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196-117
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: 3/2/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250302 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# CLU 11 50133205590000 206058 2/19/2025 AK E-LINE CBL,CIBP CLU 11 50133205590000 206058 2/13/2025 AK E-LINE CIBP END 1-65A 50029226270100 203212 1/27/2025 HALLIBURTON COILFLAG END 2-56A 50029228630100 198058 2/6/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 2/2/2025 HALLIBURTON PPROF MPU F-29 50029226880000 196117 1/31/2025 HALLIBURTON MFC24 MPU L-02A 50029219980100 209147 2/17/2025 READ CaliperSurvey MPU L-36 50029227940000 197148 1/18/2025 HALLIBURTON MFC24 MPU R-144 50029238090000 224148 2/11/2025 HALLIBURTON WFL-TMD3D NCIU A-21 50883201990000 224086 2/18/2025 AK E-LINE Perf ODSN-25 50703206560000 212030 2/16/2025 READ MemoryLeakPoint PBU 06-05A 50029202980100 224115 1/15/2025 BAKER MRPM PBU 06-15A 50029204590200 224108 12/27/2024 HALLIBURTON RBT PBU 06-16B 50029204600200 223072 1/25/2025 BAKER MRPM PBU B-12B 50029203320200 224133 1/19/2025 BAKER MRPM PBU S-126B 50029233630200 224084 2/7/2025 HALLIBURTON RBT PBU V-105 50029230970000 202131 2/9/2025 HALLIBURTON IPROF PBU W-01A 50029218660100 203176 1/19/2025 AK E-LINE CBL PBU W-01B 50029218660200 224149 1/28/2025 HALLIBURTON RBT PCU 02A 50283200220100 224110 1/24/2025 AK E-LINE CIBP Please include current contact information if different from above. T40161 T40161 T40162 T40163 T40164 T40165 T40166 T40167 T40168 T40169 T40170 T40171 T40172 T40173 T40174 T40175 T40176 T40177 T40178 T40179 MPU F-29 50029226880000 196117 1/31/2025 HALLIBURTON MFC24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.03 10:15:14 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 17,014'16,768 (Fill) 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-29 MILNE POINT KUPARUK RIVER OIL N/A 7,520' 16,768' 7,348' 1,214 16,908' 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): 12/1/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0355018 196-117 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22688-00-00 Hilcorp Alaska LLC C.O.816 Length Size Proposed Pools: 112' 112' 6.5# / L-80 / EUE 8rd TVD Burst 16,389' MD N/A 5,750psi 7,240psi 4,480' 7,506' 8,019' 16,994' 80' 20" 9-5/8" 7" 7,988' 16,965' 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 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:00 am, Nov 25, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.11.22 15:09:55 - 09'00' Taylor Wellman (2143) 324-669 * BOPE pressure test to 2000 psi. A.Dewhurst 25NOV24 10-404 DSR-12/16/24MGR25NOV24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.16 15:41:44 -09'00'12/16/24 RBDMS JSB 121724 Well: MPF-29 PTD: 196-117 API: 50-029-22688-00-00 Well Name:MPF-29 API Number:50-029-22688-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:12/1/2024 Estimated Duration:4 days Regulatory Contact:Tom Fouts Permit to Drill Number:196-117 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: 1918 psi @ 7,039’ TVD 11/7/2024 | 5.3 EMW, 5.5 KWF Max Potential Surface Pressure: 1,214 psi Gas Column Gradient (0.1 psi/ft) Max Angle:77° Sail Angle @ 6,500’ MD Brief Well Summary: MPU producer F-29 was drilled and completed as a Kuparuk A-sand producer in 1996. ESPs were installed in 1998, 2001, 2006, 2010, 2016 and 2020 Previous ESP installs had run lives of approximately 4 to 6 years. The well has a history of solids production; however, the previous three ESP installs were due to a blown cable and holes in the tubing. The current failure is suspected to be due to a shorted cable, possibly from a hole in tubing. The BHP started rising but so did the Amps which could indicate at shallow hole where the ESP was still lifting the full column of fluid. 4 days later we lost the sensor and then it grounded out. Objectives: Pull failed ESP completion, TIH with test packer and test casing run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 2,000 psi on 12/8/2016 at 8,050’ MD. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,000psi high. 2. Drift and tag with sample bailer. 3. Tubing punch 5’ at 16,275’ MD 4. Pull GLV and set dummy valve in upper GLM at 193’ MD. 5. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE per CT weekly test protocol. 2. PU 1.75” jet nozzle. 3. Jet down to discharge head at 16,291’ MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU tubing punch. 7. RIH and tag discharge head. 8. Pump down ball to fire tubing punch. 9. Confirm circulation by pumping down backside of coil. 10. Freeze protect tubing as POOH. Well: MPF-29 PTD: 196-117 API: 50-029-22688-00-00 11. 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. 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/ 2,000 psi high. Test annular to 250 psi low/ 2,000 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” and 3-1/2” 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 7-1/16” 5M with 3" LH Acme. b. 2016 tubing PU weight on ASR #1 recorded as 110 kip. 2020 Slack off weight recorded as 15 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. a. Wash and toss all tubing b. Keep ported discharge head and centralizer for future use. Well: MPF-29 PTD: 196-117 API: 50-029-22688-00-00 c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 468 ii. Protectolizers: 2 iii. Pump Clamps: 8 iv. Flat guard: 1 10. Lay Down ESP. If the ESP comes out clean, then go straight to the test packer run. 11.Contingency: PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 8,100’ MD. 12. Circulate well clean. 13. Scrape casing interval from 8,000’ to 8,100’ MD. 14. POOH while filling hole with 2x displacement. 15. PU and RIH with 7” test packer to 8,050’ MD. 16. Test 7” casing to 1,900 psi for 30 minutes. 17. POOH with test packer. 18. RIH with 2-7/8” 6.5# 13Cr JFE BEAR ESP completion to +/- 16,389’ and obtain string weights. 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 11 Motor - 150HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 3 Gas Separator 52 5.38 10 Pumps – GINPSHL 45 5.38 22 Pumps – Flex7ER 45 5.38 22 Pumps – Flex7ER 45 1 Ported Discharge Head 13 2-7/8" 10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8" 30 2-7/8" JFE-BEAR 8rd L-80 6.5 13Cr 2-7/8"10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 13Cr 2-7/8"10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8" 30 2-7/8" JFE-BEAR 8rd Jt 6.5 13Cr 2-7/8"10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 13Cr Cond B 2-7/8"10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8" ~15,964 2-7/8" JFE-BEAR 8rd Jt 6.5 13Cr Cond B 191jts Well: MPF-29 PTD: 196-117 API: 50-029-22688-00-00 2-7/8"10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 13Cr Cond B ~200 MD 2-7/8"10 2-7/8" JFE-BEARxEUE 8rd Pup Jt 6.5 13Cr 2-7/8" 150 2-7/8" JFE-BEAR 8rd Jt 6.5 13Cr 2-7/8" 10 Space out pup 6.5 13Cr 2-7/8" 30 Tubing Hanger with full joint 6.5 13Cr 19. Land tubing hanger. Use extra caution to not damage cable. 20. Lay down landing joint. 21. Set BPV. 22. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 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. Double BOPE Schematic _____________________________________________________________________________________ Revised By TDF 11/19/2024 SCHEMATIC Milne Point Unit Well: MPU F-29 Last Completed: 3/1/2020 PTD: 196-117 TD =17,014’ (MD) / TD = 7,520’(TVD) 20” RA Tag @ 16,358’ WLM Orig. KB Elev.: 41.24’/ GL Elev.: 12.1’ (N22E) RT to Tbg. Spool = 28.6’ (N 22E) 7” 3 9&10 1 1 9 12 & 13 9-5/8” 1 PBTD =16,908’ (MD) / PBTD = 7,446’(TVD) 5, 6 & 7 4 KUP A Sands 8 16,768’ WLM on 8/18/1996 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 /H-40/ N/A N/A Surface 112' .0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 8,019’ 0.0759 7" Production 26 / L-80 / MBTC 6.276 Surface 16,994’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 16,389’ 0.00579 JEWELRY DETAIL No Depth Item 1 193’GLM STA# 1: Dummy GLM/w .25" OV 2 5,991’GLM STA# 2:Dummy 3 16,248’ 2.205” XN Nipple 4 16,291’ Discharge Gauge Assembly 5 16,302’ Pump 3: 400PMXSD 126stg FLEX 7 ER SXD 6 16,324’ Pump 2: 400PMXSD 126stg FLEX 7 ER SXD 7 16,346’ Pump 1: 400PMXSD 24GINPSHL 8 16,357’ Gas Separator: 400 GSV X M 9 16,359’ Upper Tandem Seal: GSB3DB H6 SB/SB PFSA 10 16,366’ Lower Tandem Seal: GSB3DB H6 SB/SB PFSA 11 16,373’ Motor: 562XP- 105Hp / 2,420A / 38A 12 16,384’ Motor Gauge Zenith PT00752 13 16,387’ Centralizer: Bottom @ ±16,389’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,545’ 16,557’ 7,192’ 7,201’ 12 8/17/1996 Open 16,563’ 16,583’ 7,205’ 7,219’ 20 8/17/1996 Open 16,591’ 16,609’ 7,225’ 7,237’ 18 8/17/1996 Open 16,609’ 16,629’ 7,237’ 7,251’ 20 8/17/1996 Open Ref Log: 08/17/96 GR (PFC)/CCL –22gm. Alpha Jet Charges @ 45°/ 135°Phasing –EHD=0.76” / TTP=6.4” Mid-perf = 7226’ TVD / 16,587’ MD OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 24” Hole 9-5/8" 1500 sx PF ‘E’, 900 sx Class ‘G’, 150 sx PF ‘E’ 12-1/4” Hole 7” 264 sx Class ‘G’ 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1,000’ Max Hole Angle = 77° @ 6,500’ 70 Deg.+ from 4,000’ to 14,900’ Hole Angle through perf interval = 46° TREE, WELLHEAD & HANGER Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8rd on bottom, 2.5” BPV CIW Profile Hanger 7-1/16" 5M TBG Hanger 3" LH Acme Lift Threads GENERAL WELL INFO API: 50-029-22688-00-00 Drilled and Cased by Nabors 22E - 7/23/1996 ESP Completion Installed by Nabors 4ES-9/22/1996 RWO ESP by Nabors 4ES 3/26/1998, 11/12/1998 & 9/30/2001, 3/13/2010 RWO ESP by N3S - 7/17/2006 RWO ESP by Nabors 4ES - 3/13/2010 RWO ESP by ASR#1 - 12/10/2016 & 3/1/2020 STIMULATION SUMMARY 8/31/96 – Casing Frac. 178.3 M lbs. 20/40 and 16/20 Carbolite behind pipe. NOTE ESP lowered into well to check perfs or TD to 16,701’ during 3/13/2010 RWO. No fill evident. _____________________________________________________________________________________ Revised By TDF 11/19/2024 PROPOSED Milne Point Unit Well: MPU F-29 Last Completed: 3/1/2020 PTD: 196-117 TD =17,014’ (MD) / TD = 7,520’(TVD) 20” RA Tag @ 16,358’ WLM Orig. KB Elev.: 41.24’/ GL Elev.: 12.1’ (N22E) RT to Tbg. Spool = 28.6’ (N 22E) 7” 3 9&10 1 1 9 12 & 13 9-5/8” 1 PBTD =16,908’ (MD) / PBTD = 7,446’(TVD) 5, 6 & 7 4 KUP A Sands 8 16,768’ WLM on 8/18/1996 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 /H-40/ N/A N/A Surface 112' .0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 8,019’ 0.0759 7" Production 26 / L-80 / MBTC 6.276 Surface 16,994’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±16,389’ 0.00579 JEWELRY DETAIL No Depth Item 1 ±XXX’GLM STA# 1: GLM/w .25" OV 2 ±X,XXX’GLM STA# 2:Dummy 3 ±X,XXX’ 2.205” XN Nipple 4 ±X,XXX’ Ported Discharge Head: 5 ±X,XXX’ Pump 3: 6 ±X,XXX’ Pump 2: 7 ±X,XXX’ Pump 1: 8 ±X,XXX’ Gas Separator: 9 ±X,XXX’ Upper Tandem Seal: 10 ±X,XXX’ Lower Tandem Seal: 11 ±X,XXX’ Motor: 150Hp 12 ±X,XXX’ Intake Sensor: 13 ±X,XXX’ Centralizer: Bottom @ ±X,XXX’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,545’ 16,557’ 7,192’ 7,201’ 12 8/17/1996 Open 16,563’ 16,583’ 7,205’ 7,219’ 20 8/17/1996 Open 16,591’ 16,609’ 7,225’ 7,237’ 18 8/17/1996 Open 16,609’ 16,629’ 7,237’ 7,251’ 20 8/17/1996 Open Ref Log: 08/17/96 GR (PFC)/CCL –22gm. Alpha Jet Charges @ 45°/ 135°Phasing –EHD=0.76” / TTP=6.4” Mid-perf = 7226’ TVD / 16,587’ MD OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 24” Hole 9-5/8" 1500 sx PF ‘E’, 900 sx Class ‘G’, 150 sx PF ‘E’ 12-1/4” Hole 7” 264 sx Class ‘G’ 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1,000’ Max Hole Angle = 77° @ 6,500’ 70 Deg.+ from 4,000’ to 14,900’ Hole Angle through perf interval = 46° TREE, WELLHEAD & HANGER Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8rd on bottom, 2.5” BPV CIW Profile Hanger 7-1/16" 5M TBG Hanger 3" LH Acme Lift Threads GENERAL WELL INFO API: 50-029-22688-00-00 Drilled and Cased by Nabors 22E - 7/23/1996 ESP Completion Installed by Nabors 4ES-9/22/1996 RWO ESP by Nabors 4ES 3/26/1998, 11/12/1998 & 9/30/2001, 3/13/2010 RWO ESP by N3S - 7/17/2006 RWO ESP by Nabors 4ES - 3/13/2010 RWO ESP by ASR#1 - 12/10/2016 & 3/1/2020 STIMULATION SUMMARY 8/31/96 – Casing Frac. 178.3 M lbs. 20/40 and 16/20 Carbolite behind pipe. NOTE ESP lowered into well to check perfs or TD to 16,701’ during 3/13/2010 RWO. No fill evident. 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 THE STATE °ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F-29 Permit to Drill Number: 196-117 Sundry Number: 319-500 Dear Mr. Helgeson: Alaska Gil and Cas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the 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 V Price Chair DATED this ✓ day of November, 2019. RBDMSL NOV 0 6 2019 RECEIVED STATE OF ALASKA NOV 01 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A�GCC 9n AAC or 9An 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑r 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 ❑✓ Stratigraphic Service EJ 196-117 r 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22688-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.432D L Will planned perforations require a spacing exception? Yes ❑ No ❑ MILNE PT UNIT F-29 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0355018 •ADI.00i$5Qq MILNE POINT/ KUPARUK RIVER OIL r 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): 17,014' 7,520' 16,768' 7,348' 1,244 16,908' 16,768 (Fill) Casing Length Size MD TVD Burst Collapse Conductor 80, 20" 112' 112' N/A N/A Surface 7,988' 9-5/8" 8,019' 4,480' 5,750psi 3,090psi Production 16,965' 7" 16,994' 7,506' 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 / ELF 8rd 16,417' 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 r Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Rr Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/20/2019 OIL E WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinson hIIC f .Corn Contact Phone: 777-8343 Authorized Signature: Date: 11/1/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 111-5b6 31 Plug Integrity ❑ BOP Test EV/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: t 1BDMS 6JNnV 0 6 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ / LI Spacing Exception Required YYes No Subsequent Form Required: (� — (' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: U6) X II/ //-S/ Submit Fonn and Form 10-403 evised 4/201 / Approved application is I' 1 1 to of approval. Attachments in Duplicat GWAf .«1, �o ..1 H nil.n, Alaska, LL ESP Change -Out Well: MPU F-29 Date: 11-01-19 Well Name: MPU F-29 API Number: 50-029-22688-00 Current Status: Shut-in ESP Producer Pad: F -Pad Estimated Start Date: December 201h, 2019 Rig: ASR #1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-117 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,908 psi @ 7,060' TVD Downhole Gauge (10/1/1 r5.2 PPG T Maximum Expected BHP: 1,950 psi @ 7,060' TVD Reservoir Pressure Build- 5.3 MPSP: 1,244 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 77" @ 6,500' MD Max Dogleg: 5.2'/100ft @ 6,428' MD BPV Profile: 2-1/2" CIW Type H Brief Well Summary: MPU producer F-29 was drilled and completed as a Kuparuk A -sand producer in 1996. The last ESP completion was installed in December 2016 and the well remained online until February 2017 after it was shut-in due to a suspected pump failure. Previous ESP installs had run lives of approximately 4 to 6 years. The well has a history of solids production; however, the previous two ESP installs were due to a blown cable and holes in the tubing. The current failure is suspected to be due to a parted shaft. The Flex10 pump design was operating outside of the design curve. A newly developed pump, the Flex7, should address the proper design considerations with down -thrust protection. Due to the known history of solids buildup, the plan will be to increase the flowing bottom -hole pressure target from 500 to 700 psig. Notes Regarding Wellbore Condition • The 7" production casing passed an MIT to 2,000 psig on 12/8/16 (� o Utilized 7" test packer set at 8,050' MD. Offset Injection Support: o F-10: Online, injecting 1,300 BWPD o F-90: Shut-in Obiective: • Pull 2-7/8" Tubing String, FIex10 ESP, and 250 HP motor. • Install new Baker Hughes 150 HP motor, 244 -stage Flex 7ER, and new 2-7/8" tubing. Pre -Rig Procedure: 1. RU LRS and PT lines to 3000 psi. 2. Well is expected to be on a vacuum. Pump one IA volume (500 bbls) with 8.3 ppg source -water down IA, taking fluids to formation. 3. Clear and level pad area in front of well. Spot rig mats and containment. 4. RD well house and flowlines. Clear and level area around well. 5. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. U IIikoru Almkx, LL ESP Change -Out Well: MPU F-29 Date: 11-01-19 a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 6. RD Little Red Services. 7. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 8. NU BOPE house. Spot mud boat. Brief RWO Procedure: 9. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 10. 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/ 8.3 ppg source -water prior to pulling BPV. 11. 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. Vvr a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. ' 13. Contingency: If BOPE test fails ( L _ (` 1 a. Notify Operations Engineer (H PM , Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) �f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to returns tank. Pull TWC. Kill well w/ 8.3 ppg source -water as needed. 15. Rig up spooler for ESP #2 cable. a. Baker Hughes representative should be onsite for ESP pull. f 16. MU landing joint or spear and PU on the tubing hanger. � a. The ASR #1 PU weight during the 2016 ESP completion was 110K lbs / SOF = 15K lbs b. If needed, circulate (long or reverse) pill with lubricant, source -water, and/or baraclean pill prior to laying down the tubing hanger. 17. Recover the tubing hanger. ESP Change -Out Well: MPU F-29 Hil.m Alaska, LLI Date: 11-01-19 Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 18. POOH and lay down the 2-7/8" tubing. Lay down ESP and motor. a. Plan to re -run most of tubing. Note that 287 of 522 joints were newly installed in 2016 with 3 - month run time. i. Remove any joints that are suspect. Send tubing joints to G&I for washing and dispose. b. Re -run GLM c. Dispose of AVA Nipple. d. Note any sand or scale inside or on the outside of the ESP on the morning report. e. Look for over -torqued connections from previous tubing runs. f. The completion has the following amount of clamps/guards/cap-string. Send to G&I for cleaning and re -use on future wells. i. 524 Cross Collar Cannon Clamps ii. 2 Protectolizers iii. 1 Flat Guard iv. 8 Body Clamps 19. PU new ESP and RIH on 2-7/8" 6.5# L-80 tubing. Set base of ESP assembly at± 16,400' MD. a. Upper 2-7/8"x 1" Side -pocket GLM @ ±200' MD with 0.25" OV b. 2-7/8" tubing c. Lower 2-7/8"x 1" Side -pocket GLM @ ± 6,000' with Dummy GLV d. 2-7/8" tubing e. 2-7/8" XN (2.205" No -Go) Nipple f. 1 joint of 2-7/8" tubing g. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. h. Baker Hughes 244 stage Iex7ER E P i. Baker Hughes 25 stage GINPSH ESP j. Gas Separator k. 150 HP Baker Hughes 562XP Motor I. Motorgauge m. Base of ESP centralizer @ ± 16,400' MD. 20. Land tubing hanger. RILDS. Lay down landing joint. Note Pick-up and slack -off weights on tally. 21. Set BPV. Post -Rig Procedure: 22. RD mud boat. RD BOPE house. Move to next well location. 23. RU crane. NO BOPE. H Illlcura Alaska, Lb 24. NU existing 2-9/16" 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 25. Pull BPV. 26. RD crane. Move 500 bbl returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic ESP Change -Out Well: MPU f-29 Date: 11-01-19 n Qilcoro Alnek,. LLC Orig. KB EW.: 41.241/ GL Bev.: 12.1' (N22E) TD =17,014' (MD) / TO=7,520'(ND) PMD =16,908' (MD) / PBTD= 7,446'UVD) Milne Point Unit SCHEMATIC Well: MPU F-29 Last Completed: 12/10/2016 PTD: 196-117 TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead 11"x7 -1/16"5M FMC Gen 5A,w/2-7/8" FMC Tbg. Hngr., 3" LH Acme on top and 2-7/8" EUE 8rd on bottom, 2.5" BPV CI W Profile OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 24" Hole 9-5/8" 1500 sx PF'E', 900 sx Class 'G', 150 sx PF 'E' 12-1/4" Hole 7" 264 sx Class 'G'8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn Drift lD Top Btm BPF 20" Conductor 1 91.1/H-40/ N/A j N/A I Surface I 12' .0355 9-5/8" Surface 40/L-80/BTC 8.679 Surtace 8,019' 0.0759 7" Production 26/L-80/MBTC 6.151 1 Surface 16,994' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80 /EUE Srd 2.347 Surface 16,417 0.00579 WELL INCLINATION DETAIL KOP @ 1,000' Max Hale Angle = 77° @ 6,500' 70 Deg.+ from 4,000'to 14,000' Hole Angle through pert interval = 46° STIMULATION SUMMARY 8/31/96 -Casing Frac. 178.3 M lbs. 20/40 and 16/20 Carbolite behind pipe. JEWELRY DETAIL No Depth Item 1 118' GLM STA91: Camco 2-7/8" x 1" Side Pocket w/ Dummy 2/23/2017 2 16,288' AVA Nipple w/ Blanking Sleeve 3 16,331.6' Discharge Head: FPDIS 4 16,332' Pump: 119FLEX10 SXD 5 16,356' Pump: 119FLEX10 SXD 6 16,379' Gas Separator: GSHVVX H6 PER 7 16,383' Upper Tandem Seal: G583DBUT SB/58 PFSA 8 16,390 Lower Tandem Seal: GSB3DBUT SB/SB PFSA 9 16,397' Motor: XP -200- 250HP/ 2,505V/ 61A SO 16,413' I Sensor: Phoenix XT150 11 16,415' 1 Centralizer: Bottom @ 16,417' PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (ND) FT*�P=6.4" Status 16,545' 16,557' 7,192' 7,201' 12Open Kup.ASands 16,563' 16,583' 7,205' 7,219' 20Open 16,591' 16,609' 7,225' 7,237' 18Open 16,609' 16,629' 7,237' 7,251' 20OpenRef Lg: 08/17/96 GR (PFq/CCL-22gm. Alpha Jet Charges @ 45'f 135° Phasing -EH" Mid-perf = 7226' WD / 16,587' MD GENERAL WELL INFO EESPCo 9-22688-00-00 Cased by Nabors 22E -7/23/1996 letion Installed by Nabors 4ES-9/22/1996y Nabors 4ES 3/26/1998, 11/12/1998 &,3/13/2010by N3S- 7/17/2006y Nabors 4ES-3/13/2010 R WO ESP by ASR41 -12/10/2016 NOTE [FNofill wered into well to check perfs or TO16,701' during 3/13/2010 RWO. evident. Revised By TDF 12/29/2016 16, 8'1 R Icorp Alaska, LLC Ori& KB Elm: 41.24'/ GL Bev.: 12.r (N22E) TD =17,014' (MD) /TD=7,52(Y(TVD) PBT) =16,908' (NW) / PBTD= 7,446 (f VD) PROPOSED TREE & WELLHEAD Milne Point Unit Well: MPU F-29 Last Completed: 12/10/2016 PTD: 196-117 Tree Cameron 2-9/16"5M Wellhead 11" x 7-1/16" 5M FMC Gen 5A, w/ 2-7/8" FMC Tbg. Hngr., 3" LH Acme on top and 2-7/8" EUE Sod on bottom, 2.5" BPV CI W Profile OPEN HOLE/ CEMENT DETAIL 20" 250 sx of Arcticset i (Approx) 24" Hole 9-5/8" 1500 sx PF 'E', 900 sx Class 'G', 150 sx PF 'E' 12-1/4" Hole 7" 264 sx Class 'G' 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn -911 Top (TVD) op Btm BPF 20" Conductor /H-40/ N/A M6.15ISurface face 112' .0355 9-5/8" Surface 40/L-80/BTC Pump: 2ge Flex7,340' face 8,019' 0.0759 7" Production 26/L-80/MBTC ' 16,994' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE Srd 2.347 Surface ±16,400' 0.00579 WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle = 77° @ 6,500' 70 Deg .+ from 4,000' to 14,900' Hole Angle through perf interval = 46° STIMULATION SUMMARY 8/31/96 -Casing Frac. 178.3 M Iles. 20/40 and 16/20 Carbolite behind pipe. JEWELRY DETAIL PERFORATION DETAIL Sands epth Item Top (TVD) 200' GLM STE 0.25" OV Date ,000' GLM STDMY ' ,250' 2.205"ple 7,201 ,310' Dischard:6,315' Open Kup.ASands' Pump: 2ge Flex7,340' 16,583' 16,609' 13Gas Pum : G,360' 20 18 8/17/1996 8/17/1996 Gas Sep:,365' ' Upper TSeal:,370' 7,237' 7,251' Lower TSea!:,380' 8/17/1996 Open Motor: EHD=0.76" / TTP=6.4" ,395' Sensor:,400' Mid -pert= 7226' ND / 16,587' MD Centralittom@±16,400' PERFORATION DETAIL Sands Btm (MD) Top (TVD) Btm (TVD) FT Date Status ' 16,557' 7,192 7,201 12 8/17/1996 Open Kup.ASands' ]TopD) ' 16,583' 16,609' 7,205' 7,225' 7,219' 7,237' 20 18 8/17/1996 8/17/1996 Open Open ' 16,629' 7,237' 7,251' 20 8/17/1996 Open Ref Log: 08/17/96 GR IPFCI/CCL- 229m. Alpha Jet Charges @ 45/ 135° Phasing- EHD=0.76" / TTP=6.4" Mid -pert= 7226' ND / 16,587' MD NOTE F red into well to check perfs or 701' during 3/13/2010 RWO. dent. GENERAL WELL INFO FP,112188-00-00288-00-00 asd by Nabors 22E - 7/23/1996 oInstalled by Nabors 4ES-9/22/1996 Nbors 4ES 3/26/1998, 11/12/1998 & 9/30/2001, 3/13/2010 N35 - 7/17/2006 RWO ESP by Nabors 4ES - 3/13/2010 RWO ESP by ASR#1 - 12/10/2016 Revised By TDF 11/1/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 5/14/2018 ?-7/8" x 5" VBR ind es Iva STATE OF ALASKA ALIRA OIL AND GAS CONSERVATION COMAtION DEC- REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program El Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑., Re-enter Susp Well❑ Other: ESP Change-out ❑., 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 196-117 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22688-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT KR F-29 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 17,014 feet Plugs measured 16,908 feet true vertical 7,520 feet Junk measured 16,768 feet Effective Depth measured 16,768 feet Packer measured N/A feet true vertical 7,348 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 7,988' 9-5/8" 8,019' 4,480' 5,750psi 3,090psi Production 16,965' 7" 16,994' 7,506' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic �,r �q�e it4 ¢� ; 2.t r i a True Vertical depth See Attached Schematic `� 9� Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 16,417' 7,103' 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 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 0 440 0 Subsequent to operation: 77 9 320 260 226 14.Attachments(required per 20 MMC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory Development El Service ❑ Stratigraphic El Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-600 --' Contact Paul Chan Email pchan@hilcorp.com JoL% A .z.f.A 3 c.