255 5387.62 5339.89 55 30 7349 5441.10 5393.37 54 40 7444 5495.40 5447.67 56 1 N 2.31 W .40 3847.94N 106 N 1.71 W .59 3925.77N 109 N 1.76 W .38 4004.03N 111 N 1.95 W .90 4080.61N 114 N .87 W 1.69 4159.13N 116 .64W .37W · 74W .22W .15W 3849.32 3927.19 4005.48 4082.09 4160.64 7540 5547.98 5500.25 57 9 7634 5599.06 5551.33 57 1 7729 5651.34 5603.61 56 43 7823 5702.87 5655.14 56 23 7918 5755.76 5708.03 56 0 N .50 W 1.23 4238.83N 117 N .69 W .22 4317.74N 117 N .79 W .33 4397.83N 118 N 1.88 W 1.03 4475.82N 120 N 1.42 W .57 4554.78N 123 .10W .92W .96W .77W .05W 4240.34 4319.24 4399.34 4477.35 4556.34 8012 5808.77 5761.04 8107 5862.28 5814.55 8202 5914.87 5867.14 8295 5965.93 5918.20 8389 6018.05 5970.32 55 5O 55 34 56 45 56 22 56 32 N 1.57 W .21 4633.12N 125 N 1.53 W .30 4711.57N 127 N 1.26 W 1.27 4789.98N 129 N 1.72 W .58 4867.29N 131 N 3.47 E 4.59 4945.83N 129 .09W · 21W .12W .13W .93W 4634.71 4713.18 4791.62 4868.95 4947.45 8482 6069.74 6022.01 8577 6123.06 6075.33 8671 6175.96 6128.23 8768 6231.52 6183.79 8863 6287.07 6239.34 56 55 55 55 53 12 36 17 6 13 N 1.61 E 1.70 5023.46N 126 N 2.66 E 1.10 5102.17N 123 N 1.67 E .94 5178.94N 120 N 1.06 E .55 5258.85N 118 N 1.59 E 2.03 5335.77N 116 .48W .55W · 65W · 74W .97W 5024.99 5103.63 5180.32 5260.17 5337.05 8958 6344.66 6296.93 52 4 9054 6404.94 6357.21 49 57 9149 6467.31 6419.58 47 49 9244 6532.64 6484.91 45 49 9338 6599.05 6551.32 43 57 N 1.15 E 1.27 5411.22N 115 N 2.56 E 2.49 5485.67N 112 N 2.77 E 2.25 5557.07N 109 N 1.99 E 2.18 5626.65N 106 N .72 E 2.21 5692.79N 104 · 16W .77W .44W .54W .97W 5412.45 5486.83 5558.15 5627.65 5693.75 9433 6668.38 6620.65 42 49 9528 6738.73 6691.00 40 44 9623 6812.28 6764.55 38 35 9719 6887.62 6839.89 37 16 9813 6962.76 6915.03 36 21 N .50 E 1.19 5758.34N N 1.62 E 2.35 5821.20N N .33 W 2.59 5882.18N N 2.41 W 1.92 5940.89N N 3.18 W 1.10 5997.07N 104.27W 103.12W 102.41W 103.80W 106.54W 5759.27 5822.09 5883.04 5941.77 5998.00 ~RRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ~ EXPLORATION (ALASKA) INC MILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 MWD SURVEY JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 FT. OPERATOR: BP EXPLOR3kTION 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. 9907 7039.07 6991.34 36 2 N 3.33 W .34 6052.85N 109.71W 10000 7114.66 7066.93 35 49 N 3.17 W .26 6107.56N 112.81W 10096 7192.38 7144.65 35 4 N 4.02 W .95 6162.78N 116.28W 10191 7271.28 7223.55 33 30 N 4.25 W 1.65 6216.43N 120.16W 10285 7350.19 7302.46 32 28 N 3.83 W 1.12 6267.52N 123.77W 6053.83 6108.59 6163.87 6217.59 6268.74 10328 7386.39 7338.66 31 36 N 2.65 W 2.49 6290.14N 10435 7476.97 7429.24 31 36 N 2.65 W .00 6345.82N 125.05W 6291.38 127.63W 6347.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6347.11 FEET AT NORTH 1 DEG. 9 MIN. WEST AT MD = 10435 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 358.83 DEG. 'GOHL~N ~HQLVAHQD Wi1MININ NOISN~NI~-~HHL ~0 ~SQ ~HL NO ~SV~ ~f S~HflG~DOH~ NOIi~qQOT~O ~HI E6'IL I~'9SE £0'8S6E M £9'LEI N E8'S~£9 ~E'6E~L L6'9L~L S£~0I II'988E M 8L'EII N 00'L019 9I'990£ 68'£IIL 0000I 6I'I£~ ~0'E~ ~0'9E~ 0L'6E9E M 0S'~II N £I'~S LS'EE£9 0£'0L£9 0006 IS'86IE M 0g'~EI N 0~'EE9~ 9L'£SLS 6~'I0gS 0008 L~'9SLI M L£'~0I N E6'E6L£ 0g'S6IS £S'£~ES 000L EL'IE£I M ES'gL N 9S'g96E SS'0£9~ gE'gL9~ 0009 L6'S06 M SL'SS N g£'LSIE 0£'9~0~ £0'560~ 000S 06'ES£ LL'gII Sg'L ~6'6L~ M LI'LI N E8'6££I ££'EL~£ 90'0ES£ 000~ ~0'LEI Z L£'S5 N I6'£gS £E'SEgE 96'ELSE 0005 9~'g ~ £0'EE N 9E'8£I I0'~6I ~L'I66I 000E E~' M 08'9 N SI'GE S8'IS6 8S'666 000I 00' ~ 00' N 00' £L'L~- 00' 0 NOILDZ~OD ~DNZ~JIQ ISZM/IS~ HIDOS/HI~ON HL8EG HLg~G H~8~ (IAL-~N SZLVNI~OOD ~q~DN-lfLDZ~ q~DILEZA q~DIL~ZA GS~ZN HLdZ~ ~Z~S~ZN JO LZZJ 000I NZAZ ~OJ SZ~A NOIi~r~o7dxz d~ :~Oi~r~ZdO £L'L~ = 'AZ%Z DNIHS~ Xq%Z~ S68060 :XZA%IflS JO ZLVQ S6/5I/6 :ZL~ NOIL~L~dNOD H©DO~Off ZdO~S HLEON 009gSEE6E00S 69-JdN / i~IO~ ZN~IN DNI (~f~/S~) NOIL~f~Oq~XZ ~ ZD~d ~ZSV%~ Z©~"cIOHDN~ SZDIAE~S DNI~I~G NflS-X~Z , £~"RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~ EXPLORATION (ALASKA) INC MILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 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 47 47 147 147 247 247 347 347 .0O .73 .73 .73 .73 -47 100 200 3OO .73 .00 .00 .00 .00 .00 N .00 E .00 N .00 E .84 N .41 W 2.73 N 1.28 W 4.53 N 2.04 W .00 .00 .00 .01 .01 .03 .03 .06 .03 447 447 547 547 647 647 747 747 847 847 .73 .73 .73 .73 .73 400 500 600 700 800 .00 .00 .00 .00 .00 5.69 N 2.62 W 7.54 N 3.55 W 10.10 N 4.32 W 13.07 N 5.31 W 16.79 N 6.75 W .07 .01 .09 .02 · 13 .04 .17 .05 .25 .08 948 947 1048 1047 1148 1147 1248 1247 1349 1347 .73 .73 .73 .73 .73 9OO 1000 1100 1200 1300 .00 .00 .00 .00 .00 20.97 N 7.93 W .36 .10 25.55 N 5.44 W .50 .14 32.32 N 1.46 W ... .81 .31 40.27 N 2.37 E 1.20 .39 49.32 N 6.14 E 1.69 .49 1450 1447 1550 1547 1651 1647 1752 1747 1853 1847 .73 .73 .73 .73 .73 1400 1500 1600 1700 1800 .00 .00 .00 .00 .00 60.82 N 9.99 E 2.42 .73 72.32 N 13.47 E 3.15 .72 84.17 N 16.51 E 3.89 .75 97.88 N 18.84 E 4.86 .97 112.37 N 20.37 E 5.92 1.06 1955 1947 2057 2047 2160 2147 2265 2247 2372 2347 .73 .73 .73 .73 .73 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 129.44 N 21.72 E 7.39 1.47 150.63 N 22.05 E 9.61 2.23 176.54 N 24.16 E 12.96 3.34 208.24 N 27.39 E 17.93 4.97 247.12 N 28.74 E 25.26 7.33 2483 2447 2597 2547 2715 2647 2838 2747 2967 2847 .73 .73 .73 .73 .73 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 293.50 N 33.42 E 347.21 N 38.87 E 409.80 N 44.18 E 482.01 N 46.60 E 562.78 N 45.93 E 35.61 49.28 67.39 90.79 119.36 10.36 13.66 18.12 23.40 28.57 3099 2947.73 2900. 3239 3047.73 3000. 3386 3147.73 3100. 3544 3247.73 3200. 3707 3347.73 3300. 