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Home My WebLink About195-151CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Davies, Stephen F (OGC) To:Gluyas, Gavin R (OGC) Cc:Guhl, Meredith D (OGC) Subject:FW: [EXTERNAL] RE: MPU J-41 (224-071) Permit to Drill Application - Request Date:Friday, June 14, 2024 12:43:49 PM Attachments:H-06 and I-07 cement information.pdf From: Nathan Sperry <Nathan.Sperry@hilcorp.com> Sent: Friday, June 14, 2024 8:55 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] RE: MPU J-41 (224-071) Permit to Drill Application - Request Hi Steve, See attached. Regards, Nate Sperry Drilling Engineer Hilcorp Alaska, LLC From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, June 12, 2024 3:17 PM To: Nathan Sperry <Nathan.Sperry@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] RE: MPU J-41 (224-071) Permit to Drill Application - Request Nathan, In addition to my request below, AOGCC’s records are also a bit confusing for MPU I-07 (195- 151). Could Hilcorp also please provide any cementing records and the depths of any stage collars in this well? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov From: Davies, Stephen F (OGC) Sent: Wednesday, June 12, 2024 1:17 PM To: Nathan Sperry <Nathan.Sperry@hilcorp.com> Subject: MPU J-41 (224-071) Permit to Drill Application - Request Nathan, I’m reviewing Hilcorp’s Permit to Drill application for the planned MPU J-41 injector. I’m reviewing cementing records for nearby wells within the Area of Review, which are in many cases quite limited and somewhat cryptic descriptions in the daily operations summaries. Could Hilcorp please provide cement reports for MPU H-06 (PTD 195-115), and depth of the second-stage cementing collar in the 9-5/8” casing string? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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PTD: 1951510 E-Set: 34797 Received by the AOGCC 03/19/2021 03/22/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-07 (PTD 195-151) PLUG SET RECORD 03/05/2021 Please include current contact information if different from above. PTD: 1951510 E-Set: 34796 Received by the AOGCC 03/19/2021 03/22/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-07 (PTD 195-151) Memory Multi Finger Caliper Log 03/06/2021 Please include current contact information if different from above. Received by the AOGCC 03/10/2021 PTD: 1951510 E-Set: 34768 03/10/2021 MEMORANDUM TO: Jim Regg Kelly I P.I. Supervisor FROM: Adam Earl Petroleum Inspector . Section: 33 Drilling Rig: Operator Rep: Township: Rig Elevation: Jon Arend Casing/Tubing Data (depths are MD) Conductor: 20" - O.D. Shoe@ Surface: 9 5/8" O.D. Shoe@ Intermediate: O.D. Shoe@ Production: 7 O.D. Shoe@ Liner: O.D. Shoe@ Tubing: O.D. Tail@ Plugging Data Test Data State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 16, 2021 SUBJECT: Plug Verification MPU 1-07 - Hilcorp North Slope LLC PTD 1951510; Sundry 320-544- 13N Range: 10E - Meridian: Umiat Total Depth: 7,444 ft MD Lease No.: ADI -0025906' Suspend: X P&A: 112 - Feet 2,680 - Feet Feet 7,425 Feet Feet Feet Tvoe Pluq Casing Removal: Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ Feet Csg Cut@ na Feet Csg Cut@ Feet Tbg Cut@ Feet Tvoe Pluq Founded on Depth Btm Depth To MW Above Verified Fullbore - Retainer 3720 ft MD 3233 ft MD Wireline tag OA 0 0 0 Initial 1 S min In min 45 min Result Tubing 1753 _ 1680 - 1659 IA 1733 - 1662 - 1640 P OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Solid Wire line tag @ 3,233ft MD. Tool string made up with weight bars and 5 -ft by 2.25 -inch bailer; down wt. 250lbs. Good sample in bailer - chips of cement and interface. A combo pressure test of Tubing and IA as shown in chart above. Attachments: none rev. 11-28-18 2021-0216_Plug_Verification_MPU_I-07_ae DATE: 02/08/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-07 (PTD 195-151) PLUG SET RECORD 01/17/2021 blame Type MPU I -'D7 PLUG 17JAN21 PDF Document MPU_I-U�7_PLUG_17JAN21_img TIFF File LAS FILES File folder Please include current contact information if different from above. Received by the AOGCC 02/08/2021 Size PTD: 1951510 E -Set: 34674 2,087 KB 4,146 KB Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: .R�6 U1a 02/08/2021 Contractor/Rig No.: Hilcorp ASR 1 Operator: Hilcorp Alaska, LLC Type Operation: WRKOV/ Type Test: [NIT STATE OF ALASKA Reviewed By: % OIL AND GAS CONSERVATION COMMISSION P 1 Supry `/ 2:rN BOPE Test Report for: MILNE PT UNIT I-07 ✓ Comm Sundry No: 320-544 MISC.INSPECTIONS: TEST DATA P/F Location Gen.: P - Housekeeping: P PTD On Location P ' Standing Order Posted P " Well Sign P ' Drl. Rig P Hazard Sec. P ' Misc NA PTDH: 1951510 - DATE: 1/17/2021 " Operator Rep: Carl Linaman Test Pressures: Rams: Annular. Valves: MASP: 250/2500 ' 250/2500- 250/2500 TEST DATA 3050 MUD SYSTEM: Pressure After Closure Visual Alarm Trip Tank NA NA Pit Level Indicators P - P - Flow Indicator P P - Meth Gas Detector P P - H2S Gas Detector P P ' MS Misc NA NA 1117 - Inspector Guy Cook - Rig Rep: John Hoskins Inap Source Inspector Inspection No: bopGDC210115231502 Related Insp No: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3050 . P _- Pressure After Closure 1600 - P 200 PSI Attained 17 - P ' Full Pressure Attained 72 ' P Blind Switch Covers: All Stations - P Nitgn. Bottles (avg): 4na,2337 - P " ACC Misc 0 NA FLOOR SAFTY VALVES: BOP STACK: P/F No. Valves Quantity P/F Quantity Size P/F Upper Kelly 0 NA Stripper 0 NA Lower Kelly 0 NA Annular Preventer 1 - 11" 5000 P - Ball Type 1 FP #1 Rams 1 '2 7/8"x5" VB' P' Inside BOP 1 P #2 Rams 1 . Blinds P FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1- 2 1/16115000 • P HCR Valves 1 " 2 1/16" 5000 - P' Kill Line Valves 3 2 1/16" 5000 - P Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity WIT Inside Reel Valves 0 NA Number of Failures: I ✓ Test Results Test Time 7.5 Remarks: Used 2 7/8" test ioint for testing. Troubled testing, but not due to well control equipment. I left location on the second test after approximately 2.5 hours of troubleshooting the leak that was giving us issues and couldn't be located. Testing was stopped and I instructed them to find and fix the leak and after they had two good shell tests in a row, to call me and I would come back out to start the testing all over again. They located the leak and it was an isolation valve between the Doke manifold and the kill line valves (K-07). The leak was a small low pressure leak that held on the high. The valve was replaced and they called me back out, after searching for the leaky valve for approximately 16 hours. We started the testing again from the beginning and the testing went well. The TIW valve that failed on the 2nd test of the first go around passed giving us the only faillpass of the BOP test. So I was on the rig testing for only 7.5 hours, but including the time it took to identify the leak and repair it, 23 hours had elapsed. Quantity P/F No. Valves 16, P Manual Chokes 1 P Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity WIT Inside Reel Valves 0 NA Number of Failures: I ✓ Test Results Test Time 7.5 Remarks: Used 2 7/8" test ioint for testing. Troubled testing, but not due to well control equipment. I left location on the second test after approximately 2.5 hours of troubleshooting the leak that was giving us issues and couldn't be located. Testing was stopped and I instructed them to find and fix the leak and after they had two good shell tests in a row, to call me and I would come back out to start the testing all over again. They located the leak and it was an isolation valve between the Doke manifold and the kill line valves (K-07). The leak was a small low pressure leak that held on the high. The valve was replaced and they called me back out, after searching for the leaky valve for approximately 16 hours. We started the testing again from the beginning and the testing went well. The TIW valve that failed on the 2nd test of the first go around passed giving us the only faillpass of the BOP test. So I was on the rig testing for only 7.5 hours, but including the time it took to identify the leak and repair it, 23 hours had elapsed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ƚŚĞƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚĨŽƌůĞĂŬƐƚŽĞŶƐƵƌĞƚŚĂƚƚŚĞĨůƵŝĚŝƐŐŽŝŶŐĚŽǁŶͲŚŽůĞĂŶĚŶŽƚůĞĂŬŝŶŐ ĂŶǇǁŚĞƌĞĂƚƐƵƌĨĂĐĞ͘Ϳ Ě͘,ŽůĚĂĐŽŶƐƚĂŶƚƉƌĞƐƐƵƌĞŽŶƚŚĞĞƋƵŝƉŵĞŶƚĂŶĚŵŽŶŝƚŽƌƚŚĞĨůƵŝĚͬƉƵŵƉƌĂƚĞŝŶƚŽƚŚĞ ǁĞůů͘ZĞĐŽƌĚƚŚĞƉƵŵƉŝŶŐƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞ͘ Ğ͘KŶĐĞƚŚĞKWƌĂŵĂŶĚĂŶŶƵůĂƌƚĞƐƚƐĂƌĞĐŽŵƉůĞƚĞĚ͕ƚĞƐƚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞƐǇƐƚĞŵĨŽůůŽǁŝŶŐ ƚŚĞŶŽƌŵĂůƚĞƐƚƉƌŽĐĞĚƵƌĞ;ĨůŽŽƌǀĂůǀĞƐ͕ŐĂƐĚĞƚĞĐƚŝŽŶ͕ĞƚĐ͘Ϳ Ĩ͘ZĞĐŽƌĚĂŶĚƌĞƉŽƌƚƚŚŝƐƚĞƐƚǁŝƚŚŶŽƚĞƐŝŶƚŚĞƌĞŵĂƌŬƐĐŽůƵŵŶƚŚĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌͬWsƉƌŽĨŝůĞ ͬƉĞŶĞƚƌĂƚŽƌǁŽƵůĚŶ͛ƚŚŽůĚƉƌĞƐƐƵƌĞĂŶĚƌŽůůŝŶŐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚŽŶKWƋƵŝƉŵĞŶƚĂŶĚůŝƐƚ ŝƚĞŵƐ͕ƉƌĞƐƐƵƌĞƐĂŶĚƌĂƚĞƐ͘ ϭϬ͘ZhƚŽƉƵůůϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶ͘ ϭϭ͘WƵůůƚŚĞƉůƵŐŽĨĨƚŽŽů͕ĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌƚŚĞWs͕ŝĨŶĞĞĚĞĚŬŝůůƚŚĞǁĞůůǁŝƚŚϴ͘ϯƉƉŐƐŽƵƌĐĞ ǁĂƚĞƌĂŶĚƉƵůůƚŚĞWs͘ ϭϮ͘DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌ͘K>^͕ƵŶƐĞĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚƉƵůůƚŽƚŚĞƌŝŐĨůŽŽƌ͘ Ă͘^Kсϳϱ<ĂŶĚWhсϳϳ<ǁŚĞŶůĂŶĚĞĚŝŶϴ͘ϱƉƉŐƐĞĂǁĂƚĞƌďǇŽǇŽŶϭϲ;ďůŽĐŬǁĞŝŐŚƚсϰϬ<ͿŝŶ ϮϬϭϯ͘ ϭϯ͘>ĂǇĚŽǁŶƚŚĞůĂŶĚŝŶŐũŽŝŶƚĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘ZhƚŽƉƵůů^WĐ ĂďůĞŽǀĞƌƚŚĞƐŚĞĂǀĞƐƚŽƚŚĞƐƉŽŽůŝŶŐ ƵŶŝƚ͘ Ă͘/ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚŶŽƚĞĂŶǇĚĂŵĂŐĞ͘/ĨĂŶǇĚĂŵĂŐĞŝƐĨŽƵŶĚ͕ĐŽŶƚĂĐƚǁĞůůŚĞĂĚ ƐƉĞĐŝĂůŝƐƚĨŽƌƌĞĚƌĞƐƐŽƌƌĞƉůĂĐĞŵĞŶƚ͘ ŽŶƚŝŶŐĞŶĐǇ;/ĨĂƌŽůůŝŶŐƚĞƐƚǁĂƐĐŽŶĚƵĐƚĞĚͿ͗DhŶĞǁŚĂŶŐĞƌŽƌƚĞƐƚƉůƵŐƚŽƚŚĞĐŽŵƉůĞƚŝŽŶƚƵďŝŶŐ͘ ZĞͲůĂŶĚŚĂŶŐĞƌ;ŽƌƚĞƐƚƉůƵŐͿŝŶƚƵďŝŶŐŚĞĂĚ͘dĞƐƚKWƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ͘ ϭϰ͘WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘>ĂǇĚŽǁŶ^WĂŶĚŵŽƚŽƌ͘ Ă͘EŽƚĞĂŶǇĐŽƌƌŽƐŝŽŶ͕ƐĂŶĚŽƌƐĐĂůĞŽŶƚŚĞƚƵďŝŶŐǁŝƚŚĂƐƐŽĐŝĂƚĞĚĚĞƉƚŚƐĂŶĚ^WĐŽŵƉŽŶĞŶƚƐŽŶ ƚŚĞŵŽƌŶŝŶŐƌĞƉŽƌƚ͘ ď͘>ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐ͘ Đ͘/ĨĂŶǇũŽŝŶƚ;ƐͿĂƉƉĞĂƌƐƵƐƉĞĐƚŽĨĚĂŵĂŐĞƚŽƚŚƌĞĂĚƐŽƌƚƵďŝŶŐ͕ƐĞŶĚƚŽ'Θ/ĨŽƌĚŝƐƉŽƐĂůĂŶĚ ƌĞƉůĂĐĞǁŝƚŚŶĞǁ͘ WůƵŐĨŽƌĐŽƌĞ^d tĞůů͗DWh/ͲϬϳ ĂƚĞ͗ϭϮͲϮϴͲϮϬϮϬ ƋƵŝƉŵĞŶƚŝƐƉŽƐŝƚŝŽŶ dƵďŝŶŐŚĂŶŐĞƌsŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ ĨŽƌŬŝůůƐƚƌŝŶŐ dƵďŝŶŐΘWƵƉũŽŝŶƚƐsŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ ĨŽƌŬŝůůƐƚƌŝŶŐ ^WĞƋƵŝƉŵĞŶƚͬWŽǁĞƌĂďůĞĞŶƚƌŝůŝĨƚƚŽƚĂŬĞƉŽƐƐĞƐƐŝŽŶĨŽƌŝŶƐƉĞĐƚŝŽŶΘƚĞĂƌĚŽǁŶ ,ĞĂƚƚƌĂĐĞ:ƵŶŬ '>D͛ƐΘŶŝƉƉůĞ:ƵŶŬ WƌŽƚĞĐƚŽƌůŝǌĞƌ;ϰͿ:ƵŶŬ ƵĂůĐŚĂŶŶĞůĂŶŶŽŶĐůĂŵƉƐ;ϰϰϬͿ:ƵŶŬ ^ŝŶŐůĞĐŚĂŶŶĞůĂŶŶŽŶĐůĂŵƉƐ;ϭϵͿ :ƵŶŬ &ůĂƚŐƵĂƌĚ;ϮͿ:ƵŶŬ ^ƚĂŝŶůĞƐƐƐƚĞĞůďĂŶĚƐ:ƵŶŬ ϰ͟ƐŝŶŐůĞĂŶŶŽŶĐůĂŵƉ;ϳͿ:ƵŶŬ ,ĂůĨĂŶŶŽŶĐůĂŵƉ:ƵŶŬ ,ĞĂƚƚƌĂĐĞƐƚĂƌƚĞƌĐůĂŵƉ;ϭͿ:ƵŶŬ Ϯ͛ƐƉĂĐĞƌĐůĂŵƉ;ϵͿ:ƵŶŬ ϭϱ͘ZhͲůŝŶĞ͘ ϭϲ͘Wh͕DhĂŶĚZ/,ǁŝƚŚ>ƚŽũƵƐƚďĞůŽǁƚŚĞďŽƚƚŽŵƉĂĐŬĞƌĂƚϰ͕ϬϮϮ͛D;ĚŽŶŽƚĞǆŝƚƚŚĞƚƵďŝŶŐͿ͘ Ă͘DŝŶŝŵƵŵ/сϮ͘ϯϴϬ͟ƐƚĂƌƚŝŶŐĂƚϯ͕ϵϲϯ͛D͘ ϭϳ͘>ŽŐĨƌŽŵϰ͕ϬϮϮ͛ƚŽϯ͕ϳϬϬ͛ĨŽƌďĂƐĞůŝŶĞũĞǁĞůƌǇůŽŐ͘ ϭϴ͘Wh͕DhĂŶĚZ/,ǁŝƚŚďƌŝĚŐĞƉůƵŐĨŽƌϮͲϳͬϴ͟ƚƵďŝŶŐǁŝƚŚ>ƚŽϰ͕ϬϮϮ͛͘ ϭϵ͘>ŽŐƵƉĂŶĚƉůĂĐĞƚŚĞďƌŝĚŐĞƉůƵŐŽŶĚĞƉƚŚ͘^ĞƚƚŚĞďƌŝĚŐĞƉůƵŐĂƚΕϯ͕ϵϴϱ͛;ŵŝĚĚůĞŽĨƚŚĞƐĞĂůĂƐƐĞŵďůǇͿ ϮϬ͘WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞƌƵŶŶŝŶŐƚŽŽů͘ Ϯϭ͘Wh͕DhĂŶĚZ/,ǁŝƚŚďƌŝĚŐĞƉůƵŐĨŽƌϯͲϭͬϮ͟ƚƵďŝŶŐǁŝƚŚ>ƚŽΕϯ͕ϵϲϬ͛͘ Ă͘DŝŶŝŵƵŵ/сϮ͘ϵϴϬ͘͟/ƌĞĚƵĐĞƐƚŽϮ͘ϯϴϬĂƚϯ͕ϵϲϯ͛D ϮϮ͘>ŽŐƵƉĂŶĚƉůĂĐĞƚŚĞďƌŝĚŐĞƉůƵŐŽŶĚĞƉƚŚ͘^ĞƚƚŚĞďƌŝĚŐĞƉůƵŐĂƚΕϯ͕ϴϲϲ͛;ŵŝĚĚůĞŽĨƚŚĞƐĞĂůĂƐƐĞŵďůǇͿ Ϯϯ͘WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞƌƵŶŶŝŶŐƚŽŽů͘ Ϯϰ͘ZDKͲůŝŶĞ͘ Ϯϱ͘Wh͕DhĂŶĚZ/,ĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂŶĚZ/,ŽŶϮͲϳͬϴ͟ƚƵďŝŶŐƚŽϯ͕ϳϬϬ͛D͘ Ϯϲ͘>ŝŐŚƚůǇƚĂŐƚŚĞƉĂĐŬĞƌĂƚϯ͕ϳϮϬ͛D͘WhĂŶĚƐƉĂĐĞŽƵƚƚŽĂŐŽŽĚǁŽƌŬŝŶŐŚĞŝŐŚƚĨŽƌƚŚĞĐĞŵĞŶƚĞƌƐŽŶĐĞ ƚŚĞƐƚŝŶŐĞƌŝƐƉƵůůĞĚĨƌŽŵƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘ Ϯϳ͘^ĞƚƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘WdƚŚĞ/ƚŽϭ͕ϱϬϬƉƐŝĨŽƌϭϬŵŝŶƵƚĞƐƚŽĞŶƐƵƌĞĂŐŽŽĚƐĞƚ͘ Ϯϴ͘ZhƚŚĞĐĞŵĞŶƚĞƌƐ Ϯϵ͘ƐƚĂďůŝƐŚŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞĂƚϯWD͘ ϯϬ͘DŝǆĂŶĚƉƵŵƉϮϬďďůƐŽĨϭϱ͘ϴƉƉŐĐůĂƐƐ'ĐĞŵĞŶƚ͘ ϯϭ͘WƵŵƉϱďďůƐŽĨĐĞŵĞŶƚƚŚƌŽƵŐŚƚŚĞƌĞƚĂŝŶĞƌ;dƵďŝŶŐсϭ͘ϳϱďďůƐΘ/сϯ͘ϮϱďďůƐͿ͕ƵŶͲƐƚŝŶŐĨƌŽŵƚŚĞ ĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂŶĚƉƵŵƉϭϱďďůďĂůĂŶĐĞĚĐĞŵĞŶƚƉůƵŐ;ĐĞŵĞŶƚŚĞŝŐŚƚŝŶϳ͟ĐĂƐŝŶŐсϯϵϮ͛Ϳ͘^ůŽǁůǇ WKK,ϱϬϬ͛;ƚŚŝƐƐŚŽƵůĚďĞΕϭϬϴ͛ĂďŽǀĞƚŚĞdKͿĂŶĚĐŝƌĐƵůĂƚĞƚŚĞǁĞůůĐůĞĂŶ͘ ϯϮ͘ŽŶƚŝŶƵĞƚŽWKK,ĂŶĚůĂǇĚŽǁŶƚŚĞĐĞŵĞŶƚƐƚŝŶŐĞƌ͘ ϯϯ͘Wh͕DhĂŶĚZ/,ǁŝƚŚŵƵůĞƐŚŽĞƉƵƉũŽŝŶƚŽŶϵϬũŽŝŶƚƐŽĨƉƵůůĞĚϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ͘ ϯϰ͘WhĂŶĚDhƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐŚĂŶŐĞƌ͘ŶƐƵƌĞ^WƉŽƌƚĂŶĚĂŶǇĐŽŶƚƌŽůůŝŶĞƉŽƌƚƐĂƌĞĚƵŵŵŝĞĚŽĨĨ͘ WůƵŐĨŽƌĐŽƌĞ^d tĞůů͗DWh/ͲϬϳ ĂƚĞ͗ϭϮͲϮϴͲϮϬϮϬ ϯϱ͘>ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌĂŶĚZ/>^͘>ĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘ZĞĐŽƌĚWhĂŶĚ^KǁĞŝŐŚƚƐŽŶƚŚĞƚĂůůǇĂŶĚ tĞůů͘ ϯϲ͘^ĞƚϮ͘ϱ͟,WWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϯϳ͘ZŵƵĚďŽĂƚ͘ZKWŚŽƵƐĞ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϯϴ͘ZhĐƌĂŶĞ͘EKW͘/ŶƐƚĂůůƚŚĞƉůƵŐŽĨĨƚŽŽů͘ ϯϵ͘EhƚŚĞƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂŶĚEhϮͲϵͬϭϲ͟ϱDƚƌĞĞ͘ ϰϬ͘WdƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬͬϱ͕ϬϬϬƉƐŝ͘WdƚŚĞƚƌĞĞƚŽϮϱϬͬϱ͕ϬϬϬƉƐŝ͘ ϰϭ͘WƵůůƚŚĞƉůƵŐŽĨĨƚŽŽůĂŶĚWs͘ ϰϮ͘ZĐƌĂŶĞ͘DŽǀĞƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϰϯ͘ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϰϰ͘dƵƌŶǁĞůůŽǀĞƌƚŽƚŚĞǁĞůůƐŐƌŽƵƉǀŝĂŚĂŶĚŽǀĞƌĨŽƌŵ͘ ϰϱ͘Zh>Z^͕ĨƌĞĞǌĞƉƌŽƚĞĐƚƚŚĞǁĞůůǁŝƚŚĚŝĞƐĞůĂŶĚZ>Z^͘ ϰϲ͘D/Zh^>͘ Ă͘EŽƚŝĨǇƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞĨŽƌƚĂŐŽĨdKĂŶĚWd͘ ϰϳ͘Z/,ǁŝƚŚĚƌŝǀĞĚŽǁŶďĂŝůĞƌ͕ƚĂŐdK;ŶŽƚĞƚĂŐĚĞƉƚŚŝŶtĞůůƌĞƉŽƌƚͿĂŶĚWKK,͘ ϰϴ͘WdƚŚĞĐĞŵĞŶƚƉůƵŐĂŶĚϳ͟ĐĂƐŝŶŐƚŽϭ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ;ĐŚĂƌƚĞĚͿ ϰϵ͘ZDK^>͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘KWƐƚĂĐŬƐŬĞƚĐŚ ϰ͘ůĂŶŬZtKDK&Žƌŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗E>tϭϮͲϮϳͲϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh/ͲϬϳ >ĂƐƚŽŵƉůĞƚĞĚ͗ϯͬϮϵͬϮϬϭϯ Wd͗ϭϵϱͲϭϱϭ dс ϳ͕ϰϰϰ͛;DͿͬdс ϳ͕ϯϬϳ͛;dsͿ KƌŝŐ͘<ůĞǀ͗͘ ϲϰ͘Ϭ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϰ͘ϱ͛ Z<ʹ ,ĂŶŐĞƌ͗Ϯϯ͘Ϭ͛;ŽǇŽŶϭϲͿ ϳ͟ ´+2:&2µ(6¶ &HPHQWHU #¶ ϮϬ͟ Wdс ϲ͕ϴϴϱ͛;DͿͬWdс ϲ͕ϳϲϳ͛;dsͿ (VW72&#¶ ϵͲϱͬϴ͟ 2$ 1% 1& SSJ0XG 2% DŝŶ/сϮ͘ϮϬϱ͟ +HDW7UDFHIURP VXUIDFHWR¶ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϯϯ͛^dϮ͗ϮͲϳͬϴ͟ǆϭ͟<DD'>D;<ͲƵŵŵǇϭϮͲϮϲͲϮϬͿ Ϯ ϯ͕ϯϭϴ͛^dϭ͗ϮͲϳͬϴ͟ǆϭ͟<DD'>D ;ŵƉƚǇƉŽĐŬĞƚϭϮͲϮϲͲϮϬͿ ϯ ϯ͕ϰϲϴ͛ ϮͲϳͬϴ͟yEWƌŽĨŝůĞ ;Ϯ͘ϮϬϱ͟EŽͲ'ŽWĂĐŬŝŶŐŽƌĞ/Ϳ ϰ ϯ͕ϱϭϭ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗&W,s/^ ϱ ϯ͕ϱϭϮ͛ WƵŵƉ͗ϭϰϭWϲ͕DŽĚĞůͲWD^y ϲ ϯ͕ϱϮϴ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'Z^&dyZ,ϲ ϳ ϯ͕ϱϯϯ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^ϯhd^ͬ^W&^ ϴ ϯ͕ϱϰϬ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗'^ϯhd^ͬ^W&^ ϵ ϯ͕ϱϰϳ͛ DŽƚŽƌ<D,Ͳϳϲ,W;ZĞͲƌĂƚĞƚŽϱϱ,WͿ ϭϬ ϯ͕ϱϱϳ͛ ĞŶƚƌĂůŝǌĞƌǁͬydϭϱϬ^ĞŶƐŽƌʹŽƚƚŽŵΛϯ͕ϱϱϵ͛ ϭϭ ϯ͕ϳϮϬ͛ ϳ͟,^sd>WĂĐŬĞƌ;ϯ͘ϴϴϬ͟/Ϳ ϭϮ ϯ͕ϳϱϭ͛ ^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď;Ϯ͘ϵϴϬ͟/Ϳ ϭϯ ϯ͕ϴϬϮ͛ ϰ͟ϭϮ'ĂƵŐĞϯϬϰ^^tĞůĚĞĚ^ĐƌĞĞŶ;ϲϭ͛>ŽŶŐ͖ϯ͘ϱϰϴ͟/Ϳ ϭϰ ϯ͕ϴϲϯ͛ >ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ;Ϯ͘ϵϴϱ͟/Ϳ ϭϱ ϯ͕ϴϲϯ͛ ϳ͟,^sd>WĂĐŬĞƌ;ϯ͘ϴϴϬ͟/Ϳ ϭϲ ϯ͕ϴϵϰ͛ ^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď;Ϯ͘ϵϴϬ͟/Ϳ ϭϳ ϯ͕ϵϮϳ͛ ϯ͘ϱ͟ϮϬ'ĂƵŐĞϯϬϰ^^tĞůĚĞĚ^ĐƌĞĞŶ;ϯϱ͛>ŽŶŐ͖Ϯ͘ϵϵϮ͟/Ϳ ϭϴ ϯ͕ϵϲϯ͛ >ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ;Ϯ͘ϯϴϬ͟/Ϳ ϭϵ ϯ͕ϵϲϰ͛ ϳ͟,^/ƐŽůĂƚŝŽŶWĂĐŬĞƌ;ϯ͘ϯϬϬ͟/Ϳ ϮϬ ϯ͕ϵϵϮ͛ ϰ͘Ϭ͟ϮϬ'ĂƵŐĞϯϬϰ^^tĞůĚĞĚ^ĐƌĞĞŶ;Ϯϰ͛>ŽŶŐ͖ϯ͘ϱϰϴ͟/Ϳ Ϯϭ ϰ͕Ϭϭϲ͛ >ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ;ϯ͘ϮϱϬ͟/Ϳ ϮϮ ϰ͕Ϭϭϳ͛ ϳ͟,^tZWĞƌŵĂŶĞŶƚWĂĐŬĞƌ;ϰ͘ϬϬϬ͟/Ϳ Ϯϯ ϰ͕ϬϮϮ͛ ŽůůĞƚ^ŚŽƵůĚĞƌ Ϯϰ ϰ͕ϮϮϯ͛ &ŝƐŚʹϭϮ͘ϰϲ͛W^DdddŽŽůǁͬϰͲĂƌŵĞŶƚƌĂůŝǌĞƌ WZ&KZd/KEd/> ^ĐŚƌĂĚĞƌ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ ͞E͟^ĂŶĚƐ ϯ͕ϴϬϴ͛ ϯ͕ϴϮϲ͛ ϯ͕ϳϴϱ͛ ϯ͕ϴϬϯ͛ ϭϴ ϭϬͬϬϱͬϭϵϵϲ KƉĞŶ ͞E͟^ĂŶĚƐ ϯ͕ϴϯϵ͛ ϯ͕ϴϰϲ͛ ϯ͕ϴϭϲ͛ ϯ͕ϴϮϯ͛ ϳ ϭϬͬϬϱͬϭϵϵϲ KƉĞŶ ͞K͟^ĂŶĚƐ ϯ͕ϵϯϯ͛ ϯ͕ϵϲϬ͛ ϯ͕ϵϭϭ͛ ϯ͕ϵϯϴ͛ Ϯϳ ϵͬϮϰͬϭϵϵϲ KƉĞŶ ͞K͟^ĂŶĚƐ ϯ͕ϵϵϯ͛ ϰ͕ϬϭϬ͛ ϯ͕ϵϳϬ͛ ϯ͕ϵϴϳ͛ ϭϳ ϵͬϮϰͬϭϵϵϲ KƉĞŶ ͚E͛^ĂŶĚƐϰͲϭͬϮ͟t>WĞƌĨ͛ĚǁͬϮϰŐŵϭϮƐƉĨ͖͚K͛^ĂŶĚƐt>WĞƌĨ͛ĚǁͬϮϰŐŵϭϮƐƉĨ t>>/E>/Ed/KEd/> <KWΛϭ͕ϰϱϬ͛ DĂǆ,ŽůĞŶŐůĞсϮϬĚĞŐ͘Λϱ͕ϵϲϰ͛ ,ŽůĞĂŶŐůĞƚŚƌƵƉĞƌĨƐсϮĚĞŐ͘ dZΘt>>, dƌĞĞ ϮͲϵͬϭϲ͟ʹϱDt<D tĞůůŚĞĂĚ ϭϭ͟ϱDt<Dǁͬϭϭ͟ǆϮͲϳͬϴ͟ƚďŐ͘,ĂŶŐĞƌ͕Ϯ͘ϱ͚͟,͛ WsƉƌŽĨŝůĞĂŶĚϴƌĚhƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϬϮͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮʹϭϬͬϬϳͬϭϵϵϱ ŽŵƉůĞƚĞĚǁͬ'ƌĂǀĞůWĂĐŬĂŶĚ&ƌĂĐĂŶĚ^WǁͬEĂďŽƌƐϰ^ʹϭϬͬϬϴͬϭϵϵϲ ZtK^WZĞƉĂŝƌďǇEĂďŽƌƐϰ^ʹϵͬϬϮͬϮϬϬϴ ZtK^WZĞƉĂŝƌďǇŽǇŽŶϭϲʹϯͬϮϵͬϮϬϭϯ KWE,K>ͬDEdd/> ϮϬ͟ ϮϱϬƐǆƌĐƚŝĐ^Ğƚ/ŝŶĂϮϰ͟,ŽůĞ ϵͲϱͬϴ͟ ϱϱϬƐǆWĞƌŵΘϮϱϬƐǆůĂƐƐ͚'͛ŝŶĂϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϰϵϬƐǆůĂƐƐ͚'͛ŝŶĂϴͲϭͬϮ͟,ŽůĞ ^d/Dh>d/KE^hDDZz ͚E͛^ĂŶĚƐ&ƌĂĐWĂĐŬǁͬϱϯ͕ϳϱϬůďƐŽĨϭϲͬϮϬĂƌďŽůŝƚĞ͕ϰϬ͕ϬϬϬůďƐŽĨϮϬͬϰϬ ͚K͛^ĂŶĚƐ&ƌĂĐWĂĐŬǁͬϴϵ͕ϱϬϬůďƐŽĨϭϲͬϮϬĂƌďŽůŝƚĞ ͚K͛^ĂŶĚƐ&ƌĂĐWĂĐŬǁͬϱϲ͕ϬϬϬůďƐŽĨϭϲͬϮϬĂƌďŽůŝƚĞ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϭϮΖ Ϭ͘ϯϱϲϴ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ Ϯ͕ϲϴϬ͛ Ϭ͘Ϭϳϱϴ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬd ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϳ͕ϰϮϱ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϮͲϳͬϴ͟ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨ ϯ͕ϱϱϵ͛ Ϭ͘ϬϬϱϳϵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗/dϭϮͬϮϮͬϮϬϮϬ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh/ͲϬϳ >ĂƐƚŽŵƉůĞƚĞĚ͗ϯͬϮϵͬϮϬϭϯ Wd͗ϭϵϱͲϭϱϭ dс ϳ͕ϰϰϰ͛;DͿͬdсϰϰ ϳ͕ϳ ϯϬϳ͛;dsͿ Kƌŝ Ő͘<ůĞǀ͗͘ϲϰ͘Ϭ͛ϬϬ ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϰ͘ϱ͛ Z<ʹ ,ĂŶŐĞƌ͗Ϯϯ͘Ϭ͛;ϬϬŽǇŽŶϭϲͿ ϳ͟ ´+2:&2µ(6¶ &HPHQWHU #¶ ϮϬ͟ Wdсϲ͕ϴϴϱ͛;DͿͬWdсϲ͕ϳϲϳ͛;dsͿ (VW72&DWц¶ ϵͲϱͬϴ͟ 2$ 1% 1& SSJ0XG 2% (VW72&DW¶ WƌŽƉŽƐĞĚ/WΛ цϯ͕ϴϲϲ͛ WƌŽƉŽƐĞĚ/WΛ цϯ͕ϵϴϱ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϮ͕ϴϲϴ͛DƵůĞ^ŚŽĞWƵƉ:ŽŝŶƚʹ ŽƚƚŽŵĂƚ цϮ͕ϴϳϴ͛ Ϯ цϯ͕ϳϭϬ͛ ĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϭ ϯ͕ϳϮϬ͛ ϳ͟,^sd>WĂĐŬĞƌ;ϯ͘ϴϴϬ͟/Ϳ ϭϮ ϯ͕ϳϱϭ͛^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď;Ϯ͘ϵϴϬ͟/Ϳ ϭϯ ϯ͕ϴϬϮ͛ ϰ͟ϭϮ'ĂƵŐĞϯϬϰ^^tĞůĚĞĚ^ĐƌĞĞŶ;ϲϭ͛>ŽŶŐ͖ϯ͘ϱϰϴ͟/Ϳ ϭϰ ϯ͕ϴϲϯ͛>ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ;Ϯ͘ϵϴϱ͟/Ϳ ϭϱ ϯ͕ϴϲϯ͛ ϳ͟,^sd>WĂĐŬĞƌ;ϯ͘ϴϴϬ͟/Ϳ ϭϲ ϯ͕ϴϵϰ͛^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď;Ϯ͘ϵϴϬ͟/Ϳ ϭϳ ϯ͕ϵϮϳ͛ϯ͘ϱ͟ϮϬ 'ĂƵŐĞϯϬϰ^^tĞůĚĞĚ^ĐƌĞĞŶ;ϯϱ͛>ŽŶŐ͖Ϯ͘ϵϵϮ͟/Ϳ ϭϴ ϯ͕ϵϲϯ͛>ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ;Ϯ͘ϯϴϬ͟/Ϳ ϭϵ ϯ͕ϵϲϰ͛ ϳ͟,^/ƐŽůĂƚŝŽŶWĂĐŬĞƌ;ϯ͘ϯϬϬ͟/Ϳ ϮϬ ϯ͕ϵϵϮ͛ ϰ͘Ϭ͟ϮϬ'ĂƵŐĞϯϬϰ^^tĞůĚĞĚ^ĐƌĞĞŶ;Ϯϰ͛>ŽŶŐ͖ϯ͘ϱϰϴ͟/Ϳ Ϯϭ ϰ͕Ϭϭϲ͛>ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ;ϯ͘ϮϱϬ͟/Ϳ ϮϮ ϰ͕Ϭϭϳ͛ ϳ͟,^tZWĞƌŵĂŶĞŶƚWĂĐŬĞƌ;ϰ͘ϬϬϬ͟/Ϳ Ϯϯ 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They are available in the original file and viewable by direct inspection. I¢_¢'/.