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Home My WebLink About195-1171. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change-out 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,120' N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT F-61 MILNE POINT KUPARUK RIVER OIL N/A 7,467' 12,006' 7,374' 805 12,006' Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12/25/2025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 195-117 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22582-00-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 112' 112' 6.5# / L-80 / EUE 8rd TVD Burst 11,562' MD N/A 5,750psi 7,240psi 4,604' 7,446' 6,586' 12,095' 80' 20" 9-5/8" 7" 6,549' 12,062' Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" N/A and N/A N/A and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.10.27 10:50:18 - 08'00' Taylor Wellman (2143) 325-667 By Grace Christianson at 11:06 am, Oct 27, 2025 * BOPE test to 1500 psi. 24 hour notice to AOGCC MGR31OCT25 A.Dewhurst 30OCT25 10-404 DSR-10/30/25 11/03/25 Well: MPF-61 PTD: 195-117 API: 50-029-22582-00-00 Well Name:MPF-61 API Number:50-029-22582-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:11/02/25 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:195-117 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,506 psi @ 7,012 TVD BHGauge 10/14/2025 / 4.2 ppg EMW 4.4 KWF Max Potential Surface Pressure: 805 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 69°+ Sail Angle from 7,230 MD Brief Well Summary: MPU F-61, a Kuparuk producer, was drilled in August 1995, fracture stimulated in October and completed in February 1996. ESP installation history: February 1996 (initial), May 1996, May 1996, October 1996, August 2004, January 2010, December 2012, January 2018 and February 2022. The ESP has failed with a suspected twisted shaft. Objectives: Pull failed ESP completion, run an ESP Notes Regarding Wellbore Condition: Last CSG Test 1/29/2022. Offset Injector Support F-74 This well has never had an indication of scale. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Attempt to pull dummy valve from GLM at 11,264 MD and leave open. 4. Pull GLV and set dummy valve in upper GLM at 182 MD. 5. Caliper from the discharge head to surface. 6. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of produced water. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. Well: MPF-61 PTD: 195-117 API: 50-029-22582-00-00 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 1,500 psi high. Test annular to 250 psi low/ 1,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC Gen 5, 11" x 2-7/8" EUE Box top & bottom, 2-1/2" H BPVG b. 2022 tubing PU weight on ASR recorded as 75 kip. Slack off weight recorded as 34 kip. c. 2-7/8 L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8 tubing and ¼ cap tube. a. Replace tubing based on caliper results. Wash and toss jts 96-101, 114-119, 130-135 and 176-186 b. Toss the ¼ cap tube. c. Keep ported discharge head and centralizer for future use. d. Note any sand or scale inside or on the outside of the ESP on the morning report. e. Recorded Clamp Totals: i. Canon Clamps: 368 ii. Protectolizer Clamps: 5 iii. Flat Cable Guards: 2 10. Lay Down ESP. Collect any solids sample and get them to chemical guys Cole or Mitch for analysis. Make sure the ESP tech posts all pictures to the Centrilift folder on the Hilcorp drive. 2-7/8 ESP Completion: 11. RIH with used 2-7/8 6.5# L-80 ESP completion to +/- 11,560 and obtain string weights. Well: MPF-61 PTD: 195-117 API: 50-029-22582-00-00 a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 17 Motor - 350HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 3 INTAKE GPXARCINT FER H6 35 5.38 10 PUMP GNPSHL 45 5.38 13 PUMP 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~11,050 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 12. Land tubing hanger. Use extra caution to not damage cable. 13. Lay down landing joint. 14. Set BPV. 15. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. Well: MPF-61 PTD: 195-117 API: 50-029-22582-00-00 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. 11 DOUBLE BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 10/15/2025 SCHEMATIC Milne Point Unit Well: MPU F-61 Last Completed: 1/31/2022 PTD: 195-117 TD =12,120 (MD) / TD = 7,467(TVD) 20 Orig. KB Elev.:49.2/CellarboxElev.:13.6 7 10 9-5/8 Capline Splice @ 10,847 Min ID 2.205 @ 11,423 MD KUP B Sands PBTD =12,006(MD) / PBTD = 7,374(TVD) KUP A Sands 6 7 & 8 9 1 2 3 4 5 ESP Splice @ 5,473 MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,586 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 12,095 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5# / L-80 / EUE 8rd 2.441 Surface 11,562 0.0058 1/4 Capstring Stainless Steel N/A Surface 11,562 N/A JEWELRY DETAIL No Top (MD) Item 1 182 STA 2: GLM Camco 2 7/8 X 1'' s/Orifice 2 11,264 STA 1: GLM Camco 2 7/8 X 1'' w/Dummy 3 11,388 2-7/8 XN Nipple ID= 2.205 No-Go 4 11,504 Discharge Head: B/O PMP 513 2.87X8 EUE1040 5 11,505 Pump: PMP 538PMSXD 161 P11 M FER 6 11,527 Gas Separator: 538GSTHVEVX MT H6 FER 7 11,533 Upper Tandem Seal: GSBDB H6 SB/AB PFSA 8 11,540 Lower Tandem Seal: GSBDB H6 SB/AB PFSA 9 11,547 Motor: MTR 562XP S CS 150/2420/38_06R 10 11,558 Motor Gauge Zenith w/6 Fin Centralizer Bottom @ 11,562 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Size SPF Kup. B Sands 11,675 11,681 7,106 7,111 6 11/12/1995 Open 4-1/2 5 Kup. A Sands 11,730 11,814 7,150 7,218 84 10/7/1995 Open 3-3/8 6 Ref Log: 9/13/1995 GR/ CCL/ FDN OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (approx.) in 30 hole 9-5/8"1,237 sx PF E, 250 sx Class G, plus 250 sx PF E top job in 12-1/4 hole 7 250 sx Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 Max Hole Angle = 64 to 69 deg. f/ 4,200 to 9,900 Max Hole Angle through perforations = 36 deg. TREE & WELLHEAD Tree Cameron 2-9/165M Wellhead 11 x 11 5M FMC Gen 5, w/ 11 x 2-7/8 Tbg. Hngr. w/ 2-7/8 8 rd EUE threads top and bottom and 2.5 CIW H BPV profile GENERAL WELL INFO API: 50-029-22582-00 Drilled by Nabors 27E - 8/30/1995 Original Completion by Nabors 4ES - 2/22/1996 ESP RWO by Nabors 4ES 5/19/1996 and 5/26/1996 ESP RWO by Nabors 4ES 10/12/1996 ESP RWO by Nabors 4ES 8/15/2004 ESP RWO by Nabors 4ES 1/27/2010 ESP RWO by Doyon 16 12/11/2012 ESP RWO by ASR#1 1/25/2018 ESP RWO by ASR#1 1/31/2022 STIMULATION SUMMARY 10/16/1995 158M lbs 16-20 Carbolite behind pipe, went to flush, no apparent TSO _____________________________________________________________________________________ Revised By: TDF 10/15/2025 PROPOSED Milne Point Unit Well: MPU F-61 Last Completed: 1/31/2022 PTD: 195-117 TD =12,120 (MD) / TD = 7,467(TVD) 20 Orig. KB Elev.:49.2/CellarboxElev.:13.6 7 10 9-5/8 Min ID 2.205 @ 11,423 MD KUP B Sands PBTD =12,006(MD) / PBTD = 7,374(TVD) KUP A Sands 6 7 & 8 9 1 2 3 4 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,586 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 12,095 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5# / L-80 / EUE 8rd 2.441 Surface ±11,560 0.0058 JEWELRY DETAIL No Top (MD) Item 1 ±200 STA 2: GLM 2-7/8 X 1'' w/ ¼ OV 2 ±XX,XXX STA 1: GLM 2-7/8 X 1'' DV Installed 3 ±XX,XXX 2-7/8 XN Nipple ID= 2.205 No-Go 4 ±XX,XXX Ported Discharge Head: 5 ±XX,XXX Pump: 6 ±XX,XXX Intake: 7 ±XX,XXX Upper Tandem Seal: 8 ±XX,XXX Lower Tandem Seal: 9 ±XX,XXX Motor: 10 ±XX,XXX Intake Sensor & Centralizer Bottom @ ±11,560 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Size SPF Kup. B Sands 11,675 11,681 7,106 7,111 6 11/12/1995 Open 4-1/2 5 Kup. A Sands 11,730 11,814 7,150 7,218 84 10/7/1995 Open 3-3/8 6 Ref Log: 9/13/1995 GR/ CCL/ FDN OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (approx.) in 30 hole 9-5/8"1,237 sx PF E, 250 sx Class G, plus 250 sx PF E top job in 12-1/4 hole 7 250 sx Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 Max Hole Angle = 64 to 69 deg. f/ 4,200 to 9,900 Max Hole Angle through perforations = 36 deg. TREE & WELLHEAD Tree Cameron 2-9/165M Wellhead 11 x 11 5M FMC Gen 5, w/ 11 x 2-7/8 Tbg. Hngr. w/ 2-7/8 8 rd EUE threads top and bottom and 2.5 CIW H BPV profile GENERAL WELL INFO API: 50-029-22582-00 Drilled by Nabors 27E - 8/30/1995 Original Completion by Nabors 4ES - 2/22/1996 ESP RWO by Nabors 4ES 5/19/1996 and 5/26/1996 ESP RWO by Nabors 4ES 10/12/1996 ESP RWO by Nabors 4ES 8/15/2004 ESP RWO by Nabors 4ES 1/27/2010 ESP RWO by Doyon 16 12/11/2012 ESP RWO by ASR#1 1/25/2018 ESP RWO by ASR#1 1/31/2022 STIMULATION SUMMARY 10/16/1995 158M lbs 16-20 Carbolite behind pipe, went to flush, no apparent TSO Updated 10/24/2024 Milne Point ASR Rig 1 BOPE 2024 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8 x 5 VBR Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. 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Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change-out 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,120'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7,467'12,006'7,374'1,968 12,006' 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Taylor Wellman twellman@hilcorp.com 907-777-8449 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: N/A and N/A N/A and N/A See Schematic See Schematic 11/28/2021 2-7/8" Perforation Depth MD (ft): PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 195-117 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22582-00-00 Hilcorp Alaska LLC MILNE PT UNIT F-61 MILNE POINT / KUPARUK RIVER OIL C.O. 432D 112' 6.5# / L-80 / EUE 8rd TVD Burst 11,582' N/A 5,750psi 7,240psi 4,604' 7,446' 6,586' 12,095' Length Size 112' MD 12,062' 80' 20" 9-5/8" 7" 6,549' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:39 am, Nov 17, 2021 321-593 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.11.17 10:31:39 -09'00' David Haakinson (3533) MGR26-NOV -21 BOPE test to 2500 psi. DSR-11/17/21 X DLB 11/17/2021 10-404 dts 11/30/2021 11/30/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:23:07 -09'00' RBDMS HEW 12/1/2021 ESP Change Out Well: MPU F-61 Date: Nov 16, 2021 Well Name:MPU F-61 API Number:50-029-22582-00-00 Current Status:Oil Well [Failed ESP]Pad:F-Pad Estimated Start Date:November 28, 2021 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:195-117 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Current Bottom Hole Pressure: 2,684 psi @ 7,162’ TVD (SBHPS 09/14/2021 / 7.42 ppg EMW) Maximum Expected BHP:2,684 psi @ 7,162’ TVD (SBHPS 09/14/2021 / 7.42 ppg EMW) MPSP:1,968 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-14 was drilled in August 1995, fracture stimulated in October, and completed in February 1996 as a Kuparuk River producer. ESP installation history: February 1996 (initial), May 1996, October 1996, August 2004, February 2010, December 2012 and January 2018. Notes Regarding Wellbore Condition x CO 390A: A packer is not required on this ESP completion as the reservoir pressure of 7.7 ppg EMW is less than 8.55 ppg EMW. BHP based on 13 month shut in build up. x Last CSG Test 12/09/2010. A casing test will be performed. x Offset Injector Support o F-74: Offline 8/17/21 Objective: Pull failed ESP, pressure test casing and run a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. a. Partial returns will probably be seen. After attempting circulation down the tubing, load the IA. 6. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. ESP Change Out Well: MPU F-61 Date: Nov 16, 2021 Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to the returns tank. Pull TWC. Kill well with produced water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2018 ESP swap was 80K lbs to free pipe, 77K up wt. after free. The current completion was landed with an up wt of 75.5K. b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. ESP Change Out Well: MPU F-61 Date: Nov 16, 2021 16. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8” tubing. Number all joints. Tubing will be re-run. Lay down failed ESP. a. Pull out all visually bad joints for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. c. 347 Cannon Cross Collar Clamps, 2 Protectolizers and 3 Flat Cable Guards were installed. 18. PU test packer and run on 2-7/8” workstring to 7,000’ md. a. Base of the Schrader is at 6,803’ md / 4,646’ TVDSS. 19. Test casing to 1,500psi for 30 minutes (charted). 20. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’ and cap string integrity. a. Base of ESP at ± 11,580’ MD a. A capstring injection valve to be clamped to the centralizer. b. 2 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 3 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. Mulitple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV h. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 21. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 22. Set BPV. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Base of the upper confining zones of the Kuparuk sands ~11,600' MD or top of confirmed cement on 7" production liner. _____________________________________________________________________________________ Revised By: TDF 2/9/2018 SCHEMATIC Milne Point Unit Well: MPU F-61 Last Completed: 1/25/2018 PTD: 195-117 TD =12,120’ (MD) / TD = 7,467’(TVD) 20” Orig. KB Elev.: 49.2’/ Cellar box Elev.: 13.6’ 7” 10 9-5/8 ” Min ID 2.205” @ 11,423’ MD KUP B Sands PBTD =12,006’(MD) / PBTD = 7,374’(TVD) KUP A Sands 6 7 & 8 9 1 2 3 4 5 ESP Splice @ 2,475’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,586’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 12,095’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 11,582’ 0.0058 JEWELRY DETAIL No Top (MD) Item 1 143’ STA 2: GLM Camco 2 7/8 X 1'' Side pocket,W/Orifice 2 11,312’ STA 1: GLM Camco 2 7/8 X 1'' Side pocket,W/Dummy 3 11,423’ 2-7/8” XN Nipple –ID= 2.205” No-Go 4 11,527.6’ Discharge Head: GPDIS 2 7/8" EUE 8Rd 5 11,528’ Pump: 161P11 SXD 6 11,550’ Gas Separator: GRS FER N AR 7 11,553’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 11,560’ Lower Tandem Seal: GSB3DBLT SB/SB PFSA, CL5 9 11,567’ Motor: XP – 150Hp / 2,420A / 38A 10 11,578’ WellLift E Sensor w/6 Fin Centralizer –Bottom @ 11,582’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Size SPF Kup. B Sands 11,675’’ 11,681’ 7,106’ 7,111’ 6 11/12/1995 Open 4-1/2”5 Kup. A Sands 11,730’ 11,814’ 7,150’ 7,218’ 84 10/7/1995 Open 3-3/8” 6 Ref Log: 9/13/1995 GR/ CCL/ FDN OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (approx.) in 30” hole 9-5/8"1,237 sx PF “E”, 250 sx Class “G”, plus 250 sx PF “E” top job in 12-1/4” hole 7” 250 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 64 to 69 deg. f/ 4,200’ to 9,900’ Max Hole Angle through perforations = 36 deg. TREE & WELLHEAD Tree Cameron 2-9/16”5M Wellhead 11” x 11” 5M FMC Gen 5, w/ 11” x 2-7/8”” Tbg. Hngr. w/ 2-7/8” 8 rd EUE threads top and bottom and 2.5” CIW ‘H’ BPV profile GENERAL WELL INFO API: 50-029-22582-00 Drilled by Nabors 27E - 8/30/1995 Original Completion by Nabors 4ES - 2/22/1996 ESP RWO by Nabors 4ES – 5/19/1996 and 5/26/1996 ESP RWO by Nabors 4ES – 10/12/1996 ESP RWO by Nabors 4ES – 8/15/2004 ESP RWO by Nabors 4ES – 1/27/2010 ESP RWO by Doyon 16 – 12/11/2012 ESP RWO by ASR#1 – 1/25/2018 STIMULATION SUMMARY 10/16/1995 – 158M lbs 16-20 Carbolite behind pipe, went to flush, no apparent TSO _____________________________________________________________________________________ Revised By: TDF 10/12/2021 PROPOSED Milne Point Unit Well: MPU F-61 Last Completed: 1/25/2018 PTD: 195-117 TD =12,120’ (MD) / TD = 7,467’(TVD) 20” Orig. KB Elev.: 49.2’/ Cellar box Elev.: 13.6’ 7” 10 9-5/8” Min ID 2.205” @ 11,423’ MD KUP B Sands PBTD =12,006’(MD) / PBTD = 7,374’(TVD) KUP A Sands 6 7 & 8 9 1 2 3 4 5 ESP Splice @ 2,475’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,586’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 12,095’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±11,580’ 0.0058 1/4“ Capstring Stainless Steel N/A Surface ±11,580’ N/A JEWELRY DETAIL No Top (MD) Item 1 ±200’ STA 2: GLM Camco 2 7/8 X 1'' 2 ±11,312’ STA 1: GLM Camco 2 7/8 X 1'' 3 ±11,423’ 2-7/8” XN Nipple – ID= 2.205” No-Go 4 ±11,527.6’ Discharge Head: 5 ±11,528’ Pump: 6 ±11,550’ Gas Separator: 7 ±11,553’ Upper Tandem Seal: 8 ±11,560’ Lower Tandem Seal: 9 ±11,567’ Motor: 10 ±11,578’ WellLift E Sensor w/6 Fin Centralizer – Bottom @ ±11,580’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Size SPF Kup. B Sands 11,675’’ 11,681’ 7,106’ 7,111’ 6 11/12/1995 Open 4-1/2”5 Kup. A Sands 11,730’ 11,814’ 7,150’ 7,218’ 84 10/7/1995 Open 3-3/8” 6 Ref Log: 9/13/1995 GR/ CCL/ FDN OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (approx.) in 30” hole 9-5/8"1,237 sx PF “E”, 250 sx Class “G”, plus 250 sx PF “E” top job in 12-1/4” hole 7” 250 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 64 to 69 deg. f/ 4,200’ to 9,900’ Max Hole Angle through perforations = 36 deg. TREE & WELLHEAD Tree Cameron 2-9/16”5M Wellhead 11” x 11” 5M FMC Gen 5, w/ 11” x 2-7/8”” Tbg. Hngr. w/ 2-7/8” 8 rd EUE threads top and bottom and 2.5” CIW ‘H’ BPV profile GENERAL WELL INFO API: 50-029-22582-00 Drilled by Nabors 27E - 8/30/1995 Original Completion by Nabors 4ES - 2/22/1996 ESP RWO by Nabors 4ES – 5/19/1996 and 5/26/1996 ESP RWO by Nabors 4ES – 10/12/1996 ESP RWO by Nabors 4ES – 8/15/2004 ESP RWO by Nabors 4ES – 1/27/2010 ESP RWO by Doyon 16 – 12/11/2012 ESP RWO by ASR#1 – 1/25/2018 STIMULATION SUMMARY 10/16/1995 – 158M lbs 16-20 Carbolite behind pipe, went to flush, no apparent TSO Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head STATE OF ALASKA • AL1kA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑., Re-enter Susp Well❑ Other: ESP Change-out ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development Q Exploratory ❑ 195-117 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22582-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT F-61 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 12,120 feet Plugs measured 12,006 feet true vertical 7,467 feet Junk measured N/A feet Effective Depth measured 12,006 feet Packer measured N/A feet true vertical 7,374 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 6,549' 9-5/8" 6,586' 4,604' 5,750psi 3,090psi Production 12,062' 7" 12,095' 7,446' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 11,582' 7,031' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCANNED 1y ri 2 2,1, ;. 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 0 780 0 Subsequent to operation: 86 21 875 200 219 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-012 Authorized Name: Bo York - - Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hllcorp.com Authorized Signature:7,7 Dab 2/9/2018 Contact Phone: 777-8333 /2 —22--t ‘? Form 10-404 Revised 4/2017 ��6(// Y y„ F 1 v j`18 Submit Original Only • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-61 ASR#1 50-029-22582-00 195-117 1/20/18 1/25/18 Daily Operations: 1/17/2017-Wednesday No activity to report. 1/18/2017 -Thursday No activity to report. 1/19/2017 - Friday No activity to report. 1/20/2017 -Saturday Continue to R/D on well F-01 and move to F-61. Remove rig floor, BOPE, and set production tree. Wellhead reps on location to test tree adapter void (Good Test). Remove well house, mud boat, and prep mid pits. Electrician on location to test ESD on mud pits. (Good Function Test) Finish spotting rig mats into place on F-61. Continue to R/D on F-01 and move to F-61. Spot horseshoe scaffolding on F-61, R/U circulation trailer. Spot LRS into position for well kill. NES trucks on location at 2:00pm w/580bbls of 8.5ppg seawater. Start well kill @ 3:30pm. Circulate 512bbls clean@ 5BPM = 1400psi TBG, 300psi IA,Monitor well static, install BPV. Pull scaffolding, N/D tree, N/U BOPE, Spot mud boat & pits, install well house & rig floor, spot rig on mud boat, & level same. Meeting both crews, go over sundry for F-61. 1/21/2017 -Sunday Cont. prep rig & lift mast, run fluid lines, set catwalk, winterize lines & cellar. Cont. winterize &warm rig, troubleshoot generator on T/P trailer/accumulator. Bring in new generator from Prudhoe and have electricians wire it. New generator not functioning properly. Swap out w/generator from spooling unit and order replacement. 1/22/2017 - Monday Continue to heat rig and perform shell test in prep for AOGCC witness. Good shell test. Pit generator shut down.Trouble shoot. Fuel tank equalization line found to be gelled up, not allowing fuel to flow from one tank to the other.Thaw line and re-start generator. Notify state we are ready to test. Wait on AOGCC rep Lou Laubenstein to arrive on location prior to beginning test. Continue to monitor heating systems to ensure BOPE is properly heated in order to test. R/U ESP sheave and elephant trunk in prep for pulling ESP cable.Test BOPE as per Sundry to 250psi low f/5 charted mins and 2,500psi high f/5 charted mins vv/2-7/8" test joie AOGCC rep Lou Laubenstein on location to witness test. Retrieve blanking plug f/TBG hanger threads utilizing retrieving head on landing joint. Well head reps on location to pull BPV and BOLDS. New generator from Prudhoe having issues running. Call VMS for help. Cannot pull pipe until generator fixed since it powers accumulators. VMS fix generator issue. M/U landing joint to TBG hanger(9.5 turns), pull TBG hanger to rig floor. Weight indicator showing 80klbs to prior to breaking over and leveling off at 77klbs. Cut ESP cable and L/D TBG hanger. Pull ESP cable over sheave and fill hole (23bbls to fill annulus). Continue to POOH w/ ESP completion on 2-7/8" 6.5ppf EUE TBG f/' 11,517'md. Cont. POOH w/ESP assembly sorting out bad 2-7/8"joints, t/3,750' +-. Change out cable spool. Cont. POOH w/ESP assembly sorting out bad 2-7/8"joints. • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-61 ASR#1 50-029-22582-00 195-117 1/20/18 1/25/18 Daily OpetatFons;�s _ ' (111`g,','1;' — 1/23/2017 -Tuesday Continue to POOH w/ ESP completion on 2-7/8" EUE TBG up to discharge head. Fill hole and monitor prior to pulling ESP into BOP stack . 13bbls to fill, fluid falling down hole. 357 joints recovered, 132 total joints discarded from completion. Last 5 joints pulled wet, discharge head packed off. POOH and L/D ESP completion. Close blinds and monitor hole while preparing to P/U new ESP. Roads and Pads on location to pull out spooling unit and swap reels. Load out ESP pump on pipe rack. P/U ESP centralizer, motor and lower/upper seal sections. Begin servicing process.Attempt to pull MLE cable with pothead out of spooling unit and over sheave. Pothead caught while pulling line and bent MLE. Centrilift recommendation was to redo pothead prior to connecting and running in hole. Redo MLE pothead in prep for running in hole. Rig crew clean rig and work on written procedures for operations. Cont. Service ESP assy,Test cable,good, Rack&tally 2-7/8" 6.5# L-80 EUE 8RD Completion. RIH w/ ESP assy on 2-7/8"tubing, testing cable every 1,000' t/2,127'. • • ! Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-61 ASR#1 50-029-22582-00 195-117 1/20/18 1/25/18 Daily Operations: d1Id�O01r 1/24/2017-Wednesday RIH w/ ESP completion on 2-7/8" EUE TBG f/2,127'md to "7,600'md. Hydraulic systems slowed due to cold temperatures ("450'/hr) Cont. RIH w/ ESP completion on 2-7/8" EUE TBG f/7,600' —t/8,883', testing cable every 1,000' good Make cable splice, (splice landed @ 9,100'—jt 77) Cont. RIH w/ ESP completion on 2-7/8" EUE TBG f/8,883'1/10,883', testing cable every 1,000' good 1/25/2017 -Thursday Continue to RIH w/ ESP completion on 2-7/8" EUE TBG.Test ESP cable every 2,000'md. Circulate well prior to landing completion and ensure no obstructions in TBG or pump. P/U TBG hanger and perform ESP cable splice w/ Baker Centrilift. Well head reps on location to plug off control line ports. Land TBG hanger as per well head reps. 5' mark pipe while RIH. Land @ 18' f/floor in TBG hanger. Set BPV. Tail of ESP assy @ 11,581', XN nipple @ 11,422', lower GLM 11,318', upper GLM 142' R/D on well F-61 in prep to move to 1-17. Canrig on location performing installation of Rig watch system. Conam electricians on location to walk down strobe and audible alarm installation. Prep & I/d mast, pull rig off mud boat, setup crane pull floor,& well house, N/D BOPE, N/U tree &test t/5000 psi good Baker perform final cable meg test Good, pull BPV& secure well. Cont. r/d, prep for rig move. 1/26/2017 - Friday No activity to report. 