00 00 00 00 00 649.96 N 42.70 E 746.96 N 35.99 E 854.12 N 26.07 E 976.56 N 14.08 E 1104.80 N 2.88 E 152.08 191.58 238.52 297.10 360.10 32.72 39.50 46.94 58.57 63.01 ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE JP EXPLORATION (ALASKA) INC MILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3875 3447.73 3400.00 1239.03 N 8.72 W 4048 3547.73 3500.00 1379.72 N 20.57 W 4225 3647.73 3600.00 1524.59 N 33.36 W 4400 3747.73 3700.00 1667.86 N 44.14 W 4571 3847.73 3800.00 1806.47 N 48.06 W 427.91 67.81 500.94 73.03 577.44 76.49 652.50 75.07 723.47 70.97 4744 3947.73 3900.00 1947.91 N 50.83 W 4919 4047.73 4000.00 2090.96 N 53.78 W 5093 4147.73 4100.00 2234.06 N 57.99 W 5265 4247.73 4200.00 2374.29 N 60.77 W 5437 4347.73 4300.00 2513.46 N 64.43 W 796.72 73.25 871.28 74.56 945.92 74.64 1018.18 72.26 1089.59 71.41 5609 4447.73 4400.00 2653.67 N 68.43 W 5780 4547.73 4500.00 2791.90 N 72.75 W 5948 4647.73 4600.00 2926.74 N 77.13 W 6119 4747.73 4700.00 3066.29 N 81.65 W 6293 4847.73 4800.00 3207.66 N 85.34 W 1161.86 72.27 1232.52 70.67 1300.46 67.94 1372.20 71.74 1445.42 73.22 6470 4947.73 4900.00 3353.52 N 87.50 W 6648 5047.73 5000.00 3501.67 N 92.81 W 6829 5147.73 5100.00 3651.54 N 97.61 W 7007 5247.73 5200.00 3799.12 N 104.64 W 7185 5347.73 5300.00 3945.76 N 109.97 W 1522.28 76.86 1601.11 78.83 1681.35 80.24 1759.76 78.41 1837.34 77.58 7360 5447.73 5400.00 4089.96 N 114.54 W 7539 5547.73 5500.00 4238.44 N 117.10 W 7723 5647.73 5600.00 4392.34 N 118.88 W 7903 5747.73 5700.00 4542.88 N 122.75 W 8082 5847.73 5800.00 4690.35 N 126.65 W 1912.88 75.54 1991.94 79.06 2075.48 83.54 2156.26 80.78 2234.48 78.22 8262 5947.73 5900.00 4839.93 N 130.31 W 8443 6047.73 6000.00 4990.59 N 127.41 W 8621 6147.73 6100.00 5138.16 N 121.90 W 8796 6247.73 6200.00 5282.09 N 118.31 W 8963 6347.73 6300.00 5415.16 N 115.08 W 2314.45 79.97 2395.38 80.93 2473.73 78.35 2549.03 75.30 2615.54 66.51 9119 6447.73 6400.00 5535.48 N 110.49 W 9266 6547.73 6500.00 5642.18 N 106.00 W 9405 6647.73 6600.00 5739.20 N 104.44 W 9539 6747.73 6700.00 5828.95 N 102.90 W 9668 6847.73 6800.00 5910.36 N 102.65 W 2672.11 56.57 2718.43 46.33 2757.79 39.36 2792.19 34.40 2821.17 28.98 S/'~RRY-SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE £ EXPLORATION (ALASKA) INC MILNE POINT / MPF-69 500292258600 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/13/95 DATE OF SURVEY: 090895 JOB NUMBER: AK-MM-950944 KELLY BUSHING ELEV. = 47.73 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 9794 6947.73 6900.00 5986.03 N 105.92 W 2846.62 25.45 9918 7047.73 7000.00 6059.14 N 110.07 W 2870.57 23.95 10041 7147.73 7100.00 6131.38 N 114.14 W 2894.00 23.43 10163 7247.73 7200.00 6200.89 N 119.00 W 2915.89 21.89 10283 7347.73 7300.00 6265.96 N 123.66 W 2935.29 19.40 10400 7447.73 7400.00 6327.85 N 126.80 W 2952.94 17.65 10435 7476.97 7429.24 6345.82 N 127.63 W 2958.03 5.09 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS HO'~'.~. ~ D OKLAND At ....... ;'A OIL + GAS CONSERVATION 30:)i ~":'7.,tU?iNE DRIVE AK; '~ .7 21. Date: 3 June 1996 Transmittal of Data Sent by: HAND CARRY Dear Sfr/Madam, Enclosed, please find the data as described below: WELL $ DESCRIPTION ECC No. ~.ii7 ~?r-~! ~l PLS FINAL BL+RF Run ~ ! 6480.03 ~ PFC/PERF FINAL BL+RF Run # 1 ~ PFC/PERF FINAL BL+RF ~1 PFC/PERF FINAL BL+RF Run # I 6480.04 Run # I 6485.04 Rec~ i',,=d by: Ple?.o~_ ?t3n and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ' Date: JUt'I ~,.~(,~: 0 Fil Cl_l IM G S I=: I=IL~ I I~ E S WELL LOG TRANSMITTAL To: State of Alaska May 15, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Records Keeper 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-69 AK-MM-950944 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention oF Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-69: 1 LDWG formatted LIS tape with verification listing. APIg: 50-029-22586-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company [3 F! I I_1_ I I~ r= WELL LOG TRANSMITTAL To-' State of Alaska Alaska Oil and Gas Conservation Comm. Attn: Larry Gram 3001 Porcupine Dr. Anchorage, Alaska 99501 February 27, 1996 RE: MWD Formation Evaluation Logs - MP F-69, AK-MM-950944 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: 2" x 5" MD Neutron and Density Logs: 2"x 5" TVD Neutron and Density Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 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: 17 November 1995 Transmittal of Data Sent by: US MAIL Dear Sir/Madam, Enclosed, please find the data as described below: MPL-16 ~ DESCRIPTION 1 GR/CCL FINAL BL & RF Run # -1 · · 1 PLS FINAL BL & RF Run 1 PFC/PERF FINAL BL&RF .Run 1 PLS STATIC FIN BL&RF 1 PFC/PERF FINAL BL&RF Run # 1 Run # 1 ! PFC/PERF FINAL BL&RF Run ~ 1 ECC No. '6453.01 6478.02 6480.02 6485.01 :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 ~/~¢J Date: ~o~£-[9s (£o~) o~ x~a ~ss~S ~ 009~ uosIn~d 'G XsupoH 'ugly :og u~n~s~ puw uBIs ss~sId I # unit S I ~I+.~ cltf.T. DMO~I I : ssggsMSTrl/SmdmT, ~66I ~sqo~oo 0I :~olaq paqI:asap s~ ~p aq~ pu7~ as~aId 'pasolouS ~ '~dO%S H~HON 69-~N 'I0~66 ~D~OHDN~ ~AIHG ~NI~fiOHOd I00~ NOIA~AH~SNOD S~D + ~IO ~2~S~%~ 'u~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: # DESCRIPTION 1PFC/PERF FINAL BL+RF 1GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 6478.01 'Run # 1 6485.00 Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 j Or FAX to (907) 563-7803 Received ~/~<~// Date: .. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, ~99501. Date: 21 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPJ-09 MPF-61 MPL-12 DESCRIPTION PAS 'FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6258.04 Run $ 1 6472.01 R~n ~ 1 Run ~ 1 6480.00 Run ~ 1 6482.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Anchorage, AK 99518 y Or FAX to (907) 563-7803 Received by: Please sign and ret%u~ ~O: Petrotechnical Data Cen~e~ BP Exploration (Alaska) ~00 East Benson Boulevar~ Anchorage, Alaska 9990~ Received bF CONSERVATION COMMISSION ?,f. 