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Home My WebLink About196-0761. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,400 feet N/A feet true vertical 7,286 feet N/A feet Effective Depth measured 8,306 feet 8,027 & 8,142 feet true vertical 7,210 feet 6,986 & 7,078 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 7,921' 6,901' 7" Versatrieve Packers and SSSV (type, measured and true vertical depth)7" BWD Sump N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 470psi 3,090psi 5,410psi 5,750psi 7,240psi8,389' 7,278' Burst 1,490psi 3,652'Surface Production 20" 9-5/8" 7" 110' 3,652' MILNE PT UNIT K-37 Plugs Junk measured Length Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-076 50-029-22674-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0375133 MILNE POINT / KUPARUK RIVER OIL measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 110' Size 110' 3,501' Casing Conductor 8,389' N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16 540 2034 1401 0 00 214 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 322-552 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 11:57 am, Dec 06, 2022 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.12.06 09:18:44 -09'00' David Haakinson (3533) WCB 11-29-2024 DSR-12/6/22 RBDMS JSB 120822 _____________________________________________________________________________________ Revised By: TDF 12/5/2022 SCHEMATIC Milne Point Unit Well: MPU K-37 Last Completed: 11/19/2022 PTD: 196-076 TD =8,400’ (MD) / TD = 7,287’(TVD) 20” KB Elev.: 28’/ GL Elev.: 33’ (Nabors 27E) 7” 3 5 &6 7 8&9 10 9 12 13 14 15 9-5/8” 1 2 3/8” SS Capstring 16 KUP C Sands PBTD =8,306’(MD) / PBTD = 7,210’(TVD) 4 KUP B Sands 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 3,652’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 8,389’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / 8rd EUE 2.347 Surface 7,921’ 3/8” Capstring Stainless Steel N/A Surface 7,921’ JEWELRY DETAIL No Depth Item 1 159’ GLM #2: w/ .25'' ORIFICE 2 7,741’ GLM #1 w/ DGLV 3 7,800’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 7,843’ Ported Sub & Discharge Head: 5 7,852’ Pump #2: 538PMSXD FLEX27 82 FER H6 6 7,870’ Pump #1: 538PMSXD 20 GINPSHH H6 FER 7 7,880’ Intake & Gas Separator: GPXARCINT FER H6 & 538GM2T HV E V X MT HS FER 8 7,886’ Upper Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB PFSA 9 7,893’ Lower Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB PFSA 10 7,900’ Motor: 562XP S CS 250 Hp/2505 V/ 61 A 11 7,916’ Sensor w/ Centralizer –Bottom @ 7,921’ 12 8,027’ 7” Versatrieve Packer 13 8,060’ Closing Sleeve Assy. 3.5”, 9.2ppf , N-80, LTC Blank Pipe (ID=2.992”) 14 8,076’ 3.5”, .020 Ga. All weld screen ID= 2.992”, 3.5” Seal Unit 15 8,124’ 7” BWD Sump Packer 16 8,158’ 3.5” XN Nipple ID= 2.635”PX Plug Installed PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 8,094’ 8,140’ 7,039’ 7,076’ 46 Unknown 5spf / Open Kup. C Sands 8,094’ 8,140’ 7,039’ 7,076’ 46 11/16/1996 12spf / Open Kup. B Sands 8,158’ 8,174’ 7,090’ 7,103’ 16 Unknown 5spf / Open Perforation Charge Detail: “32 gm. RDX Alpha Jet 135 / 45 Deg Phasing (0.44” EHD, 32.1” TTP) 4 spf shot on 24g RDX 43C Big Hole 0 Deg Phasing 12 spf shot on 11/16/1996 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 30” Hole 9-5/8" Cmt w/ 779 sks PF “E”, 686 sx Class “G”, 250 sx PF “C” in 12-1/4” Hole 7” Cmt w/ 305 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 42 deg. @ 3,700’ Max Hole Angle through perforations = 36.9 deg. TREE & WELLHEAD Tree 5M CIM 2-9/16” Wellhead 11” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., EUE lift threads, 2.5” CIW H BPV profile GENERAL WELL INFO API: 50-029-22674-00-00 Drilled and Cased by Nabors 4-ES - 11/28/1996 Completed with ESP by Nabors 4ES – 8/2/1996 Frac Pack & 2nd ESP Completion w/ Nabors 4-ES – 11/17/1996 RWO w/ Nabors 4-ES – 11/1/2000 RWO w/ Nabors 4-ES – 11/1/2003 ESP Replacement w/ 3S – 7/28/2007 ESP Replacement w/ Doyon 16 – 3/4/2014 ESP Replacement w/ Nordic 3 – 4/18/2015 WELL STIMULATION 11/17/1996 – Frac’d with 6,400lbs. of 20/40 Propant behind pipe. Well Name Rig API Number Well Permit Number Start Date End Date MP K-37 ASR#1 50-029-22674-00-00 196-076 11/16/2022 11/19/2022 No operations to report. Terminate the ESP Cable through the Hanger. Test Cable good. Monitor the cable continuity while landing hanger. RILDS. BPV is in the Hanger. PUW=65K, SOW=44K. 6 hour fluid loss to the formation = 10 bbl. Total fluid loss for the work over = 475 bbl. Blow Down all circulating lines and equipment. Bleed down accumulator. Secure cellar and well head. R/D Catwalk. Start rigging down. Rig Released at 12:00 Hours. 11/19/2022 - Saturday No operations to report. 11/22/2022 - Tuesday 11/20/2022 - Sunday No operations to report. 11/21/2022 - Monday 11/18/2022 - Friday Rack and Tally 2-7/8" EUE Completion. Hang ESP Cable Sheave. Pull ESP Cable and Cap line through Sheaves to the floor. M/U ESP; Centralizer, Motor, Lower & Upper Tandem Seals, Gas Sep. Pump 1 & 2, Ported Sub & Discharge Head. Service pumps as per Baker Rep. Test ESP Cable for continuity. RIH with 2-7/8" EUE / ESP completion as per well program detail T/7900' MD. Test ESP cable every 2000'. Pump 5 BPH for hole fill. PUW = 63 K, SOW = 42K;Make up Landing Joint and Tubing Hanger. 11/16/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Hooking up all circulating lines and equipment. Hook up 6" Flow line. Take on 40 bbls. fresh water for testing and 130 bbls. 8.5 ppg. Brine for the work over. Fill the BOP Stack and R/U Testing equipment. Test BOPE as per state approved Sundry 250 psi low / 2500 psi high. All tests charted for 5 minutes each. Witness of test was waived by AOGCC Rep. Sully Sullivan. The completed 10-424 form has been submitted to the AOGCC. R/D all testing equipment. Blow down all circulating lines and equipment. R/U ESP Cable Sheave and Spooler. Run Rope through the sheaves to spooler. P/U Tee Bar and pull CTS Plug. Check for well pressure. Pull BPV. M/U Landing joint. BOLDS. Pull 66K to off seat Hanger. Pull Hanger to the floor with PUW of 68K. Pump 30bbl. 8.5 Brine, with no fluid to surface. L/D Landing joint and Hanger. POOH Laying down 2-7/8" EUE Completion F/ 7924' T/ 1650' at report time. Inspect and Account for all tubulars and hardware that is recovered. Pump 2X Pipe Displacement for hole fill. 11/17/2022 - Thursday Continue to POOH Laying down 2-7/8" EUE Completion. Recovered a total of 226 good joints. 18 bad joints. 2 GLM's. 1 XN Nipple. 130 Cross collar clamps. 4 Protectolizers. 1 Motor Clamp. Note: The last +/- 1000' of ESP cable was damaged and blown out. Also lost the small door off of one of the Protectolizers. L/D ESP Assembly. Pump was locked up. Found clean oil in the motor and seals;R/D ESP Handling Equipment. Clean the rig floor. Move pipe racks to allow room for Slickline. MIRU Halliburton Slickline. Run #1 with 5.9" Gauge Ring / Junk Basket. RIH T/ 8082' SLM. Recovered 3 cups of pieces of Rubber and metal from the damaged ESP cable. Run #2 with same GR / JB. Recovered 1 cup of Rubber and metal from the damaged ESP cable. Run #3 with KJ, 3.5" Centralizer, Dual 3.5" Magnet, 1.75" Magnet. No Recovery of the missing door. Run #4 KJ, 2.5" Centralizer, 3.5" BLB. Tag at 8082' SLM. Run#5 KJ, 2' X 1-7/8" Stem, 3.5"BLB, 2.30" Centralizer. Tag bottom at 8170' SLM;Run #6 QL, KJ, 5' X 1-7/8" Stem, 2.7" Centralizer, 3.5" XN Plug with P-Bottom. Unable to get past Closing Sleeve Assy. at 8060' SLM;Run #7 QC, KJ, 3.5" RXN, with 3.5" PXN Plug. Successful set PXN Plug in XN Nipple at 8158" MD. Run #8 QC, XO, 2.5 SB W/ P-Prong. Tagged up at 8060';Run #9 RS, Stem, XO, Centralizer, P-Prong. Successful set into PXN Plug at 8158 MD. R/D Halliburton Slickline. 18 bad joints. 2 GLM's. 1 XN Nipple. 130 Cross collar clamps. 4 Protectolizers. 1 Motor Clamp. Note: The last +/- 1000' of ESP cable was damaged and blown out. Also lost the small door off of one of the Protectolizers. L/D ESP Assembly. Pump was locked up. Found clean oil in the motor and seals;R/D ESP Handling Equipment. Continue to POOH Laying down 2-7/8" EUE Completion. Recovered a total of 226 good joints. RIH with 2-7/8" EUE / ESP completion as per well program detail T/7900' MD. Test ESP cable every 2000'. Pump 5 BPH for hole fill. PUW = 63 K, SOW = 42K;Make up Landing Joint and Tubing Hanger Terminate the ESP Cable through the Hanger. Test Cable good 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, December 19, 2022 3:04 PM To:Charles Huntington - (C) Cc:Regg, James B (OGC) Subject:RE: BOPE Test MPU K-37 , 11/16/2022 I made a minor revision, changing the well name from PBU to MPU K‐37. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Charles Huntington ‐ (C) <Charles.Huntington@hilcorp.com> Sent: Wednesday, November 16, 2022 6:52 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS ‐ ASR ‐ Well Site Managers <AlaskaNS‐ASRWellSiteManagers@hilcorp.com> Subject: BOPE Test MPU K‐37 , 11/16/2022 Please find attached Test Form for MPU‐K‐37 on 11/16/2022 Thank you, Charles Huntington 907‐385‐1266 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Some people who received this message don't often get email from charles.huntington@hilcorp.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit K-37PTD 1960760 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:11/16/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1960760 Sundry #322-552 Operation:Drilling:Workover:x Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2259 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1825 P Check Valve 0 NA 200 psi Attained (sec)20 P BOP Misc 0 NA Full Pressure Attained (sec)56 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2133 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 27 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/14/2022 8:07 Waived By Test Start Date/Time:11/16/2022 10:00 (date)(time)Witness Test Finish Date/Time:11/16/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Hilcorp Test preformed w/ 2-7/8" test joint. Bottle precharge pressure 1000 psi. C.Pace / J. Werlinger Hilcorp Alaska LLC A.Hiem / C. Huntington MPU K-37 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2022-1116_BOP_Hilcorp_ASR1_MPU_K-37          J. Regg; 12/27/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp ASR1 Date:Tuesday, December 27, 2022 11:55:54 AM Attachments:2022-1116_BOP_Hilcorp_ASR1_MPU_K-37.pdf MPU K-37 (PTD 1960760) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221116-1 Well API # PTD # Log Date Log Company Log Type AOGCC Eset# MPU KͲ37 50029226740000 196076 11/8/2022 READ CaliperSurvey MPU KͲ34 50029227120000 19616911/9/2022 READ CaliperSurvey Please include current contact information if different from above. T37261 T37262 By Meredith Guhl at 2:01 pm, Nov 16, 2022 MPU KͲ37 50029226740000 196076 11/8/2022 READ CaliperSurvey Meredith Guhl Digitally signed by Meredith Guhl Date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DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϯϲ͘ϵĚĞŐ͘ dZΘt>>, dƌĞĞϱD/DϮͲϵͬϭϲ͟ tĞůůŚĞĂĚϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϮͲϳͬϴ͟&DdďŐ͘,ŶŐƌ͕͘hůŝĨƚƚŚƌĞĂĚƐ͕ Ϯ͘ϱ͟/t,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϳϰͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰͲ^ͲϭϭͬϮϴͬϭϵϵϲ ŽŵƉůĞƚĞĚǁŝƚŚ^WďǇEĂďŽƌƐϰ^ʹϴͬϮͬϭϵϵϲ &ƌĂĐWĂĐŬΘϮŶĚ^WŽŵƉůĞƚŝŽŶǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭϳͬϭϵϵϲ ZtKǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭͬϮϬϬϬ ZtKǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭͬϮϬϬϯ ^WZĞƉůĂĐĞŵĞŶƚǁͬϯ^ʹϳͬϮϴͬϮϬϬϳ ^WZĞƉůĂĐĞŵĞŶƚǁͬŽǇŽŶϭϲʹϯͬϰͬϮϬϭϰ ^WZĞƉůĂĐĞŵĞŶƚǁͬEŽƌĚŝĐϯʹϰͬϭϴͬϮϬϭϱ t>>^d/Dh>d/KE ϭϭͬϭϳͬϭϵϵϲʹ&ƌĂĐ͛ĚǁŝƚŚϲ͕ϰϬϬůďƐ͘ŽĨ ϮϬͬϰϬWƌŽƉĂŶƚďĞŚŝŶĚƉŝƉĞ͘ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ STATE OF ALASKA AL.._r<A OIL AND GAS CONSERVATION COMiv,.,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LI Plug Perforations U Fracture Stimulate LI Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ESP Change-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 196.076 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22674-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375133 Milne Pt Unit KR K-37 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8,400 feet Plugs measured N/A e ECEIVED true vertical 7,286 feet Junk measured N/A feet MAY 2 2 2015 8,027 Effective Depth measured 8,306 feet Packer measured 8,124 feet AOGCC 6,986 true vertical 7,210 feet true vertical 7,078 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1,490psi 470psi Surface 3,652' 9-5/8" 3,652' 3,501' 5,750psi 3,090psi Intermediate Production 8,389' 7" 8,389' 7,278' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic feet ANNE© ju 020 `' True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 7,924' 6,904' 7"Versatrieve 8,027'/6,986' Packers and SSSV(type,measured and true vertical depth) 7"BWD Sump N/A 8,124'/7,078' N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 500 112 Subsequent to operation: 3 2 1,645 0 200 14.Attachments(required per 20 AAC 25.070.,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Lj Gas U WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SU SP❑ 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: 315-202 Contact Chris Kanyer Email ckanver(cr�.hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 5/21/2015 Form 10-404 Revised 5/2015 311., s-..,26,-/S' SubmitQriginal Only e 5-m, ,--- RBDMS MAY 2 9 2015 Milne Point Unit . ii • Well: MPU K-37 SCHEMATIC Last Completed: 3/3/2014 Hilcorp Alaska,LLA; PTD: 196-076 CASING DETAIL KB Elev.:28/GL Elev.:33'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 3,652' 7" Production 26/L-80/Btc Mod 6.151 Surface 8,389' di 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.347 Surface 7,924' 3/8" Capstring Stainless Steel N/A Surface 7,924' JEWELRY DETAIL No Depth Item 95/g, a 1 170' GLM 2 7,704' GLM 3 7,849' 2-7/8"XN-Nipple(2.25 No-go ID) 4 7,860.7' Discharge Head:GPDIS 5 7,861' Pump:119P23/SXD 6 7,878' Gas Separator:GSTHVVX H6 7 7,884' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 3/8"SSCapstring. 8 7,891' Lower Tandem Seal:GSB3DBLT SB/SB PFSA CL5 9 7,898' Motor:MSP1-325/210hp/2,145V/59A 10 7,920' Phoenix XT150 w/Centralizer-Bottom @ 7,924' 11 8,027' 7"Versatrieve Packer 12 8,060' Closing Sleeve Assy.3.5",9.2ppf,N-80,LTC Blank Pipe(I0=2.992") 13 8,076' 3.5",.020 Ga.All weld screen ID=2.992",3.5"Seal Unit 14 8,124' 7"BWD Sump Packer 15 8,158' 3.5"XN Nipple ID=2.635" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 8,094' 8,140' 7,039' 7,076' 46 Unknown 5spf/Open a 2 Kup.C Sands 8,094' 8,140' 7,039' 7,076' 46 11/16/1996 12spf/Open Kup.B Sands 8,158' 8,174' 7,090' 7,103' 16 Unknown 5spf/Open Perforation Charge Detail:"32 gm. RDX Alpha Jet 135/45 Deg Phasing(0.44"EHD,32.1"TTP)4 spf shot on 24g RDX 43C Big Hole 0 Deg Phasing 12 spf shot on 11/16/1996 f 3 WELL INCLINATION DETAIL KOP @ 2,000' Max Hole Angle=42 deg. @ 3,700' 4 Max Hole Angle through perforations=36.9 deg. s OPEN HOLE/CEMENT DETAIL j 20" Cmt w/250 sks of Arcticset I in 30"Hole • 6 9-5/8" Cmt w/779 sks PF"E",686 sx Class"G",250 sx PF"C"in 12-1/4"Hole 7&6 7" Cmt w/305 sks Class"G"in 8-1/2"Hole 1, TREE&WELLHEAD 9 Tree 5M CIM 2-9/16" Wellhead 11"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,EUE lift threads, .' 2.5"CIW H BPV profile GENERAL WELL INFO �_J 11 API:50-029-22674-00-00 12 Ti.iiiiiiii iiiiiiiiii Drilled and Cased by Nabors 4-ES -11/28/1996 13allill Mil 1-SCS Completed with ESP by Nabors4ES-8/2/1996 Frac Pack&2nd ESP Completion w/Nabors 4-ES-11/17/1996 RWO w/Nabors 4-ES-11/1/2000 14 • ti. RWO w/Nabors 4-ES-11/1/2003 15;'" =}KUP B Sands ESP Replacement w/35-7/28/2007 ESP Replacement w/Doyon 16-3/4/2014 7"1 ►' ESP Replacement w/Nordic 3-4/18/2015 TD=8,400'(MD)/TD=7,287'(TVD) WELL STIMULATION PBTD=8,306'(MD)/PBTD=7,210'(TVD) 11/17/1996-Frac'd with 6,400Ibs.of 20/40 Propant behind pipe. Created By:TDF 5/21/2015 Hilcorp Alaska, LLC ililcorp ,,:,,�:,. , , , Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K-37 50-029-22674-00-00 196-074 4/14/2015 4/18/2015 Daily Operations: 4/8/15-Wednesday No operations to report. 4/9/15-Thursday No operations to report. 4/10/15-Friday No operations to report. 4/11/15-Saturday No operations to report. 4/12/15-Sunday No operations to report. 4/13/15-Monday No operations to report. 