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Home My WebLink About200-0661. 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: Convert to Rev. Circ. Jet Pump 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,790' N/A Casing Collapse Conductor N/A Surface 2,570psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT F-81 MILNE POINT KUPARUK RIVER OIL N/A 7,193' 12,701' 7,105' 2,564 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12/15/2025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 200-066 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22959-00-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 110' 110' 6.5# / L-8 0/ EUE 8rd TVD Burst 12,148' MD N/A 8,430psi 3,950psi 7,240psi 4,153' 6,830' 7,192' 7,515' 12,422' 110' 20" 9-5/8" 7" 7,515' 4-1/2"558' 12,422' Perforation Depth MD (ft): 12,789' See Schematic See Schematic 2-7/8" 7'' x 2 7/8 DL & ZXP and N/A 3,814 MD / 2,876 TVD & 12,231 MD / 6,641 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:39 pm, Oct 10, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.10.10 12:16:02 - 08'00' Taylor Wellman (2143) 325-620 MGR05NOV2025 10-404 * BOPE test to 3000 psi. Annular to 2500 psi. 24 hour notice. * Approved for reverse circulating jet pump w/ open shoe on OA. * AOGCC witnessed SSSV/SSV performance test required within 5 days after POP. * Power fluid SSV low pressure trip will be set to 50% of header pressure * Production SSV high pressure trip will be set to 1100 psi * Production SSV low pressure trip will set to 25% of flowing tubing pressure or 50% of first vessel pressure (whichever is greater) * SSV closure on IA will initiate closure within 2 minutes on SSV on production tubing and visa versa. A.Dewhurst 30OCT25 DSR-10/15/25JLC 11/5/2025 11/06/25 RWO Convert to JP Well: MPF-81 Date: 08/04/2025 Well Name:MPU F-81 API Number:50-029-22959-00-00 Current Status:ESP producer Rig:ASR 1 Estimated Start Date:12/15/2025 Estimated Duration:7 days Reg.Approval Reqd?Yes Date Reg. Approval Recvd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:200-066 First Call Engineer:Ryan Lewis 303-906-5178 Second Call Engineer:Taylor Wellman 907-947-9533 Current Bottom Hole Pressure:3,259 psi @ 6,950 TVD 8/13/25 9.1# MWE 9.3# KWF Max. Anticipated Surface Pressure:2,564 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.205 @ 11,999 XN Nipple Brief Well Summary and Objective MPU F-81 was completed in August 2000 initially targeting the Kuparuk A2 sands. The well was completed with an ESP which has been replaced eight times, with an average run life of 604 days. The early failures from 2000-2005 were caused by the pump seizing due to sand production. After the A1 and A3 sands were perforated in 2005 the ESPs predominantly failed due to a combination of frac proppant and sand. The last ESP was run on 3/7/2021 and ran until 2/1/2023 when the ESP apparently lost stages and/or tbg holes resulting in reduced performance. The ESP lost gauges readings after 4 month and grounded electrically in July 2025. Notes on Well Condition Tubing caliper ran on 3/28/23 showed 30-50% wall loss from 0-5,000 MD. MIT-IA 1,500 psi passed on 8/8/2023 Pre-Rig Procedure (Non-Sundried steps) Slickline & 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. RU SL. Pressure test to 3,000 psi. 6. Set 2-7/8 XX-plug in X-nip 7. Pull DGLV from STA#3 8. Circulate at least one wellbore volume with 9.3# brine down tubing, taking returns up casing to 500 barrel returns tank. IA above the packer is killed. 9. Set DGLV in STA#3 10. Pull DGLV from STA#2 11. Bullhead down tbg out STA#2 and down the IA taking returns to formation as needed to establish and maintain a full column of 9.3# brine. IA below the packer is killed 12. Set DGLV in STA#2 13. Pull 2-7/8 XX-plug in X-nip 14. Bullhead down the TBG 15. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 16. RD Little Red Services and reverse out skid. RWO Convert to JP Well: MPF-81 Date: 08/04/2025 17. Set BPV. ND tree. NU BOPE. Procedure (Sundried steps) RWO 18. MIRU ASR and ancillary equipment. 19. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/9.3# brine prior to setting CTS. 20. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams and annular on 2-7/8 and 4-1/2 test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 21. Pull CTS plug. Bleed any pressure off casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well with 9.3# brine as needed. 22. MU landing joint or spear and BOLDS. 23. POOH with 2-7/8 tubing. a. 2023 ASR PU weight was 74k, SO was 33K. b. Packer is 30K shear to release. 24. Rig up ESP spooler. 25. POOH and lay down the 2-7/8 ESP completion and 3/8 capstring. a. Wash and inspect all joints for re-use. b. Keep gas lift mandrels and nipple for reuse. c. Make sure to account for all clamps below: i. 209 Canon Clamps ii. 7 - Protectorlizers iii. 1 - 2-7/8" half clamp iv. 1 - Flat Guard v. 4 - 4" Cannon Mid-Clamps (Mid. Each Pump) vi. 1 - 4" Cannon Mid-Clamp on PVV 26. PU new 4-1/2 Jet Pump Completion and RIH. Nom. Size ~Length Item Lb/ft Material 4.5 10WLEG Pup Joint at ~12,200 MD 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 XN Nip with RHC profile 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 7 X 4-1/2 Premier Packer 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 40 Joint 4-1/2 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 BHPG Geo PSI 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 Sliding Sleeve 12.6 L-80 RWO Convert to JP Well: MPF-81 Date: 08/04/2025 4.5 10'Pup Joint 12.6 L-80 4.5 Joints 12.6 L-80 4.5 4-1/2 5k 3.813 X Profile TR-SSSV ~2,20012.6 L-80 4.5 Space out PUPS 12.6 L-80 4.5 1 Joint 12.6 L-80 4.5 PUP 12.6 L-80 4.5 Tubing Hanger 12.6 L-80 27. Space out and land the hanger. a. Note PU and SO weights on tally. 28. RILDS and lay down landing joint. 29. Reverse Circulate and spot a 100 bbl pill of corrosion inhibited water across the packer swapping over to FP for the final 46 bbls of displacement. 30. Drop ball and rod and complete loading tubing with FP and hydraulically set the packer as per Vendor setting procedure. 31. Bleed off the tubing to 1000psi. Perform MIT-IA to 3650 psi for 30 minutes charted. 32. Set CTS. 33. RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU 4-1/16 tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. Pull CTS. 5. MIRU SL. 6. RIH and pull ball & rod and RHC plug. 7. Open SS and install JP. 8. RD crane. Move 500 bbl returns tank and rig mats to next well location. 9. Turn well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Schematic * Safety valve system performance test required within 5 days of POP. - mgr _____________________________________________________________________________________ Revised By: TDF 9/5/2023 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790 (MD) / TD = 7,193(TVD) 20 Orig DF Elev.= 27.4 / Orig. GL Elev. = 11 7 5 4 8 9 & 10 11, 12, 13 & 14 15 9 20 21 22 23 9-5/8 1 3 24 KUP A Sands PBTD =12,701(MD) / PBTD = 7,105(TVD) 7 4-1/2 2 KUP C Sands 16 & 17 18 19 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,515 7" Production 26 / L-80 / Hydril 563 6.276 Surface 12,422 4-1/2 Liner 12.6 / L-80 / IBT Mod 3.958 12,231 12,789 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.441 Surface 12,148 3/8 Capstring Stainless Steel N/A Surface 12,148 JEWELRY DETAIL No Depth Item 1 385 GLM #4: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 2 1,004 TAM Port Collar 3 3,759 GLM #3: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 4 3,814 7'' x 2 7/8 DL Packer Assembly pinned @ 30K Shear Release 5 3,870 GLM #2: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 6 3,929 X Nipple w/RHC-M Installed 7 11,909 GLM #1: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 8 11,999 HES XN-Nipple ID= 2.205 9 12,051.8' Discharge Head: B/O PMP 400 2.88X8 EUE CS 10 12,052 Zenith Ported Sub: HEAD S/A B/O PRESS PORT 400P 11 12,053 Pump #4: 400PMSSD FLEX7 ER 108 H6 12 12,072 Pump #3: 400PMSSD FLEX7 ER 108 H6 13 12,091 Pump #2: 400PMSXD 069 MVPER H6 FER 14 12,104 Pump #1: 400PMSXD 024 GINPSHL HS 416SS 15 12,114 Gas Separator: 400 GSEV MT H6 16 12,118 Upper Tandem Seal: GS3, B/B/L , SB, H6, PFSA HL FER 12CRC 17 12,125 Lower Tandem Seal: GS3, B/B/L , SB, H6, PFSA HL FER 12CRC 18 12,132 Motor: 562XP series CS 150 HP /2420V/38A 06R 19 12,143 Motor gauge w/ 6 Fin Centralizer Bottom 12,148 20 12,231 Baker ZXP Packer 21 12,245 Baker HMC Liner Hanger 22 12,422 7, 26#, L-80 BTC Shoe 23 12,702 4.5 Float Collar (PBTD) 24 12,789 4.5 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477 12,491 6,884 6,898 14 3/11/2015 3-3/8/6spf / Open Kup. A3 Sands 12,530 12,540 6,896 6,936 10 6/6/2005 3-3/8/6spf / Open Kup. A2 Sands 12,550 12,570 6,956 6,975 20 6/21/2000 2.5/ 6spf / Open Kup. A2 Sands 12,550 12,570 6,956 6,975 20 6/23/2000 3-3/8/ 6spf / Open Kup. A1 Sands 12,581 12,591 6,986 6,996 10 6/7/2005 3-3/8/ 6spf / Open Kup. A1 Sands 12,591 12,605 6,996 7,010 14 8/6/2023 3-1/8/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30 Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class G in 12-1/4 Hole 7 Cmt w/ 156 sks Class G in 8-1/2 Hole 4-1/2 Cmt w/ 79 sx Class G in 6-1/8 Hole WELL INCLINATION DETAIL KOP @ 554 Max Hole Angle = 75 deg. @ 8,832 Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16 FLS Wellhead 11 x 11 5M FMC Gen 5A, w 11 x / 2-9/16 NSCT. 2.5 CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES 8/12/2000, 1/30/2001 & 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES 6/9/2005 RWO & ESP Completion w/ Nabors 3S 7/19/2007, 1/5/2008 & 4/3/2009 ESP RWO & Add Capstring by Nordic #3 3/12/2015 ESP RWO & Add Packer by Doyon 14 3/7/2021 _____________________________________________________________________________________ Revised By: TDF 10/10/2025 PROPOSED Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790 (MD) / TD = 7,193(TVD) 20 Orig DF Elev.=27.4/ Orig. GL Elev. = 11 7 5 4 7 8 9 10 9-5/8 1 3 11 KUP A Sands PBTD =12,701(MD) / PBTD = 7,105(TVD) TAM Port Collar @ 1,004 MD 4-1/2 2 KUP C Sands 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,515 7" Production 26 / L-80 / Hydril 563 6.276 Surface 12,422 4-1/2 Liner 12.6 / L-80 / IBT Mod 3.958 12,231 12,789 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / JFE Bear 3.958 Surface ±12,200 JEWELRY DETAIL No Depth Item 1 ±2,200 4-1/2 5k 3.813 X Profile TR-SSSV 2 ±XX,XXX Sliding Sleeve 3 ±XX,XXX BHPG Geo PSI 4 ±XX,XXX 7'' x 4-1/2 Premier Packer 5 ±XX,XXX XN-Nipple with RHC Profile 6 ±XX,XXX Wireline Entry Guide: Btm @ ±12,200 7 12,231 Baker ZXP Packer 8 12,245 Baker HMC Liner Hanger 9 12,422 7, 26#, L-80 BTC Shoe 10 12,702 4.5 Float Collar (PBTD) 11 12,789 4.5 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477 12,491 6,884 6,898 14 3/11/2015 3-3/8/6spf / Open Kup. A3 Sands 12,530 12,540 6,896 6,936 10 6/6/2005 3-3/8/6spf / Open Kup. A2 Sands 12,550 12,570 6,956 6,975 20 6/21/2000 2.5/ 6spf / Open Kup. A2 Sands 12,550 12,570 6,956 6,975 20 6/23/2000 3-3/8/ 6spf / Open Kup. A1 Sands 12,581 12,591 6,986 6,996 10 6/7/2005 3-3/8/ 6spf / Open Kup. A1 Sands 12,591 12,605 6,996 7,010 14 8/6/2023 3-1/8/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30 Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class G in 12-1/4 Hole 7 Cmt w/ 156 sks Class G in 8-1/2 Hole 4-1/2 Cmt w/ 79 sx Class G in 6-1/8 Hole WELL INCLINATION DETAIL KOP @ 554 Max Hole Angle = 75 deg. @ 8,832 Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16 FLS Wellhead 11 x 11 5M FMC Gen 5A, w 11 x / 2-9/16 NSCT. 2.5 CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO& ESP Completion w/ Nabors 4-ES 8/12/2000, 1/30/2001 & 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES 6/9/2005 RWO & ESP Completion w/ Nabors 3S 7/19/2007, 1/5/2008 & 4/3/2009 ESP RWO & Add Capstring by Nordic #3 3/12/2015 ESP RWO & Add Packer by Doyon 14 3/7/2021 Milne Point ASR Rig 1 BOPE 2025 Updated 7/31/2025 11 BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR 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 HCRManualManualManual Stripping Head STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT F-81 JBR 09/28/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 2 7/8" Test Joint, Manual Choke Valve C1 failed was changed out and passed test. 12 each Precharge bottles all 1000psi each. Test Results TEST DATA Rig Rep:J. WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:M. Heinz-Brown Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2000660 DATE:8/5/2023 Type Operation:WRKOV Annular: 250/3000Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopBDB230808070914 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 2895 Sundry No: 323-392 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 2 7/8"x5"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/16"P HCR Valves 1 3 1/16"P Kill Line Valves 3 3 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1825 200 PSI Attained P18 Full Pressure Attained P56 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2225 ACC Misc NA0 P PTrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P16 #1 Rams P7 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 99 9 9 9999 9 9 Manual Choke Valve C1 failed FP 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 Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,790 feet N/A feet true vertical 7,193 feet N/A feet Effective Depth measured 12,701 feet 3,759 & 12,231 feet true vertical 7,105 feet 3,825 & 6,641 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 12,148' 6,559' DL Packer Packers and SSSV (type, measured and true vertical depth)ZXP 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: Wells Manager Contact Phone: 7,500psi 3,950psi 7,240psi 8,430psi 12,422' 6,830' Burst N/A Collapse N/A 2,570psi 5,410psi 558' Casing Conductor 7,192'12,789' 12,422' 7,515'Surface Production Liner 20" 9-5/8" 7" 110' 7,515' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-066 50-029-22959-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025509 & ADL0388235 Milne Point Unit / Kuparuk River Oil MILNE PT UNIT F-81 Plugs Junk measured Length 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) 82 Gas-Mcf MD 110' 420 Size 110' 4,153' 1114 4806 70 342188 332 323-197 & 323-392 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 5 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 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:07 am, Sep 06, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.09.05 15:01:25 - 08'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: TDF 9/5/2023 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790 (MD) / TD = 7,193(TVD) 20 Orig DF Elev.= 27.4 / Orig. GL Elev. = 11 7 5 4 8 9 & 10 11, 12, 13 & 14 15 9 20 21 22 23 9-5/8 1 3 24 KUP A Sands PBTD =12,701(MD) / PBTD = 7,105(TVD) 7 4-1/2 2 KUP C Sands 16 & 17 18 19 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,515 7" Production 26 / L-80 / Hydril 563 6.276 Surface 12,422 4-1/2 Liner 12.6 / L-80 / IBT Mod 3.958 12,231 12,789 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.441 Surface 12,148 3/8 Capstring Stainless Steel N/A Surface 12,148 JEWELRY DETAIL No Depth Item 1 385 GLM #4: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 2 1,004 TAM Port Collar 3 3,759 GLM #3: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 4 3,814 7'' x 2 7/8 DL Packer Assembly pinned @ 30K Shear Release 5 3,870 GLM #2: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 6 3,929 X Nipple w/RHC-M Installed 7 11,909 GLM #1: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 8 11,999 HES XN-Nipple ID= 2.205 9 12,051.8' Discharge Head: B/O PMP 400 2.88X8 EUE CS 10 12,052 Zenith Ported Sub: HEAD S/A B/O PRESS PORT 400P 11 12,053 Pump #4: 400PMSSD FLEX7 ER 108 H6 12 12,072 Pump #3: 400PMSSD FLEX7 ER 108 H6 13 12,091 Pump #2: 400PMSXD 069 MVPER H6 FER 14 12,104 Pump #1: 400PMSXD 024 GINPSHL HS 416SS 15 12,114 Gas Separator: 400 GSEV MT H6 16 12,118 Upper Tandem Seal: GS3, B/B/L , SB, H6, PFSA HL FER 12CRC 17 12,125 Lower Tandem Seal: GS3, B/B/L , SB, H6, PFSA HL FER 12CRC 18 12,132 Motor: 562XP series CS 150 HP /2420V/38A 06R 19 12,143 Motor gauge w/ 6 Fin Centralizer Bottom 12,148 20 12,231 Baker ZXP Packer 21 12,245 Baker HMC Liner Hanger 22 12,422 7, 26#, L-80 BTC Shoe 23 12,702 4.5 Float Collar (PBTD) 24 12,789 4.5 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477 12,491 6,884 6,898 14 3/11/2015 3-3/8/6spf / Open Kup. A3 Sands 12,530 12,540 6,896 6,936 10 6/6/2005 3-3/8/6spf / Open Kup. A2 Sands 12,550 12,570 6,956 6,975 20 6/21/2000 2.5/ 6spf / Open Kup. A2 Sands 12,550 12,570 6,956 6,975 20 6/23/2000 3-3/8/ 6spf / Open Kup. A1 Sands 12,581 12,591 6,986 6,996 10 6/7/2005 3-3/8/ 6spf / Open Kup. A1 Sands 12,591 12,605 6,996 7,010 14 8/6/2023 3-1/8/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30 Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class G in 12-1/4 Hole 7 Cmt w/ 156 sks Class G in 8-1/2 Hole 4-1/2 Cmt w/ 79 sx Class G in 6-1/8 Hole WELL INCLINATION DETAIL KOP @ 554 Max Hole Angle = 75 deg. @ 8,832 Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16 FLS Wellhead 11 x 11 5M FMC Gen 5A, w 11 x / 2-9/16 NSCT. 2.5 CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES 8/12/2000, 1/30/2001 & 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES 6/9/2005 RWO & ESP Completion w/ Nabors 3S 7/19/2007, 1/5/2008 & 4/3/2009 ESP RWO & Add Capstring by Nordic #3 3/12/2015 ESP RWO & Add Packer by Doyon 14 3/7/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Fullbore 50-029-22959-00-00 200-066 7/24/2023 8/11/2023 7/21/2023 - Friday No operations to report. 7/19/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/20/2023 - Thursday No operations to report. No operations to report. No operations to report. 7/22/2023 - Saturday T/I/O=690/937/0 (Well Kill) Pumped 20 bbls of 90* diesel followed by 85 bbls of 90* 10.3 ppg brine w/ Low Torque down TBG up IA taking returns to tank. Not getting good returns. Swap to IA and bullheaded 360 bbls 10.3 ppg brine. Freeze protected surface lines with 3 bbls 60/40. Let well settle over night. Final Whps= 206/246/5. 7/25/2023 - Tuesday 7/23/2023 - Sunday No operations to report. 7/24/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 Upon derrick inspection, the wear plate the topdrive rides on, at the top and bottom sections on the upper, lower half of the mast are cracked. Upon further inspection more cracks on the wear plates observed. Prep rig to weld / grind out welds. Rig on dw time. Rig rate reduced to labor only. Welding completed on wear plates at 17:00. Waiting 24 hr for complete bonding, then proceed with inspection of the mast. Continue Rig work on F-pad. Received fluid for well work (10.5 ppg NACL / NABR) in pits & upright tank. Change hydraulic oil. Change hydraulic HP filters & return filters. Replace rig floor insulation panel. Rig rate reduced to labor only. 7/29/2023 - Saturday 7/30/2023 - Sunday Awaiting inspection of mast welds. Fill IA w/ 20 bbls of 10.5 ppg brine. IA on a vacuum. Check pressure & fill nitrogen pre- charge bottles on accumulator. Cont. w/ maintenance & cleaning. Inspection complete of derrick. Mobilize rig to F-pad. Spot rig on mud boat & level out. Raise derrick, tighten guy lines. Install rack pins. Install stairs to rig floor. Nipple up spacer & flow spools. Complete rig acceptance checklist. Rig accepted at 00:00 on 7/30/23. Pressure up accumulator, ensure function. Fill pits w/ fresh water. Flood stack & purge lines. Pressure up for shell test. Pressure test BOPE as per approved sundry. AOGCC waived witness to test. Test t/ 250 psi low & 3,000 psi high F/ 5/5 charted mins. 7/28/2023 - Friday Remove flow/ spacer spools, place on floor. Prep to lay derrick on head ache rack. Install rack pins, Knife over & lay derrick on head ache rack. Raise jacks, Road rig to A Pad. Remove Kommey line, gen cables & comms. Spot in crane. On F-81 stab BOPE on wellhead & torque. Remove floor & cellar. Mobilize rig to F-81. Fly heater & HCR hoses. Load out equipment on trucks & send to F-81 Stow pit landing, Hook truck to pits. Move off well. N/D BOPE on F-09, remove 11 x 7 adapter. ON F-09 Install tree and test void. For 500 low & 5000 PSI high F/ 5min &10 min high (Good test) ALS rep. Tested ESP (good). On F-81 Spot in Crane. Set mud boat, set cellar, rig floor. Back in pits & set dw. Remove truck. R/U landing, fly stairs & attach. Fly Flow/ spacer spools to rig floor. Set on BOPE & N/U. Spot in HCR lines. Rig continuing w/ maintenance on A-pad. 7/26/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/27/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 Hilcorp Alaska, LLC Weekly Operations Summary POOH w/ jet cut 2-7/8" 6.5# L-80 EUE tubing F/ 2,150' T/ surface. L/D ESP PKR secure cap lines & ESP cable. Recovered 15.83' tubing. Placing cut at 3907', Rack & tally 3-1/2" workstring. Simops; L/D man basket from rig floor for welding. Remove ESP L/D equip. P/U fishing BHA, 5-3/4" overshot, XO, bumper sub, HYD. JARS, 6x 4-1/4" DC, accelerator. RIH w/ over shot fishing BHA on 3-1/2" workstring F/ 218' T/ 3986'. Tagged fish adjusted w/ ORKB indicates cut ESP completion traveled 93' downhole. P/U off fish tag f/ 3,986'. Kelly up obtain parameters. PU wt = 32 k S/O wt = 21. ROT wt = 28 at 60 RPM w/1000 ft/lbs TQ. AT 1 BPM w/ 60 PSI wash over fish to dress off flared cut. applying 1k down on tubing stub, TQ increased to 1.4K ft/lbs after dressing 1 ft. Stop rotary & attempt to engage grapple. Set 20k dw on tubing stub. P/U no over pull. P/U wt = 38k. Cont. to dress off & engage grapple with state parameters. 3x Cont. to attempt to engage grapple, no issues picking up off fish, no over pull at any time. Increase set down wt on grapple to 33K. No fish. Possible damaged grapple. POOH to inspect. POOH w/ over shot fishing BHA on 3-1/2" workstring F/ 3,986' T/ 218'. Pressure test BOPE as per approved sundry. AOGCC waived witness to test. Test t/ 250 psi low & 3,000 psi high F/ 5/5 charted mins. Perform accumulator drawdown test. R/D testing equip. Remove fresh water from pits. Fill gas buster & lock out valve. Prep to pull hanger. Hang ESP cable sheave, M/U kelly hose. Install TIW to landing JT & P/U landing JT. Engage hanger. Pull CTS & BPV w/ tee bar. Rig service. Check equip. fluid levels. BOLDS. Open IA , well static. P/U to shear release PKR. P/U to 40K hanger offseat. Cont. to P/U to 60K. Cont. to P/U in 5K increments up to max pull of 125K. Obtain approval to P/U T/ 129K on 2-7/8" L-80 TBG. PKR not release. Cont. to work pipe to 128K, while mobilizing e-line to Jet cut TBG. R/U E-line, hang sheave & P/U Jet cut tool string; CH, CCL, Cent, 1x WB, cent, SS, Jet cut. RIH w/ Jet cutter to 3790'. Unable to pass. POOH to drop one centralizer & add WB. Reconfigure tool string. CH, CCL, 2x WB, cent, SS, Jet cut. RIH correlta CCL log to well tubing tally. Jet cut at 3,907'. In middle of first full joint below X nipple. R/D E-line. R/U kelly hose & P/U landing JT. Hanger off seat at 25K. P/U to 88K PKR released. Free P/U wt = 28K. Pump a surf. to surf. for a total of 163 bbls at 3 BPM at 500 PSI. dynamic loss rate = 20 BPH. Shut dw monitor well. Static. Pull hanger to floor. Cut ESP cable & cap lines from hanger. Rig service. Check equip. fluid levels. Run ESP cable over sheave & cap lines while POOH slowly. Remove ropes. Tie back cap lines & ESP cable to respected spooling units. POOH w/ jet cut 2-7/8" 6.5# L-80 EUE tubing F/ 3,907' T/ 2,150'. 8/1/2023 - Tuesday 7/31/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 8/4/2023 - Friday Continue POOH w/ clean-out BHA F/ 5,900' T/ 386'. L/D BHA, all equipment accounted for and in good condition. Shut down and check equipment. P/U YJOS 7" AS1X Test Packer and RIH on 3-1/2", 10.37#, G-105, NC31, R3 Worksting to 5,018'. Cont. RIH to 9,622'. Up weight 61k, down weight 28k. Shut down and check equipment. Cont. RIH to 12,170'. Up weight 93k, down weight 36k. Set 7" AS1X Test Packer, line up to test. Install gauge on OA. Fill hole. Close Rams. Begin testing Casing to 1650psi. Good Test. POOH w/ Test Packer F/ 12,170'. 8/2/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary POOH w/ 2-7/8" 6.5# L-80 EUE tubing & ESP completion F/ 6,300 T/ 3,117' while pumping 1x displacement. Safety meeting. Check fluids & inspect handling equipment. POOH w/ 2-7/8" 6.5# L-80 EUE tubing & ESP completion F/ 3,117' to Discharge head. TBG pulled wet from XN Nipple down. L/D ESP assy. Top Motor seized, BTM Pump oil was dirty but rotated freely. Recovered what appears to be piece from Jet Cutter and 3 Packer pieces in Motor Clamps. RECOVERED 208 CC Clamps, 5 Protectolizers, 2 Flat Guard Clamps. Discharge Head and pup blockage of scale buildup. Clean and clear rig floor. Switch over handling equipment. R/D Elephant trunk. Rack and Tally BHA & W/S. M/U BHA 3.75" Bit, Bit Sub, 13 Joints of 2-7/8",7.90#, P110, PH6 Work String 2ea 5-1/2" Boot Baskets, 7" Casing Scraper, Bumper Jars, Oil Jars, 6ea 4- 1/4" Drill Collars, Accelerator Jars. Shut down and check equipment. RIH w/ Cleanout BHA T/ 3,200'. 8/3/2023 - Thursday RIH w/ 3.75" Bit, Bit Sub, 13 Joints of 2-7/8",7.90#, P110, PH6 Work String 2ea 5-1/2" Boot Baskets, 7" Casing Scraper, Bumper Jars, Oil Jars, 6ea 4-1/4" Drill Collars, Accelerator Jars. F/ 3,200' T/ 9,261 while filling hole w/ 5 BBLS every 3 hours. RIH w/ BHA through Liner Top without issue T/ 12,366' (above perfs). Swivel up. Reverse Circulate well w/ 107 BBLS of 10.4ppg Brine. Bring pump on at 2.5bpm @300psi. Returns established w/ 5bbls away. Increase rate to 4bpm @ 900psi. Shut down pump. Well swapped to10.2ppg fluid during reverse circ. Pump 50bbls 10.4ppg down W/S taking returns up 6". Well returned to static losses. Continue RIH and tag fill at 12,586' ORKB. Swivel up. Clean out F/ 12,586' T/ 12,626'. Circulate 260bbls of 10.4ppg brine 5bpm @ 2000psi. At 260bbls, returns coming back at 9.7ppg. Shut down pumping. Pits 3&4 had been reduced to 10.1 & 10.0ppg. Transfer pits 3&4 to Tiger Tank. 110bbls total. Refill pits w/ 10.4ppg. Begin circulating 10.4ppg down W/S while taking returns to Tiger Tank checking return weight. Circulated 70bbls before 10.4ppg returned. Switch back to pits and continue pumping until returns were clean. Circulated 330bbls total. POOH from 12,626' to 11,046'. Reciprocated Scraper F/ 12,180' to 12,150'. 80k up and 32k down. Perform Kick while Tripping Drill. Shut down and check equipment. Continue POOH w/ BHA F/ 11,046' T/ ~5,900 while pumping 1x displacement. Continue POOH w/ YJOS 7" AS1X Test Packer and RIH on 3-1/2", 10.37#, G-105, NC31, R3 Work sting T/ 5,219'. Continue OOH F/ 5,219' to Surface. L/D Packer. Prepare to test BOP test and E-Line. Install TBG Hanger w/ TWC. P/U 2-7/8" Test Mandrel and Lower into BOP. Lock in Pipe Rams and fill with fresh water from water truck. AOGCC Rep. Brian Bixby witnessing - Fire and Gas Alarms, Test BOP Shell, Mud Cross, Choke/Kill Manifold Valves to 250psi low, 3,000psi high for 5 minutes each charted. C1 failed. Performed Choke bleed-off & Accumulator Drawdown. 16 second Annular close time, 58 second Full Charge. Blow down underneath Blind Rams. Prep for E-Line while continuing with BOP process. 23:37 E-Line arrives. Remove and replace the "C-1" Valve. Fill with fluid, test Blinds and HCR 250psi low, 3,000psi high - good test. Test Blind Rams and "C-1" Valve 250psi low, 3,000psi high - good test. Move Pipe racks, R/U E-Line crane, "Gilroy Wireline Riser", PCE to Rig Floor, Assemble and prepare to test against. Pressure test E-Line PCE 250psi low, 3,000psi high. Good test. Drain fluid from PCE, break connection at Quick Test Sub. MU E-Line Perforating Guns. 8/5/2023 - Saturday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 Hilcorp Alaska, LLC Weekly Operations Summary Continue testing PVV Line to 5000psi. Good, Bleed pressure to 500psi and verify valve closes. Continue RIH after Packer Splice. Test ESP every 1000' - 9301', 10,335', 11,011. Shut down and service rig. RIH from 11,011' to 11,195'MD. Swap Chemical Injection Spools. Continue RIH to 12,112' MD. MU TBG HNGR. Terminate Chem. Inj,, PVV, ESP though Hanger. Pressure up to 5000psi / 5min - Good. Bleed to 1000psi to land Hanger. ESP electrical checks - Good. Final PUW = 74,000#, SOW = 33,000#. Land Hanger (all pressures good), RILDS. Completion landed @ 12,147.97' ORKB. Unable to monitor ESP as the ambilocal cable will not fit beside the TBG O.D. Drop B&R (8.70' OAL) Hook up hose to pump down TBG. 1.5bbls to fill TBG. Pressure up TBG to 1200psi and see Packer start to set. Continue up to 3500psi & hold for 15min. Bleed to zero & Pressure back up to 3500psi for 5min. Bleed TBG & PVV to zero. Perform step-rate (50psi/min) to pressure up IA to 1500psi. Chart record 30min test. During MIT-IA, TBG and OA remained at 0psi - GOOD TEST. Install BPV, Release Rig. RIH testing every 1000', pumping 5bbls every 3hrs. rearrange job and tighten motor on cap line spool. Continue tripping to ESP splice, CC clamp installed on bottom and top of jt 189 @ 6032'. Reel to reel ESP splice. Clean floor and location. Shut down and check fluids. Continue Splice. Continue RIH w/ ESP completion testing every 1000' from 6063' to 8,320'. Install X- Nipple w/ RHC-M & GLM #2. P/U Tripoint DLESP Packer. Perform ESP Cable and Chemical Injection Line feedthroughs. Initial ESP cut for Penetrator was too long causing cable slack to hang out further that the OD of the Packer. Procedure was not followed. Cut termination, pull slack out of cable and re-terminate. Purge, connect and test Chemical Injection line. Continue working on upper Penetrator splice. Spot in Mud Boat & Rig Mats at L-13. Connect ESP Cable above Packer. Purge and connect PVV control line. Pressure up on PVV and see opening, unable to determine actual opening pressure due to pump output being erratic. Continue up to 5000psi for test. ESP Cable test after Penetrator - Good. Testing PVV line to 5000psi. 8/8/2023 - Tuesday 8/6/2023 - Sunday RIH w/ YJOS GR-CCL, 3-1/8" GEO Razor 6 SPF 60Deg Phase 14' Guns. Correlate with survey, verify w/ John Salsbury. Perforate Kuparuk A1: 12,591' - 12,605' MD. Pump through Mud Cross to monitor well. 10bbl loss in 45min. POOH w/ E-Line guns. RD Wireline Valves, Sheaves, Gilroy Riser, Pull Hanger w/ Landing Joint, Swap Elevators. Rig up equipment to run 2-7/8" EUE ESP Completion. Shut down and check fluids. Spot in Pipe Racks. Fill hole w/ 4.5bbls 10.5ppg Brine. Rack and Tally 2-7/8" EUE Tubing. Spot in ESP Cable spooler and cap line spoolers. PU Motor & Seals, Service. Hang Sheaves. Tie in ESP. Purge and test Chemical Injection - open Injection valve with 4,800psi. MU Gas Seperator, Pumps, and Discharge Head. Installed 7ea. Protectolizers, 1ea. Flat Guard, 4ea. 4" Cannon Clamps in middle of each Pump. Keep 500psi on Chem. Line while RIH. Perform Electrical on ESP system - Good. RIH w/ 2-7/8",9.3#, L, EUE R2 ESP Completion. 