„ Printed Name Bo York Title Operations Manager Signature SPhone 777-8345 Date 12/27/2016 .:,) :7 02—747 ORIGINAL, 7 Form 10-404 Revised 5/2015 RBDMS [,(i JAN 2 5 2017 Submit Original Only • Milne Point Unit II 6 SCHEMATIC well: MPU F-29 Last Completed: Hilrorp AIni ka,LLC 12/10/2016 TREE&WELLHEAD Orig.KB Elev.:41.24'/GL Elev.:12.1'(N22E) Tree Cameron 2-9/16"5M RT to Tbg.Spool=28.6' (N 22E) 11"x 7-1/16"5M FMC Gen 5A,w/ 2-7/8"FMC Tbg.Hngr.,3"LH Wellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"BPV CIW Profile ] l;, .:4 LI 20' k OPEN HOLE/CEMENT DETAIL ;' , 20" 250 sx of Arcticset I(Approx)24"Hole ll 1 ' 9-5/8" 1500 sx PF`E',900 sx Class'G',150 sx PF'E'12-1/4"Hole 4 '' 7" 264 sx Class`G'8-1/2"Hole . r CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF ii 20" Conductor 91.1/H-40/N/A N/A Surface 112' .0355 9-5/8" Surface 40/L-80/BTC 8.679 Surface 8,019' 0.0759 1; )" 7" Production 26/L-80/MBTC 6.151 Surface 16,994' 0.0383 w, TUBING DETAIL t= 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 16,417' 0.00579 ( -4 WELL INCLINATION DETAIL *4 KOP @ 1,000' Max Hole Angle=77°@ 6,500' 70 Deg.+from 4,000'to 14,900' Hole Angle through perf interval=46° ¢ ,e. ( I"? . ' STIMULATION SUMMARY 9-5/8 ) 0 8/31/96-Casing Frac.178.3 M lbs. ( 20/40 and 16/20 Carbolite behind pipe. ° I JEWELRY DETAIL No Depth Item 1 118' GLM STA#1:Camco 2-7/8"x 1"Side Pocket w/Dual Screen Orifice I 2 16,288' AVA Nipple w/Blanking Sleeve 3 16,331.6' Discharge Head:FPDIS 4 16,332' Pump:119FLEX10 SXD 5 16,356' Pump:119FLEX10 SXD 6 16,379' Gas Separator:GSHVVX H6 FER 7 16,383' Upper Tandem Seal:GSB3DBUT SB/SB PFSA i 8 16,390' Lower Tandem Seal:GSB3DBUT SB/SB PFSA lil ' 9 16,397' Motor:XP-200-250HP/2,505V/61A 10 16,413' Sensor:Phoenix XT150 kA ° Y ; ' 11 16,415' Centralizer:Bottom @ 16,417' t. 2 f, PERFORATION DETAIL 3 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status i ;i4&5 16,545' 16,557' 7,192' 7,201' 12 8/17/1996 Open RtATag @ n 1 16,563' 16,583' 7,205' 7,219' 20 8/17/1996 Open 16,358'VLM r Kup.A Sands Iltl, 6 16,591' 16,609' 7,225' 7,237' 18 8/17/1996 Open ' 16,609' 16,629' 7,237' 7,251' 20 8/17/1996 Open 73,8 Ref Log: 08/17/96 GR(PFC)/CCL-22gm.Alpha Jet Charges @ 45°/135"Phasing-EHD=0.76"/TTP=6.4" = Mid-perf=7226'TVD/16,58T MD 2 GENERAL WELL INFO ,x ,� API:50-029-22688-00-00 I:: Drilled and Cased by Nabors 22E -7/23/1996 1 f "1 t;10&11 ESP Completion Installed by Nabors 4E5-9/22/1996 RWO ESP by Nabors 4ES 3/26/1998,11/12/1998& 16,766'V\LM on 714 9/30/2001,3/13/2010 8/18/1996 °;:i RWO ESP by N3S-7/17/2006 KUPASands RWO ESP by Nabors 4ES-3/13/2010 -. RWO ESP by ASR#1-12/10/2016 4e, NOTE 1D=17,014'(MD)/TD=7,520'(TVD) ESP lowered into well to check perfs or PBTD=16,908'(MD)/PBTD=7,446(TVD) TD to 16,701'during 3/13/2010 RWO. No fill evident. Revised By TDF 12/29/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-29 ASR#1 50-029-22688-00-00 196-117 12/4/2016 12/10/2016 Daily Operations: 11/30/26/2016-Wednesday No activity to report. 12/1/2016-Thursday No activity to report. 12/2/2016- Friday No activity to report. 12/3/2016-Saturday No activity to report. 12/4/2016-Sunday Moved Alaska Crane over to F-29 Hoisted and Installed Well House, Hoisted and Nipple up Bop stack and Equipment, spot Mud tanks, move well site trailer and spot in place. Set well enclosure, Nipple up BOPs (AOGCC was notified of right to witness BOP Test on 12-4-16 @ 11:16 AM) 12/5/2016- Monday Nipple up BOPs, spot supervisor trailer&crew change house, (SIMOPS, Nipple up Tree on MPF-38) (AOGCC Brian Bixby waived right to witness BOP Test on 12-5-16 @ 05:58 AM),Set Rig floor with crane, Move Rig on to Mud Boat.,(NPT) Trouble shoot X Box screens, discussed with Prostar, Reboot on screens. Raise Derrick, & pin, attach anchors lines to Rig & mud boat, set cat walk, Rig up floor, continue to Nipple up BOP, Electricians Connected Fire and Gas Alarms and Tested (Good),Held Safety Sundry Meeting with rig Crew F-29 Procedure Shell test BOPE. 250/2,500psi.Test BOPE per Sundry# 316-600 and ASR-1 procedure. Test all Valves and Rams to 250/3,000psi 5 min each,Tested 2-7/8" and 3-1/2"Tests Joints, Tested Annular 250/2,500psi 5 min each Recorded Accumulator Pre-Charge Pressures and Charted Tests ( AOGCC Rep. Brian. Bixby waived witness of Test on 12/5/16 @ 05:58 am) Rig Down Test Equipment Same,Well Head Rep Removed TWC Valve ( Roads and Pads Spotted ESP Spooler),Hang ESP Sheave and E-Trunk in Derrick, Made up 2-7/8" Landing Joint into Hanger, BOLDS,Check IA Pressure =0 Pulled Hanger to the rig Floor Max Pull at 117k Free Pull at 110k, Break and lay down Tubing Hanger and Landing Joint, Adjust Bop Stack to Center and install Drip Pan on Bop Stack 12/6/2016-Tuesday Service Rig, check all fluid levels.,TOOH, laying down 2-7/8" completion tubing to 7,900'. (Found a dime sized hole injoint# 103 out),Service Rig, check all fluid levels. Continued POOH, laying down 2-7/8" completion tubing F/7,900' to 3,500', Equipment Repair Replace Broken Cat Walk Cable for Skate,Continued POOH, laying down 2-7/8" completion tubing F/ 3,500' to 890'. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPF 29 ASR# 1 50-029-22688-00-00 196-117 12/4/2016 12/10/2016 Daily Operations y := 07,9 • 12/7/2016-Wednesday Service rig, check fluids in all equipment. Continue TOOH F/890'to Surface with ESP. Lay down ESP assembly, Small amount of sand was noted in discharge head,Top seal had water in each both chambers, Lower seal had clean mineral oil, all shafts had good rotation. Clear&Clean Rig floor, change handling tools over to 3.5" Load &Tally 275 joints of 3.5" Work string. Make up 7" Casing Scraper assembly.TIH with 7" Casing scraper on 3.5" CS Hydril work string T/3,900' Service rig, check fluids in all equipment.TIH with 7" Casing scraper on 3.5" CS Hydril work string F/3,900' 8,100' P/U/W=56K S/O/W=21K Total Jt. 273) Reciprocate T Casing Scraper Across Packer Setting Depth 8,000-8,059 on Joints 271and 272 Several Times, Flush Backside with 20 bbls of Seawater Tripping out of the hole with 7" Casing scraper on 3.5" CS Hydril work string F/ 8,100'to 4,700'. 12/8/2016-Thursday Service Rig, Check fluids in all equipment. Continue to TOOH with 3.5" Work String F/4,700'md to surface.lay down 7" Scraper Assembly. Make up Halliburton 7" Champ Packer(Halliburton Rep Calvin Timothy on location)TIH with Halliburton 7" Champ Packer on 3.5" Work String f/surface to "8.0h5t d. P/U weight= 54klbs, S/0 weight= 25klbs, set PKR on up stroke w/3 rotations to the right, set down string weight on PKR (Good Set). Line up to pump down annulus and fill backside (60bbls to fill annulus). Close 2-7/8" x 5" VBR's and test 7"x 3.5" work stringannulus to2000psi f/30 charted_ mins. (Good Test) Bleed off test pressure, release Halliburton Champ PKR and bullhead 15bbls down annulus. Blow down fluid lines and prepare to POOH. POOH w/ Halliburton Champ PKR on 3.5" work string f/"'8,050'md to 4,700' md, filling pipe with a double displacement every 15 joints. 12/9/2016-Friday Service Rig, Check all fluid levels in equipment. Continue to TOOH with 3.5" Work string&7" Champ Packer F/4700' T/Surface Lay down 7" Champ Packer&XO Load ESP Assembly on Catwalk, Load 234 joints of 2-7/8" Completion Tubing. (Note:These 234 joints were reused from current well F-29) Make up &Service ESP Assembly TIH with ESP Completion picking up 2 7/8" EUE 6.5# L-80 Tubing down to—6,100' md, checking ESP cable insulation every 2,000' md. At joint 192 ("6,100'md) fill tubing and circulate through ESP to ensure flow path is clear. 16bbls needed to catch pressure when filling tubing. Pump through ESP @ 0.5bpm f/3bbls=800psi. Continue to RIH f/6,100'md w/ ESP completion on 2-7/8" EUE 6.5# L-80 TBG down to 8500'md. Check ESP cable insulation every 2,000'md. 12/10/2016-Saturday Make up Reel to Reel splice with ESP cable, (SIMOPS, Load and tally completion tubing on racks) (Note:This 286 joints were used pipe that had been pulled from MPI-12) Continue to TIH with ESP & 2-7/8" EUE 6.5# L-80 Tubing F/8,500'to 16,415' md.Test cable each 2,000' & pump 3 bbls through Pump. (SIMOPS: Killed MPF-53A utilizing little Red Services, Bullheaded 600 bbls of 140 degree Seawater). Notify AOGCC of upcoming BOPE test on F-53A. P/U TBG hanger w/ landing joint and M/U to 2-7/8" EUE 6.5# L-80 TBG.Wellhead Rep Dean Norris on location to M/U TBG hanger and insert penetrator in TBG hanger. Baker Rep mark and cut ESP cable in prep for penetrator splice. Roads and Pads on location to remove ESP spooler from the well row and prep well F-53A for rig arrival. Rig crew begin mobilizing equipment to well F-53A. Baker Rep perform ESP cable splice to penetrator. SIMOPS: Roads and pads level location in front of F-53A and lay down matting. ASR crew mobilize catwalk, pipe racks, support equipment,to F-53A. Land TBG hanger, RILDS, set BPV. R/D, M/O. Release from well F-29 @ 06:OOam. OF TjJ, • • THE STATE Alaska Oil and Gas — p f A T 1 Conservation Commission 11JAsJ���1 1 s -- _ 333 West Seventh Avenue 2'=_ Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OP ALAS*P- Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager N�� r �� Hilcorp Alaska, LLC sats IL 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-29 Permit to Drill Number: 196-117 Sundry Number: 316-600 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, A;' 1L& Cathy ". Foerster Chair DATED this 25 day of November, 2016. RBDms Lc, kuv [ 8 2818 • S • • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS NOV 2 1 2016 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well ElA;O. : CCtdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well El Alter Casing ❑ Other: ESP Change-out ❑f 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development El 196-117 i 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage AK 99503 50-029-22688-00-00 ‘ 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 KR F-29 ' 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): 17,014' 4 7,520' 4 16,768' . 7,348' 1,090 16,908' 16,768(Fill) Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 7,988' 9-5/8" 8,019' 4,480' 5,750psi 3,090psi Production 16,965' 7" 16,994' 7,506' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic 1 See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 16,424' 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 ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory 0 Stratigraphic❑ Development❑✓ ' Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/7/2016 OIL ❑✓ , WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ ❑ SPLUG Commission Representative: GINJ El Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan(a�hilcorp.com Printed Name Bo York Title Operations Manager 7-3,-------------- Signature Phone 777-8345 Date 11/21/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \L.Q - LQUU Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: )E 3000 p.5 c.. SO ( --7 i— iF-" Cs .1^.S Ili ,, 4--- itsz_a)z)/ s',_. - . , 1--,-,),I, Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes El Nod Subsequent Form Required: 1 RBDMS l-I- NOV 2 8 20;6 Approved by: / APPROVED BY in #/21)/c•��� COMMISSIONER THE COMMISSION r< Date: 1!)` �3 111.71,e1, //-ze -( 0 RI I ,/� Submit Form and Form 10-403 Revised 11/2015 4vV'!' a/y"gt valid for 12 months from the date of approval. Attachments in Duplicate . 11 • 0 Milne Point Unit SCHEMATIC Well: MPU F-29 Last Completed: 3/13/2010 PTD: 196-117 flilcora Alaska,LLC TREE&WELLHEAD Orig.KB Elev.:41.24'/GL Elev.:12.1'(N22E) Tree Cameron 2-9/16"5M RT to Tbg.Spool=28.6' (N 22E) 11"x 7-1/16"5M FMC Gen 5A,w/ 2-7/8"FMC Tbg.Hngr.,3"LH LIWellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"BPV CIW Profile 20- "11 OPEN HOLE/CEMENT DETAIL r' 20" 250 sx of Arcticset I(Approx)24"Hole R 1 9-5/8" 1500 sx PF'E',900 sx Class'G',150 sx PF'E'12-1/4"Hole 7" 264 sx Class`G'8-1/2"Hole tit %a CASING DETAIL 4 4 Size Type Wt/Grade/Conn Drift ID Top Btm BPF t', 20" Conductor 91.1/H-40/N/A N/A Surface 112' .0355 r ti 9-5/8" Surface 40/L-80/BTC 8.679 Surface 8,019' 0.0759 fr 7" Production 26/L-80/MBTC 6.151 Surface 16,994' 0.0383 TUBING DETAIL «? 0 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 16,424' 0.00579 WELL INCLINATION DETAIL il et KOP@1,000' ' : Max Hole Angle=77°@ 6,500' 11 i` 70 Deg.+from 4,000'to 14,900' S' Hole Angle through perf interval=46° q (* STIMULATION SUMMARY 95/8 8/31/96-Casing Frac.178.3 M lbs. Hole(s)in Tubing 20/40 and 16/20 Carbolite behind pipe. 4 4-..... Unknown Depth JEWELRY DETAIL No Depth Item 1 130' GLM STA#1:Camco 2-7/8"x 1"KBMM-2 w/DPSOV 2 16,311' AVA Ported Sleeve,ID=2.313"w/Nan-king-Sleeve Removed 6/10/16 3 16,355' Discharge Head:FPDIS 4 16,355' Pump:141-P8/SXD 5 16,371' Pump:141-P8/SXD 6 16,387' Gas Separator:GRSFTXAR H6 Topof Fill @ 7 16,392' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 16,304'C it g f 8 16,399' Lower Tandem Seal:GSB3DBLT SB/SB PFSA 6/10/16 V s Blanking Sleeve 9 16,406' Motor:CL-5 KMH-152HP/2,325V/40A-Rerated 110HP/2152V/31A IVANID=2.313 or; Removed6/10/16 10 16,420' Sensor:Pumpmate XTO-16343 1875"w/ r^= 11 16,422' Centralizer:Bottom @ 16,424' Blanking Sleeve k 2 PERFORATION DETAIL 3 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 4&5 16,545' 16,557' 7,192' 7,201' 12 8/17/1996 Open RA Tag @ 16,563' 16,583' 7,205' 7,219' 20 8/17/1996 Open 16,358'1M.M Kup.A Sands I 6 16,591' 16,609' 7,225' 7,237' 18 8/17/1996 Open 16,609' 16,629' 7,237' 7,251' 20 8/17/1996 Open 7&8 Ref Log: 08/17/96 GR(PFC)/CCL-22gm.Alpha Jet Charges @ 45°/135°Phasing-EHD=0.76"/TTP=6.4" mid-perf=7226'TVD/16,587'MD GENERAL WELL INFO 9 API:50-029-22688-00-00 il. Drilled and Cased by Nabors 22E -7/23/1996 010811 ESP Completion Installed by Nabors 4ES-9/22/1996 eaea RWO ESP by Nabors 4ES 3/26/1998,11/12/1998& 16,768 VbLM on 9/30/2001,3/13/2010 8/18/1996 it RWO ESP by N3S-7/17/2006 RWO ESP by Nabors 4ES-3/13/2010 t ,-KUPASarxls NOTE i Y', 5 * ESP lowered into well to check perfs or TD=17,014'(MD)/TD=7,520'(TVD) TD to 16,701'on 3/10/2010 RWO.No PBTD=16,908'(MD)/PBTD=7,446r/D) fill evident. Revised By TDF 11/21/2016 14 • Milne Point Unit • PROPOSED Well: MPU F-29 Last Completed: 3/13/2010 lli(carp Alaska,LLC PTD: 196-117 TREE&WELLHEAD Orig.KB Elev.:41.24'/GL Elev.:12.1'(N22E) Tree Cameron 2-9/16"5M RT to Tbg.Spool=28.6' (N 22E) 11"x 7-1/16"5M FMC Gen 5A,w/ 2-7/8"FMC Tbg.Hngr.,3"LH '� Wellhead (, r. iAcme on top and 2-7/8"EUE 8rd on bottom,2.5"BPV CIW Profile 2l7 OPEN HOLE/CEMENT DETAIL tt i 20" 250 sx of Arcticset I(Approx)24"Hole 1 9-5/8" 1500 sx PF'E',900 sx Class'G',150 sx PF'E'12-1/4"Hole 7" 264 sx Class'G'8-1/2"Hole li CASING DETAIL 0 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 91.1/H-40/N/A N/A Surface 112' .0355 t1'1" 9-5/8" Surface 40/L-80/BTC 8.679 Surface 8,019' 0.0759 E 7" Production 26/L-80/MBTC 6.151 Surface 16,994' 0.0383 "# TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface ±16,424' 0.00579 WELL INCLINATION DETAIL at;' KOP @ 1,000' a 0 Max Hole Angle=77°@ 6,500' t. oi4 70 Deg.+from 4,000'to 14,900' a Hole Angle through perf interval=46° fi STIMULATION SUMMARY 9-5/8" 08/31/96-Casing Frac.178.3 M lbs. 20/40 and 16/20 Carbolite behind pipe. JEWELRY DETAIL No Depth Item 1 ±130' GLM STA#1:Camco 2-7/8"x 1"KBMM-2 w/DPSOV 2 ±16,311' AVA Ported Sleeve,ID=2.313"w/0la Sleevc Removed 6/10/16 3 ±16,355' Discharge Head:FPDIS 4 ±16,355' Pump:141-P8/SXD 5 ±16,371' Pump:141-P8/SXD 6 ±16,387' Gas Separator:GRSFTXAR H6 7 ±16,392' Upper Tandem Seal:GSB3DBUT SB/SB PFSA La ,0 8 ±16,399' Lower Tandem Seal:GSB3DBLT SB/SB PFSA 9 ±16,406' Motor:CL-5 KMH-152HP/2,325V/40A-Rerated 110HP/2152V/31A 10 ±16,420' Sensor:Pumpmate XTO-16343 k 'i 11 ±16,422' Centralizer:Bottom @±16,424' Ila 2 PERFORATION DETAIL 3 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status s 4&5 16,545' 16,557' 7,192' 7,201' 12 8/17/1996 Open RA Tag 114 16,563' 16,583' 7,205' 7,219' 20 8/17/1996 Open 16,358'V1iM Kup.A Sands 1111 6 16,591' 16,609' 7,225' 7,237' 18 8/17/1996 Open 16,609' 16,629' 7,237' 7,251' 20 8/17/1996 Open 7&8 Ref Log: 08/17/96 GR(PFC)/CCL-22gm.Alpha Jet Charges @ 45°/135°Phasing-EHD=0.76"/TTP=6.4" mg 1 Mid-perf=7226'TVD/16,587 MD 64 GENERAL WELL INFO s !e API:50-029-22688-00-00 1 Drilled and Cased by Nabors 22E -7/23/1996 t1D&11 ESP Completion Installed by Nabors 4ES-9/22/1996 ki kt RWO ESP by Nabors 4ES 3/26/1998,11/12/1998& 16,768''AIM on ali f1' 9/30/2001,3/13/2010 8/18/1996 )+ RWO ESP by N3S-7/17/2006 KUPASands RWO ESP by Nabors 4ES-3/13/2010 ) 0 NOTE 7 , V > j ESP lowered into well to check perfs or TD=17,014'(MD)/TD=7,520'(TVD) TD to 16,701'during 3/13/2010 RWO. PBTD=16,908'(MD)/PBTD=7,446'(TVD) No fill evident. Revised By TDF 11/21/2016 • • II EXISTING TREE/WELLHEAD Wellhead/Tree iiacorn Alaska,r.Ic Milne Point Unit Tree Cap �.E nil <I --”ii.!I IO , Tree Valve 2-9/16" 5M Prrrz©�O ' —1111111110... Tree Cross 2-9/16" 5M oho)0) Tree Valve 2-9/16" 5M my SSV 2-9/16" 5M O 'A.. 1111 Wis p a Heat Trace Tree Valve 2-9/16" 5M 6 i o:) - 0 0o - ESP Cable . , Tubing Adapter a—■ I mom. Tubing Head lift— Nil 11" 5M Top x11" 5M Btm = �u l�)11111 01.ZE W ii .11 ' : illi m--,- t!E" sE �',` Casing Head i ami l 11" 5MTopx11" 5MBtmI�III� ! 191i INiii,f, i III ". ,fir • • • ii Milne Point ASR Rig 1 BOPE lbkrnp Al*Ak..1.AA. 11" BOPE Stripping Head ifill 1 3.98' air / Shaffer 11" - 5000 it fti Iii hilt"! 0 U1Jli1 i 4J P1 /-41-7141 CI t -U P 4.54' v H VBR or Pipe Rams '4-111"-5000 H H Blind r Cl Ill a `1 ril 2 1/16 5M Kill Line Valves 21/16 5M Choke Line Valves I 2.00' li- i , � , , f 4----i-LI tijittil 11-0/41)11 1 coli i , i k) I i \ f_,_--IT IL31T_l..l.ltl__1. iri N 1 119k i 1 Manual Manual Manual HCR Updated 8/19/2015 • • Well Prognosis Well: MPU F-29 Hilcorp Alaska.L L' Date:11/21/2016 Well Name: MPU F-29 API Number: 50-029-22688-00 Current Status: Oil Well [Failed ESP] Pad: Estimated Start Date: December 7th, 2016 Rig: ASR Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-117 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number. ;w '3'' _- Job Type: ESftfte,pair Current Bottom Hole Pressure: 1,790 psi @ 7,000' TVD (SBHPS 11/16/2016/4.93 ppg EMW) Maximum Expected BHP: 1,790 psi @ 7,000' TVD (No new perfs being added) w MPSP: 1,090 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-29 was drilled in July 1996,fracture stimulated in August, and completed in September 1996 as a Kuparuk River producer. ESP installation history: September 1996 (initial), March 1998, November 1998, September 2001,July 2006, and March 2010. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing was not tested at the last ESP change out in 2010. • 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. Objective: 5� p� Replace failed ESP. 1'6 //-2_7 14 Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • Well Prognosis Well: MPU F-29 liilearp Alaska,Lb Date: 11/21/2016 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/Z, 5 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" and 3-1/2" test joints. 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. 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 s anywhere at surface.) ce 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 2010 ESP swap was 100K lbs. (block weight not noted) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. c. Contingency Casing Jack Procedure: If the tubing hanger will not come off seat or the ESP will not come off bottom after circulating lubricant, RU casing jacks as follows: i. PU Casing Jacks via the beaver slide and Tugger winches to rig floor ii. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. iii. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point iv. 100%Yield strength of 2-7/8", 6.5#, L-80= 145K lbs v. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 16. Recover the tubing hanger. • • Well Prognosis Well: MPU F-29 Metal>Alaska.LL Date: 11/21/2016 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 failed ESP. a. Lay down bad joints as indicated by tubing tally run November 17, 2016: i. Joints 90 through 365 ii. Joints 393-398 and 457 -464 b. Replace bad joints of tubing as necessary and note on tally new tubing run. c. Look for over-torqued connections from previous tubing runs. 18. PU & RIH with 7" 26#scraper assembly to—8,100' MD on 3-1/2" workstring. Reciprocate scraper across packer setting depth of 8,050' MD. Circulate the well clean. 19. POOH. L/D scraper assembly and 3-1/2" workstring. 20. PU test packer and RIH on 3-1/2" workstring to—8,050' MD. 4 21. Set test acker and pressure test 9-/8" casi1gsito 2000 for 30 charted minutes. tit (' 22. Unseat test packer and POOH LDDP. 23. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at± 16,424' MD. a. Upper GLM@ ± 130' MDw/SO 0 b. AVA Ported Sleeve @ ±16,311' MD j c. Base of ESP centralizer @ ± 16,424' MD 24. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 25. Set BPV. Post-Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. 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 MOC Form 0 • r . 0., _ cp a) d ? (a a) * - 0 � 3toC o a) U to C 0 co 2 Qa ° = a) aQ E• rn O . -0 0 o C ; RS 0 0 Y0 = ani 2Qv L •- w C L a) Y m To a) a: = ,_• 'L 2aQi Q L alm am o & 0 0 cn c a) as rn_c C o (E N t L U --, CD L o 13 > 0 iii m o CD w L om N > a3 a C C Q L ea a, • O L a) L 0 a) i E N d o 0 dO '' La)2 a) nmc o• � (teac_ II N am d R = aQ N O c Y 0 0 0 C� Q d (B O C C xCn Q .0 m o 0 0 ^ 1 O d C C c L L d .< #ei > CO o o a) m a) Ri 0- 0 0- V O *k `= Q .= 1.1 MCD 0 o 0 > a) CL •1--1 .0 w c N 2Q o V o in con CO Q a` STATE OF ALASKA AKA OIL AND GAS CONSERVATION COASION ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing❑ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 9rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: CT FCO ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: N 2- Hilcorp Alaska LLC Development 0 Exploratory ❑ 196-117 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22688-0S�It ECE1VED 7.Property Designation(Lease Number): '8.Well Name and Number: ADL0355018 MILNE PT UNIT KR F-29 JUN 3 0 2016 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A 1MILNE POINT/KUPARUK RIVER OIL y� 4.,r C�r"r. 11.Present Well Condition Summary: s'"'� Total Depth measured 17,014 feet Plugs measured 16,768 feet true vertical 7,520 feet Junk measured 16304(FILL) feet Effective Depth measured 16,304 feet Packer measured N/A feet true vertical 7,025 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 7,988' 9-5/8" 8,019' 4,480' 5,750psi 3,090psi Production 16,965' 7" 16,994' 7,506' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 16,424' 7,108' 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 FEB @ (al? 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 0 360 0 Subsequent to operation: 0 0 0 200 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development El Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-276 Sof' -r.„-1,,A c.%., Contact Paul Chan Email pchan C(�hilcorp.com Printed Name Bo York Title Operations Engineer Signature . Phone 777-8345 Date 6/27/2016 7127 /4 Form 10-404 Revised 5/2015 Ai 6 ` RBDMS vi JUL 0 6 2016 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-29 CTU 50-029-22688-00-00 196-117 6/8/16 6/10/16 Daily Operations: 6/8/2016—Wednesday Hold safety meeting discuss JSA and job procedures. Pick injector head.Stab lubricator. Make up coil connector. Stab on well. Fluid pack CT 1.75"tapered string. 34 bbl reel volume. Start BOPE test.Test all rams and valve to 250/3,500psi. Draw down test completed. BOPE test complete. Blow down stack. Pop off well Instal remaning BHA. Coil connector, BPV, DISCO, Weight bar,Weight bar,Wash nozzle.All OD 1.75". BHA length 8'. Pressure test stack to 250/3,500psi. Open master swab 14.5 turns. SSV open and blocked with fusible cap. RIH. Intial WHP 280psi gas cap. Bleed down to zero. Small stream of fluid at tank while RIH. RIH at 80 ft/min and perform weight checks every 3,000'. Clean pick up weights and RIH weights.Start pumping at 7,000' at .5 bbls/min. No indication of returns. Call pad op to attempt to fire up ESP pump. Ct parked at 9,222'. ESP pump online. Ct circluating at 1.5 bbls/min. Returns at surface after 12 minutes of pumping. 2 bbls a minute at return tank. Pumping bottoms up from 9,220' of 24 bbls. Start chasing OOH. OOH weight 18k. Noticed overpull to 28k. Couldn't RIH either. IH weight 1,000lbs stack to-10k. Could have sand pile behind CT. Over pull to 32k. Coil pops free and starts POOH at 18k normal weight. Returns slowing down and stopped. POOH at 100 ft/min. Continue to circluate at 1.5 bbls/min. No returns ever established after pulling out of fill. Dispatched N2 truck for tomorrow and Gel transport.Tagged up at surface. Close master and swab. 190 bbsl pumped down hole.Total pumped for day 260 bbls. (BOPE test and fluid pack) blow down stack. Pop off well. Halliburton dispatched mechanics.Tractor and powerpack has variation in RPM's. All ground valves closed and wellhead isolated. SDFN. 6/9/2016-Thursday Hold safety meeting. Discus JSA and job procedure. Pick injector head. Make up bha. Coil Connector, BPV, DISCO, 2x weight bar,Jet swirl nozzle. BHA OD 1.75" Total length 8'. Stab on well. PT stack 250/3,500psi. Open well. RIH, Initial WHP 280psi. IA pressure 280psi. Bleed down tubing to 0 psi, cool down N2. 