4/14/15-Tuesday Accepted rig, MIRU Nordic 3 and associated equipment. Loaded pits w/hot seawater. Pulled BPV,spotted kill tank RU hard line Tested to 3,000psi.Started pumping, Rev cir @ 4bpm, broke circulation at 57bbls,continued cir until well cleaned up.SD pump,386 bbls pumped,299bb1s returned,87bbls lost.Set BPV,blow return lines dry, ND Tree/NU Bop's. Pulled BPV and installed TWC. Filled stack and performed shell test 250psi low/3,000psi high.Tested BOPE per AOGCC reg.,annular 250psi low/2,500psi high.Valves 250psi low/3,000psi high, rams 250psi low/3,000psi high. Performed Koomey drawdown test and gas dection. Hilcorp Alaska, LLC „i,,.,,,.,, ,,,,, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K-37 50-029-22674-00-00 196-074 4/14/2015 4/18/2015 Daily Operations: 4/15/15-Wednesday Continued testing BOPE,tested BOPE,Annular 250psi low/2E500psi high.Valves 250psi l,ow/2,500ps.i high. Rams 250psi low/2,500psi high. Performed Koomey drawdown test and gas dection. No failures recorded. RU test equipment and pulled TWC. PU landing jt MU to tbg hanger, pulled 110k to unseat tubing hanger and pulled to rig floor. meg esp cable. Decompleted hanger BO/LD same. Pull stand and thread cable to spooler.TOOH w/esp completion,tallied stands out LD GLM's and XN nipple. BO/LD ESP assembly. Note:from xn-nipple to centralizer is coated with scale. PU/MU casing scraper muleshoe assembly,TIH to 7,800' reciprocated scraper thru test packer,set depth. Continued TIH to 8,000'. MU top drive, lined up manifold to reverse circulate.Started pumping at 3bpm down casing, Broke cir and increased rate to 6bpm. Reversed circulated 3 tubing volumes (140bbIs), 1st volume returns scale, 2nd volume returns min scale, 3rd volume returns clean. SD pump. POOH with cleanout assembly and LD same, LD jt 4,30, 200 and 201 identified bad from caliper log. PU/MU 7' Champ test packer and tallied,TIH w/same. 4/16/15-Thursday �S Continued TIH w/test packer to 7,800'.Set packer 20k compression.Started pumping and pressured up on casing to 1,600psi and held,charted for 30 mins-test ok. Bled off pressure, lined up manifold to reverse circulate.Started pumping 6bpm broke circultation and pumped 2 tbg volumes returns clean,SD pump.TOOH w/champ test packer and LD same. PU/MU dutch riser, MIRU SL tested lubricator to 500psi-test ok. RIH with 2-1/2" bailer and tag @ 8,018'slm.Tried to work thru packer with no luck, POOH L/D same, MU 1-3/4" sample bailer w/2-1/2"swedge and RIH tag 8,122'slm.Tried working down no luck POOH. Bailer full of broken up scale. RD SL. PU/MU BHA mule shoe, 6jts of 2-1/16" CS Hyd and xo, TIH.TIH w/cleanout BHA on 2-7/8"tubing and tagged fill at 8,137'.Started pumping down tbg 5 bpm,Washed down to 8,147' reversed out bottoms up returns scale and sand. Started pumping down tubing 5bpm,washed down to 8.159' reversed 2 tbg volumes scale and sand. Returns clean SD pump. 4/17/15-Friday MIRU acid truck and pump tuck. MU hose to rigs manifold and test to 1,500psi. Pumped down tubing 3bbls of 40/60 Methanol,5bbls 10%HCL acid,3 bbl 40/60 methanol flush. Isolated acid pump and RU. Pumped 36 bbls of seawater with rig pump down to tbg and spotted acid, let acid soak for 1 hr. Lined up manifold and revered circulated out acid pill w/90 bbls to kill tank,SD pump. Prep rig floor to trip pipe.TOOH standing back 2-7/8" and LID xo 6jts of 2-1/16" CS Hydr and mule shoe. MU dutch riser to BOP stack, MIRU SL,tested Lubricator to 1,500psi-test ok. MU 2"JDC pulling tool w/2.5" swedge centralizer and RIH latched prong @ 8,148',jarred prong free and POOH, LD prong. MU 3"GS pulling tool and RIH latched plug,jarred free and POOH w/px plug. RDMO SL, RD Dutch riser. PU MU and service new ESP assembly,sting new cable and Cap string over sheave make motor and cap connection.Test all cap string check break @ 3,400 psi. RIH w/new ESP on 2-7/8" 8rd L-80 tbg with XN nipple and Lower GLM, continue RIH check cable and cap every 2,000'. 4/18/15-Saturday PU top GLM and drill noticed wrong GLM was RIH on bottom,changed dummy valve out with orifice valve, PU top GLM continued TIH w/ESP completion from hanger depth @ 8,158'. Depths as follows: Hanger, Pup,4 jts 2-7/8 L-80 6.5#tbg, pup,GLM @170', 237 jts tbg, pup GLM @7,704',4 jts tbg,XN Nipple@ 7,849', pup. Head @ 7,861,gas separator @ 7,879', Tandem Seals @ 7,884', Motor @ 7,898', EOT Centralizer @7,922. PU landing joint. Install hanger and penetrators.Test cable and cap string. Cut and splice cable connector and cap string, install same. Meg check connector. Land string SW 100K up 87k down. Run in lock down screws. ND BOPE. NU tree.Test all breaks and void 250psi low/5,000psi high. RDMO Nordic 3, D-mobe to K-34 4/19/15-Sunday No operations to report. 7Alaska Oil and Gas r-CrOF �\��j,�sTHE STATE��, of Conservation Commission _ ALASIc:A 333 West Seventh Avenue ' = J GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 04t, ALA914� Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED r az. Chris Kanyer Operations Engineer - Vq Hilcorp Alaska, LLC I Ij 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-37 Sundry Number: 315-202 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. rfitCJ Commissioner DATED this!day of April, 2015 Encl. RECEIVED STATE OF ALASKA APR 0 6 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO CC 20 AAC 25.280 1.Type of Request. Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well[l Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing[r Time Extension ❑,-�/ Operations Shutdown❑ Re-enter Susp.Well El Stimulate❑ Alter Casing❑ Other. Es? a--0 ),..i [ 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Numb r. Hilcorp Alaska,LLC - Exploratory ❑ Development 2. 196-076 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22674-00-00, 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.432C Will planned perforations require a spacing exception? Yes ❑ No ❑, , Milne Pt Unit KR K-37 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375133 ' Milne Point Field/Kuparuk River Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,400' 7,286- 8,306 ' 7,210 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural • Conductor 110' 20" 110' 110' 1,490psi 470psi Surface 3,652' 9-5/8" 3,652' 3,501' 5,750psi 3,090psi Intermediate Production 8,389' 7" 8,389' 7,278' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): I See Attached Schematic ' See Attached Schematic 2-7/8" 6.5#/L-80 7,932 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"Versatrieve&7"BWD Sump Packers and N/A , 8,027(MD)&8,142(MD)&6,986(TVD)&7,078(TVD) 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch [ Exploratory ❑ Stratigraphic❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/16/2015 Oil Q • Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 4/6/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 -202 Plug Integrity ❑ BOP Test II Mechanical Integrity Test ❑ Location Clearance ❑ Other: ' tic.., P O-L 04i- APPROVED Exception Required? Yes ❑ No El/ Subsequent Form Required: / ` ��///��7 THERO MM S 1I7/ / / Approved by: � COMMISSIONER THE COMMISSION �yJ Date:tJ!� y'7-i� "14� 1 ) II- //{L4 �"; '1 Submit Form and Form 10-403(Revised /2012) OrRdiGcitiNs ri i for 12 months fr9jn t e d e gkapproval. Attach sin Date 1 ` '4e r. 3 RBDS� APR 9 2016 , ii Well Prognosis • Well: MPK-37 Hilcorp Alaska,LL Date:4/6/2015 Well Name: MPK-37 API Number: 50-029-22674-00-00 Current Status: SI Producer Pad: K Pad Estimated Start Date: April 16, 2015 Rig: Nordic 3 Reg.Approval Req'd? April 15, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-076 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907)250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1550809 Current Bottom Hole Pressure: —3,057 psi @ 7,000' TVD (Last BHP measured 3/4/2015) Maximum Expected BHP: —3,057 psi @ 7,000'TVD (No new perfs being added) Max.Allowable Surface Pressure: 166 psi (Based on actual reservoir conditions and water cut of 88% (0.427psi/ft)with an added safety factor of 1000' ND of oil cap) Brief Well Summary: The Milne Point K-37 well was drilled as a Kuparuk development well that TD'd at 8,400' and ran and cemented 7" casing in November 1996. The initial ESP completion installs were troublesome and first three installs were in 1996. Subsequent ESPs failed and were replaced in 2000, 2003, 2007, and 2014. The recent pump failed October 4, 2014. The most recent casing pressure test performed after initial cementing of casing on X45/1/1996.A casing pressure test will be completed during this workover. Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. RWO Objective: Pull ESP, run casing scraper, pressure test casing, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000 jihigh, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. rT4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure • 1111 Well Prognosis Well: MPK-37 Hilcorp Alaska,LL Date:4/6/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion from 7,932'to surface and lay down same. Contingency: (Pending condition of pulled completion—sand/scale in pump) 6. RIH with cleanout BHA to+/-8,000'. POOH with same. 7. RIH and set test packer at+/-7,800' (within 500ft of open perforations). 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 9. RU slickline.Attempt to pull plug in XN nipple at 8,158'. RD Slickline. 10. MU and RIH with ESP with gas separator and 3/8" chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-7,932'. Land tubing hanger. 11. ND BOP, NU and tree. 12. RDMO workover rig and equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU K-37 II SCHEMATIC Last Completed: 3/3/2014 Ili!cora Alaska,LLC PTD: 196-076 CASING DETAIL KB Elev.:28/GL Elev.:33'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm 4 ::' d 20" Conductor 91.1/NT8OLHE/N/A N/A Surf 110' 20" iii ; ; 9 5/8" Surface 40/L-80/Btrc. 8.679 Surf 3,652' 7" Production 26/L-80/Btc Mod 6.151 Surface 8,389' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.347 Surf 7,932' S' �' JEWELRY DETAIL No Depth Item ,J1 143' Camco 2-7/8"x 1"KBMM GLM 2 7,675' Camco 2-7/8"x 1"KBMM GLM 95/8" 3 7,831' 2-7/8"XN-Nipple(2.25 No-go ID) 4 7,875' Pump 119P23,Model SXD 5 7,892' Gas Separator 6 7,898' Tandem Seal Section GSB3DBBFERHLSSCVH6S/BS/BPFS 7 7,911' Motor,250HP,2380 Volt,53 amp,Model KMH 8 7,928' PumpMate w/6 Fin Centralizer (6,976'TVD) 9 7,932' Centralizer Bottom 10 8,027' 7"Versatrieve Packer 11 8,060' Closing Sleeve Assy.3.5",9.2ppf,N-80,LTC Blank Pipe(ID=2.992") 12 8,076' 3.5",.020 Ga.All weld screen ID=2.992",3.5"Seal Unit 13 8,124' 7"BWD Sump Packer 14 8,158' 3.5"XN Nipple ID=2.635" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Kup.C Sands 8,094' 8,140' 7,039' 7,076' 46 Unknown Sspf/Open Kup.C Sands 8,094' 8,140' 7,039' 7,076' 46 11/16/1996 12spf/Open Kup.B Sands 8,158' 8,174' 7,090' 7,103' 16 Unknown Sspf/Open 2 Perforation Charge Detail:"32 gm. RDX Alpha Jet 135/45 Deg Phasing(0.44"EHD,32.1"TTP)4 spf shot on 24g RDX 43C Big Hole 0 Deg Phasing 12 spf shot on 11/16/1996 WELL INCLINATION DETAIL KOP @ 2,000' i I 13 Max Hole Angle=42 deg. @ 3,700' � :% 1 i % Max Hole Angle through perforations=36.9 deg. li+ °`4 OPEN HOLE/CEMENT DETAIL ; 20" Cmt w/250 sks of Arcticset I in 30"Hole d 9-5/8" Cmt w/779 sks PF"E",686 sx Class"G",250 sx PF"C"in 12-1/4"Hole •..A= 5 6 7" Cmt w/305 sks Class"G"in 8-1/2"Hole 111 i' TREE&WELLHEAD t 7 t, Tree SM CIM 2-9/16" 1 11"5M FMC Gen 5A,w/2-7/8"FMCTbg.Hngr.,EUE lift threads, Wellhead 2 5"CIW H BPV profile w'41 I t .6 GENERAL WELL INFO IIIc ,, "y API:50-029-22674-00-00 0r Drilled and Cased by Nabors 4-ES -11/28/1996 iB Completed with ESP by Nabors 4ES-8/2/1996 11 is Frac Pack&2"d ESP Completion w/Nabors 4-ES-11/17/1996 I2;c RWO w/Nabors 4-ES-11/1/2000 12 }I0 RWO w/Nabors 4-ES-11/1/2003 ' Replacement w/ - 7 134 r; A ESPESP Replacement w/3S Doyon7/28/200/ 16-34/2014 14 - }KUPBsands WELL STIMULATION 11/17/1996-Frac'd with 6,400Ibs.of 71 • 20/40 Propant behind pipe. TD=8,4W(M))/TD=7,287(TVD) PBTD=8,306'(MD)/PBTD=7,210'(TVD) Created By:TDF 11/7/2014 Milne Point Unit Well: MPU K-37 II PROPOSED Last Completed: 3/3/2014 Ililcorp Alaska,LLC PTD: 196-076 CASING DETAIL KB Elev.:28'!GL Elev.:33'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm j20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' 2O I 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 3,652' 7" Production 26/L-80/Btc Mod 6.151 Surface 8,389' r' 1 ., TUBING DETAIL .: 2-7/8" Tubing 6.5/L-80/8rd EUE 2.347 Surface ±7,932' 3/8" Capstring Stainless Steel N/A Surface ±7,932' 4 a , JEWELRY DETAIL 0 a No Depth Item i ii 1 ±143' GLM 35/g,"4 2 ±7,675' GLM 3 ±7,831' 2-7/8"XN-Nipple(2.25 No-go ID) 4 ±7,875' Pump 5 ±7,892' Gas Separator 6 ±7,898' _ Tandem Seal Section 7 ±7,911' Motor 3/8"SS Capstring 8 ±7,928' PumpMate w/6 Fin Centralizer 9 ±7,932' Centralizer Bottom 10 8,027' 7"Versatrieve Packer 11 8,060' _ Closing Sleeve Assy.3.5",9.2ppf,N-80,LTC Blank Pipe(ID=2.992") 12 8,076' 3.5",.020 Ga.All weld screen ID=2.992",3.5"Seal Unit 13 8,124' 7"BWD Sump Packer 14 8,158' 3.5"XN Nipple ID=2.635" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Kup.C Sands 8,094' 8,140' 7,039' 7,076' 46 Unknown 5spf/Open Kup.C Sands 8,094' 8,140' 7,039' 7,076' 46 11/16/1996 _ 12spf/Open 2 Kup.B Sands 8,158' 8,174' 7,090' 7,103' 16 Unknown 5spf/Open Perforation Charge Detail:"32 gm. RDX Alpha Jet 135/45 Deg Phasing(0.44"EHD,32.1"TTP)4 spf shot on 24g RDX 43C Big Hole 0 Deg Phasing 12 spf shot on 11/16/1996 WELL INCLINATION DETAIL I ti) 3 KOP @ 2,000' it 1 I i'4 Max Hole Angle=42 deg. @ 3,700' Max Hole Angle through perforations=36.9 deg. iw'', 1 t.4 OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 30"Hole h 5 6 9-5/8" Cmt w/779 sks PF"E",686 sx Class"G",250 sx PF"C"in 12-1/4"Hole 17 T; a ,!•., i; 7" Cmt w/305 sks Class"G"in 8-1/2"Hole 1 TREE&WELLHEAD I4 ' Tree 5M CIM 2-9/16" .A 6 Wellhead 11"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,EUE lift threads, V II 2.5"CIW H BPV profile 1 liAPI: gGENERAL WELL INFO 50-029-22674-00-00 6 44;64_4 4:io Drilled and Cased by Nabors 4-ES -11/28/1996 ,, W #1 Completed with ESP by Nabors 4ES-8/2/1996 i I-12 - 1 KUP C Sarxls Frac Pack&2"d ESP Completion w/Nabors 4-ES-11/17/1996 r RWO w/Nabors 4-ES-11/1/2000 i. RWO w/Nabors 4-ES-11/1/2003 13* CI A ESP Replacement w/35-7/28/2007 14 v, KIP B Sands ESP Replacement w/Doyon 16-3/4/2014 -PcY 1WELL STIMULATION ;f 11/17/1996-Frac'd with 6,400lbs.of TD=8,400 (MD)/TD=7,287(TVD) 20/40 Propant behind pipe. PBTD=8,306'(MD)/PBTD=7,210'(TVD) Created By:TDF 11/7/2014 11" BOP Stack r 1 OO • is i i � Hydril 11" 5M iiiii / ' \___i- i _ Shaffer OD 2 3/8" Rams _ L =0 11" 5M2 7/8-5.5 ..__4:\. I_ variables i Hydril N CO 1� 11" 5M .... Op Blinds _6 — _ 3 Optional valve port ■ I ■ XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~)-0~ 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~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: ~si STATE OF ALASKA RECEIVED AL __,KA OIL AND GAS CONSERVATION CO,....1ISSION MAR 2 7 2014 • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ®GCC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic . 196-076 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22674-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 375133 ' MPK-37 . 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point/Kuparuk River Oil 11. Present well condition summary: Total depth: measured 8400' feet Plugs:(measured) None feet true vertical 7286' feet Junk:(measured) None feet Effective depth: measured 8306' feet Packer: (measured) 8027'-8142' feet true vertical 7210' feet Packer: (true vertical) 6986'-7078' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 38'- 110' 38'- 110' 1490 470 Surface 3616' 9-5/8" 36'-3652' 36'-3501' 5750 3090 Intermediate Production 8356' 7" 33'-8389' 33'-7278' 7240 5410 Liner Perforation Depth: Measured Depth: 8094'-8174' feet SCANNED JUL 1 6 2014 True Vertical Depth: 7040'-7104' feet Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5# L-80 7932' 6910' Packers and SSSV(type,measured and true vertical depth): Gravel Pack Assembly:7"HES Versatrieve 8027' 8142' 6986' 7078' Packer and 7"BWD Sump Packer 12.Stimulation or cement squeeze summary: Intervals treated(measured): RB . 14 2014 Treatment description including volumes used and final pressure: \ 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 480 0 Subsequent to operation: 50 30 669 100 209 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic IN Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: IN Oil 0 Gas 0 WDSPL ®Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: J.E.B.Bolen,564-5110 Email: J.E.B.Bolen@bp.com N/A Printed Name: Joe Lastu Title: Drilling Technologist /I Signature: \) ...--4 Phone: 564-4091 Date: 5/Z(oI�if Form 10-404 Revised 10/2012 ?�� Submit Original Only North America-ALASKA-BP Page 1 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:00AM Rig Release:3/3/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292267400 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/27/2014 00:00 - 03:00 3.00 MOB P PRE PJSM,LAY DERRICK OVER AND SECURE ON STAND -PULL OFF OF WELL MPJ-26,WSL PRESENT, PAD OPERATOR NOTIFIED -POSITION RIG ON PAD FOR BOP REMOVAL -REMOVE BOP FROM CELLAR -INSTALL REAR BOOSTER WHEELS AND FUNCTION CHECK 03:00 - 06:30 3.50 MOB P PRE MOVE OFF OF MPJ-PAD,DOWN TRAC ACCESS ROAD -MOVE PAST I,H,AND G PADS -RIG AT CORNER OF ACCESS ROAD AND MILNE PT SPINE ROAD AT 6:00 -SET DOWN RIG SO CREWS CAN WARM UP AND EAT. -NOTICE MIST FROM REAR BOOSTER JACKING CYLINDOR HYDRAULIC HOSE. -CHANGE OUT HOSE WHILE CREW EATS LUNCH. 06:30 - 09:00 2.50 MOB P PRE MOVE RIG DOWN MILNE POINT SPINE ROAD -MOVE RIG FROM SPINE ROAD,ACCESS ROAD CORNER TO MILNE POINT MAIN CAMP - SET DOWN RIG IN PREPARATION FOR REMOVING REAR BOOSTER. 09:00 - 11:00 2.00 1 MOB P PRE REMOVE REAR BOOSTERS -DISCONNECT REAR BOOSTER HYDRAULICS. -DISCONNECT BOOSTER AND MOVE OFF OF RIG. -STAGE BOOSTER AND LOAD ON TRUCK FOR TRANSPORT TO DOYON 14. -NOTIFY AOGCC OF UPCOMING BOP TEST AT 09:30 HOURS. -STATE RESPONDED AT 10:21 HOURS AND ASKED FOR UPDATE ON MORNING OF 2/28/2014. 11:00 - 15:00 4.00 MOB P PRE MOVE RIG DOWN K PAD ACCESS ROAD. -MOVE RIG DOWN MILNE SPINE ROAD TO K- PAD ACCESS ROAD. -MOVE ONTO K PAD ACCESS ROAD AND MOVE TO K PAD. -RIG ON LOCATION AT 14:00 HOURS. RECEIVED PRIOR APPROVAL FROM WELL TEAM LEAD RICH BURNETT FOR A NIGHT SHIFT WELL KILL SHOULD IT BECOME NECESSARY. 