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209-147
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 L-02A 50029219980100 209147 2/17/2025 READ CaliperSurvey 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): 9,444'N/A Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi Drill Liner N/A Slotted Liner N/A Slotted Liner N/A Slotted Liner N/A 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 7" x 4.5" Packer and N/A 7,344'(MD) / 6,853'(TVD) and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic 1,252' 2-3/8" See Schematic 9,492'1,583' 2-7/8" 7,159' 1,401' 82' 13-3/8" 9-5/8" 7" 5,076' 3-3/16"581' 7,901' 7,145' 5,076' 7,901' 7,074'2-3/8" 9,444' 7,985' Proposed Pools: 82' 82' 6.5# / L-80 / EUE 8rd Mod TVD Burst 7,278 N/A MD 1,730psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 209-147 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21998-01-00 Hilcorp Alaska LLC C.O. 816 AOGCC USE ONLY N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3/15/2025 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 Length Size 7,034' 1,592 7,560' Subsequent Form Required: Suspension Expiration Date: N/A 3,250psi 7,240psi 4,950' 7,317' 7,074' 2-3/8" 9,501' 7,091' N/A MILNE PT UNIT L-02A MILNE POINT KUPARUK RIVER OIL N/A 7,560' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-106 By Gavin Gluyas at 7:55 am, Feb 26, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.02.25 15:51:29 - 09'00' Taylor Wellman (2143) DSR-2/28/25A.Dewhurst 03MAR25MGR10MAR25 * BOPE test to 2000 psi. 10-404 *&: 3/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.10 13:17:48 -08'00' RBDMS JSB 031125 Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 Well Name:MPL-02A API Number:50-029-21998-01-00 Current Status:Shut-in Producer Rig:ASR Estimated Start Date:3/15/2025 Estimated Duration:5days Regulatory Contact:Tom Fouts Permit to Drill Number:209-147 First Call Engineer:Ryan Lewis (333) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2,269 psi @ 6,778’ TVD ESP Intake Sensor 1/27/25 | 6.5 MWE 6.7 KWF Max Potential Surface Pressure: 1,592 psi Gas Column Gradient (0.1 psi/ft) Max Angle:33° @ 7,700’ MD to TD Brief Well Summary: MPL-02 is a shut-in Kuparuk CTD sidetrack. The well was originally drilled as a Kuparuk development well to a depth of 7,901’ MD. In 2010 the well was plugged back and sidetracked with three coil tubing laterals and cased with 2-3/8” slotted liner. MPL-02 has historically been lifted via ESP. An ESP completion was installed in March 2010 post-CTD completion and February 2015 after an ESP failure. In 2023 the pump shaft broke on the current ESP after an 8 year run. The current ESP completion lasted 1.75 years before the twisted shaft. The proposed workover will pull the failed ESP completion and run a new ESP completion. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: Last production casing test was 2,300 psi on 3/18/2023. Pre-Rig Procedure 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. 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. Brief RWO Procedure 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl 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. Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 3. NU BOPE. 4. 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” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. 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. 6. Call out Centrilift for ESP pull. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Expected PU ~56k 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints. a. Based on caliper results, joints to be kept will be reported to rig. Trash visibly bad joints. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs, trash these joints. e. Previous workover did not record clamp placement. i. Canon clamps – 123 ii. Flatguard - 2 iii. Protectolizers - 5 10. Lay Down ESP. Eline Perf Add 11. RU Eline PCE and test to 250 psi low/ 2,000 psi high. 12. RIH to drift to 7,800’ MD 13. MU RIH with perf guns. 14. Tie-in with the GR/CCL and send to Geologist & OE for correlation: Graham Emerson, graham.emerson@hilcorp.com, 907-793-0315 and Ryan Lewis 303-906-5178. 15. Perforate 7,710’-7,740’ MD. 16. POOH while monitoring well and bullhead as needed. 17. Eline RDMO. 2-7/8” ESP Completion 18. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 7,250’ 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 Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.7 20 Motor - 250HP - 562XP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 5 Gas Separator 52 5.4 20 Pump - 137-P17 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 6,840 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 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 Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 2. Proposed Wellbore Schematic 3. 11” Double BOPE Schematic _____________________________________________________________________________________ Revised By: RJL 2/18/2025 PROPOSED Milne Point Unit Well: MPL-02A Last Completed: 3/21/2023 PTD: 209-147 17 L-02A 2-3/8” Alum. Billit w/ GS FN L-02A1 L-02A2 TD =7,901’ (MD) / TD = 7,317’(TVD) 13-3/8” Orig.KB Elev.: 56.0’/ GL Elev.: 21(Nabors 27E) 7” 3 6 7 10 8 & 9 11 12 13 14 15 9-5/8” 1 2 16 PBTD =7,560’ (MD) / PBTD =7,034’(TVD) 4 & 5 Perf’s Cement Squeezed CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / Weld 12.559 Surface 82’ 9-5/8" Surface 36 / J-55 / Btc. 8.765 Surface 5,076’ 7" Production 26 / L-80 / Btc 6.151 Surface 7,901’ 3-3/16” Drill Liner 6.2 / L-80 / N/A 2.805 7,404’ 7,985’ 2-3/8” 2A Slotted Liner 4.4 / L-80 /N/A 1.901 8,192’ 9,444’ 2-3/8” 2A1 Slotted Liner 4.4 / L-80 / N/A 1.901 8,100’ 9,501’ 2-3/8” 2A2 Slotted Liner 4.4 / L-80 / N/A 1.901 7,909’ 9,492’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd Mod 2.441 Surface ±7,250’ JEWELRY DETAIL No Depth Item 1 ±X200’ Sta 2: GLM, 2-7/8" x 1" - 1/4" OV 2 ±X,XXX’ Sta 1: GLM, 2-7/8" x 1" - w/ DV installed 3 ±X,XXX’ XN- Nipple (2.205” No-Go) 4 ±X,XXX’ Discharge Head: 5 ±X,XXX’ Ported Discharge Flange: 6 ±X,XXX’ Pump: 7 ±X,XXX’ Gas Separator: 8 ±X,XXX’ Upper Tandem Seal: 9 ±X,XXX’ Lower Tandem Seal: 10 ±X,XXX’ Motor: 250 HP –562XP 11 ±X,XXX’ Intake Sensor: 12 ±X,XXX’ Centralizer - Bottom @ ±7,250’ 13 7,296’ BOT PBR 80-47 Seal Nipple 14 7,344’ BOT 7” x 4.5” S-3 Packer 15 7,378’ 4.5” ‘X’ Nipple (3.813” ID) 16 7,560’ Top of Whipstock 17 7,909’ 2-3/8” Deployment Sleeve PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT I.D. Status Kup. A3 Sands 7,710’ 7,740’ 7,123’ 7,133’ 30 L-02A Open Kup. A3/A2 Sands 8,192’ 9,444’ 7,134’ 7,074’ 1,252 L-02A Isolated Kup. A3/A2 Sands 8,100’ 9,501’ 7,139’ 7,091’ 1,401 L-02AL1 Isolated Kup. A2 Sands 7,909’ 9,492’ 7,150’ 7,159’ 1,583 L-02AL2 Open OPEN HOLE / CEMENT DETAIL 20" To Surface 9-5/8" Cmt w/ 367 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 52 sks Class “G” in 8-1/2” Hole GENERAL WELL INFO API: 50-029-21998-01-00 Drilled and Cased by Nabors 27E- 11/16/1990 Recompleted by Nabors 4ES –5/28/1996 RWO by Nabors 4ES –5/30/2001 ESP RWO by Nabors 3S –2/28/2006 CTD Sidetrack by Nordic 2 –2/1/2010 ESP Changeout by Nordic 3 –2/20/2015 ESP Changeout by ASR#1 –3/21/2023 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 9-5/8” x 11” WKM Tubing Spool. WKM 11” x 2-7/8” EUE T&B & 2.5” CIW ‘H” BPV Profile WELL INCLINATION DETAIL KOP @ 3,200’ MD Max Hole Angle = 33.58° f/ 7,700’ to TD Hole Angle thru Perfs= 33° WINDOW DETAIL 7,567’ to 7,572’ 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 1 Regg, James B (OGC) From:Wade Hudgens - (C) <Wade.Hudgens@hilcorp.com> Sent:Saturday, March 18, 2023 6:11 AM To:Alaska NS - ASR - Well Site Managers; Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:ASR 1 MPU L-02 BOPE Test Report Attachments:MPU L-02 BOPE test report 3-17-23.xlsx Thank you. Regards, Wade Hudgens ASR DSM, Mobile: 903-331-6711 Office: 907-685-1266 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit L-02APTD 2091470 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:3/17/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2091470 Sundry #323-073 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1808 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"5M P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5" VBR P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"5M P Time/Pressure Test Result HCR Valves 1 2 1/16"5M P System Pressure (psi)2950 P Kill Line Valves 3 2 1/16"5M P Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)13 P BOP Misc 0 NA Full Pressure Attained (sec)62 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 x 2050 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 17 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-15-23/4:03 pm Waived By Test Start Date/Time:3/17/2023 5:30 (date)(time)Witness Test Finish Date/Time:3/17/2023 11:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Tested w/2-7/8" and 3-1/2" Test Jts. Precharge bottle psi = 1,000psi C.Pace / M. Boord Hilcorp Alaska LLC S.Heim / W. Hudgens MPU L-02A Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2023-0317_BOP_Hilcorp_ASR1_MPU_L-02A J. Regg Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230310 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# TBU M-14RD 50733204080100 201171 3/5/2023 AK E-LINE Perf MPU L-02A 50029219980100 209147 3/5/2023 READ Caliper Survey SRU 23-33 50133101630000 161019 2/17/2023 AK E-LINE CBL CIBP Jet Cut SRU 23-33 50133101630000 161019 2/11/2023 AK E-LINE Plug Cement Punch Please include current contact information if different from above. MPU L-02A 50029219980100 209147 3/5/2023 READ Caliper Survey 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Change-out Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,444 feet 7,560 feet true vertical 7,074 feet N/A feet Effective Depth measured 7,560 feet 7,344 feet true vertical 7,034 feet 6,853 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 EUE 8rd Mod 7,278' 6,798' Packers and SSSV (type, measured and true vertical depth)BOT 7” x 4.5” S-3 Packer N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: Drill Liner 581' 3-3/16" 7,985' 7,145' N/A N/A 323-073 Sr Pet Eng: N/A Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 144 Gas-Mcf MD 82' 740 Size 82' 4,950' 1727 34022 0 00 318 measured TVD 2-3/8" N/A 2-3/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-147 50-029-21998-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025509 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT L-02 Plugs Junk measured Length Slotted Liner Slotted Liner 1,252' 1,401' 1,583' Casing Conductor 7,074' 7,091' 2-3/8" 9,444' 9,501' 9,492' 7,159' 7,901' 5,076'Surface Production Slotted Liner 13-3/8" 9-5/8" 7" 82' 5,076' N/A N/A 3,250psi 7,240psi N/A N/A 7,901' 7,317' Burst 1,730psi Collapse 740psi 2,020psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.14 09:17:24 -08'00' David Haakinson (3533) RBDMS JSB 042023 DSR-4/14/23WCB 12-27-2023 ESP Change-out Pull Tubing 323-073 MILNE PT UNIT L-02 209-147 _____________________________________________________________________________________ Revised By: TDF //2023 SCHEMATIC Milne Point Unit Well: MPL-02A Last Completed: 3/21/2023 PTD: 209-147 17 L-02A 2-3/8” Alum. Billit w/ GS FN L-02A1 L-02A2 TD =7,901’ (MD) / TD = 7,317’(TVD) 13-3/8” Orig. KB Elev.: 56.0’/ GL Elev.: 21 (Nabors 27E) 7” 3 6 7 10 8 &9 11 12 13 14 15 9-5/8” 1 2 16 PBTD =7,560’(MD) / PBTD =7,034’(TVD) 4 & 5 Perf’s Cement Squeezed CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / Weld 12.559 Surface 82’ 9-5/8" Surface 36 / J-55 / Btc. 8.765 Surface 5,076’ 7" Production 26 / L-80 / Btc 6.151 Surface 7,901’ 3-3/16” Drill Liner 6.2 / L-80 / N/A 2.805 7,404’ 7,985’ 2-3/8” 2A Slotted Liner 4.4 / L-80 / N/A 1.901 8,192’ 9,444’ 2-3/8” 2A1 Slotted Liner 4.4 / L-80 / N/A 1.901 8,100’ 9,501’ 2-3/8” 2A2 Slotted Liner 4.4 / L-80 / N/A 1.901 7,909’ 9,492’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd Mod 2.441 Surface 7,278’ JEWELRY DETAIL No Depth Item 1 123’ Sta 2: GLM, Camco, 2-7/8" x 1" KBMM with DPSOV installed 2 7,042’ Sta 1: GLM, Camco, 2-7/8" x 1" KBMM with DV installed 3 7,165’ XN- Nipple (2.205” ID) 4 7,217.4’ Discharge Head 5 7,218’ Ported Discharge Flange 6 7,219’ Pump: 538PMSXD 137P17 M FER NO PNT 7 7,238’ Gas Separator: GRS FER N AR 8 7,243’ Upper Tandem Seal: GSB3DB FER HL SSSC H6 SB/SB CL-5E 9 7,250’ Lower Tandem Seal: GSB3DB FER HL SSSC H6 SB/SB CL-5E 10 7,257’ Motor: 250 HP – 562XP S CS 250/2505/61 10R 11 7,273’ Intake Sensor: Zenith 12 7,276’ Centralizer - Bottom @ 7,278’ 13 7,296’ BOT PBR 80-47 Seal Nipple 14 7,344’ BOT 7” x 4.5” S-3 Packer 15 7,378’ 4.5” ‘X’ Nipple (3.813” ID) 16 7,560’ Top of Whipstock 17 7,909’ 2-3/8” Deployment Sleeve PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT I.D. Status Kup. A3/A2 Sands 8,192’ 9,444’ 7,134’ 7,074’ 1,252 L-02A Isolated Kup. A3/A2 Sands 8,100’ 9,501’ 7,139’ 7,091’ 1,401 L-02AL1 Isolated Kup. A2 Sands 7,909’ 9,492’ 7,150’ 7,159’ 1,583 L-02AL2 Open OPEN HOLE / CEMENT DETAIL 20" To Surface 9-5/8" Cmt w/ 367 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 52 sks Class “G” in 8-1/2” Hole GENERAL WELL INFO API: 50-029-21998-01-00 Drilled and Cased by Nabors 27E- 11/16/1990 Recompleted by Nabors 4ES – 5/28/1996 RWO by Nabors 4ES – 5/30/2001 ESP RWO by Nabors 3S – 2/28/2006 CTD Sidetrack by Nordic 2 – 2/1/2010 ESP Changeout by Nordic 3 – 2/20/2015 ESP Changeout by ASR#1 – 3/21/2023 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 9-5/8” x 11” WKM Tubing Spool. WKM 11” x 2-7/8” EUE T&B & 2.5” CIW ‘H” BPV Profile WELL INCLINATION DETAIL KOP @ 3,200’ MD Max Hole Angle = 33.58° f/ 7,700’ to TD Hole Angle thru Perfs= 33° WINDOW DETAIL 7,567’ to 7,572’ Well Name Rig API Number Well Permit Number Start Date End Date MP L-02A SL 50-029-21998-01-00 209-147 3/5/2023 3/21/2023 3/3/2022 - Friday No operations to report. 3/1/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/2/2022 - Thursday No operations to report. No operations to report. No operations to report. 3/4/2022 - Saturday No operations to report. 3/7/2023 - Tuesday 3/5/2023 - Sunday WELL S/I ON ARRIVAL. RAN 10' X 2'' BAILER (ball) TAG @ 7250' SLM / 7195' MD. RAN READ 24 ARM CALIPER, LOG WELL FROM 7195' SLM TO 0' SLM (good data). PULL DGLV @ 7097' SLM / 7042' MD. PULL DPSOV @ 145' SLM / 139' MD. SET 1'' DGLV, SET @ 145' SLM / 139' MD. WELL S/I ON ARRIVAL. 3/6/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP L-02A ASR#1 50-029-21998-01-00 209-147 3/5/2023 3/21/2023 Continued L/d ESP Pump and Motor assembly and Centralizer. There was some scaling on the assembly but no trace of sand or corrosion. Clean rig floor, changed out handling eq to 3-1/2", R/d Elephant Trunk, emptied pipe racks, loaded racks with 3- 1/2" wk. string, brake thread protectors and tallied 1st row. Tally, Inspect and M/u 7" AS1x Test Packer. RIH w/7" Test Packer P/u 3-1/2 wk. string f/surface t/7257'md, pumping 3bbls of 8.7ppg NaCl every 15 joint ran in hole. Est parameters PUW=73k SOW=52k, set packer @ 7257', Fluid packed IA, pumped 2bbls and pressured up on IA to 2300psi, MIT-IA for 30mins and charted-good test. Bled off IA. Released packer and prep to POOH. POOH L/d 3-1/2" Wk. String f/7257'md t/6115', fill hole with dbl displace every 15 jts. Selector pins sheared on tongs, called rig mechanic out to troubleshot issue found pieces of pin debris wedged in the gear. POOH L/d 3-1/2" Wk. String f/6115' t/4500', fill hole with dbl displace every 15 jts. 3/18/2022 - Saturday 3/17/2022 - Friday Tested BOPE per Sundry as following: Annular 250-2500psi, Rams 250-2500psi, Valves 2502500psi, performed Koomey Drawdown and Test Fire and Gas, Tested BOP's w/2-7/8" and 3-1/2" Test Jt. No failures recorded. AOGCC witness was waived by Kam StJohn on 3/15/2023 @ 5:26 PM. Blow Stack and lines dry, R/d Testing eq. Prep handling tools to pull completion, hung sheave and R/u Elephant trunk and threaded fish rope. Check IA static, P/u tee bar, pulled CTS/BPV, tbg was static. P/u Landing Jt., BOLDS and pulled hanger off seat to rig floor, PUW=65k. De-completed and L/d Tbg hanger (note no capstring ran with completion). POOH L/d 2-7/8" ESP Completion f/7275' t/ESP assembly, removing clamps and spooling ESP cable, filling hole w/8.7ppg double displacement every 10jts out, no drag or over overpull while tripping. Note: some scaling recovered on the XN Nipple and discharge head. L/d ESP assembly at report time. 3/15/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O = 703/693/534 Well Kill, Pumped 10 bbls 130* Diesel down Tubing, Pumped 450 bbls 8.7 KCL down Tubing taking returns up IA into tank, 363 bbls total returns to tank, FWP = Vac/Vac/158. Bleed void to 0 pressure. Set 2.5 BPV with dry rod. N/D adaptor and tree, install CTS plug and test sub, test 500/5 5K.10 good test. Test hanger seals to 5K good test. rig to N/U BOP stack. Wells group pumped the well kill and set the BPV. L-52, cleaned and cleared rig floor, removed pipe shed, R/d cat walk. Bled off koomey and disconnect lines. R/d circulating lines and winterization. L-02 Set well house, N/d Tree and N/u the BOP stack. L-52, Moved Rig to Tent at A-pad for warm storage, M/o mud boat, Began crane work. Fly off floor, N/d BOP's, N/u Tree test 500/5000psi (good test), pulled CST and BPV, fly off well cellar. R/d pits, moved and R/u on L-02. Moved camps and pusher shack to L-02 and continue MIRU ASR and eq. 3/16/2022 - Thursday Spot and hookup camps, level and fill pits with 140bbls of 8.7ppg NaCl, spot in cutting box and glycol unit, R/u crane, fly on floor, and spacer spools, lay out kill/choke and koomey lines, set stairs, park rig on mud boat. Prep to stand up rig, ran electrical and communication lines, installed winterization tarps under rig, test ESD's on rig and pits, leveled rig and raised mast, secured guy lines. Connected circulating lines for rig to pits, startup glycol unit and warmed lines, installed rack pins, r/u work floor, R/u 6" flowline and pop-off line, set in catwalk and pipe shed. took on 30bbls of fresh water for testing BOP's, hooked up koomey lines. Winterize cold spots as needed, final torque on stack, chained BOP stack over to center, function test bop's, built 2-7/8" and 3-1/2" test mandrels. R/u testing eq. flood stack and purge air out of system, Shell Testing BOP's 250/2500psi at report time. - motor, not packer. -WCB De-completed and L/d Tbg hanger (note no capstring ran with completion). POOH L/d 2-7/8" ESP Completion f/7275' t/ESP assembly, removing clamps and spooling ESP cable, filling hole w/8.7ppg double displacement every 10jts out, no drag or over overpull while tripping Continued L/d ESP Pump and Motor assembly and Centralizer Tally, Inspect and M/u 7" AS1x Test Packer. RIH w/7" Test Packer P/u 3-1/2 wk. string f/surface t/7257'md, pumping 3bbls of 8.7ppg NaCl every 15 joint ran in hole. Est parameters PUW=73k SOW=52k, set packer @ 7257', Fluid packed IA, pumped 2bbls and pressured up on IA to 2300psi, MIT-IA for 30mins and charted-good test.. Well Name Rig API Number Well Permit Number Start Date End Date MP L-02A ASR#1 50-029-21998-01-00 209-147 3/5/2023 3/21/2023 Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD: ND BOP stack, clean hgr void, nerw RX54, land tree/adapter and torque to spec. Test void 500/5000 (PASS). Pull Bpv with dry rod. Install tree cap, valves in correct position. JOB Complete. Continued RIH w/ESP Assembly P/u New 2-7/8" 6.5# L-80 EUE 8rd Tubing f/surface f/5000', utilizing clamps the first 10jts and every other joint thereafter, PUW= 58k, Test Electrical Continuity every 1000', filled hole 3bph while tripping. PU/MU L/d Jt and Hanger w/BPV installed, make penetrator splice to cable, terminate penetrator to hanger, final surface check on cable good, landed completion w/46k down on hanger, RILDS, EOT @ 7,277'KB. Clean and clear floor, blow lines dry, Bled off and disconnected Koomey lines. R/d circulating lines, Moved out pipe shed and catwalk, soft break BOP stack. Organized and put away tools, emptied and hauled fluid from pits, Moved out stairs prep for crane work. Rid released @ 23:59hrs 3/21/2023 - Tuesday 3/19/2023 - Sunday POOH L/d 3-1/2" Wk. String f/4500' and L/d Test Packer, rubber element was missing from packer, fill hole with dbl displace every 15 jts out. Cleaned rig floor, R/u 2-7/8" ESP Handling eq. Thread cable thru sheave and prep to RIH. Racked ESP assembly and Tally. PU/MU and Serviced New Centrilift ESP Assembly as designed. Centralizer, Mtr Gauge, Motor, Upper and Lower Seals, Gas Sep, Pump, Ported Sub and Discharge Head. RIH w/ESP Assembly P/u New 2-7/8" 6.5# L-80 EUE 8rd Tubing f/surface t/5000', utilizing clamps the first 10jts and every other joint thereafter, Test Electrical Continuity every 1000', filled hole 3bph while tripping. Crew performed kick while tripping drill w/ ESP cable responds time was 2mins and 5secs. 3/20/2023 - Monday R/u 2-7/8" ESP Handling eq. Thread cable thru sheave and prep to RIH. Racked ESP assembly and Tally. PU/MU and Serviced New Centrilift ESP Assembly as designed. Centralizer, Mtr Gauge, Motor, Upper and Lower Seals, Gas Sep, Pump, Ported Sub and Discharge Head. RIH w/ESP Assembly P/u New 2-7/8" 6.5# L-80 EUE 8rd Tubing f/surface t/5000', PU/MU L/d Jt and Hanger w/BPV installed, make penetrator splice to cable, terminate penetrator to hanger, final surface check on cable good, landed completion w/46k down on hanger, RILDS Continued RIH w/ESP Assembly P/u New 2-7/8" 6.5# L-80 EUE 8rd Tubing f/surface f/5000' 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,444'N/A Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi Drill Liner N/A Slotted Liner N/A Slotted Liner N/A Slotted Liner N/A 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: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 / EUE 8rd 7,280 2/16/2023 7" x 4.5" Packer and N/A 7,344'(MD) / 6,853'(TVD) and N/A See Schematic See Schematic 9,492' 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 209-147 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21998-01-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT L-02A Length Size Proposed Pools: 82' 82' TVD Burst PRESENT WELL CONDITION SUMMARY 7,074' 7,560' 7,034' 1,808 7,560' 82' 13-3/8" MILNE POINT N/A MD 1,730psi N/A 3,250psi 7,240psi 4,950' 7,317' 7,145' 5,076' 7,901' 7,091'9,501' 7,985' N/A Perforation Depth MD (ft): 3-3/16"581' 1,401' 2-3/8"1,583' 7,159' 2-3/8" 9-5/8" 7" 5,076' 7,901' 1,252' 2-3/8" 9,444' 7,074' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Taylor Wellman for David Haakinson By Samantha Carlisle at 1:39 pm, Feb 06, 2023 323-073 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2023.02.06 13:26:46 -09'00' Taylor Wellman (2143) MGR10FEB23 10-404 SFD 2/6/2023 BOPE test to 2500 psi. DSR-2/6/23 1,808 GCW 02/13/23 JLC 2/13/2023 2/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.13 14:31:46 -09'00' RBDMS JSB 021423 Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 Well Name:MPL-02A API Number:50-029-21998-01-00 Current Status:Shut-in Producer Rig:ASR Estimated Start Date:2/16/2023 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:209-147 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2,486 psi @ 6,778’ TVD ESP Intake Sensor |8.28 PPGE Max Potential Surface Pressure: 1,808 psi Gas Column Gradient (0.1 psi/ft) Max Angle:33° @ 7,700’ MD to TD Brief Well Summary: MPL-02 is a shut-in Kuparuk CTD sidetrack. The well was originally drilled as a Kuparuk development well to a depth of 7,901’ MD. In 2010 the well was plugged back and sidetracked with three coil tubing laterals and cased with 2-3/8” slotted liner. MPL-02 has historically been lifted via ESP. An ESP completion was installed in March 2010 post-CTD completion and February 2015 after an ESP failure. In early January 2023 the pump shaft broke on the current ESP. The current ESP completion lasted eight years before the downhole failure. The proposed workover will pull the failed ESP completion and run a new ESP completion. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: Last production casing test was 2,000 psi on 12/12/2009. Pre-Rig Procedure Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Pull dummy valve from GLM at 7,042’ MD. 4. Pull GLV and set dummy valve in upper GLM at 139’ MD. 5. Caliper tubing for possible reuse. 6. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 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. Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 8. Set BPV. ND tree. Brief RWO Procedure 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl 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. NU BOPE. 4. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. 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. 6. Call out Centrilift for ESP pull. 7. RU spoolers to handle ESP cable and 3/8” capillary string. a. Use extreme care in spooling the capillary string to promote reuse of the string. 8. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Expected PU ~80k 9. Confirm hanger free, lay down tubing hanger. 10. POOH and lay down the 2-7/8” tubing. Number all joints. a. Based on caliper results, joints to be kept will be reported to rig. Trash visibly bad joints. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs, trash these joints. e. Previous workover did not record clamp placement. i. Estimated roughly 130 canon clamps ii. Protectolizers on discharge head, pump, upper and lower seals 11. Lay Down ESP. 12. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. 13. PU 3-1/2” workstring, RIH with 7” test packer to 7,257’ MD. 14. Test casing to 2,000 psi. 15. POOH while filling hole with 2x pipe displacement. 16. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 7,255’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. and casing. a. If needed, kill well with produced water prior to setting CTS. Charted and recorded 30 minute pressure test. mgr 3. 2. mgr Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 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 5.7 20 Motor - 250HP - 562XP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 5 Gas Separator 52 5.4 20 Pump - 137-P17 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.505" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 6,840 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 17. Land tubing hanger. Use extra caution to not damage cable. 18. Lay down landing joint. 19. Set BPV. 20. 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. Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 Current Schematic _____________________________________________________________________________________ Revised By: STP 2/1/2023 PROPOSED Milne Point Unit Well: MPL-02A Last Completed: 2/20/15 PTD: 209-147 16 L-02A 2-3/8” Alum. Billit w/ GS FN L-02A1 L-02A2 TD = 7,901’ (MD) / TD = 7,317’(TVD) 13-3/8” Orig. KB Elev.: 56.0’/ GL Elev.: 21 (Nabors 27E) 7” 3 5 6 9 7 & 8 1 0 11 12 13 14 9-5/8” 1 2 15 PBTD =7,560’(MD) / PBTD =7,034’(TVD) 4 Perf’s Cement Squeezed CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / Weld 12.559 Surface 82’ 9-5/8" Surface 36 / J-55 / Btc. 8.765 Surface 5,076’ 7" Production 26 / L-80 / Btc 6.151 Surface 7,901’ 3-3/16” Drill Liner 6.2 / L-80 / N/A 2.805 7,404’ 7,985’ 2-3/8” 2A Slotted Liner 4.4 / L-80 / N/A 1.901 8,192’ 9,444’ 2-3/8” 2A1 Slotted Liner 4.4 / L-80 / N/A 1.901 8,100’ 9,501’ 2-3/8” 2A2 Slotted Liner 4.4 / L-80 / N/A 1.901 7,909’ 9,492’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±7,257’ JEWELRY DETAIL No Depth Item 1 ±139’ Sta 2: ¼” OV 2 ±7,042’ Sta 1: DGLV 3 ±7,185’ XN- Nipple (2.205” ID) 4 ±7,195’ Discharge Head 5 ±7,196’ Pump: 137-P17/ SXD 6 ±7,215’ Gas Separator: 538GM2 7 ±7,220’ Upper Tandem Seal -GSB3DB 8 ±7,227’ Lower Tandem Seal – GSB3DB 9 ±7,234’ Motor: 250 HP – 562XP 10 ±7,254’ Intake Sensor 11 7,255’ Centralizer - Bottom @ 7,257’ 12 7,296’ BOT PBR 80-47 Seal Nipple 13 7,344’ BOT 7” x 4.5” S-3 Packer 14 7,378’ 4.5” ‘X’ Nipple (3.813” ID) 15 7,560’ Top of Whipstock 16 7,909’ 2-3/8” Deployment Sleeve PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT I.D. Status Kup. A3/A2 Sands 8,192’ 9,444’ 7,134’ 7,074’ 1,252 L-02A Isolated Kup. A3/A2 Sands 8,100’ 9,501’ 7,139’ 7,091’ 1,401 L-02AL1 Isolated Kup. A2 Sands 7,909’ 9,492’ 7,150’ 7,159’ 1,583 L-02AL2 Open OPEN HOLE / CEMENT DETAIL 20" To Surface 9-5/8" Cmt w/ 367 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 52 sks Class “G” in 8-1/2” Hole GENERAL WELL INFO API: 50-029-21998-01-00 Drilled and Cased by Nabors 27E- 11/16/1990 Recompleted by Nabors 4ES – 5/28/1996 RWO by Nabors 4ES – 5/30/2001 ESP RWO by Nabors 3S – 2/28/2006 CTD Sidetrack by Nordic 2 – 2/1/2010 ESP Changeout by Nordic 3 – 2/20/2015 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 9-5/8” x 11” WKM Tubing Spool. WKM 11” x 2-7/8” EUE T&B & 2.5” CIW ‘H” BPV Profile WELL INCLINATION DETAIL KOP @ 3,200’ MD Max Hole Angle = 33.58° f/ 7,700’ to TD Hole Angle thru Perfs= 33° WINDOW DETAIL 7,567’ to 7,572’ Well: MPL-02A PTD: 209-147 API: 50-029-21998-01-00 BOPE Schematic STATE OF ALASKA AL , (A OIL AND GAS CONSERVATION COMM,,26ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well LI Plug Perforations U Perforate LI Other U ESP Changeout Performed: Alter Casing ❑ Pull Tubing j Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 209-147 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-21998-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025509 MILNE PT UNIT KR L-02A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Unit Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,492 feet Plugs measured N/A D true vertical 7,159 feet Junk measured N/A Effective Depth measured 9,492 feet Packer measured 7,344 feet MAR 0 3 2015 true vertical 7,159 feet true vertical 6,853' feet AOGCC Casing Length Size MD TVD Burst Collapse Conductor 82' 13-3/8" 82' 82' 1,730psi 740psi Surface 5,076' 9-5/8" 8,076' 4,950' 3,250psi 2,020psi Production 7,901' 7" 7,901' 7,317' 7,240psi 5,410 Liner 581' 3-3/16" 7,985' 7,145' Liner 1,252' 2-3/8" 9,444' 7,074' Liner 1,401' 2-3/8" 9,501' 7,091' Liner 1,583' 2-3/8" 9,492' 7,159' Perforation depth Measured depth See Attached Schematic SCb�r�IVti1'b'�J 1". True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 7,257'(MD) 6,780'(TVD) 7,344'(MD) Packers and SSSV(type,measured and true vertical depth) 7"x 4.5"Packer N/A 6,853'(TVD) 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: 156 18 401 260 259 Subsequent to operation: 239 35 882 260 259 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑� Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A i f,C.O.Exempt: 315-067&315-075 .---" Contact Chris Kanyer Email ckanver a.hilcorp.com Printed Name 01.A,"' Chris Kanyer Title Operations Engineer Signature % Phone 907-777-8377 Date 3/3/2015 ,�3,---7-‘)....--._ RBDMS J MAR - 5 2015 Form 10-404 Revised 10/2012 _ 3 —��JSubmit Original Only /Of 7(((///Vt7//p Milne Point Unit Well: MPL-02A SCHEMATIC Last Completed: 2/20/15 Hite.",Alaska.Lu: PTD: 209-147 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:21 Size Type Wt/Grade/Conn Drift ID Top Btm 13-3/8" Conductor 48/H-40/Weld 12.559 Surface 82' .: L 9-5/8" Surface 36/J-55/Btc. 8.765 Surface 5,076'_ 13-3/8' _ 7" Production 26/L-80/Btc 6.151 Surface 7,901' 3-3/16" Drill Liner 6.2/L-80/N/A 2.805 7,404' 7,985' , I. , . 2-3/8" _ 2A Slotted Liner 4.4/L-80/N/A 1.901 8,192' 9,444' 2-3/8" 2A1 Slotted Liner 4.4/L-80/N/A 1.901 8,100' 9,501' 2-3/8" 2A2 Slotted Liner 4.4/L-80/N/A 1.901 7,909' 9,492' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 7,257' 3/8" Cap.String Stainless Steel N/A Surface 7,257' 95/8' • 6 JEWELRY DETAIL No Depth Item 1 139' GLM 3r8"SS Capillary 2 7,042' GLM Suing -......_________s3 7,185' XN-Nipple(2.205"ID) 4 7,195.95' Discharge Head 5 7,196' Pump 6 7,215' Gas Separator 7 7,220' Top of Upper&Lower Tandem Seal IN 2 8 7,234' Motor 9 7,254' PumpMate Sensor 10 7,255' Centralizer - Bottom @ 7,257' 11 7,296' BOT PBR 80-47 Seal Nipple 12 7,344' BOT 7"x 4.5"S-3 Packer 13 7,378' 4.5"'X'Nipple(3.813"ID) 14 7,560' Top of Whipstock 15 7,909' 2-3/8"Deployment Sleeve 43 PERFORATION DETAIL 4 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT I.D. Status 5 Kup.A3/A2 Sands 8,192' 9,444' 7,134' 7,074' 1,252 L-02A Isolated tUi Kup.A3/A2 Sands 8,100' 9,501' 7,139' 7,091' 1,401 L-02AL1 Isolated g Kup.A2 Sands 7,909' 9,492' 7,150' 7,159' 1,583 L-02AL2 Open 11 OPEN HOLE/CEMENT DETAIL GENERAL WELL INFO 7 20" To Surface API:50-029-21998-01-00 9-5/8" Cmt w/367 sx Class"G"in 12-1/4"Hole Drilled and Cased by Nabors 27E-11/16/1990 ® 7" Cmt w/52 sks Class"G"in 8-1/2"Hole Recompleted by Nabors 4ES-5/28/1996 8 RWO by Nabors 4ES-5/30/2001 _ 9 ESP RWO by Nabors 35-2/28/2006 CTD Sidetrack by Nordic 2-2/1/2010 10 ESP Changeout by Nordic 3-2/20/2015 TREE&WELLHEAD 11 Tree 2-9/16"5M WKM 9-5/8"x 11"5M CIW 11"x 11"WKM Tubing Spool,WKM 11"x 1 12 Wellhead 2-7/8"EUE 8rd T&B Threads&2.5"CIW'H'BPV Profile. 2-3/8"Alum. 13 Billit w/GS FN 14 1 L-02A Perls _ Cement Squeezed\ 5 7"A L-02A1 TD=7,901'(MD)/TD=7,31711VD) PBTD=7,560'(MD)/PBTD=7,034'(TVD) 411*11141 L-02A2 Created By:TDF 3/3/2015 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPL-L-02AL2 50-029-21998-61-00 209-149 2/18/2015 2/20/2015 Daily Operations: 2/18/15-Wednesday Purge and P/T all lines 250psi low/3,000psi high. Line up and circ down tubing 8.5#hot sea water,pressure up after.5 bbl 900 psi breakover, ICP 550psi,220psi on choke. FCP 530psi,60psi on choke.Catch oil/gas returns in 23 bbls.Catch seawater returns early. Note possible hole in tubing identified by caliper,jt 215 circ attained prior to tubing hole depth at approx.6,750'.Contine to circ 3 BPM @ 500 psi.Total 329 bbls pumped. Losses 54 bbls @ 275 bbls in Kill tank Oil water mix.Observe well static on both sides. Install BPV ND tree 2/19/15-Thursday NU BOPE,slip n cut drilling line. Hook up and purge all lines. Pull BPV install TWC shell test.Test and chart BOPE 250psi low/3,000psi higth test annular 250psi low/2,500psi high,draw down test accumulator. Pull TWC with difficulty due to extended neck hanger. Install landing joint. Pull completion @ 90K SW is 54 K. Decomplete hanger, RU spooler, pull stands snake line to spooler POOH w 2-7/8"completion and ESP cable. BO LD 2 GLMs and pup joints and LD jt 215 as identified off caliper no visible hole. Pulled slow and checked all stands prior and 3 stands below to top of pump, all looks good. Recovered all 121 LaSalle clamps. BO LD pump recover 5 protectolizers and 3 flat guards. 2/20/15-Friday PJSM. BO/LD ESP assembly,off load tools,spool loose cable,organize floor for new ESP deployment. PU/MU ESP assembly and service same. Install ESP connector protectorlizers and flatbars. PJSM RIH with ESP assy and 2-7/8" L-80 EUE tbg string. PU/MU tbg hanger, penetrator and landing jt. Make up splice connector on cable. Make OHM and meg check. Land tbg hanger in WKM R 80k up 85k down SW run in alignment screw and lockdown screws. Install BPV, ESP landed @ 7,257', PMS @ 7,251', motor@ 7,232',top of tandem seals 7,218',gas separator@ 7,213', pump @ 7,194', discharge head 7,193',XN nipple/2.205 ID @ 7,183',GLM @ 7,039',GLM@ 7,039', and GLM @ 137'. ND BOP. PJSM ESP connector.NU tree check tubing connector. Pressure test tree void 250psi low/5,000psi high.Tree previously tested no flange breaks. PJSM RDMO, rig released. 2/21/15-Saturday No operations to report. 2/22/15-Sunday No operations to report. 2/23/15-Monday No operations to report. 2/24/15-Tuesday No operations to report. DC>) —`L1 1 ti OF Ty- ' � ,'',\ y�;,s, THE STATE Alaska Oil and Gas mw '- . "" 7 of Conservation Commission ojihiipALASIc:A : 1 - .#_= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T' Al Main: 907.279.1433 OF ALASY'P Fax. 907.276 7542 www.aogcc.alaska,gov Chris Kanyer SCANNED r B 2 t► L01;3 Operations Engineer l Hilcorp Alaska, LLC aP 6 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR L-02A Sundry Number: 315-075 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 / /°;„1/4,1-,_,_ Cathy :. Foerster Chair DATED this /3t of February, 2015 Encl. RECEIVED • STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 11 2015 APPLICATION FOR SUNDRY APPROVALS Z 1 I < 20 MC 25.280 AOGG�./((�� 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing 0' Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing El Other: ESP Changeout 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 209-147 3.Address: Stratigraphic El Service CI6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-21998-01-00 • 7.If perforating: 433,c 36 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. lir Will planned perforations require a spacing exception? Yes ❑ No 0/ MILNE PT UNIT KR L-02A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025509 - Milne Point Unit Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth D(ft): Total Depth TVD(ft): 4V Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 19,42,1_ 7,1 0'l 8;48 1 :0'1 N/A N/A Casing Length Size MD ND Burst Collapse Conductor 82' 13-3/8" 82' 82' 1,730psi 740psi Surface 5,076' 9-5/8" 8,076' 4,950' 3,250psi 2,020psi Production 7,901' 7" 7,901' 7,317' 7,240psi 5,410psi - Liner 581' 3-3/16" 7,985' 7,145' Liner 1,252' 2-3/8" 9,444' 7,074' Liner 1,401' 2-3/8" 9,501' 7,091' Liner 1,583' 2-3/8" 9,492' 7,159' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 7,280 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"x 4.5"Packer and N/A t 7,344'(MD)/6,853'(TVD)and N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 r Service ❑ 14.Estimated Date for / 15.Well Status after proposed work: Commencing Operations: 2/i /IC Oil 0 r Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ El WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer /) Signature ( XvyJou; I Phone 777-8377 Date i i/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k6 - 0`75 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: -4 3'34°/-si Oct,S` ,g[9 I t r' ( /14AsP .: i Yoa 11_5-, Spacing Exception Required? Yes ❑ No Subsequent Form Required: J a '" I 61 APPROVED BY _ Approved by: M IS TONER THE COMMISSION Date: 2 _R ipP� 1�0 ut I roanane Form 10-403( evised 10/2012) A o a I!��a�771Mtl 12 months f om t e ate of approval. // Attachment i uplicate ye. z-/2-/S ` .4,2-z,3-/S �l4 IZ 15 A-7/1 fly/ RBDMS a'' FEB 1 3 7015 Well Prognosis Well: MPL-02A Hilcorp Alaska,LL Date:2/11/2015 Well Name: MPL-02A API Number: 50-029-21998-01-00 Current Status: SI Producer Pad: L Pad Estimated Start Date: February 21, 2015 Rig: Nordic 3 Reg.Approval Req'd? February 17, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 209-147 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907)250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1550110 Current Bottom Hole Pressure: —2,076 psi @ 7,000'ND (Last BHP measured 9/1/2014) Maximum Expected BHP: —2,076 psi @ 7,000'ND (No new perfs being added) Max.Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 70% (0.407psi/ft)with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point L-02A well was drilled as a Kuparuk development well that TD'd at a depth of 7,901' and ran and cemented 7" production casing in November 1990. The well was perforated and Frac'd in the Kuparuk A sands and initially completed with an ESP. The well had ESP change outs in 1991, 1996, 2001, and 2006. The well was plugged back and sidetracked with three coil tubing laterals (L-02AL2) and cased with 2-3/8" slotted liners in February 2010, and had an ESP installed in March 2010. A successful 7" casing pressure test was performed for 30min (charted) on 12/12/2009 to 2,000psi. The current ESP failed in December 2014. The well has remained shut in ever since. A downhole chemical injection line will be run as part of the new completion.A Scale Inhibition Treatment (SIT) was last performed in July 2012. No subsidence issues are expected in this well. A tubing caliper has been run on 2/3/2015 as part of the rig prep of this well and did not indicate any issues. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP& run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: t 1. MIRU Nordic#3 Rig. S 2. Attempt to circulate well with 8.5ppg brine. Monitor well. 3a)D 10 3. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi to psi high, annular to 250psi low/2,SOOpsi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Unseat hanger and pull 2-7/8" ESP completion from 7,280'to surface and lay down same. 5. RU Slickline. RIH and tag top of packer at+/-7,296'with gauge ring. POOH with same and RD slickline. Well Prognosis Well: MPL-02A ffilcorp Alaska,LL, Date:2/11/2015 Contingency: (Pending results of slickline tag depth and/or condition of pulled completion—sand/scale in pump) a. RIH with 7"cleanout BHA and attempt a cleanout upper wellbore(not CTD slotted liners)and circulate well clean to+/-7,296'. b. POOH with 7" cleanout BHA from+/-7,296'. 6. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-7,280'. Land tubing hanger. 7. ND BOP, NU and tree. 8. RDMO workover rig and equipment. 9. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic . Milne Point Unit Well: MPL-02A SCHEMATIC Last Completed: 2/28/10 Hilcorp Alaska,LLC PTD: 209-147 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:21 Size Type Wt/Grade/Conn Drift ID Top Btm % kid 13 3/8" Conductor 48/H-40/Weld 12.559 Surface 82' 9-5/8" Surface 36/J-55/Btc. 8.765 Surface 5,076' 13-3/8' 7" Production 26/L-80/Btc 6.151 Surface 7,901' n 4 1 i 3-3/16" Drill Liner 6.2/L-80/N/A 2.805 7,404' 7,985' 2-3/8" 2A Slotted Liner 4.4/L-80/N/A 1.901 8,192' 9,444' 2-3/8" 2A1 Slotted Liner 4.4/L-80/N/A 1.901 8,100' 9,501' ', 2-3/8" 2A2 Slotted Liner 4.4/L-80/N/A 1.901 7,909' 9,492' }' a t TUBING DETAIL a 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 7,280' ,W � 9-5/8" it JEWELRY DETAIL No Depth Item 1 166' GLM KBMM 2-7/8"x 1"w/DPSOV 2 7,064' GLM KBMM 2-7/8"x 1"w/Dummy 3 7,207' 2-7/8"XN-Nipple(2.250 No-go ID) 4 7,218' Discharge Head GPDIS 5 7,219' Pump 137-P17 SXD 6 7,238' Gas Separator 7 7,243' Top of Upper&Lower Tandem Seal • 2 8 7,256' Motor,KMH 228HP,2,305 Volt,60 Amp 9 7,276' PumpMate Sensor 10 7,278' Centralizer-Bottom=7,280' 11 7,296' BOT PBR 80-47 Seal Nipple 12 7,344' BOT 7"x 4.5"S-3 Packer 13 7,378' 4.5"'X'Nipple(3.813"ID) 14 7,560' Top of Whipstock 11 3 15 7,909' 2-3/8"Deployment Sleeve RD 4 PERFORATION DETAIL I5 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT I.D. Status Kup.A3/A2 Sands 8,192' 9,444' 7,134' 7,074' 1,252 L-02A Isolated III6 Kup.A3/A2 Sands 8,100' 9,501' _ 7,139' 7,091' 1,401 L-02AL1 Isolated Jim Kup.A2 Sands 7,909' 9,492' 7,150' 7,159' 1,583 L-02AL2 Open illalaw 7 SNIT verr OPEN HOLE/CEMENT DETAIL an 20" To Surface 8 9-5/8" Cmt w/367 sx Class"G"in 12-1/4"Hole 7" Cmt w/52 sks Class"G"in 8-1/2"Hole MR 1 9 TREE&WELLHEAD 10 Tree 2-9/16"5M WKM Wellhead 9-5/8"x 11"5M CIW 11"x 11"WKM Tubing Spool,WKM 11"x 2- 11 7/8"EUE 8rd T&B Threads&2.5"CIW'H'BPV Profile. GENERAL WELL INFO 12 API:50-029-21998-01-00 13 Drilled and Cased by Nabors 27E-11/16/1990 Recompleted by Nabors 4ES-5/28/1996 RWO by Nabors 4ES-5/30/2001 2-3/8"Alum. ESP RWO by Nabors 3S-2/28/2006 14 Billit w/GS FN CTD Sidetrack by Nordic 2-2/1/2010 L-02A Perls -Cemerd (\4115 -' 1; 4+ e „r..r-: w f.. r' L-02A1 4 L I ID=7,901'(IVU)/TD=7,317(TVD) PBTD=7,560'(MD)/PBTD=7,034'(TVD) L-02A.?Ai-L- Created By:TDF 2/11/2015 Milne Point Unit Well: MPL-02A ` - PROPOSED Last Completed: 2/28/10 Ililcorp Alaska,LLt. PTD: 209-147 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:21 Size Type Wt/Grade/Conn Drift ID Top Btm F; 13-3/8" Conductor 48/H-40/Weld 12.559 Surface 82' 'Al •, `F 9-5/8" Surface 36/J-55/Btc. 8.765 Surface 5,076' 73/8 7" Production 26/L-80/Btc 6.151 Surface 7,901' 3-3/16" Drill Liner 6.2/L-80/N/A 2.805 7,404' 7,985' , i 1 • 2-3/8" 2A Slotted Liner 4.4/L-80/N/A 1.901 8,192' 9,444' 2-3/8" 2A1 Slotted Liner 4.4/L-80/N/A 1.901 8,100' 9,501' 2-3/8" 2A2 Slotted Liner 4.4/L-80/N/A 1.901 7,909' 9,492' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd _ 2.441 Surface ±7,282' 3/8" Cap.String Stainless Steel N/A Surface ±7,282' 9-5/8" JEWELRY DETAIL No Depth Item 1 ±160' GLM 3/8"SS Capillary 2 ±7,050' GLM String3 ±7,210' Discharge Head 4 ±7,215' Pump 5 ±7,240' Gas Separator -----------41 6 ±7,245' Top of Upper&Lower Tandem Seal 7 ±7,255' Motor 2 8 ±7,275' PumpMate Sensor 9 _ ±7,280' Centralizer 10 7,296' BOT PBR 80-47 Seal Nipple 11 7,344' BOT 7"x 4.5"S-3 Packer 12 7,378' 4.5"'X'Nipple(3.813"ID) 13 _ 7,560' Top of Whipstock 14 7,909' 2-3/8"Deployment Sleeve 1,_,I 3 PERFORATION DETAIL 4 Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT I.D. Status Kup.A3/A2 Sands 8,192' 9,444' 7,134' 7,074' 1,252 L-02A Isolated I J>@L 5 Kup.A3/A2 Sands 8,100' 9,501' 7,139' 7,091' 1,401 L-02AL1 Isolated 6 Kup.A2 Sands 7,909' 9,492' 7,150' 7,159' 1,583 L-02AL2 Open \r---A OPEN HOLE/CEMENT DETAIL 20" To Surface 7 9-5/8" _ Cmt w/367 sx Class"G"in 12-1/4"Hole 7" Cmt w/52 sks Class"G"in 8-1/2"Hole 8 TREE&WELLHEAD 9 Tree 2-9/16"5M WKM Wellhead 9-5/8"x 11"5M CIW 11"x 11"WKM Tubing Spool,WKM 11"x 2- 10 7/8 EUE 8rd T&B Threads&2.5"CIW'H'BPV Profile. GENERAL WELL INFO ARM 11 ' API:50-029-21998-01-00 Drilled and Cased by Nabors 27E-11/16/1990 12 Recompleted by Nabors 4ES-5/28/1996 a RWO by Nabors 4ES-5/30/2001 2-3/8"Alum. ESP RWO by Nabors 35-2/28/2006 13 Billit w/GS FN CTD Sidetrack by Nordic 2-2/1/2010......___pbii ..,..._ 14 1L-02A Pees Cement 01=giffellZkr2 , 7'A 1 4Nikt .o..........„\ 4'-1 %.1'''.--•-. ' L-02A-1-h`-( TD=7,901'(MD)/TD=7,317'(TVD) PBTD=7,560'(MD)/PBTD=7,034'(TVD) L-02A-2 AL--1/ Created By:TDF 2/11/2015 MPU BOP Stack r _ � O O iiiiii Hydril 13 5/8 5M rat Aiii 13 5/8 5M Om 2 7/8"-S-1/2" variables L _ INEN INIrj Spacer spool 13 5/8 5M 135/8 SM Blinds • ■ in- coins ions. Spacer spool 13 5/8 SM 13 5/8" SMX11" 5M DSA 11111 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (.2Roy - j Lk7 Well History File Identifier Organizing (done) ❑ Two -sided 1111111111111 ❑ Rescan Needed 1111111 1 R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Di kettes, No. *� ❑ Maps: Vg(Greyscale Items: Other, No/Type: �iY 140• ❑ Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: c ❑ Other:: l p BY: Maria Date: 0. c7 1 3 /s/ Project Proofing I BY: aria Date: 441 3 /s/ lip Scanning Preparation a x 30 = tl3 C7 +.3_ = TOTAL PAGES S (Count does not include cover sheet) ,,/� BY: Maria / Date: a, 5 7 /s/ n Scanning 11411111 1111 Product�o g Stage 1 Page Count from Scanned File: / 0 (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES fl/j NO / 3 /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 111 111111111111 ReScanned 1311111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 8/15/2012 Permit to Drill 2091470 Well Name /No. MILNE PT UNIT KR L -02A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21998 -01 -00 MD 9444 TVD 7074 Completion Date 3/1/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve 41110. DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: • Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 7157 9443 Open 4/23/2010 ED Lis 19566 Induction /Resistivity 7157 9443 Open 4/23/2010 OH LIS GR, ROP, GRC, RAD, RAS, RPD, RPS Data Plus CGM & PDF Graphics Log Induction /Resistivity 25 Col 7560 9444 Open 4/23/2010 MD MPR, GR Log i Induction /Resistivity 5 Col 7560 9444 Open 4/23/2010 TVD MPR, GR Log f Gamma Ray 25 Col 7560 9444 Open 4/23/2010 MD GR Log r Gamma Ray 5 Col 1740 9410 Open 4/23/2010 Depth Shift Monitor Log Rpt / LIS Verification 7158 8529 Open 5/17/2010 PB1 ED '`C Lis 19642 Induction /Resistivity 7158 8529 Open 5/12/2010 PB1 OH LIS GR, ROP, GRC, RAD, RAS, RPD, RPS Data Plus CGM & • PDF Graphics Rp(,/ LIS Verification 7158 8340 Open 5/12/2010 PB2 ED Lis 19643 Induction /Resistivity 7158 8340 Open 5/12/2010 PB2 OH LIS GR, ROP, GRC, RAD, RAS, RPD, RPS Data Plus CGM & PDF Graphics ED Lis 19702 Induction /Resistivity 7158 8529 Open 5/27/2010 REDO PB1& PB2 LIS GR, ROP, GRC, RAD, RAS, RPD, RPS Data Plus CGM & PDF Graphics ED '- C Directional Survey 7680 9444 Open Rpt Directional Survey 7680 9444 Open ED / C Directional Survey 7500 8529 Open PB1 Rpt / Directional Survey 7500 8529 Open PB1 DATA SUBMITTAL COMPLIANCE REPORT 8/15/2012 Permit to Drill 2091470 Well Name /No. MILNE PT UNIT KR L -02A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21998 -01 -00 MD 9444 TVD 7074 Completion Date 3/1/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N ED C "-" Directional Survey 7561 8340 Open PB2 Rpt Directional Survey 7561 8340 Open PB2 Log Induction /Resistivity 25 Col 7560 8529 Open 5/17/2010 PB1 MD MPR GR Log u) Induction /Resistivity 5 Col 7560 8529 Open 5/17/2010 PB1 TVD MPR GR Log / Gamma Ray 25 Col 7560 8529 Open 5/17/2010 PB1 MD GR Log Gamma Ray 5 Col 7140 8540 Open 5/17/2010 PB1 MD GR Depth Shift III Monitor Plot Log L, Induction /Resistivity 25 Col 7560 8340 Open 5/17/2010 PB2 MD MPR GR Log Induction /Resistivity 5 Col 7560 8340 Open 5/17/2010 PB2 TVD MPR GR Log,. Gamma Ray 25 Col 7560 8340 Open 5/17/2010 PB2 MD GR Log „... Gamma Ray 5 Col 7140 8340 Open 5/17/2010 PB2 MD GR Depth Shift Monitor Plot Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Daily History Received? ti N Chips Received? Y714 Formation Tops a Analysis v %,_,,.^� -. Received? Comments: Compliance Reviewed By: Date: /w • • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPL- 02APB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) Please note the CD enclosed will supersede the previous delivered data sent on 05/11/10. LAC Job #: 2970157 009 — ii q' i 9 P Sent by: Donna Moss Date: 05/27RECE1VED Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY ' ' • NCB C OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ NM 7260 Homer Drive BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 • • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPL- 02APB2 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) Please note the CD enclosed will supersede the previous delivered data sent on 05/11/10. LAC Job #: 2970157 go9 if6) b , Sent by: Donna Moss Date: 05/27/1 ECEIVED R Received by: Date: MAY 2 ; ' L ! Iii✓ PLEASE ACKNOWLEDGE RECEIPT BY SIGN X43.1! 