¢/ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Beverly Dianq~~--~Nathan Lowell Is~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ ` STATE OF ALASKA RECEIVED I SKA OIL AND GAS CONSERVATION C•ISSION REPORT OF SUNDRY WELL OPERATIONS APR 2 3 2013 1. Operations Performed: AOGCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing IS Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other El Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other 1:1 Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 195 - 151 • 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 22602 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 MPI -07 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 7444' feet Plugs:(measured) 4236' feet true vertical 7305' feet Junk: (measured) 4235' feet Effective depth: measured 6885' feet Packer: (measured) 3720', 3863', feet 3964', 4020' true vertical 6766' feet Packer: (true vertical) 3646', 3996' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32' - 112' 32' - 112' 1490 470 Surface 2649' 9 -5/8" 31' - 2680' 31' - 2663' 5750 3090 Intermediate Production 7397' 7" 28' - 7425' 28' - 7287' 7240 5410 Liner Perforation Depth: Measured Depth: 3808' - 4010' feet True Vertical Depth: 3784' - 3986' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 3559' 3535' Packers and SSSV (type, measured and true vertical depth): (Screen Assembly) HES VTL Packer, HES Isolation Packer, 3720', 3863', 3696', 3839' HES VTL Packer, HES 7" AWR Sump Packer 3964', 4020' 3940', 3996' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED JUL 1 0 2013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 151 40 56 260 215 Subsequent to operation: 138 36 29 40 212 14. A ❑C opies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 64 -5683 N/A Email: David.Bjork @bp.com Printed Na e: Joe La tL Title: Drilling Technologist Signature: Phone: 564 -4091 Date: 4/ 15I 13 Form 10-404 Re ' d 10/2012 V/ 2 R DMS APR 2 4 201 Submit Original Only ?// // ✓ 11°,.X,,, • • Nih ra •CXS U p@CFl h Summary R @p+D1't Common Well Name: MPI -07 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 End Date: 3/29 /2013 'X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678"8 Long: 10149°34'49.433'W Active datum: ORIG KELLY BUSHING ©66.O0usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — (usft) 3/25/2013 05:00 - 10:00 5.00 MOB P PRE MOVE RIG OFF WELL MPG -02. MOVE RIG AROUND BACK OF PAD AND OUT TO MAIN ROAD, PAST H PAD AND ONTO I PAD. 10:00 - 12:00 2.00 MOB P PRE , SPOT RIG NEAR 1 -07. FINISH LAYING MATS. MOVE RIG OVER WELL AND SET DOWN. 12:00 - 13:00 1.00 MOB P PRE SHIM RIG AND BERM AROUND CELLAR. BACK IN FIRST LOAD OF FLUID. ACCEPT RIG AT 13:00. 13:00 - 15:30 2.50 WHSUR P DECOMP RIG UP CIRC SKID IN CELLAR. RIG UP HIGH PRESSURE HOSE TO FLOWBACK TANK. PRESSURE TEST ALL CIRC LINES, INITIAL FAIL ON HIGH PRESSURE HOSE. CHANGE OUT HOSE AND IT PASSES. 15:30 - 16:00 0.50 WHSUR P DECOMP RIG EVAC DRILL WITH AAR. 16:00 - 17:30 1.50 WHSUR P DECOMP RIG UP LUBRICATOR TO PULL BPV. PRESSURE TEST TO 250 / 3500 PSI, GOOD. PULL BPV, R/D DSM LUBRICATOR TUBING = 1150 PSI, IA =1290 PSI, OA= 200 PSI 17:30 - 20:00 2.50 KILLW P DECOMP PJSM FOR WELL KILL WITH CREW, TOOL PUSHERS, BOTH DAY AND NIGHT WSL'S BLEED GAS OFF IA THRU KILL MANIFOLD CHOKE TO FLOW BACK TANK FROM 1290 PSI TO 280 PSI, 4 MINUTES - PUMP 20 BBLS OF 8.5 PPG 120 DEGREE ' SEAWATER DOWN TUBING, TAKING RETURNS FROM IA THRU CHOKE TO FLOW BACK TANK - FLUID RETURNS AFTER 2 BBLS PUMPED TUBING PRESSURE DROPPED TO 200 PSI, IA= 1120 PSI DURING INITIAL 20 BBL CIRCULATION - CLOSE CHOKE, BULLHEAD 40 BBLS DOWN TUBING, TUBING = 600 PSI, IA = 1440 PSI - OPEN CHOKE TO FLOW BACK TANK, PUMP 1 5 BPM DOWN TUBING 40 BBLS SOAP PILL, FOLLOWED BY 180 BBLS OF 8.5 PPG SEAWATER - TAKE RETURNS THRU CHOKE TO FLOW BACK TANK ICP TUBING = 720 PSI - ICP IA = 1360 PSI, 150 PSI ON DOWN STREAM LINE FCP TUBING = 740 PSI - FCP IA = 140 PSI, CHOKE FULL OPEN - PUMPS OFF, TUBING = 0 PSI, IA = 0 PSI PUMPED A TOTAL OF 300 BBLS, RETURNED 111 BBLS TO FLOW BACK TANK, 40 BBLS BULLHEADED I- 149 BBLS LOSS DURING CIRCULATION Printed 4/8/2013 10:25:55AM . • • N ©rth,Amerhcal - ALASKA 44P . ; Operation Summary Report Common Well Name: MPI -07 ' AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 I End Date: 3/29/2013 ,X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AMI Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678 "8 Long: — — — , 0149 °34'49.433 "W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) _ Date From - To ' Hrs I Task Code NPT j NPT Depth Phase 1 Description of Operations (hr) (usft) i T— 20:00 - 20:30 ' 0.50 KILLW P DECOMP I MONITOR WELL FOR 30 MINUTES - WSL VERIFY THAT WELL IS ON A VAC - BLOW DOWN ALL CIRCULATING LINES - MAINTAIN CONSTANT HOLE FILL TO IA - ESTABLISH LOSS RATE = 21 BPH 20:30 - 22:00 1.50 I WHSUR 1 P DECOMP PJSM, M/U DSM LUBRICATOR - TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN, I I CHART ' - INSTALL TWC, R/D DSM LUBRICATOR 22:00 - 23:00 1 1.00 WHSUR P DECOMP PERFORM ROLLING TEST BELOW TWC '- 5 BPM = 500 PSI, 10 MIN, CHART, 50 BBLS I I PUMPED - TEST TWC FROM ABOVE, 250 / 3500 PSI, 5 1 MIN, CHART 23:00 - 00:00 1.00 WHSUR P DECOMP I FMC HAND BLEED HANGER VOID - N/D FMC 11" X 2 916" ADAPTER AND CAMERON 2 9/16" TREE I - OA= 100 PSI 1 - LOSS RATE = 21 BPH 1 I 1 - 24 HOUR FLUID LOSS = 149 BBLS 8.5 SEAWATER 3/26/2013 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - N/D ADAPTER FLANGE AND TREE FMC REP INSPECT HANGER AND CHECK ' THREADS = 8.5 RH TURNS 01:00 - 03:00 2.00 BOPSUR P DECOMP PJSM, N/U BOP AND RISER SERVICE CHOKE MANIFOLD 1 03:00 - 04:30 1.50 BOPSUR ' P DECOMP PJSM TO C/O PIPE RAMS - REMOVE 2 3/8 LOWER RAMS - INSTALL 2 7/8" X 5" VARIABLE PIPE _RAM 04:30 - 05:30 1.00 BOPSUR 1 P DECOMP 1 PJSM, R/U TO TEST BOP - R/U TEST JOINTS, M/U FLOOR VALVES I- FILL BOP AND CHOKE MANIFOLD 1, - OA =0PSI - FLUID LOSS RATE = 24 BPH OF 8.5 PPG SEAWATER 05:30 - 13:30 8.00 BOPSUR I P DECOMP 1 PJSM, TEST BODE AND RELATED EQUIPMENT 1- TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES TEST ANNULAR WITH 2 -7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES ' EACH, CHARTED - TEST 2 7/8" X 5" VARIABLE RAMS WITH 2 -7/8" AND 4" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, I CHARTED I - TEST BLIND RAMS, FLOOR VALVES, AND I CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 i MIN, CHARTED I- TEST WITH FRESH WATER ' - PERFORM ACCUMULATOR DRAW DOWN TEST I - AOGCC INSPECTOR CHUCK SCHEVE I WAIVED STATES RIGHT TO WITNESS BOP ! ,TEST Printed 4/8/2013 10:25:55AM • • chi,. - ��y KA .: +81?'.`.,. rte, �, ;,:.:.:.. , ...... .:.. ::.:.. ,,,r77 ,r � <1t � Common Well Name: MPI -07 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 End Date: 3/29/2013 X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678 "8 Long: 0149 °34'49.433 "W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 1 (hr) (usft) 13:30 - 15:00 1.50 BOPSUR P DECOMP BLOW DOWN ALL SURFACE LINES - FLUSH AND DRAIN BOP STACK 1- Mill OFF -SET UBRICATOR TO HANGER 1- CLEAR / CLEAN RIG FLOOR R/U CENRTILIFT TOOLS 15:00 - 16:30 1.50 WHSUR P DECOMP PJSM, DSM LUBRICATOR R/U AND M/U DSM LUBRICATOR TEST TO 250 / 3500 PSI, 5 MIN, CHART 1 - PULL TWC, R/D DSM AND OFF -SET (LUBRICATOR 16:30 - 18:00 1.50 PULL P DECOMP M/U LANDING JOINT WITH FOSV TO HANGER - VERIFY NO PRESSURE UNDER HANGER, WELL IS STILL ON VAC - FMC REP BACK OUT LDS - PULL HANGER TO RIG FLOOR - PUWT = 66K, SOWT = 73K, INCLUDES 40K BLOCK WT - PULL TO CLAMP AT FIRST FULL JOINT i BELOW HANGER AND CUT ESP CABLE I - POSITION SLICK PIPE ACROSS BOP STACK - CLOSE ANNULAR AND LINE UP TO TAKE RETURNS THRU GAS BUSTER 18:00 - 18:30 0.50 PULL P DECOMP CIRCULATE ONE TUBING VOLUME, 20 BBLS, THRU GAS BUSTER I - 4 BPM = 420PSI - SPR @ 2 BPM = 100 PSI, 3 BPM = 270 PSI 18:30 - 19:30 1.00 PULL P DECOMP UD LANDING JOINT AND HANGER - R/U ESP SHEAVE - MAINTAIN CONSTANT HOLE FILL, LOSS RATE = 12 BPH 19:30 - 22:30 3.00 PULL DECOMP POOH WITH 2 7/8" 6.5# EUE 8RD TUBING ESP I COMPLETION - STAND TUBING BACK IN DERRICK - FROM 3573' TO 232' 22:30 - 23:30 1.00 PULL P DECOMP PJSM, PUNCH PIPE OBSERVE SAND IN TOP OF JOINT #103 AND PIPE IS NOT DRAINING - ALSO OBSERVE SMALL AMOUNT OF PRESSURE BREAKING OUT IN TOP OF BOX, NO GAS DETECTED - PUNCH LAST 5 JOINTS AS PRECAUTION, FROM 232' TO ESP MOTOR AND PUMP ASSY - NO MORE SAND ENCOUNTERED, PIPE DRAINED CLEAN SEAWATER FREELY THRU — _ PUNCHED HOLES 23:30 - 00:00 0.50 PULL P DECOMP UD ESP PUMP AND MOTOR ASSY PER CENTRILIFT REP -OA =0 PSI - LOSS RATE = 18 BPH - 24 HOUR FLUID LOSS = 279 BBLS 8.5 SEAWATER 3/27/2013 00:00 - 02:00 2.00 PULL P DECOMP 1PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - L/D ESP PUMP AND MOTOR ASSY PER CENTRILIFT REP - RECOVERED; 62 LASALLE CLAMPS, 3 PROTECTOLIZERS, 2 FLAT GUARDS Printed 4/8/2013 10:25:55AM • Common Well Name: MPI -07 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 End Date: 3/29/2013 X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678 "8 Long: 0149 °34'49.433 "W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:00 2.00 PULL P DECOMP PJSM TO RIG DOWN ESP SHEAVE AND TRUNK - CLEAR CLEAN RIG FLOOR R/D ESP CABLE TRUNK [- INSTALL 9" ID WEAR RIG I- MOBILIZE CHAMP PACKER TO RIG FLOOR 04:00 - 07:00 3.00 EVAL P DECOMP I PJSM, P/U HES 7" CHAMP PACKER PER HES 1 REP. RIH T / 3326' MD. WITH PACKER ON 2 7/8" 1 TBG FROM DERRICK. - PUW / 57K, SOW = 63K. 07:00 - 07:30 0.50 EVAL P DECOMP PJSM, MU TOP DRIVE TO 2 -7/8" TBG STRING. - PUMPED 5 BBLS KWF TO FLUSH PACKER AND TBG. - SET HES PACKER PER HES REP W/ 20K DOWN WT. -WSL VERIFIED SET DEPTH @ 3326' MD. 07:30 - 08:30 1.00 EVAL P DECOMP PJSM, MIT -IA, 7" L -80 26 # CSG BY 2 -7/8" EUE ANNULUS. - WSL / TOOLPUSHER VERIFY VALVE ALIGNMENT. - PUMPED 10 STKS (1 BBLS) KWF TO / 1500 PSI FOR 30 CHARTED MINUTES. - MAINTAIN CONTINUOUS HOLE FILL WITH KWF DOWN TBG, DURING TEST - '0' OA PRESSURE. MIT -IA TEST, MEETS BP STP CRT -AK -10-45 CRITERIA. RECEIVED PERMISSION TO PROCEED FROM WTL. - BLEED OFF PRESSURE. " 0 " READING. BLED BACK -1 BBLS. - WSL/TOOLPUSHER /DRILLER VERIFIED NO TRAPPED PRESSURE. - FILLED TBG WITH KWF. RELEASED CHAMP PACKER PER HES REP. 08:30 - 10:30 2.00 EVAL P DECOMP PJSM, POH WITH CHAMP PACKER FROM 3326' MD T/ SURFACE. - UD CHAMP PACKER. - 10 -12BPH LOSS RATE. 10:30 - 14:00 3.50 EVAL P DECOMP PJSM WITH SWS SLICK -LINE CREW. I- R/U DUTCH RISER SYSTEM. - MAINTAIN HOLE FILL THRU KILL LINE. SPOT WIRE LINE UNIT. - R/U PDS TOOL, WAIT ON PDS REP FROM [NORDIC RIG #1 JOB 14:00 - 16:00 2.00 EVAL P j DECOMP RIH W/ PDS LOGGING TOOL - LOG UP FROM 1000' MD. - 50 FPM. 16:00 - 22:00 6.00 EVAL P DECOMP PJSM, CHANGE TOOL STRING TO MTT. - RIH W/ MTT LOGGING TOOL - LOG UP F/ 1000' MD TO SURFACE Printed 4/8/2013 10:25:55AM . • • iita = ;MAW. -BF O 'y' j - fir , Common Well Name: MPI -07 I AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 End Date: 3/29/2013 1X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678 "8 Long: 014_ 9 °3 "W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) Date From - To 1 Hrs Task I Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 EVAL N DFAL DECOMP PULLED LOGGING TOOLS TO RIG FLOOR PDS MTT /DATA LOGGING TOOLS WERE ' !LEFT IN THE HOLE, 12.46', SEE ATTACHED DIAGRAM TOOLS SEPARATED AT THREADED CONNECTION, THREADS DID NOT APPEAR STRESSED - DISCUSS OPTIONS WITH ODE AND RWO FIELD SUPERINTENDENT - ORDER OUT ANOTHER PDS LOGGING TOOL 1 FOR SECOND MTT /DATA RUN - MOBILIZE SLICK LINE FISHING TOOLS TO LOCATION - OA= 0 PSI 1 - LOSS RATE = 10 BPH 1 - 24 HOUR FLUID LOSS = 264 BBLS 8.5 SEAWATER 3/28/2013 00:00 - 01:30 1.50 EVAL N 1 DFAL DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS 1- WAIT ON PDS LOGGING TOOLS 01:30 - 08:00 6.50 EVAL N DFAL DECOMP 1 M/U PDS MTT /DATA LOGGING TOOLS TO 1 ' WIRELINE BHA j - RIH AND LOG UP F/ 1000' MD TO SURFACE 1 . 1 - MADE (4) LOGGING PASSES, AT 20 FPH. 08:00 - 09:00 1.00 FISH N DFAL ' DECOMP R/D PDS / MTT LOGGING TOOLS - M/U 5.50" OVER SHOT GRAPPLE ASSEMBLY. - RUN # 1, ON SLICK LINE. 09:00 - 10:00 1.00 FISH 1 N DFAL DECOMP FISHING RUN # 1 RIH ON SLICK LINE T/ 3719' WLM. WITH 5.50" OVER SHOT GRAPPLE ASSEMBLY. - NO RECOVERY. 10:00 - 11:00 1.00 FISH N DFAL DECOMP FISHING RUN # 2 i M/U 3.25" O.D. LEAD IMPRESSION BLOCK. RIH ON SLICK LINE T/ 3753' WLM. PICK UP AND TAG TOP OF HES VTL PACKER 1 -3722' WLM. - POH TO SURFACE -'LIB' INDICATES THE TOP OF PACKER TAG, BUT NOT THE FISH. I I DISCUSS PLAN FORWARD WITH RWO ODE DUE TO A SMALL I.D.(2.380 ") IN THE SECOND 1 VTL PACKER, NO -GO LOCATOR AT (3962' MD). WSL HELD FACE TO FACE MEETING WITH 1 PAD OPERATOR ON MPI -03, NEXT WELL. "WELL WORK TRANSFER PERMIT' WSL HELD FACE TO FACE 1 HAND- OVER - MEETING WITH MPU PE ON NEXT WELL MPI -03. 11:00 - 12:00 1.00 FISH N DFAL I DECOMP FISHING RUN # 3 - M/U 1.7" O.D. LEAD IMPRESSION BLOCK. 1- RIH ON SLICK LINE AND PUSH FISH TO 4025' WLM. 1- POH TO SURFACE 1 1 - 'LIB' INDICATES CONTACT MADE WITH FISH. 1 - THE FISH WAS LEFT IN THE RAT HOLE BELOW 4025' WLM. Printed 4/8/2013 10:25:55AM , • • ifpEe r „. A ration Common Well Name: MPI -07 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 End Date: 3/29/2013 X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point i Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678"8 Long: 0149°34'49.433"W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 12:30 0.50 EVAL P DECOMP PJSM, R/D SLICK LINE CREW. - L/D SLICK LINE TOOLS / EQUIPMENT. 12:30 - 13:00 0.50 BOPSUR P DECOMP PJSM, R/D DUTCH RISER. - PULL WEAR RING -- 13:00 - 14:00 1.00 RUNCOM ', P RUNCMP I PJSM, R/U TO RUN HEAT TRACE / ESP COMPLETION. HANG DOUBLE CABLE SHEAVE IN DERRICK - SPOT SPOOLING UNIT. - P/U HEAT TRACE / ESP CABLE CLAMPS TO RIG FLOOR. 14:00 - 16:00 2.00 RUNCOM P RUNCMP M/U ESP AND PUMP ASSY PER CENTRILIFT REP _ - INSTALL ESP CABLE AND TEST SAME 16:00 18:30 2.50 RUNCOM P RUNCMP RIH WITH 2 7/8” 6.5# EUE 8 RD TUBING ESP COMPLETION FROM DERRICK. - RIH FROM ESP ASSEMBLY TO 1029' MD. TUBING TORQUE = 2300 FT /LBS INSTALL CANNON CLAMPS ON EVERY COLLAR ON THE FIRST 9 JOINTS, THEN EVERY OTHER JOINT THEREAFTER CHECK CONDUCTIVITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM / 2140 PSI. EVERY 2000', NOT TO EXCEED 3000 PSI 18:30 - 19:30 1.00 RUNCOM P RUNCMP INSTALL HEAT TRACE ON BOTTOM OF JOINT #31 1- CHECK HEAT TRACE AND ESP CONDUCTIVITY - BOTTOM OF HEAT TRACE WILL BE AT 2493' 19:30 - 00:00 4.50 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING ESP COMPLETION FROM DERRICK. - FROM 1029' TO 2053' MD - PUWT = 55K, SOWT = 60K - FLUSH THRU PUMP W/ 5 BBLS AT 2000' MD, 1/2 BPM = 2220 PSI - OA =0PSI - LOSS RATE = 10 BPH - 24 HOUR FLUID LOSS = 248 BBLS 8.5 SEAWATER 3/29/2013 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM WITH CENTRILIFT REP - PERFORM SPCC AND EQUIPMENT CHECKS 1- CROSS THREAD 1 CONNECTION ON BOTTOM OF STAND LAY DOWN BAD JOINT AND REPLACE CHECK CONDUCTIVITY OF ESP AND HEAT TRACE Printed 4/8/2013 10:25:55AM • • , , ,tfi' • , ratiion 3�rmmia :Report ;„,7:g • Common Well Name: MPI -07 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 , End Date: 3/29/2013 X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'11.678 "8 Long: 0149 °34'49.433 "W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 08:30 7.00 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING ESP COMPLETION FROM DERRICK. - FROM 2053' TO 3534' MD - FLUSH THRU PUMP W/ 5 BBLS AT 2000' MD, 1/2 BPM = 2220 PSI - CHECK CONDUCTIVITY OF HEAT TRACE AT 3377' - MAINTAIN CONSTANT HOLE FILL WITH 8.5 PPG SEAWATER - PUW / 75K, SOW / 77K (INCLUDES 40K TOP DRIVE WT) - RWO WTLAND RWO SUPERINTENDENT ATTENDED "MORNING CALL" AND VISITED RIG - HELD PRE -SPUD MEETING FOR MPI -03 DURING MORNING CALL, ONE OPS NOT TO FOLLOW 08:30 - 09:00 0.50 RUNCOM P RUNCMP 1 PJSM, MAKE UP 'NEW FMC 2 7/8" EUE x 11" HANGER M/U 2 7/8" EUE LANDING JOINT W/ FOSV TO FMC HANGER 09:00 - 11:00 2.00 RUNCOM P RUNCMP FMC AND CENTRILIFT REP INSTALL HEAT 'TRACE AND ESP PENETRATORS I I INTO 'NEW TBG HANGER. - TERMINATE HEAT TRACE AND ESP CABLE TO PENETRATORS. - WITH CAPS. - 2 FT SINGLE CHANNEL CANNON =19. 5 FT DUAL CHANNEL CANNON = 370. - 2 FT DUAL CHANNEL CANNON = 70. PROTECTOLIZERS = 4. - FLAT GUARDS = 2. SS BANDS = 4. 4 INCH SINGLE CANNON = 7. HALF CANNON = 1. 1 - RED HEAT TRACE STARTER CLAMP = 1. (USE CAUTION WHEN REMOVING THIS CLAMP) I - 2 FT SPACER CLAMPS = 9. 11:00 - 12:00 1.00 RUNCOM P RUNCMP 1PJSM, LANDING 'NEW 2 -7/8" X 11" TBG HANGER. FMC REP, WSL, TP, CENTRALIFT REP IN ATTENDANCE. - LAND HANGER PER FMC REP - PU WT = 77K, SOW = -751K INCLUDING 40K TOP DRIVE WT. - HANGER SET AT 3559' MD. - RUN IN LOCK DOWN SCREWS PER FMC REP. - LD LANDING JOINT. - FMC REP INSTALL 2 -1/2" TYPE 'H' TWC. 12:00 - 12:30 0.50 WHSUR P RUNCMP PERFORM ROLLING PRESSURE TEST FROM BELOW TWC / HANGER. - 4 BPM ROLLING 500 PSI F/ 10 CHARTED MIN. PASSED. - 64 BBLS PUMPED, 19.5 BBLS BLEED BACK. - TEST FROM ABOVE TWC, 250 / 3500 PSI, 5 MIN, CHARTED. PASSED. I I MAINTAIN CONTINUOUS HOLE FILL AT -10 BPH W/ 8.5# SEAWATER. Printed 4/8/2013 10:25:55AM • • s. ate "..., tion Summar "Report Common Well Name: MPI -07 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2013 End Date: 3/29/2013 X4- 00X6D- E:DRILL (1,380,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1995 12:00:00AM Rig Release: 3/29/2013 Rig Contractor: DOYON DRILLING INC. 1 UWI: / Lat: 070 °26'11.678 "8 Long: 0149 °34'49.4 "W Active datum: ORIG KELLY BUSHING @66.00usft (above Mean Sea Level) Date From - To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 12:30 - 13:00 0.50 BOPSUR P RUNCMP BLOW DOWN ALL SURFACE LINES - DRAIN / VAC OUT BOP STACK. 