15:00 - 16:00 1.00 MOB P PRE PREP PAD -STAGE RIG FOR MOVING OVER WELL -MOVE SNOW IN PREPARATION FOR SPOTTING RIG. -SPOT MATS AROUND WELL. -REMOVE BOPE FROM CRADLE AND PLACE IN CELLAR Printed 3/17/2014 10:24:09AM North America-ALASKA-BP Page 2 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) ,Start Date:2/27/2014 End Date:3/3/2014 •X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:00AM Rig Release:3/3/2014 Rig Contractor.DOYON DRILLING INC. UWI:500292267400 • Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 16:00 - 16:30 0.50 MOB P PRE MILNE ROADS AND PADS CLEAR NEW SNOW DRIFTS AROUND MPK-37 -INSPECT PITS FOR WEAK AREAS -PIT WATCHER IDENTIFIED TWO QUESTIONABLE AREAS IN PIT#3 16:30 - 17:30 - 1.00 MOB P PRE LAY DOUBLE RIG MATS AROUND MPK-37 17:30 - 19:30 2.00 MOB P PRE PJSM,SPOT RIG OVER WELL,MPK-37 -LOWER CELLAR DOORS,SHIM RIG,SECURE STEPS AND LANDINGS 19:30 - 20:00 0.50 MOB P PRE PJSM,RAISE AND PIN DERRICK RIG WELDER INSPECT AND REPAIR PIT#3 20:00 - 22:00 2.00 MOB P PRE R/U AND SECURE RIG FLOOR -SPOT SLOP TANK,CREW TRAILER,BERM AROUND CELLAR AREA,RAISE CATTLE CHUTE -R/U CELLAR KILL MANIFOLD LINES -ACCEPT RIG AT 22:00 HOURS ON MPK-37 22:00 - 23:00 1.00 WHSUR P DECOMP LOAD PITS WITH 9.8 PPG 120 DEGREE BRINE -BRIDLE DOWN BLOCKS -R/U CIRC LINES TO TREE IN CELLAR -SPOT FLOW BACK TANK 23:00 - 00:00 1.00 WHSUR P i DECOMP !WELL SUPPORT R/U HARDLINE TO FLOW BACK TANK -CONT'R/U FLOOR AND MUD MANIFOLD -OA=150 PSI -IA=500 PSI 2/28/2014 00:00 - 00:30 0.50 WHSUR P DECOMP PERFORM SPCC AND EQUIPMENT CHECK -INSPECT R/U OF CELLAR CIRC LINES AND FLOW BACK TANK 00:30 - 02:00 1.50 WHSUR P DECOMP PJSM,TEST KILL MANIFOLD AND ALL CIRCULATION LINES -250 PSI,3500 PSI,5 MIN,CHARTED -R/U REMOTE SSV RIG FLOOR CONTROL • 02:00 - 02:30 0.50 WHSUR P DECOMP HOLD RIG EVACUATION"FIRE"DRILL -HOLD AAR AND PRE-SPUD MEETING 02:30 - 05:30 3.00 WHSUR P DECOMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST TO 250/3500 PSI,5 MIN,CHART -PULL BPV,R/D WS LUBRICATOR Printed 3/17/2014 10:24:09AM North America-ALASKA-BP Page 3 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:00AM Rig Release:3/3/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292267400 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 08:00 2.50 KILLW P DECOMP PJSM,BEGIN WELL KILL OPERATIONS -TUBING=560 PSI -IA=650 PSI -OA=140 PSI -BLEED DOWN IA FOR 5 MINUTES HOLD 100 PSI ON CHOKE,GAS-NO FLUID RETURNS -OPEN CHOKE,NO PRESSURE OR FLOW. -LINE UP TO PUMP DOWN TUBING WITH 9.8 PPG BRINE. -POST PRESSURES,IA=100 PSI,TUBING= 350 PSI. -EQUALIZE PRESSURE AND BRING ON PUMPS AT 3 BPM WITH 1200 PSI INITIAL CIRCULATING PRESSURE AND 500 PSI ON IA. PUMP 45 BBLS WITH FINAL CIRCULATING PRESSURE OF 375 PSI AND 300 PSI ON IA. CHOKE HELD AT 150 PSI DOWNSTREAM. '-CLOSE CHOKE AND BULLHEAD 17 BBLS 9.8 PPG BRINE AT 3 BPM. -TUBING PRESSURE CLIMBED TO 1250 PSI AND IA PRESSURE CLIMBED FROM 300 PSI TO 2500 PSI.HIGH PRESSURE INDICATED A •HARD BOTTOM BUT AT SHUT DOWN THE PRESSURES BLED OFF READILY TO 0 PSI.OA PRESSURE AT 320 PSI. LOU GRIMALDI WITH AOGCC WAIVED STATES RIGHT OF WITNESS TO BOP TEST AT 06:55 HOURS 2-28-14. 08:00 - 09:00 1.00 KILLW P DECOMP WELL KILL OPERATIONS -OPEN UP TO TAKE RETURNS TO THE FLOW BACK TANK. -BRING ON PUMPS WITH 9.8 PPG BRINE AT 3 BPM AND INCREASE TO 4 BPM WITH 800 PSI ICP AND 1070 FCP FOR 280 BBLS. -IA ICP WAS 250 PSI WITH A FCP OF 170 PSI. OA CLIMBED TO 500 PSI.CHOKE PRESSURE AT START 125 PSI AND 65 PSI AT SHUTDOWN. 09:00 - 09:30 0.50 KILLW P DECOMP -SHUT DOWN TO STRAP FLOW BACK TANK, MONITOR PRESSURES.STRAP INDICATED CLOSE TO A 1 FOR 1 RETURN RATIO WITH 325 BBLS PUMPED AND 309 BBLS BACK. -SUCK OUT FLOW BACK TANK WITH VAC TRUCK UNTIL ROOM TO CONTINUE. 09:30 - 10:00 0.50 KILLW P DECOMP -BRING PUMPS BACK ON AT BPM WITH 1240 PSI ON TUBING AND 160 PSI ON IAAND 70 PSI ON CHOKE. -PUMP REMAINING 128 BBLS OF 9.8 BRINE FOR A TOTAL OF 408 BBLS. -FINAL PRESSURES WERE TUBING 1150 PSI, IA 150 PSI WITH 75 PSI ON THE CHOKE AND OA PRESSURE OF 500 PSI. -SHUT DOWN AND PRESSURE DROPPED TO 0 PSI. -OPEN UP BLEEDER AND WELL ON VAC. -PUMPED A TOTAL CIRCULATION VOLUME OF 453 BBLS AND GOT BACK 414 BBLS FOR A LOSS OF 39 BBLS.INJECTION VOLUME WAS 17 BBLS. Printed 3/17/2014 10:24:09AM North America-ALASKA-BP Page 4 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 'X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:00AM Rig Release:3/3/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292267400 Active datum:Kelly Bushing/Rotary Table(gt61.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 KILLW P DECOMP MONITOR WELL -MONITOR WELL FOR 30 MINUTES,WELL ON SLIGHT VAC. -EMPTY FLOW BACK TANK. -BLEED OF OA PRESSURE FROM 500 PSI TO 0 PSI. 11:00 - 12:00 1.00 KILLW P DECOMP RIG DOWN FROM WELL KILL OPERATIONS -BLOW DOWN CIRCULATING LINES AND CELLAR MANIFOLD. RIG DOWN LINES AND MANIFOLD. 12:00 - 13:00 1.00 WHSUR P DECOMP RIG UP LUBRICATOR -RIG UP LUBRICATOR AND TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-PASS. -INSTALL TWC. 13:00 - 15:30 2.50 WHSUR P DECOMP TEST TWC -RIG UP TO PERFORM TWC TEST. -PERFORM ROLLING TEST FROM BELOW. -TEST TO 500 PSI FOR 5 MINUTES PUMPING AT 1 BPM.PUMPED A TOTAL OF 4 BBLS. BLEED BACK 1 BBL ON SHUT DOWN. -TEST FROM ABOVE TO 250 PSI LOW,3500 .PSI HIGH FOR 5 CHARTED MINUTES EACH- PASS. -FILL ACROSS THE BACKSIDE AT 18 BPH WHILE TESTING TWC. -RIG DOWN. 15:30 - 17:30 2.00 WHSUR P i DECOMP I NIPPLE DOWN TREE -DRAIN TREE -NIPPLE DOWN TREE AND ADAPTER. •-INSPECT HANGER LIFTING THREADS NO DAMAGE. -LH ACME,8-3/4 TURNS AND BOTTOM OUT. 17:30 - 20:00 2.50 BOPSUR P DECOMP NIPPLE UP BOP -M/U TURNBUCKLES,RISER,KOOMEY LINES, MOUSE HOLE,CHOKE AND KILL LINES PERFORM KOOMEY PUMP SYSTEM TEST, FUNCTION HI-LOW BY-PASS 20:00 - 21:30 1.50 BOPSUR P DECOMP R/U BOPE TEST EQUIPMENT -M/U FLOOR VALVES AND TEST JOINTS FOR TESTING 21:30 - 22:00 0.50 BOPSUR P DECOMP FUNCTION TEST ALL RAMS -PERFORM BODY AND SYSTEM TEST F Printed 3/17/2014 10:24:09AM North America-ALASKA-BP Page 5 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:OOAM Rig Release:3/3/2014 Rig Contractor DOYON DRILLING INC. UWI:500292267400 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM,TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -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, CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST -LOU GRIMALDI OF AOGCC WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST -24 HOUR FLUID LOSS=244 BBLS 9.8 PPG BRINE -MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST @ 15 BPH,9.8 PPG BRINE 3/1/2014 00:00 - 02:00 2.00 BOPSUR P DECOMP PJSM,CONT.TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -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, CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST -NO FAILURES -LOU GRIMALDI OF AOGCC WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST 0200 - 02-30 0.50 BOPSUR P DECOMP BLOW DOWN AND R/DALL TEST EQUIPMENT AND FLOOR VALVES -DRAIN BOP OF FRESH WATER 02:30 - 04:00 1.50 WHSUR P DECOMP R/U WELL SUPPORT LUBRICATOR -TEST,250/3500 PSI.5 MIN,CHART -PULL TWC,R/D LUBRICATOR 04:00 - 05:00 1.00 PULL P DECOMP C/O ELEVATORS AND R/U POWER TONGS -R/U CENTRILIFT EQUIPMENT -M/U LANDING JOINT WITH FOSV AND • SCREW INTO HANGER 05:00 - 07:30 2.50 PULL P DECOMP PJSM,PULL HANGER TO RIG FLOOR -CUT ESP CABLE AT BOTTOM OF FIRST JOINT -L/D HANGER AND LANDING JOINT -PLACE SLICK PIPE ACROSS BOP,CLOSE ANNULAR -CBU 1X THRU GAS BUSTER 3 BPM @ 680 PSI. Printed 3/17/2014 10:24:09AM North America-ALASKA-BP Page 6 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 X4-00YWL-E:(1,080,000.00) Project:Milne Point i Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:OOAM Rig Release:3/3/2014 Rig Contractor:DOYON DRILLING INC. UW:500292267400 Active datum:Kelly Bushing/Rotary Table @61.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 08:00 0.50 PULL P DECOMP PJSM,MONITOR WELL. -MONITOR WELL 10 MIN. -BLOW DOWN CIRC LINES AND GAS BUSTER. 08:00 - 09:00 1.00 PULL P DECOMP POH WITH 2 7/8"6.5#8 RD TBG F/7942'MD TO 7635'MD. -LAY DOWN FIRST 15 JTS 1 X 1 TO PIPE SHED AND REMOVE BAD JTS PER WELL PLAN. 09:00 - 10:30 1.50 PULL P DECOMP WELL SLIGHTLY OUT OF BALANCE. -INSTALL FOSV AND CIRC SURFACE TO SURFACE PER WSL. -PUMP 5 BPM @ 1830 PSI. MONITOR WELL 15 MIN. 10:30 - 12:00 1.50 PULL P DECOMP PJSM,POH WITH TBG. CONTINUE TO POH WITH ESP COMPLETION IF/7635'MD TO 6500'MD. LOSSES TO WELL=84 BBLS KWF. 12:00 - 12:30 0.50 PULL P DECOMP SERVICE RIG COMPONENTS. -SERVICE TOP DRIVE,DRAWWORKS,AND FLOOR EQUIPMENT. 12:30 - 23:00 10.50 PULL P DECOMP CONTINUE TO POH WITH 2 7/8"ESP COMPLETION F/6500'MD. -KEEP RUNNING TALLY OF ALL CLAMPS, BANDS,AND FLAT GUARDS -AT 43 STAND OUT,(FROM-4069'MD) OBSERVED CORROSION ON INCREASING NUMBER OF PIPE AND COLLARS -L/D CORRODED JOINTS AS NECESSARY, FLAG ALL BAD JOINTS 23:00 - 00:00 1.00 PULL P DECOMP MONITOR WELL BEFORE PULLING BHA THRU BOP -L/D ESP PUMP AND MOTOR ASSY -24 HOUR FLUID LOSS=87 BBLS 8.9 PPG BRINE -MAINTAIN CONTINUOUS HOLE FILL,LOSS RATE=1 BPH,9.8 PPG BRINE 3/2/2014 00:00 - 02:00 2.00 PULL P DECOMP CONT.L/D ESP MOTOR AND PUMP ASSY -INITIAL FAILURE DIAGNOSIS=TOP PUMP LOCKED UP,TWISTED SHAFT,ELECTRICAL =GOOD -ALL CLAMPS WERE RECOVERED -LASALLE CLAMPS=131 -PROTECTOLIZERS=4 -FLAT GUARDS=2 -TOTAL CORRODED PIPE LAYED DOWN=72 JTS 02:00 - 03:00 1.00 PULL P DECOMP PJSM,LOWER ESP CABLE TRUNK CLEAN AND CLEAR RIG FLOOR 03:00 - 05:00 2.00 RUNCOM P RUNCMP LOAD,STRAP AND DRIFT 2 7/8"EUE 8RD TUBING TO REPLACE CORRODED PIPE LAYED DOWN -CENTRILIFT REMOVE OLD ESP SPOOL, INSTALL NEW ESP CABLE SPOOL IN UNIT PULL ESP OVER SHEAVE FOR SPLICE 05:00 - 09:00 4.00 RUNCOM P RUNCMP CENTRILIFT PERFORM ESP CABLE SPLICE -CENTRALIFT REP PERFORM CONDUCTIVITY TEST. Printed 3/17/2014 10:24:09AM • North America-ALASKA-BP Page 7 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:00AM Rig Release:3/3/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292267400 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 12:00 3.00 RUNCOM P RUNCMP PJSM,MU POT HEAD MOTOR LEAD. -SERVICE ESP PUMP ASSEMBLY PER CENTRALIFT REP. LOSSES TO WELL=0 12:00 - 13:30 1.50 RUNCOM P RUNCMP TEST ESP CABLE -PERFORM OHM TEST,MEG TEST AND CONDUCTIVITY TEST ON ESP CABLE. -ALL TESTS IN SPEC. 13:30 - 00:00 10.50 RUNCOM P RUNCMP RUN 2-7/8 6.5#EUE 8RD L80 ESP COMPLETION -PICK UP AND RUN COMPLETION ASSEMBLY WITH XN,2 X GLM AND 246 JOINTS. -PERFORM CONDUCTIVITY TEST AND BREAK CIRC EVERY 2000'AT 1 BPM FOR 5 BBLS, RETURNS WITH NO LOSSES -AT 7828',1 BPM=1340 PSI -PROTECTOLIZERS=3 -FLAT GUARDS=2 -2'CANNON CLAMPS=130 -OA=0PSI -24 HOUR FLUID LOSS=0 BBLS 8.9 PPG BRINE -MAINTAIN CONTINUOUS HOLE FILL,NO LOSSES 3/3/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP M/U LANDING JOINT AND HANGER -FMC INSTALL PENETRATOR AND ORIENT HANGER 00:30 - 02:30 2.00 RUNCOM P RUNCMP CENTRILIFT SPLICE ESP/PENETRATOR AND TEST 02:30 - 03:00 0.50 RUNCOM P RUNCMP DRAIN STACK AND LAND HANGER,ESP ASSY AT 7932'MD -FMC RUN IN LOCK DOWN SCREWS -L/D LANDING JOINT -PUWT=96K,SOWT=82K 03:00 - 04:00 1.00 WHSUR P RUNCMP FMC INSTALL TWC -ROLLING TEST BELOW 500 PSI FOR 5 MINUTES -TEST ABOVE 250 PSI AND 3500 PSI FOR 5 MINUTES EACH,CHART -MAINTAIN CONSTANT HOLE FILL WITH KWF -LOSS RATE INCREASED FROM 0 BPH TO 10 BPH AFTER ROLLING TEST 04:00 - 04:30 0.50 BOPSUR P RUNCMP BLOW DOWN ALL LINES,DRAIN BOP STACK -R/D LANDING JOINT 04:30 - 06:00 1.50 BOPSUR P RUNCMP PJSM,N/D BOPE AND RELATED EQUIPMENT -FMC CLEAN AND INSPECT HANGER 06:00 - 07:30 1.50 WHSUR P OTHCMP NIPPLE UP -NU TREE AND ADAPTER. -CENTRILIFT MAKE FINAL CHECK OF ESP COMPLETION-PASS. 07:30 - 09:30 2.00 WHSUR P OTHCMP PRESSURE TEST ADAPTER -PRESSURE TEST ADAPTER TO 250 PSI LOW, 3500 PSI HIGH-PASS. Printed 3/17/2014 10:24:09AM North America-ALASKA-BP Page 8 of 8 Operation Summary Report Common Well Name:MPK-37 AFE No Event Type:WORKOVER(WO) Start Date:2/27/2014 End Date:3/3/2014 X4-00YWL-E:(1,080,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/21/1996 12:00:00AM Rig Release:3/3/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292267400 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) '09:30 - 11:00 1.50 WHSUR P OTHCMP PRESSURE TEST TREE RIG UP DRILL SITE MAINTENANCE LUBRICATOR. -PRESSURE TEST LUBRICATOR AND TREE. -TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-PASS. PULL TWO WAY CHECK(TWC) 11:00 - 12:30 1.50 WHSUR P OTHCMP SET BACK PRESSURE VALVE(BPV) -CHANGE OUT VALVE TOOLS. -MAKE UP LUBRICATOR AND TEST. -INSTALL BPV. -RIG DOWN DRILL SITE MAINTENANCE. 12:30 - 18:00 5.50 WHSUR P OTHCMP FREEZE PROTECT WELL -RIG UP LITTLE RED SERVICES -PRESSURE TEST LINES TO 250 PSI LOW, 3500 PSI HIGH-PASS. -FREEZE PROTECT IA WITH 73 BBLS DIESEL AND TUBING WITH 15 BBLS DIESEL. -PUMP AT 1BPM TOA MAX OF 1500 PSI. -UNABLE TO MAINTAIN PUMP RATE,SLOW PUMP RATE BUT STILL PRESSURING UP TO 1500 PSI. -SHUT DOWN AND LET PRESSURE BLEED DOWN. -CONTINUE OPERATION OF PUMPING DIESEL AND SHUTTING DOWN AT 1500 PSI UNTIL ALL DIESEL PUMPED DOWNHOLE. -PERFROM 5 MINUTE ROLLING TEST FROM BELOW TO 500 PSI PASS. -SECURE TREE,R/D LRS -RELEASE RIG AT 18:00 HOURS FROM MPK-37 Printed 3/17/2014 10:24:09AM Tree: 2 9/16"-5M CIW M P K-37 ORIG. .ELEV= 61'(N 27-E) Wellhead: 11" 5M FMC Gen 5A ORIG.GL.ELEV= 33.' (N 27-E) % w/ 2 7/8" FMC Tubing Hanger, EUE Different KB ELEV=14.08'(aEs) lift threads,2.5" CIW H BPV profile / / i 110' � / Camco 2 7/8" x 1" 143' sidepocket KBMM GLM KOP @ 2,000' MAX HOLE Angle:42° / @ 3.700' 9 5/8",40#/ft, 3,652' L-80 Btrc. Camco 2 7/8"x 1" / sidepocket KBMM GLM 7675 ' _ / 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg (drift ID =2.50",cap. =0.00592 bpf) / 4 HES "XN"Nipple (2.25"ID) 7,831' Top pert TVD-7036' / Bttm Pert TVD -7106' / Mid-pert TVD-7071' i Pump, SXD 119P23 7,875' PBTD TVD -7210' / NNE Intake, GPINTXAR 7,892' Intake @ 6888'TVD Tandem Seal Section 7,897' MB Stimulation Summary - GSB3DBFERHLSSCVH6S/BS/BPFS 11/17/96-frac packed with 6400 lbs.of '111111 ® 20/40 proppant behind pipe. -;) Motor, 250 HP, 2380 volt 7,911' 53 amp, Model KMH Perforation Summary imi Ref Log : GR/CCL 7/07/96 imi PumpMate w/6 fin Centralizer 7,928 SIZE SPF INTERVAL (TVD) z 7" HES Versatrieve pkr. 8,027' Kula C Closing sleeve ass'bly 4.5" 5 8,094'-8,140' 7039'-7076' y 8,060, 3.5 ,9.2 ppf, N-80, LTC 4.5" 12 8,094' 8,140' / Y/ — Blank pipe (ID =2.992" Kula B / / _ 3.5", .020" Ga.All Weld 8,076' 4.5" 5 8,158'-8,174' 7090'-7103' screen (ID =2.992") r 3.5" Seal unit 32g RDX Alpha Jet 135/45 Deg Phasing 8,142' X 7" "BW D" Sump pkr. (0.44" EHD,32.1"TTP) 4-SPF , 3.5"XN-Nipple (2.635 id) 8,158' 24g RDX 43C UP Big Hole 0 Deg = Phasing 12-SPF _ _ PBTD 8306' m (3.5" PXN plug installed 11-17-96) 7"26#, L-80, Mod. BTRS 8389' DATE REV.BY COMMENTS - MILNE POINT UNIT 8/02/96 MDO ESP COMPLETION 4ES 11/17/96 MDO Frac Pack& 2nd ESP Completion 4-ES WELL MPK-37 11/1/00 GMH RWO-Nabors 4ES API NO: 50-029-22674 5/17/03 MAS RWO-Nabors 4ES 7/28/07 BKr se k Hulme ESP ESP 3/04/14replacement-Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 w ° ", Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 SLIANNED FEB L 7 ?Q1E Mr. Tom Maunder ( r1 3 Alaska Oil and Gas Conservation Commission \CA 333 West 7 Avenue . Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -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, G O 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) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK -06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK 33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK -34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 -� MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK-38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 ..AH- . STATE OF ALASKA . ;/.S-ð-1 RECEtVED ALASKA OIL AND GAS CONSERVATION COMMISSION ,. REPORT OF SUNDRY WELL OPERATIONS ~l(y AUG 1 4 2007 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ~ Repair Well ~ Pull Tubing o Operation Shutdown 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 61.00 8. Property Designation: ADL 375133- 11. Present well condition summary Total depth: measured 8400' feet true vertical 7286 ' feet Effective depth: measured 8306 feet true vertical 7210 feet Casing Length Size Structural Conductor 72' 20" Surface 3616' 9-5/8" Intermediate Production 8356' 7" Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 8094' - 8174' 7040' - 7104' Tubing Size (size, grade, and measured depth): o Plug Perforations o Perforate New Pool o Perforate Anchorage o Re-Enter Suspended Well ~ Other Change out ESP . o Stimulate o Waiver o Time Extension 4. Well Class Before Work: ~ Development 0 Exploratory o Service 0 Stratigraphic 5. Permit To Drill Number: 196-076 . 