'Y KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 28, 1995 Tim Schofield, Senior Ddlling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-69 BP Exploration (Alaska), Inc. Permit No 95-125 Surf Loc 2125'NSL, 2502'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc 3276'NSL, 2610'WEL, Sec. 31, T14N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be field inspector 659-3607. David W. J'~,,.nston \ -"'-----" Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILl_ 2O AAC 25.OO5 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-1 Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 46 f e e t Mi/ne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2125' NSL, 2502' WEL, SEC. 6, T13N, RIOE Mi/ne Point Unit At top of productive interval 8. Well number Number 3043' NSL, 2602' WEL, SEC. 31, T14N, RIOE MPF-69 2S100302630-277 At total depth 9. Approximate spud date Amount 3276' NSL, 2610' WEL, SEC. 31, T14N, RIOE 09/01/95 $200,000.00 :12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD) property line ADL355017 2610' feet NoC/oseApproach feet 5083 10557'MD/7554'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 900 feet Maximum hole angle 56 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 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 Btrc 5674' 31' 31' 5805' 4511' 1122 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 10527' 30' 30' 10577' 7554' 245 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 Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report• 20 AAC 25.050 requirements[] 21. I hereby c~i~ tha~'~he ~oregoing is true and correct to the best of my knowledge Signed /\,~ ~,,,~ t, tu~ ,0 ~',,' ,/~,-~ ~.~'~/~ ,-~/,~ /¢,// Title Senior Drilling Engineer ~1//~t/~d,,~ Date "--'" '-' ' ~ Commission Use Only ' Permit Number JAPI number Approval date_ ISee cover letter ~,..~'-,,,/~...~" 150-~-~'---- .Z--~.-,J4"~ ~-'~' ~-'- Ifor other requirements Conditions of approval Samples required [] Yes '~ No Mud log required []Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; RI~]v3M; ,~.5M; []10M; I-I15M; Other: Original Signed...., by order of_/ / _Approved by David W. Johnston Commissioner tne commission Date,,., ,-.o~'/~'~ Form 10-401 Rev. 12-1-85 Submit ii cate ~U~ £~ ~95 03:0~PM SH~RED SER¥ICES DRILLIM~ P.~ MP F-69 Proposed Summary of Operations . . i 10. Drill and Set 20" Conductor. Weld an FMC landing ring, for the FMC Gen 5 Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E drilllng rig. NU and function test 20" Divcrter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. BuiId Spud Mud, Drill a 12-1/4" surfaco hole to 5805' md (451r ted), (Note: This hole section will be LWD logged with OR/Res), Run and ccmont 9-5/$" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE, Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot ' pressure vs volume for LOT baseline. Drill out float equipment and 10 f~t of now formation, Perfo, rm,a LOT to a maximum of 12,5 ppg as per Recommended Practices Manual. R~ord pressure vs, cummamvc volume for LOT test for well file. Drill 8-1/2" hole to TD at 10577' MD (755Y TVD), (Note: This hole section will be logged LWD with Triple Combo (OR/Rcs/Neu/Dens), 11. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing, Test casing to 3500 psi and freeze protect wdlbore to 2000' TVD with dbscl, 12. ND BOPE and NU dry hole tree. Release rig to MPF-77. Note: This well will be perforated, hydraulically fractured and cleaned out with a completion rig and prior to running the ESP completion. Following the stimulation tho well will be left with a retrievable bridge plug CRBP) set 500' above the perforations and kill weight brine in the w~llbore. 13. MIRU workover completion unit. ND dry hole tree, NU BOPs and test, 14. PU and RIH with 2-7/8" I~UE 8rd tubing with RBP retrieving tool, Release RBP and POH standing back tubing, ~ 5, RIH with Electric Submersible Pump (F. SP) completion on 2-7/8" EUE 8rd tubing. 16. Set 2 way check. ND BOPB and NU tree and test, Pull two way check, freeze protect, set BPV, close valvos, Test tree. 17, RDMO with workover/completion rig. ~ E ~ E ~ V ~ P PO_ST 1, i AUG £5 995 FIIG WOnK ~S~ ~0jl & 6as Cons. ~mm'~s~N¢' Complete the handover form and turn it and the well file~ over to production. Turn over the well files along with the handover form, A SBT/G~CCL is not required on this well and will only be run if there are problems on the produ~ion ~ement job. An adequate volume to ~over ~000' of diesel needs to be inje~ed down the 7" X 9-5/8" annulus before moving the rig off the well, P~e note ~D~_ ~dvolu~of fm~e ~mte~~ ~9wn th~ar ~ulus on~orning_~eDo~. The rig will not complete this well. PEs will psrforate, frae and clean out this well with completion rig. API# $0- August 24, 199~ ]Well Name: I MPF-69 Well Plan Summary I Type of Well (producer or injector): I Kupamk Producer I Surface Location: 2125' FSL 2502' FEL Sec 06 T13N R10E UM., AK. Target Location: 3043' FSL 2602 FEL Sec 31 T14N R10E UM., AK. Bottom Hole 3276' FSL 2610' FEL Sec 31 T14N R10E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. [AFE Number: 1330184 I I Rig: I Nabors 27E~ I Estimated Start Date:ISEPT ~, 1995 I IOperating days to drill and case: I1VID: I10557' I I TVD: 17554'BKB I IKBE: 146. I Well Design (conventional, slimhole, IUltra Slimhole, 7" Longstring etc.): I Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1802' 1795' n/a MA n/a n/a n/a NA (Top Schrader) ' 3975' 1687 psig / 8.0 ppg OA ' 4195' 1725 psig / 8.0 ppg Base Schrader Bluff 5605' 4445 1795 psig / 8.0 ppg Top HRZ 9962' 6809' n/a Base HRZ ' 6869' n/a Kupark D Shale 9936' 7029' n/a Kuparuk C ' 7174' 3536 psig / 9.6 ppg Target KUP A3 10169' 7220' 3536 psig / 9.6 ppg Total Depth 10577' ' n/a Casing/Tubing Pro ,ram. Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 5674' 31/31 5805/4511 8 1/2" 7" 26# L-80 btrc 10527' 30/30 10577/7554 N/A (tbg) 2-7/8" 6.5# L-80 EUE 10058' 29/29 10087/7035 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7175' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3536 psi is 2828 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: ]Open Hole Logs: Surface LWD GR/Resistivity Intermediate None Final ICased Hole Logs: LWD GR/Resistivity/Neutron/Density None A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. API # 50- August 17, 1995 Mud Program: Special design considerations LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per pad data sheet are encouraged. Surface Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 9.6 100 35 15 30 10 15 Production Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.2 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: II °v: 19°°' I Maximum Hole Angle: [ 56 degrees Maximum Dog Leg: [ < 4 degrees Inclination in target: 35 Degrees Close Approach Well: None - See Traveling Cylinder report There are no close approach wells for drilling MPF-69. API# 50- August 17, 1995 Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. pit can be opened in emergencies by notifying Karen Thomas (564-4305) The Milne Point reserve with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request 1. 2. to AOGCC for Annular Pumping Approval for MPF-69: Approval is requested for Annular Pumping into the MPF-69, 9-5/8" x 7" casing annulus. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 5795' md (4446' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2302 psi for a 10.4 ppg fluid in this well. MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permiability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point F-1 0 35,000 1/1/95 - 12/31/95 Milne Point F-13 684 35,000 1/1/95 - 12/31/95 Milne Point F-25 230 35,000 1/1/95 - 12/31/95 Milne Point F-37 0 35,000 1/1/95 - 12/31/95 Milne Point F-45 0 35,000 1/1/95 - 12/31/95 Milne Point F-53 0 35,000 1/1/95 12/31/95 Milne Point F-61 0 35,000 1/1/95 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. API # 50- August 17, 1995 DRILLING HAZARDS AND RISKS: See both the Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the BHA, rather than formation drilling problems. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F- pad. The max mud weight 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. There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: The last well drilled on F pad MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 92.3 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3536 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 (3536 psi @ 7085' ssTVD). There has been no injection in this region since then, only production, therefore the reservoir pressure should not exceed this estimate. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. API # 50- August 17, 1995 MPF-69 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: 1122 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: 1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0ppg Y1ELD:2.17cuft/sk. MIXWATER: ll.63gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. API# 50- August 17, 1995 MPF-69 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST 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: 245 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 rain @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8"" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 17 joints of 7" Casing (34 total). Use stop collars to fasten centralizers to casing joints. This will cover 300' above the top of the Kupamk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator a minimum of 60 feet inside the 9- 5/8"casing shoe to avoid hanging up on the shoe. This centralizer may be attached across a casing collar connection. 3. Total 7-1/8 .... x 8-1/4" Straight Blade Turbulators needed is 35. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm until the plug bumps, but not more than to displace cement just above the production zone. Batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kuparuk Sands with 30% excess over a guage hole. API# 50- August 17, 1995 BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt · MPF MPF-69 As-Built CRITICAL ~DI.T DAT~ MD Ina Az~. TVD N/S E/W ~lrr o~,'"-"'"-~" WD3 TIE IN O D,DO' 358,50' 0 0 N 0 E KDP / ~TART 900 0,00' 358,50' 900 0 N 0 E OF BUILD ~ l,OO'/IOD F~ START DF BUILD 1200 3.00' 358,50' 1200 8 N 0 ~rERTICAL VIE~ e t,5o'/too SCALE §00 fL / DIVISION TVD REF: lVEIilmal) START DF BUILD 1500 7.50' 359.50' t499 35 N t V YERTICAh SECTION RIFF: I~I~IJ.HgAD e 2, O0'/tO0 END DF BUILD 1700 11,50' 358,50' 1696 68 N 2 W 0 q 0,00' ~ 0 MD TIE IN B, Pe~maFpo~g 1801 11,50' 359,50' 1795 BB N 2 W 0 I START DF 1980 11,50' 358,50' ~970 ~24 N 3 W | CURVE ~ I / 2,5o'/too F~ I / END D~ CURVE 3760 56,00' 350,90' 34t3 lOBS N ~3 W 500~ j B, Schrader 5605 56,00' 358,90' 4445 ~618 N 53 W J J I I , , START DF B8~O 56.00' 35B,90' 6242 5292 N ~0~ W 900/ I 0 00' e 900 MD KDP / START DF 9UILD ~ ! 00'/100 F~ CURVE e 0 I ' ' 2,00'/~00 F~ 1000-- . THRZ 9663 39,14' 358,60' 6809 5902 N 117 W 1~00 ~ 3.00' ~ l~O0 MD START DF BUILD ~ 1.50'/100 ~t END BF' CURVE 9870 35.00' 358,50' 6974 6027 N 1~0 W 8 J TKUD 9937 35,00' 358,50' 7029 6065 N 1~1W A T~r 2% 10170 35,00' 358,50' 7885 6199 N 125 W t~----35 7,50' . LSOO MD START DF BUILD . 2,00'/[00 ~ (7/~4/95)~ / : 1696~68[ ~1.50' E 1700 MD END DF BUILD TKUA3 . . 1195 -- -- 86 ]--.. 11,50' ~ t80t MD B. Peema~eo$t THLV [0~77 35,00 358,50' 7308 6260 N l~7 W 1970-- [24"--~ Lt.50' ~ [990 M3 START DF CURVE ~ 2.50'/[00 Ct ............... 2000 ~16.50'~ E 8180 MB 21,50' e 2380 M9 2500~ ~26,50' ~ ~500 MD ~31,50' ~ 2780 MD ~ 36,50' E ~980 M~ . . . 3000~ ~4[.50' ~ 3t80 MD T~fie~ N:me TVD 46 50' ~ 3380 MB L088 ~ ~' 56 00' E 3760 MD ENg D~ CURV~ I 7~0 6L99 N W 54tDOO 4000~ ~ J 9 5/8 }n 5805 56,00' 358,90' 4557 8784 N 56 W ,~ , ~ 7 ~n [0577 35,00' 358,50'. 7554 6438 N i3l W ~000~ ~SO0~ 6000 ~ 6242 ~ 56,00' e 8820 MD START DF CURVE ~ 2,OO'/lOO 5883 ~5~,00' ~ 90~0 MD ~500~ 8,00' ~ 9~0 4.00' ~ 94~0 MD ' 35,00' e 9870 MD END DF CURVE ~ 5,00' ~ 99~7 MD TKUD ~J-- 6434 7 In 0D, ~ L0577 MD, 7554 TVD 35,00' e L0577 ND PROPOSED TVD ?553.75 D~te .oo I I I J J J J J I I J J I J I ~s 6433.73 Checkea 8~8~.