1 - DRAIN GAS BUSTER. 13:00 - 14:00 1.00 BOPSUR P RUNCMP PJSM, N/D 13 -5/8" 5M BOP - N/D 13 5/8" BOPE - REMOVE FLOW NIPPLE AND TURNBUCKLES. LOTO KOOMY AND REMOVE HOSES. 1- SET BACK BOP STACK MAINTAIN CONTINUOUS HOLE FILL AT -10 - 18 BPH 8.5 PPG BRINE. 1 14:00 - 16:30 2.50 1 WHSUR P RUNCMP 1 PJSM, N/U 2- 9/16" CAMERON PRODUCTION TREE, 'NEW ADAPTER. FMC REP CLEAN AND INSPECT TBG HANGER VOID. - N/U TREE AND ADAPTER PER FMC REP. - PRESSURE TEST ADAPTER VOID - 250 PSI FOR 5 CHARTED MINUTES, PASSED. - 5000 PSI FOR 30 CHARTED MINUTES. PASSED. CENTRILIFT TAKE FINAL READINGS = TESTED GOOD 16:30 - 18:00 1.50 WHSUR P RUNCMP PSJM, PRESSURE TEST 2- 9/16" PRODUCTION !TREE WITH DIESEL. I- 250 / 5000 PSI, BOTH 5 MINUTES CHARTED. r PASSED. WHSUR -- --- - -- - - - -- 18:00 - 21:00 3.00 P RUNCMP M/U DSM LUBRICATOR AND TEST, 250 / 3500 PSI, 5 MIN, CHART - PULL TWC, RE -TEST LUBRICATOR - INSTALL BPV - PERFORM ROLLING TEST FROM BELOW, 4 BPM, 500 PSI, 10 MIN, CHARTED 21:00 - 00:00 3.00 ! WHSUR P RUNCMP PJSM, R/U LITTLE RED SERVICES TO FREEZE PROTECT WELL - PUMP 65 BBLS DEAD CRUDE DOWN IA, 1.2 BPM = 700 PSI, PUMP OFF FINAL PRESSURE ON IA= 450 PSI - PUMP 15 BBLS DEAD CRUDE DOWN TUBING, .5 BPM = 1650 PSI, PUMP OFF FINAL PRESSURE ON TUBING = 180 PSI EQUALIZED FREEZE PROTECT LEVEL AT 2374' MD 1- OFF LOAD AND CLEAN PITS DURING FREEZE PROTECT - RIG CREW PREP FOR RIG MOVE OA =0PSI - 24 HOUR FLUID LOSS = 166 BBLS 8.5 SEAWATER - RELEASED RIG FROM MPI -07 FOR MOVE TO I MPI -03 AT MIDNIGHT, 24:00 HRS, 3-29 -2013 Printed 4/8/2013 10:25:55AM r 1111 Tree: 2 9/16" - 5M FMC MPU 1 - 07 Wellhead: 11" 5M FMC Gen 5 - - / Orig. DF elev. = 64.0' (N 22E) w/ 2 7/8" FMC Tubing Hanger , EUE 0 Orig. GL elev. = 34.5' lift threads, 2.5" CIW H BPV profile RTTo7 "csg,hng.= 28.5'(N22E; 20" 91.1 ppf, H -40, cond. 115' 0 2 7/8" Camco KBMM 133' KOP @ 1450' 0 gas lift mandrel Max. hole angle = 20 deg. 0 f/ 5300' to 5950' $ Hole angle across perfs 0 � • 1 . ,2 7/8" Camco KBMM 3318' 9 5/8 ", 40ppf, L -80 Btrc. 2680' % gas lift mandrel j 2 7/8" HES XN Nipple 3468' g 2.250 no - go ID Two 7" x 21' marker jts. f/ 3348' tp 3351' x 0 II w/ Radioactive marker on top / . Pump 141 -P6 PMSXD 3512' g if 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. Gas Separator GRSFTXAA H6 3528' ( drift ID = 2.347 ", cap. = 0.00592 bpf) % — Tandem Seal Section 3533' GSB3DB UT /LT SB /SB PFSA g Motor KMH 562 Series, 3547 76hp. motor, 1360 v. / 34 amp. 7" 26 ppf, L -80, Btrc. production casing rated to 55 h / 1259 v / 26 Am p 3/37/13 - Re rated drift ID = 6.151 ", cap. = 0.0383 b p f ( p ) PumpMate XT150 w/ 6 fin I 3555' centralizer PumpMate TVD = 3549' - T HES VTL 3720' — — packer. Stimulation Summary — 'OA' Sand - 9/24/96 - 56,300 lbs. _ — HES Safety shear sub 3751' 16/20 Carbolite placed behind pipe. — HES 4" screen(0.012 "ga.) 3802' Job was flush. HES Isolation pkr 3863' 'OB' Sand - 10/03/96 - 98,500 lbs. — — 16/20 Carbolite placed behind pipe. — HES Safety shear sub 3894' — Job was flush. — HES 3.5" screen(0.020 "ga.) 3927' 'N' Sands - 10/05/96 - 92,500 Ibs 11_ — HES VTL packer 3964' proppant behind pipe, of which 40 M — Ibs was 20/40 with the balance being — HES 4" prepacked screen 3992 16/20 tailed in. Job was flush. A 0 HES 7" AWR sump pkr. 4020' wlm Perforation Summary ' Ref log: 11/09/95 GR /CCL/ press. /temp ' Fish 12.46 ft Centraliser SDX4 -am 1 4236' El well file 4236' SIZE SPF INTERVAL (TVD) 'N' Sand \Howco 7" cementer 4.5" 12 3808' - 3826' (3785'- 3803') stage collar 4.5" 12 3839' - 3846' (3816- 3823') 10.2 ppg Stage collar 'OA' Sand plug DrIg. Fluid p 4.5" 12 3933' - 3960' (3911'- 3938') 'OB' Sand 4.5" 12 3993' - 4010' (3970'- 3987') Schl. 43C Ultra Pack, 24 gm. charges (EHD = 0.70 ", TTP = 788 ") Orig. PBTD (casing float) 6885' 7" casing shoe 7425' DATE REV. BY COMMENTS MILNE POINT UNIT 10/11/95 JBF Drill & Case by N 22E WELL I - 07 10/9/96 M. Linder Initial completion Nabors 4 -ES API NO: 50 -029 -22602 9/2/08 L. Hulme Replace ESP - Nabors 3S 3/31/13 B. Kruskie Replace ESP - Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 FEB 1 7 2012 December 30, 2011 Mr. Tom Maunder L q 5- F 5 Alaska Oil and Gas Conservation Commission 1 333 West 7 Avenue C Y t- P ` Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Q� Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI-02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA - 4." NV1-07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI-10 2001090 50029229660000 Open Flutes - Treated NA NA MPI-11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI-16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI-17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI-19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 • STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS ~~~ /O~OS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-151 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22602-00-00 7. KB Elevation (ft): 66, 9. Well Name and Number: MPI-07 8. Property Designation: 10. Field /Pool(s): 025906 ~ Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 7444 - feet true vertical 7305. feet Plugs (measured) 4236' Effective depth: measured 6885 feet Junk (measured) None true vertical 6766 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 2649' 9-5/8" 2680' 2663' 5750 3090 Intermediate Production 7397' 7" 7425' 7287' 7240 5410 Liner Perforation Depth MD (ft): 3808' - 4010' Perforation Depth TVD (tt): 3784' - 3986' 2-7/8", 6.5# L-80 3577' Tubing Size (size, grade, and measured depth): ~eolation pakcer, HES 3720', 3863, Packers and SSSV (type and measured depth): p m " a e p pa nd a ES 7 AWR Su ack r 3964' & 4020' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run _ 15. Well Class after work: ^ Explorato ®Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 584-471 N/A Printe a ra Stewman Title Drilling Technologist _ F ii Preparod By Name/Nur~er. Si ture " Phone 564-4750 Date 1~ ~~-O~j Sondra Stewman 584-4750 Form 10-404 Revised 04/2006 ,,~~ ~ a ~-.,, ~ ~ti, ~ t` ~ ;.:., ~ ~~;:~9 ~~~" , ` ~ ~ ~~j0~ Submit Original Only ~! ~.. .~---~nlas Tree: 2 9/16" - 5M FMC ~ MPU I - 07 Wellhead: 11 " 5M FMC Gen 5 Orig. DF elev. = 64.0' (N 22E) w/ 2 7/8" FMC Tubing Hanger , EUE Orig. GL elev. = 34.5' lift threads, 2.5" CIW H BPV profile RT To 7" csg, hng. = 28.5' (N 22E 20" 91.1 ppf, H-40, cond. 115' °' 2 7/8 Camco KBMM-2 143' KOP Cc3 1450' gas lift mandrel Max. hole angle = 20 deg. f/ 5300' to 5950' Hole angle across perfs 2 7/8" Camco KBMM-2 3327' 9 5/8", 40ppf, L-80 Btrc. 2680' gas lift mandrel 2 7/8" HES XN Nipple 3480' 2.250 no-go ID Two 7" x 21' marker jts. f/ 3348' tp 3351' w/ Radioactive marker on top Pump 127-P6 PMSXD 1:7 3533' 2 7/8" 6.5 ppf, L-80, 8 rd EU E tbg.. Gas Separator cRSFTx AR Hs 3547' ( drift ID = 2.347", cap. = 0.00592 bpf ) Tandem Seal Section 3552' GS63DB UT~1T SB/SB PFSA Motor KMH 562 Series, 3566' 7" 26 ppf, L-80, Btrc. production casing 57 hp. motor, 1315 v. / 26 amp. ( drift ID = 6.151 ", cap. = 0.0383 bpf) PumpMate XTO wl 6 fin 3573' centralizer PumpMate TVD = 3549' HES VTL 3720' packer. Stimulation Summary 'OA' Sand - 9/24/96 - 56,300 lbs. 16/20 Carbolite placed behind pipe. Job was flush. 'OB' Sand- 10/03/96 - 98,500 lbs. 16/20 Carbolite placed behind pipe. Job was flush. 'N' Sands - 10/05/96 - 92,500 Ibs proppant behind pipe, of which 40 M Ibs was 20/40 with the balance being 16/20 tailed in. Job was flush. Perforation Summary Ref loa: 11/09/95 GR/CCL/ press./temp SIZE SPF INTERVAL (TVD) 'N' Sand 4.5" 12 3808' - 3826' (3785'-3803') 4.5" 12 3839' - 3846' (3816'-3823') 10.2 ppg 'oA' Sand " ' ' ' ' Drlg. Fluid 4.5 12 3933 - 3960 (3911 -3938 ) 'OB' Sand 4.5" 12 3993' - 4010' (3970'-3987') HES Safety shear sub 3751' HES 4" screen(0.012"ga.) 3802' HES Isolation pkr 3863' HES Safety shear sub 3894' HES 3.5" screen(0.020"ga.) 3927' HES VTL packer 3964' HES 4" prepacked screen 3992 I HES 7" AWR sump pkr. 4020' wlm I Howco 7" cementer 4236' \ stage collar Stage collar plug Schl. 43C Ultra Pack, 24 gm. charges (EHD = 0.70", TTP = 7.88") Orig. PBTD (casing float) 6885' 7" casing shoe 7425' DATE REV. BY COMMENTS 10/11/95 JBF Drill & Case by N 22E 10/9/96 M. Linder Initial completion Nabors 4-ES 9/2/08 L. Hulme Replace ESP -Nabors 3S MILNE POINT UNIT WELL I - 07 API NO: 50-029-22602 Page 1 of 1 Well: MPI-07 • Well History Well Date Summary MPI-07 8/17/2008 Flush production line w/ 2 bbls 60/40 meth, 3 bbls diesel, & 2 bbls 60/40 meth for de-mobe & RWO. Flush test line w/ 2 bbls 60/40 meth, 3 bbls diesel, & 2 bbls 60/40 meth for de-mobe. MPI-07 8/19/2008 (Displace TBG / Infectivity test) T/I/0= 1350/1320/120 Pump 31 bbls diesel down TBG to displace. Established an infectivity rate ~ .62 bpm C~3 2550 Psi. FWHP= 1400/1440/300 Valve position= swab- closed /wing-closed /ssv=closed /master-closed / IA and oa are open to gauges. MPI-07 8/20/2008 (DisplaceTBG) T/I/0= 1250/1260/120 Pump 20 bbls dead crude down TBG followed by 12 bbls diesel to verify circ holes in TBG. = 1.9 BPM @ 950 PSI FWHP= 300.1300.190 . Valve position =swab-closed / wing-closed /ssv-closed /master-closed / IA and OA open to gauges. MPI-07 8/20/2008 PRE-RWO *** ARRIV ON LOC WELL S/I *** DMY OFF MANDREL C~3 117' SLM. PUNCH HOLE @ 3,554' AND 3,555' SLM IN 10' PUP JT. ABOVE ESP. CIRCULATION PROVEN BY LR . MPI-07 8/29/2008 ey set The Well Support Techs rigged up and removed the wellhouse, flowlines and the foundation. Th y the BPV after slicklines work was completed. NOTE: The BPV was left in and the well is ready for RWO. MPI-07 8/29/2008 ***ARRIV ON LOC WELL S/I *** RWO BHP RIH W/ 2.12 CEN SOFT SET SPARTEK GAUGES MADE GRADIENT STOP (~ 3000 FT FOR 15 MIN MADE BHS ~ 3559 FOR THREE HOURS ***CONTINUE ON 9/30/08*** MPI-07 8/30/2008 ***CONTINUE FROM 8/29/08*** RWO/BHPS*** SET BPV. TURN WELL OVER TO DSO. JOB COMPLETED*** MPI-07 9/1/2008 PULLED AND RESET DGLV AND SET DPSOV IN MANDRELS FOR 4ES. MANDREL WITH DPSOV FLAGGED AND TAGGED. MPI-07 9/2/2008 T/I/O=0/0/0 Freeze Protect (Post RWO) Pumped 65 bbls Dead Crude down IA. Pumped 15 bbls Dead Crude down tubing .FWHP= 0/200/0 Master, IA, OA, swab, SSV, and Wing closed. Nabors 4es still on well. MPI-07 9/9/2008 The Well Support Techs rigged up and pulled the BPV and leak tested the flowlines to 1150 psi. MPI-07 9/18/2008 (Freeze protect TBG) T/I/0= 250/320/0 Pump 15 bbls diesel down TBG To freeze protect well. FWHP= 800/360/0 (swab-closed /wing-closed /ssv-closed /master-open / IA and OA open to gauges. ) Print Date: 9/30/2008 Page 1 of 1 • BP EXPLORATION Operations Summary Report Legal Well Name: MPI-07 Common Well Name: MPI-07 Event Name: WORKOVER Start: 9/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/2/2008 Rig Name: NABORS 4ES Rig Number: i Page 1 of 3 Spud Date: 9/29/1995 End: 9/2/2008 Date 'From - To Hours Task Code NPT Phase Description of Operations _-- _ _ - - 8/31/2008 ~ 02:00 - 04:00 2.00 MOB P PRE PJSM on scoping and laying down derrick. Scope derrick down. RU & lay derrick down. Prep for rig move. Clean up around location. 04:00 - 05:00 1.00 MOB P PRE Wait on trucks that were delayed by D-16 rig move and crane move from MPU Texaco Pad. 05:00 - 08:30 3.50 MOB P PRE Move rig compenents and equipment from MPU G-18 to MPU 1-07. 08:30 - 09:00 0.50 RIGU P PRE Spot sub, pipe shed and pits. 09:00 - 09:30 0.50 RIGU P PRE PJSM -raise and scope derrick. 09:30 - 11:00 1.50 RIGU P PRE Raise and scope derrick. Rig up circulating lines from tree to blowdown tank. 11:00 - 11:30 0.50 RIGU P PRE Pre-spud meeting to review RWO scope and current plan forward. 11:30 - 13:00 1.50 WHSUR P DECOMP Make up lubricator to swab valve. P/T lubricator. MPU W Support pulled BPV. L/D lubricator. P/T onboard circulating Ines to 35 -psi an o oar ine to blowdown tank to 120-psi w/rig air. Take on fluid to pits. 12:30 - 14:00 1.50 KILL P DECOMP SITP = 850-psi, IAP = 1300-psi, OAP = 120-psi. Bleed tubing and IA simultaneously to blowdown tank through Super Choke. 14:00 - 16:00 2.00 KILL P DECOMP Bullheaded 25-Bbls. 8.4-ppg produced water down tubing ~ 5.0-BPM ~ 65-psi. Bullheaded 185-Bbls. 8.4-ppg produced water down IA ~ 5.0-BPM ~ 880-psi. Bullheaded 25-Bbls. 8.4-ppg produced water down tubing ~ 3.0-BPM ~ 880-psi. Shut in well and monitored for 30-minutes. Pressure after 30-minutes 500-psi. Bled pressure down to 0-psi with well flowing slightly. Shut well in to monitor. 16:00 - 17:00 1.00 KILL P DECOMP Weekly HSE meeting. Reviewed recent safety incidents on other rig operations. 17:00 - 17:45 0.75 KILL P DECOMP - - - i with well flowin sli htl . Circulate well long way ~ 4.0-BPM ~ 750-psi taking returns to blowdown tank. Shut in well and monitor. 17:45 - 19:00 1.25 KILL P DECOMP Monitor well. Tubing pressure drops to 10-psi. Monitor Tbg and IA pressure together and they equalize at 10-psi. Bleed off 10-psi and monitor well. Well i~s_static. Hang ESP /heat trace spooling sheave and install handling sleeve. 19:00 - 21:30 2.50 WHSUR P DECOMP ch T-bar in TWC. Test TWC from above to 3500-psi for 10-charted minutes -good test. Test TWC from. 10-minutes. Pumped a total of 59-Bbls. Caught fluid with 3.5-Bbls pumped indicating fluid level at -116'. When done pumping, bleed IA pressure to 0-psi and get 23-Bbls back. Monitor well when pressure bled off -static. 21:30 - 22:30 1.00 WHSUR P DECOMP PJSM on ND tree. FMC tech bleed pressure from tubing hanger void. ND tree. Monitor IA for flow while ND. FMC tech inspect tbg hanger threads - MU with 8-1/2 turns and in good condition. 22:30 - 00:00 1.50 BOPSU P DECOMP PJSM on NU BOP stack and lines. NU BOP stack and attach choke and kill lines. 9/1/2008 00:00 - 01:00 1.00 BOPSU P DECOMP Weekly safety meeting with Smith crew. Discuss recent incidents on rig and in ADW, 8 Golden Rules, driving safety and operational concerns. 01:00 - 01:30 0.50 BOPSU P DECOMP RU to test BOPs. Fill stack and lines. Function blind rams. PU 2-7/8" test jt. Printed: 9/15/2008 3:34:11 PM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPI-07 Common Well Name: MPI-07 Spud Date: 9/29/1995 Event Name: WORKOVER Start: 9/2/2008 End: 9/2/2008 Contractor Name: NABOBS ALASKA DRILLING i Rig Release: 9/2/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code' NPT Phase Description of Operations 9/1/2008 01:30 - 05:30 4.00 BOPSU P DECOMP Test BOPE per BP and AOGCC procedures. Low pressure test to 2 -psi, High pressure test to 3500-psi. Hold and chart all tests for 5-minutes. All tests witnessed by BP WSL and Nabors TP. AOGCC rep Chuck Scheve waived witness of BOP test. 05:30 - 06:30 1.00 BOPSU P DECOMP RU MPU Well Support lubricator and pressure test to 500-psi. Good Test. Pull TWC. RD MPU Well Support lubricator. 06:30 - 07:00 0.50 PULL P DECOMP - ewewe pu ing ESP with heat trace cable procedure. 07:00 - 08:00 1.00 PULL P DECOMP MU 2-7/8" EUE 8RD. landing joint with closed TIW valve to hanger top thread. FMC BOLDS. Unland and hoist hanger to P/U wt. = 40K. Break out and lay Ian ing iomt an tubing hanger. 08:00 - 08:30 0.50 PULL DECOMP Circulate bottoms up ~ 4.0-BPM C~? 570-psi. Small a_ m_ oust of 08:30 - 15:00 6.50 PULL P DECOMP POH w/ESP completion and cable and heat trace cable over dual cable sheave wheel. Standing back 2-7/8" tubing in . Recovered 111 jts. 2-7/8" EUE 8RD tbg., 1 2-7/8" x 1" GLM, 36 short flat guards, 312 long flat guards, 1270 pre-formed bands, 25 LaSalle clamps and 3 protectorlizers. 15:00 - 16:30 1.50 PULL P DECOMP Centrilift inspect and lay down ESP BHA. Lay down ESP cable containment trunk. 16:30 - 17:30 1.00 PULL P DECOMP Clear and clean rig floor. 17:30 - 18:00 0.50 BUNCO RUNCMP Pre-tour safety meeting with night crew. Discussed upcoming operations and Working at Heights Golden Rule. 18:00 - 18:30 0.50 BUNCO RUNCMP RU to run 2-7/8" ESP completion. Pull ESP cable and motor lead extension over ESP sheave. 18:30 - 21:30 3.00 BUNCO RUNCMP PU new ESP pump/ seal /motor assembly. Connect Motor lead extension and ESP cable to pump and check function - good test. Centrilift tech service ESP assembly. Install 2-flat guards and 4-Protectrolizers. RIH with ESP. 21:30 - 00:00 2.50 BUNCO RUNCMP RIH with 2-7/8" ESP completion. Run 108-jts of 2-7/8" 6.5# L-80 EUE 8rd tbg, 1-GLM with Dummy valve, 1-GLM with DPSOV, 1-XN nipple, 62-LaSalle clamps and equipment noted above. Centrilift hand check ESP cable function with 5-stds in the hole and at 2000'. Both tests good. MU 2-7/8" EUE 8rd to optimum torque of 2300-Ibs/ft. Utilize Best-O-Life 2000 thread compound on all connections. Install LaSalle clamps on the first 9-jts run and then on every second jt except the tubing hanger pup jt. 9/2/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Continue to RIH with 2-7/8' ESP completion. RIH with 2-7/8" ESP completion. Run 108-jts of 2-718" 6.5# L-80 EUE 8rd tbg, 1-GLM with Dummy valve, 1-GLM with DPSOV, 1-XN nipple, 62-LaSalle clamps, 4-Protectrolizers and 2-Flat guards.. Centrilift hand check ESP cable function at 2000' -good test. Pump thru completion at 2000' to flush pump. MU 2-7/8" EUE 8rd to optimum torque of 2300-Ibs/ft. Utilize Best-O-Life 2000 thread compound on all connections. Install LaSalle clamps on the first 9-jts run and then on every second jt except the tubing hanger pup jt. 01:00 - 01:30 0.50 BUNCO RUNCMP PU tbg hanger and landing jt and MU to tubing string. FMC tech install ESP penetrator and blank penetrator into hanger. 