'it OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ MI 7260 Homer Drive BAICER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 • BAKER NY6NES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUN'1 Y NORTH SLOPE BOROUGH WELL NAME MPL- 02APB1 STATE ALASKA FIELD Milne Point Unit DATE 5/11/2010 THIS DISTRIBUTION LIST AUTHORIZED BY Donna Moss SO #: 2970157 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: RECE 1 MAY 1 7 2010 c x. ;.irt -gym corn • Artionoe Page 1 of 1 • • � /tom BAKER MVGMES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH WELL NAME MPL- 02APB2 STATE ALASKA FIELD Milne Point Unit DATE 5/11/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #: 2970157 Comes of Copies Digital Comes of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: REL „." (9 41-1?-- b9Am - 2010 co lt c Page 1 of 1 • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. , Suite 100 r Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPL- 02APB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) ! 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job #: 2970157 Sent by: Donna M ss Date: 0 Received by: Date: ',1 3 ? 1 a._ Cry. PLEASE ACKNOWLEDGE RECEIPT BY SIGN12ETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 0 04i —i NM 7260 Homer Drive BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 p �1 c � INTEQ FAX: (907) 267 -6623 • . INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken ' f Reference: MPL- 02APB2 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job #: 2970157 Sent by: Donna Moss Date: 05/1 Received by Date: •;,� PLEASE ACKNOWLEDGE RECEIPT BY SIGNINr& RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive /96 3 BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 1NTEQ FAX: (907) 267 -6623 R • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 5 2010 ` WELL COMPLETION OR RECOMPLETION REPORT ANELfifice 1a. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25. 110 ® Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 3/1/2010 209 - 147 3. Address: 6. Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 1/14/2010 50 029 - 21998 - 01 - 00 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 1/25/2010 MPL -02A • 3207' FSL, 5056' FEL, SEC. 08, T13N, R10E, UM 8. KB (ft above MSL): 56' 15. Field / Pool (s): Top of Productive Horizon: 3925' FSL, 1724' FEL, SEC. 07, T13N, R10E, UM GL (ft above MSL): Milne Point Unit / Kuparuk River Total Depth: 9. Plug Back Depth (MD+TVD): Oil Pool 3003' FSL, 558' FEL, SEC. 07, T13N, R10E, UM 9444' 7074' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth ( MD+TVD): 16. Property Designation: Surface: x- 544825 y - 6031397 Zone- ASP4 9444' 7074' ADL 025509 TPI: x - 542871 y - 6032104 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 544046 y- 6031188 Zone- ASP4 None 18. Directional Survey: 181 Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill /Lateral Top Window MD/TVD: MWD DIR, GR, RES 8188' 7134' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2 -3/8" 4.4# L -80 8192' 9444' 7134' 7074' 3" Uncemented Slotted Liner ,. 3 3 /k." 4. 2-if 1. -80 T/o`f' 7185' ''1 ro " 4rat 4ner Sa'• /s ( Ai dT G GMeAA - Co° 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD+TVD of Top & Bottom; Perforation Size and Number): 2 -3/8" Slotted Section Note: See MPL -02AL2 MD TVD MD TVD For Tubing Data _ 8211' - 9443' 7133' - 7074' Well Branch Well Branch 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. MPL -02A MPL -02A Departs From Is not Directly DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED Well Branch Accessible MPL -02AL1 PTD # 209 -148, at 8188' MD (7134' TVD) 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Reported on MPL-02AL2 See MPL -02AL2 (Dated 03/25/10, PTD # 209-149) for Production & Test Data P ( ) Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL - BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil • as or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results -'t ! � :To 1. DA None -5 • 1 0 .1 VERIFIED Form 10-407 Revised 12/2 DMS MAR 2 5 2010 I ED ON REVERSE 5.5 • 10 Submit Original Only ' , / /.d C' 29. GEOL9GIC MARKERS (List all formations and fliers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes -∎ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kicked off within Kuparuk A2 None Top Kuparuk A2 7760' 7140' Kuparuk A2 (invert) 8233' 7132' Kuparuk A3 Shale (invert) 8402' 7124' Kuparuk A3 Shale (revert) 8658' 7115' Kuparuk A2 (revert) 8719' 7121' Kuparuk A2 (invert) 9113' 7101' Kuparuk A3 Shale (invert) 9183' 7094' Formation at Total Depth (Name): Kuparuk A3 Shale 9183' 7094' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. � a3 1 2 If0 Signed: Terrie Hubble I Y J 44�.J� T itle: D rilling Technologist D ate: MPL -02A 209 -147 Prepared ByName/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water- Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • BP EXPLORATION Page 1 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2010 00:00 - 00:10 0.17 MOB P PRE SAFETY MTG 00:10 - 04:10 4.00 MOB P PRE MOVE RIG FROM MPC -24 TO MPL PAD 04:10 - 07:00 2.83 MOB N WAIT PRE WO ROADS AND PADS TO RELEVEL IN FRONT OF WELL CREW CHANGE SAFETY MTG 07:00 - 09:00 2.00 MOB P PRE MOVE RIG OVER WELL AND SET DOWN 09:00 - 11:00 2.00 MOB P PRE ACCEPT RIG FOR OPERATION AT 0900 HRS 1/12/2010 SET CUTTINGS BOX, BERM CELLAR W/ SNOW, GENERAL RU R X P MOVE SNOW PILES AT EDGE OF PAD TO GIVE MORE ROOM 11:00 - 14:00 3.00 BOPSUF P PRE ND TREE CAP. NU BOPE. DIFFICULT DUE TO WELLHEAD NOT BEING VERTICAL MOVE OFFICE TRAILER FROM MPC PAD AND SPOT SET BULLRAIL AND SWAP TO RIG POWER 14:00 - 20:00 6.00 BOPSUF P PRE NU MPD LOOP, CONTINUE TO RU BOPE. SHELL TEST BOPE. 20:00 - 00:00 4.00 BOPSUF P PRE PRESSURE TEST BOPE PER AOGCC REGS, 250PSI / 3500PSI. JOHN CRISP WAIVED WITNESS TO TEST. 1/13/2010 00:00 - 04:10 4.17 BOPSUF P PRE CONTINUE TO PRESSURE TEST BOPE PER AOGCC REGS, 250PSI /3500PS1. 04:10 - 04:25 0.25 BOPSUF P PRE BLOW DOWN STACK, KILL LINE & MPD LOOP. 04:25 - 04:40 0.25 RIGU P PRE PJSM REGARDING RU TO PULL BPV. 04:40 - 06:45 2.08 RIGU P PRE RU LUBRICATOR. FILL STACK WITH DIESEL. PRESSURE TEST 250PSI /1100PSI. PULL 4" BPV AND FOUND 275 PSI. CREW CHANGE/SAFETY MTG REMOVE LUBRICATOR AND TOOLS FROM FLOOR. RDMO MPU DSM 06:45 - 08:50 2.08 BOPSUF P PRE SAFETY MTG RU INJECTOR. FILL CT W/ KCL AND TAKE DIESEL AND NaCI TO CUTTINGS BOX PT PACKOFF AND VALVE IN REEL 250/3500 08:50 - 10:30 1.67 RIGU P PRE PUMP SLACK BACK INTO REEL 3.12/2280. BLOW CT BACK W/ AIR. RU HYD CUTTER AND CUT 324' BEFORE FINDING WIRE. RD CUTTER 10:30 - 13:45 3.25 STWHIP P WEXIT INSTALL CTC. PT 40K CT IS 13006', CTV =49.1, 440K RF INSTALL BHI LQC. PT 4000 HOOK UP HYD PANEL TO TRSSSV AND VERIFY FLAPPER IS OPEN OPEN WELLBORE TO CLOSED CHOKE. IAP 7, OAP 6. BLEED DOWN 10 PSI WHP TO TIGER TANK AND BLOW DOWN LINE 13:45 - 14:30 0.75 STWHIP P WEXIT MONITOR WELL FOR FLOW. SET INJECTOR OVER BUNGHOLE. PUMP 1.5 CT VOLUMES FORWARD 2.75/1640 WHILE HAVE PRESPUD MTG. THEN HAVE MEETING TO MU BHA 14:30 - 16:00 1.50 STWHIP P WEXIT MU BHA #1. SET BHA IN WELLBORE AND CONFIRM SPACE OUT 16:00 - 17:25 1.42 STWHIP P WEXIT RIH w/ BHA #1 CIRC THRU MILL 1.0/540 17:25 - 17:40 0.25 STWHIP P WEXIT LOG TIE -IN DOWN FROM 7200' TO 7540'. MINUS 26' CORRECTION. 17:40 - 17:45 0.08 STWHIP P WEXIT DRY TAG WS AT 7567'. Printed: 3/19/2010 1:28:50 PM • . BP EXPLORATION Page 2 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 p Rig Name: NORDIC 2 Rig Number: N2 rt Date From - To Hours Task Code NPT Phase Description of Operations 1/13/2010 17:45 - 00:00 6.25 STWHIP P WEXIT TIME MILL WINDOW FROM 7567' @ 1' /HR USING 1% KCL WHILE SWAPPING HOLE TO USED GEOVIS. 2.53BPM, 2300PSI FS. DHWOB: 0.5 - 0.9K #. 10.27 ECD BLED IA FROM 900PSI TO 100PSI - ALL FLUID. MILL TO MIDNIGHT DEPTH OF 7570.6' 1/14/2010 00:00 - 03:30 3.50 STWHIP P WEXIT CONTINUE TO TIME MILL WINDOW FROM 7570.6' @ 1' /HR a''� USING USED GEOVIS. 2.56BPM, 2300PSI FS. DHWOB: 0.8 - 0.9K #. 10.29 ECD. 03:30 - 05:55 2.42 STWHIP P WEXIT STRING REAMER HAS EXITED THE WINDOW. PRELIMINARY WINDOW DEPTHS ARE TOP = 7566.6' BOTTOM = 7572.4 MILL 10' OF RATHOLE TO 7582'. BOTTOM'S UP REVIELS 15 -20% SHALE. 05:55 - 07:15 1.33 STWHIP P WEXIT REAM & BACK REAM WINDOW USING 2.5BPM, 2550PSI. DRY TAG CLEAN. PVT 354 07:15 - 08:30 1.25 STWHIP P WEXIT POH CIRC THRU MILL 2.56/2530 08:30 - 11:00 2.50 STWHIP P WEXIT PRESSURE UNDEPLOY W/ 370 PSI INDUCED WHP ON MPD LOOP I n MII 1 ING BHA. MILL WAS 3.77" NG, SR 3.78" NG. LOAD OUT BTT TOOLS 11:00 - 12:45 1.75 DRILL P PROD1 BHI RECONFIGURE MWD ASSY FOR DRILLING NORDIC CUT OFF 25' OF SLICKLINE AND REHEAD SWS CHANGE GEAR OIL IN REEL DRIVE PLANETARYS 12:45 - 13:00 0.25 DRILL P PROD1 SAFETY MTG TO PRESSURE DEPLOY 13:00 - 14:45 1.75 DRILL P PROD1 PRESSURE DEPLOY BHA #2 W/ 3.3 DEG MOTOR. UNABLE TO RIH PAST -2' BELOW THE TUBING HANGER SAFETY MTG CLOSE TRSSSV AND BLEED OFF WHP ABOVE RAISE LUB, BREAK OFF MOTOR, SET MWD IN MOUSEHOLE. STANDBACK LUB 14:45 - 16:15 1.50 DRILL P PROD1 MU BUILD BHA. OPEN EDC, CIRC 0.50/830. PRESSURE WELLBORE TO 400 PSI, OPEN TRSSSV 16:15 - 16:45 0.50 DRILL P PROD1 RIH W/ BHA #2 CIRC THRU EDC 0.56/1210 FOLLOWING PRESSURE SCHEDULE. NO WT LOSS THRU TRSSSV. RIH TO 2400'. ADJUST INJECTOR WT CELL 16:45 - 17:15 0.50 DRILL P PROD1 RECEIVE ORDERS FROM GEO'S THAT WE MAY CHANGE BACK TO 'ORIGINAL' PLAN. IF SO, A LARGER BEND MOTOR MAY BE NECESSARY. SO, RIH SLOW WHILE WOO 17:15 - 18:11 0.93 DRILL P PROD1 RECEIVE ORDERS TO RESUME RIH 18:11 - 19:00 0.82 DRILL P PROD1 LOG DOWN FOR TIE -IN FROM 7370', MINUS 25' CORRECTION. S /D, TRAP WHP & CLOSE EDC. 19:00 - 19:15 0.25 DRILL P PROD1 RIH. RUN THROUGH WINDOW - SMOOTH. TAG AT 7581.5'. 19:15 - 20:30 1.25 DRILL P PROD1 DRILL BUILD FROM 7581.5' 2.56/2825/30 -0L W/ 100 -300 PSI DIFF, 0.75 -1.5K WOB W/ 10.27 ECD AT 10- 20' /HR (CONTROLLED ROP TO ESTABLISH WEAR PATTERN) 36 DEG AT 6928' TVD. PVT 347. DRILL TO 7594' PVT 347. TURN ON CENTRIFUGES. 20:30 - 21:20 0.83 DRILL N DFAL PROD1 PULL UP THROUGH WINDOW. CHECK STOPS IN THE HOT. ALL OK, MAGNETICS IN TOOLS & PROXIMITY TO CASING WAS THE PROBLEM. 21:20 - 00:00 2.67 DRILL P PROD1 DRILL BUILD FROM 7594' 2.45/2630/30 -0L W/ 100 -300 PSI Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 3 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/14/2010 21:20 - 00:00 2.67 DRILL P PROD1 DIFF, 1.75 -2.5K WOB W/ 10.30 ECD AT 20- 30' /HR, 36.4 DEG AT 6928' TVD. PVT 346. DRILL TO MIDNIGHT DEPTH OF 7658' PVT 369 (DUE TO CENTRIFUGE). 1/15/2010 00:00 - 01:00 1.00 DRILL P PROD1 CONTINUE TO DRILL BUILD FROM 7658' 2.45/2600/40 -0L W/ 100 -300 PSI DIFF, 1.95 -2.4K WOB W/ 10.32 ECD AT 25- 40' /HR, 50.1 DEG AT 7033' TVD. PVT 370. DRILL TO 7700' PVT 367 01:00 - 01:15 0.25 DRILL P PROD1 WIPER TO BASE OF WINDOW & TO TD W/ REDUCE RATE WHILE RIH - CLEAN BOTH WAYS. 01:15 - 02:30 1.25 DRILL P PROD1 DRILL BUILD FROM 7700' 2.59/2640/40 -0L W/ 100 -300 PSI DIFF, 1.95 -2.4K WOB W/ 10.38 ECD AT 45- 65' /HR, 67 DEG AT 7064' TVD. PVT 367. DRILL TO 7756' PVT 359 02:30 - 02:45 0.25 DRILL P PROD1 SLOWLY PUN & EVALUATE LOW DOG LEGS. WIPER TO BOTTOM WITH REDUCED PUMP RATE. CLEAN BOTH WAYS. 02:45 - 05:15 2.50 DRILL P PROD1 DRILL BUILD/TURN FROM 7756' 2.25/2430/70 -40L W/ 300 -500 PSI DIFF, 2.5 -3.4K WOB W/ 10.33 ECD AT 35- 100' /HR, 74 DEG AT 7074' TVD. USE LOWER PUMP RATE & MORE WOB IN ATTEMPT TO GAIN MORE DLS. PVT 358. DRILL TO 7950' PVT 353 05:15 - 05:45 0.50 DRILL P PROD1 WIPER TO THE WINDOWUSING 2.6BPM/2740PSI & TO TD WITH REDUCED PUMP RATE THROUGH BUILD SECTION, 1.25BPM /1100PSI - CLEAN BOTH WAYS. 05:45 - 07:50 2.08 DRILL P PROD1 DRILL BUILD/TURN FROM 7950' 2.5/2900/90L W/ 250 -400 PSI DIFF, 2.25 -3.1K WOB W/ 10.50 ECD AT 65- 100' /HR, 95DEG AT 7095' TVD. DRILLED TO 8075' AND COMPLETED TURN PVT 350 07:50 - 08:15 0.42 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN. PULL THRU WINDOW, OPEN EDC 08:15 - 09:50 1.58 DRILL P PROD1 POOH CIRC THRU EDC 3.05/2640 FOLLOWING PRESSURE SCHEDULE 09:50 - 12:00 2.17 DRILL P PROD1 PRESSURE UNDEPLOY W/ 370 PSI WHP. ATTEMPT TO PULL BHA INTO LUBRICATOR AND WOULDN'T BUDGE. CLOSE TRSSSV AND REMOVE BHA FROM WELLBORE. LD BUILD BHA. BIT WAS 1 -2 -1 W/ CHIPPED CUTTERS, MOTOR WAS OKAY AND WILL RERUN 12:00 - 12:45 0.75 DRILL P PROD1 RHI RFCONFIGURE BHA FOR LATERAL 12:45 - 13:00 0.25 DRILL P PROD1 SAFETY MTG TO MU BHA 13:00 - 14:30 1.50 DRILL P PROD1 MU LATERAL BHA W/ USED 1.3 DEG MOTOR AND NEW BI -RAZOR BIT 14:30 - 16:00 1.50 DRILL P PROD1 RIH W/ BHA #3 CIRC THRU BIT 0.25/1160 16:00 - 16:45 0.75 DRILL P PROD1 LOG TIE -IN DOWN FROM 7370', CORR -15'. RIH THRU WINDOW, CLEAN TO 7600'. LOG TIE -IN TO RA MARKER IN WS AND FOUND AT 7571.0' PVT 346 16:45 - 19:45 3.00 DRILL P PROD1 DRILL FROM TAG AT 8074' 2.55/2730. APPEARED TO PLUG JETS TWICE IN FIRST 20'. DRILL AHEAD W/ 2.55/3100/90L W/ 200 -300 PSI DIFF, 1.4 -2.0K WOB W/ 10.45 ECD AT 93 DEG AT 20- 120' /HR. DRILL TO 8200' PVT 346 19:45 - 19:50 0.08 DRILL P PROD1 WIPER TO 8075' - CLEAN. 19:50 - 21:55 2.08 DRILL P PROD1 MAD PASS UP FROM 8075' TO BASE OF THE WINDOW USING 2.5BPM/2780PSI, SLIGHT OP & MW AT 7665. WIPER TO TD USING REDUCED PUMP RATE THROUGH THE BUILD. Printed: 3/19/2010 1:28:50 PM • BP EXPLORATION Page 4 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/15/2010 21:55 - 00:00 2.08 DRILL P PROD1 RESUME DRILLING LATERAL SECTION FROM 8200' 2.5/2770/70 -90L W/ 150 -300 PSI DIFF, 1.5 -2.4K WOB W/ 10.52 ECD AT 35- 90' /HR, PVT 344. DRILL TO MIDNIGHT DEPTH OF 8240' PVT 342 1/16/2010 00:00 - 01:40 1.67 DRILL P PROD1 CONTINUE DRILLING LATERAL SECTION FROM 8240' 2.5/2840/60 -30L W/ 150 -300 PSI DIFF, 1.5 -4.4K WOB W/ 10.50 ECD AT 5- 115' /HR, PVT 342. PERFORM NUMEROUS BHA & MINI WIPER TRIPS. DRILL TO 8275' PVT 341 01:40 - 02:00 0.33 DRILL P PROD1 WIPER TO 8100' & TO TD - CLEAN BOTH WAYS. 02:00 - 04:40 2.67 DRILL P PROD1 DRILL LATERAL SECTION FROM 8275' 2.45/2800/90 -30L W/ 150 -300 PSI DIFF, 1.5 -4.0K WOB W/ 10.54 ECD AT 10- 118' /HR CLIMBING TVD, PVT 341. PERFORM NUMEROUS BHA & MINI WIPER TRIPS. DRILL TO 8366' PVT 340 04:40 - 06:15 1.58 DRILL P PROD1 WIPER TO THE WINDOW, SLIGHT MW AT 8055'. 06:15 - 10:20 4.08 DRILL P PROD1 , DRILL FROM 8366' ?.50/3100/170L W/ 100 -200 PSI DIFF, 3.5 -4.5K WOB W/ 10.52 ECD IN WHAT DRILLS LIKE ANKERITE. TRYING TO DROP TVD TO GET INTO TARGET A2 /A3 SANDS. PAINFULLY SLOW DRILLING. GEO SAYS THIS MAY BE THE A4? SHALE PVT 340 10:20 - 14:00 3.67 DRILL P PROD1 DRILL FROM 8400' 14:00 - 17:30 3.50 DRILL P PROD1 DRILL FROM 8430' 2.48/2930/1701 W/ 90 DEG AT THE BIT. SEE 120 -150 API SHALE (A4) FROM 8360'. CONTINUE DROP AT SLOW PENETRATION RATE THRU SHALE. DRILL TO 8456' AND HAD INCREASE IN PENETRATION RATE PVT 338 17:30 - 18:00 0.50 DRILL P PROD1 DRILL FROM 8456' 2.48/2920/170L. DRILL TO 8465'. 18:00 - 18:15 0.25 DRILL P PROD1 WIPER TO 8100, SLIGHT OP & MW AT 8350' (CREST OF A4) & TO TD. 18:15 - 21:15 3.00 DRILL P PROD1 DRILLING LATERAL FROM 8465' 2.47/3040/180 W/ 150 -200 PSI DIFF, 1.0 -2.0K WOB W/ 10.56 ECD AT 10- 118'/HR, PVT 339. PERFORM NUMEROUS BHA & MINI WIPER TRIPS. DRILL TO 8529' PVT 339. HAVE ENOUGH GEOLOGICAL DATA FOR SIDETRACK. 21:15 - 23:00 1.75 DRILL C PROD1 WIPER TO WINDOW - CLEAN. PULL THROUGH WINDOW, SLIGHT OP @ 7555'. MAKE UP / DOWN PASS. OPEN EDC. JET TO 7300' & DOWN TO 7600' (EDC STILL 20' ABOVE WINDOW). PUH THRU WINDOW - CLEAN. 23:00 - 00:00 1.00 DRILL C PROD1 POH FOLLOWING PRESSURE SCHEDULE. 1/17/2010 00:00 - 01:20 1.33 DRILL C PROD1 CONTINUE TO POH. JET TRSSSV. PJSM REGARDING HANDLING BHA WHILE POH. TAG UP. TRAP 400PSI ON WELL. CLOSE TRSSSV. 01:20 - 01:45 0.42 DRILL C PROD1 TAG UP. FLOW CHECK. BLOW DOWN & SHORT CHAIN BHA OOH. LD MOTOR, BEARINGS WITH MOTOR HAVE FAILED. BIT WAS 1 -1. 01:45 - 02:00 0.25 DRILL C PROD1 PJSM REGARDING MU BHA. 02:00 - 03:00 1.00 DRILL C PROD1 MU OHWS SETTING BHA. STAB ONTO WELL. POWER UP & TEST TOOLS. PRESSURE UP WELL TO 450PSI. OPEN TRSSSV. 03:00 - 04:55 1.92 DRILL C PROD1 SLOWLY RIH FOLLOWING PRESSURE SCHEDULE. 04:55 - 05:15 0.33 DRILL C PROD1 LOG DOWN FOR TIE -IN FROM 7350', MINUS 19' CORRECTION. CLOSE EDC. 05:15 - 06:00 0.75 DRILL C PROD1 RIH. WT CK @ 7480' = 32K, 14K RIW. WINDOW WAS Printed: 3/19/2010 1:28:50 PM BP EXPLORATION Page 5 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/17/2010 05:15 - 06:00 0.75 DRILL C PROD1 SMOOTH. SET DOWN AT 7590'. WORK TO GET FREE, 12K OP. 06:00 - 07:30 1.50 DRILL X DPRB PROD1 POH. CLOSE TRSSSV 07:30 - 09:15 1.75 DRILL X DPRB PROD1 LD BHA, BILLET WAS LEFT IN HOLE. NO OBVIOUS PROBLEM W/ SETTING TOOL DISCUSS. RECONFIGURE BHA TO REDRILL. TOP OF WS SHOULD BE ABOUT 7' OUTSIDE OF WINDOW 09:15 - 09:25 0.17 STKOH X DPRB PROD1 SAFETY MTG TO MU BHA 09:25 - 10:40 1.25 STKOH X DPRB PROD1 MU BUILD BHA W/ 3.3 DEG MOTOR AND USED BI RAZOR BIT. HAD TO WRENCH BHA IN HOLE 10:40 - 12:25 1.75 STKOH X DPRB PROD1 RIH W/ CIRC THRU EDC 0.40/1170 FOLLOWING PRESSURE SCHEDULE. OPEN TRSSSV 12:25 - 12:40 0.25 STKOH X DPRB PROD1 LOG TIE -IN FROM 7370', CORR -26' 12:40 - 12:50 0.17 STKOH X DPRB PROD1 RIH THRU WINDOW, CLEAN AND TAG TOP OF BILLET AT 7580' AT MIN RATE. PUH 31.3K. RETAG AT 7580' AND STACK 8.5K BHI WOB. PUH THRU WINDOW, CLEAN 12:50 - 13:20 0.50 STKOH X DPRB PROD1 WO BHI TO RECONFIGURE PC'S FOR NEW WELLBORE 13:20 - 13:35 0.25 STKOH X DPRB PROD1 RIH THRU WINDOW AT MIN RATE TO TAG AT 7580'. PUH 31 K AND ORIENT TF AROUND. START MOTOR 2.52/2550/15R AND EASE BACK DOWN TO 7578.0' 13:35 - 13:55 0.33 STKOH X DPRB PROD1 REAM FROM 7578' AT 5' /HR TO 7580' 13:55 - 15:00 1.08 STKOH X DPRB PROD1 DRILL FROM 7580' 2.53/2570/15R AT 10' /HR W/ <0.5K WOB. HAD TO PU TWICE TO VERIFY TF WHEN NBI WAS ACROSS TRAY. DRILL FROM 7585' 2.51/2530/? AT 15- 20' /HR W/ 100 PSI W/ 0.5 -1.0K WOB A 10.4 ECD PVT 319 15:00 - 16:30 1.50 STKOH X DPRB PROD1 DRILL FROM 7589.0' 2.51/2550/30L W/ 150 -250 PSI DIFF, 1.0 -1.5K W/ 10.41 ECD AT 15- 20' /HR 16:30 - 22:15 5.75 STKOH X DPRB PROD1 DRILL FROM 7612' 2.51/2750/60L W/ 150 -300 PSI DIFF, 1.25 -1.75K W/ 10.4 ECD AT 40- 60' /HR AND SEE WE HAVE 41 DEG VS 35 DEG IN ORIGINAL WELLBORE. DRILL TO 7750'. PVT 319 22:15 - 22:30 0.25 STKOH X DPRB PROD1 WIPER TO THE WINDOW & TO TD - CLEAN. 22:30 - 00:00 1.50 STKOH X DPRB PROD1 DRILL FROM 7750' 2.48/2800/60L -90L W/ 150 -300 PSI DIFF, 1.25 -3.75K W/ 10.38 ECD AT 40- 75' /HR. DRILL TO MIDNIGHT DEPTH 7780'. PVT 319 1/18/2010 00:00 - 01:30 1.50 STKOH X DPRB PROD1 DRILL FROM 7780' 2.48/2800/60L -90L W/ 150 -300 PSI DIFF, 1.25 -3.75K W/ 10.38 ECD AT 40- 75' /HR. DRILL TO 7805'. PVT 315 01:30 - 01:50 0.33 STKOH X DPRB PROD1 SURVEY'S SEEM TO BE IMPOSSIBLE. PUH & RESURVEY WELLBORE. TOOL IS OK. ** *NOTE * ** POSSIBLE HIGH DOG LEGS AT 7740' 01:50 - 05:00 3.17 STKOH X DPRB PROD1 DRILL FROM 7805' 2.52/2950/60L -90L W/ 150 -300 PSI DIFF, 2.25 -2.75K W/ 10.38 ECD AT 10- 75' /HR. DRILL TO 7857'. PVT 311 05:00 - 05:20 0.33 STKOH X DPRB PROD1 WIPER TO WINDOW - CLEAN. PULL THROUGH WINDOW - CLEAN. OPEN EDC. 05:20 - 07:00 1.67 STKOH X DPRB PROD1 POH FOLLOWING PRESSURE SCEDULE TO INSPECT MOTOR. 07:00 - 07:30 0.50 STKOH X DPRB PROD1 CLOSE TRSSSV. LD DRILLING BHA 07:30 - 07:45 0.25 BOPSUF X DPRB PROD1 FUNCTION TEST BOPE. CHANGE OUT PACKOFF 07:45 - 08:45 1.00 STKOH X DPRB PROD1 MU BUILD BHA 08:45 - 10:00 1.25 STKOH X DPRB PROD1 RIH CIRC THRU EDC 0.4/1120. OPEN TRSSSV Printed: 3/19/2010 1:28:50 PM • BP EXPLORATION Page 6 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/18/2010 10:00 - 10:30 0.50 STKOH X DPRB PROD1 LOG TIE -IN DOWN FROM 7370'. CORR -21' CLOSE EDC 10:30 - 11:00 0.50 STKOH X DPRB PROD1 WIPER TO TD WAS CLEAN PVT 301 11:00 - 12:35 1.58 STKOH X DPRB PROD1 DRILL FROM 7857 2.54/2650/90L W/ 150 -300 PSI DIFF, 1.5 -2.5K WOB (+11K SURFACE WT) W/ 10.43 ECD ON OPEN CHOKE TO COMPLETE THE TURN AT 7940' 12:35 - 13:00 0.42 STKOH X DPRB PROD1 WIPER TO WINDOW WAS CLEAN THRU WINDOW. OPEN EDC 13:00 - 14:25 1.42 STKOH X DPRB PROD1 POH CIRC THRU EDC 3.0/2530 FOLLOWING PRESSURE SCHEDULE 14:25 - 15:30 1.08 STKOH X DPRB PROD1 LD DRILLING BHA BHI RECONFIGURE BHA FOR RES AND ADJUST MOTOR NORDIC ADJUST MM READINGS 15:30 - 16:25 0.92 STKOH X DPRB PROD1 MU LATERAL BHA W/ USED 1.3 DEG MOTOR, USED BI RAZOR BIT AND ADDED RES TOOL 16:25 - 18:05 1.67 STKOH X DPRB PROD1 RIH W/ BHA #6 CIRC THRU BIT 0.35/1220 FOLLOWING PRESSURE SCHEDULE. OPEN TRSSSV 18:05 - 18:30 0.42 STKOH X DPRB PROD1 LOG DOWN FOR TIE -IN FROM 7370'. MINUS 19' CORRECTION. CLOSE EDC. 18:30 - 18:45 0.25 STKOH X DPRB PROD1 RIH & TAG AT 7580'. TRY DIFFERENT SPEEDS, ROLL PUMPS @ 0.25 & 0.5BPM - NO GO. 18:45 - 20:00 1.25 STKOH X DPRB PROD1 PUH & DISCUSS. 20:00 - 20:25 0.42 STKOH X DPRB PROD1 LOG DOWN FOR TIE -IN FROM 7370'. PLUS 2' CORRECTION. 20:25 - 20:35 0.17 STKOH X DPRB PROD1 RIH & TAG AT 7581'. TRY DIFFERENT SPEEDS, 0 -30R TF, YO -YO PIPE & ROLL PUMPS - NO GO. 20:35 - 22:15 1.67 STKOH X DPRB PROD1 POH FOLLOWING PRESSURE SCHEDULE. 22:15 - 22:25 0.17 STKOH X DPRB PROD1 PJSM REGARDING PRESSURE UNDEPLOYING TOOLS. 22:25 - 00:00 1.58 STKOH X DPRB PROD1 PRESSURE UNDEPLOY BHA. BIT WAS 1 -1 & BALLED UP WITH FORMATION. 1/19/2010 00:00 - 00:35 0.58 STKOH X DPRB PROD1 DIAL UP MOTOR & SCRIBE SAME. CLEAN UP BIT. 00:35 - 00:50 0.25 STKOH X DPRB PROD1 PJSM REGARDING PRESSURE DEPLOYING. 00:50 - 02:15 1.42 STKOH X DPRB PROD1 PRESSURE DEPLOY BHA. 02:15 - 03:45 1.50 STKOH X DPRB PROD1 RIH FOLLOWING PRESSURE SCHEDULE. 03:45 - 04:10 0.42 STKOH X DPRB PROD1 LOG DOWN FOR TIE -IN FROM 7385', MINUS 25' CORRECTION. 04:10 - 05:40 1.50 STKOH X DPRB PROD1 SET DOWN AT 7582'. ROLL PUMPS, RIH AT DIFFERENT SPEEDS - NO LUCK. PUMP 2.5BPM /2800PSI. RIH TO 7583' & TURN PUMPS OFF. SET DOWN AT 7585' & IS ACTING LIKE WE ARE PUSHING SOMETHING - BIG BALL OF CUTTINGS? PUMP 2.5BPM/2775PSI. GOT PAST. REDUCE TO 1 BPM & RIH. SET DOWN AT 7686'. 25K OP TO GET FREE. WIPER BACK TO 7590' AT FULL RATE. RIH & TAG AT 7680 °. TRY TO WORK PAST AT MIN RATE - NO LUCK. PUMP AT 2.5BPM /2600PSI @ 1' /MIN FROM 7575 - 7585'. RIH AT 10' /MIN AFTER THAT. TAG BOTTOM AT 7940'. 05:40 - 06:15 0.58 STKOH X DPRB PROD1 WIPER TO WINDOW, SLOWLY BACKREAM THRU SHALES AT 7680'. 06:15 - 07:15 1.00 STKOH X DPRB PROD1 BACK REAM THRU THE BILLET AREA 25DEG L &R OF DTF UNTIL CLEAN. ABLE TO PASS WHILE RIH AT 0.6/1500 15' /MIN CLEAN. PULL THRU WINDOW, BACKREAM 7" TO EOT TWICE. OPEN EDC 07:15 - 09:30 2.25 STKOH X DPRB PROD1 POH CIRC THRU EDC 2.90/2400 Printed: 3/19/2010 1•28•50 PM • BP EXPLORATION Page 7 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/19/2010 07:15 - 09:30 2.25 STKOH X DPRB PROD1 NO ADDITIONAL SOLIDS OR ALUMINUM FROM 7" LINER SECTION AT BU, HOWEVER, WHEN AT 2000' ( -TWO BU'S) RECOVERD A BUNCH OF SHALE AND MINOR ALUMINUM. GEO CAN'T TELL WHAT SHALE IT IS. ASSUME IT CAME FROM HIGH GR AREA AT 7680' WHICH IS A4 /A5 SHALE INTERFACE AND MAY HAVE BEEN HIDING OUT IN THE 7" BELOW WHERE THE EDC CLEANS 09:30 - 14:00 4.50 STKOH X DPRB PROD1 PRESSURE UNDEPLOY W/ 400 PSI WHP. ADJUST MOTOR TO 1.5 DEG BEND. RE -RUN BIT. PRESSURE DEPLOY BHA. 14:00 - 15:20 1.33 STKOH X DPRB PROD1 RIH WITH LATERAL BHA #9. EDC OPEN. 15:20 - 16:00 0.67 STKOH X DPRB PROD1 LOG GR TIE -IN. -14' CORRECTION 16:00 - 17:00 1.00 STKOH X DPRB PROD1 RIH, WORK PAST BILLET, RIH TO BOTTOM AT 7940'. 17:00 - 21:00 4.00 STKOH X DPRB PROD1 DRILL LATERAL IN A2 SAND. DRILL FROM 7940' 2.45/2850/60L -90L W/ 150 -300 PSI DIFF, 2.25 -2.75K W/ 10.65 ECD AT 40- 75' /HR, CONDUCT MUD SWAP. DRILL TO 8100'. 21:00 - 21:15 0.25 STKOH X DPRB PROD1 WIPER TO 7940' - CLEAN. 21:15 - 22:30 1.25 STKOH X DPRB PROD1 MAD PASS UP FROM 7940' TO 7590', STILL RATTY FROM 7690' -7650' (SHALE & HIGH DLS AREA). 22:30 - 23:00 0.50 STKOH X DPRB PROD1 RIH WITH REDUCED RATE THRU THE BUILD SECTION. SET DOWN AT 7680', TRY NO PUMPS, 1 BPM, GOT THRU WITH 2.2BPM. REDUCE RATE & RIH TRHU BUILD SECTION. 23:00 - 00:00 1.00 STKOH X DPRB PROD1 DRILL INVERT LATERAL IN A2/A3 SAND. DRILL FROM 8100' 2.7/23600/60L -110L W/ 150 -300 PSI DIFF, 2.5 -3.25K W/ 10.70 ECD AT 40- 50' /HR. PVT 397. DRILL TO MIDNIGHT DEPTH OF 8139'. PVT 391 1/20/2010 00:00 - 03:25 3.42 STKOH X DPRB PROD1 DRILL INVERT LATERAL IN A2 /A3 SAND. DRILL FROM 8139' 2.7/23600/60L -110L W/ 150 -300 PSI DIFF, 2.5 -3.25K W/ 10.70 ECD AT 40- 50' /HR. PVT 391. DRILL TO 8250'. PVT 385 03:25 - 04:10 0.75 STKOH X DPRB PROD1 WIPER TO 7700' & DOWN TO TD USING REDUCED PUMP RATE THRU BUILD SECTION - CLEAN. 04:10 - 06:00 1.83 STKOH X DPRB PROD1 DRILL INVERT LATERAL IN A2/A3 SAND. DRILL FROM 8250' 2.66/2460/60 -110R W/ 150 -300 PSI DIFF, 2.5 -3.5K W/ 10.72 ECD AT 40- 50' /HR. PVT 382. DRILL TO 8286'. PVT 380 DRILLED TO 8288'. 06:00 - 10:30 4.50 STKOH X DPRB PROD1 DRILL A3 LATERAL, 2.6 BPM, 10.7 ECD, 100R TF, 10 -20 FPH, 3 -4 K WOB, SLOW ROP, DRILLING SILTSTONE AT TOP OF A3 SAND. DRILLED TO 8333'. 10:30 - 11:30 1.00 STKOH X DPRB PROD1 DRILL A3 LATERAL, 2.5 BPM, 3400 -3800 PSI, 90R TF, 4.5K WOB, STACKING WT. VERY SLOW DRILLING. DRILLED TO 8340'. 11:30 - 12:30 1.00 STKOH X DPRB PROD1 POH TO CHECK BIT AND MOTOR. WASH 7" CASING FROM TOP OF WINDOW TO 7450'. PACKED OFF AT 7445'. NO RETURNS. WORK PIPE, NO RETURNS STACK FULL WT, WORK PIPE UP TO 55K UP WT, -6K DOWN WT. OPEN EDC. 12:30 - 12:45 0.25 STKOH X STUC PROD1 PACKED OFF. STOP PUMP, BLEED OFF PRESS. RIH AND WORKED BHA FREE. Printed: 3/19/2010 1:28:50 PM 'e S BP EXPLORATION Page 8 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/20/2010 12:30 - 12:45 0.25 STKOH X STUC PROD1 DWN WT = 12K, UP WT = 29K RIH TO 7550'. CIRC AT 2.7 BPM, 3600 PSI. PULL CLEAN TO 7500'. 12:45 - 13:30 0.75 STKOH X DPRB PROD1 CIRC BOTTOMS UP WHILE RECIPROCATE COIL FROM 7450- 7550'. CIRC 2.7 BPM, 3600 PSI. OVERPULL TWICE AT 7445'. LAST TIME UP WAS OK. RECOVERED GOOD AMOUNT OF ROUNDED 1/4 -1/2" SHALE OVER SHAKER. 