1/27/2017 -Saturday No activity to report. 1/28/2017 -Sunday No activity to report. 1/29/2017 - Monday No activity to report. .. , 14 . . Milne Point Unit Well: MPU F-61 SCHEMATIC Last Completed: 1/25/2018 llilcorp Alaska,LLC PTD: 195-117 TREE&WELLHEAD Orig.KB Elev.:49.2'/Cellar box Elev.:13.6' Tree Cameron 2-9/16"5M 11"x11"5M FMC Gen 5,w/11"x2-7/8""Tbg. 4 ,. Wellhead Hngr.w/2-7/8"8 rd EUE threads top and 20' l r 1 bottom and 2.5"CIW'H'BPV profile OPEN HOLE/CEMENT DETAIL ' :, 20" 250 sx of Arcticset I(approx.)in 30"hole L!'`, ' 9-5/8 1,237 sx PF"E",250 sx Class"G",plus 250 sx PF"E"top it job in 12-1/4"hole 7" 250 sx Class"G"in 8-v2"Hole CASING DETAIL ESP splice@ a,+ Size Type Wt/Grade/Conn ID Top Btm BPF 2,475'MD 20" Conductor 91.1/NT80LHE/N/A N/A Surface 112' N/A 9 5/8" Surface 40/L-80/BTC 8.835 Surface 6,586' 0.0758 7" Production 26/L-80/BTC 6.276 Surface 12,095' 0.0383 4': TUBING DETAIL °N`. 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 11,582' 0.0058 WELL INCLINATION DETAIL itl KOP @ 500' Max Hole Angle=64 to 69 deg. f/4,200'to 9,900' 35/8"4 ► Max Hole Angle through perforations=36 deg. JEWELRY DETAIL No Top(MD) Item 1 143' STA 2:GLM Camco 2 7/8 X 1"Side pocket,W/Orifice 2 11,312' STA 1:GLM Camco 2 7/8 X 1"Side pocket,W/Dummy 3 11,423' 2-7/8"XN Nipple—ID=2.205"No-Go 4 11,527.6' Discharge Head:GPDIS 2 7/8"EUE 8Rd 5 11,528' _ Pump:161P11 SXD 6 11,550' Gas Separator:GRS FER N AR 7 11,553' Upper Tandem Seal:GSB3DBUTSB/SB PFSA 8 11,560' Lower Tandem Seal: GSB3DBLT SB/SB PFSA, CL5 9 11,567' Motor:XP—15OHp/2,420A/38A P 2 imp 10 11,578' WeIILift E Sensor w/6 Fin Centralizer—Bottom @ 11,582' Mn ID PERFORATION DETAIL 2.205"@ 0 a 3 L 11,423'MD Sands Top Btm Top Btm FT Date Status Size SPF Pi moi: 4 (MD) _ (MD) (TVD) (TVD) p Kup.BSands 11,675" 11,681' 7,106' 7,111' 6 11/12/1995 Open 4-1/2" 5 5 Kup.A Sands 11,730' 11,814' 7,150' 7,218' 84 10/7/1995 Open 3-3/8" 6 l Ref Log:9/13/1995 GR/CCL/FDN III 416 STIMULATION SUMMARY 7&8 10/16/1995—158M lbs 16-20 Carbolite behind oo� pipe,went to flush,no apparent TSO 9 GENERAL WELL INFO Oi API:50-029-22582-00 Drilled by Nabors 27E-8/30/1995 10 Original Completion by Nabors 4ES-2/22/1996 ESP RWO by Nabors 4ES 5/19/1996 and 5/26/1996 Id 1-iup B Sands ESP RWO by Nabors 4ES—10/12/1996 ll ESP RWO by Nabors 4ES—8/15/2004 tt t KUPASands ESP RWO by Nabors 4ES—1/27/2010 ill ESP RWO by Doyon 16—12/11/2012 rr ESP RWO by ASR#1—1/25/2018 th 7" I TD=12,120'(MD)/TD=7,467(TVD) PBTD=12,006'(MD)/PBTD=7,374'(TVD) Revised By:TDF 2/9/2018 OF TA, S THE STAT• /� LAsKA Alaska Oil and Gas � Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ® ain: 907.279.1433 "ALAS*" MFax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager 5 NNEU 1\1 1 9 22c1.,1? Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F-61 Permit to Drill Number: 195-117 Sundry Number: 318-012 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CiCk- c, is . rench Chair DATED this I� day of January, 2018. RBDMS (v\-/JAN 1 1 2018 RECEIVED ED • • 7S5i�18Ie / $' STATE OF ALASKA AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q . 195-117 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22582-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT F-61 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355018, MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,120'' 7,467' , 12,006' 7,374' a 2,141 12,006' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 6,549' 9-5/8" 6,586' 4,604' 5,750psi 3,090psi Production 12,062' 7" 12,095' 7,446' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 11,517' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary e" Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development Q, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/26/2018 Commencing Operations: OIL Q I WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchant hiICOI'p.COl71 Contact Phone: 777-8333 Authorized Signature: — Date: 1/5/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: •— ,ss2.-, 31g.a , 2 Plug Integrity ❑ BOP Test Z Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,____,....,i' 2 5-0 0 / s .: &P te5 L Post Initial Injection MIT Req'd? Yes ❑ No ❑ I�BDMS i'�, 1 1 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /a `.- 41 0 4-4 ?C10 0 APPROVED BY Approved by: tOarr"\..... -- COMMISSIONER THE COMMISSION Date: Ltk )16 iig 4' ORIGINALS ,_ 1 (-- ig Submit Form and \/,� Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU F-61 Ililcorp Alaska,LL Date: 1/9/2018 Well Name: MPU F-61 API Number: 50-029-22582-00 Current Status: Oil Well Pad: F-Pad Estimated Start Date: January 26th, 2018 Rig: ASR 1 .`" Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-117 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Job Type: 1 ESP Repair Current Bottom Hole Pressure: 2,841 psi @ 7,000'TVDss (SBHPS 12/22/2017/7.76 ppg EMW) V Maximum Expected BHP: 2,841 psi @ 7,000'TVDss (No new perfs being added) MPSP: 2,141 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-61 was drilled in August 1995, fracture stimulated in October, and completed in February 1996 as a Kuparuk River producer.'ESP installation history: February 1996 (initial), May 1996, May 1996, October 1996, August 2004,January 2010, and December 2012. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing was tested to 1500 psi at 6,600' MD on December 9, 2012. r` • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. I') /94_4�ti (..lttitVe.J/ Objective: Co 37, ,4 / - //-/ Replace failed ESP. Pre-Rig Procedure: Ad-- 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volujne with 8.5 ppg sea water down tubing, taking returns up casing to 500 bbl returns tank. */ 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU F-61 Mean)Alaska,LL Date:1/9/2018 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. (l P b. With stack out of the test path,test choke manifold per standard procedure fitAl 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 1 anywhere at surface.) 1.1" d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap was 120K lbs. (includes 36K block weight) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. b. Junk the 2-7/8" GLM#1. c. Junk joints: 75—175, 185—200, and 230-235 d. Note any sand or scale inside or on the outside of the ESP on the morning report. • • Well Prognosis Well: MPU F-61 Hikora Alaska,LL Date: 1/9/2018 e. Look for over-torqued connections from previous tubing runs. 18. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP assembly at± 11,600' MD. a. Upper GLM @ ± 140' MD w/SO b. Lower GLM @ ± 11,335' MD w/DGLV c. 2-7/8" XN (2.205" No-Go) @ ±11,485' MD d. Base of ESP centralizer @ ± 11,600' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO Sundry Change Form II • 411 Milne Point Unit Well. MPU F 61 SCHEMATIC Last Completed: 12/11/2012 Hi!carp Alaska,LLC PTD: 195-117 TREE&WELLHEAD Tree Cameron 2-9/16"5M Ong.KB Elev.:49.2'/Cellar box Elev.:13.6' 11"x 11"5M FMC Gen 5,w/11"x 2-7/8""Tbg. 1L Wellhead Hngr.w/2-7/8"8 rd EUE threads top and 20" bottom and 2.5"CIW'H'BPV profile .. 71 1 OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I(approx.)in 30"hole i, 1,237 sx PF"E",250 sx Class"G",plus 250 sx PF"E"top 9-5/8" ' ) job in 12-1/4"hole V t 7" 250 sx Class"G"in 8-1/2"Hole I CASING DETAIL 95/8„ 4 ) I Size Type Wt/Grade/Conn ID Top Btm BPF 20” Conductor 91.1/NT8OLHE/N/A N/A Surface 112' N/A 9-5/8" Surface 40/L-80/BTC 8.835 Surface 6,586' 0.0758 7" Production 26/L-80/BTC 6.276 Surface 12,095' 0.0383 iI TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 11,517' 0.0058 I i ! WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=64 to 69 deg. f/4,200'to 9,900' Max Hole Angle through perforations=36 deg. JEWELRY DETAIL No Top(MD) Item GLM STA 2:Camco 2-7/8"x 1",BK,Dev=0.6,VLV=DMY,Port=0,TVD= t. 1 143' 143',D = GLM STA ate1:C2/27/amc02021-7/87 "x 1",BK,Dev=40,VLV=Empty,Port=0,TVD= u 2 11,249' 6,767',Date=2/27/2017 6,. C A , ' /8"XN = "No-Go 4 1111,444401'' Welllift DischargeN —GaugeIDUnit as � L 53 11,449Centrilift2-7ESP SXDipple 141-P62.250/SXD 141-P6 6 11,481' Gas Separator 7 11,486' Centrilift Tandem Seal Section 8 11,500' Centrilift KMH-A Motor,152 hp,2,325 v./40 amps 9 11,513' Welllift MGU 2 10 11,515' 6 Fin Centralizer—Bottom @ 11,517' s PERFORATION DETAIL iJ 4 Sands Top Btm Top Btm Y 34 FT Date Status Size SPF s (MD) (MD) (TVD) (TVD) AKup.B Sands 11,675' 11,681' 7,106' 7,111' 6 11/12/1995 Open 4-1/2" 5 Kup.A Sands 11,730' 11,814' 7,150 7,218' 84 10/7/1995 Open 3-3/8" 6 1111: 6 Ref Log:9/13/1995 GR/CCL/FDN STIMULATION SUMMARY 10/16/1995—158M lbs 16-20 Carbolite behind !" 8 pipe,went to flush,no apparent TSO .� GENERAL WELL INFO E ,,9 10 API:50-029-22582-00 k Drilled by Nabors 27E-8/30/1995 Original Completion by Nabors 4ES-2/22/1996 ESP RWO by Nabors 4ES—5/19/1996 and 5/26/1996 KUP B Sands ESP RWO by Nabors 4ES—10/12/1996 }KUPASands ESP RWO by Nabors 4ES—8/15/2004 ESP RWO by Nabors 4ES—1/27/2010 4 ESP RWO by Doyon 16—12/11/2012 TD=12,120'(MD)/TD=7,467'(TVD) PBTD=12,006'(MD)/PBTD=7,374'(TVD) Revised By:TDF 1/5/2018 II • . Milne Point Unit Well: MPU F-61 PROPOSED Last Completed: 12/11/2012 Hilcorp Alaska,LLc PTD: 195-117 TREE&WELLHEAD Tree Cameron 2-9/16"5M Orig.KB Elev.:49.2'/Cellar box Elev.:13.6' 11"x 11"5M FMC Gen 5,w/11"x 2-7/8""Tbg. , Wellhead Hngr.w/2-7/8"8 rd EUE threads top and 2011 : li bottom and 2.5"CIW'H'BPV profile 1 OPEN HOLE/CEMENT DETAIL 0 A 20" 250 sx of Arcticset I(approx.)in 30"hole k, c ' °' 1,237 sx PF"E',250 sx Class"G",plus 250 sx PF"E"top a- 9-5/8" job in 12-1/4"hole 7" 250 sx Class"G"in 8-1/2"Hole ) ) CASING DETAIL 95/8"4 ff Size Type Wt/Grade/Conn ID Top Btm BPF 1 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 112' N/A 9-5/8" Surface 40/L-80/BTC 8.835 Surface 6,586' 0.0758 7" Production 26/L-80/BTC 6.276 Surface 12,095' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 11,517' 0.0058 i WELL INCLINATION DETAIL KOP@500' Max Hole Angle=64 to 69 deg. f/4,200'to 9,900' a Max Hole Angle through perforations=36 deg. 11: JEWELRY DETAIL No Top(MD) Item 1 ±140' STA 2:GLM 2 ±11,335' STA 1:GLM 3 ±11,484' 2-7/8"XN Nipple—ID=2.250"No-Go 4 ±11,527' Discharge Head 5 ±11,532' Pumps 6 ±11,564' Gas Separator 7 ±11,569' Tandem Seal Section 8 ±11,583' Motor 9 ±11,596' Sensor Gauge j 10 ±11,598' 6 Fin Centralizer—Bottom @±11,600' 2 min ID .1 PERFORATION DETAIL 2.25", ,..,., 0"s 3 11,40r MD i, C 3, Sands Top Btm Top Btm FT Date Status Size SPF ii«4 (MD) (MD) (TVD) (TVD) 5 Kup.B Sands 11,675" 11,681' 7,106' 7,111' 6 11/12/1995 Open 4-1/2" 5 Vi Kup.A Sands 11,730' 11,814' 7,150' 7,218' 84 10/7/1995 Open 3-3/8" 6 & , Ref Log:9/13/1995 GR/CCL/FDN II " �6 7 STIMULATION SUMMARY 10/16/1995—158M lbs 16-20 Carbolite behind 8 pipe,went to flush,no apparent TSO GENERAL WELL INFO 9 API:50-029-22582-00 10 Drilled by Nabors 27E-8/30/1995 ,_, 4 Original Completion by Nabors 4ES-2/22/1996 f ESP RWO by Nabors 4ES-5/19/1996 and 5/26/1996 V, }KUPBSands ESP RWO by Nabors 4ES—10/12/1996 il ESP RWO by Nabors 4ES—8/15/2004 r;}KUPA Saids ESP RWO by Nabors 4E5—1/27/2010 .< p ESP RWO by Doyon 16—12/11/2012 '+ " 7 TD=12,120'(MD)/TD=7,467(TVD) PBTD=12,006'(MD)/PBTD=7,374'(TVD) Revised By:TDF 1/5/2018 • • Milne Point ASR Rig 1 BOPE HiI tp AI43.4,I.t.(: 2018 11" BOPE , , Stripping Head r— ( 1 4.48' 1 "/ P ydril G . 4 imp 11" - 5000 I1INIi lil lila, lad Il IIl I1I 111 I1I aL 4.54' CIE CI o_U a " VBR or Pipe Rams a11"-A 000 Exiii6 1012 1p H Blind WINA 0 / _ ill Ii l 111 al al 2 1/16 5M Kill Line Valves \____ 2 1/16 5M Choke Line Valves IIiil1'IIPIll lIl 2.00' _t tl°1 i • i — I 'I.II.II1Il.11U -� Manual Manual Manual HCR Updated 1/05/2018 • • • Swab Valve CIW FL-2 9/16" MPF-61mi ''. "'tommolk 5K, manual gate valve, EE 1-4-18 mimma PSL2,PR2 2 9/16" 5K tree with ^ PN 141522-31-07-02 2 7/8" tbg hgr `�' G Wing valve CIW FL-2 9/16" 5K, manual gate valve, EE With ESP o ® © PSL2,PR2 No Heat Trace ..a ';. PN 141522-31-07-02 No control lines N' SSV CIW FL 2 9/16" 5K, O �� reverse actuating gate valve, EE.PSL2,PR2 w/ Baker CAC ",' ""' actuator. Assy PN 2012043-03-04 PN 91-031-129 \\:.....1,,, ,_..) II" .l Master CIW FL-2 9/16" 5K, IIImanual gate valve, EE it Note, this tbg HGr can be r® ;� PSL2,PR2 plugged on top for BOPS • �� ‘ PN 141552-31-07-02 equipment testing o ., Tbg Hd adapter FMC 11" 5K iMIN.IMIS" I" x 2 9/16" 5K, rotating (IL Al flanges, w/2ea control line preps and 2ea BIW penetrator preps. Bottom prepped for 2 7/8" seal Tbg Head, FMC MONO, 11" _ . PIN 134132-0002 1111M1111.1111 . x 11" 5K, 11" 5K API flang �� ' =' top by clamp bottom. W 2ea 2 1/16" 5K outs. Min ID-uilp iIIjI1IINE r 9.85"PN 13-30-662A III 1 jjl Ilial � .III. ' iismBio _ ) . _ t. ......,. ,.... , }� V • • \ . @ FDI /® = CS g ^ / . . 7 § 0a Q q 0. "< 0 ` CD i I 2 » \ g go ■ m • o ■ ›A G 2 § 0AT 5 k / 0cn r■ . Q 7 = op f 2m NI D. o . C*/ < \ 0 cx n O . 0 § § @ a § �. / \ 0. O -0 CD § 5. o CD c o c < -a m ] CD ° > = oh c k / ƒ \ 0J E 9 ƒ/ 2 /f CIS * m / \ 0 -,H CD o C CD 1 cp « « § � - 0 Fe. � � I ei 5-0D aB E94 x mrn / o_ oc CJ /J ^21 � \ AS D � ƒ (7a. , o co ] • D / § 2 » o 3. o0 = m m _ A) 0 / ƒ Q ( 3 CD mei CC RECEIVED STATE OF ALASKA AUG 18 2014 i .KA OIL AND GAS CONSERVATION COMIC JON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Cement Top Job Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Dnll Number Name. BP Exploration(Alaska),Inc Development[] Exploratory ❑ 195-117-0 3 Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22582-00-00 7 Property Designation(Lease Number). 8.Well Name and Number ADL0355018 KUP MPF-61 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 12120 feet Plugs measured None feet true vertical 7466.9 feet Junk measured None feet Effective Depth measured 12006 feet Packer measured None feet true vertical 7373.74 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20"91 1#H-40 35-113 35-113 1530 520 Surface 6552 9-5/8"40#L-80 34-6586 34-4604.22 5750 3090 Intermediate None None None None None None Production 12062 7"26#L-80 33-12095 33-7446.47 7240 5410 Liner None None None None None None Perforation depth Measured depth 11675-11681 feet 11730-11754 feet 11754-11784 feet 11784-11814 feet True Vertical depth 7106.04-7110 85 feet 7150 16-7169 45 feet 7169.45-7193.6 feet 7193.6-7217.81 feet Tubing(size,grade,measured and true vertical depth) 2-7/8"6.5#L-80 35-11515 35-6977.44 Packers and SSSV(type,measured and true vertical depth) None None None Packer None None None SSSV 12.Stimulation or cement squeeze summary: % WED {"!4 r",' > L .?(j i 5 Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 113 116 249 140 285 Subsequent to operation 137 112 236 140 297 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑Q Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work. Oil U Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUc] 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt. N/A Contact Nita Summerhays Email Nita.Summerha s• b•.com Printed Name Nita Summerhays / Title Petrotechnical Data Engineer S.l i- /, �� C/fig �,, �_ Phone 564-4035 Date 8/18/2014 AUG 19 LL `r k77- 3/i9;! /5 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0355018 ACTIVITYDATE SUMMARY ! T11'1 ems•= srfr'"'.'. .. emen con. or . ESP well is online. Schlumberger pumped 20 bbls cement into conductor. Job complete. Final WHPs= 300/300/310. 7/28/2014 SV=C. WV, SSV, MV=0. IA, OA= OTG. NOVP. 11:30. T/I/0=300/300/310 Temp=74*. Conductor Top Job, SLB pumped 20 bbls AS- 1 cement down Conductor x Surface casing. Will follow with RG-2401 once set. 50 bbl contam pill w/600 lbs citric acid and 5 gal D110 took returns for total of 112 bbls of material for GNI disposal. Job complete. Final WHPs= 7/28/2014 300/300/310. SV= C. WV, SSV, MV= 0. IA, OA= OTG. NOVP. 11:30 T/1/0= 290/275/335. Temp= 79g. Strap Conductor(Post top job). Online. TP decreased 10 psi, IAP decreased 25 psi&OAP increased 25 psi overnight. Cement is 23.5" bellow top of conductor, measurement taken @ the 5 o'clock position on the conductor. Job complete. 7/29/2014 SV= C. WV, SSV, MV= 0. IA, OA= OTG. NOVP 11:00 Hrs. FLUIDS PUMPED BBLS 20 AS-1 CEMENT 100 FRESH WATER 112 CONTAM PILL W/600LBS CITRIC ACID AND 5 GALS D110 232 TOTAL FLUIDS PUMPED GALS 10 D110 RETARDER 5 D206 ANTIFOAMING 15 TOTAL • Tree: Cameron 2 9/16" 5M MPU F- 61 Orig. KB.elev. = 49.2' (N 27E) Wellhead:11" x11" 5M FMC Gen 5 / Orig. GL. Elev. = 13.6' (N 27E) w/ 11"x 2 7/8"tbg. hng. w/2 7/8" RT To Tbg.Spool =32.62' 8 rd EUE threads top and bottom / I and 2.5"CIW'H' bpv profile / 1 20"91.1 ppf, H-40 113' % "` / � Camco 2 7/8"x 1" 143' sidepocket KBMM GLM KOP @ 500' Max. hole angle = 64 to 69 deg. f/ / 4200'to 9900' / Hole angle through perfs = 36 deg. 9 5/8",40 ppf L-80 Btrc. 6586' and I / 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. / (drift ID = 2.347", cap. / = 0.00592 bpf) 7" 26 ppf, L-80, BTR production casing (drift ID = 6.151", cap. = 0.0383 bpf) II 1 Camco 2 7/8"x 1" sidepocket KBMM GLM 11,249' 2-7/8"XN-Nipple (2.250") 11,401' IWeIILift DGU 11,444' = Centrilift ESP 11,449` SXD 141-P6 / SXD 141-P6 .1 li 51E4 Gas Separator 11,481' GRSFTXAR H6 Centrilift Tandem Seal Section Stimulation Summary GSB3DBUT SB/SB PFSA 11,486' it- GSB3DBUT SB/SB PFSA 10/16/95 - 158 M lbs. 16-20 Carbolite Centrilift KMHA, behind pipe, went to flush, no apparent 152 hp motor, 2325 v. /40 11,500' TSO amps Ems imir WeIILift MGU 11,513' Perforation Summary 4 Ref log: PLS GR/CCL 9/14/95 IMO 6 Fin Centralizer 11,515' "B" Sand SIZE SPF INTERVAL (TVD) 4.5" 5 11,675'-11,681 (7116'-7120') Alpha Jet charges (EHD = 0.50", _ _ Mid-pert=7171'TVD TTP =32") @ 60 deg. phasing 11744' MD "A"Sand SIZE SPF INTERVAL (TVD) 3 3/8" 6 11730'-11814' (7160'-7227') 7344'TVD Jumbo Jet charges (EHD = 076" , 7"Float collar(PBTD) 12,006' TTP = 6.4" )@ 60 deg. phasing 7"Float shoe 12,095' DATE REV BY COMMENTS MILNE POINT UNIT 09/11/95 JBF Drilled andCased By Nabors 27E 5/19/95 _ JBF 5/26/95 ESP RWO/10/10/96 ESP RWO WELL F-61 08/15/04 MDO ESP RWO Nabors 4-ES API NO: 50-029-22582 01/26/10 REH ESP RWO-Nabors 4E5 12/12/12 B.Bixby Doyon 16 RWO-ESP BP EXPLORATION (AK) Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~ Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ , OF ALASKA SPKA OIL AND GAS STATE ON CO ISSION RECEIVED A • REPORT OF SUNDRY WELL OPERATIONS JAN 0 4 2013 1. Operations Performed: AOGCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 195 - 117 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 — 50.029 22582 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025509 & 355018 MPF - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary: Total depth: measured 12120' feet Plugs:(measured) None feet true vertical 7467' feet Junk: (measured) None feet Effective depth: measured 12006' feet Packer: (measured) None feet true vertical 7374' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 6550' 9 -5/8" 6586' 4604' 5750 3090 Intermediate Production 12062' 7" 12095' 7446' 7240 5410 Liner Perforation Depth: Measured Depth: 11675' - 11814' feet True Vertical Depth: 7106' - 7217' feet Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L80 11517' 6979' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 117 146 208 280 234 Subsequent to operation: 117 114 226 280 226 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: IN Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 564 -5683 N/A Email: David.Bjork @bp.com Printed am Jo L a Title: Drilling Technologist Signatu - � _ , f Pho e: 564 -4091 Date: 1 /+/1 Form 10 -404 Revised 10/201 ' 1' v ,IAN t7 7 20 3 ' L v ti r 11 1 12_013 a ;` , Submit Original Only • • r r .- . ; 4 u ` , ? � ``�. i .5 � ,,�',�.,, , ., r �, *° ,, .; .: 5 h'"-", ''+; fi y y , r ° a a �,F:.' c " . ,rr y .* * m { '' k' . r...F' m"3 -* * t „�fa :' Y 2.+a 3 3 . 33 3334 �4, . -,. 'a ';s5 't s 2 fi ,d' .i '' * r S F3 gkr, , 3 r'" ', 3 t r a 3 r9 t., a°+e --P 1 A 7 t foe t t ,,, ` `' ¢ � .�e�.e Po- � - m,,�� ;'e 41 . i3 1 . ;. Y c s.,,c _ .'^r �"- �'r'rr3 -., � s}� { ,, 107,' a " a' k� z t '£s ;'a -t y �. t`Y .� ®z�> :5,';. '�,: .t` _ � ,. .�. "� '� � '� ,.^i.'A fi r., -�. `'c ., .. . s . : w .M. c,. � u�� .... .`�s� .m. � '..*. Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149 °39'22.174 "W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/6/2012 20:00 - 00:00 4.00 MOB P PRE PJSM, MOVE RIG - WSL, DAY AND NIGHT TOOLPUSHERS PRESENT, PAD OPERATOR NOTIFIED - WARM UP RIG HYDRAULICS, MAKE SPCC CHECKS - JACK UP RIG, REMOVE SHIMS, FUNCTION TEST E -STOP - MOVE OFF OF MPF -54 - MOVE AROUND PAD AND STAGE NEXT TO WELL MPF -61 - MOVE RIG MATS INTO PLACE, DOUBLE MAT UNDER RIG - INSTALL 13 5/8" X 11" SPACER SPOOL - SPOT CELLAR EQUIPMENT AROUND WELL 12/7/2012 00:00 - 02:00 2.00 MOB P PRE PJSM, CHECK HYRAULIC MOVING SYSTEM - CONTINUE TO SET MATS - SPOT RIG OVER MPF -61 02:00 - 03:00 1.00 MOB P PRE PREP RIG FOR ACCEPT - SHIM SUBBASE FOR LEVEL - SPOT CUTTINGS TANK - SPOT FUEL TRAILER AND CHANGE TRAILER - SET PIPE SHED RAMPS - ACCEPT RIG AT 03:00 03:00 - 06:00 3.00 WHSUR P DECOMP PJSM, RIG UP TO KILL WELL - SPOT FLOW BACK TANK - HARDLINE CREW HERE TO M/U HARDLINE TO RIG - TAKE ON 8 5 PPG 120,DEGREE TO PITS - R/U WELL KILL CIRCULATING LINES AND CHOKE MANIFOLD IN CELLAR - TEST ALL LINES AND CONNECTIONS TO 250 / 3500 PSI, 5 MIN, CHARTED - R/U REMOTE SSV PANEL AND FUNCTION TEST - IA = 920 PSI, TUBING = 140 PSI (WITH BPV INSTALLED), OA = 0 PSI 06:00 - 06:30 0.50 WHSUR P DECOMP HELD RIG EVACUATION DRILL. AAR: - ALL PERSONAL ACCOUNTED FOR. - WSL AND TOOL PUSHER DISCUSSED WHO THEY ARE REQUIRED TO NOTIFY. - DISCUSSED THE LOCATION OF EACH WORKER AND THE EXIT ROUTE TAKEN DURING THE DRILL. 06:30 - 07:30 1.00 WHSUR P DECOMP PJSM, TEST HARD LINE. - TEST ALL LINES AND CONNECTIONS TO 250 / 3500 PSI, 5 MIN, CHARTED. - BLOW DOWN ALL LINES. 07:30 - 11:00 3.50 WHSUR P DECOMP PJSM, R/U TO TEST DSM LUBRICATOR. - TEST DSM LUBRICATOR 250 / 3500 PSI AND CHART EACH 5 MINUTES. - PULL BPV PER DSM REP. SITP = 1050 PSI. - RLD 13 ,1_CAT - Printed 12/26/2012 9:56:01AM ' t ; °gig? ra 2' i a x 2 r' :# ? x Y i. ' "* x A fi P44 # z i-o ; ` i e rif) . ._., . u, ., . r , ye?r. ,' %''.`'`' ` .�..x* e, x-z rah i Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Ri g Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 p Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149 °39'22.174"W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:00 1.00 WHSUR P DECOMP PJSM ON DDI WELL KILL SOP. - SITP = 1050 PSI. SICP = 1000 PSI. - WSL & TOOL PUSHER VERIFY VALVE ALIMENT. - BLEED GAS FROM THE IA TO FLOW BACK TANK. - BLEED IA TO 250 PSI IN 40 MINUTES. SITP = 550 PSI. 12:00 - 14:00 2.00 WHSUR P DECOMP R/U TO BULLHEAD WELL VIA WELL KILL SKID IN CELLAR. - WSL & TOOL PUSHER VERIFY VALVE ALIMENT. - BULLHEAD DOWN 2 7/8" TBG AND IA SIMULTANEOUSLY. - BULLHEAD WITH 120 DEGREE 8.5 PPG SEAWATER. - PUMPED 870 BBLS KWF @ 7 TO 7.5 BPM. - ICP TBG = 500 PSI. I/A = 200 PSI. - FCP @ TBG @ 7 BPM = 2100 PSI VA = 1780 PSI. - SLOW TO 1 BPM @ TBG = 120 PSI. I/A = 1000 PSI. - PUMPS OFF @ 1400 HRS. - SITP = 1000 PSI. SICP = 780 PSI. 14:00 - 18:00 4.00 WHSUR P DECOMP MONITOR WELL HEAD PRESSURES PER WSL. - FIRST 30 MINUTES: SITP = 390 PSI. SICP = 210 PSI. - SECOND 30 MINUTES: SITP = '0' PSI SICP = 560 PSI. - DISCUSSED OPTIONS WITH RWO ENGINEER. - WITH TBG ON A VACUUM, BLEED DOWN IA FROM 450 PSI TO A NEAR '0' PSI. - PUMP 50 BBLS KWF (8.5 PPG SEAWATER) DOWN THE IA WITH THE TBG STILL ON A VACUUM. - MONITOR TBG AND IA BOTH ON A VACUUM. 