01:30 - 03:00 1.50 BUNCO RUNCMP Centrilift tech make and test final ESP cable splice. Good test. Attach cable to hanger and test again. Good test. Printed: 9/15/2008 3:34:11 PM Printed: 9/75/2008 3:34:11 PM ANNULAR INJECTION DATA ENTRY SCREEN Asset ~ilo.e. .......................................... Rig Name J~.~tb.Ql'.~..~;~F,, ............................. Inj Well Name M..P..[:.QT.. ....................................... Sur Csg Dep ~.6.1~.0. ................ Cumulative Data Permit Start ........ .~/.P,,~l../.~.~ ........ Legal Desc ~.~.:~.9.'.[~.L~.9.0.6.'.~..E~..~.f~.~..:~I.,.T.~I.~.~,.B.~.Q~ .................................. Research Permit End ........1.~.~.1/.~1.5. ....... Rig Completion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ......... .~.~.~ ................... t,~.o. .................... ~.o. ................................................................................... ~.o. ........................ 7..o. ............ Daily Data iWei Injeclion Drlg Mud ~ Flu~ Fluids ~ Protecl~. Total Rate Pms~re Status UPI-07 10/08/95 150 60 210 '0'~ ............................. :i"§'{~'"~'~i:'"~'h~J"'~'~ ~'~'i:~; ............... ' ................... -- MPI-05i 10/14/95 240 20 260 MpI-05i 10/15/95 1,040 100 ~ 70 1,210 ,., -- - [ ~.!.C' '~ -'~. '! t~ 8 -- -'~ -- ,"~,{~.':!,,",~ 0i.~ ,,: L.~I.,, ~'"" . ' '~' ~' ~,~O~lo. ["'~ "" i:"" ,, ......................................................................................................................................................................................................................................................................................................................... ...................................................................................................................................................................................................................................................................................................... : ........................................ ............................................................................................................... ~ .......................................................................................................................................... :. ..................................................................................................................................................................................................................................................................................................................... .............................................................................................................................................................. ................................................................................................................................................................................................. ...................................................... ~ .................................................. ~ ....................................................................................................................................................................................................... ............................................... i ................................................ ' [ _ hared ,, .u ervices 'Drilling 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 Re: Annular Disposal Information Request RECEIVED DEC 1998 Dear Ms. Mahan: Naska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/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,/_5-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · - The wells listed above in italics were permitted but not used for annular disposal. * The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry '- Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide'-you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: , ,.Annular Disposal Letter ', 12/14/98 ! · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh 4/3 - 3%oo ~4 ,=~ · ~me ~o~t wells F-06, H-05, H-06, J-13, L-24 - ~ s-o? ~ · PBU wells-18-30, 18-31, 14~,~-43, ~,34, E-36, G-~A, ~d S-33- · ~dividu~ logs ~e provided to ~ou fo~ t~ese ~ogs as w~l. ~'zo ioZ. · 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 Naska 0ii & 6as Cons. Commission Anchoraoje f, har(:.d SerVice Dlilling nn~ar Injection Volumes Jly 25, 1995 until December 1998 umulative Report Surface Casing I Inj Well · Depth dicott Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End SlatUS i/on 15 1-19/I;18 5000 Sec. 36, T12N, R16E 8,960 7,848 992 120 12/5/95 12/5/96 Open ion 15 1-23/O-15 4246 2020'FNL, 2087'FEW, SEC.36.T12N.R16E 32,084 30.604 1.160 200 120 9/30/95 12/31/95 Open /on 15 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9.729 150 8/31/95 12/31/95 Broached /on 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open ~on 15 2-40/S-22 4531 2020'FNL, 2289'FEL, Sec 36,T12N. R16E 31,195 29,952 1,063 120 60 7/25/95 12/31/95 Open A ton 14 15-47 3515 3648'NSL, 4956'WEL, Sec 22,T11N R14E 3,002 903 2 009 90 11/7/95 12/31/95 Open ,on 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 ,on 14 DS 15-48 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open 'on 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open .on 9 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open 'on 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 on 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 on 9 18-33 4140 3690'NSL .56'WEL Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open ors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open o..r.~._l..~.E._ ..................... !.~.:~.~. .................................. ..37..~.~ .................................. 2..?:.N....S.L..:.!~.!_7'_W_E..L..,.._.S...e.c_..9_,..T I__O_N.,._.R.?_~ .......................... .3:.9.7A ............................... ..2.:...3..!..9- .............................. !:~?.~ .............................. 120 8/17~95 12/3U95 Open Ioration ' 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed le -_- MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 · Open Open ~rs 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 ~rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open ~rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 ,DEC 1 1998 ~chorago :)har~d SerVice Drilling ~.nn'~iar Injection Volumes July 25, 199,~ until December 1998 ;umulative Report lig Inj Well labors 22E MPF-06 labors 22E MPF-14 abors 22E MPF-70 abors 22E MPH-05 Surface Casing Depth 8766 6690 7919 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Lega! Desc Cum Total & Ctgs Wash Fluids Fluids Freeze .... Ereeze Start End. Status Se(~.0.6,T13N, R10E 1,927 1,731. . 196 1/25/96 1/25/97 Open Sec'06,T13N, R10E UM 18,717 17,107 1,270 340' 6/3/96 6/3/97 Open 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 190 56 6/17/96 6/17/97 Open 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open abors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open abors 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31195 Open 10/17/95 abors 22E MPJ-13 ' 2835 2319'NSL 3179'WEL Sec 28 T13N R10E 14 127 13 292 645 60 130 12/31/95 Open abors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 O)en abors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 . 1/25/96 1/25/97 O)en ab.~ . ~.~ ................ Hk~a~:~r~ .................... ~.~ ........................ ~.~.~...Q6...,..~.!:~.N..,.....i~.!0E UM . 6,536 6,466 . 70 12/12/95 12/12/96 O)en abors 27E MPF-25 3405 1857'NSL 2696'WEL sec 6 T13N R10E ' 9 897 9 357 250 · 225 65 12/26/95 12/26/96 O abors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 O3en ~bors 27E MPF-38 8561 1994'NSL 2731'WEL Sec 6 T13N R10E 9 232 9 157 75 12/6/95 12/31/95 O~en ~bors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' O3en ~bors 27E MPF-53 6750 2028'NSL. 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 O~en 75 8/31/95 12/31/95 O ~bors 27E MPF-61 6585 2077'NSL 526'WEL Sec 31 T14N, R10E 5 732 5,657 3en 70 10/13/95 12/31/95 O ~bors 27E MPF-62 6059 2141'NSL. 2627'WEL, Sec 6 T13N R10E 386 316 3eh ~bors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 75 8/31/95 12/31/95 O3en ~bors 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 O3en ~bors 27E MP/-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 O3en OA E F-33 3570 3332'NsL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open E 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 ~yon 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 4/10/97 Open ~yon 9 D-33 3222 2965' HSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open ~bors 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 Se'i~ice Dr..illing Annl~i~'r injection Volumes July 25, 1995~ until December 1998 Cumulative Report Sudace Casing :{ig Inj Well Depth ~labors 28E B-33 3504' ~abors 28E E-34 3664 , ~abors 28E E-36 3648 , .. Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze 969'SNL, 1898'EWL, Sec 31, TllN, R14E 3,974 2,842 857' 195 80 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 1706'SNL, 822'WEL, Sec 6,T11N, R 14E 9,271 4 417 1,293 3,096 365 100 Disposal Period Annulus Start End S.t~tus 5/1/96 12/31/96 Broached 8/23/95 12/31/95 Open 7/25/95 12/31/95 Open ~abors 28E E-37' 3810 3391'NSL 881'WEL SeC 6 T11N R14E 4 695 4 241 374 80 9/16/95 12/31/95 Open ........... . ........................................................................... -_,._. ,. ......... ,_ ....! ........ · .... . .... -,. ................................. ~ ........................................................................................... labors 28E E-39 3638 3358'NSL, 501'WEL,' Sec 6,.T11N, R14E 2,250 928 . 220 1,022 80 8/28/95 12/31/95 Open labors 28E G-O4A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 ' 10/20/95 12/31/95 Open labors 28E G-21 3509 2911'NSL 2368'WEL Sec 12 T11N R14E 11 430 3 956 3 072 4 270 70 '62 9/8/95 12/31/95 Open labors 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open labors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open labors 28E S-41 3331 4152' NSL 4504' WEL Sec 35 T12N 8 062 4,159 2 034 1,754 115 2/8/96 2/8/97 Open labors2ES H-35 3157 4535'NSL 1266'WEL Sec21 T11N R13E 4860 3725 555 480 20 80 10/26/95 12/31/95 Open rabors 2ES H-36 3550 4478'NSL 1265'WEL Sec 21 T11N R13E 1 452 857 100 410 85 10/26/95 12/31/95 Open !..........~ ................................. ~ ............................... !. ...................... !. ............................................................ .'. ...................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................... Page 3 h sred o loes 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 · .: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner DATE: April 22, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Unit J'& I Pads Sunday Ar)ril 22, 200!: I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the welihouses were very clean and the equipment appeared to be in excellent condition. Summary: i witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11'>wells 22 components 0 failures MPU I Pad 6wellS 12 components 0 failures 23 wellhouse inspeCtions Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: 'Chuck ~ci~eve ' Date: Field/Unk/Pad: Milne Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE I-O1 1~00900 ....... 1-02 1900910 ' 140 100 " 95 'P ' 'P ........ OiL 1-03 1900920 140 100 95 P P OIL 1-04 1900930 140 100 95 P P OIL 1-06 1971950 140 100 95 P P oIL 1-07 19515i0 ~40 'io6 " 95 ' e 'P OIL 1-08 1971920 "'i40 100 95 P e ' ' iDIL Wells: ~ 6 Components: 12 Failures: 0 Failure Rate: 0.00% ~9o oar Remarks: I I . I I I ,~, I I, J I I II I, , il , I I , i I I , I , , II , I I I RJF 1/16/01 Page 1 of 1 SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Huime AOGCC Rep: ..... Cl~u~k SCheve' Submitted By: Chuck Scheve Date: Field/Unit~ad: Milne Point / MPU / J Pad Separator psi: LPS ...... 14~) "'HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date o~, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE , ,, J-01A 1991110 140 100 95 P P OIL J-03 1900970 140 100 95 P P OIL J-'04 ' 1900980 '140 100 95' P P .... OIL J-05 1910950 140 100 95 p p OIL ~06 1940950 140 100 125' "P P ....... OIL J2~7 19i0970 140'' ' 100~ 95 P' P OIL ,, , J-08A 1991170 140 100 95 P P oIL J-09A ' 1991140 ..... 140' ' 100 110~ P P OIL J-10 1941100 140 100 95 P P OIL J-11 1941140 J-12' 19~11801 ........ J. 18' ' 1972200 ....... 319A 1951700 J'20 19~2150 "' ~21 1972000! 140 lOOi 951 P P OIL J-22 ..... 1981240 .... 140j 100i 9~ P ' P ' OIL ~23 2001200 , Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% [3 90 var Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU J Pad 4-22-01 CS PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 95-151 CDR ~;m'~2620 - 7390 Page: 1 Date: 09/15/98 RUN RECVD FINAL 08/08/96 95-151 CDR - TVD ~2616-7250 95-151 CDN ~670-7330 95-151 CDN - TVD ~'~2650-7200 95-151 7367 ~CDR/CDN - MWD , 95-151 PERF/PACKER ~3300-4199 95-151 PERF ~3350-3840 95-151 SRXTY CALC 10-407 FINAL 08/08/96 FINAL 08/08/96 FINAL 08/08/96 1 08/08/96 FINAL 10/21/96 FINAL 10/21/96 ~ SCHLUM 112-7444 06/30/97 DAILY WELL OPS ~ q/~..~/e]7 TO I~/ C~/~/ Are dry ditch samples required? yes ~n~And received? Was the well cored? yes ~A~alysis & description received? yes~- Are well tests required? yes ~o?Received? Well is in compliance Initial COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 95-151 95-170 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22602 4. Location of well at surface ,,,~,,,,,,,~,,.-,~, 9. Unit or Lease Name 2339' NSL, 3906' WEL, SEC. 33, T13N, R10E, UM ~-'J~-~-' ............ _~ ; ,~0,';~.~L?' i0. ,,~~ Milne Point Unit At top of productive interval ~. ~'r~!-~ ,~,~ ~i 10. WellNumber 2572' NSL, 3733' WEL, SEC. 33, T13N, R10E, UM ~ .~_O_ ~'~i___"_ ,'~o ' MPI-07 Attotal depth ! ;,~.~r.,~..-; i 11. Field and Pool 2849' NSL, 2992' WEL, SEC. 33, T13N, R10E, UM ~~-_. i Milne Point Unit / Schrader Bluff i5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Des-i~t~0~ ~tnd Serial No. KBE = 63'I ADL 025906 12. Date Spudded9/29/95 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband115' Water depth' if °fish°re 116' N°' °f C°mpleti°nsl 0/5/95 10/8/96 N/A MSL, One 17. Total Depth (MD+TVD)118. Plug Back Depth ,MD+TVD)I19. Directional Survey 120. Depth where SSSV sot 121. Thickness of Permafrost 7444 7307 FTI 6885 6767 FTI [~Yes [] No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, CDR, GR/CCL, GR/JB 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 2680' 12-1/4" 550 sx PF 'E', 250 sx 'G', 140 sx PF 'E' 7" 26# L-80 28' 7425' 8-1/2" 1490 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) '~' "" ^N/A 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 3605' MD TVD MD TVD ~ ~.~, ~ .... . 3808'-3826' 3784'-3802' 3839'-3846' 3815'-3822' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 3933'-3960' 3909'-3936' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3993'-4010' 3969'-3986' Freeze protect with 75 bbls diesel 4236' 7" ES Cementer Stage Collar Plug (10/95) Frac Packs See Attachment 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) January 13, 1997I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, ~pparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. ,,, (subsea) 'NA' Sands/SBF2 3800' 3710' 'NC' Sands/SBE4 3843' 3753' 'OA' Sands/TSBD 3937' 3847' 'OB' Sands/TSBB 3996' 3906' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is trt~e and c~rrect to the best of my knowledge Signed ~'~4 ._~' /3.¢~2.-~-'¢I Title Senior Drilling Engineer ///~ /'~:i Tim Schofield ~'~ Date -~ /-¢ 7 / / MPI-07~'~_//95-151 95-170 Prepared By Name~Number' Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. · .... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments· ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ~, ~'~. i! "~.¢ ~'_ dtl[",] 50 997 ~.~a-s~a.Oil .& Gas Cons, 6omi'Cs,s?,* ' ~nchora~¢ Form 10-407 Rev. 07-01-80 ~/~' F .~/~ B/~EXPLORATION - ENGINEERING DATA P.1 sUBJECT BASED ON ENGINEER DEPT. APP'VL GUDCE'F/AFE NO. DATE FILE NO, - _ ,, i i i 3,t37.1 (3194) BP EX PLORATION ENGINEERING DAI'A SUBJECT ~,"~gED ON ENGINEER DEPT. APP'VL DATE .~O/F,~;~_~"' FILE NO. OF~ -~ 7'0 c ~ $/oo',~& k,....-, ," i:D OCT 1 0 1995 AlaSka Oil & Gas Cons. Commission Anchorage AK 2337-1 ,~XPLORATION .,P Exploration (Alaska) Ina. PO Box 196612 Anchorage, Alaska 99519-6612 TELECOPY COMMUNICATIONS CENTER MESSAGE# 'Company: Location: Fax # Confirm # FROM: Name & Ext.: Department: Mail Stop: NOTES: PAGES TO FOLLOW (Do Not Include Cover Sheet) OCT 1 0 1995 AlaSka Oil & Gas Cons. Commission Anchorage SECURITY CLASSIFICATION PRIVATE SECRET CONFIDENTIAL Telecopy # Confirm # For Communications Center Use Only Time In Time Sent Time Confirmed Confirmed By Operator WELL NAME' MPI-07 26. (10-407) Attachment - Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Frac pac, 3720'-3802' Frac pac, 3720'-3802' Frac pack, 3863'-3927' Frac pack, 3964'-4020' Amount & Kind of Material Used 40000# 20/40 Carbolite behind pipe 52500# 16/20 Carbolite behind pipe (tailed in) 98500# 16/20 Carbolite behind pipe 56300# 16/20 Carbolite behind pipe ANNULAR INJECTION DATA ENTRY SCREEN Asset .l~lilD.e. .......................................... Rig Name ~l.~b.9.r.~..~;~E ............................. Inj Well Name ~...P..[:.Q.7. ....................................... Sur Csg Dep :~.6.6.Q. ................ Cumulative Data Legal Desc ~.3.3.9.'.bI.~.I~,..3.9.0.6'.W.E,L,..~;.e.C..3.3.,.TJ.3.H,.B.1.QE .................................. Research Permit End ........1.