1JT, XN-Nipple 2.205" No-Go, 2jts, Patco GLM#1 w/ Dummy Valve. Install Over-the-collar Clamp every connection first 15, every other connection after that. Shut down and check equipment. RIH w/ 2-7/8",9.3#, L, EUE R2 ESP Completion from 751' MD to 1,100' Check ESP electrically - Good. Pump Displacement 1x. RIH from 1,100' to 1,990' MD. Check ESP electrically - Good. Pump Displacement 1x. Continue RIH to 3,070' Check ESP electrically - Good. Pump Displacement 1x. 8/7/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 8/11/2023 - Friday RIG UP COMPLETE, PT W/ TRI-PLEX, 300 LOW, 1500 HIGH, GOOD TEST, RIH W/ 2.2" CENT. 2" JUC, LATCH B&R @ 3,899' SLM, POOH. RIH W/ 2-7/8" GS, LATCH RHC @ 3,908' SLM, JAR A COUPLE TIMES, CAME FREE, POOH. OOH, SIBP, REDRESS & PIN UP RHC, BEGIN RIGGING DOWN. 8/9/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD: BOP stack pulled, remove CL and clean tbg hgr void. Install RX54 gasket, (2) CL seal subs and seal sub for bore. PU tree/adapter, set and torque to spec. Test 500/5000 5 and 10 min (PASS), bleed off void and pull Bpv with T bar. All valves in closed position. Install tree cap. 8/10/2023 - Thursday No operations to report. No operations to report. No operations to report. 8/12/2023 - Saturday No operations to report. 8/15/2023 - Tuesday 8/13/2023 - Sunday No operations to report. 8/14/2023 - Monday 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 Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,790 feet N/A feet true vertical 7,193 feet N/A feet Effective Depth measured 12,701 feet 3,759 & 12,231 feet true vertical 7,105 feet 3,825 & 6,641 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 12,148' 6,559' DL Packer Packers and SSSV (type, measured and true vertical depth)ZXP 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: Wells Manager Contact Phone: 7,500psi 3,950psi 7,240psi 8,430psi 12,422' 6,830' Burst N/A Collapse N/A 2,570psi 5,410psi 558' Casing Conductor 7,192'12,789' 12,422' 7,515'Surface Production Liner 20" 9-5/8" 7" 110' 7,515' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-066 50-029-22959-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025509 & ADL0388235 Milne Point Unit / Kuparuk River Oil MILNE PT UNIT F-81 Plugs Junk measured Length 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) 82 Gas-Mcf MD 110' 420 Size 110' 4,153' 1114 4806 70 342188 332 323-197 & 323-392 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 5 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 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:20 pm, Sep 05, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.09.05 15:01:25 - 08'00' Taylor Wellman (2143) RBDMS JSB 091123 DSR-9/12/23WCB 4-9-2024 _____________________________________________________________________________________ Revised By: TDF 9/5/2023 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 5 4 8 9 & 10 11, 12, 13 & 14 15 9 20 21 22 23 9-5/8” 1 3 24 KUP A Sands PBTD =12,701’(MD) / PBTD = 7,105’(TVD) 7 4-1/2” 2 KUP C Sands 16 & 17 18 19 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.276 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.958 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.441 Surface 12,148’ 3/8” Capstring Stainless Steel N/A Surface 12,148’ JEWELRY DETAIL No Depth Item 1 385’ GLM #4: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 2 1,004’ TAM Port Collar 3 3,759’ GLM #3: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 4 3,814’ 7'' x 2 7/8 DL Packer Assembly pinned @ 30K Shear Release 5 3,870’ GLM #2: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 6 3,929’ X Nipple w/RHC-M Installed 7 11,909’ GLM #1: 2 7/8 X 1'' Side pocket,w/Dummy & BK Latch 8 11,999’ HES XN-Nipple – ID= 2.205” 9 12,051.8' Discharge Head: B/O PMP 400 2.88X8 EUE CS 10 12,052’ Zenith Ported Sub: HEAD S/A B/O PRESS PORT 400P 11 12,053’ Pump #4: 400PMSSD FLEX7 ER 108 H6 12 12,072’ Pump #3: 400PMSSD FLEX7 ER 108 H6 13 12,091’ Pump #2: 400PMSXD 069 MVPER H6 FER 14 12,104’ Pump #1: 400PMSXD 024 GINPSHL HS 416SS 15 12,114’ Gas Separator: 400 GSEV MT H6 16 12,118’ Upper Tandem Seal: GS3, B/B/L , SB, H6, PFSA HL FER 12CRC 17 12,125’ Lower Tandem Seal: GS3, B/B/L , SB, H6, PFSA HL FER 12CRC 18 12,132’ Motor: 562XP series CS 150 HP /2420V/38A 06R 19 12,143’ Motor gauge w/ 6 Fin Centralizer Bottom 12,148’ 20 12,231’ Baker ZXP Packer 21 12,245’ Baker HMC Liner Hanger 22 12,422’ 7”, 26#, L-80 BTC Shoe 23 12,702’ 4.5” Float Collar (PBTD) 24 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10 6/7/2005 3-3/8”/ 6spf / Open Kup. A1 Sands 12,591’ 12,605’ 6,996’ 7,010’ 14 8/6/2023 3-1/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000, 1/30/2001 & 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007, 1/5/2008 & 4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 ESP RWO & Add Packer by Doyon 14 – 3/7/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Fullbore 50-029-22959-00-00 200-066 7/24/2023 8/11/2023 7/21/2023 - Friday No operations to report. 7/19/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/20/2023 - Thursday No operations to report. No operations to report. No operations to report. 7/22/2023 - Saturday T/I/O=690/937/0 (Well Kill) Pumped 20 bbls of 90* diesel followed by 85 bbls of 90* 10.3 ppg brine w/ Low Torque down TBG up IA taking returns to tank. Not getting good returns. Swap to IA and bullheaded 360 bbls 10.3 ppg brine. Freeze protected surface lines with 3 bbls 60/40. Let well settle over night. Final Whps= 206/246/5. 7/25/2023 - Tuesday 7/23/2023 - Sunday No operations to report. 7/24/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 Upon derrick inspection, the wear plate the topdrive rides on, at the top and bottom sections on the upper, lower half of the mast are cracked. Upon further inspection more cracks on the wear plates observed. Prep rig to weld / grind out welds. Rig on dw time. Rig rate reduced to labor only. Welding completed on wear plates at 17:00. Waiting 24 hr for complete bonding, then proceed with inspection of the mast. Continue Rig work on F-pad. Received fluid for well work (10.5 ppg NACL / NABR) in pits & upright tank. Change hydraulic oil. Change hydraulic HP filters & return filters. Replace rig floor insulation panel. Rig rate reduced to labor only. 7/29/2023 - Saturday 7/30/2023 - Sunday Awaiting inspection of mast welds. Fill IA w/ 20 bbls of 10.5 ppg brine. IA on a vacuum. Check pressure & fill nitrogen pre- charge bottles on accumulator. Cont. w/ maintenance & cleaning. Inspection complete of derrick. Mobilize rig to F-pad. Spot rig on mud boat & level out. Raise derrick, tighten guy lines. Install rack pins. Install stairs to rig floor. Nipple up spacer & flow spools. Complete rig acceptance checklist. Rig accepted at 00:00 on 7/30/23. Pressure up accumulator, ensure function. Fill pits w/ fresh water. Flood stack & purge lines. Pressure up for shell test. Pressure test BOPE as per approved sundry. AOGCC waived witness to test. Test t/ 250 psi low & 3,000 psi high F/ 5/5 charted mins. 7/28/2023 - Friday Remove flow/ spacer spools, place on floor. Prep to lay derrick on head ache rack. Install rack pins, Knife over & lay derrick on head ache rack. Raise jacks, Road rig to A Pad. Remove Kommey line, gen cables & comms. Spot in crane. On F-81 stab BOPE on wellhead & torque. Remove floor & cellar. Mobilize rig to F-81. Fly heater & HCR hoses. Load out equipment on trucks & send to F-81 Stow pit landing, Hook truck to pits. Move off well. N/D BOPE on F-09, remove 11 x 7 adapter. ON F-09 Install tree and test void. For 500 low & 5000 PSI high F/ 5min &10 min high (Good test) ALS rep. Tested ESP (good). On F-81 Spot in Crane. Set mud boat, set cellar, rig floor. Back in pits & set dw. Remove truck. R/U landing, fly stairs & attach. Fly Flow/ spacer spools to rig floor. Set on BOPE & N/U. Spot in HCR lines. Rig continuing w/ maintenance on A-pad. 7/26/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/27/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 Hilcorp Alaska, LLC Weekly Operations Summary POOH w/ jet cut 2-7/8" 6.5# L-80 EUE tubing F/ 2,150' T/ surface. L/D ESP PKR secure cap lines & ESP cable. Recovered 15.83' tubing. Placing cut at 3907', Rack & tally 3-1/2" workstring. Simops; L/D man basket from rig floor for welding. Remove ESP L/D equip. P/U fishing BHA, 5-3/4" overshot, XO, bumper sub, HYD. JARS, 6x 4-1/4" DC, accelerator. RIH w/ over shot fishing BHA on 3-1/2" workstring F/ 218' T/ 3986'. Tagged fish adjusted w/ ORKB indicates cut ESP completion traveled 93' downhole. P/U off fish tag f/ 3,986'. Kelly up obtain parameters. PU wt = 32 k S/O wt = 21. ROT wt = 28 at 60 RPM w/1000 ft/lbs TQ. AT 1 BPM w/ 60 PSI wash over fish to dress off flared cut. applying 1k down on tubing stub, TQ increased to 1.4K ft/lbs after dressing 1 ft. Stop rotary & attempt to engage grapple. Set 20k dw on tubing stub. P/U no over pull. P/U wt = 38k. Cont. to dress off & engage grapple with state parameters. 3x Cont. to attempt to engage grapple, no issues picking up off fish, no over pull at any time. Increase set down wt on grapple to 33K. No fish. Possible damaged grapple. POOH to inspect. POOH w/ over shot fishing BHA on 3-1/2" workstring F/ 3,986' T/ 218'. Pressure test BOPE as per approved sundry. AOGCC waived witness to test. Test t/ 250 psi low & 3,000 psi high F/ 5/5 charted mins. Perform accumulator drawdown test. R/D testing equip. Remove fresh water from pits. Fill gas buster & lock out valve. Prep to pull hanger. Hang ESP cable sheave, M/U kelly hose. Install TIW to landing JT & P/U landing JT. Engage hanger. Pull CTS & BPV w/ tee bar. Rig service. Check equip. fluid levels. BOLDS. Open IA , well static. P/U to shear release PKR. P/U to 40K hanger offseat. Cont. to P/U to 60K. Cont. to P/U in 5K increments up to max pull of 125K. Obtain approval to P/U T/ 129K on 2-7/8" L-80 TBG. PKR not release. Cont. to work pipe to 128K, while mobilizing e-line to Jet cut TBG. R/U E-line, hang sheave & P/U Jet cut tool string; CH, CCL, Cent, 1x WB, cent, SS, Jet cut. RIH w/ Jet cutter to 3790'. Unable to pass. POOH to drop one centralizer & add WB. Reconfigure tool string. CH, CCL, 2x WB, cent, SS, Jet cut. RIH correlta CCL log to well tubing tally. Jet cut at 3,907'. In middle of first full joint below X nipple. R/D E-line. R/U kelly hose & P/U landing JT. Hanger off seat at 25K. P/U to 88K PKR released. Free P/U wt = 28K. Pump a surf. to surf. for a total of 163 bbls at 3 BPM at 500 PSI. dynamic loss rate = 20 BPH. Shut dw monitor well. Static. Pull hanger to floor. Cut ESP cable & cap lines from hanger. Rig service. Check equip. fluid levels. Run ESP cable over sheave & cap lines while POOH slowly. Remove ropes. Tie back cap lines & ESP cable to respected spooling units. POOH w/ jet cut 2-7/8" 6.5# L-80 EUE tubing F/ 3,907' T/ 2,150'. 8/1/2023 - Tuesday 7/31/2023 - Monday Cont. to work pipe to 128K, while mobilizing e-line to Jet cut TBG 3 BPM at 500 PSI. dynamic loss rate = 20 BPH. Shut dw monitor well. Static. Pull hanger to floor. Cut ESP cable & cap lines from hanger. Rig service. Check equip. fluid levels. Run ESP cable over sheave & cap lines while POOH slowly. Hanger off seat at 25K. P/U to 88K PKR released. Free P/U wt = 28K. Pump a surf. to surf. for a total of 163 bbls at POOH w/ jet cut 2-7/8" 6.5# L-80 EUE tubing F/ 2,150' T/ surface. L Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 8/4/2023 - Friday Continue POOH w/ clean-out BHA F/ 5,900' T/ 386'. L/D BHA, all equipment accounted for and in good condition. Shut down and check equipment. P/U YJOS 7" AS1X Test Packer and RIH on 3-1/2", 10.37#, G-105, NC31, R3 Worksting to 5,018'. Cont. RIH to 9,622'. Up weight 61k, down weight 28k. Shut down and check equipment. Cont. RIH to 12,170'. Up weight 93k, down weight 36k. Set 7" AS1X Test Packer, line up to test. Install gauge on OA. Fill hole. Close Rams. Begin testing Casing to 1650psi. Good Test. POOH w/ Test Packer F/ 12,170'. 8/2/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary POOH w/ 2-7/8" 6.5# L-80 EUE tubing & ESP completion F/ 6,300 T/ 3,117' while pumping 1x displacement. Safety meeting. Check fluids & inspect handling equipment. POOH w/ 2-7/8" 6.5# L-80 EUE tubing & ESP completion F/ 3,117' to Discharge head. TBG pulled wet from XN Nipple down. L/D ESP assy. Top Motor seized, BTM Pump oil was dirty but rotated freely. Recovered what appears to be piece from Jet Cutter and 3 Packer pieces in Motor Clamps. RECOVERED 208 CC Clamps, 5 Protectolizers, 2 Flat Guard Clamps. Discharge Head and pup blockage of scale buildup. Clean and clear rig floor. Switch over handling equipment. R/D Elephant trunk. Rack and Tally BHA & W/S. M/U BHA 3.75" Bit, Bit Sub, 13 Joints of 2-7/8",7.90#, P110, PH6 Work String 2ea 5-1/2" Boot Baskets, 7" Casing Scraper, Bumper Jars, Oil Jars, 6ea 4- 1/4" Drill Collars, Accelerator Jars. Shut down and check equipment. RIH w/ Cleanout BHA T/ 3,200'. 8/3/2023 - Thursday RIH w/ 3.75" Bit, Bit Sub, 13 Joints of 2-7/8",7.90#, P110, PH6 Work String 2ea 5-1/2" Boot Baskets, 7" Casing Scraper, Bumper Jars, Oil Jars, 6ea 4-1/4" Drill Collars, Accelerator Jars. F/ 3,200' T/ 9,261 while filling hole w/ 5 BBLS every 3 hours. RIH w/ BHA through Liner Top without issue T/ 12,366' (above perfs). Swivel up. Reverse Circulate well w/ 107 BBLS of 10.4ppg Brine. Bring pump on at 2.5bpm @300psi. Returns established w/ 5bbls away. Increase rate to 4bpm @ 900psi. Shut down pump. Well swapped to10.2ppg fluid during reverse circ. Pump 50bbls 10.4ppg down W/S taking returns up 6". Well returned to static losses. Continue RIH and tag fill at 12,586' ORKB. Swivel up. Clean out F/ 12,586' T/ 12,626'. Circulate 260bbls of 10.4ppg brine 5bpm @ 2000psi. At 260bbls, returns coming back at 9.7ppg. Shut down pumping. Pits 3&4 had been reduced to 10.1 & 10.0ppg. Transfer pits 3&4 to Tiger Tank. 110bbls total. Refill pits w/ 10.4ppg. Begin circulating 10.4ppg down W/S while taking returns to Tiger Tank checking return weight. Circulated 70bbls before 10.4ppg returned. Switch back to pits and continue pumping until returns were clean. Circulated 330bbls total. POOH from 12,626' to 11,046'. Reciprocated Scraper F/ 12,180' to 12,150'. 80k up and 32k down. Perform Kick while Tripping Drill. Shut down and check equipment. Continue POOH w/ BHA F/ 11,046' T/ ~5,900 while pumping 1x displacement. Continue POOH w/ YJOS 7" AS1X Test Packer and RIH on 3-1/2", 10.37#, G-105, NC31, R3 Work sting T/ 5,219'. Continue OOH F/ 5,219' to Surface. L/D Packer. Prepare to test BOP test and E-Line. Install TBG Hanger w/ TWC. P/U 2-7/8" Test Mandrel and Lower into BOP. Lock in Pipe Rams and fill with fresh water from water truck. AOGCC Rep. Brian Bixby witnessing - Fire and Gas Alarms, Test BOP Shell, Mud Cross, Choke/Kill Manifold Valves to 250psi low, 3,000psi high for 5 minutes each charted. C1 failed. Performed Choke bleed-off & Accumulator Drawdown. 16 second Annular close time, 58 second Full Charge. Blow down underneath Blind Rams. Prep for E-Line while continuing with BOP process. 23:37 E-Line arrives. Remove and replace the "C-1" Valve. Fill with fluid, test Blinds and HCR 250psi low, 3,000psi high - good test. Test Blind Rams and "C-1" Valve 250psi low, 3,000psi high - good test. Move Pipe racks, R/U E-Line crane, "Gilroy Wireline Riser", PCE to Rig Floor, Assemble and prepare to test against. Pressure test E-Line PCE 250psi low, 3,000psi high. Good test. Drain fluid from PCE, break connection at Quick Test Sub. MU E-Line Perforating Guns. 8/5/2023 - Saturday Install TBG Hanger w/ TWC POOH w/ 2-7/8" 6.5# L-80 EUE tubing & ESP completion F/ 6,300 T/ 3,117' while pumping 1x displacement Continue POOH w/ clean-out BHA F/ 5,900' T/ 386'. L/D BHA, all equipment accounted for and in good condition Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 Hilcorp Alaska, LLC Weekly Operations Summary Continue testing PVV Line to 5000psi. Good, Bleed pressure to 500psi and verify valve closes. Continue RIH after Packer Splice. Test ESP every 1000' - 9301', 10,335', 11,011. Shut down and service rig. RIH from 11,011' to 11,195'MD. Swap Chemical Injection Spools. Continue RIH to 12,112' MD. MU TBG HNGR. Terminate Chem. Inj,, PVV, ESP though Hanger. Pressure up to 5000psi / 5min - Good. Bleed to 1000psi to land Hanger. ESP electrical checks - Good. Final PUW = 74,000#, SOW = 33,000#. Land Hanger (all pressures good), RILDS. Completion landed @ 12,147.97' ORKB. Unable to monitor ESP as the ambilocal cable will not fit beside the TBG O.D. Drop B&R (8.70' OAL) Hook up hose to pump down TBG. 1.5bbls to fill TBG. Pressure up TBG to 1200psi and see Packer start to set. Continue up to 3500psi & hold for 15min. Bleed to zero & Pressure back up to 3500psi for 5min. Bleed TBG & PVV to zero. Perform step-rate (50psi/min) to pressure up IA to 1500psi. Chart record 30min test. During MIT-IA, TBG and OA remained at 0psi - GOOD TEST. Install BPV, Release Rig. RIH testing every 1000', pumping 5bbls every 3hrs. rearrange job and tighten motor on cap line spool. Continue tripping to ESP splice, CC clamp installed on bottom and top of jt 189 @ 6032'. Reel to reel ESP splice. Clean floor and location. Shut down and check fluids. Continue Splice. Continue RIH w/ ESP completion testing every 1000' from 6063' to 8,320'. Install X- Nipple w/ RHC-M & GLM #2. P/U Tripoint DLESP Packer. Perform ESP Cable and Chemical Injection Line feedthroughs. Initial ESP cut for Penetrator was too long causing cable slack to hang out further that the OD of the Packer. Procedure was not followed. Cut termination, pull slack out of cable and re-terminate. Purge, connect and test Chemical Injection line. Continue working on upper Penetrator splice. Spot in Mud Boat & Rig Mats at L-13. Connect ESP Cable above Packer. Purge and connect PVV control line. Pressure up on PVV and see opening, unable to determine actual opening pressure due to pump output being erratic. Continue up to 5000psi for test. ESP Cable test after Penetrator - Good. Testing PVV line to 5000psi. 8/8/2023 - Tuesday 8/6/2023 - Sunday RIH w/ YJOS GR-CCL, 3-1/8" GEO Razor 6 SPF 60Deg Phase 14' Guns. Correlate with survey, verify w/ John Salsbury. Perforate Kuparuk A1: 12,591' - 12,605' MD. Pump through Mud Cross to monitor well. 10bbl loss in 45min. POOH w/ E-Line guns. RD Wireline Valves, Sheaves, Gilroy Riser, Pull Hanger w/ Landing Joint, Swap Elevators. Rig up equipment to run 2-7/8" EUE ESP Completion. Shut down and check fluids. Spot in Pipe Racks. Fill hole w/ 4.5bbls 10.5ppg Brine. Rack and Tally 2-7/8" EUE Tubing. Spot in ESP Cable spooler and cap line spoolers. PU Motor & Seals, Service. Hang Sheaves. Tie in ESP. Purge and test Chemical Injection - open Injection valve with 4,800psi. MU Gas Seperator, Pumps, and Discharge Head. Installed 7ea. Protectolizers, 1ea. Flat Guard, 4ea. 4" Cannon Clamps in middle of each Pump. Keep 500psi on Chem. Line while RIH. Perform Electrical on ESP system - Good. RIH w/ 2-7/8",9.3#, L, EUE R2 ESP Completion. 1JT, XN-Nipple 2.205" No-Go, 2jts, Patco GLM#1 w/ Dummy Valve. Install Over-the-collar Clamp every connection first 15, every other connection after that. Shut down and check equipment. RIH w/ 2-7/8",9.3#, L, EUE R2 ESP Completion from 751' MD to 1,100' Check ESP electrically - Good. Pump Displacement 1x. RIH from 1,100' to 1,990' MD. Check ESP electrically - Good. Pump Displacement 1x. Continue RIH to 3,070' Check ESP electrically - Good. Pump Displacement 1x. 8/7/2023 - Monday Terminate Chem. Inj,, PVV, ESP though Hanger. Pressure up to 5000psi / 5min - Good. Bleed to 1000psi to land Hanger Continue RIH to 12,112' MD. MU TBG HNGR Perform step-rate (50psi/min) to pressure up IA to 1500psi. Chart record 30min test. During MIT-IA, TBG and OA remained at 0psi - GOOD TEST Well Name Rig API Number Well Permit Number Start Date End Date MPU F-81 ASR #1 50-029-22959-00-00 200-066 7/28/2023 8/11/2023 8/11/2023 - Friday RIG UP COMPLETE, PT W/ TRI-PLEX, 300 LOW, 1500 HIGH, GOOD TEST, RIH W/ 2.2" CENT. 2" JUC, LATCH B&R @ 3,899' SLM, POOH. RIH W/ 2-7/8" GS, LATCH RHC @ 3,908' SLM, JAR A COUPLE TIMES, CAME FREE, POOH. OOH, SIBP, REDRESS & PIN UP RHC, BEGIN RIGGING DOWN. 8/9/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD: BOP stack pulled, remove CL and clean tbg hgr void. Install RX54 gasket, (2) CL seal subs and seal sub for bore. PU tree/adapter, set and torque to spec. Test 500/5000 5 and 10 min (PASS), bleed off void and pull Bpv with T bar. All valves in closed position. Install tree cap. 8/10/2023 - Thursday No operations to report. No operations to report. No operations to report. 8/12/2023 - Saturday No operations to report. 8/15/2023 - Tuesday 8/13/2023 - Sunday No operations to report. 8/14/2023 - Monday 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: 08/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230821 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU F-81 50029229590000 200066 7/30/2023 YELLOW JACKET Cut MPU F-81 50029229590000 200066 8/6/2023 YELLOW JACKET Perf SRU 213-15 50133206520000 215100 7/29/2023 YELLOW JACKET Plug/Perf/GPT Please include current contact information if different from above. T37949 T37949 T37950 8/21/2023 Perf YELLOW JACKET/20238//6///20006650029229590000MPU -81F- - -81F--MPU 50029229590000 200066 7//30///2023/JACKET YELLOW Cut Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.21 10:19:38 -08'00' 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 Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,790'N/A Casing Collapse Conductor N/A Surface 2,570psi Production 5,410psi Liner 7,500psi 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 Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-81 MILNE POINT KUPARUK RIVER OIL N/A 12,701' 7,105' 2,895 N/A Tubing MD (ft):Perforation Depth TVD (ft): 7/27/2023 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22959-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: 6.5#/ L-80/ EUE TVD Burst 12,154' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 200-066 7,192' 7,515' 12,422' Length Size Proposed Pools: 110' 110' 7,193' 4-1/2"558' 12,422' MD N/A 8,430psi 3,950psi 7,240psi 4,153' 6,830' Perforation Depth MD (ft): 12,789' See Schematic See Schematic 2-7/8" 110' 20" 9-5/8" 7" 7,515' Viking ESP Retrievable & Baker ZXP Packer and N/A 3,825 MD/ 2,879 TVD & 12,231' MD / 6,641' TVD and N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 Authorized Name and Digital Signature with Date: No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.11 15:46:13 - 08'00' Taylor Wellman (2143) By Grace Christianson at 1:47 pm, Jul 12, 2023 323-392 DSR-7/12/23 10-404 MDG 7/21/2023 Perforate 2,895 MGR12JUL2023 * BOPE test to 3000 psi. Annular to 2500 psi. * Pressure test 7" casing to 1650 psi. GCW 07/24/2023JLC 7/24/2023 07/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.24 19:05:00 -06'00' RBDMS JSB 072523 ESP Replacement Well: MPU F-81 Well Name:MPU F-81 API Number: 50-029-22959-00-00 Current Status:ESP Producer [OFFLINE]Pad:F-Pad Estimated Start Date:July 27th, 2023 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:200-066 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) AFE Number:Job Type:ESP Recomplete Current Bottom Hole Pressure:3,287 psi @ 6,550’ TVD BH Gauge (03/27/23) |9.65 PPG Maximum Expected BHP:3,550 psi @ 6,550’ TVD 1 Month Buildup |10.42 PPG MPSP:2,895 psi Gas Column Gradient (0.1 psi/ft) Max Deviation:75° @ 8832 MD Greater than 70° from 3,550’to 10,000’ MD Max Dogleg:8.9°/100ft @ 2000’ MD MIN ID:2.205” XN @ 12,046’ MD BPV Profile:2.5” CIW Type H Brief Well Summary: MPU F-81 was completed in August 2000 initially targeting the Kuparuk A2 sands. The well was completed with an ESP which has been replaced eight times, with an average run life of 604 days. The early failures from 2000- 2005 were caused by the pump seizing due to sand production. After the A1 and A3 sands were perforated in 2005 the ESPs predominantly failed due to a combination of frac proppant and sand. The last ESP was run on 3/7/2021 and ran until 2/1/2023 when the ESP apparently lost stages and/or tbg holes resulting in reduced performance. Notes Regarding Wellbore Condition x Tubing caliper ran on 3/28/23: No holes identified but Tbg from surface - ±6,075’ MD has multiple joints with penetrations up to 82.5%. x Supporting Injectors: o F-83 – shut in until F-81 BHP is drawn down Objective: x Pull 2-7/8” Tubing ESP completion. x PU new 2-7/8” tubing with ESP completion x Test 7” Production Casing. x Install ESP packer per CO 390A w/ 2-7/8” ESP completion with packer and dual vent valves. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Review well kill plan with Engineer based on current well conditions. 6. Circulate (conventionally) wellbore volume (~367 BBLS down IA, 65 BBLS down the TBG) with calculated kill fluid based on updated well pressures, estimated KWF of 10.7 ppg Nacl/Nabr Brine. 7. Bullhead down tubing for a volume of 65 bbls, taking returns to formation. 8. Monitor surface pressures. ESP Replacement Well: MPU F-81 9. If necessary, swap to IA and bullhead 372 bbls to formation. 10. Confirm well is dead. 11. RD Little Red Services and reverse out skid. 12. Set BPV and CTS Plug Brief RWO Procedure: 13. MIRU ASR #1, ancillary equipment and lines to returns tank. 14. ND tree. NU BOPE. a. When ND tree, ensure that control line to the vent valves is pressured up and capped. Note and highlight to crew that capstring will have pressure on it when recovering hanger. This will keep vent valves open. 15. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi 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 joints e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 16. Pull CTS Plug. Check for pressure below the BPV. a. If indications show pressure underneath BPV, lubricate out BPV and re-kill as needed. 17. MIRU spooler to pull #2 Cable and 1/4" SS Control Line. a. 12,153’ of ¼” SS Control Line b. 12,153’ of #2 Cable. Splice location is on Joint 264. 18. MU landing joint, BOLDS, PU on the tubing hanger. a. The previous RWO had a PUW of 75 Klbs. b. The ESP packer is pinned to shear release at 49k overpull. Estimated PUW to release packer is ~124 Klbs. c. Work pipe up from 75 Klbs to 125 Klbs in 5 klbs increments. d. If pipe has not released at 125 klbs, contact engineer prior to working pipe any further. 19. Confirm hanger free, lay down tubing hanger. a. Bleed off pressure from control line prior to laying down hanger. 20. POOH and lay down the 2-7/8” tubing and ESP completion components. a. All joints from surface - ±6,075’ MD are to be washed and junked. Joints from 6,075’- 12,097’ can be re-used. b. Clamps to be recovered, washed and saved for re-use if possible. 207 Cross Collar Cannon Clamps 1 Motor LaSalle Clamp 4 Pump/Seal Lasalle Clamps 2 Flat Guards 1 Single Cable Clamp. 21. Lay Down ESP. ESP Replacement Well: MPU F-81 22. PU 3-1/2” workstring, rotatable 7” casing scraper, 2-7/8” extension and 4-1/2” clean out BHA. a. Make note of ESP condition to understand likely casing and liner condition. 23. Run in hole cleaning out down to ~12,620’ MD. a. Note that well is known for scale deposition. Take care on any weight stack outs. b. Circulate out scale and debris in 4-1/2” via reverse circulation if possible. 24. Reciprocate casing scraper from 12,150’ to 12,180’ MD. 25. POOH and lay down casing scraper / cleanout BHA. 26. PU 7” test packer and run in hole to 12,170’ MD. 27.Test 7” Production Casing to 1,650 psi.Chart and record test for 30 minutes. 28. POOH and lay down test packer BHA and 3-1/2” workstring. 29. MIRU E-Line and pressure test lubricator to 250 psi low / 3,000 psi high. 30. RIH with 3-3/8” HC gun assembly. a. Perforate Kuparuk A1: 12,591’ – 12,605’ MD b. Correlate to log provided by geologist John Salsbury (Mobile: 907-350-1088) 31. POOH and RDMO E-Line. 32. RU to run ESP completion. 33. PU and MU new ESP assembly. Set base of ESP assembly at ±12,150’ MD. Check electrical integrity test every 1,000’. Install clamps on the first 15 joints then every other joint to surface. a. Motor centralizer b. Motor gauge unit c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Gas separator g. Pumps h. Ported discharge head i. Bolt on discharge head with pup joint, 2-7/8”, 6.5#, L-80, EUE 8rd box up j. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing k. 2.205” XN Nipple l. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8RD tubing m. 2-7/8” GLM with Dummy installed n. Multiple joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing o. 2-7/8” GLM with Dummy installed p. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing q. Nipple, HES X-Nipple (2.313”) with 10’ handling pups above and below,RHC plug body installed r. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing s. Packer, Viking ESP retrievable with dual vent valves (setting depth = ±2,400’ MD) 34. PU and MU the Viking packer. Verify that there are 4 setting shear pins and confirm w/ OE number of release shear pins. MIRU E-Line and pressure test lubricator to 250 psi low / 3,000 psi high. RIH with 3-3/8” HC gun assembly. a. Perforate Kuparuk A1: 12,591’ – 12,605’ MD b. Correlate to log provided by geologist John Salsbury (Mobile: 907-350-1088) ESP Replacement Well: MPU F-81 a. Shear pins will be dependent upon expected PUW of completion. Initial target is 20k overpull to release. b. Document packer with photos above and below all jewelry as installed on 2-7/8” tubing. 35. Terminate the ESP cable and MU the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 36. MU the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in AWGRS). Bleed the pressure to 500 psi and lock it in to maintain 500 psi while RIH. 37. Continue to RIH with ESP completion. Check electrical integrity test every 1,000’. a. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing b. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below (setting depth ±3,600’ MD) c. Multiple joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing d. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below (setting depth ±175’ MD) e. ~5 joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing 38. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator, MU the control line to the tubing hanger and dummy off any additional control line ports if present. 39. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in AWGRS). Bleed the pressure to 500 psi and lock it in to maintain 500 psi while landing the hanger. 40. Land tubing hanger with extreme caution to avoid damaging the ESP cable, penetrator, or control line. RILDS. Record PU and SO weights on tally and AWGRS. 41. Drop the ball & rod and allow time for it to gravitate to the ball seat. 42. Pressure up on the tubing to 4,000 psi and hold for 15 minutes to set the packer. Bleed the tubing pressure to 0 psi. Pressure back up to 4,000 psi and hold for 5 minutes then bleed to 0 psi. 43. Bleed the control line pressure to 0 psi to close the vent valves. 44. Slowly pressure up at 50 psi/min on the IA to 1,500 psi and hold for 30 minutes on chart recorder. 45. Set BPV. ND the BOP stack. Set CTS Plug. 46. NU the tubing head adapter and 2-9/16”, 5M tree. 47. PT tubing hanger void to 500/5000 psi. PT the tree to 250/5000 psi. 48. Pull CTS plug and BPV. 49. Replace gauge(s) if removed. Secure the tree and cellar. 50. RDMO Post-Rig Procedure: 51. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 52. Pull TWC. 53. Replace gauge(s) if removed. 54. RU SL 55. RIH Pull the ball and rod. 56. Pull DV from GLM at ~175’ and install OV. ESP Replacement Well: MPU F-81 57. Pull RHC plug body. 58. RD SL 59. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: DH 3/19/2021 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 5 4 7 8 9 10 9 14 15 16 17 9-5/8” 1 3 18 KUP A Sands PBTD = 12,701’ (MD) / PBTD = 7,105’(TVD) 6 4-1/2” 2 KUP C Sands 11 12 13 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1 169’ Sta 3: GLM 2-7/8”x1”, SOGLV 2 1,004’ TAM Port Collar 3 3,767’ Sta 2: GLM 2-7/8”x1”, DV 4 3,825’ Packer: Viking ESP Retrievable w/ Dual Vent Valves 5 3,880’ X Nipple w/RHC installed 6 11,896’ Sta 1: GLM 2-7/8”x1”, Dummy 7 12,046’ HES XN-Nipple – ID= 2.205” 8 12,097' Discharge Head 9 12,099’ Pump 10 12,118’ Gas Separator 11 12,123’ Upper & Lower Tandem Seal Section 12 12,137’ Motor, 562XP 13 12,149’ Motor gauge w/ 6 Fin Centralizer Bottom 12,154’ 14 12,231’ Baker ZXP Packer 15 12,245’ Baker HMC Liner Hanger 16 12,422’ 7”, 26#, L-80 BTC Shoe 17 12,702’ 4.5” Float Collar (PBTD) 18 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 ESP RWO & Add Packer by Doyon 14 – 3/7/2021 _____________________________________________________________________________________ Revised By: TDF 7/11/2023 PROPOSED Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 5 4 8 9 10 11 9 15 16 17 18 9-5/8” 1 3 19 KUP A Sands PBTD =12,701’(MD) / PBTD = 7,105’(TVD) 7 4-1/2” 2 KUP C Sands 12 13 14 6 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface ±12,150’ 3/8” Capstring Stainless Steel N/A Surface ±12,150’ JEWELRY DETAIL No Depth Item 1 ±169’ Sta 3: GLM 2-7/8”x1” 2 ±1,004’ TAM Port Collar 3 ±3,767’ Sta 2: GLM 2-7/8”x1” 4 ±3,825’ Packer: Viking ESP Retrievable w/ Dual Vent Valves 5 ±3,880’ X Nipple w/RHC installed 6 ±11,896’ Sta 1: GLM 2-7/8”x1”, Dummy 7 ±11,916’ HES X-Nipple (2.313”) w/ RHC Plug 8 ±12,046’ HES XN-Nipple – ID= 2.205” 9 ±12,097' Discharge Head 10 ±12,099’ Pump 11 ±12,118’ Gas Separator 12 ±12,123’ Upper & Lower Tandem Seal Section 13 ±12,137’ Motor, 562XP 14 ±12,149’ Motor gauge w/ 6 Fin Centralizer Bottom ±12,150’ 15 12,231’ Baker ZXP Packer 16 12,245’ Baker HMC Liner Hanger 17 12,422’ 7”, 26#, L-80 BTC Shoe 18 12,702’ 4.5” Float Collar (PBTD) 19 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10 6/7/2005 3-3/8”/ 6spf / Open Kup. A1 Sands ±12,591’ ±12,605’ ±6,996’ ±7,010’ ±14 Future 3-3/8”/ 6spf / Future OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 ESP RWO & Add Packer by Doyon 14 – 3/7/2021 Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2023 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 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: 04/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230414 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPF-81 50029229590000 200066 3/29/2023 READ CaliperSurvey MPI-04A 50029220680100 201092 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 3/20/2023 READ CaliperSurvey MPL-12 50029223340000 193011 4/2/2023 READ CaliperSurvey MPU I-27 50029236920000 221013 3/23/2023 READ LeakPointSurvey PBU 09-23A 50029210660100 198044 3/28/2023 READ MultipleArrayProductionProfile PBU L-112A 50029231290100 222138 3/27/2023 READ MemoryRadialCementBondLog END 1-11 50029221070000 190157 3/19/2023 AK E-LINE Perf END 1-29 50029216690000 186181 2/9/2023 AK E-LINE Perf NCI A-08 50883200280000 169063 3/20/2023 AK E-LINE Perf BCU 19RD 50133205790100 219188 4/4/2023 AK E-LINE PPROF SRU 224-10 50133101380100 222124 3/31/2023 AK E-LINE CIBP_GPT_Perf SRU 224-10 50133101380100 222124 4/3/2023 AK E-LINE GPT_Perf SRU 231-33 50133101630100 223008 3/29/2023 AK E-LINE GPT Please include current contact information if different from above. T37595 T37596 T37599 T37599 T37597 T37599 T37598 T37601 T37603 T37600 T37602 T37594 T37604 T37604 T37605 MPF-81 50029229590000 200066 3/29/2023 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 14:10:44 -08'00' JLC 4/10/2023 RBDMS JSB 041123 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,790 feet N/A feet true vertical 7,193 feet N/A feet Effective Depth measured 12,701 feet 3,825' & 12,231'feet true vertical 7,105 feet 2,879' & 6,641'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 12,154' 6,565' Packers and SSSV (type, measured and true vertical depth)Viking ESP Pkr ZXP 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 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,570psi 5,410psi 7,500psi8,430psi 20" 9-5/8" 7" 4-1/2" 4,153' 110' 7,515' 12,422' Burst N/A 3,950psi 7,240psi Surface Production N/A measured 558' N/A measured 6,830' 7,192' Length Tubing Pressure 38 Junk Liner Casing Conductor Size 160 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-066 371 Authorized Signature with date: Authorized Name: David Gorn dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-066 50-029-22959-00-00 Plugs ADL025509 & ADL0388235 5. Permit to Drill Number: Milne Point Unit / Kuparuk River Oil 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data NA0 MILNE PT UNIT F-81 Gas-Mcf 1,050 637 Oil-Bbl measured true vertical Packer 12,789' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 159 Casing Pressure WINJ WAG 0 Water-Bbl MD 110' 7,515' 12,422' TVD 110' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:46 pm, Apr 06, 2021 Chad Helgeson (1517) 2021.04.05 16:37:08 - 08'00' MGR24JUN21 RBDMS HEW 4/6/2021 SFD 4/7/2021DSR-4/6/21 _____________________________________________________________________________________ Revised By: DH 3/19/2021 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/7/2021 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 5 4 7 8 9 10 9 14 15 16 17 9-5/8 ” 1 3 18 KUP A Sands PBTD =12,701’(MD) / PBTD = 7,105’(TVD) 6 4-1/2” 2 KUP C Sands 11 12 13 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1 169’ Sta 3: GLM 2-7/8”x1”, DV 2 1,004’ TAM Port Collar 3 3,767’ Sta 2: GLM 2-7/8”x1”, DV 4 3,825’ Packer: Viking ESP Retrievable w/ Dual Vent Valves 5 3,880’ X Nipple w/RHC installed 6 11,896’ Sta 1: GLM 2-7/8”x1”, Dummy 7 12,046’ HES XN-Nipple – ID= 2.205” 8 12,097' Discharge Head 9 12,099’ Pump 10 12,118’ Gas Separator 11 12,123’ Upper & Lower Tandem Seal Section 12 12,137’ Motor, 562XP 13 12,149’ Motor gauge w/ 6 Fin Centralizer Bottom 12,154’ 14 12,231’ Baker ZXP Packer 15 12,245’ Baker HMC Liner Hanger 16 12,422’ 7”, 26#, L-80 BTC Shoe 17 12,702’ 4.5” Float Collar (PBTD) 18 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8"Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 ESP RWO & Add Packer by Doyon 14 – 3/7/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Doyon 14 50-029-22959-00-00 200066 2/28/2021 Future 2/12/2021 - Friday Hilcorp Alaska, LLC Weekly Operations Summary (Pressure test surface lines 250/2500psi) HOT Diesel flush laterals (Pre RWO) Pumped 5 bbls of 180* diesel down Prod lat. No Test lat per DSO.Tags hung. 2/16/2021 - Thursday Well Support techs pulled wellhouse, foundation and production piping. Prep for Doyon. No issues Move rig to F-Pad. Spot rig and shim level. Skid rig floor into position. Begin rigging up. Hook up power to top drive. Centered and level rig. R/U rig lines. Prepare mud pits and bring on w/ 11.1 ppg NaCl/NaBr brine. Spot rock washer and fuel trailer. Rig accepted 12:00. R/U 2" hardline and hoses to flow back tank. Blow air and steam through lines to tank. Fill pill pit with fresh H2O. Fill lines with fresh water and pressure test to 3500 PSI - good. Blow down lines. Initial 950 PSI on tubing and 1100 PSI on annulus. Line up and bullhead 375 bbls 11.1 ppg NaCl/NaBr down IA. ICP = 1950 psi @ 3 BPM, FCP = 2450 psi @ 2.6 BPM. Initial Tbg pressure = 1200 psi, Final Tbg pressure 2750 psi. Shut in and monitor Well for 45 minutes. Initial SITP = 2300 psi stabilize at 1350 psi. Initial Shut in IA @ 1950 psi, stabilize at 950 psi. Discuss with town Engineer. Line up and reverse circulate 102 bbls 11.1 ppg NaCl/NaBr down IA, returns from tubing to kill tank. Stage up from 0.5 BPM to 2 BPM, ICP 790 psi IA, 1040 psi Tbg. FCP – 550 psi IA, 430 psi TBG. Saw diesel if returns and then crude Bomide mix. Trace bromid at 40 bbl away. Bromide increasing in returns. 95% bromide in returns at 102 bbl away. Shut in and monitor 20 min. Initial shut in 150 psi Tbg / 200 psi IA, build to and stabilize at 380 psi Tbg / 425 psi IA. Bleed 5 bbls back to kill tank and shut in. 150 psi Tbg / 200 psi IA, build back to 380 psi Tbg / 400 psi IA in 15 min. Discuss with town Engineer to circ down tubing taking retunes to pits to clear oil contamination. Rig up lines to circulate down tubing, take returns through choke manifold and mud gas separator to mud pits. Test lines and blow down. Tbg @ 380 psi / IA @ 400 psi after 2 hrs. Pump down tubing, returns from IA to choke manifold and mud gas separator to mud pits. 30 bbl viscosified 11.1 ppg NaCl/NaBr spacer followed with 557 bbls 11.1 ppg NaCl/NaBr brine. Pump 1 BPM while holding 600 PSI on the IA for 1st 30 bbls then stage pumps up to 3 BPM and hold IA pressure at 400-500 PSI first 70 bbls then hold 1100-1200 psi on Tbg. ICP @ 1 BPM – 530 psi Tbg / 500 psi IA. FCP – 1120 psi Tbg, 400 psi IA. First 20 bbls return was crude cut to 7.9 ppg. Observe partial sweep returns at 127 bbls pumped. 11.1 ppg back at 200 bbls total pumped. Max Gas @ bottoms up = 337u. Continue circulate a full calculated circulation plus 25% excess. Spacer strung out with SS pumped and max gas 687u. Shut down and monitor pressures. Initial shut in 340 psi Tbg / 340 psi IA, drop to and stabilize at 330 psi Tbg / 320 psi IA. Bleed off 3 bbls in 1 bbls increments, monitor pressures between. Initial shut in readings 320 psi Tgb / 320 psi IA , stabilized at 250 psi Tbg / IA after 1st bleed. 2nd bbl 130 psi Tbg / IA stab at 150 psi both sides. 3rd bbl Initial 120 psi both sides, stab at 130 psi on Tbg / 140 on IA. Discuss with Town Engineer. Start weighting up surface volume to 11.4 ppg to pump down tubing and evaluate. 2/28/2021 - Sunday Blow down and rig down lines & squeeze manifold. Finish pre-skid rig floor checklist. PJSM, Skid rig floor into moving position. Jack up Rig and pull off L-01A. Move rig from L-Pad to F-Pad. 3/1/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Doyon 14 50-029-22959-00-00 200066 2/28/2021 Future Hilcorp Alaska, LLC Weekly Operations Summary 3/3/2021 - Wednesday Rig up Centrilift tools, string ropes for cap line and ESP cable. Make up landing joint with FOSV ,PJSM. P/U and unseat hanger with 110K (40K block weight). Fill hole - 10 bbls to fill. Hoist hanger to the rig floor with 115K PU. Cut ESP cable and remove penetrator from the hanger. Crimp cable pulls on ESP cable, hang ESP elephant trunk and pull rope through. L/D hanger and landing joint. POOH L/D 2-7/8" 6.5# EUE L-80 tubing from 12100' to 5011'. Hole in joint #83 @ 2628’ verified. Losses @ 6 BPH, Swap ESP cable to empty reel in spooling unit. Continue POOH L/D 2-7/8" 6.5# EUE L-80 tubing from 5011' to 73’. Tight connection on jt. # 369, tongs crushed the pipe and twisted tube apart 1.5’ above connection. Jt # 377 has 5’ perforated section, 20 holes. 19’ of slick line tools recovered sticking out of pup jt above #2 GLM. Losses slow to 3 BPH. Lay down ESP pump assembly to shed. Motor/pump assembly shows pitting erosion on outside body and internally packed with sand, last 4 jts & pup jt had moderate scale build up. All ESP cable spooled to unit. 199 total cannon clamps and 2 protectolizers recovered. Clear and clean rig floor. R/D Centrilift drain hose. Remove Cap String spool from rig floor. SimOps: Removed used ESP spool from unit. Continue monitor pressures after circulating 11.1 ppg NaCl/NaBr brine STS. IA @ 130 psi, Tbg @ 120 psi. Discuss with production engineer to bring wt to 11.4 ppg. While prepping and weighting up active system to 11.4 with NaBr, pressure slowly dropped to 100 psi in 3 hrs. Circulate 11.4 ppg KWF down tubing, take returns from IA through choke / mud gas separator and to pits. ICP 280 psi @ 1.5 BPM, FCP 420 psi @ 2 BPM. Hold 100 psi backpressure first 200 bbls then full open choke. See trace kill wt fluid in returns after 100 bbl pumped. Took 660 bbl to get 11.4 ppg to surface. Well volume is 425 bbl. Shut down and monitor well – Static, remaining static after 30 min monitor. Install BPV. Blow down and rig down circulating lines. Close SSV on Tree. N/D tree & secure in cellar. Clean and inspect hanger threads - good. Dummy run 2-7/8” EUE-8rd pup in hanger. Install test dart in BPV & pressure test against test dart to 500/5000 PSI - good. Thread blanking plug on control line penetration. Function lockdown, verify free – good. Nipple up BOP, M/U kill line, energize accumulator, install riser. Obtain RKB measurements. Function BOP Rams,Install 2-7/8" test joint and R/U test equipment. Fill stack with water. Perform shell test: 250/3500 psi -good. Test BOPs as per AOGCC, PTC & Hilcorp requirements. AOGCC notified of testing at 05:53 on 27 Feb 2021. AOGCC representative Austin McLeod waived the right to witness test at 16:14 on 02 March 2021. All test performed with fresh water against a test dart installed in BPV. Test held for 5 min each and charted. Annular tested to 250 PSI / 2500 PSI & all other tests to 250 PSI / 3500 PSI.,1) Annular on 2-7/8" test joint, 2) Upper 2-7/8" x 5" VBR on 2-7/8" test joint, choke valves 12, 13, 14, kill line Demco & 3-1/2" dart valve, 3) Choke valves 9, 11, HCR kill & 3- 1/2" FOSV, 4) Choke valves 5, 8, 10, manual kill & upper IBOP, 5) Choke valves 4, 6, 7 & lower IBOP, 6) Choke valve 2, 7) Lower 2-7/8" x 5" VBR on 2-7/8" test joint, 8) Choke valve 1 & 3, 9) HCR choke , 10) Manual choke valve, 11) Blind Rams, 12) Manual choke B, 13) Hydraulic choke A. Perform accumulator test, 3100 psi system pressure, 1700 psi after closure, 200 psi attained in 44 sec, full pressure in 193 sec. 6 N2 bottle avg = 2100 psi. Rig electrician test rig gas alarms, verify PVT system. Note: 1- F/P on Upper IBOP, service and re-test, good. R/D test equipment, Blow down lines and rig down test equipment. Suck out stack, Remove test dart and BPV. Rig up Centrilift to pull ESP & Cap String. 3/2/2021 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Doyon 14 50-029-22959-00-00 200066 2/28/2021 Future Hilcorp Alaska, LLC Weekly Operations Summary POOH F/12606' T/ 11871' L/D unneeded tubing. POOH standing back 2-7/8 tubing F/ 11871' T/ surface. Hole taking 2 BPH losses for the trip out. Clear floor, PJSM, R/U Centralift. String lines through sheaves, Bring tools to rig floor. PJSM, M/U ESP assembly as per baker & tally to 65'. Pressure up on cap string & held 1500 psi for 5 Min. Good. Pump through cap string at rig floor at 3500 psi. Saw good fluid at rig floor. M/U ESP cable to pump. Test cable. Total of 1 motor protectolizer, 4 pump protectolizers and 2 flat guards ran. RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing f/ 65' to 7495'. Torque to 2250 ft/lbs, Install 1 cannon clamp every collar for first 10. Install cannon clamp every other connection from jt #8. Test cable connection every 1000’ and cap line every 2000’. Consistent 4.6 phase to phase & CV open at 3800 psi. Losses @ 1.5-2 BPH. Total of 18.5 bbls loss running ESP. 60k SOW. 3/6/2021 - Saturday RIH with 2-7/8" ESP Completion f/ 7495' t/ 7956'. Baker perform cable to cable splice on new reel. Pump through cap string at 3800 psi. Meg cable. Good. RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing as per tally f/ 7956' t/ 8325'. 60k SOW. Losses @ 2 BPH, P/U Viking packer. (Packer has 15x 3254 lbs release shear pins installed for a 48,810 lbs straight pull release). Make cable splice to penetrator. Splice cap sting. Install vent valves. Test vents. Open at 4500 psi. Visually observe valves open. Meg cable. Good. Pump through cap string at 3800 psi. Drain stack for visual confirmation of packer going through stack and well head without hanging up. Losses @ 2 BPH, Continue RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing f/ 8325' to 12118'. Torque to 2250 ft/lbs. Install cannon clamp every other connection and above & below GLM bodies. Test cable connection every 1000’ and cap Line every 2000’. Trap 4500 psi on control line while RIH, pressure drop to 4200 psi @ 2000' then start increase to 4400 psi at end. Losses @ 2 BPH. Total 39 bbls loss running ESP completion. 70k SOW / 115k PU, Rig up landing joint with cross overs and FOSV to Hanger and M/U to tubing. Test cable connections. Install penetrator and control lines in Hanger. Splice ESP cable to penetrator and attach umbilical cord. Blow down Kill, Choke & Hole fill lines. Hold 800 psi on control line while landing. Land tubing with 30k on Hanger. RILDS. 7.5 phase to phase reading after landing. Bottom of motor centralizer @ 12,153.92',110 new clamps & 97 re-used for a total of 207 full canon clamps ran & 1 Half clamp @ packer. ESP assembly has 1 Motor Protectolizer, 4 Pump Protectolizers, 2 Flat Guards., L/D landing joint, cross over and FOSV. Make up T-Bar & Install BPV. Clean and clear rig floor. Prep to remove control line spool and nipple down BOP stack. 3/4/2021 - Thursday Mobilize crossovers to rig floor. Change out top drive saver-Sub to 3-1/2” IF, Make up mule shoe to 2-7/8” tubing joint . RIH picking up 2-7/8" 6.5# EUE L-80 tubing to 12,152’, 87k PU / 66k SO 1.5-3 BPH Losses. Install 30’ Mousehole. Make up stand of 2-7/8” tubing with XO and FOSV and Kelly up. Rig up lines to reverse circulate. Wash stand down T/ 12240' pumping through tubing at 1 BPM, 200 psi. No fill observed. 88k PU / 66k SO. Line up and reverse circulate, 1 BPM – 170 psi stage pumps up to 3 BPM 620 psi. Pump 187 bbls total, 37 bbls loss. Sand returns with bottoms up, cleaning up with by 2nd BU. Approx 0.5 bbls sand returned.,Monitor Well, static. Blow down topdrive. Continue RIH picking up 2-7/8" 6.5# EUE L-80 tubing to 12606’ . 90k PU / 62k SO. Losses at 1 BPH, Line up and reverse circulate, 3 BPM – 685 psi. Pump 220 bbls, 11.4 ppg NaCl/NaBr Brine, 26 bbls loss. Good sand returns with bottoms up, cleaning up at 200 bbls pumped. Approx 0.5 bbls sand returned. 2.75x BU circulated. Seeing 11.1 ppg returns with 2nd BU. Max Gas = 285u, Line up and circulate a string volume of 11.4 ppg down tubing. 16 bbls loss ,Monitor Well 30 min while blow down TopDrive and prep to L/D tubing. Well start taking fluid. 3/5/2021 - Friday Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Doyon 14 50-029-22959-00-00 200066 2/28/2021 Future Hilcorp Alaska, LLC Weekly Operations Summary 3/10/2021 - Wednesday WELL SHUT-IN ON ARRIVAL (post rig), PT PCE 250L / 3500H. PULL BALL & ROD AND RHC PLUG BODY FROM 3,880' MD (intact). PULL BK-DGLV FROM 170' MD (station #2) AND SET BKP-DPSOV AT 170' MD. WELL S/I ON DEPARTURE, NOTIFIED PAD OP. 3/7/2021 - Sunday Pull riser, N/D BOPE, hoist stack and set on stump. Install plug in BPV. SimOps: Clean in pits. Spool excess ESP cable and Cap lines back to spooling unit. Remove casing and Centrilift equipment from rig floor. N/U tree and adaptor flange. Terminate control line to tubing head adapter. Test void to 500/5000 psi for 15 min. Centrilift take final readings. 7.4 phase to phase, 477 meg, 3802 pump intake psi, 3794 discharge psi, 149° Ti, 152° Tm. R/U & test tree to 250/5000 psi. Good,Pull BPV & Test dart. Install lubricator extension on tree and load ball and rod. R/U high pressure lines and squeeze manifold. PT lines t/ 4000 psi. Line up on 7'' X 2 7/8 and bullhead 58 bbl seawater with1% Concor 303 corrosion inhibiter. ICP 80 psi @ 0.5 BPM, FCP 1205 psi @ 1 BPM. Blow down lines and pumps. Pump 58 bbl diesel freeze protect down IA, ICP 650 psi @ 0.5 BPM, FCP 1630 psi @ 1 BPM. Shut in IA. Pump 12 bbl diesel freeze protect in wing valve down tubing. ICP 100 psi @ 0.5 BPM, FCP 3000 psi @ 1 BPM, Line up test pump to lubricator and equalize pressure. Open swab and drop 1.30” ball and rod. Let fall on seat for 15 min. Pressure up to 4150 psi down tubing setting packer. Hold for 15 min. Bleed down to cuttings box. Pressure up to 4200 psi with test pump down tubing. Hold 5 min. Bleed down to cuttings box. Line up and bleed I.A. pressure down f/ 950 psi t/ 0 psi @ 25 psi/min increments. MITIA, Pump diesel down IA, pressure up to 1700 psi @ 50 psi/min increments with test pump. Hold for 30 charted min and bleed pressure off @ 25 psi/min increments. Secure Tree. Final Wellhead Pressures IA - 0 psi, OA - 0 psi, Tubing - 750 psi. SimOps: Rig down / Blow down service lines to rig floor. Rig Released at 00:00. Refer to F-05 PreDrill for details. Wellhead: Land 11 X 27/8 ESP Tubing hanger (P134137-0002) RILDS, Set 2.5" CTS BPV in well, Nipple down BOPs set CST Dart and nipple up tree and new adapter ( P134133-0002). Test adaptor and tree to 500 / 5000 psi for 5 and 10 mins, Pull CST dart and BPV. 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 Swap 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,790'N/A Casing Collapse Conductor N/A Surface 2,570psi Production 5,410psi Liner 7,500psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Hilcorp Alaska LLC MILNE PT UNIT F-81 Tubing Grade:Tubing MD (ft): COMMISSION USE ONLY Authorized Name: N/A Perforation Depth TVD (ft): PRESENT WELL CONDITION SUMMARY 3,082 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388235 200-066 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22959-00-00 8,430psi Length Size 7,193'12,701'7,105' 4-1/2" N/A Milne Point Unit / Kaparuk River Sands 110'110' 6.5#/ L-80/ EUE TVD Burst 12,103' MD N/A 12,422' 558' 12,422' 3,950psi 7,240psi 4,153' 6,830' 7,192' 7,515' See Schematic See Schematic Tubing Size: 2/21/2021 110'20" 9-5/8" 7" 7,515' C.O. 432D ZXP Packer and N/A 12,231' MD / 6,641' TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 12,789' dgorm@hilcorp.com 2-7/8" Perforation Depth MD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:08 am, Feb 03, 2021 321-066 Chad Helgeson (1517) 2021.02.02 21:12:58 - 09'00' , ADL 025509 SFD 2/3/2021 Oil Pool SFD 2/3/2021 SFD 2/3/2021 SFD 2/3/2021 SFD 2/3/2021 3,082 MGR03FEB21 10-404 MPSP > 3000 psi, 3 ram BOPE tested to 3500 psi. Annular test to 2500 psi. DSR-2/4/21 2/5/21 RBDMS HEW 2/8/2021 ESP Replacement Well: MPU F-81 Well Name:MPU F-81 API Number: 50-029-22959-00-00 Current Status:ESP Producer [OFFLINE]Pad:F-Pad Estimated Start Date:February 21st, 2021 Rig:Doyon 14 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:200-066 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Ian Toomey (907) 777-8434 (O) (907) 903-3987 (M) AFE Number:Job Type:ESP Recomplete Current Bottom Hole Pressure:3,780 psi @ 6,975’ TVD BH Gauge (01/28/21)10.5 PPG Maximum Expected BHP:3,780 psi @ 6,975’ TVD 10.5 PPG MPSP:3,082 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 75° @ 8832 MD | Greater than 70° from 3,550’to 10,000’ MD Max Dogleg:9°/100ft @ 2000’ MD BPV Profile:2.5” CIW Type H Brief Well Summary: MPU F-81 was completed in August 2000 initially targeting the Kuparuk A2 sands. The well was completed with an ESP which has been replaced eight times, with an average run life of 604 days. The early failures from 2000- 2005 were caused by the pump seizing due to sand production. After the A1 and A3 sands were perforated in 2005 the ESPs predominantly failed due to a combination of frac proppant and sand. The ESP on F-81 was shut down in 2016 due to a hole in the TBG. In August 2020 tested the electrical operation of the ESP, the system was functional. On 9-18-2020 SL operations identified a hole in the TBG at 2,633’ MD, SL set a TBG patch to isolate the hole in the TBG. On 9-20-2020 the ESP was turned back on and F-81 was returned to production. The ESP failed and went down on a twisted shaft on 12/5/2020. On 1/11/2021 SL pulled the TBG patch, attempted to pull the lower GLV the SL tool latched and got stuck. The SL was cut and recovered leaving the SL tools in the TBG. Notes Regarding Wellbore Condition x The 7” production casing last CSG test - 3/29/2009. x Caliper ran on 12/17/2016 show > 60% damage to joints 83, 95, 62, 147, and 128. x Supporting Injectors: o F-83 – shut in until F-81 BHP is drawn down Objective: x Pull 2-7/8” Tubing ESP completion. x PU new 2-7/8” TBG x Install ESP packer per CO 390A w/ 2-7/8” ESP completion with packer and dual vent valves. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Review well kill plan with Engineer based on current well conditions. (NOTE: #1- TBG has a confirmed hole at 2,633’ MD, review well kill to ensure placement of kill fluid. The lower GLV has stuck SL tools preventing pulling of the GLV.) ESP Replacement Well: MPU F-81 6. Circulate wellbore volume (~360 BBLS down IA, 65 BBLS down the TBG) with calculated kill fluid based on updated well pressures, estimated KWF of 11.1 ppg Nacl/Nabr Brine (Contact Operations engineer to confirm KWF based on current well data). Monitor well for returns after the well kill. 7. Confirm well is dead. 8. RD Little Red Services and reverse out skid. Brief RWO Procedure: 9. MIRU Doyon 14 Rig, ancillary equipment and lines to returns tank. 10. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/11.1 ppg NaCl/NaBr Brine prior to pulling BPV. 11. Set TWC. 12. NU 13-5/8”3 Ram Bop Stack with 2-7/8” x 5” VBR’s in the upper and lower ram cavities. 13. Test BOPE to 250 psi Low/ 3,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR ram on 2-7/8” test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14.Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/11.1 ppg NaCl/NaBr Brine as needed. 16. Rig up spoolers for ESP cable and 3/8” capillary string. a. ~12,099’ of ESP cable was installed in the completion. b. ~12,105’ of capillary string installed in the completion. 17. MU landing joint, BOLDS and PU tubing hanger and pull pump free. 18. Remove ESP cable and capillary string from hanger. 19. Lay down the landing joint and tubing hanger. a. Evaluate pulled tubing hanger for damage. 20. POOH and lay down the 2-7/8” tubing (junking TBG) while spooling ESP cable and capillary tubing. ESP Replacement Well: MPU F-81 a. Note any corrosion, sand, scale or damage on the tubing or jewelry. i. Dispose all of the 2-7/8” TBG Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Junk 3/8” Capillary Tubing Junk ESP Cable Test and restock Gaslift Mandrels (2)Visually inspect on site then re-stock XN Nipple Visually inspect on site then re-stock ESP Components and Centralizer Junk Clamps (201)Visually inspect on site then re-stock 21. RD ESP pulling equipment 22. RU to run ESP completion 23. MU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’. a. Base of ESP centralizer @ ± 12,150’ MD b. Motor gauge c. ESP motor d. Gas Separator e. ESP pump f. Discharge head g. 2 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing h. 2-7/8” XN (2.205” No-Go) Nipple i. 3 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing j. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV k. ± 252 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing l. 2-7/8” X with 10’ handling pups above and below w/RHC plug body installed m. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing n. Packer, Viking ESP retrievable with dual vent valves (setting depth = +/-3,800’ MD) 24. PU and MU the Viking packer. Verify that there are 4 setting shear pins and 18 shear to release pins. 25. Terminate the ESP cable and MU the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 26. MU the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in WellEZ). Bleed the pressure to 500 psi and lock it in to maintain 500 psi while RIH. 27. Continue to RIH with ESP completion. Check the electrical integrity test every 1,000’. a. 1 joint 2-7/8”,6.5#, L-80, EUE 8rd tubing ESP Replacement Well: MPU F-81 b. GLM, 2-7/8”x1”, DV installed with 10’ handling pups above and below (setting depth +/- 3,750’ MD). c. +/- 111 joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing. d. GLM, 2-7/8”x1”, DV installed with 10’ handling pups above and below (setting depth +/- 175’ MD). e. +/- 5 joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing. 28. PU and MU the 2-7/8” tubing hanger with landing joint. Make the final splice of the ESP cable to the penetrator, MU the control line to the tubing hanger. Plug off any additional control line ports if present. 29. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in WellEZ). Bleed the pressure to 500 psi and lock it to maintain 500 psi while landing the hanger. 30. Land the tubing hanger with extreme caution and ensure centralization to avoid damaging the ESP cable. a. Note pick-up and slack-off weights on tally. 31. Drop the ball & rod and allow time for it to gravitate to the ball seat. 32. Pressure up on the TBG to 4,000 psi and hold for 15 minutes to set the packer. Bleed the tubing pressure to 0 psi. Pressure back up to 4,000 psi and hold for 5 minutes then bleed to 0 psi. 33. Bleed the control line pressure to 0 psi to close the vent valves. 34. Slowly pressure up at 50 psi/min on the IA to 1,500 psi and hold for 30 minutes on chart recorder. a. Test of ESP packer @ +/-3,800’ MD. 35. Slowly bleed the IA pressure at 25 psi/min to 0 psi. 36. Set TWC. 37. RDMO Post-Rig Procedure: 38. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 39. Pull TWC. 40. Replace gauge(s) if removed. 41. RU SL 42. RIH Pull the ball and rod. 43. Pull DV from GLM #2 and install OV. 44. Pull RHC plug body. 45. RD SL 46. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic ESP Replacement Well: MPU F-81 4. Sundry Change Form _____________________________________________________________________________________ Revised By: TDF 01/13/2021 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/12/2015 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 4 6 7 8 9 9 11 12 13 14 9-5/8” 1 3 3/8” SS Capstring 15 KUP A Sands PBTD =12,701’ (MD) / PBTD = 7,105’(TVD) 5 4-1/2” 2 KUP C Sands 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1149’GLM - Orificed 2 1,004’ TAM Port Collar 3 11,894’ GLM – Dummy Slickline tool string 1-11-21 left in hole 4 12,031’ HES XN-Nipple – ID= 2.250 5 12,042 Discharge Head 6 12,064’ Pump – 161P11 PMSXD 7 12,069’ Gas Separator- GRSFTXAR 8 12,076’ Upper Tandem Seal Section- GSB3DBUT SB/SB PFSA: Lower- GSB3DBUT SB/SB PFSA 9 12,099’ Motor - MSP1-250: 210HP/ 2,380 V/ 53 Amp 10 12,101 Phoenix Sensor w/ 6 Fin Centralizer Bottom 12,103’ 11 12,231’ Baker ZXP Packer 12 12,245’ Baker HMC Liner Hanger 13 12,422’ 7”, 26#, L-80 BTC Shoe 14 12,702’ 4.5” Float Collar (PBTD) 15 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8" Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 _____________________________________________________________________________________ Revised By: TDF 2/2/2021 PROPOSED Milne Point Unit Well: MPF-81 Last Completed: 3/12/2015 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 4 6 7 8 9 9 13 14 15 16 9-5/8” 1 3 17 KUP A Sands PBTD =12,701’ (MD) / PBTD = 7,105’(TVD) 5 4-1/2” 2 KUP C Sands 10 11 12 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1 ±175’ Sta 3: GLM 2-7/8”x1”, DV 2 1,004’ TAM Port Collar 3 ±3,750’ Sta 2: GLM 2-7/8”x1”, DV 4 ±3,800’ Packer: Viking ESP Retrievable w/ Dual Vent Valves 5 ±11,894’ Sta 1: GLM 2-7/8”x1”, Dummy 6 ±12,080’ HES XN-Nipple – ID= 2.250 7 ±12,091' Discharge Head 8 ±12,113’ Pump 9 ±12,118’ Gas Separator 10 ±12,125’ Upper & Lower Tandem Seal Section 11 ±12,148’ Motor 12 ±12,149’ Phoenix Sensor w/ 6 Fin Centralizer Bottom ±12,150’ 13 12,231’ Baker ZXP Packer 14 12,245’ Baker HMC Liner Hanger 15 12,422’ 7”, 26#, L-80 BTC Shoe 16 12,702’ 4.5” Float Collar (PBTD) 17 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8" Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 ] Milne Point Doyon 14 13-5/8” BOP Stack Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: February 2nd, 2021Subject: Changes to Approved Sundry Procedure for Well MP F-81Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Remove Tubing Patch Hilcorp Alaska 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 12,790 feet N/A feet true vertical 7,193 feet N/A feet Effective Depth measured 12,701 feet 12,231 feet true vertical 7,105 feet 6,641 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 12,103' 6,514' Packers and SSSV (type, measured and true vertical depth)ZXP 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 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 110' 7,515' 12,422' TVD 110' 0 Oil-Bbl measured true vertical Packer 12,789' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Casing Pressure 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 8400 MILNE PT UNIT F-81 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-066 50-029-22959-00-00 Plugs ADL025509 & ADL0388235 5. Permit to Drill Number: Milne Point Unit / Kuparuk River Sands 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1,000 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com Tubing Pressure 0 Junk Liner Casing Conductor Size 0 Surface Production N/A measured 558' N/A measured 6,830' 7,192' Length 110' 7,515' 12,422' Burst N/A 3,950psi 7,240psi 8,430psi 20" 9-5/8" 7" 4-1/2" 4,153' 777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,570psi 5,410psi 7,500psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:21 am, Jan 13, 2021 Chad Helgeson (1517) 2021.01.13 10:05:08 - 09'00' MGR18FEB2021 SFD 1/13/2021RBDMS HEW 1/13/2021 DSR-1/19/21 _____________________________________________________________________________________ Revised By: TDF 01/13/2021 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/12/2015 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 4 6 7 8 9 9 11 12 13 14 9-5/8” 1 3 3/8” SS Capstring 15 KUP A Sands PBTD =12,701’ (MD) / PBTD = 7,105’(TVD) 5 4-1/2” 2 KUP C Sands 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1 149’ GLM - Orificed 2 1,004’ TAM Port Collar 3 11,894’ GLM – Dummy Slickline tool string 1-11-21 left in hole 4 12,031’ HES XN-Nipple – ID= 2.250 5 12,042 Discharge Head 6 12,064’ Pump – 161P11 PMSXD 7 12,069’ Gas Separator- GRSFTXAR 8 12,076’ Upper Tandem Seal Section- GSB3DBUT SB/SB PFSA: Lower- GSB3DBUT SB/SB PFSA 9 12,099’ Motor - MSP1-250: 210HP/ 2,380 V/ 53 Amp 10 12,101 Phoenix Sensor w/ 6 Fin Centralizer Bottom 12,103’ 11 12,231’ Baker ZXP Packer 12 12,245’ Baker HMC Liner Hanger 13 12,422’ 7”, 26#, L-80 BTC Shoe 14 12,702’ 4.5” Float Collar (PBTD) 15 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8" Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Slick Line 50-029-22959-00-00 200-066 1/11/2021 1/11/2021 No operations to report. No operations to report. 1/9/2021 - Saturday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/3500H. PULLED 2-7/8" D&D SLIP STOP FROM 2,602' SLM (2,572' MD). PULLED 2-7/8" D&D PACK OFF W/ 10' PATCH SECTION & STINGER FROM 2,604' SLM (2,574' MD), ELEMENT INTACT, ALL ORINGS RECOVERED. PULLED 20' PATCH SECTION W/ STINGER FROM 2,616' SLM (2,586' MD), ALL ORINGS RECOVERD. PULLED 20' PATCH SECTION W/ STINGER FROM 2,637' SLM (2,607' MD), ALL ORINGS RECOVERD. PULLED 2-7/8" D&D PACK PACK OFF FROM 2,659' SLM (2,629' MD), ELEMENT INTACT. PULLED 2-7/8" D&D SLIP STOP FROM 2,661' SLM (2,631' MD). RAN RIH W/ QC, KJ, 2-7/8" OK-1 W/ 1-1/4" JDC (steel), LOC & S/D IN ST# 1 @ 11,922' SLM (11,894' MD), WORKED TOOLS FOR 1hr, UNABLE TO SHEAR OFF, LRS PUMPED 90bbls WATER & 15bbls METH FOR FREEZE PROTECT. 1/12/2021 - Tuesday 1/10/2021 - Sunday No operations to report. 1/11/2021 - Monday 1/8/2021 - Friday No operations to report. 1/6/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/7/2020 - Thursday No operations to report. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch Hilcorp Alaska 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 12,790 feet N/A feet true vertical 7,193 feet N/A feet Effective Depth measured 12,701 feet 12,231 feet true vertical 7,105 feet 6,641 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 12,103' 6,514' Packers and SSSV (type, measured and true vertical depth)ZXP 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 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,570psi 5,410psi 7,500psi8,430psi 20" 9-5/8" 7" 4-1/2" 4,153' 110' 7,515' 12,422' Burst N/A 3,950psi 7,240psi Surface Production N/A measured 558' N/A measured 6,830' 7,192' Length Tubing Pressure 4 Junk Liner Casing Conductor Size 340 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 347 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-066 50-029-22959-00-00 Plugs ADL025509 & ADL0388235 5. Permit to Drill Number: Milne Point Unit / Kuparuk River Sands 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1,1100 MILNE PT UNIT F-81 Gas-Mcf 0 911 Oil-Bbl measured true vertical Packer 12,789' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 52 Casing Pressure WINJ WAG 0 Water-Bbl MD 110' 7,515' 12,422' TVD 110' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 7:45 am, Sep 30, 2020 Chad A Helgeson 2020.09.29 17:16:45 -08'00' DSR-10/1/2020MGR02OCT2020 RBDMS HEW 10/26/2020 SFD 9/30/2020 _____________________________________________________________________________________ Revised By: NLW 9/25/2020 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/12/2015 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 4 6 7 8 9 9 11 12 13 14 9-5/8” 1 3 3/8” SS Capstring 15 D&D Patch set @ 2632’ – 2578’ OAL = 54’ Min ID = .75” KUP A Sands PBTD =12,701’ (MD) / PBTD = 7,105’(TVD) 5 4-1/2” 2 KUP C Sands 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1 149’ GLM - Orificed 2 1,004’ TAM Port Collar 3 11,894’ GLM – Dummy 4 12,031’ HES XN-Nipple – ID= 2.250 5 12,042 Discharge Head 6 12,064’ Pump – 161P11 PMSXD 7 12,069’ Gas Separator- GRSFTXAR 8 12,076’ Upper Tandem Seal Section- GSB3DBUT SB/SB PFSA: Lower- GSB3DBUT SB/SB PFSA 9 12,099’ Motor - MSP1-250: 210HP/ 2,380 V/ 53 Amp 10 12,101 Phoenix Sensor w/ 6 Fin Centralizer Bottom 12,103’ 11 12,231’ Baker ZXP Packer 12 12,245’ Baker HMC Liner Hanger 13 12,422’ 7”, 26#, L-80 BTC Shoe 14 12,702’ 4.5” Float Collar (PBTD) 15 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8" Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 Well Name Rig API Number Well Permit Number Start Date End Date MP F-81 Slickline 50-029-22959-00-00 200-066 9/18/2020 9/18/2020 9/18/2020 - Friday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 3,500H. RAN 3'x1-1/2" STEM, 2.1" CENT, SAMPLE BAILER W/ 12" FRAYED ROPE, FOUND HOLE @ 2,633' SLM (2,605' MD), FLAGGED WIRE 30' BELOW @ 2,663' SLM (2,633' MD). RAN KJ, 3'x1- 1/2" STEM, 2-7/8" BLB, 2" GAUGE RING, BRUSH & FLUSHED TUBING 50' ABOVE & BELOW HOLE @ 2,633' SLM (2,605' MD). SET 2-7/8" SLIP STOP TUBING STOP (oal: 24") @ 2,662' SLM (2,632' MD). SET 2-7/8" D&D PACK OFF (oal: 24") @ 2,662' SLM (2,632' MD). SET 20' PATCH SECTION (oal: 254") @ 2,660' SLM (2,630' MD). SET 20' PATCH SECTION (oal: 254") @ 2,639' SLM (2,609' MD). SET 2-7/8" D&D PACK OFF, 10' PATCH SECTION (oal: 149") @ 2,618' SLM (2,588' MD). RUN D&D HOLE FINDER DOWN TO PATCH @ 2,606' SLM (2,576' MD), LRS PRESSURED UP TUBING TO 2000psi & WATCH FOR 5min, NO PRESSURE LOSS (pass). SET 2-7/8" TUBING STOP SLIP STOP (oal: 18") @ 2,606' SLM (2,576' MD). WELL S/I ON DEPARTURE, DSO NOTIFIED. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/17/2020 - Thursday No operations to report. No operations to report. No operations to report. 9/19/2020 - Saturday No operations to report. 9/22/2020 - Tuesday 9/20/2020 - Sunday No operations to report. 9/21/2020 - Monday Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-81 (PTD 200-066) Leak Detection Log 08/14/2020 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 2000660 E-Set: 34249 Abby Bell 11/13/2020 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: Install Tubing Patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,790'N/A Casing Collapse Conductor N/A Surface 2,570psi Production 5,410psi Liner 7,500psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8/31/2020 4-1/2" MILNE PT UNIT F-81 C.O. 432D 8/19/2020 ZXP Packer and N/A 12,231' MD / 6,641' TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 12,789' Authorized Signature: 12,422' 2-7/8" Perforation Depth MD (ft): See Schematic See Schematic 110' 20" 9-5/8" 7" 7,515' N/A 8,430psi558' 12,422' 3,950psi 7,240psi 4,153' 6,830' 7,192' 7,515' 3,386 N/A Milne Point Unit / Kaparuk River Sands 110' 110' 6.5#/ L-80/ EUE TVD Burst 12,103' MD Hilcorp Alaska LLC Length Size 7,193'12,701'7,105' Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388235 200-066 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22959-00-00 Tubing Grade:Tubing MD (ft): David Haakinson COMMISSION USE ONLY Authorized Name: N/A Perforation Depth TVD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.10 09:19:15 -08'00' By Samantha Carlisle at 11:49 am, Sep 10, 2020 320-372 SFD 9/11/2020 DSR-9/10/2020 X DLB 09/10/2020 ADL 025509 Kuparuk 10-404 MGR15SEP20 Waiver to CO390 A is approved for a 4 month production period. A monthly estimated reservoir BHP to be provided to AOGCC during the 4 month production period. Wellhead/tree to be visually inspected 4 times daily by pad operator during 4 month production period. Comm pq Yes 9/16/2020 dts 9/16/2020 JLC 9/16/2020 RBDMS HEW 9/17/2020 Tubing Patch Well: MPU F-81 Date: 08-18-2020 Well Name:MPU F-81 API Number: 50-029-22959-00-00 Current Status:Shut In - ESP Producer Pad:F-Pad Estimated Start Date:August 31 st, 2020 Wellwork unit:SL/EL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:2000660 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 AFE Number:Job Type:Tubing Patch Current Bottom Hole Pressure: 4,037 psi @ 6,512’ TVD ESP Gauge (7/28/2020) |11.9 PPG Maximum Expected BHP:4,037 psi @ 6,512’ TVD Stable SBHP |11.9 PPG MPSP:3,386 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 51° @ patch set depth MIN ID:2.441” to patch set depth Brief Well Summary MPU F-81 was drilled and completed as a Kuparuk A sand producer. Perforations in the C Sand were added in 2015. The well has been SI since November 2016 due to an apparent ESP failure. After further review of the loss of flow, indications of a tubing leak were found. Subsequent well-work did in fact find a tubing leak at 2,605’ MD. The ESP is suspected to still be in operable condition. The well was producing 100 BOPD prior to shut in. Notes Regarding Wellbore Condition x Hilcorp Alaska seeks approval to return MPU F-81 to production as either a free-flowing or ESP producer in variance to CO 390A. o A Risk Mitigation Plan is attached. x Well was SI on 11/6/16 due to increasing FBHP and increase in downhole motor load. x Single Tubing leak confirmed at 2,605’ MD on 8/14/20 with a Slickline leak detect. o The tubing Joint from 2,600 MD to 2,631’ MD also has considerable wall loss per the caliper survey. Objective x Set D&D tubing patch x Backup Contingency: o E-line Paragon packer patch Procedure Slickline 1. MIRU SL. PT lubricator to 200 psig low, 3500 psig high. 2. RU LRS for pump support 3. RIH w/ rope leak detect to leak interval and locate leak depth at 2,605’ MD. a. Depths correlated to SL Memory Spinner/GR/CCL log dated 8-14-2020. Tubing Patch Well: MPU F-81 Date: 08-18-2020 4. Flag wire and POOH. 5. Brush and Flush tubing at patch setting interval (±50’ up/down from leak point). 6. RIH with tubing slip-stop and set 30’ below leak depth (flagged wire) @ ±2,635’ MD. 7. Set D&D pack-off on slip-stop. 8. RIH with stinger, spacer pipe, and receptacles to make tubing patch at ±50’ element to element. 9. Land in lower D&D pack-off seal assembly and set upper D&D pack-off. 10. Set upper D&D pack-off at a target depth of ±2,585’ MD. 11. RIH with D&D hole-finder to top of patch. 12. PT tubing to 1,500 psig to confirm upper packer and up-hole tubing integrity. 13. After passing test, RIH w/ 2.875” tubing stop and set on top of upper D&D pack-off. 14. RDMO Slick-line and LRS. Leave well SI. Contingency Tubing Patch Set (If D&D patch is unsuccessful) E-line 1. MIRU EL. PT lubricator to 200 psig low, 3500 psig high. 2. RIH with GR/CCL and 2.875” paragon packer and set packer mid-element @ ±2,635’ MD a. Correlate to SL Memory Spinner/GR/CCL log dated 8-14-2020. Slickline 3. MIRU SL. PT lubricator to 200 psig low, 3500 psig high. 4. RIH with latch seal assembly, ±50’ of 1.9” spacer pipe in two intervals, and top 2.875” paragon packer. 5. Land in lower paragon packer and set top packer mid-element @ ±2,585’ MD 6. RIH with 2.875” paragon packer test tool and land in upper packer. 7. PT tubing to 1,500 psig to confirm upper packer and up-hole tubing integrity. 8. RDMO Slick-line Attachments: 1) Risk Mitigation Plan 2) Current Schematic 3) Proposed Schematic Tubing Patch Well: MPU F-81 Date: 08-18-2020 Risk Mitigation Plan x Hilcorp Alaska seeks approval to return MPU F-81 to production as either a free-flowing or ESP producer in variance to CO 390A. The request is to flow the well to reduce reservoir pressure through the following risk mitigation plan: o Offset Injector F-83 will remain shut-in and flagged to not return to injection until the reservoir pressure is below 8.5 ppge. o Pad Operator to have increased oversight on well by visually inspect wellhead and flowline 4- times daily. _____________________________________________________________________________________ Revised By: TDF 3/13/2020 SCHEMATIC Milne Point Unit Well: MPF-81 Last Completed: 3/12/2015 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 4 6 7 8 9 9 11 12 13 14 9-5/8” 1 3 3/8” SS Capstring 15 KUP A Sands PBTD =12,701’ (MD) / PBTD = 7,105’(TVD) 5 4-1/2” 2 KUP C Sands 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1149’GLM - Orificed 2 1,004’ TAM Port Collar 3 11,894’ GLM – Dummy 4 12,031’ HES XN-Nipple – ID= 2.250 5 12,042 Discharge Head 6 12,064’ Pump – 161P11 PMSXD 7 12,069’ Gas Separator- GRSFTXAR 8 12,076’ Upper Tandem Seal Section- GSB3DBUT SB/SB PFSA: Lower- GSB3DBUT SB/SB PFSA 9 12,099’ Motor - MSP1-250: 210HP/ 2,380 V/ 53 Amp 10 12,101 Phoenix Sensor w/ 6 Fin Centralizer Bottom 12,103’ 11 12,231’ Baker ZXP Packer 12 12,245’ Baker HMC Liner Hanger 13 12,422’ 7”, 26#, L-80 BTC Shoe 14 12,702’ 4.5” Float Collar (PBTD) 15 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8" Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 _____________________________________________________________________________________ Revised By: TDF 8/17/2020 PROPOSED Milne Point Unit Well: MPF-81 Last Completed: 3/12/2015 PTD: 200-066 TD =12,790’ (MD) / TD = 7,193’(TVD) 20” Orig DF Elev.= 27.4’ / Orig. GL Elev. = 11’ 7” 4 6 7 8 9 9 11 12 13 14 Proposed Tubing Patch: ±2,585’ to ±2,635’ 9-5/8” 1 3 3/8” SS Capstring 15 KUP A Sands PBTD =12,701’ (MD) / PBTD = 7,105’(TVD) 5 4-1/2” 2 KUP C Sands 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 54.5 / K-55 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 7,515’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,422’ 4-1/2” Liner 12.6 / L-80 / IBT Mod 3.883 12,231’ 12,789’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.347 Surface 12,103’ 3/8” Capstring Stainless Steel N/A Surface 12,103’ JEWELRY DETAIL No Depth Item 1149’GLM - Orificed 2 1,004’ TAM Port Collar 3 11,894’ GLM – Dummy 4 12,031’ HES XN-Nipple – ID= 2.250 5 12,042 Discharge Head 6 12,064’ Pump – 161P11 PMSXD 7 12,069’ Gas Separator- GRSFTXAR 8 12,076’ Upper Tandem Seal Section- GSB3DBUT SB/SB PFSA: Lower- GSB3DBUT SB/SB PFSA 9 12,099’ Motor - MSP1-250: 210HP/ 2,380 V/ 53 Amp 10 12,101 Phoenix Sensor w/ 6 Fin Centralizer Bottom 12,103’ 11 12,231’ Baker ZXP Packer 12 12,245’ Baker HMC Liner Hanger 13 12,422’ 7”, 26#, L-80 BTC Shoe 14 12,702’ 4.5” Float Collar (PBTD) 15 12,789’ 4.5” 12.6#, L-80 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup C Sand 12,477’ 12,491’ 6,884’ 6,898’ 14’ 3/11/2015 3-3/8”/6spf / Open Kup. A3 Sands 12,530’ 12,540’ 6,896’ 6,936’ 10’ 6/6/2005 3-3/8”/6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/21/2000 2.5”/ 6spf / Open Kup. A2 Sands 12,550’ 12,570’ 6,956’ 6,975’ 20’ 6/23/2000 3-3/8”/ 6spf / Open Kup. A1 Sands 12,581’ 12,591’ 6,986’ 6,996’ 10’ 6/7/2005 3-3/8”/ 6spf / Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 30” Hole 9-5/8" Cmt w/ 980 sx AS 3-Lite, 205 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 156 sks Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 79 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 554’ Max Hole Angle = 75 deg. @ 8,832’ Max Hole Angle through perforations = 9 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” “FLS” Wellhead 11” x 11” 5M FMC Gen 5A, w 11” x / 2-9/16” NSCT. 2.5” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22959-00-00 Drilled and Cased by Doyon 141 - 6/18/2000 Perforate, Frac & Cleanout - 6/23/2000 RWO & ESP Completion w/ Nabors 4-ES – 8/12/2000 RWO & ESP Completion w/ Nabors 4-ES – 1/30/2001 RWO and w/ Nabors 4-ES – 3/27/2002 RWO and Add Perfs w/ Nabors 4-ES – 6/9/2005 RWO & ESP Completion w/ Nabors 3S – 7/19/2007 RWO, ESP Completion & Cup Pkr and Excluder Screen w/ Nabors 3S -1/5/2008 ESP RWO, Pull Cup and Packer Screens w/ Nabors 3S –4/3/2009 ESP RWO & Add Capstring by Nordic #3 – 3/12/2015 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMI„oION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations ❑ Perforate U Other U ESP Change-out Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 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 0 Exploratory ❑ 200-066 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22950-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0388235 MILNE PT UNIT KR F-81 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): <>A N/A Milne Point Unit/Kuparuk River, apds 11.Present Well Condition Summary: Qom' Total Depth measured 12,790 feet Plugs measured N/A t E C II\E D true vertical 7,193 feet Junk measured N/A feet APR 4 2 5 Effective Depth measured 12,701' feet Packer measured 12,231' feet true vertical 7,105' feet true vertical 6,641' feet A V G C C Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7,515' 9-5/8" 7,515' 4,152' 3,950psi 2,570psi Intermediate Production 12,422' 7" 12,422' 6,830' 7,240psi 5,410psi Liner 558' 4-1/2" 12,789' 7,192' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic CANNED . � 1 , ' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 12,103' 6,514' 12,231'(MD) Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 6,641'(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: 118 18 439 260 327 Subsequent to operation: 171 81 741 300 285 14.Attachments: 15.Well Class after work: Copies f Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 GiEl WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sus ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-112 Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer SignatureZ. Phone 907-777-8377 Date 4/14/2015 b 2 ‘1 i•-/-- 0.-/`'; RBDMS 'i\ APR 1 8 2015 Form 10-404 Revised 10/20127/4...., /o/f�— Submit Original Only Milne Point Unit Well: MPF-81 SCHEMATIC Last Completed: 3/12/2015 Hilcora Alaska,LLC PTD: 200-066 CASING DETAIL Orig DF Elev.27.4'/Orig.GL Elev.=11' Size Type Wt/Grade/Conn Drift ID Top Btm 20 aj j20" Conductor 54.5/K-55/N/A N/A Surface 110' e t 9-5/8" Surface 40/L-80/BTC 8.679 Surface 7,515' 7" Production 26/L-80/Hydril 563 6.151 Surface 12,422' 44. 1 4-1/2" Liner 12.6/L-80/IBT Mod 3.883 12,231' 12,789' a TUBING DETAIL x" 2-7/8" Tubing _ 6.5/L-80/EUE 2.347 Surface 12,103' 1; 3/8" Capstring Stainless Steel N/A Surface 12,103' 2 ': JEWELRY DETAIL No Depth Item 9-5/8" fi 1 149' GLM-Orificed 1,4 2 1,004' TAM Port Collar kilo * 3 11,894' GLM-Dummy 3/8SS Capstring .' 4 12,031' HES XN-Nipple-ID=2.250 5 12,042 Discharge Head 6 12,064' Pump-161P11 PMSXD 7 12,069' Gas Separator-GRSFTXAR }; 8 12,076' Upper Tandem Seal Section-GSB3DBUT SB/SB PFSA:Lower-GSB3DBUT SB/SB PFSA 9 12,099' Motor- MSP1-250:210HP/2,380 V/53 Amp 1 4,1 10 12,101 Phoenix Sensor w/6 Fin Centralizer Bottom 12,103' 11 12,231' Baker ZXP Packer :a "< `� 12 12,245' Baker HMC Liner Hanger 'f` 13 12,422' 7",26#,L-80 BTC Shoe 14 12,702' 4.5"Float Collar(PBTD) .2, '4 15 12,789' 4.5"12.64,L-80 Float Shoe td ,- ` PERFORATION DETAIL ' Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Size/SPF/Status ) 3 % Kup C Sand 12,477' 12,491' 6,884' 6,898' 14' 3/11/2015 3-3/8"/6spf/Open S+ Kup.A3 Sands 12,530' 12,540' 6,896' 6,936' 10' 6/6/2005 3-3/8"/6spf/Open I Kup.A2 Sands 12,550' 12,570' 6,956' 6,975' 20' 6/21/2000 2.5"/6spf/Open to Kup.A2 Sands 12,550' 12,570' 6,956' 6,975' 20' 6/23/2000 3-3/8"/6spf/Open tall Kup.Al Sands 12,581' 12,591' 6,986' 6,996' 10' 6/7/2005 3-3/8"/6spf/Open 11 IS 4 I WELL INCLINATION DETAIL '" KOP@554' 'y8,832' Max Hole Angle=75 deg. @ 5 z ).s Max Hole Angle through perforations=9 deg. OPEN HOLE/CEMENT DETAIL ' f r 6 7 20" Cmt w/260 sx of Arcticset I in 30"Hole to sea ? 9-5/8" Cmt w/980 sx AS 3-Lite,205 sx Class"G"in 12-1/4"Hole V _ 8 7" Cmt w/156 sks Class"G"in 8-1/2"Hole ift', i.• =,•,, 4-1/2" Cmt w/79 sx Class"G"in 6-1/8"Hole j 41 9 TREE&WELLHEAD Tree 5M CIW 2-9/16""FLS" st l ► 11"x 11"5M FMC Gen 5A,w 11"x/2-9/16"NSCT. 2.5"CIW-H l ;k 10 Wellhead BPV profile k 11 12 GENERAL WELL INFO 7' , 13 API:50-029-22959-00-00 Drilled and Cased by Doyon 141 -6/18/2000 KUP CSar�s Perforate,Frac&Cleanout-6/23/2000 r KLPASands RWO&ESP Completion w/Nabors 4-ES-8/12/2000 L RWO&ESP Completion w/Nabors 4-ES-1/30/2001 " RWO and w/Nabors 4-ES-3/27/2002 RWO and Add Perfs w/Nabors 4-ES-6/9/2005 4-1/2"i 14 15 RWO&ESP Completion w/Nabors 3S-7/19/2007 TD=12,790'(MD)/1D=7,193'(1VD) RWO,ESP Completion&Cup Pkr and Excluder Screen w/Nabors 3S-1/5/2008 PBTD=12,701'(MD)/PBTD=7,105'(TVD) ESP RWO,Pull Cup and Packer Screens w/Nabors 3S-4/3/2009 ESP RWO&Add Capstring by Nordic#3-3/12/2015 Created By:TDF 4/14/2015 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number _Start Date End Date MPF-81 50-029-22959-00-00 200-066 3/6/2015 3/12/2015 Daily Operations: 3/4/15-Wednesday No operations to report. 3/5/15-Thursday No operations to report. 3/6/15-Friday Notified AOGCC of upcoming BOP test @ 3/6/2015 11:40. Move rig to F-81. 3/7/15-Saturday Rig accepted and on company time @ 0600. Burm cellar. Load 9.6 ppg brine. Hook up kill tanks and prep to bleed down the well. Move&spot Nordic 3 camp. Pull BPV.Tubing 700 psi,620 IA. Perform derrick inspection. Blow air though hard lines. R/U second kill tank. Pressure test to 3,000psi. PJSM,start to bleed down F-81 @ 13:40.Tubing pressure @ 600psi, IA @ 650psi.Bleed tubing& IA down to 40psi.Shut in and strap tank. Pressure came up to 80psi in 5 min. Bled back gas&143 bbl fluids.Continue to bleed down while waiting on second truck of seawater. Pressure @ 130psi on the annulus.Tubing @ 80psi.All hot seawater on location.Start to pump down tubing @ 3-4 bpm with an open annulus. Got seawater back @ 42 bbl away. Continue pumping until 150 bbl away getting gas&crude in with 8.5 ppg seawater. Shut down,getting clean seawater back. Monitor well.OA built to 240psi.Tubing 200psi. Bleed off gas from annulus. Got fluid back strait away.Start pumping @ 4-5 bpm monitoring returns.Seawater mixed with crude and gas.Pump total 580 bbl getting full returns. Line up on 9.6 ppg brine. Pump @ 2 bpm getting 8.5-8.8 ppg returns.Tubing pressure climbing&annulus pressure dropping.Continue pumping as ppg increases slowly. Pump surface to surface.Still getting 8.8 ppg hack. Pump total 548 bbl&9.6 PPG returns. Monitor well. Well on slight vac.Set BPV. Blow down all surface equipment. N/D Tree. Inspect threads on hanger. N/U BOPs. Received our last load of 9.6 ppg brine. 3/8/15-Sunday Finish N/U operations.Grease choke. Fill stack with water. Perform body test to 250psi low/3,000psi high.GOOD.Test BOPs as per AOGCC. 250psi low/3,000psi high. Had a 2 failures on the 3-1/2"IF floor valves.Change out same.Third valve tested good. Perform accumulator draw down.Good.Test gas&flow detection.Good. Work on strap&tally new 2-7/8"pipe.Suck out stack, R/D testing equipment. R/D Kill tanks and move out of way for spooling unit. Spot&R/U ESP spooling unit. Pull TWC. Fill tubing.8 bbl. M/U Landing joint with TIW. BOLD. Pull hanger to the rig floor. 108k up. Pull pump free 125K. Monitor well. 25 bph losses.Terminate ESP cable to hanger.Test ESP cable.GOOD. L/D hanger& landing joint.Top clamps corroded.Static losses @ 14 bph. Losses slowing. POOH,string ESP cable over sheaves&to spooler. POOH F/12,113' T/11,162'. Stand back 9 stands. Start L/D planed pipe. L/D 2-7/8"tubing F/11,162'T/ 9,800'.Cut out old splice from cable.Well out of balance.Circ tubing volume.Still out of balance.Circ btm up at 4 bpm. Monitor well static. POOH F/9,800'T/6,886'.Static loss @ 6 bph.Total losses to the well 127 bbl 9.6 brine. 3/9/15-Monday POOH F/6,886'T/4,678'. L/D 2-7/8"to pipe shed. POOH standing back 2-7/8"F/4,678'T/ESP Discharge head. Filling the hole wtih 1.5 over pipe displacment. Laid down 214 joints total. Load strap&tally 250 joints new pipe. L/D ESP assembly.Scale built up on discharge head.Take sample to send in. Motor locked up.Clean&clear rig floor. Count clamps, unload new ESP assembly&load out old assembly. Recovered 201 Lasallie clamps,5 pump protectrolizers,3 flat guards& 1 motor protectrolizer. P/U 2-7/8" mule shoe. RIH out of the derrick 51 stands slow inspecting pipe. L/D 18 more joints due to outer pitting&some thread erosion.Total joints layed down 231. P/U new pipe out of the pipe shed. F/4,925'T/7,600'+/-. Well fluid staying visible while running in the hole. • 3/10/15-Tuesday Continue TIH with total 249 jts,tag up 13'in on jt 249 less 30'RKB.Tag depth 12,588'in lower most perfs. Mouse hole single RU TIW and PU with top drive. Hole is holding fluid. Close annular BOP,attempt to reverse circulate. No go, formation broke over @ ICP 230psi and injecting 2 BPM @ 430psi FCP. No circ established.Bottom tag is solid will not wash. Report to engineer. Prepare to trip for perforating run. POOH LD 18 singles leaving 12,065'and rack back 77 stands new pipe and 51 stands original production string.Strapping stands.Hole fill is normal. RD Bell nipple, NU 13- 5/8"5M x 11"5M spool adapter and Dutch riser.Close annular fill Dutch riser. RU sand pipe to pump in on riser, PT riser against CSO to 500 psi. PJSM,finish RU.Check fire CCL PU 14'guns top shot 7'8"from CCL, 14 feet loaded 3-3/8"6 spf HC guns. Deploy RIH w/same. Hilcorp Alaska, LLC Hii,.or!) Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPF-81 50-029-22959-00-00 200-066 3/6/2015 3/12/2015 Daily Operations: 3/11/15-Wednesday RIH with CCL,GR and 14'3-3/8"JRC SD 6SPF,coorelate and tie in,verify with Eng/Geo on correlation adjust correlation 1'up.Perforate Kuparuk C sand from 12,477'-12,491'.Observe well. No surface response. POOH w/Eline.Verify all shots fired.RD Halliburton E-line,drain stack,ND dutch riser and adapter spool.Install bell nipple.Spool swap in spooling unit,organize ESP tools, PU/MU and service motor,tandem seals and pump. Install motor lead and cap check flat guards and protectolizers.Test ESP and cap string to 4,200 psi cycle check. Install top pup and XN Nipple. RIH w 2- 7/8" L-80 EUE completion cannon clamps for intitial 10 connections,continue RIH with clamps every other joint,test ESP and cap check every 2,000'average cap cycle 4,000psi.Well is holding column 9.6 ppg Brine. 3/12/15-Thursday Continue RIH to splice depth 8,000''.Splice ESP cable.Ambient Temp-40 degrees.Splice complete.Temp below running threshhold for ESP Cable.Temp-40. RIH very slow until splice in fluid in hole and meg test cable. RIH @ 30'per minte to TD with remainder of 2-7/8" ESP completion.Test cable,drain BOPS, install hanger and penetrator. Male cable penetrator connecor and feed capillary through hanger and land same.Orient and RI lockdowns. Install BPV. Hole in finely balanced well is staying full slide formation fluid feed.ND BOP/NU Tree and Test. Final depth from THF 12,103' bottom of centralizer,pumpmate 12,099', Motor 12,083'.Top of Tandem seals 12,069', gas separartor 12,064', pump/ discharge head @ 12,041', 1-10' pup Joint,XN nipple @12,030',3jts tbg, 1 pup joint Blank GLM @ 11,887', 1 pup jt, 377 jts tbg, 1 pup jt,GLM @ 142',3jts tbg,5' pup and tubing hanger.Hardware 199 cannon clamps,2 half clamps,3 flatbars,5 protectolizers. Remove BPVFreeze Protect.Ambient temp now-42.Pump 15 bbls diesel down tubing and 15 bbls diesel down annulus. Release Rig. 3/13/15-Friday No operations to report. 3/14/15-Saturday No operations to report. 3/15/15-Sunday No operations to report. 3/16/15-Monday No operations to report. 3/17/15-Tuesday No operations to report. A.= T1 �• icOF �� s7 THE STATE Alaska Oil and Gas , �4 o Conservation Commission - :=_ fALA Ic;A ..04.- - ,11).:__ _ 333 West Seventh Avenue — GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T a, ".� �`, Main: 907.279.1433 OFALASY'� 0 �4 "� Fax 907.276.7542 SCApNE www.aogcc alaska.gov Chris Kanyer _ � /'(Q / ,�f Operations Engineer a,00 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk Oil Pool, MPU KR F-81 Sundry Number: 315-112 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, / s )kA'351-e -- Cathy P. oerster Chair, Commissioner DATED this 0 day of March, 2015 Encl. • RECEWED STATE OF ALASKA FEB 2 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 343//5— APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well giG()¢- Change Approved Program ❑ Suspend❑ Plug Perforations ❑y Perforate Q Pull Tubing❑✓ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. Remove and Replace ESP Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ ' 200-066 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22959-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C/ Will planned perforations require a spacing exception? Yes ❑ No ❑� / MILNE PT UNIT KR F-81 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0388235 . Milne Point Unit/Ka aruk River Sands , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,790 • 7,193 12,701 7,105 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7,515' 9-5/8" 7,515' 4,153' 3,950psi 2,570psi Intermediate Production 12,422' 7" 12,422' 6,830' 7,240psi 5,410psi Liner 558' 4-1/2" 12,789' 7,192' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 12,117 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker ZXP Packer and N/A • 12,231 MD/6,641 ND and N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/6/2015 Oil E• Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanvertc'�i.hilcorp.com Printed Name /Chris Kanyer Title Operations Engineer Signature (,/I_. Phone 777-8377 Date 2/26/2015 777777 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(S -HZ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1- 3 , SPS Ej O F �S C AAA S tP - s/60 /S,. Spacing Exception Required? Yes ❑ No Subsequent Form Required: /p-YaI APPROVED BY Approved by: / L _ . COMMISSIONER THE COMMON Date: 3- ,3.