5,000' come online with n2 while POOh. Shot backside fluid level with echo meter indicating fluid level at 2,700'. N2 returns to surface. 3 bbls of water unloaded. Rlh from 2,700' IA pressure at 190psi. Continue in hole. Increase rate to 1,000 scf/min. 1,675psi circulating pressure. Good fluid and nitrogen returns to tank. Online with fluid pump at.5 bbls/min.Sending 5 bbls of gel and 10 bbl of 1% KCI spacer. Repeat pump procedure for whole job. Continue RIH performing weight checks every 3,000'. Return tank strap looks as if we are getting 1:1 returns. Weight check at 8,790' 13k. IA pressure climing to 1,475psi. OA pressure 160psi. Continue in hole3 Wt chk at 9,650' 15k clean. Rih WT-3,800Ibs. Sample of returns indicate trace of sand.Wt chk at 10,500' 16k clean. 200'wiper trip. Continue IH. Stack weight at 10,563'- 10,593'. Loss ROP weight does break back. Increase fluid pump rate to .8 bbls/min and 800 scf/min. Good returns at surface. Stacking wieght again at 10,956'. Pu wt 16k. Continue in hole at 20 ft/min. Weight stacks 5k and breaks back to RIH weight of-4200 lbs from 10,593'-11,075'. Stacking-8k then weight breaks back. IA pressure 1,400psi/OA 300psi. Continue in hole. Look to be friction bite and no solids. Stack-18k@ 11,744'. PU to 9,800' wiper trip. No heavy solids in returns. Stop pumping gel. Circulate wellbore with 1% KCL only. Halliburton suggests gel causes more friction. Mixed up Friction Reducer and increase fluid pump rate to 1 bbl/min and 800 scf/min.Trip back IH. Circulating pressure 4,271psi. Rlh with no gel and friction reducer. Not able to pass 10,960'. Decided to POOh to surface. 5000' shut down fluid pump and N2 pump. Total bbls pumped 256.Total N2 pumped 4,000 gallons.Tagged up at surface. Close master and swab. Opsi on wellhead. Bleed down CT string. Blow down stack. Pop off well. Break down lubricator. Set injector head down. Lay down Crane. Close all ground valves and shut down equipment. Wellsite secure. SDFN. 6/10/2016 Friday • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-29 CTU 50-029-22688-00-00 196-117 6/8/16 6/10/16 Daily Operations — Hold safety meeting. Discuss JSA and job procedures.;Pick injector head. Stab 10' lub and 5' lubricator. Pack offs changed. Install Pull plate on existing Halliburton cold roll connector. Pull test to 20k. Make up MHA as follows from top to bottom. 1.8 OD CC, 1.7" OD DFCV, 1.7" OD Accelerator, 1.7" OD Dual Acting Jars, 1.69" OD Hyd Disco with .5" ball for disco. 1.69" XRV, 2"xo sub, 2.25" OD G spear. Total BHA length 14.29';Pressure test MHA to 250/3500 psi. Good PT. Bleed off to bleed tank. Stab on well. Lined up to pressure test stack 250/3500 psi.;RIH. Initial whp 540 psi. IA 700, OA 75 psi. Continue in hole performing weight checks every 3000'. WT chk @ 6500' 16k. RIH not pumping will attempt dry tag. WT chk @ 7500'. 17.6k. Clean . Rlh WT. 2k.;Wt chk 8500' 18.6 K . Clean. RIH wt,3400 lbs rih wt. 9500' 20k. Clean, Rlh wt 2090 lbs. Wt chk at 11500' 23k. Continue IH. RIH WT 4500 lbs.;Start seeing weight stack of 2k @ same depth as previous day11,744' . Continue in Hole . Plck up wt at 12,000' 24.6k clean. Continue IH. RIH wt 3500 lbs. 300 la pressure 40 OA. 13,000' WT CHk. 27K. weight check. WT chk @ 14,000' 28.7k Clean. RIH WT 2000 lbs At 14,400'.;WT chk @ 15,000' 32.5k Clean. RIH wt @ 15,200' 1900 lbs. Clean. 16,000' wt chk. 35k. clean.;RIH to stack weight at AVA sleeve. Set down 10k at 16,304' CT depth. Pick up. 45k. 10k over. Saw jar lick. PU clean. RIH stack 10k down on AVA sleeve. Pick up to 45k then breaks over and pulling ooh heavy 4K over normal string weight.;POOH. consistent 4k over pull all the way OOH. Tagged up at surface. Master swab closed. Blow down stack. Pop off. AVA valve recovered. Total BBLS pumped 30. SITP 0 psi. IA 189 psi OA 40 psi. 6/11/2016 Saturday No activity to report. 6/12/2016-Sunday No activity to report. 6/13/2016- Monday No activity to report. 6/14/2016-Tuesday No activity to report. tll 0 0 Milne Point Unit Well. MPU F-29 SCHEMATIC Last Completed: 3/13/2010 Hilcorp Alaska,LLC PTD: 196-117 TREE&WELLHEAD Orig.KB Elev.:41.24'/GL Elev.:12.1'(N22E) Tree Cameron 2-9/16"5M RT to Tbg.Spool=28.6' (N 22E) 11"x 7-1/16"5M FMC Gen 5A,w/ 2-7/8"FMC Tbg.Hngr.,3"LH Wellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"BPV CIW Profile 2a 1 i* OPEN HOLE/CEMENT DETAIL C. �+ 20" 250 sx of Arcticset I(Approx)24"Hole 1 ,,, '° 9-5/8" 1500 sx PF'E',900 sx Class'G',150 sx PF`E'12-1/4"Hole 7" 264 sx Class'G'8-1/2"Hole 'ate': `� c+'. CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF #. 20" Conductor 91.1/H-40/N/A N/A Surface 112' .0355 A 9-5/8" Surface 40/L-80/BTC 8.679 Surface 8,019' 0.0759 tt7" Production 26/L-80/MBTC 6.151 Surface 16,994' 0.0383 TUBING DETAIL ( 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 16,424' 0.00579 ( WELL INCLINATION DETAIL r. KOP @ 1,000' ,,v, , Max Hole Angle=77°@ 6,500' 11 70 Deg.+from 4,000'to 14,900' i. Hole Angle through perf interval=46° r STIMULATION SUMMARY 9-5/8` 8/31/96-Casing Frac.178.3 M lbs. Hole(s)in Tubing 20/40 and 16/20 Carbolite behind pipe. al Unknown Depth JEWELRY DETAIL No Depth Item 1 130' GLM STA#1:Camco 2-7/8"x 1"KBMM-2 w/DPSOV 2 16,311' AVA Ported Sleeve,ID=2.313"w/Blanking Sleeve Removed 6/10/16 3 16,355' Discharge Head:FPDIS 4 16,355' Pump:141-P8/SXD 5 16,371' Pump:141-P8/SXD 6 16,387 Gas Separator:GRSFTXAR H6 7 16,392' Upper Tandem Seal:GSB3DBUT SB/SB PFSA Blanking Sleeve 8 16,399' Lower Tandem Seal:GSB3DBLT SB/SB PFSA MIN ID=2.313"or g + Removed 6/10/16 9 16,406' Motor:CL-5 KMH-152HP/2,325V/40A-Rerated 11OHP/2152V/31A 1.875"w/ BlankingSleeve 10 16,420' Sensor:Pumpmate XTO-16343 11 16,422' Centralizer:Bottom @ 16,424' I 'z PERFORATION DETAIL MK 4 s Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status t L ,4&5 16,545' 16,557' 7,192' 7,201' 12 8/17/1996 Open RATag@ E4 16,563' 16,583' 7,205' 7,219' 20 8/17/1996 Open 16,358'VbLM ° Illi 6 Kup.A Sands 16,591' 16,609' 7,225' 7,237' 18 8/17/1996 Open x 16,609' 16,629' 7,237' 7,251' 20 8/17/1996 Open 7&8 Ref Log: 08/17/96 GR(PFC)/CCL-22gm.Alpha Jet Charges @ 45°/135"Phasing-EHD=0.76"/TTP=6.4" 0° 7Mid-perf=7226'TVD/16,587'MD 0 I . GENERAL WELL INFO 9 API 50 029 22688 00 00 t Drilled and Cased by Nabors 22E -7/23/1996 f ,1 X10&11 ESP Completion Installed by Nabors 4ES-9/22/1996 14 1 13 RWO ESP by Nabors 4ES 3/26/1998,11/12/1998& 16,768'VLM on 9/30/2001,3/13/2010 8/18/1996 :# • RWO ESP by N3S-7/17/2006 RWO ESP by Nabors 4ES-3/13/2010 }KUP A Sands CT FCO-6/10/2016 TD=17,014'(MD)/TD=7,520'(TVD) NOTE PBTD=16,908'(MD)/PBTD=7,446'(TVD) ESP lowered into well to check perfs or TD to 16,701'during 3/13/2010 RWO Revised By STP 6/28/2016 OFT • • yw�ti\�i y7,-,s THE STATE Alaska Oil and Gas ' -- � ®fsKA LAConservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OSA Fax: 907.276.7542 www.aogcc.alaska.gov Bo York HEV SEP 2: 8X016 Operations Manager SCh Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-29 Permit to Drill Number: 196-117 Sundry Number: 316-276 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, Cathy P. Foerster Chair DATED this day of May, 2016. RBDMS LMAI 3 1 2016 • • 'RECEIVED .. • STATE OF ALASKA MHy ] 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 512.5f/6 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 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: Coil Fill Clean-out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. r 1i_- Hilcorp Alaska LLC ' Exploratory ❑ Development Q 196-117 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Dr,Suite 1400 Anchorage AK 99503 50-029-22688-00-00 ' 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 Ej / MILNE PT UNIT KR F-29 ' 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): 17,014' - 7,520' , 16,908'. 7,446'. 320 16,908' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 7,988' 9-5/8" 8,019' 4,480' 5,750psi 3,090psi Production 16,965' 7" 16,994' 7,506' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 16,424' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary En Wellbore schematic ©' 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic ❑ Development 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/31/2016 Commencing Operations: OIL Q . 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 r-- herein will not be deviated from without prior written approval. Contact Paul Chan Email pchanehilcorp.com Printed Name j' Bo York Title Operations Manager Signature _� -"t`" �1 rid/le-- Phone 777-8345 Date 5/12/2016 COMMISSION USE ONLY Conditions o approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test [ ' Mechanical Integrity Test ❑ Location Clearance ❑ Other: '' . ,S--0v l5 L. sly' /c,: f- r) Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS V'- MAY 3 1 2016 Spacing Exception Required?. Yes ❑ No Subsequent Form Required: /O" ! 0 il APPROVED BY Approved by: t7 COMMISSIONER THE COMMISSION Date: -25_<� 5-16- l �/�v3 3�13�IS 3 JJJ AL `�� Submit Form and Form 10-403 Revi d 11/2015 Chat GINor 12 months from the date of approval. Attachments in Duplicate • •• • Well Prognosis Well: MPU F-29 Hilcora Alaska,LL Date:5/11/2016 Well Name: MPU F-29 API Number: 50-029-22688-00 Current Status: SI Oil Well Pad: F-Pad Estimated Start Date: May 31St, 2016 Rig: CTU Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-117 First Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Current Bottom Hole Pressure: 1,461 psi @ 7,000' TVDss (SBHPS 08/05/2013/4.01 ppg EMW) Maximum Expected BHP: 1,461 psi @ 7,000' TVDss (No new perfs being added) MPSP: 320 psi (SITP) Brief Well Summary: MPU F-29 was drilled in July 1996, fracture stimulated in August and completed with an ESP in September 1996. The well has had multiple ESPs installed: September 1996 (initial), March 1998, November 1998, September 2001, July 2006, and March 2010. The well quit surfacing fluid even though the ESP is still operational and slickline was unable to bail past 4,303' MD due to hole deviation and sand in the tubing_ Hole angle is 70.7°—77.1°from 4,000'to 14,700' MD.s Obiective: Perform a CT FCO to the top of the ESP at 16,355' MD (or as deep as possibleLand return the well to production. If the ESP still will not surface fluids, check tubing for integrity. If a hole is found in the tubing and can be repaired, another 10-403 sundry will be submitted. Coil Tubing Procedure , I V' 1. MIRU CTU and tanks. 2. NU CT BOPE. Perform initial pressure test to 250 psi low and ,.O01psi high. Subsequent pressure tests will be to 250 psi low/3500 psi high. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures are per the approved Sundry. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. PU lubricator. MU and test coil connector. MU coil cleanout BHA. 4. Stab lubricator onto tree and pressure test to 250 psi low/3500 psi high. 5. Open tree and count turns on valves. Record in Ops cab. Start RIH and perform weight checks as needed 6. RIH with CT and attempt to dry tag. Maximum slickline depth reached was 4,303'SLM. 7. Clean out fill down to 16,355' MD with seawater and N, as needed._Add lubricant as needed. Come online with N2 at 800-1500 SCF/min and fluid rate of 1.5 BPM. Cleanout to top of ESP at 16,355' MD. Adjust N2 and fluid rate accordingly. Watch returns. Strap return tanks to ensure 1:1 returns:pumped. Adjust rates accordingly. 8. Once top of ESP is reached continue to circulate bottoms up. 9. Start POOH. Come offline with N2 and fluid. Bleed N2 down. POOH with CT. • ! Well Prognosis Well: MPU F-29 Hileorp Alaska,Lb Date:5/11/2016 10. RDMO CTU. 11. Turn well over to production. Attachments: 1. Well Schematic 2. CTU BOPE/Tree/Wellhead Schematic 3. Standard Well Procedure:Nitrogen Operations • 4. Flow diagram: Nitrogen • • Milne Point Unit . firSCHEMATIC Well: MPU F-29 Last Completed: 3/13/2010 Hilcorp Alaska,LLC PTD: 196-117 TREE&WELLHEAD Orig.KB Elev.:41.24'/GL Elev.:12.1'(N22E) Tree Cameron 2-9/16"5M RT to Tbg.Spool=28.6' (N 22E) 11"x 7-1/16"5M FMC Gen 5A,w/ 2-7/8"FMC Tbg.Hngr.,3"LH Wellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"BPV CIW Profile :k �tii?,20 OPEN HOLE/CEMENT DETAIL C, ^^ 20" 250 sx of Arcticset I(Approx)24"Hole 1 eF 9-5/8" 1500 sx PF'E',900 sx Class'G',150 sx PF'E'12-1/4"Hole .= 7" 264 sx Class'G'8-1/2"Hole 1 ,: CASING DETAIL p Size Type Wt/Grade/Conn Drift ID Top Btm BPF ,. *P. 20" Conductor 91.1/H-40/N/A N/A Surface 112' .0355 lo 9-5/8" Surface 40/L-80/BTC 8.679 Surface 8,019' 0.0759 q', * 7" Production 26/L-80/MBTC 6.151 Surface 16,994' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 16,424' 0.00579 , WELL INCLINATION DETAIL LIKOP @ 1,000' l Max Hole Angle=77°@ 6,500' 70 Deg.+from 4,000'to 14,900' I Hole Angle through perf interval=46° r' m ± STIMULATION SUMMARY 9./85 8/31/96-Casing Frac.178.3 M lbs. 20/40 and 16/20 Carbolite behind pipe. JEWELRY DETAIL No Depth Item 1 130' GLM STA#1:Camco 2-7/8"x 1"KBMM-2 w/DPSOV P( ` 2 16,311' AVA Ported Sleeve,ID=2.313"w/Blanking Sleeve ID=1.875" J7 \r'�- 3 16,355' Discharge Head:FPDIS '‘w • 4 16,355' Pump:141-P8/SXD 5 16,371' Pump:141-P8/SXD 6 16,387' Gas Separator:GRSFTXAR H6 7 16,392' Upper Tandem Seal:GSB3DBUT SB/SB PFSA k , ": 8 16,399' Lower Tandem Seal:GSB3DBLT SB/SB PFSA MIN ID=2313''or 9 16,406' Motor:CL-5 KMH-152HP/2,325V/40A-Rerated 110HP/2152V/31A Blanking Sleeve t4 10 16,420' Sensor:Pumpmate XTO-16343 1 11 16,422' Centralizer:Bottom @ 16,424' i PERFORATION DETAIL / Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status (i; 4&5 16,545' 16,557' 7,192' 7,201' 12 8/17/1996 Open R/+Tag t 1, 16,563' 16,583' 7,205' 7,219' 20 8/17/1996 Open 16,358'VVLMKup.A Sands I 6 16,591' 16,609' 7,225' 7,237' 18 8/17/1996 Open 16,609' 16,629' 7,237' 7,251' 20 8/17/1996 Open '„, 7&8 Ref Log: 08/17/96 GR(PFC)/CCL-22gm.Alpha Jet Charges @ 45°/135°Phasing-EHD=0.76"/TTP=6.4" Mid-pert=7226'TVD/16,587'MD WELL INFO '9 API:50-029-22688-00-00 li Drilled and Cased by Nabors 22E -7/23/1996 10&11 ESP Completion Installed by Nabors 4ES-9/22/1996 11 1 RWO ESP by Nabors 4ES 3/26/1998,11/12/1998& 16,765 VILM on 9/30/2001,3/13/2010 8/18/1996 RWO ESP by N3S-7/17/2006 11 _A_,_1! RWO ESP by Nabors 4ES-3/13/2010 4 .KUPASands NOTE r' � w r ESP lowered into well to check perfs or TD=17,014'(MD)/TD=7,520'(TVD) TD to 16,701'during 3/13/2010 RWO PBTD=16,908'(MD)/PBTD=7,446'(TVD) Revised By TDF 5/12/2016 • • Milne Point Unit COIL BOPE MPU F-29 5/02/2016 Hii.nrp,%hs4 .LLC MPU F-29 20 x 9% x 7 x 278 Coil Tubing BOP Lubricator to injection head 6 O 1.75"Single Stripper 1 f , •',I. BlindMi _31/1615 in= Blind All 1 •I11I110 !� ! h1 _hhh1 - Oma _ c 0 __ Slip Ml Slip •I,I• I ill" Pipe _ - Pipe ,I,I• 1 I I Crossover spoolsi 41/16 15M X41/16 10M Crossover spool1 4 1/16 10M X 4 1/16 5M , r....., ...... r i I 6 Pump-In Sub III . . o {1,1111 (° F��:�(,( � ) MIN 1502 Union M.Crossover spool Manual Gate Manual Gate 4 1/16 5M X 2 9/16 5M 2 1/8 5M 2 1/8 5M alkataMMOMM Valve,Swab,WKM-M, t,,, -,� �0 2 9/16 5M FE � -� w 4- � H'0),e,. dal.le 9��(') B 1 A Valve,Upper Master,Baker, Oo v 2 9/16 5M FE,w/Hydraulic tworrr Valve,Lower Master,WKM-M, "*a 2 9/16 5M FE 14211, .. 1®i Tubing Adapter,2 9/16 5M °AM S 0 1- 0 i Ft L.9 c._ R c 0_ c g:z a z 8 u'I ,,,co''' ''> ' i2 0 =w o cc cc •. . ;-... = Lu cc w c ..J 7,, ''-ci: c. . 4. > ID 2 <1 711 a 0 L!, 2 ,..., . v, — 2 • z : "•• D • - . V 0 > bp r..• C -a '74 • D. •••• W ,.. U > cr, -6 ,;, > CD . .,.. .. -0 Z ... ',.,..,..._ . !,„,..• 't ' : 1..•,, ..4 ,,,_ ... • II" : tw „..._ ... ...„.......„. . • L.)-` P11,1 I. 4 ••• ; • 11.11 •.1 PO. 0 11,....:it,......11 .•41 En ..ik Via °., .4,1+o• A r a+ • i -:- — :I „ 71 Imi vIf- . \--". L• ir . ';.,4•••'"-i..: I • Mill'a i-rp 41 P.--..--1 ti.J..,..rnr-2,NTI,o.• A-.U1 .-..‘c. I, 4. 1411_41.„up,„-vi i,447)1134A — 'it*:f ini mii ini <-4 i i 1. 1 NJ 2 LIJ < 42 .. ... .q. 11.1 ,... CC C. 5, 5, 5 5. L.,. – , :-, 0 0 a a ctt.w co 01– o cc 0, a 7 , / ,./ z < I- C L.11 `.: 23 ' • • STANDARD WELL PROCEDURE lliknrp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder /_ - Alaska Oil and Gas Conservation Commission l l�J 333 West 7 Avenue 3,9 Anchorage, Alaska 99501 ei Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator ......gym ;. rt' ., .�.,- .ter..- e...;*yw.o_,. .. • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF -09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 ---p. MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF -46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 WA 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 NA 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 WA 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/312011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 NA 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/122011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF-89 2050900 50029232680000 1.2 NA 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 WA 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 ALAS IL AND GAS CONSERVA ON COMM N ~~~~E® REPO~OF SUNDRY WELL OPERA~ONS APR 0 5 ~ 2010 1. Operations Performed: g ' ' ~ ~ ~~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate en ^ Re-Enter S usp ^ 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 196-117 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22688-00-00 7. Property Designation: ~ 8. Well Name and Number: 1 ADL 355018 \ MPF-29 9. Field /Pool(s): Milne Point Unit / Kuparuk River Oil Pool 10. Present well condition summary Total depth: measured 17014 feet true vertical 7520 feet Plugs (measured) None Effective depth: measured 16908 feet Junk (measured) None true vertical 7446 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 7988' 9-5/8" 8019' 4481' 5750 3090 Intermediate Production 16965' 7" 16994' 7506' 7240 5410 Liner Perforation Depth: Measured Depth: 16545' - 16629' True Vertical Depth: 7192' - 7251' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 16433' 7114' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: Intervals treated (measured): r:$t;~w~~~~ ~1 ~ I{ '~ ~ ~ tr~ k 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: 101 10 105 340 312 Subsequent to operation: 42 3 403 400 317 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service Re ort of Well O erations ® Dail y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Terrie Hubble Title Drilling Technologist e ~ Prepared By Name/Number. Signature Phone 564-4628 D at ~~ Tercie Hubble, 564-4628 Form 10-404 Revised 07/2009 ~ Submit Original Only RBDMS APR a~ YO'~ =~~\ ~- `/•~ •!~ ,~ ~~/,~ • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-29 Common Well Name: MPF-29 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT Start: 2/22/2010 Rig Release: 3/13/2010 Rig Number: 4ES Page 1 of 6 Spud Date: 7/3/1996 End: 4/30/2010 Phase Description of Operations 3/6/2010 15:00 - 00:00 9.00 RIGD N WAIT PRE PREP FOR LD DERRICK WAITING ON PEAK SOW TIED UP ON RIG MOVE FOR RIG141. 3/7/2010 00:00 - 15:30 15.50 RIGD N WAIT PRE PREP FOR L/D DERRICK WAITING ON PEAK SOW TIED UP ON RIG MOVE FOR RIG141. -REPLACE TUGGER LINE. -SCOPE AND UD DERRICK. -ASSIST LITTLE RED WITH FREEZE PROTECTING THE WELL WHILE WAITING. ***CHUCK SCHEVE, AOGCC, WAIVED WITNESS OF THE BOPE TEST FOR F-29 AT 08:35 *** 15:30 - 19:00 3.50 MOB P PRE PEAK TRUCKS ON LOCATION AT 15:30 HRS. -PULLED OFF OF MPL-36A AT 16:20. -WAIT 30 MIN FOR MPU TO PULL GUARDRAIL ON MPF PAD. 19:00 - 22:30 3.50 MOB P PRE MOVE TO MPU F PAD SPOT SUB OVER WELL, SPOT PIPE SHED AND PITS. 22:30 - 00:00 1.50 RIGU P PRE RU UP RIG CONNECT FLOW LINES ,TIGER TANK ,CUTTING BOX, FUEL TRAILER. 3/8/2010 00:00 - 02:00 2.00 RIGU P PRE RAISE AND SCOPE DERRICK ACCET RIG AT 02:00 HOURS 02:00 - 03:45 1.75 RIGU P PRE FILL PITS RU FLOOR. 03:45 - 05:30 1.75 BOPSU P PRE RU LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PULL BPV. 200 PSI TUBING,300 PSI ANNULUS AND 50 PSI ON OUTER ANNULUS. TEST LINE TO TT TO 150 PSI AND TEST RIG LINES TO 3500 PSI. 05:30 - 10:15 4.75 BOPSU P PRE BULL HEAD WELL KILL -1.5 X WELLBORE VOLUME: -PUMP DOWN TUBING W/ 8.5 PPG, 120 DEG F SEAWATER. -380 STKS (22.4 BBLS) TO CATCH FLUID. -SHUT-IN ANNULUS AND BULL HEAD DOWN TUBING. -PUMP A TOTAL OF 1700 STKS (100 BBLS) ~ 2000 PSI. -SHUT-IN TUBING AND BULL HEAD DOWN IA W/ 8.5 PPG, 120 DEG F SEAWATER. -PUMP A TOTAL OF 14000 STKS (823 BBLS) ~ 1750 PSI. -923 BBLS TOTAL PUMPED DURING BULL HEAD KILL. -BLEED OFF -16 BBLS BACK TO PITS AND LET TUBING AND IA U-TUBE. -AFTER U-TUBE BOTH IA AND TUBING ON A VACUUM. 10:15 - 12:30 2.25 BOPSU P PRE INSTALL TWC WITH T-BAR AND TEST. -FROM ABOVE TO 3500 PSI FOR 10 CHARTED MINUTES - GOOD TEST -ATTEMPT TO TEST FROM BELOW TO 500 PSI. -FLUID IS LEAKING BY THE TWC FROM BELOW. -MPU WELL SUPPORT CALLED OUT W/ LUBRICATOR. -RU MPU LUBRICATOR AND TEST TO 500 PSI. -PULL AND RE-DRESS TWC. -RE-INSTALL TWC AND TEST. -TEST TWC FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES -GOOD TEST. -TEST TWC FROM ABOVE TO 3500 PSI FOR 10 CHARTED MINUTES -GOOD TEST. 12:30 - 14:00 1.50 BOPSU P PRE ND TREE. INSPECT HANGER AND LOCK DOWN SCREWS. 14:00 - 16:00 2.00 BOPSU P PRE NU BOP. Printetl: 3/19/2010 1:32:18 PM • BP EXPLORATION Page 2 of 6 ~ Operations Summary Report Legal Well Name: MPF-29 Common Well Name: MPF-29 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT Spud Date: 7/3/1996 Start: 2/22/2010 End: 4/30/2010 Rig Release: 3/13/2010 Rig Number: 4ES Phase Description of Operations 3/8/2010 16:00 - 17:00 1.00 BOPSU P PRE SERVICE MUD CROSS AND CHOKE MANIFOLD. 17:00 - 19:00 2.00 BOPSU P PRE REPLACE HCR. 19:00 - 00:00 5.00 BOPSU P PRE WHILE FILLING 20 BBL/HOUR. TEST BOPE PER BP/AOGCC REQUIREMENTS: BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. ~~ -SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. -TEST THE CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" TEST JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -GAS DETECTION SYSTEM TESTED. -200 PSI BUILD UP FROM 1700 PSI = 53 SECONDS. -FULL BUILD UP TO 3000 PSI = 176 SECONDS. -4 BOTTLES x 1800 PSI. 3/9/2010 100:00 - 02:00 I 2.001 PULL I P 02:00 - 04:00 I 2.001 PULL I P 04:00 - 05:00 I 1.001 PULL I P 05:00 - 06:00 1.00 PULL I P 06:00 - 10:30 I 4.501 PULL I P - CHUCK SCHEVE STATE AOGCC INSPECTOR, WAIVED WITNESSING BOPE TEST ON 3-7-10. ~ 08:36 HRS DECOMP CLEAR FLOOR. INSTALL DUTCH SYSTEM. PU LUBRICATOR AND TEST TO 500 PSI. -ATTEMPT TO PULL TWC. -UNABLE TO ENGAGE DOG ON SETTING TOOL. -PU RETRIEVING TOOL. SUCCESSFULLY RECOVERED TWC. -ZERO PRESSURE . RD DUTCH SYSTEM. DECOMP PU AND MAKE UP LANDING JOINT. -100K UP -95K SOW. DECOMP LD HANGER AND SECURE ESP CABLE. PU 10 JOINTS OF 2-7/8 EUE 8RD. -RIH TO 16701 4ES RKB. -NO FILL EVIDENT. DECOMP POH AND LD 10 SINGLES THAT WERE PICKED UP FROM SHED. -WELL U-TUBED WHEN BREAKING OUT FIRST JOINT. -SPENT 15 MINUTES CLEANING UP RIG FLOOR. DECOMP CIRCULATED OUT CRUDE, DIESEL, AND GAS_. __ -51-75 SPM l~ 960-1950 PSI. -BEGAN TAKING RETURNS AFTER 950 STKS (56 BBLS). -TOOK -90 BBLS OF CRUDE AND DIESEL TO TIGER TANK. -PUMPED A TOTAL OF 20,738 STKS (1,220 BBLS). Printetl: 3/192010 1:3'La t3 PM • • BP EXPLORATION Operations Summary Report Page 3 of 6 Legal Well Name: MPF-29 Common Well Name: MPF-29 Spud Date: 7/3/1996 Event Name: WORKOVER Start: 2/22/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/13/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2010 ~ 06:00 - 10:30 ~ 4.50 ~ PULI ~ P 10:30 - 18:00 I 7.501 PULL I P 18:00 - 18:30 I 0.501 PULL I P 18:30 - 00:00 ~ 5.50 ~ PULL ~ P 3/10/2010 100:00 - 04:30 I 4.501 PULL I P 04:30 - 06:00 1.50 PULL P 06:00 - 07:00 1.00 PULL P 07:00 - 10:45 I 3.751 PULL I P 10:45 - 11:30 0.75 PULL P 11:30 - 12:30 1.00 PULL P 12:30 - 18:00 5.50 PULL P 18:00 - 18:30 I 0.501 PULL I P 18:30 - 19:30 1.00 PULL P DECOMP MONITORED WELL -FLUID CLEANED UP WITH SMALL "CHAMPAIGN BUBBLES" STILL PRESENT. DECOMP PULL OUT OF HOLE W/ 2-7/8" ESP COMPLETION. -ATTACH ESP CABLE TO SPOOL. -STANDING BACK 2-7/8" TUBING IN DERRICK. CHANGE OUT SPOOL IN SPOOLING UNIT -88 STDS IN DERRICK. -RIG HAND LOOKED DOWN TUBING WITH FLASHLIGHT FOR FLUID LEVEL AND NOTICED SEVERE PITTING BELOW THE COLLAR. -RIG UP HEAD PIN AND FLUSH TUBING. DECOMP CREW CHANGE OUT -SERVICE RIG -INSPECT DERRICK DECOMP POH LAYING DOWN EACH JOINT. -SEVERE PITTING ON THE INTERIOR OF THE TUBING. -SEVERE CORROSION ON THE PIN END OF THE TUBING. -FILLING THE HOLE AT 20 BPH PLUS DISPLACEMENT WITH SEAWATER. DECOMP POH LAYING DOWN EACH JOINT. -SEVERE PITTING ON THE INTERIOR OF THE TUBING. -SEVERE CORROSION ON THE PIN END OF THE TUBING. -FILLING THE HOLE AT 20 BPH PLUS DISPLACEMENT WITH SEAWATER. DECOMP LAY DOWN ESP ASSEMBLY -MAINTAIN FILLING THE HOLE AT 20 BPH WITH SEAWATER. DECOMP CREW CHANGE -CHECK AND SET PVT ALARMS. -ENVIRONMENTAL WALK AROUND. -SERVICE DRAWWORKS AND BLOCKS. DECOMP RIH WITH 88 STANDS OF 2-7/8" TUBING FROM DERRICK. -MAINTAIN HOLE FILL AT 20 BPH WITH SEAWATER. -65 OF THE 88 STANDS APPEAR TO BE IN GOOD SHAPE. DECOMP FLUSH TUBING WITH 48 BBLS. PREP PIPE SHED TO LD TUBING. DECOMP ADJUST BRAKES ON DRAW WORKS. DECOMP POH AND LD EACH JOINT OF 2-7/8" TUBING TO THE PIPE SHED. -INSPECT EACH JOINT LD. -FIRST 190+ JOINTS APPEAR TO BE IN GOOD CONDITION. DECOMP CREW CHANGE -CHECK AND SET PVT ALARMS. -ENVIRONMENTAL WALK AROUND. -SERVICE DRAWWORKS AND BLOCKS. DECOMP POH AND LD EACH JOINT OF 2-7/8" TUBING TO THE PIPE SHED. -INSPECT EACH JOINT LD. ' -JOINT #196 STARTED SEEING SCALE BUILDUP AND PITTING. -LAY DOWN 264 JOINTS. Printed: 3/19/2010 1:32:18 PM • • BP EXPLORATION Page 4 of 6 ~ Operations Summary Report Legal Well Name: MPF-29 Common Well Name: MPF-29 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT Spud Date: 7/3/1996 Start: 2/22/2010 End: 4/30/2010 Rig Release: 3/13/2010 Rig Number: 4ES Phase Description of Operations 13/10/2010 118:30 - 19:30 I 1.001 PULL I P 19:30 - 20:00 I 0.501 PULL I P 20:00 - 00:00 ~ 4.001 RU 13/11/2010 100:00 - 05:00 I 5.00 05:00 - 09:00 4.00 09:00 - 10:00 1.00 10:00 - 13:00 I 3.00 13:00 - 15:00 I 2.00 15:00 - 00:00 I 9.00 3/12/2010 100:00 - 04:30 I 4.50 DECOMP -FILL HOLE AT 20 BPH PLUS PIPE DISPLACEMENT WITH SEAWATER. DECOMP CLEAR AND CLEAN RIG FLOOR -CLEAR PIPESHED AND PREP TO LOAD WITH PIPE RUNCMP LOAD 2-7/8" EUE 8RD, L-80 TUBING IN PIPESHED. -REMOVE THREAD PROTECTORS AND STRAP TUBING. -LOAD ESP ASSEMBLY IN PIPESHED -R/U FLOOR TO RUN ESP COMPLETION -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER. RUNCMP LOAD 2-7/8" EUE 8RD, L-80 TUBING IN PIPESHED. -REMOVE THREAD PROTECTORS AND STRAP TUBING. -LOAD ESP ASSEMBLY IN PIPESHED -R/U FLOOR TO RUN ESP COMPLETION -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER RUNCMP P/U AND SERVICE ESP ASSEMBLY AS PER CENTILIFT PRCEDURES. RUNCMP CREW CHANGE -CHECK AND SET PVT ALARMS. -ENVIRONMENTAL WALK AROUND. -SERVICE DRAWWORKS AND BLOCKS. RUNCMP RUN 2-7/8" EUE 8RD, L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -40 JOINTS OF 2-7/8" IN THE HOLE RUNCMP NEAR MISS ON PIPE SKATE JOINT OF 2-7/8" TUBING ROLLED ACROSS SKATE AND FELL PART WAY DOWN GAP BETWEEN SKATE AND CATWALK. -STOPPED OPERATION AND INVESTIGATED. -DEVELOPED PLAN AND REMOVED JOINT OF TUBING FROM GAP. -RIG MANAGEMENT SUBMITED MOC AND MADE CHANGES TO SKATE TO PREVENT PIPE FROM ROLLING INTO GAP. TRACTION REPORT#2010-IR-3426221 RUNCMP RUN 2-7/8" EUE 8RD, L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -TEST ESP CABLE AND PUMP 10 BBLS OF SEAWATER DOWN TUBING EVERY 2,000' -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -187 JOINTS OF 2-7/8" IN THE HOLE RUNCMP RUN 2-7/8" EUE 8RD, L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -TEST ESP CABLE AND PUMP 10 BBLS OF SEAWATER Pdnted: 3/19/2010 1:32:18 PM • • BP EXPLORATION Page 5 of 6 ~ Operations Summary Report Legal Well Name: MPF-29 Common Well Name: MPF-29 Spud Date: 7/3/1996 Event Name: WORKOVER Start: 2/22/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/13/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date I From - To I Hours I Task I Code I NPT I Phase Description of Operations 3/12/2010 00:00 - 04:30 4.50 BUNCO RUNCMP DOWN TUBING EVERY 2,000' -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -247 JOINTS OF 2-7/8" IN THE HOLE 04:30 - 07:30 3.00 BUNCO RUNCMP MAKE REEL TO REEL SPLICE IN SPOOLING UNIT. -DRIFT TOP ROW OF TUBING IN SHED. -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER. 07:30 - 08:45 1.25 BUNCO P RUNCMP CONTINUE TO RUN 2-7/8" EUE 8RD, L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -255 JOINTS OF 2-7/8" IN THE HOLE 08:45 - 09:45 1.00 BUNCO RUNCMP ARMOR ON CABLE SPLICE CAUGHT ON SHEAVE. -SPLICE NEAR NEAR COLLAR ON JOINT 255. -RE-INSTALL ARMOR OVER CABLE SPLICE. -RE-TEST ESP CABLE CONDUCTIVITY -GOOD TEST. 09:45 - 12:00 2.25 BUNCO P RUNCMP CONTINUE TO RUN 2-7/8" EUE 8RD L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -TEST ESP CABLE AND PUMP 10 BBLS OF SEAWATER DOWN TUBING EVERY 2,000' -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -320 JOINTS OF 2-7/8" IN THE HOLE 12:00 - 13:00 1.00 BUNCO RUNCMP CREW CHANGE -INSPECT DERRICK. -CHECK AND SET PVT ALARMS. -SERVICE DRAWWORKS. -ENVIRONMENTAL WALK AROUND. 