~.;~.1/~.5. ....... Permit Start .........9~.~..1../.9.5. ........ ............................... Rig Completion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ......... .1,,6.8.0 ................... '}., ?-,,6.0. .................... 2~.0. ................................................................................... 6.Q ........................ 7.Q ............ Daily Data M PI-07 10/08/95 150 60 210 M Pl-05i 10/14/95 240 20 260 M Pl-05i 10/15/95 1,040 ! 1 O0 70 1,210 \ __ Open 1995 Year End Summary SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPI-07 Rig Name: N-4ES AFE: 330181 Accept Date: 09/22/96 Spud Date: . Release Date: 10/08/96 Sept 22 1996 MIRU. Sept 23 1996 Move rig over MPI-07, berm herculite & trim. Raise derrick & scope up. Check well for pressure-no pressure, take on brine. Rig accepted 09/22/96 @ 1100 hrs. ND CIW tree & FMC adapter spool, pull tubing hanger, set test plug. NU DSA, NU BOP stack. RU lines, test BOPE: all rams, lines & valves. Test Hydril. Test TIW, IBOP, upper & lower kelly valves - all ok. Install wear bushing. Finish load pipe shed with tubing workstring, drift & strap. MU BHA, TIH picking up tubing to 2100'. Circ out diesel freeze protect to outside tank. Finish TIH with tubing to PBTD @ 4229' (4ES RKB). Pump casing wash. Cont circ brine with MI filter unit. Sept 24 1996 Cont circ & filter completion fluid with MI unit. Fluid clean of solids, but discolored from rust. LD tubing, POOH stand back 41 stands. Close blind rams, test casing-ok. ND bell nipple, NU lubricator flange to Hydril. RU Schlumberger, test lubricator. Perforate 4010'-3993' and 3960'-3933' with 4-1/2" Ultra Pack Guns, 12 spf. No fluid loss to formation, all shots fired, correlated to GR/CCL log. RIH with GR/JB to WL PBTD at 4220' - small amount of gun debris in first run make second GR/JB run. Second run clean. MU Halliburton AWR sump packer, RIH set pump packer at 4017'. POOH, RD Schlumberger. ND lubricator flange, NU bell nipple. MU Halliburton Dual Frac-Pack assembly. TIH with Frac pac assy on 3-1/2" workstring. Page 1 Sept 25 1996 Cont TIH with Frac pac assy, tag sump packer at 4022'. Space out & install TIW valve one stand below rotary table. Drop 2" ball & set top packer with 3200 psi. Reverse out ball, pressure up & set middle isolation packer at 3965' - top packer at 3856'. Finish rigging up BJ equipment, test line. Pickle tubing string. Reverse out to slop tank. Perform data frac on bottom zone & perform step rate test. Frac OB zone with 16/20 Carbolite in 60# gel system, 56000# sand behind pipe. Attempt to reverse out with rig pump, could not reverse, pressure up to 3500 psi, bleed off pressure, change over to BJ below pipe rams, BJ started fluid moving at 1600 psi. Change back to rig pump, reverse out, attempt to set down to stress pack, tool string difficult to move down-void stress test. RD BJ frac valve, RU 2" hole, pull one stand to TIW, close TIW & set back stand. Circ & attempt to verify location of frac tool, seals on tool not holding, can not verify position. Tools need redressing. RD surface lines, fluid out of balance. Circ tubing volume to balance fluid. Attempt POOH to redress tool string, LD one single, pulling weight on second jr. Will not go back down. Rev circ attempt to free pipe-no success. Work string to 85K-stuck. Circ long way attempt free pipe-stuck. Pull to 160K, no success, no movement in string. Wait on Atlas WL for chemical cutter. RU prepare to cut tubing one joint above tool string. Bottom tool string at 3942'. Top tool string at 3714'. Sept 26 1996 Cont wait on Atlas chemical cutter. RU Atlas, RIH with 2.625" chemical cutter, cut tubing at 3682'. (5' below collar on bottom joint of 3-1/2" tubing before frac pac tool string) POOH, RD Atlas. POOH with 3-1/2" tubing. RU to run DP. MU fishing BHA #1. TIH, PU 3-1/2" 'E' DP, tag fish at 3683'. Latch fish, attempt to beat fish down hole with bumper sub & drill collar. No movement. Attempt to jar upward, oil jars not working. Release overshot. POOH for new set jars. Change out oil jars, change grapple. TIH with fishing assy. Latch fish, jar on fish. Jar fish free. POOH with fish. LD fishing tool & fish. Recovered frac pac tool string down to closing sleeve shifter, left hole 81.3' frac pac tool string-parted shifter. Sept 27 1996 Wait on mill from Baker fishing. MU fishing assy #2, 3-1/4" Metal Muncher mill on 3-1/8" ext. TIH. Tag fish at 3857'. Mill 3857'-3859'. Pump pressure increased. POOH, mill worn out. Looked like bull plug. Clean frac sand out of boot baskets. TIH with metal muncher mill. Mill on fish at 3859', no success. Indication of junk on bottom. POOH, mill worn out-looked like bull plug. Clean boot basket, frac sand. Wait on mill from Baker. TIH with mill #3, metal muncher mill. Mill on fish at 3859', no success. Mill ran smooth, no indication of junk. POOH with mill #3. Wait on flat bottom concave Cut-Rite mill, inspect tools. Page 2 Sept 28 1996 MU venture jet basket, TIH. Circ & wash bottom 3830'-3859'. POOH with jet basket, recovered small pieces of junk metal-mostly from mills. MU mill #4, TIH. Mill on frac pac tool string 3859'-3861 '. POOH, mill worn out. MU mill #5, TIH. Repair cat engine #2 fuel injector. Mill on fish 3861 '-3863'. POOH, mill worn out. MU mill #6, TIH. Mill on fish 3863'-3864'. Sept 29 1996 Cont milling on frac pac tool string at 3864'. POOH, clean out boot baskets. MU Halliburton VSA packer retrieving tool, TIH to 3841 '. Circ & wash down to packer, tag VSA packer & attempt to latch- cannot latch packer, set down wt up to 40K, cannot latch. POOH, LD retrieving tool. MU 6 X 4-1/2" burning shoe & ext. to burn over VSA packer, TIH. Slip & cut drill line. Finish TIH with burning shoe. Tag top VSA packer at 3860'. Burn over packer 3860'-3864'. POOH for new shoe. MU shoe #2, TIH. Cont burning over packer 3864'-3865'. Sept 30 1996 Cont burning over VSA packer 3865'-3865.5', on packer slips. POOH for new shoe, clean boot baskets. TIH with shoe #3. Burn over packer 3865.5'-3866', milled up slips. Outside of packer appeared to have started to spin after mill slips. Could not make any more hole milling over outside. POOH, LD shoe & boot baskets. MU overshot with 4- 5/8" grapple. TIH with overshot. Tag fish at 3861 '. Latch fish & attempt to release from isolation packer by rotating out of left hand release sub. POOH, recovered 2' of VSA packer mandrell. Pulled out of thread on packer mandrell. Dress overshot with 4-5/8" grapple, TIH. Tag fish at 3863', attempt to latch-no success. Can not get overshot over fish top. POOH with overshot. Page 3 Oct 1 1996 Finish POOH with overshot, no fish, LD fishing tools. Pull wear bushing, set test plug. Test BOP. Test all rams, lines & valves. Test Hydril, kelly, upper & lower kelly valves, TIW & IBOP. Witness of test waived by Bobby Foster of AOGCC. Pull test plug, set wear bushing. MU 6 X 4-1/2" burning shoe on reverse jet basket, TIH. Dress off fish neck 3863'-3866'. Assy torquing up due to junk iron. POOH, LD shoe & clean out jet baskets. Several pieces junk metal in basket. MU overshot with 4-5/8" grapple, TIH. Tag fish at 3863', latch fish & attempt to release from isolation packer by rotating to right. Grapple slipping off fish. POOH, recovered 3" piece of metal off packer-part of a outside sleeve. MU overshot with 4-1/2" grapple, TIH. Latch fish at 3863', attempt to rotate out of releasing sub to right, will not rotate with above 10K over pull. Grapple slips & releases. Overshot releases by rotating to the right & releasing sub releases be rotating to the right. Attempt blind back off to left-grapple slip. POOH, found grapple broken. Change out grapples. TIH, latch fish at 3863'. Blind back off by rotating string to left. POOH, recovered VSA packer. Backed off at top of seal bore below packer. LD packer (packer 5.36' long). Wait on fishing tools from Baker. Oct 2 1996 MU hollow mill & overshot dressed with 2-7/8", TIH. Tag frac pac tool string fish at 3864'. Mill over top of fish & latch fish. Jar on stuck fish. Attempt to back out releasing sub to right, will not back out. Make blind back off of fish to left, DP broke, screw back into DP & torque up, blind back off of fish to left-ok. POOH with fish, break & dope each connection, check for proper torque. Recovered 18.17' of GP screen assy fish & 8' of tool string fish. Cut fish of overshot. MU overshot with 3-1/4" grapple & stop. TIH. Tag up at 3865'. POOH with fish, full recovery of 2-7/8" tool string fish. MU overshot dress with 4-3/4" grapple, TIH. Tag GP screen assy at 3885' & latch. Make blind back off fish. POOH with fish, recovered two jts 4" blank pipe 47' - LD fish. Dress overshot with 4" grapple, TIH. Tag top GP screen at 3933'. Attempt back off of GP screens, grapple slipping, screen stuck. DP broke. POOH with overshot, check each connection for proper torque. Oct 3 1996 TOH & LD FTA #24. 1 piece of metal in overshot guide. Lub rig. MU FTA #25, shoe & wash pipe & TIH with same. Slip drlg line. TIH with FTA #25. Wash & rotate over fish 3933'-3970'. CBU. TOH w/FTA #25. MU FTA #26, TIH. Overshot w/4" grapple. Engage fish at 3933', attempt blind back off-no good. Rig Atlas work left hand torque in fish string & fire fish string shot @ 3966' & POOH with Atlas & complete back off. RD Atlas. TOH & LD fish-full recovery of screen. MU magnet & RIH on DP tag packer at 3965'. TOH & rec 1/~ cup of metal shavings. PU 2 jts 1-1/4" csh & mule shoe & TIH to 4030'. Circ @ 4023'. Wait on clean filtered brine due to truck availability. Displace well bore with clean filtered brine. Page 4 Oct 4 1996 Displace well bore with filtered fluid. TOH & LD BHA. MU HES frac pac assy. TIH with frac pac assy & tag packer @ 3963' & space out. RU frac valve & drop ball & set packer. Psi backside & shear out pressure tubing & PU & shear out with 38K over. Reverse out setting ball. Rig BJ & test lines. Perform step rate & injection test & perform data frac & design frac & perform frac. Put 89500# of 16/20 sand behind pipe & pac screen as well plan & restress twice with BJ to same. Unsting & reverse out & attempt to restress with rig. Unable to sting into frac pac assy. Well flowing, bring wt to 9.5ppg. Circ well static. Sting into frac pac assy & restress assy twice to 1600 psi & bleed down to 500# first time slowly & to 1000 twice second stress. Oct 5 1996 POOH with HES frac pac tool. MU HES running tool & JP plug & FIIH with same & set at 3863' spot sand. POOH with JP running tool. RU shooting flange & lubricator & test same & rig Schlumberger. MU gun #1 & RIH & get on depth & perf 3846'-3839', 12 spf. Run gun #2 & perf 3826'-3808', 12 spf. RIH with 6" GR/JB to 3750'. RD Schlumberger & ND perf flange & NU riser & flowline. MU & RIH w/HES JP pulling tool & pump Zanvis pill. Rev frac sand from top of JP plug & latch & release same. POOH with HES plug. Oct 6 1996 Cont POOH & LD JP plug. MU frac pac assy & RIH with same & space out. Drop ball & circ down set packer. Test annulus. Test lines. Perform data frac & injectivity test & step rate test & design frac. Perform frac as designed. Put 93750# sand. 92500# behind pipe, pack screen as designed. Release & restress two times. Frac went good & looked good. Rev sand from tubing & sting in restress frac twice, ok. RD BJ. POOH & LD HES frac tool & re down floor & set test plug. Change rams to 2-7/8" in BOP & test same. MU & service ESP. RIH with ESP completion. Oct 7 1996 RIH with ESP completion. Make ESP cable splice. Heat trace developed bad meg readings. Check on availability of replacing & accessed the problem of how to correct it. Cont RIH with ESP completion MU hanger & landing jr. Make ESP pigtail splice at hanger. Oct 8 1996 MU splice at hanger. Rig floor to POOH & check heat trace tape. Decision was made that the heat trace tape could be repaired in the field in the problem continued in the end. POOH to end of heat trace tape. Lead in end was not good. Seal allowing fluid to enter into wire causing short. Repair end of ESP cable. RIH with ESP completion. Page 5 Oct 9 1996 MU splice for ESP & heat tract tape @ hanger. Land tubing & RILDS & LD landing jt & set two way check. ND BOP's & NU tree & test same. Freeze protect tubing & annulus to 2000' & RD lines & secure wellhead. Rig released 10/08/96 @ 1800 hrs. Page BP/ALI SHARED SERVICE DAILY OPERATIONL PAGE: 1 WELL: MPI-07 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/28/95 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 22E 09/28/95 (1) TD: 112'( 0) 09/29/95 (2) TD: 112'( 0) MOVING RIG MW: 0.0 VIS: 0 MOVE IN & RIG UP. MOVE RIG FROM H-PAD TO I-PAD. ALL COMPLEXES ON I-PAD @ 0600 HRS. P/U DRILL PIPE ACCEPT RIG 09/28/95, 2100 HRS. MW: 0.0 VIS: 0 09/30/95 (3) TD: 295' ( 183) 10/01/95 ( 4) TD: 1626' (1331) 10/02/95 (5) TD: 2700' (1074) 10/03/95 (6) TD: 2890' ( 190) 10/04/95 ( 7) TD: 4612' (1722) REPAIRING TOP DRIVE MW: 0.0 VIS: 0 FINISH PU DP. FUNCTION TEST DIVERTER. DOUG AMOS WITH AOGCC WAIVED WITNESSING. MU BIT, MOTOR & COLLARS. SPUD & DRILL T/295'. POOH. PU MWD, LC, STAB & ORIENT. SERVICE TOP DRIVE. DRILLING 12-1/4" HOLE MW: 0.0 VIS: 0 REPAIR ELECTRICAL PROBLEM IN TOP DRIVE. TEST MWD & RIH. DRILL 12-1/4" HOLE F/295' T/1626'. CIRC & COND MUD FOR CMT MW: 0.0 VIS: 0 DRILL & SURVEY 12-1/4" HOLE F/1626' T/2700'. CIRC SWEEP AROUND. SHORT TRIP TO HWDP. OK. CIRC & COND MUD TO RUN CASING. DROP EMS & PUMP PILL. POOH TO RUN CASING. LD BHA. OK. CLEAR RIG FLOOR & RIG UP TO RUN CASING. RUN CASING TO SHOE @ 2680'. RU CEMENT HEAD. CIRC & COND MUD. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 TEST LINES, MIX & PUMP CEMENT & DISPLACE WITH RIG PUMPS. BUMP PLUG, FLOATS HELD. CIP @ 0730 HRS. RD CEMENT HEAD, LD LANDING JT & ND 20" DIVERTER. RU HOWCO & PUMP TOP JOB. INSTALL SPEED HEAD & TEST SAME. NU 13-5/8" BOPE. INSTALL TEST PLUG & TEST BOPE. JOHN SPAULDING WITH AOGCC WITNESSED TEST. REPAIR CHOKE VALVE, SEATS WASHED OUT. RE-TEST. OK. PULL TEST PLUG & INSTALL WEAR RING. MU BHA #2. ORIENT & TEST MWD. PU DP & TIH TO FC. TEST CASING. DRILL FC, CEMENT, FS & 10' NEW FORMATION T/2710'. CIRC & COND MUD. PERFORM FIT. DRILL HOLE F/2710' T/2890' FIT = ~,5~~ DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL 8-1/2" HOLE F/2890' T/3739'. CBU. WAIT ON GUZZLER. HIGH CONCENTRATION OF SAND AFTER DRILLING THRU UGNU SANDS. DRILL 8-1/2" HOLE F/3739' T/4511'. PUMP SWEEP AROUND. POOH TO CASING SHOE. OK. SERVICE RIG. TIH. PU 60 JTS DP. DRILL 8-1/2" HOLE F/4511' T/4612' WELL : MPI-07 OPERATION: RIG : NABORS 22E PAGE: 2 10/05/95 (8) TD: 6802' (2190) DRILLING DRILL F/4612' T/6802' MW: 0.0 VIS: 0 10/06/95 (9) TD: 7444' ( 642) 10/07/95 (10) TD: 7444'( 0) 10/08/95 (11) TD: 7444 PB: 0 CBU MW: 0.0 VIS: 0 CIRC SWEEPS, MONITOR WELL. PUMP PILL. BLOW DOWN TOP DRIVE. POOH. SERVICE CROWN & TOP DRIVE. RIH, PU 18 JTS G PIPE. DRILL F/6802' T/7444'. PUMP SWEEP. CBU. MONITOR WELL. PUMP PILL. POOH TO SHOE. OK. SERVICE TOP DRIVE & CROWN, CUT & SLIP DRILLING LINE. TIH. OK. CBU, MONITOR WELL. PUMP PILL. INSTALL 7" PACKOFF MW: 0.0 VIS: 0 DROP EMS, PUMP PILL, BLOW DOWN TOP DRIVE. POOH WITH DP. LD BHA. CHANGE RAMS, PULL WB, INSTALL TEST PLUG, TEST DOOR SEAL. RIH W/ 7" CASING. RU CEMENT HEAD, CIRC MUD. PUMP WATER, TEST LINES, DROP PLUG. CIRC. PUMP WATER, SPACER, CEMENT, DROP PLUG, WASH LINES, BUMP PLUG. RD CEMENT EQUP, LANDING JT, CHANGE ELEVATOR LINKS. INSTALL PACKOFF. RIG RELEASED MW: 0.0 TEST PACKOFF. ND BOPE & FLOWLINE. INSTALL TUBING HANGER & TREE & TEST. CLEAN PITS, INJECT EXCESS WATER & FREEZE PROTECT ANNULUS. RIG RELEASED @ 1600 HRS., 10/07/95. SIGNATURE: (drilling superintendent) DATE: SPE .... Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 100695 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -64.00 122 122.96 58.96 214 214.13 150.13 304 304.16 240.16 395 395.69 331.69 0 0 0 25 0 29 0 33 0 37 N .00 E .00 .00N .00E N 76.61 E .35 .lin .45E N 74.96 E .07 .29N 1.16E N 82.99 E .11 .44N 1.97E S 79.74 E .21 .41N 2.91E .00 .46 1.19 2.00 2.88 487 487.11 423.11 578 578.33 514.33 669 669.28 605.28 760 760.85 696.85 851 851.88 787.88 0 39 0 41 0 52 0 51 0 27 S 78.52 E .04 .21N 3.92E S 81.13 E .04 .02N 4.98E S 78.99 E .22 .19S 6.21E N 88.40 E .21 .31S 7.58E N 68.17 E .49 .15S 8.59E 3.76 4.68 5.76 7.00 8.01 942 942.57 878.57 1036 1036.38 972.38 1131 1130.97 1066.97 1226 1226.77 1162.77 1322 1322.53 1258.53 0 3O 0 28 0 35 0 36 0 36 N 47.99 W .90 .25N 8.63E N 77.46 W .27 .61N 7.94E N 76.80 W .12 .81N 7.07E N 79.61 W .04 1.02N 6.09E N 79.61 W .00 1.20N 5.08E 8.19 7.66 6.92 6.06 5.18 1417 1417.70 1353.70 1512 1512.86 1448.86 1607 1606.85 1542.85 1702 1701.91 1637.91 1798 1796.85 1732.85 0 38 1 53 5 49 6 51 8 23 N 73.57 W .08 1.44N 4.07E 4.32 N 18.33 E 2.12 3.08N 4.05E 4.86 N 32.66 E 4.26 8.58N 7.11E 9.64 N 36.11 E 1.15 17.27N 13.09E 18.25 N 36.07 E 1.60 27.54N 20.57E 28.82 1892 1889.13 1825.13 1988 1982.74 1918.74 2083 2076.37 2012.37 2129 2121.16 2057.16 2179 2170.33 2106.33 12 23 11 42 10 55 11 1 10 51 N 38.24 E 4.29 40.98N 30.84E N 36.82 E .79 56.82N 43.01E N 34.07 E .99 72.07N 53.88E N 33.94 E .24 79.27N 58.74E N 33.86 E .33 87.16N 64.05E 43.09 59.99 75.45 82.50 90.21 2274 2264.23 2200.23 2370 2358.27 2294.27 2414 2401.08 2337.08 2464 2450.64 2386.64 2559 2544.45 2480.45 10 40 10 40 10 33 10 19 10 7 N 33.27 E .24 102.04N 73.92E N 32.88 E .08 116.89N 83.59E N 32.85 E .26 123.63N 87.95E N 32.29 E .52 131.32N 92.86E N 31.17 E .29 145.71N 101.76E 104.61 118.81 125.23 132.50 145.82 2591 2575.65 2511.65 2725 2706.90 2642.90 2820 2800.55 2736.55 2915 2894.39 2830.39 3011 2988.85 2924.85 10 7 10 33 10 40 9 32 7 40 N 30.95 E .11 150.49N 104.64E N 33.29 E .45 170.76N 117.38E N 33.55 E .13 185.41N 127.05E N 34.54 E 1.19 199.28N 136.41E N 34.54 E 1.96 211.06N 144.52E 150.17 169.13 183.25 196.83 208.51 SPE, .f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 100695 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3106 3083.79 3019.79 3202 3178.70 3114.70 3297 3274.00 3210.00 3392 3369.39 3305.39 3488 3464.71 3400.71 5 36 N 36.83 E 2.18 220.06N 150.94E 3 39 N 45.50 E 2.17 225.92N 155.90E 1 46 N 71.52 E 2.31 228.52N 159.47E 1 50 N 76.69 E .19 229.34N 162.37E 1 46 N 73.49 E .14 230.11N 165.28E 217.64 224.32 228.57 231.57 234.57 3583 3560.30 3496.30 3679 3655.90 3591.90 3774 3751.28 3687.28 3870 3846.56 3782.56 3965 3942.00 3878.00 1 47 N 70.82 E .09 231.02N 168.10E 2 5 N 66.48 E .36 232.21N 171.12E 2 2 N 66.98 E .07 233.58N 174.28E 0 49 N 58.41 E 1.28 234.60N 176.43E 0 47 N 54.09 E .07 235.36N 177.56E 237.53 240.77 244.22 246.59 247.91 4061 4037.75 3973.75 4156 4133.15 4069.15 4252 4228.72 4164.72 4347 4323.25 4259.25 4442 4418.74 4354.74 0 49 N 52.37 E .04 236.17N 178.65E 0 52 N 49.87 E .05 237.06N 179.75E 0 52 N 43.71 E .10 238.05N 180.81E 1 40 N 67.55 E .99 239.09N 182.58E 4 51 N 79.51 E 3.39 240.36N 187.85E 249.21 250.55 251.88 253.91 259.30 4538 4513.77 4449.77 4631 4607.20 4543.20 4726 4701.31 4637.31 4822 4796.34 4732.34 4918 4890.92 4826.92 5 13 N 79.66 E .39 241.88N 196.11E 5 9 N 79.25 E .09 243.44N 204.46E 6 24 N 76.02 E 1.36 245.50N 213.76E 8 4 N 76.53 E 1.74 248.36N 225.49E 9 52 N 75.19 E 1.90 252.03N 239.96E 267.57 275.95 285.39 297.38 312.23 5013 4984.39 4920.39 5108 5077.14 5013.14 5202 5168.07 5104.07 5298 5259.70 5195.70 5394 5350.66 5286.66 11 48 N 73.55 E 2.06 256.87N 257.20E 14 5 N 70.09 E 2.53 263.58N 277.44E 16 11 N 72.16 E 2.31 271.51N 300.73E 16 43 N 71.03 E .65 280.06N 326.43E 19 47 N 71.75 E 3.20 289.62N 354.86E 330.08 351.39 375.99 403.05 433.04 5487 5439.00 5375.00 5581 5527.55 5463.55 5677 5617.47 5553.47 5758 5694.23 5630.23 5772 5707.41 5643.41 19 37 N 71.13 E .28 299.69N 384.86E 19 25 N 70.57 E .29 309.99N 414.51E 19 32 N 70.52 E .13 320.58N 444.51E 19 32 N 71.20 E .28 329.52N 470.25E 19 45 N 71.50 E 1.62 331.02N 474.71E 464.67 496.06 527.86 555.11 559.81 5868 5797.29 5733.29 5963 5887.17 5823.17 6057 5975.78 5911.78 6153 6066.15 6002.15 6248 6156.67 6092.67 20 2 N 71.19 E .32 341.43N 505.53E 20 7 N 70.63 E .22 352.18N 536.59E 18 40 N 69.14 E 1.64 362.89N 565.89E 18 38 N 68.62 E .18 373.88N 594.34E 18 20 N 67.18 E .57 385.27N 622.39E 592.33 625.19 656.39 686.89 717.14 SP}~ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/9 DATE OF SURVEY: 100695 ELECTRONIC MULTI-SHOT SURVEY JOB N-UMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 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. 6343 6247.19 6183.19 17 36 N 62.84 E 1.61 397.65N 649.00E 6438 6337.72 6273.72 17 35 N 63.12 E .09 410.69N 674.58E 6534 6429.08 6365.08 17 11 N 63.62 E .45 423.52N 700.15E 6629 6519.80 6455.80 16 34 N 66.10 E .99 435.22N 725.07E 6724 6611.27 6547.27 16 0 N 68.52 E .93 445.55N 749.73E 746.39 774.90 803.33 830.76 857.47 6820 6703.31 6639.31 15 57 N 68.90 E .12 455.12N 774.30E 6915 6794.95 6730.95 15 44 N 69.31 E .25 464.40N 798.60E 7011 6886.91 6822.91 15 24 N 69.90 E .38 473.33N 822.63E 7106 6979.03 6915.03 15 13 N 69.91 E .20 482.00N 846.32E 7189 7059.11 6995.11 15 2 N 70.11 E .23 489.41N 866.67E 883.82 909.84 935.47 960.70 982.36 7202 7071.28 7007.28 14 59 N 71.52 E 2.94 490.48N 7291 7157.03 7093.03 14 57 N 71.53 E .03 497.75N 869.75E 985.62 891.51E 1008.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1021.05 FEET AT NORTH 60 DEG. 49 MIN. EAST AT MD = 7291 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 69.80 DEG. SPT,]~._~f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 100695 JOB NUMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 OPERATOR: BP EXPLOP~ATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -64.00 .00 N .00 E .00 1000 999.94 935.94 .55 N 8.24 E .06 2000 1994.31 1930.31 58.74 N 44.45 E 5.69 3000 2977.75 2913.75 209.83 N 143.67 E 22.25 4000 3976.24 3912.24 235.64 N 177.95 E 23.76 .06 5.64 16.56 1.51 5000 4971.39 4907.39 256.10 N 254.59 E 28.61 6000 5921.04 5857.04 356.29 N 548.30 E 78.96 7000 6876.15 6812.15 472.31 N 819.84 E 123.85 7291 7157.03 7093.03 497.75 N 891.51 E 133.97 4.85 50.35 44.89 10.12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE .... f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 100695 JOB NUMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -64.00 .00 N .00 E .00 64 64.00 .00 .01 N .03 E .00 164 164.00 100.00 .18 N .75 E .00 264 264.00 200.00 .39 N 1.58 E .01 364 364.00 300.00 .47 N 2.57 E .01 .00 .00 .00 .01 464 464.00 400.00 .27 N 3.66 E .02 564 564.00 500.00 .05 N 4.81 E .02 664 664.00 600.00 .18 S 6.13 E .03 764 764.00 700.00 .31 S 7.62 E .05 864 864.00 800.00 .12 S 8.68 E .05 .01 .01 .01 .01 .01 964 964.00 900.00 .38 N 8.49 E .06 1064 1064.00 1000.00 .66 N 7.71 E .06 1164 1164.00 1100.00 .89 N 6.74 E .06 1264 1264.00 1200.00 1.09 N 5.69 E .07 1364 1364.00 1300.00 1.28 N 4.64 E .08 .00 .00 .01 .01 .01 1464 1464.00 1400.00 1.67 N 3.63 E .08 1564 1564.00 1500.00 5.46 N 5.21 E .18 1664 1664.00 1600.00 13.59 N 10.41 E .65 1765 1764.00 1700.00 23.62 N 17.72 E 1.43 1866 1864.00 1800.00 36.86 N 27.61 E 2.80 .01 .10 .47 .77 1.37 1969 1964.00 1900.00 53.71 N 40.69 E 5.05 2071 2064.00 2000.00 70.09 N 52.55 E 7.08 2172 2164.00 2100.00 86.16 N 63.37 E 8.94 2274 2264.00 2200.00 102.01 N 73.90 E 10.73 2376 2364.00 2300.00 117.80 N 84.18 E 12.49 2.25 2.03 1.86 1.79 1.76 2478 2464.00 2400.00 133.38 N 94.16 E 14.19 2579 2564.00 2500.00 148.70 N 103.57 E 15.79 2681 2664.00 2600.00 164.08 N 112.99 E 17.41 2783 2764.00 2700.00 179.67 N 123.24 E 19.13 2884 2864.00 2800.00 195.07 N 133.51 E 20.83 1.70 1.60 1.61 1.73 1.70 2986 2964.00 2900.00 208.30 N 142.62 E 22.12 3086 3064.00 3000.00 218.51 N 149.77 E 22.91 3187 3164.00 3100.00 225.26 N 155.23 E 23.30 3287 3264.00 3200.00 228.42 N 159.17 E 23.45 3387 3364.00 3300.00 229.30 N 162.20 E 23.50 1.29 .79 .39 .15 .05 SPEi f-SUN DRILLING SERVICES ANCHOP~AGE ALAS KA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 100695 JOB NUMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 3487 3464.00 3400.00 230.11 N 165.25 E 23.55 3587 3564.00 3500.00 231.06 N 168.21 E 23.59 3687 3664.00 3600.00 232.33 N 171.39 E 23.65 3787 3764.00 3700.00 233.75 N 174.70 E 23.72 3887 3864.00 3800.00 234.73 N 176.65 E 23.75 .O5 .05 .06 .06 .03 3987 3964.00 3900.00 235.54 N 177.81 E 23.76 4087 4064.00 4000.00 236.40 N 178.95 E 23.77 4187 4164.00 4100.00 237.36 N 180.11 E 23.78 4287 4264.00 4200.00 238.44 N 181.18 E 23.79 4387 4364.00 4300.00 239.59 N 184.19 E 23.85 .01 .01 .01 .01 .06 4488 4464.00 4400.00 241.07 N 191.66 E 24.15 4588 4564.00 4500.00 242.71 N 200.62 E 24.56 4688 4664.00 4600.00 244.49 N 209.70 E 24.99 4789 4764.00 4700.00 247.29 N 221.03 E 25.67 4890 4864.00 4800.00 250.83 N 235.43 E 26.77 .3O .41 .43 .68 1.10 4992 4964.00 4900.00 255.66 N 253.11 E 28.45 5094 5064.00 5000.00 262.45 N 274.34 E 30.93 5198 5164.00 5100.00 271.15 N 299.61 E 34.45 5302 5264.00 5200.00 280.49 N 327.67 E 38.73 5408 5364.00 5300.00 291.12 N 359.42 E 44.21 1.68 2 .47 3.53 4 .28 5.47 5514 5464.00 5400.00 302.57 N 393.29 E 50.41 5620 5564.00 5500.00 314.26 N 426.63 E 56.46 5726 5664.00 5600.00 326.06 N 460.09 E 62.57 5832 5764.00 5700.00 337.51 N 494.04 E 68.80 5939 5864.00 5800.00 349.36 N 528.58 E 75.25 6.20 6.06 6.11 6.23 6.46 6045 5964.00 5900.00 361.48 N 562.17 E 81.45 6150 6064.00 6000.00 373.62 N 593.67 E 86.99 6256 6164.00 6100.00 386.21 N 624.63 E 92.43 6361 6264.00 6200.00 400.08 N 653.74 E 97.51 6466 6364.00 6300.00 414.46 N 682.01 E 102.42 6.19 5.54 5.44 5.08 4.91 6571 6464.00 6400.00 428.32 N 709.83 E 107.14 6675 6564.00 6500.00 440.52 N 737.09 E 111.51 6779 6664.00 6600.00 451.07 N 763.81 E 115.55 6883 6764.00 6700.00 461.31 N 790.44 E 119.54 6987 6864.00 6800.00 471.16 N 816.70 E 123.40 4.72 4.37 4.04 3.99 3.86 SPEo_ _f-SUN DRILLING SERVICES ANCHORAGE ALAS KA PAGE SHARED SERVICES DRILLING MILNE PT/MPI-07 500292260200 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 100695 JOB NUMBER: AK-EI-50092/95 KELLY BUSHING ELEV. = 64.00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7091 6964.00 6900.00 480.60 N 842.48 E 127.10 3.70 7194 7064.00 7000.00 489.84 N 867.91 E 130.70 3.60 7291 7157.03 7093.03 497.75 N 891.51 E 133.97 3.27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS P~E HO, ~3E. 330181 ~I# WELL HEAl) LOF.~ATIOH: LAT(H/-S) 0o00 DEP(E/-W) 0,00 ~.I{~fl-I 1~ ROT~Y T~BLE Ti] T~E'f I8 67,80 TIE IH POIHT(TIP) ~ MEAgURED D~TH 112o00 ~ VERT DEPTH 112o00 INCLINATION 0.00 AZIMUTH 0.00 LATITUDE(~/-S) 0.00 D~ARTI]{~(~-W) 0 ORIGINAL MPI-07 **~xx:~**** At, iAI)RILL ~********** SLE6~Y CAlCULi?IONS ~*****~-* CIF<C~ ARC ~AS~D INT)iRVAL U~RTICA~ D~TH D~Filq ft ft ft 112,00 0,0 112,00 176,50 64,5 176,50 262,37 85,9 262,36 352.54 90,2 352,53 444.61 92.1 444.60 TARGET STATION AZIMUTH LAT II%ll)E $£CTIOH' INCLIq, ft deg deq ft 0,00 0,00 0,.00 0,00 -0,15 0.48 193.~6 -0,26 -0,03 0.54 106.98 -0,73 0.79 0.70 99.33 -0,94 1.68 0,71 113,72 -1,26 DEPA~ DISPLACEI~'IIT at AZlltUIl-i ~-W it ft deg 0,00 0,00 -0,06 0.27 192.56 0,24 0,77 161,91 1,18 1,51 128,53 2,25 2.58 119.22 DLS deg/ lOOft 0.00 0.74 0,82 0.20 0,19 534,75 99,1 522,73 626,2.5 91,5 626.22 716,99 99,6 716,86 606,60 91,7 8~,54 8~.~ 990.8 2,52 0,78 113,45 -1,73 3,32 3,74 117,47 0,07 -3,50 0,87 10%79 -2,21 4,54 5,06 115.92 0.11 4,60 0,95 110,07 -2.70 5,89 6,48 114.60 0,08 5,80 0,87 95,20 -3,02 7,20 7,99 112,49 0,27 6,45 0,21 349.82 -2,92 7,95 8,47 110,17 1,04 9!~),24 1064,05 1178,54 1274,22 1269,91 90.9 F99,18 93+8 1063,99 94.5 1178,46 95,8 1274,28 95,6 1269,64 6,37 0,24 303,25 -2,&6 7,77 8,21 106,8~ 0.19 6,04 0,40 2~7,~ -2,40 7,31 7,70 106.16 0,18 5,58 0.47 303.47 -2.03 6.70 7,00 106.88 0,09 5,00 0,51 265,76 -1,70 5,96 6,20 105.92 0.16 4+33 0.55 292.47 -1.41 5.13 5.22 105.37 0,07 1464,83 1560,20 1653,57 1749,22 1844.16 94.9 1464.76 95,5 1560,16 93.3 1653,06 95.8 1748.10 94,8 1841.65 3,85 0,45 316,94 -0.97 4.46 4,56 102,24 0,24 5.92 3,57 28,22 1,92 5,61 5,92 71,07 3.61 12.37 6.49 23.93 8,85 9.92 13.30 48,26 3,17 22,02 7,50 37,22 18,32 16,73 24,81 42,3? 1,14 35.06 11.26 37.67 20,58 26,13 40,23 40,51 3,96 1927,06 2020,91 2120.70 2224,72 2221,47 92.9 1992,56 93,9 2024,50 99,8 2122,44 94.0 2214,76 96.8 2309.82 51,32 12,36 39,14 45,46 67,20 10,99 24,91 60,61 82,94 11,06 34,62 76,20 97.41 10.70 34.03 90.97 112,05 10,77 34,28 105,88 37,95 59.23 39,85 1,23 49,41 78,20 399,19 1,72 60.30 97,25 38,32 0,10 70,32 114,98 37.71 0.41 80.44 132.97 37.22 0,07 2415,88 2509.16 2603,32 2636.83 2761,62 94.4 2402,60 93,3 2494.33 94.2 2586.99 35,5 2621.94 122.8 2742,74 126,27 10,62 23,80 120,40 139,80 10,30 31,87 134,62 152,90 10,17 20,&8 148.90 157,78 10,16 30,76 154,28 175.04 10,51 32.00 173,09 99,25 150,47 36.85 0.18 99,43 167,26 36,45 0,51 108.14 164.03 35,99 0.23 111,25 190,27 25,82 0,06 122,83 212.24 35,26 0,34 2802,56 2896,21 2991,16 3067,14 3162,39 40,9 2782.99 93.6 2875,17 9'3.0 2968,96 96,0 2064,18 9'3,2 3159.03 180.99 10.54 32,93 179,40 194,20 9,75 23,22 193.22 206,02 8,20 32,20 205,67 215,53 6,14 32,48 215.80 222,58 4.28 37,36 222,92 126.64 219,71 25,26 0,42 12'3.84 236,19 25.1I 0.84 143,65 250,99 34,97 1,64 150,26 262,96 34,85 2,15 155.15 271,59 34.84 2,01 3277,49 2371.44 3467,47 3563.44 3658,77 ~,1 3"'~3.98 94,0 3347.88 96.0 3443,87 96.0 2537.81 95.3 3635.09 227.27 2.16 51,68 226,85 ~0,20 1,65 71,75 228,37 232,97 1.54 71,79 229.20 235,56 1,56 67,55 220,10 228,20 1,74 64,12 221,22 158,71 276,85 34,98 2.37 161,37 279,62 162,91 281,78 25,57 O,11 166,22 283,93 35,&6 0,12 168,84 286,31 26.14 0.21 P~£ ~, ~I-07 · ~ CALCULATI~ ~~** CIIU3UL~ ARC II~SL~D INTERVAL VERTICAL D~TffH DHPTH ft Tt ft 3~3,~ 94,6 37~.66 ~48.79 ~,4 ~,03 ~45,03 96,2 ~1,26 ~,~ ~,2 4016,49 41~,10 95.B 4112,21 TARGET S~ATI~ AZI)qUTH LATITUDE S]3CYI~ I~LN, N/-S ft deg deg. ft 241,33 1,95 64,02 232,54 243,81 1,07 54,2)3 233.79 245,12 0,60 41,27 234,70 246,11 0,00 35,99 2C3~.61 247,13 0,74 28,35 236,70 D~ARTURE DISPLACHM£H~ at AZlMtrFH ft ft de9 171,58 289,01 36,42 173,77 291,30 36,62 174,83 292,66 36,66 175.55 293,82 36,69 176,24 295,10 36,67 DLS deg/ lOOft 0,23 0,96 0.52 0,21 0.12 4220,54 4325,47 4425.41 4521,48 4617.46 94.4 4206,75 94,9 4301,67 9~,9 4401.53 96,1 96,0 4572,93 248,0~ 0,77 31.57 237,78 249.07 0,77 28,06 23B.B9 252.74 3.68 7%00 240.09 259.9B 5.10 79.02 241,44 268,27 4,95 79,32 242,96 176,86 296,34 36,64 0,05 177,50 297,61 36,61 0.04 180,96 300.66 37,01 3,25 188,19 306,12 37,94 1,46 196,46 312,45 3B,% 0,17 4710.76 4805,96 4901,52 4997.73 5093,27 93,3 4685,82 95,2 4780,40 95,6 4874,~ 96,2 4969,77 95.5 S063,27 276,~ 5.79 74.58 244.96 287,66 7.21 74,89 247.79 201.15 9,07 74,19 251,41 317,68 10,78 74,15 255,93 227,25 12,89 69.86 262,04 204.95 319,28 39,92 1,02 215,34 328.29 40,99 1,49 22B.3B 3~.65 42,25 1,95 244,34 353,84 43,67 1,77 262,94 371.22 45,10 2,40 5168,11 52B2,02 5377,11 5473,21 5566,92 94,8 5155,24 93.9 5245,~ 95.1 5335,52 96.1 5425,98 93.7 5514,26 360,36 15,32 69,59 270,05 386,85 17,46 71.45 278,86. 416,95 19.46 70,95 286.57 449,39 20.00 71,01 2~9,14 480.81 19.19 71,01 309,37 284.62 392,35 46.50 2,56 30~,60 416.67 47.99 2,35 338.10 444,51 49,52 2,11 368,78 474,85 50,95 0.56 ~B,50 504.49 52,18 0,67 5662,9B 5758,17 5854,05 5949.41 6045,25 96,1 5604,96 95,2 5694,75 95,9 5705,07 95,4 5074.77 95,8 5965.12 512,45 19,29 71,57 319,52 544,02 19,47 71.51 329,52 576,19 19,75 70,81 339,92 608,56 19,94 71.36 350,41 640.52 19,03 70.22 360.89 426,48 534,50 53,29 0,22 458,44 564.58 54.29 0,19 488,89 ' 595,45 55,19 0,39 519,52 626,65 56.00 0,27 549,71 657,59 56,71 1.O1 6139,51 6235,64 6330,11 6425,01 6521,14 94,3 6054.37 96,1 6145,56 94,5 6235,46 94,9 6226,01 96,1 6417,82 670,82 18,49 68.77 371,48 701.25 18,42 70,20 282,15 720.22 17.29 63.85 393,43 758,~ 17,44 64.82 405.72 786.87 17.06 63.45 418,15 578,11 687,18 57,28 0.78 606,61 716,95 57.79 0,48 633.33 745.58 58.15 2,33 658,94 773,83 58.3B 0.31 684,59 802.19 58.58 0,58 6616.22 6715.19 6806,00 6902.65 6998,16 95.2 650B,68 98.9 6603.73 90,8 6691,06 96,7 67~.09 95.5 6876.16 B14,4B 16,B2 65.19 430.17 842.25 15.90 66,33 441,61 8~7,15 15.95 68.21 451.24 893,33 15,50 66.79 461.27 918,69 15,22 68.74 470,87 7(Y?,56 B29,79 58,77 0,59 734,97 857,44 59.04) 0.99 7b-/,95 BB2,11 59,23 0,57 782.16 908.04 59.47 0,61 805,65 933,17 59,70 0,57 71BB,B3 72B2,11 7355,35 THE LAST 7444.00 95,4 95.2 94.3 72,2 SURVEY IS ~.7 6968.25 943,79 15,17 68,71 479,98 7060,20 968,57 15,01 69,65 488.79 7151,20 992,82 14,81 71,70 496.82 7221,16 lOlI,1B 14,65 71.69 502,56 7306,93 1032,56 14.65 71.69 50~.53 829,04 957.96 59,93 0,16 852,21 982,44 60,16 0,31 875.10 1006,29 60.42 0,59 892,55 1024,31 60,62 0,24 9i3,85 1046,30 60,86 0,03 / GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10497 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape M PI-07 PERF & PACKER RECORD 9 6 0 9 2 3 I 1 M PI-07 PERF RECORD 9 61 0 0 4 I I 10/17/96 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road ~ .. ~ Anchorage, Alaska Received by: . . OCT 2 '1 1996 Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus,) (907) 563-3309 (Fax) August 6, 1996 TO: AUG 0 8 1996 BP Exploration (Alaska) Inc. Petrotechnical Data Center, M B3-~aS~¢, 0il & Gas Cons. 900 E. Benson Blvd. AflChOf~e Anchorage, Alaska 99519-6612 The following data of the Depth shifted CDR/CDN,CDR/ODN TVD'S for well MPI-07~'-'['--'%'-I~"l Job # 95350 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth shift display State of Alaska Alaska Oil & Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Ddve Anchorage, Alaska 99501 ._ I OH LIS Tape. 1 Blueline each" 1 RF Sepia each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 429 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By:,. OXY USA, INC. Attn. DARLENE FAIRLY P. O. BOX 50250 MIDLAND TX~ 79710. Date: RE: 22 November 1995 Transmittal of Data ECC #: 6518.00 Sent by: PRIORITY MAIL Data: PLS Dear Sir/Madam, Reference: MPI-07 MILNE POINT / SBP NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services Suite5600 B201Street Anchorage, AK 99518 Received by: /% / Date: LARRY GRANT . Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 November 1995 Transmittal of Data Sent by: US MAIL Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION PFC/PERF FINAL BL&RF PFC/PERF FINAL BL&RF PFC/PERF FINAL BL&RF SBT FINAL BL & RF 1 PLS FINAL BL & RF 1 PLS FINAL BL & RF Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run # 1 ECC No. 6511.01 6512.01 6516.00 6517.00 6518.00 Please sign and return to: Attn. Rodney D. Paulson " Atlas Wireline Services 5600 B Street Received by:_///'~ . date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Chairma~ October 2, 1995 THRU: Blair Wondzell, ~'J~ FILE NO: P. I. Supervisor AWOLJBCD.doc FROM: John Spaulding~ SUBJECT: Petroleum Insp. BOPE Test Nabors 22E BPX MPU MPI-07 Kuparuk R. Field PTD 95-151 Monday October 2, 1995' I witnessed the B©PE test on Nabors 22E at BPX's Milne Point Unit well MPI-07. The AOGCC BOPE (est report is attached for reference. The rig was well laid out with good access, and an excellent test was observed. One valve on the choke manifold failed and was rebuilt and testing resumed with no further problems Summary.: ! witnessed the succcessful BOPE test on Nabors 22E, 1 failure, 4 hour test time. Attachments: AWOLJBCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: DATE: Nabors Rig No. 22E PTD # 95.151 Rig Ph.