~0 ~ Approved By ' -SOO ~ SO0 JO~O JSO0 ~000 eSO0 2000 2SO0 4000 4SO0 SOgO SSO0 6000 6SO0 7000 ~ 181.08 ~ g~e ~ ~/~ '~ J ~RTIC~ ~BCTION P~: 358,83 t .... 60417751 Blt 7195 9,56 a~ ] HALL l BURTnN HORIZONTAL VIEW (TRUE NORTH) SCALE 500 ft./ DB/IS[ON SURVEY REF: WELLHEAD 7335 [000 500 0 ;[ 35B.50' 358.67' 358.74' i6423 - 358.81' 6300 - 358.87' 4445 - 358,93' ----~5 O O ---4500 ---4000 ---3500 ;---3333 34L3 - 358,90' 3306 - 35B,BB' 3175 - 35B,B7' 3031 - 35B,BS' 2B76 - 35B,83' 27t0 - 35B,St 2445 - 358.75 2164 - 358,641 t696 358.50 i 500 ---~53 ] ~000 --15,33 --1000 ---50O l 500 lO00 Halliburton Energy Services - Drilling Systems PSL Proposal Report Page I Date: 8/17/95 Time: 9:57 am Wellpath ID: MPF-69 Wp3 Last Revision: 8/17/95 Survey Reference: WELLHEAD Refenmce World Coordinates: Lat. 70.30.29 N- Long. 149.39.21 W Reference GRID System: Ala~ka~ State Plane Zone: Alaska 4 Reference GRID Coordinales: (fl): 6035577.63 N 542059.97 E North Aligned To: TRUE NORTH Vealical Section Reference: WELLHEAD Clos~e Refexence: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2, I.B Vertical Section Plane: 358.83 deg. BPX-Shared Sexvice~ Drilling Alaska State Plane: ZoneA MiMe Pt: MPF MPF-69 As-Built MPF-69 Wp3 Measured lncl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (fl) (deg.) (deg.) (fi) (fi) (ft) (fi) (ft) GRID Coordinates Northing Easting (fi) (fi) ~E~ 0.00 0.00 0.00 45.00 0.00 0.00 0.00N ~.00 0.00 0,00 855.00 ~,00 ~.00 0.00N 1000.00 1.00 358.50 954.99 ~.99 100.00 0.87N 0.00 E 6035577.63 542059.97 0.00 E 6035577.63 542059.97 O.07W 6035578.50 542059.94 Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hor Dir. Vert Dist, Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (fi) (dg/100ft) (dg/l(X)ft) (dg/10Oft) (deg) (ft) (ft) (ft) (fi) (deg.) (fi) 1100.00 2.00 358.50 1054.96 1099.96 100.00 3.49N START OF BUILD @ 1.50 deg/100 ft 1200.00 3.00 358.50 1154.86 1199.86 100.00 7.85N 1300.00 4.50 358.50 1254.65 1299.65 100.00 14.39N 0.0gW ~)35581.12 542059.86 0.21W 6035585.48 542059.72 0.3~W 6035592.01 542059.51 0.0(~@ 0.00 0.00 0.00@ 0.00 0.00 0.87@ 358.50 0.87 1400.00 6.00 358.50 1354.22 1399.22 100.00 23.53N STARTOF BUILD@2.00degt100ft 1500.00 7.50 358.50 1453.53 1498.53 100.00 35.28N 1600.00 9.50 358.50 1552.42 1597.42 100.00 50.06N 3,49@358.50 3.49 7.85@358.50 7.85 14.39@358.50 14.39 END OF BUILD 1700.00 11.50 358.50 1650.74 1695.74 100.00 68.28N B. Permafrost 1801.29 11.50 358.50 1750.00 1795.00 101.29 88.46N 1900.00 11.50 358,50 1846.73 1891.73 98.71 108.13N 0.62'N 6035601.16 542059.22 23.54@358.50 23.54 0.97W 6035612.90 542058.85 35.30@358.50 35.30 1.31W 6035627.68 542058.38 50,08@358.50 50.07 STARTOFCURVE@2.50deg/100fl 1979.62 11.50 358.50 1924.75 1969.75 79.62 124.00N 2079.62 14.00 358.58 2022.27 2067.27 100.00 146.06N 2179.62 16.50 358.64 2118.74 2163.74 100.00 172.36N 1.7~'W 6035645.89 542057.80 68.30@358.50 68.30 2.32AV 6035666.07 542057.15 88.49@358.50 88.49 2.8~aW 6035685.74 542056.53 108.17@358.50 108.17 2279.62 19.00 358.69 2213.98 2258.98 100.00 202.83N 2379.62 21.50 358.72 2307.79 2352.79 100.00 237.43N 2479.62 24.00 358.75 2400.00 2445.00 100.00 276.(~N 3.25W 6035701.60 542056.02 124.04@358.50 124.04 3.81W 6035723.66 542055.34 146.11@358.51 146.11 4.44W 6035749.94 542054.55 '172.41@358.52 172.41 5.1~q~V ~)35780.41 542053.67 202.90@358,55 202.89 5.92~V 6035815.~) 542052,69 237.51@358.57 237.50 6.7~'W 6035853.65 542051.62 276.17@358.59 276.17 Survey Ttn)l 0.00 0,00 0,00 0.0 0,00N 0.00 0.00 0.00 0.0 0.00N 1.00 0.00 1.00 1.0 0.87 N 1.00 0.00 1,00 2.0 3.49 N 1.00 0.00 1.00 3.0 7.85N 1.50 0.00 1.50 4.5 14.39N 1.50 0.00 1,50 6.0 23.53N 1.50 0.00 1.50 7.5 35,28N 2.00 0.00 2.00 9,5 50,06N 0.00 E 0.00 0.00 0.00 0.00 MWD 0.00 E 3.00 3.00 0.00 1.28 BPHM-PBD 0.0LAV 3.20 3.20 88.50 1.43 BPHM-PBD 0.0~W 3.41 3.41 88.50 1.59 BPHM-PBD 0.21W 3.64 3.62 88.50 1.74 BPHM-PBD 0.3~vV 3.90 3.84 88.50 !.90 BPHM-PBD 0.62W 4.19 4.07 88.50 2.06 BPHM-PBD 0.97W 4.54 4,30 88,50 2.24 BPHM-PBD 1,32AV 4.97 4.53 88.50 2.42 BPHM-PBD 2.00 0.00 2,00 11,5 68.27N 0.00 0.00 0,00 11.5 88.46N 0.00 0.00 0.00 11.5 108,13N 1.8CW 5.50 4,76 88.50 2.62 BPHM-PBD 2.34W 6.08 5.04 88.50 2.78 BPHM-PBD 2.8Og 6.68 5.31 88.50 2.94 BPHM-PBD 0.00 0.00 0.00 11,5 124,00N 2.50 0.08 2.50 14.0 146,06N 2.50 0.06 2.50 16.5 172.35N 2,50 0.04 2,50 19,0 202.83 N 2.50 0.03 2.50 21.5 237.43N 2.50 0,03 2.50 24.0 276.09N 3.2~W 7,18 5.53 88.50 3.07 BPHM-PBD 3.85W 7.93 5.78 88.52 3.31 BPHM-PBD 4.5£W 8.81 6.04 88.54 3.57 BPHM-PBD 5.22NV 9.84 6.30 88.56 3.86 BPHM-PBD 6.02AV 11.00 6.57 88.59 4.17 BPHM-PBD 6,9CW 12.32 6.86 88.61 4.50 BPHM-PBD Halliburton Energy Services- Drilling Systems PSL Proposal Report Page 2 Date: 8/17/95 Wellpath ID: MPF-69 Wp3 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir, Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (fl) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hot Dir. Vert Dist. Dir, Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/lOOft) (dg/100ft) (dg/10Oft) (deg) (ft) (ft) (ft) (ft) (deg.) {ft) Survey Tool 2579.62 26.50 358.77 2490.44 2535.44 100.00 318.73N 2679.62 29.00 358.79 2578.93 2623,93 100.00 365.28N 2779.62 31.50 358.81 2665.31 2710,31 100.00 415.64N 7.7 IW 6035896.28 542050.46 318.83@ 358.61 318.82 2.50 0.02 8.7(~W 6035942,82 542049.20 365.38@ 358.64 365.38 2.50 0.02 9.7~%V 6035993.17 542047.86 415.76@358,66 415.75 2.50 0.02 2,50 26,5 318.73N 2,50 29,0 365.28N 2.50 31.5 415.64N 7.84W 13.78 7.15 88.63 4.87 BPHM-PBD 8.8')W ! 