18:00 - 19:00 1.00 WHSUR P DECOMP PUMP 5O_BBL . Q E EE .5 PPG SEAWATER DOWN IA 5 BP PSI - MONITOR WELL FOR 10 MINUTES - BOTH IA AND TUBING ARE ON A VAC - R/U SECONDARY KILL LINE WITH CHECK VALVE TO IA, AND BEGIN CONTINUOUS FILL AT 20 BPH 19:00 - 20:00 1.00 WHSUR P DECOMP BLOW DOWN WELL KILL MANIFOLD IN CELLAR - BLOW DOWN ALL CIRCULATING LINES AND STORE - R/U TEST EQUIPMENT FOR DSM LUBRICATOR AND TWC TESTS 20:00 - 20:30 0.50 WHSUR P DECOMP PJSM, R/U DSM LUBRICATOR - TEST LUBRICATOR T IN, CHARTED - INSTALL TWC - R/D DSM LUBRICATOR Printed 12/26/2012 9:56:01AM ",“ a �+ _ , i' , r . s S 1} 'st - a . = +,, ma as" ` ' � `' ' r ;.:, c # z; ,,, .p k ` '`'.4 =Y''`v ° Z` ` " ;'� `fi : , ' � ?e 9 , ,.� Com W e l l N am e : ID No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4 OOWYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149 °39'22.174 "W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From To Hrs Task Code NPT NPT (ft) Depth Phase Description of Operations (hr) 20:30 - 21:30 1.00 WHSUR P DECOMP PERFORM ROLLING TEST FROM BELOW TWC 4.5 BPM = 0 PSI, 10 MIN, CHARTED, 50 BBLS PUMPED AWAY TEST TWC FROM ABOVE, 250 / 350_0 PSI, 5 21:30 - 23:00 1.50 WHSUR P DECOMP PJSM, DRAIN N/D TREE FMC REP CLEAN AND IN THREA OSSOVER AND AND VE 2 7/8" EUE 8 R - MAKE DUMMY RUN WITH7/8E2, 2 7/8" SPECTED D EUE 8 RD CR = 10 1/4 NS 1 23:00 - 00:00 1.00 r BOPSUR P DECOMP PJSM, NIP IN PLE UP BOP - INSTALL TURNBUCKLES, KOOMY LINES, MOUSE HOLE MA CONTINOUS F TO AT 0 BPH _2-p PUMPED A TOTAL OF 924 HOLE BBLS ILL DURING IA WELL KILL _ - 24 HOUR FLUID LOSS = 1105 BBLS 12/8/2012 00:00 - 02:00 2.00 BOPSUR P DECOMP JSM, MAKE SAFETY AND SPCC CHECKS - CONTINUE AINT N/U BOP'S TO WELL HEAD HOOK KOOMY HOSES AND FUNCTION T PANEL INSTALL NTAI RISOLER TI AND ALL S HOL RELATED HOSES - MAIN CNNOUE L TO IA URING NIPPLE UP AT 20 BPH 02:00 - 02:30 0.50 BOPSUR P DECOMP R/U S BOP M/U TE FLOOR T VALVES EQUIPMENT AND TEST JOINTS - R/U TEST EQUIPMENT 02:30 - 07:00 4.50 BOPSUR P DECOMP PJSM, TEST BOPE AND RELATED TO TEST EQUIPMENT - TEST BOPS ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES T1= ST CNNi1L `TES JO1Nl T� 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES , CHARTED _R TES UPPER AND LOWER 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 - T WITH FRESH - PERFORM ACCUMULATO R DRAW DOWN TEST. TES - NO FAILURES. - CHUCK SCHEVE OF AOGCC STATES RIGHT TO WITNESS BOP WAIVED TEST - MAINTAIN CONTINUOUS HOLE FILL TO THE IA AT 20 BPH DURING TEST. 07:00 - 07:30 0.50 BOPSUR P DECOMP PJSM, R/D TEST EQUIPMENT. - BLOW DOWN LINES AND VALVES. - ALINE CHOKE VALVES. - R /D TEST EQUIPMENT. Printed 12/26/2012 9:56:01AM Y t 7 ,� 47kt, Fe, ass Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149°3922.174'W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code [ NPT NPT Depth I Phase Description of Operations (hr) (ft) _ 07:30 - 09:00 1.50 WHSUR P DECOMP PJSM, PULL TWC - M/U OFF SET LUBRICATOR. - PRESSURE TEST 250 PSI / 3500 PSI F/ 5 CHARTED MINUTES. - PULL TWC. - TBG ON A VAC - MISS RUN, RETEST LUBRICATOR. - MISS RUN # 2. LOST RUNNING TOOL WHILE TRYING TO RETRIEVE TWC. - DISCUSS OPTIONS WITH RWO TOWN TEAM / MPU / PBU DSM. 09:00 - 14:00 5.00 WHSUR N SFAL DECOMP PERFORM ROLLING TEST F/ BELOW, 18 BBLS TO FILL, 500 PSI, CHARTED 5 MINUTES EACH. PASSED. - DISCUSSED OPTIONS WITH RWO TOWN TEAM. - WAIT ON LEVEL THREE DECISION FROM RWO TOWN TEAM. - 13:30 HRS. RWO SUPERINTENDENT ARRIVE ON LOCATION. 14:00 - 15:00 1.00 WHSUR N SFAL DECOMP RECIEVED PERMISSION TO N/D BOPE FROM WTL @ 14:10 HRS. - L/D DSM LUBRICATOR AND OFFSET EXTENSION. - VAC OUT BOPE AND RETRIEVE DSM RUNNING TOOL WITH OUT N/D OF BOPE. - NOTIFIED RWO ENGINEER OF SUCCESSFUL RETRIEVAL OF RUNNING TOOL. - RESUME WELL PLAN STEP # 18. 15:00 - 16:30 1.50 WHSUR N SFAL DECOMP PJSM, FILL BOPE, P/U AND R/U DSM LUBRICATOR / OFFSET EXTENSION. - CLOSE ANNULAR AND PRESSURE TEST T/ 250 / 3500 PSI AND CHART F/ 5 MINUTES EACH. - PULL TWC AND R/D DSM LUBRICATOR AND EXTENSION. 16:30 - 17:30 1.00 WHSUR P DECOMP PJSM, M/U LANDING JT. WITH FOSV. - WSL VERIFIED NO TRAPPED PRESSURE BELOW TBG HANGER. - TBG AND IA ON A SLIGHT VACUUM. - FMC REP TO BOLDS. 17:30 - 18:00 0.50 PULL P DECOMP PULL TBG HANGER OFF SEAT 106 K (INCLUDES 40 K TOP DRIVE WT) - MAX PULL 120 K (INCLUDES TOP DRIVE WT). - PUW = 115K, SOW = 82K - PULL HANGER AND FIRST FULL JOINT, CUT ESP CABLE AT FIRST CLAMP BELOW HANGER - L/D LANDING JOINT AND HANGER, M/U FOSV AND CIRC HOSE - CLOSE ANNULAR - BULLHEAD 70 BBLS DOWN TUBING, 5 BPM = 620 PSI - CONTINUOUS HOLE FEED AT —20 BPH WHILE LAY DOWN HANGER. Printed 12/26/2012 9:56:01AM " ..;� s ,' ' -a- 's , . Common Well Name: MPF -61 AFE No WY - E:DRILL (1,600,000.00 Event Type: WORKOVER WO Start 12/6/2012 End Date: 12!11/2012 X4 00 R YP ( ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °3028.739 "9 Long: 0149°3922.174'W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 18:00 - 19:00 1.00 PULL P DECOMP MONITOR WELL - IA WAS FOUND TO HAVE LOW EXHALE AIR PRESSURE - PUMP 50 BBLS DOWN IA, STILL OBSERVE LOW EXHALE PSI - PUMP 30 BBLS DOWN IA MONITOR 10 MIN - OBSERVE EXHALE PSI DIE OFF AND BEGIN TO VAC - VERIFY VACUUM ON TUBING AND IA, OPEN ANNULAR 19:00 - 22:30 3.50 PULL P DECOMP PJSM, PULL 2 7/8" 6.5 #EUE 8 RD ESP COMPLETION AND STAND BACK IN DERRICK - POOH FROM 11492' TO 9160' MD - PUWT = 85K, SOWT = 70K 22:30 - 23:00 0.50 PULL P DECOMP CHANGE OUT SPOOL IN SPOOLING UNIT - MAINTAIN CONTINUOUS HOLE FILL TO THE IA AT 20 BPH 23:00 - 00:00 1.00 PULL P DECOMP CONTINUE PULL 2 7/8" 6.5# EUE 8 RD ESP COMPLETION AND STAND BACK IN DERRICK - POOH FROM 9160' TO 6692' MD OA =0PSI [- - 24 HOUR FLUID LOSS = 815 BBLS 12/9/2012 00:00 - 06:00 6.00 PULL P DECOMP PJSM, PULL 2 7/8" 6.5# EUE 8 RD ESP COMPLETION AND STAND BACK IN DERRICK - POOH FROM 6692' TO SURFACE - R/U TO LAY DOWN ESP PUMP AND MOTOR ASSY - RECOVERED: 359 LASALLE CLAMPS, 2 PROTECTOLIZERS & 3 FLAT GUARDS. - MAINTAIN CONTINUOUS HOLE FILL TO THE IA AT 20 BPH 8.5# SEAWATER. 06:00 - 07:30 1.50 PULL P DECOMP PJSM, L!D ESP ASSEMBLY. - RECOVERED: TWO SMALL PIECES OF ANNULAR RUBBER AND 4" LONG OLD SS BAND, FROM TOP OF MOTOR ASSEMBLY. - DRAIN AND LID ESP PUMP AND MOTOR ASSEMBLY. - CENTRILIFT REP REPORTED THE MOTOR WAS GROUNDED. 07:30 - 08:00 0.50 BOPSUR P DECOMP M/U WEAR RING RUNNING TOOL. - INSTALL 7 -1/8" ID WEAR RING. - L/D RUNNING TOOL. - R/D ESP SHEAVE FROM DERRICK. 08:00 - 11:30 3.50 BOPSUR P DECOMP PJSM, P/U HES 7" CHAMP PACKER PER HES REP. - RIH T/ 6588' MD. WITH PACKER ON 2 7/8" TBG FROM DERRICK. - OBTAIN PARAMETERS. - PU WT. = 73K INCLUDING 40K BLOCK WT. SO WT. = 65K. - CONTINUE RIH T/ 6600' MD. - P/U 1 JT 4" DP - SET HES PACKER PER HES REP W/ 20K DOWN WT. - WSL VERIFIED SET DEPTH. Printed 12/26/2012 9:56:01AM ttsrt„..t.,L:tfrl'tltll:#;Stttarif -17 1;6 5:1tftzt g '11 Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149°39'22.174'W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:00 0.50 BOPSUR P DECOMP PJSM, R/U AND TEST 7" CSG. - FILL I/AWITH 85 BBLS KWF. - LET AIR BREAK OUT AFTER FILL W/ FOSV CLOSED. - B/D TOP DRIVE AND ASSOCIATED LINES. 12:00 - 14:00 2.00 BOPSUR P DECOMP PJSM, WSL, TOOLPUSHER, HES REP, AND RIG CREW IN ATTENDANCE. - CLOSE ANNULAR AND FILL RIG CHOKE AND GAS BUSTER. - CIRCULATE ACROSS WELL BORE TO ALLOW AIR TO MIGRATE OUT. - VERIFY NO TRAPPED PRESSURE & OPEN ANNULAR. - CLOSE UPPER PIPE RAMS. - 20 PSI OBSERVED ON TBG. - DISCUSS W/ TOWN RWO ENGINEER. 14:00 - 15:00 1.00 BOPSUR P DECOMP M/U TOP DRIVE TO FOSV ON TBG. - 54 BBLS TO CATCH FLUID. - BULL HEAD 70 BBLS KWF DOWN TBG @ 3 -5 BPM WITH 540 PSI. - WITH THE 7" CHAMP PACKER SET @ 6600' MD. - PUMPS OFF, TBG ON A VACUUM. - DISCUSS W/ TOWN RWO ENGINEER. 15:00 - 16:30 1.50 BOPSUR P DECOMP PJSM, MIT-IA, 7" CSG BY 2 -7/8" ANNULUS. - PUMPED 17 STK (1.4 BBLS) T/ 1,500 PSI FOR 30 CHARTED MINUTES. - DISCUSS W/ TOWN RWO ENGINEER. - FEED 2 BBLS KWF DOWN THE TBG EVERY 5 MINUTES TO MAINTAIN THERMAL / PRESSURE CHANGES DURING TEST. - MIT -IA TEST, MEETS BP STP CRT- AK -10 -45 - RECEIVED PERMISSION TO PROCEED FROM WTL. - SEE ATTACHMENTS 16:30 - 18:00 1.50 CASING P DECOMP PJSM, BULL HEAD THE TBG WITH CHAMP PACKER SET. - WSL TOOL PUSHER CHECK VALVE ALIGNMENT. - OPEN PIPE RAMS. - 23 BBLS TO CATCH FLUID. - BULL HEAD 310 BBLS KWF DOWN THE TBG INTO THE FORM_ATION :TOP (BULL HEAD) = 7 BPM / 1050 PSI - FCP (BULL HEAD) = 7 BPM / 2850 PSI - PUMPS OFF, MONITOR TBG GOING TO A VACUMM. -'0' PSI IN 5 MINUTES. - MAINTAIN CONTINUOUS HOLE FILL TO THE IA AT 30 BPH 8.5# SEAWATER 18:00 21:30 3.50 CASING P DECOMP PJSM, POOH WIT H 7" C HAMP PACKER FROM 6600' MD - PUWT = 70K, SOWT = 65K - L/D CHAMP PACKER 21:30 - 23:00 1.50 CASING P DECOMP CLEAN, CLEAR RIG FLOOR - PULL WEAR BUSHING - MOBILIZE CENTRILIFT EQUIPMENT TO RIG FLOOR - HANG ESP CABLE SHEAVE Printed 12/26/2012 9:56:01AM f . ex 54V r 1' z x` F 3 " 'III �+J( x <, � " �� ?;aa�,�a� ', � � � �+ �^ a �' ',��,� �' , , a� � � � a � ��,:. "��t`�i � � t`�,r'�``�;' .'X-3 " ", z„�`�'{ ,k z„ a ',%"„ "s r 's`. .s,�;r,� �. F d .pia a ..,,?, �� `�r �. � �,�'; aE.;: �x <. o it ,r�k . 5 k` ar 4" a..K ` Yx`n' M.1 iy .:., + r ,.. � � '. -% i �; ti <Yt � 0`�4 ,.. rr . Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149 °39'22.174 "W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM, M/U ESP PUMP AND MOTOR ASSY - 24 HOUR FLUID LOSS = 921 BBLS - MAINTAIN CONTINUOUS HOLE FILL TO THE IA AT 30 BPH 8.5# SEAWATER 12/10/2012 00:00 - 04:00 4.00 RUNCOM P RUNCMP WEEKLY 1 HOUR SAFETY MEETING WITH CREW, TOUR PUSHER, WSL AND RWO SUPERINTENDENT - DISCUSSED DROPPED OBJECTS, DRIVING SAFETY, STOP PROGRAM AND RECENT INCIDENTS - CONTINUE M/U CENTRILIFT ESP PUMP AND MOTOR ASSY - TIE IN ESP CABLE AND CHECK CONDUCTIVITY 04:00 - 10:30 6.50 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8 RD TU BING ESP COMPLETION FROM ESQ A�SY - 83' TO 7588' MD - TUBING TORQUE = 2300 FT /LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 - 1 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL AT 30 BPH W/ 8.5# SEAWATER. 10:30 - 13:30 3.00 RUNCOM P RUNCMP CENTRILIFT REP PERFORM ESP CABLE REEL TO REEL SPLICE. - FLUSH PUMP WITH 5 BBLS KWF, 1 BPM / 7588' MD. 13:30 - 17:30 4.00 RUNCOM P RUNCMP CONTINUE RUN ESP COMPLETION FROM DERRICK. - F/ 7588' MDT/ 11517' MD 17:30 - 18:30 1.00 RUNCOM P RUNCMP M/U LANDING JOINT WITH FOSV - FMC REP REDRESSED HA NGER AND INSTALLED TWC - M!U lAND1N JT TO TUBING HANGER - M/U HANGER TO STRING AND ORIENT PER FMC REP - INSTALL PENETRATORS IN HANGER HELD DOYON 16 "CI" MEETING - DAY AND NIGHT WSL'S, BOTH TOOL PUSHER'S, BOTH SITE CONTROL SPECIALISTS, SITE CONTROL SUPERINTENDENT, DOYON DRILLING SUPERINTENDENT, AND RWO SUPERINTENDENT WERE PRESENT. - TOPICS DISCUSSED; - TIME ALLOTTED FOR RIG SERVICE AND RIG REPAIR - POSSIBILITY OF ADDING ASSISTANT DRILLERS TO THE RIG - COLD WEATHER ISSUES AND RESTRICTIONS ON EQUIPMENT - TRAINING CREW MEMBERS TO ADVANCE IN RIG SKILLS AND MOVE UP WITHIN THE CREW - SUMMER MAINTENANCE PLANNING Printed 12/26/2012 9:56:01AM '`' �s �i .l*"�' m. ,;,;. dik. z - ' "� *� " .tm.,„a".."�,, °"' fr e- 'pia e �, I t - — p ? x v� 4r xyit s `S . i ,° � tR . y " ` - w :'�r g :" , fi r - k ty ' wit, ,?,,,,: -a Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149°39'22.174'W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 19:30 1.00 RUNCOM P RUNCMP CENTRILIFT TERMINATED ESP CABLE - M/U ESP CABLE TO HANGER AND TEST CONDUCTIVITY THRU PENETRATOR 19:30 - 20:30 1.00 RUNCOM P RUNCMP LAND HANGER IN WELLHEAD RUN IN LOCK DOWN SCREWS - L/D LANDING JOINT PUWT = 120K, SOWT = 75K , INCLUDING 40K BLOCKS - FULL CANNON CLAMPS = 362 - HALF CANNON CLAMPS = 2 - PROTECTOLIZERS = 3 - PUMP CANNON CLAMPS = 10 20:30 - 21:00 0.50 RUNCOM P RUNCMP PERFORM ROLLING TEST FROM BELOW TWC - 7BPM = 0 PSI, 110 BBLS PUMPED AWAY - TEST FROM ABOVE TWC, 250 / 3500 PSI, 5 MIN, CHARTED - MAINTATONTINUOUS HOLE FILL AT 30 BPH WI 8.5# SEAWATER 21:00 - 23:00 2.00 BOPSUR P RUNCMP PJSM, N/D BOPE - N/U FMC GEN 5 11X 2 9/16" ADAPTER, 2 9/16" CAMERON TREE 23:00 - 00:00 1.00 WHSUR P RUNCMP FMC REP TEST ADAPTER VOID - 250 PSI LOW, 5 MIN, 5000 PSI HIGH, 30 MINUTES 12/11/2012 00:00 - 00:30 0.50 WHSUR P RUNCMP PJSM, SPCC CHECKS COLD WEATHER DISCUSSED - FMC REP CONTINUE TESTING HANGER VOID - 250 PSI LOW, 5 MIN, 5000 PSI HIGH, 30 MINUTES, GOOD TEST 00:30 - 01:30 1.00 WHSUR P RUNCMP FILL AND TEST TREE WITH DIESEL - 250 / 5000 PSI, 5 MIN, CHARTED, GOOD TEST 01:30 - 03:00 1.50 WHSUR P RUNCMP PJSM, R/U AND TEST DSM LUBRICATOR - TEST 250 / 3500 PSI, 5 MIN, CHARTED, PULL TWC - TEST LUBRICATOR, INSTALL BPV 03:00 - 03:30 0.50 WHSUR P RUNCMP ATTEMPT ROLLING TEST FROM BELOW BPV - PUMP 8 BPM = 0 PSI,10 MIN, CHARTED, 84 BBLS PUMPED AWAY - FLUID LOSS TO WELL = 332 BBLS Printed 12/26/2012 9:56:01AM "404140,f-': ,,,11,..404117470.3.140.4b,'?*attrittiOWA4Mx"AIPC3filt ,V Z"4. ' ' ". er < -' , �` -� a = ` 02 4 s r � � n M: �� - ;3°.+S - t ' r @ B {a t "� .'"` `. „ x��a t.0"/' � Common Well Name: MPF -61 AFE No Event Type: WORKOVER (WO) Start Date: 12/6/2012 End Date: 12/11/2012 X4- 00WYR- E:DRILL (1,600,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/17/1995 12:00:00AM Rig Release: 12/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.739 "9 Long: 0149 °39'22.174 "W Active Datum: ORIG KELLY BUSHING @46.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 06:00 2.50 WHSUR P OTHCMP SECURE TREE, INSTALL GUAGES - RIG DOWN AND BLOW DOWN ALL CIRC. LINES - SECURE CELLAR FOR RIG MOVE - CLEAN PITS AND CUTTINGS BOX - PREP RIG FOR MOVE OFF WELL WHP = T /0, IA = O. OA =0 PSI. RELEASE RIG AT 06:00 HOURS WEATHER RELATED OPERATIONAL NOTE: - AS OF 4:00, AMBIENT TEMP IS - 42 DEGREES - WELL SUPPORT WAS SCHEDULED TO INSTALL BPV ON MPF -14 PRIOR TO US MOVING ON THE WELL - THEY WERE UN -ABLE TO COMPLETE THE JOB THAT THEY WERE ON AND MOVE TO MPF -14, BECAUSE OF THEIR BOOM TRUCK COLD WEATHER RESTRICTIONS - AS SOON AS THE TEMP FALLS WITHIN THEIR GUIDLINES, THEY WILL RIG DOWN, MOVE TO MPF -14 AND INSTALL BPV Printed 12/26/2012 9:56:00AM �� • Tree: Cameron 2 9/16" 5M MPU F- 61 Orig. Klev. = 49.2' (N 27E) Wellhead:11" x11" 5M FMC Gen 5 Orig. GL. Elev. = 13.6' (N 27E) w/ 11" x 2 7/8" tbg. hng. w/ 2 7/8" / RT To Tbg. Spool = 32.62' 8 rd EUE threads top and bottom and 2.5" CIW 'H' bpv profile r 0 f 20" 91.1 ppf, H -40 113' Camco 2 718" x 1" 143' ✓ sidepocket KBMM GLM KOP @ 500' • Max. hole angle = 64 to 69 deg. f/ r 4200' to 9900' / ' Hole angle through perfs = 36 deg. / 9 5/8 ", 40 ppf L -80 Btrc. 6586' and A 0 , 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. (drift ID = 2.347 ", cap. 0 = 0.00592 bpf) • 7" 26 ppf, L -80, BTR production d casing • (drift ID = 6.151 ", cap. = 0.0383 bpf) / Camco 2 7/8" x 1" 11,249' • ' sidepocket KBMM GLM 2 -7/8" XN- Nipple ( 2.250 ") 11,401' WeIILift DGU 11,444' ✓ , Centrilift ESP 11,449' SXD 141 -P6 / SXD 141 -P6 r r Gas Separator 11,481' GRSFTXAR H6 0 Centrilift Tandem Seal Section Stimulation Summary re. GSB3DBUT SB /SB PFSA 11,486' GSB3DBUT SB /SB PFSA 10/16/95 - 158 M lbs. 16 -20 Carbolite � Centrilift KMHA, behind pipe, went to flush, no apparent g ` 152 hp motor, 2325 v. / 40 11,500' TSO amps mm. mow sm WeIILift MGU 11,513' Perforation Summary Ref log: PLS GR/CCL 9/14/95 1 OD 6 Fin Centralizer 11,515' "B " Sand SIZE SPF INTERVAL (TVD) 4.5" 5 11,675'- 11,681 (7116'- 7120') Alpha Jet charges (EHD = 0.50 ", Mid - perf = 7171' TVD TTP = 32 ") @ 60 deg. phasing 11744' MD "A" Sand SIZE SPF INTERVAL (TVD) 3 3/8" 6 11730' - 11814' (7160' - 7227') 7344' TVD 7" Float collar (PBTD) 12,006' Jumbo Jet charges (EHD = 076" , 12,095' TTP = 6.4" )@ 60 deg. phasing 7" Float shoe DATE REV BY COMMENTS MILNE POINT UNIT 09/11/95 JBF Drilled andCased By Nabors 27E 5/19/95 JBF 5/26/95 ESP RWO / 10/10/96 ESP RWO WELL F -61 08/15/04 MDO ESP RWO Nabors 4 -ES API NO: 50 -029 -22582 01/26/10 REH ESP RWO - Nabors 4ES 12/12/12 B. Bixby Doyon 16 RWO - ESP BP EXPLORATION (AK) STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N REPO OF SUNDRY WELL OPERATIONS RE~EIV~D DES o ~ zo~~ 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter SuspendeQVV+ewllere0® ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-117 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22582-00-00 7. Property Designation: \ 8. Well Name and Number. \ ADL 355018 \ MPF$1 9. Field / Pools Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured ~ 12120' feet true vertical ~ 7467' feet Plugs (measured) None Effective depth: measured 12006' feet Junk (measured) None true vertical 7374' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 6550' 9-5/8" 6586' 4604' 5750 3090 Intermediate Production 12062' 7" 12095' 7446' 7240 5410 Liner Perforation Depth: Measured Depth: 11675' - 11814' True Vertical Depth: 7106' - 7218' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 11495' 6961' Packers and SSSV (type, measured and true vertical depth): N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A H C.O. Exempt: Contact Mehrdad Nadem. 564-5941 N/A Printed Name Terris Hubble Title Drillin Technolo ist ~ ~ /1C" Prepared By Nama/Number: Signature Phone 564-4628 Date lJ~ Terris Hubble 564-4628 Form 10-404 Revised 07/2009 Submit Original Only RBDMS FEB 0 8 2010 ~~ 2 . ~- <~ ~ ~; ~ o • MPF-61, Well .History (Pre Rig Workover) Date Summary 01/10/10 WELL S/I ON ARRIVAL. PULLED 1" DGLV FROM 11277' MD. POCKET EMPTY. PULLED 1" DPSOV & SET 1" DGLV ~ 138' MD. WELL LEFT S/I ON DEPARTURE. 01/18/10 WELL S/I ON ARRIVAL. RIH W/ 2.06" CENT, SS, DUAL SPARTEK GAUGES. MADE 15 MINUTE STOP ~ 10930' SLM & 2 HOUR STOP ~ 11407' SLM. WELL S/I ON DEPARTURE. 01/20/10 The Well Support Techs rigged up and set a back pressure valve, removed the wellhouse, flowlines and foundation. NOTE: The BPV was left IN. Page 1 of 1 • • BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPF-61 Common Well Name: MPF-61 Spud Date: 8/17/1995 Event Name: WORKOVER Start: 1/21/2010 End: 1/27/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/27/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase " Description of Operations -- 1/22/2010 18:00 - 23:30 5.50 MOB P PRE RDMO TO MPF-61 -LOWER DERRICK -MOVE FUEL TANK & GENERATOR 3 -PREP UNITS TO MOVE FROM F-34 TO F-61 --AOGCC GIVEN 24-HR. NOTICE OF IMPENDING BOPE TEST. -NOTICE GIVEN AT 17:30-HRS. ON 1/22/2009. -WITNESS WAIVED BY CHUCK SHEVE 23:30 - 00:00 0.50 MOB P PRE PJSM ON RIG MOVE OPERATIONS WITH PEAK AND NABOBS PERSONEL -MOVE FROM MPF-34 TO MPF-61. 1/23/2010 00:00 - 01:30 1.50 MOB P PRE PJSM ON RIG MOVE OPERATIONS WITH PEAK AND NABOBS PERSONEL -MOVE FROM MPF-34 TO MPF-61. 01:30 - 04:00 2.50 MOB P PRE MIRU -SPOT SUB OVER MPF-61 WELL -SPOT PITS & PIPE SHED ALLIGNED TO SUB -RU LINES TO FLOW BACK TANK -SPOT DIESEL TANK AND GEN # 3. 04:00 - 05:00 1.00 MOB P PRE RAISE DERRICK RIG AGCCEPTED @ 05:00 05:00 - 06:00 1.00 MOB P PRE RU KILL LINES TO TREE. 06:00 - 06:30 0.50 RIGU P PRE RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 09:00 2.50 RIGU P PRE RU KILL LINES TO TREE -TAKE ON -120 DEG 8.45 PPG SEAWATER -TEST SURFACE LINES T/ 3,500 PSI -TEST TIGER TANK LINES W/ AIR TO 120 PSI 09:00 - 09:30 0.50 RIGU P PRE CHECK 6 HELD REFRESHER MEETING WITH RIG CREW AND LEADERSHIP. 09:30 - 10:00 0.50 RIGU P PRE PRE-KILL MEETING WITH CREW. 10:00 - 11:30 1.50 WHSUR P WHDTRE RU LUBRICATOR -TEST T/ 500 PSI W/ DIESEL -PULL BPV -SET TWC -RD LUBRICATOR 11:30 - 12:30 1.00 WHSUR N WHDTRE THAW ICE PLUG IN SUCTION OF TIGER TANK. 12:30 - 17:00 4.50 WHSUR N SEAL WHDTRE HOLE IN # 3 MUD PIT -DRAIN PIT #3 -NABOBS WELDER MAKE REPAIRS. 17:00 - 17:30 0.50 WHSUR N WHDTRE -FILL PIT #3 AND BLOW DOWN ALL LINES. 17:30 - 19:00 1.50 WHSUR P DECOMP TEST CIRCULATING LINES TO CHOKE TO 3500 PSI. -TEST LINES TO TIGER TANK W/ AIR TO 250 PSI. -OPEN WELL TAKE PRESSURES -IA=1280 - OA=O - T=1230 19:00 - 23:30 4.50 KILL P DECOMP PJSM FOR WELL KILL OPERATIONS -WELL KILL -BLEED IA AND TBG THROUGH CHOKE TO TIGER TANK. -PUMPED 70 BBLS. OF 120E SEAWATER DOWN TUBING AT 3-4-BPM -IA=1280 - OA=O -TBG=1230 CLOSED CHOKE AND BULLHEADED 25 BBLS DOWN TBG AT3-4BPM rnntea: uai~~w ii:vo:ccr.m • B'P' EXPLORATION Page 2 of 5 Operations Summary Report' Legal Well Name: MPF-61 Common Well Name: MPF-61 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date. From- To Hours Task Code NPT 1/23/2010 19:00 - 23:30 4.501 KILL P 23:30 - 00:00 ~ 0.50 ~ KILL ~ P 1 /24/2010 00:00 - 02:00 2.00 ~ W H SU R A P 02:00 - 03:00 1.00 WHSUR P 03:00 - 06:00 3.00 BOPSUFI P 06:00 - 06:30 0.50 BOPSU~ P 06:30 - 11:00 4.50 BOPSU P Spud Date: 8/17/1995 Start: 1 /21 /2010 End: 1 /27/2010 I Rig Release: 1/27/2010 Rig Number: 4ES .Phase Description of Operations DECOMP -IA=100 -TBG=90 OPENED CHOKE AND CONTINUED CIRCULATING DOWN THE TBG. -GOT RETURNS AT 1600 STROKES (94 BBLS) -PUMPED 500 BBLS UNTIL RETURNS CLEANED UP AT 3-4.5 BPM PUMPED A TOTAL OF 595 BBLS GOT BACK 220 BBLS TO THE TIGER TANK. DECOMP SHUT DOWN PUMPING AND MONITORED WELL FOR 20-MINUTES. -TBG. AND IA ON VACUUM. OA=O PSI DECOMP (FMC) SET TWC WITH T-BAR -TESTED FROM ABOVE TO 3500 PSI FOR 10 CHARTED MIN -CONDUCTED ROLLING TEST FROM BELOW ~ 3 BPM REACHING 100 PSI, DECOMP N/D 2-9/16" 5M CAMERON TREE -TREE WILL STAY ON LOCATION DECOMP N/U 13-5/8" x 5K HYDRIL BOPE. -RIG UP BOPE TEST EQUIPMENT. -FILL STACK DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS•,_ -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" TEST JOINT. -TESTED ANNULAR WITH 2 7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED FLOOR VALVES. -PERFORM KOOMEY TEST -200 PSI BUILD UP TO 1850 PSI FROM 1650 PSI = 44 SECONDS. -FULL BUILD UP TO 3000 PSI = 173 SECONDS. -4 BOTTLES x 1800 PSI. 11:00 - 11:30 0.50 BOPSU~ P 11:30 - 12:30 1.00 WHSUR P 12:30 - 14:00 1.501 WHSUR I P -WITNESSING TEST WAIVED BY CHUCK SCHEVE OF AOGCC. ON 1/23/2010 DECOMP RU DUTCH RISER SYSTEM. -CROSSOVER/LUBRICATOR DECOMP RU LUBRICATOR AND TEST SAME TO 500 PSI WITH DIESEL. -PULL TWC. -TUBING AND IA ARE ON A VAC. -LD LUBRICATOR AND RD DUTCH SYSTEM. DECOMP MU LANDING JOINT W/ TIW VALVE SCREW INTO HANGER. -"FMC" BOLDS -TBG AND IA ON A VACUUM. -PULL TBG HANGER OFF SEAT ~ 70 K -PUW = 85 K, SOW = 42 K. -LD HANGER rnntea: uoiwiv i i:w:cc Nm BP EXPLORATION Page 3 of 5' Operations Summary Report Legal Well Name: MPF-61 Common Well Name: MPF-61 Spud Date: 8/17/1995 Event Name: WORKOVER Start: 1/21/2010 End: 1/27/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/27/2010 ,Rig Name: NABOBS 4ES Rig Number: 4ES .Date From - To Hours Task Code NPT Phase Description of Operations 1/24/2010 12:30 - 14:00 1.50 WHSUR P DECOMP -CUT ESP CABLE AND BAND TO TBG. -MU LANDING JOINT W/ TIW VALVE. 14:00 - 14:30 0.50 WHSUR P DECOMP PUMP 70 BBLS 8.45 SEAWATER DOWN THE TBG, WITH NO RETURNS. -T/ CLEAR THE TBG. -SPR = 1 BPM / 30 PSI -3 BPM / 400 PSI 14:30 - 16:30 2.00 WHSUR P DECOMP CUT AND SLIP 84 FT. OF DRILLING LINE. 16:30 - 21:30 5.00 PULL P DECOMP PJSM: -POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -F/ 11,489' MD -STANDING BACK IN DERRIC -41 STANDS OUT. 21:30 - 22:30 1.00 PULL P DECOMP SWAP OUT ESP CABLE SPOOLS AND SPLICE - ~ 3500' , 39 STNDS OUT -SWAP REEL WITH MPU HEAVY LOADER 22:30 - 00:00 1.50 PULL P DECOMP PJSM: -POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -STANDING BACK IN DERRICK 1/25/2010 00:00 - 05:30 5.50 PULL P DECOMP CONTINUE POH j -F/ _11,489' MD W/ ESP ASSEMBLY ~ -STAND BACK 117 STANDS 2 7/8" TBG IN DERRICK. -FEED WELL ~ -20 BPH - -20 BPH LOSS RATE DURING TRIP - 183 LASALLE CLAMPS RETRIEVED (77 BAD) - 3 FLAT GUARDS - 5 PROTECTOLIZERS 05:30 - 08:30 3.00 PULL P DECOMP LD PUMP AND MOTOR ASSEMBLY 08:30 - 09:30 1.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. -RD ESP CABLE TRUNK. 09:30 - 13:30 4.00 BUNCO P RUNCMP PU / MU ESP PUMP AND MOTOR ASSEMBLY -WELL LIFT GAUGE W/ I-WIRE 13:30 - 18:00 4.50 BUNCO RUNCMP RUN ESP COMPLETION ON 2-7/8" TBG FROM DERRICK. -INSTALL LASALLE CLAMPS. -FLUSH PUMP W/ 5 BBLS SEAWATER AND -CHECK CONDUCTIVITY OF CABLE -EVERY -2,000' 1 BPM / 1,500 PSI -SPR = .75 / 500 PSI 18:00 - 19:00 1.00 BUNCO RUNCMP PTSM PRE TOUR CHECKS 19:00 - 20:30 1.50 BUNCO RUNCMP RUN ESR COMPLETION ON 2-7/8" TBG FROM DERRICK. -INSTALL LASALLE CLAMPS. -FLUSH PUMP W/ 5 BBLS SEAWATER AND -CHECK CONDUCTIVITY OF CABLE -EVERY _2,000' 1 BPM / 1,500 PSI -SPR = .75 / 500 PSI -78 STANDS IN _ 8,000' -SPR = 1.0 / 1100 PSI -TWO BAD JOINT REMOVED -WHEN WE BROKE THE STANDS DOWN TO LD THE BAD JNTS SOME PITTING WAS NOTICED ON THE INSIDE OF THE TBG. CONSULTED WITH ANC ADW RWO ENGINEER rnrnea: uoiLUiv II:VJ:LL HM • • BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPF-61 Common Well Name: MPF-61 Spud Date: 8/17/1995 Event Name: WORKOVER Start: 1/21/2010 End: 1/27/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/27/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To, Hours Task Gode NPT Phase- 'Description of Operations 1/25/2010 19:00 - 20:30 1.50 BUNCO P RUNCMP ON PLAN FORWARD. 