13:30 - 15:15 1.75 STKOH X DPRB PROD1 POH WHILE CIRC 2.7 BPM. FOLLOW PRESS SCHEDULE. JOG UP /DWN /UP AT SURFACE. 15:15 - 15:30 0.25 STKOH X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PRESSURE UNDEPLOYMENT OF BIG TOOL BHA. 15:30 - 17:45 2.25 STKOH X DPRB PROD1 BUMP UP, RIH 1.6'. FOLLOW BIG TOOL UNDEPLOYMENT PROCEDURE, STEP BY STEP. HOLD 400 PSI WHP. 17:45 - 19:00 1.25 STKOH X DPRB PROD1 DUE TO THE COMPLEXITY OF PRESSURE DEPLOYING, WAIT FOR C /O. C/O WITH NIGHT CREW. DO TO NEW HIRES /PEOPLE IN NEW POSITIONS, PERFORM WALK AROUNDS. FINISH TAKING ON FUEL, WHILE WAITING ON MOTORMAN C/O SHAKER SCREENS. WAIT FOR SLB TO C /O. 19:00 - 19:30 0.50 STKOH X DPRB PROD1 PJSM REGARDING PRESSURE DEPLOYMENT. 19:30 - 20:00 0.50 STKOH X RREP PROD1 A SLIGHT HYDRAULIC LEAK ON THE BOP HYDRAULIC'S WAS NOTICED WHILE ROUGHNECK WAS IN POSITION TO PERFORM BOP /PRESSURE DEPLOYMENT ACTIVITY. STOP & ASSESS THE SOURCE OF THE LEAK. FUNCTION TEST BLIND RAMS & 3" SLIP RAMS. SLIGHT HYDRAULIC LEAK WAS FOUND ON THE BLIND RAM BONNET. 20:00 - 20:30 0.50 STKOH X RREP PROD1 PJSM REGARDING REMOVING & REPAIRING FAILED 0-RING ON BLIND RAM, WORKING AT HEIGHTS. FILL OUT TOOL LOG & FLAG OFF CELLAR. 20:30 - 00:00 3.50 STKOH X RREP PROD1 OPEN BOP RAM ACCESS DOOR. REMOVE BLIND RAM BONNET. REPLACE FAILED 0-RING & REPLACE OTHER 0-RINGS WITH NEW ONES. INSTALL BONNET. CLOSE BOP RAM ACCESS DOOR. 1/21/2010 00:00 - 00:45 0.75 STKOH X RREP PROD1 CONTINUE TO REPAIR BLIND RAM BONNET. FUNCTION TEST BLIND RAMS. 00:45 - 01:00 0.25 STKOH X RREP PROD1 SHELL TEST BOPE. PRESSURE TEST BOPE PER AOC-mC REGS 250PSI/3500PSI - PASS. 01:00 - 01:25 0.42 STKOH X DPRB PROD1 PJSM REGARDING PRESSURE DEPLOYING BHA. 01:25 - 03:00 1.58 STKOH X DPRB PROD1 PRESSURE DEPLOY BHA. INSPECT CTC. C/O FAILED CHECK VALVES IN UQC. 03:00 - 04:30 1.50 STKOH X DPRB PROD1 RIH FOLLOWING PRESSURE SCHEDULE, CIRC THRU BIT. 04:30 - 05:00 0.50 STKOH X DPRB PROD1 LOG DOWN FOR TIE -IN FROM 7380', 0' CORRECTION. 05:00 - 05:55 0.92 STKOH X DPRB PROD1 RIH. TAG AT 7580'. PUH, RIH NO PROBLEMS. SET DOWN AT 7685'. TRY TO GET PAST USING - NO PUMPS ALL THE WAY TO 2.5BPM AT DTF, ALSO TRYING 2' -40' /MIN. APPLY 100PSI WHP. 05:55 - 07:45 1.83 STKOH X DPRB PROD1 WIPER TO THE WINDOW. CIRC THRU THE BIT & CLEAN UP THE 7 ", MAKE 2 PASSES. FOLLOW PRESSURE SCHEDULE WHILE POH. CIRC 2.5 BPM, 2800 PSI. Printed: 3/19/2010 1:28:50 PM • BP EXPLORATION Page 9 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/21/2010 07:45 - 08:00 0.25 STKOH X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PRESSURE UNDEPLOYMENT OF BHA. 08:00 - 10:00 2.00 STKOH X DPRB PROD1 PRESSURE UNDEPLOY BHA. HOLD 500 PSI WHP, 10.4 PPG ECD. 10:00 - 12:00 2.00 STKOH X DPRB PROD1 LAY OUT RES TOOL. ADJUST MOTOR TO 3.3 DEG BEND. RE -RUN HYC BC BIT. 12:00 - 12:15 0.25 STKOH X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CLOSING SSSV AND DEPLOYING BHA. 12:15 - 13:20 1.08 STKOH X DPRB PROD1 CLOSE SSSV, BLEED OFF WHP. OPEN SWAB AND MASTER. M/U CLEANOUT BHA #10 WITH 3.3 DEG MOTOR AND HYC BC BIT #10. CIRC 0.6 BPM, HOLD 600 PSI AND OPEN SSSV. 13:20 - 15:00 1.67 STKOH X DPRB PROD1 RIH WITH CLEANOUT BHA. CIRC 0.6 BPM, FOLLOW PRESS SCHEDULE. 15:00 - 15:30 0.50 STKOH X DPRB PROD1 LOG GR TIE -IN, -24' CORRECTION. 15:30 - 18:30 3.00 STKOH X DPRB PROD1 RIH PAST WINDOW AND BILLET OK. SET DOWN BELOW SHALE AT 7691'. COULD NOT MAKE FURTHER PROGRESS WITH SPUDDING OR LOW PUMP RATE. DRILL AHEAD WITH THE ORIGINAL AS DRILLED TF. APPEAR TO HAVE SIDETRACKED AT 7691'. DRILLED WITH 2.5 BPM, 3.2K WOB, 60 R TF, 20 FPH, DRILLED TO 7721'. 18:30 - 19:00 0.50 STKOH X DPRB PROD1 SLOWLY WIPER TO THE WINDOW & PROGRAM BHI'S COMPUTERS. SLIGHT OP & MW AT 7665' & 7655'. 19:00 - 00:00 5.00 STKOH X DPRB PROD1 CONTINUE TO DRILL BUILD FROM 7721'., 2.5/2850/0 -110L HOLD 100PSI WHP W/ 150 -300 PSI DIFF, 1.5 -3.5K W/ 10.72 ECD AT 40- 115' /HR. PVT 358. DRILL TO MIDNIGHT DEPTH OF 7974'. PVT 353 1/22/2010 00:00 - 00:20 0.33 STKOH X DPRB PROD1 CONTINUE TO DRILL BUILD FROM 7974'. 2.5/2850/0 -110L HOLD 100PSI WHP W/ 150 -300 PSI DIFF, 1.5 -3.5K W/ 10.72 ECD AT 40- 50' /HR. PVT 353. DRILL TO EOB 7985'. PVT 353 00:20 - 01:15 0.92 STKOH X DPRB PROD1 WIPER TO THE WINDOW HOLDING 100- 150PSI WHP, SLIGHT OP & MW AT 7655' & 7655'. WIPER TO TD, SET DOWN AT 7680', WENT THROUGH 2ND TIME NO PROB. TAG BOTTOM AT 7984'. 01:15 - 01:35 0.33 STKOH X DPRB PROD1 WIPER TO WINDOW WHILE LAYING IN LINER PILLHOLDING 100- 125PSI WHP - CLEAN ! 01:35 - 02:20 0.75 STKOH X DPRB PROD1 RECIPROCATE FOUR IN 7" FROM 7450' TO 7560' USING 2.8BPM THRU THE BIT HOLDING 130PSI WHP. STUCK FOR 3 MIN, NO RETURNS, WORK PIPE & PUMPS, GOT FREE. CONTINUE TO RECIPROCATE IN 7" 02:20 - 02:30 0.17 STKOH X DPRB PROD1 RIH THRU WINDOW PUMPING MIN RATE WHILE HOLDING 380PSI. SET DOWN AT 7580', PUH & ORIENTATE HS. RIH TO 7595', CLEAN. 02:30 - 02:45 0.25 STKOH X DPRB PROD1 OPEN EDC & JET 7" & 4 -1/2" TUBING USING 3BPM. FOLLOW PRESSURE SCHEDULE WHILE PUH TO 7320'. 02:45 - 03:50 1.08 STKOH X DPRB PROD1 LOG DOWN FOR TIE -IN FROM 7320', PLUS 2' CORRECTION. 1/4" SIZE SHALE PIECES COMING OVER SHAKER. PUH TO 7190'. LOG CCL DOWN FOR TOL PLACEMENT TO 7500'. 03:50 - 06:00 2.17 STKOH X DPRB PROD1 POH FOLLOWING PRESSURE SCHEDULE. RECIPROCATE ACROSS TRSSSV. JOG AT SURFACE. Printed: 3/19 /2010 1:28:50 PM • • BP EXPLORATION Page 10 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/22/2010 06:00 - 06:45 0.75 STKOH X DPRB PROD1 CLOSE SSSV. BLEED DOWN AND FLOW CHECK, OK. 06:45 - 07:00 0.25 STKOH X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT DRILLING BHA. 07:00 - 07:45 0.75 STKOH X DPRB PROD1 LAY OUT COILTRAK DRILLING BHA. 07:45 - 08:00 0.25 STKOH X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR RUNNING 18 JTS OF 3- 3/16" DRILLING LINER WITH BAKER TOOLS AND COILTRAK. 08:00 - 11:15 3.25 STKOH X DPRB PROD1 BAKER LOCK BTT BULLNOSE, 10' X 2 DEG BENT PUP JT AND FIRST 6 JTS OF 3- 3/16 ", 6.2 #, TCII, L -80 LINER. M/U TOTAL OF 18 JTS, 3- 3/16" TCII DRILLING LINER AND TORO THRU DEPLOYMENT SLEEVE WITH BTT HYD PUMP OFF GS SPEAR. M/U COILTRAK TOOLS. DRILLING LINER BHA OAL = 640.03'. 11:15 - 12:50 1.58 STKOH X DPRB PROD1 PRESS UP WHP TO 700 PSI AND OPEN SSSV. SET WHP = 650 PSI. RIH WITH 3- 3/16" DRILLING LINER BHA #12. FOLLOW PRESS SCHEDULE. CIRC 0.2 BPM. 1550 PSI, 400 WHP, UP WT AT 7500' = 29K, DWN WT = 13.5K AT 7500'. 12:50 - 16:00 3.17 STKOH X DPRB PROD1 RIH CLEAN PAST WINDOW AND BILLETT, SET DOWN AT 7648', PICK UP AND RELEASED EARLY FROM LINER AT 0.2 BPM. RIH AND STACK WT AND RECONNECT TO LINER. WE HAVE IT FROM WT AND TORQUE ON ORIENTOR. WORK LINER PAST 7654', RIH AND SET DOWN AT LEDGE BELOW SHALE AT 7690'. WORK PAST. RIH CLEAN TO BOTTOM, LAND DRILLING LINER AT 7992' UNCORRECTED DEPTH. STACK 5K. PUMP 2.7 BPM, 3800 PSI AND PICK UP. STILL HAVE LINER. WORK UP /DOWN AT SEVERAL PUMP RATES. USE ORIENTOR TO PUT RIGHT AND LEFT FORCE ON LINER WHILE PICKING UP. PICK UP SEVERAL TIMES AND STILL HAVE DRILLING LINER. PICK UP 100' AND RIH TO BOTTOM, WORK PIPE SEVERAL TIMES AND STILL HAVE LINER. 16:00 - 17:35 1.58 STKOH X DPRB PROD1 POH WITH LINER TO CHECK GS SPEAR. UP WT = 32K. PULLED 44K AT 7875' LINER SHOE DEPTH AND PULLED FREE FROM LINER. LINER IS 116' OFF BOTTOM, BUT LEDGE AND SHALES AT 7691 FT ARE COVERED. T9P OF DEPLOYMENT SLEEVE IS A 7295'. POH HOLDING 600 PSI WHP. 17:35 - 17:45 0.17 STKOH X DPRB PROD1 PJSM REGARDING LD BHA. 17:45 - 19:10 1.42 STKOH X DPRB PROD1 LD LINER RUNNING BHA. TORQUE TURN DOGS (2) ARE SMEARED IN PLACE. LD BHI COIL TRAC TOOLS. RECONFIGURE NEW TOOL STRING DUE TO EDC FAILURE. 19:10 - 19:30 0.33 STKOH X DPRB PROD1 PJSM REGARDING MU FISHING BHA. 19:30 - 20:00 0.50 STKOH X DPRB PROD1 MU FISHING BHA W/ MINIMAL BHI TOOLS+JARS +GS. STAB ONTO WELL. POWER UP & TEST TOOLS. SET Printed: 3/19/2010 1:28:50 PM S BP EXPLORATION Page 11 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/22/2010 19:30 - 20:00 0.50 STKOH X DPRB PROD1 COUNTERS. PRESSURE UP WELL TO 700PSI & OPEN TRSSSV 20:00 - 21:30 1.50 STKOH X DPRB PROD1 RIH FOLLOWING PRESSURE SCHEDULE, PUMP MIN RATE TO KEEP GS DOGS CLEAR OF DEBRIS. TAG AT 7278'. 21:30 - 21:40 0.17 STKOH X DPRB PROD1 PUMP 2.4BPM, PUSH /PUMP LINER TO BOTTOM WITH MINIMAL EASE (AFTER IT GOT GOING). TOL = 7422' UNCORRECTED. 21:40 - 21:50 0.17 STKOH X DPRB PROD1 PUH TO 7150'. LOG CCL DOWN FROM 7150' DOWN TO 7408'. MINUS 18'. TOL = 7404' CORRECTED. 21:50 - 23:30 1.67 STKOH X DPRB PROD1 POH, PUMP 2.4BPM /3100PSI WHILE POH TO ENSURE HOLE IS CLEAN. JOG AT SURFACE. 23:30 - 23:40 0.17 STKOH X DPRB PROD1 PJSM REGARDING LD BHA. 23:40 - 00:00 0.33 STKOH X DPRB PROD1 TAG UP. FLOW CHECK. POP OFF WELL. BLOW DOWN TOOLS. LD BHA. 1/23/2010 00:00 - 00:15 0.25 STKOH X DPRB PROD1 CONTINUE TO LD FISHING BHA. MU SWIZZLE STICK BHA. 00:15 - 00:45 0.50 STKOH X DPRB PROD1 STAB ONTO WELL. JET STACK. POP OFF. LD SWIZZLE BHA. 00:45 - 03:30 2.75 STKOH X DPRB PROD1 BREAK OUT UQC. STAB ONTO WELL. RU NITROGEN TRUCK. COOL DOWN & PRESSURE TEST SAME. PUMP INHIBITED WATER +METHANOL COCKTAIL INTO REEL FOLLOWED BY NITROGEN. RD NITROGEN UNIT. 03:30 - 04:40 1.17 STKOH X DPRB PROD1 RD INNER REEL IRON. RD PULL BACK WINCH. RU STABBING WINCH CABLE & INTERNAL CONNECTOR. 04:40 - 04:55 0.25 STKOH X DPRB PROD1 PJSM REGARDING UNSTABBING COIL. 04:55 - 06:30 1.58 STKOH X DPRB PROD1 UNSTAB COIL FROM INJECTOR. PULL COIL ACROSS & SECURE COIL WITH SHIPPING BAR. UNPIN COIL & PREP TO LOWER TO GROUND. 06:30 - 06:45 0.25 STKOH X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LOWERING 2 -3/8" REEL AND PICKING UP 2" REEL WITH BRIDGE CRANE. 06:45 - 09:00 2.25 STKOH X DPRB PROD1 OPEN BOMBAY DOOR. POSITION TRAILER. LOWER 2 -3/8" REEL ONTO TRAILER AND SECURE IT. PICK UP 2" REEL AND SET IN REEL STAND. CLOSE BOMBAY DOOR. 09:00 - 12:30 3.50 STKOH X DPRB PROD1 M/U HARDLINE INSIDE REEL. CHANGE OUT BOP RAMS FOR 2" COIL. CHANGE OUT GRIPPER BLOCKS ON INJECTER HEAD FOR 2" COIL. GREASE CHOKE MANIFOLD AND TREE VALVES. M/U 2" GRAPPLE AND CABLE TO PULL COIL TO INJECTER HEAD 12:30 - 20:30 8.00 BOPSUF X DPRB PROD1 PRESSURE TEST BOPE PER AOGSS BEGS, 250PSI /3500PSI. AOGCC TEST WITNESS WAIVED BY INSPECTOR CHUCK SCHEVE, SEND TEST REPORT TO AOGCC. 20:30 - 21:30 1.00 BOPSUF X DPRB PROD1 BLOW DOWN STACK. REPAIR BLIND RAMS. FLOOD STACK. 12:30 - 20:30 8.00 BOPSUF X DPRB PROD1 PRESSURE TEST BLIND RAMS, 250PSI /3500PSI - PASS. 20:30 - 22:30 2.00 BOPSUF X DPRB PROD1 RD TEST JOINTS, HOSE & EQUIPMENT. BLOW DOWN STACK, KILL LINE & MPD LOOP. 22:30 - 22:40 0.17 DRILL X DPRB PROD1 PJSM REGARDING MU INJECTOR PACK OFF 22:40 - 23:00 0.33 DRILL X DPRB PROD1 RU INJECTOR PACKOFF ASSEMBLY TO INJECTOR. 23:00 - 23:15 0.25 DRILL X DPRB PROD1 PJSM REGARDING PULL COIL ACROSS & STABBING PIPE. Printed: 3/19/2010 1:28:50 PM Page 12 of 23 BP EXPLORATION P g Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/23/2010 23:15 - 00:00 0.75 DRILL X DPRB PROD1 PULL COIL ACROSS & STAB PIPE INTO INJECTOR. REMOVE GRAPPLE. CUT COIL TO FIND, TEST & PROTECT E -LINE. 1/24/2010 00:00 - 02:00 2.00 DRILL X DPRB PROD1 FILL COIL WITH 5BBLS OF METH FOLLOWED BY WATER. 02:00 - 02:35 0.58 BOPSUF X DPRB PROD1 TEST INNER REEL & PACK OFF PER AOGCC REGS, 250PSI /3500PSI - PASS. BLOW 3 BBLS BACK WITH RIG AIR. 02:35 - 02:50 0.25 DRILL X DPRB PROD1 PJSM REGARDING CUTTING COIL. 02:50 - 05:00 2.17 DRILL X DPRB PROD1 RU COIL CUTTER. CUT 320' OF COIL. TEST WIRE. INSTALL SLB DIMPLE CTC. PULL TEST 35K. HEAD UP BHI UQC. 05:00 - 05:30 0.50 DRILL X DPRB PROD1 PRESSURE TEST CTC & UQC TO 4000PSI. 05:30 - 06:15 0.75 DRILL X DPRB PROD1 M/U 2.74" MILLING BHA WITH 2.74" HCC PARABOLIC MILL, STRAIGHT MOTOR AND COILTRAK. BHA OAL = 41.78'. 06:15 - 08:45 2.50 DRILL X DPRB PROD1 RIH W/ MILLING BHA. CIRC 0.4 BPM, 1300 PSI. SET DOWN AT 7560, 7590, 7745', CHASING SOMETHING. .TAG PBTD AT 8013'. UNCORRECTED. 08:45 - 10:45 2.00 DRILL X DPRB PROD1 MILL AL BULLNOSE GUIDE SHOE. 1.7 BPM, 3000 -3200 PSI, 700 WOB, TIME MILL 1 FPH FOR 30 MIN. NO STALLS. MILL FORMATION FOR 5 FT AT 6 FPH. MILLED TO 8018' UNCORRECTED. SWAP TO NEW GEOVIS. ECD = 10.0 OLD MUD, ECD = 9.8 WITH NEW MUD. REAM UP /DWN TWICE, CLEAN SHOE AREA. MILLED TO 7990' CORRECTED DEPTH. 10:45 - 12:30 1.75 DRILL X DPRB PROD1 POH WHILE CIRC 1.7 BPM. 12:30 - 12:45 0.25 DRILL X DPRB PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CHANGING BHA. 12:45 - 14:00 1.25 DRILL X DPRB PROD1 ADJUST MOTOR TO 1.0 DEG BEND, M/U HYC RE -RUN SRRE BC BIT #11, M/U COILTRAK WITH RES TOOL. BHA OAL = 71.97' 14:00 - 15:30 1.50 DRILL X DPRB PROD1 RIH WITH LATERAL / RES BHA #15. CIRC MIN RATE. 15:30 - 15:50 0.33 DRILL X DPRB PROD1 LOG GR TIE -IN AT RA TAG, -26' CORRECTION. 15:50 - 16:10 0.33 DRILL X DPRB PROD1 RIH TO BOTTOM, TAG BOTTOM AT 7989' 16:10 - 17:30 1.33 DRILL X DPRB PROD1 DRILL LATERAL, 1.7 BPM, 3300 -3700 PSI, 10.7 ECD, 1 -2K WOB, 80 -140 FPH, DRILLED TO 8150'. 17:30 - 17:50 0.33 DRILL X DPRB PROD1 WIPER TRIP TO SHOE. CLEAN TRIP. 17:50 - 19:10 1.33 DRILL X DPRB PROD1 DRILL LATERAL, 1.7 BPM, 3300 -3700 PSI, 10.7 ECD, 2K WOB, 140 FPH, 93 DEG INCL. DRILL TO 8300'. 19:10 - 19:35 0.42 DRILL X DPRB PROD1 WIPER TO SHOE & TO TD - CLEAN BOTH WAYS. 19:35 - 21:30 1.92 DRILL C PROD1 DRILL LATERAL SECTION FROM 8300' 1.67/3260/80L -110L W/ 150 -300 PSI DIFF, 2.2 -3.K W/ 10.83 ECD AT 60- 100' /HR. HOLDING 300PSI WHP. PVT 385. DRILL TO 8450' . PVT 392 21:30 - 22:35 1.08 DRILL C PROD1 WIPER TO SHOE - CLEAN. OPEN EDC & JET TO 7000'. USING 2.5BPM /3800PSI. 22:35 - 22:45 0.17 DRILL C PROD1 LOG DOWN FOR TIE -IN FROM 7590' (PLUS 2.5' CORRECTION). 22:45 - 23:10 0.42 DRILL C PROD1 WIPER TO 7990'. CLOSE EDC. WIPER TO TD. 23:10 - 23:50 0.67 DRILL C PROD1 DRILL LATERAL SECTION FROM 8450' 1.60/3200/80L -110L Printed: 3/19 /2010 1:28:50 PM • BP EXPLORATION Page 13 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/24/2010 23:10 - 23:50 0.67 DRILL C PROD1 W/ 150 -300 PSI DIFF, 1.75 -2.3K W/ 10.80 ECD AT 60- 100' /HR. HOLDING 300PSI WHP. PVT 376. DRILL TO 8500'. 23:50 - 00:00 0.17 DRILL P PROD1 BACK ON PLANNED TIME. CONTINUE TO DRILL LATERAL SECTION FROM 8500' 1.60/3200/80L -110L W/ 150 -300 PSI DIFF, 1.75 -2.3K W/ 10.68 ECD AT 60- 100' /HR. HOLDING 200PSI WHP. PVT 370. DRILL TO MIDNIGHT DEPTH OF 8520' . PVT 370 1/25/2010 00:00 - 00:15 0.25 DRILL P PROD1 DRILL LATERAL SECTION FROM 8520' 1.60/3130/180 -135R W/ 150 -300 PSI DIFF, 1.5-2.1K W/ 10.68 ECD AT 60- 100' /HR. HOLDING 200PSI WHP. PVT 370. DRILL TO 8531' . PVT 370 00:15 - 00:35 0.33 DRILL P PROD1 GEO WIPER - CLEAN. 00:35 - 01:15 0.67 DRILL P PROD1 DRILL LATERAL SECTION FROM 8531' 1.60/3180/30L -35R W/ 150 -300 PSI DIFF, 1.5-2.1K W/ 10.8 ECD AT 60- 100' /HR. HOLDING 250PSI WHP. PVT 369. DRILL TO 8600' . PVT 368 01:15 - 01:50 0.58 DRILL P PROD1 WIPER TO THE SHOE & TO TD - CLEAN. 01:50 - 03:40 1.83 DRILL P PROD1 DRILL LATERAL SECTION FROM 8600' 1.60/3180/90L -180L W/ 150 -300 PSI DIFF, 1.5-2.1K W/ 10.8 ECD AT 60- 100' /HR. HOLDING 250PSI WHP. PVT 367. DRILL TO 8750' . PVT 369 03:40 - 04:25 0.75 DRILL P PROD1 WIPER TO THE SHOE & TO TD - CLEAN. 04:25 - 04:40 0.25 DRILL P PROD1 DRILL LATERAL SECTION FROM 8750' 1.60/3160/30L -30R W/ 150 -300 PSI DIFF, 1.75 -2.2K W/ 10.87 ECD AT 60- 110' /HR. HOLDING 250PSI WHP. PVT 367. DRILL TO 8774' . PVT 366 04:40 - 04:55 0.25 DRILL N SFAL PROD1 PUH & REBOOT SLB & BHI COMPUTERS. 04:55 - 06:30 1.58 DRILL P PROD1 DRILL LATERAL SECTION FROM 8774' 1.60/3160/30L -30R W/ 150 -300 PSI DIFF, 1.75 -2.2K W/ 10.92 ECD AT 60- 150' /HR. HOLDING 250PSI WHP. PVT 366. DRILLED TO 8867'. 06:30 - 07:00 0.50 DRILL P PROD1 DRILL LATERAL, 1.6 BPM, 3200 -3700 PSI, 80R TF, 10.7 ECD, 200 PSI WHP, 90 FPH, 93 INCL, DRILLED TO 8900'. 07:00 - 07:45 0.75 DRILL P PROD1 WIPER TRIP UP TO RA TAG. CLEAN HOLE. 07:45 - 08:00 0.25 DRILL P PROD1 LOG GR TIE -IN AT RA TAG. ADD 8' TO CTD. 08:00 - 08:45 0.75 DRILL P PROD1 RIH CLEAN TO BOTTOM. 08:45 - 10:50 2.08 DRILL P PROD1 DRILL LATERAL, 1.6 BPM, 3200 -3700 PSI, 90L TF, 10.7 ECD, 200 PSI WHP, 2K WOB, 90 FPH, 93 INCL, DRILLED TO 9050'. 10:50 - 11:45 0.92 DRILL P PROD1 WIPER TRIP TO SHOE. CLEAN TRIP. RIH CLEAN TO BOTTOM. 11:45 - 13:30 1.75 DRILL P PROD1 DRILL LATERAL, 1.6 BPM, 3300 -3700 PSI, 100L TF, 10.7 ECD, 200 PSI WHP, 2K WOB, 90 FPH, 93 INCL, DRILLED TO 9200'. 13:30 - 14:45 1.25 DRILL P PROD1 WIPER TRIP TO SHOE. CLEAN TRIP. RIH CLEAN TO BOTTOM. 14:45 - 16:00 1.25 DRILL P PROD1 DRILL A3 LATERAL, 1.6 BPM, 3300 -3700 PSI, 110R TF, 10.7 ECD, 200 PSI WHP, 2K WOB, 90 FPH, 95 INCL, STACKING -5K COIL WT TO GET WOB. DRILLED TO 9300'. 16:00 - 16:30 0.50 DRILL P PROD1 DRILL A3 LATERAL, 1.6 BPM, 3300 -3700 PSI, 120R TF, 10.7 ECD, 200 PSI WHP, 2K WOB, 90 FPH, 94 INCL, STACKING -6K COIL WT TO GET WOB. DRILLED TO 9321'. 16:30 - 18:10 1.67 DRILL P PROD1 WIPER TRIP UP TO RA TAG. CLEAN HOLE. Printed: 3/19/2010 1:28:50 PM • S BP EXPLORATION Page 14 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/25/2010 18:10 - 20:20 2.17 DRILL P PROD1 DRILL A3 LATERAL, 1.6 BPM, 3100 -3700 PSI, 90 -120R TF, 10.9 ECD, 200 PSI WHP, 0.5 -2K WOB, 40 -150 FPH, 93 INCL, STACKING -6K COIL WT TO GET WOB & NUMEROUS BHA WIPER TRIPS. DRILLED TO TD AT 9440'. PVT 352 20:20 - 21:45 1.42 DRILL P PROD1 WIPER TO THE SHOE. OPEN EDC & JET TO 7300' & BACK DOWN TO 7550'. 21:45 - 21:50 0.08 DRILL P PROD1 LOG DOWN FOR TIE -IN FROM 7590'. PLUS 7'. 21:50 - 22:00 0.17 DRILL P PROD1 RIH TO THE SHOE. CLOSE EDC. 22:00 - 22:30 0.50 DRILL P PROD1 WIPER TO TD. SLIGHT SET DOWN AT 9120' & 9170'. TAG TD AT 9444'. 22:30 - 23:30 1.00 DRILL P PROD1 WIPER TO SHOE, LAY IN LINER PILL - CLEAN. OPEN EDC. 23:30 - 00:00 0.50 DRILL P PROD1 POH FOLLOWING PRESSURE SCHEDULE JETTING 3- 3/16" LINER, 4 -1/2" TUBING & JEWELRY. 1/26/2010 00:00 - 01:15 1.25 DRILL P PROD1 CONTINUE TO POH FOLLOWING PRESSURE SCHEDULE. PJSM REGARDING LD BHA WHILE POH. 01:15 - 02:20 1.08 DRILL P PROD1 TAG UP. TRAP 700PSI WHP. CLOSE TRSSSV. BLEED OFF WHP & FLOW CHECK. POP OFF. LD 5' LUBRICATOR. BLOW DOWN & LD BHI COIL TRACK TOOLS. 02:20 - 02:30 0.17 DRILL P PROD1 P.1SM REGARDING MU LINER. 02:30 - 04:30 2.00 CASE P RUNPRD MU LINER PER PROGRAM, AL BILLET +10' PUP JT +39 JTS OF 2 -3/8" SLOTTED +GUIDE SHOE. DOG COLLAR EACH JT. MU COIL TRACK TOOLS, KNUCKLE JT, GS. STAB ONTO WELL. POWER UP & TEST TOOLS. SET COUNTERS. PUMP DOWN KILL LINE TO PRESSURE UP WELL. OPEN TRSSSV, 440PSI WHP. 04:30 - 06:05 1.58 CASE P RUNPRD RIH FOLLOWING PRESSURE SCHEDULE. WT CK @ 7375' (TOL) = 24K, RIW = 11K. WT CK @ 7900' (SHOE) = 25.5K, RIW = 12K. 06:05 - 06:35 0.50 CASE P RUNPRD LOG DOWN FOR TIE -IN FROM 8585' (GR DEPTH = 7330'), MINUS 24' CORRECTION. 06:35 - 06:50 0.25 CASE P RUNPRD CONTINUE TO RIH. WT CK AT 9435' = 26.6K, RIW = 8K. T. TD AT 9442'. LANDED SLOTTED LINER AT TD. PUMP 1.9BPM /4400PSI. PUH, 22K. LEFT LINER AT TD. TOP OF BII LET AT 8192'. 06:50 - 08:00 1.17 CASE P RUNPRD POH FOLLOWING PRESSURE SCHEDULE. 08:00 - 08:20 0.33 DRILL P PROD2 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CHANGING TO LATERAL / RES DRILLING BHA. 08:20 - 13:15 4.92 DRILL P PROD2 LAY OUT BAKER GS PUMP OFF SPEAR. M/U COILTRAK / RES LATERAL BHA WITH HYC SRRE BC BIT #12 AND 1.1 DEG EXTREME MOTOR. BHA OAL = 71.97' 13:15 - 14:40 1.42 DRILL P PROD2 RIH WITH LAT / RES DRILLING BHA #17. CIRC 0.3 14:40 - 14:50 0.17 DRILL P PROD2 LOG GR TIE -IN AT RA TAG, -26' CORRECTION. 14:50 - 15:10 0.33 DRILL P PROD2 RIH AND TAG BILLET AT 8188'. PICK UP 20' AND TROUGH HOLE AT 180 DROHS. 15:10 - 16:20 1.17 DRILL P PROD2 TROUGH DOWN AT 40 FPH WITH 180 DROHS TF, TWICE. 1 6 RPM 3170 PSI 16:20 - 18:30 2.17 DRILL P PROD2 DRII L OF OF RII I FT WITH 180 DROHS TF, FIRST 3� STALLS AT 8187'. SWAP TO NEW GEOVIS, DRILL 1 FPH AT 8187'. 1.6 BPM, 3160 PSI, 0 WOB, Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 15 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/26/2010 16:20 - 18:30 2.17 DRILL P PROD2 DRILLED TO 8188'. 18:30 - 18:50 0.33 DRILL P PROD2 DRILL LOWSIDE OFF OF BILLET. 4 STALLS TOTAL GETTING STARTED DRILL 2 FPH, 700# WOB, 18:50 - 20:55 2.08 DRILL P PROD2 BEGIN DRILLING AHEAD. UP WEIGHT 20K LB. RIH WEIGHT 11,200 LB. FREESPIN 3250 PSI AT 1.68 BPM W/ 300 PSI BACKPRESSURE. DRILL AHEAD W/ 250 - 370 PSI MOTOR WORK AND 2500 - 3500 LB WOB W/ AVEREAGE ROP OF -80 FPM. ECD = 10.8 PPG. AVERAGE INCLINATION OF 93 DEGREES. DRILL AHEAD TO 8350' MD. 20:55 - 22:10 1.25 DRILL P PROD2 WIPER TO SHOE AT 7985' MD. CLEAN BOTH DIRECTIONS. 22:10 - 00:00 1.83 DRILL P PROD2 RESUME DRILLING AHEAD. UP WEIGHT 20,500 LB. RIH WEIGHT 11,000 LB. FREESPIN 3250 PSI AT 1.69 BPM W/ 300 PSI BACKPRESSURE. DRILL AHEAD W/ 300 - 500 PSI MOTOR WORK AND 2500 - 4000 LB WOB (STACKING 5K LB ON SURFACE TO ACHIEVE 3K LB WOB). AVERAGE ROP OF 85 FPH. ECD = 10.85 PPG. INCLINATION -90 DEGREES. DRILLING AHEAD AT 8485' MD. IAP = 270 PSI OAP = 310 PSI CONTINUED ON DIMS REPORT 01/27/10. 1/27/2010 00:00 - 00:20 0.33 DRILL P PROD2 CONTINUED FROM DIMS REPORT 01/26/10. IAP = 270 PSI OAP = 310 PSI. CONTINUE DRILL AHEAD FROM 8485' MD. UP WEIGHT 20,500 LB. RIH WEIGHT 11,000 LB. FREESPIN 3250 PSI AT 1.69 BPM W/ 300 PSI BACKPRESSURE. DRILL AHEAD W/ 300 - 500 PSI MOTOR WORK AND 2500 - 4000 LB WOB (STACKING 5K LB ON SURFACE TO ACHIEVE 3K LB WOB). AVERAGE ROP OF 85 FPH. ECD = 10.85 PPG. INCLINATION -90 DEGREES. DRILL AHEAD TO 8500 MD. 00:20 - 01:00 0.67 DRILL P PROD2 WIPER TO SHOE AT 7985' MD FROM 8500' MD. CLEAN BOTH DIRECTIONS. 01:00 - 02:20 1.33 DRILL P PROD2 RESUME DRILLING AHEAD. UP WEIGHT 21000 LB. RIH WEIGHT 10500 LB. FREESPIN 3380 PSI AT 1.61 BPM W/ 320 PSI BACKPRESSURE. DRILL AHEAD WITH 250 - 480 PSI MOTOR WORK AND 2000 - 4000 LB WOB W/ AVERAGE ROP OF 105 FPH AND AVERAGE INCLINATION OF 90 DEGREES. ECD = 10.85 PPG. DRILL AHEAD TO 8650' 02:20 - 04:00 1.67 DRILL P PROD2 WIPER TO 7000' MD FROM 8650' MD (OPENING EDC AT 7990' MD). CLEAN IN UP DIRECTION. AT 03:30 HOURS, CIRCULATING WHILE RBIH AT 7900' W/ OPEN EDC CIRCULATING AT 2.28 BPM AT 3680 PSI W/ 256 PSI BACKPRESSURE W/ 10.7 PPG (AT TOOL). CLOSE EDC AT 7990' AND RBIH TO RESUME DRILLING AHEAD. TIE -IN, CORRECTION OF ( +4') AT 03:50 HOURS, WHILE RBIH AT 1.6 BPM AT 3300 PSI FREESPIN W/ 300 PSI BACKPRESSURE, SEE 10K LB WEIGHT BOBBLE AND 150 PSI MOMENTARY MOTOR WORK WHILE RIH PAST 8330' MD. WORK THROUGH WITH THIS SAME RESPONSE (TWO MORE WEIGHT Printed: 3/19/2010 1:28:50 PM • BP EXPLORATION Page 16 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/27/2010 02:20 - 04:00 1.67 DRILL P PROD2 BOBBLES) TO 8400' MD. NOTE: TOOLFACE CHANGE HERE IS FROM 100 DEG LOHS TO 140 DEG LOHS. GEO BELIEVES THAT THIS IS THE A3 SHALE THAT WE ARE ENCOUNTERING AT THIS DEPTH. 04:00 - 06:00 2.00 DRILL P PROD2 RESUME DRILLING AHEAD. ENGAGE AT 8652' MD. UP WEIGHT 21000 LB. RIH WEIGHT 10300 LB. FREESPIN 1.58 BPM AT 3250 PSI W/ 300 PSI BACKPRESSURE (ECD OF 10.87 PPG). DRILL AHEAD WITH 1700 - 3000 LB WOB W/ 250 - 350 PSI MOTOR WORK, STACKING 3500 LB WEIGHT AT SURFACE TO ACHIEVE -2000 LB WOB. INCLINATION -92 DEGREES. DRILL AHEAD TO 8800' MD. 06:00 - 06:45 0.75 DRILL P PROD2 WIPER TO SHOE AT 7985' MD FROM 8800' MD. CLEAN TRIP. 06:45 - 08:15 1.50 DRILL P PROD2 DRILL A3 LATERAL, 1.6 BPM, 3300 -3700 PSI, 2K WOB, 30 -90 FPH, 10.8 ECD, 93 DEG INCL, DRILLED TO 8890'. 08:15 - 09:00 0.75 DRILL P PROD2 DRILL A3 LATERAL, 1.6 BPM, 3300 -3700 PSI, 2K WOB, 100 FPH, 10.8 ECD, 94 DEG INCL, DRILLED TO 8950'. 09:00 - 10:00 1.00 DRILL P PROD2 WIPER TO SHOE. CLEAN TRIP. 10:00 - 11:30 1.50 DRILL P PROD2 DRILL A3 LATERAL, 1.6 BPM, 3300 -3800 PSI, 2K WOB, 120 FPH, 10.8 ECD, 93 DEG INCL, DRILLED TO 9100'. 11:30 - 12:00 0.50 DRILL P PROD2 WIPER TRIP UP TO WINDOW. CLEAN HOLE. 12:00 - 12:20 0.33 DRILL P PROD2 LOG GR TIE -IN, ADD 3' CTD. 12:20 - 13:00 0.67 DRILL P PROD2 RIH CLEAN TO BOTTOM. 13:00 - 14:50 1.83 DRILL P PROD2 DRILL A3 LATERAL, 1.6 BPM, 3350 -3800 PSI, 2K WOB, 120 FPH, 10.8 ECD, 93 DEG INCL, STACKING FULL WT. -6K COIL WT. DRILLED TO 9241'. 14:50 - 16:00 1.17 DRILL P PROD2 WIPER TRIP TO SHOE. CLEAN HOLE. RIH CLEAN TO BOTTOM. 16:00 - 17:10 1.17 DRILL P PROD2 DRILL A2 LATERAL, 1.6 BPM, 3400 -3900 PSI, 2K WOB, 100 FPH, 10.8 ECD, 86 DEG INCL, STACKING FULL WT. DRILLED TO 9308'. 17:10 - 17:20 0.17 DRILL P PROD2 200 FT WIPER TO HELP COIL SLIDE. 17:20 - 17:50 0.50 DRILL P PROD2 DRILL A2 LATERAL, 1.6 BPM, 3400 -3900 PSI, 2K WOB, 100 FPH, 10.8 ECD, 91 DEG INCL, DRILLED TO 9356'. 17:50 - 18:00 0.17 DRILL P PROD2 350' WIPER TO HELP COIL SLIDE. 18:00 - 19:00 1.00 DRILL P PROD2 DRILL A2 LATERAL, FREESPIN 1.5 BPM AT 3270 PSI W/ 280 PSI BACKPRESSURE (ECD = 10.86 PPG). DRILL AHEAD W/ 2000 LB WOB W/ 250 - 400 PSI MOTOR WORK AT -80 FPH AT -93 DEGREES INCLINATION. DRILLED TO 9385'. 19:00 - 20:10 1.17 DRILL P PROD2 WIPER TRIP TO SHOE. CLEAN BOTH DIRECTIONS. 20:10 - 20:50 0.67 DRILL P PROD2 RESUME DRILLING AHEAD. UP WEIGHT 21000 LB. RIH WEIGHT 8000 LB. FREESPIN 1.5 BPM AT 3300 PSI W/ 280 PSI BACKPRESSURE (10.86 PPG ECD). ENGAGE AT 9384' MD. DRILL AHEAD W/ 250 - 300 PSI MOTOR WORK W/ 1500 - 2000 LB WOB (STACKING TO -7000 LB WEIGHT AT SURFACE TO ACHIEVE 2000 LB WOB). DRILL AHEAD WITH AVERAGE ROP OF 70 FPH. DRILL AHEAD TO 9417' MD. Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 17 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/27/2010 20:50 - 21:15 0.42 DRILL P PROD2 300' WIIPER, CLEAN BOTH DIRECTIONS. 21:15 - 23:30 2.25 DRILL P PROD2 RESUME DRILLING AHEAD. UP WEIGHT 20500 LB. RIH WEIGHT 6000 LB. FREESPIN 1.5 BPM AT 3300 PSI W/ 280 PSI BACKPRESSURE (10.86 PPG ECD). DRILL AHEAD WITH 250 PSI MOTOR WORK AND 1500 LB WOB (STACKING TO -8000 LB WEIGHT AT SURFACE TO ACHIEVE 1500 LB WOB). CONSISTENTLY BECOMING MORE DIFFICULT TO APPLY WOB. MAKING MORE FREQUENT SHORT ( -300') WIPER TRIPS. 