5.38 7.45 88.65 5.26 BPHM-PBD 9.9c3~r 17.12 7.76 88.67 5.68 BPHM-PBD 2879.62 34.00 358.82 2749.41 2794.41 100,00 469.72N 10.8~V 6036047.24 542046.44 469.85@ 358.67 469.85 2.50 0.01 2979.62 36.50 358.83 2831.06 2876.06 100,00 527.42N 12.0~%V 6036104.92 542044.93 527.56@358.69 527.56 2.50 0.01 3079.62 39.00 358,84 2910.13 2955.13 100,00 588.62N 13.3(~W 6036166.11 542043.34 588.77@358.71 588,77 2.50 0.01 2.50 34.0 469.72N 11.13hr 19.00 8.09 88.69 6.13 BPHM-PBD 2,50 36.5 527.41N 12.3zIW 21.01 8.42 88.71 6.62 BPHM-PBD 2.50 39.0 588.62N 13.6~%V 23.15 8.76 88,72 7.14 BPHM-PBD 3179.62 41.50 358,85 2986.45 3031.45 100,00 653.22N 14.6~W 6036230.69 542041.68 653.38@358.72 653.38 2.50 0.01 3279.62 44.00 358.86 3059.87 3104.87 100,00 721.08N 15,9~%V 6036298.54 542039.94 721.26@358.73 721.25 2.50 0.01 3379.62 46.50 358.87 3130.27 3175.27 100.00 792.08N 17,3~V 6036369.52 542038.13 792.27@358.74 792.27 2.50 0.01 3479.62 49.00 358.88 3197.50 3242.50 100.00 866.08N 18.81W 6036443.50 542036.26 866.28@358.76 866.28 2.50 0.01 3579.62 51.50 358.88 3261.44 3306.44 100.00 942.94N 20.31W 6036520.35 542034.32 943.16@358.77 943.16 2.50 0.01 3679.62 54.00 358.89 3321.96 3366.96 100.00 1022.52N 21.8~W 6036599.91 542032.33 1022.75@358.78 1022.75 2.50 0.01 2,50 41.5 653.21N 14.9~W 25.41 9.10 88.73 7.69 BPHM-PBD 2.50 44.0 721.07N 16.4(NV 27.79 9.45 88.75 8.28 BPHM-PBD 2.50 46.5 792.07 N 17.8ON 30.28 9.80 88.76 8.90 BPHM-PBD 2.50 49.0 866.07N 19.3~,W 32.87 10.15 88.77 9.57 BPHM-PBD 2,50 51.5 942.93N 20.9¢W 35.57 10.49 88,78 10.26 BPHM-PBD 2.50 54,0 1022.51N 22.5~W 38.37 10.82 88.79 10.99 BPHM-PBD END OF CURVE 3759.63 56.00 358.90 3367.86 3412.86 80.01 1088.05N 23.12W 6036665.42 542030.69 1088.29@358.78 1088.29 2.50 0,01 B. Schrader Bluff 5605.40 56.00 358.90 4400.00 4445.00 1845.78 2617.98N 52,6~2W 6038195.02 541992,55 2618.51@358.85 2618.51 0.00 0.00 CASING POINT OD = 9 5/8 in, ID = 8.84 m, Weight = 40.00 lb/ti. 5805.40 56.00 358.90 4511.84 4556.84 200.00 2783.75N 55.81W 6038360.75 541988.41 2784.31@358.85 2784.31 0.00 0.00 2.50 56.0 1088.03N 23.92NV 40.66 11.08 88.79 11.60 BPHM-PBD 0,00 56,0 2617.94N 54.9(.W 94.02 20.48 88.85 24.22 BPHM-PBD 0.(X) 56,0 2783.75N 55,81W 0.00 0.00 0.00 0.00 BPHM-PBD START OF CURVE @ 2.00 deg/100 ft 8819.59 56.00 358.90 6197.35 6242.35 3014.19 5282.16N 103.9FW 6040858.60 541926.13 5283.19@358.87 5283.19 0.00 0.00 8919.59 54.00 358.87 6254.70 6299.70 100.00 5364.06N 105.5F~r 6040940.48 541924.07 5365,10@358,87 5365.10 -2.00 -0,03 9019.59 52,00 358.84 6314.88 6359.88 100,00 5443.90N 107,1'7W 6041020.31 541922.03 5444.96@358.87 5444.96 -2.00 -0.03 0,00 56.0 5282.07N 108,8ON 187.34 37.13 88.87 48.01 BPHM-PBD 2.00 58.0 5363.96N I10,5~N 190.18 37,90 88.87 48.54 BPHM-PBD 2.00 60.0 5443.80N 112.23V 192,94 38.68 88.87 49.04 BPHM-PBD 9119,59 50.00 358.81 6377.81 6422.81 100,00 5521.60N 108,77W 6041097,98 541919.99 5522,67@358,87 5522.67 -2.00 -0.03 9219.59 48.00 358,78 6443,41 6488.41 100.00 5597.05N ll0.3t°qV 6041173.42 541917.98 5598,14@358.87 5598,13 -2.00 -0.03 9319.59 46.00 358.74 6511.61 6556,61 100.00 5670.16N 111.94W 604'1246.51 541915.98 5671.27@358.87 5671.27 -2.00 -0.03 2.00 62.0 5521.50N 113,8~W 195.63 39.48 88.87 49.50 BPHM-PBD 2,00 64.0 5596.95N II5.5..'NV 198.23 40.28 88.87 49.92 BPHM-PBD 2,00 66.0 5670.06N 117.2£W 200.76 41.09 88.87 50.30 BPHM-PBD 9419.59 44.00 358.71 6582.31 6627.31 100.00 5740.85N 113.51W 6041317.19 541914.01 5741.98@358.87 5741.98 -2.00 -0.04 '2.00 68.0 5740.75N l18.8,fW 203.20 41.90 88.87 50.64 BPHM-PBD 9519.59 42.00 358.67 6655.44 6700.44 100.00 5809.03N 115.0~¥ 6041385.35 541912.06 5810.17@358.87 5810,17 -2.00 -0.04 2.00 70.0 5808.93N 120.4t%V 205.55 42.71 88.86 50.95 BPHM-PBD 9619.59 40.00 358.62 6730.91 6775.91 100,00 5874.62N 116,6~%V 6041450.92 541910.14 5875.78@358.86 5875.78 -2,00 -0.04 2,00 72.0 5874.51N 122.0~V 207.81 43.52 88.86 51.22 BPHM-PBD THRZ 9662.52 39.14 358,60 6764.00 6809.00 42.93 5901.96N 117.2gW 6041478.25 541909.33 5903.13@ 358.86 5903.12 -2.00 -0,05 9719.59 38.00 358,58 6808.62 6853.62 57,07 5937.53N 118.16V 6041513.82 541908.25 5938.71@358.86 5938.71 -2.00 -0.05 9819.59 36.00 358.53 6888.48 6933.48 100,00 5997.69N 119,6~W 6041573.96 541906.39 5998.89@358.86 5998.89 -2.00 -0,05 2.00 72.9 5901.85 N 122,7~W 208.76 43.86 88.86 51.33 BPHM-PBD 2.(X) 74.0 5937.42N 123.67W 210.00 44.32 88.86 51.46 BPHM-PBD 2.00 76.0 5997.58N 125.2dW 212.07 45.10 88.85 51.66 BPHM-PBD F~ND OF CURVE 9869.68 35.00 358.50 6929.25 6974.25 50.09 6026.77N 120,44W 6041603,03 541905.47 6027.97@ 358.86 6027.97 -2.00 -0.05 TKUD 9936.51 35.00 358.50 6984.00 7029.00 66,83 6065.09N 121,44W 6041641,34 541,904.25 6066,31@ 358,85 6066.31 0,00 0,00 Target (7/24/95) I TKUA3 10169.68 35.00 358.50 7175.00 7220.00 233.17 6198.79N 124.9&V 6041775.00 541900.00 6200.04@358.85 6200.04 -0.00 -0.00 10266.77 35.00 358.50 7254.54 7299.54 97.10 6254.46N 1,26.4(3V 6041830.66 541898,23 6255,74@358.84 '6255.74 0.00 0,00 TMLV 10277.10 35.00 358.50 7263.00 7308,00 10.33 6260.38N 126.55W 6041836.58 541898,04 6261,66@358.84 6261166 0.00 0.00 2,00 77,0 6026.66N 126.02W 213.08 45.50 88.85 51.75 BPHM-PBD 0.bX) 77.0 6064.98N 127,0CW 214.43 45.86 88.85 52,01 BPHM-PBD 0,00 77,0 6198.67N 130.6gW 219,14 47.12 88.84 52.92 BPHM-PBD 0,00 77.0' 6254,34N 132.1gW 221.10 47.64 88.84 53.30 BPHM-PBD 0.00 77,0 6260,27N 132.3~:W 221,31 47.70 88.84 53.34 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 3 Date: 8/17/95 Wellpath ID: MPF-69 Wp3 Measured Incl Drift Subsea TVD Course T 0 T A L Depth Dff. Depth Length Rectangular Offsets (fl) (deg.) (deg.) (fi) (ft) (fi) (ft) (ft) GRID C~.~rdinates Northing Easting (It) (fl) Closure Vertical Build Walk DLS Cmn. Expected Total Max Hot Mm Hot Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/10Oft) (dg/10Oft) (dg/10Oft) (deg) (ft) (ft) (fl) (ft) (deg.) (ft) Survey Tool CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. 10577.10 35.00 358.50 7508.75 7553.75 300.00 6432.40N 131.0ON 6042008.55 541892.56 6433.73@358.83 6433.73 0.00 0.00 0.00 77.0 6432.28N 137.02A~r 227.37 49.32 88.83 54.51 BPI-[M-PBD BPX-SHo, n ed Alo,~l-<o, ~-t:o,-t:e Plo, ne: IMiLn e Pt ', MPF MPF-69 Wp3 Sen vices nmiLLing Z-one4 FE]IRIZl]NT~L ~ (TR~JE N[]Rlla) SCALE ~ rt, / DIVISIE]N SL~RVEY RE?: WEI_LPF__~J] ~ i .......................................... z~_. ......................................................... :: .... :T:L'Z;::'"-=Z: -'2:_-7 "'2' ':~ZL]ZZZ':Z::] '" ZLZ2LLL']Z:]]-'":]::' ? 