20:30 - 00:00 3.50 BUNCO RUNCMP REEL TO REEL ESP CABLE SPLICE -TESTED DOWN HOLE BEFORE SPLICE WAS MADE, TEST WAS GOOD. -MADE THE SPLICE AND TESTED, TEST BAD. -CUT OUT SPLICE AND TESTED DOWN HOLE ,TEST BAD. -TESTED 300 OHMS TO GROUND. -CONSULTED WITH CENTRILIFT REP AND DAY WSL, DECISION WAS MADE TO POH. 1/26/2010 00:00 - 01:00 1.00 BUNCO P RUNCMP "HELD SUNDAY SAFETY MEETING WITH RIG LEADERSHIP TEAM AND RIG CREW FROM 23:00 TO 00:00 REEL TO REEL ESP CABLE SPLICE -TESTED DOWN HOLE BEFORE SPLICE WAS MADE, TEST WAS GOOD. -MADE THE SPLICE AND TESTED. TEST BAD. -CUT OUT SPLICE AND TESTED DOWN HOLE ,TEST BAD. -TESTED 300 OHMS TO GROUND. -CONSULTED WITH CENTRILIFT REP AND DAY WSL, DECISION WAS MADE TO POH. 01:00 - 01:30 0.50 PULL N DFAI DECOMP RU TO POH ON 2-7/8" TUBING -BRING UP BASKETS TO RIG FLOOR -PUT EMPTY REEL IN SPOOLING UNIT 01:30 - 08:30 7.00 PULL N DECOMP POH FOR FAILED ESP CABE CONDUCTIVITY TEST. -POH ON 2-7/8" TBG F/ 8,000', _ 234 JTS IN. -STAND IN DERRICK -ONE LEG FAILED PHASE /GROUNDED TEST j -ARMOR WAS ROLLED /DAMAGED IN MIDDLE OF CLAMP TO CLAMP AREA. 08:30 - 14:30 6.00 PULL N DECOMP CHANGE OUT REEL IN SPOOLER UNIT -SPLICE ON POT-HEAD FLAT LEAD. -SNAKE OVER SHEAVE IN DERRICK 14:30 - 18:00 3.50 BUNCO RUNCMP MU ESP POT HEAD T/ ESP ASSEMBLY -RUN ESP ON 2-7/8" TBG F/ DERRICK. -(1) CABLE CLAMP PER JOINT. -FLUSH PUMP EVERY _2,000' AND CHECK ESP CONDUCTIVITY. -1 BPM / 1500 PSI. SPR = .75 BPM / 500 PSI. -MAINTAIN-20 BPH FILL RATE. -T/JOINT # 90 18:00 - 18:30 0.50 BUNCO RUNCMP PERFORM PRE-TOUR 18:30 - 23:30 5.00 BUNCO RUNCMP RUN ESP COMPLETION ON 2-7/8" TBG F/ DERRICK -(1) CALBE CLAMP PER JOINT. -F/JOINT # 90 T/ 237 -FLUSH PUMP EVERY -2,000' AND CHECK ESP CONDUCTIVITY. -1 BPM / 1000 PSI. -MAINTAIN -20 BPH FILL RATE. 23:30 - 00:00 0.50 BUNCO RUNCMP MAKE CABLE SPLICE. -LOAD NEW REEL INTO SPOOLER UNIT. 1/27/2010 00:00 - 04:00 4.00 BUNCO RUNCMP CONTINUE MAKING CABLE SPLICE AND TEST SAME 04:00 - 07:30 3.50 BUNCO RUNCMP RUN ESP COMPLETION ON 2-7/8" TBG F/ DERRICK -(1) CABLE CLAMP PER JOINT. F'flflt@tl: 2/D/'LULU 11:W:ZZ HM • BP EXPLORATION Page 5 of 5 Operations Summary Report. Legal Well Name: MPF-61 Common Well Name: MPF-61 Spud Date: 8/17/1995 Event Name: WORKOVER Start: 1/21/2010 End: 1/27/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/27/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/27/2010 04:00 - 07:30 3.50 BUNCO RUNCMP -F/JOINT # 237 T/ 357 -FLUSH PUMP EVERY _2,000' AND CHECK ESP CONDUCTIVITY. -1 BPM / PSI. -MAINTAIN -20 BPH FILL RATE. 07:30 - 08:00 0.50 BUNCO P RUNCMP MU TBG HANGER W/ LANDING JOINT AND TIW VALVE. 08:00 - 10:00 2.00 BUNCO P RUNCMP CENTRILIFT TECH PERFORM PENETRATOR PIGTAIL SPLICE. 10:00 - 10:30 0.50 BUNCO P RUNCMP LAND TUBING HANGER -PUW = 75 K, SOW = 44 K. -FMC RILDS -L / D LANDING JOINT. 10:30 - 12:00 1.50 BUNCO P RUNCMP DRY ROD TWC. -TEST TWC F/ ABOVE TO 1,000 PSI FOR 10 CHARTED MINUTES. -TEST TWC F/ BELOW BY INJECTING INTO THE FORMATION AT 3 BPM / 00 PSI -CHARTED TEST 12:00 - 15:00 3.00 BOPSU P WHDTRE ND 13-5/8" BOPE AND 11 "X13 5/8" DSA. -REMOVE VBR's AND BLIND SHEAR RAMS 15:00 - 17:30 2.50 WHSUR P WHDTRE NU 2 9/16" PRODUCTION TREE -TEST HANGER VOID TO 5,000 PSI F/ 10 MIN. 17:30 - 18:30 1.00 WHSUR P WHDTRE MU LUBRICATOR -TEST T/ 500 PSI W/ DIESEL -PULL TWC -INSTALL BPV -TEST BPV ~ X BPM TO XXX PSI FOR 5 MIN -CENTRILIFT TAKE FINAL READING 18:30 - 19:00 0.50 WHSUR P WHDTRE BLOW DOWN LINES -SECURE WELL -RIG RELEASED AT 19:00 HOURS 1/27/2010 Pfintetl: "L/S/1UlU 11:US:ZZ AM Tree: Cameron 2 9/16" 5M Wellheadl l "x11 " 5M FMC Gen 5 w/ 11 " x 2 7/8" tbg. hng. w/ 2 7/8 8 rd EUE threads top and bottom and 2.5" CIW 'H' bpv profile 20" 91.1 ppf, H-40 113' ~ KOP C~ 500' Max. hole angle = 64 to 69 deg. f/ 4200' to 9900' Hole angle through perfs = 36 deg. 9 5/8", 40 ppf L-80 Btrc. 6586' and ~ 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, BTR production casing (drift ID = 6.151 ", cap. = 0.0383 bpf ) Stimulation Summary 10/16/95 - 158 M lbs. 16-20 Carbolite behind pipe, went to flush, no appare TSO Perforation Summary Ref log: PLS GR/CCL 9/14/95 "B" Sand SIZE SPF INTERVAL (TVD) 4.5" 5 11,675'-11,681 (7116'-7120') Alpha Jet charges (EHD = 0.50", TTP = 32") C~ 60 deg. phasing ~ "A" Sand SIZE SPF INTERVAL (TVD) 3 3/8" 6 11730' -11814' (7160' -7227 MPU F- 61 Jumbo Jet charges (EHD = 076" , TTP = 6.4" )C~3 60 deg. phasing DATE REV. BY COMMENTS 09/11/95 JBF Drilled andCased By Nabors 27E 5/19/95 JBF 5/26/95 ESP RWO / 10/10/96 ESP RWO 08/15/04 MDO ESP RWO Nabors 4-ES 01/26/10 REH ESP RWO -Nabors 4ES Orig. KB. el't?G. = 49.2' (N 27E) Orig. GL. Elev. = 13.6' (N 27E) RT To Tbg. Spool = 32.62' Camco 2 7!8" x 1 " 138' sidepocket KBMM GLM Camco 2 7/8" x 1" 11,277` sidepocket KBMM GLM 2-7/8" XN-Nipple (2.250") 11,420' WeIILift DGU 11,431' Centrilift ESP 11,436' SXD 137-P17 Gas Separator 11,455` GRSFTXAR Centrilift Tandem Seal Section 11,461 ` Centrilift KMH, 190 hp motor, 2415 v. / 48 11,475' amps WeIILift MGU 11,492` Short Joint f/ 11,521' to 11,542' Mid-pert = 7171' TVD 11744' M D 7344' TVD 7" Float collar (PBTD) 12,006' 7" Float shoe 12,095' MILNE POINT UNIT WELL F-61 API NO: 50-029-22582 BP EXPLORATION · I 1Jt1' Ka.:VL_t v L-U STATE OF ALASKA AU'~ ~ ~ '~'f\7 ALA KA OIL AND GAS CONSERVATION COM SION···'~ REPORT OF SUNDRY WELL OPERtihi1J1QaNS¡ä" . ,;ilS ,'¡nmÎssÎon D D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development IV Stratigraphic StimulateD. nc.hCtj!¡er Q ACID TREATMENT Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ... 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Exploratory Service 195-1170' P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 3. Address: 6. API Number: 50-029-22582-00-00 / 9. Well Name and Number: 46 KB MPF-61 ' 8. Property Designation: ADLO-355018 11. Present Well Condition Summary: 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool Total Depth measured true vertical 12120 I 7466.9 leet leet Plugs (measured) Junk (measured) None None Effective Depth measured 12006 leet true vertical 7374 leet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" Surface - 110' Surface - 110' Surface 6550' 9-5/8" 40# L-80 Surface 6586' Surface - 4604' 5750 3090 Production 12062' 7" 26# L-80 Surface - 12095' Surface - 7446' 7240 5410 Perforation depth: Measured depth: 11675 - 11681 True Vertical depth: 7106.04 - 7110.85 11730 -11754 7150.16 - 7169.45 11754 -11784 7169.45 - 7193.6 11784-11814 7193.6 -7217.81 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 Surface - 11489' Packers and SSSV (type and measured depth) 5CJ~NED AUG 1 '12007 o o o o N/A o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and linal pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies 01 Logs and Surveys Run Daily Report 01 Well Operations Oil-Bbl 275 288 Representative Daily Average Production or Injection Data Gas-Mcl Water-Bbl Casing Pressure 58 421 0 60 423 0 15. Well Class after proposed work: Exploratory Development IV 16. Well Status after proposed work: Oil IV Gas WAG Tubing pressure 291 283 13. Service x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the loregoing is true and correct to the best 01 my knowledge. Sundry Number or N/A il C.O. Exempt: N/A Title Data Management Engineer Signature Phone 564-4944 Date 8/14/2007 Form 10-404 ReVised 04/2006 OR 1 G \ ~\J /}\ L RBDMSBFl AUG 17 20D7 k4'l-" Submit Original Only . . , .. MPF-61 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY (Acid treatment/ESP trouble). Pump 10 bbls crude down tbg injectivity test. Pump 13 bbls 12% DAD acid down tbg followed by 3 bbls 60/40 meth & 59 bbls crude to spot acid across ESP. Turn well over to DSO to spin ESP as per procedure. FWHP=500/340/330. FLUIDS PUMPED BBLS 69 Crude 13 12% dad acid 3 60/40 meth 85 TOTAL ~ STATE OF ALASKA .~ ALASKA ......L AND GAS CONSERVATION CO.lrllv1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 46' 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface. 6550' Intermediate Production 12062' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): B Repair Well 0 Plug Perforations B Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate Change Out ESP 0 Stimulate BOther 0 Waiver 0 Time Extension 0 Re-Enter Suspended Well 4. Current Well Class: B Development 0 Exploratory 0 Stratigraphic 0 Service 195-117 6. API Number: 50-029-22582-00-00 9. Well Name and Number: MPF-61 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 12120 7467 12006 7374 feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 112' 112' 9-5/8" 6586' 4604' 5750 3090 7" 12095' 7446' 7240 5410 11675' - 11814' 7106' - 7218' 2-7/8", 6.5# L-80 11489' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A RECEIVED SEP 1 '* 2004 SEP 1 3 2004 Alaska Oil & Gas Cans. Commission Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl Treatment description including volumes used and final pressure: 13. Oil-Bbl Tubin Pressure Re resentative Dail Gas-Met Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run B Daily Report of Well Operations B Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory B Development 0 Service 16. Well Status after proposed work: BOil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL ge. Sundry Number or N/A if C.O. Exempt: 17. Printed Name Sandra Stewman Title Technical Assistant Date~ - 10 Prepared By Name/Number: Sondra Stewman, 564-4750 Submit Original Only Tree: Cameron 2 9/16" 5M Wellhead:11 " x11" 5M FMC Gen 5 wI 11" x 2 7/8" tbg. hng. w/2 7/8" 8 rd EUE threads top and bottom and 2.5" CIW 'H' bpv profile 20" 91.1 ppf, H-40 I 113' KOP @ 500' Max. hole angle = 64 to 69 deg. fI 4200' to 9900' Hole angle through perfs = 36 deg. 95/8",40 ppf L-80 Btrc.6586' md I 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift 10 = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, BTR production casing (drift 10 = 6.151", cap. = 0.0383 bpf ) Stimulation Summary 10/16/95 - 158 M Ibs. 16-20 Carbolite behind pipe, went to flush, no apparent TSO Peñoration Summary Ref loa: PLS GRlCCL 9/14/95 "8" Sand SIZE SPF INTERVAL (TV D) 4.5" 5 11,675'-11,681 (7116'-7120') Alpha Jet charges (EHD = 0.50", TTP = 32") @ 60 deg. phasing "A" Sand SIZE SPF INTERVAL (TVD) 33/8" 6 11730' -11814' (7160' -7227') Jumbo Jet charges (EHD = 076" , TTP = 6.4" )@ 60 deg. phasing DATE 09/11/95 5/19/95 08/15/04 Ev. BY JBF JBF MDO COMMENTS Drilled andCased By Nabors 27E 5/26/95 ESP RWO /10/10/96 ESP RWO ESP RWO Nabors 4-ES MILNE POINT UNIT WELL F-61 API NO: 50-029-22582 MPU F- 61 Orig. "d. elev. = 49.2' (N 27E) Orig. GL. Elev. = 13.6' (N 27E) AT To Tbg. Spool = 32.62' Camc027/8"x1" I sidepocket KBMM GLM 138' Cameo 2 7/8" x 1" sidepocket KBMM GLM I 11 ,277' I 2-7/8" XN-Nipple (2.250") I 11,389' I Centrilift GC 1700 ESP, I 11,431' I AR 1:1 , GPMT, 151 Stg. Centrilift Tandem seal sec. I 11 ,449' I GRSFTXAR 400 Internals Centrilift Tandem seal sec. I 11,454' I GSB3DBUTILH6PFSHSN GSB3DBLTH6HSN Centrilift KMH 562 series, I 11,468' I 171 hp motor, 2290 v. 144 amps I I Centrilift Pumpmate 11 ,487' Short Joint fl 11,521' to 11,542' Mid-perf = 7171' TVO 11744' MO 7" Float collar (PBTD) 7" Float shoe 7344' TVO I 12,006' I I 12,095' I BP EXPLORATION AK Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/14/2004 8/15/2004 Date ,~ ~ BP EXPLORATION Operations Summary Report MPF-61 MPF-61 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Phase 06:00 - 07:00 07:00 - 09:00 09:00 - 10:30 10:30 - 11 :00 11 :00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 21 :30 21 :30 - 23:30 23:30 - 00:00 00:00 - 05:00 05:00 - 07:30 07:30 - 08:30 08:30 - 10:00 10:00 - 14:00 14:00 - 16:00 16:00 -18:00 18:00 -18:30 18:30 - 20:30 120:30 - 21:00 21 :00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 Task Code NPT 1.00 MOB 2.00 RIGU - ------- -- P P PRE PRE 1.50 RIGU P PRE 0.50 RIGU 2.00 KILL P P PRE DECOMP 0.50 KILL P 1.00 WHSUR P 1.50 BOPSUF P 3.50 BOPSUF P DECOMP DECOMP DECOMP DECOMP 0.50 WHSUR P DECOMP 1.00 PULL DECOMP P 0.50 PULL 2.00 PULL 0.50 PULL 5.00 PULL P P P DECOMP DECOMP DECOMP DECOMP 2.50 PULL P 1.00 RUNCO! ~ DECOMP RUNCMP 1.50 RUNcm~ 4.00 RuNcmfp 2.00 RuNcmfp 2.00 RuNcmf'p 0.50 RUNcm~ 2.00 RuNcmfp 0.50 RuNcmfp 0.50 BOPSUF P 1.50 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 1.00 WHSUR P RUNCMP Page 1 of 1 Start: 8/14/2004 Rig Release: 8/15/2004 Rig Number: Spud Date: 8/17/1995 End: 8/15/2004 Description of Operations ---------------- .---- Move Rig and Equipment from MPL-Pad to MPF-61. Spot Sub Base, Pits, and Pipe Shed. Raise and scope Derrick. Spot Camp. Accept Rig at 09:00 hrs. Take on Sea Water in Pits. Spot tiger Tank and lay Lines. Hook up To Production Tree. Pick-up Lubricator and pull BPV. Lay down same. Tbg Press = 280 psi. Csg Press = 260 psi. PJSM with All. Pump down Tbg at 4.25 bpm/400 psi..,unable to surface any fluid after pump 70 bbls (Tbg Vol +). Bullhead w/350 bbls down Annulus at 5.8 bpm/1100 - 1500 psi and kill Well. Monitor Well...on vac. Blow down Lines. Install TWC and test. Nipple down Production Tree. Nipple up BOPE. Function test. Rig up test equipment. Test BOPE per BP/AOGCC requirments at 250/3,500 psi. State's right to witness the test waived by J. Jones. P/U lubricator. Pull TWC, had 30 psi on plug. Bleed off same. UD lubricator. P/U landing jt & M/U into hanger. BOLDS. Pull hanger to floor w/103K. Monitor well. Unplug cable from penetrator & check same. Ud hanger & landing it. Pull ESP cable over sheave & connect to spooler. POOH wI 2 7/8" ESP completion by stands. Pull 34 stands. Change out spools in spooling unit. Con't to POOH wI completion. On stand # 52 had wrapped up & damaged cable from 4919 to 4972'. Stood back a total of 118 stands. UD tubing punched jt & 3 singles. UD pump & motor. Clear and cleand floor. Load new ESP Assembly boxes in Pipe shed. Swap Cable reels in Spooling Unit. Bring LaSalle Clamps (old style) to Floor. Pick-up and service and inspect ESP Assembly. Attach Motor Lead and check Cable. Start RIH with ESP Assembly and 2 7/8" Tbg. Check Cable every 2,000'. Stop to make Reel to Reel splice (80 Stds ran). Splice Cable. Check Cable. Continue RIH with ESP Completion. P/U landing jt & M/U hanger. Install penetrator in hanger. Make field splice in ESP cable. Test same. Land completion. RILDS. Set & test TWC. N/D BOPE. N/U adapter flange & tree. Test tree to 5000 psi, Ok. Make final check on ESP. M/U lubricator & set BPV. UD lubricator. Test BPV. Secure tree & cellar area. RIG RELEASE @ 2400 hrs, 8/15/2004 Printed: 8/16/2004 8:57:59 AM h sred rijllJJng TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: APl # MPB-24 Well Suspension 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose Setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8, x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 .: . , GANNED NOV 1 ~Z6 OOL L61:, 06~' .................................. ~ ............................ . ............................. , ...................................................... , ................................................ ~ ................................... .......................... ~. ................. ...:.~. ................... ~ .................................. ~ ............................... ~. ................. 668 cj6/9 I./60 8Z---IdlAI 00 I. cJ6/i;, I./60 8Z---I d IAI S I. I- §6/[~ I./60 8Z---Id ~ 9 I.;~ cj6/~ I./60 8Z-...q d IAI 0 96/I. I./60 69-...-Idi/~ ......................................... , .................. , ................................... ~ ...................... ~ .................... 86;~ 96/0 I./60 69-ddlAI 0~1. 689'1. ...... . 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I;§'-'~'~l'fl euJeN Ile/~ JUl ............................. ~ZS"~JS'qt~'l~ eUJeN .......................................... ~'OlIlR ~essv ~00;~ 8 -[ AON QaNN¥..9$ N I= blOS AEIJ. N3 VZVO NOI.LO=IPNI BV'lnNNV ared rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 Re: Annular Disposal Information Request Dear Ms. Mahan: RECEIVED DEC 14 1,998 Alaska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular DispoSal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1~03/P-16, 1~65/~-25, 1-59/0-24 · Exploration well Pete's Wicked · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted.for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. We also provide .you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: .. ,Annular Disposal Letter '. 12/14/98 Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well S_ourdou~h #3 - ~' ~ o ~ · Mflne_PointwellsF-06, H-05, H_06, J~13, L_24 _ · PBUwells-18-30, 18-31, 14~4,.~-4_3, E,.-34, E-36, G-04A, andS.33-~-~oz- .... oS ~3- ~.a ' q ~-. · Ind,mdual logs are prov, dod to ~6u ~ ttiese ~ogs as We~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED OEC !4 1998 Alaska Oil & Gas Cons. Commission Anchorage I, ~ar(~,d SerVice Drilling ~n~ar Injection Volumes ly 25, 199,5 until December 1998 ~mulative Report 'Surface Casing Inj Well. Depth Legal Desc licott on 15 on 15 Cum Total Cum Mud & Ctgs 1-19/I-18 5000 Sec. 36, T12N, R16E 8,960 7,848 1-23/O-15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 · ot~ 15 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 on 15 1-61/Q-20 4236 .3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 Cum Rig Wash Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Fluids Fluids .Freeze Freeze Start E~nd Status. . 992 1,160 150 120 12/5/95 12/5/96 Open 200 120 9/30/95 12/31/95 Open 8/31/95 12/31/95 Broached on 15 2.40/S-22 4531 2020'FNL 2289'FEL Sec 36 T12N R16E 31 195 29 952 1 063 120 60. 7/25/95 12/31/95 Open ............................................................................ '. ........................ '. .............. , ........ ! ............................ ', ....................... ,'. ......................... '. ................................................................................................................................................................................ 01114 15-47 3515 3648'NSL 4956'WEL Sec 22 T11N R14E 3 002 903 2 009 90 11/7/95 12/31/95 Open on 14 DS 15-45 3829 4749' NSL 5180' WEL Sec 22 T11N 1 882 1 697 134 51 4/4/96 4/4/97 Broached on 14 DS 15-48 . 3548 Sec..22, TllN, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open 3n 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open 3n 9 18-30 3930 1499'SNL, 26'WEL, Sec 24 T11N R14E 2 266 936 380 800 150 7/25/95 12/31/95 Open .'. ............... .'.............: ....................................................... · ........................................................................................................................................................................................................................................................................................................................................................................................................ 3..0...9. ................................... !..8.:3"! ...................................... .3..6..~.0. ................................ .3..7. !...~'.N..S..L..L.6....4.'...W....E.L.!...?.~..2...4..,..T..!..!.N...,.....R...!..4..E. ..................................... .6...,..(~.8.~ ............................... .2...,..2..~_0. ........................... !.,_!..o. ?.. .............................. .2..,..5..~.~ ...................................................................................................................... !..7..! ................ ..7.(..2..6..(..9....5. ........................ .!...2/..3.!.(.9...5,. ..................... ~.p....e..n.. ................. ~..n...~ ................................. 2?...2 ........................................ ~..3....0. ................................ .3.?.~'....N..S.L.,...~.!..:.w.....E...L..~..S..~.?~.,.T.!..LN..?_.I.~_E' ............................. ..3.,._3..!..! .................................. !.,.~.~.1. ................................... ._2.o_.o.. ........................ !.,_!.0....0. ............................................................................... !_~_0. .......... _8L2.~!.9_5' ............... !??_.5. .................. .O_,p_e_n. .............. ~n 9 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open 3rs 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open 3rs 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open 3rs 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open :)..r..S...1....8.E- .................... !..4_-..4..~ ................................... .3..2..~~ ................................. .2....8.2..~?..S...L..L.!_ .6...!._7_'. _W_ .E L..,......s..e.. c_..9_,..T 1_ O__Nz..R.!..4_ _E- ......................... .3..!.9..7.4. ............................... ..2..,..3...1..9_ ........................... !_,..5...3...5. ............................ 120 8/17195 12/31/95 Open Ioration 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed e -- MPK- 17 3508 3648'NSL,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 100 4/18/96 4/18/97 ~ Open )rs 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open )rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open )rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open )rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 NOV.: 2002 DEC 1 4 1998 · ~ a6ed N:ldO 96ff. 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STATE OF ALASKA ... · ALASKA O~..-~ND GAS CONSERVATION COMk SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I~ Operation Shutdown ~Stimulate [] Plugging E~ PeRorate [] Pull Tubing [~Alter Casing [] Repair Well I-]Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 2077', NSL, 2537' WEL, SEC. 06, T13N, R10E At top of productive interval 4593' NSL, 571' WEL, SEC. 31, T14N, R10E At effective depth 4745' NSL, 490' WEL, SEC. 31, T14N, R10E At total depth 4808' NSL, 501' WEL, SEC. 31, T14N, R10E 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-61 9. Permit Number / Approval No. 95-117 10. APl Number 50-029-22582 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12120 feet 7466 feet 12006 feet 7374 feet Length Size 80' 20" 6550' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx) 1237 sx PF 'E', 250 sx 'G' 250 sx PF 12062' 7" 250 sx Class 'G' MD TVD 112' 112' 6586' 4604' 12095' 7446' PeRoration depth: measured 11675'-11681'; 11730'-11814' true vertical 7106'-711 ', 7150'-7218' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 11462' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure OP, 161NAL 14. Representative Daily Average Production or lniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments _i Copies of Logs and Surveys run iA Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~~ ~/'~ ~// Production Engineer KATRINA N. COOPER . '~/ Title Prepared By Name/Number: I16. Status of well classifications as: I~ Oil E~] Gas [] Suspended Service Date II-I- ¥ Michael Williams, 564-4657 Form 10-404 Rev. 06/15/88 Submit In Duplicat.~.e MPF-61 DESCRIPTION OF WORK COMPLETED Stimulation Operation 02/25/99 AESP 2000 Stimulation Treatment was performed using the following fluids: SUMMARY Arrived location, held pre job safety meeting. Since the chemical is new to Milne point, the MSDS was discussed during the meeting. RU HB&R Pressure tested, start to fill up the annulus with dead crude. 75 Bbls 2 bpm @ 800 psi. RU to annulus start down tubing with ESP 2000,5 Bbls 2 bpm. @ 600 psi. switch to diesel pumped 30 Bbls 2 bpm @ 670 psi. followed by dead crude, 150 Bbls @ 2 bpm. 1000 psi. the tubing started to trend up during the last 30 Bbls tubing final pump pressure was 1150 psi. Stop pumping. Let treatment sit in the formation for approx, two hours Started ESP and ramped up slowly. Fluids Pumped I' BBLS. Description 5 ESP 2000 ¢kei~ 30 Diesel 225 Dead crude 260 Total Pumped RECEI'V D OV 0 5 1999 Gas Cons. Commission ........ . STATE OF ALASKA - ALASKA C. AND GAS CONSERVATION COMI~,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: E~] Operation Shutdown l--]Stimulate ~] Plugging ~] Perforate ~] Pull Tubing I~Alter Casing [~ Repair Well ~]Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2077' NSL, 2537' WEL, SEC. 06, T13N, R10E, UM At top of productive interval 4593' NSL, 571' WEL, SEC. 31, T14N, R10E, UM At effective depth 4745' NSL, 490' WEL, SEC. 31, T14N, R10, EUM At total depth 4808' NSL, 501' WEL, SEC. 31, T14N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [--]Service 6. Datum Elevation (DF or KB) KBE = 49.2' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-61 9. Permit Number / Approval No. 95-117 10. APl Number 50-029-22582 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12120 feet true vertical 7466 feet Effective depth: measured 12006 feet true vertical 7374 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" 6550' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx,) 1237 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 12062' 7" 250 sx Class 'G' MD TVD 112' 112' 6586' 4604' 12095' 7446' Perforation depth: measured 11675'-11681', 11730'-11814' true vertical 7106'-7111', 7150'-7218' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 11462' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the, foregoing is true and correct to the best of my knowledge si, ed Terrie Hubbl -v .~-- Title Technical Assistant III Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicat Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-61 Rig Name: Nabors 4ES AFE: Accept Date: 10/09/96 Spud Date: .... Release Date: 339024 10/12/96 10/09/96 Move in, rig up. Take on sea water and hook lines to tree and TT for well kill. 10/10/96 Pull BPV, rig up hard lines and test to 2000 psi. Displace influx in well bore with sea water. Set two-way check and ND tree and NU BQP's. Test BOP's to 250 Iow and 5000 high (test witnessed by Lew Grimmaldi with the AOGCC). Pull hanger to floor and check ESP cable. Mix and pump 40 bbls Zanvis pill. POOH with ESP completion. 10/11/96 Lay down ESP assembly. Rig Camco wireline and run 6" GR/JB to 11915' wlm. POOH and rig down. Make up ESP assembly and service same. RIH with ESP assembly to 6900', 74 stands. Tubing had a Iow Ohms check. POOH and found lead at top of motor badly damaged. 10/12/96 MU splice to new motor lead and change out motor and PHD. RIH with ESP assembly. Slice ESP cable. Continue RIH with ESP completion. Make up hanger and landing joint. Splice on penetrator pig tail. Land tubing. RILDS -lay down joint, set 2-way check. Nipple down BOP and NU tree. Test tree and hanger to 5000 psi. Pull check and set BPV. Freeze protect well with 75 bbls of diesel. Make final check on ESP cable and rig down lines and secure tree. PERMIT DATA 95-117 6801 95-117 7006 AOGCC Individual Well Geological Materials Inventory 95-117 T DATA PLUS ~700-11978 GR ~MWD SPERRY'S FM EVAL CN/D ,NS - MD 95-117 CN/DENS - TVD ~L~SEPIA 95-117 EWR/GR - MD ~SEPIA 95 - 117 EWR/GR ~ TVD . 95-117 GR/CCL ~'~'/[ '~'~'-'~ / 95 - 117 PLS ' (STAT) 95 - 117 CCL/PERF 95-117 CCL/PERF ~-~EPIA 3m/i1650-11890 ~SEPIA 11391-11411 ~'~SEPIA 11280-11396 ~'/SEPIA 11270-11442 Page: Date: RUN 1 05/13/98 DATE RECVD 09/28/95 03/07/96 02/13/96 02/13/96 02/13/96 02/13/96 10/24/95 06/21/96 06/21/96 06/21/96 10-407 DAILY WELL OPS ~OMPLETION DATE R Y/fl/ 7 TO Are dry ditch samples Was the well cored? Are well tests required? i~es Well is in compliance ~ Initial COMMENTS required? yes ~ And received? yes yes ~_~Analysis & description received? n~_,Received? ~ , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of WeLl Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-117 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o-029-22582 4. Location of well at surface i :~ .'. ~';~-'-,ii-"~. f~ ~"i ,.'~ ~;i"~ -~,.,~.~ 9. Unit or Lease Name 2077' NSL, 2537' WEL, SEC. 6, T13N, RIOE;¢./~.?,~,,f;,.'"-: ;'~~ Milne Point Unit At Top Producing Interval ~---/-~-'~=~L~-¢~ 10. Well Number 4593'NSL,,Z,'WEL, SEC. 31, T14N, R10E! ...... ~;_ ...... ;. i?~iL! '~ 11. Field and ,oo, i ...... ' MPF-61 At Total Depth '; .... ---"-'" ..... %;~: ' Milne Point/Kuparuk River Sands 4808' NSL, 501' WEL, SEC. 31, T14N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 49.2' ADL 355018 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore [16. No. of Completions 08/17/95 08/28/95 05/26/96 '~I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 12120' MD / 7466' TVD 12006' MD / 7374' TVD YES [] NO [] N/A feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, GR/RES/DEN/NEU 23. CASING, LINER AND CEMENTING RECORD SE'I-RNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT8OLHE 32' 112' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 6586' 12-1/4" 1237 sx PF 'E; 250 sx 'G', 250 sx PF 'E' 7" 26# L-80 33' 12095' 8-1/2" 250 SX Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 2-7/8", L-80 11460' N/A MD TVD 11675'-11681 7106'-7111' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w~ 70 bbls diesel 3-3/8" Gun Diameter, 6 spf Kuparuk 'A' Sand, Il730:11814' Frac'd w~ 158000# 16/20 Carbofite MD TVD 11730'-11814' 7150'-7218' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 05/28/96 ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATERoBBL CHOKESlZE IGAS-OIL RATIO rEST PERIOD ~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. !24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ,." !i" '-"'...7. '~ .... ¢;? ",.'.-~ .. ' ' :'~.,;:,.... :, ... ,~' , .'.., .-. ,-"i " .~,.-,~;. r... ~.. -' .. .. ...,;-.,. ~: ": :, '" ;" i..-'' % : .,~.:,, ~'... '.:; .....:'; :'..'.: ; '~ ,.,,,:', ,.... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) TKUA 11727' 7102' .. TKA3 11733' 7107' TKA2 11757' 7126' TKA 1 11787' 7150' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .. Signed ~ ~--~'~~ ' Title Senior Drilling Engineer Date ~--'~"'FH 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~AI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPF-61 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 08/17/95 06:00 SPUD: 08/17/95 05:30 RELEASE: OPERATION: DRLG RIG: NABORS 27E WO/C RIG: 08/18/95 ( 1) TD: 1350' ( 0) 08/19/95 (2) TD: 3400' (2050) 08/20/95 (3) TD: 5271' (1871) 08/21/95 ( 4) TD: 6600' (1329) 08/22/95 (5) TD: 6600'( 0) TAKE ON WATER MW: 0.0 VIS: 0 TAKE ON WATER, MIX MUD, SET CUTTINGS BOX. SET CEMENT TANKS. N/U 20" HYDRIL AND DIVERTER SYSTEM, INSTALL RISER, HOOK UP FLOWLINE, INSTALL MOUSE HOLE, PUT UP WELL SIGN. MU BHA #1. ORIENT MWD/MOTOR, CHECK MWD. FILL HOLE, CHECK FOR LEAKS. RETIGHTEN FLOW NIPPLE, LEVEL RIG. KELLY UP. BREAK CIRCULATION. PRESSURE TO HIGH. SET BACK KELLY. BREAK OFF BIT. GRAVEL ON TOP OF JETS. FLUSH COLLARS, MU BIT, KELLY UP, PRESSURE OK. DRILL F/ll0' TO 1350' DRILLING MW: 0.0 VIS: 0 DRILL F/1350' TO 2946'. PULSER IN MWD FAILED. CIRCULATE HOLE CLEAN. CHECK FOR FLOW. DOWNLOAD MWD. CHECK PULSER. CHANGE OUT PULSER. CHANGE BIT. ORIENT MWD W/MOTOR. RIH, CHECK SHOT SURVEY AT 2937'. CIRC, CONDITION MUD. SHAKERS UNABLE TO HANDLE DRILLING FLOW RATE. DRILL F/2946' TO 3400' DRILLING MW: 0.0 VIS: 0 DRILL F/3400' T/4078'. PUMP SWEEP,CIRC TILL HOLE CLEAN. SHORT TRIP T/3100. OK. NO FILL. DRILL F/4708' T/5271' SHORT TRIP MW: 0.0 VIS: 0 PUMP HI/LO SWEEP,CIRC HOLE CLEAN. CHECK FOR FLOW. SET BACK KELLY. SHORT TRIP T/4078'. OK. NO FILL. DRILL F/5271' T/6600' CIRC HOLE CLEAN,MONITOR. PUMP DRY JOB. POOH. DISPLACE CEMENT MW: 0.0 VIS: 0 SHORT TRIP TO HWDP,SLM, NO CORRECTION. MONITOR WELL @ HWDP. TIH. OK. NO FILL. CIRC & COND MUD,MONITOR. PUMP DRY JOB. POOH. LD 100 JTS 'G' PIPE. LD BHA. DOWNLOAD,FINISH LD BHA, CLEAR FLOOR. RU TO RUN 9-5/8" CASING. LEVEL RIG. MU LANDING JT & HANGER. LAND CASING. MU CEMENT HEAD. CIRC CASING VOLUME,10 BPM 460 PSI. TEST LINES W/3000 PSI. CEMENT CASING. DISPLACE CEMENT WITH WATER @ 12 BPM. INITIAL CIRC PRESSURE 750 PSI. WELL : MPF-61 OPERATION: RIG : NABORS 27E PAGE: 2 08/23/95 (6) TD: 6600'( 0) 08/24/95 ( 7) TD: 7349' ( 749) 08/25/95 (8) TD: 8199' ( 850) 08/26/95 (9) TD:10249' (2050) RIH W/ BHA #3 MW: 0.0 VIS: 0 DISPLACE CEMENT @ 12 BPM. BUMP PLUG W/ 3000 PSI. CIP @ 0630 HRS. LD CEMENT EQUIP. ND FLOWLINE,RISER & DIVERTER LINE. ND 20" ANNULAR. RU & DO TOP JOB. NU FMC GEN 5 WELLHEAD & TBG SPOOL. NU ADAPTOR. PU BOPE STACK. CLEAR FLOOR. TEST WELLHEAD W/1000 PSI. OK. NU BOPE,CHOKELINE,RISER, FLOWLINE & INSTALL MOUSE HOLE. SET TEST PLUG. TEST BOPE,CHOKE MANIFOLD & SAFETY VALVES W/500 & 5000 PSI. ATTEMPT TO PULL TEST PLUG. PU ABOUT 2' & HUNG UP. GOT IT TO MOVE UP & DOWN ABOUT 4",THEN IT HUNG UP & WOULD NOT GO EITHER WAY. ND FLOWLINE & CHOKELINE. SEPERATE BOPE FROM ADAPTOR ON TOP OF TBG SPOOL. FISH OUT PIECE OF ALUMINUM 1/2" X 2" LONG. STILL MORE PIECES BETWEEN TEST PLUG & WELLHEAD. CUT OFF TEST JT ABOVE ADAPTOR. ND 7" SPOOL. REMOVE MORE PIECES OF JUNK FROM BETWEEN TEST PLUG & CSG SPOOL. REPAIR TEST JT. NU CSG SPOOL. WASH OUT & FUNCTION RAMS. NU BOPE. NU CHOKE & FLOWLINE. TIGHTEN TURNBUCKLES. OPEN RAM DOORS. WASH OUT & INSPECT FOR JUNK. INSTALL TEST PLUG. BODY TEST BOPE & WELLHEAD. LD TEST PLUG. INSTALL WEAR BUSHING. MU BHA #3. ORIENT MOTOR W/ MOTOR. TRIP IN HOLE W/ BHA #3. DRILLING MW: 0.0 VIS: 0 CONT RIH. CUT & SLIP DRILLING LINE. ADJ BRAKES. RESET CROWN-O-MATIC. POOH. LD PDC BIT & PU MILL TOOTH BIT DUE TO POSSIBLE JUNK IN HOLE. RIH T/2279'MD. FINISH RIH. TAG FC @ 6502' MD. CIRC. TEST CSG T/3000 PSI FOR 30 MIN. OK. DRILL FC, CMT,FS & 10' NEW HOLE. CBU. PERFORM LEAKOFF TEST TO 12.5 PPG ENW W/8.5 PPF MUD WT AT 6610' MD / 4603' TVD. DRILLING F/6610' MD T/6784' MD. DRILLING F/6784' MD T/7349' MD. DRILLING MW: 0.0 VIS: 0 DRILLING F/6784' MD T/8169' MD. CIRC SWEEP AROUND. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. POOH TO MWD. DOWNLOAD MWD. REMOVE RESOURCES. CHANGE BIT. LOAD SOURCES. ORIENT MWD. RIH T/8125' MD. OK. REAM F/8125' MD T/8169' MD. NO FILL. CBU. RU ATLAS WIRELINE & GYRO/DATA. RIH & RUN IN HOLE REFERENCE GYRO. RD ATLAS WIRELINE & GYRO/DATA. DRILLING F/8169' MD T/8199' MD. DRILLING MW: 0.0 VIS: 0 DRILLING F/8911' TO 9649'. SWEEP HOLE. FLOWCHECK WELL, OK. PUMP DRY JOB. SET BACK KELLY. SHORT TRIP, 16 STANDS. NO PROBLEMS. HOLE IN GOOD SHAPE. RIH, NO PROBLEMS, NO FILL. DRILLING FROM 9649' TO 10249' WELL : MPF-61 OPERATION: RIG : NABORS 27E PAGE: 3 08/27/95 (10) TD:11228' ( 979) 08/28/95 (11) TD:12120' ( 892) 08/29/95 (12) TD:12120' ( 0) DRILLING MW: 0.0 VIS: 0 DRILLING F/10249' TO 11069'. SWEEP HOLE, FLOWCHECK WELL, OK. PUMP DRY JOB. SET BACK KELLY. 16 STANDS, SHORT TRIP T/9629'. NO PROBLEMS. RIH, NO PROBLEMS, NO FILL. DRILLING F/11069' TO 11129' CHANGEOUT SWAP #2 PUMP. DRILLING F/11129' TO 11228' CHANGEOUT SWAP #2 PUMP. MONITOR WELL MW: 0.0 VIS: 0 DRILLING F/11228' MD T/11385' MD. PU TO MAKE CONNECTION. WELL FLOWING. SHUT IN WELL. MONITOR. 11385' MD ESTIMATED AT +- 150' ABOVE KUPARUD 'D' SHALE CAP. MONITOR. SIDDP T/120 PSI. SICP T/120 PSI. BLEED OFF 5.6 BBL FROM ANNULUS & SHUT IN. SICP T/0 PSI. SIDPP T/80 PSI. BLEED OFF 1.5 BBL FROM DP. DP PRESSURE T/0 PSI. CBU. NO GAS/OIL AT BOTTOMS UP. CONTACTED PAD ENGINEERS/GEOLOGY. NO INJECTORS IN AREA. POSSIBLE CROSSED FAULT. MONITOR AFTER CBU. WELL CONT TO FLOW W/ VERY SLIGHT TRICKLE. WELL ACTING JUST LIKE MPF-53. DRILLING F/11385' MD T/12120' MD. EST FORMATION TOPS. CIRC SWEEP AROUND. CIRC & COND MUD FOR SHORT TRIP. FLOWCHECK WELL. VERY SLIGHT TRICKLE. EST HAVE LOST 140 BBL TO FORMATION SINCE 0930 HRS. PUMP DRY JOB. SET BACK KELLY. POOH W/ 5 STDS. HOLE STAYS FULL. GO BACK TO BOTTOM. MONITOR 30 MIN. WELL OOZING WITH VERY SLIGHT TRICKLE (NO MEASURABLE GAIN). POOH WITH 5 STDS. WELL TAKING FLUID. POOH WITH 5 MORE STDS. HOLE TAKES 8 BBL FOR 8 STDS (CALCULATED 7.6 BBL). MONITOR. WELL STABLE. LD 10 SINGLES. POOH TO 9-5/8" CASING SHOE. CALCULATED UNDER-DISPLACEMENT ON TRIP TO SHOE OF 10 BBL. MONITOR. WELL STABLE. ESTIMATE NET LOSS TO FORMATION SINCE 0930=130 BBL. RIH W/7",26# L-80 BTC CSG MW: 0.0 VIS: 0 RIH T/11752' MD. OK. REAM 11 JTS TO BOTTOM @ 12120' MD. CIRC SWEEP AROUND. CIRC & COND MUD TO RUN 7" CASING. FLOWCHECK WELL. SLOW TRICKLE. NEVER SAW INDICATIONS OF GAS OR OTHER HYDROCARBON IN MUD. PUMP DRY JOB. POOH SLM & RACK BACK DP. STOP @ SHOE & MONITOR WELL FOR 30 MIN. STILL TRICKLING SLIGHTLY. CONT POOH. DOWNLOAD MWD. PULL SOURCES. LAY DOWN BHA. SLM NO CORRECTION NEEDED. PULL WEAR RING. CHANGE RAMS TO 7". INSTALL TEST PLUG. TEST DOOR SEALS TO 3000 PSI. OK. LD TEST JT & TEST PLUG. RU TO RUN 7", 26# L-80 BTC CASING. RIH WITH 7",26# L-80 BTC CASING. ON JOINT 152 OF 280 @ 0600 HRS. WELL : MPF-61 OPERATION: RIG : NABORS 27E PAGE: 4 08/30/95 (13) TD:12120' ( 0) 08/31/95 (14) TD: 12120' ( 0) ND BOPE MW: 0.0 VIS: 0 FINISH RIH W/7",26# L-80 BTC CASING T/12095' MD.VERY SMOOTH TRIP INTO THE HOLE.LAND CASING.PU WT 325K, SO WT 120K,WITH 10.2 PPG MUD.RU HALLIBURTON CEMENTERS.CIRC 400 BBO MUD.EST LOSE 300 BBL MUD WHILE CIRC/COND.SHUT DOWN. FLUSH #1,#2 RIG MUD PUMP WITH TOTAL OF 150 BBL FRESH WATER.HALLIBURTON PUMPS 10 BBL WATER.TEST LINES T/3000 PSI. OK.HALLIBURTON PUMPS 10 MORE BBLS WATER.HALLIBURTON PUMPS 70 BBL SPACER AT 11.2 PPG. DROP BOTTOM PLUG. HALLIBURTON PUMPS 250 SX OR 51.2 BBL OR 287.5 CUFT OF PREMIUM 'G' CEMENT. ISOLATE WELLBORE.FLUSH HALLIBURTON CEMENT LINES TO MOUSEHOLE.DROP TOP PLUG. LINE UP ON WELLBORE.HALLIBURTON PUMPS 80 BBL 55 DEGREES DIESEL, FOLLOWED BY 5 BBL WATER.RIG TAKES OVER & DISPLACES WITH RIG MUD PUMP #1 AT 10 BPM WITH 376 BBL OF SEAWATER. BUMP PLUG. CALCULATED STROKES 3743. ACTUAL 3759. BUMP PLUG T/3500 PSI. CIP @ 1800 HRS.,8/29/95. ANNULUS FLOWING. SHUT IN ANNULUS. TEST CSG 3500 PSI FOR 30 MIN. OK. NO LOSS.RD CSG TOOLS & HALLIBURTON EQUIP. RD MOUSEHOLE. REMOVE TURNBUCKLES FROM STACK. 280 PSI ON ANNULUS. OPEN ANNULUS & ALLOW MUD LOST DURING CEMENT JOB TO FLOWBACK UNTIL RATE +- 2 BPM. EST TOTAL OF 140 BBL FLOWED BACK. PREPARE TO SET PACKOFF. DRAIN BOP STACK. BREAKOUT LANDING JT & LD. SET PACKOFF & TEST T/5000 PSI F/15 MIN. OK. SET TBG HANGER W/ 2 WAY CHECK IN IT. CHANGE OUT 7" RAMS TO 5". ND CHOKELINE,FLOWLINE,RISER, BOP STACK & SET BACK. ND DOUBLE STUDDED ADAPTOR FLANGE. PREPARE NU TREE MIRU MW: 0.0 VIS: 0 NU TREE. TEST TBG SPOOL W/ 5000 PSI FOR 15 MIN. TEST TREE W/5000 PSI. NU MOUSEHOLE. FINISH CLEAN PITS & CELLAR. LD DP IN MOUSEHOLE. FREEZE PROTECT MPF-53 W/ 80 BBL. REMOVE EXCESS DIESEL F/STORAGE TANK. CLEAN CELLAR. RIG RELEASED @ 2200 HRS.,8/30/95. MOVE RIG TO MPF-69. SIGNATURE: (drilling superintendent) DATE: SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-61 Rig Name: 4ES AFE: 33011 9 Accept Date: 02/1 7/96 Spud Date: Release Date: 02/22/96 Feb 17 1996 .. Rig accepted 02/17/96 @ 0100 hrs. RU & test against 7" RBP. ND tree, NU BOP, change rams to 3-1/2". Feb 18 1996 RU flowline & hardline to tiger tank. Install test plug, test BOP's, pull test plug, install WB. Doug Amos w/AOGCC waived witness of BOP test. MU Baker retrieving tool, PU 3-1/2" DP, TIH t/2600'. Rev circ, 12 bbls methanol, store in tiger tank. TIH, PU 3-1/2" DP, RIH with Baker retrieving tool. Circ & displace clean brine out of hole with hi-visc brine. Close annular, set down on RBP at 11397', monitor pressures & release RBP. CBU thru choke manifold. Hole static, no gains or losses while circ. Feb 19 1996 CBU thru choke, monitor well, wash down (rev) to 11418', take weight, monitor well. TOH, LD Baker RBP & retrieving tool. Strap & MU BHA, space out csg, scrapper above mill. TIH w/3-1/2" DP & BHA #2. Rev circ. Tag sand at 11417', could not reverse sand, PU kelly, rotate thru hard spot f/11417'-11425' with 5M bit weight. Rev wash sand f/ 11425'- 11844', rev circ. Rev CBU every 60'. " Feb 20 1996 Monitor well, rev circ, static fluid loss. TOH above perfs at 11630'. Build pit volume, reduce brine weight, condition same with xanvis & liquid csg. Rev circ, displace well with 9.8 ppg brine. RIH, finish clean out sand 11844'-11993'. Rev circ hole clean, observed loss circ, materials on bottoms up appeared to be quick seal, circ until clean, monitor well. POOH 50' below perfs at 11864', spot25 bbl LCM pill across perfs. POOH 200' above perfs at 11475' for csg wash. Clean pits, take on clean brine & reduce to 9.8 ppg. Rev circ csg wash, follow with filtered brine, final reading 40 NTU on returns. Monitor well. POOH, LD 3-1/2" DP. ., · . .~, _.:~,,'~?i'..~;'~'''~ ' ' ' , ...' . · z, .. ,-,~" '-" · .,. Page Feb 21 1996 Lubricate & service rig. LD 3-1/2" DP. Cut & slip drill line. LD DP. TOH, LD DP. Pull WB, install test plug, change rams to 2-7/8" & test. PU kelly, flush BOP stack & flowline of sand,etc. RU floor for ESP completion. MU ESP pump & motor assy. PU 2-7/8" tbg, RIH with ESP completion Feb 22 1996 Cont to RIH with ESP completion & splice cable. MU hanger & splice ESP cable & land same & RILDS, back out L J, set 2-way check. Change out rams in BOP to 3-1/2". ND riser & BOP's. NU tree & flange & test. Freeze protect well with diesel & RD cellar & set BPV, secure well. Rig released 02/22/96 @ 0600 hrs. Page 2 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P F-61 Rig Name: 4 E S AFE: 3 3 01 I 9 Accept Date: 05/1 7/96 Spud Date: Release Date: 05/1 9/96 May 17 1996 MIRU. Berm & trim herculite & raise & scope derrick. RU lines to tree & pull BPV, take on brine. Berm & spot tiger tank & test mud line & found flange leak. Welder to change flange. Rig accepted 05/17/96 @ 2400 hrs. May 18 1996 Change out flange on mud line in pit module & test. 'Displace well bore fluids with brine & monitor well. Set 2-way check & ND hardline & tree. NU BOP's & test. Pull two way check & MU LJ & BOLDS. Pull hanger to floor & check ESP cable,etc & LD hanger. POOH with ESP completion. May 19 1996 Cont POOH with ESP completion. ND flowline & NU shooting flange. Rig Atlas lubricator & test. Run Gyro survey f/12012' t/surface & RD Atlas. ND shooting flange & NU flowline. MU & service ESP. RIH with ESP completion. May 20 1996 RIH with ESP assy. MU hanger & LJ & land tbg. RILDS back out LJ & LD. ND flowline & riser & BOP's. NU tree & hanger & test, pull TWC. Freeze protect tbg & annulus. Rig lub & set BPV. Blow down lines & secure tree,etc. Rig released 05/19/96 @ 1800 hrs. Page ] SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P F-61 Rig Name: 4 E S AFE: 3 3 01 I 9 Accept Date: 05/24/96 Spud Date: Release Date: 05/26/96 May 24 1996 Standby for pre-rig workover prep. MIRU & berm & raise derrick & level over well. Take on water & mixing brine & rig hard lines to tree. Rig accepted 05/24/96 @ 0300 hrs. May 25 1996 Weight water to 9.8 ppg. Circ out influx. Set 'I'WC & ND tree & nu BOP's. Test BOP. Test waived by Chuck Seavy. BOLDS & pull hanger & check. Monitor well, LD hanger. POOH with ESP completion. May 26 1996 Cont POOH with ESP completion & rec 2 flat bands & 2 float guards inside BOP. MU FTA #1 & RIH with same t/11983'. Circ & spot pill. POOH with ESP completion. MU ESP assy & check out. RIH with ESP completion. May 27 1996 RIH with ESP completion. MU hanger & penetrator & splice ESP cable. Land hanger & RILDS & LD LJ & install 'I'WC. ND BOP'$ & NU tree & test & pull TWC & freeze protect. Secure wellhead. Rig released 05/26/96 @ 2100 hrs. Page S~'.RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ~P EXPLORATION MILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/95 TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DGMN DEGREES DATE OF SURVEY: AUGUST, 1995 COMBINED MWD/GYRO SURVEY JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 FT. OPERATOR: BP EXPLOP,_ATION DLS TOTAL RECTANGULAR COORDINATES VERT. DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -49.20 100 100.00 50.80 200 199.99 150.79 300 299.97 250.77 400 399.96 350.76 0 0 0 15 1 10 1 1 0 56 N .00 E N 28.89 E N 20.53 E N 42.22 E N 2.44 E .00 .00N .00E .00 .25 .19N .liE .21 .92 1.34N .57E 1.44 .44 2.95N 1.53E 3.24 .67 4.43N 2.16E 4.83 500 499.93 450.73 600 599.90 550.70 700 699.86 650.66 800 799.81 750.61 900 899.75 850.55 1 25 1 34 1 42 2 0 1 59 N 10.19 E N 14.36 E N 16.79 E N 22.45 E N 37.77 E .50 6.47N 2.41E 6.87 .19 9.03N 2.97E 9.48 .14 11.78N 3.74E 12.34 .35 14.81N 4.84E 15.55 .53 17.80N 6.57E 18.87 1000 999.65 950.45 1100 1099.49 1050.29 1200 1199.17 1149.97 1300 1298.66 1249.46 1400 1397.99 1348.79 2 52 3 30 5 28 6 9 7 5 N 18.88 E N 17.24 E N 20.39 E N 12.90 E N 18.55 E 1.19 21.55N 8.44E 22.97 .64 26.85N 10.16E 28.53 1.98 34.25N 12.74E 36.33 .. 1.01 43.95N 15.60E 46.43 1.15 55.03N 18.76E 57.95 1500 1497.08 1447.88 1600 1596.00 1546.80 1700 1694.79 1645.59 1800 1793.46 1744.26 1900 1891.92 1842.72 8 17 8 33 9 14 9 28 10 38 N 20.18 E N 18.80 E N 13.76 E N 17.00 E N 16.05 E 1.21 67.65N 23.21E 71.29 .34 81.46N 28.10E 85.87 1.03 96.31N 32.40E 101.32 .57 111.97N 36.72E 117.57 1.18 128.71N 41.68E 135.01 2000 1989.80 1940.60 12 54 N 14.22 E 2100 2086.92 2037.72 14 35 N 13.95 E 2200 2183.02 2133.82 17 28 N 14.47 E 2300 2277.75 2228.55 19 51 N 16.60 E 2400 2371.03 2321.83 22 19 N 16.49 E 2.30 148.41N 46.97E 155.41 1.68 171.46N 52.75E 179.18 2.88 198.23N 59.54E 206.79 2.48 229.03N 68.14E 238.76 2.48 263.52N 78.39E 274.71 2500 2462.74 2413.54 2600 2553.02 2503.82 2700 2641.93 2592.73 2800 2729.14 2679.94 2900 2813.74 2764.54 24 36 26 18 28 8 30 24 34 0 N 17.38 E N 14.05 E N 14.02 E N 14.90 E N 14.67 E 2.30 301.60N 89.99E 314.47 2.23 342.96N 101.59E 357.42 1.84 387.35N 112.69E 403.17 2.30 434.69N 124.91E 452.06 3.59 486.21N 138.50E 505.35 3000 2895.10 2845.90 3100 2973.53 2924.33 3200 3049.62 3000.42 3300 3123.82 3074.62 3400 3195.69 3146.49 37 4 39 35 41 17 42 54 45 10 N 14.28 E N 15.27 E N 14.18 E N 16.23 E N 16.33 E 3.09 542.49N 153.02E 563.47 2.59 602.46N 168.86E 625.49 1.83 665.20N 185.33E 690.35 2.12 729.86N 202.93E 757.36 2.28 796.58N 222.41E 826.82 3500 3263.83 3214.63 3600 3327.94 3278.74 3700 3388.75 3339.55 3800 3446.00 3396.80 3900 3499.43 3450.23 48 53 51 20 53 43 56 25 58 59 N 15.79 N 15.14 N 15.28 N 15.32 N 15.53 E 3 . 73 866 . 89N 242 . 64E E 2 . 51 940 . 83N 263 . 09E E 2 . 37 1017 . 41N 283 . 91E E 2.70 1096.48N 305.54E E 2 . 58 1177. 96N 3.28 ? 03E 899.95 976.65 1055.99 1137.96 1222.47 S~.