22:30 HOURS: DRILLED AHEAD TO 9447', PERFORM 300' WIPER. 23:10 HOURS: DRILLED AHEAD TO 9461' MD, PERFORM 300' WIPER. 23:30 - 00:00 0.50 DRILL P PROD2 ATTEMPT TO DRILL AHEAD FROM 9461' MD. UNABLE TO ACHIEVE WOB. PERFORM WIPER TO 7900' MD. CLEAN PASS UP. IAP = 320 PSI. OAP = 320 PSI. CONTINUED ON DIMS REPORT 01/28/10. 1/28/2010 00:00 - 00:45 0.75 DRILL P PROD2 CONTINUED FROM DIMS REPORT DATED 01/27/10. IAP = 320 PSI. OAP = 320 PSI. CONTINUE WIPER TO 7900'. WIPER CLEAN BOTH DIRECTIONS. 00:45 - 01:30 0.75 DRILL P PROD2 RESUME DRILLING AHEAD FROM 9461' MD. UP WEIGHT 20200 LB. RIH WEIGHT 6000 LB. FREESPIN 3280 PSI AT 1.5 BPM W/ 280 PSI BACKPRESSURE (10.86 PPG ECD). DRILL AHEAD WITH 1800 LB WOB AND -250 PSI MOTORWORK. DRILL AHEAD TO 9482' MD. UNABLE TO MAINTAIN WOB. 01:30 - 01:50 0.33 DRILL P PROD2 200' WIPER, CLEAN BOTH DIRECTIONS. 01:50 - 02:00 0.17 DRILL P PROD2 RESUME DRILLING AHEAD FROM 9482' MD. UP WEIGHT 20000 LB. RIH WEIGHT 7200 LB. FREESPIN 1.5 BPM AT 3285 PSI W/ 270 PSI BACKPRESSURE (ECD 10.8 PPG). ACHIEVE -1500 LB WOB, BUT IT RAPIDLY WORKS OFF. UNABLE TO MAINTAIN WOB. DRILL AHEAD TO 9486'. 02:00 - 02:40 0.67 DRILL P PROD2 300' WIPER, CLEAN BOTH DIRECTIONS. INCREASE CIRC RATE TO 1.7 BPM (FREESPIN 3700 PSI W/ 240 PSI BACKPRESSURE). TAG BOTTOM, DRILL AHEAD FROM 9486' MD WITH 250 PSI MOTOR WORK AND 2000 LB WOB (STACKED TO -7000 LBS AT SURFACE TO ACHIEVE THIS WOB). ECD IS 10.86 PPG. DIFFICULT TO MAINTAIN WOB. DRILL AHEAD TO 9500' MD - CALL TD. 02:40 - 04:40 2.00 DRILL P PROD2 WIPER TO WINDOW (CLEAN). TIE -IN AT RA TAG, CORRECTION OF ( +7.5'). R4H TO TAG TD. TAG TD AT 9501' MD. 04:40 - 07:15 2.58 DRILL P PROD2 POOH CIRCULATING. OPEN EDC ABOVE 3- 3/16" SHOE AND CIRC AT MAX RATE AS POOH, ADJUSTING BACKPRESSURE TO MAINTAIN -10.8 PPG ECD. 05:50 - AT 7000' MD CIRCULATING AT 2.2 BPM AT 3970 PSI W/ 388 PSI BACKPRESSURE. 07:15 AT SURFACE. HOLD 650 PSI WHP AND CLOSE Printed: 3/19/2010 1:28:50 PM • BP EXPLORATION Page 18 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/28/2010 04:40 - 07:15 2.58 DRILL P PROD2 SSSV. 07:15 - 07:30 0.25 DRILL P PROD2 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT THE DRILLING BHA. 07:30 - 08:30 1.00 DRILL P PROD2 LAY OUT COILTRAK /RES LATERAL DRILLING BHA #17. 08:30 - 08:45 0.25 CASE P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR M/U 44 JTS, 2 -3/8" SLOTTED LINER AND RUNNING TOOLS. 08:45 - 11:00 2.25 CASE P RUNPRD M/U INDEXING GUIDE SHOE, 44 JTS, 2 -3/8 ", 4.41 #, L -80, STL, SLOTTED LINER WITH BAKER 2.70" AL BILLETT WITH GS PROFILE. BHA OAL = 1445.7. LINER OAL = 1401.05'. 11:00 - 12:20 1.33 CASE P RUNPRD OPEN SSSV WITH 750 WHP. RIH WITH 2 -3/8" SLOTTED LINER, BHA #18. CIRC 0.1 BPM, 700 PSI, UP WT AT 7400' = 24K. DWN WT = 11.5K. UP WT AT 8000' =26K, DWN WT =11K. 12:20 - 12:50 0.50 CASE P RUNPRD RIH IN OPEN HOLE AT 55 FPM, 0.1 BPM, 1700 PSI 9K DWN WT AT 9000'. RIH CLEAN TO TD. LAND 2 -3/8" SLOTTED LINER AT 9515' UNCORRECTED. 26.5K UP WT. RIH LAND AGAIN AT 9515'. STACK 10K ON LINER. CIRC 1.5 BPM, 4000 PSI, PICK UP FREE AT 21K. LINER IS LANDED AT 9501' WITH TOP OF LINER AT 8100', 12:50 - 14:00 1.17 CASE P RUNPRD POH WITH LINER RUNNING TOOLS. CIRC 1.0 BPM, 2700 PSI. HOLD 650 WHP AND CLOSE SSSV. 14:00 - 14:15 0.25 CASE P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR L/O BHA AND M/U LATERAL / REST COILTRAK DRILLING BHA. 14:15 - 14:45 0.50 CASE P RUNPRD LAY OUT LINER RUNNING TOOLS. 14:45 - 16:00 1.25 DRILL P PROD3 M/U COILTRAK LATERAL / RES DRILLING BHA #19 WITH HYC RE BC BIT #13 AND 1.1 DEG MOTOR. BHA OAL = 71.74'. 16:00 - 17:40 1.67 DRILL P PROD3 PRESS WHP TO 700 PSI AND OPEN SSV. RIH WITH LATER DRILLING BHA #19. ALZ FOLLOW PRESSURE SCHEDULE. CIRC 0.2 BPM, 17:40 - 18:30 0.83 DRILL P PROD3 LOG GR TIE -IN AT RA TAG, CORRECTION OF ( -19'). 18:30 - 19:15 0.75 DRILL P PROD3 TAG AT 8097.5' MD. TROUGH DOWN TWO TIMES WITH 180 DEG TF FROM 8080' MD TO 8096' MD. 19:15 - 23:00 3.75 DRILL P PROD3 TIME DRILL INTO BILLET AT 1 FPH. ENGAGE WITHOUT STALLING. TIME DRILL THROUGH BILLET AT 1 FPH FOR 1', 2 FPH FOR 2' AND THEN RAMP UP TO 4 FPH. EXPERIENCE SOME SLIP /STICK EFFECT, CAUSING THREE TOTAL STALLS WHILE TIME DRILLING THROUGH BILLET. ONCE THROUGH BILLET, INCREASE ROP TO 5 FPH. 23:00 - 23:30 0.50 DRILL P PROD3 DRILL AHEAD TO 8130' AT 5 FPH (FREESPIN 1.57 BPM AT 3440 PSI WITH 330 PSI BACKPRESSURE, ECD: 10.87 PPG). DRILLING AHEAD WITH MINIMAL MOTOR WORK/WOB. Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 19 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/28/2010 23:30 - 23:50 0.33 DRILL P PROD3 BACKREAM 8103' MD TO 8080' MD AT 1 FPM. NO MOTOR WORK OBSERVED WHILE BACKREAMING. RBIH THROUGH BILLET WHILE PUMPING AT MINIMUM RATE, OBSERVED NO WEIGHT BOBBLES WHEN PASSING THROUGH BILLET AREA. RBIH TO DRILL AHEAD. 23:50 - 00:00 0.17 DRILL P PROD3 DRILL AHEAD FROM 8130' MD. FREESPIN 1.6 BPM AT 3600 PSI W/ 300 LB BACKPRESSURE, ECD =10.9 PPG. PVT 300 BBLS. DRILL AHEAD WITH 250 -350 PSI MOTOR WORK W/ 2000 -3000 LB WOB WITH AVERAGE ROP OF 40 FPH. IAP = 10 PSI OAP = 150 PSI CONTINUED ON DIMS REPORT 01/29/10. 1/29/2010 00:00 - 01:00 1.00 DRILL P PROD3 CONTINUED FROM DIMS REPORT 01/28/10. IAP = 10 PSI. OAP = 150 PSI. DRILL AHEAD. FREESPIN 1.6 BPM AT 3650 PSI W/ 300 LB BACKPRESSURE, ECD =10.9 PPG. PVT 300 BBLS. DRILL AHEAD WITH 250 -350 PSI MOTOR WORK W/ 2000 -3000 LB WOB WITH AVERAGE ROP OF 40 FPH. 01:00 - 01:30 0.50 DRILL P PROD3 BEGIN MUD SWAP. SWAP TO FRESH GEOVIS DOWN CT. IMMEDIATELY PRIOR TO SWAPPING TO NEW MUD, DRILING PARAMETERS AS FOLLOWS: FREESPIN 1.61 BPM AT 3740 PSI W/ 320 PSI BACKPRESSURE (ECD 10.9 PPG). UP WEIGHT 20000 LB, RIH WEIGHT 9700 LB. DRILLING AHEAD WITH 300 PSI MOTOR WORK AND 2000 (AVERAGE) LB WOB. WOB IS INCONSISTENT; EXPERIENCING SLIP /STICK EFFECT ON BOTTOM. 01:30 - 02:10 0.67 DRILL P PROD3 NEW MUD AT BIT WHILE ON BOTTOM DRILLING AHEAD. DRILLING AHEAD AT 8190' MD AT 1.60 BPM AT -3980 PSI CIRC PRESSURE ( -240 PSI OVER PREVIOUS FREESPIN) W/ 320 PSI BACKPRESSURE AND 1500 LB WOB. INCLINATION OF 85 DEG. AVERAGE ROP OF 45 FPH. 02:10 - 04:45 2.58 DRILL P PROD3 STALL THREE TIMES AT 8220' MD. PU OFF BOTTOM. NEW MUD IS 30 BBL FROM SURFACE, UP WEIGHT 20000 LB. RIH WEIGHT 10000 LB. FREESPIN 3560 PSI AT 1.6 BPM W/ 330 PSI WHP (ECD = 10.78 PPG). RBIH AND RESUME DRILLING AHEAD FROM 8220' MD W/ 2000 - 3000 LB WOB (STACKING TO 6500 LB SURFACE WEIGHT TO ACHIEVE THIS WOB) AND 250 - 350 PSI MOTOR WORK. DRILLING AT 85 DEGREES INCLINATION. DRILL AHEAD TO 8300' MD. AFTER WORKING THROUGH HARD SPOT AT 8220' MD, AVERAGE ROP OF 40 FPM. 04:45 - 05:20 0.58 DRILL P PROD3 WIPER TO 7995', CLEAN BOTH DIRECTIONS, CLEAN AT BILLET. RBIH TO RESUME DRILLING. 05:20 - 07:30 2.17 DRILL P PROD3 UP WEIGHT 20300 LB. FREESPIN 1.6 BPM AT 3530 PSI W/ 330 PSI BACKPRESSURE (ECD = 10.81 PPG). BEGIN DRILLING AHEAD W/ 2000 -3000 LB WOB AND 150 - 300 PSI MOTOR WORK W/ AVERAGE ROP OF 40 FPH. DRILLED TO 8450'. 07:30 - 08:30 1.00 DRILL P PROD3 WIPER TO SHOE, CLEAN HOLE. RIH CLEAN TO BOTTOM. 08:30 - 10:45 2.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3550 -4100 PSI, 2 -3K WOB, 90L TF, 50 -60 FPH, 85 DEG INCL, Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 20 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2010 08:30 - 10:45 2.25 DRILL P PROD3 DRILLED TO 8600'. 10:45 - 11:15 0.50 DRILL P PROD3 WIPER TRIP UP TO RA TAG AT 7590'. CLEAN HOLE. 11:15 - 11:30 0.25 DRILL P PROD3 LOG GR TIE -IN AT RA TAG. 11:30 - 11:50 0.33 DRILL P PROD3 RIH, STACKED WT AT 8420'. RIH CLEAN TO BOTTOM. 11:50 - 13:45 1.92 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3450 -4100 PSI, 2 -3K WOB, 40L TF, 60 FPH, 94 DEG INCL, DRILLED TO 8700' 13:45 - 15:00 1.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3450 -4100 PSI, 2 -3K WOB, 90R TF, 40 -50 FPH, 94 DEG INCL, DRILLED TO 8750'. 15:00 - 16:40 1.67 DRILL P PROD3 WIPER TRIP TO SHOE. REAM SHALES AT 8400 - 8480'. THE REST OF HOLE WAS CLEAN. 16:40 - 17:30 0.83 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3450 -4100 PSI, 2 -3K WOB, 90R TF, 50 -60 FPH, 96 DEG INCL, DRILLED TO 8800'. 17:30 - 18:45 1.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3450 -4100 PSI, 2 -3K WOB, 90R TF, 50 -60 FPH, 96 DEG INCL, 18:45 - 19:45 1.00 DRILL P PROD3 DRILLING AHEAD AT 8859' MD. UP WEIGHT 22100 LB, RIH WEIGHT 7500 LB, FREESPIN 1.65 BPM AT 3660 PSI W/ 310 PSI BACKPRESSURE (ECD 10.86 PPG). DRILL AHEAD W/ 350 PSI MOTOR WORK AND 2000 LB WOB (STACKING TO 2000 LB SURFACE WEIGHT TO ACHIEVE 2000 LB WOB). INCLINATION 96 DEGREES. IAP = 215 PSI, OAP = 264 PSI. DRILL AHEAD TO 8900' MD. 19:45 - 20:45 1.00 DRILL P PROD3 WIPER TO SHOE. STALL AND OVERPULL 12K AT 8403' MD ON UP WIPER PASS. TAG AND STALL AT 8397' MD ON DOWN PASS. DROP PUMP RATE TO 0.5 BPM AND RIH AT 55 FPM AND RIH CLEANLY. 20:45 - 23:25 2.67 DRILL P PROD3 RESUME DRILLING AHEAD AT 8900' MD. FREESPIN 1.65 GPM AT 3650 PSI W/ 310 PSI WHP (ECD 10.86 PPG). DRILL AHEAD W/ 200 - 350 PSI MOTOR WORK AND 1500 -3000 LB WOB. PITS 368 BBL. AVERAGE ROP OF 55 FPH. DRILL AHEAD TO 9050' MD. 23:25 - 00:00 0.58 DRILL P PROD3 WIPER TO WINDOW. IAP = 345 PSI OAP = 340 PSI CONTINUED ON DIMS REPORT 01/30/10 1/30/2010 00:00 - 00:20 0.33 DRILL P PROD3 CONTINUED FROM DIMS REPORT 01/29/10 IAP = 345 PSI OAP = 340 PSI WIPER TO WINDOW. BEGIN TO STALL AND OVERPULL AT 8415' MD - COME DOWN ON PUMP AND BOBBLE THROUGH WITH A 10000 LB WEIGHT BOBBLE. 00:20 - 01:10 0.83 DRILL P PROD3 TIE -IN, CORRECTION OF ( -2.5') RBIH. REDUCE RATE TO RUN PAST SHALE AT 8400' - DID NOT SEE SHALE. 01:10 - 04:00 2.83 DRILL P PROD3 RFSI I.MF_DHII I ING FROM 9050' MD. MAINTAINING -90 DEG INCLINATION AS PER GEO. FREESPIN 1.58 BPM AT 3500 PSI W/ 280 PSI BACKPRESSURE (ECD = 10.8 PPG). RIH WEIGHT 9000 LB. DRILL AHEAD W/ 200 -300 PSI MOTOR WORK W/ 1500 - Printed: 3/19/2010 1:28:50 PM • BP EXPLORATION Page 21 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2010 01:10 - 04:00 2.83 DRILL P PROD3 2500 LB WOB (STACKING TO -3300 LB SURFACE WEIGHT TO ACHIEVE 1500 LB WOB). DRILL AHEAD TO 9200' MD. AVERAGE ROP 50 FPH. 04:00 - 05:45 1.75 DRILL P PROD3 WIPER TO SHOE. UP WEIGHT 22200 LB. REDUCE RATE TO 1 BPM TO PULL PAST 8400' - SEE NO WEIGHT BOBBLE. RBIH TO RESUME DRILLING, CLEAN. 05:45 - 07:30 1.75 DRILL P PROD3 RESUME DRILLING FROM 9200' MD. FREESPIN 1.59 BPM AT 3540 PSI W/ 300 PSI BACKPRESSURE (ECD = 10.88 PPG). RIH WEIGHT 9100 LB. DRILL AHEAD W/ 150 - 250 PSI MOTOR WORK W/ 1300 - 2500 LB WOB (STACKING TO -1000 LB SURFACE WEIGHT TO ACHIEVE 1300 LB WOB). STACKING -6K WT AT SURFACE. DRILLED TO 9270'. 07:30 - 09:30 2.00 DRILL P PROD3 200' WIPER TO GET BETTER WT TRANSFER. STILL STACKING WT. WIPER TO SHOE. RIH AND REAM SHALES AT 9400'. RIH CLEAN TO BOTTOM. 09:30 - 11:45 2.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3600 -3900 PSI, 2K WOB, 80L TF, 10.9 ECD, 20 -50 FPH, STACKING FULL WT. -6K AT SURFACE. DRILLED TO 9345'. 11:45 - 14:00 2.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3600 -3900 PSI, 2K WOB, 80L TF, 10.9 ECD, 20 -50 FPH, DRILLED TO 9409'. 14:00 - 15:30 1.50 DRILL P PROD3 WIPER TRIP TO SHOE. REAMED SHALES AT 8400' RIH CLEAN TO BOTTOM. 15:30 - 16:45 1.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3600 -3900 PSI, 1.5K WOB, 80L TF, 10.9 ECD, 20 -50 FPH, STACKING -6K AT SURFACE. DRILLED TO 9470'. 16:45 - 18:00 1.25 DRILL P PROD3 DRILL Al LATERAL, 1.6 BPM, 3600 -3900 PSI, 1.5K WOB, 80L TF, 10.9 ECD, 20 -50 FPH, STACKING -7K, MAX DOWN WT. DRILLED TO TD OF 9495 (CALL THIS TD)'. 18:00 - 19:00 1.00 DRILL P PROD3 WIPER TRIP TO 9000', REAM SHALES - SEE SMALL MOTOR WORK IN SHALES FROM 9380' MD TO TD. RBIH TO BOTTOM. 19:00 - 20:05 1.08 DRILL P PROD3 WIPER OFF BOTTOM TO WINDOW. 20:05 - 20:30 0.42 DRILL P PROD3 SIGNIFICANT MOTOR WORK IN SHALE AT 8400' - 8390' MD. BACKREAM SEVERAL RECIPROCATIONS ACROSS THIS SHALE TO DRESS. 20:30 - 21:30 1.00 DRILL P PROD3 PUH TO WINDOW. TIE -IN, CORRECTION OF -4.5'. 21:30 - 22:40 1.17 DRILL P PROD3 RBIH AND TAG TD AT 9492' MD. (PUH AND SEND LINER PILL DOWN CT. 22:40 - 23:30 0.83 DRILL P PROD3 PUH LAYING -IN LINER PILL AT 1.6 BPM 23:30 - 00:00 0.50 DRILL P PROD3 8280' MD LINER PILL OUT OF COIL (SOME OF THE 40 BBL LINER PILL ABOVE BIT, CHASE THIS TO SURFACE AS A VISCOUS SWEEP). POOH. IAP = 170 PSI OAP = 230 PSI CONTINUED ON DIMS REPORT 01/31/10 1/31/2010 00:00 - 01:45 1.75 DRILL P PROD3 CONTINUED FROM DIMS REPORT 01/30/10 IAP = 175 PSI Printed: 3/19 /2010 1:28:50 PM • • BP EXPLORATION Page 22 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2010 00:00 - 01:45 1.75 DRILL P PROD3 OAP = 230 PSI CONTINUE PULL TO SURFACE. OPEN EDC AT 7975' MD, CONTINUE PULL TO SURFACE CIRCULATING AT MAX RATE AND FOLLOWING PRESSURE SCHEDULE TO MAINTAIN CONSTANT BHP AT -10.8 PPG. JET TRSSSV. PERFORM IN /OUT JOG NEAR SURFACE - RETURN SUBSTANTIAL CUTTINGS AND PLUG OFF CHOKE NUMEROUS TIMES. SAMPLE THESE CUTTINGS: MOSTLY Al SANDSTONE W/ MINOR AMOUNT OF SHALE. ALL OF SAMPLE IS WELL ROUNDED AND LOOKS LIKE IT WAS ROLLING AROUND IN THE HOLE FOR QUITE SOME TIME. CLOSE TRSSSV LOCKING 700 PSI BELOW. 01:45 - 02:00 0.25 DRILL P PROD3 PJSM FOR LAYING DOWN DRILLING BHA. 02:00 - 02:30 0.50 DRILL P PROD3 LAY DOWN DRILLING BHA. FUNCTION TEST BOPE. 02:30 - 03:00 0.50 CASE P RUNPRD PJSM FOR MU LINER. 03:00 - 05:45 2.75 CASE P RUNPRD MU LINER ASSEMBLY (ROTATING GUIDE SHOE, 50 JOINTS 2 -3/8" ST -L SLOTTED LINER, DEPLOYMENT SLEEVE, HYDRAULIC G -SPEAR ASSEMBLY). OAL OF LINER: 1583.4 OAL OF BHA: 1626.9 05:45 - 07:00 1.25 CASE P RUNPRD OPEN TRSSSV W/ 750 PSI WHP. BEGIN RIH W/ LINER CIRCULATING AT 0.1 BPM FOLLOWING PRESSURE SCHEDULE TO MAINTAIN BHP -10.8 PPG ECD. RIH TO 7900'. UP WT = 26K, DWN WT = 12K 07:00 - 07:20 0.33 CASE P RUNPRD RIH THRU OPEN HOLE, 60 FPM, RIH CLEAN PAST BILLET. DWN WT AT 8400' = 10K DWN WT AT 9000' = 9K DWN WT AT 9400' = 7K LAND LINER AT TD AT 9520'. UNCORRECTED DEPTH. TD = 9492'. UP WT = 29.5K. STACK 6K DWN WT. CIRC DOWN COIL AT 4000 PSI, 1.5 BPM, PICK UP CLEAN OFF OF TOL AT 20K UP WT. TOP OF 2 -3/8" SLOTTED LINER IS AT 7909'. 07:20 - 08:00 0.67 CASE P RUNPRD PULL TO 6000'. 08:00 - 09:30 1.50 CASE N WAIT RUNPRD WAIT ON KCL VAC TRUCK. TRUCK SHORTAGE. 09:30 - 10:00 0.50 CASE P RUNPRD CIRC WELL TO NEW 2% KCL WATER. 2.0 BPM, 3700 psi. 10:00 - 12:00 2.00 CASE P RUNPRD POH WHILE CIRC WELL TO KCL. 2.2 BPM, 3700 PSI. CLEAN RIG PITS. HAUL USED GEOVIS BACK TO MI PLANT. CLOSE SSSV. 12:00 - 12:30 0.50 CASE P RUNPRD CREW CHANGE. SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT BHA. 12:30 - 13:30 1.00 CASE P RUNPRD LAY OUT COILTRAK AND BAKER RUNNING TOOLS. M/U NOZZLE BHA. 13:30 - 17:00 3.50 WHSUR P POST OPEN SSSV. RIH WITH NOZZLE TO 2500'. FREEZE PROTECT THE 4 -1/2" TUBING WITH DIESEL. Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 23 of 23 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: REENTER +COMPLETE Start: 1/8/2010 End: 2/1/2010 Contractor Name: NORDIC CALISTA Rig Release: 2/1/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2010 13:30 - 17:00 3.50 WHSUR P POST POH. BLEED WHP TO ZERO, FLOW CHECK, WELL IS DEAD. 17:00 - 18:00 1.00 RIGD P POST PUMP 40 BBL RIG WATER, PUMP 10 BBL INHIBITOR AND 10 BBL MEOH. 18:00 - 18:30 0.50 RIGD P POST CREW CHANGE. SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PUMPING N2 AND BLEEDING THE N2 TO THE TIGER TANK. 18:30 - 20:00 1.50 RIGD P POST REEL BLOWDOWN W/ N2 W/ RETURNS TO TIGER TANK. 20:00 - 21:30 1.50 RIGD P POST INSTALL AND PT INTERNAL GRAPPLE. PULL CT STUB TO REEL AND SECURE. 21:30 - 22:30 1.00 RIGD P POST STANDBACK AND SET DOWN INJECTOR. 22:30 - 22:50 0.33 RIGD P POST PJSM W/ BPV CREW REGARDING PU LUBRICATOR, SETTING BPV. 22:50 - 00:00 1.17 RIGD P POST PU LUBRICATOR. SET BPV. IAP = 0 PSI OAP = 30 PSI CONTINUED ON DIMS REPORT 02/01/10 2/1/2010 00:00 - 00:45 0.75 RIGD P POST CONTINUED FROM DIMS REPORT 01/31/10 IAP = 0 PSI OAP = 30 PSI PJSM FOR ND BOPE AND MP DRILLING LOOP 00:45 - 05:00 4.25 RIGD P POST NIPPLE DOWN BOPE AND MP DRILLING LOOP. PT TREE CAP, TREE, AND DOWNSTREAM FLANGE OF WING VALVE (WHERE MP DRILILNG LOOP HAD BEEN INSTALLED). 05:00 - 08:00 3.00 RIGD P POST PULL OFF WELL AND CLEAR CELLAR AREA. RELEASED RIG AT 0800 HRS, 02/01/2010. TOTAL OF 19 DAYS, 23 HOURS FROM RIG ACCEPT TO RELEASE. FURTHER NORDIC 2 DIMS INFORMATION WILL BE UNDER MPL -36 Printed: 3/19/2010 1:28:50 PM • • BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 2/23/2010 End: 3/1/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/1/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/20/2010 00:00 - 00:00 24.00 MOB N WAIT PRE RIG PREPERATION ON 4ES,GETTING READY TO GO BACK TO WORK AFTER WARM STORAGE AT TEXACO PAD. RIG IS STILL ON TEXACO PAD -PREP WORK FOR MOBILIZIATION TO MPL -02 - ORGANIZING RIG PARTS -LIST AND ORGANIZE XO'S -PM DONE ON MUD PUMP -WORK COMPLETED ON NEW MUD TROUGH IN THE PITS WAITING ON WEATHER HELD A SUNDAY SAFETY MEETING WITH NEW NIGHT CREWS. - REVIEWED NABORS SAFE WORK PLAN - REVIEWED RECENT ADW / NABORS INCIDENT COMMUNICATIONS 2/21/2010 00:00 - 10:30 10.50 MOB N WAIT PRE PHASE 1 , LEVEL 3 ON THE PADS - WAITING ON L -PAD TO BE CLEARED IN ORDER TO START RIG MOVE TO MPL -02 -DOING MAINTENCE ON RIG 10:30 FINAL DECISION WAS MADE TO CALL OFF THE RIG MOVE TILL FURTHER NOTICE FROM MILNE POINT ROADS AND PADS. 10:30 - 13:30 3.00 MOB N WAIT PRE - CONDUCTED LEVEL 2 HAZARD IDENTIFICATION & TASK RISK ASSESMENT - ACTIVITY TYPE : TWO DRILLING RIGS ON LOCATION. - INITIAL ASSESMENT DONE BY HERB WILLIAMS AND DAVE RHODES. - SECOND ASSESMENT DONE BY T.DAVID BOYD AT MILNE POINT 13:30 - 00:00 10.50 MOB N WAIT PRE PHASE 1 , LEVEL 3 ON THE PADS - WAITING ON L -PAD TO BE CLEARED IN ORDER TO START RIG MOVE TO MPL -02 -DOING MAINTENCE ON RIG -NAD MASTER MECHANIC PERFORMED PM ON DRAW WORKS AND OMEGA BREAK. - TUBOSCOPE INSPECTED WELD MUD LINE. 2/22/2010 00:00 - 00:00 24.00 MOB N WAIT PRE PHASE 1 , LEVEL 3 ON THE PADS - WAITING ON L -PAD TO BE CLEARED IN ORDER TO START RIG MOVE TO MPL -02 -DOING MAINTENCE ON RIG - INSTALLED FALL ARREST BEAM CLAMPS IN CELLAR. -MILNE POINT FIELD OPERATIONS WENT DOWN -20:00 HRS -14:30 HRS HELD MEETING WITH MPU ROADS AND PAD SUPERVISOR -OUT COME FROM MEETING IS WAIT ON WEATHER 2/23/2010 00:00 - 04:00 4.00 MOB N WAIT PRE PHASE 1 , LEVEL 3 ON THE PADS - WEATHER FINALLY LAID DOWN AROUND MIDNIGHT. - WAITING FOR A CALL FROM ROADS AND PADS ON L -PAD. Printed: 3/19/2010 1:29:19 PM • BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 2/23/2010 End: 3/1/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/1/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/23/2010 00:00 - 04:00 4.00 MOB N WAIT PRE -WILL START RIG MOVE FROM TEXACO PAD TO MPL -02 AS SOON AS WE ARE CLEARED CLEANING AND PAINTING ON THE RIG, PERFORMING MAINTENCE CALLED FOR TRUCK AT 04:00 04:00 - 06:00 2.00 MOB N WAIT PRE WAITING FOR PEAK RIG MOVE TRUCKS - TRUCKS WERE CALLED AT 04:00 - TRUCKS ON LOCATION 0800 HRS -LOAD CAMP AND RIG UNITS -START MOVE OFF TEXACO PAD AND MPS -PAD 1000 HRS 06:00 - 15:00 9.00 MOB P PRE - TRUCKS ON LOCATION 0800 HRS -LOAD CAMP AND RIG UNITS -24 HOUR NOTICE TO AOGCC PAGER AT 0930 HRS. -START MOVE OFF TEXACO PAD AND MPS -PAD 1000 HRS -ON MP -L PAD AT 1500 HRS 15:00 - 20:00 5.00 RIGU P PRE SPOT SUB OVER MPL -02 -SPOT CAMP AND RIG UNITS -SPOT SHOP 2000 HRS 20:00 - 21:00 1.00 RIGU P PRE -RAISE DERRICK -SPOT TIGER TANK AND RU LINE TO TT -SPOT GUARD SHACK,GEN AND SIGN -N -SHACK 21:00 - 00:00 3.00 RIGU P PRE -" "ACCEPT RIG AT 21:00HRS * ** -FILL PITS -RU LINES TO TIGER TANK. 2/24/2010 00:00 - 00:30 0.50 RIGU P PRE RU SECOND ANNULUS VALVE. REMOVE TREE CAP. 00:30 - 01:00 0.50 WHSUR P DECOMP PJSM FOR PULLING BPV. 01:00 - 01:30 0.50 WHSUR P DECOMP RU LUBRICATOR AND TEST WITH DIESEL TO 500 PSI. PULL PBV TUBING PRESSURE = 10 PSI, IA = 20 PSI. OA = 70 PSI. 01:30 - 02:30 1.00 KILL P DECOMP RU AND TEST LINES TO TUBING AND ANNULUS. 02:30 - 04:30 2.00 KILL P DECOMP REVERSE DIESEL FROM THE TUBING AND CIRCULATE DIESEL FROM ANNULUS. @4 BPM 380 PSI REVERSED 1900 STK AND CIRCULATED 3000 STK TOTAL 4900 STK. MONITOR WELL. WELL DEAD. 04:30 - 06:00 1.50 KILL P DECOMP, SET TWC. TFST FROM BELOW TO 1000 PSI, TEST FROM ABOVE TO 3500 PSI, -CALL AOGCC, JOHN CRISP RETURNED CALL AND SAID -GIVE UP -DATE AROUND NOON TODAY. 06:00 - 06:30 0.50 WHSUR P DECOMP RIG SERVICE - PERFORM PRE -TOUR CHECK 06:30 - 08:00 1.50 WHSUR P DECOMP ND CTD 4 -1/8" TREE AND REMOVE FROM CELLAR. 08:00 - 16:30 8.50 BOPSUF P DECOMP NU 13 -5/8" x 5k BOPE - REMOVE 13 -5/8" TEST SPOOL -NU BOPE, 13 -5/8" X 11" DSA - REPLACE HCR KILL / MANUAL KILL VALVES / KILL 90 -CHOKE HOSE BLOCK. 16:30 - 00:00 7.50 BOPSUF P DECOMP TEST BOPE PER BP /AOGCC REQUIREMENTS: BOP CONFIGURATION: - 13 -5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. Printed: 3/19/2010 1:29:19 PM • . BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 2/23/2010 End: 3/1/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/1/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/24/2010 16:30 - 00:00 7.50 BOPSUF P DECOMP - 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" & 4 -1/2 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 = 45 SECONDS. -FULL BUILD UP TO 3000 PSI = 171 SECONDS. -4 BOTTLES x 1800 PSI. - JOHN CRISP STATE AOGCC INSPECTOR, WITNESSED BOPE TEST ON 2- 24 -10. 2/25/2010 00:00 - 01:30 1.50 BOPSUF P DECOMP COMPLETE TEST OF HYDRIL 01:30 - 01:45 0.25 BOPSUF P DECOMP INSTALL DUTCH SYSTEM AND RISER. 01:45 - 02:00 0.25 BOPSUF P DECOMP PJSM FOR PICKING UP BOP. 02:00 - 04:00 2.00 WHSUR P DECOMP SUCK OUT STACK. MU PULLING TOOL. INSTALL LUBRICATOR AND TEST TO 500 PSI. -PULL TWC -LD LUBRICATOR -RD DUTCH SYSTEM 04:00 - 06:30 2.50 WHSUR P DECOMP SHEAR -OUT PLUG WITH 3.2 BBLS AT 2100 PSI -BULL HEAD 40 BBLS SEAWATER AT 1 BPM /1500 PSI -BLEED BACK LESS THEN (1) BBL. -BLOW DOWN LINES. 06:30 - 07:00 0.50 WHSUR P DECOMP FMC REP, BOLDS, PULL TBG HANGER -OFF SEAT AT 63K -PUW = 78K, NO DRAG OBSERVED 07:00 - 08:30 1.50 PULL P DECOMP PUMP 117 BBL SEAWATER TO CLEAR TBG. -4 BPM @ 160 PSI. ---7 BPH LOSS RATE. 08:30 - 09:30 1.00 PULL P DECOMP RU FLOOR TO PULL CTD WORK STRING -PJSM -PU SSSV CONTROL LINE SPOOLER 09:30 - 14:00 4.50 PULL P DECOMP PULL AND LAY DOWN -56 JOINTS 4 -1/2" IBT TBG -SSSV AND RECOVERED 62 SS BANDS 14:00 - 17:00 3.00 PULL P DECOMP PULL AND LAY DOWN -149 JOINTS 4 -1/2" IBT TBG 17:00 - 17:30 0.50 PULL P DECOMP TBG COMING WET - -4700' -PUMP 59 BBLS SEAWATER DOWN THE TBG -3.5 BPM / 90 PSI -1 BPM / 20 PSI 17:30 - 19:00 1.50 PULL P DECOMP PULL AND LAY DOWN -TOTAL OF 179 JOINTS 4 -1/2" IBT,12.6 #, L -80 TBG -(1) GLM, "X" NIPPLE, PB SEAL ASSEMBLY = 27.67' Printed: 3/19 /2010 1:29:19 PM • • BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 2/23/2010 End: 3/1/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/1/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/25/2010 19:00 - 20:00 1.00 PULL P DECOMP RU FLOOR 20:00 - 21:30 1.50 PULL P DECOMP PU 3 JTS OF TUBING. PU RETRIEVABLE BRIDGE PLUG AND RUNNING TOOL. MU PACKER TO RUNNING TOOL 21:30 - 23:30 2.00 PULL P DECOMP RIH WITH PACKER PICKING UP 2 -7/8 EUE TUBING. PICKED UP 61 JOINTS. BENT JOINT 62 WHILE PICKING IT UP. THE HAND REMOVING THE SECONDARY SAFETY LINE GOT OFF CADENCE CALLED TO STOP BUT MOMENTUM OF THE DRAWORKS CAUSED THE JOINT TO BE BENT AS THE ELEVATORS RAISED THE JOINT WHILE RESTRAINED BY THE SAFETY LINE. 23:30 - 00:00 0.50 PULL N WAIT DECOMP INVESTIGATE PROPERTY DAMAGE INCIDENT SEE IR 3412308 2/26/2010 00:00 - 00:30 0.50 PULL N WAIT DECOMP COMPLETE INVESTIGATION OF BENT JOINT INCIDENT 00:30 - 10:00 9.50 DHB P DECOMP CONTINUE TO RIH PICKING UP 2 -7/8" TBG FROM PIPE SHED, -WITH RBP, F/ JT #61 T/ JT# 232 - TAGGED W/ 5K SOW AT 7,306' MD -PUW= 36K, SOW= 36K 10:00 - 12:00 2.00 DHB P DECOMP SET AND TEST 7" RBP AT 7,285' MD -PJSM -1,000 PSI F/ 10 CHARTED MINUTES. -LD 3 JTS 2 -7/8" TBG 12:00 - 12:30 0.50 DHB P DECOMP WEEKLY CREW CHANGE - PERFORM PRE -TOUR CHECKS -PJSM WITH WSL / TOOLPUSH 12:30 - 14:30 2.00 WHSUR P DECOMP PU /MU AND STEAM HEAT 7" STORM PACKER -SET AT 33' MD -LD SETTING TOOL -TEST @ 1,000 PSI F/ 10 CHARTED MINUTES. 14:30 - 17:00 2.50 WHSUR P DECOMP ND BOPE - SUCK FLUID FROM BOP - REMOVE 11" X 11" 5K FMC TBG SPOOL - MADE TUBING HANGER DUMMY RUN PER WKM PROCEDURE. - INSPECT ALIGHMENT PIN. 17:00 - 00:00 7.00 WHSUR P DECOMP NU TEST SPOOL WITH BOP. 2/27/2010 00:00 - 01:00 1.00 WHSUR P DECOMP CONTINUE TO NU BOP'S. 01:00 - 02:00 1.00 WHSUR P DECOMP BODY TEST BOP AND TEST SPOOL. 250 PSI LOW AND 3500 PSI HIGH. 02:00 - 05:00 3.00 DHB P DECOMP RELEASE RTTS WITH 21 ROTATION TO RT. PU 39.8K. LD RTTS. -PU 4 JOINTS AND ENGAGE RBP OPEN BY PASS. MONITOR WELL. RELEASE RBP. 05:00 - 07:00 2.00 DHB P DECOMP CBU,4 BPM / 1000 PSI, 262 BBLS - LOSSED 7 BBLS -LOSS RATE AT — 2 -4 BPH 07:00 - 11:00 4.00 DHB P DECOMP POH WITH RBP. - STANDING BACK 2 -7/8" EUE 8RD TUBING. 11:00 - 11:30 0.50 DHB P DECOMP BO /LD 7" RBP 11:30 - 12:30 1.00 RUNCOMP RUNCMP CLEAN AND CLEAR RIG FLOOR. 12:30 - 15:00 2.50 RUNCOMV WAIT RUNCMP TEMP -46 DEG -ROADS & PADS MOVED NORDIC 2's TIGER TANK Printed: 3/19/2010 1:29:19 PM • • BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: MPL -02 Common Well Name: MPL -02 Spud Date: 2/21/1990 Event Name: WORKOVER Start: 2/23/2010 End: 3/1/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/1/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/27/2010 12:30 - 15:00 2.50 RUNCOMN WAIT RUNCMP -TO MAKE ROOM FOR ESP SPOOLER UNIT - NORDIC 2 IS WAITING ON MPF -PAD FOR WEATHER -MPU MECHANIC WORKING ON TRUCK FOR ESP SPOOLER UNIT -RU TO RUN ESP COMPLETION 15:00 - 18:00 3.00 RUNCOMP RUNCMP SPOT SPOOLER AND LOAD REEL. 18:00 - 20:30 2.50 RUNCOMP RUNCMP PU MOTOR,TANDEM SEALS,GAS SERERATOR AND PUMP. 20:30 - 22:45 2.25 RUNCOMP RUNCMP SERVICE PUMP. PULL ESP CABLE TO FLOOR. PU PUP, XN NIPPLE AND JOINT TUBING. RU FLAT CABLE AND GUARDS. 