6. API Number: 50-029-22674-00-00 - 9. Well Name and Number: MPK-37 ' 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands : Plugs (measured) N/A Junk (measured) N/A MD TVD Burst Collapse 110' 110' 1490 470 3652' 3501' 5750 3090 8389' 7278' 7240 5410 SC.ANNED AUG 2 02007 2-7/8",6.5# L-80 7942' Packers and SSSV (type and measured depth): Gravel Pack Assembly: 7" HES Versatrieve packer and 7" BWD sump packer 8027' - 8142' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory ~ Development 0 Service ~ Daily Report of Well Operations 16. Well Status after proposed work: ~ Well Schematic Diagram ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Sondra Stewman Form 10-404 Revised 04/20060 R , G , N A I Title Technical Assistant Phone Sondra Stewman, 564-4750 Submit Original Only Prepared By Name/Number: Tree: 2 9/16" - 5M CIW Wellhead: 11" 5M FMC Gen 5A w/ 2 7/8" FMC Tubing Hanger, EUE lift threads, 2.5" CIW H BPV profile 1110' 1- KOP @ 2,000 ' MAX HOLE Angle: 42° @ 3.700 ' 9 5/8", 40#/ft, L-80 Btrc. 3,652' 27/8" 6.5 ppf, L-80, 8rd EUE tbg ( drift 10 = 2.347", cap. = 0.00592 bpf) Top perl TVD - 7036' Bttm Perl TVD - 7106' Mid-perl TVD - 7071 ' PBTD TVD - 7210' Stimulation Summary 11/17/96 - frac packed with 6400 Ibs. of 20/40 proppant behind pipe. Perforation Summary Ref Loa: GR ICCL 71 071 96 SIZE SP INTERVAL (TVO) Kup C 4.5" 5 8,094' - 8,140' 7039'- 7076' 4.5" 12 8,094' - 8,140' Kup B 4.5" 5 8,158' - 8,174' 7090'-7103' 32g ROX Alpha Jet 135/45 Oeg Phasing (0.44" EHO, 32.1" TIP) 4-SPI 24g ROX 43C UP Big Hole 0 Oeg Phasing 12 -SPF PBTO 8306' 7" 26#, L-80, Mod. BTRS I 8389' MPK-37 REV. BY MOO MOO GMH MAS COMMENTS ESP COMPLETION 4ES Frac Pack & 2nd ESP Completion 4-ES RWO Nabors 4ES DATE 8/02/96 11/17/96 11!1/O0 5117103 RWO Nabors 4ES 7/28/07 Lee Hulme ESP replacement - 3S ORI . ELEV = 61' (N 27-E) ORIG. GL. ELEV = 33.' (N 27-E) Different KB ELEV = 14.08' ( 4ES) Cameo 2 7/8" x 1" I 1 sidepoeket KBMM GLM 138' Cameo 2 7/8" x 1" sidepoeket KBMM GLM 17,730' HES "XN" Nipple (2.205" 10) I 7872' I Pump, SXO 119P23 Intake, GPINTXAR Intake @ 6888' TVO Tandem Seal Section GSB3DBFE RHLSSCVH6S/BS/BPFS 7.886' 7,904' 7,905' Motor, 228 HP, 2305 volt 60 amp, Model KMH 7,919' PumpMate w/6 fin Centralizer 7938' 7" HES Versatrieve pkr. Closing sleeve ass'bly 3.5", 9.2 ppf, N-80, LTC Blank pipe (10 = 2.992" 3.5", .020" Ga. All Weld screen (10 =2.992") 3.5" Seal unit 7" "BWO" Sump pkr. 3.5" XN-Nipple ( 2.635 id) 8,027' 8,060' 8,076' 8,142' 8,158' (3.5" PXN plug installed 11-17-96) MILNE POINT UNIT WELL MPK-37 API NO: 50-029-22674 BP EXPLORATION AK . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-37 MPK-37 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: Spud Date: 4/21/1996 End: 7/27/2007 7/29/2007 PRE Move rig, pits and pipe shed from K-06 to K-37. Accept rig @ 1800 hrs 07/26/07. 18:00 - 19:00 DECOMP Pull BPV wI lubricator. T = 500 psi, IA = 300 psi, OA = 0 psi 19:00 - 22:00 DECOMP Install additional valve on IA. RU kill & Tiger tank lines. 22:00 - 22:30 DECOMP Fill and pressure test surface lines to superchoke to 3500 psi. Fill and pressure test Tiger tank lines to 500 psi. 22:30 - 00:00 1.50 KILL P DECOMP Open choke to well. T = 380 psi, IA = 320 psi. Circulate 290 bbls hot seawater down tubing to Tiger tank through choke. Stage up to 3 bpm @ 760 psi wI IA = 260 psi. 7/27/2007 00:00 - 01 :00 1.00 KILL P DECOMP Bullhead 15 bbls hot seawater down tubing @ 3 bpm wI 1450 psi. Shut in to monitor tubing pressure. At 15 minutes: T = 170 psi, IA = 170 psi. 01 :00 - 02:30 1.50 KILL P I DECOMP Weight up pits to 9.1 ppg. Order one truck of 9.1 ppg brine from MI. 02:30 - 03:00 0.50 KILL P DECOMP Circulate 50 bbls 9.1 ppg brine down tubing through choke to Tiger tank @ 3 bpm wI 640 psi. Bullhead 15 bbls 9.1 ppg brine down tubing wI 1450 psi. Shut in to monitor tubing pressure: T 1= 0 psi, IA = 150 psi. 03:00 - 03:30 0.50 KILL P DECOMP Finish offload seawater to pits and weigth up to 9.1 ppg. 03:30 - 05:30 2.00 KILL P DECOMP Circulate 250 bbls 9.1 ppg brine down tubing through choke to Tiger tank @ 2 bpm. MI brine truck delayed 3-hrs due to Nordic 2 rig move. Finish kill wI 9.1 ppg fluid in pits. 05:30 - 06:00 0.50 KILL DECOMP Shut in and monitor well. 06:00 - 07:00 1.00 KILL DECOMP ! Monitor well ,perform derrick inspection,service rig. 07:00 - 08:30 1.50 BOPSU DECOMP I Dry rod TWC and test from below to 1000 psi, hold for 10 minutes and chart. Test TWC from above to 3500 psi,hold for 10 minutes and chart. 08:30 - 09:00 0.50 BOPSU DECOMP Blow down surface lines. 09:00 - 10:00 1.00 BOPSU DECOMP Bleed hanger void and nipple down tree 10:00 - 11 :00 1.00 BOPSU DECOMP Nipple up 7" x 13-5/8" adapter flange and set down BOP on flange. 11 :00 - 13:00 2.00 BOPSU DECOMP Nipple up BOP and riser. 13:00 . 18:00 5.00 BOPSU DECOMP Test BOPE and related valves to 250 psi low and 3500 psi high. Test witness waived by AOGCC rep Chuck Scheive Test witnessed by BP rep Blair NeufeldlStiem (WSLs) and Nabors Drilling rep Gene Sweatt/Fritts (tool pushers) 18:00 - 19:30 1.50 BOPSU DECOMP Finish BOPE test. RD test equipment. 19:30 - 20:30 1.00 BOPSU DECOMP RU lubricator on extension wI TWI valve, FMC XO and head pin. MU to hanger. 20:30 - 22:00 1.50 DHB P DECOMP Attempt to pull TWC wlo success. Back out extension from hanger. RU to circulate fluid & compressed air through lubricator extension to clean off top of TWC. MU to hanger and i pull TWC. Found sand on TWC. 22:00 - 22:30 0.50 I DHB P DECOMP I LD lubricator, extension & FMC XO. 22:30 - 00:00 1.50 DHB P DECOMP Hang ESP cable trunk. RU langing joint to pull tubing hanger. 7/28/2007 00:00 - 02:30 2.50 PULL N DECOMP Repair gas detection system failure. Called Lou Grimaldi wI AOGCC to report failure per Title 20 AAC 25.066 Gas Detection. Received verbal waiver to continue operations with hand-held gas detectors at two non functional gas detectors. Estimated repair dateltime for fully functional gas dectection is 07/28/07 1200 hrs. Printed: 8/2/2007 1 :40:54 PM . . .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-37 MPK-37 WORKOVER NABORS ALASKA DRILLING I NABORS 38 Start: Rig Release: Rig Number: 7/27/2007 7/29/2007 Spud Date: 4/21/1996 End: 7/28/2007 02:30 - 03:30 1.00 PULL P DECOMP MU landing joint to tubing hanger. Pull 65K to unseat hanger. Fill well with 11 bbls 9.1 brine. 03:30 - 14:30 11.00 PULL P DECaMP POOH wI 2-7/8" ESP completion, 247 joints. Layout 3 joints. 14:30 - 17:00 I 2.50 PULL P DECaMP Lay down ESP assembly. 17:00 - 18:00 I 1.00 PULL P DECaMP Rig down berm for ESP cable. 18:00 - 21 :00 3.00 RUNCO RUNCMP PUMU ESP & cable 21 :00 - 00:00 3.00 RUNCO RUNCMP I Run ESP completion assembly on 247 joints tubing. Check I cable conductivity and flush pump w/10 bbls brine every 2000'. 7/29/2007 00:00 - 05:00 5.00 RUNCMP Continue to RIH wI new ESP completion assembly on 247 joints 2-7/8" tubing. 05:00 - 06:00 1.00 RUNCMP MU tubing hanger. Flush pump w/10 bbls brine. 06:00 - 06:30 0.50 RUNCMP Service rig and inspect derrick. 06:30 - 09:00 2.50 RUNCMP Splice ESP cable plug and test same. Land tubing hanger. 09:00 - 09:30 0.50 RUNCMP RILDS. LD landing joint. 09:30 - 10:30 1.00 RUNCMP Dry rod TWC and test from above to 1000 psi for 10 charted minutes. Test TWC from below to 1300 psi for 10 charted minutes. 10:30 - 12:00 RUNCMP ND BOPE. BOPE in cradle. 12:00 - 15:00 RUNCMP NU tree. Test hanger to 5000 psi - OK. Attempt to test tree to 5000 psi wlo success. Test pump leaking. Change out test pump valves. 15:00 - 18:00 RUNCMP Attempt to retest tree wlo success. Replace TWC. Isolate tree from test pump. Test tree & TWC to 5000 for 15 minutes - OK. Did not chart due to test line configuration. Received approval from Milne Point (Brian Bixby) to pass tree test w/o chart. Test pressure and duration witnessed by Alex Stiem via gauge on swab valve. Released rig @ 1800 hrs 07/29/07. 7/3012007 00:00 - 06:00 6.00 RUNCO RUNCMP Wait on trucks. I Printed: 8/2/2007 1 :40:54 PM ' t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE - 61' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3509' NSL, 2045' WEL, SEC. 03, T12N, R11E, UM X = 584513, Y = 6005644 MPK-37 At top of productive interval 9. Permit Number / Approval No. 196-076 389' NSL, 3098' WEL, SEC. 03, T12N, R11E, UM X = 583489, Y = 6002485 10. APl Number At effective depth 50-029-22674-00 273' NSL, 3149' WEL, SEC. 03, T12N, R11E, UM X = 583451, Y = 6002397 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 222' NSL, 3172' WEL, SEC. 03, T12N, R11 E, UM X = 583429, Y = 6002346 Sands 12. Present well condition summary Total depth: measured 8400 feet Plugs (measured) true vertical 7286 feet Effective depth: measured 8306 feet Junk (measured) true vertical 7210 feet Casing Length Size Cemented MD TVD Structural Conductor 72' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 3616' 9-5/8" 779 sx PF 'E', 686 sx 'G', 250 sx PF 3652' 3501' Intermediate Production 8356' 7" 305 sx Class 'G' 8389' 7278' Liner RECEIVED Perforation depth: measured 8094' - 8140', 8158' - 8174' JUN ] 3 2003 true vertical 7040' - 7076', 7091' - 7104' Alaska 0il & Gas Cons. Comr~'~issi0t~ Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 7948' Anchora99 Packers and SSSV (type and measured depth) Gravel Pack Assembly: 7" HES Versatrieve packer at 8027'; 7" 'BWD' sump packer at 8142' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl 6as-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations ...... '~ 7. I hereby certify that the..ro.r~for oing is tr correct to the best of my knowledge Signed so~~~ _Tj.i.i~le Technical Assistant Date (-"~'" t ~-03 Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: MPK-37 Common Well Name: MPK-37 Spud Date: 4/21/1996 Event Name: REENTER+COMPLETE Start: 5/13/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/15/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 5/1312003 22:00 - 00:00 2.00 MOB P PRE Held PJSM. RDMO MPC - 07 5/14/2003 00:00 - 04:30 4.50 MOB P PRE Held PJSM. Rigged Down and Moved Off of MPC - 07. Moved from MPC - 07 to MPK - 37. 04:30 - 06:00 1.50 MOB P PRE Moved and Spotted Rig Over MPK - 37. 06:00 - 07:00 1.00 RIGU P PRE Held PJSM. Raised and Scoped Derrick. 07:00 - 08:30 1.50 RIGU P PRE Held PJSM. Took on 135 deg Seawater. Spotted Slop Tank, R / U Hardline to Tree. Accepted Rig at 0700 hfs 5 / 14 / 2003. 08:30 - 09:00 0.50 WHSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled BPV, R / D DSM. Tubing Pressure 200 psi, Casing Pressure 200 psi. 09:00 - 09:30 0.50 KILL P DECOMP R / U Hardline to Slop Tank. Tested Lines to 3,500 psi, OK. Blew Down Lines. 09:30 - 10:00 0.50 KILL P DECOMP Held Spud Meeting w/Crew. 10:00 - 13:00 3.00 KILL P DECOMP Circulated Well to 8.5 ppg, 140 deg Seawater. Pump Rate 3 bpm, 570 psi. Took Returns to Slop Tank. Monitored Well, Well Dead. Blew Down Lines. 13:00 - 13:30 0.50 KILL P DECOMP Set TWC and Tested, OK. 13:30 - 14:30 1.00 WHSUR P DECOMP Held PJSM. N / D Production Tree. 14:30 - 16:00 1.50 BOPSUF P DECOMP Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Blind Rams, Mud Cross, Lower Pipe Rams wi 2-7/8" x 5" Variable Rams. 16:00 - 20:00 4.00 BOPSUF P DECOMP Held PJSM. Tested BOPE. Tested Lower Rams, Blind Rams, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 3,500 psi High / 250 psi Low. Tested Annular Preventer to 2,500 psi High / 250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held w/No Leaks or Pressure Loss. Performed Accumulator Test. BOP Test Witnessed by AOGCC Rep John Crisp. 20:00 - 21:30 1.50 WHSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled TWC, R / D DSM. 21:30 - 22:00 0.50 PULL P DECOMP M / U 3-1/2" DP and XO to Tubing Hanger. 22:00 - 23:00 1.00 PULL P DECOMP Held PJSM. Pulled on Tubing, Tubing Movement w/79,000# Up Weight. Pulled Tubing Hanger to Floor w/75,000# Up Weight. Terminated ESP Cable. Broke Out and L / D Tubing Hanger. 23:00 - 00:00 1.00 PULL ;P DECOMP POOH w/2-7/8" Tubing. Racked Tubing in Derrick. Spooled Up ESP Cable. 5/15/2003 00:00 - 04:30 4.50 PULL P DECOMP POOH w/2-7/8" Tubing. Racked Tubing in Derrick. 82 Stands, (246 Jts), 1 Single Jt, 2 GLM Assemblies, XN Nipple, 2 Pup Jts. 04:30 - 06:30 2.00 PULL P DECOMP Terminated ESP Cable to Pump. Broke Out and L / [] Pump. 06:30 - 07:30 1.00 RUNCO~P COMP P / U and Serviced New ESP Pump. Installed Pumpmate. 07:30 - 08:30 1.00 RUNCO~P COMP Held PJSM. Ran ESP Cable Through Sheave. M / U Cable to ESP Pump. Tested Cable. OK. 08:30 - 11:30 3.00 RUNCOI~ COMP 'RIH w/ESP Pump and Cable on 2-7/8" 6.5# 8rd Tubing. M / U ~Torque 2,350 ft / lbs. RIH to 4,950'. ESP Cable was Pulled into Spool, Damaging Cable. 11:30 - 14:00 2.50: RUNCOI~I HMAN COMP Shut Down Operations. Cut Cable and Pulled Same Free from Spool. Inspected Cable, Spliced and Tested Cable. 14:00- 14:30 0.50 RUNCOI~ COMP Serviced Rig. 14:30 - 16:00 1.50 RUNCOI~ COMP RIH w/ESP Pump and Cable on 2-7/8" 6.5# 8rd Tubing. M / U Torque 2,350 ft / lbs. 16:00 - 18:00 2.00 RUNCOr~ COMP M / U Tubing Hanger and Installed Penetrator. M / U EFT Connector Splice, Attached Cable and Tested, OK. String Weight Up 73,000#, String Weight Down 52,000#. Landed Printed: 5/19/2003 10:43:53AM BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPK-37 Common Well Name: MPK-37 Spud Date: 4/21/1996 Event Name: REENTER+COMPLETE Start: 5/13/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/15/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 5/15/2003 16:00- 18:00 2.00 RUNCQi~ COMP Tubing Hanger and RILDS. Completion Equipment Set At The Following Depths: Item Length Depth ESP Pump Assembly 63.22' 7,947.70' 2-7/8" 6.5# 8rd Pup Jt 10.15' 7,874.33' 2-7/8" 6.5# 8rd Pup Jt 2.27' 7,872.06' XN Nipple 1.17' 7,870.89' 4 Jts 2-7/8" 6.5# 8rd Tbg 127.23' 7,743.66' #1 GLM Assembly 22.77' 7,720.21' 240 Jts 2-7/8" 6.5# 8rd Tbg 7,571.23' 149.47' #2 GLM Assembly 23.03' 126.44' 3 Jts 2-7/8" 6.5# 8rd Tbg 95.03' 31.41' 2-7/8" 6.5# 8rd Pup Jt 8.14' 23.27' 2-7/8" 6.5# 8rd Pup Jt 3.70' 19.57' Tubing Hanger 0.69' 18.80' 18:00 - 19:00 1.00 RUNCO~ COMP Broke Out and L / D Landing Joint. Set TWC and Tested. Drained BOP Stack and Blew Down Lines. 19:00 - 20:00 1.00 BOPSUF:P COMP Held PJSM. N / D BOPE. 20:00 - 21:30 1.50 WHSUR P COMP Held PJSM. N / U Tree. 21:30 - 22:30 1.00 WHSUR P COMP Held PJSM. R / U to Tree. Pressure Tested Tree to 5,000 psi, OK. R / D Lines From Tree. 22:30 - 23:30 1.00 WHSUR P COMP Held PJSM. R / U DSM Lubricator, Pulled TWC, Set BPV, R / D DSM. 23:30 - 00:00 0.50 WHSUR P COMP Secured Well. Released Rig at 2359 hrs 5 / 15 / 2003 Printed: 5/19/2003 10:43:53 AM . ---.. STATE OF ALASKA ALASK~ _ AND GAS CONSERVATION COMN 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 61' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3509' NSL, 2045' WEL, SEC. 03, T12N, R11E, UM MPK-37 At top of productive interval 9. Permit Number / Approval No. 196-076 389' NSL, 3098' WEL, SEC. 03, T12N, R11E, UM 10. APl Number At effective depth 50-029-22674-00 273' NSL, 3149' WEL, SEC. 03, T12N, RllE, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 222' NSL, 3172' WEL, SEC. 03, T12N, RllE, UM Sands 12. Present well condition summary Total depth: measured 8400 feet Plugs (measured) true vertical 7286 feet Effective depth: measured 8306 feet Junk (measured) true vertical 7210 feet Casing Length Size Cemented MD TVD Structural Conductor 72' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 3616' 9-5/8" 779 sx PF 'E', 686 sx 'G', 250 sx PF 'C' 3652' 3501' Intermediate Production 8356' 7" 305 sx Class 'G' 8389' 7278' Liner Perforation depth: measured 8094' - 8140', 8158' - 8174' true vertical 7039' - 7076', 7091' - 7104' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 7933' Packers and SSSV (type and measured depth) Gravel Pack Assembly: 7" HES Versatrieve packer at 8027'; 7" 'BWD' sump packer at 8142' D ~,~ iF.~ fl ~' ,~ ~.~ 13. Stimulation or cement squeeze summary I '~ L._ Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Anchnrnn~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terde Hubble,.~.,~~ ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 .. Submit In Duplicate Form 10-404 Rev. 06/15/88 :OP rati6ns SUmmarY Report Legal Well Name: MPK-37 Common Well Name: MPK-37 Spud Date: 4/21/1996 Event Name: REPAIR Start: 10/3'1/2000 End: 11/2/2000 Contractor Name: NABORS Rig Release: 11/2/2000 Group: RIG Ri9 Name: NABORS 4ES Rig Number: : : Description of Operations 10/31/2000 10:00 - 17:00 7.00 MOB PRE MOVE ON & RIG UP ON MPK-37. 17:00 - 19:00 2.00 RIGU PRE BERM UP TIGER TANK. PJU HARD LINES. R/U LINES TO TREE & HCR. 19:00 - 19:30 0.50 RIGU PRE PRESSURE TEST LINES TO 2500 PSI. 19:30 - 20:30 1.00 WHSUR DECOMP P/U LUBRICATOR & PULL BPV. 20:30 - 22:00 1.50 KILL DECOMP WAIT ON FRESH WTR.. SITP 400 PSI, SICP 550 PSI. 22:00 - 00:00 2.00 KILL DECOMP PUMP 8.6 PPG BRINE WATER AROUND & ATTEMPT TO KILL WELL. WELL NOT DEAD. 11/1/2000 00:00 - 01:30 1.50 KILL DECOMP OBSERVE WELL, WELL NOT DEAD. TP 100 PSI, CP 150 PSI. 01:30 - 03:30 2.00 KILL DECOMP WT UP BRINE TO 9 PPG. KILL WELL WI 9.0 PPG BRINE. 3 BPM @ 850 PSI. 03:30 - 04:00 0.50 KILL DECOMP MONITOR WELL, WELL DEAD. BTREAK DOWN HARD LINES. SET TWC VALVE. 04:00 - 05:00 1.00 WHSUR DECOMP N/D X-MAS TREE. 05:00 - 08:30 3.50 BOPSUF DECOMP N/U DOPE. 08:30 - 10:30 2.00 BOPSUF DECOMP PRESSURE TEST DOPE. LP 250 PSI, HP 3500 PSI. CHANGE OUT RING IN CHOKE LINE. 10:30 - 11:30 1.00 WHSUR DECOMP P/U LUBRICATOR & PULL TWC VALVE. WELL ON VACUM. 11:30 - 13:00 1.50 PULL DECOMP P/U LANDING JT. BOLDS. PULL TBG HANGER. P/U WT 67K. TEST ESP. 13:00 - 17:00 4.00 PULL DECOMP POOH W/2 7/8" COMPLETION STRING. 17:00 - 18:00 1.00 PULL DECOMP CLEAR OFF RIG FLOOR. REMOVE SPOOL F/SPOOLING UNIT. 18:00 - 19:00 1.00 PULL DECOMP CHECK & L/D ESP. 19:00 - 20:00 1.00 REST DECOMP CLEAR FLOOR. R/U TO RUN COMPLETION. 20:00 - 21:30 1.50 REST DECOMP M/U NEW ESP & SERVICE SAME. 21:30 - 22:00 0.50 REST DECOMP INSTALL & TEST E-LINE CABLE IN ESP. CHECK SPOOLER. 22:00 - 00:00 2.00 REST DECOMP RIH W/27/8" COMPLETION STRING. 11/2/2000 00:00 - 03:00 3.00 RUNCOI~I COMP RIH W/2 7~8" COMPLETION STRING. 03:00 - 05:30 2.50 RUNCOIt COMP M/U LANDING JT. SPACE OUT & SPLICE EFT CONNECTOR. LAND TBG STRING. RILDS. CHECK CONNECTOR. 05:30 - 06:00 0.50 WHSUR COMP INSTALLTWC VALVE.