13:00 - 17:30 4.50 BUNCO RUNCMP CONTINUE TO RUN 2-7/8" EUE 8RD, L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -TEST ESP CABLE AND PUMP 10 BBLS OF SEAWATER DOWN TUBING EVERY 2,000' -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -413 JOINTS OF 2-7/8" IN THE HOLE 17:30 - 20:00 2.50 BUNCO RUNCMP MAKE REEL TO REEL SPLICE IN SPOOLING UNIT. -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER. 20:00 - 00:00 4.00 BUNCO RUNCMP CONTINUE TO RUN 2-7/8" EUE 8RD, L-80 ESP COMPLETION -AVERAGE MAKE UP TORQUE IS 2,300 FT/LBS -USE BEST-O-LIFE 2000 PIPE DOPE ON CONNECTIONS -USE CANNON CLAMPS ON EVERY JOINT -TEST ESP CABLE AND PUMP 10 BBLS OF SEAWATER DOWN TUBING EVERY 2,000' Printed: 3/19/2010 1:32:18 PM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-29 Common Well Name: MPF-29 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT 13/12/2010 120:00 - 00:00 I 4.00 13/13/2010 100:00 - 00:30 I 0.50 00:30 - 02:00 I 1.50 02:00 - 02:30 0.50 02:30 - 04:00 I 1.501 BOPSUR P 04:00 - 05:30 I 1.501 BOPSUFt P 05:30 - 06:00 0:50 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 07:30 1.00 WHSUR P 07:30 - 08:30 1.00 WHSUR P 08:30 - 09:00 I 0.501 WHSUR I P Start: 2/22/2010 Rig Release: 3/13/2010 Rig Number: 4ES Page 6 of 6 ~ Spud Date: 7/3/1996 End: 4/30/2010 Phase Description of Operations RUNCMP -MAINTAIN 20 BPH HOLEFILL WITH SEAWATER WHILE RIH -RAN 520 JOINTS OF 2-7/8" EUE 8 RD, L-80 TUBING, RUNCMP M/U FMC 2-7/8" TUBING HANGER -ORIENT HANGER AS PER FMC -INSTALL PENETRATOR IN HANGER. RUNCMP CUT ESP CABLE TO LENGTH -MAKE PENETRATOR SPLICE -INSTALL ESP CABLE TO PENETRATOR -MAKE CHECKS ON ESP CABLE, ALL GOOD. RUNCMP LAND TUBING HANGER -UP WEIGHT 90K, DOWN WEIGHT 30K -RUN IN LOCK DOWN SCREWS, TORQUE TO 350 FT/LBS -UPPER HANGER THREAD IS 3" LEFT HAND ACME RUNCMP SET 2-1/2" CAMERON TYPE "H" TWC WITH FMC WELLHEAD TECH. -TEST FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES. -TEST FROM BELOW WITH ROLLING TEST 4 BPM WITH PRESSURE BUILDING TO 800 PSI OVER 10 MINUTES. RUNCMP BLOW DOWN MUD, KILL AND CHOKE LINES. -N/D 13-5/8" 5M, BOPE -SET ROPE ONTO PEDESTAL RUNCMP NIPPLE UP 2-9/16" 5M TREE AND ADAPTER FLANGE. RUNCMP CREW CHANGE AND SERVICE RIG. -ENVIRONMENTAL WALK AROUND. -SERVICE DRAWWORKS -IDENTIFY HAZARDS IN WORK AREAS. RUNCMP CONTINUE TO NIPPLE UP 2-9/16" 5M TREE AND ADAPTER FLANGE. -TEST HANGER VOID TO 5000 PSI FOR 30 MINUTES. -BODY TEST TREE WITH DIESEL TO 5000 PSI. RUNCMP PICK UP MILNE POINT LUBRICATOR AND TEST WITH DIESEL TO 500 PSI. -PULL TWC. -INSTALL BPV AND TEST FROM BELOW. -ROLL PUMPS AT 4 BPM AND 70 PSI. RUNCMP -RIG DOWN MUD LINES. -CENTRILIFT PERFORMED FINAL CHECKS ON ESP. '"'RELEASE RIG AT 09:00"' __ _-_ Printed: 3/19/2010 1:32:1 S PM Tree: Cameron 2 9/16" 5M Wellhead: 11" x 7 1/16" 5M FMC Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8rd on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 115' M P U F-29 ORIG. KB.1~€V = 41.24' (N 22E) ORIG. GL. ELEV = 12.10' (N 22E) ~~- RT To Tbg. Spool = 28.60' •7/8" x 1" Camco KBMM-2 130` Gas lift mandrel KOP @ 1,000' Max. hole angle = 77° , @ 6500' 70°+ 4,000' to 14,900' Hole angle through perfs = 46 deg. 9 5/8", 40 ppf, L-80 Btrc. Float Shoe 8,019' 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, MBTC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) I AVA Ported sleeve (1.875 id ) ~ ~ w/ blanking sleeve ID - 2.313" 16 311' Tandem Pumps, 141-P8/141-P8 16,355' SXD/PMSXD Tandem Gas Separator 16,387` Model GRSFTXAR H6 Stimulation Summary 8/31/96 casing frac 178.3 M# 20/40 and 16/20 carbolite behind pipe Mid-Perf = 7226 TVD, 16587' MD Perforation Summary Ref log: 08/17/96 GR (PFC)/ CCL 22 gm. AlphaJet charges (0.76" EHD, TTP = 6.4")@ 45 / 135 deg. phasing Size SP Interval TVD Kup 'A"'Sand 3 3/8" 6 16,545'-16,557' (7197' - 7206' 3 3/8" 6 16,563'-16,583' (7210' - 7224' 3 3/8" 6 16,591'-16,609' (7225' - 7237' 3 3/8" 6 16,609'-16,629' (7237' - 7251' Tandem Seal Sections, model 16,392' GSB3DBUT SB/SB PFSA Motor, 152 HP, 2325 volt, 40 amp, model KMH 16,406' *NOTE:Motor rerated to 110 HP, 2152 volt, 31 amp PumpMate w/6 Fin Centralizer 16,420` RA TAG @ 16,358' wlm. ESP lowered into well to- check perfs or TD to 16,701' during 3/31/10 RWO. 7377' TVD PBTD , 7" Howco Float Collar 16,908' 7" 26#, L-80, MBTC, Float Shoe 16,994' DATE REV. BY COMMENTS 9/ 23/ 96 MDO ESP Completion 4-ES 03/27/98 M. Linder 11/98 9/01 ESP RWO Nabors 4-ES 07/17/06 R. Handy ESP RWO 03/13/10 L. Hulme ESP RWO by Nabors 4ES MILNE POINT UNIT WELL F-29 API NO: 50-029-22688 BP EXPLORATION . STATE OF ALASKA . ~ ALA Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 41.24 KB ( 8. Property Designation: ADLO-355018 / 11. Present Well Condition Summary: Total Depth measured 17014 ~ feet true vertical 7519.73-- feet Effective Depth measured 16098 feet true vertical 7446 feet Casing Length Size Conductor 80' 20" 91.5# H-40 Surface 7988' 9-5/8" 40# L-80 Production 16965' 7" 26# L-80 Perforation depth: Measured depth: 16545 - 16557 True Vertical depth: 7192.3477200.73 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 264 262 x RECEIVED MAY 0 2 2007 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development r;; Stratigraphic n Stimulate 0 Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 196-1170 t' Exploratory Service 6. API Number: 50-029-22688-00-00 /' 9. Well Name and Number: MPF-29 / 10. Field/Pool(s): / MILNE POINT Field/ KUPARUK RIVER OIL Pool Plugs (measured) None Junk (measured) None SCANNED MA'f 0 9 2007 MD TVD Burst Collapse 32' - 112' 32' - 112' 1490 470 31' - 4481' 31' - 3558' 5750 3090 29' - 7506' ~"~"435r 7240 5410 16563 - 16583 7204.93 - 7218.92 16591 - 16609 7224.52 - 7237.11 16609 - 16629 7237.11 - 7251.09 2-7/8" 6.5# L-80 SURFACE - 16249' o o o o o o o o IRBDMS 8Ft MAYO 8 2007 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 38 131 0 37 131 0 15. Well Class after oroposed work: Exploratory r Development P 16. Well Status after proposed work: Oil r;; Gas WAG r Tubing pressure 275 283 Service WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ Contact Gary Preble Printed Name Signature Title Data Management Engineer Phone 4/30/2007 564-4944 Date Form 10-404 Revised 04/2006 ORIGINAL Submit Original Only krC6 ... . . MPF-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/27/2007 ESP Acid Wash T/I/O= 400/320/250 Pumped 13 bbls Crude for Injectivity Test. Pumped 11.5 bbls 15% DAD HCL Acid, 3 bbls 60/40 Meth and 89 bbls Crude. Final WHP's=1500/380/250 FLUIDS PUMPED BBLS 102 CRUDE 3 60/40 METH 11.5 15% HCL DAD ACID 126.5 TOTAL 1. Operations Performed: Anch.rage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 196-117 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22688-00-00 7. KB Elevation (ft): 41.24 9. Well Name and Number: MPF-29 8. Property Designation: 10. Field / Pool(s): ADL 355018 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 17014 feet true vertical 7520 feet Plugs (measured) None Effective depth: measured 16908 feet Junk (measured) None true vertical 7446 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 7988' 9-5/8" 8019' 4481' 5750 3090 Intermediate Production 16965' 7" 16994' 7506' 7240 5410 Liner (~t~~iNf:f) (, ~~) (-: &.f' ite', ' -~ - tl L.' ii' Perforation Depth MD (ft): 16545' - 16629' Perforation Depth TVD (ft): 7192' -7251' 2-7/8",6.5# L-80 16429' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 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-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 144 94 17 0 323 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Printed Name Sondra Stewman Title Technical Assistant (;-- ~.~ _(l);; ~.~ Prepared By Name/Number: . v /' ~~-\ Phone 564-4750 Date O~ -I ) -D( A)ondra Stewman, 564-4750 Signature / _~ '/?- "-/ ''- Form '['(µJ{)4 Revised 04/2006 ij rr"1 IIIUI..... tst'L-" AUG Submit Original Only . STATE OF ALASKA ~fG JjJb/o6 ALA Oil AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED AUG 1 4 2006 ORIGINAL 1 6 2006 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-29 MPF-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/6/2006 Rig Release: Rig Number: N3S Spud Date: 7/3/1996 End: 7/6/2006 09:00 - 00:00 15.00 RIGD P PRE Prepare rig for move. Lower Derrick and disconnect modules. Wait on wellsite preparation at MPF-29. Prepare carrier and hookup sow to pits and move to F-29. 7/7/2006 00:00 - 02:00 2.00 MOB P PRE Rig Carrier main drive system developed loud noise in transfer case area just after making the turn off the Milne Point Spine Road onto the Land F pads access road. 02:00 - 06:00 4.00 MOB N RREP PRE Disconnect drive shafts and pull Rig Carrier out of the way to allow Pad Operator and Rig Crew changeout. 06:00 - 07:00 1.00 MOB N RREP PRE Continue pulling Rig Carrier to L-pad to initiate diagnosis and repairs. 07:00 - 12:00 5.00 MOB N RREP PRE Strip out drive system covers inside motor room to gain access to the transfer case. Drain transfer case, open inspection covers on transfer case. It appears that the oil pump inside the transfer case failed and the upper gear shafts were not oiled. This transfer case is also connected to the drawworks, so there is no utility in trying to back the rig over the well with a sow. 12:00 - 00:00 12.00 MOB N RREP PRE Continue stripping the transfer case out of the underbelly of the rig carrier. The Transfer Case will have to be sent to Canada for a complete rebuild. A drive shaft will be built to direct-drive the Drawworks, then the rig will be positioned over the well by a sow tractor. 7/8/2006 00:00 - 06:00 6.00 MOB N RREP PRE Continue stripping the transfer case out of the underbelly of the rig carrier. The Transfer Case will have to be sent to Canada for a complete rebuild. A drive shaft will be built to direct-drive the Drawworks from the compound transmission, then the rig will be positioned over the well by a sow tractor. 06:00 - 00:00 18.00 MOB N PRE Wait on engineering drawings and parts to build temporary drive shaft. Parts are not available on the Slope. 7/9/2006 00:00 - 00:00 24.00 MOB N RREP PRE Wait on engineering drawings and parts to build temporary drive shaft. Parts are not available on the Slope. 7/10/2006 00:00 - 00:00 24.00 MOB N RREP PRE Drivelines Northwest in Seattle built a new drive shaft and has shipped it on Alaska Airlines to Deadhorse with an expected ETA sometime July 11th. 7/11/2006 00:00 - 00:00 24.00 MOB N RREP PRE Waiting on arrival of new temporary driveshaft from Drivelines Northwest. Continuing to clean, repair, and paint Rig Carrier and Mud Pits. Driveshaft arrived last flight to Deadhorse on AK airlines. Checked out and delivered to location. 7/12/2006 00:00 - 16:00 16.00 MOB N RREP PRE Mechanics working on installing Driveshaft on Rig Carrier. Problems with keyway and keystock. Camp, Shop, and Pits on location. Move Pipe Shed from G pad to F pad. Install Driveshaft and test to ensure proper installation. 16:00 - 19:00 3.00 MOB N RREP PRE Move Rig Carrier from L pad to F pad. Manuever carrier with forklift to position over well. Call AOGCC and notify of upcoming BOPE test. 19:00 - 00:00 5.00 RIGU N RREP PRE Position rig and modules. Re-connect disassembled components. 7/13/2006 00:00 - 05:00 5,00 RIGU P PRE Continue RU on Well. Prep to Pull BPV. 05:00 - 06:00 1.00 RIGU P PRE Accept rig @ 05:00. RU to pull BPV and Kill Well. 06:00 - 09:00 3.00 KILL P DECOMP Crew Change. Complete rigging up and pull BPV. WHP's T/INOA - 500/410/0 psi. RU LRS. PT surface linens to 500/2500 psi. Bleed gas to Flowback tank. 09:00 - 12:30 3.50 KILL P DECOMP Pump 100 Bbls of 140 deg /2% KCL down tubing with open choke to Flowback tank. NO returns. Close choke, bullhead Printed: 7/24/2006 11 :21 :58 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-29 MPF-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/6/2006 Rig Release: Rig Number: N3S Spud Date: 7/3/1996 End: 7/13/2006 09:00 - 12:30 3.50 KILL P DECOMP 70 Bbls into formation @ 4 Bpm / 600 psi. Shut down, well on vacuum. Swap lines to bullhead down IA. Pump 2% KCL down lA, no returns, @ 5 BPM /750 psi. 400 Bbls away, reduce rate. 4.5 BPM /1170 psi. 500 Bbls away, 4.5 BPM / 1300 psi. 600 Bbls away, 4.5 BPM /1350 psi. 12:30 - 14:00 1.50 KILL P DECOMP 700 Bbls 2% KCL bullheaded down annulus. No-Flow test well. Tbg and IA on vacuum. Set TWC and test from above to 1000 psi / ok. 14:00 - 00:00 10.00 BOPSU P DECOMP ND Tree. NU BOPE. Contact AOGCC regarding upcoming BOPE test. State witness of BOPE test waived by Chuck Scheve. 7/14/2006 00:00 - 02:30 2.50 BOPSU P DECOMP N/U BOPE. 02:30 - 08:00 5.50 BOPSU P DECOMP Test BOPE to 250 psi low and 3500 psi high. Witness of test waived by Chuck Scheve of AOGCC. 08:00 - 10:30 2.50 PULL P DECOMP PUMU ESP shieve, elephant Trunk. Pump out stack and prep floor for pulling ESP. Get XO 31/2" Buttress Box X 3" LH Acme Pin from Nabors 4 ES. 10:30 - 13:00 2.50 PULL N WAIT DECOMP Waiting on Tool Svc. and Expediter to deliver crossover from J pad. 13:00 - 16:00 3.00 PULL P DECOMP PUMU Opso-Lopso and Lubricator. Pull TWC. Tbg and IA on Vacuum. Laydown Lubricator and Opso-Lopso. PUMU landing joint with 3" LH Acme thread. Screw into Tbg Hgr and pull to rig floor. PU Wt of 116K #'s. Break out and lay down Tbg Hgr and landing joint. Lay down pup joints and 1 single of 2 7/8" Tbg. Run ESP cable through shieve as stand back 1 stand of 2 7/8" Tbg and lay down GLM assy. 16:00 - 00:00 8.00 PULL P DECOMP POOH standing back 2 7/8" Tbg in Derrick. RU ESP cable to spooling unit. Continue POOH as loading hole with double Tbg displacement every 5 stands. 7/15/2006 00:00 - 00:30 0.50 PULL P DECOMP Changeout ESP Cable Spool. 00:30 - 03:00 2.50 PULL P DECOMP POOH standing back 2 7/8" Tbg in Derrick; loading hole with double Tbg displacement every 5 stands. 03:00 - 03:30 0.50 PULL P DECOMP Threads on pin ends of tubing are in very poor condition on stands # 165- #169. At stand #167 (top of pump @ 6046'), overpull 50K and popped free. Decision made to UD bad pipe. Order new pipe to replace junked tubing. Build containment for old tubing. Clear Pipe Shed for UD of tubing. 03:30 - 06:00 2.50 PULL P DECOMP POOH UD poor condition 2 7/8" Tbg in Pipe Shed; loading hole with double Tbg displacement every 5 stands. 06:00 - 11 :00 5.00 PULL P DECOMP 61 joints of 2 7/8" tubing layed down. Inspect threads and continue POOH standing back in Derrick. With 109 joints of tubing left in hole (top of pump @ 3431'), overpull10K and slipped free. Continue POOH standing back in Derrick, 11 :00 - 14:00 3.00 PULL P DECOMP Break out and lay down AVA sleeve. POOH and inspect BHA and motor. Test motor electrically, phase to phase and phase to ground - OK. Small piece of top part of pump damaged and broken off. Break out and lay down ESP BHA. Total of 66 joints of 2 7/8" Tbg layed down with suspect threads and corrosion. 14:00 - 19:00 RUNCMP Clean and Clear rig floor. Pump 80 Bbls 2% KCL into well. Load pits with 220 Bbls of 120 deg Seawater. Lay down elephant trunk. PUMU new ESP assembly. 19:00 - 00:00 RUNCMP RIH w/ESP completion. Every 5 stands load hole with double Printed: 7/24/2006 11 :21 :58 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06:00 - 07:30 07:30 - 09:30 09:30 - 12:00 12:00 - 20:00 20:00 - 22:00 22:00 - 23:00 7/17/2006 23:00 - 00:00 00:00 - 04:30 04:30 - 06:30 06:30 - 08:00 08:00 - 12:00 MPF-29 MPF-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/6/2006 Rig Release: Rig Number: N3S Spud Date: 7/3/1996 End: 1.50 2.00 pipe displacement. RIH wI ESP completion. Replace 79 joints of bad tubing with 2 7/8" Class B tubing. 62 stands buried @ 0300. RUNCMP Test conductivity of cable @ 75 stands, OK. Continue RIH RUNCMP 102 Stands in hole. Check conductivity of cable. Is grounded. Check instrumentation, double check and get good test. Continue RIH wI 2 7/8" DP from Derrick. RUNCMP 128 Stands in hole. Make cable splice and check conductivity. RUNCMP Continue RIH w/2 7/8" DP from Derrick. RUNCMP PUIMU tbg hanger and penetrator and install TWC. Make lower wellhead ESP cable connector splice. Centrilift check conductivity. Good test. RUNCMP Load well with 47 bbls seawater. Land tubing, RILD5, and test TWC to 2500 psi. Test O.K. 5/0 = 45k #. PIU = 95k #. RUNCMP PJSM N/D BOPE. RUNCMP N/D BOPE. RUNCMP N/U Tree and test to 5000 psi and chart. RUNCMP Pull TWC and set BPV. RUNCMP Release rig @ 08:00. Prep to move to MPL-20 2.50 8.00 2.00 1.00 1.00 BOPSU 4.50 BOPSU P 2.00 WHSUR P 1.50 WHSUR P 4.00 WHSUR P Printed: 7/24/2006 11 :21 :58 AM , .. Tree: Cameron 2 9/16" 5M Wellhead: 11" x 71/16" 5M FMC Gen 5A, w/2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 ~ MPU F-29 KOP @ 1 ,000' Max. hole angle = 77° , @ 6500' 70°+ 4,000' to 14,900' Hole angle through perfs = 46 deg. 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, MBTC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 95/8",40 ppf, L-80 Btrc. I 8,019' I Float Shoe Stimulation Summary 8/31/96 casing frac 178.3 M# 20/40 and 16/20 carbolite behind pipe Mid-Perf = 7226 TVD, 16587' MO Peñoration Summary Ref loa: 08/17/96 GR CPFC)I CCl Size SP Interval KUD 'A"'Sand 3 3/8" 6 16,545'-16,557' (7197' - 7206' 3 3/8" 6 16,563'-16,583' (7210' - 7224' 22 gm. AlphaJet charges (0.76" EHO, TIP = 6.4")@ 45 / 135 deg. phasing DATE 9/ 23/ 96 03/27/98 07/17/06 REV, BY COMMENTS MDO ESP Completion 4-ES M. Linder 11/98 9/01 ESP RWO Nabors 4-ES R. Handy ESP RWO ORIG. . ELEV = 41.24' (N 22E) ORIG. GL ELEV = 12.10' (N 22E) RT To Tbg. Spool = 28.60' 2-7/8" x 1" Camco KBMM 137' Gas lift mandrel AVA Ported sleeve ( 1 .875 id) I 16 328' I w/ blanking sleeve ID - 2.313" , Pump, 151 GC1700, model GPMTAR 1:1 16,372' Tandem Gas Separator Model GRSFTXAR 16,390' Seal Section, model GSB3DBUT AB/HSNPFSA Motor, 130 HP, 2145 volt, 35 amp, model KME-1 *NOTE:Motor rerated from KMH 152 HP 2325 volt, 40 amp PumpMate w/6 Fin Centralizer 16,395' 16,409' 116,423' RA TAG @ 16,358' wlm. 7377' TVO PBTD , 7" Howco Float Collar 116,908' I 7" 26#, L-80, MBTC, Float Shoe 16,994' I MILNE POINT UNIT WELL F-29 API NO: 50-029-22688 BP EXPLORATION AK STATE OF ALASKA ALASKA ~J~L AND GAS CONSERVATION COMM~o,~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 41.24' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1881' NSL, 2678' WEL, SEC. 6, T13N, R10E MPF-29 At top of productive interval 9. Permit Number / Approval No. 196-117 2825' NSL, 4162' WEL, SEC. 25, T14N, R09E 10. APl Number At effective depth 50-029-22688-00 3050' NSL, 4285' WEL, SEC. 25, T14N, R09E 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3117' NSL, 4321' WEL, SEC. 25, T14N, R09E Sands 12. Present well condition summary Total depth: measured 17014 feet Plugs (measured) true vertical 7520 feet Effective depth: measured 16908 feet Junk (measured) true vertical 7446 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 7988' 9-5/8" 1500 sx PF 'E', 900 sx 'G', 150 sx PF 'E' 8019' 4481' Intermediate Production 16965' 7" 264 sx Class 'G' 16994' 7506' Liner Perforation depth: measured 16545'- 16557', 16563'- 16583', 16591'- 16629' true vertical 7192'- 7201', 7205' - 7219', 7224' - 7251' RECEIVE D Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to16419' 00'r 0 5 ~ool Packers and SSSV (type and measured depth) None /~llilS~i!l 0il & Gas Cons. Commissior~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify~~_~., ..~that the f~_o~egoing is true_¢.nd correct to the best of my knowledge Signed So _~aStewm - - c- Title TechnicalAssistant Date 10'- f.~-© ( Prepared By Name/Number: Sondra Stewman, 564-4750x, Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicate ORATION Page l of l ns summary Report Legal Well Name: MPF-29 Common Well Name: MPF-29 Spud Date: 7131~996 Event Name: RE ENTER Start: 9/23/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 4ES Rig Number: ~Date ~Erom- To ~H~urs Activi~!~ Code I~iPT 1~ ehase Description of Operations DEOOMP MOVED RIG TO F-29. SPO~ED AND BERMED RIG. 02:30 - 04:00 1.50 MOB P DEOOMP ~ISED AND seePED DERRICK. 04:00 - 08:00 4.00 PULL P DEGOMP ~U TIGER TANK, LINES TO TREE. FILLED TIGER TANK WITH SEAWATER. ACCEPTED RIG AT 04:00 HRS ON 912812001. 08:00 - 08:30 0.50 PULL P DECOMP TESTED LINES TO 3,500 PSI. 08:30 - 12:00 3.50 PULL P DECOMP PJSM TO KILL WELL. OPENED WELL. 650 PSI ON TBG AND 590 PSI ON ANNULUS. BULLHEADED TBG VOLUME AND BULLHEADED ANNULUS VOLUME WITH 3 BBL EP MUDLUBE PILL. 12:00 - 14:00 2.00 PULL P DECOMP MONITORED WELL. INSTALLED ~C. TESTED TO 3,500 PSI. 14:00- 15:00 1.00 PULL P DECOMP N/D TREE. 15:00- 17:00 2.00 PULL P DECOMP N/U BOPs. 17:00 - 20:00 3.00 PULL P DEOOMP TESTED BOPs AND CHOKE MANIFOLD TO 250 PSI LOW AND 3,500 PSI HIGH. BOP TEST WITNESSING WAIVED BY JOHN SPALDING. 20:00 - 20:30 0.50 PULL P DECOMP RIGGED DOWN TEST EQUIPMENT. BLEW DOWN LINES. 20:30 - 21:00 0.50 PULL ~ DECOMP P/U LUBRICATOR AND PULLED ~C. 21:00 - 22:00 1.00 PULL ~ DEOOMP MADE UP ~NDING JOINT AND SCREWED INTO HANGER. BOLDS. 22:00 - 23:00 1.00 PULL ~ DEOOMP PULLED HANGER TO RIG FLOOR. TESTED ESP. ~ID DOWN HANGER AND ~NDING JOINT. 23:00 - 00:00 1.00 PULL ~ DECOMP POH WITH 2 7/8 TBG AND SPOOL ESP CABLE. 912912001 00:00 - 05:30 5.50 PULL ) DEOOMP POH TO 7,900-FT SPOOLING ESP CABLE ON SPOOL. 05:30 - 06:00 0.50 PULL P DECOMP CHANGE OUT ESP SPOOLS 06:00 - 12:30 6.50 PULL P DEOOMP CONTINUE POOH WITH 2 7/8" TBG AND ESP CABLE. ,12:30 - 14:00 1.50 PULL P DEOOMP CUT ESP CABLE AND REMOVE F~T GUARDS. INSPECT PUMP. 14:00 - 15:30 1.50 PULL P DEOOMP SERVICE NEW ESP ASSY. 15:30 - 17:00 1.50 PULL P DEOOMP A~ACH AND SECURE ESP CABLE. MEG TEST PUMP. 17:00-23:30 6.50 PULL P DEGOMP RIHWITHNEWESPASSYAND27/8"TBG. TESTESPAT 1800-FT. 23:30 - 00:00 0.50 PULL P DEOOMP STOP AT 8000-FT TO CHANGE ESP SPOOLS AND SPLICE. 9/30/2001 00:00 - 03:00 3.00 RUNCO~ ~NTERV ~DE MID LINE SPLICE IN ESP CABLE. 03:00 - 08:30 5.50 RUNCO~ INTERV MADE UP HANGER AND ~NDING JOINT. 08:30 - 10:30 2.00 RUNCO~'~ INTERV MADE UP ESP CONNECTOR, TESTED AND SECURED SAME. STRING WEIGHT UP 106,000 LBS AND STRING WEIGHT DOWN 40,000 LBS. ~NDED HANGER AND RILDS. 10:30 - 11:00 0.50 RUNCO~ INTERV SET~CAND TESTED TO 1000 PSI. D~INED BOPsAND BLEW DOWN LINES. 