~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~P EXPLORATION MiLNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/95 DATE OF SURVEY: AUGUST, 1995 COMBINED MWD/GYRO SURVEY JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 FT. OPERATOR: BP EXPLOR3~TION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4000 3548.84 3499.65 4100 3595.07 3545.87 4200 3638.97 3589.77 4300 3680.06 3630.86 4400 3719.81 3670.61 61 46 N 15.59 E 2.78 1261.70N 351.35E 63 9 N 15.67 E 1.39 1347.09N 375.24E 64 45 N 15.46 E 1.60 1433.63N 399.34E 66 43 N 15.24 E 1.99 1521.53N 423.47E 66 25 N 14.89 E .45 1610.13N 447.32E 1309.37 1398.01 1487.82 1578.96 1670.71 4500 3760.36 3711.16 4600 3802.23 3753.03 4700 3844.00 3794.80 4800 3885.28 3836.08 4900 3925.91 3876.71 65 44 N 14.76 E .69 1698.50N 470.71E 64 45 N 14.78 E .99 1786.31N 493.86E 65 51 N 14.93 E 1.12 1874.12N 517.15E 65 22 N 14.92 E .48 1962.13N 540.61E 66 40 N 15.04 E 1.29 2050.39N 564.23E 1762.11 1852.92 1943.76 2034.84 2126.20 5000 3966.69 3917.49 5100 4007.04 3957.84 5200 4045.85 3996.65 5300 4084.91 4035.71 5400 4124.28 4075.08 65 11 N 15.13 E 1.47 2138.55N 587.99E 67 11 N 14.91 E 2.01 2226.90N 611.69E 67 7 N 14.97 E .10 2315.95N 635.45E 66 54 N 14.93 E .22 2404.89N 659.20E 66 43 N 14.92 E .17 2493.71N 682.88E 2217.49 2308.96 2401.11 2493.17 2585.08 5500 4163.97 4114.77 5600 4204.86 4155.66 5700 4246.51 4197.31 5800 4287.15 4237.95 5900 4327.13 4277.93 66 30 N 14.94 E .23 2582.40N 706.52E 65 13 N 14.87 E 1.27 2670.58N 730.00E 65 32 N 14.52 E .44 2758.52N 753.06E 66 30 N 14.59 E .96 2846.95N 776.02E 66 22 N 14.34 E .26 2935.71N 798.91E 2676.86 2768.11 2859.02 2950.38 3042.04 6000 4367.52 4318.32 6100 4407.25 4358.05 6200 4446.73 4397.53 6300 4487.53 4438.33 6400 4528.31 4479.11 65 58 N 14.11 E .44 3024.38N 821.39E 67 11 N 14.08 E 1.22 3113.38N 843.74E 66 17 N 14.10 E .91 3202.49N 866.11E 65 33 N 13.80 E .79 3291.09N 888.12E 66 19 N 13.90 E .78 3379.74N 909.97E 3133.52 3225.28 3317.16 3408.45 3499.75 6500 4568.73 4519.53 6600 4609.81 4560.61 6700 4651.59 4602.39 6800 4693.70 4644.50 6900 4735.15 4685.95 65 59 N 13.74 E .36 3468.56N 931.82E 65 30 N 13.91 E .51 3557.09N 953.61E 65 6 N 13.84 E .40 3645.29N 975.39E 65 5 N 13.41 E .39 3733.44N 996.76E 65 55 N 12.77 E 1.02 3822.08N 1017.37E 3591.21 3682.38 3773.23 3863.93 3954.91 7000 4776.38 4727.18 7100 4817.37 4768.17 7200 4856.21 4807.01 7230 4867.22 4818.02 7260 4878.08 4828.88 65 22 N 12.24 E .74 3911.02N 1037.10E 66 13 N 11.36 E 1.18 4000.30N 1055.75E 68 3 N 10.80 E 1.89 4090.72N 1073.45E 68 54 N 10.60 E 2.93 4118.14N 1078.63E 68 39 N 10.60 E .87 4145.63N 1083.77E 4045.97 4137.10 4229.09 4256.94 4284.85 7290 4889.02 4839.82 7320 4899.97 4850.77 7350 4911.01 4861.81 7380 4922.15 4872.95 7410 4933.32 4884.12 68 34 N 10.48 E .46 4173.09N 1088.88E 68 35 N 10.36 E .38 4200.56N 1093.94E 68 12 N 10.25 E 1.34 4228.00N 1098.93E 68 11 N 10.34 E .28 4255.41N 1103.90E 68 4 N 10.13 E .78 4282.81N 1108.85E 4312.73 4340.59 4368.42 4396.21 4423.98 S~RRY-SUN DRILLING SERVICES ANCHORAGE ALJkS KA PAGE ,P EXPLOR3tTION MILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31 /95 DATE OF SURVEY: AUGUST, 1995 COMBINED MWD/GYRO SURVEY JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 FT. OPER3tTOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7440 4944.54 4895.34 68 1 7470 4955.81 4906.61 67 50 7500 4967.17 4917.97 67 37 7530 4978.60 4929.40 67 35 7560 4990.06 4940.86 67 30 N 10.01 E .40 4310.21N 1113.72E N 9.95 E .66 4337.59N 1118.53E N 9.85 E .77 4364.94N 1123.31E N 9.55 E .93 4392.28N 1127.98E N 9.65 E .41 4419.62N 1132.60E 4451.73 4479.46 4507.14 4534.79 4562.42 7590 5001.60 4952.40 67 14 7620 5013.26 4964.06 67 0 7650 5024.95 4975.75 67 7 7680 5036.47 4987.27 67 41 7710 5047.87 4998.67 67 39 N 9.53 E .97 4446.92N 1137.22E N 9.52 E .77 4474.18N 1141.79E N 9.30 E .79 4501.44N 1146.31E N 9.11 E 1.96 4528.78N 1150.74E N 8.66 E 1.39 4556.20N 1155.03E 4590.02 4617.57 4645.10 4672.69 4700.32 7740 5059.31 5010.11 7770 5070.79 5021.59 7800 5082.21 5033.01 7830 5093.63 5044.43 7932 5133.06 5083.86 67 30 67 30 67 43 67 31 67 11 N 8.75 E .54 4583.61N 1159.22E N 8.95 E .62 4611.00N 1163.49E N 9.64 E 2.26 4638.37N 1167.97E N 10.37 E 2.35 4665.69N 1172.79E N 9.35 E .97 . 4758.85N 1188.98E 4727.92 4755.52 4783.15 4810.81 4905.09 8025 5169.31 5120.11 66 58 8121 5207.33 5158.13 66 31 8216 5244.26 5195.06 67 41 8308 5279.02 5229.82 67 50 8403 5314.65 5265.45 68 4 N 9.14 E .31 4843.50N 1202.76E N 8.78 E .59 4930.93N 1216.54E N 9.50 E 1.43 5017.28N 1230.44E N 9.37 E .21 5101.19N 1244.38E N 10.72 E 1.34 5187.87N 1259.74E 4990.53 5078.66 5165.77 5250.54 5338.32 8498 5350.17 5300.97 68 7 8593 5385.42 5336.22 68 13 8688 5421.58 5372.38 66 41 8783 5459.05 5409.85 66 58 8877 5495.68 5446.48 67 11 N 12.46 E 1.70 5274.43N 1277.49E N 12.07 E .40 5360.48N 1296.20E N 13.16 E 1.94 5445.51N 1315.22E N 12.84 E .42 5530.84N 1334.92E N 12.99 E .28 5615.30N 1354.29E 5426.59 5514.60 5601.70 5689.25 5775.88 8972 5533.32 5484.12 66 5 9066 5572.84 5523.64 64 17 9162 5614.45 5565.25 64 11 9257 5655.66 5606.46 64 18 9350 5696.23 5647.03 64 20 N 14.39 E 1.79 5700.00N 1374.92E N 15.16 E 2.05 5782.65N 1396.71E N 14.78 E .37 5865.96N 1418.99E N 14.74 E .13 5948.57N 1440.75E N 15.18 E .43 6030.11N 1462.54E 5863.04 5948.51 6034.75 6120.18 6204.57 9444 5736.98 5687.78 64 18 9538 5777.77 5728.57 64 9636 5820.66 5771.46 63 53 9731 5862.43 5813.23 63 52 9826 5904.63 5855.42 63 40 N 15.14 E .06 6111.96N 1484.72E N 14.91 E .37 6193.35N 1506.56E N 14.63 E .29 6278.23N 1528.94E N 15.62 E .94 6360.47N 1551.17E N 15.58 E .22 6442.98N 1574.21E 6289.35 6373.62 6461.40 6546.58 6632.22 9920 5946.30 5897.10 63 34 10016 5990.04 5940.84 62 0 10108 6034.33 5985.13 60 26 10203 6082.83 6033.63 58 30 10297 6133.09 6083.89 56 57 N 15.71 E .16 6523.91N 1596.87E N 15.48 E 1.65 6605.87N 1619.75E N 15.94 E 1.76 6683.51N 1641.59E N 15.75 E 2.03 6762.63N 1664.04E N 15.65 E 1.66 6839.25N 1685.58E 6716.25 6801.31 6881.93 6964.15 7043.71 S?'"RRY-SUN DRILLING SERVICES · ANCHORAGE ALASKA PAGE 4 ~ EXPLORATION ?!ILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/9 DATE OF SURVEY: AUGUST, 1995 COMBINED MWD/GYRO SURVEY JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10392 6185.73 6136.53 55 7 N 15.76 E 1.93 6914.49N 1706.74E 10486 6241.09 6191.89 53 14 N 15.72 E 2.00 6988.33N 1727.55E 10580 6298.38 6249.18 51 29 N 16.43 E 1.96 7059.73N 1748.12E 10675 6358.53 6309.33 49 45 N 15.60 E 1.95 7130.17N 1768.34E 10769 6420.44 6371.24 48 23 N 15.11 E 1.50 7199.03N 1787.25E 7121.85 7198.54 7272.80 7346.06 7417.45 10865 6485.56 6436.36 45 53 N 14.74 E 2.63 7266.83N 1805.33E 10958 6550.96 6501.76 44 13 N 14.84 E 1.81 7330.19N 1822.06E 11054 6620.86 6571.66 42 37 N 15.30 E 1.68 7394.08N 1839.26E 11149 6691.49 6642.29 41 28 N 15.22 E 1.21 7455.55N 1856.03E 11244 6763.56 6714.36 40 1 N 16.51 E 1.77 7515.28N 1872.99E 7487.62 7553.15 7619.30 7683.01 7745.08 11338 6836.41 6787.21 38 30 N 17.70 E 1.79 7572.20N 1890.50E 11434 6912.36 6863.16 36 28 N 18.53 E 2.20 7627.57N 1908.60E 11528 6987.89 6938.69 36 15 N 18.85 E .31 7680.24N 1926.42E 11623 7064.37 7015.17 36 40 N 18.87 E .44 7733.72N 1944.69E 11717 7139.50 7090.30 36 39 N 18.63 E .15 7786.68N 1962.67E 7804.56 7862.68 7918.12 7974.44 8030.21 11808 7213.34 7164.14 36 9 N 18.43 E .56 7838.32N 1979.97E 11903 7290.20 7241.00 35 44 N 17.85 E .57 7891.28N 1997.33E 12010 7376.94 7327.74 35 11 N 17.92 E .52 7950.09N 2016.30E 8084.51 8140.12 8201.79 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8201.79 FEET AT NORTH 14 DEG. 13 MIN. EAST AT MD = 12010 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 14.26 DEG. COMBINED SSDS MWD DATA AND GYRO-DATA GYROSCOPIC DATA 12,120' IS EXTRAPOLATED SURVEY AT TD ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3P EXPLORATION MILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/95 DATE OF SURVEY: AUGUST, 1995 JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH FT. TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TV]D VERTICAL DIFFERENCE CORRECTION 0 .00 -49.20 .00 N .00 E 1000 999.65 950.45 21.55 N 8.44 E 2000 1989.80 1940.60 148.41 N 46.97 E 3000 2895.10 2845.90 542.49 N 153.02 E 4000 3548.84 3499.65 1261.70 N 351.35 E .00 .35 .35 10.20 9.85 104.90 94.70 451.16 346.25 5000 3966.69 3917.49 2138.55 N 587.99 E 6000 4367.52 4318.32 3024.38 N 821.39 E 7000 4776.38 4727.18 3911.02 N 1037.10 E 8000 5159.31 5110.11 4820.27 N 1199.02 E 9000 5544.49 5495.29 5724.40 N 1381.18 E 1033.31 582.16 1632.48 599.17 2223.62 591.14 2840.69 617.07 3455.51 614.82 10000 5982.46 5933.26 6592.13 N 1615.94 E 11000 6580.92 6531.72 7358.38 N 1829.53 E 12000 7368.53 7319.33 7944.44 N 2014.48 E 12010 7376.94 7327.74 7950.09 N 2016.30 E 4017.54 562.03 4419.08 401.54 4631.47 212.40 4633.35 1.88 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ERRY-SUN DRILLING SERVICES ANCHOR_AGE ALAS KA PAGE BP EXPLORATION MILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/95 INTERPOLATED VALUES DATE OF SURVEY: AUGUST, 1995 JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 FT. OPERATOR: BP EXPLORATION FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 0 .00 -49 49 49.20 149 149.20 100 249 249.20 200 349 349.20 300 449 449.20 400 549 549.20 500 649 649.20 600 749 749.20 700 849 849.20 800 .20 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 N .00 E .00 .02 N .01 E .00 .00 .45 N .23 E .00 .00 2.25 N .94 E .02 .02 3.62 N 2.06 E .04 .02 5.28 N 2.21 E 7.68 N 2.64 E 10.35 N 3.32 E 13.20 N 4.19 E 16.39 N 5.54 E .05 .08 .12 .16 .22 .01 .03 .04 .04 .06 949 949.20 900 1049 1049.20 1000 1149 1149.20 1100 1250 1249.20 1200 1350 1349.20 1300 .00 .00 .00 .00 .00 19.25 N 7.60 E 23.96 N 9.26 E 29.92 N 11.14 E 38.83 N 14.36 E 49.33 N 16.89 E .29 .41 .61 1.06 1.65 .06 .13 .20 .45 .58 1451 1449.20 1400 1552 1549.20 1500 1653 1649.20 1600 1755 1749.20 1700 1856 1849.20 1800 .00 .00 .00 .00 .00 61.18 N 20.85 E 74.82 N 25.82 E 89.15 N 30.61 E 104.92 N 34.58 E 121.03 N 39.46 E 2.43 3.48 4.61 5.93 7.34 .78 1.05 1.14 1.31 1.41 1958 1949.20 1900 2061 2049.20 2000 2164 2149.20 2100 2269 2249.20 2200 2376 2349.20 2300 .00 .00 .00 .00 .00 139.43 N 44.69 E 9 161.94 N 50.39 E 11 188.25 N 56.98 E 15 219.16 N 65.20 E 20 254.92 N 75.84 E 27 .16 .82 .44 .45 .20 .82 .67 .62 .01 .75 2485 2449.20 2595 2549.20 2708 2649.20 2823 2749.20 2943 2849.20 3068 2949.20 3199 3049.20 3334 3149.20 3477 3249.20 3634 3349.20 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 295.68 N 88.14 E 341.13 N 101.13 E 391.12 N 113.63 E 446.28 N 127.99 E 509.96 N 144.68 E 35.91 46.54 59.05 74.18 93.93 8.71 10.63 12.51 15.13 19.75 583.33 N 163.69 E 119.43 25.50 664.84 N 185.24 E 150.24 30.81 752.51 N 209.52 E 185.45 35.21 851.01 N 238.13 E 228.74 43.29 966.50 N 270.04 E 284.85 56.11 S~_~RRY-SUN DRILLING SERVICES ANCHOR3~GE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/95 DATE OF SURVEY: AUGUST, 1995 JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 FT. OPERATOR: BP EXPLORg~TION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3805 3449.20 3400.00 4000 3549.20 3500.00 4223 3649.20 3600.00 4472 3749.20 3700.00 4712 3849.20 3800.00 1101.17 N 306.83 E 1262.33 N 351.52 E 1454.52 N 405.12 E 1674.56 N 464.40 E 1885.32 N 520.14 E 356.62 71.77 451.55 94.93 574.77 123.22 723.65 148.88 863.50 139.85 4958 3949.20 3900.00 5208 4049.20 4000.00 5462 4149.20 4100.00 5706 4249.20 4200.00 5954 4349.20 4300.00 2101.96 N 578.09 E 2323.61 N 637.50 E 2549.58 N 697.77 E 2764.25 N 754.54 E 2984.47 N 811.35 E 1009.06 145.56 1159.41 150.35 1313.76 154.35 1457.30 143.54 1605.75 148.45 6206 4449.20 4400.00 6451 4549.20 4500.00 6694 4649.20 4600.00 6934 4749.20 4700.00 7181 4849.20 4800.00 3207.94 N 867.48 E 3425.91 N 921.38 E 3640.29 N 974.16 E 3852.76 N 1024.32 E 4073.62 N 1070.19 E 1756.94 151.19 1902.74 145.80 2045.12 142.38 2185.25 140.14 2332.04 146.79 7452 4949.20 4900.00 7713 5049.20 5000.00 7974 5149.20 5100.00 8229 5249.20 5200.00 8496 5349.20 5300.00 4321.56 N 1115.72 E 4559.39 N 1155.51 E 4796.73 N 1195.21 E 5029.15 N 1232.43 E 5272.08 N 1276.97 E 2503.24 171.20 2664.30 161.06 2824.89 160.59 2980.65 155.76 3147.15 166.50 8758 5449.20 5400.00 9011 5549.20 5500.00 9242 5649.20 5600.00 9473 5749.20 5700.00 9701 5849.20 5800.00 5508.25 N 1329.77 E 5734.66 N 1383.81 E 5935.58 N 1437.34 E 6136.48 N 1491.35 E 6334.49 N 1543.91 E 3309.02 161.87 3462.39 153.37 3593.13 130.73 3723.94 130.81 3851.91 127.97 9926 5949.20 5900.00 10138 6049.20 6000.00 10327 6149.20 6100.00 10500 6249.20 6200.00 10660 6349.20 6300.00 6529.53 N 1598.45 E 6708.71 N 1648.78 E 6863.10 N 1692.26 E 6998.79 N 1730.49 E 7119.56 N 1765.38 E 3977.78 125.87 4089.10 111.32 4178.15 89.04 4251.02 72.88 4311.69 60.67 10813 6449.20 6400.00 10955 6549.20 6500.00 11092 6649.20 6600.00 11225 6749.20 6700.00 11355 6849.20 6800.00 7230.20 N 7328.54 N 7419.24 N 7503.72 N 7581.90 N 1795.66 E 1821.62 E 1846.14 E 1869.57 E 1893.59 E 4363.88 52.19 4406.53 42.65 4443.76 37.23 4476.76 33.00 4505.96 29.20 S~_.RRY-SUN DRILLING SERVICES A/~CHORAGE ALAS ICA PAGE BP EXPLOR3~TION MILNE POINT / MPF-61 500292258200 NORTH SLOPE COMPUTATION DATE: 8/31/95 DATE OF SURVEY: AUGUST, 1995 JOB NUMBER: AK-MM-950839 KELLY BUSHING ELEV. = 49.20 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 11480 6949.20 6900.00 7653.39 N 1917.26 E 4531.16 25.20 11604 7049.20 7000.00 7723.03 N 1941.03 E 4555.32 24.16 11729 7149.20 7100.00 7793.52 N 1964.97 E 4579.99 24.67 11853 7249.20 7200.00 7863.16 N 1988.24 E 4604.05 24.06 11976 7349.20 7300.00 7931.48 N 2010.29 E 4627.15 23.10 12000 7368.53 7319.33 7944.44 N 2014.48 E 4631.47 4.32 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS y oldata B.P. EXPLORATION F PAD WELL NUMBER MPF-61 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Of 5" drillpipe Survey date · 25 August, 1995 Job number' AK0895G288 SR288.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 September 12, 1995 Ms. Sharmaine V. Copeland B.P. Exploration (Alaska) inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re' F Pad, Well # MPF-61, Milne Point Field, Alaska Enclosed please find one (1) original and five copies (5) of the completed survey of Well #MPF-61 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyrc /data CONTENTS JOB NUMBER :AK0895G288 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR288.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR288.DOC gyro/data DISCUSSION JOB NUMBER: AK0895G288 Tool 725 was run in MPF-61 on ATLAS 5/16" Wireline inside 5 inch drillpipe. The survey was run without problems. SR288.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0895G288 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been Checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR288.DOC gyro/data 2. SURVEY DETAILS SR288.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0895G288 CLIENT: B.P. EXPLORATION RIG: LOCATION· NABORS 22E MILNE POINT FIELD WELL: MPF-61 LATITUDE: 70.505 N LONGITUDE: 149.5 W SURVEY DATE: 25-August, 1995 SURVEY TYPE : MULTISHOT IN 5" drillpipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 46.1 feet 7830' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 100' from 100 to 7500 feet. 30' from 7500 to 7830 feet. UTM CO-ORDINATES: TARGET DIRECTION: 125.310 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR288.DOC gyro/data 3. OUTRUN SURVEY LISTING SR288.DOC A Gyro da t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G288 Run Date: 25-Aug-95 01:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 46.1 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction- 14.260 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, Location: F PAD, MILNE POINT FIELD, Job Number: AK0895G288 5" DRILLPIPE ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet' deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -46.1 0.00 0.0 0.0 MEASURED DEPTHS REFERENCED TO.NABORS 22E R.K.B. HEIGHT OF 46.1 FEET. 0.0 - 7830.0 FEET; GYRODATA GYRO SURVEY RUN IN 5 INCH DRILLPIPE. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .25 28.89 100.0 .2 53.9 .25 .2 28.9 200.0 1.17 20.53 200.0 1.4 153.9 .92 1.5 23.0 300.0 1.02 42.22 300.0 3.2 253.9 .44 3.3 27.3 400.0 .94 2.44 400.0 4.8 353.9 .67 4.9 25.9 500.0 1.42 10.19 499.9 6.9 453.8 .50 6.9 20.4 600.0 1.58 14.36 599.9 9.5 553.8 .19 9.5 18.2 700.0 1.70 16.79 699.9 12.3 653.8 .14 12.4 17.6 800.0 2.00 22.45 799.8 15.5 753.7 .35 15.6 18.1 900.0 1.99 37.77 899.8 18.9 853.7 .53 19.0 20.2 1000.0 2.88 18.88 999.7 23.0 953.6 1.19 23.1 21.4 1100.0 3.51 17.24 1099.5 28.5 1053.4 .63 28.7 20.7 1200.0 5.48 20.39 1199.2 36.3 1153.1 1.99 36.5 20.4 1300.0 6.15 12.90 1298.7 46.4 1252.6 1.01 46.6 19.5 1400.0 7.10 18.55 1398.0 58.0 1351.9 1.15 58.1 18.8 1500.0 8.29 20.18 1497.1 71.3 1451.0 1.20 71.5 18.9 1600.0 8.56 18.80 1596.0 85.9 1549.9 .34 86.2 19.0 1700.0 9.24 13.76 1694.8 101.3 1648.7 1.04 101.6 18.6 1800.0 9.47 17.00 1793.5 117.6 1747.4 .57 117.9 18.2 1900.0 10.64 16.05 1892.0 135.0 1845.9 1.18 135.3 17.9 2000.0 12.91 14.22 1989.8 155.4 1943.7 2.30 155.7 17.6 .19 N .11 E 1.34 N .57 E 2.95 N 1.52 E 4.43 N 2.15 E 6.47 N 2.41 E 9.02 N 2.97 E 11.77 N 3.74 E 14.81 N 4.83 E 17.79.N 6.56 E 21.55 N 8.44 E 26.85 N 10.16 E 34.25 N 12.74 i ~.' 43.95 N 15.60 E 55.04 N 18.76 E 67.66 N 23.21 E 81.47 N 28.10 E 96.32 N 32.41 E 111.99 N 36.72 E 128.73 N 41.68 E 148.44 N 46.98 E A Gyro da t a D i r e c t i o na I Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, Location: F PAD, MILNE POINT FIELD, Job Number: AK0895G288 5" DRILLPIPE ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 14.59 13.95 2087.0 2200.0 17.47 14.47 2183.1 2300.0 19.85 16.60 2277.8 2400.0 22.33 16.49 2371.1 2500.0 24.60 17.38 2462.8 179.2 2040.9 1.69 179.4 17.1 206.8 2137.0 2.88 207.0 16.7 238.8 2231.7 2.48 239.0 16.6 274.8 2325.0 2.48 275.0 16.6 314.5 2416.7 2.30 314.8 16.6 171.49 N 52.76 E 198.26 N 59.55 E 229.07 N 68.15 ' ~ 263.56 N 78.40 E" 301.65 N 90.01 E 2600.0 26.31 14.05 2553.1 2700.0 28.15 14.02 2642.0 2800.0 30.41 14.90 2729.3 2900.0 34.00 14.67 2813.9 3000.0 37.08 14.28 2895.2 357.5 2507.0 2.23 357.8 16.5 403.2 2595.9 1.83 403.5 16.2 452.1 2683.2 2.30 452.4 16.0 505.4 2767.8 3.60 505.6 15.9 563.6 2849.1 3.08 563.7 15.8 343.02 N 101.61 E 387.41 N 112.71 E 434.76 N 124.93 E 486.29 N 138.52 E 542.57 N 153.05 E 3100.0 39.60 15.27 2973.6 3200.0 41.29 14.18 3049...7 3300.0 42.90 16.23 3124.0 3400.0 45.18 16.33 3195.8 3500.0 48.89 15.79 3264.0 625.6 2927.5 2.59 625.8 15.7 690.4 3003.6 1.83 690.6 15.6 757.4 3077.9 2.12 757.6 15.5 826.9 3149.7 2.28 827.1 15.6 900.0 3217.9 3.73 900.3 15.6 602.54 N 168.88 E 665.27 N 185.36 E 729.95 N 202.95 E 796.67 N 222.44 E 866.98 N 242.68 E 3600.0 51.35 15.14 3328.1 3700.0 53.72 15.28 3388.9 3800.0 56.42 15.32 3446.2 3900.0 58.99 15.53 3499.6 4000.0 61.77 15.59 3549.0 976.8 3282.0 2.51 977.0 15.6 1056.1 3342.8 2.37 1056.4 15.6 1138.1 3400.1 2.70 1138.4 15.6 1222.6 3453.5 2.58 1222.9 15.6 1309.5 3502.9 2.77 1309.8 15.6 940.93 N 263.13 F 1017.52 N 283.95 L 1096.59 N 305.57 E 1178.07 N 328.05 E 1261.81 N 351.37 E 4100.0 63.16 15.67 3595.3 4200.0 64.75 15.46 3639.2 4300.0 66.73 15.24 3680.2 4400.0 66.42 14.89 3720.0 4500.0 65.74 14.76 3760.5 1398.1 3549.2 1487.9 3593.1 1579.1 3634.1 1670.8 3673.9 1762.2 3714.4 1.39 1398.5 15.6 1.60 1488.3 15.6 2.00 1579.5 15.6 .45 1671.2 15.5 .70 1762.7 15.5 1347.20 N 1433.75 N 1521.66 N 1610.26 N 1698.63 N 375.26 E 399.36 E 423.50 E 447.35 E 470.74 E A Gyro da t a D i r e c t z o na 1 Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, Location: F PAD, MILNE POINT FIELD, Job Number: AK0895G288 5" DRILLPIPE ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 64.75 14.78 3802.4 4700.0 65.86 14.93 3844.2 4800.0 65.38 14.92 3885.5 4900.0 66.67 15.04 3926.1 5000.0 65.20 15.13 3966.9 1853.1 3756.3 1943.9 3798.1 2035.0 3839.4 2126.3 3880.0 2217.6 3920.8 .99 1853.5 15.5 1.12 1944.3 15.4 .48 2035.4 15.4 1.29 2126.8 15.4 1.47 2218.1 15.4 1786.44 N 1874.26 N 1962.27 N 2050.54 N 2138.69 N 493.89 E 517.18 E 540.64 564 25 E ~ 588.01 E 5100.0 67.20 14.91 4007.2 5200.0 67.12 14.97 4046.1 5300.0 66.90 14.93 4085.1 5400.0 66.73 14.92 4124.5 5500.0 66.50 14.94 4164.2 2309.1 3961.1 2401.3 4000.0 2493.3 4039.0 2585.2 4078.4 2677.0 4118.1 2.01 2309.5 15.4 .09 2401.7 15.3 .23 2493.8 15.3 .17 2585.7 15.3 .23 2677.5 15.3 2227.06 N 2316.10 N 2405.04 N 2493.87 N 2582.56 N 611.72 E 635.48 E 659.24 E 682.91 E 706.56 E 5600.0 65.23 14.87 4205.0 5700.0 65.54 14.52 4246.7 5800.0 66.50 14.59 4287.3 5900.0 66.37 14.34 4327.3 6000.0 65.98 14.11 4367.7 2768.3 4158.9 2859.2 4200.6 2950.6 4241.2 3042.2 4281.2 3133.7 4321.6 1.28 2768.7 15.3 .45 2859.6 15.3 .95 2951.0 15.2 .26 3042.6 15.2 .45 3134.1 15.2 2670.74 N 2758.69 N 2847.12 N 2935.88 N 3024.55 N 730.03 E 753.09 E 776.05 E 798.95 E 821.43 E 6100.0 67.20 14.08 4407.4 6200.0 66.29 14.10 4446.9 6300.0 65.55 13.80 4487.7 6400.0 66.32 13.90 4528.5 6500.0 65.99 13.74 4568.9 3225.5 4361.3 3317.3 4400.8 3408.6 4441.6 3499.9 4482.4 3591.4 4522.8 1.22 3225.9 15.2 .91 3317.7 15.1 .79 3409.0 15.1 .78 3500.3 15.1 .36 3591.7 15.0 3113.55 N 3202.66 N 3291.27 N 3379.92 N 3468.74 N 843.77 E 866.14 1 888.15 E 910.00 E 931.84 E 6600.0 65.50 13.91 4610.0 6700.0 65.11 13.84 4651.8 6800.0 65.09 13.41 4693.9 6900.0 65.93 12.77 4735.3 7000.0 65.37 12.24 4776.6 3682.6 4563.9 3773.4 4605.7 3864.1 4647.8 3955.1 4689.2 4046.2 4730.5 .51 3682.9 15.0 .39 3773.7 15.0 .39 3864.4 14.9 1.02 3955.4 14.9 .74 4046.4 14.9 3557.27 N 3645.48 N 3733.63 N 3822.27 N 3911.21 N 953.63 E 975.41 E 996.78 E 1017.39 E 1037.12 E A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, Location: F PAD, MILNE POINT FIELD, Job Number: AK0895G288 5" DRILLPIPE ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7100.0 66.23 11.36 4817.6 7200.0 68.05 10.80 4856.4 7230.0 68.91 10.60 4867.4 7260.0 68.65 10.60 4878.3 7290.0 68.57 10.48 4889.2 4137.3 4771.5 4229.3 4810.3 4257.1 4821'.3 4285.1 4832.2 4312.9 4843.1 1.18 4137.5 14.8 1.90 4229.4 14.7 2.94 4257.3 14.7 .86 4285.2 14.7 .47 4313.0 14.6 4000.49 N 4090.92 N 4118.34 N 4145.83 N 4173.29 N 1055.77 E 1073.48 E 1078.66 r ,, 1083.80 L ? 1088.91 E 7320.0 68.60 10.36 4900.2 7350.0 68.21 10.25 4911.2 7380.0 68.20 10.34 4922.3 7410.0 68.07 10.13 4933.5 7440.0 68.03 10.01 4944.7 4340.8 4854.1 4368.6 4865.1 4396.4 4876.2 4424.2 4887.4 4451.9 4898.6 .37 4340.9 14.6 1.33 4368.7 14.6 .28 4396.5 14.5 .80 4424.2 14.5 .38 4452'.0 14.5 4200.76 N 4228.20 N 4255.61 N 4283.01 N 4310.40 N 1093.96 E 1098.96 E 1103.94 E 1108.88 E 1113.75 E 7470.0 67.84 9.95 4956.0 7500.0 67.63 9.85 4967.4 7530.0 67.59 9.55 4978.8 7560.0 67.51 9.65 4990.2 7590.0 67.24 9.53 5001.8 4479.7 4909.9 4507.3 4921.3 4535.0 4932.7 4562.6 4944.1 4590.2 4955.7 .67 4479.7 14.5 .77 4507.4 14.4 .94 4535.0 14.4 .40 4562.6 14.4 .98 4590.2 14.3 4337.79 N 4365.14 N 4392.48 N 4419.82 N 4447.12 N 1118.57 E 1123.34 E 1128.01 E 1132.64 E 1137.25 E 7620.0 67.01 9.52 5013.4 7650.0 67.13 9.30 5025.1 7680.0 67.69 9.11 5036.7 7710.0 67.65 8.66 5048.1 7740.0 67.51 8.75 5059.5 4617.8 4967.3 4645.3 4979.0 4672.9 4990.6 4700.5 5002.0 4728.1 5013.4 .76 4617.8 14.3 · 77 4645.3 14.3 1.96 4672.9 14.3 1.42 4700.5 14.2 · 55 4728.1 14.2 4474.38 N 4501.64 N 4528.98 N 4556.39 N 4583 . 81 N 1141.82 E 1150.77 E 1155.06 E 1159.26 E 7770.0 67.58 8.95 5071.0 7800.0 67.73 9.64 5082.4 7830.0 67.53 10.37 5093.8 4755.7 5024.9 4783.4 5036.3 4811.0 5047.7 .65 4755.7 14.2 2.20 4783.4 14.1 2.34 4811.1 14.1 4611.20 N 4638.59 N 4665.91 N 1163.52 E 1168.00 E 1172.83 E Final Station Closure: Distance: 4811.05 ft Az: 14.11 deg. A Gyro da t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G288SS Run Date: 25-Aug-95 01:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 46.1 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 14.260 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i o n a I Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G288SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. -46.1 0.00 0.00 0.0 0.0 0.00 0.0 0.0 MEASURED DEPTHS REFERENCED TO NABORS 22E R.K.B. HEIGHT OF 46.1 FEET. 0.0 - 7830.0 FEET; GYRODATA GYRO SURVEY RUN IN 5 INCH DRILLPIPE. Page HORIZONTAL COORDINATES feet 0.0 N 0.0 E 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 100.0 .67 25.03 146.1' .8 .56 200.0 1.10 30.53 246.1 2.3 .70 300.0 .98 23.87 346.1 4.0 .55 400.0 1.16 6.02 446.1 5.8 .59 500.0 1.49 12.11 546.1 8.1 .36 00.0 1.63 15.48 646.1 10.8 .17 00.0 1.84 19.41 746.1 13.8 .24 00.0 2.00 29.54 846.1 17.1 .44 00.0 2.41 29.01 946.1 20.8 .84 00.0 3.17 18.12 1046.1 25.6 .93 00.0 4.43 18.71 1146.1 32.2 1.27 00.0 5.80 16.86 1246.1 41.1 1.53 00.0 6.61 15.60 1346.1 51.9 1.08 00.0 7.68 19.34 1446.1 64.4 1.18 00.0 8.42 19.50 1546.1 78.5 .78 00.0 8.91 16.24 1646.1 93.7 .69 00.0 9.36 15.44 1746.1 109.8 .80 00.0 10.10 16.49 1846.1 126.9 .90 00.0 11.90 15.04 1946.1 146.3 1.80 00.0 13.89 14.07 2046.1 169.2 1.94 1.5 26.2 3.3 25.0 4.9 26.7 6.9 23.4 9.5 19.4 12.4 17.9 15.6 17.8 19.0 19.1 23 .1 20.8 28.7 21.1 36.5 20.6 46.6 20.0 58.1 19.2 71.5 18.9 86.2 19.0 101.6 18.8 117.9 18.4 135.3 18.0 155.7 17.7 179.4 17.3 .7 N .3 E 2.1 N 1.0 E 3.6 N 1.8 E 5.4 N 2.3 E 7.6 N 2.7 E 10.3 N 3.3 E 13.2 N 4.2 E 16.2 N 5.6 E 19.5 N 7.4 E 24.0 N 9.2 E 30.3 N 11.4 E 38.8 N 14.1 E 49.2 N 17.1 E 61.2 N 20.9 E 74.5 N 25.6 E 89.0 N 30.3 E 104.5 N 34.6 E 120.9 N 39.4 E 139.6 N 44.6 E 161.8 N 50.3 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G288SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 16.36 14.27 2146.1 196.2 2200.0 19.05 15.89 2246.1 228.1 2300.0 21.67 16.52 2346.1 265.1 2400.0 24.19 17.22 2446.1 307.3 2500.0 26.18 14.31 2546.1. 354.1 2.42 2.61 2.48 2.33 2.24 207.0 16.9 239.0 16.6 275.0 16.6 314.8 16.6 357.8 16.5 188.0 N 56.9 E 218.8 N 65.3 E 254.3 N 75.7 E 294.7 N 87.9 E 339.8 N 100.7 E 2600.0 28.25 14.06 2646.1 405.5 2700 . 0 31 . 13 14 . 85 2746 . 1 462 . 8 2800.0 . 35.22 14.52 2846.1 528.5 2900 . 0 38 . 71 14 . 92 2946 . 1 603 . 8 3000.0 41.21 14 . 