22:45 - 23:00 0.25 RUNCOMP RUNCMP PJSM FOR RUNNING ESP COMPLETION. 23:00 - 23:30 0.50 RUNCOMP RUNCMP TEST ESP CABLE. FILL WELL WITH 8 BBLS. 23:30 - 00:00 0.50 RUNCOMP RUNCMP RIH WITH 2 -7/8 TUBING IN STANDS. 11TH STAND -2 -3 BPH FLUID LOSS RATE. 2/28/2010 00:00 - 05:00 5.00 RUNCOMP RUNCMP CONTINUE TO RIH WITH ESP COMPLETION. -ON 2 -7/8" TUBING FROM DERRICK -F/ STAND #12 T/ STAND #66 05:00 - 07:30 2.50 RUNCOMP RUNCMP REEL TO REEL CABLE SPLICE @ STAND 66. 07:30 - 09:00 1.50 RUNCOMP RUNCMP RUN ESP COMPLETION F/ STAND #66 T/ STAND #227 09:00 - 09:30 0.50 RUNCOMP RUNCMP MU TBG HANGER TO LANDING JOINT -121 LASALLE CLAMPS, 5- PROTECTOLIZERS, 3 FLAT GUARDS. 09:30 - 11:00 1.50 RUNCOMP RUNCMP CENTRILIFT REP PERFORM PENETRATOR SPLICE. 11:00 - 12:00 1.00 P RUNCMP LAND TBG HANGER -WSL VERIFIED ORIENTATION BY FEEL. -PUW= 46K -SOW= 43K -RILDS -DRY ROD TWC -TEST F/ ABOVE T/ 3500 PSI F/ 10 CHARTED MINUTES -TEST FROM BELOW, 680 PSI AT 2 SPM F/ 10 CHARTED MINUTES. 12:00 - 14:00 2.00 RUNCOMP RUNCMP ND BOPE 14:00 - 19:00 5.00 RUNCOMP RUNCMP NU CAMERON 11" ADAPTOR AND 2- 9/16" 5M TREE. - TESTED ADAPTOR T/ 5,000 PSI F/ 30 MINUTES. - CENTRILIFT REP TAKE FINAL CHECKS. -PU LUBRICATOR AND TEST TO 500 PSI. -PULL TWC -SET BPV WITH LUBRICATOR 19:00 - 00:00 5.00 RUNCOMP RUNCMP BULLHEAD 13 BBL DEAD CRUDE TO 2300' IN TUBING @ 1BPM 750 PSI, BULLHEAD 69 BBL CRUDE INTO ANNULUS .5 BPM @ 1450 PSI. 3/1/2010 00:00 - 01:00 1.00 RUNCOMP RUNCMP COMPLETE FREEZE PROTECTING WELL WITH DEAD CRUDE. 01:00 - 02:00 1.00 RUNCOMP RUNCMP AFTER ACTION REVIEW & WEEKLY SAFETY MEETING. RELEASE RIG AT 02:00. Printed: 3/19/2010 1:29:19 PM • • Mill BAKER HUGHES INTEQ North America - ALASKA - BP Milne Point M Pt L Pad MPL -02 MPL- 02APB1 Survey: MWD Survey Report - Geographic 26 January, 2010 � bp • . Bi anns 0 Su rvey Report - Geographic bP 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL -02 Project: Milne Point TVD Reference: 2:02 2/21/1990 00:00 © 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 © 56.00ft (generic drilling Well: MPL -02 North Reference: True Welibore: MPL- 02APB1 Survey Calculation Method: Minimum Curvature Design: MPL- 02APB1 Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt L Pad, TR -13 -10 Site Position: Northing: 6,029,799.28ft Latitude: 70° 29' 32.230 N From: Map Easting: 544,529.55ft Longitude: 149° 38' 9.412 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 0.34 ° Well MPL -02 API No 500292199800 Well Position +N / -S 0.00 ft Northing: 6,031,396.60 ft Latitude: 70° 29' 47.923 N +E / -W 0.00 ft Easting: 544,824.78 ft Longitude: 149° 38' 0.439 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Welibore MPL- 02APB1 API No 500292199870 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nT) BGGM2009 1/18/2010 21.97 80.96 57,667 Design MPL- 02APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,500.00 Vertical Section: Depth From (TVD) +N/-S +E / -W Direction (ft) (ft) (ft) (") 39.00 0.00 0.00 277.46 Survey Program Date: 1/19/2010 From To (ft) (ft) Survey (Welibore) Tool Name Description 100.00 7,500.00 1 : Schlumberger GCT multishot (MPL -02) GCT -MS Schlumberger GCT multishot ' 7,561.00 8,529.00 MWD (MPL- 02APB1) MWD MWD - Standard 1/26/2010 10:04:59AM Page 2 COMPASS 2003.16 Build 71 • 0 s Survey Report - Geographic <> 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL - 02 Project: Milne Point TVD Reference: 2:02 2/21/1990 00:00 Qa 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21 /1990 00:00 cQ 56.00ft (generic drilling Well: MPL - 02 North Reference: True Welibore: MPL 02APB1 Survey Calculation Method: Minimum Curvature Design: MPL 02APB1 Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N / -S +E/ -W Northing Easting (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,500.00 33.32 290.20 6,983.98 733.29 - 1,761.62 6,032,119.19 543,058.95 70° 29' 55.133 N 149° 38' 52.298 W TIP 7,561.00 33.62 290.06 7,034.86 744.87 - 1,793.20 6,032,130.57 543,027.29 70° 29' 55.247 N 149° 38' 53.228 W KOP 7,600.27 37.89 280.74 7,066.75 750.85 - 1,815.29 6,032,136.42 543,005.17 70° 29' 55.306 N 149° 38' 53.878 W 7,631.84 48.60 275.45 7,089.72 753.80 - 1,836.67 6,032,139.23 542,983.78 70° 29' 55.334 N 149° 38' 54.507 W 7,662.08 58.18 271.42 7,107.74 755.19 - 1,860.87 6,032,140.49 542,959.57 70° 29' 55.348 N 149° 38' 55.220 W 7,691.18 67.37 268.13 7,121.04 755.06 - 1,886.71 6,032,140.20 542,933.74 70° 29' 55.347 N 149° 38' 55.981 W 7,721.34 73.53 263.47 7,131.13 752.96 - 1,915.03 6,032,137.93 542,905.43 70° 29' 55.326 N 149° 38' 56.814 W 7,751.03 74.30 251.75 7,139.38 746.85 - 1,942.84 6,032,131.64 542,877.67 70° 29' 55.266 N 149° 38' 57.633 W 7,782.25 80.90 242.52 7,146.10 734.99 - 1,970.87 6,032,119.62 542,849.71 70° 29' 55.149 N 149° 38' 58.458 W 7,812.07 83.88 233.70 7,150.05 719.39 - 1,995.93 6,032,103.87 542,824.74 70° 29' 54.996 N 149° 38' 59.196 W I 7,847.16 88.49 223.74 7,152.39 696.32 - 2,022.20 6,032,080.64 542,798.62 70° 29' 54.769 N 149° 38' 59.969 W 7,886.50 92.15 212.59 7,152.17 665.44 - 2,046.47 6,032,049.62 542,774.54 70° 29' 54.465 N 149° 39' 0.683 W 7,915.92 92.52 202.19 7,150.97 639.38 - 2,059.97 6,032,023.48 542,761.19 70° 29' 54.209 N 149° 39' 1.080 W', 7,950.69 94.89 191.64 7,148.72 606.23 - 2,070.06 6,031,990.28 542,751.31 70° 29' 53.883 N 149° 39' 1.377 W 7,980.63 94.46 181.21 7,146.27 576.62 - 2,073.39 6,031,960.65 542,748.15 70° 29' 53.591 N 149° 39' 1.475 W 8,011.01 93.01 170.70 7,144.29 546.42 - 2,071.25 6,031,930.47 542,750.47 70° 29' 53.294 N 149° 39' 1.411 W 8,045.71 91.20 159.04 7,143.01 513.01 - 2,062.22 6,031,897.11 542,759.71 70° 29' 52.966 N 149° 39' 1.145 W 8,079.47 92.73 149.18 7,141.85 482.69 - 2,047.50 6,031,866.89 542,774.60 70° 29' 52.668 N 149° 39' 0.712 W 8,119.09 93.32 138.62 7,139.75 450.77 - 2,024.23 6,031,835.11 542,798.07 70° 29' 52.354 N 149° 39' 0.026 W 8,150.84 93.37 141.27 7,137.90 426.51 - 2,003.83 6,031,810.98 542,818.61 70° 29' 52.115 N 149° 38' 59.426 W 8,180.50 92.70 137.13 7,136.33 404.10 - 1,984.48 6,031,788.68 542,838.09 70° 29' 51.895 N 149° 38' 58.856 W 8,209.20 92.30 133.99 7,135.07 383.63 - 1,964.41 6,031,768.34 542,858.29 70° 29' 51.694 N 149° 38' 58.265 W 93.50 130.54 7,133.47 362.29 - 1,940.93 6,031,747.14 542,881.89 70° 29' 51.484 N 149° 38' 57.574 W 8,268.59 96.70 129.09 7,131.01 344.68 - 1,919.80 6,031,729.66 542,903.12 70° 29' 51.311 N 149° 38' 56.952 W 8,303.01 97.87 124.41 7,126.64 324.25 - 1,892.46 6,031,709.40 542,930.59 70° 29' 51.110 N 149° 38' 56.147 W 8,332.37 98.50 120.89 7,122.46 308.58 - 1,867.99 6,031,693.88 542,955.14 70° 29' 50.956 N 149° 38' 55.426 W 8,362.64 98.01 117.91 7,118.12 293.87 - 1,841.90 6,031,679.33 542,981.32 70° 29' 50.811 N 149° 38' 54.658 W 8,395.92 94.02 116.91 7,114.63 278.64 - 1,812.52 6,031,664.28 543,010.79 70° 29' 50.662 N 149° 38' 53.793 W 8,425.84 90.18 116.23 7,113.53 265.27 - 1,785.79 6,031,651.07 543,037.60 70° 29' 50.530 N 149° 38' 53.006 WI 8,455.43 86.01 115.48 7,114.52 252.38 - 1,759.18 6,031,638.34 543,064.28 70° 29' 50.403 N 149° 38' 52.223 W 8,483.33 83.39 114.72 7,117.09 240.59 - 1,734.02 6,031,626.71 543,089.51 70° 29' 50.288 N 149° 38' 51.482 W 8,529.00 83.39 114.72 7,122.35 221.62 - 1,692.81 6,031,607.99 543,130.83 70° 29' 50.101 N 149° 38' 50.269 W TD I Survey Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/ -W (ft) (ft) (ft) (ft) Comment 7,500.00 6,983.98 733.29 - 1,761.62 TIP 7,561.00 7,034.86 744.87 - 1,793.20 KOP 8,529.00 7,122.35 221.62 - 1,692.81 TD Checked By: Approved By: Date: I 1/26/2010 10:04:59AM Page 3 COMPASS 2003.16 Build 71 • • FA kill BAKER HUGHES LNTEQ North America - ALASKA - BP Milne Point M Pt L Pad MPL -02 MPL- 02APB2 Survey: MWD Survey Report - Geographic 26 January, 2010 � bp • S Wars Survey Report - Geographic 0 � 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL - 02 Project: Milne Point TVD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling Well: MPL - 02 North Reference: True Wellbore: MPL 02APB2 Survey Calculation Method: Minimum Curvature Design: MPL- 02APB2 Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 1 Site M Pt L Pad, TR -13 -10 Site Position: Northing: 6,029,799.28ft Latitude: 70° 29' 32.230 N From: Map Easting: 544,529.55ft Longitude: 149° 38' 9.412 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.34 ° Well MPL - 02 API No 500292199800 Well Position +N / - 0.00 ft Northing: 6,031,396.60 ft Latitude: 70° 29' 47.923 N +E / - 0.00 ft Easting: 544,824.78 ft Longitude: 149° 38' 0.439 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore MPL 02APB2 API No 500292199871 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (0) (nT) BGGM2009 1/21/2010 21.96 80.96 57,667 Design MPL- 02APB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,561.00 Vertical Section: Depth From (TVD) +N/-S +E / -W Direction (ft) (ft) (ft) ( 39.00 0.00 0.00 281.54 Survey Program Date: 1/22/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 7,500.00 1 : Schlumberger GCT multishot (MPL -02) GCT -MS Schlumberger GCT multishot 7,561.00 7,561.00 MWD (MPL- 02APB1) MWD MWD - Standard 7,580.00 8,340.00 MWD (MPL- 02APB2) MWD MWD - Standard 1/26/2010 10:07:14AM Page 2 COMPASS 2003.16 Build 71 • • MOUES Survey Report - Geographic 0 bp 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL - 02 Project: Milne Point TVD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling Well: MPL - 02 North Reference: True Wellbore: MPL 02APB2 Survey Calculation Method: Minimum Curvature Design: MPL 02APB2 Database: EDM .16 - Anc Prod - WH24P I Survey - I Measured Vertical Map Map Depth Inclination Azimuth Depth +N /S +E/ -W Northing Easting (ft) r) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,561.00 33.62 290.06 7,034.86 744.87 - 1,793.20 6,032,130.57 543,027.29 70° 29' 55.247 N 149° 38' 53.228 W TIP 7,580.00 38.02 282.76 7,050.27 747.97 - 1,803.86 6,032,133.61 543,016.62 70° 29' 55.277 N 149° 38' 53.542 W KOP 7,622.37 50.03 270.86 7,080.73 751.11 - 1,832.98 6,032,136.57 542,987.49 70° 29' 55.308 N 149° 38' 54.399 W 7,651.36 58.50 264.89 7,097.66 750.18 - 1,856.45 6,032,135.50 542,964.02 70° 29' 55.299 N 149° 38' 55.090 W 7,680.64 65.43 259.89 7,111.42 746.72 - 1,882.04 6,032,131.89 542,938.46 70° 29' 55.265 N 149° 38' 55.843 W 7,710.16 68.51 247.78 7,123.00 739.15 - 1,908.05 6,032,124.16 542,912.49 70° 29' 55.190 N 149° 38' 56.609 W 7,740.83 73.52 236.93 7,133.00 725.68 - 1,933.67 6,032,110.54 542,886.96 70° 29' 55.058 N 149° 38' 57.363 W 7,770.67 77.22 224.52 7,140.57 707.43 - 1,955.95 6,032,092.15 542,864.79 70° 29' 54.878 N 149° 38' 58.019 W 7,801.43 82.74 213.41 7,145.93 683.91 - 1,974.94 6,032,068.52 542,845.94 70° 29' 54.647 N 149° 38' 58.577 W 7,831.95 86.61 200.71 7,148.78 656.90 - 1,988.73 6,032,041.43 542,832.32 70° 29' 54.381 N 149° 38' 58.983 WI 7,874.43 92.12 185.78 7,149.25 615.69 - 1,998.42 6,032,000.17 542,822.88 70° 29' 53.976 N 149° 38' 59.268 W' 7,902.63 91.50 174.97 7,148.36 587.54 - 1,998.61 6,031,972.02 542,822.86 70° 29' 53.699 N 149° 38' 59.273 W 1 7,935.37 91.17 163.79 7,147.59 555.42 - 1,992.58 6,031,939.95 542,829.08 70° 29' 53.383 N 149° 38' 59.096 W 7,960.42 92.03 157.08 7,146.89 531.84 - 1,984.20 6,031,916.42 542,837.60 70° 29' 53.151 N 149° 38' 58.849 W 7,990.90 94.76 149.68 7,145.08 504.66 - 1,970.58 6,031,889.32 542,851.38 70° 29' 52.884 N 149° 38' 58.448 W 8,018.56 90.25 143.50 7,143.88 481.61 - 1,955.38 6,031,866.37 542,866.73 70° 29' 52.657 N 149° 38' 58.000 W 8,050.55 91.26 137.57 7,143.45 456.93 - 1,935.06 6,031,841.81 542,887.19 70° 29' 52.415 N 149° 38' 57.401 W 8,080.19 94.36 131.07 7,142.00 436.26 - 1,913.89 6,031,821.27 542,908.48 70° 29' 52.211 N 149° 38' 56.778 W 8,111.51 95.13 125.19 7,139.41 417.00 - 1,889.35 6,031,802.15 542,933.13 70° 29' 52.022 N 149° 38' 56.056 W 8,139.97 95.04 119.03 7,136.88 401.93 - 1,865.35 6,031,787.24 542,957.22 70° 29' 51.874 N 149° 38' 55.349 W 8,169.92 93.60 114.48 7,134.62 388.49 - 1,838.69 6,031,773.96 542,983.96 70° 29' 51.742 N 149° 38' 54.564 W 8,200.32 92.58 108.82 7,132.98 377.30 - 1,810.49 6,031,762.94 543,012.23 70° 29' 51.632 N 149° 38' 53.734 W' 8,226.74 93.93 103.27 7,131.48 370.01 - 1,785.15 6,031,755.81 543,037.61 70° 29' 51.560 N 149° 38' 52.988 W 8,243.97 93.10 100.54 7,130.43 366.47 - 1,768.32 6,031,752.36 543,054.45 70° 29' 51.525 N 149° 38' 52.493 W 8,287.55 93.04 105.90 7,128.09 356.52 - 1,725.97 6,031,742.67 543,096.86 70° 29' 51.428 N 149° 38' 51.246 W 8,340.00 93.04 105.90 7,125.31 342.17 - 1,675.60 6,031,728.62 543,147.31 70° 29' 51.287 N 149° 38' 49.763 W TD Survey Annotations i Measured Vertical Local Coordinates I Depth Depth +N /S +E / -W (ft) (ft) (ft) (ft) Comment 7,561.00 7,034.86 744.87 - 1,793.20 TIP • 7,580.00 7,050.27 747.97 - 1,803.86 KOP 8,340.00 7,125.31 342.17 - 1,675.60 TD Checked By: Approved By: Date: i I I 1/26/2010 10:07:14AM Page 3 COMPASS 2003.16 Build 71 I • BAKER iS INTEQ North America - ALASKA - BP Milne Point M Pt L Pad MPL -02 MPL -02A Survey: MWD Survey Report - Geographic 26 January, 2010 � bp s Survey Report - Geographic 0 bP INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL -02 Project: Milne Point TVD Reference: 2 : 02 2/21/1990 00:00 © 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 © 56.00ft (generic drilling Well: MPL -02 North Reference: True Wellbore: MPL -02A Survey Calculation Method: Minimum Curvature Design: MPL -02A Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt L Pad, TR -13 -10 Northing: 6, 029,799.28 Site Position: 9� ft Latitude: 70° 29' 32.230 N From: Map Easting: 544,529.55ft Longitude: 149° 38' 9.412 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.34 ° J Well MPL -02 API No 500292199800 Well Position +N / -S 0.00 ft Northing: 6,031,396.60 ft Latitude: 70° 29' 47.923 N +E / -W 0.00 ft Easting: 544,824.78 ft Longitude: 149° 38' 0.439 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore MPL -02A API No 500292199801 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ° 1 ( (nT) BGGM2009 1/22/2010 21.96 80.96 57,667 Design MPL -02A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,680.64 Vertical Section: Depth From (TVD) +N/-S +E / -W Direction (ft) (ft) (ft) ( 39.00 0.00 0.00 255.31 Survey Program Date: 1/26/2010 From To (ft) (ft) Survey ( Wellbore) Tool Name Description 100.00 7,500.00 1 : Schlumberger GCT multishot (MPL -02) GCT -MS Schlumberger GCT multishot 7,561.00 7,561.00 MWD (MPL- 02APB1) MWD MWD - Standard 7,580.00 7,680.64 MWD (MPL- 02APB2) MWD MWD - Standard 7,690.00 9,444.00 MWD (MPL -02A) MWD MWD - Standard 1/26/2010 10:02:23AM Page 2 COMPASS 2003.16 Build 71 • • HUGHES BAUM Survey Report - Geographic bP 4 INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL - 02 Project: Milne Point TVD Reference: 2 : 02 2/21/1990 00:00 © 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 (g 56.00ft (generic drilling Well: MPL - 02 North Reference: True Weilbore: MPL - 02A Survey Calculation Method: Minimum Curvature Design: MPL - 02A Database: EDM .16 - Anc Prod - WH24P Survey 1 Measured Vertical Map Map Depth Inclination Azimuth Depth +N /-S +E / -W Northing Easting (ft) ( °) ( ° ) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,680.64 65.43 259.89 7,111.42 746.72 - 1,882.04 6,032,131.89 542,938.46 70° 29' 55.265 N 149° 38' 55.843 W TIP 7,690.00 66.31 255.99 7,115.25 744.94 - 1,890.39 6,032,130.05 542,930.12 70° 29' 55.247 N 149° 38' 56.089 W KOP 7,718.00 69.64 249.78 7,125.76 737.29 - 1,915.17 6,032,122.25 542,905.39 70° 29' 55.172 N 149° 38' 56.818 W 7,739.52 69.82 240.64 7,133.23 728.83 - 1,933.47 6,032,113.69 542,887.14 70° 29' 55.089 N 149° 38' 57.357 W 7,766.30 74.24 229.97 7,141.51 714.34 - 1,954.36 6,032,099.07 542,866.34 70° 29' 54.946 N 149° 38' 57.972 W 7,801.91 82.15 221.09 7,148.80 689.94 - 1,979.16 6,032,074.52 542,841.69 70° 29' 54.706 N 149° 38' 58.702 W 7,834.47 87.98 210.56 7,151.61 663.68 - 1,998.10 6,032,048.15 542,822.91 70° 29' 54.448 N 149° 38' 59.259 W 7,865.35 90.06 197.60 7,152.14 635.55 - 2,010.67 6,032,019.95 542,810.51 70° 29' 54.171 N 149° 38' 59.629 W 7,891.84 94.42 188.64 7,151.10 609.80 - 2,016.67 6,031,994.17 542,804.66 70° 29' 53.918 N 149° 38' 59.805 W 7,914.68 93.97 180.42 7,149.43 587.12 - 2,018.47 6,031,971.48 542,803.00 70° 29' 53.695 N 149° 38' 59.858 W 7,940.84 94.17 170.11 7,147.57 561.15 - 2,016.32 6,031,945.52 542,805.31 70° 29' 53.439 N 149° 38' 59.794 W 7,985.00 91.50 153.00 7,145.37 519.47 - 2,002.41 6,031,903.93 542,819.47 70° 29' 53.030 N 149° 38' 59.385 W 3 3/16" 8,011.32 92.74 149.01 7,144.39 496.47 - 1,989.66 6,031,881.01 542,832.35 70° 29' 52.803 N 149° 38' 59.009 W 8,043.21 93.72 147.05 7,142.60 469.46 - 1,972.81 6,031,854.11 542,849.37 70° 29' 52.538 N 149° 38' 58.513 W, 8,070.03 94.06 144.00 7,140.78 447.40 - 1,957.66 6,031,832.15 542,864.65 70° 29' 52.321 N 149° 38' 58.067 W 8,101.47 93.69 140.71 7,138.65 422.57 - 1,938.51 6,031,807.43 542,883.95 70° 29' 52.077 N 149° 38' 57.503 W 8,130.12 93.75 137.92 7,136.79 400.89 - 1,919.87 6,031,785.87 542,902.71 70° 29' 51.864 N 149° 38' 56.954 W 8,160.80 92.49 134.33 7,135.12 378.81 - 1,898.64 6,031,763.92 542,924.07 70° 29' 51.646 N 149° 38' 56.329 W 8,195.58 92.98 131.15 7,133.46 355.24 - 1,873.13 6,031,740.50 542,949.72 70° 29' 51.415 N 149° 38' 55.578 W 8,236.47 92.77 126.73 7,131.41 329.58 - 1,841.38 6,031,715.04 542,981.63 70° 29' 51.162 N 149° 38' 54.643 W 8,263.79 92.37 123.49 7,130.18 313.88 - 1,819.05 6,031,699.48 543,004.05 70° 29' 51.008 N 149° 38' 53.986 W 8,292.53 93.41 120.39 7,128.73 298.70 - 1,794.70 6,031,684.44 543,028.49 70° 29' 50.859 N 149° 38' 53.269 W1 8,320.79 92.34 117.09 7,127.32 285.13 - 1,769.95 6,031,671.03 543,053.31 70° 29' 50.725 N 149° 38' 52.540 W 8,351.06 91.94 113.37 7,126.19 272.24 - 1,742.59 6,031,658.30 543,080.75 70° 29' 50.599 N 149° 38' 51.735 W 8,379.92 92.03 110.75 7,125.19 261.41 - 1,715.87 6,031,647.63 543,107.54 70° 29' 50.492 N 149° 38' 50.948 W 8,409.92 92.37 107.33 7,124.03 251.63 - 1,687.53 6,031,638.03 543,135.93 70° 29' 50.396 N 149° 38' 50.114 W 8,440.95 93.97 104.17 7,122.32 243.22 - 1,657.72 6,031,629.80 543,165.79 70° 29' 50.314 N 149° 38' 49.236 W 8,472.39 93.84 100.71 7,120.18 236.47 - 1,627.09 6,031,623.23 543,196.45 70° 29' 50.247 N 149° 38' 48.335 W 8,501.57 91.84 100.83 7,118.73 231.02 - 1,598.46 6,031,617.95 543,225.11 70° 29' 50.194 N 149° 38' 47.492 W 8,531.96 90.61 103.88 7,118.08 224.52 - 1,568.79 6,031,611.63 543,254.82 70° 29' 50.130 N 149° 38'46.618 W 8,562.84 93.53 106.30 7,116.96 216.49 - 1,539.00 6,031,603.78 543,284.66 70° 29' 50.051 N 149° 38' 45.741 W 1 8,599.66 92.55 110.18 7,115.01 204.98 - 1,504.08 6,031,592.49 543,319.63 70° 29' 49.938 N 149° 38' 44.713 W1 8,632.77 89.36 112.06 7,114.46 193.05 - 1,473.21 6,031,580.75 543,350.58 70° 29' 49.821 N 149° 38' 43.805 W 8,663.17 86.47 113.64 7,115.57 181.26 - 1,445.22 6,031,569.12 543,378.64 70° 29' 49.705 N 149° 38' 42.981 W 8,692.93 84.19 116.97 7,117.99 168.58 - 1,418.41 6,031,556.61 543,405.52 70° 29' 49.580 N 149° 38' 42.191 W 8,726.00 83.85 120.79 7,121.44 152.70 - 1,389.61 6,031,540.91 543,434.41 70° 29' 49.424 N 149° 38' 41.344 W 8,756.20 85.33 124.30 7,124.28 136.53 - 1,364.27 6,031,524.89 543,459.84 70° 29' 49.265 N 149° 38' 40.598 W 8,786.47 89.29 125.63 7,125.70 119.21 - 1,339.50 6,031,507.72 543,484.72 70° 29' 49.095 N 149° 38' 39.868 W 8,816.01 90.71 128.70 7,125.70 101.36 - 1,315.96 6,031,490.02 543,508.36 70° 29' 48.919 N 149° 38' 39.175 W 8,849.93 94.55 130.77 7,124.15 79.71 - 1,289.91 6,031,468.52 543,534.54 70° 29' 48.706 N 149° 38' 38.408 W 8,876.15 94.58 132.82 7,122.06 62.29 - 1,270.43 6,031,451.22 543,554.13 70° 29' 48.535 N 149° 38' 37.835 W 8,900.13 93.93 135.94 7,120.28 45.57 - 1,253.34 6,031,434.60 543,571.31 70° 29' 48.370 N 149° 38' 37.332 W 8,929.46 94.70 134.41 7,118.07 24.82 - 1,232.72 6,031,413.99 543,592.05 70° 29' 48.166 N 149° 38' 36.725 W 8,960.64 95.22 130.86 7,115.38 3.79 - 1,209.87 6,031,393.09 543,615.03 70° 29' 47.960 N 149° 38' 36.052 W 8,990.38 96.12 128.19 7,112.44 -15.05 - 1,187.05 6,031,374.40 543,637.96 70° 29' 47.774 N 149° 38' 35.380 W 9,020.80 95.48 125.71 7,109.36 -33.24 - 1,162.86 6,031,356.36 543,662.25 70° 29' 47.596 N 149° 38' 34.668 W 9,050.27 96.00 123.17 7,106.42 -49.82 - 1,138.68 6,031,339.92 543,686.53 70° 29' 47.433 N 149° 38' 33.956 W 9,080.71 95.63 120.15 7,103.33 -65.71 - 1,112.91 6,031,324.19 543,712.40 70° 29' 47.276 N 149° 38' 33.198 W ' 9,110.27 93.72 116.85 7,100.92 -79.77 - 1,087.02 6,031,310.29 543,738.37 70° 29' 47.138 N 149° 38' 32.436 W 9,141.18 94.58 113.52 7,098.68 -92.88 - 1,059.13 6,031,297.34 543,766.34 70° 29' 47.009 N 149° 38' 31.615 W 9,174.34 96.56 110.52 7,095.46 - 105.26 - 1,028.54 6,031,285.15 543,797.00 70° 29' 46.887 N 149° 38' 30.714 W 9,200.64 96.12 107.60 7,092.56 - 113.79 - 1,003.83 6,031,276.77 543,821.75 70° 29' 46.804 N 149° 38' 29.987 W 1/26/2010 10:02:23AM Page 3 COMPASS 2003.16 Build 71 • • Mill Wies 0 Survey Report - Geographic bP INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL - 02 Project: Milne Point ND Reference: 2 : 02 2/21/1990 00:00 © 56.00ft (generic drilling Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 © 56.00ft (generic drilling Well: MPL - 02 North Reference: True Wellbore: MPL - 02A Survey Calculation Method: Minimum Curvature Design: MPL - 02A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +141 -S +El -W Northing Easting (ft) (^) ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,225.67 95.48 105.47 7,090.03 - 120.88 - 979.96 6,031,269.83 543,845.66 70° 29' 46.734 N 149° 38' 29.284 W 9,250.99 95.39 103.48 7,087.63 - 127.18 - 955.56 6,031,263.68 543,870.10 70° 29' 46.672 N 149° 38' 28.566 W 9,280.31 94.64 106.76 7,085.07 - 134.80 - 927.37 6,031,256.23 543,898.33 70° 29' 46.597 N 149° 38' 27.736 W 9,314.05 94.06 109.93 7,082.51 - 145.38 - 895.44 6,031,245.83 543,930.32 70° 29' 46.493 N 149° 38' 26.796 W 9,341.68 94.49 113.59 7,080.45 - 155.60 - 869.85 6,031,235.78 543,955.97 70° 29' 46.393 N 149° 38' 26.043 W 9,370.08 93.81 117.55 7,078.39 - 167.82 - 844.31 6,031,223.71 543,981.58 70° 29' 46.272 N 149° 38' 25.291 W 9,401.64 92.95 120.39 7,076.53 - 183.08 - 816.75 6,031,208.62 544,009.23 70° 29' 46.122 N 149° 38' 24.480 W 9,444.00 92.95 120.39 7,074.35 - 204.48 - 780.25 6,031,187.44 544,045.85 70° 29' 45.912 N 149° 38' 23.406 W TD - 2 -7/8" Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 7,985.00 7,145.37 3- 3/16" 2.875 4.125 9,444.00 7,074.35 2 -7/8" 2.875 4.500 Survey Annotations Measured Vertical Local Coordinates Depth Depth +N /S +E/ -W (ft) (ft) (ft) (ft) Comment � I 7,680.64 7,111.42 746.72 - 1,882.04 TIP 7,690.00 7,115.25 744.94 - 1,890.39 KOP 9,444.00 7,074.35 - 204.48 - 780.25 TD Checked By: Approved By: Date: 1 1/26/2010 10:02:23AM Page 4 COMPASS 2003.16 Build 71 Tree: 2 9/16" 5M WKM 1p M P L -02A Ori Elev. = 56.0' (N 27E) K Wellhead: 9 5/8" x 11" 5M CIW Pad Elev. = 21' 11" x 11" WKM tbg spool a WKM 11" x 2 7/8" Hgr w/ 2 7/8" EU 8rd 1. T &B thds & 2.5" CIW 'H' BPV profile 13 3/8" 48 #/ft , H -40 Weld + -80' Camco 2 -7/8" x 1" I 166' I sidepocket KBMM GLM Set. KOP @ 3,200' Max. hole angle = 33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 deg 9 5/8 ", 36 #/ft , J -55 BTC. 5,076' , , 2 7/8" 6.5 # /ft, L -80, EUE 8rd Tubing Camco 2 -7/8" x 1" (drift ID = 2.347 ", cap. = 0.0087 bpf) ' ` sidepocket KBMM GLM 7064' 7" 26 # /ft, L -80, BTC production casing drift ID = 6.182 , cap. = 0.0383 bpf) 2 -7/8" XN nipple 7207 I ( " p• f - p) (ID 2.250") 3 1/16" 6.2 # /ft, L -80, TC -II Liner (drift ID = 2.805 ", cap. = 0.0076 bpf) Pump, 137 -P -17 SXD 7219' I 2 3/8" 4.4 # /ft, L -80, STL Slotted Liner Gas Separator GRSFTX AR H6 7238' adavir (drift ID = 1.901 ", cap. = 0.0039 bpf) I ntake = 6764' TVD Illoraillit Tandem Seal Section ( 7243' Model GSB3DB UT /LT SB /SB PFSA Motor, Rerated to 165 HP, 7256' I Vielliiir 2133 volt, 43 amp, KMH NSW IMISMIS PumpMate XTO w/6 fin 1 7276' I Centralizer PumpMate = 6796' TVD 0 BOT PBR 80 -47 Seal Nipple) 7296' millullommulli BOT 7" x 4.5" S -3 Pkr ( 7344' I I 4.5" X Nipple ( 3.813" ID) 7378' Top of 3- 3/16" liner 7404' ' 4.5 " WLEG 3- 3/16" un- cemented Drill Liner to 7985' ► 12 -3/8" Deployment Sleeve 7909' 1 2 -3/8" Aluminum Billit w/ GS FN Top of Whipstock ( 7560' AL1 12 -3/8" slotted liner -.--- A lateral - 8192' - 9444' -AL2 AL1 lateral - 8100' - 9501' lateral - 7909' - 9492' 7" float collar 7,808' and 7" 26 #/ft float shoe 7,901' and DATE REV. BY COMMENTS MILNE POINT UNIT 11 05/28/96 JBF Rec by Nabors Nabors 27E 05 /30 /01 BMH RWO by Nabors 4 ES WELL L -2A, L1, L2 02/28/06 MDO ESP RWO Nabors 3 -S API NO: 50-029- 21998 -01 02/1/10 LH CTD Sidetrack - Nordic 2 02/28/10 LH Install ESP - Nabors 4ES BP EXPLORATION (AK) Tv BAK E 4 9J MIJGMES Baker Atlas PRINT DISTRIBUTION LIST COMPANY HP EXPLORATION (ALASKA) INC COUNI Y NORTH SLOPE BOROUGH WELL 'aNAME MPL -02A STATE ALASKA FIELD Milne Point Unit DATE 4/22/2010 THIS DISTRIBUTION LIST AUTHORIZED BY Donna Moss SO #: 2970157 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company STATE OF ALASKA - AOGCC Company 1 Person CHRISTINE MAHNKEN Person Address 333 W 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: Page 1 of I s • INTEQ Log & Data Transmittal Form e' C=E . 