& TEST SAME. 06:00 - 07:00 1.00 BOPSUF COMP N/D DOPE. 07:00 - 08:30 1.50 WHSUR COMP N/U X-MAS TREE. & TEST TO 5000 PSI, OK. 08:30 - 09:30 1.00 WHSUR COMP PULL TWC & INSTALL BPV. 09:30 - 10:00 0.50 DEMOB COMP SECURE WELL & CLEAN CELLAR. 10:00 - 22:00 12.00 DEMOB POST COMPLETED OPERATIONS. WAIT ON NEXT LOCATION TO BE PREPARED. PERFORM RIG MAINTAINANCE. RLEASED RIG @ 2200 HRS. 11-2-00. RECEIVED DEC g 2, 7n.n, Ala~a 0il & Gas Cons, Commission Anchorage Printed: 11/28/2000 8:53:30 AM PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 11/05/98 RUN RECVD 96-076 GR/CCL 96-076 7377 96-076 CDR-MD ~-~4- 8289 SCL ~i00-8340 1 07/26/96 1 08/12/96 FINAL 09/05/96 96-076 CDR-TVD ~00-7230 FINAL 09/05/96 96-076 CDN-MD ~.~ 3580-8280 96-076 CDN-TV]D ~%~3500-7190 96-076 PLS (STATIC) uL~ 8140-8230 FINAL 09/05/96 FINAL 09/05/96 1 08/30/96 96-076 GR/CCL 96-076 7447 96-076 PERF L~'7950-8269 ~,~'g'6- 8400 CD~/CDN ~ 8094-8140 1 08/30/96 1,2 09/05/96 FINAL 11/27/96 96-076 PROD PACKER 10-407 8094-8142 DAILY WELL OPS R ~7 /~?)/:!%~ / TO ~¢~/¢-~q/'~?~/ Are dry ditch samples required? yes ~.~d received? FINAL 11/27/96 · ) /l~ 3.1/~;I ~. ~ti /~. 7/ Was the well cored? yes ~_._Analysis & description received? Are well tests required? 7~s ~¢.Receive~,~ Well is in compliance Initial COMMENTS STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION CO~vfMISSlON 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. 96-76 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22674 4. Location of well at surface ' ~'¢¢.~ 9. Unit or Lease Name 3509' NSL, 2045' WEL, SEC. 3, T12N, R11E i'"'~,;-:";!i=~:'~:'-'-"~.:~ - i ~ ~ Milne Point Unit Attop of productive interval i ~/~,~_.f~ ~,..,~_I!~ ~ 10. Well Number 390' NSL, 3094' WEL, SEC. 3, T12N, R11E~ ...........,_/--~ --/- i t a ~;~:::Z2, i MPK-37 Attotal depth !;~~" .... '~':'~ i~' 11. Field and Pool 223' NSL, 3167' WEL, SEC. 3, T12N, R11E ~ '; ............. Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 62.5'I ADL 375133 12. Date Spudded04/21/96 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband[15' Water depth' if OffshOre I 16' NO' Of COmpletiOns04/28/96 11/28/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set[21. Thickness of Permafrost 8400 7287 FT[ 8306 7210 FT I~Yes []No N/A MD! 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, EMS, GR/RES, CDN, GR/CCL, GR/JB ,, 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NTSOLHE 38' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 3652' 12-1/4" 779 sx PF 'E', 686 sx 'G', 250 sx PF 'C' 7" 26# L-80 33' 8389' 8-1/2" 305 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 7951' N/A M D TVD M D TVD 8094'-8140' 7040'-7077' 8094'-8140' 7040'-7077' 8158'-8174' 7091 '-7104' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/70 bbl diesel Gravel pacassy, 8027'-8142' 6400 # 20/40 Carbolite behind pipe i27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) August 7, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I iFIow Tubing Casing Pressure CALCULATED . OIL-DEL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIV D 0RIGINAL Al~.ska 0il & Gas Cons. Commissior~ Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marke,~ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top KC1 8092' 6977' Top Kuparuk 'B' 8143' 7018' Top Kuparuk B7 8156' 7028' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that :_~ , i ~/r/r~tC.LI '2'/'2''/~ the fore oing is true nd corre t o the best of my knowledge Signed . ._ ~ ~ ..~ ~ Tim Schofield r ~ C~.~ , Title Senior Drilling Engineer Date ~ ?, Prepared By Name/Number: Kathy Campoamor, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: Accept Date: MPK-37 Rig Name: N-27E AFE: 0 4/21/9 6 Spud Date: 0 4/21/9 6 Release Date: 337015 05/01/96 Apr 20 1996 (1) Rig moved 0%. Apr 21 1996 (2) Rig moved 0%. Rig moved 100%. RU additional services. Apr 22 1996 (3) RU divertor. Rig accepted 04/21/96 @ 0600 hrs. Held safety meeting. Held safety meeting. Drilled to 322 ft. Serviced shaker discharge line. ft. Serviced shaker discharge line. Drilled to 864 ft. MU BHA #1. Drilled to 596 Apr 23 1996 (4) Drilled to 1210 ft. Circulated at 1210 ft. POOH to 225 ft. RIH to 1210 ft. Drilled to 2409 ft. Circulated at 2409 ft. POOH to 1200 ft. RIH to 2409 ft. Apr 24 1996 (5) Drilled to 3658 ft. Circulated at 3658 ft. POOH to 851 ft. RIH to 3658 ft. Circulated at 3658 ff. Apr 25 1996 (6) POOH to 852 ft. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 3652 ft (9.625 in OD). Circulated at 3652 ft. Held safety meeting. Tested high pressure lines. Mixed and pumped slurry - 441.5 bbl. Displaced slurry - 270.33 bbl. Flow check. RU high pressure lines. Mixed and pumped slurry- 34 bbl. RD casing handling equipment. RD divertor. RU BOP stack. Apr 26 1996 (7) RU BOP stack. Tested all functions. Installed wear bushing. MU BHA #2. Repaired flowline. MU BHA #2. Repaired flowline. RIH to 2900 ft. Held drill (stripping). Held safety meeting. RIH to 3455 ft. Washed to 3565 ft. Tested casing. Drilled installed equipment - float collar. Performed formation integrity test, 15.6 ppg EMW. Drilled to 3668 ft. Page Apr 27 1996 (8) Drilled to 3668 ft. Circulated at 4668 ft. POOH to 3600 ft. Repaired kelly/top drive hose. RIH to 4668 ft. Repaired kelly/top drive hose. Drilled to 5674 ft. Circulated at 5674 ft. POOH to 4594 ft, RIH to 5674 ft. Apr 28 1996 (9) Drilled to 6720 ft. Circulated at 6720 ft. POOH to 5600 ft. RIH to 6720 ft. Drilled to 768O ft. Apr 29 1996 (10) Drilled to 7724 ft. Circulated at 7724 ft. Flow check. POOH to 6676 ft. RIH to 7724 ft. Drilled to 8400 ft. Circulated at 8400 ft. Flow check. POOH to 3600 ft. Flow check. RIH to 8400 ft. Circulated at 8400 ft. Apr 30 1996 (11) Circulated at 8400 ft. Flow check. Took EMS survey at 8400 ft. LD 4000 ft of 5" OD drill pipe. Serviced drawworks. Repaired drillstring handling equipment. LD 8140 ft of 5" OD drillpipe. Pulled BHA. Removed wear bushing. RU casing handling equipment. Held safety meeting. Ran casing to 3600 ft (7 in OD). Circulated at 3600 ft. Ran casing to 8379 ft (7 in OD). May I 1996 (12) Ran casing to 8379 ft (7 in OD). Circulated at 8379 ft. Held safety meeting. Mixed and pumped slurry- 112.2 bbl. Displaced slurry- 318.2 bbl. Tested casing. Held safety meeting. RD casing handling equipment. RD all functions. Installed adapter spool. Tested seal assembly. Installed Xmas tree. Installed hanger plug. Rig released 05/01/96 @ 0001 hrs. Page 2 Milne Point Completion/Workover Report POLAR RIG #1 TO: Hendrix / Stevens DATE: 9/12/96 I DAY# I 7 FROM: Dave Hildreth REPORT DAY 9/11/96 WELL: MPK-37 AFE NO: 339509 DAILY COST: 12610 EST CUM COST: I126769 OBJECTIVE: ESP Chan,qe Out and WLRBP Set IFORMATION: I PBTD: 18265 IOSG. SIZE: 17"26#/ft ~TBG. SIZE: 127/8"6.5#/ftb-808rd OPERATION AT 06:00 hrs: IRi,q Released at 2400 hours 9/12/96. Demob to Deadhorse1 Alaska. PERSONNEL ONLOCATION: BP: I 1 ICONTRACT: 5 IS""V'C": I~ ~OTAL: 8 WEATHER: ICIoudy/cool IM,SC: ] Time Breakdown Item Time Item Time Item Time Item Time RU / RD PU 6 Tripping 4.50 Rig Service Testing RU / RD BOP 7.50 Circulating 2.00 Maintainance W O O PT BOP's Drilling RU to Log Csg Wash PU / LD Tubing Reaming Logging ESP Splice 4.00 PU / LD BHA Rig Repairs Wireline Start Stop 0600 0930 TIH with ESP Completion. 0930 1030 PU 10' PJ, GLM w/DGLV and 10' PJ. Ran 3 jts 2 7/8" Installe FMC 7 1/16" Gen 5A Hanger with 3" LH threads 1030 1330 Splice in Pig Tail with Centralift. Install hanger and tie-in ESP. Installed new seal ring on hanger 1330 1430 Landed Tubing with PHD at 8956' MD Up weight = 69k and down weight = 47k 1430 2100 ND BOP's and Install Tree, Pressure test to 5000 psi (adaptor and tree). 2100 2300 Pull TWC, RU HB&R and FP the wellbore with 60 bbl's diesel down the IA and and 12 bbl diesel down the tubing. Install BPV 2300 2400 Secure Tree. Rig Released at 2400 hours 9/11/96 2400 0600 RD Polar Pulling Unit. FLUIDS PUMPED BBLS. DISCRIPTION 72 Diesel TOTAL FLUIDS LOST IN HOLE BBLS. DESCRIPTION TOTAL CUM TOTAL TO DATE BOTTOM-HOLE ASSEMBLY #1 Tool Strin~l Descriptions O.D. I.D. Length Comments TOTAL LENGTH ? F (..' F~\/? [) F l::.., 1 o ll?j,Cj7 Airtska 0}1 & (:;as Cor;s ~.;u~'~rn~ssio~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: M PK-37 Rig Name: N-4ES AFE: Accept Date: 11/1 3/96, Spud Date: -- Release Date: 11/27/96 339027, 339032 11/18/96, 11/28/96 Nov 13 1996 MIRU. Raise derrick & RU. Rig accepted 11/13/96 @ 0130 hrs. Pull BPV with lubricator. Take on source water as kill fluid, RU hard line to tiger tank & tree. Nov 14 1996 Test surface lines, check for leaks. OK. Kill well with source water, pump down tubing taking returns out annulus, pump tubing volume & attempt to bullhead rat hole volume into perf--pressure up. Perfs would not take fluid. Circ out backside, monitor well. Well dead. Set TWC valve. ND CIW tree & FMC adapter spool. NU BOP & test. Test all rams, lines & valves. Test kelly, upper & lower kelly valves, TIW & IBOP. Test Hydril. Witness of test waived by Mr. Foster of AOGCC. Pull TVVC valve. MU 3" LH acme landing jr, pull tubing hanger to rig floor & LD. CBU, monitor well - OK. POOH with ESP. Pull tubing, recovered all clamps-no junk left in hole. Drain BOP stack to change rams to 3-1/2" DP, slight flow out annulus valve that would not stop. Close annulus valve. MU Baker BP retrieving tool on 2-7/8" tubing. TIH with tubing from derrick. CBU @ 7770'. Small amount of gas on bottoms up, monitor well-OK. Cont TIH picking up singles. Tag fill @ 8000', monitor well-slight flow. RU & rev circ hole volume. Small amount of gas on bottoms up. Cont ¢irc hole volume, monitor well- slight flow. Circ long way & increase brine with salt. Nov 15 1996 Cont circ@ 8000' & increase brine weight, monitor well-OK. Rev circ, clean out formation sand 8000' to 8261' Bridge plug did not appear to be set, no indication of releasing plug when latched. POOH with bridge plug to 8049'. Circ & balance brine weight. POOH & LD bridge plug. Install wear bushing. MU bit on tubing & space out 7" casing scraper above perfs. TIH to 8261'. Wash fill long way 8261' to PBTD. Rev circ until hole clean, 60% returns. Circ long way & displace to clean filter, pump Xanvis sweep followed by dirt magnet water & Xanvis sweep, followed by brine-NTU return fluid at shaker, monitor well. Slight flow, shut in well. Displace, clean pits--take on fluid. Prepare to weight up fluid. Page Nov 16 1996 Circ increase weight of brine, monitor well. Well dead-fluid loss. Circ & filter brine with Baroid filter unit-45 NTU return fluid, no solids. POOH, LD drillpipe t/8000'. Spot Xanvis pill above perf. Finish LD drillpipe, stand back tubing. ND bell nipple, NU perf flange. RU Schlumberger, test lubricator. RIH with 4-1/2" casing perf gun. Perf 8140'-8120', 12 spf. RDX big hole charge, POOH. Repair electric line. Pull off & cut electric line & re-head. RIH with 4-1/2" gun run #2. Perf 8120'-8100', 12 spf. Big hole charge. Correlated to GR/CCL. POOH with gun #2. Nov 17 1996 Cont perforating. 4-1/2" gun run #3. Perf 8100'-8094', 12 spf. Big hole charge. Correlated to GR/CCL. All shots fired. RIH with 6" GR/JB to 8282'. POOH, small amount of gun debris. MU HES 7" "BWD" sump packer with plug in tailpipe-RIH. Set sump packer at 8142', correlated to GR/CCL. POOH, RD Schlumberger. ND perf flange, NU bell nipple. RU to run frac pac screen. Repair V-door, weld hinge. MU frac pac assy. TIH with frac pac assy on 2-7/8" tubing. Tag sum packer at 8132'. Space out, drop 2" ball & circ down. Pressure up & set 7" versatrieve packer at 8026'. Test backside, shear off & reverse out ball. Test lines. Pickle tubing & reverse out to tank. Preform injectivity test. Acidize formation with HCL into formation. Perform data frac. Perform step rate test. Pump gel slurry & sqeeze into formation with brine water. Shut down. Analysis-Data Frac information. Nov 18 1996 Pump frac pac as follows: gel pad, sand slurry, brine. Screen out with slurry behind pipe. 5063# of sand behind pipe-reverse out 1-1/2 tubing volume. Wait one hour for gel to break before stressing pac. Stress pac with rig pump-pack circulated. Test line. Re-gravel pac with gel pad, sand slurry, gel behind followed by brine. Screen out with slurry, 1366# sand behind. Reverse out 1-1/2 tubing volume. Wair for one hour for gel to break. Stress pac. Re-stress three times, would not circulate. Called gravel pac good. Slight flow on tubing & annulus. CBU, monitor well. Slight flow both sides. Circ increase brine weight, monitor well. Slight flow. Circ increase brine weight, monitor well-OK. Slight loss. POOH with frac pac tool string. Drift tubing on way out, LD tool string. Pull wear bushing. RU to run ESP. PU & service ESP assy. TIH with 2-7/8" tubing from derrick. Ran same ESP cable back into well that was pulled. Nov 19 1996 Finish TIH with ESP. MU FMC tubing hanger. Ran total of 248 jts 2-7/8",6.5#,L-80 tubing. MU splice on ESP cable at tubing hanger. Land tubing. Set TWC & test. ND BOP stack. NU FMC adapter spool. NU tree. Test tree & pack-off, ok. Install BPV. Freeze protect with diesel. Bullhead 61 bbls down annulus. Bullhead 11 bbls down tubing. RD lines, secure well, clean pits. Rig released 11/18/96 @ 1700 hrs. ,. c' i-: i ?' i Page 2 Nov 27 1996 MIRU. Rig accepted 11/27/96 @ 0100 hrs. RU lines to tree & tiger tank. Pull BPV with lubricator. Water back brine. Test lines. Kill well. Circ down tubing, take returns to tiger tank through choke, pump tubing volume & shut down monitor well. Tubing dead. Circ out backside. Monitor well--well dead with 8.6 ppg to surface, slight vacuum. Prepare to set BPV & ND tree. Nov 28 1996 Set TWC. ND tree. NU adapter flange & BOP's. Test BOP's. Test waived by AOGCC Doug Amos. Pull TWC. MU landing jt. Pull hanger to floor and check same. Pigtail connection to hanger, burnt up. POOH with ESP completion & LD pump & motor. Rig HES wireline truck & RIH with GR/JB @ 8024'. Nothing rec. RIH with 2.3" bull nose plug to 8150'. Tag XN nipple. POOH & RD HES. Splice ESP cable splice & MU & service pump & motor. RIH with ESP completion. Nov 29 1996 Cont RIH with ESP completion & MU hanger & landing jt. Splice pigtail at hanger. Land hanger. RILDS, LD landing jt. Set & test TWC. ND BOP's. NU adapter flange & tree. Test hanger & adapter flange & tree. Check ESP cable, OK. Pull TWC. Set BPV. MU hard lines to tree & test. Freeze protect well with 70 bbls diesel. RD cellar lines & secure tree. Rig released 11/28/96 @ 1800 hrs. Page 3 ANNULAR INJECTION DATA ENTRY SCREEN Asset ~iJ~e .......................................Legal Desc .3.6.~8[;I~.S.I..,21.0~Q:.~.EL,...~ec.O.%'['.:I.2~L~.1.:I£ ......................... Rig Name .blP7.E. ........................................ · .................................................................................................................... Inj Well Name .M.E~.-.12. ..................................Permit Start ' Permit End ............................... Sur Csg Dep .3.5.0,8[ ............. ......4.=.1..8.;.9.1~ ........... .4.=..1.8.:.9.Z ..... Cumulative Data :~:: i i Rig ~ Completi0n~ ~F°rmati°n ::intermittant Final Well Total Mud)Ctg : -~:: WaSh~ :: ::' FlUids ~ i'.? ?lUids : '::: : :"Freeze · Freeze ...... 1.9..6.0,8[ ........... 1.8..5.3~ .......... .2.6.5 ....... ; :...,.... .......... 6.8.5 .......... ; ....... ;L0,Q ......... ~ ' i :~ :- ' : Daily Data Source i Date of c0ntaminat~dl: Rig WaSh l; C°mPleti°n:] ::::F°;~a{i°n~:l:;: F~Z~i:;I FreeZe~: Daily I Annulus Well i Injection Drg MUd | :Fluids { ; FlUids I FlUidS::[ Protecti6nl ProteCtion Total Rate i Pressure Status Commenls Complications 'MPK-25 ' 03/15/96 i 140I 140 ~t 03/20/96 17~ 225 ~00 I~-~ !0~/2~/~ 300 ~;~ ~00 ~ 03/23/96 80 80 i ~i 03/24/96 70 70 ~PK-3S ~03/2~/~I 1so ~ 1~0 U~K-3a ~03/2S/~ 1,~ I 1,~9~ ~~~ 03/30/~ ~55 ~' ~55 ~~03/3~/~ 2so i ~0 2~0 ~~'0~/0~/~ ~0 ~ ~0 UPK-3S ~.04/02/9~ 1~5 i ~~ 04/03/~ 335 185 ~MPK-38 ~ 04/04/96 400 ~ 10 345 ~ 400 ~MPK-38 ~04/05/96 949 ~ 60 ~ 1,009 IMPK-38 .~04/06/96 0 ~ 0 MPK-38 ~ 04/07/96 0 j 0 ~MPK-38 ~'04/08/96 150 I ~ 150 ~MPK-38 ~ 04/12/96 490 J 7 ~ 497 ~ ~04/~/~ J. ~0~ ~~04/~./~ ~I ~0 ~4~ ~~ 04/1 s/9~ 50 70 120 ~~o4/~/.~ ~o ~o ~o ~oo ~~04/24/9s ~,240 10 1,2s0 l~K-3~J - / ,04/25/96 300 I 10 310 ~~ 04/26/96 200 ~ 10 210 1.5 BPM ~ 700 PSI 04/27/96 700 i 10 710 1.5 BPM ~ 700 PSI IMPK-37 .~ MPK-37 { 04/28/96 50 i 20 70 1.5 BPM ~ 700 PSI MPK-37,i 04/29/96 350 ~ 350 1.5 bpm ~ 700 PSI MPK-37 .~04/30/96 1,000 ]. 60 1,060 3BPM ~ 800PSI MPK-02 J 05/04/96 350 ~ 350 3 BPM ~ 800 PSI MPK-02 '?05/05/96 950 ~, 10 960 70 bbls of the 950 was returned cement ,MPK-02 .~ 05/06/96 390 ] 20 410 [MPK-02 ] 05/07/96 280 ~ 10 290 1.5 BPM ~ 700 PSI ~o~o~ ~ ~ ~o I ~i 05/10/96 221 ~ 10 ~ 231 ~U~K-02 i iMPK-02 ~05/11/96 335 i ] 335 , MPK-02 ~ 05/13/96= 625 ~ . 100 725 3 BPM ~ 750 PSI ********* ********** ********* ANADRILL ********** ********* SC~U]MBERGER ********** ********* :********** ******************************************************* COMPANY BP WELL NAME ~'.".(-37 LOCATION 1 MILN~. F? LOCATION 2 ALASI<A MAGNE?!C DECLINATION 27,.77 ~Ig C£~4V~RGENCB ANGLE O, O0 I~TE: 2?-APR-?6 APl ~ 50-0~-~674 ~ ~ 337015 JOB ~ 37888 W~LL H~D ~ATiON~ LAT(N/-S) 0,00 D~'(E/-W) 0,00 AZIMUTH FROM ROTAG:Y TABLE TO TARGET IS TIE IN POINT(TIP) M~/,~L~BD DEPTH 112,00 T~]~ g~RT D~PTH 112,00 INCLINATION AZIMUTH 0~00 LATITUD~(N/-S) D~PARTI]RE(~/-W) 0~00 RECEIVED Alask Oil & (~l~.s O'.ms. Commissior' Ar, cl'~or~g~ MPK-37 MEASURED INTERVAL U~'~^~ ~EFTH ii2,00 0,0 153.7! 41~Y I53.71 246,56 92,9 246,56 337.59 91,0 337,57 427,49. 