8/t6/g5 ~P2 p~ WELLS STATUS No P~,:-,~ 'No.J. ..v;:".=-53 , .',¢w~ FL:Z]~NG >'..'..'-¥' -- 4E:. !','..'~:;, -'"::...:'::wS'~¥.: ~-L~... ~g '~-4: FLBWINS TVD 7553,75 MD t057'7.10 VS 6433,73 N/S 643[~.4D N E/W 131,DS W SPX-Sheped Sepvlces "~iLLin9 ALask~ State PLane', Z'ene4 Mikn e P~ ', MPF HPF-69 As-BuiLt MPF-69 Wp3 310 33O \ .. I I i/ tO i -/ 210 O_[]SEST PBINTS · .',~F. -T7 PF~F'-61 As-]B~lt ~-~--..-46 .A~ -~lt :"'FF-37 !-~!:'--53 :-,~- ~,~-~t ~°F-85 ~-BUL't 34,65 216,79 247.~ ?73.17 ~3,!7 2'.. :.-.:..~.;.'.¢ PPP, 14 .;~ ! 5.89 215,77 HALLIBURTON 8/t 7/cy5 t031 o~ ReP TV'D 0,00 ! 6~.,~ I~6,66 ' CO.:,',':.'~ tSgg,65 0.00 190 tSO 130 ReP MI) 0.~3 1443903 t .S,5C'.', c~) 0.00 170 li~., ,Fact~ 42,33 11518,10 E5,~9 50.4© 39.,50 WE]_LS STATUS : 8/i7/g5 Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2. I.B Page 1 Date: 8/17/95 Time: 10:31 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-69 As-Built MPF-69 Wp3 N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 10577.10 ft.(MD) All Directions using BP Highside Method in Dec.Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Well Safety Min. Clear Spread MD TVD MPF-77 Wp5 52.9 56.7 300 300 MPF-61 Wp3 9.1 36.8 2350 2325 No Point N 205.6 208.1 200 200 MPF-37 Spe 197.5 215.6 1450 1449 MPF-53ST M 19.1 40.9 1750 1745 MPF-53 MNVD 19.1 40.9 1750 1745 MPF-45 Mwd 165.2 173.4 650 650 MPF-25 MWD 298.1 314.3 1300 1300 MPF -13 G- 404.5 414.5 800 800 MPF-01 G-I 494.8 506.1 900 900 Flowing Shut-in Enter Enter Exit Exit Safety Safety Shut-in Danger Danger Shut-in Dist Dist Zone Zone Zone Zone 4.5 0.8 33.5 5.9 3.0 0.5 21.8 3.6 26_3 4.4 26.3 4.4 9.8 1.6 19.5 3.2 12.0 2.0 13_q 2.2 Close Approach Status OK OK OK OK OK OK OK OK OK OK Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2. I.B Page 1 Date: 8/17/95 Time: 10:31 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-69 As-Built MPF-69 Wp3 N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 10577.10 ft.(MD) All Directions using BP Highside Method in Dec.Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Welipath MPF-77 MPF-77 Wp5 MPF-61 As-Built MPF-61 Wp3 MPF-46 As Built No Point No.1 Distance Direction Ref MD Ref TVD Sep Factor 60.50 34.65 0.00 0.00 1606.01 100.88 3150.00 3009.14 59.09 216.79 0.00 0.00 70.47 142.14 2500.00 2463.59 211.09 247.40 50.00 50.00 693135 269.86 8900.00 6288.24 MPF-37 Sperry MPF-37 Sperry 22836 225.29 1400.00 1399.22 2935.72 282~56 8800.00 6231.40 MPF-53 As-Built MPF-53ST MWD MPF-53 As-Built MPF-53 MWD MPF-45 As-Built MPF-45 Mwd MPF-25 As'BuiltMPF-25 MWD MPF-13 As-Built MPF -13 G-IHR MPF-1 As-Built MPF-01 G-IHR 59.04 273.17 1650.00 1646.66 1171.78 7.92 8800.00 6231.40 59.04 273.17 1650.00 1646.66 812.72 6.03 6700.00 5057.09 178.66 216.24 400.00 400.00 887.47 293.26 5500.00 4386.06 325.81 222.14 1300.00 1299.65 4617.69 264.81 10350.00 7367.71 41932 215.89 0.00 0.00 5845.10 251.96 8500.00 6063.64 509.63 215.77 0.00 0.00 4995.64 261.70 5450.00 4358.10 11742.3 163 11518.1 2.9 223.6 10.6 25.4 6.5 4.6 2.9 4.6 3.0 50.4 4.4 39.5 8.2 42059.2 16.2 50727.2 19.4 WELL PERMIT CHECKLIST GEOL AREA ~O UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ADMINISTRATION 3. 4. 5. 6. 8. 9. 10. 11. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............ N Well located proper distance from drlg unit boundary. N Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party ............. N Operator has appropriate bond in force ........ N Permit can be issued without conservation order .... N N N Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 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 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potent±al overpressure zones ..... 32. Seismic analysis 9f shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . ./ [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo. A:tFORMS~cheklist rev 03/94 o Z I--I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 6600.00 A. PIEPER J. GAFFANEY OPEN HOLE 500292258600 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 07-MAY-96 MWD RUN 2 A. PIEPER J. GAFFANEY MWD RUN 3 M. HANIK J. ROBERTSON 6 13N 10E 2125 2502 , CROF LMED 46.23 _. CAS ING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 20.000 112.0 3RD STRING 12.250 9.625 5785.0 PRODUCTION STRING 8.500 10435.0 REMARKS: MWD - DGR/EWR4/CNP/SLD. ALL DEPTHS ARE MEASURED BIT DEPTHS· ALL GAMMA RAY DATA WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TUBE DETECTORS (DGR/SGRC). MWD RUNS 1 & 2 WERE DIRECTIONAL WITH GAMMA RAY (DGR) & ELECTROMAGNETIC 4-PHASE WAVE RESISTIVITY (EWR4). MWD RUN 3 WAS DIRECTIONAL WITH GAMMA RAY (DGR), ELECTROMAGNETIC 4-PHASE WAVE RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP), & STABILIZED LITHO DENSITY (SLD) . ENVIRONMENTAL PARAMETERS FOR NUCLEAR LOG PROCESSING: HOLE SIZE = 8 5" .................. MUD WEIGHT = 8 . 4 - 10 . 2 ppg MIYD FILTRATE SAL. = 4 0 0 - 10 0 0 ppm ~ ~. ~ , . FORMATION WATER SAL. = 14545 ppm FLUID DENSITY = 1.0 g/cc ~TRIX DENSITY = 2.65 g/cc LITHOLOGY = S~DSTONE FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 73.0 66.0 5619.0 5632.0 BASELINE DEPTH GR 66.5 66.5 9308.0 9308.0 9367.5 9371.0 9369.5 9375.5 9540.0 9547.5 9619.5 9623.5 9639.0 9644.0 9646.5 9651.0 9749.0 9756.0 9780.5 9785.5 9800.0 9803.0 9818.0 9821.5 9823.5 9827.5 9834.5 9838.0 9873.0 9877.0 9882.0 9886.5 9932.0 9936.0 9958.5 9961.5 10015.0 10016.5 10033.5 10035.5 10061.5 10064.5 10081.0 10084.5 10132.0 10134.5 10266.0 10268.0 10287.0 10290.0 10300.5 10308.5 10427.5 10435.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: all bit runs merged. STOP DEPTH 10366.0 10339.0 10346.0 10355.0 (WALS, 22-SEP-95) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 123.0 3673.0 2 3673.0 5810.0 3 5810.0 10435.