11:00 - 12:30 1.50 RUNCOAP INTERV N/D BOPs. 12:30 - 13:30 1.00 RUNCOAP INTERV N/U TREE. :13:30 - 14:00 0.50 RUNGOAP INTERV TESTED ADAPTOR F~NGE AND TREE TO 5,000 PSI. MADE FINAL CHECK AT PENET~TOR. 14:00 - 14:30 0.50 RUNGO~P INTERV P/U LUBRICATOR AND PULLED ~C. SET BPV AND ~ID I DOWN LUBRICATOR. 14:30 - 15:00 0.50 RUNCO~ INTERV SECURED TREE AND CEL~R. RELEASED RIG AT 15:00 HRS ON 9/30/01. Printed: 10/2/2001 2:10:49 PM ALASKA C'''~ AND GAS CONSERVATION COM' .... $SION REPOh, OF SUNDRY WELL OPERATioNS 1. Operations performed: [-] Operation Shutdown []Stimulate [~] Plugging I--I Perforate E~ Pull Tubing []Alter Casing E~]Repair Well ~]Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 1881' NSL, 2678' WEL, SEC. 6, T13N, R10E At top of productive interval 2827' NSL, 4159' WEL, SEC. 25, T14N, R9E At effective depth 3050' NSL, 4285' WEL, SEC, 25,T14N, R9E At total depth 3119' NSL, 4317' WEL, SEC. 25, T14N, R9E 5. Type of well: [] Development r-] Exploratory E~] Stratigraphic I-] Service 6. Datum Elevation (DF or KB) 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-29 9. Permit Number / Approval No. 96-117 10. APl Number 50-029-22688 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 17014' feet 7519' feet 16908' feet 7446' feet Length Size 83' 20" 7990' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1500 sx PF'E', 900 sx 'G',150 sx PF'E; 16965 7" 264 sx Class 'G' MD TVD 112' 112' 8019' 4480' 16994' 7506' Perforation depth: measured 16545'-16557';16563'-16583';16591'-16629' true vertical 7192'-7201';7205'-7219';7224'-7251' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 @ 16392' Packers and SSSV (type and measured depth) N/A ":,, :;:,;.:ii:,"; 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments I--I Copies of Logs and Surveys run I~ Daily Report of Well Operations 16. Status of well classifications as: I~ Oil [-I Gas F--I Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge KATRINA N, COOPER . Title Production Engineer Prepared By Name/Number: Date Michael Williams, 564-4657 ~'~_., Submit In Duplicate~ Form 10-404 Rev. 06/15/88 MPF-29 DESCRIPTION OF WORK COMPLETED Stimulation Operation 04/11/99 A Enzyeme Stimulation Treatment was performed using the following fluids: SUMMARY HB&R arrives location. PT line to annulus 3000 psi. Start dead crude down annulus. Shut down after loading annulus. RID HB&R TIME FLUIDTbg/Ann RATE VOL. Rig up BJ pump and nitrogen truck. Hold safety meeting. PT treating lines N2 (4400 psi), Hardline (4300 psi) Start breakdown fluids down tubing. Start 1st stage Enzyeme. Pumped 10 bbls Enzyeme. Switch to foam. Pumped 8 bbls seawater/2100 scf N2/DH foam. Finished 2nd stage Enzyeme. On flush Switch to diesel freeze protection. Shut down pumping. Job complete.. Fluids Pumped BBLS. Description 20 Enzyeme 15 Diesel 85 Sea Water 120 Total Pumped ..... ·STATE OF ALASKA ALASKA 0,_ AND GAS CONSERVATION COMh~,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--IOperation Shutdown I~Stimulate i--] Plugging ~1 Perforate [] Pull Tubing [] Alter Casing l--J Repair Well [] Other Change Out ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1881' NSL, 2678' WEL, SEC. 6, T13N, R10E At top of productive interval 2827' NSL, 4159' WEL, SEC. 25, T14N, R09E At effective depth 3050' NSL, 4285' WEL, SEC. 25, T14N, R09E At total depth 3119' NSL, 4317' WEL, SEC. 25, T14N, R09E t5. Type of well: [] Development [] Exploratory [---] Stratigraphic l--I Service 6. Datum Elevation (DF or KB) KBE = 41.24' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-29 9. Permit Number / Approval No. 96-117 10. APl Number 50-029-22688 11. Field and Pool Milne Point Unit / Kuparuk River Sands ~... ~ ~ 12. Present well condition summary Total depth: measured 17014 feet true vertical 7519 feet Effective depth: measured 16908 feet true vertical 7446 feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented 80' 20" 7988' 9-5/8" 250 sx Arcticset I (Approx.) 1500 sx PF 'E', 900 sx 'G', 150 sx PF 'E' 16965' 7" 264 sx Class 'G' 112' 112' 8019' 4481' 16994' 7506' Perforation depth: measured true vertical 16545'-16557', 16563'-16583', 16591'-16629' 7192'-7201', 7205'-7219', 7224'-7251' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 16392' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run I [] Oil [] Gas [] Suspended [] Daily Report of Well Operations 17. I hereby certify that the fCegoing is true arid correct to the best of my knowledge Signed ~~,~~ Terrie Hubble Title Technical Assistant III Prepared By Name/Number: Service Form 10-404 Rev. 06/15/88 Date ¢~'~'?? Submit In Duplicate Progress Report Facility M Pt F Pad Well MPF-29 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 22 Mar 98 23 Mar 98 24 Mar 98 25 Mar 98 26 Mar 98 06:00-11:00 11:00-13:00 13:00-16:00 16:00-19:30 19:30-20:30 20:30-22:00 22:00-00:00 00:00-02:00 02:00-06:00 06:00-09:30 09:30-02:00 02:00-06:00 06:00-14:00 14:00-15:00 15:00-00:00 00:00-06:00 06:00-07:00 07:00-19:30 19:30-20:30 20:30-00:00 00:00-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-09:00 Duration 5hr 2hr 3hr 3-1/2 hr lhr 1-1/2 hr 2hr 2hr 4hr 3-1/2 hr 16-1/2 hr 4hr 8hr lhr 9hr 6hr lhr 12-1/2 hr lhr 3-1/2 hr 2-1/2 hr lhr 1/2hr lhr lhr 3hr Activity Rig moved 100.00 % Cleared Chicksan lines Circulated closed in well at 16392.0 ft Bullhead well Removed Xmas tree Installed BOP stack Tested BOP stack Worked toolstring at 16392.0 ft Circulated at 16392.0 ft Reverse circulated at 16392.0 ft Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run R.I.H. to 16784.0 ft Pulled out of hole to 16154.0 ft Repaired Draw works Pulled out of hole to 5728.0 ft Pulled out of hole to 0.0 ft Ran Tubing in stands to 14000.0 ft Serviced Block line Ran Tubing in stands to 16315.0 ft Installed Tubing hanger Removed BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 75.000 bbl of Production fluids Freeze protect well - 75.000 bbl of Production fluids Progress Report Facility M Pt F Pad Well MPF-29 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 09 Nov 98 10 Nov 98 11 Nov 98 12 Nov 98 00:30-06:00 06:00-06:15 06:15-07:30 07:30-09:00 09:00-10:30 10:30-11:00 11:00-11:30 11:30-11:45 11:45-12:30 12:30-13:15 13:15-13:30 13:30-18:00 18:00-18:15 18:15-18:45 18:45-19:00 19:00-19:15 19:15-20:00 20:00-21:30 21:30-23:30 23:30-00:30 00:30-01:00 01:00-02:15 02:15-02:30 02:30-06:00 06:00-06:15 06:15-06:30 06:30-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-22:30 22:30-00:00 00:00-00:30 00:30-03:00 03:00-06:00 06:00-06:15 06:15-06:30 06:30-08:00 08:00-11:00 11:00-13:30 13:30-18:00 18:00-18:15 18:15-20:30 20:30-23:00 23:00-02:30 02:30-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:15 06:15-07:30 07:30-08:00 08:00-08:30 08:30-09:00 Duration 5-1/2 hr 1/4 hr 1-1/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr 3/4 hr 1/4hr 4-1/2 hr 1/4 hr 1/2 hr 1/4 hr 1/4 hr 3/4 hr 1-1/2 hr 2hr lhr 1/2 hr 1-1/4 hr 1/4 hr 3-1/2 hr 1/4 hr 1/4 hr 10hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 3hr 1/4 hr 1/4 hr 1-1/2 hr 3hr 2-1/2 hr 4-1/2 hr 1/4 hr 2-1/4 hr 2-1/2 hr 3-1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 1/2 hr Activity Rig moved 90.00 % Held safety meeting Rig moved 100.00 % Rigged up Drillfloor / Derrick Retrieved Hanger plug Installed High pressure lines Tested High pressure lines Held safety meeting Bleed down well Circulated closed in well at 16226.0 ft Bullhead well Circulated closed in well at 16226.0 ft Held safety meeting Circulated at 16226.0 ft Flow check Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All functions Retrieved Hanger plug Retrieved Tubing hanger Circulated at 16006.0 ft Flow check Pulled Tubing in stands to 12699.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 50.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Held safety meeting Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing in stands to 2725.0 ft Held safety meeting Serviced Drillfloor / Derrick Ran Tubing in stands to 4000.0 ft Pulled Tubing in stands to 55.0 ft Serviced Electrical submersible pumps Ran Tubing in stands to 5200.0 ft Held safety meeting Ran Tubing in stands to 7800.0 ft Serviced Electric cable Ran Tubing in stands to 16375.0 ft Rigged up Tubing hanger Serviced Electric cable Ran Tubing on landing string to 16393.0 ft Removed BOP stack Held safety meeting Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Facility Date/Time Progress Report M Pt F Pad Well MPF-29 Rig Nabors 4ES Page Date 09:00-09:15 09:15-09:30 Duration 1/4 hr 1/4 hr Activity Freeze protect well - 13.000 bbl of Diesel Rigged down High pressure lines 2 10 February 99 T~T~T~X 6pa~TaOa~ UoTqdT~asap ~ STSAietrg-~~ sea ap~xoo II~ ~q~ / % / ~/ L6/ET./50 q-gNIa L6/~T./[O ~nmza L6/~T~/~O ~xIa 0~cJ£-98~1;' .~ 0[SL-98~..~ £0~-0T fiE9L LIT-96 ~-Q%S/OND/NDQ LTI-96 Q~-S~N/ND~ LTI-96 (IA~-S~/~D~ LIT-96 (IA~-~$/~ND/~D~ LIT-96 96/9I/0I 96/II/60 96/II/60 q-~fbIIeI 86/ET/80 :sqeQ T :~bed / fi~L9I- 00LilT/j7,~ S~L9T-00L~ A~oqus~uI SIeT~aqe~ iemTBOiOaD IIaM TenpTATpuI DDDO~ fi6~t LIT-96 %DD/HD LIT-96 - ~DD/~D £TT-96 ,l, I I4'd,~4 !,~O'L I WELL LOG TRANSMITTAL To: State of Alaska March 5, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor ~ "1 ,~,,~ 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-29 AK-MM-96736 The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. API#: 50-029-22688-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Sl;-rr j-sun ri I:! I I..1_ I IM 5 WEI,L LOG TRANSMITTAL To: State of Alaska February 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-29, AK-MM-960736 ~f Co ~ 1 l --J The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22688-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22688-00 2" x 5" MD Neutron and Density Logs: 50-029-22688-00 2" x 5" TVD Neutron and Density Logs: 50-029-22688-00 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, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-117 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22688 4. Location of well at surface :. ........... ' - -- 1881' NSL, 2678' WEL, SEC. 6, T13N, R10E ? ¢::);"h" i: "i, .i- ~ '~1~~! 9. UnitMilneOrpointLeaseunitName At top of productive interval ~',,~/~_~_.. ! 10. Well Number 2827' NSL, 4159' WEL, SEC. 25, T14N, R9E? ....... MPF-29 At total depth 11. Field and Pool 3119' NSL, 4317' WEL, SEC. 25, T14N, R9E,' Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands Plan RTE = 42'I ADL 355018 12. Date Spudded07/03/96 113' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re ' 16' N°' °f c°mpleti°ns07/19/96 09/21/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)~19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosl 17014 7519 FT~ 16908 7446 F~ []Yes []No I N/A MD! 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, EMS, GR/CDR/CDN, GR(PFC)/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE VV'T. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 8019' 12-1/4" 1500sxPF'E',900sx'G', 150sxPF'E' 7" 26# L-80 29' 16994' 8-1/2" 264 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 16392' N/A MD TVD MD TVD 16545'-16557' 7192'-7201' , 16563'-16583' 7205'-7219' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 16591 '-16629' 7224'-7251' INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED '~-~ ~ ~ Freeze protect w/72 bbls diesel 16545'-~6557",16563'-16583', Frac'd w/178300# 16/20 & 20/40 Carbolite behind pipe 16591'-16629' 27. Date First Production IMethod of Ol~...¢~{'Ft~)~;ga~liff,,. etc.) September 26, 1996 I Electdc Su'bmersible~J~p Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure OALCULATED. OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top Kuparuk 16315' 6991' Top Kuparuk 'A' 16550' 7155' Top Kuparuk A2 16569' 7168' Top Kuparuk A1 16598' 7188' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is tr.ue and,cgrrect to the best of my knowledge Signed .~~ ~"~ Tim Schofield Title Senior Drilling Engineer Date ~ .. Prepared By Name/Number: Kathy Campoamor, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M PF-29 Rig Name: N-22E AFE: 337041 Accept Date: 07/02/96 Spud Date: 07/03/96 Release Date: 07/23/96 Jul 2 1996 (1) RD drillfloor/derrick. Held safety meeting. Rig moved 20 %. Rig moved 30 %. Rig moved 40 %. Rig moved 50 %. Jul 3 1996 (2) Held safety meeting, Rig waited: Production facilities. Rig moved 50%. Rig waited: Production facilities. Rig moved 100%. Nabors rig #22E accepted 07/02/96 @ 1600 hrs. RU divertor. RU divertor. Jul 4 1996(3 ) Held safety meeting. RU divertor. Tested divertor. Tested fluid system. MU BHA #1. Held drill (kick while drilling). Drilled to 1359 ft. Jul 5 1996 (4) Held safety meeting. Drilled to 2491 ft. Circulated at 2491 ft. POOH to 1050 ft. RIH to 2491 ft. Held drill (fire). Drilled to 3720 ft. Jul 6 1996 (5) Held safety meeting. Drilled to 4286 ft. Circulated at 4286 ft. POOH to 250 ft. Pulled BHA. Serviced blockline. RIH to 4286 ft. Drilled to 4943 ft. Jul 7 1996 (6) Held safety meeting. Held drill (spill). Drilled to 6267 ft. Circulated at 6267 ft. POOH to 1900 ft. RIH to 6267 ft. Drilled to 6801 ft. Jul 8 1996 (7) Held safety meeting. Held drill (kick while drilling). Drilled to 8040 ft. Circulated at 8040 ft. POOH to 1080 ft. RIH to 8040 ft. Circulated at 8040 ft. Jul 9 1996 (8) Held safety meeting. Circulated at 8040 ft. POOH to 250 ft. Pulled BHA. Serviced drillfloor/derrick. Ran casing to 8019 ft (9.625 in OD). Circulated at 8019 ft. Mixed and pumped slurry- 764 bbl. RD casing handling equipment. Page Jul 10 1996 (9) Held safety meeting. Drilled cement to 7933 ft. Circulated at 7933 ft. Jul 11 1996 (10) Held safety meeting. Circulated at 7932 ft. POOH to 5143 ft. Circulated at 5143 ft. POOH to 90 ft. Pulled BHA. Circulated at 8018 ft. Held safety meeting. Circulated at 8019 ft. Circulated at 8019 ft. Held safety meeting. Mixed and pumped slurry - 765 bbl. Displaced slurry - 591 bbl. Jul 12 1996 (11) Held safety meeting. Wait on cement. Mixed and pumped slurry - 57 bbl. RD casing handling equipment. RU BOP stack. Took Gyro multi-shot w/line survey. Held safety meeting. Took Gyro multi-shot w/line survey. RU BOP stack. Tested BOP stack. Pulled BHA. MU BHA #4. Jul 13 1996 (12) Held safety meeting. MU BHA #4. Serviced top drive. Serviced block line. RIH to 4960 ft. Held safety meeting. Held drill (kick while tripping). RIH to 7632 ft. Washed to 7932 ft. Circulated at 7932 ft. Tested casing - via annulus. Repaired high pressure lines. Tested casing - via annulus. Drilled to 8060 ft. Oirculated at 8060 ft. Performed formation integrity test, 8.3 ppg EMW. POOH to 1000 ft. Jul 14 1996 (13) Held safety meeting. Held drill (fire). Pulled BHA. RIH to 8018 ft. RU drillstring handling equipment. RIH to 8060 ft. Mixed and pumped slurry- 75.8 bbl. POOH to 6650 ft. Reverse circulated at 6650 ft. Displaced slurry -7.5 bbl. Held 1600 psi pressure on 29.5 bbl squeezed cement. Held safety meeting. POOH to 0 ft. Pulled BHA. RU drillstring handling equipment. MU BHA #6. RIH to 7000 ft. Washed to 7250 ft. Drilled cement to 8060 ft. Drilled to 8080 ft. Held drill (kick while drilling). Circulated at 8080 ft. Performed formation integrity test, 11.7 ppg EMW. Jul 15 1996 (14) Held safety meeting. Held drill (spill). Drilled to 9560 ft. Held safety meeting. Drilled to 10790 ft. Held drill (spill). Drilled to 11169 ft. Jul 16 1996 (15) Held safety meeting. Held drill (H2S). Drilled to 11641 ft. Circulated at 11641 ft. Flow check. POOH to 8018 ft. Serviced top drive. Serviced block line. Serviced drillstring handling equipment. RIH to 11641 ft. Held safety meeting. Drilled to 12774 ft. Held drill (fire). Drilled to 12960 ft. Page 2 Jul 17 1996 (16) Held safety meeting. Held drill (kick while drilling). Drilled to 14094 ft. Circulated at 14094 ft. Held safety meeting. Circulated at 14094 ft. Flow check. Monitor well pressures. Circulated closed in well at 14064 ft. Flow check. POOH to 11600 ft. Singled in drill pipe to 14094 ft. Drilled to 14286 ft. Jul 18 1996 (17) Held safety meeting. Held drill (fire). Drilled to 15137 ft. Held safety meeting. Held drill (H2S). Drilled to 15712 ft. Jul 19 1996 (18) Held safety meeting. Held drill (spill). Drilled to 16173 ft. Circulated at 16173 ft. Flow check. POOH to 8018 ft. Held drill (kick while tripping). Held safety meeting. Serviced block line. Serviced top drive. RIH to 16173 ft. Drilled to 16195 ft. Circulated at 16195 ft. Drilled to 16455 ft. Jul 20 1996 (19) Held safety meeting. Held drill (H2S). Drilled to 16551 ft. Circulated at 16551 ft. Flow check. Drilled to 17014 ft. Circulated at 17014 ft. Flow check. Circulated at 17014 ft. Held safetymeeting. Flow check. Circulated at 17014 ft. Flow check. POOH to 14500 ft. Flow check. RIH to 17014 ft. Circulated at 17014 ft. Jul 21 1996 (20) Held safety meeting. Flow check. Circulated at 17014 ft. POOH to 8018 ft. POOH to 1600 ft. Held safety meeting. Held drill (fire). POOH to 266 ft. Pulled BHA. Downloaded MWD tool. Pulled BHA. Tested BOP stack. RU casing handling equipment. Held safety meeting. Ran casing to 3230 ft (7 in OD). Jul 22 1996 (21) Held safety meeting. Ran casing to 5200 ft (7 in OD). Serviced casing handling equipment. Ran casing to 6000 ft (7 in OD). Serviced casing handling equipment. Ran casing to 8026 ft (7"). Circulated at 8025 ft. Ran casing to 10600 ft (7 in OD). Held safety meeting. Held drill (kick while tripping). Ran casing to 16994 ft (7"). RD casing handling equipment. Circulated at 16994 ft. Held safety meeting. Pumped spacers- volume 70 bbl. Jul 23 1996 (22) Held safety meeting. Mixed and pumped slurry- 54.2 bbl. Displaced slurry - 646 bbl. Tested casing. RD casing handling equipment. Installed seal assembly. RD BOP stack. Installed wellhead primary components. Held safety meeting. Held drill (H2S). LD 4000 ft of 5 in OD drillpipe. Serviced top drive. Serviced block line. Nabors rig #22E released 07/23/96 @ 0100 hrs. Rig moved 90 %. Page 3 Milne Point Unit, Alaska TO: Steve Rossberg FROM: J. Fox Well Name: IMP F-29 Main Category:I P E R F Sub Category: Pre- frac E-Line Operation Date: ~08/,16 - 17 / 96 Date: 108/18 / 96 I Objective: In preparation for the completion of this well; a primary correlation log is needed, the Kup. "A" sands perforated, and a SBHP recorded. This wellbore is deviated to a max. of 77 deg. which historically is marginal for getting wireline tools down. Sequence of Events: 08 / 16 / 96 1230 - MIRU Atlas E-Line unit. 1330 - Make and RIH w/1 11/16" OD GR/CCL toolstring w/weight bar and roller stem on magnetically marked line. Tooistring repeatedly setting down between 4702' and 4695'. POOH. Noted relatively large (0.75" x 0.50" ) flat slivers of metal stuck to the side of the CCL. Abandon effort to get correlation log. 2200 - RD E-Line unit for the night. 08 / 17 / 96 0745 - MIRU Atlas E-Line unit. 0830 - MU and RIH w/3 3/8" x 20' perforating assembly w/4.5" rollers to PBTD on magnetically marked line. Running speed slowed down throughout high deviation portions of the hole but never came to a stop. Tagged TD at 16,768' wlm. Log up to 15,700' w/PFC gamma ray / CCL. RIH. Log up to 16,607'. SIWHP =0 psig. (pressure from line displacement was bled off at surface) Detonate gun perforating casing from 16,609' - 16,629' wlm. SIWHP =0 psig. Log off and POOH. All shots fired. 1300 - RIH w/3 3/8" x 18' perforating assembly to line flag. Make tie-in pass and correct depth. Log up to 16,587' wlm. WHP = 0 psig. Detonate gun perforating the casing from 16,591' to 16,609'. Log off and POOH. WHP = 20 psig. 1600 - RIH w/3 3/8" x 20' assembly to line flag. Toolstring sat down a couple times at 5883' and 14,395'. Make tie-in pass and correct depth. Log up to 16,561' wlm. Detonate gun perforating the casing from 16,563' to 16,583'. Log off and POOH. 1900 - RIH w/3 3/8" x 12' assembly (w/extra weight bar above the gun) to line flag. Make tie-in pass and correct depth. Log up to 16,539' wlm. Detonate gun perforating the casing from 16,545' to 16,557'. Log off and POOH. 2230 - RDMO Atlas E-Line unit. 08/18/96 1700 - SIWHP = 360 psig. Results: Hole deviation appears to be too great to get a standard GR / CCL logging tool down. The toolstring configuration used has been successfully used to get down on other high angle wells. The toolstring set down at the same depth that the slickline tools were setting down several days prior to this. There were some relatively large piece of metal flakes on the GR / CCL toolstring suggesting that there may be enough debris on the Iow side of the hole to stop the wireline tools (???). Now that the 4 guns have been made there this debris may have been displaced - or on the other hand they may have strung perf debris throughout the wellbore and made conditions worse. A GR/CCL primary correlation log was run using the (Iow quality) PFC perforating GR tool. It is usable but is not as clean as a standard GR. It was not run back to surface due to it's relatively poor quality. The log was stopped at 15,700' above which the GR/CCL shows little or n.o character. PBTD was determined to be at 16,768' whereas the float collar is supposed to be 16,908'. This is 140' shallower than expected. There is still 211' of rathole. The casing was perforated at the depths listed below as per procedure. The actual depths according to marked line GR corrected by lithology were 7' more shallow than the depths on the MWD log. As with other high angle holes the wireline tends to "yo-yo" when pulling the guns into shooting depth. This makes accuracy of correlations and therefore depths plus or minus I to 2'. This is particularly true on the later guns runs due to add'l drag from perf debris. A SBHP was planned to follow the last gun run however the E-Line unit was partially blocking access to the pad and the Nabors 4ES rig was preparing to move around the pad and over F-25 (right next to F-29). In addition is likely that this toolstring would not make it down as it's configuration is similar to the GR/CCL toolstring that could not get down. It is hoped that a SBHP on slickline can be run at a later date. There did not seem to be a very quick pressure.response while perforating. The lubricator PI indicated a WHP of 20 psig or so but not much for a new well in this area. However a pressure reading the following day was 360 psig. In retrospect and for other reasons I suspect the pressure gauge may have been inaccurate. This is still seems relatively Iow. Tie in log/date PFC GR / CCL 08 / 17 / 96 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density 16,545' II 16,557' 16,563' 16,583' 16,591' 16,629' 3 3/8" 6 JSPF 22 gm. JumboJet charges (EHD = 0.76", TTP = 6.4") Orientation random f~ Phasing BP EXPLORATION (ALASKA) INC. Milne Point Unit TO: S. Rossberg/ Bill Hill FROM: Dan Robertson/ Mark O'Malley DATE: 8/31/96 -RE: MP F-29 DATA FRAC AND FRAC DOWN 7" casing SERVICE CO'S.: BJ, Peak !1 I uoa SUMMAR DATA FRAC Bbls Bbis XL Time XL gel Final STP, ISIP, psi NWB Treat grad, Pumped gel thru on perfs psi friction, psi/ft Perfs min. psi 300 290 7.1 2549 1675 50 0.68 FRA C Sand ~ead~pp .Tailp[op ~Design;:total Tresaver pumped, i~-~b'e.l~!~'d'~ b~h'i'nd behind Liner rubber left Job was M# --.'pip~e;~ M~!pipe,,~M# pipe;'~M# Sand, M# in hole? /size ~ i/size flushed I 88 35/2~0,;4-~q 153/16- 1178,'3. 9.7 none . Ft of Estimated Final ISIP, psi ISIP Incr Actual TSO, TSO, sand in sand top STP, over Pad design, Nolte Pipe psi datafrac, Fraction min Plot psi 420 16130 2520 2075 400 26 % 14.35 ? Comments: Placed 178 M# of 20/40 and 16/20 carbolite behind pipe with no problems. Calculated BHTP increased until 10 ppg at perfs, then leveled off. Dropped rate to 30 bpm, then 20 bpm trying to force screenout at end of job. Did not seem to have much effect though. All BJ personnel did an excellent job in spite of the fact that this is their last frac job on the slope at this time. The job was completed routinely and without incident. 