89,9 4~.~, , ~ TA~ET STATION AZIMUTH LATITUDE SECTION 1~.$5:L!4, N/-S ~t d~g Oeo ft 0,c)3 O,O~J 0,00 0+00 -0,08 0,57 84.30 0.02 -0.~ 0.65 89,~I 0~07 -0+65 0.67 103,23 -0.05 -0.59 0,43 ~26,10 -0~37 DEPARTURE DISPLA'3EMD.fF at AZIMUTH 10Oft ! ~36 0.11 0,17 'J * .5./ 5i6,~ 605,80 7~5,02 877,84 89.4 516.82 69.0 605.78 90~0 z,',~ 7~ 69~2 784.98 9~.6 877.6! -0.32 0.52 !~.15 -0.85 3.58 3.68 i03.36 0.I? 0.06 0.68 i3i.40 -!.48 4.27 4~52 109.08 0.17 0.'~? 0,21 ~12.31 -2.91 5.62 6.33 117.37 0.74 0.84 0.23 351.51 -2.7? 5,75 6,39 115.90 0.4J' '~.5 973.32 94.3 1067.61 95.1_ ii62..-69 94.9 i257 94./-, i352 '"~' · ..- 0.43 0.30 7.44 -2.36 5.76 6.~ 112.27 0.10 -0.16 0.46 352.36 -1.74 5.74 6.00 106.86 0.20 ^ 'A n.37 320.34 -I,!2 5,49 5,60 t0~,55 0,26 -0.8i 0,36 ... 4,~.~ 100.07 0,~i -0.~z. 0,51 1445.28 ~540~d3 i636,94 1732,i3 i627 ~: 953.0 !445.23 95.1 96.6 1.~6.68 95.2 !732.04 9S~2 167._7.22 -0.~ ~ 0.64 WS.V^~. ... -07~.. 3.32 3.4i 102.52 r).!6. -0.06 0.7! 27t.80 -0~67 2,21 ~.3! t06.79 0.20 0.66 261.4i -0.50 0.69 i.07 119~48 0.23 1 .~^ i .~A ~' ': -0 ' t,24 217.2¥ 0,9? 20i4.74 2i08.74 94.6 192!.67 ~2.~ 2014.33 94.0 2107~96 ...,o ZZO4,,Z 92,3 2~75.52 8.49 3.3i 205.56 -7 ~ ' - ' . .~o -4.37 ~..'~ ~ 'i!1.6o_ 1.09 i4.52 4.!6 !96~59 -i3.04 -6.60 14.71 2C)7,q4 i.04 .... =' 5.59 ..... ~.~! i95,44 -20.69 0.11 22.61 ZO:J~,'6 l.b5 3:~,42 7,37 ~no.ns~=~...~ -31,00 -i2,70 ...... 33.5(, 202,27 1,'79 46.25 8.7i 2o~.88 -42,77 -~7.'76 46,39 202.78 2486,00 2579.61 2675.04 2769,~ 94~! 2~86.26 2460,47 257t.2%~ 94~6 2752.~0~ 6!.65 10.32 ~>_'..56 -%.72 -24.83 6!.97 203.65 !.72 80.44. 12,~ 200,74 -74,03 -32,3i 80.76 203,56 2,94 !03.44 15.A~ ............ 0,._.? 103.7! 202.44 3.19 1o~,43 ........ -~/.o5 161.35 200,62 1.lA 161.20 16.64 2¢0.44 -1~.~ =. ~ . 304.9,61 324~,72 95.3 2842.01 92.9 2926.58. 91.8 %.7 3~77.69 96.4 3180.60 !93.09 20.53 2cXJ.06 -180.75 226.72 21.97 19~.00 -212.45 263,&3 25,49 t96,16 -247,86 2~7,26 26,85 ~o~..~..~a~ -2A9.66_ 356.47 32,58 i96.57 -337,01 -&q.~) 193.26 200.73 1.76 -79.64 226.68 200.55 1.64 00,73 263,76 200.12 4,03 -i02.62 307,32 199.51 3,52 -t!6.24 ~='oJo. 49 i99.03 3.91 ~36,22 .~.32,56 3528.59 3579.45 34.45.~ y4,¢ 3258,66 96,3 3334,62 96,0 3407,.% 50,? 3446,07 i05.9 3526.37 409.69 [~..01 i97.34 -3~.7.93 ~58.89 39.87 196.34 -444.62 531,21 41,!2 i96,52 -5~,43 564.52 40.78 i96.50 -536.38 633,49 40.55 196,27 -602.20 -t31.78 409.70 -148.91 '~ ~" 4,.,8.~Y -176.02 5~4.52 -196,63 633f~' EC 198.76 3.66 198.52 4,05 198.27 1.31 198.17 0.66 F I::B '1 3 1997 C'J:~-o. Akcaka Oil & f:;a~: ',- .-e, .P~E NQ~ ************* CiRCUkAR ARC M~?HOD******** MF'E-37 MEAS. URFg iN%RVAL VERTICAL DEPTH D[PTH 377?,?6 ?4,7 3598,56 3875,30 95,3 3671.48 3970,43 $5,I 3744,43 ~,01 ?5,6 3818,05 4162,!4 76,1 38?2,57 TARGET SgAT!ON AZIMUTH LATITUDE SE~ION IN~LN, ft des de~ 6?4,70 40,06 ~97,o0 75,6,10 40,15 i77,44 8!7,17 [~.71 i97,83 -777,4i ?~,83 3~.,84 I~,25 -85~,85 DEPARTURE DIoPLAC~.MEN? at ~/-W ft ft -2i5~17 674,71 '~'~ ~ 756,12 -25i,85 8!7,19 -270.73 878.12 -~?0,26 935,85 AZIM~.ITH DLS dee/ de..] DOit 195,04 177,76 0,32 177,75 0,53 t77,% 0,36 I75,01 0 ';'~ 4257,i2 4352,38 4447,71 Eoo ~^ 4632,23 95,0 3966,79 95,2 404!M0 95,6 4i16,23 5~,0 4i88,28 c,~ 42~,42 ?~8,11 38.39 198,10 049,0i 1057,20 28.37 198.48 -1695,!1 1ti6,72 ~" . .... o~,~3 t9R.3~ -10A!,58 1173.71 28,26 198.57 -i115,82 1231,51 38,98 200,66 -I!70,09 -309,25 998,12 198,05 -327,79 t057,21 1%,06 0,25 -346,6i l11A,7R 198.08 0 ~'~ -~44,7¢ !173,72 i98,10 0,42 -384,06 1231,52 198,17 1,62- 4727,~ ~_21,/2 4912,75 1Ve,.3O '~,4 4354,49 94,i 4407,09 91,0 4477,54 96,1 4552,87 95,5 4628,C~. 129!,64 39,21 200,66 -1226,39 1[~1,28 -~.~4 200,5i -1282,37 14(~.,97 28,86 20i,76 -t3~6,i5 0/.97 ~^ ~ -i39!,90 1527.39 38,09 20i ~= -i446,89 -405,32 129i,64 195,29 0.24 -426,34 1351,38 "" "" - - 14,~+U? -447,13 !40~,98 195,50 1,30 -4AA+53 14~+^4 15'8,60 t ~ -489.40 1.527,42 i95.69 0,74 5!99,34 5293,34 5386,93 5_~.1,71 95,0 4702,98 94,0 4777,32 93,6 485!,36 94,8 4926,26 9!,6 4998,55. i585,76 qT,=n i99,o9 -ign~ 1643+28 37,67 198,06 -1556,24 1700,53 37,75 198,72 -1610,56 ~=~a A~ 37,84 198~09 -i665 1814.92 37,99 i96,8i .... "-q~ · -i/!7 -509,55 1585,79 198.,74 1+54 %27,84 i643,32 195,74 0,64 -545.9i 17C~),57 !98,72 %64,24 1755.65 195.7! 0,42 ="1 " %572.i2 5767,42 6053,t5 98,8 5076,38 95,3 5!5!,35 95.1 ~'~" ' ~z~6,48 94,6 5302,!0 %.1 ~ ..... ~ ~o 28,02 197.A1 -1777,50 1~34,55 .... q !99,37 -i833,29 !992,8! 37.35 198,!2 -18~,45 2~49+~ "' ~' 196+06 ,.~ .~ 21(~.,74 36.59 !96,,°5_ -1997,55 %99,12 1875,75 i 95,6.'_: 0,50 -617,78 1934,56 19~_..62 1,17 %36,5i 17'72,84 1':78+A3 I+23 -653,2! 2049,60 i98,58 i "': -669,45 2i06,75 i95,53 0,57 6146.80 6242,97 &338,45 6434.07 6529,48 93,7 5454,49 96,2 5531,&3 9'~ ~ 5AOA,41 95+6 5685,60 ~+4 5762+85 2i62+58 36,64 197,37 -2050.93 2219,99 36,70 i95,65 -2105,99 2276,68 36,23 .... .4A -?~n ~9 2338,11 36.I2 198,e% -2214,32 22~9,I0 35,75 196,73 -2267,66 %85,93 2162+59 19~,49 0.27 -~n~ o~ 2219,99 198,44 -717,94 227,6,68 1'98,38 ,';, 70 _~o~ .~ 2333,11 i95,~A 1,37 -75i,99 E389,09 198,'~= 1,25 - OJ . 6718,53 68ii,87 6905,47 6999,i6 93+6 58Z~+98 95,5 5916,85 o+o 55"~.!7 93,6 6~59,97 93,7 6147,15 Z44¢,0~ 35,40 196,73 -2319,8! 2498,71 35,28 196,23 -2372,75 2552,42 5~,02 196,55 -2424,3! 17o,_. -2475,38 2659,02 34,~S ~o~ ~ -2525~82 -767,66 2443,52 198,3i 0,38 ~ ~ 2498,71 198,27 0+33 -79&,49 2552,42 198.23 0,34 · "'" ~' ,00 -814,4! 2605,91 %31,06 2659,02 198,21 0,44 7091.01 7282,21 7376,48 7470.62 9i,8 6223,27 I'l~ ~o,9 y~+o 6[~3.22 94,3 646i,~, 94,t 6537,89 2710,41 33.71 198.13 -2574,62 2762,95 32,75 i98+37 -2624,51 2815,16 33,66 i99,42 -2673,91 2868,33 35,02 !'??,39 -2724,06 2WZ2+71 35,56 199,13 -2775,41 -~7,19 2710,42 %63,64 2762,96 %80,55 2815,16 -898,22 2868,33 -9t6,16 2922,71 198,21 0,73 195,21 1,00 198,23 t,13 198,25 1,45 198,27 RECEIVED FEB 1 3 1997 Alnska 0il & Gas Cons. Commission Anol'lor~go MEAS%~ED iN%RVAL V~T!CAL DE~H DEPTH ft ft ft 75&5,~ 96,3 6616,27 7661.~. 94,8 66~,26 7757,40 95.7 6770,&5 7650,16 92.6 6645,!4 7944,33 ?4,2 6920.03 8035,~5 9i.0 6~72.57 8130.69 95,5 7069.23 8224.26 93.4 7144,47 &305,4~ 6!,i 7210.02 ~ELAS~ DJR~OBY IS PR[O~TED 84®.00 94,6 7286,56 ~* ANADRILL ~*~**~****** SURVEY CALCUL~TiONS ************* CiRCULA~ A~ ~P]¢~-37 TARGET STATION AZtMU?d LATITUDE DEPARTURE DISPLACEMENT at %C~ION D~£LN. Ni-S ~I-~ ~t deo deo ft ft ft 29'78.55 35.37 !~,69 -2828,0~ -~34.7£ 2978,55 ~a~o~.~.,~,~v 36,07 ?C~,68_ . -288~,04 -753,81' 3033,87 ~90,13 ~5,02 20i,80 °2?32,54 -974,22 3090,!3 3145,30 37,16 202,61 -278~'.,74 -995.12 3145,31 o~,~t ~/,4~ 202,42 -3~D36,45 -1016,97 320~,~3 - iV¥,¢8 -3087,79 -i036,68 ~",17 3314,05 3~,4~ ~03,87 -3140~74 -!057,78 3314,09 3369,13 36,24 203.36 -3!9!.42 -i079,75 3369.20 3416,73 35,98 204,ii -3235~!? -1077,20 3416,82 i98,56 1,78 198,61 2~74 3472,02 35,98 204,ii -S~85,91 -1121,87 3472,15 198,85 0.02 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10600 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole& Open Hole) 11/27/96 Well Job # Log Description Date BL RF Sepia LIS Tape MPK-37 PERFORATING RECORD ....... ~-~-:i'~1-~-"~- I 1 MPK-37 !PRODUCTION PACKER 961 I 1 6 I 1 MPF-58 ~-t~ '7 5 ~""J 96357 CDR 961005 I 1 ...... 1__ MPF-58 96357 CDR TVD 961 005 I 1 ...... __ -- -- [ .-- ___ .__ __ _ __ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnicat Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~.~.~ 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 30, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Job # 96154 was sent to: CDR/CDN. CDR/CDN TVDfor well MPK-37 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 State of.Alaska Alaska Oil & Gas Conservation Comm. Attni Larry Grant 300i ,Porcupine Drive AnchOrage, Alaska 99501 1 OH LIS Tape' .. .... 1 Blueline each "- 1 RF Sepia each oxY USA, Inc Attn: Dadene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 467 .NOTE: NO DEPTH SHIFT PER MATT LINDER 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 Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED Date Delivered:~Er'r'm ~,,,, ~1:;: '~nne~,/,~ u Received By: Alaska 0il & Gas Cons, ~ommiss~ Anchorage HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A/<, 99501. Date: 22 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPK-38 ~-~ MPK-17 MPK-37 MPF-21 MPF-21 MPF-02 q~- ~ 0 DESCRIPTION /~C/PER~ ~IN~ BL+R~ vC'P~C/PER~ ~ZNAL BL+R~ PLS FINAL BL+RF ~[/ff/TEMP FINAL BL+RF r'~SBT FINAL BL+RF GR/CCL ~INAL BL+R~ ~C/PER~ ~I~AL BL+R~ ECC No. Run # 1 6638.03 Run # 1 6639.02 Run # 1 Run # 1 6729.01 Run # 1 6773.00 Run # 1 6773.01 Run # 1 Run # 1 Run # 1 6774.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 563-7803 Received by: RECEIVED Or FA~ to (907) AUG 30 1995 Date: ...... ,., ,. .... . ...; ,,l,,.,,, .'. ~,e~l~ HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Date: RE: 2 August 1996 Transmittal of Data ECC ~: 6729.00 Sent by: HAND CARRY Data: ML-LDWG Run # 1 Please si~ and return to: Attn. Ro~ey D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 ~chorage, AK 99518 Received by Date: AUG 'I 2 ~996 AJ~ska Oil & Gas Cons. Commis~ic, n An~orage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~ DATE: Chairman THRU' Blair Wondzell, (1~_ ,-~_ FILE NO: P. I. Supervisor FROM' Chuck Scheve, c5 SUBJECT: Petroleum Inspector August 1, 1996 aw9khadd.doc BOPE Test- Nabors 4ES BPX - MPU - K-37 PTD # 96-76 Kuparuk River Field Wednesday Au,qust 1, 1996: ! traveled to BPX's MPU K-37 Well, being completed by Nabors Rig 4ES,and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 4 hours and there was 1 failure. A flange gasket on the choke line had a small leak, it was tightened and retested OK. The rig was clean and the equipment appeared to be in good condition. The location was well organized allowing good access to the rig. Summary: I witnessed the initial BOPE test on Nabors Rig 4ES at Miine Point K Pad Well 37 test time 4 hours 1 failure. Attachment: aw9khadd X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALAS KA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: ~ Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Set @ X Weekly Other Workover: X DATE: Nabors Rig No, 4ES PTD # g6-76 Rig Ph.# BPX Rep.: Ed Vau~lhn MPK-37 Rig Rep.: Gene Sweatt 8,299 Location: Sec. 3 t. 8/1/96 659-4154 12N R. l lE Meridian , , Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES FLOOR SAFETY VALVES: Well Sign Upper Kelly / IBOP Drl. Rig OK Lower Kelly / IBOP Hazard Sec. OK Ball Type Inside BOP Quan. 1 Test Pressure P/F 250/5,000 P 250/5,000 P 250/5,000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves 1 Check Valve NZA I 250/5,000 N/A 250/5,000 I 250/5,000 I 250/5,000 2 250/5,000 Test Press. Test 250/3,000 Pressure P/F 250/5, OOO P P/F P P N/A' P P P P N/A 250/5,000 CHOKE MANIFOLD: No. Valves g No. Flanges Manual Chokes 1 Hydraulic Chokes I 18 250/5,000 P Functioned P Funcl~oned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 30 sec. Trip Tank OK OK System Pressure Attained 2 minutes 15 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: YES Remote: YES Flow Indicator OK OK Nitgn. Btl's: 4 Bottles Meth Gas Detector OK OK 1900 average Psig. H2S Gas Detector OK OK 3,000 ~,800 Number of Failures: t ,Test Time: 4.0 Hours. Number of valves tested 16. Repair or Replacement of Failed Equipment will be made within N/A 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: One small leak on choke line tightened and tested OK 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 I Waived By: Wrtnessed By: Chuck Scheve F 1-021L (Rev. 12/94) AW9KHADD.XLS HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL M -o2 MPK-37 DESCRIPTION 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 SBT/GR FINAL BL+RF ECC No. Run ~ 1 6638.02 Run # 1 6639,01 Run ~ 1 6728.00 Run ~ 1 6729.00 Run ~ 1 6730.00 Please sign and return to: Attn. Rodney D. Paulson Received by:~~ Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, A/4 99518 Or FAX to (907) 563-7803 Date: JUL 2 6 199~ Oil & Gas CoDs. ~mm~ion An~orage TONY KNOWLE$o GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 12, 1996 Tim Schofield, Sr Drlg Eng BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit MPK-37 BPXA Permit No: 96-76 Sur. Loc. 3509'NSL, 2045'WEL, Sec. 3, T12N, R11E, UM Btrnhole Loc. 264'NSL, 3126'WEL, Sec. 3, T12N, R11E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular Disposal approval is contingent on a submittal of a Sundry Application (Form 10-403) that addresses surface casing evaluation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission e pager at 659-3607. David W. 'Jo,,,hnston\ - : Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrilll-I lb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 61 fe et Milne Point Unit / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3509' NSL, 2045' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well number Number 405' NSL, 3079' WEL, SEC. 3, T12N, R11E MPK-37 2S100302630-277 At total depth 9. Approximate spud date Amount 264' NSL, 3126' WEL, SEC. 3, T12N, R11E 04/12/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD) property line ADL375132, 3126 feet MPK-25, 72'@2000'TVD feet 2560 8299'MD/7210'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^AC 25.035 (e)(2)) Kickoff depth 2ooo feet Maximum hole angle36.,~8 o Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3628' 31' 31' 3655' 3500' 779 sx PF 'E', 686 sx Class 'G' 8-1/2" 7" 26# L-80 Mod B 8269' 30' 30' 8299' 7210' 313 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) R F_ C E IV E D true vertical feet True Vertical depth Casing Length Size Cemented Measured depth APE:{ 1 u 1996 Structural Conductor Surface Alaska 0il & Gas Cons. Com,missiorl Intermediate Anchorage Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ced~j,f:y that,,~.~t~ is true and correct to the best of my knowledge (,.,oM-~-~ £r~0'~cJ'.' ~h/','~ Signedf/""-/r.~~..~~ Title Senior Orillin~l Engineer Date Commission Use Only Permit Number IAPI number.~--~ .,,~ .~..,~..~/,,IApproval date, , See cover letter I.~-4-~J- '~'~"-7~' 150.0~- '.--' r-~___-~.,~=,.-7~ ~///z.l~¥ for other requirements Conditions of approval Samples required [] Yes ,E~No Mud Icg required IIYes ,]~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey requirecl J~l Yes [] No Required working pressure for BOPE [] 2M; CI3M; l~i~.5M; I--Il OM; []15M; Other: Ui'iginal Signed By by order of Approved by David W. Johnston Commissioner the comm,ssion Date Form 10-401 Rev. 12-1-85 Submit in triplicate MPK-5 Kick Tolerance 4/10/96 12:07 PM Well: Name: Milne Point K-37 Kuparuk Sands <= Data Input LOW GOR Milne Formation Fluids <--=- Data Input Mud Weight (ppg) 10.00 For Well Plans: Mud Wt. = Zone of interest pore pressure Weak point - Measured depth (ft) Weak point - True vertical depth (ft) Weak point - Hole angle (deg) Weak point - Hole size (in) Weak point pressure - EMW (ppg) r655' ,500' 37.0= 8.500" 12.50 Zone of interest - Measured depth (ft) Zone of interest - True vertical depth (ft) Zone of interest - Hole angle (deg) Zone of interest - Hole size (in) Zone of interest - Pore pressure EMW (ppg) 37.0. 8.500" 10.00 Gas gradient (psi/ft) 0.10 Bottom hole assembly OD (in) Bottom hole assembly length (ft) Drill pipe OD (in) BHA annular vol. @ zone of interest (bbl/ft) DP annular vol. @ zone of interest (bbl/ft) DP annular vol. @ weak 6.500" 270' 5.000" 0.0291 0.0459 0.0459 Additional safety margin (psi) <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <==- Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input 0.00 <== Data Input Weak point pressure (psi): Plo 2,275 psi Weak point pressure - Safety margin: Pmax 2,275 psi ~ Pmax EMW 12.50 ppg Max anticipated formation pressure (psi): Pf 3,647 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD} 3,513' Weak Pt to Zone of Interest distance (MD ft): OH {MD} 4,398' Maximum influx height at the bit (TVD ft): H {TVD} 1,083' Maximum influx height at the bit (MD ft): H {MD} 1,356' Calc. volume of {H} around BHA: Vlbha Calc. volume of {H} around drill pipe: Vldp 7.9 bbl 49.9 bbl Calc. volume that H equals @ initial shut in: V 1 57.7 bbl Calc. vol. that H equals @ weak point (MD ft): Vwp 62.3 bbl Calc. volume of Vwp @ initial shut in: V 2 Kick Tolerance: V 2 Initial SICP which equals the Weak Point Pressure: NOTE: Spreadsheet Created by:, G. S. Walz 11/22/94 38.8 bbl 38.8 bbl 455 psi I Well Name: I MPK-37 Well Plan Summary ]Type of Well (producer or injector): I Kuparuk Producer REC .F.:iV D AP!:I 1 0 lqq~ Alaska Oil & Anchorage Surface Location: 3509' FSL 2045' FEL Sec 3 T12N R11E UM., AK. Target Location: 405' FSL 3079' FEL Sec 3 T12N R11E UM., AK. Bottom Hole 264' FSL 3126' FEL Sec 3 T12N RllE UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: 1337015 I I Rig: I Nabors27E I IEstimated Start Date: I April 12, 1996 IOperating days to drill and case: [13 j I~m: 18299' I I TVD: 17210' BKB I I KBE: 161' I Well Design (conventional, slimhole, I Ultra Slimhole, 7" Longstring I etc.): Formation Markers: Formation Tops MD TVD Formation Pressure/EMW B use permafrost 1811 1811 n/a NA (Top Schrader) 5074 4661 1905 psi# / 8.0 ppg OA 1955 psi# / 8.0 ppg Base Schrader Bluff 5335 4871 1995 psi# / 8.0 ppg Top HRZ 7374 6511 n/a Base HRZ n/a Kupark D Shale 7859 6901 n/a Kuparuk C 8145 7131 3650 psi# / 10 ppg TKB 3669 psig/ 10 ppg Total Depth 8299 7210 n/a Casing/Tubing Prol ;ram: T Hole Csg/ Wt/Ft Grade Corm Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32' 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3628' 31' 3655/3500 8 1/2" 7" 26# L-80 Mod B 8269' 30' 8299/7210 N/A (tbg) 2-7/8" 6.5# L-80 EUE 6771' 29' 6800/7021 8rd Internal yield pressure of the 7" 264/casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 264/will be run on bottom. Logging Program: [Open Hole Logs: Surface MWD ONLY Schrader Bluff Final LWD GR/Resistivity/SFC CSG to TD CDN over Kupamk intervals [Mud Logs: Mud logs and samples are not required API # 50-029-22659 April 10, 1996 Mud Program: Special design considerations Hydrates LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. We will have hydrates on K Pad. We will have our mud weight to 11 PPG by 2000 feet. We will weight up in 0.5 ppg increments as necessary. We will use the coldest mix water available to minimize warming if the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to below 600 GPM when hydrates are present to keep mud temperatures to a minimum. Surface Mud Properties: I Spud Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 11.5 100 35 15 30 10 15 Production Mud Properties: ]LSND Density Marsh Yield 10 see 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.5 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1 2000' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 36.48 degrees _< 4 degrees 36.48 Degrees MPK 25 Well Plan is 72 feet @ 2000 feet TVD This wellplan will allow MPK-37 wellpath to be drilled as per BP's close approach guidelines. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. 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 after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. AP1 # 50-029-22659 April 10, 1996 Request for AOGCC Approval Disposal of Drilling Wastes (20AAC25.254) 1. Approval is requested for Annular Pumping for K Pad well MPK-37 to be drilled, and any well on the pad/drillsite previously permitted for disposal activities by AGOCO. 2. The Base of the Permafrost for all wells located in the Milne Point Unit is 1750 feet. 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. 3. The receiving zone to which the fluids will migrate is identified as the Prince Creek geological formation at 2500 - 3300' TVD. The confining layer is the Sagavanirktok Shale defined by logs between _+ 2150 to _+ 2500 'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7-24-95. 4. There are no wells on Milne Point K Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The drilling wastes to be disposed of during this operations can be defined as drilling mud, cement contaminated drilling mud, and drill cuttings; rig wash fluid (inclusive of rig boiler blow down, and mud and cement rinse water of associated rig equipment, completion fluids (seawater and brine), formation fluids, reserve pit fluids, and drill rig domestic waste water. (Note: if you plan to dispose of fluids OTHER than those outlined above you must list them on the request) The maximum volume to be disposed of in the annulus is 35,000 bbls. Fluid densities will range from 8.3 to 13.0 ppg. Any deviation from this program must be detailed separately. 6. The 9.625 "surface casing shoe will set at 3659'md 3523 ('tvd) and cemented with 703 "E" and 250 "G" sacks cement. This depth is below the base of the permafrost (1750' TVD) and into the top of the Prince Creek formation which has a long established history of annular pumping at Milne Point. The break down pressure of the Prince Creek formation is 13 to13.5 ppg equivalent mud weight. 7. The burst rating (80%) for the 9.625" 40# 'surface casing is 4600 psi. The collapse rating (80%) for the7" 26# 'intermediate/production casing is 4325 psi. 8. The Maximum Allowable Surface Pressure while annular pumping is the lesser of 2000 psi or the calculated pressure according to the following equation: MASP (psi) = (Max Breakdown ppg-8.3 ppg) X 0.052 X Surf Csg Shoe TVD MASP (psi) = 952 psi 9. The maximum pressure imposed at the surface casing shoe is calculated according to the following equation: Max Press @ Surf Csg Shoe (psi) = .052 x Max Breakdown ppg x Surf Csg Shoe TVD Max Prss at Surf Csg Shoe =2473 psi This pressure is less than the 80% burst and collapse casing pressures calculated in #7. 1 0. Additional data supplied as needed. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREVVOL PERMITTED PERMITTED DATES , INJECTED (BBL) VOL (BBL) Milne Point M P K- 1 7 0 35,0 00 Requested Milne Point M PK-25 0 35,000 Requested Milne Point M P K- 1 8 0 35,000 Requested Milne Point M PK-37i 0 35,000 Requested Milne Point M P K- 3 8 0 3 5,0 0 0 Requested Milne Point M P K- 1 0i 0 3 5,0 0 0 Requested FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. AP1 # 50-029-22659 April 10, 1996 DRILLING HAZARDS AND RISKS: See both the NEW Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on the Cascade wells , and review recent wells drilled on E Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. Hydrates We will have hydrates on K Pad. We will have our mud weight to 11 PPG by 2000 feet. We will weight up in 0.5 ppg increments as necessary. We will use the coldest mix water available to minimize warming if the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to below 600 GPM when hydrates are present to keep mud temperatures to a minimum. The MPU PE group will be perforating, and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Be prepared to treat these losses while drilling initially with LCM treatments. This will become even more prevalent in the production hole when we shallow set surface casing. Weighting up before entering the reservoir will be the most likely time we would lose circulation. Stuck Pipe Potential: There has been several cases of stuck pipe occuring at the top of the Kuparuk, with both the intervals above and below the Schrader Bluff open. We have made improvements to the mud system and continue to monitor for stuck pipe conditions. The stuck pipe intervals and short trip guidelines on the Pad Data Sheet should be followed to avoid stuck pipe incidents. Running casing should be as smooth and quickly as possible to avoid stopping casing and possibly getting stuck. Shallow Set Casing: The wells at K Pad will use shallow set casing which can provide cost savings if the wells are trouble free. There are increased risk for stuck pipe, lost circulation, especially while running casing. The casing program will include running centralizers over both the Kuparuk and Schrader Bluff, and cemented in a single stage. The rig team will need to be more careful on these wells to fully realize the cost benefits. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 38.8 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3708 psig (9.9 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.9 ppg EMW (3708 psi @ 7131' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. We will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. Alaska AP1 # 50-029-22659 April 10, 1996 MP K-37 Proposed Summary of Operations o , , o . 10. 12. 13. 14. 15. 16. 17. 18. 17. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5A Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. Drill 12-1/4" surface hole to 3655' md (3500' tvd). Use extreme care when drilling through the known hydrate interval down to + 3100 feet TVD. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulative volume for LOT test for well file. Follow Pad Data Sheet short trip guidelines. Drill 8-1/2" hole to TD at 8300' MD (7210' TVD). (Note: This hole section will be logged with LWD Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with 1 stage cement program. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. Make sure there is a circulating head for the topdrive before starting to run casing. ND BOPE and NU dry hole tree. Release rig to next well. Note: This well will be perforated, and cleaned out with a completion rig and prior to running the ESP completion. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. PU and RIH with perforating string (procedure to be distributed later with perforation intervals). PU and R/H with 2-7/8" EUE 8rd tubing with Electric Submersible Pump (ESP) completion. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST RIG WORK o Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. . A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. , An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. , The rig will not complete this well. PEs will perforate and clean out this well with a pulling unit. API # 50-029-22659 April 10, 1996 MPK-37 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 70 bbls NSCI Spacer weighted to 12 ppg LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 779 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES' 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS' 686 FLUID LOSS: 100-150 cc YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 CENTRALIZER PLACEMENT: 1. 1 TURBULATOR centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. 1 TURBULATOR centralizer per joint of 9-5/8" casing from 2000 to 2500 feet. OTHER CONSIDERATIONS: This well is being drilled after MPK-25 was suspended following problems with the surface casing job. We cannot stress the importance of getting a sucessful cement job on the well. There are changes to the spacer, cement volumes and centralizer program on this well. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while the rig was shut down filling only 5 joints. CEMENT VOLUME: 1. The Tail Slurry volume is increased to 623 sacks is calculated to cover the 9-5/8" to 1800 feet with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints is 6 BBL. AP1 # 50-029-22659 April 10, 1996 MPK-37 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK and SCHRADER BLUFF: CIRC. TEMP: 115° F BHST 120 deg F at 7040' TVDSS. SPACER: 50 bbls fresh water . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.3% CFR-3, 30#/SK Silicalite, 1.7% Halad 344 WEIGHT: 12.25 ppg YIELD: 2.81 cu ft/sk APPROX # SAC}CS: 313 FLUID LOSS: < 45cc/30 min @ 140° F MIX WATER: 16 gal/sk THICKENING TIME: 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (34 total). This will cover 200' above the C Sand. 2. 7"x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6900' - 6100' to cover the Schrader Bluffs Sands (20Total). 3. Run one 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 55. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. ECEiVFD APR Oil & ~.i~-,, API # 50-029-22659 April 10, 1996 MPK-5 Cement Calculator !Milne Point Cement and Centralizer Calculations Well MPK-37 Surface (1 Stage) Cement Job cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF 0.0558 BPF + 30% 0.0725 BPF + 200% 0.1673 Depth BBLS Cu. Ft. Sacks Top of Cemenl Shoe Depth ~~ Calculated G Tail Volume 1855 140.5 789 686 1800 E Lead Volume 1800 301.2 1691 779 Surface Total E 7 7 9 Total G 6 8 6 9-5/8" Turbs 10 From 3655 to 3255 9-5/8" Turbs 10 From 2400 to 2000 Production 1-Stage Cement Job J 75 Cement Yield Hole Size 8. Silicalite Slurry 2.05 Casing Size BPF I 0.0226 i BPF + 30% J 0.0294 Top of Cemenl Stage 1 BBLS Cu. Ft. Sacks Calculated NATop - ',~? 114 642 313 4510 Seabee Top Kuparuk Top Centralizers 2 5 Across the Kuparuk Centralizers 27 Across the Schrader Bluff Total G ST1 31 3 Total ST Blades 5 4 Page 1 BPX - Sha ed SePvic' .... s IDmiLLin9 i Mitne ' MPK il MPK-37 As-Sui[t ]i MPK-37 WpS MPK- 5 T get Fe s \ t I!.,: ! 'x~~ ....... /i 419196 7;24 pm CRITICAL POINT DATA MD Inc Azi, TVD N/S E/W TIE IN 0 0.00 198,35 0 0 N 0 E Base 1813 O.Q3 1~.35 1813 0 N 0 E PermaFrost KOP / ST~T 1~7 0.~ 198.~ ~7 0 N 0 E OF BUILD ~ ~.50/100 ~t END ~ BUILD 3387 37.~ 1~.35 3287 4~ S ~45 W N~ Sands 5010 37,~ 1~,35 4583 1~5 S 453 W Base Schrader 5~79 37.~ 1~.35 4798 1519 S ~ W T~Z 7~76 37.~ t98,35 6~3 ~ S ~ W TKUD 7765 37.~ 1~,35 6783 ~939 S 974 W Taraet (96E 8053 37.~ 1~.35 7013 3~03 S 1029 W M[)l<gS) / I'KUCI 1000-- 1500-- 1813--~ 19O7--~ 2000--~ 2500-- 3287 3500-- 4000-- 4500-- 4583 4798 5000-- 5500-- 6000-- 6393. 6500-- 6783 7210 7500 VERTICAL VIEW SCALE 500 Pt. / DIVISION TVD REP WELLHEAD VERTICAL SECTION RED WELLHEAD 0-- 0,00 @ 0 MD TIE IN 0,00 @ 1813 MD Base PermoP~ost 0,00 e 1907 MD KOP / START EF BUILD @ 2.50/100 Pt 2.50 8 20(37 MD 5.00 ~ 2107 MD 7,50 ~ 2207 MD 3710,00 ~ 2307 MD 12.50 @ 2407 MD 15,00 @ 8507 MD 17,50 ~ 2607 MD 20.00 8 2707 MD 22,5O@ 2807 MD 25.O0 8 29O7 MD 87.50 ~ 30O7MD 30.00 8 3107 MD 2,50 8 32O7 MD .0O 8 3387 MD END[~- BUILD 5 MD. 350(] TVD . ~37.0O @ 5010 MD NA S~nds !438 \ 1600 HORIZONTAL VIEW (TRUE NORTH) SCALE 250 Pt, / DIVISION SURVEY REP WELLHEAD 1850 100O 750 500 850 0 250 0O8 5279 MD B~se Scl'~ader ~ CASING POINT DATA ~ OD M---~--IIn-~-I~z; TVD N/S E/W ~ 9 5/8 in 3655 37,~ 198,35 3~ 591S 196 3844 7810 1076 ~ 5__~ 8300 37,00 198,35 S ~ I To~t ~e TVD NS EW ~,dX ~idY I ~[To~t (96E ~k85) 7013 3103 S 1089 ~~ 7~76 MD T~Z 7.~ ~ 7765 MD ~6 ~37,~ ~ ~53 MD TQ~% (96E MOk85) / TK~i 3869 ' ~5~,~ ~%MD, 7210 TVD 3418 0 500 100O 1500 200O 25[X] 3000 3500 4000 VERTICAL SECTION PLAND 19835 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.25.31 N - Long. 149.18.41 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6005644.17 N 584512.89 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.1 Vertical Section Plane: 198.35 deg. Page I Date: 4/9/96 Time: 7:24 pm Wellpath ID: MPK-37 Wp2 Last Revision: 4/9/96 BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-37 As-Built MPK-37 Wp2 MPK-25 Target Feas Measured Incl Drift Subsea TVD Course T 0 T A L Depth Dir. Depth Length Rectangular Offsets (fl) (deg.) (deg.) (ft) (ft) (ft) (ft) (fl) GRID Coordinates Northing Easting fit) (fl) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (fl) (deg.) (fl) (dgtl00ft) (dgtl00ft) (dg/100ft) (deg) (fl) (fl) (ft) (fl) (deg.) (ft) Survey Tool TIE IN 0.00 0.00 0.00 -62.50 0.00 0.00 0.00N Base Permafrost 1812.50 0.00 0.00 1750.00 1812.50 1812.50 0.00N KOP / START OF BUILD @ 2.50 deg/100 ft 1907.25 0.00 0.00 1844.75 1907.25 94.75 0.00N 0.00E. 6005644.18 584512.89 0.00E 6005644.18 584512.89 0.00E 6005644.18 584512.89 0.~@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00E 0.00 0.~@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00E 5.00 0.~@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00E 5.23 0.00 0.00 0.00 MWD 5.00 0.00 2.62 BPHM-PBD 5.23 0.00 2.77 BPHM-PBD 2007.25 2.50 198.35 1944.72 2007.22 100.00 2.07 S 2107.25 5.00 198.35 2044.50 2107.00 100.00 8.28 S 2207.25 7.50 198.35 2143.89 2206.39 100.00 18.61 S 0.6b'W 6005642.10 584512.23 2.74W 6005635.87 584510.24 6.17W 6005625.50 584506.93 2.18@198.35 2.18 2.50 0.00 2.50 2.5 2.07 S 0.685~r 5.47 8.72@ 198.35 8.72 2.50 0.00 2.50 5.0 8.28 S 2.73W 5.73 19.61@ 198.35 19.61 2.50 0.00 2.50 7.5 18.63 S 6o12W 6.03 5.47 288.35 2.93 BPHM-PBD 5.70 288.35 3.10 BPHM-PBD 5.92 288.35 3.30 BPHM-PBD 2307.25 10.00 198.35 2242.72 2305.22 100.00 33.05 S 10.9fiW 6005611.01 584502.31 2407.25 12.50 198.35 2340.79 2403.29 100.00 51.56 S 17.103/ 6005592.43 584496.38 2507.25 15.00 198.35 2437.92 2500.42 100.00 74.12 S 24.58W 6005569.79 584489.15 34.82@ 198.35 34.82 2.50 0.00 2.50 10.0 33.08 S 10.8EW 6.39 54.33@ 198.35 54.33 2.50 0.00 2.50 12.5 51.63 S 16.91W 6.85 78.{73@ 198.35 78.09 2.50 0.00 2.50 15.0 74.23 S 24.27W 7.43 6.14 288.35 3.51 BPHM-PBD 6.35 288.35 3.75 BPHM-PBD 6.57 288.35 4.02 BPHM-PBD 2607.25 17.50 198.35 2533.92 2596.42 100.00 100.68 S 33.3~¥ 6005543.13 584480.65 106.07@ 198.35 106.07 2707.25 20.00 198.35 2628.60 2691.10 100.00 131.19 S 43.5CW 6005512.51 584470.88 138.21@198.35 138.21 2807.25 22.50 198.35 2721.80 2784.30 100.00 165.59S 54.91W 6005477.99 584459.86 174.4~@198.35 174.46 2.50 0.00 2.50 0.00 2.50 0.00 2.50 17.5 100.84 S 32.91W 8.15 2.50 20.0 131.42 S 42,81W 9.05 2.50 22.5 165.91 S 53.95W 10.11 6.78 288.35 4.30 BPHM-PBD 6.99 288.35 4.61 BPHM-PBD 7.21 288.35 4.95 BPHM-PBD 2907.25 25.00 198.35 2813.32 2875.82 100.00 203.81S 67.589/ 6005439.63 584447.62 214.73@198.35 214.73 3007.25 27.50 198.35 2903.00 2965.50 100.00 245.79 S 81.5CW 6005397.50 584434.18 258.95@198.35 258.95 3107.25 30.00 198.35 2990.67 3053.17 100.00 291.44 S 96.64W 6005351.69 584419.56 307.05@198.35 307.05 2.50 2.50 2.50 0.00 0.00 0.00 2.50 25.0 204.24 S 66.3CW 11.36 2.50 27.5 246.35 S 79.83W 12.78 2.50 30.0 292.15 S 94.5 IW 14.38 7.43 288.35 5.31 BPHM-PBD 7.66 288.35 5.70 BPHM-PBD 7.89 288.35 6.12 BPHM-PBD 3207.25 32.50 198.35 3076.15 3138.65 100.00 340.68 S 112.97W 6005302.27 584403.79 358.92@198.35 358.92 3307.25 35.00 198.35 3159.29 3221.79 100.00 393.41 S 130.45W 6005249.35 584386.91 414.47@198.35 414.47 END OF BUILD 3387.25 37.00 198.35 3224.01 3286.51 80.00 438.04 S 145.25W 6005204.56 584372.62 461.4~@198.35 461.49 2.50 2.50 2.50 0.00 0.00 2.50 32.5 341.56 S 110.31W 16.15 2.50 35.0 394.49 S 127.2CW 18.09 2.50 37.0 439.29 S 141.47W 19.74 8.14 288.35 6.56 BPHM-PBD 8.39 288.35 7.04 BPHM-PBD 8.60 288.35 7.44 BPHM-PBD CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 3654.57 37.00 198.35 3437.50 3500.00 267.32 590.74 S 195.85W 6005051.31 584323.71 622.37@198.35 622.37 NA Sands 5010.01 37.00 198.35 4520.00 4582.50 1355.44 1365.00 S 452.63W 6004274.27 584075.74 1438.0(3@ 198.35 1438.09 0.00 0.00 0.00 0.00 0.00 37.0 590.74 S 195.859/ 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 37.0 1369.81 S 438.12W 55.05 16.69 288.35 13.26 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 4/9/96 Wellpath ID: MPK-37 Wp2 Measured Incl Drift Subsea TVD Course T O T A L GRID Coordinates Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hor Dir. Vert Survey Tool Depth Dir. Depth Length Rectangular Offsets Northing Fasting Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Base Schrader 5279.22 37.00 198.35 4735.00 4797.50 269.21 1518.78 S 503.63W 6004119.94 584026.49 1600.11@198.35 1600.11 0.00 0.00 0.00 37.0 1524.18 S 487.34W 61.01 18.12 288.35 14.32 BPHM-PBD THRZ 7276.37 37.00 198.35 6330.00 6392.50 1997.16 2659.62 S 881.92W 6002975.04 583661.06 2802.03@ 198.35 2802.03 0.00 0.00 0.00 37.0 2669.39 S 852.43W 105.34 28.87 288.35 22.48 BPHM-PBD TKUD 7764.71 37.00 198.35 6720.00 6782.50 488.33 2938.57S 974.42a3/ 6002695.10 583571.70 3095.91@198.35 3095.91 0.00 0.00 0.00 37.0 2949.41S 941.7UN 116.20 31.53 288.35 24.52 BPHM-PBD Target (96E Mpk25) / TKUC 1 8052.70 37.00 198.35 6950.00 7012.50 287.99 3103.07S 1028.97W 6002530.00 583519.00 3269.23@198.35 3269.23 0.00 0.00 CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. 