23 3046.1 687.3 1.86 2.56 3.39 2.76 1.87 452.4 16.2 505.6 16.0 563.7 15.8 625.8 15.7 690.6 15.6 389.6 N 113.3 E 445.0 N 127.6 E 508.6 N 144.3 E 581.5 N 163.3 E 662.3 N 184.6 E 3100.0 43.60 16.26 3146.1 778.9 3200.0 47.91 15.93 3246.1 880.9 3300.0 52.05 15.18 3346.1 1000.2 3400.0 56.42 15.32 3446.1 1138.0 3500.0 61.60 15.59 3546.1 1304.4 2.17 3.35 2.47 2.70 2.76 827.1 15.6 900.3 15.6 1056.4 15.6 1138.4 15.6 1309.8 15.6 750.5 N 209.0 E 848.5 N 237.4 E 963.6 N 269.3 E 1096.5 N 305.5 E 1256.9 N 350.0 E 3600.0 65.08 15.43 3646.1 1503.3 3700.0 65.98 14.80 3746.1 1729.7 3800.0 65.84 14.93 3846.1 1948.1 3900.0 65.95 15.08 3946.1 2171.1 4000.0 67.12 14.97 4046.1 2401.4 1.67 .61 1.09 1.38 .09 1579.5 15.6 1762.7 15.5 2035.4 15.4 2218.1 15.4 2493.8 15.3 1448.6 N 403.4 E 1667.2 N 462.4 E 1878.3 N 518.3 E 2093.8 N 575.9 E 2316.2 N 635.5 E 4100.0 66.61 14.93 4146.1 2635.3 4200.0 65.54 14.52 4246.1 2857.9 4300.0 66.19 14.23 4346.1 3084.8 4400.0 66.31 14.10 4446.1 3315.4 4500.0 66.18 13.83 4546.1 3539.7 .20 .46 .35 .92 .59 2677.5 15.3 2859.6 15.3 3134.1 15.2 3317.7 15.1 3591.7 15.1 2542.2 N 695.8 E 2757.4 N 752.8 E 2977.1 N 809.4 E 3200.8 N 865.7 E 3418.6 N 919.5 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPF-61, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G288SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4600.0 65.17 13.85 4646.1 3761.1 .41 4700.0 65.78 12.63 4746.1 3978.9 .95 4800.0 67.57 10.95 4846.1 4204.9 1.71 4900.0 68.01 10.00 4946.1 4455.3 .41 5000.0 67.66 8.74 5046.1 4695.8 1.51 3773.7 15.0 4046.4 14.9 4229.4 14.7 4479.7 14.5 4700.5 14.2 3633.5 N 972.5 E 3845.5 N 1022.5 E 4066.9 N 1068,8 E 4313.7 N 1114.3 E 4551.7 N 1154.3 E 5047.7 67.53 10.37 5093.8 4811.0 2.34 4811.1 14.1 4665.9 N 1172.8 E Final Station Closure: Distance: 4811.05 ft Az: 14.11 deg. gyro/data 4. QUALITY CONTROL SR288.DOC Quality Control Comparisons B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPP-61, Location: F PAD, MILNE POINT, ALASKA 9 5/8" Job Number : AK0895G288 / AK0895G288 / Comparison Depth Inc Inc Delta 500.© 1.10 1.42 -.322 1000.0 2.83 2.88 -.054 1500.0 8.58 8.29 .293 2000.0 12.64 12.91 -.272 2500.0 24.50 24.60 -.099 3000.0 36.93 37.08 -.149 3400.0 44.91 45.18 -.266 7830.0 67.50 67.53 -.029 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.1630 deg. Average Azimuth Difference = .53399 deg. Az 13.80 14.48 20.18 15.09 16.55 15.12 17.26 11.24 Az 10.19 18.88 20.18 14.22 17.38 14.28 16.33 10.37 Delta 3.614 -4.395 -.008 .862 -.827 .836 .931 .868 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0895G288 TOOL NUMBER: 725 MAXIMUM GYRO TEMPERATURE: 74.31 C MAXIMUM AMBIENT TEMPERATURE: 39.8 C MAXIMUM INCLINATION: 68.88 AVERAGE AZIMUTH: 14.3627 WIRELINE REZERO VALUE: N/A REZERO ERROR/K: N/A CALIBRATION USED FOR FIELD SURVEY: 1224 CALIBRATION USED FOR FINAL SURVEY: 1224 PRE JOB MASS BALANCE OFFSET CHECK: -.25 POST JOB MASS BALANCE OFFSET CHECK] · CONDITION OF SHOCK WATCHES -.38 USED -.38 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M,D. INC AZIMUTH TVD FIELD SURVEY 7830.0 67.53 10.37 5093.80 FINAL SURVEY 7830.0 67.53 10.37 5093.80 NORTHING 4665.9O N 4665.91 N EASTING 1172.84 E 1172.83 E SR288.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0895G288 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft I 2 3 4 5 3400 45.18 45.18 45.18 45.18 45.18 AZIMUTH M.D. ft 1 2 3 4 5 3400 16.23 16.29 16.27 16.23 16.32 SR288.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR288.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0895G288 8/25/95 1800 1930 2300 0130 0230 0430 0600 0700 LEAVE ATLAS ARRIVED AT LOCATION SPOT UNIT, MAKE UP TOOL RUNNING IN HOLE 7830' SURVEYING OUT LAY DOWN AND BREAK DOWN TOOL PROCESS SURVEY. RETURN TO ATLAS. SR288.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0895G288 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 725 GYRO SECTION A0065 DATA SECTION C0031 POWER SECTION C0006 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0085 A0029 A0035 BACKUP TOOL No. 722 GYRO SECTION A0051 DATA SECTION C0023 POWER SECTION C0022 COMPUTER POWER SUPPLY PRINTER INTERFACE A0213 A0055 A0079 A0071 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: 17.5 feet MAXIMUM O.D.: 2.5 INCHES TOTAL WEIGHT OF TOOL: 240Lbs SR288.DOC HOWAPD OKLAND Art's. ~!.~':IA OIL + GAS CONSERVATION 3001 ~'?k,'.~UPir-iE DRIVE AK~ Dates 3 June 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~/ PLS FINAL BL+RF ~.~ PFC/PERF FINAL BL+RF ~1 PFC/PERF FINAL BL+RF C~IPFC/PERF FINAL BL+RF ECC No. Run # I 6480.03 Run $ i Run $ i 6480.04 Run $ i 6485.04 Please zign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Rec~i,r~d by: . Date: JUN 2 1 1995 Alsska Oil & Gas Cons. Commission ~¢hore.fle sper r -sur, CIF! I CCI N (3 SEFIVI r"~ S WELL LOG TRANSMITTAL To: State of Alaska March 07, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-61 AK-MM-950839 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-61: 1 LDWG formatted LIS tape with verification listing. API~: 50-029-22582-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Ci I~! I I_1_ I IM (3 S I~ I~! U' I I-- I:::: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Dr. Anchorage, Alaska 99501 ,2,.. ;, ' , MWD Formation Evaluation Logs - MP F-61, AK-MM-950839 February 07, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs: 2"x 5" MD Neutron and Density Logs: 2"x 5" TVD Neutron and Density Logs: · / ' 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT ~ Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 November 1995 Transmittal of Data Sent by: US MAIL Dear Sir/Madam, Enclosed, please find the data as described below: MPL-16 ~ ,.- DESCRIPTION GR/CCL FINAL BL & RF Run # 1 PLS FINAL BL & RF Run # 1 PFC/PERF FINAL BL&RF .Run # 1 PLS STATIC FIN BL&RF Run # 1 PFC/PERF FINAL BL&RF Run # 1 PFC/PERF FINAL BL&RF Run # 1 ECC No. 6453.01 6478.02 6480.02 6485.01 ~Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 . Or FAX to (907) 563-7803 Received ~/~ ~/~J Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 12 October 1995 Transmittal of Data ECC #: 6480.01 Sent by: HAND CARRY Data: PFC/PERF Dear Sir/Madam, Reference: MPF-61 MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL&RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 /~ Anchorage, AK 99518 ;% ~ ~ Or.VAX to (907) 563-7803 ~<~/, ~ ~ ~---~ f,'"/ --' ....... - · "( ~- ~.t~o,~. ~,:;~ ...,., , i. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE _ AK, 99501. Date: 22 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION LDWG TAPE+LIS i LDWG TAPE+LIS Run ~ 1 Run # I E'CC No. 6478.00 6480.00 .............. _ .. Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: VOr FAX to (907) 563-7803 RECEIVED SEP 2 8 19 5 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS ,' CON'SERYATION' COMMISSION · TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 3, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-61 BP Exploration (Alaska), Inc. Permit No 95-117 Surf Loc 2077'NSL, 2537'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc 4820'NSL, 469'WEL, Sec. 31, T14N, R10E, UM Dear Mr Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. . Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I-Illb. Type of well. ExploratoryF-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 46 feet Milne Point/Kuparuk River 3. Address 6. Property Designation ,'~d.. Sands P. O. Box 196612, Anchorac/e, Alaska 99519-6612 ADL ~ .Z, ..¢'..¢'~/ ~' 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2077' NSL, 2537' WEL, SEC 06, T13N, RIOE Milne Point Unit At top of productive interval i8. Well number Number 4600' NSL, 526' WEL, SEC 31, T14N, RIOE MPF-61 2S100302630-277 At total depth 9. Approximate spud date Amount 4820' NSL, 469' WEL, SEC 31, T14N, RIOE 08-10-95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(MD~ndTVD) property line ADL 355018 4676 feet No Close Approach feet 5760 12145MD/7460 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^AC 25.035 (e)(2)) Kickoff depth 965 feet Maximum hole angle 6~ o Maximum surface 2828 psig At total depth (TVD) 7376'/3536 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NTSOLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 6573' 31' 31' 6604' 4576' 1487 sx PF 'E', 250 sx 'G' 8-1/2" 7" 26# L-80 Btm 12115' 30' 30' 12145' 7460' 225 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Oonductor Surface Intermediate ¢- . Production ..j~jL ~ 7 Liner l\b. Sl(a Oil & Gas Con~. Oommissio~ Perforation depth: measured Anchor:',.. 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[] 21.1 hereby ce~i~ t~_at the,~,for~going is/jtjJue and correct to the best of my knowledge // Signed '~/['/~,¢~q~ Title Senior Drilling Engineer Date '~//~7~,~ Commission Use Only Permit Number APInumber IAppr~date See cover letter -- ~-',¢..~,/' for other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes j~ No Hydrogen sulfide measures [] Yes J~ No Directional survey required ,J~ Yes [] No Required working pressure for BOPE []2M; []3M; []5M; I-I10M; []15M; Other: Original Signed By by order of',-V /'' Approved by David W. Johnston Oommissioner [ne oomm~ssion Date Form 10-401 Rev. 12-1-85 Submit in triiSlicate I Well Name: }MPF-61 Well Plan Summary [Type of Well (producer or injector): [ Kuparuk Producer Surface Location: 2077' FSL 2537' FEL Sec 06 T13N R10E UM., AK. Target Location: 4600' FSL 526 FEL Sec 31 T14N R10E UM., AK. Bottom Hole 4820' FSL 469' FEL Sec 31 T14N R10E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. AFE Number: [330119 I l Rig: [Nabors 27E [ IEstimated Start Date: [August 10, 1995I IOperating days to drill and case: 117 I [MD: [12145' I [TVD: [7460' BKB [ IKBE: 146. I IWell Design (conventional, slimhole, etc.): Ultra Slimhole, 7" Longstring Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1800' 1796' n/a MA n/a n/a n/a NA (Top Schrader) 5694' 4206' 1687 psig / 8.0 ppg OA 6087 4366' 1725 psig / 8.0 ppg Base Schrader Bluff 6407' 4496' 1795 psig / 8.0 ppg Top HRZ 11179' 6677' n/a Base HRZ 11270' 6747' n/a Kupark D Shale 11518' 6947' n/a ToP Kuparuk A 11749' 7136' 3536 psig / 9.6 ppg Target 11749' 7136' 3536 psig / 9.6 ppg Total Depth 12145' 7460' n/a Casing/Tubin,; Program: Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 6573' 31/31 6604/4576 8 1/2" 7" 26# L-80 btrc 12115' 30/30 12145/7460 N/A (tbg) 2-7/8" 6.5# L-80 EUE 11620' 29/29 11649/7053 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7376' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3536 psi is 2828 psi, well below the internal yield pressure rating of the 7" casing. Logging Prol [Open Hole Logs: ,ram. ICased Hole Logs: Surface LWD GR/Resistivity Intermediate None Final LWD GR/Resistivity/Neutron/Density None A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. Mud Program: ISpecial design considerations INone- LSND freshwater mud Surface Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 9.6 100 35 15 30 10 15 Production Mud Properties: Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 tO to to to to to to 10.2 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1965' IMaximum Hole Angle: Close Approach Well: 66 degrees None There are no close approach wells for drilling MPF-61. 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. Requests have been made for MPF-53 and MPF-61 wells for annular pumping. Request 1. 2. to AOGCC for Annular Pumping Approval for MPF-61: Approval is requested for Annular Pumping into the MPF-63 9-5/8" x 7" casing annulus. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 6604' md (4576' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2302 psi for a 10.4 ppg fluid in this well. MASP -- 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permiability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BEE) Milne Point F-1 0 35,000 1/1/95 - 12/31/95 Milne Point F-13 684 35,000 1/1/95 - 12/31/95 Milne Point F-25 230 35,000 1/1/95 - 12/31/95 Milne Point F-37 0 35,000 1/1/95 - 12/31/95 Milne Point F-45 0 35,000 1/1/95 - 12/31/95 Milne Point F-53 0 35,000 1/1/95 12/31/95 Milne Point F-61 0 35,000 1/1/95 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. MP F-61 Proposed Summary of Operations . . . . . 10. 11. 12. 13. 14. 15. 16. 17. POST RIG WORK Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E 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 a 12-1/4" surface hole to 6604' md (4576' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Drill 8-1/2" hole to TD at 12145' MD (7461' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. ND BOPE and NU dry hole tree. Release rig to MPF-69. Note: This well will be perforated, hydraulically fractured and cleaned out with a completion rig and prior to running the ESP completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine in the wellbore. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 2-7/8" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. RIH with Electric Submersible Pump (ESP) completion on 2-7/8" EUE 8rd tubing. 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. ., , , , . Complete the handover form and turn it and the well files over to production. Turn over thio well files along '""'~- ~-~'"'~ ..... vv,., the ,,~,,,.,,..~.., ,,..,,,,. A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9- 5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. The rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. MPF-61 ,WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls flesh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 1237 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc FREE WATER: 0 YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TOP ,lOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPF-61 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST 170 deg F at 7260' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 225 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8"" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 17 joints of 7" Casing (34 total). Use stop collars to fasten centralizers to casing joints. This will cover 300' above the top of the Kuparuk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator a minimum of 60 feet inside the 9-5/8"casing shoe to avoid hanging up on the shoe. This centralizer may be attached across a casing collar connection. 3. Total 7-1/8 .... x 8-1/4" Straight Blade Turbulators needed is 35. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kuparuk Sands with 30% excess over a guage hole. DRILLING HAZARDS AND RISKS: See both the Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the, rather than formation drilling problems. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F-pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells L-07, L-08, L-09 and L-11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses initially with LCM treatments. There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L- 11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick toleranc.e of 92.3 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3536 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3536 psi @ 7085' ssTVD). There has been no injection in this region since then, only production, therefore the reservoir pressure should not exceed this estimate.. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt · MPF MPF-6 1 As-Built Well Plan Fe~tstbillty Only MPF-6 1 Wp2 ?hi~,i2.ota.^pp,.ved De,ig. has not ~en ccrtif~d 500 3000 SCALE 500 ft. / DMSION TVD REF: WEIAHEAD VERTICAL SECTION REF: I[ELLHEAD 0.00' ~ O. ND TIE IN ~0 In OD, E 'tM5 MD, tEE T¥D o.oo' e 965 MD KDP / START DF BUILD e 1.00'/100 F'~ 3.00' e 1~65 HD START DF BUILD e 1.50'/100 ~t 7.50' E L565 MD START DF BUILD i E.O0°/tO0 Ft tO.O0' E L690 MD END OF BUILD START OF' CURVE ~ E.50'/100 f~ 15,00' ~ ~073 MB EO.O0' E ~E73 MD ES.00' ~ R473 MD 30,00' ~ Z673 MD 35,00' E a873 MD 40.00' ~ 3073 H~ 45.00' t 3t73 MD 50.00' ~ 3473 ~D 55.00' ~ 3673 ~D 66.00' i~ 4[13 MD END OF CURVE t4tt 4000 4E06 4366 a855 66.00' ~ 5694 MD T. Sch-~der B~uFF / NA 66.00' E 6087 MD OA g~nds CRITICAL POINT DATA MD Inc Azt. TVD N/S E/V TIE IN 0 0.00' 14.E5' 0 0 N O E KDP / START 965 O.O0' 14.85' 965 0 N 0 E DF BUILD ~ t.O0'/tO0 f~ START OF BUILD IE65 3.00' 14.E5' rE65 O N a E 8 1.50'/100 START OF BUILD 1565 7.50' 14.85' 1564 34 N 9 E ~ a. O0'/tO0 END DF BUILD 1690 10.00' 14.E5' 1687 D. Perm~Fros~ 1801 10.00' 14.85' 1796 START DF 1873 10,00' 14.E5' 1867 CURVE 8 E.50'/tO0 f~ END OF CURVE 4113 66,00' 14,E6° 3563 T, Sch~e~ 5694 66,00' 14,~6' 4~06 Btuff / NA DA S:n~s 6087 66,00' 14.E6' 4366 B. Schrmaer 6407 66.00' 14,a6' 4496 BtufF End Gyro 7604 66,00' 14.E6' 4983 7604 66.00' 14.a6' 4983 START OF 9899 66.00' 14.E6' 5916 CURVE ~ a. O0'/lO0 ~ THRZ ll~79 40,39' 14,a5' 6677 BHRZ 11ETO 38,58' 14.a5' 6747 MK-19 11383 36.31' 14,a5' 6837 END OF CURVE 11449 35,00' 14,a5' 6890 TKUD 11518 35.00' 14.a5' 6947 TKUC 11677 35,00' 14.E5' 7077 TKUB 11686 35.00' 14,E5' 7084 T~roe~ C / tL749 35.00' 14.85' 7136 TKUA3 TKUAE 11767 35.00' 14.E5' 7151 TKUA~ t1789 35.00' 14.~5' 7169 D. Kup~puk 11845 35.00' 14.ES' 7~L5 53 N 13 E 7l N 18 E 83 N El E 1367 N 347 E E767 N 703 E 3116 N 792 E 3399 N 864 E 4458 N LL33 E 4459 N 1L33 E 6490 N L649 E 7476 N 1900 E 753E N 1914 E 7598 N 193l E 7636 N 1940 E 7674 N 1950 E 7768 N 197~ E 7767 N L974 E 7BOE N L983 E 7BIE N L985 E 7BE5 N IBBB E 7856 N 1996 E CASING POINT DATA 00 MD Inc Azl TVD N/S E/W ED In lES O.OO' O.OO' 1E5 0 N 0 E 9 5/B ~n 6604 66.00' 14.26' 4576 3573 N 908 E 7 ~n tEL45 35.00' 14.~5' 7461 BOa3 N ~039 E Tmroet C 7136 7BOa N 1983 E 54396a 6043343 5000 -- 5500 -- 3507 .-.~6,00' ~ 6407 MD B. Schrader BluFF 9 5/8 ~n 09, ~ 6604 MD, 4576 TVD~~ ' . "'.,~66.00' ~ 9899 MD START OF CURVE ~ E.OO'/IOO Ft 6697 '~0.00' ~ 10199 MD 54.00' ~ 10499 MD 50.00' ~ t0699 MD '~-46.00' ~ t0899 MD 3~$?~.eett7B9 MD TKUAL 11845 MD B. KupQmuk 8~78 7 ;n 00, ~ let45 MD, 7461TVD 35,00' ~ ret45 MD BO00 -500 0 500 tO00 1500 POOO ~500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 VERTICAL SECT[ON PLANE: 14.26 750( 35, 1 5O HALL I BURTON 7/L8/95 10,31 HORIZONTAL VIEw (TRUE NORTH) SCALE 500 ft./ DIVISION SURVEY REF: WEIJi-IEAD 76 TVD 500 0 500 1000 1500 EOOO 2500 3000 3500 PROPOSED BHL TVD 7460.85 · MD 12145.46 VS 8277.64 N/S 8022.70 N E/W 2038.53 E D:te Plo::ed , l/_LB/95 Checked By ~2 App-ove~ By i Survey Refexence: WEI ~I.HEAD Reference World Coordinates: Lat. 70.30.29 N - Long. 149.39.22 W Refemmce GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6035530.11 N 542024.85 E Nca'th Aligned To: TRUE NORTH ' Vertical Section Reference: WELLI~AD Closure Refexence: WELLHEAD 'IW'D Reference: WELLHEAD Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2. I.B Vertical Section Plane: 14.26 deg. Well Plan Feasibilit Onl Thiaan~la not all Approved Design has not I~en certified Page ! Date: 7118/95 . Time: 10:26 am Wellpath ID: MPF-61 Wp2 Last Revision: 7/18/95 BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-61 As-Built MPF-61 Wp2 Measured Incl Drift Subsea TVD Corse T O T A L Depth " Dir. Depth Length Rectangular Offsets (fi) (deg.) (deg.) (ft) (ft) fit) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) 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 (fi) (deg.) (ft) (dg/10Oft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool TIE IN 0.00 0.00 0.00 -46.10 0.00 0.00 0.00N CASING POINT OD = 20 in, ID = 19.12 in, Weight= ~.00 lb/ft. 125.00 0.00 0.00 78.90 125.00 125.00 0.00N KOP I START OF BUILD @ 1.00 deg/100 fl 965.00 0.00 0.00 918.90 965.00 840.00 0.00N 0.00E 6035530.11 542024.85 0.00E 6035530.11 542024.85 0.00E 6035530.11 542024.85 0.~@ 0.~ 0.~ 0.~ 0.~ 0.~@ 0.~ 0.~ 0.~ 0.~ 0.~@ 0.~ 0.~ 0.~ 0.~ 0.00 0.0 0.00N 0.00 0.0 0.00N 0.00 0.0 0.00N 0.~E 0.~ 0.~ 0.~ 0.~ BPHM-PBD 0.~E 0.~ 0.~ 0.~ 0.~ BPI-IM-PBD 0.~E 3.13 3.13 0.~ 1.38 BPFI34-PBD 1065.00 1.00 14.25 1018.89 1064.99 100.00 0.85N 1165.00 2.00 14.25 1118.86 1164.96 100.00 3.38N START OF BUILD @ 1.50 deg/lO0 ft 1265.00 3.00 14.25 1218.76 1264.86 100.00 7.61N 0.21 E 6035530.96 542025.06 0.86 E 6035533.50 542025.69 1.93 E 6035537.73 542026.74 0.87@ 14.25 0.87 1.00 0.00 3.49@ 14.25 3.49 1.00 0.00 7.85@ 14.25 7.85 1.00 0.00 1.00 1.0 0.85N 1.00 2.0 3.38N 1.00 3.0 7.61N 0.22E 3.33 3.33 284.25 1.53 BPHM-PBD 0.86E 3.55 3.55 284.25 1.68 BPHM-PBD 1.94E 3.78 3.76 284.25 1.84 BPHM-PBD 1365.00 4.50 14.25 1318.55 1364.65 100.{30 13.95N 1465.00 6.00 14.25 1418.12 1464.22 100.00 22.82N START OF BUILD @ 2.00 deg/100 fl 1565.00 7.50 14.25 1517.43 1563.53 100.00 34.21N 3.54E 6035544.08 542028.31 14.39@ 14.25 14.39 5.79E 6035552.96 542030.52 23.54@ 14.25 23.54 8.69E 6035564.37 542033.34 35.30@ 14.25 35.30 1.50 0.00 1.50 0.00 1.50 0.00 1.50 4.5 13.95 N 1.50 6.0 22.81N 1.50 7.5 34.20N 3.56 E 4.04 3.99 284.25 2.00 BPHM-PBD 5.83 E 4.34 4.21 284.25 2.16 BPHM-PBD 8.74 E 4.68 4.44 284.25 2.33 BPHM-PBD 1665.00 9.50 14.25 1616.32 1662.42 100.00 48.54N 12.33E 6035578.71 542036.90 50.08@ 14.25 50.08 END OF BUILD 1690.00 10.00 14.25 1640.96 1687.06 25.00 52.64N 13.37 E 6035582.82 542037.92 54.31@ 14.25 54.31 B. Permafrost 1800.72 10.00 14.25 1750.00 1796.10 110.72 71.27N 18.10E 6035601.48 542042.55 73.54@ 14.25 73.54 ZOO 0.00 ZOO 0.00 0.00 0.00 2.00 9.5 48.51N 12.42E 5.11 4.67 284.25 2.52 BPHM-PBD 2.00 10.0 52.61N 13.48E 5.23 4.73 284.25 2.57 BPHM-PBD 0.00 10.0 71.23N 18.26E 5.77 5.02 284.25 2.74 BPHM-PBD 1870.00 10.00 14.25 1818.23 1864.33 69.28 82.93N 21.06E 6035613.16 542045.44 85.57@ 14.25 85.57 START OF CURVE @ 2.50 deg/lO0 ft 1873.04 10.00 14.25 1821.23 1867.33 3.04 83.45N 21.19E 6035613.67 542045.57 86.09@ 14.25 86.09 1973.04 12.50 14.25 1919.30 1965.40 100.00 102.35N 25.99 E 6035632.60 542050.26 105.60@ 14.25 105.60 0.00 2.50 0'.00 0.00 0.00 10.0 82.89N 21.25E 6.13 5.20 284.25 2.85 BPHM-PBD 0.00 10.0 83.40N 21.38E 6.15 5.21 284.25 2.86 BPHM-PBD 2.50 12.5 102.29N 26.25 E 6.78 5.45 284.25 3.08 BPI-IM-PBD 2073.04 15.00 14.25 2016.42 2062.52 100.00 125.39N 31.85 E 6035655.67 542055.98 129.37@ 14.25 129.37 2173.04 17.50 14.25 2112.42 2158.52 100.00 152.51N 38.74E 6035682.82 542062.72 157.35@ 14.25 157.35 2.50 2.50 0.00 0.00 2.50 15.0 125.30N 32.20 E 7.54 5.70 284.25 3.33 BPHM-PBD 2.50 17.5 152.38N 39.22 E 8.45 5.95 284.25 3.60 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 7/18/95 Wellpath ID: MPF-61 Wp2 Measured Incl Drift Subsea TVD Course T O T A L GRID Coordinates Depth Dir. Depth Length Rectangular Offsets Northing Easting (R) (deg.) (deg.) (fi) (ft) (fl) (ft) (ft) (ft) (ft) 2273.04 20.00 14.25 2207.11 2253.21 100.00 183.66N 46.65 E 6035714.02 542070.46 189.49@ 14.25 189.49 2373,04 22.50 14.25 2300.30 2346.40 100.00 218.78N 55.57E 6035749.19 542079.18 225.73@ 14.25 225.73 2473.04 25.00 14.26 2391.82 2437.92 100.00 257.82N 65.49E 6035788.27 542088.87 266.00@ 14.25 266.00 2573.04 27.50 14.26 2481.50 2527.60 100.00 300.68N 76.38E 6035831.19 542099,52 310.23@ 14.25 310.23 2673.04 30.00 14.26 2569.17 2615.27 100.00 347.29N 88.22E 6035877.87 542111,10 358.32@ 14.25 358.32 2773.04 32.50 14.26 2654.65. 