- /5 / 3 Z /�n ❑ I '1)1'd 4ot711s JaV,� Submit Form and Form 10-403(Revise 0/2012) d Il r 12 months from the date of approval. Attachments in Duplicate RBDM MAR - 5 2015 /f0 3"2"is' 11 Well Prognosis Well: MPF-81 Ililcorp Alaska.LL Date:2/26/2015 Well Name: MPF-81 API Number: 50-029-22959-00-00 Current Status: SI Producer Pad: F Pad Estimated Start Date: March 7, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 6, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 200-066 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: 1550550 rr 'j Current Bottom Hole Pressure: — 3,413 psi @ 7,000' ND Gl. '(Last BHP measured 1/28/2015) Maximum Expected BHP: — 3,500 psi @ 7,000' TVD (Assume virgin pressure gradient of 0.5psi/ft for added perfs: Kuparuk sands) 'c' KA_e Max.Allowable Surface Pressure: 860 psi (Based on actual reservoir conditions and water cut of 50% (0.385psi/ft) (currently WC 78%)with an added safety factor of 1000' ND of oil cap) Brief Well Summary: The Milne Point F-81 well was drilled as a Kuparuk development well that TD'd at a depth of 12,790' and ran and cemented 7" production casing & 4-1/2" liner in June 2000. The well was perforated and Frac'd in the Kuparuk A2`sands and initially completed with an ESP. The well has had ESPs failed and replaced in 2001 and 2002. In June 2005 the Kuparuk Al & A3 sands were perforated and an ESP was run. Subsequent failed ESPs were changed out in January 2009, March 2009, and 2012. The recent pump was shut in due to a hole in the tubing. A patch was set in October 2014 across the suspected tubing leak, but the pump was still unable to produce significant fluids. The well has remained shut in ever since. A recent casing pressure test was performed on 3/29/2009 to 1500psi. Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP, perform fill cleanout, add Kuparuk C sand perforations, & run 2-7/8" ESP completion with downhole chemical injection. - Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater and monitor well. r/ 3. If necessary,circulate well withg brine (or appropriate kill weight fluid). Monitor well. 4. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 5. Unseat hanger and pull 2-7/8" ESP completion from 12,117'to surface and lay down same. I/ Well Prognosis Well: MPF-81 llileorp Alaska.LL Date: 2/26/2015 6. RIH with tapered 4-1/2" x 7" cleanout BHA to +/-12,592'. POOH with same. 7. RU Eline, RIH and perforate the Kuparuk C sands at+/-12,477'to +1-12,491', POOH with same. Monitor well. 8. 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+/-12,117'. Land tubing hanger. 9. ND BOP, NU and tree. 10. RDMO workover rig and equipment. 11. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPF-81. • II SCHEMATIC Last Completed: 4/3/2009 Hilcorp Alaska,LLC PTD: 200-066 CASING DETAIL Orig DF Elev.27.4'/Orig.GL Elev.=11' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 54.5/K-55/N/A N/A Surf 110' 20 5 9 5/8" Surface 40/L-80/BTC 8.679 Surf 7,515' i 7" Production 26/L-80/Hydril 563 6.151 Surf 12,422' "+ 1 4-1/2" Liner 12.6/L-80/IBT Mod 3.883 12,231' 12,789' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surf 12,117' ®2 JEWELRY DETAIL No Depth Item 1 139' Camco 2-7/8"x 1"KBMM GLM 9-5/8, 2 1,004' TAM Port Collar • 3 11,894' Camco 2-7/8"x 1"KBMM GLM ' 4 12,033' 2-7/8"HES XN-Nipple(2.25 No-go ID) 5 12,049' Centrilift Tandem ESP 137-P17/ SXD 18-P75 SXD 6 12,075' Intake Gas Separator 7 12,080' Tandem Seal Section 8 12,094' Motor KMHG,228HP,2,305 Volt,60 Amp 19 12,113' PumpMate XTO w/6 Fin Centralizer(TVD=6,524),Bott.12,117' 1,, -, 10 12,231' Baker ZXP Packer W�J x, 11 12,245' Baker HMC Liner Hanger (� ,J� 12 12,422' 7",26#,L-80 BTC Shoe 13 12,702' 4.5"Float Collar(PBTD) . 14 12,789' 4.5"12.64,L-80 Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Size/SPF/Status Kup.A3 Sands 12,530' 12,540' 6,896' 6,936' 10' 6/6/2005 3-3/8"/6spf/Open Kup.A2 Sands 12,550' 12,570' 6,956' 6,975' 20' 6/21/2000 2.5"/6spf/Open 3 Kup.A2 Sands 12,550' 12,570' 6,956' 6,975' 20' 6/23/2000 3-3/8"/6spf/Open Kup.Al Sands 12,581' 12,591' 6,986' 6,996' 10' 6/7/2005 3-3/8"/6spf/Open WELL INCLINATION DETAIL KOP @ 554' a Max Hole Angle=75 deg. @ 8,832' Max Hole Angle through perforations=9 deg. J 5 OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset I in 30"Hole 9-5/8" Cmt w/980 sx AS 3-Lite,205 sx Class"G"in 12-1/4"Hole 7" Cmt w/156 sks Class"G"in 8-1/2"Hole a: 6 7 4-1/2" Cmt w/79 sx Class"G"in 6-1/8"Hole s TREE&WELLHEAD Tree 5M CIW 2-9/16""FLS" Wellhead 11"x 11"5M FMC Gen 5A,w 11"x/2-9/16"NSCT. 2.5"CIW-H BPV profile 9 GENERAL WELL INFO API:50-029-22959-00-00 10 11 Drilled and Cased by Doyon 141 -6/18/2000 lk Perforate,Frac&Cleanout-6/23/2000 7" 12 RWO&ESP Completion w/Nabors 4-ES-8/12/2000 RWO&ESP Completion w/Nabors 4-ES-1/30/2001 _ RWO and w/Nabors 4-ES-3/27/2002 KUPASands RWO and Add Perfs w/Nabors 4-ES-6/9/2005 RWO&ESP Completion w/Nabors 3S-7/19/2007 RWO,ESP Completion&Cup Pkr and Excluder Screen w/Nabors 3S-1/5/2008 41/7'1 13 14 ESP RWO,Pull Cup and Packer Screens w/Nabors 3S-4/3/2009 TD=12,790'(MD)/TD=7,193'(TVD) NOTE: PBTD=12,701'(MD)/PBTD=7,105'(TVD) Need Cementing Report to Establish Tops Created By:TDF 1/14/2015 Milne Point Unit • Well: MPF-81 PROPOSED Last Completed: 4/3/2009 Hilcorp Alaska,LLc PTD: 200 066 CASING DETAIL Orig DF Elev.=27.4'/Orig.GL Elev.=11' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 54.5/K-55/N/A N/A Surface 110' 2(Y' 9-5/8" Surface 40/L-80/BTC 8.679 ' Surface 7,515' 7" Production 26/L-80/Hydril 563 6.151 Surface 12,422' . 1 4-1/2" Liner 12.6/L-80/IBT Mod 3.883 12,231' 12,789' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surface ±12,11 3/8" Capstring Stainless Steel N/A Surface ±12,117' ©2 JEWELRY DETAIL No Depth Item 95/g • ' 1 39' GLM 2 1,004' TAM Port Collar 3 ±11,894' GLM 4 ±12,033' HESXN-Nipple 5 ±12,049' Pump 6 ±12,075' Intake Gas Separator 7 ±12,080' Tandem Seal Section 8 ±12,094' Motor 9 ±12,113' XTO w/6 Fin Centralizer Bottom±12,117' ' 10 12,231' Baker ZXP Packer 11 12,245' Baker HMC Liner Hanger 12 12,422' 7",26#,L-80 BTC Shoe 13 12,702' 4.5"Float Collar(PBTD) 14 12,789' 4.5"12.6#,L-80 Float Shoe ' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Size/SPF/Status Kup C Sand ±12,477' ±12,491' ±6,884' ±6,898' ±14' Future Future 3 Kup.A3 Sands 12,530' 12,540' 6,896' 6,936' 10' 6/6/2005 3-3/8"/6spf/Open Kup.A2 Sands 12,550' 12,570' 6,956' 6,975' 20' 6/21/2000 2.5"/6spf/Open rt� Kup.A2 Sands 12,550' 12,570' 6,956' 6,975' 20' 6/23/2000 3-3/8"/6spf/Open V' Kup.Al Sands 12,581' 12,591' 6,986' 6,996' 10' 6/7/2005 3-3/8"/6spf/Open ii #" :, WELL INCLINATION DETAIL M4 t, KOP @ 554' 4 Max Hole Angle=75 deg. @ 8,832' 5 Max Hole Angle through perforations=9 deg. OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset I in 30"Hole �_ 6 7 9-5/8" Cmt w/980 sx AS 3-Lite,205 sx Class"G"in 12-1/4"Hole 7" Cmt w/156 sks Class"G"in 8-1/2"Hole j4 8 4-1/2" Cmt w/79 sx Class"G"in 6-1/8"Hole rt TREE&WELLHEAD fi fe. Tree 5M CIW 2-9/16""FLS" Wellhead 11"x 11"5M FMC Gen 5A,w 11"x/2-9/16"NSCT. 2.5"CIW-H fi9 BPV profile t GENERAL WELL INFO A wc.1011 API:50-029-22959-00-00 7" , 12 Drilled and Cased by Doyon 141 -6/18/2000 4 ' Perforate,Frac&Cleanout-6/23/2000 • 4 KIR C Sands RWO&ESP Completion w/Nabors 4-ES-8/12/2000 KUPASands RWO&ESP Completion w/Nabors 4-ES-1/30/2001 RWO and w/Nabors 4-ES-3/27/2002 ' - RWO and Add Perfs w/Nabors 4-ES-6/9/2005 RWO&ESP Completion w/Nabors 3S-7/19/2007 4-1/2"; gi 13 14 RWO,ESP Completion&Cup Pkr and Excluder Screen w/Nabors 3S-1/5/2008 1D=12,790'(MD)/TD=7,193'(TVD) ESP RWO,Pull Cup and Packer Screens w/Nabors 3S-4/3/2009 PBTD=12,701'(MD)/PBTD=7,105'(TVD) NOTE: Need Cementing Report to Establish Tops Created By:TDF 2/26/2015 MPU BOP Stack I f 1 O iiiiii 1111, Hydril 13 5/8 5M €_ 13 5/8 5M _ 2 7/8"-5-%z" variables Spacer spool 13 5/8 5M IIIILIIIILALIIMILIIMBI aMerl_ 13 5/8 5M ) Blinds 1[111MINPAIMIFf---1 ! ' 71:-Aill, --- „1.-:,, 1 0 M i t gricth ji t ' Vc . illhilladallikill clinuriorip Spacer spool 13 5/8 5M 135/8" 5MX11" 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. They are available in the original file, may be scanned during the rescan activi~ or are viewable by direct inspection of the file. ~Z~__- ~) ~ ~ Well History File Identifier RESCA/ DIGITAL DATA /olor items: ~ Diskettes, No~, rayscale items: [] Other, No/Type Poor Quality Originals: Other: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES://~ NOTES: ORGANIZED BY: BEVERLY BREN ~SHERYL MARIA LOWELL [] Other DATE: /6 ~/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN~SHERYL MARIA LOWELL Scanned (so..) II1[111111111111111 PAGES://~:? (at the time of scanning) SCANNED BY; BEVERLY E~ VINCENT SHERYL MARIA LOWELL RESoA..EO.Y: BEVE.L¥ "~ V,.CE.T S.E.Y' M^.IA LOWELL O^TE=/~. ?.. ~ ~ ,s, ~ General Notes or Comments about this file: Quality Checked (done) RevlNOT~cannecl.wl~d • bp BP Exploration (Alaska) Inc. • Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder a,U © J n6@ Alaska Oil and Gas Conservation Commission � F� 333 West 7th Avenue I • ' Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, A Mehreen Vazir BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Wet Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 WA 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 WA 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top lob MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF-58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 WA 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 --- MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF-89 2050900 50029232680000 1.2 WA 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPOR SUNDRY WELL OPERAT NS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory - 200 - 066 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 22959 - 00 - 00 7. Property Designation: _ 8. Well Name and Number: ADL 025509 & 388235 MPF-81 9. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 12790' feet Plugs (measured) None feet true vertical 7193' feet Junk (measured) None feet Effective depth: measured 12701' feet Packer: (measured) None feet true vertical 7105' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7487' 9 - 5/8" 7515' 4153' 5750 3090 Intermediate Production 12396' 7" 12422' 6830' 7240 5410 Liner 558' 4 -1/2" 12231' - 12789' 6641' - 7192' 8430 7500 Perforation Depth: Measured Depth: 12530' - 12591' H a � 2.011 2 ; Au r True Vertical Depth: 6936' - 6996' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 12117' 6528' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: , * �, Intervals treated (measured): �; p, ,,, � ° dt ° : Treatment description including volumes used and final pressure: Alai,, ail t &i �,�yp st y ( rp /► v"Ois vY�l� / a A 1 A0'4nerigg 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: 14. Well Class after work: ❑ Copies of Logs and Surveys run 4 Daily Report of Well Operations ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic co Well Schematic Diagram 15. Well Status after work: ❑ GINJ ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ryan Ciolkosz, 564 -5977 N/A Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: Signature i��a,� Phone 564 -4628 Date 07 s�11 Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 REIDMS JUL 13 1016 ty 7./1' Submit Original Only • • " , : North America. - ALASKA, - BP Page t of s . , Operation Summary Report Common Well Name: MPF -81 1AFE No Event Type: WORKOVER (WO) I Start Date: 6/22/2011 End Date: X4- 00T6L -E: (800,000.00 ) I Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 5/30/2000 12:00:00AM , Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. ' UWI_500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations ! (hr) i (ft) 6/22/2011 x00:00 - 03:00 3.00 WHSUR P _ WHDTRE I MU DSM LUBRICATOR AND PT TO 250/3500 PSI FOR 5 MIN. I I I PULL TWC - TWC CAME OUT OF THE HOLE WITH NO RUBBER ELEMENT LEFT ON. I I- COULD NOT FIND THE ELEMENT IN THE WELLHEAD I !MU LUBRICATOR WITH BPV AND SET ' - TESTED BPV WITH ROLLING TEST AT 23 SPM I-OR 600 PSI FOR 5 MIN WITH NO LEAK I PAST BPV AT SURFACE , RD DSM AND INSTALL TREE CAP 03:00 - 04:00 1.00 MOB I P I PRE I CONTINUE TO RD RIG I - OFF LOAD 30 BBLS FROM PIT 3 AND RINSE , ! - MOVE OUT GENERATOR, AND CHANGE TRAILER - MOVE OUT SLOP TANK - DISCONNECT FLOW BACK TANK HARD LINE ' 04:00 - 05:00 1 1.00 MOB P I PRE I NOTIFY PAD OPERATOR OF RIG MOVE OFF , , OF MPF -86 TO MPF -81 - CONTINUE TO PREP THE RIG TO MOBILIZE ! -CLIMB DOWN FROM 4 HIGH MAT BOARD STACK 12:30 05:00 - 7.50 MOB P PRE PULL OFF OF MPF -86 AND SET DOWN ON I PAD -MOVE MAT BOARDS FROM MPF -86 TO . MPF -81 -HAD TO RELAY MATS DUE TO COLSE WELL I I I HOUSE SPACING. -SPOT OVER MPF -81 WITH TOOLPUSHER _ AND BP WSL PRESENT. 12:30 - 14:00 1.50 I RIGU P PRE SPOT RIG COMPONENTS ! I 1-HARD LINE CREW M/U HARD LINE TO FLOW ' I BACK TANK. -RIG UP BELLY BOARD ** *ACCEPT RIG AT 12:30 HRS 6/22/2011 * ** 14:00 - 16:00 2.00 RIGU P PRE TAKE ON 10.9 # BRINE -R/U KILL LINES TO THE TREE 16:00 - 17:00 1.00 RIGU P PRE HELD RIG EVAC DRILL AAR: ONE WORKER WAS INSTRUCTED TO DISREGARD THE DRILL AND CONTINUE WORKING IN HIS AREA. WORKER WAS FOUND BY THE SWEEPER TEAM AND ESCORTED TO THE MUSTER AREA. AAR: IT WAS SUGGESTED THAT TRUCK DRIVERS USE HARMONY RADIOS IF THEY HAVE QUESTION ON CHANGE IN MUSTER AREA. ----- - - - - -- 17:00 - 19:00 2.00 RIGU P PRE FILL AND TEST CIRCULATING LINES, CHOKE MANIFOLD AND LINES TO FLOW BACK TANK. TEST TO 250 LOW AND 3,500 HIGH AND I CHART TEST Printed 7/11/2011 10:33:48AM North America - ALASKA BP - Page 2 of g ration Summa Re P Common Well Name: MPF -81 AFE No Event Type: WORKOVER (WO) Start Date: 6/22/2011 I End Date: r X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM 1Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date ! From - To Hrs i Task Code NPT NPT Depth I Phase Description of Operations 19:00 23:00 4.00 - BOPSUR (ft) PRE — (hr) - - - -- - � P PRE STAND BY AND ALLOW LITTLE RED HOT OIL TO FREEZE PROTECT F -86 IA ' I THERE UNIT IS RIGHT NEXT TO OUR FLOW BACK TANK M P U WELLS GROUP HAS ASSUMED OUR RESPONSIBILITY FOR FREEZE PROTECT ' OPPS ON F -86 23:00 - 00:00 I 1.00 BOPSUR P ' PRE iMU DSM LUBRICATOR PT TO 250 / 3500 PSI FOR 5 CHARTED MIN PULL TWC ' WHP = 1250 IA = 1050 OA = 50 6/23/2011 I 00:00 - 00:30 0.50 WHSUR P WHDTRE ' CREW CHANGE 00:30 01:00 0.50 I WHSUR P WHDTRE PJSM WITH RIG CREW AND TRUCK DRIVERS NOTIFIED MPU RADIO OF GAS VENTING , ! NOTIFIED PAD OPPERATOR OF GAS VENTING 01:00 - 02:30 1.50 WHSUR P WHDTRE WITH WHP = 1250 AND IA = 1050 OPEN IA THOUGH HAND CHOKE TO FLOW I I BACK TANK I '-SLOWLY BRING DOWN STREAM CHOKE , PRESSURE TO 100 PSI -BLEED IA DOWN TO 380 PSI -LOTS OF GAS RETURNS WITH CRUDE '- SHUT IN TO RE- SUPPORT FLOW BACK TANK VALVE CONNECTION -73 BBLS OF CRUDE IN FLOW BACK TANK -IA PRESSURE INCREASED TO 800 PSI IN 20 MIN 1 -OPEN MANUEL CHOKE AND BLEED IA BACK TO 390 PSI 02:30 - 03:10 0.67 ' WHSUR P ! WHDTRE LINE UP TO PUMP DOWN TUBING - OUT THE IA - TO HAND CHOKE - TO FLOW BACK TANK - CIRCULATE IN 75 BBLS / 850 STKS AT 3 BPM - SLOWLY WORK PUMPS UP TO 3 BPM , KEEPING DOWN STREAM PRESSURE BELOW 150 PSI - INITIAL PRESSURES AT 0.75 BPM IA =670 TUBING =810 - AT 3 BPM IA =840 AND TUBING = 1230 PSI WITH 105 PSI DOWNSTREAM OF CHOKE -FCP ARE IA =1170 AND WHP =820 PSI AT 3 BPM -SHUT DOWN PUMPS AND SHUT IN AT 850 STKS /72BBLS PRESSURES STABLE AT IA =1050 AND WHP=0 03:10 - 04 :00 0.83 I WHSUR P WHDTRE BULL HEAD DOWN TUBING AT 5 BPM FOR 850 STKS OR 72 BBLS INITIAL PRESSURES ARE IA =1670 WHP =1830 PSI FINAL PRESSURES ARE IA =234 AND WHP =2580 PSI SHUT DOWN PUMPS AND ALLOW FORMATION TO RELAX BACK TO IA =1050 AND WHP =0PSI VAC TRUCK RECOVED 135 BBLS OF CRUDE FROM FLOW BACK TANK Printed 7/11/2011 10:33:48AM North America ,- :ALASKA - BP : Page 3:of 9 ' C (eration Summary Report, : Common Well Name: MPF- 81 -- ___._.__- _ - __� _ _-- AFE No u � Event Type: WORKOVER (WO) Start Date: 6/22/2011 End Date: X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM I Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date ! From - To Hrs Task Code ! NPT I NPT Depth I Phase l Description of Operations hr (ft) ( ) ft 04:00 - 07:15 3.25 WHSUR P ! WHDTRE 1CIRCULATE IN THE LONG WAY HOLDING NO MORE THAN 150 PSI DOWN STREAM OF THE CHOKE WITH DIRTY RETURNS GOING TO " THE FLOW BACK TANK LOTS OF GAS AND CRUDE RETURNS VAC TRUCK RECOVERED A TOTAL OF 220 j BBLS OF CRUDE (MORE CAME OUT BUT WE WANTED IT CLEAN FOR THE RECYCLE I GUYS) ' ' AT 4500 STKS / 381 BBLS RETURN KWF IS UP TO 10.1 PPG BY 4800 STKS / 407 BBLS RETURN CLEAN, ' 10.9 PPG RETURNS AT 4900 STKS / 415 BBLS SHUT IN AND I • MONITOR FOR 15 MIN WELL ISONAVAC 07:15 - 08:00 0.75 WHSUR ', P I WHDTRE ;ESTABLISH LOSS RATES OF ! 15 BPH STATIC AND 48 BPH PUMPING 08:00 09:00 1.00 WHSUR i P WHDTRE R/D CHOKE MANIFOL AND KILL LINES IN CELLAR TO AND FROM THE TREE. ' I -R/U LINES TO FILL THE IA FROM THE MUD I PUMP. - CONTINUOUS HOLE FILL RATE -16 BPH. 09:00 - 10:30 1.50 WHSUR P WHDTRE PERFORM DERRICK INSPECTION. i -PERFORM TOP DRIVE INSPECTION. 10:30 WHSUR P 11:30 1.00 - WHDTRE DISCUSS STRIPPING DRILL 11:30 12:00 0.50 WHSUR P WHDTRE PJSM, -R /U CHOKE AND KILL LINE HOSES TO THE BOPE. 12:00 - 14:30 2.50 WHSUR P , WHDTRE FMC REP INSTALLED TWC. ! -ROLLING TEST FROM BELOW TO 500 PSI AT 1 -1.5 BPM, FOR 10 CHARTED MINUTES, GOOD TEST. - TESTED FROM ABOVE TO 250 PSI / 3,500 PSI FOR 10 CHARTED MINUTES. GOOD TEST. -DRAIN TREE. 14:30 - 16:30 2.00 WHSUR P WHDTRE PJSM WITH FMC REP. -N /D PRODUCTION TREE -INSPECT TBG HANGER. -9 TURNS TO M/U 8 RD EUE LANDING THREADS. 16:30 - 18:30 2.00 BOPSUR P DECOMP PJSM, N/U 13 5/8" 4 PREVENTER BOPE. - ANNULAR, 2 7/8" VBR, BLIND SHEARS, MUD CROSS, 2 7/8" SINGLE. -GREASE CHOKE MANIFOLD. -R/U TEST EQUIPMENT. 18:30 - 21:00 ' 2.50 BOPSUR P DECOMP PJSM, REMOVE 3 1/2" X 6" VBR FROM TOP RAM AND LOAD WITH 2 7/8" X 5" VBR. - REMOVE 2 7/8" X 5" VBR FROM BOTTOM RAM AND LOAD WITH 2 7/8" SINGLE SOLID BODY RAM. - VISUAL INTERNAL INSPECTION OF BOP'S Printed 7/11/2011 10:33:48AM North, America - ALASKA,- BP Page 4 of 9 1 ration Summary Report Common Well Name: MPF -81 AFE No Event Type: WORKOVER (WO) Start Date: 6/22/2011 End Date: , X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. LWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date From - To Task Code NPT NPT Depth Phase Description of Operations , (hr) — (ft)-- — 21:00 00:00 1 3.00 BOPSUR P T DECOMP TESTING 13 -5/8" BOPE TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. TEST WITNESS WAIVED BY LOU GRIMALDI OF AOGCC -RAMS TESTED TO 250 PSI LOW AND 3,500 I PSI HIGH. -HYDRILL TESTED TO 250 PSI LOW AND 3,500 n PSI HIGH -BOP'S DRESSED WITH 2 -7/8" X 5" VBR'S ABOVE THE BLINDS AND 2 -7/8" SOLID RAMS �� IN THE BOTTOM. ' -TEST USING 2 -7/8" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. ' -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA I DOCUMENTED IN CRT - AK -10 -45 i * * "10 BPH LOSS RATE WITH CONTINUOUS HOLE FILL. * ** 6/24/2011 00:00 - 02:30 1 2.50 1 BOPSUR P DECOMP ' CONTINUE TESTING 13 -5 /8" BOPE TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. TEST WITNESS WAIVED BY LOU GRIMALDI OF AOGCC ' -RAMS TESTED TO 250 PSI LOW AND 3,500 PSI HIGH. , - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -BOP'S DRESSED WITH 2 -7/8" X 5" VBR'S ABOVE THE BLINDS AND 2 -7/8" SOLID RAMS IN THE BOTTOM. ' -TEST USING 2 -7/8" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 CONTINUE TO FILL HOLE, LOSSES HAVE REDUCED TO 10 BPH 02:30 - 03:00 0.50 BOPSUR P DECOMP KOOMEY DRAW DOWN TEST: INITIAL PRESSURES:2900 1500 800 DRAW DOWN TO: 1500 1500 800 RECOVERED TO: 2900 1500 800 -200 PSI INCREASE IN 18 SECONDS. -FULL PRESSURE IN 94 SECONDS. -5 N2 BOTTLES @ 1900 PSI. 03:00 03:30 1 0.50 BOPSUR P DECOMP RD TEST EQUIPMENT DRAIN STACK 'TIMED RAM CLOSSURES: ' - ANNULAR 44 SEC @ 800 PSI -UPPER RAMS 8 SEC -BLIND SHEARS 17 SEC @ 700 PSI OPPERATING PRESSURE -LOWER RAMS 8 SEC CLEAN OFF THE TOP OF TWC 03:30 - 04:15 ' 0.75 BOPSUR P ' DECOMP MU OPSO LOPSO CROSS OVER TO THE TOP OF TUBING HANGER MU PUMP IN SUB TO TOP OF OPSO LOPSO ' MU DSM HYDRAULIC LUBRICATOR TO TOP OF PUMP IN SUB Printed 7/11/2011 10:33:48AM North America ALASKA BP . ' '! . Page „5 of 9 • 1ration Summary Report Common Well Name: MPF -81 AFE No Event Type: WORKOVER (WO) Start Date: 6/22/2011 I End Date: X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date From - To 1 Hrs Task Code NPT I NPT Depth ' Phase Description of Operations (hr) I (ft) 04:15 - 04:35 0.33 i BOPSUR P DECOMPTPRESSURE TEST LUBRICATOR 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MIN. 04:35 - 05:15 0.67 BOPSUR P DECOMP PULL TWC WHP =VAC I I I, RD LUBRICATOR ' 10 BPH LOSS RATE WITH CONTINUOUS HOLE 05:15 06:15 FILL * *. 1.00 PULL P DECOMP RU TO PULL 2 -7/8" ESP COMPLETION 06:15 - 07:30 1.25 I PULL P DECOMP ! IA IS ON A VAC FMC RUN OUT LOCK DOWN SCREWS I !PULL HANGER FREE WITH 120,000 PUW PULLING 110,000 CUT ESP CABLE AND L/D TBG HANGER. SECURE ESP CABLE TO LANDING JT AND RIH TO 12,145 MD r07:30 - 09:30 I 2.00 PULL 1 P I DECOMP CIRCULATE SURFACE TO SURFACE THROUGH- GAS BUSTER I -5 BPM/ 2280 -1980 PSI -NO HYDROCARBONS OBSERVED DURING — CIRCULATION. 09:30 - 10:30 PULL 1.00 P DECOMP I HANG ESP CABLE SHEAVE IN DERRICK. -BLOWN DOWN LINES - INSPECT TBG HANDLING EQUIPMENT. 10:30 - 14:30 T 4.00 P PULL D PULL 2 7/8" EUE TBG ESP COMPLETION AND STAND IN DERRICK -FROM –12,145' MD TO –10,145 MD. ' -L/D BAD JTS FROM JT# 64 TO 155. ** *COMPLETED WELL WORK TRANSFER ' PERMIT FOR W -PAD WELL- 04. * ** ** *13:00 HRS LOSS RATE @ 6 BPH WITH CONTINUOUS HOLE FILL. * ** PULL 2 7/8" EUE TBG ESP COMPLETION 14:30 - 21:30 7.00 PULL P DECOMP LD JOINTS 64 -155 PER WELL PLAN TIE INTO SECOND SPOOL FOR ESP CABLE MAINTAIN CONTINUOUS HOLE FILL 21:30 - 00:00 2.50 PULL P DECOMP PULL 2 7/8" EUE TBG ESP COMPLETION AND STAND IN DERRICK MAINTAIN CONTINUOUS HOLE FILL LOSSES ARE STILL AT 6 BPH AT 7,332 FT FOR CREW CHANGE 6/25/2011 00.00 00:30 0.50 PULL P DECOMP CREW CHANGE ! WALK AROUNDS / PJSM I 00:30 - 04:30 4.00 ' PULL P DECOMP CONTINUE TO PULL 2 7/8" EUE TBG ESP COMPLETION AND STAND BACK IN DERRICK FROM 7,732 FT MAINTAIN CONTINUOUS HOLE FILL AT 6 BPH 04:30 - 06:30 2.00 PULL P DECOMP PULL AND LD 5 -1/2" ESP PUMP ASSEMBLY IN SECTIONS -ALLOW ASSEMBLY OIL TO DRAIN BEFORE I LAYING DOWN. -PUMP LOCKED -UP. -MOTOR TESTED GOOD. ' -NO EXTERNAL SCALE NOTED. -RECOVERD 200 LASALLE CLAMPS. ' -6 PROTECTOLIZERS. ' -3 FLAT GUARDS. 06:30 - 07:30 1.00 PULL P � DECOMP CLEAN AND CLEAR RIG FLOOR. Printed 7/11/2011 10:33:48AM North America - ALASKA - BP Page & of 9 , Alp eration Summary Report Common Well Name: MPF -81 AFE No Event Type: WORKOVER (WO) Start Date: 6/22/2011 End Date: X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. , UWI: 500292295900 - - - -- - - - -- - - -- --- - - - - -- - - -- -- Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations hr) (ft) 07:30 - 08:00 0.50 RUNCOM 1 P RUNCMP I FINISH REMOVE AND LOAD ESP REELS INTO SPOOLING UNIT. , 1 ! - CONFER WITH RWO ENGINEER ON COMPLETION TALLY. * ** 5 BPH LOSS RATE WITH CONTINUOUS HOLE FILL * ** 08:00 - 11:00 3.00 RUNCOM P RUNCMP PJSM -PU / MU AND SERVICE ESP PUMP AND ; MOTOR ASSEMBLY. -PULL NEW ESP CABLE OVER SHEAVE IN ' DERRICK. 1 -TAKE ESP CABLE CONDUCTIVITY READINGS. 11:00 - 12:00 1.00 RUNCOM P RUNCMP PJSM -M /U PUPS AND ('XN' 2.250 ") -RIH ONE STAND FROM DERRICK AND P/U 1 I JTS 2 7/8" EUE TBG FROM PIPE SHED. -DUMMY GLM. -- . • •UU' •. •► :"• • .. RD TBG, FROM DERRICK (12 STANDS) - 1,100' ' MD. 12:00 12:45 0.75 RUNCOM P RUNCMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. - TRANSFER FUEL. - TRANSFER KWF TO PITS. _ -PJSM 12:45 - 20:30 7.75 RUNCOM RUNCMP I RUN ESP COMPLETION ON 2 7/8" TBG FROM 1l / DERRICK TO (STAND #12 TO - CHANGE OUT BAD COLLAR AND REPLACE JT #76 (BAD PIN) WITH NEW JOINT ( #100 ON , RACK IN SHED) 1 ' -USE BEST -O -LIFE 2000 DOPE -MU TORQUE OPT = 2300FTLB MAX = 2800 ! 1 FTLB I - INSTALL LASSALE ON EVERY OTHER JOINT -CHECH CONDUCTIVITY OF CABLE AND FLUSH PUMP EVERY 2000 FT. 13:00 HRS LOSS RATE @ -4 BPH. - MAKE UP 81 STANDS FROM DERRICK 20:30 - 00:00 3.50 RUNCOM 1 P RUNCMP MAKE REEL TO REEL SPLICE ON JOINT 244 (STAND 81+ 1 SINGLE) STAB FLOOR SAFETY VALVE DURING SPLICE TEST CONDUCTIVITY OF SPLICE HELD MAN DOWN / FIRE DRILL WITH AAR PERFORM DOYON WORK ORDERS WHILE WAITING ON SPLICE — — LOSS RATE AT 23:30 = 4.8 BPH 6/26/2011 00:00 - 00:30 0.50 RUNCOM P RUNCMP CREW CHANGE, PJSM, AND WALK AROUNDS Printed 7/11/2011 10:33:48AM t North America ALASKA BP P 7 of 9 1rati Summary Repg on m rY Common Well Name: MPF -81 AFE No Event Type: WORKOVER (WO) I Start Date: 6/22/2011 End Date: X4- 00T6L -E: (800,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM ' Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. ' UWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date I From - To Hrs h Task I Code 1 NPT NPT Depth Phase I Description of Operations ft 00:30 - 01:30 ' 1.00 RUNCOM li P O RUNCMP ! CONTINUE TO MU AND RUN 2 -7 /88" EUE L -80 ESP COMPLETION FROM JOINT 244 -USE BEST -O -LIFE 2000 PIPE DOPE -MU TORQUE OPT = 2300FTLB MAX = 2800 FTLB 1 -CLAMP EVERY OTHER JOINT WITH LASSALE 'i CLAMPS !- MAINTAIN CONTINUOUS HOLE FILL AT 4 TO 5 BPH OPEN ENDED BACK TO PITS WITH 10.9 PPG BRINE -RAN A TOTAL OF 97 STANDS FROM THE DERRICK OF ORIGINAL TUBING FROM ! DECOMPLETE FOR JOINTS 1 THROUGH _ �_ _ `_ 1 293 (BOTTOM JOINTS) 01:30 - 03:30 'I 2.00 RUNCOM P � RUNCMP � CONTINUE TO MU AND RUN 2 -7/8" EUE L -80 ' I ESP COMPLETION WITH SINGLES FROM PIPE SHED -RAN 31 USED GRADE B SINGLES FOR y/ I JOINTS 293 -323 -USE BEST -O -LIFE 2000 PIPE DOPE ! -MU TORQUE OPT = 2300FTLB MAX = 2800 , !FTLB -CLAMP EVERY OTHER JOINT WITH LASSALE CLAMPS - TESTED ESP CABLE CONDUCTIVITY 2,000 FT FROM SPLICE ' - CIRCULATED 5 BBLS AT 1 BPM AT 1470 PSI , -ESP SPOOL RAN OUT OF CABLE EARLY, • RECORDED LENGTH OF CABLE WAS 1 : DIFFERENT FROM ACTUAL LENGTH, REQUIRING ADDITIONAL SPLICE. I- MAINTAIN CONTINUOUS HOLE FILL AT 4 TO 5 BPH OPEN ENDED BACK TO PITS WITH 10.9 j PPG BRINE 03:30 - 07:00 3.50 RUNCOM N RUNCMP MAKE REEL TO REEL SPLICE FROM SECOND SPOOL TO THIRD ON JOINT 323 IN THE HOLE -STAB IN FLOOR SAFETY VALVE - MAINTAIN CONTINUOUS HOLE FILL AT 4 BPM 07:00 - 10:30 3.50 RUNCOM P RUNCMP CONTINUE RUN ESP COMPLETION ON SINGLE FROM PIPE SHED. -F /JT #323 T /JT #384 -RAN 199 LASALLE CLAMPS -6 PROTECTOLIZERS -3 FLAT GUARDS 10:30 - 11:00 0.50 RUNCOM P RUNCMP ' MU LANDING JT WITH TIW VALVE ! -MU TBG HANGER -CLEAR RIG FLOOR -- - - 11:00 - 12:00 - - - - -- - -- - -- - - -- -- - 1.00 RUNCOM P RUNCMP CENTRILIFT REP TERMINATE ESP CABLE TO HANGER. -MAKE UP PENITRATORS Printed 7/11/2011 10:33:48AM North America ALASKA - BP Page 8 of 9 a ration Summary Report Common Well Name: MPF -81 AFE No Event Type: WORKOVER (WO) Start Date: 6/22/2011 End Date: ;X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations L. (hr) 1 (ft) RUNCMP FMC REP INSTALL TWC AND INSPECT TBG 12:00 14:30 2.50 RUNCOM P HANGER WHILE TRAINING NEW WORKER. -PUW 110,000 LBS -SOW 70,000 LBS -RILDS -L/D LANDING JT AND TIW VALVE. - PERFORM ROLLING TEST FROM BELOW I -AT 1 1/2 BPM / 525 PSI, FOR 10 CHARTED I MINUTES. - TESTED FROM ABOVE AT 250 / 3,500 PSI FOR 10 CHARTED MINUTES. R/D CLEAR ALL SURFACE LINES AND DRAIN BOP STACK. 14:30 18:00 3.50 BOPSUR P WHDTRE PULL ALL RAMS FROM BOP'S - INSTALL 3 -1/2 x 6" VBR'S IN SINGLE GATE RAM BODY -CLEAR RIG. FLOOR OF ALL 2 -7/8" HANDLING ' EQUIPMENT -BREAK DOWN OPSO LOPSO CROSS OVERS 18:00 20:00 2.00 BOPSUR P 1 WHDTRE ND BOP'S AND STAND BACK ON TRANSPORT STAND ', - SECURE RIG FLOOR AND PREP FOR DERRICK DOWN 20:00 - 00:00 4.00 _ WHSUR • P , WHDTRE : CENTERLIFT TESTED PENATRATOR -3648 PSI BOTTOM HOLE PRESSURE AND 156 DEG BOTTOM HOLE TEMP FMC INSTALLED ROTATING ADAPTOR AND 1 ,TESTED - TESTED TO 250 PSI LOW FOR 5 MIN AND 5,000 PSI FOR 30 MIN CHARTED OF DIGITAL RECORDER - INSTALLED TREE AND RE- ORIENTATED 6/27/2011 00:00 t 00:30 0.50 WHSUR P WHDTRE I CREW CHANGE, PJSM, AND WALK AROUNDS fi -- - - - -- - - - ' — - -- 00:30 - 01:30 1.00 WHSUR P WHDTRE RU AND FILL TREE WITH DIESEL TEST TREE FOR 5 CHARTED MIN AT 250 PSI LOW AND 5,000 PSI HIGH WITH DIESEL 01:30 - 03:30 2.00 WHSUR I P WHDTRE RU DSM LUBRICATOR AND TEST TO 250 PSI LOW AND 3,500 PSI HIGH FOR 5 MIN ' PULL TWC WITH WELL STILL ON A VAC RD TWC AND MU BPV TOOLS STAB ON LUBRICATOR AND TEST SET BPV RD DSM LUBRICATOR AND INSTALL TREE CAP WITH PRESSURE GAUGE RU AND TEST BPV FROM BELOW WITH "ROLLING" TEST WITH RIG PUMP DOWN IA CHARTED 10 MIN AT -1.8 BPM @ 600 PSI WITH NO WELL HEAD PRESSURE BD LINES AND RD 03:30 - 06:00 2.50 WHSUR P WHDTRE BACK IN LITTLE RED HOT OIL SERVICES AND ALLOW THEM TO FREEZE PROTECT WELL -PJSM / SLIP AND CUT DRILL LINE -SUCK OUT REMAINING BRINE FROM PITS AND SLOP TANK - L.R.S. PUMPED 15 BBLS DOWN TBG AND 65 BBLS DOWN IA. I - SECURE ALL TREE VALVES * ** RIG RELEASED FOR MOVE TO EOA W -04 AT 06:00 HRS 6/27/2011*** Printed 7/11/2011 10:33:48AM North America - ALASKA - BP Page 9 of 9 E eratian Summary Report Common Well Name: MPF -81 1 AFE No Event Type: WORKOVER (WO) Start Date: 6/22/2011 ' End Date: !X4- 00T6L -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/30/2000 12:00:00AM Rig Release: 6/27/2011 Rig Contractor: DOYON DRILLING INC. 1 UWI: 500292295900 Active Datum: MPF -81 @40.00ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth ' Phase Description of Operations : PRE PREP FOR RIG MOVE 0600 09:30 3.50 I MOB RD SLOP TANK I RD FLOW BACK TANK ' CLEAN AND CLEAR RIG FLOOR OFF LOAD TOOLS FROM PIPE SHED AND _ CELLAR 1 09:30 - 11:00 1.50 MOB PRE PULL OFF MPF -81 WELL WITH TOOLPUSHER AND BP WSL PRESENT. SPOT RIG AT THE FRONT OF PAD. 11:00 20:30 9.50 BOPSUR PRE CONFIGURE BOP STACK FROM 4 TO 3 PREVENTOR. '- SINGLE GATE WITH MUD CROSS. -BLIND SHEARS -LOAD BOP STACK ONTO TRANSPORT SKID TO BE SENT TOW PAD ; -LOWER BELLY BOARD OUT OF DERRICK TO RIG FLOOR 20:30 - 00:00 3.50 MOB PRE INSTALL MOVING SYSTEM CRADLE AND FRONT BOOSTERS FOR RIG MOVE 6/28/2011 00:00 - 06:00 6.00 MOB 1 N ' PRE I PULL BOP'S FROM CELLAR INSTALL REAR BOOSTER WHEELS CLOSED OUT WELL WORK TRANSFER PERMIT WITH PAD OPERATOR - CONTINUE WITH DOYON WORK ORDERS AND GENERAL RIG CLEANING WHILE ON STBY WAITING ON RIG MATS TO BECOME 'AVAILABLE Printed 7/11/2011 10:33:48AM r Tree: CIW 2 9/16" 5M 'FLS' p/1C11 1 ��Q� Wellhead: 11" x 11" 5M FMC Gen 5a �Y� 1� V V Orig. DF Elev. = 27.40' (Doyon 141) 11" x 2 -9/16" NSCT. 2.5" CIW -H BPV 0 Orig. GL Elev. = 11.00' (Doyon 141) profile. 0 „ r r3 I / 4 ! 20” 91.51# ppf, H -40 78' / 1 Camco 2 -7/8" x 1" KBMM GLMI 139' 0 0 TAM port collar 1 1004' %: /,. / 9 5/8 ", 40 ppf, L -80 Btrc. 7515' OF I I Camco 2 -7/8" x 1" KBMM GLM 111,894' 2.875" 6.5 # /ft, L -80 8rd. EUE Or ( drift ID = 2.347 ", cap. = 0.00579 bpf) kilia 7" 29 ppf, L -80, Hydrill.563 casing, / ( drift ID = 6.184 ", cap. = 0.0371 bpf) 0s I I'i.: KOP @ 544' E ) . Max. hole angle = 75°at 8832. t.i. Hole angle thru' perfs = 9 # �, I, t mow iMF .a_a MEE 'II� Pun -sic- t2.