# BPX Rep.: J. C. Pyron MPI-07 Rig Rep.: Leonard Schiller Set @ 2680' Location: Sec. 33 T. 13N R. tOE Meridian Umiat Weekly Other 0/2/95 659-4446 TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes Well Sign ok Drl. Rig ok Hazard Sec. yes BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve Test Press. PIF 300/3,000 P 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 P P P P 1 500/5,000 P NA MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F '1 500/5, 000 P 500/5, 000 P 500/5, 000 P 500/5, 000 P CHOKE MANIFOLD: No, Valves No. Flanges Manual Chokes Hydraulic Chokes 18 Test Pressure P/F 500/5, 000 P('I F) 42 500/5, 000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 ~ 2000 AVG. 3,~00 [ P ~,900 P minutes 29 sec. minutes 43 sec. X Remote: X' Psig. TEST RESULTS Number of Failures: 1 ,Test Time: 4.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 24 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Very good test, 1 valve failure on the choke man~fold, repaired and re-tested Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X' NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AWOLJ BCD.XLS STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSioN "' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging ~ Time extension __ Stimulate __ Change approved program X Pull tubing __ Variance __ Perforate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2339' NSL, 3906' WEL, SEC 33, T13N, RIOE 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 66 7. Unit or Property name Milne Point Unit 8. Well number MPI-07 At top of productive interval 9. At effective depth ORIGINAL At total depth Permit number 95-151 10. APl number 50- 029-22602 11. Field/Pool Milne Point / Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth _..,'--' k? 2~ 7 19,5 0il & Gas Cons. Commission , Anchorage 112' 2680' 7508' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation O9/28/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas Suspended __ Service 17. I hereby certify?at the foregoing is true and correct to the best of my knowledge. Signed /'~-~ ~ C//%~,~_~;¢~ Title Senior Drilling Engineer Date / FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so repr~entative may witness I Approval No. Plug integri~ BOP Test ~. Location clearance ~ Approved Copy~ Mechanical Integri~ Test~ Subsequgn[~orm reqgired 10- ~ ~ 7 ~,..rn~, Original ~ignea ~y Approved by order of the Commission David W. Johnston '" ~/%~/~--CommissionerSUBMIT IDate Form 10-403 Rev 06/15/88 h a r ,ed TO: Blair Wondzell FROM: Joe Polya DATE: September 28, 1995 SUBJECT: MPI-07 Proposed Change in Surface Casing Setting Depth An approved Permit to Drill (Form 10-401 dated 9/21/95) was received for the drilling of the Milne Point 1-07 production well. Since submitting this application we have reason to change the surface casing setting depth from below the Schrader Bluff Sands to above the Schrader Bluff Sands. As per my discussion with Blair Wondzell I am submitting the attached Form 10-403 requesting a change in the surface casing setting depth as follows: Orignial Approved: 9-5/8" 40# Casing set at the base of the Schrader Bluff 4261' md / 4234' tvd. Cement Volumes: Stage 1 Cement Job 107 sxs Permafrost E Lead and 275 sxs Premium G Tail. Stage 2 Cement Job 611 sxs Permafrost E Lead and 50 sxs Premium G Tail. 250 sx Permafrost E Top Job if No Cement to surface. Proposed Change: 9-5/8" 40# Casing set at the base of the Schrader Bluff 2700' md / 2680' tvd. Cement Volumes: Stage 1 Cement Job 542 sxs Permafrost E Lead and 250 sxs Premium G Tail 250 sx Permafrost E Top Job if No Cement to surface. Explanation: This well is planned as a Kuparuk Producer; however, it has potential production in the Schrader Bluff Reservoir. If the Kuparuk is deemed to be non-commercial, then 7" casing will be run thru the Schrader Bluff Reservoir and the well will be completed as a producer. The next Schrader Bluff producer is scheduled to be stimulated with a resin consolidated sand treatment which is better fitted to 7" casing than it is 9-5/8" casing -- therefore, the change in the setting depth for the surface casing. This will be the first resin consolidated sand stimulation job attempted on the slope -- we need to ensure we do everything possible to optimize the chances for success. Thanks for your prompt attention and assistance in this matter. Joe Polya Drilling Operations Engineer, Nabors 22E Gas Cons. Commissiur, Anchorage Well Name: I Revised MPI-07 Well Plan Summary I Type of Well (producer or injector): I Kuparuk Producer [ Surface Location: 2339 NSL 3906 WEL Sec 33 T13N R10E UM., AK. Target Location: 2809 NSL 3071 WEL Sec 33 T13N R10E UM., AK. Bottom Hole Location: 2865 NSL 2919 WEL Sec 33 T13N R10E UM., AK. [AFE Number: [ 330181 I I Estimated Start Date: 19/28/95 [ Rig: I Nabors 22-E I Operating days to complete: [ 1 2 IMD: 17649, I I TVD: 17508' bkb I IKBE: I64' I Well Design (conventional, slimhole, etc.): [ Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops MI) TYD (bkb) base permafrost 1885 1884 NA 3821 3794 Top of Schrader Bluff Sands (8.3 ppg) OB 4041 4034 (8.3 ppg) Seabee Shale 4241 4214 Base of Schrader Bluff Sands (8.3 ppg) HRZ 6297 6206 High Resistivity Zone Top Kup 6713 6606 Kuparuk Cap Rock Top C1 Sand--Target 7053 6934 Target Sand (9.9 ppg) Total Depth 7649 7508 Casing/Tubing Program: Hole ~ize - Csg/- Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 2669 31/31 2700/268( 8 1/2" 7" 26# L-80 btrc 7619 30/30 7649/750~ 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 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3570 psi is 2885 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional DSS Intermediate N/A Final 1. PDC Bit f/Prince Creek to TD w/MWD Dir and LWD (GR/CDR/CDN). Cased Hole Logs: Sample Catchers and Lithology logs will be required for thru Colville, Kuparuk, and Miluveach for this well. Alaska Uti & Gas Co~s. Corr}nlissior~ Anchorage Mud Program: ] Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 10.5 100 35 15 30 10 15 Intermediate Mud Properties: N/A Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: [ None- LSND freshwater mud Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 115o0' IMaximum Hole Angle: Close Approach Well: 15'72° (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: There is not an annulus open for annular injection for the drilling of the MPI- 07; however, once this well is complete, all drilling and completion fluids can be annular injected. Request to AOGCC for Annular Pumping Approval for MPI-07: 1. Approval is requested for Annular Pumping into the MPI-07 9-5/8" x 7" casing annulus. 2. 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 2700' md (2680' tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# LB0 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 3140 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). 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 · vvhich.demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point MPI-07 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. 27 Anchorage MPI-07 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD and LWD CDR (Gr/Res). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. MU a on a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out FE and 10' of new formation -- Perform LOT. 8. Drill 8.5" hole to TD -- This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Run and Cement 7" Casing. 9. RIH while PU 3-1/2" drill pipe and 7" 26# scraper and bit. Drill the ES Cementer and RIH to PBTD, perform a casing wash while displacing the hole with source water. Filter source water to 2 micron absolute. Freeze Protect Top 2000' of with diesell. 10. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 11. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine. 12. MIRU Nabors 4ES. NU & Test BOPE to 5000 psig. 1 3. RIH while PU 3-1/2" drill pipe and 7" 26# scraper and bit. RIH to PBTD, perform a casing wash while displacing the hole with 10.2 ppg brine. Filter brine water to 2 micron absolute. 14. POOH laying down 3-1/2" Drill Pipe. 15. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. 1 6. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: 1. Hydrates have been encountered while drilling E and H Pad Wells are expected on Pad. 2. There is no history of hydrates on the MPI-Pad; however, be prepared with the standard action plan as outlined in the Well Plan. ;,~ ¢.,;.-~ ~.,I~ & Gas Cons. Anchorage CASING SIZE' 9-5/8" MPI-07 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 542 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE' ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G 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: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX NO SACKS: 250 YIELD:2.17 ft3/sx MIX WATER: 11.63 CENTRALIZER PLACEMENT' 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to !500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 250 sacks. Gas Coris. Cornmissior, Anchorage MPI-07 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 202 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/s THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP: 60° F BHST 80 deg F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: 1 55 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 16 joints of 7" (32 total). This will cover 300' above the C1 Sand. 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer above and below the 7" ES Ceme Total). 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from OB Base Sand to 200' abl NA Sand (30Total). 3. Run two 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 66. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage I cement volume is calculated to cover 1000' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OB base to 500' above the NA Top with 30% excess.~1'~,L'¢,'- .,~:- ',~ i~;,..L''i Alaska _Oil .& Gas Coils. C0mmJssJon "~ch0rago TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279ol 433 FAX: (907) 276-7542 September 21, 1995 Tim Scofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit MPI-07 BP Exploration (Alaska), Inc. Permit No 95-151 Surf Loc 2339'NSL, 3906'WEL, Sec. 33, T13N, R10E, UM Btmhole Loc 2865'NSL, 2919'WEL, Sec. 33, T13N, R10E, UM Dear Mr. Scofield: Enclosed is the approved application for permit to ddll 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 (DOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the DOPE 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 eld inspector 659-3607. · David V~. Johnston \ ~- '~...._~ Chairma~ ~ BY ORDER OF T COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation o w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrillCIIlb. Type of well. Exploratoryl-1 Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 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 = 66 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 025906 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2339' NSL, 3906' WEL, SEC 33, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2809' NSL, 3071' WEL, SEC 33, T13N, RIOE MPI-07 2S100302630-277 At total depth 9. Approximate spud date Amount 2865' NSL, 2919' WEL, SEC 33, T13N, RIOE 09/25/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 025517 2361 feet No Close Approach feet 2560 7649'MD/7508' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~5oo feet Maximum hole angle~5, z2 o Maximum surface 2885 psig At total depth (TVD) 7000'/3570 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 8692' 31' 31' 4261' 4234' 8-1/2" 7" 26# L-80 Btrc 15848' 30' 30' 7649' 7508' 244 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ' ~,,., i~, Intermediate ProductionSEP 9 995 Liner Perforation depth: measured ~;~$~a,.0il.& Gas Cons, C0mmissi0.r~ true vertical , /~ch0rage 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 certify that the foregoing is true and correct to the best of my kn.o_wledge........_,.~. Signed ...~C'o.,. 'T~,w~ .~c.~"~|e...~c~L Title SeniorDrillin~lEn~gieer~~'""'' Date~/tl~J/t~' Commission Use Only Permit Number APl number Approval date See cover letter ~,_~-///,~.,? 50-O2.¢.-'.~-----.~--. ¢0.2-, ¢--~/--¢,~,~,~ for other requrements Conditions of approval Samples required [] Yes [~No Mud Icg requir.ed []Yes ~'No Hydrogen sulfide measures [] Yes ]~ No Directional survey required ~ Yes [] Required working pressure for BOPE []2M; []3M; J~5M; []10M; []15M; Other: Original Signed By by order of / Approved by David W. Johnston Commissioner tne commission Date ...,/~ ~.; Form 10-401 Rev. 12-1-85 Submit I Well Name: I MPI-07 I Well Plan Summary Type of Well (producer or injector): I Kuparuk Producer Surface Location: 2339 NSL 3906 WEL Sec 33 T13N R10E UM., AK. Target Location: Bottom Hole Location: 2809 NSL 3071 WEL Sec 33 T13N R10E UM., AK. 2865 NSL 2919 WEL Sec 33 TI3N R10E UM., AK. [AFE Number: I 330180 I Estimated Start Date: 19/25/95 IMD: 17649. ! ITVD: I Well Design (conventional, slimhole, etc.): Rig: I Nab~ Operating days to complete: ! 7508' bkbI 112 I KBE: 166' I Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1885 1884 NA 3821 3794 Top of Schrader Bluff Sands (8.3 ppg) OB 4041 4034 (8.3 ppg) Seabee Shale 4241 4214 Base of Schrader Bluff Sands (8.3 ppg) HRZ 6297 6206 High Resistivity Zone Top Kup 6713 6606 Kuparuk Cap Rock Top C1 Sand--Target 7053 6934 Target Sand (9.9 ppg) Total Depth 7649 7508 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 8692 31/31 4261/4234 8 1/2" 7" 26# L-80 btrc 15848 30/30 7649/7508 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 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3570 psi is 2885 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional and CDR (Gr/Res) across Schrader Bluff Intermediate N/A Final 1. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). Cased Hole Logs: GR/CCL will be run in 7" casing to Tie-in the TCP Guns for Completion. Mud loggers are not required for this well. Mud Program: Special design considerations None- SPUD MUD Surface Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 100 35 15 30 10 15 Intermediate Mud Properties: N/A ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: ] None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. '~ [..o Directional: IKOP: 11500. IMaximum Hole Angle: Close Approach Well: 15.72 (No Shut Ins) il.; E;t':> 't 9 1995 I /Ma~l~.a l,.Jll .&qas Cor~s. Commission -: t~ch0rage Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected. Approvals have been granted for MPH-05 and MPH-06 wells for annular pumping. Request to AOGCC for Annular Pumping Approval for MPH-06: 1. Approval is requested for Annular Pumping into the MPH-07 9-5/8" x 7" casing annulus. 2. 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 8723' md (4266' 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 2450 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). 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 permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (aBES) (aBES) Milne Point MPI-07 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MPI-07 Proposed Summary of Operations . 2. 3. 4. 5. . . , 10. 11. 12. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD and LWD CDR (Gr/Res). ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a on a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out FE and 10' of new formation -- Perform LOT. Drill 8.5" hole to TD -- This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Run and Cement 7" Casing. Freeze Protect Top 2000' of with diesel and bump plug with source water. I'- ND BOPE, NU and Test Tree. RDMO Nabors 225 drilling rig to drill next well. i~'. ~... L, ~ Perforate and Stimulate in absence of rig. MIRU Nabors 4ES. NU & Test BOPE to 5000 psig. ,;.,~,~k~ u,u & GaS Coliu. .. RIH while PU 3-1/2" drill pipe and 7" 26# scraper and bit. RIH to PBTD, perform a casing f~icl~orage. wash while displacing the hole with 10.2 ppg brine. Filter brine water to 2 micron absolute. 1 3. POOH laying down 3-1/2" Drill Pipe. 14. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. 1 5. Install Surface Lines and Wellhouse and put the well on production. fDrilling Hazards and Risks: 1. Hydrates have been encountered while drilling the MPH-05, 06, and 07 wells. 2. There is no history of hydrates on the MPI-Pad; however, be prepared with the standard action plan as outlined in the Well Plan. MPI-07 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON STAGE I CEMENT JOB across the Schrader Bluff Formation- CIRC. TEMP: 60° F BHST 80°F SPACER- 10 bbls fresh water followed by 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder Type E Permafrost WEIGHT: 12.0 ppg gal/sk YIELD:2.17 ft3/sx MIX WATER: 11.63 APPROX #SACKS: 107 THICKENING TIME: Greater than 3-4 hrs at 60° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Haled 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 275 FLUID LOSS: 100-150 cc THICKENING TIME: 3-4 hours @ 60° F. FREE WATER: 0cc @ 45 degree angle. '. ~. , L. ~ ', l.~ i,,} STAGE II CEMENT JOB ACROSS Prince Creek to Surface' CIRC. TEMP: 60° F BHST SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder 40° F .) '1 9 1995 0il & Gas Cor~s, C0mmissiun /~]ch0rage WEIGHT: 12.0 ppg gal/sk YIELD:2.17 ft3/sx MIX WATER: 11.63 APPROX #SACKS: 611 THICKENING TIME: Greater than 3-4 hrs at 60° F. TAIL CEMENT TYPE: ADDITIVES: 2% CaCI2 Premium G WEIGHT: 15.8ppg APPROX # SACKS: 50 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 3-4 hours @ 60° F. FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 250 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 9-5/8" x 12" Straight Blade Rigid Centralizers-- two per joint on the bottom 16 joints of 9-5/8" Casing (32 total). This will cover 200' above the Na Sand. 2. Run one 9-5/8" x 12" Straight Blade Rigid Centralizer on each side of ES Cementer (2 Total). 3. Total 9-5/8" x 12" Straight Blade Rigid Centralizers needed is 34. 