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. /??SHIFT.OUT CN : BP EXPLORATION WN : MPF-69 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * 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 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 DRHO MWD 68 1 G/C3 4 9 PEF MWD 68 1 BN/E 4 10 ROP MWD 68 1 FPHR 4 11 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 4 90 180 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 988 Tape File Start Depth = 10436.000000 Tape File End Depth = 66.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 248893 datums Tape Subfile: 2 1112 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 73.0 EWR4 66.0 $ 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 3624.0 3617.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MLTD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OPIMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 02-SEP-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 3673.0 123.0 3673.0 0 .4 52.4 TOOL NUMBER P0403CRG8 P0403CRG8 12.250 112.0 SPUD 9.20 57.0 8.5 300 9.0 2.100 1.800 2.100 3.000 72.0 85.0 72.0 80.0 .00 .000 .0 0 REMARKS: MWD RUN 1. $ CN : BP EXPLORATION WN : MPF-69 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 234 Tape File Start Depth = 3680.000000 Tape File End Depth = 66.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57833 datums Tape Subfile: 3 299 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3624.0 EWR4 3617.0 $ 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 5760.0 5753.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 04-SEP-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 5810.0 3673.0 5810.0 0 51.8 55.5 TOOL NUMBER P0403CRG8 P0403CRG8 12.250 112.0 SPUD 9.30 52.0 7.6 1000 8,5 2.000 1.560 2.000 3.000 72.0 94.0 72.0 72.0 .00 .000 .0 0 REMARKS: MWD RUN 2. $ CN : BP EXPLORATION WN : MPF-69 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 143 Tape File Start Depth = 5815.000000 Tape File End Depth = 3610.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 284182 datums Tape Subfile: 4 208 records... Minimum record length: Maximum record length: 62 bytes 998 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5638.0 10374.0 EWR4 5611.0 10347.0 CNP 5619.0 10354.0 SLD 5632.0 10363.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIM UMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 09-SEP-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 10435.0 5810.0 10435.0 0 31.6 57.1 TOOL NUMBER P0389CRNSLDG6 P0389CRNSLDG6 P0389CRNSLDG6 8.500 5785.0 LSND-LT 10.10 45.0 9.5 400 4.6 3.000 1.510 3.000 4.800 75.0 156.0 75.0 75.0 SANDSTONE 2.65 8.500 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. $ CN : BP EXPLORATION WN : MPF-69 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .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 TIP TIP 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 NPHI MWD 68 1 PU-S 4 7 RI{OB NEWD 68 1 G/C3 4 8 DRHO MWD 68 1 G/C3 4 9 DE MWD 68 1 BN/E 4 10 ROD MWD 68 1 FPHR 4 11 PET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 t 4 90 810 01 1 4 90 180 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 461 Tape File Start Depth = 10436.000000 Tape File End Depth = 5605.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 173790 datums Tape Subfile: 5 529 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes MPF- 69 MILNE POINT R£C£1v£b Alaska 0il ::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::: .... iiii~,~i?i~3i:_~qiE!i¢:~ .......................... . ~,~...+:~/---. ¥::,: ..:~:~- - :::::::::::::::::::::::::::::::: ~::~:: .... ::::::::::::::::::::::::: ~::;:~:: ....... :::::~:::~,~ ::::::::::::::::::::::::::::: ============================ '~!~!::::~:::::~ ............................................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Run I' 22 - September - 1995 GRCH marked line Cased Hole 9300 10305 Ni l C O F I I. NI [ D ~ervi. ces Tape Subfile 2 is type. ~IS 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 - 69 500292258600 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 07-0CT-95 6485.00 t BRAD ESARY D. ROBERTSON 6 13N 10E 2124 2502 47.73 46.23 12.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 5778.0 PRODUCTION STRING 7.000 10408.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 1 1 22-SEP-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: Marked Line GR. 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** THIS PASS WAS NOT DEPTH SHIFTED SINCE IT IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL. .[ILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9300.0 10305.0 _ $ 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). CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-69 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 310 01 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 17 Tape File Start Depth = 10321.000000 Tape File End Depth = 9300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4087 datums Tape Subfile: 2 105 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY FDN FLUID DENSITY $ STOP DEPTH 10308.5 22-SEP-95 FSYS REV. J001 VER. 1.1 1135 22-SEP-95 10326.0 10318.0 9300.0 10316.0 1800.0 YES TOOL NUMBER 8250EA/8248EA 8220XA 8223XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 10408.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 8.40 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZIN~ WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-69 : MILNE POINT : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 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 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 82 Tape File Start Depth = 10321.000000 Tape File End Depth = 9300.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20426 datums Tape Subfile: 3 157 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 4 is type: LIS 95/10/ 7 01 **** REEL TRAILER **** 95/10/ 9 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 9 OCT 95 8:27a Elapsed execution time = 0.94 seconds. SYSTEM RETURN CODE = 0