2700.75 100.00 397.57N 101.00E 6035928.21 542123.58 410,20@ 14.25 410.20 2873.04 35.00 14.26 2737.79 2783.89 100,00 451.41N 114.68E 6035982.12 542136,96 465.75@ 14.25 465.75 2973.04 37.50 14.26 2818.43 2864.53 100.00 508.72N 129.24E 6036039.50 542151.19 524.88@ 14.25 524.88 3073.04 40.00 14.26 2896.41 2942.51 100.130 569.38N 144.65 E 6036100.24 542166.26 587.46@ 14.25 587.46 3173.04 42.50 14.26 2971.59 3017.69 100.00 633.27N 160.89E 6036164.23 542182.13 653.39@ 14.25 653.39 3273.04 45.00 14.26 3043.82 3089.92 100.00 700.29N 177.92E 6036231.33 542198,78 722.54@ 14.26 722.54 3373.04 47.50 14.26 3112.97 3159.07 100.00 770.30N 195.71 E 6036301.43 542216,17 794.77@ 14.26 794.77 3473.04 50.00 14.26 3178.90 3225.00 100.00 843.16N 214,22E 6036374.39 542234,26 869.95@ 14.26 869.95 3573.04 52.50 14.26 3241.49 3287.59 100,00 918.74N 233.43E 6036450.07 542253,04 947.93@ 14.26 947.93 3673.04 55.00., 14.26 3300.61 3346.71 100.00 996.89N 253.29E 6036528.33 542272.45 1028.57@' 14.26 1028.57 3T/3.04 57.50 14.26 3356.16 3402.26 100.00 I077.47N 273.76E 6036609.02 542292.47 1111.71@ 14.26 1111.71 3873.04 60.00 14.26 3408.04 3454.14 100.00 1160.32N 294.81 E 6036691.98 542313.05 1197.19@ 14.26 1197.19 3973.04 62.50 14.26 3456.13 3502.23 100.00 1245.29N 316.41 E 6036777.06 542334.15 1284.86@ 14.26 1284.86 4073.04 65.00 14.26 3500.36 3546.46 100.00 1332.21N 338.49 E 6036864.09 542355.74 1374.54@ 14.26 1374.54 END OF CURVE 4113.O4 66.00 14.26 3516.95 3563.05 40.00 1367.48N 347.46 E 6036899.42 542364.50 1410.94@ 14.26 1410.94 T. Schrader Bluff / NA 5694.05 66.00 14.26 4160~00 4206.10 1581.01 2767.32N 703,18E 6038301.13 542712.16 2855.26@ 14.26 2855.26 Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hor Dir. Vein Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2.50 0.00 2.50 0.00 2.50 0.00 2.50 20.0 183.49N 47130E 9.50 6.21 284.25 3.89 BPHM-PBD 2.50 22.5 218.56N 56.44 E 10.71 6.47 284.25 4.21 BPI-[M-PBD 2.50 25.0 257.53N 66.62E 12.08 6.75 284.25 4.55 BPHM-PBD 2.50 2.50 2.50 0.00 0.00 0.00 2.50 27.5 300.31N 77.82 E 13.60 7.04 284.25 4.92 BPHM-PBD 2.50 30.0 346.83N 90.03 E 15.28 7.34 284.25 5.32 BPHM-PBD 2.50 32.5 397.00N 103,22E 17.11 7.65 284.25 5.75 BPHM-PBD 2.50 2.50 2.50 0.00 0.00 0.00 2.50 35.0 450.72N 117.38E 19.08 7.97 284.25 6.21 BPHM-PBD 2.50 37.5 507.89N 132.48E 21.19 8.30 284.25 6.70 BPHM-PBD 2.50 40.0 568.40N 148.50E 23.45 8.64 284.25 7.23 BPHM-PBD 2.50 2.50 2.50 0.00 0.00 0.00 2.50 42.5 632.13N 165.40E 25.83 8.98 284.26 7.80 BPHM-PBD 2.50 45.0 698.96N 183.16E 28.35 9.33 284.26 8.40 BPHM-PBD 2.50 47.5 768.76N 201.74 E 30.99 9.67 284.26 9.03 BPHM-PBD 2.50 2.50 2.50 0.00 0.00 0.00 2.50 50.0 841,41N 221.11 E 33.75 10.02 284.26 9.71 BPHM-PBD 2.50 52.5 916.76N 241.23 E 36.63 10.35 284.26 10.41 BPHM-PBD 2.50 55.0 994.66N 262.07 E 39.61 10.68 284.26 11.16 BPHM-PBD 2.50 0.00 2.50 0.00 2.50 0.00 2.50 57.5 1074.98N 283.59 E 42.70 10.99 284.26 11.94 BPHM-PBD 2.50 60.0 1157.55N 305.73 E 45.88 11.30 284.26 12.75 BPHM-PBD 2.50 62.5 1242.22N 328.47 E 49.15 11.58 284.26 13.59 BPHM-PBD 2.50 0.00 2.50 65.0 1328.84N 351.75 E 52.51 11.84 284.26 14.46 BPHM-PBD 2.50 0.00 2.50 66.0 1363.99N 361.21 E 53.86 11.95 284.26 14.82 BPHM-PBD 0.00 0.00 0.00 66.0 2758.94N 736.17 E 107.84 18.55 284.26 27.97 BPHM-PBD OA Sands 6087.43 66.00 14.26 4320.00 4366.10 393.37 3115.61N 791.68E 6038649.89 542798.65 3214.62@ 14.26 3214.62 0.00 0.00 B. Schrade~ Bluff 6407.04 66.00 14.26 4450.00 4496.10 319.62 3398.60N 863.60 E 6038933.26 542868.93 3506.61@ 14.26 3506.61 0.00 0.00 CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 6604.00 66.00 14.26 4530.11 4576.21 196.96 3572.99N 907.91 E 6039107.89 542912.23 3686.54@ 14.26 3686.54 0.00 0.00 End Gyro 7604.00 66.00 14.26 4936.85 4982.95 10(~J.00 4458.40N 1132.91E 6039994.49 543132.07 4600.08@ 14.26 4600.08 0.00 0.00 7604.25 66.00 14.26 4936.95 4983.05 0.25 4458.62N 1132.96E 6039994.72 543132.12 4600.31@ 14.26 4600.31 0.00 0.00 START OF CURVE @ 2.00 deg/lO0 ft 9899.02 66.00 14.26 5870.32 5916.42 2294.77 6490.42N 1649.28 E 6042029.30 543636.50 6696.69@ 14.26 6696.69 0.00 0.00 9999.02 64.00 14.26 5912.58 5958.68 100.130 6578.25N 1671.60 E 6042117.26 543658.30 6787.32@ 14.26 6787.32 -2.00 -0.00 10099.02 62.00 14.26 5957.97 6004.07 100.00 6664.61N 1693.54 E 6042203.73 543679.73 6876.41@ 14.26 6876.41 -2.00 -0.00 10199.02 60.00 14.26 6006.45 6052.55 100.00 6749.37N 1715.08E 6042288.61 543700.77 6963.87@ 14.26 6963.87 -2.00 -0.00 10299.02 58.00 14.26 6057.95 6104.05 100.00 6832.44N 1736.18 E 6042371.80 543721.39 7049.58@ 14.26 7049.58 -2.00 -0.00 10399.02 56.00 14.26 6112.41 6158.51 100.00 6913.72N 1756.84E 6042453.19 543741.56 7133.45@ 14.26 7133.45 -2.00 -0.00 IOAO0,02 54,00 14.26 6160,77 6215,87 10().00 6O03.11N 1777.01 E 6042532.6q 5.13761.26 7215.36o,) 14.26 7215.36 -2.(X) -0.(g) 0.00 66.0 3106.01N 829.46E 121.32 20.21 284.26 31.40 BPHM-PBD 0.00 66.0 3388.02N 905.26E 132.28 21.56 284.26 34.22 BPHM-PBD : 0.00 66.0 3572.99N 907.91 E 0.t30 0.00 0.00 0.130 BPHM-PBD " .~ 0.00 66.0 ~,~.~,4.11N 1189.14E 173.35 26.62 284.26 44.85 BPHM-PB'!~.. :.:~'~: 0.00 66.0 4~.44.33N 1189.20E 173.36 26.62 284.26 44.86 BPHM-PBD · . 0.00 66.0 6469.03N 1733.44E 252.17 36.36 284.26 65.46 BPHM-PBD .... 2.00 68.0 6556.57N 1756.93E 255.54 37.05 284.26 66.20 BPFIM-PBD 2.00 70.0 6642.63N 1780.01E 258.85 '37.77 284.26 66.90 BPHM-PBD i:~" · ..--,,' 2.00 72.0 6727.12N 1802.64E 262.08 38.53 284.26 67.57 BPHM-PBD 2.00 74.0 6809.92N 1824.80E 265.25 39.32 284.26 68.19 BPHM-PBD 2.00 76.0 6890.95N 1846.46E 268.33 40.13 284.26 68.78 BPHM-PBD 2.(X) 78.0 6970.10N 1867.58 I'; 271.33 40.96 284.26 (,9.33 BPIIM.PI~D Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 3 Date: 7/18/95 Wellpath ID: MPF-61 Wp2 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (fl.) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (fl) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vent Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/lOOft) (dg/lOOft) (dg/lOOft) (deg) (fl) (ft) (ft) (fl) (deg.) (ft) Survey Tool 10599.02 52.00 14.26 6229.95 6276.05 100.00 7070.51N 1796.67 E 6042610.20 543780.46 7295.22@ 14.26 7295.22 -2.00 -0.00 10699.02 50.00 14.25 6292.87 6338.97 100.00 7145.83N 1815.81 E 6042685.62 543799.15 7372.93@ 14.26 7372.93 -2.00 -0.00 10799.02 48.00 14.25 6358.48 6404.58 100.0() 7218.97N 1834.39 E 6042758.86 543817.30 7448.39@ 14.26 7448.39 -2.00 -0.00 2.00 80.0 7047.27N 1888.15 E 274.25 41.80 284.26 69.84 BPHM-PBD 2.00 82.0 7122.37N 1908.14E 277.07 42.66 284.26 70.30 BPHM-PBD 2.00 84.0 7195.31N 1927.53 E 279.81 43.53 284.26 70.73 BPHM-PBD 10899.02 46.00 14.25 6426.67 6472.77 100.00 7289.85 N 1852.40 E 6042829.84 543834.89 7521.53@ 14.26 7521.53 -2.00 -0.00 10999.02 44.00 14.25 6497.38 6543.48 100.00 7358.38N 1869.81 E 6042898.47 543851.89 7592.23@ 14.26 7592.23 -2.00 -0.00 11099.02 42.00 14.25 6570.51. 6616.61 100.00 7424.48N 1886.60 E 6042964.66 543868.29 7660.43@ 14.26 7660.43 -2.00 -0.00 2.00 86.0 7266.00N 1946.29 E 282.44 44.40 284.26 71.12 BPHM-PBD 2.00 88.0 7334.35N 1964.40E 284.98 45.27 284.26 71.46 BPHM-PBD 2.00 90.0 7400.28N 1981.84E 287,42 46.15 284.26 71.77 BPHM-PBD THRZ 11179.41 40.39 14.25 6631.00 6677.10 80.39 7475.80N 1899.63 E 6043016.04 543881.02 7713.38@ 14.26 7713.38 -2.00 -0.00 11199.02 40.00 14.25 6645.98 6692.08 19.61 7488.07N 1902.75 E 6043028.33 543884.06 7726.03@ 14.26 7726.03 -2.00 -0.00 BHRZ 11270.11 38.58 14.25 6701.00 6747.10 71.09 7531.70N 1913.83 E 6043072.02 543894.88 7771.05@ 14.26 7771.05 -2.00 -0.00 2.00 91.6 7451.47N 1995.37E 289.32 46.84 284.26 72.00 BPHM-PBD 2.00 92.0 7463.71N 1998.61 E 289.77 47.01 284.26 72.05 BPHM~PBD 2.00 93.4 7507.24N 2010.09E 291.38 47.62 284.26 72.22 BPHM-PBD 11299.02 38.00 14.25 6723.69 6769.79 28.91 7549.06N 1918.24 E 6043089.40 543899.19 7788.96@ 14.26 7788.96 -2.00 -0.00 MK-19 11383.48 36.31 14.25 6791.00 6837.10 84.46 7598.50N 1930.79E 6043138.91 543911.45 7839.97@ 14.26 7839.97 -2.00 -0.00 11399.02 36.00 14.25 6803.55 6849.65 15.54 7607.38N 1933.05E 6043147.81 543913.66 7849.14@ 14.26 7849.14 -2.00 -0.00 2.00 94.0 7524.56N 2014.66E 292.03 47.87 284.26 72.29 BPHM-PBD 2.00 95.7 7573.89N 2027.65E 293.83 48.59 284.26 72.46 BPHM-PBD 2.00 96.0 7582.75N 2029.98 E 294.16 48.72 ' 284.26 72.49 BPHM-PBD END OF CURVE 11449.02 35.00 14.25 6844.25 6890.35 50.00 7635.53N 1940.20E 6043175.99 543920.64 7878.17@ 14.26 7878.17 -2.00 -0.00 11518.30 35.00 14.25 6901.00 6947.10 69.27 7674.04N 1949.98 E 6043214.56 543930.19 7917.91@ 14.26 7917.91 0.00 0.00 TKUC 11677.00 35.00 14.25 7031.00 7077.10 158.70 7762.26N 1972.39 E 6043302.91 543952.07 8008.94@ 14.26 8008.94 -0.00 0.00 2.00 97.0 7610.83N 2037.37 E 295.20 49.14 284.26 72.59 BPHM-PBD 0.00 97.0 7649.26N 2047.48E 296.63 49.51 284.26 72.85 BPHM-PBD 0.00 97.0 7737.29N 2070.65 E 299.91 50.36 284.26 73.46 BPHM-PBD TKUB 11685.54 35.00 14.25 7038.00 7084.10 8.55 7767.01N 1973.59E 6043307.66 543953.25 8013.84@ 14.26 8013.84 Target C / TKUA3 11749.02 35.00 14.25 7090.00 7136.10 63.48 7802.30N 1982.56E 6043343.00 543962.00 8050.25@ 14.26 8050.25 TKUA2 11767.33 35.00 14.25 7105.00 7151.10 18.31 7812.48N 1985.14E 6043353.20 543964.52 8060.75@ 14.26 8060.75 0.00 0.00 0.00 -0.00 0.00 0.00 0.00 97.0 7742.03N 2071.90E 300.08 50.41 284.26 73.49 BPHM-PBD 0.00 97.0 7777.25N 2081.17 E 301.40 50.75 284.26 73.74 BPHM-PBD 0.00 97.0 7787.41N 2083.84 E 301.77 50.85 284.26 73.81 BPHIM-PBD TKIJAI 11789.31 35.00 14.25 7123.00 7169.10 21.97 7824.70N 1988.24E 6043365.43 543967.55 8073.35@ 14.26 8073.35 B. Kuparuk 11845.46 35.00 14.25 7169.00 7215.10 56.16 7855.92N 1996.17E 6043396.69 543975.30 8105.56@ 14.26 8105.56 CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. 12145.46 35.00 14.25 7414.75 7460.85 300.00 8022.70N 2038.53 E 6043563.70 544016.66 8277.64@ 14.26 8277.64 0.00 0.00 0.00 0.00 0.00 0.00 0.00 97.0 7799.59N 2087.05 E 302.23 50.96 284.26 73.89 BPHM-PBD 0.00 97.0 7830.74N 2095.24E 303.39 51.27 284.26 74.11 BPHM-PBD 0.00 97.0 7997.16N 2139.04E 309.59 52.88 284.26 75.26 BPHM-PBD BPx-sh~ed ~e~vice. D~iLLing AL~sk~ ~~e PLane', Zone4 MiLne P~ ', MPF MPF-6 i As-BuiLt MPF-6 i Wp~ FORIZENTAL ..~W (TRUE FORTH) SCALE 500 f'%-l- / DIVISION SURVEY REF: ~ELLHEAD ,T ,,500 0 5OO tO00 , i500 L:030 25(3O 3OOO 350O HALLIBURTON 71i8/g5 932 o~ IWELLS STATUS ~FF-53Wc~3 FLOVING No Pon'f; No, i F'I_BW]N~ kF'F'-45 RlgMwd FI..C~NG PFC'-37 G~Z~o lFRm~diJ]~ Well Plan Feasibility Only This is not an Approved Design and has not been certified TVD 7460,85 MD 12i45,46 VS 82_77,64 N/S ~,70 N E,,5,,t 8038,53 E II '~-~1 "?'~'---~,~x-J/I . ]31~X-Sh~eol ~e~vlce D~illing Alc~sk~ ~~e Plc~ne~ Zone4 Miln e P~ ', MPF MPF-6 1 As-]3uil~ ~PF-61 ~p~ HZRIZ~NTAL VIEW (TRUE KCRTH) SCALE lO0 C'L / DIVI$IEN SURVEY REP WELLHEAD 7118195 iDOl cu~ F:~73 6~76 6~I6 68m i 1500 1603 1700 I I I I and has not t)cen TVD 7460,85 HI) 12145,46 VS 8277,64 N/S 8(]22,70 N ~ L:~(38,5;3 E Do:te Plod-ted D,~-t~ By ~pp~oved% Dc"ce 016 ~ 3~0 //:~o / / / 700 IlO 84O 190 170 [I_[]SEST POINTS ~_Z~. Slot .~.~ ~,~--z-/ No Pdn~ No, l ~F-~ ~ ~..-45 ~9~'~'d ~F.--45 /~-.-~.~it ~:"F-..3;' ~. ~.~-f,~!...~ ~:T' -13 GY'E~']!~-~T.-.I3 Dst~nce D~ec~on Ref' HI) ReP TVD SeD,Fac-¢~ 119,~ 3~,69 ~,~ ~,~ I~,~ S~%~t ;~58.C0 ! 4(7) 09 1399.53 4.40 163,~ ~.03 ~,~ ~,~ 1~,40 119.57 :.'~c~ 4~,~ 4~O.~ 34.10 · ~c~ '~ ;~ ~: ~q E2).('~.'~ ,x;.U~.~"""" 3 f ~..40 ~,~ 215,73 ~,~. ~,~ 4~,~ 4~.G1 815.63 ~,~ ~.~ 45i,~ WELLS STATUS Ff~c-77 WL:~ FLOWING .~V~.'.'4-- ,.-,). : : :r .~ - .-, ¢ ~ p, ~ FL.tT.~ bis No Pc,~n'~ No, I FL.OVI,NG :. : ~., ,,.... ,.. :r ::...:. F~--13 MWD FI_B'W]NG 1'~'-0! Well Plan Feasibility Only This is not an A. ppmved Desitln and has not been certified .... Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.1.B Page 1 Date: 7/18/95 Time: 9:16 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-61 As-Built MPF-61 Wp2 N/S and FJW are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 12145.46 ft.(MD) All Directions using BP Highside Method in Dec.Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Flowing Shut-in Well Safety Min. Safety Clear Spread MD TVD Dist Enter Enter Exit Exit Close Safety Shut-in Danger Danger Shut-in Approach Dist Zone Zone Zone Zone Status ! MPF-77 Wp5 112.0 115.8 300 300 4.5 0.8 MPF-53Wp3 7.8 25.9 1450 1449 21.8 3.6 No Point N 157.6 160.1 200 200 3.0 0.5 MPF-45 Rig 106.2 1143 650 650 9.8 1.6 MPF-37 Gyr 136.8 154.3 1400 1400 21.0 3.5 MPF-25 RIG 237.9 254.2 1300 1300 19.5 3~2 MPF -13 GY 345.5 355.5 800 800 12.0 2.0 MPF-13 MW'D 352.3 357-3 400 400 6.0 1.0 MPF-01 Gyr 434.9 446.8 950 950 14.3 2.4 OK OK OK OK OK OK OK OK OK Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.1.B Page 1 Date: 7/18/95 Time: 9:17 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-61 As-Built MPF-61 Wp2 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 12145.46 ft.(MD) Ali Directions using BP Highside Method in Dee.Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Wellpath MPF-77 MPF-77 Wp5 MPF-53 As-Built MPF-53Wp3 MPF-46 As Built No Point No.1 MPF-45 As-Built MPF-45 RigMwd MPF-37 As-Built MPF-37 Gyro IHRm MPF-25 As-BuiltMPF-25 RIGBHAMWD MPF-13 As-Built MPF -13 GYROIHRM MPF-13 As-Built MPF-13 MWD MPF-1 As-Built MPF-01 Gyro-IHRM Distance 119.58 1430.10 38.81 1673.25 163.03 10915.95 119.57 2036.97 168.08 3181.48 265.62 463735 360.25 7226.27 360.26 5227.69 450.61 5529.68 Direction Ref MD 35.69 50.00 105.65 3450.00 258.00 1400.00 286.93 9950.00 Ref TVD Sep Factor 50.00 180.9 3210.10 13.4 , 139933 4.4 593736 33 258.03 50.00 50.00 177.4 277.46 8650.00 540839 13.2 215.97 400.00 283.97 6350.00 229.09 1350.00 281.66 6700.00 224.42 1360.00 277.47 6900.00 400.00 34.1 4472.90 7.2 1349.69 16.6 46152,6 11.1 1299.81 32.4 4696.60 11.4 215.73 50.00 50.00 311.4 273.14 6700.00 4615.26 22.2 215.73 50.00 50.00 458.0 273.64 5250.00 4025.49 14.6 215.63 50.00 50.00 451.6 277.88 4100.00 3557.71 25.0 WELL PERMIT CHECKLIST F=LD , FOOL INIT CLASS UNIT# PROGRAM: exp [] If 3'.2_ F dev [] redrll [] serv [] ON/OFF SHORE 6~9~ ADMINISTRATION 1. Permit fee attached .................. · N 2. Lease number appropriate ................ ' Y N 3. Unique well name and number ............... Y N 4. Well located in a defined pool ............. Y N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ...... N ' 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ......... IY~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order ..... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ........ N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~3 N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing.designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ;Y ~ /~ 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~(~d~Zi) psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y N/ 32. Seismic analysis 9f shallow gas zones ......... ~~ .~'/'~ ~ 33. Seabed condition survey (if off-shore) ........ /Y N ~ 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMM~I?N: Co~ments/Instructions: HOW/jo - A:~ORMS~cheklist rev 03/94 o o I--t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 2 is type LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF - 61 500292258200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 22-SEP-95 6480.00 K. RICHARDS J. FOX 6 13N 10E 2077 2537 49.20 47.70 13.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 20.000 113.0 3RD STRING 9.625 6586.0 PRODUCTION STRING 7.000 12095.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ GR GRCH 1 1 14-SEP-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH REMARKS: GR/CCL Cased Hole. 91.10 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9680.0 11970.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: - EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT : BP EXPLORATION : MPF - 61 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 37 1022 BYTES * Tape File Start Depth = 9675.000000 Tape File End Depth = 11975.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9203 datums Tape Subfile: 2 125 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 START DEPTH STOP DEPTH GRCH 11750.0 11975.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 11753.5 11754.5 11761.0 11762.0 11762.5 11764.0 11764.5 11766.0 11765.0 11767.0 11772.0 11774.5 11774.0 11776.5 11777.0 11778.5 11783.0 11784.5 11784.0 11785.0 11785.0 11786.0 11807.0 11809.0 11899.0 11901.0 11961.5 11963.0 11963.0 11964.5 11965.0 11965.0 11965.5 11965.5 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). CN WN FN COUN STAT / ? ?MATCH2A . OUT $ : BP EXPLORATION : MPF - 61 : MILNE POINT/KUPARUK : NORTH SLOPE : 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: 1022 BYTES * Tape File Start Depth = 11745.000000 Tape File End Depth = 11975.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 923 datums Tape Subfile: 3 52 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCRF3~ENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9675.5 $ 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 12001.0 14-SEP-95 FSYS REV. J001 VER. 1.1 1916 14-SEP-95 12006.0 11980.0 9700.0 11978.0 3000.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EBAR SBAR EBAR CCL GR FDEN $ ECCENTRIC SINKER BAR SINKER BAR ECCENTRIC SINKER BAR PCM/COLLAR LOC. GAMMA RAY FLUID DENSITY TOOL NUMBER 8250EA/8248EA 8262XA 8223XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 12095.0 .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): DIESEL/SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT R,_ .2 NORMALIZATION IN OIL ZON. TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION : MPF - 61 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 187 Tape File Start Depth = 9675.500000 Tape File End Depth = 12001.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55719 datums Tape Subfile: 4 263 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 run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11745.0 $ 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 12018.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EBAR SBAR EBAR CCL GR FDEN $ ECCENTRIC SINKER BAR SINKER BAR ECCENTRIC SINKER BAR PCM/COLLAR LOC. GAMMA RAY FLUID DENSITY 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) : 14-SEP-95 FSYS REV. J001 VER. 1.1 1905 14-SEP-95 12006.0 11980.0 9700.0 11978.0 3000.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 8223XA .000 12095.0 .0 DIESEL/SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RA ~ NORMALIZATION IN OIL ZON~ TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN) : .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION : MPF - 61 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 22 Tape File Start Depth = 11745.000000 Tape File End Depth = 12018.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6389 datums Tape Subfile: 5 98 records... Minimum record length:- 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS 95/ 9/22 01 **** REEL TRAILER **** 95/ 9/22 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 22 SEP 95 7:32a Elapsed execution time = 6.71 seconds. SYSTEM RETURN CODE = 0 ~'Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 6591.00 M. HANIK J. GAFFANEY MPF-61 500292258200 BP EXPLORATION ALASKA INC. SPERRY-SUN DRILLING SERVICES 29-FEB-96 MWD RUN 2 M. HANIK J. GAFFANEY MWD RUN 4 J. STRAHAN J. ROBERTSON MWD RUN 5 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M. WORDEN J. ROBERTSON WELL CASING RECORD CP OF LMED 2077 Date...__ 49.20 47.70 13.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 20.000 112.0 3RD STRING 12.250 9.625 6585.0 PRODUCTION STRING 8.500 12120.0 REMARKS: MWD - GR/EWR4/SLD/CNP. ALL DEPTHS ARE MEASURED BIT DEPTHS. NO FOOTAGE WAS DRILLED ON RUN 3. MWD RUNS 1 & 2 WERE DIRECTIONAL WITH GAMMA RAY (DGR/ SGRC) & PHASE-4 RESISTIVITY (EWR4) MWD RUNS 4 & 5 WERE DIRECTIONAL WITH GAMMA RAY (DGR/ SGRC), PHASE-4 RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP), & STABILIZED LITHO DENSITY. (SLD). ALL GAMMA RAY DATA WAS AQUIRED WITH GEIGER MUELLER TUBE DETECTORS. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP RHOB NPHI $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 110.0 106.0 6586.0 6586.0 BASELINE DEPTH GR 54.0 53.0 9797.0 9796.0 9853.5 9853.0 9899.0 9910.0 10079.0 10090.0 10116.0 10125.5 10238.5 10239.5 10251.5 10252.5 10325.0 10334.5 10366.5 10378.5 10388.0 10397.5 10617.5 10627.5 10774.5 10783.5 10903.0 10909.0 10918.0 10926.5 10998.0 11005.0 11026.0 11029.0 11103.0 11111.5 11169.5 11175.5 11222.5 11226.0 11292.5 11300.0 11306.0 11317.0 11319.5 11326.0 11323.0 - 11331.5 11520.5 11523.5 11589.0 11597.5 11602.5 11611.0 11647.5 11653.5 11678.5 11685.5 11729.0 11736.0 11735.0 11742.0 11752.5 11759.5 11758.5 11765.5 11779.0 11787.5 11813.5 11821.5 11851.5 11860.5 11985.5 11989.0 12116.5 12120.0 $ MERGED DATA SOURCE all bit runs merged. STOP DEPTH 12053.0 12026.0 12042.0 12033.0 (marked line), WALS 14-SEP-95. EQUIVALENT UNSHIFTED DEPTH PBU TOOL CODE $ REMARKS: BIT RgN NO MERGE TOP MERGE B~E 1 112.0 2947.0 2 2947.0 6602.0 4 6602.0 8169.0 5 8169.0 12120.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. CN WN FN COUN STAT /??SHIFT. OUT $ : BP EXPLORATION (ALASKA) : MPF- 61 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1150 Tape File Start Depth = 12120.000000 Tape File End Depth = 50.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 289693 datums Tape Subfile: 2 1284 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 61.0 EWR4 105.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOW-NHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2898.0 2890.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 18-AUG-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 2947.0 112.0 2947.0 0 .8 28.5 TOOL NUMBER P0404CRG8 P0404CRG8 12.250 112.0 SPUD 9.30 62.0 8.5 1700. 10.2 1.850 1.550 1.700 1.900 75.0 91.0 80.0 80.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 1. $ : BP EXPLORATION (ALASKA) : MPF- 61 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 188 Tape File Start Depth = 2950.000000 Tape File End Depth = 50.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 46409 datums Tape Subfile: 3 253 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2889.0 EWR4 2880.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMIIMANGLE: STOP DEPTH 6553.0 6545.0 21-AUG-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 6602.0 2947.0 6602.0 0 35.4 67.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ TOOL NUMBER P0404CRG8 P0404CRG8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SP~ 9.60 53.0 9.5 1200 7.2 1.850 1.240 1.700 1.900 75.0 115.0 80.0 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 2. $ : BP EXPLORATION (ALASKA) : MPF- 61 : MILNE POINT : NORTH SLOPE : ALASKA FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 241 Tape File Start Depth = 6610.000000 Tape File End Depth = 2875.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 349462 datums Tape Subfile: 4 306 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6501.0 EWR4 6473.0 SLD 6491.0 CNP 6483.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8106.0 8079.0 8095.0 8086.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STAB. LITHO DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 24-AUG-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 8169.0 6602.0 8169.0 0 64.9 68.8 TOOL NUMBER P0389CRNSLDG6 P0389CRNSLDG6 P0389CRNSLDG6 P0389CRNSLDG6 8.500 6585.0 LSND 9.10 42.0 10.0 900 .0 .000 .000 .000 .000 .0 121.0 .0 .0 SANDSTONE 2.65 HOLE CORRECTION (IN; : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-61 : MILNE POINT : NORTH SLOPE : ALASKA .OOO .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FCNT MWD 68 1 CPS 4 11 NCNT MWD 68 1 CPS 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 180 01 1 4 90 810 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 190 Tape File Start Depth = 8175.000000 Tape File End Depth = 6470.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 94164 datums Tape Subfile: 5 259 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NIIMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 F I LE SUMMARY VENDOR TOOL CODE START DEPTH GR 8106.0 EWR4 8079.0 SLD 8095.0 CNP 8086.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12056.0 12029.0 12045.0 12037.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STAB. LITHO DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 28-AUG-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 12120.0 8169.0 12120.0 0 35.2 68.2 TOOL NUMBER P0389CRNSLDG6 P0389CRNSLDG6 P0389CRNSLDG6 P0389CRNSLDG6 8.500 6585.0 LSND 10.30 48.0 9.0 80O 5.5 2.400 1.420 2.900 1.950 77.0 135.0 75.0 79.0 SANDSTONE 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF- 61 : MILNE POINT : NORTH SLOPE : ALASKA .0~0 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FCNT MWD 68 1 CPS 4 11 NCNT MWD 68 1 CPS 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 180 01 1 4 90 810 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 450 Tape File Start Depth = 12121.000000 Tape File End Depth = 8075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 462765 datums Tape Subfile: 6 519 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 96/ 2/29 01 **** REEL TRAILER **** 96/ 2/29 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 29 FEB 96 2:35p Elapsed execution time = 9.01 seconds. SYSTEM RETURN CODE = 0