10/23/96 12:06 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M PF-29 Rig Name: N-4ES AFE: 347041 Accept Date: 09/1 2/96 Spud Date: Release Date: 09/21/96 Sep 13 1996 MIRU, spot & berm rig. RU & test 7" RBP. ND frac tree. NU BOP's & change out mud cross on BOP stack. Test BOP's. Test waived by Chuck w/AOGCC. Nabors rig #4ES accepted 09/12/96 @ 1800 hrs. Sep 14 1996 Cont BOP test. Change out annular element. RU & test annular & install wear bushing. Slip & cut drilling line. Load & strap 2-7/8" tubing. MU Baker retrieve tool & RIH t/600'. Circ out meoh. Cont to PU 2-7/8" tubing. Sep 15 1996 Cont to PU tubing t/16242' & tag up. Circ & PU t/125K & CBU. Rec frac sand in returns. Cont rev & vis system up. Monitor well. Assess the risk of not having the RBP & washing to the original setting depth. RIH & tag SD @ 16234'. (Original setting depth of RBP 16358'). Rev frac SD f/16234' t/16346' & set down on packer & equalize & release packer & RIH 20' below pulling depth & no SD immediately below packer. Rev CBU & monitor well. Well flowing slightly. Raise brine wt. POOH & LD rbg & ret tool. PU scraper & space out above perfs & RIH same. Sep 16 1996 Cont RIH with tubing & scraper tag SD @ 16504'. Rev frac SD f/16504' t/16557'. Tubing stuck @ 16557' & work tbg free. Cont to rev circ, tbg stuck again @ 16573'. Cont working tbg w/pumping lub tex & high & Iow vis sweeps w/tbg t/16588' & decision to POOH & check scraper etc. POOH & LD casing scraper (found nothing wrong with scraper). Cut drlg line & adj brakes. RIH w/2-7/8" tbg & mule shoe. Sep 17 1996 Rev circ tbg f/16588' t/16628'. PU & rev circ at 16596'. Tbg stuck @ 16591'. Cont circ & work tbg. Pump hi-low vis sweeps & cont to work stuck tbg. Rig Atlas & RIH with APR stretch reading tool t/16515'. Pipe showed to be free to this point. MU & RIH with Atlas chemical cutter & cut tbg @ 16472'. POOH. RD Atlas. POOH with 2-7/8" tbg for overshot. Page ! Sep 18 1996 Cont TOH with 2-7/8" tbg. Tbg left in hole=mule shoe+2 jts+cut jt total of 78.43' left in hole. Change rams to 3-1/2" & test same. MU FTA #1 & strap & drift & RIH with same on 3-1/2" drillpipe. Engage fish with overshot depth @ 16512' & work free. Wash down t/16548' overshot depth+fish length=16628'. Unable to make forward progress. CBU & POOH with FTA #1. Sep 19 1996 Service rig. Cont POOH with fish. LD 119', 2-7/8" tubing fish, full recovery. Clear floor. MU BHA #2. Slip 42' drill line. TIH with mill & casing scraper to clean out to PBTD - tag up @ 16584'. Circ & wash 16584' to16873', carbolite returns. Circ bottoms up every 90'. Had to rotate thru hard spot @ 16621'. Circ at 16873', 35' to PBTD. Sep 20 1996 Wash sand 16873' to PBTD at 16899'. Circ long way. Rotate & reciprocate. Circ until carbolite stop at shaker. Reverse circ Xanvis sweep. Cont rev circ pumping casing wash. Clean pits & flow line of carbolite when clean brine to surface. Monitor well, fluid loss. POOH, LD drillpipe t/16300'. Mix & spot Xanvis LCM pill for fluid loss control. Cont POOH, LD drillpipe. Sep 21 1996 Finish POOH, LD drillpipe & BHA. Pull wear bushing. Change bottom rams to 2-7/8", test ram, OK. PU 2200 centrilift pump & service pump. RU to run ESP completion. TIH with 2-7/8" tubing from derrick. Drift tubing as run from derrick. Sep 22 1996 Service rig. Splice ESP cable. Cont RIH with 2-7/8" tubing from derrick. MU tubing hanger. Make ESP cable splice at tubing hanger. Plug heat trace & control line ports in hanger. Land tubing hanger. Run in lock down screws. Set two way check valve. ND BOP stack. NU FMC tubing spool adapter, Gen 5. Test pack off. NU CIW 2-9/16 5K tree, test tree-OK. Set BPV. Test surface lines. Freeze protect annulus. Freeze protect tubing. RD lines, secure well, clean pits. Nabors rig #4ES release 09/21/96 @ 2100 hrs. Page 2 ANNULAR INJECTION DATA ENTRY SCREEN Asset _Milne ................ Legal Desc Rig Name ~J~hnr,s:2_SE ............ - ................................................... Inj Well Name ~P~;~ ................. Permit Start ~~.~. Permit End._~.2~9.~_ Sur Csg Dep ~ .... Cumulative Data Well Total Mud/Ct~ ::;h~~?:~j ;;;~;El'b~dE.; I Daily Data e Dat'e' of Contaminated :/; Ri~W~shi!".! ~l~o..mpleli,o,,,nr:: ..~.Format[~n tI. :,: ~reez,e;~?'l,%.,Freeze'];;;~, ~i;;' ~;a. !y:~E;,~' ;' '. ;:;'?:!'i;':i .".'].?,-:,::'?,:?.;~l:~Anna us,,L,, ..... . .... -.,~..,..~ ....... ~ .,~.,: 7-,e,.::...-¢~..~ ~-~,.::',-.'.,. ~,'::.,:, ..:.' .'. · · -' "'","':'~'~;;';'- ;-" ":'~'"':' ',,'" '1 · -06 01/28/96 90 90 Rig .Nabors 27E MPF-06 01/29/96 188 40 228 Rig Nabors 27E MPF-06 01/30/96 165 165 Rig Nabors 27E MPF-06 01/31/96 275 275 Rig Nabors 27E MPF-06 02101/96 547 547 Rig Nabors 27E MPF-06 02/02/96 270 .... 270 Rig Nabors 27E MPF-06 02/03/96 545 545 Rig Nabors 27E MPF-06 02/04/96 2,000 130 2~130 .... Rig Nabors 27E MPF-06 04/20/96 900 ... 60 ...960 .. RIG NABORS 22E MPF-10i 05/23/96 960 40 1~000 RIG NABORS 22E MPF-10i 05/27/96 660 660 RIG NABORS 22E MPF-10i 05/28/96 70 70 RIG NABORS 22E MPF-10i 05/29/96 255 255 RIG NABORS 22E ,,. 'MPF-101 05/30/96 100 100 RIG NABORS 22E MPF-10i 05/31/96 550 550 RIG NABOR,S 22E .,, MPF-18 06/07/96 550 550 RIG NABORS 22E MPF-18 06/08/96 850 .... 850 RIG NABORS PPF .MPF-18 06/09/96 60 60 RIG NABORS PPF M PF-18 06/10/96 200 200 RIG NABORS ??F .... MPF-18 06/11/96 475 475 RIG NABORS ??F 1.8. 06/12/96 105 105 RIG NABORS ??F B 06/13/96 147 147 RIG NABORS ??F -18 06/14/96 290 290 RIG NABORS 22E MPF-18 06/15/96 650 60 710 RIG NABORS 22F MPF-29 07/06/96 200 20 220 RIG NABORS 22F MPF-29 07/07/96 550 ... 550 RIG NABORS 221= M. PF-29 07/06/96 1,000 1 ~000 RIG NABORS ??F MPF-29 ..... 07109196 t,280 ~-280 RI(~I-NABORS-22E .... MPF-29 07/1 0/96 1 ~280 ... ' 1 ~280 3 1500 RIG NABORS22E MPF-29 07/11/96 515 515 3 1500 RIG NABORS 22E MPF-29 07/12/96 125 125 3 1500 RIG NABORS 22E MPF-29 07/13/96 75 75 150 2.5 1700 RIG NABORS 22E MPF-29 07/14/96 110 110 2.5 1750 RIG NABORS 22E MPF-29 07/15/96 340 150 490 2,5 1700 RIG NABORS 22E MPF-29 07/16/96 100 100 2.5 1700 RIG NABORS 22E MPF-29 07/17/96 300 ....360 660 2.5 1650 RIG NABORS 22E M PF-29 07/1 8/96 200 95 295 2.5 1600 RIG NABORS 22E .... MPF-29 07/19/96 140 ....140 2.5 1650 .... RIG NABORS 22E {PF-29 07/22/96 340 160 70 570 3 1 700 RIG NABORS 22E ,,, ..~ OQQ 99~996/_0~1V: JeqLunu qol' gyro//data Gyrodata incorporated P,O, Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 July 30, 1996 B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: F-Pad, Well No: MPF-29, Milne Point, North Slope AK Enclosed please find one (1) original and six (6) copies and one (1) disk of the completed survey ofWell #MPF-29 We xvould 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/fec Serving the Wor!dwJde Energy Industry v,'Jti: Precision Survey ," ....... 'i-n gyro/data CONTENTS JOB NUMBER :AK0796G356 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR356.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR356.DOC gyro/data DISCUSSION JOB NUMBER' AK0796G356 Tool 749 was run in WELL# MPF-29 on ATLAS 15/32" Wireline inside drillpipe, survey was run without problems. SR356.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0796G356 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR356.DOC gyro/data 2. SURVEY DETAILS SR356.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0796G356 CLIENT: B.P. EXPLORATION RIG: NABORS 22E LOCATION: MILNE POINT FIELD, ALASKA WELL: MPF-29 LATITUDE: 70.507 N LONGITUDE: SURVEY DATE: 149.66 W 11 JUiY, 1996 SURVEY TYPE : MULTISHOT IN 9.625 IN. CASING DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 41.6 7600 SURVEY TIED ONTO: NA SURVEY INTERVAL: 100' 0-1100' 50'1100-7600' UTM CO-ORDINATES: TARGET DIRECTION: 330.03 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD SR356.DO( gyro/data 3. OUTRUN SURVEY LISTING SR356. gyro/data 4. QUALITY CONTROL SR356.DOC gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0796G356 TOOL NUMBER: MAXIMUM GYRO TEMPERATURE · MAXIMUM AMBIENT TEMPERATURE · 749 79.32 C 33.5 C MAXIMUM INCLINATION: 75,56 AVERAGE AZIMUTH: 330.08 WIRELINE REZERO VALUE: REZERO ERROR/K: CALIBRATION USED FOR FIELD SURVEY: 1534 CALIBRATION USED FOR FINAL SURVEY: 1534 PRE JOB MASS BALANCE OFFSET CHECK: -.3 POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES .36 USED 0.0 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 7600 75.52 328.72 4370.4 4248.09 -2445.15 7600 75.52 328.72 4370.4 4248.10 -2445.20 SR356.DOC gyro/data SR356.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0796G356 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.~ 1 2 3 4 5 3500 55.36 55.36 55.36 55.36 55.36 AZIMUTH M.D. ft I 2 3 4 5 3500 328.97 328.92 329.19 328.97 328.97 SR356.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR356.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0796G356 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 749 GYRO SECTION A0119 DATA S ECTi ON C0002 POWER SECTION C0001 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 BACKUP TOOL No. 750 GYRO SECTION A0126 DATA SECTION C0025 POWER SECTION C0026 COMPUTER POWER SUPPLY PRINTER INTERFACE A0122 A0074 A0029 A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 15/32" RUNNING GEAR 2.5" W/3" HEATSHIELD,3.6" W/B,4.5" CASING ROLLERS TOTAL LENGTH OF TOOL: 33.5 FEET MAXIMUM O.D.: 4.5 INCHES TOTAL WEIGHT OF TOOL: 310 POUNDS SR356.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0796G356 07/11/96 14:30 15:30 17:15 17:45 17:50 18:10 20:00 23::30 TRANS TO LOCATION ARRIVE AT LOCATION MU TOOL TOOL WORKING, STANDBY PU TOOL, MU PUMPIN SUB RIH. 0' STRT.INRUN 7600' STRT OUTRUN LD TOOL 07/12/96 00:00 01:30 03:50 BD. TOOL RD. ATLAS ARRIVE AT ATLAS RTN. TO RIG W / SURVEY. 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MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 MWD SURVEY JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL D I RE CT I ON RE CTANGULAR COORDINATE S DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -41.24 100.00 100.00 58.76 200.00 200.00 158.76 300.00 299.99 258.75 400.00 399.99 358.75 0 0 N .00 E .00 0 24 S 86.95 E .40 0 22 S .50 E .53 0 22 N 69.15 W .62 0 19 N 50.37 E .61 .00N .00E .00 .02S .35E -.19 .36S .70E -.66 .56S .39E -.69 .26S .30E -.38 500.00 499.99 458.75 600.00 599.99 558.75 700.00 699.99 658.75 800.00 799.98 758.74 900.00 899.98 858.74 0 24 S 71.16 E .37 0 22 S 53.59 W .69 0 23 S 89.91 E .72 0 29 S 67.75 E .20 0 31 S 2.79 W .58 .20S .87E -.60 .50S .94E -.91 .69S 1.02E -1.11 .86S 1.76E -1.62 1.47S 2.13E -2.34 1000.00 999.98 958.74 1100.00 1099.95 1058.71 1150.00 1149.91 1108.67 1200.00 1199.85 1158.61 1250.00 1249.76 1208.52 0 14 N 20.25 W .75 1 45 N 38.57 W 1.52 2 42 N 26.45 W 2.13 3 14 N 27.57 W 1.07 3 31 N 25.97 W .59 1.73S 2.04E -2.52 .34S 1.02E -.80 1.32N .01E 1.13 3.63N 1.17W 3.73 6.26N 2.49W 6.67 1300.00 1299.62 1258.38 1350.00 1349.42 1308.18 1400.00 1399.11 1357.87 1450.00 1448.64 1407.40 1500.00 1498.01 1456.77 4 48 N 28.20 W 2.58 5 26 N 27.52 W 1.29 7 17 N 26.65 W 3.70 8 22 N 28.26 W 2.20 9 45 N 27.58 W 2.77 9.48N 4.15W 10.29 13.43N 6.24W 14.75 18.37N 8.76W 20.28 24.41N ll.90W 27.09 31.36N 15.59W 34.96 1550.00 1547.29 1506.05 1600.00 1596.55 1555.31 1650.00 1645.70 1604.46 1700.00 1694.73 1653.49 1750.00 1743.59 1702.35 9 43 N 28.46 W .30 10 3 N 29.25 W .71 11 1 N 29.91 W 1.96 11 33 N 29.68 W 1.06 12 56 N 30.86 W 2.82 38.83N 19.56W 43.41 46.36N 23.71W 52.00 54.31N 28.23W 61.15 62.81N 33.09W 70.94 71.97N 38.45W 81.55 1800.00 1792.26 1751.02 1850.00 1840.88 1799.64 1900.00 1889.46 1848.22 1950.00 1937.83 1896.59 2000.00 1985.94 1944.70 13 29 N 30.55 W 1.09 13 32 N 30.46 W .10 13 47 N 31.39 W .67 15 30 N 30.61 W 3.44 16 7 N 30.10 W 1.27 81.81N 44.28W 92.99 91.87N 50.21W 104.67 102.01N 56.29W 116.48 112.84N 62.79W 129.12 124.60N 69.67W 142.74 2050.00 2033.74 1992.50 2100.00 2081.22 2039.98 2150.00 2128.31 2087.07 2200.00 2175.00 2133.76 2250.00 2221.39 2180.15 17 55 N 30.91 W 3.65 18 38 N 31.00 W 1.42 20 36 N 31.33 W 3.95 21 18 N 31.78 W 1.44 22 27 N 31.03 W 2.37 137.21N 77.11W 157.38 150.66N 85.18W 173.06 165.02N 93.87W 189.85 180.26N 103.23W 207.73 196.17N 112.94W 226.36 Si .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) , INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 PAGE DATE OF SURVEY: 071996 MWD SURVEY JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2300.00 2267.46 2226.22 2350.00 2313.10 2271.86 2400.00 2358.27 2317.03 2450.00 2402.99 2361.75 2500.00 2447.16 2405.92 23 24 25 27 28 18 52 52 17 32 N 30.65 W 1.73 212.87N 122.90W N 30.09 W 3.15 230.47N 133.22W N 29.77 W 2.02 249.04N 143.91W N 29.41 W 2.86 268.49N 154.95W N 28.78 W 2.59 288.95N 166.33W 245.80 266.21 287.63 310.00 333.41 2550.00 2490.89 2449.65 2600.00 2534.13 2492.89 2650.00 2576.93 2535.69 2700.00 2619.20 2577.96 2750.00 2661.03 2619.79 29 30 31 33 33 28 46 30 2 23 N 28.49 W 1.86 310.23N 177.95W N 28.57 W 2.62 332.28N 189.94W N 28.45 W 1.45 355.00N 202.28W N 28.25 W 3.11 378.50N 214.95W N 27.68 W .92 402.69N 227.80W 357.65 382.73 408.58 435.27 462.64 2800.00 2702.37 2661.13 2850.00 2743.14 2701.90 2900.00 2783.28 2742.04 2950.00 2822.61 2781.37 3000.00 2861.05 2819.81 35 35 37 38 40 2 40 30 43 46 N 26.94 W 3.42 427.67N 240.69W N 26.55 W 1.34 453.52N 253.72W N 27.37 W 3.79 480.08N 267.23W N 27.90 W 2.53 507.42N 281.55W N 29.34 W 4.48 535.47N 296.87W 490.73 519.62 549.38 580.22 612.17 3050.00 2898.40 2857.16 3100.00 2934.66 2893.42 3500.00 3191.13 3149.89 3550.00 3218.65 3177.41 3600.00 3245.04 3203.80 42 44 55 57 58 31 29 35 36 39 N 30.05 W 3.64 564.33N 313.33W N 30.30 W 3.94 594.09N 330.63W N 30.79 W 2.78 857.69N 486.31W N 29.92 W 4.27 893.71N 507.40W N 30.15 W 2.14 930.47N 528.65W 645.40 679.82 985.94 1027.67 1070.14 3650.00 3270.25 3229.01 60 3700.00 3294.11 3252.87 62 3750.00 3316.68 3275.44 64 3800.00 3338.17 3296.93 64 3850.00 3358.67 3317.43 66 46 12 7 58 37 N 30.82 W 4.39 967.67N 550.55W N 31.11 W 2.91 1005.34N 573.16W N 31.08 W 3.82 1043.54N 596.20W N 30.82 W 1.76 1082.26N 619.42W N 30.83 W 3.30 1121.42N 642.78W 1113.31 1157.23 1201.83 1246.97 1292.57 3900.00 3377.96 3336.72 3950.00 3396.20 3354.96 4000.00 3413.47 3372.23 4050.00 3429.73 3388.49 4100.00 3445.42 3404.18 67 69 70 71 71 58 13 21 4O 45 N 30.83 W 2.72 1161.02N 666.42W N 30.85 W 2.50 1200.99N 690.29W N 30.59 W 2.31 1241.33N 714.25W N 30.59 W 2.62 1282.02N 738.31W N 30.70 W .26 1322.87N 762.51W 1338.69 1385.23 1432.15 1479.42 1526.89 4150.00 3461.20 3419.96 4200.00 3476.42 3435.18 4250.00 3490.46 3449.22 4300.00 3504.33 3463.09 4350.00 3518.73 3477.49 71 73 74 73 73 27 6 15 31 0 N 30.64 W .59 1363.68N 786.71W N 30.29 W 3.37 1404.73N 810.86W N 29.60 W 2.65 1446.30N 834.81W N 29.55 W 1.48 1488.08N 858.52W N 29.89 W 1.21 1529.66N 882.26W 1574.34 1621.96 1669.94 1717.98 1765.86 S PAGE 3 IRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA),INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 MWD SURVEY JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 OPERATOR: BP EXPLORATION FT. 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. 4400.00 3533.48 3492.24 4450.00 3548.49 3507.25 4500.00 3562.73 3521.49 4550.00 3576.21 3534.97 4600.00 3590.09 3548.85 72 72 74 74 73 4O 22 33 9 37 N 29.84 W .67 1571.10N 906.05W N 29.64 W .73 1612.51N 929.70W N 29.70 W 4.36 1654.15N 953.43W N 29.71 W .80 1695.96N 977.28W N 29.94 W 1.13 1737.64N 1001.17W 1813.63 1861.32 1909.25 1957.39 2005.43 4650.00 3603.91 3562.67 74 16 4700.00 3616.90 3575.66 75 37 4750.00 3629.46 3588.22 75 16 4800.00 3642.35 3601.11 74 50 4850.00 3655.61 3614.37 74 24 N 29.83 W 1.30 1779.30N 1025.12W N 29.64 W 2.72 1821.22N 1049.06W N 29.98 W .96 1863.21N 1073.12W N 30.14 W .90 1905.03N 1097.32W N 30.19 W .91 1946.71N 1121.54W 2053.48 2101.76 2150.15 2198.46 2246.67 4900.00 3669.21 3627.97 74 2 4950.00 3683.06 3641.82 73 48 5000.00 3697.06 3655.82 73 40 5050.00 3710.72 3669.48 74 36 5100.00 3723.69 3682.45 75 19 5150.00 3736.50 3695.26 74 58 5200.00 3749.89 3708.65 73 58 5250.00 3763.98 3722.74 73 16 5300.00 3778.40 3737.16 73 12 5350.00 3792.64 3751.40 73 41 N 30.37 W .80 1988.26N 1145.81W N 30.54 W .58 2029.67N 1170.16W N 28.89 W 3.18 2071.36N 1193.95W N 28.66 W 1.93 2113.51N 1217.10W N 28.65 W 1.44 2155.89N 1240.25W N 28.70 W .73 2198.29N 1263.45W N 28.57 W 2.00 2240.57N 1286.53W N 28.62 W 1.42 2282.69N 1309.49W N 28.62 W .12 2324.72N 1332.42W N 28.16 W 1.30 2366.88N 1355.21W 2294.79 2342.83 2390.82 2438.90 2487.18 2535.50 2583.66 2631.62 2679.48 2727.39 5400.00 3807.09 3765.85 72 43 5450.00 3821.36 3780.12 74 6 5500.00 3835.53 3794.29 72 57 5550.00 3850.39 3809.15 72 28 5600.00 3865.33 3824.09 72 45 N 27.57 W 2.24 2409.19N 1377.58W N 27.30 W 2.83 2451.72N 1399.66W N 27.35 W 2.30 2494.32N 1421.67W N 27.02 W 1.16 2536.79N 1443.48W N 27.14 W .61 2579.27N 1465.20W 2775.22 2823.09 2870.99 2918.67 2966.32 5650.00 3879.62 3838.38 5700.00 3893.39 3852.15 5750.00 3907.55 3866.31 5800.00 3921.91 3880.67 5850.00 3935.96 3894.72 74 73 73 73 73 2 59 5 31 50 N 27.01 W 2.59 2621.93N 1487.01W N 26.30 W 1.37 2664.89N 1508.57W N 26.06 W 1.86 2707.92N 1529.73W N 26.51 W 1.23 2750.86N 1550.94W N 26.99 W 1.12 2793.71N 1572.54W 3014.18 3062.16 3110.01 3157.80 3205.71 5900.00 3950.13 3908.89 5950.00 3964.95 3923.71 6000.00 3979.64 3938.40 6050.00 3993.76 3952.52 6100.00 .4007.28 3966.04 73 72 73 73 74 12 18 31 40 55 N 27.05 W 1.29 2836.43N 1594.32W N 27.23 W 1.83 2878.92N 1616.10W N 28.15 W 2.99 2921.24N 1638.31W N 28.66 W 1.03 2963.43N 1661.13W N 29.67 W 3.15 3005.45N 1684.58W 3253.59 3301.29 3349.04 3396.99 3445.11 I0'080S S6'L86~ £I'668~ 69'0S8~ M8S'S8SE bi6S'6t~ 68' MSE'L£SE biZ0'T0~ 8T' ML£'68~E biS£'EE£~ 6T' MSE'£~E biI~'9~E~ 96' M00'SI~E biS0'~0E~ SE'I M 6L'I£ bi 8~ ~t M 6£'I8 bi £5 St M 8E'I£ N I£ SL LL'EO~ I0'~ EE'E88L 9£'8L£~ 09'6I~ 6L'98Lt 9L'5S£5 00'96£~ EL'T69L 96'I££~ 0E'£L£~ 00'009£ £9'6I£~ 88'09£~ 00'0SS£ ~I'E08~ SS'~0L~ ££'9S9~ £I'I£9~ M89'E6£E NE9'£9I~ tS' M~£'L9£E N90'EEI~ M86'I~£E biSS'080~ 8L' MI9'9I£E N9I'6£0~ 80'I ME~'£0CE N69'LI0~ 9~'~ 5L'LO£5 86'85£5 00'00SL 6E'96E~ 8S'L££5 £L'~SE5 L6'SE£5 00'005£ ~L'ELE~ 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ANCHORAGE ALASKA BP EXPLORATION (ALASKA), INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 PAGE DATE OF SURVEY: 071996 MWD SURVEY JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7953.20 4462.88 4421.64 8063.52 4491.97 4450.73 8161.43 4517.37 4476.13 8259.35 4543.04 4501.80 8351.51 4567.46 4526.22 74 75 74 74 74 22 3 52 43 31 N 31.53 W .70 4537.84N 2621.49W N 31.22 W .67 4628.69N 2676.90W N 31.15 W .19 4709.58N 2725.86W N 31.53 W .41 4790.29N 2775.01W N 31.86 W .41 4865.90N 2821.70W 5240.63 5347.01 5441.54 5536.01 5624.84 8445.33 4592.63 4551.39 8543.14 4618.83 4577.59 8638.28 4643.52 4602.28 8730.64 4666.57 4625.33 8824.60 4690.09 4648.85 74 74 75 75 75 20 34 20 45 15 N 33.66 W 1.86 4941.90N 2870.60W N 31.95 W 1.70 5021.10N 2921.64W N 29.55 W 2.57 5100.04N 2968.61W N 29.79 W .50 5177.75N 3012.88W N 31.39 W 1.73 5256.05N 3059.17W 5715.10 5809.21 5901.06 5990.49 6081.45 8916.79 4713.52 4672.28 9011.68 4737.11 4695.87 9106.99 4760.16 4718.92 9199.34 4782.76 4741.52 9296.51 4807.23 4765.99 75 75 76 75 75 18 54 5 34 15 N 29.90 W 1.56 5332.76N 3104.61W N 25.54 W 4.50 5414.10N 3147.35W N 26.25 W .75 5497.30N 3187.74W N 26.10 W .60 5577.65N 3227.23W N 28.08 W 2.00 5661.36N 3270.05W 6170.60 6262.41 6354.66 6444.00 6537.91 9389.42 4831.03 4789.79 9480.61 4854.76 4813.52 9574.85 4879.59 4838.35 9667.67 4904.16 4862.92 9762.47 4929.14 4887.90 75 74 74 74 74 3 47 39 38 48 N 28.72 W .70 5740.36N 3312.77W N 29.00 W .41 5817.48N 3355.26W N 28.93 W .16 5897.02N 3399.29W N 30.82 W 1.96 5974.62N 3443.87W N 29.57 W 1.28 6053.66N 3489.86W 6627.68 6715.72 6806.61 6896.11 6987.55 9857.47 4954.06 4912.82 9951.53 4978.74 4937.50 10045.93 5003.55 4962.31 10139.89 5028.22 4986.98 10237.59 5054.06 5012.82 74 74 74 74 74 47 46 45 48 30 N 30.24 W .68 6133.12N 3535.56W N 32.72 W 2.54 6210.51N 3582.95W N 31.44 W 1.31 6287.68N 3631.32W N 31.68 W .25 6364.93N 3678.77W N 33.30 W 1.63 6444.40N 3729.38W 7079.22 7169.94 7260.95 7351.58 7445.70 10329.97 5078.97 5037.73 10425.52 5104.97 5063.73 10520.70 5131.08 5089.84 10614.69 5155.82 5114.58 10710.60 5179.26 5138.02 74 74 73 75 76 11 13 56 32 10 N 31.10 W 2.32 6519.66N 3776.77W N 30.89 W .21 6598.47N 3824.12W N 32.35 W 1.50 6676.41N 3872.10W N 29.66 W 3.24 6754.12N 3918.80W N 29.96 W .72 6834.82N 3965.03W 7534.57 7626.50 7717.98 7808.63 7901.63 10804.07 5201.78 5160.54 10899.17 5224.92 5183.68 10994.13 5248.15 5206.91 11088.80 5271.47 5230.23 11184.01 5295.29 5254.05 75 75 75 75 75 56 52 48 40 20 N 28.14 W 1.90 6914.11N 4009.08W N 30.22 W 2.12 6994.63N 4054.04W N 30.56 W .36 7074.06N 4100.62W N 30.37 W .23 7153.14N 4147.14W N 30.91 W .66 7232.45N 4194.12W 7992.33 8084.54 8176.62 8268.37 8360.54 .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA),INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 MWD SURVEY JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 OPERATOR: BP EXPLORATION PAGE FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11279.70 5319.61 5278.37 75 11373.82 5343.60 5302.35 75 11465.88 5366.61 5325.37 75 11561.76 5389.96 5348.71 76 11653.95 5412.24 5371.00 75 13 15 47 1 59 N 30.44 W .49 7312.05N 4241.33W N 31.18 W .76 7390.22N 4287.95W N 29.95 W 1.42 7466.96N 4333.27W N 29.97 W .25 7547.53N 4379.71W N 30.52 W .58 7624.81N 4424.77W 8453.08 8544.08 8633.21 8726.20 8815.65 11747.73 5435.15 5393.91 75 11844.47 5458.60 5417.36 76 11939.37 5481.08 5439.84 76 12035.98 5503.75 5462.51 76 12128.73 5525.46 5484.22 76 43 13 22 29 25 N 31.29 W .84 7702.84N 4471.48W N 29.03 W 2.32 7783.97N 4518.62W N 28.85 W .24 7864.66N 4563.24W N 29.48 W .65 7946.66N 4609.00W N 29.04 W .47 8025.33N 4653.08W 8906.58 9000.42 9092.60 9186.50 9276.67 12223.02 5547.46 5506.22 76 12315.12 5568.83 5527.58 76 12411.69 5591.49 5550.25 76 12504.60 5614.20 5572.96 75 12599.57 5638.24 5597.00 75 12694.83 5662.23 5620.99 75 12789.32 5685.82 5644.58 75 12881 14 5709 04 5667 80 75 12974.65 5733.05 5691.81 75 13070.37 5758.00 5716.76 74 35 34 16 26 13 35 29 12 1 45 N 29.84 W .84 8105.17N 4698.14W N 29.43 W .43 8183.04N 4742.44W N 31.05 W 1.66 8264.13N 4789.71W N 28.43 W 2.88 8342.35N 4834.40W N 27.64 W .83 8423.44N 4877.58W N 28.00 W .53 8504.98N 4920.60W N 28.09 W .15 8585.73N 4963.62W N 28.54 W .56 8663.94N 5005.76W N 29.70 W 1.21 8742.88N 5049.74W N 29.50 W .36 8823.23N 5095.38W 9368.35 9457.93 9551.79 9641.88 9733.70 9825.82 9917.27 10006.07 10096.43 10188.83 13164.70 5782.99 5741.75 13259.49 5808.16 5766.92 13354.39 5833.24 5792.00 13449.51 5858.25 5817.01 13544.40 5882.98 5841.74 74 74 74 74 74 31 4O 41 49 58 N 29.97 W .53 8902.22N 5140.50W N 29.80 W .23 8981.45N 5186.03W N 28.90 W .92 9061.23N 5230.89W N 30.18 W 1.31 9141.07N 5276.14W N 31.13 W .98 9219.87N 5322.84W 10279.79 10371.18 10462.70 10554.46 10646.07 13639.65 5907.83 5866.59 74 13732.83 5932.28 5891.04 74 13825.88 5956.58 5915.34 74 13919.75 5980.63 5939.39 75 14015.83 6004.68 5963.44 75 46 47 56 22 38 N 31.40 W .34 9298.47N 5370.57W N 31.21 W .20 9375.29N 5417.28W N 30.92 W .34 9452.23N 5463.63W N 31.61 W .85 9529.79N 5510.72W N 32.23 W .69 9608.74N 5559.91W 10737.99 10827.88 10917.69 11008.40 11101.36 14112.00 6028.47 5987.23 14207.26 6052.31 6011.06 14297.66 6075.15 6033.91 14392.69 6098.91 6057.67 14487.38 6122.33 6081.09 75 75 75 75 75 42 18 24 38 43 N 30.80 W 1.44 9688.17N 5608.61W N 30.83 W .42 9767.38N 5655.86W N 30.68 W .20 9842.55N 5700.58W N 32.40 W 1.77 9920.96N 5748.71W N 30.87 W 1.57 9999.07N 5796.83W 11194.50 11286.72 11374.18 11466.15 11557.85 '~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA),INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 MWD SURVEY JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 14580.79 6146.20 6104.96 74 39 14675.66 6173.99 6132.75 71 16 14769.41 6205.88 6164.64 68 56 14865.77 6240.50 6199.26 68 56 14960.63 6275.14 6233.90 68 13 N 31.81 W 1.49 10076.19N N 31.89 W 3.57 10153.23N N 31.25 W 2.56 10228.32N N 30.81 W .43 10305.38N N 28.94 W 1.99 10381.94N 5843.79W 11648.12 5891.65W 11738.77 5937.80W 11826.87 5984.15W 11916.78 6028.14W 12005.07 15055.98 6312.12 6270.88 66 8 15148.89 6350.93 6309.69 64 28 15243.85 6392.85 6351.61 63 7 15337.99 6436.80 6395.56 61 12 15431.86 6483.33 6442.08 59 21 N 29.26 W 2.20 10458.72N N 28.64 W 1.90 10532.57N N 28.25 W 1.46 10607.48N N 26.31 W 2.73 10681.46N N 28.03 W 2.53 10753.98N 6070.87W 12092.94 6111.73W 12177.32 6152.31W 12262.49 6190.48W 12345.64 6227.68W 12427.05 15525.52 6532.38 6491.14 57 27 15620.90 6584.67 6543.43 56 2 15715.70 6638.79 6597.55 54 19 15809.15 6694.49 6653.25 52 29 15903.01 6752.90 6711.66 50 31 N 30.04 W 2.73 10823.72N N 29.72 W 1.52 10892.88N N 29.20 W 1.86 10960.63N N 28.76 W 2.00 11026.26N N 29.33 W 2.15 11090.48N 6266.38W 12506.80 6306.12W 12586.56 6344.39W 12664.38 6380.75W 12739.39 6416.40W 12812.83 15997.21 6814.11 6772.87 48 24 16089.74 6876.78 6835.54 46 19 16184.09 6941.87 6900.63 46 25 16279.69 7007.93 6966.69 46 9 16373.46 7072.92 7031.68 46 4 N 28.58 W 2.32 11153.10N N 28.70 W 2.26 11212.84N N 28.49 W .20 11272.80N N 27.44 W .84 11333.84N N 27.41 W .09 11393.83N 6451.06W 12884.39 6483.68W 12952.44 6516.37W 13020.71 6548.78W 13089.78 6579.91W 13157.30 16469.01 7139.19 7097.95 46 5 16562.44 7204.29 7163.05 45 34 16658.54 7271.50 7230.26 45 41 16753.75 7337.93 7296.69 45 49 16848.91 7404.31 7363.06 45 43 N 28.68 W .96 11454.58N N 28.17 W .68 11513.51N N 28.46 W .25 11573.99N N 28.73 W .24 11633.88N N 29.02 W .24 11693.58N 6612.27W 13226.09 6644.17W 13293.08 6676.75W 13361.75 6709.40W 13429.93 6742.32W 13498.10 16937.28 7465.97 7424.73 45 46 N 27.99 W 17014.00 7519.49 7478.25 45 46 N 27.99 W .84 11749.20N 6772.53W 13561.38 .00 11797.75N 6798.33W 13616.32 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 13616.32 FEET AT NORTH 29 DEG. 57 MIN. WEST AT MD = 17014 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 330.03 DEG. GYRODATA SURVEYS FROM 0.00' - 7,600.00' MD PROJECTED SURVEY AT 17,014.00' MD .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA),INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 PAGE DATE OF SURVEY: 071996 JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -41.24 .00 N .00 E 1000.00 999.98 958.74 1.73 S 2.04 E 2000.00 1985.94 1944.70 124.60 N 69.67 W 3000.00 2861.05 2819.81 535.47 N 296.87 W 4000.00 3413.47 3372.23 1241.33 N 714.25 W .00 .02 .02 14.06 14.03 138 . 95 124 . 89 586.53 447.58 5000.00 3697.06 3655.82 2071.36 N 1193.95 W 6000.00 3979.64 3938.40 2921.24 N 1638.31 W 7000.00 4226.76 4185.52 3751.07 N 2138.09 W 8000.00 4475.49 4434.25 4576.25 N 2645.06 W 9000.00 4734.26 4693.02 5403.91 N 3142.42 W 1302.94 716.41 2020.36 717.42 2773.24 752.88 3524.51 751.27 4265.74 741.23 10000.00 4991.47 4950.23 6249.87 N 3608.21 W 11000.00 5249.59 5208.35 7078.96 N 4103.51 W 12000.00 5495.34 5454.10 7916.21 N 4591.78 W 13000.00 5739.60 5698.36 8764.16 N 5061.87 W 14000.00 6000.75 5959.51 9595.77 N 5551.73 W 5008.53 742.79 5750.41 741.88 6504.66 754.25 7260.40 755.74 7999.25 738.85 15000.00 6289.75 6248.51 10413.93 N 6045.83 W 16000.00 6815.97 6774.73 11154.94 N 6452.06 W 17000.00 7509.72 7468.48 11788.89 N 6793.62 W 17014.00 7519.49 7478.25 11797.75 N 6798.33 W 8710.25 711.00 9184.04 473.79 9490.28 306.24 9494.51 4.23 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. .