-IV" Stimulation Summary eakorn A ion °} 156M# 1 6/20 proppant 6/24/00 t2 17 Perforation Summary . Baker ZXP packer 12231' Ref log: GR / CCL 6/20/00 Baker HMC liner hanger I 12245' Kuparuk "A" Sand Perfs L 7 ", 26# L -80 btc shoe 12422' 1 Size SPF Interval (TVD) *3 3/E 6 12,530- 12,540 6935' - 6946 2.5 6 12,550 -1 2,570 6955' - 7004' 3 3/8 6 12,550 -1 2,570 6955' - 7004' *3 3/E 6 12,581- 12,591 6986' - 6996' Doyon 16 drifted to 12,641' with ESP 6/26/11 * Add perfs done 6/08/05 _ 3S cleanout and tagged TD @ 12,641' 7/19/2007 4.5" float collar (PBTD) 12702' 4.5" 12.6 #, L -80 float shoe 12789' DATE REV. BY COMMENTS 6/18/00 M.Linder Initial Completion Doyon 141 MILNE POINT UNIT b/4.34.11/ Muu Nen h Ol ean o ui 8/12/00 GMH RWO - ESP Completion Nabors 4ES WELL F -81 1/30/01 GMH RWO - ESP Completion Nabors 4ES 3/27/02 M. limier RWO Nabors 4-ES API NO: 50- 029 - 22959 -00 06/09/05 MDO RWO & Add perfs Nabors 4es 7/19/2007 808 RWO- ESP Completion Nabors 1/5/2008 REH Nabors 3S -ESP RWO/ cup Pkr & Excluder Screen 4/03/09 REH ESP RWO - Nabors 3S (Pull Cup Pkr & Screens) BP EXPLORATION (AK) STATE OF ALASKA A OIL AND GAS CONSERVATION COM ION REP T OF SUNDRY WELL OPEIONS 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing • ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. • ®Development ^ Exploratory 200-066 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22959-00-00 7. KB Elevation (ft): 40, • 9. Well Name and Number: MPF-81 8. Property Designation: 10. Field /Pool(s): ADL 388235 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 12790 ' feet true vertical 7193 • feet Plugs (measured) None Effective depth: measured 12701 feet Junk (measured) None true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7487' 9-5/8" 7515' 4153' 5750 3090 Intermediate Production 12396' 7" 12422' 6830' 7240 5410 Liner 558' 4-1/2" 12231' - 12789' 6641' - 7192' 8430 7500 PerForation Depth MD (ft): 12530' - 12591' Perforation Depth TVD (ft): 6936' - 6996' Tubin Size (size rade and measured de th): 2-7/8", 6.5# ~,t / 12124' g , g , p 1~ Packers and SSSV (type and measured depth): ~~ ~~ ~~~~ ze summary: 12. S l s t. 8S X08, ~Dh~t1 ~ nterv al treated measured ( ) ~~ p~ An~h~r~~s. Treatment description including volumes used and final pressure: ~~ \\ SS 3 ~ ~: ~~ ~~~ 13. Re resentative Dail Avera a Production or ln'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 350 57 236 300 268 Subsequent to operation: 354 ~ 63 222 280 246 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Terrie Hubble Title Drilling Technologist ~ ~ Prepared By Name/Number: ~ j Signature ~ Phone 564-4628 Date (~~~ I ~ _Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 AS ~L auto ~ ~ coos ORIGINAL Submit Original Only to s`~~ • • BP EXPLORATION Operations Summary Report Page 1 of 8 'Legal Well Name: MPF-81 Common W ell Name: MPF-81 Spud Date: 5/30/2000 Event Nam e: WORKO VER Start : 3/20/2009 End: 4/3/2009 Contractor Name: NABOR S ALAS KA DRI LLING I Rig Release: 4/3/2009 Rig Name: NABOR S 3S Rig Number: N3S Date From - To Hours II Task Code NPT Phase Description of Operations 3/20/2009 00:00 - 12:30 12.50 RIGD N WAIT PRE R/D Unit and Ready to Move Rig to F-81. Wait on Weather - Temps colder than -40 deg F. Rig Down as much as possible and clean rig while waiting of weather. 12:30 - 14:30 2.00 RIGD P PRE Scope down derrick and lower. Ready Rig to Move. 14:30 - 18:00 3.50 RIGD N WAIT PRE Wait on Trucks to arrive. Currently moving 4ES to P-Pad at Prudhoe. Blow down steam and jack up back feet on Carrier, roll tires. 18:00 - 23:00 5.00 RIGD P PRE Jack and pin pipeshed. Jack and pin pit module. Truck on location at 20:30 hrs. Move pits and pipeshed with sow. Call pad-op to witness Carrier pulling off well slot. PU matts and herculite, sign off permit and post-pad inspection. 23:00 - 00:00 1.00 MOB P PRE Move rig to MPF-81. Spot BOPE behind well. Set matting boards and spot Carrier over well. 3/21/2009 00:00 - 04:00 4.00 RIGU P PRE Weather at -41 degF. Jack and level Carrier. Spot pipeshed and pits, place matting boards and jack down. Put up bearming and install hand rails. Spot LRS up-right tank on herculite. Set kill manifold in cellar. 04:00 - 09:30 5.50 RIGD N WAIT PRE -41 degF. Unable to raise and scope Derrick. 09:30 - 11:30 2.00 RIGU P PRE Raise and Scope Derrick. Spot Flow Back Tank and Rig Up Flow Lines to Tank. 11:30 - 12:00 0.50 RIGU P PRE Safety Meeting with Cleve Coyne and Rig Crews 12:00 - 15:00 3.00 WHSUR P DECOMP Continue to Rig Up and wait on fluids to arrive. Pressure Test Lines to 3500 psi up to Choke and 500 psi from choke to tank. ***Accept Riq at 12:00 hrs on 3-21-09*** 15:00 - 16:00 1.00 WHSUR P DECOMP P/U BPV Lubricator. Pressure Test Lubricator to 500 psi. Pull BPV. 700 psi on tbg. 16:00 - 16:30 0.50 KILL P DECOMP PJSM with rig crew and vac truck drivers. 16:30 - 17:00 0.50 KILL P DECOMP Open IA to flow back tank and bleed gas from 800 to 90 psi on IAin 20 mins. Bring on pumps at 1 bpm and 320 psi and slowly ramp up to 4 bpm and 1800 psi. 17:00 - 18:00 1.00 KILL N SFAL DECOMP Found very small pin hole size leak in discharge line of pump near pulsation dampaner. Shut down pumps and bleed down pressure. Blow Down lines. Welder inspect and repair pin hole leak 18:00 - 19:30 1.50 KILL P DECOMP Transfer fluid from pits to vac truck. Load upright with 360 bbls of 120 degF seawater.. RU Little Red unit to kill manifold. Pressure test LRS lines to 3,500 psi. 19:30 - 23:30 4.00 KILL P DECOMP PJSM. Break circulation with LRS down tubing with 120 degF seawater taking returns from IA thru choke to Tiger tank. Circulate 75 bbls at 3 BPM / 875 psi. Returned 83 bbls of crude back to Ti er tank 10% over circulated volume . Bullhead 30 bbls down tubing at 2 BPM / 1100 psi. Monitor for 10 min, tubing fell to 375 psi. Open well and circulate with LRS down tubing controlling returns thru choke to Tiger tank maintaining 1:1 returns back to tank. Circulate 475 bbls at 4 BPM / 1710 psi. Returned crude back to tank until well cleaned up to seawater returns. Shut down pump and blow down lines. 23:30 - 00:00 0.50 KILL P DECOMP Monitor well for 30 min. Well stable at 260 psi on tubing and 260 psi on IA. Calculate kil fluid with mud engineer and Day WSL. 9.2 ppg EMW and calculated kill fluid to be 9.5 ppg +100 si overbalance). Call for fluids. 3/22/2009 00:00 - 06:30 6.50 KILL N DECOMP Wait on 9.5 ppg kill weight fluid. RU elephant trunk. Pressure Printed: 4/13/2009 2:50:36 PM • • BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/20/2009 End: 4/3/2009 '.Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/3/2009 Rig Name: NABOBS 3S Rig Number: N3S i i Date From - To I Hours I, Task 'Code', NPT Phase Description of Operations 3/22/2009 00:00 - 06:30 6.50 KILL N DECOMP test repaired mud pump line to 3,500 psi -passed. Evacuate remaining fluid from Tiger tank. 06:30 - 07:30 1.00 KILL N FLUD DECOMP Trucks arriving on location. Load First Truck into pits. Check Wt at just under 9.4 ppg. Talk with mud engineer and confirm 9.5 ppg was what was ordered. Check other two trucks, both had good brine weight. 07:30 - 08:30 1.00 KILL P DECOMP Weight up fluid in pits to 9.5 ppg with NaCL. Stage other trucks and Have PJSM with rig crew and truck drivers. 08:30 - 09:00 0.50 KILL P DECOMP Blow down lines to tiger tank to make sure they are clear. Open Tbg and IA, each at 230 psi. OA at zero. 09:00 - 11:00 2.00 KILL P DECOMP Kill well by circulating 75 bbls of 9.5 ppg brine down tubing taking returns up IA through choke at 4 bpm and 1350 psi. Bullhead 30 bbls at 3 bpm and 1400 psi. Circulate another 400 bbls of 9.5 ppg brine. Had 9.5 ppg brine at surface after circulating 504 bbls. Shut-in well. Lost 15 bbls during circulation. 11:00 - 12:00 1.00 KILL P DECOMP Monitor Tbg and IA Pressures. Started with 50 psi on each. Both Tbg and IA bled down to zero psi in 25 mins, noticed both tbg and IA on slight vac after 35 mins. Well Dead. Blow down lines and hoses. 12:00 - 12:30 0.50 WHSUR P DECOMP Confirm no pressure on tree and FMC Rep set TWC. 12:30 - 13:30 1.00 WHSUR P DECOMP Pressure Test TWC from above to 3500 psi, 10 min flat line on 13:30 - 14:30 1.00 WHSUR P DECOMP Pressure Test TWC from below b um in down IA at 3 Test Failed. Found small amount of fluid coming up tree. 14:30 - 16:00 6:00 - 17:00 1.50 .00 WHSUR HSUR P P DECOMP ECOMP Pumped 35 bbls into IA while testing TWC from. below. Bleed down IA and lines. P/U Lubricator and Pressure Test to 500psi. Pull TWC. Could not find anything really wrong with it, outer seal looked good and poppet looked good. M/U different TWC. RIH and Set second TWC. Pressure Test TWC from above and below as before on chart. Both good tests. Pumped 38 bbls into well while test TWC from below at 3 bpm. 17:00 - 18:00 1.00 WHSUR P DECOMP Blow Down Lines and R/D. Prep to N/D Tree 18:00 - 19:30 1.50 WHSUR P DECOMP PJSM on N/D Tree. Bleed Voids. N/D Tree and Adapter Flange. No down hole barrier. MPU single barrier dispenstation in place. 19:30 - 00:00 4.50 BOPSU P DECOMP PJSM on N/U BOP's. N/U 13-5/8" BOPE Stack. 3/23/2009 00:00 - 02:30 2.50 BOPSU P DECOMP Continue to NU BOPE. Replace bad air boots in bell nipple. 02:30 - 05:00 2.50 BOPSU P DECOMP Function test BOPE. Attempt to get body test on BOPE, unable fo get flat line test. Track down leak points. 05:00 - 09:30 4.50 BOPSU P DECOMP Test BOPE 250 psi low and 3,500 psi high for 5 min each - charted. Test with 2-7/8" test joint and complete Koomey draw down test. Test witnessed by BP WSL and NAD Toolpusher. AOGCC rep Bob Noble waived the state's right to witness at 18:30 hrs on 3-22-09. 09:30 - 11:30 2.00 BOPSU N SFAL DECOMP BOP Test on Hydril failing. Unable to get good test, make multiple attempts. Found Hydril leaking up center around test joint. Hydril element will need to be changed out. 11:30 - 12:00 0.50 BOPSU P DECOMP Safety meeting with rig crew on volcano situation, flights and other related items. Discuss plan forward on changing out hydril element and PJSM Printed: 4/13/2009 2:50:36 PM • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Event Name: WORKOVER Start: 3/20/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/3/2009 Rig Name: NABORS 3S Rig Number: N3S .Date From - To Hours Task Code NPT __ 3/23/2009 12:00 - 13:00 1.00 BOPSU N SFAL 13:00 - 16:00 I 3.001 BOPSUR N I SFAL 16:00 - 22:00 I 6.001 BOPSUFi N I SFAL 22:00 - 00:00 I 2.001 BOPSUR N I SFAL 3/24/2009 00:00 - 04:00 4.00 BOPSU N SFAL 04:00 - 06:30 2.50 BOPSU P 06:30 - 09:00 ~ 2.50 ~ W HSUR ~ P 09:00 - 11:00 I 2.001 PULL I P 11:00 - 12:00 1.00 PULL P 12:00 - 12:30 0.50 PULL P 12:30 - 14:00 I 1.501 PULL I P 14:00 - 15:00 I 1.001 PULL I P 15:00 - 00:00 I 9.001 PULL I P 3/25/2009 100:00 - 06:00 I 6.001 PULL I P Page 3 of 8 Spud Date: 5/30/2000 End: 4/3/2009 Phase ' Description of Operations DECOMP Blow down lines and rig down test equipment. Drain stack down below hydril and close blind rams. DECOMP Pull bell nipple and nipple down Dutch System riser. Drain residual fluid from Hydril and pull studs from potato masher. Pull lock pin. Place new hydril element in cellar to warm up. DECOMP Remove bonnet and pull Hydril from annuluar body. Clean out rubber pieces and debris. Suck out old hydraulic fluid and clean bowl. Instal new seal rings on bonnet. DECOMP Set new Hydril in bowl and fill with oil. Set bonnet on Hydril. MU potato masher and screw in bonnet. LD potato masher and heavy weight. DECOMP Install hydraulic lines. Function test bag. MU Dutch system flange and bell nipple. Install flow riser and air up boots. Clean and clear rig floor and cellar. IA has positive pressure, will not register on gauge. Bleeds off in 15 seconds to static. DECOMP PJSM. Set 2-7/8" test joint in BOP stack. Test annuluar preventer 250 psi low and 3,500 psi high for 5 min each - charted. Test Kill and Choke HCR to 250 psi low and 3,500 psi high. Complete Koomey draw down test. Test witnessed by BP WSL and NAD Toolpusher. AOGCC rep Bob Noble waived the state's right to witness on 3-22-09 at 18:30 hrs. DECOMP P/U Lubricator Extension and Pump in sub. M/U Lubricator with extensions to pull TWC. Pressure Test Assembly to 500 si. Pull TWC. Tbg was on vacuum below TWC. UD Lubricator, Pump In Sub and Extension. DECOMP M.U 2-7/8" Landin Joint to Tb Han er with TIW Valve. Rig Up to Circulate. Tbg on Vac and IA has 10 psi. Pumping at 1 bpm took 13 bbls to fill pipe withj 9.5 ppg brine. Circulate thru choke at 4 bpm and 1450 psi. Only a small amount of crude seen at start of circulation. Lost 16 bbls on circulation. DECOMP Rig Down lines and blow down. Bleed down annulus. DECOMP Back Out Lock Down Screws. Double Check Annulus, on slight vac. Pull Hanger Free from well head. Pulled up to 90,000 Ibs then started moving up hole at 80,000 lbs. DECOMP Circ Bottoms Up at 4 bpm and 1450 psi. Did not see any crude or gas with circulation. Lost 17 bbls on circulation. DECOMP Pull Hanger to Rig Floor. Break Out Landing Joint and Tbg Hanger ,lay down both. Pull cable from bottom of hanger. Check Cable and cable seemed to be good. Cut off cable head and prep to run over sheave. Swabbing fluids as pulling out of hole with hanger. DECOMP POOH with 2-7/8" Tb and ESP Cable. UD 10 ft pup joint under hanger and first full joint. Stand back remaining Tbg in derrick. Weil swabbing some as pulling out o o e. ui level will drop when not pulling pipe. Amount of fluid swabbing varies with speed of pulling tbg. Consult with town decide to POOH with 5 stands slowly and then bullhead 20 bbls. Bullhead 20 bbls 9.5 ppg seawater down Tbg at 1 bpm / -300 psi, bleed to 0 psi with -7 bbls returns. 30 stands out at 00:00 hrs. DECOMP Continue to POH with 2-7/8" ESP completion and stand in Derrick from stand # 30 to stand #60. After pulling 5 stands, bullhead 20 bbls 9.5 ppg seawater down Tbg at 1 bpm /-300 Printed: 4/13/2009 2:50:36 PM • BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/20/2009 End: 4/3/2009 Contractor Name:. NABOBS ALASKA DRILLING I Rig Release: 4/3/2009 Rig Name: NABOBS 3S Rig Number: N3S ~ ~ Date. .From - To Hours Task Code NPT Phase Description of Operations 3/25/2009 00:00 - 06:00 6.00 PULL P DECOMP 1 psi, bleed to 0 psi with - 8 bbls returns. 06:00 - 12:00 6.00 PULL P DECOMP Continue to POH with 2-7/8" Tbg and ESP Completion. Drop 12:00 - 18:00 I 6.001 PULL I P 18:00 - 00:00 I 6.001 PULL I P 3/26/2009 100:00 - 05:00 I 5.001 PULL I P 05:00 - 09:00 4.00 PULL P 09:00 - 09:30 0.50 PULL P 09:30 - 10:00 0.50 PULL P 10:00 - 15:00 5.00 PULL P 15:00 - 17:00 2.00 PULL P 17:00 - 18:00 1.00 BUNCO P 18:00 - 20:00 2.00 BUNCO P 20:00 - 00:00 4.00 BUNCO P 3/27/2009 00:00 - 02:00 2.00 BUNCO P 02:00 - 03:30 1.50 BUNCO 03:30 - 07:30 4.00 BUNCO 07:30 - 08:30 1.00 BUNCO 08:30 - 10:00 10:00 - 11:00 1.501 BUNCO 1.001 BUNCO down bullhead volume to 12 bbls after 5 stands. Still seeing more return volumes and taking longer. Acting as if formation is charged up. Net volume lost to formation after pulling 75 stands was -115 bbls. Wellbore seems to be breathin CBU to confirm no influx of reservior fluids. Pull another 10 stands and Bullhead 30 bbls at 2 bpm and 560 psi. Consult town on progress. DECOMP Bleed back 13 bbls of fluid after bullheading. POH with 10 stands as per towns recomendations and then bullhead 10 bbfs. Flowing back 7-8 bbls after bullhead. Coninue io POH with Tbg to Stand 105 by bullheading 10 bbls after pulling 10 stands. DECOMP Continue to POH from stand #105 to #165, bullheading 10 bbls after pulling 10 stands, with 5 1/2-7 bbls flow back. DECOMP Continue to POH slow from stand #165 to #1, bullheading 10 bbls after pulling 10 stands, with 5 1/2-7 bbls flow back. UD GML and XN nipple. DECOMP Observe Well. DECOMP Consult with town on operations. DECOMP PJSM with rig crew on pulling and laying down ESP pump and Cup Packer bottom hole assembly. DECOMP POH with ESP Completion and Cup Packer Bottom Hole Assembly. No trapped gas seen under cup packer. Screens not plugged up but cup packers torn up slightly. DECOMP UD Elephant truck and Change Out Spools. R/U to run new ESP Completion.. RUNCMP P/U Pressure Gauge and Motor Assembly. Fill with oil and connect esp cable. RUNCMP P/U Tandem Seal Assembl and M/U to motor section. PU / MU Gas separator, ESP pumps, Discharge head and (2) 2-7/8" Tbg 10' pups. Attach ESP cable and perform conductivity test. RUNCMP Crew change, perform pre-tour checks. MU 2.250" XN nipple with XXN plug installed by MPU PE's. RIH with ESP completion assembl on 2-7/8", 6.5# L-80, EUE 8rd tubin from Derrick to stand #30 at 00:00 hrs. RUNCMP Continue to RIH with ESP completion assembly on 2-7/8", 6.5# L-80, EUE 8rd tubing from Derrick. Stand #30 to #70 . ESP DFAL RUNCMP ~ Circulate surface to surface at 4,500', 3 bpm / 380 psi with 9.5 ppg brine. DFAL RUNCMP POH from -4,500' with ESP and stand 2-7/8" tbg in Derrick. Cable conductivit test at 2,650' also failed. DFAL RUNCMP Run Diagnostics on cable, motor lead and motor. Determine that the motor is good as well as the cable. DFAL RUNCMP Spool cable back onto reel and cut off motor lead. Measure out new motor lead and splice to cable and test. DPRB RUNCMP Seeing Crude in bell nipple. Shut well in. Contact town and consult. Seeing -30 psi initially when shut in. Notify State of shutting in well. Decide to bullhead kill well with 9.8 ppg brine- Printed: 4/13/2009 2:50:36 PM • Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To BP EXPLORATION Operations Summary Report Page 5 of 8 MPF-81 MPF-81 W ORKOVER Start: 3/20/2009 NABOBS ALASKA DRILLING I Rig Release: 4/3/2009 NABOBS 3S Rig Number: N3S Hours L Task 3/27/2009 10:00 - 11:00 11:00 - 16:00 16:00 - 19:00 19:00 - 00:00 3/28/2009 100:00 - 06:00 06:00 - 11:00 11:00 - 13:00 13:00 - 16:00 16:00 - 17:00 17:00 - 20:00 20:00 - 21:30 21:30 - 00:00 3/29/2009 00:00 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 12:00 12:00 - 17:00 17:00 - 18:00 18:00 - 23:00 1.00 RUNCC 5.00 RUNCC 3.00 RUNCC 5.00 RUNCC 6.00 RUNCC 5.00 RUNCC 2.00 RUNCC 3.00 RUNCC 1.00 RUNCC 3.00 RUNCC 1.50 RUNCC 2.50 RUNCC 3.50 RUNCC 1.50 RUNCC 1.00 RUNCC 6.00 RUNCC 5.00 BOPSU 1.00 BOPSU 5.001 BOPSU Spud Date: 5/30/2000 End: 4/3/2009 ', Code NPT ', Phase. Description of Operations DPRB RUNCMP advised to stay under 2000 psi while pumping into formation. RUNCMP Order out 9.8 ppg brine from mud plant. Mix up 9.8 ppg brine in pits. RUNCMP Fluid on location and have PJSM. Bullhead 580 bbls of 9.8 rin at 4 bpm and up to 1800 psi using LRS pump truck and rig pump. RUNCMP Initial pressure after shutting down was 1500 psi and pressure fell off to 100 psi in 5 minutes. Bleed off fluid and watch pressure fall. Bleed off 10 bbls and then hold for 15 mins or more and watch build up, repeat process. 81eed a total of 119-bbls during this time period. RUNCMP Continue to monitor and bleed pressure. Shut well in for 15-minutes and monitor pressure. Then open well and bleed back 10-bbls. Shut in pressure and flow rate continue to diminish with each cycle. Shut in surface casing pressure = 20-psi. Total bleed-back volume from bullhead kill thru 0600-hrs = 185-bbls. RUNCMP Confer with ADW suppentend and RWO Engineer on plan forward. Monitor well at 8-10 bph. RUNCMP MU lines from IA valves to choke. Test plug failed to seat, wait on new test plug. Made weekly crew change at 13:00 hrs due to late flights (Volcano). RUNCMP Blind /Shear rams failed to test. Confer with town. RUNCMP Confer with town ADW RWO Engineer on plan forward. Order RBP and Storm valve from Halliburton. RUNCMP BO/LD ESP pump and motor assembly. RUNCMP MU 7" HES RBP on 2-7/8" pipe. RUNCMP RIH with RBP from surface to -4000' RUNCMP RIH with 7" RBP from -4000' to -11000'. Do not have specific tubing tally, estimating depth by using an average double of 63'. RIH 175 stands. RUNCMP Set 7" RBP, lay down single joint, RU cement head to be able to pump dowri the tubing. Attempted test to 1000 psi for 10 charted minutes. Pumped 7.2 bbls of 9.8 brine into well and had no indication that the plug was set. Will reattempt to set RBP and pressure test. RUNCMP RD cement head, PU single joint of tubing, and attempt to reset RBP. Confirm RBP set at -11 000" but will not test. RUNCMP POH 15 stands and set 7" RBP at 10,070' and test to 1,000 psi for 10 charted minutes.. (PUW = 40 K, SOW = 26K) POH 3 stands, PU/MU 7" Storm Packer with Halliburton rep, set at 69' and test to 1,500 psi for 10 charted minutes. B/O running tool and stand back lstand in Derrick. N RUNCMP Set test plug, remove Blind Shear rams, inspect and redress. N RUNCMP Install redressed blind shear rams. Closed doors and tighten bolts. One bolt would not engage, pulled bolt and determined i that bolt threads had been galled and also damaged the t threads on the BOPE. Bolt unuseable and needed to be replaced. No bolts on hand. Will wait for one to arrive from NOC. N RUNCMP Called NOC and wait for new stud bolt for the BOP doors to arrive. Will stop by 4es as well and pick up tap to redress all threads. Printed: 4/13/2009 2:50:36 PM • BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/20/2009 End: 4/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/3/2009 Rig Name: NABOBS 3S Rig Number: N3S Date. From - To I Hours ~ Task ~ Code NPT 3/29/2009 23:00 - 00:00 1.00 BOPSU N 3/30/2009 00:00 - 03:00 3.00 BOPSU N 03:00 - 04:00 I 1.001 BOPSUA N 04:00 - 06:00 2.00 BOPSU~ N 06:00 - 12:00 6.00 BOPSU N 12:00 - 18:00 6.00 BOPSU N 18:00 - 21:30 3.50 BOPSU N 21:30 - 22:00 0.50 BOPSU N 22:00 - 23:00 1.00 BOPSU N 23:00 - 00:00 1.00 BOPSU N 3/31/2009 00:00 - 01:00 1.00 BOPSUF~N 01:00 - 06:30 5.50 BOPSU N 06:30 - 20:00 I 13.50 I BOPSUF~ N 20:00 - 20:30 I 0.501 BOPSUR N 20:30 - 23:00 I 2.501 BOPSUR N 23:00 - 00:00 1.00 BOPSU N 4/1/2009 00:00 - 02:30 2.50 BOPSU N 02:30 - 06:00 I 3.501 BOPSUp N 06:00 - 13:30 ~ 7.50 ~ BOPSUF# N 13:30 - 00:00 10.501 BOPSUF{ N Phase Description of Operations RUNCMP New bolt, and tap have arrived. Fix threads on BOP doors and install new stud bolt. Test BOP leakin ast Blind/Shears Rams RUNCMP Nipple Down Blind rams door and removed blind shears. Installed redressed Blinds. Nipple Up BOP's RUNCMP Fill stack and Pressure test Blind Rams to 3500 psi. Test OK. Fill choke manifold Pressure test 300 psi low and 3500 psi high. Test OK. Call AOGCC and notified Jeff Jones ready for weekly BOP Test. Jeff Jones will come and witness BOP test. RUNCMP Service rig while awaiting Jeff Jones to arrive for BOP Test. RUNCMP Pressure Test 13-5/8" BOPE with, 2-7/8" X 5" VBR, 2-7/8" test Point against test plug. Test to 250 / 3,500 psi and chart each test for 5 minutes. Witnessed by AOGCC state inspecter, Jeff Jones. HCR Kill line valve failed. RUNCMP Change out 2-1/16" HCR Kill line valve on BOP stack and test RUNCMP Redress mud manifold kill valve. RUNCMP Pull and Lay down test plug RUNCMP Pull and Lay down RTTS RUNCMP Pull and release RBP. ig up LRS and bullhead 86 bbls 9.8 brine @ 2 bpm with 525 psi. Final pressure ~ 2 bpm :1125 psi. Slow pumps down to 1 bpm @ 950 psi, final pressure of 800 psi RUNCMP Bleed off pressure and rig down LRS RUNCMP Circulate Surface to surface with 9.8 ppg brine. 353 total bbls pumped: 3 bpm. Return mud weight cut to 8.7 ppg during bottoms up. STS complete return weight cut to 9.6 ppg. Confer with ADW RWO Engineer to increase fluid weight to 10.2 ppg KCL. RUNCMP Wait on 10.2 KCL from MI mud lant. BP Workover Ops Superintendent performs walk through of rig and provided feedback to the day crew. Hold weekly safety meetings with both crews while waiting on fluid. RUNCMP Bleed IA from 100 psi to 0, pump 10 bbls 10.2 ppg KCL down tubing. RUNCMP RIH from -10,070' with 7" RBP to -11,924' and PU 6 singles from pipe shed to -12,100' PUW=57K, SOW=30K RUNCMP Wait on 10.2 ppg KCL from MI mud plant. RUNCMP Wait on 10.2 ppg KCL from MI mud plant. Truck held up due to wide impassable load on road. RUNCMP Bleed IA from 90 psi to 0, pump 3 bpm / 740 - 800 psi down the tubing and displace with 10 2 ppq KCL Pumped total of 486 bbls. Tubin and IA on a vacuum. RUNCMP Wait on another load of 10.1 ppg brine to be mixed up and delivered to location prior to tripping out of the hole. Only have 100 bbls of 10.1 ppg brine on surface. Discuss plan forward with Anchorage Engineering -will feed the well with 10 bbls of 10.1 ppg brine per hour while waiting on the next load and work on weighting up 85 bbls of 9.3 ppg brine to 10.1 ppg. Shoot fluid levels down the IA and Tubing at 0800 hrs and were inconclusive. Shoot fluid levels again at 1200 hrs and still inconclusive. Continue feeding the well with 10 bbls per hour. RUNCMP Load of 290 bbls of 10.1 ppg brine arrives on location. Top off Pits and start filling the upright with brine. Round trip the truck Printed: 4/13/2009 2:50:36 PM • BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/20/2009 End: 4/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/3/2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours ' Task Code NPT 4/1/2009 13:30 - 00:00 10.50 BOPSU N 4/2/2009 00:00 - 00:30 0.50 BUNCO 00:30 - 03:30 3.00 BUNCO 03:30 - 08:00 4.50 08:00 - 15:30 7.50 15:30 - 20:30 5.00 20:30 - 00:00 3.50 4/3/2009 00:00 - 03:00 3.00 03:00 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 08:00 08:00 - 12:00 12:00 - 15:00 0.50 1.50 BUNCO P 1.00 BUNCO 2.00 WHSUR P Phase Description of Operations RUNCMP for another load of 10.1 ppg brine. Lay down 6 additional joints picked up. Pull out of hole slow with 7" RBP on 2-7/8" tubina standing back in the Derrick. Regulate hole fill at 20 bbls per hour with 10.1 ppg brine. Stopped at -500' to flow check Well, held Kick Drill and the RBP set. (Halliburton rep) Unset RBP and continue to POH very slow due to swabbing, BO/LD RBP / running tool. Total losses on TOH = 123 bbls. Hole is full, loss, rate is - 5 bph. RUNCMP Clear and clean Rig floor. RUNCMP PU/MU ESP assembl ,ESP cable motor-lead failed to test. Fluid loss rate is 6 bph. RUNCMP LD Failed ESP motor and PU/MU new motor (same model and length). Dress GLM with Dummy and remove XXN plug from XN nipple. Plug in MLE and perform conductivity check prior to servicing the rest of the assembly -good test. Finish servicing the ESP assembly with Centrilift reps. RUNCMP ~ RIH with new ESP Assembly on 2-7/8", 6.5#, L-80, Tubino from the Derrick. Maintain continuous hole Hari with average losses of -1U nets per Hour. using Best-O-Life pipe dope on all connections and make up torque of 2,300 ft-Ibs. Stop every 2,000' to check the conductivity of the ESP and fill the Tubing with 10.1 ppg brine. Flush the pump with 10 bbls at a rate of 0.75 bpm / 1,100 psi. RUNCMP Stop with 117 stands in the hole and perform reel to reel splice with Centrilift rep. Maintain continuous hole fill with 10.1 ppg brine while splicing. RUNCMP Continue to RIH with ESP assembly from stand #117 to stand #160. Flush the pump with 10 bbls at a rate of 0.75 bpm / 1,200 psi. RUNCMP Continue to Run ESP completion from stand # 160 to stand #192. Flush the pump with 10 bbls at a rate of 0.75 bpm / 1,250 psi. Ran total of 385 joints, 2.250" XN nipple, GLM with Dummy, GLM with DSOV. 200 LaSalle Clamps, 6 Protectolizers, 3 Flat Guards. RUNCMP MU TIW valve on landing joint, MU tubing hanger and penetrator with FMC wellhead tech. PUW =68,000 Ibs, SOW = 43,000 Ibs. RUNCMP Centrilift rep perform penetrator splice and conductivity test. RUNCMP Land tubing hanger, R1LDS with FMC wellhead tech. RUNCMP PU T-bar nd set 2-1 2" T e " " TW it F r R t st equipment and Little Red to the IA for pressure testing. Fill the Stack and pressure test the TWC from above to 3.500 osi for 10 charted mins - OK. Bleed off. Pressure test the TWC from Bleed off. RD test equipment and Little Red. 4.00 BOPSU P RUNCMP ND 13-5/8" 5M BOPE and DSA. Lay BOPE in the Cradle and remove from Cellar. 3.00 WHSUR P RUNCMP NU 2-9/16" Tree and Adapter Flange with FMC rep. Pressure test hanger void to 5,000 psi for 30 mins with FMC rep at 1330 hrs. Perform final ESP conductivity checks with Centrilift rep. Pressure at intake = 3370 psi ,Temperature at motor = 156.1 degF ,Temperature at intake = 155.5 degF ,phase to phase = Printed: 4/13/2009 2:50:36 PM BP EXPLORATION Page 8 of 8 Operations Summary Report ~, Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/20/2009 End: 4/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/3/2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours I Task 'Code NPT Phase Description of Operations 4/3/2009 12:00 - 15:00 3.00 WHSUR P RUNCMP 4.6 Ohms ,phase to ground = 700 Mega-Ohms. Fill the Tree with diesel and pressure test to 5,000 psi for 5 charted mins - OK. 15:00 - 16:00 1.00 WHSUR P RUNCMP PU Lubricator and make up to Tree with Well Support Techs. Pressure test to 500 psi with diesel. Pull TWC. Set 2-1/2" T e "H" BPV. Secure the Tree and ear. emove secon annulus valve. The Rig was released at 1600 hrs on 4/3/2009. Printed: 4/13/2009 2:50:36 PM Tree: CIW 2-9/16" 5M 'F Wellhead: 11" x 11" 5M FMC Gen 5a 11" x 2-9/16" NSCT. 2.5" CIW-H BPV profile. 20" 91.51 #ppf, H-40 78' MPU F-81 Orig. Dl~Elev. = 27.40' (Doyon 141) Orig. GL Elev. =11.00' (Doyon 141) Camco 2-7/8" x1" KBMM Gas lift mandrel 136' TAM port collar 9 5/8", 40 ppf, L-80 Btrc 7515' Camco 2-718" x1" KBMM Gas lift mandrel 2.875' 6.5#/ft, L-80 8rd. EUE ( drift ID = 2.347", cap. = 0.00579 bpf ) 7" 29 ppf, L-80, Hydrill.5t33 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) Stimulation Summary 156M# 16/20 proppant 6/24/00 KOP @ 544' Max. hole angle = 75 deg. at 8832. Hole angle thru' perfs = 9 deg. Perforation Summary Ref loa: GR / CCL 6/20/00 Kuparuk "A" Sand Perfs Size SPF Interval (ND) "3 3/ 6 12,530-12,540 6935' - 6946 2.5 6 12,550-12,570 6955' - 7004' 3 3/ 6 12,550-12,570 6955' - 7004' "3 3/ 6 12,581-12,591 6986' - 6996' * Add perfs done 6/08/05 4.5' float collar (PBTD) 12702' 4.5' 12.6#, L-80 float shoe 12789' DATE REV. BY COMMENTS 6/18/00 M.Linder Initial Com letion Do on 141 8/12/00 GMH e - rac - can ou RWO -ESP Completion Nabors 4ES 1/30101 3/27/02 GMH M. tinder M RWO -ESP Completion Nabors 4ES RWO Nabors a-ES A P rf N r 4 s 7/19/2007 1/5/2008 BDB REH RWO- ESP Completion Nabors 3S Nabors 3S -ESP RWO/ Cup Pkr & Excluder Screen 4/03/09 REH ESP RWO -Nabors 3S (Pull Cup Pkr & S 1004' I 11,898` I 12,036` I Centrilift Tandem ESP 12 058` 18-P75 PMSXD , 137-P17 SXD Intake -Gas Separator 12,084` Model - GSTHVEVX Tandem Seal Section, 12 090` MOdel - GS63DBUT/LT SB/SB , PFSA/FSA CL5 Motor, 190 HP KMH 12,104` 2415 valt/48 amp(rerated KME -1/190hp/2240hz/43A Pumpmate XTO 12,120' Centralizer 12121' Baker ZXP packer Baker HMC liner hanger 7". 26# L-80 btc shoe 12231' 12245' 12422' 3S cleanout and tagged td @ 12,641' 7/19/2007 MILNE POINT UNIT WELL F-81 API NO: 50-029-22959-00 BP EXPLORATION XN ~ 2 7I8" HES XN-Nipple (2.25" id) MPF-81 • • Page 1 of 2 Regg, James B (DOA). _ ~~ _, d ~ From: Jones, Jeffery B (DOA) Sent: Tuesday, March 31, 2009 9:07 AM To: DOA AOGCC Prudhoe Bay '~ ~'4~'"~"~~~ .