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 10-14 bpm. Batch mixing is not necessary. CEMENT VOLUME' 1. Stage 1 cement volume is calculated to cover 500' md above the Na Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the top of Stage 1 to 1500' md with 30% excess and from 1500' md to surface with 100% excess. CIRC. TEMP: SPACER: MPI-07 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON 140° F BHST:170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: None THICKENING TIME: Greater than 3-4 hrs at 180° F. TAIL 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 II~'. ¢. APPROX # SACKS: 244 THICKENING TIME: 3 1/2-4 1/2 hrs @ 140°F ':' 9 1995 FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree ai'Lgl¢,'.a ult & Gas Cor~s. Cor~ll'nissior~ A~'lchora§e CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- 44 Total (2 per joint on bottom 22 joints). 2. Run two 7-1/8" x 8-1/4" Straight Blade Centralizer 60' above the 9-5/8" casing shoe. 3. Total 7-1/8 .... x 8-1/4" RH Turbulators needed is 46. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME' 1. The cement volume is calculated to cover 1000' md above the C1 Sand with 30% excess. -95 14:20 Anadr~Jl DPC 907 ~44 2160 P.6 SHARED SERVICES DRILLING i i i i~ii i i MPI-07 (P3) VERTICAL SECTION VIEW. Section at' 69.80 TVD Scale.' ! inch : lO00 feet Dep Scale.' I inch = 1000 feet <KB> 0~= I ~ i I I Oraw, ..... ' 09/15/95 500 ..... l ..................... ~000-- Marker Identification MD BKB SECTN INCLN ! A~ KB 0 0 0 O. O0 ~ B) KOP BUILD 2/~00 1500 1500 0 0.00 1500 ..... L ....... B-- I C) END OF 2/~00 BUILD 2544 2138 61 ,2.87 ....... D) START 2/~00 DROP 2777 2756 179 12.87 E) END OF 2/~00 DROP 342, 3394 240 o.oo " F) SCHRADER BLUFF TGT 382~ 3794 240 0.00 2000--. I~P~'~SI' reg~ G) START 2/100 CURVE 406~ 4034 240 0.00 ii' HI 9-5/8" CASING 426' 4234 247 4.00 ! II ENO OF ~/~00 CURVF 4847 48~0 347 :15,72 I JJ KUPARUK TGT 7053 6934 945 ~5.72 ~K I B 3000-- .. , I ,. 3500 E -- i ........... ................ t' ...... ' .... qtr ':~-~i · i J"":ii i.i _---,...,, 4000-.-. .......... ~, -= ............ ~,r~ ,~ ' _ .. ............ A'- ~- ...... ' ..... s1~J~ .~z'~' r~' kNADR LL A <A. DPC ,~oo .......... ~. ..... F(}R ~i[RMTI Tll,,l' ..... j ~ooo-- 5500 .......................................... 60004 6soo ...................... I .... r9-~99~- ....... · 7°°°-- .... A1 ,chu~ag6 7500 ................. U ..... K -~oo0 -500 0 500 ~000 ~500 eooo 2500 3000 3500 4000 4500 5000 5500 6000 Sect ion Beparture (Anadr~]] (c)95 ~oI07P3 2.5~.02 2:~3 P~4 P) 14:21 Anadr~ll DPC 907 344 2160 P.O~ SHARED SERVICES Marker Identification MO N/S A) KB 0 0 BI KOP BUILD 2/100 1500 0 C} END OF 2/~00 BUILD 2144 57 D) START 2/100 DROP 2777 170 E) END OF 2/]00 DROP 342~ 228 FJ SCHRADER BLUFF TGT 3821 22B G) START 2/~00 CURVE 406~ 22B H) 9-5/8" CASING 426t 230 I) END OF 2/~00 CURVE 4B47 265 JJ KUPARUK TGT 7053 471 K) 7" CASING 7649 527 L) TO 7649 527 43 t28 172 172 ~72 ~78 272 834 985 985 DRILLING MPI-07 (P3) PLAN VIEW CLOSURE · ~7 feet at Azimuth 6~.87 DECLINATION.' +28.77I (EJ SCALE ' ! inch : 200 feet DRAWN · 09/15/95 ANADRILL AKA-DPC APPROVED FOR PERMITTING ~.L_ ONLY PLAN #_~ ~_~.~~ _ 500 600 700 800 900 lO00 JJO0 1200 1300 <- WEST · EAST -> (Anadri]! (c)~5 HPIO7P3 2.5~.02 t:5! Pa PI wELL PERMIT CHECKLIST PROGRAM: exp [] der ~redrll [] aery [] / ADMINISTRATION ENGINEERING 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .......... . . . 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. 'Can permit be approved before 15-day wait ....... APPRox,. D~ 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 .... Y N~ 31. Data presented on potential overpressure zones ..... Y/~--z //j/~ 32. Seismic analysis 9f shallow gas zones ......... ./~ N/L--' ,~/ ~ 33. Seabed condition survey (if off-shore) ....... / Y N' 34. Contact name/phone for weekly progress reports . ./~... Y N [exploratory only] /~ GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:~ORMS~heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is Part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. AUG 0 ~ ~996 Oil & Gas Cor~, ~chr~arCje * ALASKA COMPUTING CENTER . ****************************** . ............................ ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAlViE : B.P. EXPLORATION WELL NAME : MPI-07 FIELD NAM~ : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUFIBER : 50-029-22602-00 REFERENCE NO : 95350 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-AUG-1996 14: ~5 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 5 ORIGIN · FLIC REEL NA~E : 95350 CONTINUATION # : PREVIOUS REEL : COF~4ENT · B.P. EXPLORATION, MILNE POINT MPI-07, API #50-029-22602-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 96/08/ 5 ORIGIN · FLIC TAPE NAME : 95350 CONTINUATION # : 1 PREVIOUS TAPE : COB~iENT : B.P. EXPLORATION, MILNE POINT MPI-07, API #50-029-22602-00 TAPE HEADER MILNE POINT MWD 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 O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPI - 07 500292260200 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 5-AUG-96 BIT RUN 1 ......... 95350 R UMINER/ST. A PYRON BIT RUN 2 BIT RUN 3 33 13N iOE 2339 3906 64. O0 64. O0 34.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 8. 500 9. 625 2680.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-AUG-1996 14:u5 3RD STRING PRODUCTION STRING Well drilled 02-OCT through 06-0CT-95 with CDR/CDN. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE~ER: 1 EDITED~IERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 2558.5 7443.5 BASELINE DEPTH 88888.0 4223.5 4215.5 4187.5 4182.5 4177.0 4164.5 4161.0 4155.0 4133.0 4113.5 4067.0 4056.5 4044.5 4010.5 3999.0 3971.5 3960.0 3942.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88887.5 4223.0 4211.0 4185.0 4181.5 4176.5 4162.0 4159.5 4153 0 4131 0 4113 0 4065 0 4054 0 4042 0 4011.0 3997.5 3968.5 3957.5 3940.5 LIS Tape Ver=£'ication Listing Schlumberger Alaska Computing Center 3938.5 3935.5 3910.5 3907.5 3899.5 3896.0 3845.0 3842.0 3830.5 3827.5 3817.0 3814.0 3795.5 3792.5 3794.0 3790.0 3782.5 3779.5 3780.5 3777.5 3769.5 3765.5 3765.0 3761.5 3759.0 3756.0 3751.5 3748.5 3717.0 3714.5 3676.5 3673.5 3660.5 3658.0 3654.5 3652.5 3641.5 3639.5 3617.0 3615.0 3610.0 3608.5 3605.0 3603.0 3587.0 3585.5 3573.0 3571.0 3557.0 3554.5 3540.0 3537.5 3527.0 3524.0 3507.5 3505.5 3495.5 3493.0 3480.0 3477.0 3449.0 3446.5 3433.0 3431.0 3419.5 3416.5 3405.5 3403.5 3378.5 3376.0 3360.0 3357.0 3353.0 3351.0 3337.0 3334.5 3293.0 3291.0 3265.5 3263.5 3262.0 3258.5 3255.0 3252.5 3247.0 3243.0 3233.0 3229.0 3219.0 3216.0 3199.0 3196.0 3183.0 3179.5 3172.0 3168.5 3138.0 3134.0 3117.5 3114.0 3105.0 3102.5 3086.0 3082.5 3074.0 3070.5 3071.0 3067.0 3041.0 3037.0 5-AUG-1996 14: u5 PAGE: LIS Tape Ve~=£ication Listing Schlumberger Alaska Computing Center 5-AUG-1996 14:u5 PAGE: 3022.0 3015.5 3004.0 2937.0 2931.0 2919.0 2906.0 2896.5 2889.0 2875.5 2868.0 2858.0 2846.5 2839.0 2834.0 2820.0 2807.5 2798.0 2777.0 2774.5 2752.5 2736.5 2727.0 2722.5 2715.5 2700.5 2691.0 2674.0 2660.0 2635.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 3018.5 3012.0 3000.0 2933.0 2927.0 2915.0 2901.5 2891.5 2884.5 2871.5 2863.5 2853.0 2842.0 2836.0 2831.5 2816.0 2803.0 2794.0 2773.5 2770.5 2748.0 2731 5 2722 5 2718 5 2713 0 2697 5 2687 0 2670 5 2654 5 2629 0 94 0 BIT RUN NO. FiERGE TOP ~ERGE BASE The depth adjustments shown above reflect the MWD GR to the CH GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA LIS Tape Ve~£ication Listing Schlumberger Alaska Computing Center 5-AUG-1996 14: u5 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630204 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD Olff4M 630204 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~iM 630204 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~4M 630204 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD Ott~M 630204 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 014P~4630204 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630204 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630204 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630204 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630204 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630204 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630204 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630204 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630204 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GRCH GAPI 630204 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7443.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 98.370 FET. MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 GRCH.GRCH -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-AUG-1996 14:u5 PAGE: DEPT. 6000.000 RA.MWD VRP.MWD 1.824 DER.MWD GR.MWD 103.433 RHOB.MWD CALN. MWD 8.539 NPHI.MWD DEPT. 4000.000 RA.MWD VRP.MWD 11.777 DER.MWD GR.MWD 55.481 RHOB.MWD CALN. MWD 8.727 NPHI.MWD DEPT. 2555.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD 1.942 RP.MWD 1.829 1.870 ROP.MWD 96.251 2.414 DRHO.MWD 0.061 33.300 GRCH. GRCH -999.250 11.570 RP.MWD 12.198 ROP.MWD 2.210 DRHO.MWD 27.800 GRCH. GRCH 12.397 74.072 0.002 36.926 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 GRCH. GRCH 18.082 VRA . MWD FET.MWD PEF.MWD VRA . MWD FET. MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD 1.930 0.916 3. 002 11.258 0.904 3.346 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NABiE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SOMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... MWD 2564.5 7444.0 $ LIS Tape Ve~ x fication Listing Schlumberger Alaska Computing Center 5-AUG-1996 14: 05 PAGE: LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWArHOLE SOFTWARE VERSION: DATA TYPE (M~4ORY or REAL-TIME) TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHF~4) AT TEMPERATURE (DEGF) : MUD AT M~ASOqAED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 06-0CT-95 FAST 2.5 4. OC MEMORY 7444.0 2565.0 7444.0 54 10.2 20.0 TOOL NUMBER RGS022 NDS022 8.500 2680.0 LSND 10.40 55.0 200 4. 200 75.0 3.800 75.0 ************ RUN1 ************* DRILLED INTERVAL 2700' - 7444' HOLE ANGLE AT TD = 14.65 DEG @ 7444' RES TO BIT: 54.09'; GR TO BIT: 65.39' NEUT TO BIT: 116.89'; DENS TO BIT: 109.91' TD WELL @ 22:32 05-0CT-95 NOMAD PASS DATA COLLECTED DATA FROM DOWArHOLEMEMORY, V4.0C SOFTWARE 1.0 20000 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-AUG-1996 14: u5 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFZB SAMP ELEM CODE (HEX) DEPT FT 630204 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 Otflv~4 630204 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~M 630204 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OHMM 630204 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 630204 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 HR 630204 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 630204 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 630204 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 630204 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW1 BN/E 630204 O0 000 O0 0 2 1 1 4 68 0000000000 CALN LW1 IN 630204 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW1 PU 630204 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 630204 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU 630204 O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW1 IN 630204 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-AUG-1996 14: u5 PAGE: ** DATA ** DEPT. 7444. 000 ATR.LW1 -999.250 PSR.LW1 ROPE. LW1 98.370 TABR. LW1 -999. 250 GR. LW1 DRHO. LW1 -999. 250 PEF. LW1 - 999. 250 CALN. LW1 TABD. LW1 -999. 250 DPHI. LW1 -999. 250 DCAL. LW1 DEPT. 6000. 000 ATR. LW1 ROPE.LWi 92.310 TABR.LW1 DRHO.LW1 O. 059 PEF.LW1 TABD.LW1 1.300 DPHI.LW1 DEPT. 4000. 000 ATR. LW1 ROPE. LW1 76.166 TABR . LW1 DRHO . LW1 O . 048 PEF. LW1 TABD. LW1 1.560 DPHI. LW1 DEPT. 2564. 500 ATR. LWl ROPE. LW1 -999. 250 TABR. LW1 DRHO . LW1 -999.250 PEF. LW1 TABD.LW1 -999.250 DPHI.LW1 1.933 PSR.LW1 O . 914 GR. LW1 3. 031 CALN. LW1 15. 100 DCAL. LW1 11. 399 PSR. LW1 O . 910 GR. LWI 3. 556 CALN. LW1 10. 100 DCAL.LW1 -999. 250 PSR. LW1 -999. 250 GR. LW1 -999. 250 CALN. LW1 -999. 250 DCAL. LW1 -999. 250 DER. LW1 -999. 250 RHOB. LW1 -999. 250 TNPH. LW1 -999.250 1.83 7 DER. LW1 109. 344 RHOB. LW1 8. $56 TNPH. LW1 O. 056 14. 771 DER. LW1 52. 784 RHOB. LW1 8.788 TNPH . LW1 0.288 -999. 250 DER. LW1 -999. 250 RHOB. LW1 -999. 250 TNPH. LW1 -999.250 -999.250 -999.250 -999.250 1.872 2.413 33.100 14.268 2.556 30.400 -999.250 -999.250 52.900 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~4E : EDIT DATE : 96/08/ 5 ORIGIN : FLIC TAPE NAME : 95350 CONTINUATION # : 1 PREVIOUS TAPE : COFk4~NT : B.P. EXPLORATION, MILNE POINT MPI-07, API #50-029-22602-00 LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 5-AUG-1996 14: u5 PAGE: 10 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/ 5 ORIGIN : FLIC REEL NAM~ : 95350 CONTINUATION # : PREVIOUS REEL : COfqMF~NT : B.P. EXPLORATION, MILNE POINT MPI-07, API #50-029-22602-00 MPI- 07 MILNE nov ~o ..-'- / // / %'? .:_ - ~ Run 1' 09 - November - 1995 GRCH Marked Line Logging Services 2195 ~._. · 4210 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 MPI - 07 500292260200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 21-NOV-95 - 6518.00 K. RICHARDS J. FOX 33 13N 10E 2339 3906 64.00 0.00 34.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 20.000 115.0 3RD STRING 9.625 2680.0 PRODUCTION STRING 7.000 7425.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ GR GRCH 1 1 09-NOV-95 WESTERN ATLAS LOGGING SERVICES 91.10 40.00 26.00 REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... Marked Line GR. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MAGNETIC MARKS FOR DEPTH CONTROL. LINE LAST MARKED ON 14-0CT-95. FILE 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 2195.0 - 4210.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS i (MAIN PASS). THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPI - 07 : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME -Tape depth ID: F i Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI * DATA RECORD (TYPE# 0) Total Data Records: 33 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1022 BYTES * 4 4 30 310 01 1 Tape File Start Depth = 4227.000000 Tape File End Depth = 2179.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8195 datums Tape Subfile: 2 124 records... Minimum record length: 62 bytes Maximum record length~ 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 3890.0 4210.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH 3903.5 3903.0 3907.5 3907.5 3926.5 3926.0 3935.5 3935.0 3950.5 3950.5 3953.0 3953.0 3955.5 3955.5 3961.5 3961.0 3968.0 3968.0 3970.0 3971.0 3987.5 3987.5 4011.0 4011.5 4027.5 4027.5 4030.5 4030.0 4048.5 4049.5 4059.0 4058.5 4064.5 4064.5 4068.0 4067.0 4072.0 4072.0 4075.5 4076.0 4090.5 4090.5 4093.5 4094.0 4105.5 4106.0 4120.0 4120.0 4131.0 4131.0 4140.5 4140.5 4160.0 4160.5 4166.0 4166.0 4168.0 4168.5 4170.5 4170.5 4182.0 4182.0 4198.0 4197.5 $ REMARKS: PASS 2 (REPEAT PASS). /??MATCH.OUT CN WN FN COUN STAT .$ : BP EXPLORATION (ALASKA) : MPI - 07 : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: Tape File Start Depth = 4227.000000 Tape File End Depth = 3875.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1411 datums Tape Subfile: 3 69 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 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 2193.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 4226.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SBAR PCM GR P/T $ SINKER BAR SINKER BAR PCM/CCL GAMMA RAY PRES SURE / TEMPERATURE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 09-NOV-95 FSYS REV. J001 VER. 1.1 1004 09-NOV-95 6885.0 4215.0 2200.0 4210.0 2400.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 8255XA .O00 7425.0 .0 SOURCE WATER 8.33 .0 90.0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMA'LIZ. · 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): REMARKS: PASS 1 (MAIN PASS) . $ .0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPI - 07 : MILNE POINT/SBP : 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 GAPI 4 4 F/MN 4 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: 164 Tape File start Depth = 4227.000000 Tape File End Depth = 2179.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49161 datums Tape Subfile: 4 239 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3888.5 $ LOG HEADER DATA STOP DEPTH 4224.0 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 SBAR PCM GR P/T $ SINKER BAR SINKER BAR PCM/CCL GAMMA RAY PRES SURE / TEMPERATURE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 09-NOV-95 FSYS REV. J001 VER. 1.1 952 09-NOV-95 6885.0 4215.0 2200.0 4210.0 2400.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 8255XA .O00 7425.0 .0 SOURCE WATER 8.33 .0 90.0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP ~;ORM~.LIZi 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): REMARKS: PASS 2 (REPEAT PASS). $ .0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) · . MPI - 07 : MILNE POINT/SBP : 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 1 1 F/MN 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 29 Tape File Start Depth = 4227.000000 Tape File End Depth = 3875.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8457 datums Tape Subfile: 5 104 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS 95/11/21 01 **** REEL TRAILER **** 95/11/21 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 21 NOV 95 3:53p Elapsed execution time = 1.53 seconds. SYSTEM RETURN CODE = 0