~RY-SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE 9 BP EXPLORATION (ALASKA),INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -41.24 41.24 41.24 .00 141.24 141.24 100.00 241.24 241.24 200.00 341.25 341.24 300.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 N .00 E .00 .00 S .00 E .00 .00 .04 S .63 E .00 .00 .62 S .70 E .00 .00 .47 S .14 E .01 .00 441.25 441.24 400.00 541.25 541.24 500.00 641.25 641.24 600.00 741.26 741.24 700.00 841.26 841.24 800.00 .12 S .49 E .01 .00 .29 S 1.14 E .01 .00 .66 S .74 E .01 .00 .70 S 1.31 E .02 .00 .99 S 2.08 E .02 .00 941.26 941.24 900.00 1041.26 1041.24 1000.00 1141.32 1141.24 1100.00 1241.47 1241.24 1200.00 1341.78 1341.24 1300.00 1.84 S 2.12 E 1.55 S 1.97 E .95 N .20 E 5.79 N 2.26 W 12.74 N 5.88 W .02 .00 .02 .00 .08 .05 .23 .15 .54 .31 1442.52 1441.24 1400.00 1543.86 1541.24 1500.00 1645.45 1641.24 1600.00 1747.59 1741.24 1700.00 1850.37 1841.24 1800.00 23.45 N 11.39 W 37.92 N 19.06 W 53.56 N 27.79 W 71.51 N 38.17 W 91.95 N 50.26 W 1.28 .74 2.62 1.34 4.21 1.59 6.35 2.13 9.13 2.78 1953.53 1941.24 1900.00 2057.88 2041.24 2000.00 2163.82 2141.24 2100.00 2271.49 2241.24 2200.00 2381.07 2341.24 2300.00 113.65 N 63.27 W 139.29 N 78.36 W 169.19 N 96.41 W 203.25 N 117.19 W 241.87 N 139.81 W 12.29 3.16 16.64 4.34 22.58 5.94 30.25 7.67 39.83 9.58 2493.26 2441.24 2400.00 2608.27 2541.24 2500.00 2726.32 2641.24 2600.00 2847.66 2741.24 2700.00 2973.98 2841.24 2800.00 286.13 N 164.78 W 336.00 N 191.96 W 391.17 N 221.74 W 452.30 N 253.11 W 520.74 N 288.67 W 52.02 12.19 67.03 15.02 85.08 18.04 106.42 21.35 132.74 26.32 3109.27 2941.24 2900.00 3255.31 3041.24 3000.00 3414.29 3141.24 3100.00 3592.68 3241.24 3200.00 3807.26 3341.24 3300.00 599.72 N 333.93 W 691.47 N 387.79 W 797.80 N 450.69 W 925.06 N 525.51 W 1087.91 N 622.79 W 168.03 35.28 214.07 46.04 273.05 58.98 351.44 78.39 466.02 114.57 S, RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 BP EXPLORATION (ALASKA),INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4086.64 3441.24 3400.00 4425.99 3541.24 3500.00 4795.74 3641.24 3600.00 5168.13 3741.24 3700.00 5519.48 3841.24 3800.00 1311.96 N 1592.62 N 1901.47 N 2213.64 N 2510.86 N 756.03 W 918.38 W 1095.26 W 1271.85 W 1430.23 W 645.40 179.38 884.75 239.35 1154.50 269.75 1426.89 272.39 1678.24 251.35 5868 . 91 3941 . 24 3900 . 00 6237.53 4041.24 4000.00 6651 . 74 4141 . 24 4100 . 00 7057.58 4241.24 4200.00 7466 . 42 4341 . 24 4300 . 00 2809.89 N 3120.24 N 3463.85 N 3798.18 N 4135.71 N 1580.78 W 1752.27 W 1960.74 W 2167.86 W 2375.67 W 1927.67 249.43 2196.29 268.62 2510.50 314.21 2816.34 305.84 3125.18 308.84 7871.64 4441.24 4400.00 8252.53 4541.24 4500.00 8629.26 4641.24 4600.00 9028.63 4741.24 4700.00 9428.95 4841.24 4800.00 4470.92 N 4784.69 N 5092.45 N 5428.94 N 5773.85 N 2580.20 W 2771.57 W 2964.30 W 3154.44 W 3331.12 W 3430.40 305.22 3711.29 280.89 3988.02 276.73 4287.39 299.37 4587.71 300.31 9808.62 4941.24 4900.00 10189.50 5041.24 5000.00 10558.15 5141.24 5100.00 10965.95 5241.24 5200.00 11364.57 5341.24 5300.00 6092.36 N 6405.59 N 6707.05 N 7050.54 N 7382.56 N 3511.88 W 3704.03 W 3891.10 W 4086.73 W 4283.32 W 4867.38 279.67 5148.26 280.88 5416.91 268.66 5724.71 307.80 6023.33 298.62 11772.43 5441.24 5400.00 12196.21 5541.24 5500.00 12611.32 5641.24 5600.00 13006.34 5741.24 5700.00 13384.70 5841.24 5800.00 7723.29 N 8082.55 N 8433.51 N 8769.48 N 9086.82 N 4483.91 W 4685.16 W 4882.85 W 5064.91 W 5245.02 W 6331.19 307.86 6654.97 323.78 6970.08 315.11 7265.10 295.02 7543.46 278.36 13766.97 5941.24 5900.00 14163.63 6041.24 6000.00 14562.03 6141.24 6100.00 14867.83 6241.24 6200.00 15126.41 6341.24 6300.00 9403.47 N 9731.14 N 10060.81 N 10307.03 N 10514.77 N 5434.36 W 5634.23 W 5834.26 W 5985.14 W 6102.01 W 7825.73 282.27 8122.39 296.65 8420.79 298.40 8626.59 205.80 8785.17 158.58 15347.21 6441.24 6400.00 15541.99 6541.24 6500.00 15719.90 6641.24 6600.00 15884.67 6741.24 6700.00 16038.08 6841.24 6800.00 10688.70 N 10835.74 N 10963.61 N 11078.13 N 11179.95 N 6194.06 W 6273.33 W 6346.06 W 6409.47 W 6465.68 W 8905.97 120.80 9000.75 94.78 9078.66 77.91 9143.43 64.77 9196.84 53.41 S RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 11 BP EXPLORATION (ALASKA) , INC. MILNE POINT / MPF-29 500292268800 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/30/96 DATE OF SURVEY: 071996 JOB NUMBER: AK-MM-960736 KELLY BUSHING ELEV. = 41.24 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 16183.17 6941.24 6900.00 11272.22 N 6516.05 W 9241.93 45.10 16327.78 7041.24 7000.00 11364.63 N 6564.76 W 9286.54 44.60 16471.96 7141.24 7100.00 11456.44 N 6613.29 W 9330.72 44.18 16615.23 7241.24 7200.00 11546.74 N 6661.99 W 9373.99 43.27 16758.50 7341.24 7300.00 11636.87 N 6711.03 W 9417.26 43.27 16901.82 7441.24 7400.00 11726.77 N 6760.60 W 9460.58 43.32 17014.00 7519.49 7478.25 11797.75 N 6798.33 W 9494.51 33.93 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS l~'89£8 IS'SL[8 0~'£8~8 88'0608 [L'866L ME£'99I~ N66'9S[L L9' M L9'0£ N 9E ~L MI6'6II~ N60'LLIL 8[' M 90'0£ N ~5 ~£ M~8'£L0~ NOI'L60L 9~' M ~8'6~ N OS ~£ MLL'LEO5 N60'LIOL 8~' M ~0'0£ N 9~ ~L M56'I86£ NSI'L£69 ~£' M I9'6E N ~ 9L ~E'I~E~ 8~'[6[S 6£'I6III £~'LEE~ L9'89~ LI'960II £0'~0ES £~'S~ES S6'000II ES'08IS 90'~ES SL'S060I LS'L~I~ II'66I~ 8L'0180I ~E'906L IL'~IgL 0£'£ELL Lg'E£9L M9~'9£6£ N[9'9~89 8~' M I£'6E N 5I 9L MLE'E68£ N6S'LLL9 LI'E M II'6E N ~ 9L M~S'9~8£ N6E'L699 ~L' M ~E'0C N L~ £L MEP'I08£ NE6'8199 9P' M P9'6E N £E 5L ME~'9~L£ NOI'6£S9 £0'~ M 8I'6E N EE PL II'S£IS S£'9LIS PS'SILOI gS'EIIS 9L'£SI~ gg'gg90I 6~'L80S £L'SEIS 9~'9~50I ~8'I90S 80'£0IS 9~'~£~0I £E'9£05 L~'LLOS 8~'6~5L 98'L~£L 6I'99~£ £L'~LIL 60'580L M9E'0IL£ N6£'6S~9 SE' M EE'I£ N 95 5L M09'E99£ NIS'I8£9 ~S' M S5'I£ N 0~ 5L M86'~I9£ NSI'£0£9 96' M £I'I£ N ~ SL M~8'89S£ N~£'SE~9 9~'I M IE'0£ N ~S ~L ME£'EES£ N£S'L~I9 I8'E M E~'I£ N LE SL SL'0IOS 66'ISOS L0'EgEOI 8S'S865 ~8'9~0S £0'£~IOI 08'0965 ~0'E00S ~0'[S00I £S'9£6~ I8'L£6~ 6£'8~66 09'~I6~ ~8'£S6~ I9'~986 0I'P669 8£'E069 PE'II89 C0'EEL9 6S'6E99 M6S'9L~£ NL8'8909 £I' M £8'8E N 8~ 5L MLE'E£~£ NSS'886S E6' M S6'8E N SS ~L M~L'88££ N~'806S 8L' M 60'8E N 0~ ~L M£E'L~££ N0~'6~8~ £~' M ~'L~ N 6£ ~L M£6'~0[£ Ng0'LSL~ LS' M 90'LE N 5 ~L 8~'888~ ~8'6E65 09'0AL6 I6'£98~ SI'~06~ 0S'~L96 £I'6£8P L£'088P E0'I8S6 ~9'~I8~ 68'~S8~ ~'88~6 E9'68L5 98'0C8~ L~'E6£6 08'I~S9 [£'0S~9 0~'8S£9 £6'L919 IS'ALI9 MLE'S9~£ NI9'899S 99' M 9S'9E N LI SL MS9'~EE£ N£~'98SS CL' M ~0'9E N 6£ SL M09'58I£ NE~'£0SS IE' M 8~'SE N S 9L MI9'S~I£ NS~'IE~S C~'E M 0~'~E N 9I 9L M5£'~0I£ NE£'0~£~ IL'I M 6£'LE N LE SL 9£'99L~ 09'L08~ E9'I0£6 09'ESL5 ~8'£8L~ E6'9016 6£'6IL~ £9'09L5 LB'III6 90'L69~ 0£'8£L~ E~'8106 £E'~L9~ L~'SIL~ L6'~68 ~0'9809 9£'~66S I0'S06S £I'~I8S LS'SELS MS0'E90£ N~9'6~ES CS' M E0'6E N L ~L M9L'LI0£ N05'6LIS ~9' M 6L'SE N 5£ ~L MEI'~L6E N~8'00I~ L0'~ M 0E'8E N ~ ~L ME6'0£6E N£5'I~0§ E~'~ M 00'0£ N £~ 5L M68'£88E NE£'9~6~ 68' M II'~£ N 6~ £L 6I'0S9P £P'I69P E£'0£88 IE'9E9~ SP'L99~ 9S'S£t8 9£'£09~ 09'~59~ I£'£~98 SS'6LS~ 6L'0~9~ SS'PSS~ 0I'96SP E£'LSP8 ~£'~£9S 65'E5SS L~'[S~S ~£'T9£S 56'6£~S M68'~£8~ N6£'0£8~ 98' M L9'££ N [~ ~t M£~'ESLE N85'£6t~ T~'T M LS'E£ N ~E 5L MS£'~£LE N0£'LIL~ LB' M ~9'I£ N 6S ~L M£6'S89E N00'059~ S6' M 8~'E£ N 8 SL M9S'T~9~ N00'L£S~ 00' M £S'T£ N EE ~L £E'6ES5 L~'OLS5 ££'~9£8 E8'£0S~ 90'S5S5 06'9918 8T'6£5~ E~'0~S~ 0S'££T8 98'5S55 0I'9655 0T'6L08 9L'TES~ 00'£955 0~'£S6£ 'i~A N~DNI $~flOD ~OIIH~A qRfOIi~A ~S~ NOILkrHoqdxz d~ :HOikr~SdO 'i~ 5E'I~ = 'AZqZ ~NIHSfl~ X~q~M 96009-I~-M~ :~~ ~0~ X~AHDS &OHS-I&%D~ DI&~NDhq4 960EL0 :A~A~DS ~0 [~ 96009-I~-A~ O0889EE6EOOS 6E-~4N / iNIO~ ~N~IN NOIiYHOqdX~ d8 k~H S%fq~f .~k~HOHDN~f S~OIAH,~S DNI~I~IIHCI N/1S-AHk,~..S 6I'99SII I0'S£PII 8£'£8£II 6£'I6gII gt'g0gII M89'5££5 N68'0E00I MS9'6E£S N8I'E566 9I' M05'£89S N80'£986 M60'££9S N09'£8£6 MPP'E6SS N66'90£6 8~' M 9£'0£ N ~ S£ M £E'0£ N 9£ SA M 8I'0£ N £E SA M 05'0[ N E£ S£ ££'E£09 I9'£II9 0£'56~5I 6£'6~09 6S'0609 9E'00~I 56'~E09 6I'L909 89'S0£~I 9I'U009 05'£~09 £9'0IE5I 8I'6£6S ES'0E09 £0'6II5I 8L'0IIII 80'6IOII £8'L~60I S9'9£80I 80'S~LOI M~L'SgSS N6L'L~96 MI0'869S NS~'69~6 8£' M99'659~ N00'ZL96 IS' MIS'I0P~ N6E'P6£6 6P' M66'£S£S NIg'9I£6 M 9/.'0[ ~I 8£ SA M 00'~£ N 0I SA M 9S'I£ N 9S P£ M 80'I~ N 8S ~£ £S'SS6S I8'966S PI'~E0PI 86'I£6S EE'££6S E~'6E6£I II'806S S£'6~6S S0'S£8£I 0L'£88S P6'PE6S EP'0PL£I 5I'6S8S 8£'006S 8£'S~9£I 86'£S90I M~E'L0£S N00'8£E6 £~'59SOI M9S'I9ES NE0'I916 8E' SE'££~0I MIE'SIES NS~'E806 ES' 6S'I8£0I M~E'69IS NSI'£006 9I' £8'06EOI ME0'SEIS NL~'~E68 SI'I M 99'0£ N 6S ~/. 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OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7953.20 4463.00 4421.76 4537.00 N 2621.56 W 3490.20 8252.67 4541.24 4500.00 4781.98 N 2774.99 W 3711.44 221.24 8629.64 4641.24 4600.00 5089.18 N 2968.86 W 3988.40 276.96 9030.80 4741.24 4700.00 5432.34 N 3150.77 W 4289.56 301.16 9432.88 4841.24 4800.00 5781.77 N 3322.65 W 4591.64 302.08 9814.88 4941.24 4900.00 6106.20 N 3497.69 W 4873.64 281.99 10201.56 5041.24 5000.00 6426.39 N 3690.02 W 5160.32 286.68 10571.73 5141.24 5100.00 6734.88 N 3868.44 W 5430.49 270.17 10984.46 5241.24 5200.00 7083.23 N 4065.89 W 5743.22 312.72 11385.40 5341.24 5300.00 7416.75 N 4264.60 W 6044.16 300.94 11797.86 5441.24 5400.00 7761.04 N 4468.47 W 6356.62 312.46 12229.85 5541.24 5500.00 8126.12 N 4676.60 W 6688.61 331.99 12639.16 5641.24 5600.00 8471.59 N 4871.81 W 6997.92 309.31 13037.46 5741.24 5700.00 8808.48 N 5059.23 W 7296.22 298.30 13418.82 5841.24 5800.00 9127.94 N 5241.90 W 7577.58 281.37 13803.37 5941.24 5900.00 9446.03 N 5433.43 W 7862.13 284.55 14202.10 6041.24 6000.00 9776.43 N 5632.92 W 8160.86 298.73 14600.76 6141.24 6100.00 10108.94 N 5828.72 W 8459.52 298.65 14896.07 6241.24 6200.00 10347.19 N 5971.45 W 8654.83 195.31 15150.79 6341.24 6300.00 10549.95 N 6088.58 W 8809.55 154.72 15369.37 6441.24 6400.00 10720.99 N 6180.75 W 8928.13 118.58 15562.47 6541.24 6500.00 10865.77 N 6260.18 W 9021.23 93.10 15739.35 6641.24 6600.00 10993.38 N 6330.81 W 9098.11 76.88 15903.02 6741.24 6700.00 11105.97 N 6394.81 W 9161.78 63.67 16055.35 6841.24 6800.00 11205.25 N 6452.59 W 9214.11 52.33 16200.17 6941.24 6900.00 11297.06 N 6503.03 W 9258.93 44.83 16345.16 7041.24 7000.00 11389.39 N 6552.99 W 9303.92 44.98 16489.41 7141.24 7100.00 11480.77 N 6602.57 W 9348.17 44.25 16632.85 7241.24 7200.00 11570.42 N 6652.95 W 9391.61 43.45 16776.73 7341.24 7300.00 11660.32 N 6704.14 W 9435.49 43.88 16920.37 7441.24 7400.00 11749.70 N 6755.54 W 9479.13 43.63 17014.00 7506.46 7465.22 11807.92 N 6789.06 W 9507.54 28.42 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS MEMORANDUM TO: David J~ Chairm~-~"' THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 9, 1996 Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi, ~.,,~.,. SUBJECT: Petroleum Inspector FILE NO: AW9JJIDD.DOC BOPE Test, Nabors 4ES BPX, Milne Point Unit Well MPU MPF-61 PTD #96-117 Wednesday, October 9, 1996: I traveled to BPX's Milne Point Unit to witness a BOPE test on Nabors 4ES working over well #MPF-61. The test went slow due to a leaky back pressure valve set in the tubing hanger. There were three failures noted. The inside Blooey line valve on the choke manifold had a slight leak which could not be sealed by greasing, this valve will be changed out while the rig is down for wireline work scheduled after the tubing is pulled. The kill side HCR valve also leaked and will be changed out before the rig pulls tubing. The gas detection system was tested and a bad H2S sensor was found in the pits, this will be changed out and calibrated after the burn-in period. I also noted that the high limit on the methane detectors was set at 60% LEL. I requested that these be brought in line with our guidelines for rig gas detection systems. Summary: I witnessed the initial BOPE test on Nabors 4ES working over well #MPF-61. The test lasted 4 hours and there were 3 failures observed. Attachment: AW9JJIDD.XLS cc; Randy Thomas (Shared Services drilling) NON-CONFIDENTIAL DOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nabors Alaska BPX MPF-61 Set @ Weekly Rig No. 4ES PTD # Rep.: Rig Rep.: Location: Sec. Other DATE: 10/9/96 Rig Ph.# 6594f54 Larry Meyers Gene Sweat 6 T. 13N R. fOE Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams 1 Choke Ln. Valves 1 HCR Valves Kill Line Valves Check Valve N/A MUD SYSTEM: Visual Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector F Well Sign P Drl. Rig P Hazard Sec. P Test Press. P/F 25O/5,000 P 1' 250/5,000 P N/A N/A 250/5,000 250/5,000 P P 250/5,000 2 250/5,000 F 1' P 250/5,000 250/5,000 N/A Alarm P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F note 250/5, 000 note 250/5,000 f 25O/5, OOO p f 250/5,000 p CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 12 Test Pressure P/F 250/5,000 F 28 250/5,000 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Four bottles 3, 000 I P 1,800 I P minutes 26 sec. minutes 10 sec. P Remote: P avemge 1900 Psig. TEST RESULTS Number of Failures: 3 ,Test Time: 4.0 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: #2 Blooey line valve on choke manifold leaked, greased and retested valve still leaked, change out.~'' H2S & Methane detectors out of calibration,'"H2S in pits inop,'"repair recalibrate and notify inspector for retest. HCR on Kill side leaked slightly,~hange out retest and notify inspector of results. note: Kelly not needed, Test if picked up(notify inspector beforehand) Distribution: orig-Well File c -~Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev.12/94) AW9JJIDD.XLS HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOR3kGE AK, 99501. Dear Sir/Madam, Reference: BP MILNE POINT/KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Date: RE: 23 September 1996 Transmittal of Data ECC #: 6776.00 Sent by: HAND CARRY Data: ML-LDWG Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by , i ECEIVEIJ & Cons. mmis on HOWARD O~ Attn. ~S~ OIL + GAS CONSERVATION 3001 PORC~I~ DRI~ ~CHO~GE ~, 99501. Date: 4 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ~ ~--O~ MPF-02 MPF-29 1 PFC/PERF FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6479.02 Run # 1 Run # 1 6766.01 Run # 1 6774.01 Run # 1 Run # 1 6776.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street ~ Suite 201 ~' ' Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: . Date: MEMORANDUM State of Alaska TO: THRU: FROM: . .~/~laska Oil and Gas Conservation Commission DATE: P. I. Supervisor -z/',~' ~. 3 _~ t,~t~'~" Lou G rim aid i,"c~.~.~ '" SUBJECT: Petroleum Inspector July 14, 1996 4WOJGMDD.DOC Formation Integrity Test BPX MPU MPF-29 Milne Point Unit Kuparuk River Field PTD # 96-117 Sunday, July 14,1996: I witnessed the Formation Integrity test on BPX well # MPU MPF-29 in the Milne Point Unit of the Kuparuk River Field. A short history of this well, During the original attempt to cement the surface casing resulted in a string of casing cemented internally to surface. This was caused by a float collar plugging up while pumping the cement. The cement was drilled out to the float collar and the hole was circulated out. The plan was to pressure test the casing then shoot some holes above the estimated top of cement and circulate cement to surface. The pressure test of the casing was attempted but resulted in immediate circulation to surface. At the time it was not known whether the well was circulating at the shoe or a possible leak somewhere in the casing. A Desco slug was pumped (this material lends itself to a very strong red color) in a attempt to see at what depth they were circulating? According to pump strokes~ it was determined that they were circulating at the shoe. The surface casing was again cemented. All cement was pumped with no cement reaching surface. Returns were constant. A top job was performed and the cement was allowed to set up. The BOP's were nippled up and I came to location and witnessed a good BOP test (see AWOJGLDD.DOC/.XLS). 4WOJGMDD.DOC pa_qe 3 of 3 4) The cementing unit did a good job of providing a slow steady pump rate, during the squeeze portion of the cement job the rig pumps were used and did not seem to provide a steady rate. SUMMARY: I witnessed the Leak Off tests and cement squeeze job on BPX well MPF-29 in the Milne Point Unit; Attachments: 4WOJGMDD.XLS (6 pages) cc; Steve Horten (Shared Services drilling) CONFIDENTIAL AOGCC Confidential Cover Sheet Pag~ 1 LEAK OFF TEST Well Name MPU MPF-29 Permit to Drill # 96-117 Operater BPX Field/Unit Kuparuk River Field, Milne Point Unit Company Representative Dave Mount|or Ri_q Nabors 22-E A.O.G.C.C. Inspector Lou Grimaldi, John Spauldin.q Mud Weight in hole (P.P.G.)I 8.501 Surface Hole T.D. 8040 S.G. of Mud in hole 1.02 Drill Out MD 8080 Gradient of Mud in hole 0.441 Drill Out 'I-VD 4499 ,Su,rface pressure at break "72'5 Hydrostatic Head of Mud at T.D. 1985 Surface pressure taken to 840 B.H.P. at T.D. (with Leak Off pressure applied) 2710 Surface pressure bled to (10 seconds) 840 Equivilant Mud Gradient 0.60 Surface pressure bled to (1 minute) 820 EquiVilant Mud Specific Gravity 1.39 Surface pressure (Stabilized) 740 Equivilant Mud Weight at Break (P.P.G.) 11.60 COMMENTS Is this a repeat test No T.V.D. at Total Depth 7250 If Yes what was last tests EMW ? M.W. needed to balance wells max B.H.P. 9.60 Anticipated maximum BHP at final T.D. 3619 Mud Weight called for in program Results are from Leak off test performed after first test revealed possible channeling. Casing was squeezed with 29 bbl's of "G" cement and twenty more feet were drilled out before this second test was peformed 4WOJG M D D.XLS 7/16/96 AOGCC Confidential L.O.T. #1 "~*~i~-;~" i~=i~v_v._= _v__ Off ..................................... MPU F-29 Leak Off Test 0.00 0 0 2900 .... ...................... 0:~5" 60 .......... 20 ........... ... 2800 . .......................... ~.~ ..... ~ ............. ~0 .............. 2700: :,: ' .':'.:.; ~:;:~:,": .~ :~, ~:~;';: ;~'" :::./,?:¥/' ._~L~"'.~..'.o~?'.'....".~..'~..'~ .... ".'.'.. ~ ~. '~7...". .... ~oo 1.00 76 90 2500 .................. ..... 1.25''i02~;~0 .... ~56 ...... 130~¢~ .............. .... .__ 2400 ,,,;;,;:,::;~',:~:~:~,,~,~;': :(:;~; '~::;:; :.~.:,:; :.;;; ,:: :~::. ',; :. ~:, :~ .:" 2300 . 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',[::[. :,, ', ;: .' ............................................................................................... 1.75 228 290 '. ................................................................... 2200 · ~;':::.'~::::': ':~:=:. ;.'~:'::=..~:[:= ......................................................................................2.25 397 500 2.50 490 600 ; :~: : ' ; ........ ~' .. ~ .... :':' : .: ......................................................... 1900-: :', : ~ : : :: ==; ', ' .:=. ," 2.75 583 700 ' · · 3.00 665 ' ~70 1800 · · :..~.:=~: .;:,::=....:.:h. 3.50~0 845 820 Note; At ~ : ..................... ~ '~='~=' .... :~=~.~, ,~::~: · ;:.~,.= ..~ .~ ~:,~: ~=~=~{~ ~ ~ .~.~;:' ~[:~{~, ~. : ~ : ~:;:~ ¢,v~'. 3.7511 940 800 This point ~ 1500 ..... 4.00~2 1040 790 the pumps ~ ..~: .~ .~ == ..... :=~ , . ~; ,,?. ~ ~ . 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TVD 4499 BBL'slMinutes 4WOJG M DD.XLS 7/16/96 MEMORANDUM TO' David Johns'~ton, Chairman THRU: Blair Wondzell, ~t~'~ P. I. Supervisor FROM: Lou Grimaldi, ~o~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 12, 1996 FILE NO: AWOJGLDD.DOC SUBJECT: BOPE Test, Nabors 22E BPX, Milne Point Unit Well MPU MPF-29 PTD #96-117 Friday, July 12, 1996: I traveled to BPX's Miine Point Unit to witness a BOPE test on Nabors 22E drilling well #MPF-29. I arrived at 2130 PM, the test got underway at 0030 and ended approximately 0330 in the morning. The test went smoothly with all observed equipment functioning properly and holding its pressure test with no leakage. The test procedure used was well planned and all BOPE received a full function and pressure test. The Methane and H2S detectors were tested and worked fine. The area surrounding the rig was orderly and well kept. i am impressed with the condition of this rig, it shows the crews concern for maintaining a top rig. Summary: I witnessed the initial BOPE test on Nabors 22E drilling well #MPF-29. The test lasted 3 hours and there were no failures observed. Attachment: AWOGLHDD.XLS CC; Randy Thomas (Shared Services drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Nabors Rig No. BPX MPF-29 Set @ X Weekly Other DATE: 7/12/96 22E PTD # 96-1 17 Rig Ph.# 659-4454/4446 Rep.: Dave Mountjoy Rig Rep.: Leonard Schiller Location: Sec. 6 T. 13N R. 'IOE Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Well Sign Drl. Rig Hazard Sec. Test Press. 250/3, OOO 250/5, OO0 250/5,000 250/5,000 250/5,000 P/F P 250/5,000 P 1 250/5,000 P N/A 250/5,000 N/A Visual Alarm P P P P P P P P P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5, 000 P 250/5,000 P 250/5, 000 P 250/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 18 250/5, 000 P 42 250/5, 000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3 Eight Bottle~ 2,950 P 1,500 P minutes 39 sec. minutes 17 sec. P Remote: P 2000 average Psig. TEST RESULTS Number of Failures: 0 ,Test Time: ~ Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST/ Distribution: orig-Well File c- Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: louis R. Grimaldi FI-021 L (Rev.12/94) AWOJGLDD.XLS TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 27, 1996 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box ' r,, ~96o~ Anchorage, ~ '~ .~,-~ 99519-6612 Rez Miine Point Unit MPF-29 BP Exploration (Alaska) Inc. Permit No: 95-117 Sur. Loc. 1881'NSL, 2678'WEL, Sec. 6, T13N, R10E, UM Btmhole Loc. 3155'NSL, 4348'WEL, Sec. 25, T14N, POE, UM Dear Mr. Shultz: 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 on the North Slope pager at 659-3607. dlf/Enclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK/-~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 42' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1881' NSL, 2678' WEL, SEC. 6, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 25100302630-277 2913' NSL, 4209' WEL, SEC. 25, T14N, R9E MPF-29 Attotal depth 9. Approximate spud date Amount $200,000.00 3155' NSL, 4348' WEL, SEC. 25, T14N, R9E 06/30/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355021, 2125'I No Close Approach 5083 17087' MD / 7571' TVD 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 1000' Maximum Hole Angle 75.13° Maximum surface 2894 psig, At total depth (TVD) 7250' / 3619 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 7984' 31' 31' 8015' 4480' 1453 sx PF 'E', 856 sx 'G', 150 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 17057' 30' 30' 17087' 7571' 215 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 MD TVD Structural Conductor Surface Intermediate Production RECEIVED Liner JUN 2 5 1996 Perforation depth: measured Alaska 011 & Gas Cons. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number Kathy Carnpoarnor, 564-5122 21. I hereby cert.,~~.~:~:~ f~.~~ ~ng cs true and c°rrect t° the best °f my kn°wledge. Signed //, ~~0 ~,--~,,.~ ~./,Z~/~,t le ~__.~'~ /'~ ~' Date . "- ~ ' % Commission Use Only Permit Number APl Number I Approval Date I See cover letter ~'~'--///.,~ 50- ¢ .~.'~ --- ~ ~ ~ ~ ~:~I ~ '" c~ ? '" ~"~:'I for other requirements Conditions of Approval: Samples Required [] Yes .~ No Mud Log Required [] Yes ~'No Hydrogen Sulfide Measures i-lYes ,,~No Directional Survey Required ~¢Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 10M; [] 15M Other: Original Signed By by order of Approved By Di~ViI~ W. Johnston Commissioner the commission Date , Form 10-401 Rev. 12-01-85 i,licate Shared Services Drilling J Well Contact' James E. Robertson Name' IMP F-29 Well Plan Summary 564-5159 IType of Well (producer or injector)' IKUPARUK PRODUCER JSurface Location' Target Location: Bottom Hole Location: 1881 NSL 2678 WEL Sec 06 T13N R10E UM., AK 2913 NSL 4209 WEL Sec 25 T14N R09E UM., AK 3155 NSL 4348 WEL Sec 25 T14N R09E UM., AK IAFE Number: 1337041 I I Rig: I Nabors 22-E IWell Design (conventional, slimhole, etc.)' IMilne Point Ultra Slimhole Longstring 9- 5/8", 40# Surface X 7", 26# Longstring Formation Markers' Formation Tops MD TVD (bkb) base permafrost 1,797 1,792 NA 6,072 3,940 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 7,865 4,442 Base of Schrader Bluff Sands (8.3 ppg) HRZ 16,1 86 6,934 High Resistivity Zone Top Kuparuk 1 6,497 7,154 Kuparuk Cap Rock Target Sand -Target 1 6,692 7,292 Target Sand (9.6 ppg) Total Depth 17,087 7,571 Casing/Tubing Prol ram: Hol~ (~sg/ "Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 1 12/1 12 12 1/4" 9-5/8" 40# L-80 btrc 7984 31/31 8015/4480 8- 1/2" 7" 2 6 # L-80 btrc 17057 30/30 1 7087/7571 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 +7250 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3619 psi is 2894 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. Intermediate N/A Final Cased Hole Logs' MWD Directional and LWD (GR/CDR/CDN). N/A Mudloggers are NOT required for this well. RECEIVED JUN 2,5 199G Alaska 011 & Gas Cons. Commissio~ Anchorage Mud Pro~lram: ISpecial design considerations None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.0 150 35 1 5 30 1 0 1 5 Intermediate Mud Pro)erties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~]el Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 1 5 1 0 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: The closest approach between MP F-29 and MP F-25 is at 4822' md/3661' TVD. At this point MP F- 25 travels at an azimuth of 322.5° while MP F-29 is to be travelling at an azimuth of 330°. Although the wellpaths are virtually parallel at this point MP F-25 is only at 57° of angle while MP F-29 is to be at 75.13° of angle and quickly climbing away from MP F-25. Also, the surface casing shoe (9- 5/8", 40# casing)for MP F-25 is shallow set at 3,420' md/2,982' tvd. This is 680 TVD FT ABOVE the close approach point and the leakoff test associated with the 9-5/8" casing shoe of MP F-25 yielded an equivalent mud weight of 13.7 ppg indicating a very solid shoe In summary, with the wellpaths of MP F-25 and MP F-29 travelling in the same direction yet diverging at their closest point - coupled with a very strong 9-5/8" casing shoe 680 TVD FT above the closest approach point and a risk assessment which states that intersection of the wellpaths is statistically impossible.