1 ti To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 EL a Attention: Christine Mahnken /011 , Reference: MPL -02A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) E s 6 i LAC Job #: 2970157 a` a c9O 4414 1 95 10k Sent by: Donna M Date: 04/22/10 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive BAKER Anchorage, Alaska 99518 IRIGINES Direct: (907) 267 -6612 1NTEQ FAX: (907) 267 -6623 • • c ro r; (n tr _ \ft °` SEAN PARNELL, GOVERNOR trk L V2.) Li ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ,' ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPL -02A BP Exploration (Alaska) Inc. Permit No: 209 -147 Surface Location: 3207' FSL, 5056' FEL, SEC.08, T13N, R10E, UM Bottomhole Location: 2949' FSL, 560' FEL, SEC. 07, T13N, R10E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel . Seamount, Jr. Chair DATED this i day of December, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASIL AND GAS CONSERVATION COMMON RECEIVED PERMIT TO DRILL 20 AAC 25.005 ?tilateral of work: . 1 b. Proposed Well Class: [� /' 11 lc. Specify if well is proposed for: 1 a. Type YPe p ®Development Oi 0 - Winj Single Zone ❑ Drill ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone takg4NiedAys Claksgenilift5ftil ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp AnchIIfl Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 • MPL -02A • 3. Address: 6. Proposed Depth: 12. Field / Pool(s): _ P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 9430' • TVD 7005'ss ., Milne Point Unit / Kuparuk 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): River Oil Pool • Surface: • ADL 025509 3207' FSL, 5056' FEL, SEC. 08, T13N, R10E, UM ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3951' FSL, 1565' FEL, SEC. 07, T13N, R10E, UM January 12, 2010 • Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2949' FSL, 560' FEL, SEC. 07, T13N, R10E, UM 2560 9120' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 56' ,, feet 15. Distance to Nearest Well Open Surface: x- 544825 • y- 6031397 • Zone- ASP4 GL Elevation above MSL: z.i ' ,.,qfe t to Same Pool: 735' • 16. Deviated Wells: Kickoff Depth: t 7 � 586 • feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 96 de Downhole: 3240. Surface: 2540 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4 - 1/8" 2 - 7/8" 6.5# L - 80 STL 1210' 8220' 7050'ss 9430' 7005'ss Uncemented Slotted Liner • 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 7936' 7346' None 7808' 7240' None Casing Length Size Cement Volume MD TVD Conductor / Structural 82' 13 -3/8" To Surface 82' 82' Surface 5076' 9-5/8" 367 Bbls PF 'E'. 112 Bbls Class 'G' 5076' 4950' Intermediate Production 7901' 7" 52 Bbls Class 'G' 7901' 7317' Liner Perforation Depth MD (ft): 7555' - 7738' Perforation Depth TVD (ft): 7030' - 7182' 20. Attachments: ❑ Property Plat = BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis I ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564 -4387 Printed Name .+`n M n Title Engineering Team Leader I° Prepared By Name/Number Signature • Phone 564 -4711 Date / /T /° ? Terrie Hubble, 564 -4628 Commission Use Only Permit T d Permit p va o rill . / API Number: c 1 Tip, . /7 /C ` Number:/ ` . �� 50- 02950-029418813-01-00 01 -00 �/ / 1 See cover letter for - other requirements I: If box is checked, not be used to lore for, test, or produce coalbed thane, gas hydrates, or gas contained shales: Conditions of Approval: bo ecked well may �- y xp p [K lo 9 Y 9 ,��� Other: SD � B Q P f f - � -- Samples Req'd: ❑ yes IJ No Mud Log Req'd: �❑ Y� Ly No 4?" 2 S OO p si, 4 n ti w /c S -/- (inwr.) H Measures: I Yes ❑ No Directional Survey Req'd: Q es ❑ No /Z■// i 7 m APPROVED BY THE COMMISSION 7 Date , COMMISSIONER Form 10-401 Revised 07/2009 This rmit is valid for 2 months from the date of approval (20 AAC 25.005(g)) Submit In Duplicate :I IrINIA L '� w..A SILr11 \I ('1 -- //2v•o7 i /� 1 • • To: Tom Maunder �bp Petroleum Engineer Alaska Oil & Gas Conservation Commission From: - Sean McLaughlin CTD Engineer Date: November 11, 2009 Re: Milne Point L -02A, L- 02AL1, and L -02AL2 PTD request Approval is requested for a permit to drill a multi - lateral CTD sidetrack from well Milne Point L -02. MPL - 02 was drilled 11/16/90 and completed as an "A" sand KUP producer. The well was frac'ed Nov 1990 with 185K# Carbolite behind pipe. The well is seeing some support from MPL -09i with a quick response time but not get getting good sweep. The well is currently online making low oil rate and high water cut. A tri- lateral (MPL -02A, AL1, and AL2) will be drilled to a more optimum location. The sidetracks, MPL -02A, AL1, and AL2, is scheduled to be drilled by Nordic 2 starting January 12, 2010 using the managed pressure drilling technique. The horizontal laterals will target Kuparuk Al, A2, and A3 reserves to . capture currently nonrecoverable resources. The perforations in the parent well will be abandoned with cement downsqueezed past the whipstock. The sidetrack lateral will exit the parent well at 7,560' and in the B shale and drill 3 laterals, each targeting a different "A" sand. Slotted liner will be run into each of the laterals. An aluminium . liner top billet will facilitate the kick off for the second and third laterals. A liner top packer and solid liner across the build /turn section will slow water production from near the parent well. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. Managed Pressure Drilling Technique The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits and will be independent of the BOPE choke. This well does not have a functioning tubing sub - surface safety valve that could be utilized to facilitate BHA deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe /slips (3" slip rams, see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected for the MPL -02 laterals: • Latest Reservoir pressure in the parent well: 2,353 psi at 7000' TVDSS, 6.5 ppg EMW. • • Expected pressure in the new lateral ranges from 2,353 to 3,240psi (6.5 ppg - 8.9 ppg). • • Expected annular friction losses while circulating: 450 psi at KOP and 620 psi at TD (assuming 90 psi /1000 ft, for a 2480' lateral). • Planned mud density: 8.8 ppg equates to 3200 psi hydrostatic pressure at the window. ' • While circulating 8.8 ppg fluid, at the start of the lateral, the bottom hole circulating pressure is estimated to be 3,650 psi or 10.0 ppg ECD. For shale stability an 10.0 EMW will be held while drilling, no back pressure will be applied at surface. • When circulation is stopped, a -450 psi surface pressure will be applied to maintain a constant BHP of 10 • ppg EMD. At the start of the lateral, the mud•e rig pits will be 8.8 ppg mud. KWF will •tored on location in upright tanks. The tankage will contain 2 wellbore volumes of KWF (11 ppg expected) to exceed the maximum possible BHP to be encountered as the lateral is drilled. CTD Sidetrack Summary Prior to drilling operations a workover rig will lay down the ESP completion and run a 4 -1/2" workstring. After the coil drilling unit is rigged down the workover rig will return to pull the kill string and rerun the ESP completion. Nabors 4ES RWO operations: The RWO is slated to begin about December 05, 2009. 1. MIRU. Test BOPE to 3500 psi. 2. Kill Well 3. Pull 2 -7/8" ESP completion 4. Perform a scraper run in the 7" csg 5. RIH with 7" test packer. Test 7" csg integrity to 2000 psi. 6. Run 4 -1/2" workstring with a 7" pkr and PBR. 7. RDMO to allow Nordic II to sidetrack well Pre -CT Rig Work: The pre CTD work is slated to begin immediately following the RWO. 1. Pull ball and rod 2. Pull RHC sleeve 3. Run dummy WS drift to 7,650' 4. Set Baker whipstock at 7,560' 5. Downsqueeze cement past whipstock, 20 bbls of 15.8 ppg cement 6. Drill mousehole extension Rig Sidetrack Operations: (Scheduled to begin on January 12, 2010 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7- 1/16" CT Drilling BOPE and test. 3. Mill 3.8" window in 7" liner from mechanical whipstock set at 7,560'. • 4. Drill build section with 4 -1/8" bicenter bit, and land well in target A sand. , 5. Drill lateral section to 9,430'. 1 �'"er 6. Run 2 -7/8" slotted liner with aluminum billet at 8220'. r , 7. Kick off billet and drill 2" lateral section to 9,430'. 8. Run 2 -7/8" slotted liner with aluminum billet at 8100'. 9. Kick off billet and drill 3 lateral section to 9,430'. 10. Run 2 -7/8" slotted x 3- 3/16" solid to 7,420'. 11. Run liner top packer 12. FP well to 2000'. 13. ND 7- 1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 2. Nabors 4ES RWO operations: The RWO is slated to begin after the sidetrack. 1. MIRU after Nordic II finishes 2. Test BOPE to 3500 psi. 3. Shear PBR and pull 4 -1/2" workstring 4. Run new ESP on 2 -7/8" tubing 5. RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Pull BPV. Mud Program: • Well kill: 8.4 ppg brine to start. Adjust with real time BHP monitoring. • Milling /drilling: 8.4 ppg Geo -VIS or biozan for milling, new 8.8 ppg Geo -VIS for drilling. • Standby KWF. At the start of the well there will be 2 wellbore volumes of 11.0 ppg KWF on location in upright tanks. Disposal: • All Class II drilling and completion fluids will go to Grind & Inject at DS 4, or to the KRU 1R pad disposal . well. • All Class II drilling solids will go to Grind & Inject at DS 4. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4 -1/8" bi- center hole for all laterals Casing Program: solid and cemented production liner • MPL -02A - 2 -7/8" slotted, L -80 6.50# STL 8,220' and - 9,430' and • MPL -02AL1 - 2 -7/8" slotted, L -80 6.50# STL 8,100' and - 9,430' and • MPL -02AL2 - 3- 3/16" solid, L -80 6.2# TCII 7,420' and - 8,000' and - 2 -7/8" slotted, L -80 6.50# STL 8,000' and - 9,430' and • No liner cement planned • A liner top packer will be run to stop annular flow. Well Control: • Two wellbore volumes of KWF ( -280 bbls) will be on location at all times during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 96 deg at 8,010'. • • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 9120 ft. • Distance to nearest well within pool - 735' from MPL -02 . Anti - Collision • There are no collision issues • Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section. Hazards • The maximum recorded H2S level on MPL -02 is 12 pprri. • The maximum recorded H2S level on MP L pad was 32 ppm on well MPL -03. (Oct 09). • Lost circulation risk is low. • Reservoir Pressure • The max reservoir pressure expected on MPL -02 is 3,240 psi at 7,000' TVDSS. (8.9 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi /ft) to surface is 2,540 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble W Tree: 2 ellhead: 13 5/8" x 11" 5M CIW M OZ Pad GL Elev. = 56.0' (N 'DGB' tbg spool w/ 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" I CIW 'H' BPV profile 13 3/8" 48 #/ft , H-40 Weld ' + -80 Set. Camco 2 -7/8" x 1" 168' KOP @ 3,200' sidepocket KBMM GLM Max. hole angle = 33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 deg. 9 5/8 ", 36 #/ft , J -55 Btrc. 5,076' 1 7" 26 # /ft, L -80, Btrc. production casing ( drift ID = 6.182 ", cap. = 0.0383 bpf ) J Camco 2 -7/8" x 1" J sidepocket KBMM GLM 7,253' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf) 7" RA TAG @ 7,288' 2 7/8" "XN" Nipp 7,392' Centrilift pump 151 Stage GC1700 / 19GC8200 7,406' GPMTAR 1:1 Tandem Gas Separator 7,431' j GRSFTXARH6 (400 Internal) Tandem Seal Section Stimulation Summary GSB3 DB UTABHSNPFSA 7,436 GSB3DBLTABHSNFSACL5 11/11/90 -185.3 M lbs. 16 / 20 Carbolite Centrilift 209 HP KMH 7,450' 2385 volt / 53 amp Perforation Summary _ ® Pumpmate w/6 fin Centralizer 7,470' Ref log: DIL / GR 03/03/90 Size SPF Interval (TVD) 4.5 5 7,555'- 7,209' - 5 7,614' 7,080' 4.5 5 7,654'- 7,112' - 5 7,680' 7,134' 4.5 7,686'- 7,139'- " 7,714' 7,162' 4.5 7,730'- 7,175' - 7,738' 7,181' I 7" float collar 7,808' and 7" 26 #/ft float shoe 7,901' and DATE REV. BY COMMENTS MILNE POINT UNIT 11 / 16 / 90 JBF Drilled and Completed by Nabors 27E WELL L -2 05 / 28 / 96 MDO Recompleted by Nabors 4 ES API NO: 50 -029 -21998 05 /30 /01 BMH RWO by Nabors 4 ES 02/28/06 MDO ESP RWO Nabors 3 -S BP EXPLORATION (AK) Tree: 2 9/16" 5M M P U L - 02 Ori Elev. = 56.0' (N 27E) Wellhead: 13 5/8" x 11" IW Pal, Elev. = 21' 'DGB' tbg spool w/ 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" EUE 8 Proposed CTD sidetrack rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 48 #/ft , H -40 Weld ' + -80 Set. KOP @ 3,200' Max. hole angle = 33.58' deg. f/ 7700' to TD' Hole angle thru' perfs = 33 deg. 9 5/8 ", 36 #/ft , J -55 Btrc. 5,076' 7" 26 # /ft, L -80, Btrc. production casing ( drift ID = 6.182 ", cap. = 0.0383 bpf ) 4 -1/2" Workstring Stimulation Summary 11/11/90 -185.3 M lbs. 16 / 20 Carbolite ) 4 -1/2" x 7 packer at 7360' X NIP (3.813" ID) at 7380' TOWS at 7560' Liner top packer at 7400' Perforation Summary 1 Top of liner at 7420' Ref log: DIL / GR 03/03/90 End of tubing at 7460' 8000' - 3- 3/16" uncemented liner A Size SPF Interval (TVD) 2 -7/8" slotted liner 4.5 5 7,555'- 7,209' - 5 7,614' 7,080' 4.5 5 7,654'- 7,112' - 5 7,680' 7,134' AL1 4.5 7,686'- 7,139'- " 7,714' 7,162' AL2 4.5 7,730'- 7,175'- A lateral - 7,560' - 9430' 7,738' 7,181' A - ' 9430' AL2 L1 lateral lateral - 8100 - 9430' 7" float collar 7,808' and 7" 26 #/ft float shoe 7,901' and DATE REV. BY COMMENTS MILNE POINT UNIT 11 / 16 / 90 JBF Drilled and Completed by Nabors 27E WELL L -2 05 / 28 / 96 MDO Recompleted by Nabors 4 ES API NO: 50 -029 -21998 05 /30 /01 BMH RWO by Nabors 4 ES 02/28/06 MDO ESP RWO Nabors 3 -S BP EXPLORATION (AK) • • All Measurements are from top of Riser 11/11/2009 CC M PL -02A top of bag r BAG 7 1/16" 5000 psi. bttm of bag middle of slips 1 Blind /Shears 1 TOTs middle of pipes I 3° slips 7 1/16" 5000psi l I middle of flow cross Mud Cross Mud Cross 7 1/16" 5000psi I I middle of blind /shears I variable bore pipe 3 1/2 " -2 3/8" TOTs middle of pipe /slips 2 -3/8" combi ram /slips 7 1/16" 5000psi 1 Swab Valve l J I 1 Flow Tee Mall Baker Hughes INTEQ emu 0 , NUGHU Baker Hughes INTEQ Planning Report by INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL -02 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling Well: MPL -02 North Reference: True Welibore: Plan 3, MPL -02A Survey Calculation Method: Minimum Curvature Design: Plan 3 Database: EDM 2003.16 Single User Db Survey Toot Program Date 11/12/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 7,500.00 1 : Schlumberger GCT multishot (MPL -02) GCT -MS Schlumberger GCT multishot L 7,500.00 9,430.00 Plan 3 (Plan 3, MPL -02A) MWD MWD - Standard Planned Survey MD Inc Az! TVDSS N/S ENV Northing Easting DLeg V. Sec TFace (ft) ( ( (ft) (ft) (ft) (ft) (ft) ( °i100ft) (ft) (°) 7,500.00 33.32 290.20 6,927.98 733.29 - 1,761.62 6,032,119.19 543,058.95 0.35 - 1,764.17 6.27 TIP 7,560.00 . 33.62 290.07 6,978.03 744.68 - 1,792.68 6,032,130.39 543,027.81 0.51 - 1,794.19 -13.49 KOP 7,580.00 35.42 290.07 6,994.51 748.57 - 1,803.33 6,032,134.21 543,017.15 9.00 - 1,804.47 0.00 End of 9 Deg /100' DLS 7,600.00 43.01 286.07 7,009.99 752.46 - 1,815.35 6,032,138.02 543,005.10 40.00 - 1,815.71 -20.00 7,610.00 46.85 284.48 7,017.07 754.31 - 1,822.16 6,032,139.84 542,998.28 40.00 - 1,821.84 -16.89 4 7,700.00 72.10 254.08 7,063.20 750.65 - 1,897.63 6,032,135.73 542,922.84 40.00 - 1,872.62 -55.00 7,710.00 75.23 251.48 7,066.01 747.81 - 1,906.79 6,032,132.83 542,913.70 40.00 - 1,877.09 -38.90 5 7,800.00 86.61 216.82 7,080.63 696.33 - 1,977.31 6,032,080.93 542,843.50 40.00 - 1,890.55 -75.00 7,810.00 88.03 213.08 7,081.10 688.14 - 1,983.03 6,032,072.71 542,837.83 40.00 - 1,888.81 -69.33 6 7,900.00 91.92 177.28 7,081.13 602.71 - 2,006.21 6,031,987.14 542,815.17 40.00 - 1,844.78 -84.00 8,000.00 95.34 137.34 7,074.53 512.49 - 1,968.56 6,031,897.16 542,853.36 40.00 - 1,754.37 -83.98 8,010.00 95.56 133.33 7,073.58 505.41 - 1,961.57 6,031,890.12 542,860.39 40.00 - 1,744.41 -86.62 End of 40 Deg /100' DLS 8,100.00 95.65 122.47 7,064.76 450.47 - 1,891.00 6,031,835.62 542,931.29 12.00 - 1,655.67 -89.00 8,160.00 95.60 115.24 7,058.88 421.67 - 1,838.73 6,031,807.14 542,983.72 12.00 - 1,598.35 -90.06 8 8,200.00 95.66 120.06 7,054.95 403.20 - 1,803.48 6,031,788.88 543,019.07 12.00 - 1,560.36 89.00 11/12/2009 2 :04 :44PM Page 3 COMPASS 2003.16 Build 71 ER ■ Baker Hughes INTEQ 0 , NYONIIIS Baker Hughes INTEQ Planning Report bP . INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL -02 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling Well: MPL -02 North Reference: True Wellbore: Plan 3, MPL -02A Survey Calculation Method: Minimum Curvature Design: Plan 3 Database: EDM 2003.16 Single User Db Planned Survey MD Inc Azi TVDSS NIS EIW Northing Easting DLeg V. Sec TFace (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (°hooft) (ft) ( °) 8,300.00 95.65 132.12 7,045.06 344.69 - 1,723.22 6,031,730.86 543,099.68 12.00 - 1,462.24 89.47 8,340.00 95.57 136.94 7,041.15 316.78 - 1,694.85 6,031,703.13 543,128.22 12.00 - 1,422.44 90.67 9 8,400.00 95.53 129.71 7,035.34 275.84 - 1,651.44 6,031,662.45 543,171.87 12.00 - 1,362.79 -90.00 8,460.00 95.40 122.48 7,029.63 240.67 - 1,603.21 6,031,627.58 543,220.31 12.00 - 1,303.82 -90.70 10 8,500.00 93.74 117.96 7,026.44 220.61 - 1,568.76 6,031,607.73 543,254.87 12.00 - 1,265.28 - 110.00 8,530.00 92.48 114.58 7,024.81 207.36 - 1,541.90 6,031,594.64 543,281.80 12.00 - 1,236.91 - 110.36 11 8,600.00 92.02 122.97 7,022.06 173.72 - 1,480.65 6,031,561.37 543,343.25 12.00 - 1,169.81 93.00 8,700.00 91.28 134.96 7,019.17 110.97 - 1,403.07 6,031,499.10 543,421.20 12.00 - 1,070.59 93.33 12 8,800.00 91.25 122.95 7,016.96 48.23 - 1,325.47 6,031,436.83 543,499.17 12.00 - 971.35 -90.00 8,900.00 91.17 110.95 7,014.84 3.00 - 1,236.52 6,031,392.14 543,588.39 12.00 - 876.47 -90.27 8,940.00 91.12 106.15 7,014.04 -9.72 - 1,198.61 6,031,379.65 543,626.36 12.00 - 840.67 -90.52 13 9,000.00 91.11 113.35 7,012.87 -29.98 - 1,142.19 6,031,359.74 543,682.90 12.00 - 786.45 90.0dh 9,100.00 91.06 125.35 7,010.96 -78.90 - 1,055.20 6,031,311.35 543,770.17 12.00 - 690.35 90.1 9,185.00 90.98 135.56 7,009.45 - 133.97 - 990.62 6,031,256.67 543,835.08 12.00 - 605.74 90.37 14 9,200.00 90.99 133.75 7,009.19 - 144.51 - 979.95 6,031,246.20 543,845.81 12.00 - 590.75 -89.60 9,300.00 91.04 121.75 7,007.41 - 205.62 - 901.05 6,031,185.57 543,925.08 12.00 - 491.74 -89.63 9,400.00 91.05 109.75 7,005.57 - 248.98 - 811.16 6,031,142.76 544,015.22 12.00 - 397.52 -89.84 9,430.00 91.05 106.15 7,005.02 . - 258.22 • - 782.63 , 6,031,133.69 544,043.80 12.00 - 370.81 -90.07 TD at 9430.00 - 2 7/8" 11/12/2009 2:04:44PM Page 4 COMPASS 2003.16 Build 71 Nimue. oTree Nod WELLBORE DETAILS: Plan 3, MPL -02A WFERENCENFORM0TI0N E.. . Project: MilnePoint Magnetic Nort 22.12 Site: M Pt L Pad Coadmate MiE)Re6renre' WeIMPL -02, Tim North Magnetic F a Parent Wellbore: MPL -02 BAKER Well: MPL -02 0 SBengt. 576516.11 )Erral(TW)Returence: Mean Sealevel / �, - „ Wellbore: Plan 3, MPL -02A Dip Angle eo.se° Tie on MD: 7500.00 aetoon(VS)Re6 slot00N0 le 9DZIS rence: - (0.,.0 MYVM� N Plan: Plana( MPL - 021PIan 3, MPL - 02A) Da Q 1/2 Mod MeasaedDeplh Reference, 2: 02 2211 990 0000@ 6.00n(genenc4Ning rig) Catulofion Method Mininum Curvature 1NTEQ 900 �'� 1i ,■■■■■..■ - -- WELL DETAILS. MPL -02 ii ii 11... 11..■■ Ground Level: 0.00 7pp ���, - 0S +.60 Easing Lattude Longitude Slot 111111911111111111.1 0.00 ,00 0.00 0.00 60313961396.60 544824.78 70° 29' 47.99 W 23 N 149° 38' 0.439 W � I • SECTION DETAILS ANNOTATIONS 600 , 500 , _`, Sec MD Inc Azi sTVD +39 761.00 DLeg TFace 64.17 Target Tn oha0o t '■�� 1.1111„11■ 1 7500.00 33.32 2 290.20 6927.98 733.29 1761.69 0.0.00 0.00 -1764.17 TIP 2 7560.00 33.62 290.07 6978.03 744.68 - 1792.68 0.51 -13.49 - 1794.19 KOP ✓ 400 , , 3 7580.00 35.42 290.07 6994.51 748.57 1803.33 9.00 0.00 •1804.47 End of9Deg 100 DLS "IN.I\ SII■■,,' 4 7610.00 46.85 284.48 706.01 754.31 - 1826.9 40.00 305.00 - 1877.9 4 ^ 300 '11 5 7710.00 75.23 251.48 7066.01 747.81 - 1906.779 40.00 305.00 - 1871.009 5 6 7810.00 88.03 213.08 7081.10 688.14 - 1983.03 40.00 285.00 - 1888.81 6 O 200 7 8010.00 95.56 133.33 7073.58 505.41 - 1961.57 40.00 276.00 - 1744.41 End of 40 Deg/100' DLS ' j 8 8160.00 95.60 115.24 7058.88 421.67 - 1838.73 12.00 271.00 - 1598.35 8 V E 9 8340.00 95.57 136.94 7041.15 316.78 -1694.85 12.00 70.00 -1422.44 9 v 100. ' ,`�. � ,■�� �� Iiii 10 8460.00 95.40 122.48 7029.63 240.67 - 1603.21 1 12.00 270.00 - 130303.82 10 I 1 1 11 8530.00 92.48 114.58 7024.81 207.36 - 1541.90 12.00 250.00 - 1236.91 11 0 0 - En r of 40 i 0 - • 11 lr 12 8100.00 91.28 134.96 7019.17 110.97 - 1403.07 12.00 93.00 - 1070.59 12 ■ . ■ „ ■' � s '.imppw 13 8940.00 91.12 106.15 7014.04 -9.72 -1198.61 12.00 270.00 - 840.67 13 \ r. 14 9185.00 90.98 135.56 7009.45 -133.97 - 780.63 12.00 90.00 -605.74 14 N - 200 ■ . .■■.� ,�: 2, ���I 15 9430.00 91.05 106.15 7005.02 -258.22 -78263 12.00 270.40 -370.81 TD at 9430.00 -300. .�11�....., 011 N1 q4 -400 4'430.1 -500 -600 1111 r. 1111. 1111 1111 1111.. 1111 -2200 -2100 •2000 -1900 -1800 -1700 -1600 -1500 -1400 •1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 West( - )/East( +) (100 ft/in) ::: 1111.1111 111..11.1111E1 111111 6885 ...IIE�. 11...11 Tr 6931 .1111 E M I R L- 02,4 I!�!� . 0. 6975, AB Deg/I11 ���,.. IC I 1 12 a) 7oz1 ... ... 9 �_ �I�� .1i i `e' 11. �.. .1 MI mo, . 1,�9F. 7065 _ ,■�■ • 7110 , NNW H , ,--�.11 7155 mi....uni,, 1t•. c > 7201 . i...11 1111... J 11 M P ..111.1 7245. 111i----- ---. -2025 -1980 -1935 -1890 -1845 -1800 -1755 -1710 -1665 -1620 •1575 •1530 -1485 -1440 -1395 -1350 -1305 -1260 •1215 -1170 -1125 -1080 -1035 -990 -945 -900 -855 -810 -765 -720 -675 -630 -585 -540 -495 -450 -405 -360 -315 -270 Vertical Section at 135.00° (45 ft/in) me • BPPASSPORT s ls Travelling Cylinder Report 0 by LNTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPL -02 Project: Milne Point TVD Reference: Mean Sea Level Reference Site: M Pt L Pad MD Reference: 2 : 02 2/21/1990 00:00 @ 56.00ft (generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: MPL -02 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Weltbore Plan 3, MPL -02A Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 3 Offset TVD Reference: Offset Datum Reference Plan 3 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,500.00 to 9,430.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,139.10ft Error Surface: Elliptical Conic Survey Tool Program Date 11/12/2009 From To (ft) (ft) Survey (Wei!bore) Tool Name Description 100.00 7,500.00 1 : Schlumberger GCT multishot (MPL -02) GCT -MS Schlumberger GCT multishot 7,500.00 9,430.00 Plan 3 (Plan 3, MPL -02A) MWD MWD - Standard Casing Points I Measured Vertical Casing Hole I Depth Depth Diameter Diameter I (ft) (ft) Name (in) (In) 9,430.00 7,005.01 2 7/8" 2.875 4.125 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Welibore - Design (ft) (ft) (ft) (ft) M Pt L Pad MPL -02 - MPL -02 - MPL -02 7,575.00 7,575.00 0.17 3.03 -2.62 FAIL - Major Risk MPL -02 - Plan 1, MPL -02AL1 - Plan 1 9,228.21 9,225.00 28.16 63.70 -20.65 FAIL - Major Risk MPL -02 - Plan 1, MPL -02AL2 - Plan 1 8,124.94 8,125.00 1.27 1.05 0.32 Pass - Major Risk MPL -03 - MPL -03 - MPL -03 Out of range MPL -04 - MPL -04 - MPL -04 Out of range MPL -05 - MPL -05 - MPL -05 Out of range MPL -13 - MPL -13 - MPL -13 Out of range MPL -15 - MPL -15 - MPL -15 Out of range MPL -270P1 Plan - MPL -270P1 Plan - MPL -270P1 Out of range MPL -34 - MPL -34 - MPL -34 Out of range MPL -35 - MPL -35 - MPL -35 Out of range MPL -35 - MPL -35A - MPL -35A Out of range MPL -35 - MPL -35A - Plan #7 Out of range MPL -35 - MPL- 35APB1 - MPL- 35APB1 Out of range MPL -35 - MPL - 35APB2 - MPL - 35APB2 Out of range MPL -35 - MPL- 35APB3 - MPL- 35APB3 Out of range MPL -36 - MPL -36 - MPL -36 Out of range MPL -36 - MPL -36PB1 - MPL -36PB1 Out of range MPL -36 - Plan MPL -36A - Plan #7 Out of range MPL -37 - MPL -37 - MPL -37 Out of range MPL -37 - MPL -37A - MPL -37A Out of range MPL -37 - Plan MPL -37B - MPL -37B WP 6.0 Out of range MPL -39 - MPL -39 - MPL -39 Out of range MPL -39 - Plan MPL -39A - MPL -39A wp03 Out of range MPL -39 - Plan #1(CTD) MPL -39A - Plan #1(CTD) Out of range MPL-40 - MPL-40 - MPL-40 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/13/2009 1:50:16PM Page 2 of 8 COMPASS 2003.16 Build 71 • • TRANSMITTAL LETTER CHECKLIST WELL NAME Milne Point Unit L -02A PTD# 2091470 X Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Milne Point POOL: Milne Point, Kuparuk Oil Pool Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 � ;, Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 UNIT KR L -02A Program DEV Well bore seg Well Name: MILNE PT ❑ PTD#: 2091470 Company BP EXPLORATION (ALASKA) INC Initial Class /Type DEV / PEND GeoArea 890 _ Unit 11328 - On /Off Shore On_ _ Annular Disposal ❑ Administration 1 Permit fee attached NA 1 2 Lease number appropriate Yes This redrill lies entirely within ADL 25509 3 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, govemed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 432C has no interwell spacing restrictions 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 432C has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes an external property line where ownership or landownership changes. 