8299.74 37.00 198.35 7147.30 7209.80 247.05 3244.19S 1075.7TN 6002388.38 583473.79 3417.9£@198.35 3417.90 0.00 0.00 8299.99 37.00 198.35 7147.50 7210.00 0.25 3244.34S 1075.82r~V 6002388.24 583473.74 3418.0t5@198.35 3418.06 0.00 0.00 0.00 37.0 3114.55 S 994.35W 122.61 33.10 288.35 25.72 BPHM-PBD 0.00 37.0 3244.19 S 1075.7TN 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 37.0 3256.36 S 1039.5fiW 128.11 34.45 288.35 26.76 BPHM-PBD ivlPK-37 MPK-37 ~er~vlc _s D~iLLing PLo, ne: Zone4 , ~ / j I-I_I_.IBLJRTON \ l.,1.~1, j / As-Suil~ WpP MPK-P5 Tc~m9e~ Feas 419196 7:21 pm TmaveLLin9 CyLindem - Not, mai PLane ReFePence ~/e~l - MPK-37 Wp_2 MD: 0 - 8300 Ft, Interval, 50 ~t, AIL Directions usin~ BP Hi~hside Method Lines ape the EXACTED ~is~ance OncLes ape ~he D,P, FLB~ING/~T-]N condi~io~:~ - / P70 240 120 210 150 WELLS STATUS MPK-5 MWD FL~WiNG v::)K'"'L7 MWD MPK-25 M~D SHUT-iN ID Depth(Pt) Tod Code NPK-~7 Wp2 0-8300 20,03 BPI-~F-PBD ~<----~7 v~3 L..-.Tz.~? NPK-8$ NWD 0-3813 BO,03 B~THPI-PBD ~P<--36 xWD 9-'753} 180 CLOSEST POINTS Wellpoth SLot ]]stonce D~ectlon ReP MD ReP TVD Se~,Focto~ MPK--5 NWD F~<-5 ~'~--Bu.J[~ 239.69 3~3.40 50.~ 50.~] MP~<-.- i7 >iWD F~zY-.-. ! 7 As"-/}..~Vt .t,-ig.g,:.~ HPK-~5 NWD ~-~ As-~i[~ 7&48 3B9,~0 B~,O0 ~9~.97 6,60 MP~-38 MWD [~:ff-38 As-B,..~iC? ! lO, t2 68.48 50.00 ~.:E)/),) ]6,l.60 Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.1 Page 1 Date: 4/9/96 Time: 7:21 pm Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-37 As-Built MPK-37 Wp2 MPK-25 Target Feas N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8299.99 ft.(MD) All Directions using BP Highside Method in Dee. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Flowing Shut-in Enter Well Safety Min. Safety Safety Shut-in Clear Spread MD TVD Dist Dist Zone MD MPK-5 MWD 221.2 235.6 1150 1150 17.3 2.9 MPK- 17 MWD 119.6 143.4 1900 1900 28.5 4.7 MPK-25 MWD -2.9 35.2 3750 3576 47.5 9.4 MPK-38 MWD 76.0 101.3 2050 2050 30.5 5.1 3750 Enter Exit Exit Danger Danger Shut-in Zone Zone Zone MD MD MD Close Approach Status OK OK SHUT-IN OK Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.1 Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-37 As-Built MPK-37 Wp2 MPK-25 Target Feas N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8299.99 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Wellpath Distance Direction MPK-5 As-Built MPK-5 MWD 239.69 338.40 284.40 340.59 MPK-17 As-Built MPK-17 MWD 149.88 338.27 167.30 345.67 MPK-25 As-Built MPK-25 MWD 72.48 329.20 99.64 347.93 MPK-38 As-Built MPK-38 MWD 110.12 68.48 123.10 60.56 RefMD RefTVD Sep Factor 50.00 50.00 275.2 1850.00 1850.00 27.2 50.00 50.00 147.7 2100.00 2099.77 14.6 2000.00 1999.97 6.6 3750.00 3576.21 1.8 50.00 50.00 164.6 2200.00 2199.20 10.2 Page 1 Date: 4/9/96 Time: 7:21 pm WELL PERMIT CHECKLIST redrll [] serv [] wellbore seg [] ON/OFF SHORE ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool .............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force .......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... N 15. Surface casing protects all known USDWs ........ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. .T--~ 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... f'~;~- N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate .................. ; ; i~ N 26. BOPE press rating adequate; test to ~-OC~-~ s g N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~.Y~N-/~~V 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y N~ REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y /N L 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports .... /. Y N [explorator~ only] GEOLOGY: ENGINEERING: COMMISSION: BEW HOW/Ijb - A:%FORMS~cheklist rev 11/95 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK-37 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22674-00 REFERENCE NO : 96154 M CROE LMEg RECEIVED SEP 05 1996 AleM,,8Ofl& Ga~Con8. ~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE . 96/08/19 ORIGIN : FLIC REEL NAME : 96154 CONTINUATION # : PREVIOUS REEL COMMENT : BP EXPLORATION, MILNE POINT MPK-37, API# 50-029-22674-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE . 96/08/19 ORIGIN : FLIC TAPE NAME : 96154 CONTINUATION # : 1 PREVIOUS TAPE CO~2~ENT : BP EXPLORATION, MILNE POINT MPK-37, API# 50-029-22674-00 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 MPK-37 500292267400 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 19-AUG-96 BIT RUN 1 96154 ST. AMOUR COOPER BIT RUN 2 ......... 96154 DENNETT CARLILE BIT RUN 3 3 12N lie 3509 2045 61.20 60.20 33.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.500 9.625 3650.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~ 3RD STRING PRODUCTION STRING REMARKS: Well drilled 21-APR through 29-APR-96 with CDR/CDN. Ail data was collected in two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O0!CO1 DATE : 96/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUN~V2~Y LDWG TOOL CODE START DEPTH STOP DEPTH I4WD 56.5 8399.5 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (M~ASUREDDEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: No depth adjustments were made as per Matt Linder. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... ...... BIT RUN NO. MERGE TOP MERGE BASE 1 56.5 3658.0 2 3658.0 8399.5 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~ PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 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 619123 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0t1~M619123 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0Fff4~619123 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OFff4M619123 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD Otff4M619123 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~M 619123 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 619123 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 619123 O0 000 O0 0 1 1 1 4 68 0000000000 GR ~ GAPI 619123 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 619123 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO MWD G/C3 619123 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 619123 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 619123 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 619123 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8399.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 109.465 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~5 PAGE: DEPT. 56.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD GR.MWD 22.449 RHOB.~gWD -999.250 DRHO.MWD -999.250 PEF.~gD CAI=N. MWD -999.250 NPHI.I~WD -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH MWD 56.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH 3658.0 29-APR-96 FAST2.5 4.0 MEMORY 8400.0 56.0 8400.0 80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:45 PAGE: HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 40.8 TOOL NUMBER RGS904 12. 250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. 10 MUD VISCOSITY (S) : 45.0 MUD PH: 8.5 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 860 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.580 MUD CAKE AT (MT): 20000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) REMARKS: ***RUN 1 - CDR ONLY 112'-3658'*** RES TO BIT: 46.23'; GR TO BIT: 56.65' Rm=2. 615@60 DEG, Rmf=2.223@60 DEG ***RUN 2 - CDR/CDN 3658'-8400'*** RES TO BIT: 62.24'; GR TO BIT: 72.66' DEN TO BIT: 116.76'; NEUT TO BIT: 123.76' WELL TD'D AT 0150 29-APR-96 MAX DEVIATION 41.12 DEG AT 3528' $ LIS FORMAT DATA 68.0 69.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~5 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 619123 O0 000 O0 0 2 1 1 4 68 0000000000 ~ LW1 OH~M619123 O0 000 O0 0 2 1 1 4 68 0000000000 RP LW1 OH~M619123 O0 000 O0 0 2 1 1 4 68 0000000000 DER LWl 0tff4~619123 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 FPHR 619123 O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR 619123 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 619123 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. ROP.LW1 3658.000 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 -999.250 145.918 FET. LW1 - 999.250 GR. LW1 - 999.250 DEPT. 56.000 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 -999.250 ROP. LW1 -999. 250 FET. LW1 -999. 250 GR. LW1 23 . 483 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~5 PAGE: * * * * FILE TRAILER * * * * FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : *~** FILE HEADER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE . 96/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NOWi~ER : 2 DEPTH INCREMENT: O . 5000 FILE SU~4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 3527.0 8399.5 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RESIST./GR CDN NEUT./DENS. $ 29-APR-96 FAST2.5 4.0 MEMORY 8400.0 56.0 8400.0 80 36.0 40.8 TOOL NUMBER RGS022 NDS022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:45 PAGE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. 10 MUD VISCOSITY (S) : 45.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 5.0 RESISTIVITY (OHN~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 860 MUD AT MA~ CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT) : 1.580 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ***RUN 1 - CDR ONLY 112'-3658'*** RES TO BIT: 46.23'; GR TO BIT: 56.65' Rm=2. 615@60 DEG, Rmf=2.223@60 DEG ***RUN 2 - CDR/CDN 3658'-8400'*** RES TO BIT: 62.24'; GR TO BIT: 72.66' DEN TO BIT: 116.76'; NEUT TO BIT: 123.76' WELL TD'D AT 0150 29-APR-96 MAX DEVIATION 41.12 DEG AT 3528' $ LIS FORMAT DATA 68.0 69.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:~5 PAGE: TYPE REPR CODE VALUE 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 619123 RA LW2 0P~4~619123 O0 000 O0 0 3 1 1 4 68 0000000000 RP LW2 OH~4~ 619123 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OH~I 619123 O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 FPHR 619123 O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR 619123 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 619123 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 619123 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LW2 G/C3 619123 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LW2 BN/E 619123 O0 000 O0 0 3 1 1 4 68 0000000000 CALNLW2 IN 619123 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI LW2 PU-S 619123 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8399.500 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP. LW2 109.465 FET.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF.LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 DEPT. 3527.000 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP.LW2 -999.250 FET.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF. LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 -999.250 -999.250 -999.250 -999.250 -999.250 48.000 END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1996 09:45 PAGE: 10 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE . 96/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/08/19 ORIGIN : FLIC TAPE NAME : 96154 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · BP EXPLORATION, MILNE POINT MPK-37, API# 50-029-22674-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/08/19 ORIGIN . FLIC REEL NAME : 96154 CONTINUATION # : PREVIOUS REEL : COMMENT · BP EXPLORATION, MILNE POINT MPK-37, API# 50-029-22674-00 MPK - 37 MILNE POINT --:--~ :~'-::'-<:. :'~"h' .q :'_ -_ ':~'.:.::h. ~ //. . ':::~3'::.'~ .~ ,~:'.t:";:':*:;~:; ::.:'~:-- ~ .~: ' :'~:(~ ~'~: 07- July- 1990 ~~., ..... q .... ~ ~--,: ,,~ .... ~ -.'~':-':?.'"' ~ ~-'""~' ....... · G~CCL ~...:.....:~.~ % .:....-;:..:.:,.~ ~-~; ..... ~ ....... ,~ . ..... .-., -.;. ~arked Line .... ;. ~_--._~-.__~:_~;..~_.. ... . ',.--.-...- - ' r~-- ~-; ~'_%_.h~Z~ 4:' ~ ~-_ ;:.- ~--_-~::. .. ._~ .......... . ...... :;_, ._ . ;~;~ -~; .... .,.. .............. .-. .:. ~-. .... ~. ',':._:--:~-,~:. ~,._~- -~_~. ~--_-;.~? ~_- WESTERN ATLAS 8289' Logging Services Tape Subfile 2 is type: 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 MPK - 37 500292267400 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 01-AUG-96 6729.00 B.ESARY O'MALLEY 3 12N liE 3509 2045 61.00 60.00 33.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 20.000 112.0 3RD STRING 9.625 3652.0 PRODUCTION STRING 7.000 8389.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS GR GRCH 2 1 07-JUL-96 WESTERN ATLAS LOGGING SERVICES PBU TOOL CODE': PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH REMARKS: GR/CCL. GRCH 91.10 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** LOG TIED TO WIRELINE MARKS. SHIFT PROCEDURE AS FOLLOWS: 1) SECOND PASS GAMMA RAY DEPTH MATCHED TO FIRST PASS GAMMA RAY. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 34.0 8289.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPK - 37 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 131 1022 BYTES * Tape File Start Depth = 30.000000 Tape File End Depth = 8290.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 33043 datums Tape Subfile: 2 222 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 run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 8054.0 8054.5 8057.0 8057.5 8057.5 8058.5 8066.0 8066.0 8075.5 8076.0 8113.0 8113.5 8141.0 8141.5 8142.0 8142.0 8143.5 8143.5 8152.0 8152.5 8153.5 8154.0 8154.5 8154.5 8155.0 8155.5 8171.5 8172.0 8172.5 8172.5 8173.0 8173.5 8182.0 8182.5 8192.0 8192.0 8193.0 8193.5 8195.5 8196.0 8196.0 8196.5 8206.0 8205.5 8220.0 8219.0 8230.5 8231.0 8265.5 8266.0 8279.0 8279.0 $ START DEPTH 8050.0 STOP DEPTH 8289.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH REMARKS: PASS 2 (REPEAT PASS). / ? ?MATCH2A . OUT $ CN : BP EXPLORATION WN : MPK - 37 FN : MILNE POINT COUN : NORTH SLOPE STAT * FORMAT RECORD : ALAS._~ (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI * DATA RECORD (TYPE# 0) Total Data Records: API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1022 BYTES * 4 4 30 995 99 1 Tape File Start Depth = 8045.000000 Tape File End Depth = 8290.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 983 datums 61 records... 62 bytes 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: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 34.0 $ LOG HEADER DATA' DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR CCL CASING COLLAR LOC. PCM PULSE CODE MODULATOR GR GAMMA RAY $ 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): STOP DEPTH 8297.0 07-JUL-96 FSYS REV. J001 VER. 1.1 1616 07-JUL-96 8306.0 8291.0 34.0 8289.0 3600.0 YES TOOL NUMBER 8248XA 8250XA 8262XA 0.000 8389.0 0.0 BRINE/DIESEL CAP 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZIH~ WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT ,RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): REMARKS: PASS 1 (MAIN PASS). $ 0.0 CN : BP EXPLORATION WN : MPK - 37 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units · GR GR 68 1 GAPI 4 CCL GR 68 1 4 SPD GR 68 1 F/MN 4 TEN GR 68 1 LB 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 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: 661 Tape File Start Depth = 35.000000 Tape File End Depth = 8297.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 198289 datums TaPe Subfile: 4 735 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: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8050.0 $ 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 8297.0 07-JUL-96 FSYS REV. J001 VER. 1.1 1602 07-JUL-96 8306.0 8291.0 34.0 8289.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR CCL CASING COLLAR LOC. PCM PULSE CODE MODULATOR GR GAMMA RAY $ TOOL NUMBER 8248XA 8250XA 8262XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 8389.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE/DIESEL CAP 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0 . 0 BASE NORMALIZIN~ WINDOW (FT): J.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPK - 37 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 20 Tape File Start Depth = 8050.000000 Tape File End Depth = 8297.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5929 datums Tape Subfile: 5 94 records... Minimum record length: 62 bytes Maximum-record length: 1006 bytes Tape Subfile 6 is type: LIS 96/ 8/ 1 01 **** REEL TRAILER **** 96/ 8/ 1 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 1 AUG 96 2:20p Elapsed execution time = 20.38 seconds. SYSTEM RETURN CODE = 0