- MP F-25 will not be shut-in. I KOP: I1000' Maximum Hole Angle: Close Approach Well: I5'13° (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is +1,850' TVD. 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. 2. There are _+24 wells on Milne Pt. 'F' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not OCCUr. RECEIVED JUN 2 5 1996 Alaska Oil & Gas Cons. Commission Anchorage , , o , . . . . . 10. 11. 12. 13. 14. 15. 16. MP F-29 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD and run Gamma Ray/Resistivity LWD across Schrader Bluff sands. Run and cement 9-5/8" casing. ~ ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 10' of new formation. Perform FIT to 12.5 ppg. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with appropriate weight brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and put the well on production. DRILLING HAZARDS AND RISKS: Seethe updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY 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. Close Approach: There are no close approaches associated with the drilling of MP F-29. Lost Circulation: There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3,732 psi @ 7,250' TVD). There has been no injection in this region, therefore the reservoir pressure should not exceed this estimate and potentially could be slightly underpressured. RECEIVED JUN 2 5 1996 Alaska Oil & Ga~ Con~. Commission Anchorago CASING SIZE: MP F-29 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE' Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER' 11.63 gal/sk APPROX NO SACKS: 1453 THICKENING TIME: Greater than 4 hrs at 50° F. LEAD CEMENT: ANUULAR VOLUME FROM TOP OF TAIL CEMENT TO BASE OF PERMAFROST + 30% EXCESS, AND ANNULAR VOLUME FROM BASE OF PERMAFROST TO SURFACE + 175% EXCESS TAIL CEMENT TYPE: Premium G ADDITIVES: WEIGHT: APPROX #SACKS: 0.2% CFR-3,0.2% HALAD-344, 2.0% CaCI2 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 856 THICKENING TIME' Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREEWATER: 0 TAIL CEMENT FROM TD TO 100' TVD ABOVE TOP OF SCHRADER BLUFF WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover from TD to 300' TVD above the top of the Schrader Bluff Formation. The Lead Slurry volume is anuular volume from top of tail cement to base of permafrost + 30% excess, and annular volume from base of permafrost to surface + 100% excess. 80'md 9-5/8", 40# capacity for float joints. Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. , , MP F-29 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F SPACER- 20 bbls fresh water BHST 170° F at 7040' TVDSS. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE' Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 215 SACKS THICKENING TIME' 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: o , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 18 joints of 7" casing (36). This will cover _+300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. 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: , Stage 1 cement volume is calculated to cover 1000 FT MD above the Kuparuk Target Sand with 30% excess. Anadrill Schlumberger · Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPF-29(PT) Field ........ : MILNE POINT, F-PAD Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.50744888 N Surface Long.: 149.65730339 W LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 1881 FSL 2678 FEL S06 T13N R10E I3M 541886.14 6035333.76 TARGET ....... : 2913 FSL 4209 FEL S25 T14N R09E UM 535135.00 6046890.00 BHI ........... : 3155 FSL 4348 FEL S25 T14N R09E UM 534994.21 6047130.99 PROPOSED WELL PROFILE ANADRILL .. STATION IDENTIFICATION KOP/BUILD 1/100 BUILD 1.5/100 MEAS INCLN D I RECT ION VERT - DEPTHS SECT DEPTH ANGLE AZ IMT3TH TVD SUB - S DIST 0 0.00 1000 0.00 1100 1.00 1200 2.00 1300 3.50 0.00 0 -42 0.00 1000 958 330.03 1100 1058 330.03 1200 1158 330.03 1300 1258 COORDINATES-FROM WELLHEAD 0.00 N 0.00 N 0.76 N 3.02 N 7.18 N Prepared ..... : 06/07/96 ~ Vert sect az.: 330.03 ~ elevation.: 4~.60 ft Magnetic Dcln: +0.000 (E) Scale Factor.: 0.99990199 Convergence..: +0.32305535 AKA-DPC APPROVED FOR PERMITTING ONLY PLAN 7' STATE-PLANE X Y 0.00 E 541886.14 6035333.76 0.00 E 541886.14 6035333.76 TOOL DL/ FACE 100 0.00 0.00 0.44 W 541885.70 6035334.51 HS 1.00 1.74 W 541884.38 6035336.77 HS 1.00 4.14 W 541881.96 6035340.92 HS 1.50 BUILD 2/100 BASE PERMAFROST 1400 5.00 1500 6.50 1600 8.50 1700 10.50 1797 12.43 330.03 1400 1358 330.03 1499 1457 330.03 1598 1557 330.03 1697 1655 330.03 1792 1750 16 26 39 55 74 13.60 N 22.28 N 33.59 N 47.88 N 64.54 N 7.84 W 541878.22 6035347.31 HS 1.50 12.85 W 541873.17 6035355.96 HS 1.50 19.37 W 541866.59 6035367.23 HS 2.00 27.61 W 541858.26 6035381.48 HS 2.00 37.22 W 541848.56 6035398.08 HS 2.00 BUILD 2.5/100 1800 12.50 1900 14.50 330.03 1795 1753 330.03 1892 1850 75 99 65.15 N 85.37 N 37.57 W 541848.21 6035398.69 HS 2.00 49.23 W 541836.43 6035418.85 HS 2.00 ~D 0 ,q 0 (Anadrill (c)96 F29P7 3.0b.03 9:23 AM P) STATION IDENTIFICATION MEAS INCLN DIRECTION DEPTH ANGLE AZ IMUTH 2000 17.00 330.03 2100 19.50 330.03 2200 22.00 330.03 2]00 24.50 330.03 2400 27.00 330.03 ~,~~~/ 2500 29.50 330.03 2600 32.00 330.03 2800 37.00 330.03 2900 39.50 330.03 3000 42.00 330.03 5100 44.50 330.03 3200 47.00 330.03 3300 49.50 330.03 3'400 52.00 330.03 3500 54.50 330.03 3600 57.00 330.03 3700 59.50 330.03 3800 62.00 330.03 3900 64.50 330.03 END 2.5/100 BUILD 4000 67.00 330.03 4100 69.50 330.03 4200 72.00 330.03 4300 74.50 330.03 4.325 75.13 330.03 NA OA BASE SCHRADER 6072 75.13 330.03 7085 75.13 330.03 7865 75.13 330.03 PROPOSED WELL PROFILE VERT-DEPTHS SECT TVD SUB-S DIST 1988 1947 126 2083 2042 157 2177 2135 192 2269 2227 232 2359 2317 275 2447 2405 323 2533 2491 374 2616 2575 429 2697 2656 487 2776 2734 549 2852 2810 614 2925 2883 683 2994 2953' 754 3061 3019 829 3124 3083 906 3184 3142 987 3240 3199 1069 3293 3.251 1154 3342 3300 1241 3387 3345 1331 3428 3386 1422 3465 3423 1515 3498 3456 1609 3527 3485 1705 3533 3492 1729 3982 3940 3418 4242 4200 4397 4442 4400 5150 COORDINATES-FROM WELLHEAD 108.89 N 62.79 W 136.01 N 78.43 W 166.70 N 96.13 W 200.90 N 115.85 W 238.53 N 137.55~W 279.53 N 161.19 W 323.82 N 186.73 W 371.31 N 214.12 W 421.92 N 243.30 W 475.55 N 274.23 W 532.09 N 306.83 W 591.44 N 341.06 W 653.49 N 376.84 W 718.11 N 414.11 W 785.19 N 452.79 W 854.601N 492.81 W 926.20 N 534.10 W 999.86 N 576.58 W 1075.43 N 620.16 W 1152.79 N 664.77 W 1231.76 N 710.31 W 1312.22 N 756.70 W 1394.00 N 803.86 W 1476.94 N 851.69 W 1498.00 N 863.84 W 2960.64 N 1707.29 W 3808.91 N 2196.44 W 4461.42 N 2572.72 W 06/07/96 Page 2 STATE-PLANE X Y 541822.74 6035442.28 HS 541806.95 6035469.32 HS 541789.08 6035499.90 HS 541769.17 6035533.98 ~HS 541747.26 6035571.49 ~IS TOOL FACE 541723.39 6035612.35 HS 541697.60 6035656.49 HS 541669.95 6035703.82 HS 541640.48 6035754.26 HS 541609.26 6035807.71 HS 541576.34 6035864.06 HS 541541.78 6035923.21 HS 541505.66 6035985.05 HS 541468.03 6036049.46 HS 541428.98 6036116.31 HS 541388.57 6036185.48 HS 541346.88 6036256.84 HS 541303.99 6036330.25 HS 541259.99 6036405.58 HS 541214.95 6036482.67 HS 541168.97 6036561.38 HS 541122.12 6036641.56 HS 541074.51 6036723.07 HS 541026.22 6036805.73 HS 541013.95 6036826.72 540162.36 6038284.44 539668.47 6039129.85 539288.56 6039780.16 DL/ 100 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2 .50 2.50 2.50 2 .50 2.50 2 .50 2.50 2.50 2 .50 2.50 0.00 0.00 0.00 C C C (Anadrill (c)96 F29P7 3.0b.03 9:23 AM P)' MPF-29 (P7) STATION MEAS DEPTH 14679 14700 14800 14900 15000 15100 15200 15300 15400 15500 15600 15700 15800 15900 16000 INCLN ANGLE 75.13 74.72 72.72 70.72 68.72 66.72 64.72 62.72 60.72 58.72 56.72 54.72 52.72 50.72 48.72 16100 46.72 END 2/100 DROP 16186 45.00 THRZ 16186 45.00 BH_RZ 16271 45.00 MK-19 1.6398 45.00 TKUD 16497 45.00 TA/~GET 16692 45.00 TKUC/TKUB/TKA3/TKA2 16692 45.00 TKA1 16693 45.00 TMLV 16787 45.00 TD 17087 45.00 DIRECTION AZIMUTH 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 330.03 PROPOSED WELL PROFILE --_ VERT-DEPTHS SECT COORDINATES-FROM TVD SUB-S DIST WELLHEAD 6190 6149 11737 10167.18 N 5863.01 W 6196 6154 11757 10184.52 N 5873.01 W 6224 6182 11853 10267.67 N 5920.96 W 6255 6214 11947 10349.92 N 5968.39 W 6290 6248 12041 10431.17 N 6015.24-W 6328 6286 12134 10511.33 N 6061.46 W 6369 6327 12225 10590.29 N 6106.99 W 6413 6372 12315 10667.95 N 6151.78 W 6461 6419 12403 10744.23 N 6195.77 W 6511 6469 12489 10819.04 N 6238.91 W 6564 6523 12574 10892.27 N 6281.14 W 6621 6579 12656 10963.84 N 6322.41 W 6680 6638 12737 11033.67 N 6362.68 W 6742 6700 12815 11101.66 N 6401.89 W 6807 6765 12892 11167.74 N 6439.99 W 6874 6832 12966 11231.83',N 6476.95 W 6934 6892 13027 11285.13 N 6507.69 W 6934 6892 13027 11285.13 N 6507.69 W 6994 6952 13087 11337.11 N 6537.66 W 7084 7042 13177 11415.08 N 6582.62 W 7154 7112 13247 11475.72 N 6617.59 W 7292 7250 13385 11595.27 N 6686.53 W 7292 7250 13385 11595.27 N 6686.53 W 7293 7251 13386 11596.13 N 6687.03 W 7359 7317 13452 11653.31 N 6720.00 W 7571 7529 13664 11837.07 N 6825.97 W 06/07/96 Page STATE-PLANE TOOL X Y FACE 535966.48 6045466.72 LS 535956.38 6045484.01 LS 535907.97 6045566.88 LS 535860.08 6045648.85 LS 535812.77 6045729.83 535766.10 6045809.71 LS 535720.13 6045888.40 LS 535674.91 6045965.81 LS 535630.50 6046041.83 LS 535586.95 6046116.38 LS 535544.31 6046189.37 LS 535502.64 6046260.70 LS 535461.98 6046330.29 LS 535422.39 6046398.06 LS 535383.92 6046463.92 LS 535346.61 6046527.79 535315.57 6046580.91 535315.57 6046580.91 535285.30 6046632.72 535239.91 6046710.42 535204.60 6046770.86 535135.00 6046890.00 535135.00 6046890.00 535134.50 6046890.86 535101.21 6046947.85 534994.21 6047130.99 LS DL/ 100 0.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0 [] (Anadrill (c)96 F29P7 3.0b.03 9:23 AM P) SHARED SERVICES DRILLING S£h]umberger . -- Marker IclentlficaLlon MD BKB SEClN INCLN A) KB 0 0 0 O. O0 B) KOP/BUILD 1/100 1000 1000 0 0.00 C) BUILD 1.5/100 1200 1200 3 2.00 D) BUILD 2/100 1500 1499 26 6.50 E) BUILD 2.5/100 1900 1892 99 14.50 F) END 2.5/100 BUILD 4325 3533 1729 75. t3 G) DROP 2/100 14679 6190 11737 75.13 H) END 2/100 DROP 16186 6934 13027 45.00 I) IARGEI 16692 7292 13385 45.00 J) VD 17087 7571 13664 45.00 MPF-29 (PT) VERTICAL SECTION VIEW Section at: 330.03 lVD Scale.: i inch = 1800 feet Dep Scale.: 1 inch = 1800 feet Drawn ..... :06/07/96 A ". I : ~ I ._.i ...... ' ..... I .... :'-- I .......... B--i~ __ [ ] I .... i "'Ar4AUNIL , DPC , , : ~ I , PL, NN .... ..... I ............... ~ .......... · ~ ', ~. · , , i ~ i - ~S~ ~ ~~.~_r ...... : ..... .~ . ~.- ~.,= r. mm - - . ......... t . , · ~ ' ~ ~ .._ --. . ..... [ ..... ~ i , :J~BgffA~=~-~== ==== :'-: ..... = ................................ . u: ................ .......................... J . : ~ .......................................... ~ .............. . : 200 fe 0 900 11100 2700 3600 4500 5400 6300 7200 8100 9000 Sect ion Departure 9900 10800 11700 12600 13500 14400 15300 'Anaclrili [c}96 F29P7 3.00.03 9:33 AN P) t) 0 ',4 N 0 0un-07-96 11:01 Anadwill DPC 907 344 2160 P.06 SHARED SERVZCES BRTLLTNG , : I I I Illl I I A)MarkerK8 fdeflt,ftcat~on MBO .,so. "~o ~~ MPF-29 (P7) c~ ~,~o,.,/,oo ~oo 3, ~ PLAN VIEW ol ~i~o ~/~oo ~oo ~ ~ ~3 w~ , E) BUILD 2,5/~00 Jgo0 85 N 49 W CLOSURE ' ~3654 feet at Azimuth 330.03 FI ENO 2.5/~00 8UILO 4325 J498 N 864 W 6) OROP 2/JO0 14679 ~0167 N 5863 W DECLINATION.' +0.000 (E) H) ENO 2/tO00ROP ~6~86 ~285 N 6508 w SCALE · J ~nch = 2000 feet I) TARGET ~6692 tJ595 N 6687 ~ J) TO ~7087 t1837 N 5826 W DRAWN · 06/07/96 Anadri ]] Schlumberger ........... , .............. ................ i ....... ~ ........ : --- ~3000 I ~ i I I 12000 ...... R¢dlu~ 200 .... .............................................. ' .... ~ ~000 I . APPROVED FOR PE ~MI~TIN ~ ~oooo , i C,N LY, I~ ............. , ................................ ,,~l~ ~~ ~ ........ .'~ ' '' aooo ~ ............. i ................. ....... , ........ 7000 ' I [ ' 6000 . ~ I .................. ~ ...... ' ........................... I ..... I . J ~ooo ............... I .............................. 3000 " I 2000 i · ......... [ ................................. ~ - ~ - ~ ~ ~ o .. ~000 1~000 ~ 1000 ~0000 ~000 ~000 7000 riO00 riO00 ~000 3000 2000 1000 0 ~000 (AnaOr~]] (c)96 F29~7 3.0b,03 9:33 AX P) ·WELL PER IITCHECKLIST COMPANY ,/~,/~ WELL NAME ,/~.~/~''''' ~ ':~ PROGRAM:expI'q dev~eddlE] sen/FI wellboreseg Fqann. disposal para req FIELD & pOoL ._~'~r.~//'~ INIT CLASS ,~_~,'~,.' -,/- (::::~/"/ GEOL AREA CF' ~ UNIT# ./,~'/~',~ ~ ON/OFF SHORE ADMINISTRATION 1 1 1. Permit fee attached ...................... 2. Lease number appropriate .................. 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from drlg unit boundary .... 6. Well located proper distance from other we!is ......... 7. Sufficient acreage available in dfitli~ urfit ........... 8. If deviated, is wetlbore ~lat included ............. g. Operator only affected 'party .................. '. O. Operator has appropriate bond in force ............. 1. Permit can be issued without conservation order ...... 2. Permit can be issued without adminis~'ative approval .... 3. Can permit be approved before 15-day wait ......... ENGINEERING N ~N N N N N N N N N N N N REMARKS APPR DATE 14. Conductor string provided ................... ~k.~N 15. Surface casing protects ail known USDWs ......... .L.Y_..2 N 16. CMT vol adequate to circulate on conductor & surf csg . . . ~ N 17. CMT vol adequate to tie-in long string to surf csg ....... 18. CMT will cover ail 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 .... 22. Adequate wellbore sep~ation proposed ............ ..,,-,,.L~ N 23. If diverter required, is it adequate ................ '~("~2 ~N 24. Ddlling fluid program schemaiJc & equip list adequate .... 25. BOPEs adequate ........................ 26. BOPE press rating adequate; test to _ ¢'00~:) psig.,..-,Y N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ~ N 28. Work will occur without operation shutdown .......... ~,~ 29. Is presence of H2S gas prohS.~ie ............... Y GEOLOGY 30. Permit ca.n be issued wio hydrogen sulfide measures ..... Y N/,,~ 31. Da~. presented on potenti~ ove,.'"pressL~re zones ....... Y,,~ 32. Seismic a,n~ysis cf s~iov,.' g~s zones ............. / N 33. Se2-~ed con~itJsn scrvey (if off-shore) ........... //'. Y N 34. Con,'~.ct ns. me/~i~one for w~ekJv ~rogress repsr'~s .... ,/ . . Y N JDH ,/' JDN TAB Common ~s~Inst~uctions: 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. ,ape Subfile 2 is;~' type LIS TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM- 96736 B. ZIEMKE D. MOUNTJOY MPF-29 500292268800 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 26-FEB-97 10E 1881 Date~ .... ~ ~-- 2678 41.24 12.10 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 110.0 12.250 9.625 8019.0 8.500 17014.0 MWD - EWR4/CNP/SLD/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. THIS WELL, MPF-29, IS REPRESENTED BY RUNS 1, 2, & 4. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND NO DATA IS PRESENTED. MWD RUN 4 WAS DIRECTIONAL WITH GAMMA RAY, ELECTROMAG- NETIC WAVE 4-PHASE RESISTIVITY (EWe4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD) . GAMMA RAY DATA WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS (DGR/SGRC). THIS WELL WAS DRILLED TO A TOTAL DEPTH OF 17014'. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOGS: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 700 - 800 ppm MUD WEIGHT: 8.4 - 9.9 ppg FORM. WATER SALINITY: 14545 ppm FLUID DENSITY: 1.0 g/cc MATRIX DENSITY: 2.65 g/cc LITHOLOGY: SANDSTONE. FILE HEADER. FILE NI3MBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 7944.0 7935.0 7912.0 7953.0 BASELINE DEPTH GR 7912.0 7917.0 15730.5 15735.5 15734.0 15739.0 15735.5 15739.5 15739.0 15743.0 15829.5 15833.5 15842.5 15847.5 15856.5 15866.5 15907.0 15912.5 15923.5 15930.0 16077.0 16082.5 16079.0 16086.5 16095.0 16103.5 16296.0 16303.0 16343.5 16350.5 16358.0 16366.0 16399.5 16403.0 16544.5 16548.5 16553.0 16558.0 16558.0 16566.0 16573.0 16579.5 16592.0 16599.0 16600.5 16615.0 16999.5 17014.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: all bit runs merged. STOP DEPTH 16906.0 16898.0 16872.0 16911.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 4 8040.0 17014.0 MERGED MAIN PASS. ALL CURVES WERE SHIFTED WITH GR. CN WN FN /? ?SHIFT. OUT $ : BP EXPLOR3tTION : MPF-29 : MILNE POINT (ALASKA) s~Aq ~9 :q~6usI p~oo~ mnmixmM :q~BusI pzoos~ mnmiuiM · ''sp~oo~ O£II E :eiT~qn$ e~e~ smn~mp 89 :apoo deH :Xxemmns BuTPOOep epoo uoTqequesexde~ $Iq 00000S'6669I = BUTOeds Te~eU eITZ edel 000000'EI6£ = qqde~ pu~ eIT~ edel 000000'0 = qqde~ q~eqS eIT~ ~d~ 66 S66 06 ~ 66 S66 06 9 66 S66 06 ~ 66 S66 06 ~ 66 S66 06 ~ 66 ~66 06 ~ 66 ~66 06 ~ 66 ~66 06 ~ 66 ~66 06 ~ 66 S66 06 9 66 099 06 9 66 S66 06 9 IO 0I£ 06 ~ poM sIO clAi clAi q~Busq ezys :seA~no ET ,~ :(II q~dsp sde£ tfMS~ : ' ' ~dOqS H ~N : N/iOD · · Tape Subfil¢ 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7949.0 EWR4 7940.0 CNP 7917.0 SLD 7958.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT)I: TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 16920.0 16913.0 16887.0 16926.0 20-JUL-96 ISC 4.54 MWD 5.46 MEMORY 17014.0 8040.0 17014.0 0 45.6 76.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNP COMPENSATED NEUTRON EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY SLD LITHO DENSITY $ TOOL NUMBER P0554CRGDP6 P0554CRGDP6 P0554CRGDP6 P0554CRGDP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 8019.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.80 48.0 9.0 8O0 4.0 1.800 .872 2.250 1.650 72.0 156.0 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION N) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-29 : MILNE POINT : NORTH SLOPE : ALASKA 8.500 .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 NPHI MWD 68 1 PU-S 4 7 FCNT MWD 68 1 CPS 4 8 NCNT MWD 68 1 CPS 4 9 RHOB MWD 68 1 G/C3 4 10 DRHO MWD 68 1 G/C3 4 11 PEF MWD 68 1 BN/E 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 940 02 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1011 Tape File Start Depth = 17014.000000 Tape File End Depth = 7917.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 254731 datums Tape Subfile: 3 1080 records... .~nimum record length Maximum record l~ength: 62 bytes 1014 bytes Tape Subfile,4 is type: LIS 97/ 2/26 01 **** REEL TRAILER **** 97/ 2/26 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 26 FEB 97 4:06p Elapsed execution time = 7.47 seconds. SYSTEM RETURN CODE = 0 'E HOH~ SZDIA~ZS ©NID©0% S~%L~N~ZLSZM 96-©Q~-£I I I HO~© :XN~fdMOO DMIDDO~ :GZ©©O~ Zing :~Z~MIIN Nfl~ :ZJOD ZAHflD ~ SL~IHS EO~ ZAkIflD ZNI2ZS~E 00'9~ 0'~669I O00'L ©~I~LS ~OILD~GO~d 00'0~ 0'6108 S~9'6 ©NI~S DMI~£S ©NI~LS LSI (L,~/S~I) LHDIZM (La) HLaZG (MI) ZZIS (MI) ZZIS iI~ ©NISIfD S%{Z~I~IIHG D~IISIfD Z~IOH NZdO OI'EI 8£9~ I88I Z0I 9 XOa '£ 00'9LA9 96-dZS-0E SZDIAHZS DNI©DO~ S~L~ NEZLSZM 'DNI (tOtStf-I~) NOIik~{O~dXZ ~ 00889E~6E00S 6E - ~d~ SI~ : ~clX_~ ~T ~ ,.; a SIT~qns ~de [ ..~ .._~ ~ 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 15700.0 16745.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 29 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 26 Tape File Start Depth = 15700.000000 Tape File End Depth = 16750.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6304 datums Tape Subfile: 2 110 records... Minimum record length: 18 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NLIMBER: 1 DEPTH INCREMENT: 0.2500 FILE SI/MMARY VENDOR TOOL CODE START DEPTH GR 15696.0 $ LOG HEADER DATA STOP DEPTH 16766.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CASING COLLAR LOC. PFC $ 17-AUG-96 FSYS REV. J001 VER. 1.1 1100 17-AUG-96 16908.0 16768.0 15700.0 16745.0 3000.0 YES TOOL NUMBER 2315NA 0722XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 0.000 16994.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : SEAWATER/DIESEL 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COL[NT RA_ = SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : MPF - 29 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAP I 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 101 Tape File Start Depth = 15700.000000 Tape File End Depth = 16750.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25207 datums Tape Subfile: 3 173 records... Minimum record length: Maximum record length: 30 bytes 1014 bytes · spuoo~s 8~'I = ~mT~ uoT~no~x~ p~sd~iz s~Xq ~£I :~6u~I p~oo~ mnm~x~M s~Xq ~£I :~6u~I p~oo~ mnmTu~M · ''sp~oo~ ~ ~ :~I~qns IO IO Tape Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM-96736 B. ZIEMKE D. MOUNTJOY MPF- 29 500292268800 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 26-FEB-97 6 13N 10E 1881 2678 41.24 12.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 20.000 110.0 3RD STRING 12.250 9.625 8019.0 PRODUCTION STRING 8.500 17014.0 REMARKS: MWD - EWR4/CNP/SLD/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. THIS WELL, MPF-29, IS REPRESENTED BY RD-NS 1, 2, & 4. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND NO DATA IS PRESENTED. MWD RUN 4 WAS DIRECTIONAL WITH GAMMA RAY, ELECTROMAG- NETIC WAVE 4-PHASE RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). GAMMA RAY DATA WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS (DGR/SGRC) . THIS WELL WAS DRILLED TO A TOTAL DEPTH OF 17014' ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOGS: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 700 - 800 ppm MUD WEIGHT: 8.4 - 9.9 ppg FORM. WATER SALINITY: 14545 ppm FLUID DENSITY: 1.0 g/cc MATRIX DENSITY: LITHOLOGY: 2.65 g/cc SANDSTONE. FILE HEADER FILE N-UMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7944.0 16906.0 7935.0 16898.0 7912.0 16872.0 7953.0 16911.0 BASELINE DEPTH 7912 0 15730 5 15734 0 15735 5 15739 0 15829 5 15842 5 15856 5 15907 0 15923 5 16077 0 16079 0 16095 0 16296 0 16343 5 16358 0 16399 5 16544 5 16553 0 16558 0 16573 0 16592 0 16600 5 16999.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: GR 7917.0 15735.5 15739.0 15739.5 15743.0 15833.5 15847.5 15866.5 15912.5 15930.0 16082.5 16086.5 16103.5 16303.0 16350.5 16366 0 16403 0 16548 5 16558 0 16566 0 16579 5 16599 0 16615 0 17014 0 EQUIVALENT UNSHIFTED DEPTH -- MERGED MAIN PASS. BIT RUN NO MERGE TOP MERGE BASE 4 8040.0 17014.0 ALL CURVES WERE SHIFTED WITH GR. CN WN FN COUN STAT /??SHIFT.OUT $ : BP EXPLORATION (ALASKA) : MPF-29 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 FCNT MWD 68 1 CPS 4 8 NCNT MWD 68 1 CPS 4 9 RHOB MWD 68 1 G/C3 4 10 DRHO MWD 68 1 G/C3 4 11 PEF MWD 68 1 BN/E 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1010 Tape File Start Depth = 17000.000000 Tape File End Depth = 7912.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 254479 datums Tape Subfile: 2 1130 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7949.0 16920.0 EWR4 7940.0 16913.0 CNP 7917.0 16887.0 SLD 7958.0 16926.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNP COMPENSATED NEUTRON EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY SLD LITHO DENSITY $ 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 TEMPER3kTURE: 20-JUL-96 ISC 4.54 MWD 5.46 MEMORY 17014.0 8040.0 17014.0 0 45.6 76.6 TOOL NUMBER P0554CRGDP6 P0554CRGDP6 P0554CRGDP6 P0554CRGDP6 8.500 8019.0 LSND 9.80 48.0 9.0 800 4.0 1.800 .872 72.0 156.0 MUD FILTRATE AT MT: MI/D CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAlfDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: CN WN FN COUN S TAT MWD RUN 4. $ · BP EXPLORATION (ALASKA) : MPF-29 : MILNE POINT : NORTH SLOPE : ALASKA 2.250 1.650 SA/qDSTONE 2.65 8.500 .0 0 72.0 72.0 * 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 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 NPHI MWD 68 7 FCNT MWD 68 8 NCNT MWD 68 9 RHOB MWD 68 10 DRHO MWD 68 11 PEF MWD 68 12 FET MWD 68 13 ROP MWD 68 1 A3%PI 1 OHMM 1 OHMM 1 OHMM 1 OHMM 1 PU-S 1 CPS 1 CPS 1 G/C3 1 G/C3 1 BN/E 1 HR 1 FPHR 4 4 90 310 01 1 4 4 90 995 99 1 4 4 90 640 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 940 02 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1011 Tape File Start Depth = 17014.000000 Tape File End Depth = 7917.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 254731 datums Tape Subfile: 3 Minimum record length: Maximum record length: 1080 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS 97/ 2/26 01 **** REEL TRAILER **** 98/12/ 1 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 1 DEC 98 2:34p Elapsed execution time = 7.97 seconds. SYSTEM RETURN CODE = 0