19 Operator only affected party - Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 11/19/2009 114 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 115 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 117 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in MPL -02 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in MPL -02 1 20 CMT vol adequate to circulate on conductor & surf csg NA Casing cemented to surface 1 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in MPL -02 122 CMT will cover all known productive horizons No OH slotted liner to be run 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re-drill, has a 10 -403 for abandonment been approved Yes 309 -392 - - 26 Adequate wellbore separation proposed Yes Proximity analysis performed . No issues. 1 27 If diverter required, does it meet regulations NA Wellhead already in place. BOP stack installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 3240 psi (8.9ppg) will drill with 8.8 ppg mud and use MPD technique - - GLS 11/20/2009 29 BOPEs, do they meet regulation Yes 1 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP =2540 psi Will test BOP to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 132 Work will occur without operation shutdown No Workover required to pull workstring and run new ESP completion after drilling complete. 33 Is presence of H2S gas probable Yes H2S present. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No MPU L -02 measured 12 ppm H2S. Measures are required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 6.5 to 8.9 ppg EMW; will be drilled using 8.8 ppg mud and Appr Date 37 Seismic analysis of shallow gas zones NA managed pressure drilling technique. SFD 11/19/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA I Geologic Engineering - • is Re- drilled Kuparuk producer to recover additional A -Sand reserves that are not accessible with existing wellbores. Commissioner: Date: C mission r: Date tner Date • 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. II I 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. • tapescan.txt * * ** REEL HEADER * * ** MWD 10/04/07 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 10/01/26 2970157 01 3" CTK * ** LIS COMMENT RECORD * ** 1111111111111111111 Remark File Version 1.000 111111 1111111111111 Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 7157.5000: Starting Depth STOP.FT 9443.7500: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPL -02A FLD . FIELD: Milne Point Unit LOC . LOCATION: 70 deg 29' 47.923 "N 149 deg 38' 0.439 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 26 Jan 2010 API . API NUMBER: 500292199801 Parameter Information Block #MNEM.UNIT Value Description SECT. 08 Section TOWN.N T13N Township RANG. R1OE Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 56.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 56.00 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 Dog -110- i 9 s�6 4 tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths ( TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger SGR DIL dated 03 Mar 1990 per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPL -02 through a milled window in a 7 inch liner. Top of window 7565 ft.MD (6981.9 ft.TVDSS) Bottom of window 7570 ft.MD (6986.7 ft.TVDSS) (9) Tied to MPL -02 at 7500 feet MD (6928.0 feet TVDSS). (10) Baker Hughes INTEQ runs 2 through 4 were used to drill and set a billet on MPL- 02APB1. (11) MPL- 02APB2 was drilled as a sidetrack from MPL- 02APB1 with a billet set at 7580 feet MD (6994.3 feet TVDSS). (12) Baker Hughes INTEQ runs 7, 8 and 10 were cleanout runs. (13) The interval from 7560 ft to 7690 ft MD (6978.8 ft to 7059.3 ft TVDSS) was logged 30 hours after drilling on run 9. (14) MPL -02A was drilled as an openhole accidental sidetrack off of MPL- 02APB2 at 7690 ft MD (7059.3 ft TVDSS). (15) No ROP data available from 7690 ft to 7721 ft MD (7059.3 ft to 7080.8 ft TVDSS) due to accidental sidetrack. (16) No resistivity data available from 7690 ft to 7985 ft MD (7059.3 ft to 7089.4 ft TVDSS) due to necessity to run liner immediately after the section was drilled. No resistivity tool was present on drilling BHA. (17) The interval from 7985 ft to 9444 ft MD (7089.4 ft to 7018.4 ft TVDSS) was drilled through a liner shoe using 2 3/8 inch CoilTrak tools. (18) The interval from 9417 ft to 9444 ft MD (7019.7 ft. to 7018.4 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP.AVG -> Rate of Penetration, feet /hour GRCX -> Gamma Ray Corrected (API) RACHX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 7165.47, 7164.76, ! - 0.717773 Page 2 • tapescan.txt 7172.83, 7172.47, ! - 0.358887 7176.6, 7176.06, ! - 0.538086 7180.54, 7179.83, ! - 0.717285 7183.95, 7182.52, ! - 1.43506 7192.92, 7191.85, ! - 1.07617 7200.1, 7199.2, ! - 0.896973 7206.02, 7205.66, ! - 0.358887 7215.71, 7215.53, ! - 0.179688 7224.98, 7225.34, ! 0.358887 7231.08, 7230.9, ! - 0.179688 7235.75, 7236.11, ! 0.358398 7240.95, 7241.31, ! 0.358887 7248.48, 7248.13, ! - 0.358398 7265.61, 7265.08, ! - 0.538574 7270.1, 7270.46, ! 0.358887 7273.33, 7273.15, ! - 0.179688 7284.09, 7282.48, ! - 1.61475 7287.68, 7286.78, ! - 0.896973 7291.75, 7291.75, ! 0 7299.83, 7300.54, ! 0.717285 7311.67, 7311.13, ! - 0.538086 7314, 7313.82, ! - 0.179688 7318.66, 7319.02, ! 0.358887 7325.3, 7325.84, ! 0.538574 7330.68, 7330.86, ! 0.179199 7342.52, 7339.47, ! - 3.0498 7346.82, 7343.95, ! - 2.87061 7350.77, 7347.9, ! - 2.87012 7353.64, 7354.18, ! 0.538086 7362.79, 7361.89, ! - 0.896973 7368.17, 7368.35, ! 0.179199 7374.27, 7374.45, ! 0.179688 7382.88, 7382.52, ! - 0.358887 7385.75, 7385.03, ! - 0.717773 7398.13, 7398.66, ! 0.538086 7401.35, 7401.89, ! 0.538086 7405.16, 7406.42, ! 1.25586 7406.06, 7408.21, ! 2.15283 7415.03, 7414.67, ! - 0.358887 7422.38, 7421.49, ! - 0.896973 7427.95, 7426.15, ! - 1.79395 7432.07, 7430.1, ! - 1.97363 7437.81, 7437.81, ! 0 7442.12, 7442.48, ! 0.358887 7452.52, 7452.35, ! - 0.179688 7459.11, 7459.11, ! 0 7461.8, 7461.62, ! - 0.179199 7469.69, 7468.26, ! - 1.43555 7478.13, 7477.59, ! - 0.538574 7486.02, 7485.84, ! - 0.179199 7488.53, 7488.35, ! - 0.179688 7494.81, 7494.81, ! 0 7496.42, 7496.96, ! 0.538574 7503.06, 7502.52, ! - 0.538086 7550.36, 7550.54, ! 0.179199 7553.95, 7553.06, ! - 0.896973 7557, 7556.64, ! - 0.358398 7560.05, 7559.16, ! - 0.897461 7564.36, 7565.08, ! 0.717285 7565.61, 7567.23, ! 1.61426 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Page 3 • S tapescan.txt Tape Subfile: 1 152 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schiumberger SGR DIL dated 03 Mar 1990 per Katie Nitzberg with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 GRC MWD 68 1 API 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 RPD MWD 68 1 OHMM 4 4 7 RPS MWD 68 1 OHMM 4 4 28 Total Data Records: 148 Tape File Start Depth = 7157.500000 Page 4 • tapescan.txt Tape File End Depth = 9445.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 2 162 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code samples Units size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 GRC MWD 68 1 API 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 RPD MWD 68 1 OHMM 4 4 7 RPS MWD 68 1 OHMM 4 4 28 Total Data Records: 295 Page 5 • tapescan.txt Tape File Start Depth = 7158.250000 Tape File End Depth = 9443.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 309 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 10/01/26 2970157 01 * ** REEL TRAILER * * ** MWD 10/04/07 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP GRC RAD RAS RPD RPS 7157.5000 72.3367 - 999.2500 52.1292 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7158.0000 65.4810 - 999.2500 47.1887 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7200.0000 60.0411 - 999.2500 43.2685 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7300.0000 41.9874 - 999.2500 30.2581 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Page 6 L a6Pd ZZ9Z'9T LS8£'£T 17b68'OT Z90S'OT OSTZ'LS 6£ZZ'96 LZLT'£8 0000'00176 8086'TZ ZL66'LT 808Z'ST Z060'£T 09Z5'ti£ 196£'901 1061'0S 0000'00£6 V006'61 95017'ST Z58Z'TT 8569'TT £1ti6'19 9169'18 b£b0'06 0000'00Z6 171ZT'iT 9001'171 ti99L'£T LZI£'LT ZZ178'Z6 ZOiZ'8TT b£96'ti£T 0000'0016 17S6b'Lti 6£8T'O£ 1661'L1 LOOS'LT VZ£T'917 9569'LTT ZZ90'L9 0000'0006 11£17'95 06L6'Tb 88917'8Z 95£8'SZ 0895'tib 966S'16 188L'i79 0000'0068 TiS6'OS TSZ6'9£ 0£L9'SZ OZBZ'£Z 66£L'Ob £L08'88 Z£ZZ'6S 0000'0088 OtZS'OZ L£65'bT £b09'6 T£SS'ZT £8VV'£L £8£9' LOLL'90T 0000'00L8 TBTZ'£T 9SL8'TT ZZ9Z'OT L£9L'OT Z606'9£ LZZ8'0ZT b1759'£S 0000'0098 0050'£T tS96'TT 6680'11 9S£6'0T Z6ZL'£i £6ZL'178 9895'£9 0000'0058 9869'91 Z£Z8'£T S18S'0T 86t6'ZT OOT£'08 LL6T'69 LStL'9TT 0000'00178 58LL'TT ZtIT'ZT 66170'ZT 809Z'9T 6S£Z'16 b£90'SZT 06Z9'Z£T 0000'00£8 9955'9L ZTZ6'T£ TOZB'bT ZSTO'ST TZ£Z'L£ b89T'b01 6£ZT'iS 0000'00Z8 TtZL'Lt LiOT'8Z TTOi'LT 8ILT'9T 8L09'0S 0£85'9ZT tSSI'£L 0000'0018 6Z8b'i79 9b££'Tti T8b£'ZZ b60L'£Z L0t'9'S£ L90£'£8 ZT£L'TS 0000'0008 00SZ'666 00SZ'666 005Z'666 005Z'666 TOVT'9ti OLL6'SZ 96£T'Z9 0000'006L 00SZ'666 00SZ'666 00SZ'666 00SZ'666 OLL8'08 88017'59 TZZ6'80T 0000'008L 00SZ'666 00SZ'666 00SZ'666 00SZ'666 L9TS'Z6 00SZ'666 0£ST'iZT 0000'OOLL T£OL'b 9SST'S ILiS'S £SL6'S Z£tL'Z6 £69Z'£T 69S17'17U 0000'009L 00SZ'666 00SZ'666 00SZ'666 00SZ'666 L986'6S 00SZ'666 OO17Z'£8 0000'OOSL 00SZ'666 00SZ'666 005Z'666 00SZ'666 8STS'Sb 00SZ'666 L6ST'£9 0000'00t'L lxl•uppsadP1 . . . . • tapescan.txt 9445.5000 - 999.2500 386.0815 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File start Depth = 7157.500000 Tape File End Depth = 9445.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP GRC RAD RAS RPD RPS 7158.2500 72.3367 - 999.2500 52.1292 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7158.5000 65.3514 - 999.2500 47.0953 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7200.0000 58.3661 - 999.2500 42.0614 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7300.0000 35.4545 - 999.2500 25.5502 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7400.0000 62.5573 - 999.2500 45.0818 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7500.0000 83.3035 - 999.2500 60.0325 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7600.0000 129.0050 14.1464 96.1323 5.6770 5.3366 4.9944 4.6007 7700.0000 117.3830 - 999.2500 87.4721 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7800.0000 96.4944 31.6935 71.6492 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7900.0000 60.7794 19.7981 45.1300 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8000.0000 54.9692 84.0766 37.8716 24.3309 23.6404 40.2566 57.7559 8100.0000 74.4662 141.0850 51.3043 16.4851 17.8867 28.7879 50.0742 8200.0000 50.5853 118.2094 34.7979 15.4877 14.8594 29.7721 60.7664 8300.0000 135.3680 122.6587 93.1204 16.2626 11.5256 11.7308 11.1520 8400.0000 123.8475 69.1335 85.1951 13.2893 11.1440 14.2777 17.3306 8500.0000 60.3339 83.3428 41.5040 11.0987 11.2485 12.2070 13.3773 Page 8 • tapescan.txt 8600.0000 54.7211 122.4661 37.6429 10.6149 10.0532 11.6160 12.6620 8700.0000 104.2762 73.3004 71.7321 12.5284 9.6768 14.1237 19.4538 8800.0000 59.7430 71.3920 41.0976 23.4418 26.4125 37.0989 52.4355 8900.0000 74.2181 92.4094 51.0550 27.7411 30.0579 40.2233 51.7634 9000.0000 61.2201 120.7134 42.1136 17.2373 17.1343 32.4769 54.9100 9100.0000 127.6870 107.3840 87.8368 17.2896 13.9641 14.2728 14.3886 9200.0000 92.5336 75.1150 63.6543 11.6363 11.1132 14.2728 17.3194 9300.0000 48.8129 102.0187 33.5786 13.1186 15.3611 18.2169 22.6037 9400.0000 63.5834 77.3920 43.7393 10.4074 10.8260 13.3857 16.6880 9443.7500 -999.2500 1476.6377 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 7158.250000 Tape File End Depth = 9443.750000 Tape File Level spacing = 0.250000 Tape File Depth units = feet D Tape Subfile 4 is type: LIS Page 9 ' I tapescan.txt * * ** REEL HEADER * * ** MWD 10/04/27 BHI 01 LIS Customer Format Tape * ** TAPE HEADER ** MWD 10/01/20 2970157 01 3" CTK * ** LIS COMMENT RECORD ** mmImmm1 1 1 1111111111 Remark File Version 1.000 1111111111 11 Extract File: ldwg.las —Version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 7158.0000: Starting Depth STOP.FT 8340.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPL- 02APB2 FLD . FIELD: Milne Point Unit LOC . LOCATION: 70 deg 29' 47.923 "N 149 deg 38' 0.439 "w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 20 Jan 2010 API . API NUMBER: 500292199871 Parameter Information Block # MNEM.UNIT Value Description SECT. 08 Section TOWN.N T13N Township RANG. R1OE Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 56.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 56.00 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 )9 6 y 3 tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger SGR DIL dated 03 Mar 1990 above the Kick off Point of 7567 ft MD per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPL -02 through a milled window in a 7 inch liner. Top of window 7565 ft.MD (6981.9 ft.TVD55) Bottom of window 7570 ft.MD (6986.7 ft.TVDSS) (9) Tied to MPL -02 at 7500 feet MD (6928.0 feet TVDSS). (10) Baker Hughes INTEQ runs 2 through 4 were used to drill and set a billet on MPL- 02APB1. (11) MPL -02A was drilled as a sidetrack from MPL- 02APB1 with a billet set at 7580 ft. MD (6994.3 ft. TVDSS). (12) Baker Hughes INTEQ runs 7 and 8 were cleanout runs. (13) The interval from 7560 ft. MD to 7908 ft. (6978.6 ft. to 7092.2 ft. TVDSS) was logged 40 hours after drilling run 9. (11) The interval from 8308 ft to 8340 ft MD (7071.0 ft. to 7069.3 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP_AVG -> Rate of Penetration, feet /hour GRCX -> Gamma Ray Corrected (API) RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (oHMM) RPCHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (oHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (oHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (oHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 7163.42, 7163.42, ! 0 7165.07, 7164.66, ! - 0.410645 7171.02, 7171.02, ! 0 7174.71, 7174.51, ! - 0.205078 7182.1, 7181.28, ! - 0.820801 7184.36, 7182.51, ! - 1.84717 7192.92, 7191.85, ! - 1.07617 7195.3, 7194.07, ! - 1.23145 7198.79, 7196.94, ! - 1.84717 7201.04, 7199.61, ! - 1.43701 7205.91, 7205.3, ! - 0.615723 7213.91, 7213.38, ! - 0.538574 7216.59, 7215.97, ! - 0.615723 7224.09, 7224.44, ! 0.358887 7225.3, 7225.91, ! 0.615723 Page 2 • 0 tapescan.txt 7231.4, 7230.78, ! - 0.615723 7235.76, 7235.97, ! 0.205566 7241.45, 7241.25, ! - 0.205566 7248.31, 7247.95, ! - 0.358887 7252.43, 7251.35, ! - 1.07666 7257.09, 7255.85, ! - 1.23145 7259.34, 7259.14, ! - 0.205078 7260.78, 7261.4, ! 0.615723 7265.53, 7264.81, ! - 0.717285 7270.55, 7270.55, ! 0 7272.89, 7272.07, ! - 0.820801 7279.11, 7277.31, ! - 1.79395 7283.95, 7282.7, ! - 1.25586 7285.62, 7284.59, ! - 1.02637 7287.54, 7287, ! - 0.538574 7291.85, 7292.03, ! 0.179199 7299.92, 7300.82, ! 0.896973 7308.89, 7308.89, ! 0 7313.56, 7314.18, ! 0.615723 7318.9, 7319.93, ! 1.02637 7322.39, 7324.65, ! 2.25781 7325.75, 7326.29, ! 0.538574 7329.7, 7329.16, ! - 0.538574 7330.87, 7330.87, ! 0 7339.96, 7339.42, ! - 0.538574 7342.13, 7343.56, ! 1.43652 7354.27, 7353.86, ! - 0.410645 7362.92, 7361.85, ! - 1.07617 7365.08, 7364.54, ! - 0.538086 7367.95, 7368.48, ! 0.538086 7370.05, 7370.46, ! 0.410645 7375, 7374.39, ! - 0.615723 7376.2, 7376.38, ! 0.179688 7381.04, 7380.68, ! - 0.358887 7383.02, 7382.48, ! - 0.538086 7386.88, 7386.47, ! - 0.410645 7395.09, 7394.89, ! - 0.205566 7398.58, 7398.79, ! 0.205078 7401.57, 7401.93, ! 0.358887 7406.38, 7408.02, ! 1.64209 7415.03, 7414.85, ! - 0.179688 7418.29, 7418.29, ! 0 7422.56, 7421.85, ! - 0.717285 7428.13, 7426.51, ! - 1.61475 7430.99, 7430.37, ! - 0.615723 7433.69, 7433.69, ! 0 7437.99, 7438.35, ! 0.358398 7439.98, 7440.81, ! 0.820801 7442.69, 7442.69, ! 0 7452.95, 7452.33, ! - 0.615723 7456.47, 7455.44, ! - 1.02588 7458.8, 7458.8, ! 0 7462.01, 7461.4, ! - 0.615723 7469.51, 7468.62, ! - 0.896973 7474.54, 7473.82, ! - 0.717773 7477.82, 7477.41, ! - 0.410645 7481, 7481, ! 0 7483.15, 7483.51, ! 0.358887 7486.23, 7486.03, ! - 0.205566 7488.17, 7488.53, ! 0.358887 7495.17, 7494.81, ! - 0.358398 7497, 7497.2, ! 0.205566 7503.06, 7502.52, . - 0.538086 Page 3 • tapescan.txt 7556.87, 7556.69, ! - 0.179688 7559.92, 7559.2, ! - 0.717773 7561.9, 7561.69, ! - 0.205566 7563.92, 7564.53, ! 0.615723 7565.35, 7566.59, ! 1.23145 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 165 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** 111111II! Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger SGR DIL dated 03 Mar 1990 above the Kick off Point of 7567 ft MD per Katie Nitzberg with BP Exploration (A * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 one depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 GRCX MWD 68 1 API 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 RPD MWD 68 1 OHMM 4 4 Page 4 • tapescan.txt 7 RPS MWD 68 1 OHMM 4 4 28 Total Data Records: 77 Tape File Start Depth = 7158.000000 Tape File End Depth = 8341.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet ** FILE TRAILER * * ** Tape subfile: 2 91 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** 1111111 111111111111 Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 one depth per frame (value= 0) Datum Specification Block sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 GRCX MWD 68 1 API 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 Page 5 . . tapescan.txt 6 RPD MWD 68 1 OHMM 4 4 7 RPS MWD 68 1 OHMM 4 4 28 Total Data Records: 153 Tape File Start Depth = 7157.750000 Tape File End Depth = 8340.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Tape subfile: 3 167 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 10/01/20 2970157 01 * * ** REEL TRAILER * * ** MWD 10/04/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP GRCX RAD RAS RPD RPS 7158.0000 71.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Page 6 1 410 III tapescan.txt 7158.5000 66.3000 - 999.2500 0.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8341.0000 - 999.2500 14.7344 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 7158.000000 Tape File End Depth = 8341.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP GRCX RAD RAS RPD RPS 7157.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7158.0000 71.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8340.0000 - 999.2500 13.2000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 7157.750000 Tape File End Depth = 8340.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS Page 7 411 411 tapescan.txt * * ** REEL HEADER * * ** MWD 10/04/26 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * ** MWD 10/01/16 2970157 01 3" CTK * ** LIS COMMENT RECORD * ** 11111111 Remark File Version 1.000 1111111111111 111111 Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 7158.0000: Starting Depth STOP.FT 8529.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPL- 02APB1 FLD . FIELD: Milne Point Unit LOC . LOCATION: 70 deg 29' 47.923 "N 149 deg 38' 0.439 "w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 16 Jan 2010 API . API NUMBER: 500292199870 —Parameter Information Block #MNEM.UNIT Value Description SECT. 08 Section TOWN.N T13N Township RANG. R10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation of Perm. Datum LMF . DF Log Measured from FAPD.F 56.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 56.00 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 009 - Iu4 19 tog 1 tapescan.txt CASE.F N/A Casing Depth 051 . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger SGR DIL dated 03 Mar 1990 above the Kick off Point of 7567 ft MD per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPL -02 through a milled window in a 7 inch liner. Top of window 7565 ft.MD (6981.9 ft.TVDSS) Bottom of window 7570 ft.MD (6986.7 ft.TVDSS) (9) Tied to MPL -02 at 7500 feet MD (6928.0 feet TVDSS). (10) The interval from 7553 ft. MD to 8043 ft. (6972.1 ft. to 7087.2 ft. TVDSS) was logged 20 hours after drilling run 3. (11) The interval from 8497 ft to 8529 ft MD (7062.7 ft. to 7066.3 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP _AVG -> Rate of Penetration, feet /hour GRCX -> Gamma Ray Corrected (API) RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 7163.42, 7163.42, ! 0 7165.07, 7164.66, ! - 0.410645 7171.02, 7171.02, ! 0 7174.71, 7174.51, ! - 0.205078 7182.1, 7181.28, ! - 0.820801 7184.36, 7182.51, ! - 1.84717 7192.92, 7191.85, - 1.07617 7195.3, 7194.07, ! - 1.23145 7198.79, 7196.94, ! - 1.84717 7201.04, 7199.61, ! - 1.43701 7205.91, 7205.3, ! - 0.615723 7213.91, 7213.38, ! - 0.538574 7216.59, 7215.97, ! - 0.615723 7224.09, 7224.44, ! 0.358887 7225.3, 7225.91, ! 0.615723 7231.4, 7230.78, ! - 0.615723 7235.76, 7235.97, ! 0.205566 7241.45, 7241.25, ! - 0.205566 7248.31, 7247.95, ! - 0.358887 7252.43, 7251.35, ! - 1.07666 Page 2 411 410 tapescan.txt 7257.09, 7255.85, ! - 1.23145 7259.34, 7259.14, ! - 0.205078 7260.78, 7261.4, ! 0.615723 7265.53, 7264.81, ! - 0.717285 7270.55, 7270.55, ! 0 7272.89, 7272.07, ! - 0.820801 7279.11, 7277.31, ! - 1.79395 7283.95, 7282.7, ! - 1.25586 7285.62, 7284.59, ! - 1.02637 7287.54, 7287, ! - 0.538574 7291.85, 7292.03, ! 0.179199 7299.92, 7300.82, ! 0.896973 7308.89, 7308.89, ! 0 7313.56, 7314.18, ! 0.615723 7318.9, 7319.93, ! 1.02637 7322.39, 7324.65, ! 2.25781 7325.75, 7326.29, ! 0.538574 7329.7, 7329.16, ! - 0.538574 7330.87, 7330.87, ! 0 7339.96, 7339.42, ! - 0.538574 7342.13, 7343.56, ! 1.43652 7354.27, 7353.86, ! - 0.410645 7362.92, 7361.85, ! - 1.07617 7365.08, 7364.54, ! - 0.538086 7367.95, 7368.48, ! 0.538086 7370.05, 7370.46, ! 0.410645 7375, 7374.39, ! - 0.615723 7376.2, 7376.38, ! 0.179688 7381.04, 7380.68, ! - 0.358887 7383.02, 7382.48, ! - 0.538086 7386.88, 7386.47, ! - 0.410645 7395.09, 7394.89, ! - 0.205566 7398.58, 7398.79, ! 0.205078 7401.57, 7401.93, ! 0.358887 7406.38, 7408.02, ! 1.64209 7415.03, 7414.85, ! - 0.179688 7418.29, 7418.29, ! 0 7422.56, 7421.85, ! - 0.717285 7428.13, 7426.51, ! - 1.61475 7430.99, 7430.37, ! - 0.615723 7433.69, 7433.69, ! 0 7437.99, 7438.35, ! 0.358398 7439.98, 7440.81, ! 0.820801 7442.69, 7442.69, ! 0 i 7452.95, 7452.33, ! - 0.615723 7456.47, 7455.44, ! - 1.02588 7458.8, 7458.8, ! 0 7462.01, 7461.4, ! - 0.615723 7469.51, 7468.62, ! - 0.896973 7474.54, 7473.82, ! - 0.717773 7477.82, 7477.41, ! - 0.410645 7481, 7481, ! 0 7483.15, 7483.51, ! 0.358887 7486.23, 7486.03, ! - 0.205566 7488.17, 7488.53, ! 0.358887 7495.17, 7494.81, ! - 0.358398 7497, 7497.2, ! 0.205566 7503.06, 7502.52, ! - 0.538086 7556.87, 7556.69, ! - 0.179688 7559.92, 7559.2, ! - 0.717773 7561.9, 7561.69, ! - 0.205566 7563.92, 7564.53, ! 0.615723 7565.35, 7566.59, . 1.23145 Page 3 1 tapescan.txt EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 160 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** 11111 111111 1 1 Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger SGR DIL dated 03 Mar 1990 above the Kick off Point of 7567 ft MD per Katie Nitzberg with BP Exploration (A * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 one depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples units size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 GRCX MWD 68 1 API 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 RPD MWD 68 1 OHMM 4 4 7 RPS MWD 68 1 OHMM 4 4 28 Total Data Records: 89 Page 4 tapescan.txt Tape File Start Depth = 7158.000000 Tape File End Depth = 8530.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Tape subfile: 2 103 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** IIIIMMI!IIII Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 GRCX MWD 68 1 API 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 RPD MWD 68 1 OHMM 4 4 7 RPS MWD 68 1 OHMM 4 4 28 Page 5 f tapescan.txt Total Data Records: 177 Tape File Start Depth = 7158.000000 Tape File End Depth = 8529.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 191 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 10/01/16 2970157 01 * * ** REEL TRAILER * * ** MWD 10/04/26 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP GRCX RAD RAS RPD RPS 7158.0000 71.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7158.5000 66.3000 - 999.2500 0.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8530.0000 - 999.2500 37.1098 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Page 6 II tapescan.txt Tape File Start Depth = 7158.000000 Tape File End Depth = 8530.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP GRCX RAD RAS RPD RPS 7158.0000 71.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 7158.2500 67.6000 - 999.2500 2.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8529.0000 - 999.2500 35.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File start Depth = 7158.000000 Tape File End Depth = 8529.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet 0 Tape subfile 4 is type: LIS Page 7