~~~ ~' ~` ~~~ Subject: FW: MPF-81 FYI From: Rhodes, David (ASRC ENERGY SERVICES) [mailto:rhodd0@BP.com] Sent: Monday, March 30, 2009 1:21 AM To: Jones, Jeffery B (DOA) Subject: RE: MPF-81 Jeff, It's 02:00 AM Monday, Nabors Rig 3-S, MPF-81. The repair of BOP ram failure continues. !will up-date you later today on our progress. A 7" RBP set & tested at 10,070' and RTTS set & tested at 69'. Thanks Dave Rhodes From: Jones,-Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Sunday, March 29, 2009 1:28 PM To: Rhodes, David (ASRC ENERGY SERVICES) Cc: Admin AOGCC Prudhoe Bay Subject: RE: MPF-81 Thanks David Jeff Jones AOGCC From: Rhodes, David (ASRC ENERGY SERVICES) [mailto:rhodd0@BP.com] Sent: Saturday, March 28, 2009 6:56 AM To: Jones, Jeffery B (DOA) Subject: RE: MPF-81 Jeff, Nabors Rig 3-S on Well (MPF-81) was Bullheading 9.5 ppg Brine as POH with failed ESP and cup packer with screens completion assembly. Anew ESP completion assembly was made up and RIH. ESP cable failed its test at 4,500' while RIH. POH with Motor at surface troubleshoot repairs. Well shut in with Annular preventer around motor section of ESP. Confer with ADW town office to perform Bullhead kill with 9.8 ppg Brine. Thanks' Dave Rhodes From: Jones, Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Friday, March 27, 2009 9:12 PM To: Rhodes, David (ASRC ENERGY SERVICES) MPF-81 C ~~ -Ohr;~ Subject: RE: MPF-81 Page 2 of 2 David, 1 need you to include some more information on your a-mail; the well name, rig name & number, operations prior to taking kick, primary well control fluid parameters and yes, you are required to test every component that was used to kill the welt, including the annular, HCR's if used and choke manifold valves. Thanks, Jeff Jones AOGCC From: Rhodes, David (ASRC ENERGY SERVICES) [mailto:rhodd0@BP.com] Sent: Friday, March 27, 2009 12:34 PM To: Jones, Jeffery B (DOA) Subject: MPF-81 Jeff Jones, As per your verbal request for an a-mail note on shutting in MPU F-81. _ Observed well flowing with ESP assembly at the surface, Well shut-in with Annular. Plan to increase fluid weight ~ from 9.5 ppg to 9.8ppg Brine. And perform Bullhead kill. Please advise if we are required to re-test Annular preventer be for continuing running this completion. • STATE OF ALASKA. '~v~ai07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: iim.re g(a)_alaska.gov doa.aoacc.prudhoe.bav(a~alaska.gov bob.fleckensteinCa~alaska.gov Contractor: Nabors Rig No.: 3S DATE: 3/23/2009 Rig Rep.: J.Greco / R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: M.Aivano / V.Volpe Field/Unit & Well No.: MPF-81 PTD # 2000660 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA" MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size FLOOR SAFETY VALVES: Test Result Quantity Test Re P Upper Kelly 0 NA P Lower Kelly 0 NA P Ball Type 1 FP Inside BOP 1 P Test Result Annular Preventer 1 13 5/8 5000 FP Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind/Shear P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8-2 1/16" P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA CHOKE MANIFOLD: Quantity Test R No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1700 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 30 sec P Trip Tank P P Full Pressure Attained 2 min 37 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 2150 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 2 Test Time: 27 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: iim.regg ar7alaska.gov (Remarks: good Hydril Annular failed replaced with new and tested good. Test began 3/23/09 Cc~0230 hrs ended 24 HOUR NOTICE GIVEN YES x NO Waived By Bob Nobel Date 03/21/09 Time 1240 hrs Witness M.Aivano/J.Greco Test start 0230 hrs Finish 0530 hrs BOP Test. (for rigs) BFL 11/14/07 Nabors 3s BOP Test MPF-81 3-23-2009 .xls ` ~,~ STATE OF ALASKA !- ~~~ 1 a~ ,~~/~I; v ! A~ OIL AND GAS CONSERVATION CO SION JAN ~ 12009 ..,~.~ REPORT OF SUNDRY WELL OPE~TIONS ~~ Alaska Oil & Gas Cons. Commission 1. Operations Performed: AnChOPagB ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-066' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22959-00-00' 7. KB Elevation (ft): 40, 9. Well Name and Number: MPF-81 8. Property Designation: 10. Field !Pool(s): ADL 388235 , Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 12790 - feet true vertical 7193 feet Plugs (measured) None Effective depth: measured 12680 feet Junk (measured) None true vertical 7084 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7487' 9-5/8" 7515' 4153' 5750 3090 Intermediate Production 12396' 7" 12422' 6830' 7240 5410 Liner 558' 4-1/2" 12231' - 12789' 6641' - 7192' 8430. 7500 Perforation Depth MD (ft): 12530' - 12591' Perforation Depth TVD (ft): 6936' - 6996' 2-7/8", 6.5# L-80 12175' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker 7", 26#, Cup Packer Assembly, 12129' Baker ZXP Packer 12231' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 137 55 80 300 238 Subsequent to operation: 258 59 262 250 274 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®`Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/q Printed Name Sondra Stewman Title Drilling Technologist (~~ Prepared By NameMumber: _z ~-() Sin ure Phone 564-4750 Date Sondra Stewman 564-4750 Form 10-404 Revised 0412006 ~/ Submit Original Only ,, ~/,1 ~$I'~ ,µ~~ ~ ~~ t00~ ~rfa_ Tree: CIW 2-9/16" 5M M P U F-8 Wellhead: 1 1 " x 11 " 5M FMC Gen 5 Orig. lev. = 27.40' (Doyon 141) 11" x 2-9/16" NSCT. 2.5" CIW-H BPV I ~ Orig. GL Elev. =11.00' (Doyon 141) profile. 20" 91.51 #ppf, H-40 78' Camco 2-7/8" x1° 135' KBMM Gas lift mandrel TAM port collar 1004' 9 5/8", 40 ppf, L-80 Btrc 7515' 2.875' 6.5#/ft, L-80 8rd. EUE ( drift ID = 2.347", cap. = 0.00579 bpf ) 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) KOP @ 544' Max. hole angle = 75 deg. at 8832. Hole angle thru' perfs = 9 deg. Stimulation Summary 156M# 16/20 proppant 6/24/00 Perforation Summary Ref log: GR / CCL 6/20/00 Kuparuk "A" Sand Peres Size SPF Interval (ND) "3 3/ 6 12,530-12,540 6935' - 6946 2.5 6 12,550-12,570 6955' - 7004' 3 3/ 6 12,550-12,570 6955' - 7004' "3 3/ 6 12,581-12,591 6986' - 6996' Add perfs done 6/08/05 Camco 2-7/8" x1" 11,898` KBMM Gas lift mandrel X N HES XN-Nipple (2.205" id) 12,036' Centrilift ESP 12,058` SXD 196-P11 Intake -Gas Separator 12,084` °_ Model - GSTHVEVX - - Tandem Seal Section, 12,090' MOdel - GS63DBUT/LT SB/SB PFSA/FSA CL5 - Motor, 190 HP KMH 12,104` I 2415 volt/48 amp, Pumpmate XTO 12,120` Shear Type Safety Jt. 12 123' - , (5 pins- 33,150#) 2-7/8" Ported tbg Jt. 12 126` , Baker 7" Cu Pkr Assm ' . p . 12,129 4" Excluder Screen (Med. pore) 12 133` , & 4" Bull Plug Baker ZXP packer 12231' Baker HMC liner hanger 12245' 7", 26# L-80 btc shoe 12422' 3S cleanout and tagged td C~ 12,641' 7/19/2007 4.5" float collar (PBTD) 12702' 4.5" 12.6#, L-80 float shoe 12789' DATE REV. BY COMMENTS 6/18/00 M.Linder Initial Com letion Do on 141 MILNE POINT UNIT &12/00 GMH e - rac - can ou RWO -ESP Completion Nabors 4ES WELL F-81 1!30/01 3/27/02 0 GMH M.linder RWO -ESP Completion Nabors 4ES RWONabors4-ES R Pe sN b rs API NO: 50-029-22959-00 7/19/2007 BDB letion Nabors 3S RWO- ESP Com p 1/5/2008 REH Nabors 3S -ESP RWO/ Cup Pkr & Excluder Screen gp EXPLORATION (AK) • • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 12/31/2008 End: 1/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/5/2009 Rig Name: NABOBS 3S Rig Number: Date From - To ~ Hours Task ', Code NPT Phase Description of Operations 12/31/2008 00:00 - 01:30 1.50 RIGD P PRE Prepare floor and scope derrick down and lay over. Disconnect electrical lines. 01:30 - 02:30 1.00 RIGD P PRE Jack up pipe shed and pin. Pull pipe shed Shute away from carrier. 02:30 - 03:30 1.00 RIGD P PRE Jack up pits and pin axle. Blow down steam. 03:30 - 04:30 1.00 RIGD P PRE Roll tires on carrier to warm things up due to -20 degree weather. 04:30 - 06:00 1.50 RIGD P PRE Peak trucks on location at 0430. Move pits, pipe shed and sub structure off well MPF-25. Move witnessed by Pad operator and BP/WSL. 06:00 - 09:00 3.00 RIGD P PRE Move around pad and spot over MPF-81 witnessed by Pad operator and BP/WSL. 09:00 - 12:00 3.00 RIGD P PRE Spot Pipe shed and Pits. Scope up and raise Derrick. 12:00 - 13:00 1.00 RIGD P PRE Wait on dirty Vac truck to return from Pad-3 and off load up-right tank. Held safety stand down and discussed resent incidents on slope. 13:00 - 14:00 1.00 RIGD P PRE RU lines and handrails. Place cellar guard on MPF-25. Acce ted Ri at 14:00 hours 12/31/2008. 14:00 - 19:30 5.50 RIGD P PRE RU second annulus valve, kill manifold and hard lines to Tiger tank. Tested surface lines to 3,000 psi and down stream of choke to Tiger Tank to 500 psi. Spot up-right tank in burm and release Peak bed-truck at 16:00 hours. Load pits with 8.45 ppg seawater. 19:30 - 20;30 1.00 RIGD P PRE Conduct safety meeting with rig crews, LRS and vac truck drivers. Discuss kill procedure, egress and establish communication standards. Call Milne Pt. to notify gas venting in progress. 20:30 - 22:00 1.50 KILL P DECOMP Bleed IA pressure thru choke from 540 psi to 180 psi. Bleed tubing pressure thru choke from 400 psi to 290 psi. Fluid weight in pits = 8.45 ppg / 130 deg F. Break circulation down tubing taking returns thru choke to tiger tank at 1 BPM / 250 psi, returning all gas. Caught fluid 20 bbls into circulation. Circulate 70 bbls at 3 BPM / 780 psi, returned 50 bbls back to tiger tank. Tubing pressure fell to 0 psi. 22:00 - 23:00 1.00 KILL P DECOMP Bullhead 25 bbls down tubing at 1 BPM / 350 psi on final pump pressure. IA increased from 480 to 710 psi during bullhead. Monitor well for 15 min. Tubing at 100 psi and IA at 440 psi. 23:00 - 00:00 1.00 KILL P DECOMP Circulate 380 bbls down tubing at 3.5 BPM / 1200 psi thru choke taking returns to tiger tank. 1/1/2009 00:00 - 01:00 1.00 KILL P DECOMP Continue to circulate 380 bbls down tubing at 3.5 BPM / 1200 psi thru choke taking returns to tiger tank. Total fluid circluated on well kill = 474 bbls Total returns = 384 bbls Total losses = 90 bbls lost Burin circulation. 01:00 - 01:45 0.75 KILL P DECOMP Shut in and monitor well. Tubing at 120 psi. Talk to Anchorage engineering and order 9.1 ppg kill weight fluid. 01:45 - 11:00 9.25 KILL P DECOMP Wait on kill weight fluid from M-I and dirty Vac truck to return from Pad-3. 11:00 - 11:30 0.50 KILL P DECOMP Held PJSM with Vac truck drivers, L.R.S. and crew on Well kill operations. 11:30 - 14:30 3.00 KILL P DECOMP SITP=120 psi, Bleed IA pressure down from 100 psi to 70 psi. Pump 70 bbls 9.1 ppg 130 deg F, brine down tubing ~ 3 bpm / 650 psi with returns through choke to Tiger tank. Bull-head 25 Printed: 1/12/2009 10:47:29 AM • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPF-81 Common W ell Name: MPF-81 Spud Date: 5/30/2000 Event Nam e: WORKO VER Start : 12/31/2008 End: 1/5/2009 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 1/5/2009 Rig Name: NABOB S 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2009 11:30 - 14:30 3.00 KILL P DECOMP bbls down tubing into formation ~ 1-1/2 bpm / 830 psi. Pump 405 bbls 9.1 ppg, 130 deg F, brine C~ 4 bpm / 1150 - 1220 psi down the tubing taking returns throught the choke to Tiger tank. Lost 59 bbls. Tb & IA on a Vac. 14:30 - 16:30 2.00 KILL P DECOMP Blow down surface lines and R / D kill manifold, valves and lines. Spot LRS unit. 16:30 - 17:30 1.00 WHSUR P DECOMP Dry rod TWC with FMC wellhead tech. R/U and test LRS lines to the IA. 17:30 - 18:00 0.50 WHSUR P DECOMP Pressure test TWC from above to 3,500 si for 10 charted minutes. LRS um ed 10 bbls to fill test TWC fr Bull-heading down the IA ~ 1-1/2 bpm / 200 psi. Total pumped = 17 bbls. Witnessed by BP/WSL. 18:00 - 19:00 1.00 WHSUR P DECOMP Bleed adapter void and N/D adapter and tree. 19:00 - 00:00 5.00 WHSUR P DECOMP N/U 13-5/8" BOPE with 2-7/8"x5" VBR. Connect Koomey lines, choke line, kill line, and function test components. Test all alarms and sensors. 1/2/2009 00:00 - 05:00 5.00 WHSUR P DECOMP Test ROPE 250 psi low / 3500 psi high. Test with 2-7/8" test joint. Complete Koomey draw down test. Test witnessed by BP WSL, NAD Toolpusher. Use LRS to gravity feed backside during test at 4 BPH. RD test equipment, blow down lines. Witness of test waived by (Jeff Jones with AOGCC). 05:00 - 07:00 2.00 WHSUR P DECOMP RU Opso-Lopso and lo-torque valve. MU polish rod and lubricator to Opso. Pressure test with diesel to 500 psi: Pull TWC. Monitor well. 07:00 - 08:00 1.00 WHSUR P DECOMP M / U landing joint with TIW valve, FMC rep BOLDS, pull tubing han er off seat ~ 80 K work i e free ~ 105 K. 08:00 - 08:30. 0.50 WHSUR P DECOMP Pump 70 bbls to clear tubing, 3 bpm / 680 psi. 25 bph loss rate with um on. 08:30 - 09:30 1.00 WHSUR P DECOMP Pull hanger to rig floor, PUW = 87 K. ESP conductivity test OK, FMC rep remove penetrator. U D landing joint and hanger. 09:30 - 11:00 1.50 PULL P DECOMP R / U floor to pull completion and snake ESP cable over Derrick sheave to spooler. 11:00 - 14:30 3.50 PULL P DECOMP POH from 12,121' with 2-7/8" EUE tubing, ESP completion and stand tubing in Derrick. Pump across top of the hole, loss rate 12-15 BPH. Found cable splice on joint # 130 out. 14:30 - 16:30 2.00 PULL P DECOMP Cut cable, remove reel from spooling unit and start cable on new reel. 16:30 - 21:00 4.50 PULL P DECOMP Continue POH with ESP completion from joint #130 to joint # 332 21:00 - 21:30 0.50 PULL P DECOMP Crew change, service rig and daily inspections. 21:30 - 23:30 2.00 PULL P DECOMP Continue POH with ESP completion from joint # 332 to joint # 385. 1) X-N nipple 2) GLM's 23:30 - 00:00 0.50 PULL P DECOMP UD ESP, sand and scale in pump and gas seperator. 1/3/2009 00:00 - 01:30 1.50 PULL P DECOMP Continue to UD ESP. Recovered 200) Lasalle clamps, 5) Protectolizers, 3) Flat guards. 01:30 - 03:00 1.50 PULL P DECOMP Clear and clean rig floor. R/D elphant trunk. P/U 2-3/8" handling tools. 03:00 - 05:00 2.00 CLEAN P CLEAN P/U 2-3/8" PH6 i e to clean out 4-1/2" liner. Change over handling tools to 2-7/8". 05:00 - 06:00 1.00 CLEAN P CLEAN RIH with 2-7/8" tubing from derrick to cleanout to 12,641'. 10 stands 06:00 - 13:00 7.00 CLEAN P CLEAN Pre-tour checks. Continue RIH to 11,750' Printed: 1/12/2009 10:47:29 AM • BP EXPLORATION Page 3 of 4 ~ Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 12/31/2008 End: 1/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/5/2009 Rig Name: NABOBS 3S Rig Number: Date ~ From - To Hours Task Code NPT 1/3/2009 13:00 - 17:30 4.50 CLEAN N 17:30 - 18:00 0.50 CLEAN P 18:00 - 19:00 1.00 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 20:30 0.501 CLEAN P 20:30 - 21:30 I 1.001 CLEAN I P 21:30 - 22:30 1.00 CLEAN P 22:30 - 23:00 0.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 1/4/2009 100:00 - 05:00 I 5.001 CLEAN I P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:30 2.50 08:30 - 09:30 1.00 09:30 - 14:00 4.50 14:00 - 18:00 4.00 RUN 18:00 - 18:30 0.50 RUN 18:30 - 00:00 5.50 RUN 1 /5/2009 00:00 - 02:30 2.50 R U N 02:30 - 06:00 I 3.50 06:00 - 09:00 I 3.001 RU 09:00 - 10:00 1.00 RU 10:00 - 11:30 1.50 RUNCOf~'P 11:30 - 12:30 1.00 RNTBH P 12:30 - 14:00 ~ 1.50 ~ RNTBHC~ P .Phase Description of Operations CLEAN Thaw ice plug in stand pipe. CLEAN Circulate tubing volume ~ 3 SPM with 700 psi. CLEAN Reverse circulate C~ 3 BPM with 700 psi. Rig down lines. Up weight 60 k Down weight 30 k. CLEAN RIH with 2-7/8" tubing from derrick from 11,750' to 12,380'. Went through liner top C~? 12,231' with no problem. CLEAN Pick up 8) joints of tubing from pipe shed and RIH to 12,665'. No fill encoutered. CLEAN Break circulation down tubing. Reverse circulate C~ 4 BPM with 590 psi. Losses (~ 108 BPH. No sand recovered during reverse. CLEAN Monitor well. L/D 8) joints to pipe shed. CLEAN Monitor well above perfs. Well static. CLEAN POOH standing back 2-7/8" tubing in derrick. Continuous hole fill. CLEAN Continue POOH standing back 2-7/8" tubing in derrick. Continuous hole fill. CLEAN Lay down 2-3/8" PH6 into pipe shed. R/D handling tools, clear and clean rig floor. RUNCMP R/U to run ESP completion assembly. RUNCMP PU / MU 4" Screen and Cup packer assembly. RUNCMP PU and service ESP pump assembly per Centrilift rep. Snake ESP cable over sheave in Derrick. M/U and check conductivity of cable. RUNCMP P/U XN, KBMM GLM w/ Dummy ancj RIH on 2-7/8", 6.5#,L-80,8 rd EUE tubin from Derrick slow with continuous hole fill. Loss rate = 0 - 4 bph. RUNCMP Crew change, service rig, Daily inspections. RUNCMP Continue to RIH on 2-7/8", 6.5#,L-80,8 rd EUE tubing from Derrick slow with continuous hole fill. Loss rate = 0 - 4 bph. 218 joints in hole. RUNCMP Centrilift make cable splice. Circulate over top of hole. Static losses ~ 1 BPH. RUNCMP Continue to RIH on 2-7/8", 6.5#,L-80,8 rd EUE tubing from Derrick slow with continuous hole fill. Loss rate = 0 - 4 bph. Check conductivity and Flush pump each 2000'. Stand # 97 .5 BPM (~ 1200 psi. 155 stand RIH at 06:00 hours. RUNCMP Continue RIH with ESP completion from stand # 155 to #192, PU (1) joint from pipe shed. Ran 385 joints, 200 Lasalle clamps, 2 flat guards, 5 protectolizers. RUNCMP PU / MU landing joint with TIW and tubing hanger with FMC wellhead tech. RUNCMP Centrilift rep make penitrator cable splice. TUBHGR Pump out BOP stack, Land tubing hanger, at 12,174', RILDS and dry rod TWC with FMC wellhead tech. TUBHGR R/U and test TWC from above to 3 500 for 10 charted minutes. Test TWC from below by pumping (injecting) down the IA at 1.70 bom / 300-400 osi. num~ed 10 bbls charted. Witnessed 14:00 - 17:00 3.00 BOPSU P RUNCMP Blow down lines, remove turn buckles, ready cellar for N/D of BOPE. 17:00 - 18:00 1.00 BOPSU P RUNCMP Rig Abandonment drill, muster area truck shop. Crew, little red, vac truck driver, FMC Rep, Centrilift Rep. Debreifed by BP Printed: 1/12/2009 10:47:29 AM r ~ • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 12/31/2008 End: 1/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/5/2009 Rig Name: NABOBS 3S Rig Number: i Date From - To Hours Task Code NPT ~ Phase Description of Operations 1/5/2009 17:00 - 18:00 1.00 BOPSU P RUNCMP WSL and Tool Pusher. 18:00 - 20:00 2.00 BOPSU P RUNCMP N/D BOPE set back in craddle. 20:00 - 22:00 2.00 BOPSU P RUNCMP N/U adapter and tree. 22:00 - 23:00 1.00 BOPSU P RUNCMP Test adapter void to 5000 psi for 30 minutes. Test tree to 5000 psi for 5 charted minutes. Good tests. Cenrilift Rep checked continuity of ESP. Good test. 23:00 - 00:00 1.00 BOPSU P RUNCMP Rlg up and test lubricator with diesel to 500 psi, pull TWC and set BPV. Nomal up cellar and secure tree and wellhead for move. tRig released ~ 00:00 hrs. Printed: 1/12/2009 10:47:29 AM STATE OF ALASKA 11114!07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 1/2/2009 Rig Rep.: G.Sweatt/R. Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: D.RhodeslO.Coyne Field/Unit & Weil No.: MP F-81 PTD # 2000660 Operation: Drlg: Test: Initial: x Test Pressure: Rams: 250/3500 Workover: x Weekly: Annular. 250/3500 TEST DATA Explor.: Bi-Weekly Valves: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P WeN Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size FLOOR SAFETY VALVES: Test Result Quantity Test Re P Upper Kelly 0 NA P Lower Kelly 0 NA P BaN Type 1 P Ir~side BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind/Shear P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1/8-2 1/16" P Kill Line Valves 1 2 1116" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 1700 P 200 psi Attained 43sec P Full Pressure Attained 3 min 34sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg}: 2000psi Test Results Number of Failures: 0 Test Time: 4 Hours Comaonents tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: marks: Tested as~ainst 2 wav check. tested w/2 7/8" test int. 24 HOUR NOTICE GIVEN YES X NO..._,.,.. _ Date 12/31/08 Time 06:30 hrs est start 00:30 hrs Finish By Jeff Jones Witness O. BOP Test (for rigs) BFL 11 J14/07 Nabors 3s BOP Test MP F-81 1-2-2009.x1s STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ICON- ~~ REPORT OF SUNDRY WELL OPERATIONS 8 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory Zoo-os6o - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22959-00-00 7. KB Elevation (ft): 9. Well Name and Number: 40 KB ~ MPF-81 ' 8. Property Designation: 10. Field/Pool(s): _ ADLO-388235 - MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 12790 - feet Plugs (measured) None true vertical 7192.8 feet Junk (measured) None Effective Depth measured 12680 feet true vertical 7084 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" 91.5# H-40 Surface - 110 Surface - 110 Surface 7487 9-5/8"40# L-80 Surface - 7515 Surface - 4153 5750 3090 Production 12396 7" 29# L-80 Surface - 12422 Surface - 6830 7240 5410 8430 7500 Liner 558 4-1/2" 12.6# L-80 12231 - 12789 6641 - 7192 ~q + s~ d t J% ~ k1~~~~~~i~ ~ , . , 4, t!~ Perforation depth: Measured depth: SEE ATTACHED - - _ _ True Vertical depth: - _ - - _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 12122' 0 0 - Packers and SSSV (type and measured depth) BAKER ZXP PACKER 12231' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 298 127 290 277 Subsequent to operation: 273 149 297 256 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~' Development +~` Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil +~' Gas "' WAG GINJ ~' WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/25/2008 Form 10-404 Revised 04/2006 ~RIr1~IL~ I ~ - "~ ~~' ~~ `~ `~. ~~~~ Submit Original Only ~~aC ~ MPF-81 200-066 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-81 6/21/00 PER 12,550. 12,570.' 6,955.67 6,975.38 MPF-81 6/6/05 APF __ 12,530. 12,540. 6,935.97 6,945.82 MPF-81 6/7/05 APF 12,581. 12,591. 6,986.23 6,996.1 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL ____ FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • ITYDATE 9/11 /2008 • MPF-81 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY ( Acid treatment) Load dead crude and transport to MPF-81. MIRU. Awgers continued on 09-12-08. 9/12/2008;. (Acid Treatment) T/I/0= 400/450/0 Pump 33 bbls dead crude down TBG followed by 15 bbls Acid then 4 bbls dead crude then 3 bbls 60/40 followed by 52 bbls dead ``crude. FWHP= 600/600/0 (swab-shut /wing-shut / ssv-shut /master-open / IA and `° OA open to gauges.) FLUIDS PUMPED BBLS 15 ACID 3 60/40 89 DEAD CRUDE 107 Total . STATE OF ALASKA . ~ RECEj\/ErJ ALA~ Oil AND GAS CONSERVATION COMMISSION J REPORT OF SUNDRY WELL OPERATIONS~lttÇÃUG 0 3 2007 Alaska Oil R, g,,~ ('",. ~ f"1.,~ , 1. Operations Performed: l;nchnra~;-2q o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 200-066 ~ 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage. Alaska 99519-6612 50-029-22959-00-00 - 7. KB Elevation (ft): 40' - 9. Well Name and Number: MPF-81- 8. Property Designation: 10. Field / Pool(s): ADL 388235 Milne Point Unit / Kuparuk River Sandso/ 11. Present well condition summary Total depth: measured 12790, feet true vertical 7193 feet Plugs (measured) None Effective depth: measured 12680 feet Junk (measured) None true vertical 7084 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7487' 9-5/8" 7515' 4153' 5750 3090 Intermediate Production 12396' 7" 12422' 6830' 7240 5410 Liner 558' 4-1/2" 12231' -12789' 6641' - 7192' 8430 7500 SCANNED AUG 1 62007 Perforation Depth MD (ft): 12530' - 12591' Perforation Depth TVD (ft): 6936' - 6996' 2-7/8",6.5# L-80 12122' Tubing Size (size, grade. and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure TubinQ Pressure Prior to well operation: 0 0 0 250 0 Subsequent to operation: 483 130 446 0 292 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Sondra Stewman Title Technical Assistant . -"" Prepared By Name/Number: Signature C """'D; Í A ":II:' -' DateO'R ~bZ-{J 7 Sandra Stewman, 564-4750 ''"''''" JI...~ Phone 564-4750 .Ã1 /Y Form 10-404 Revised 04/20060 RIG I N A L Submit Original Only RBDMS BFL AUG 1 5 ZDD7 · . Tree: CIW 2-9/16" 5M Wellhead: 11" x 11" 5M FMC Gen 5 11" x 2-9/16" NSCT. 2.5" CIW-H BPV profile. 20" 91.51 # ppf, H-40 I 78' 95/8",40 ppf, L-80 Btrcj 7515' 2.875' 6.5#/ft, L-80 8rd. EUE ( drift 10 = 2.347", cap. = 0.00579 bpf ) 7" 29 ppf, L-80, Hydril1.563 casing, (drift 10 = 6.184", cap. = 0.0371 bpf) KOP @ 544' Max. hole angle = 75 deg. at 8832. Hole angle thru' perfs = 9 deg. Stimulation Summary 156M# 16/20 proppant 6/24/00 Perforation Summary Ref loa: GR / CCl 6/20/00 Kuparuk "A" Sand Perfs Size SPF Interval (TV D) *33/ 6 12,530-12,540 6935' - 6946 2.5 6 12,550-12,570 6955' - 7004' 33/ 6 12,550-12,570 6955' - 7004' *33/ 6 12,581-12,591 6986' - 6996' * Add perfs done 6/08/05 DATE REV. BY 6/18/00 M.Linder 8112/00 GMH 1/30i01 GIV1H 3/27/02 M.lìnder 06/09/05 MOO 7/19/2007 BOB MPU F-81 COMMENTS Initial Com e - rac- ean au RWO - ESP Completion Nabors 4ES R\\!O - ESP Completion Nabors 4ES RWO Nabors 4-ES RWO & Add Perfs Nabors 4es RWO- ESP Completion Nabors 3S Orig. OF Elev. = 27.40' (Doyon 141) Orig. GL Elev. =11.00' (Doyon 141) Cameo 2-7/8" x1" KBMM Gas lift mandrel TAM port coHar Cameo 2-7/8" x1" KBMM Gas lift mandrel HES XN-Nipple (2.205" id) I I INTAKE TVO 6,501' I Pump, 151 8tg. GC1700 I Model GPMTAR 1:1 Intake - Gas Separator I Model - GRSFTXARH6 . Seal Section, Model - GSB30BUT PFSA I GSB30BL TFSA CL5 Motor, 171 HP KMH I 2390 volt/44 amp, Phoenix Multi senor w/6 fin centralizer Baker ZXP packer Baker HMC liner hanger 7",26# L-80 btc shoe I 135' I 1004' I 11,897' I 12,036' I 12,058' 12,080' 12,085' 12,099' I 12,119' I 12231 ' 12245' 12422' 3S cleanout and tagged td @ 12,641' 7/19/2007 4.5" float collar (PBTO) 4.5" 12.6#, L-80 float shoe 12702' 12789' MILNE POINT UNIT WELL F-81 API NO: 50-029-22959-00 BP EXPLORATION (AK) . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-81 MPF-81 WORKOVER NABORS ALASKA DRilLING I NABORS 38 Start: Rig Release: Rig Number: 7/12/2007 7/1 9/2007 Spud Date: 5/30/2000 End: 7/19/2007 7/13/2007 06:00 - 10:30 4.50 MOB P PRE Move to MPF-Pad from MPK-Pad. Wait at Milne Point Y during C/O. Rig on location @ 1030-hrs. 10:30 - 19:30 9.00 RIGU P PRE Rig on location @ 1030-hrs. Spot Carrier, Pipe Shed, and Pits on top of Herculite. Spot Tiger Tank. Make Electrical and plumbing connections. Raise Derrick. Install additionallA Valve. M/U Hardline to Tiger Tank. Pressure test Hardline. Test high level alarm. Accept rig @ 13:00 hrs. 19:30 - 20:30 1.00 OHB P OECOMP P/U OSM Lubricator and Pull BPV. TBG Pressure- 350 psi, IA Pressure- 325 psi. UO OSM Lubricator and BPV. 20:30 - 21 :30 1.00 KILL P OECOMP R/U and pressure test tiger tank lines to 500 psi and surface lines to 3500 psi. Open well with TBG Pressure @ 280 psi and CSG Pressure @ 240 psi. 21 :30 - 22:00 0.50 KILL P OECOMP Pump TBG volume of 70 bbls down TBG as followed: Bring pump on line @ 3 BPM while keeping constant CSG pressure at 240 psi. Maintain constant CSG Pressure, ICP- 1030 psi, FCP- 770 psi. 22:00 - 22:30 0.50 KILL P OECOMP Shut in IA and Bullhead 20 bbls down TBG. ¡CP- 520 psi at 1 BPM, FCP- 1050 psi at 1 BPM. 22:30 - 23:00 0.50 KILL P OECOMP Shut in well and monitor pressures. Pressures bled down to 40 psi on TBG and 270 psi on IA. 23:00 - 00:00 1.00 KILL P OECOMP Continue killing procedures by opening IA to choke and pump down TBG at 3 BPM maintaining constent CSG pressure @ 270 psi. ICP at 3 BPM- 700 psi with 270 psi CSG pressure. Maintain ICP of 700 psi as FCP while displacing IA volume with seawater. 7/14/2007 00:00 - 01 :30 1.50 KILL P OECOMP Continue killing procedures maintaining FCP of 700 psi while displacing IA volume with seawater. Pump a total of 380 bbls to clear Annulus. 01 :30 - 02:00 0.50 KILL P OECOMP Monitor well for 30 minutes for kill weight fluid calculations. Well stabilized at 40 psi SITP and 10 psi SICP. 02:00 - 03:30 1.50 KILL P OECOMP Calculate Kill Weight fluid with 150 psi overbalance at 9.0 ppg. Weight up surface system to 9.0 ppg NaCI Brine. 03:30 - 08:00 4.50 KILL P OECOMP Open up well and circulate 9.0 ppg kill weight fluid. Bring pump on line maintaining CSG pressure of 20 psi until reaching ICP of 670 psi at 3 BPM. Maintain constant CSG pressure while pumping TBG volume. Establish FCP of 570 psi at 3 BPM and continue killing operations. Maintain FCP. 9.0 ppg returns obtained. A total of 486 Bbls of brine were circulated and 26 Bbls were lost to the formation. 08:00 - 08:30 0.50 KILL P OECOMP Monitor well. TIIA = vac/vac. 08:30 - 10:00 1.50 DHB P OECOMP Set TWC wI Ory rod. Test from above to 3500 psi and chart for 10 minutes. Test from below by bull heading down IA. Injected 14 Bbls at a rate of 2.5 BPM and 920 psi. No visually signs of TWC leaking during bullheading. 10:00 - 11 :30 1.50 WHSUR P OECOMP N/D Tree. M/U Opso Lopso XO to Hanger with 9.5 turns. Hanger threads are in good condition. 11 :30 - 15:30 4.00 BOPSU P DECOMP N/U BOPE. 15:30 - 16:00 0.50 BOPSU P OECOMP Fill Stack and Function Test BOPE. 16:00 - 22:00 6.00 BOPSU P OECOMP Test BOPE to 250 psi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by Lou Grimaldi. Test was witnessed by Nabors Tool Pusher and BP WSL. Test #1 - Choke Valves 1, 2, Blind Rams, and HCR Kill Printed: 8/2/2007 1 :40:04 PM . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-81 MPF-81 WORKOVER NABORS ALASKA DRilLING I NABORS 3S Start: Rig Release: Rig Number: Spud Date: 5/30/2000 End: 7/19/2007 7/12/2007 7/1 9/2007 7/14/2007 22:00 - 22:30 0.50 BOPSU P 22:30 - 00:00 1.50 BOPSU P 7/15/2007 00:00 - 00:30 0.50 CLEAN P 00:30 - 06:00 5.50 CLEAN P 06:00 - 07:30 1.50 PULL P 07:30 - 10:00 2.50 PULL P 10:00 - 10:30 0.50 PULL P 10:30 - 20:00 9.50 PULL P 20:00 - 20:30 0.50 PULL P 20:30 - 21 :00 0.50 PULL 21 :00 - 22:00 1.00 PULL P 22:00 - 22:30 0.50 PULL P 22:30 - 00:00 1.50 PULL P 7/16/2007 00:00 - 04:00 4.00 PULL P 04:00 - 07:00 3.00 PULL P 07:00 - 16:00 9.00 CLEAN P OECOMP Test #2- Choke Valves 3, 4, 5, and 6 Test #3- Choke Valves 7,8, and 9 Test #4- Choke Valves 10 and 11 Test #5- Choke Valves 12 and 13 Test #6- Manual Kill and HCR Choke Test #7- Pipe Rams with 2-7/8" Test Joint and TIW Valve Test #8- Annular and Outside Mud Cross Valve Test #9- Inside Mud Cross Valve Test #10- Manual Choke Test #11- Oart Valve Accumulater Test- Starting Pressure- 3000 psi, After Accuation- 1800 psi. First 200 psi Recovery in 28 Seconds, Full Recovery in 100 Seconds. 4 Nitrogen Bottles @ 1938 psi. OECOMP Orain Stack and blow down choke manifold and lines. OECOMP P/U Opso Lopso and C/O crossovers. RIH. P/U OSM lubricator with extention. Pull TWC. UO lubricator and TWC. Fill well with 7 bbls. Well losing @ 26 BPH. OECOMP Circulate through mud cross and Monitor well for loss rate of 26 BPH. DECOMP PJSM. R/U and hang blocks. Slip on new drill line from new reel. Remove and discard old drilling line. DECOMP PJSM. P/U Landing Joint and M/U to Hanger. BOLDS. Pull 75k-lbs to free Hanger. Once Hanger was free the P/U weight = 77k-lbs. DECOMP Circulate 360 Bbls of 9 ppg brine while taking returns to the pits at 3.5 BPM and 900 psi. DECOMP Pull Hanger to Floor. Conduct ESP cable checks per Centrilift Inspect Hanger which is in good condition but needs new seals. Break and UD Landing joint and Hanger. Hanger to be redressed onsite. DECOMP i Pull ESP cable through Sheave and to Spooler. POH w/2-7/8" 6.5" EUE 8rd Tubing while SIB doubles in the Derrick while filling hole continuously. Losses to formation are -10 BPH. 30-jts OOH @ 1445-hrs. 70 OOH @ 1645-hrs. C/O ESP Cable Reel. Losses @ 11 BPH @ 1700-hrs. DECOMP Continue pulling ESP completion standing back 2-7/8" TBG in derrick to 4400'. Trip sheet showed losses decreasing. DECOMP Stop trip, pull slips and monitor well. Losses slowed down to 5 BPH. DECOMP Build 10 ppg Kill Pill in pit 3 (35 bbls) to increase hydrosatic I pressure 46 psi. Pump and balance 32 bbls Kill Pill to cover 1888' of hole. DECOMP Shut down pump and monitor losses @ 8 BPH. DECOMP Continue pulling ESP completion standing back 2-7/8" EUE 8rd . TBG in derrick. DECOMP Continue POOH with ESP completion to ESP Pump standing back 2-718" EUE 8rd TBG in derrick. Check loss rate at 2000' and 1000'. Losses 12-16 BPH. OECOMP Break lay down ESP. Recovered 385 joints of 2-718" EUE 8rd TBG, 200 LaSalle Clamps, 5 Protectalizers and 3 Flat Guards. Loss Rate @ 8 BPH. CLEAN MU and RIH wI FCO workstring: Mule Shoe, 2-7/8" PAC, XO, Printed: 8/2/2007 1 :40:04 PM . . .. ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-81 MPF-81 WORKOVER NABORS ALASKA DRILLING I NABORS 3$ Start: Rig Release: Rig Number: 7/12/2007 7/19/2007 Spud Date: 5/30/2000 End: 7/19/2007 7/16/2007 07:00 - 16:00 9.00 CLEAN P CLEAN 2-7/8" EUE Tubing from Derrick. Tubing started to U-Tube at -3,300' MO. Pump 6 Bbl10 ppg pill down Tubing and allow it to drop on it's own. Tubing and IA on a vac. Continue RIH. Losses at 5-6 BPH. RIH and tag top of fill lightly @ 12,565' MO. 16:00 - 23:30 7.50 CLEAN P CLEAN Establish working parameters of Up Weight- 65,000 Ibs, Oown Weight- 35,000 Ibs, Pump Pressure (Long)- 870 psi at 3.2 BPM. P/U singles and wash down from 12,565' to 12,671' MO by Circulating @ 3.5 BPM and 1000 psi. After washing down each single, use LRHOS to Reverse Circulate @ 4-5 BPM and 950 to 1450 psi. Bring returns across Shaker and back to Pits until returns cleaned up. See Proppant across Shaker each time. Loss rate up to 100 BPH reverse circulating at 5 BPM. Slow down pump to 4 BPM brought loss rate down to 64 BPH. 23:30 - 00:00 0.50 CLEAN P CLEAN Pump high vis sweep down drill pipe at 3 BPM with 750 psi. Spot on annulus side of TBG 22 bbls out of Mule Shoe. 7/17/2007 00:00 - 01 :30 1.50 CLEAN P CLEAN Pump high vis sweep down drill pipe and spot on annulus side of TBG 22 bbls out of Mule Shoe. Turn around and reverse circulate sweep out of hole with LRHOS at 4 BPM with 1000 psi. Sweep bought up minimal returns. Continue reverse circulating one more bottoms up. Hole clean. 01 :30 - 03:00 1 .50 CLEAN P CLEAN Shut down pumping and flow check well. Well Flowing back @ 58 BPH. Flow steadily decrease to 10 BPH and stabilized there. 03:00 - 07:30 4.50 CLEAN P CLEAN Calculate 75 psi overbalance and weight up surface mud system to 9.3 ppg with NaCI Salt. Circulate at 3 BPM with 680 psi. 07:30 - 09:00 1 .50 CLEAN P CLEAN The whole system is at 9.3 ppg brine. Shut down circulation and monitor well for hourly losses. Losses are averaging 4 bbls I hour. 09:00 - 13:00 4.00 CLEAN P CLEAN Weight up the mud system and Pits to 9.5 ppg brine. Circulate the 9.5 ppg brine all the way around to swap the whole well to 9.5 ppg. Circulating pressure = 3 bpm I 700 psi. 13:00 - 16:00 3.00 CLEAN P CLEAN Monitor well for losses. Losses are ranging from 10 - 19 bbls I hour. Oiscuss with Anchorage Engineering and decision made to go ahead and come out of the hole. 16:00 - 00:00 8.00 CLEAN P CLEAN TOH standing back 2 718" Tubing in the Derrick while maintaining continuous hole fill with 9.5 ppg brine. For the first half hour, the loss rate is at 10 bbls I hour. 55 stands out of the hole at 18:30 hrs. 85 stands out of the hole at 20:00 hrs. Current losses at 20:00 hrs are at 7 bbls / hour. Continue TOH. 130 stands out of the hole at 00:00. 7/18/2007 00:00 - 02:00 2.00 CLEAN P CLEAN TOH standing back 2 7/8" Tubing in the Derrick while maintaining continuous hole fill with 9.5 ppg brine. 02:00 - 04:00 2.00 CLEAN P CLEAN Laid down top two new joints and PAC pipe while maintaining contiuous hole fill. 04:00 - 06:00 2.00 RUNCO RUNCMP RU and prepare to run new ESP Completion with Centrilift rep. Clear and clean Rig Floor. Circulate over the top to maintain continuous hole fill while on surface. Loss rate = 9 bbls / hour. 06:00 - 09:00 3.00 RUNCO RUNCMP PU new ESP components with Centrilift rep. Pull ESP cable over sheave and attach MLE to the Pump. 09:00 - 12:00 3.00 RUNCO RUNCMP RIH with new ESP Completion on 2 7/8", 6.5#, L-80, EUE 8rd Tubing. Utilizing Best-O-Life Pipe Oope on all connections. MU Torque utilized = 2,300 ft-Ibs optimum. Using LaSalle Printed: 8/2/2007 1 :40:04 PM . . ... ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12:00 - 13:00 13:00 - 18:00 18:00 - 21 :00 21 :00 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 7/19/2007 00:00 - 04:00 04:00 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 09:30 09:30 - 12:30 12:30 - 15:00 15:00 - 17:00 17:00 - 18:00 MPF-81 MPF-81 WORKOVER NABORS ALASKA DRILLING I NABORS 3S 7/12/2007 7/19/2007 Spud Date: 5/30/2000 End: 7/19/2007 Start: Rig Release: Rig Number: RUNCMP Clamps on the first 9 Jts and then every other to surface. Stopping every 2,000' to check the ESP Cable conductivity. Flush the pump with 10 bbls of 9.5 ppg brine at a rate of 0.5 bpm I 2,200 psi at every cable check. 40 stands of Tubing (80 Jts) in the hole at 12:00 hrs. Stop to check the loss rate of the well. In one hour we lost 7.1 bbls. Continue RIH with new ESP Completion. 100 stands of Tubing (200 Jts) in the hole at 17:00 hrs. Stop with 123 stands of Tubing (246 Jts) in the well to perform reel to reel splice on the ESP Cable with Centrilift reps. Maintain continuous hole fill and monitor while splicing the reels. Reel to reel splice is complete. Well Support Techs arrive on location to shoot fluid level prior to continuing in the hole with the Completion. Loss rate during the splice was 6 bbls / hour. Stopped filling the hole and allowed fluid in hole to level. Attempted first fluid level shot down annulus, could not get accurate reading. Rigged up to shoot down tubing. Took first shot down tubing, got a reading of 300'. Took second shot 15 minutes later, got the same reading of 300'. Filled hole, the hole took 11.0 bbls, which verified the 300' reading. Overbalance of 150 psi was calculated. Continued running in hole with the ESP Completion on 2 7/8" Tubing. Continued running in hole with ESP completion. Losses while tripping 5 bph at 00:30, flowchecked at 02:45, losses at 9.6 bph. Ran a total of 385 Jts of 2 7/8" Tubing in the hole, 5 Protectolizers, 3 Flat Guards and 200 LaSalle Clamps. Picked up hanger with FMC rep. Perform Penetrator Splice on the ESP cable with Centrilift rep. Establish final PUW = 72K and SOW = 40K. Align and land the Tubing Hanger with FMC rep utilizing the alignment pin. RILDS with FMC rep. PU dry rod and set TWC with FMC rep. Test from above to 1,000 psi for 10 charted mins. Line up to inject down the annulus to test from below at 3 bpm with final pressure of 950 psi. Bleed down test pressure, RO test equipment and blow down lines. PJSM. ND 13 5/8" 5M BOPE and lay down in Cradle. NU Tree and Adapter Flange with FMC rep. Utilize Sweeney Wrench for all nuts and bolts. Final readings on the ESP attained: phase to phase = 4.2 ohms, phase to ground = 500 Mega-ohms, intake pressure = 3,132 psi, intake temperature = 160 degrees, motor temperature = 162.7 degrees. Pressure test the Adapter Void to 5,000 psi for 30 mins with the FMC rep - OK. Fill the tree with diesel. Pressure test the Tree to 5,000 psi - charted. Bleed down and drain the diesel from the Tree. RU Lubricator with Well Support Techs. Lubricate out the TWC. Lubricate in the BPV. Secure the Tree and Cellar. The Rig was released at 18:00 hrs on 7/19/2007. RUNCMP 3.00 RUNCMP 1.00 RUNCO P RUNCMP 4.00 RUNCO I RUNCMP 0.50 RUNCO RUNCMP 0.50 RUNCO RUNCMP 1.00 RUNCO RUNCMP RUNCMP 0.50 RUNCO 2.00 RUNCO RUNCMP RUNCMP 1.00 RUNCO 2.00 WHSUR P POST 3.00 BOPSU P 2.50 WHSUR P POST POST 2.00 WHSUR P POST 1.00 WHSUR P POST Printed: 8/2/2007 1 :40:04 PM STATE OF ALASKA ~ ALASKA JL AND GAS CONSERVATION CG..~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. 1<8 Elevation (ft): 8. Property Designation: ADL 388235 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 0 Operation Shutdown II Perforate 0 Other II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 40' 12790 7193 12680 7084 110' 7487' 12396' 558' 4. Current Well Class: II Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 200-066 6. API Number: 50-029-22959-00-00 99519-6612 9. Well Name and Number: MPF-81 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) ":"~l\~'NEO IIJ1 o V!T 2005 \\ .1 If ,_,e,.' ~J l .. feet Junk (measured) 12B8 ' feet Size MD TVD Burst Collapse 20" 110' 110' 9-5/8" 7515' 4153' 5750 3090 7" 12422' 6830' 7240 5410 4-1/2" 12231' - 12789' 6641' - 7192' 8430 7500 2-7/8",6.5# rc~ ~:I""~ t"'\, E iV' '[~N "''' ~::: \,,,,, :::.'~ '. ~\,,:: JUN 2 ~) 2005 b¡~8g L,¡;¡\:i'., ":';',;,¡IC:~2114' 12231' 12530' - 12591' 6936' - 6996' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" ZXP Packer 12. Stimulation or cement squeeze summa~~Cß\NNED .!: II n 7 2005 Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Fl JUN 3 0 2005 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 282 265 300 249 280 250 Oil-Bbl Prior to well operation: 498 Subsequent to operation: 487 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations II Well Schematic Diagram TubinQ Pressure 320 319 15. Well Class after proposed work: o Exploratory II Development 0 Service 16. Well Status after proposed work: II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Si9~~A Form 10-4ò4~vised 04/2004 - Title Technical Assistant Phone 54?4 ~Lt,L.'tD Prepared By Name/Number: Date O(P-zg--LbSondra Stewman, 564-4750 Submit Original Only Tree: CIW 2-9/16" 5M " i' Wellhead: 11" x 11" 5M I .lc Gen 5q 11" x 2-9/16" NSCT. 2.5" CIW-H BPV profile. I ,.. 20" 91.51# ppf, H-40 78' 9 5/8", 40 ppf, L-80 Btrc~ 7515' 2.875" 6.5#/ft, L-80 8rd. EUE ( drift ID = 2.347", cap. = 0.00579 bpf ) 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf) KOP @ 544' Max. hole angle = 75 deg. at 8832. Hole angle thru' perfs = 9 deg. Stimulation Summary 156M# 16/20 proppant 6/24/00 Perforation Summary Ref log: GR 1 CCl 6/20/00 Kuparuk "A" Sand Perfs Size SPF Interval (TVD) 12,530-12,540 6935' - 6946' 12,550-12,570 6955' - 7004' 12,550-12,570 6955' - 7004' 12,581-12,591 6986' - 6996' *3 3/8 6 2.5 6 3 3/E 6 *3 3/8 6 * Add perfs done 6/08/05 MPU F-81 Ij Orig.) Elev. = 27.40' (Doyon 141) Orig. GL Elev. =11.00' (Doyon 141) Cameo 2-7/8" x1" KBMM Gas lift mandrel ) TAM port collar I 134' I 1004' I 11 ,896' I 12,045' I 12,059' 12,077' 12,082' 12,096' 12,114' I 12231 ' 12245' 12422' CTU clean out and tagged td @ 12,628' 4.5" float collar (PBTD) I 12702' 4.5" 12.6#, L-80 float shoe I 12789' DATE REV. BY COMMENTS MILNE POINT UNIT 6/18/00 M.Linder Initial Completion Doyon 141 WELL F-81 6123/00 MOO Perf· Frac . Clean out API NO: 50-029-22959-00 8/12/00 GMH RWO . ESP Completion Nabors 4ES 1/30/01 GM~I RWO - ESP Completion Nabors 4ES 3/27/02 M.linder RWO Nabors 4·ES 06/09/05 MOO RWO & Add Perfs Nabors 4es BP EXPLORATION (AK) 1 ~. , Cameo 2-7/8" x1" KBMM Gas lift mandrel HES XN-Nipple (2.205" id) Pump, 151 stg. GC1700 Model GPMTAR 1:1 Intake - Gas Separator Model - GRSFTXARH6 Seal Section, Model - GSB3DBUT PFSA GSB3DBL TFSA CL5 Motor, 171 HP KMH 2390' volt/44 amp, Phoenix Multi senor w/6 fin centralizer 1\ Baker ZXP packer Baker HMC liner hanger 7", 26# L-80 btc shoe ) ) Opera.tions Suml11ary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-81 MPF-81 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/4/2005 Rig Release: 6/9/2005 Rig Number: Spud Date: 5/30/2000 End: 6/9/2005 6/4/2005 18:00 - 19:30 1.50 DEMOB P DECOMP Scope and lower derrick 19:30 - 23:00 3.50 DEMOB P DECOMP Pre-rig inspection with Pad Operator completed Prep and move rig off MPF-38 I Spot and Berm over MPF-81 23:00 - 00:00 1.00 DEMOB P DECOMP Raise and scope derrick 6/5/2005 00:00 - 02:00 2.00 KILL P DECOMP PJSM R/U lines to tree and trip tank for circulation test to 3500 psi P/U lubricator and pull BPV I Take on heated sea water 02:00 - 04:00 2.00 KILL P DECOMP Tbg 405 psi, Annulus 490 psi I Bleed tbg psi Pump 100 bbls hot sea water down Tbg @ 4 bpm @ 450 psi I Bull head 30 bbls @ 4 bpm @ 490 psi I Circulate 100 bbls down tbgl Stop shut in monitor pressures Tbg 0 psi,Annulus 200 psi I Pump add 50 bbls to circulate no returns of gas or fluid. 04:00 - 06:00 2.00 KILL P DECOMP Pump hot sea water down annulus, 82 bbls, and see returns in Tbg. Stop, Switch to pump down down tbg and returns from annulus, getting good returns continue pumping to clean well. 06:00 - 07:30 1.50 KILL P DECOMP Crew change. PJSM. Continue pumping @ 4 bpm 11450 psi down tubing, taking (gassy oil) returns thru choke to tiger tank. WI 650 bbls seawater pumped see seawater returns. Pump 750 total bbls & see clean seawater returns. Monitor well, annulus & tubing on vacuum. 07:30 - 09:00 1.50 WHSUR P DECOMP PJSM. Pick up lubricator, set two way check valve. NID adapter flange & tree. 09:00 - 10:30 1.50 BOPSUF P DECOMP PJSM. N/U DSA, test spool & 135/8" x 5M BOPE. 10:30 - 13:00 2.50 BOPSUF P DECOMP PJSM. Rig up test equipment & conduct full test on BOPE. Witnessing of test waived by AOGCC rep Jeff Jones, (24 hour notice given). Test witnessed by Nabors toolpusher Gene Sweatt & BP rep Paul Haynes. Annular preventor failed high pressure test. 13:00 - 16:00 3.00 BOPSUP N RREP DECOMP PJSM. Remove annular preventor element. 16:00 - 19:30 3.50 BOPSUP N RREP DECOMP PJSM Install new annular preventor element. 19:30 - 20:30 1.00 BOPSUP P DECOMP Test Annular preventor, witnessed by Nabors toolpusher Gene Sweat & BP rep Danny Felder 250 psi low 3500 psi high 20:30 - 21 :30 1.00 PULL P DECOMP PJSM Rig up lubricator and pull TWCV 21 :30 - 23:00 1.50 PULL P DECOMP P/U landing Jt. and M/U to Tbg hanger Pull hanger had to work it to free 127K P/U now P/U UD hanger 23:00 - 00:00 1.00 PULL P DECOMP R/U pump line and circulate hot sea water 145 bbls to fill, fliud returns clean shut down and monitor. 6/6/2005 00:00 - 00:30 0.50 PULL P DECOMP Monitor well after circulating to fill with hot sea water 145 bbls to fill 00:30 - 04:00 3.50 PULL P DECOMP Pull ESP completion double displace with 4 bbls seawater every 10 stands 04:00 - 04:30 0.50 PULL P DECOMP At 46 stands out, change spools 04:30 - 09:30 5.00 PULL P DECOMP Continue to pull ESP completion 09:30 - 11 :30 2.00 PULL P DECOMP PJSM. UD Esp Assembly, pump locked up, motor checked out OK, well stable. 11 :30 - 12:00 0.50 PULL P DECOMP Clear I clean rig floor. 12:00 - 13:00 1.00 PRFADD P DECOMP PJSM. N/D flow nipple, nipple up shooting flange & E-Line lubricator ext wI E-Line BOPE. 13:00 - 13:30 0.50 PRFADi P I DECOMP Safety meeting wI regard to running perf guns, potential I hazards & SOP regarding use of Schlumberger equipment. .13:30 - 14:30 1.00 PRFADJ P DECOMP Rig up sheaves & pick up 3 3/8" x 10' perf gun wI CCL I , I Gamma & roller assembly. 14:30 - 18:00 3.50 PRFAD9 P DECOMP RIH wI E-Line. Trouble getting past 4100'. No Good. Pick up to I 1500' & pump 40 bbls processed water wI (1) bbl EP mud lube I Printed: 6/13/2005 11: 18: 19 AM ) ) Page 2 of 3 BP EXPLORATION Op.erations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-81 MPF-81 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/4/2005 Rig Release: 6/9/2005 Rig Number: Spud Date: 5/30/2000 End: 6/9/2005 Description of Operations Nipple down Perforating Flange Nipple up Flow Nipple Level Rig & R/U to run 2-7/8" Tbg M/U BHA of Mill 3.68 0.0. PJSM TIH with 2-7/8" Tbg Continue in hole wI 2 7/8" tbg, add X/O & single in w/3 1/2" DP. Thru 41/2" liner top @ 12,231' with no bobbles. Tag top of fill I bridge @ 12,592' DPM. PJSM. M/U headpin & circulate down, thru bridge I top of fill OK wI no resistance below it. Up wt 68K, down wt 43K, circulating @ 5 bpm I 2000 psi, see returns after 90 bbls pumped. Make connections, (2), circulating down to hard tag 22' in on DP jt #23 @ 12,678' DPM. Line up & reverse circulate @ 4 bpm 11200 psi, leading wI (40) bbls mixed wI (1) bbl EP Mud Lube & chasing wI 8.3 ppg processed water. See formation sand over shaker, followed by carbolite. Reverse circulate to clean returns. POOH with 2-7/8" clean out string LID BHA RID Flow Nipple I M/U Perforating Nipple Test lubricator 3500 psi Safety meeting with all personnel for explosive charge handling and use in operation R/U 3.375 PJ HSD, 6 spf 20' perforating guns ON ROLLERS with GR/CCL I RIH same to depth and correlation with Perf log 6/21/2000 Shot gunsand perforated 12,581' -12,591'. Saw good indication gun fired. POOH Guns fired RID E-line RID Perforating flnage N/U Flow nipple PJSM M/U and service ESP Pump. M/U and service ESP Pump, making splice between discharge head and handling pump RIH ESP 2-7/8" completion monortoring well, checking cable conductivity adding clamps first 9 Jts and every second Jt after. At 28 stands (-2,700') in hole well began to flow. Montor well and it stoped, but gas breaking out of oil at surface. R/U circulating hose and circulate at 1-2 bbls minute at 1400 - 2000 psi takaing returns of oil to pits, gas started breaking out I Stoped pumping. Closed hydril and lined up to trip tank I Continued pumping 8.4 ppg Produced water around with 1800 - 2000 psi on Tbg. with 70 psi on choke Pressure droping on choke as water comes around. RUNCMP Monitor Well. Fluid lever at top of BOP stack. Well continues to "breathe". Inspect slight damaged area to ESP Cable where Hydrill element closed around it. Centralift elected to Splice Date From - To Hours Task Code NPT Phase 6/6/2005 14:30 - 18:00 3.50 PRFADD P DECOMP 18:00 - 23:30 5.50 PRFADD P DECOMP 23:30 - 00:00 0.50 PRFADD P DECOMP 6/7/2005 00:00 - 00:30 0.50 PRFADD P DECOMP 00:30 - 01 :30 1.00 PRFADD P DECOMP 01 :30 - 02:00 0.50 PRFADD P DECOMP 02:00 - 06:00 4.00 CLEAN P DECOMP 06:00 - 07:30 1.50 CLEAN P DECOMP 07:30 - 09:30 2.00 CLEAN P DECOMP 09:30 - 14:00 4.50 CLEAN P DECOMP 14:00 - 15:30 1.50 CLEAN P DECOMP 15:30 - 16:00 0.50 CLEAN P DECOMP 16:00 - 20:30 4.50 PRFADD P DECOMP 20:30 - 21 :00 0.50 RIGU P DECOMP 21 :00 - 00:00 3.00 RUNCOtvP RUNCMP 6/8/2005 00:00 - 02:00 2.00 RUNCOtvP RUNCMP 02:00 - 03:30 1.50 RUNCOtvP RUNCMP 03:30 - 04:00 0.50 RUNCOtvP RUNCMP 04:00 - 06:00 2.00 RUNCOtvP RUNCMP 06:00 - 13:00 7.00 RUNCO~ mixed in down 7". RIH wI E-Line perforating assembly. Thru 4100', OK. Hanging up, Work down to 8850'. Opt to pick back up & immerse tools in EP mud lube pill. Pick back up to 300' to lube line and tools in EP mud lube pumped RIH to and tag hard at 12,584' Con fer with Engineering and make call to perforate upper interval @ 12530' - 12540' first, then make cleanout run. Make correlation runs and perforate at 12530' - 12540' with 3-3/8" I 6spf Power Jet charges good indication shot. POOH. Guns did fire, RID E-line. Printed: 6/13/2005 11: 18: 19 AM ) --'ì ) BP EXPLORATION Operations Summary Report Page 3 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-81 MPF-81 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/4/2005 Rig Release: 6/9/2005 Rig Number: Spud Date: 5/30/2000 End: 6/9/2005 Date From.. To Hours Task Code NPT Phase Description of Operations 6/8/2005 06:00 - 13:00 7.00 RUNCOMP RUNCMP cable. Clamp off Cable and cut. Lower tubing to position Clamp below BOP Stack. Weight up fluid in Pits to 8.7lb/gal. Order additional 8.7lb/gal Brine from MI. Service and maintain Rig. Notify AOGCC that Well had to be shut-in. 13:00-15:00 2.00 RUNCOMP RUNCMP Bull Head Kill Well with 500 bbls 8.7lb/gal Brine at 5 bpm/1750 psi start. Final 5 bpm/2000 psi. Monitor Well dead and on vacuum. 15:00 - 18:00 3.00 RUNCOMP RUNCMP Splice ESP Cable. Hole check. Fluid level was calculated to be at -760'. 18:00 - 23:00 5.00 RUNCOMP RUNCMP RIH 2-7/8" ESP completion monortoring well, checking cable conductivity, adding clamps every second Jt. 23:00 - 00:00 1.00 RUNCOMP RUNCMP Make reel to reel ESP Cable splice. Hole Check 6/9/2005 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Splice cable Hole check 01 :00 - 05:00 4.00 RUNCOMP RUNCMP RIH 2-7/8" ESP Completion checking conductivity and flushing pump each 2000'. 05:00 - 07:00 2.00 RUNCOMP RUNCMP M/U Landing Jt. and Hanger Install Peneitrator P/U Wt 75K S/O Wt. 40K. Splice Connector and test. 07:00 - 07:30 0.50 RUNCOMP RUNCMP Laod Hanger. RILDS. Test at 5K.Good. Set and test TWC. Drain BOP Stack. 07:30 - 08:30 1.00 BOPSUF P RUNCMP Nipple down BOPE. 08:30 - 10:00 1.50 WHSUR P RUNCMP Nipple up Adaptor Flange and Production Tree. Test at 5K. Good. Perform final ESP Cable check. Good. 10:00 - 10:30 0.50 WHSUR P RUNCMP Pick-up Lubricator and pull TWC. Lay down same. Set BPV. 10:30 - 11 :00 0.50 WHSUR P RUNCMP Secure Production Tree and Cellar. Release Rig. Printed: 6/13/2005 11: 18: 19 AM MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 2000660 MD 12790 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~20O2 Well Name/No. MILNE PT UNIT KR F-81 Operator BP EXPLORATION (ALASKA) INC 7206 Completion Dat 8/12/2000 ~'"~' Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22959-00-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample N__go Directional Survey ~.-I~e~./~ , DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Medi.......~mt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval OH I Start Stop CH 363 12743 Case Dataset Received Number Comments 2/22/2001 0983~-~12743 9838 FINAL LIS Verification FINAL PROD-TEM/PRES 5 FINAL 12400 LDWG LIS Listing 363 LDWG LIS Listing 363 Survey Report J~z~- C_~ '1~"- ~U t ~'./,~ ~'~,/~ ~'~ FINAL 110 ~.-R~ TVD FINAL 110 ,,,.R~P/G R/Res MD FINAL 110 ~,,R]Neu/Den TVD FINAL 110 12570 CH 12743 12743 12790 12790 12790 12790 2/22/2001 2/22/2001 6/27/2000 11912 O01 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 9838~'~1S Verification Digital Data LIS Verification Paper Copy 12400-12570 363-12743 Digital Data 363-12743 Paper Report Surface to TD Paper Report 110-12790 BL, Sepia 110-12790 BL, Sepia 110-12790 BL, Sepia 110-12790 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis ~ R P.c.~.ivP. d ? Daily History Received? ~/N Formation Tops (~/N Comments: Permit to Drill 2000660 MD 12790 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. MILNE PT UNIT KR F-81 Operator BP EXPLORATION (ALASKA) INC 7206 Completion Dat 8/12/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22959-00-00 UIC N Compliance Reviewed By: Date: ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS; 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 40' r"l Exploratory 7. Unit or Property Name 3. Address r"] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 I"! Service !4. Location of well at surface 8. Well Number 1967' NSL, 3029' WEL, SEC. 06, T13N, R10E, UM MPF-81 At top of productive interval 9. Permit Number / Approval No. 200-066 3590' SNL, 4651' WEL, SEC. 12, T13N, R09E, UM 10. APl Number At effective depth 50-029-22959-00 3726' SNL, 4578' WEL, SEC. 12, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3732' SNL, 4593' WEL, SEC. 12, T13N, R09E, UM Sands ,,,, 12. Present well condition summary Total depth: measured 12790 feet Plugs (measured) true vertical 7206 feet Effective depth: measured 12680 feet Junk (measured) 03/26/02 TCO at 12680' MD true vertical 7084 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Articset (Approx.) 80' 80' Surface 4179' 10-3/4" 980 sx AS 3 - Lite, 205 sx Class 'G' 7515' 4153' Intermediate 12396' 7" 156 sx Class 'G' 12422' 6830' Production Liner 558' 4-1/2" 79 sx Class 'G' 12231' - 12789' 6641' - 7192' Perforation depth: measured 12550'-12570'RECEIVED true vertical 6969'- 6989' APR 5 2002 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12114' Packers and SSSV (type and measured depth) 7" x 4-1/2" Liner Top packer at 12231' , , 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: r-I copies of Logs and Surveys run [] Oil I-'1 Gas I-I Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true an__d correct to the best of my knowledge Signed Son~~~.-'~~.~_~._____ Title Technical Assistant Date ~..~"~ '~J"-,)--(~ ~.. ,, ..~. ~ ~,~ ~ ~, ~ Prepared ByName/Number: SondraStewman, 564-4750 Form 10-404 Rev. 06/15/88 RePort , Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/23/2002 End: 3/27/2002 Contractor Name: NABORS Rig Release: 3/27/2002 Rig Name: NABORS 4ES Rig Number: 4ES ii?il ~:i'i ~~::~[i~~~~ ~ :N:p~.~ ::ii!p~~ ': Description of Operations 3~23~2002 10:00 - 16:00 6.00 RIGU P PRE MI/RU & SAFE OUT EQUIPMENT / RIG ACCEPT ~ 1600 HRS. 03~23~2002 16:00 - 18:00 2.00 KILL P DECOMP RU/ WELL KILL EQUIPMENT & TAKE ON 9.2 PPG. BRINE 18:00 - 18:30 0.50 KILL P DECOMP RIG LUB & PULL BPV 18:30 - 19:00 0.50 KILL P DECOMP TEST LINES TO 3500 PSI. 19:00 - 22:30 3.50 KILL P DECOMP DISP~CE WELL BORE FLUIDS WITH 9.2 PPG. BRINE & MONITOR SAME. 22:30 - 23:00 0.50 KILL P DEGOMP SET ~C.& TEST TO 3500 PSI. 23:00 - 00:00 1.00 WHSURP DECOMP NIPPLE DN TREE. 3~24~2002 00:00 - 00:30 0.50 WHSUR DECOMP NIPPLE DN TREE. 00:30- 02:30 2.00 BOPSUF DECOMP NIPPLE UP BOP 02:30 - 04:30 2.00 BOPSUF DEGOMP BODY TEST & FUNCTION BOP TO 3500 PSI. (TEST WAIVED BY CHUCK SHEVE WITH AOGC.) 04:30 - 15:00 10.50 PULL DECOMP PULL HANGER TO FLOOR & ~Y DN SAME & POOH WITH ESP COMPLETION & ~Y DN SAME. 15:00 - 20:00 5.00 CLEAN COMP MU CLN-OUT ASSY. ~ 1 MULE SHOE + 18-JTS. 2-7/8" PAC PIPE & RIH ON 2-7/8" TBG. & TAG.~ 12494' 20:00 - 22:00 2.00 CLEAN COMP REVERSE CIRC. & WORK MULE SHOE A~EMPT TO BREAK THROUGH BRIDGE (NO SUCCESS) 22:00 - 00:00 2.00 CLEAN COMP POOH WITH CLN-OUT ASSY. ~1 312512002 00:00 - 02:00 2.00 CLEAN ~ COMP POOH & ~Y DN CLN-OUT ASSY.~ 1 02:00 - 06:00 4.00 CLEAN ~ COMP MU CLN-ASSY ~ 2 MILL+MTR+18-JTS. 2-3/8" & RIH 06:00- 07:00 1.00 CLEAN ~ COMP CUT DRLG. LINE 07:00 - 14:00 7.00 CLEAN ~ COMP CONT. RIH & TAG FILL ~ 12490' & DRILL DN TO 12680' & DROP BALL & SHEAR SUB & A~EMPT TO REVERSE SAND UNABLE TO ACCOMPLISH THIS DUE TO PLUGGING OF TFA. 14:00 - 20:30 6.50 CLEAN P COMP POOH & ~Y DN CLN-OUT ASSY. NO. 2 20:30 - 00:00 3.50 CLEAN P COMP MU CLN-OUT ASSY. ~ 3 MULE SHOE & 18-JTS. 2-3/8" & RIH 3~26~2002 00:00 - 01:00 1.00 CLEAN P COMP RIH W/CLN-OUT ASSY ~ 3 & TAG ~ 12490' 01:00 - 05:00 4.00 CLEAN P COMP CLN-OUT F~C SAND F/12490' TO 12680' AT REVERSE CIRC ~TES UP TO 6-BPM LOSSES OCCURED AT 13-BBL. PER 10 MINUTES OF PUMPING TIME DURING CLN-OUT 05:00 - 08:00 3.00 CHEM P COMP RIG HB&R & PUMP 40-BBL. OF SCALE INHIBITOR FOLLOWED WITH 138 BBL. OF SOURCE WATER & DISP~CE INTO FORMATION WITH 78 BBL. 9.3 BRINE. 08:00 - 12:30 4.50 CLEAN 3 COMP POOH ~YING DN 16-JTS. TBG. & MONITOR WELL BORE FLOWING SLIGHTLY. MONITOR WELL BORE AND CONTINUE FLOW SHOWED THAT FORMATION WAS BALLOONED DUE TO TREATMENT & SOURCE WATER WAS FLOWING INTO WELL BORE AFTER CONSIDE~TION FLUID WT WAS ~ISED TO 9.6 PPG. TO COMPENSATE FOR WELLBORE CONDITIONS. 12:30 - 16:30 4.00, CLEAN P DECOMP POOH & ~Y DN CLN-OUT ASSY ~ 3 16:30 - 20:30 4.00 RUNCO~ P COMP MU ESP EQUIPMENT. 20:30 - 00:00 3.50 RUNOOk~ COMP RIH WITH ESP ASSY. 3~27~2002 00:00 - 01:30 1.50 RUNCO~ P COMP RIH WITH ESP COMPLETION. 01:30 - 04:30 3.00 RUNGO~ P COMP MAKE MID-LINE SPLICE IN ESP CABLE 04:30 - 07:00 2.50 RUNCO~ COMP CONTINUE TO RIH WITH ESP COMPLETION TO SE~ING DEPTH 12114' 07:00 - 09:30 2.50 RUNCO~ COMP MU HANGE~SPICE EFT CONNECTOR & HOOK TO HANGER & ~ND HANGER & RILDS. Printed: 4/1/2002 11:16:46 AM Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: WORKOVER Start: 3/23/2002 End: 3/27/2002 Contractor Name: NABORS Rig Release: 3/27/2002 Rig Name: NABORS 4ES Rig Number: 4ES ~:: ~:!i:!~i ~ Description of Operations 3/27/2002 09:30 - 11:00 1.50 BOPSUF P COMP SET TWC & TEST & NIPPLE DN BOP 11:00 - 13:30 2.50 WHSUR P COMP NIPPLE UP TREE & TEST SAME TO 5000 & RIG LUB & PULL TVVC & SET BPV 13:30 - 14:00 0.50 DEMOB P COMP RIG DN TEST LINES & SECURE TREE AREA & RELEASE RIG @ 1400 HRS. 03/27/2002 Printed: 4/1/2002 11:16:46 AM STATE OF ALASKA , ALASK~ L AND GAS CONSERVATION COM' REPORT OF SUNDRY WELL OPERATIONS' SION 1. OperationS performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Fill Clean Out 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 40' 3. Ad~l'~ess ........................... [] Exploratory 7. Unit or prOPerty Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at Surface 8. Well Number 1967' NSL, 3029' WEL, SEC. 06, T13N, R10E, UM MPF-81 At top of productive interval 91 Permit Number / ..... Approval NO. "' 200-066 3590' SNL, 4651' WEL, SEC. 12, T13N, R09E, UM 10. APl Number At effective depth 50-029-22959-00 3727' SNL, 4581' WEL, SEC. 12, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3605' SNL, 4690' WEL, SEC. 12, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 12790 feet Plugs (measured) true vertical 7206 feet Effective depth: measured 12701 feet Junk (measured) true vertical 7118 feet Casing Length Size Cemented MD TVD Structural Conductor 70' 20" 260 sx Articset (Approx.) 70' 70' Surface 7515' Intermediate Production 12396' 7" 156 sx Class 'G' 26' - 12422' 26' - 6790' Liner 558' 4-1/2" 79 sx Class 'G' 12231' - 12789' 6641' - 7192' Perforation depth: measured 12550'- 12570' l~ ~ true vertical 6969' - 6989' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 12106' Packers and SSSV (type and measured depth) 7" x 4-1/2" Liner Top packer at 12231' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. ' ............... Representative UaJ'i~ Average Production or Iniecti~'~' aat~ .................................. OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. A~achments 16. Status of well classifications as: ~ Copies of Logs and Su~eys run ~ Daily Repeal of Well Operations ~ Oil D Gas ~ Suspended Service ]7. I hereby ce~ify that the foregoing is true and correct to the best of my knowledge Signed MichaelWilliams ~~~[~~~ Title Technical Assistant Date Form 10-404 Rev. 06/1B/RR ........ ,-~, , ,: ,. ¢..~_:,, ~plicate.. 01/12/2001 MPF-81 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FCO.: FILL CLEAN OUT SUMMARY MIRU. BOP TEST. PU 1.75" JSN. RIH. TAG AT 12016' CTMD. WASH DOWN TO 12029' AND CIRC BOTTOMS UP TO SURFACE. ATTEMPT TO START ESP WITH VARIOUS METHODS. NO SUCCESS. RU HB&R ON IA. LOAD IA WITH DEAD CRUDE. RUN ESP. ESP NOT PUMPING. POOH. RD Fluids Pumped BBLS. Description 230 2% KCL + J313 65 60/40 METHANOL 295 Total STATE OF ALASKA '- ALASKA .L AND GAS CONSERVATION COMN,. SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: r"i Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP .... 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE -- 40' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location ~f well at surface "' 8. Well Number 1967' NSL, 3029' WEL, SEC. 06, T13N, R10E, UM MPF-81 At top of productive interval 9. Permit Number / Approval No. 200-066 3590' SNL, 4651' WEL, SEC. 12, T13N, R09E, UM 10. APl Number At effective depth 50-029-22959-00 3727' SNL, 4581' WEL, SEC. 12, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3605' SNL, 4690' WEL, SEC. 12, T13N, R09E, UM Sands 12. PreSent well condition summary Total depth: measured 12790 feet Plugs (measured) true vertical 7206 feet Effective depth: measured 12701 feet Junk (measured) true vertical 7118 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Articset (Approx.) 80' 80' Surface 4179' 10-3/4" 980 sx AS 3 - Lite, 205 sx Class 'G' 7515' 4153' Intermediate 12396' 7" 156 sx Class 'G' 12422' 6830' Production Liner 558' 4-1/2" 79 sx Class 'G' 12231' - 12789' 6641' - 7192' Perforation depth: measured 12550' - 12570' true vertical 6969' - 6989' R E C E I VE D Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12114' F' E~ B Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) 7" x 4-1/2" Liner Top packer at 12231' Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. RepresentatiVe Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments .... 16. Status of 'well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~"~,,, ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate RECEIVED : ' Repo. Alaska Oit & Gas Cons. Commission Anchora,qe Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5~30~2000 Event Name: REPAIR Start: 1/25/2001 End: 1/30/2001 Contractor Name: NABORS Rig Release: 1/30/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES Fro~ ~To H~U Task Bha~ Descri pt iO n of Operation s 1/25/2001 00:00 - 08:00 8.00 MOB TRAN PRE WAIT ON AUTHORITY TO MOVE ONTO SPINE ROAD. RIG MOVE WAS DELAYED DUE TO ACCIDENTS ON SPINE ROAD. 08:00 - 17:00 9.00 MOB PRE MOVE FROM WOA A-07 TO MPU F-81 WELL. 17:00 - 20:00 3.00 RIGU PRE SET MATS & BERM. SPOT IN SUB, PITS & PIPE SHED. SPOT CAMP. 120:00 - 00:00 4.00 RIGU PRE SHUT DOWN OPERATIONS FOR TECHNICAL LIMITS MTG W/ALL PERSONNEL. HELD MTG @ MILNE PT. CAMP. 1/27/2001 00:00 - 03:00 3.00 PULL DECOMP POOH W/2 7~8" COMPLETION ASSY. 03:00 - 03:30 0.50 PULL DECOMP SWAP OUT ESP CABLE SPOOLS. 03:30 - 09:00 5.50 PULL DECOMP POOH W/2 7~8" COMPLETION ASSY. 09:00 - 11:00 2.00 PULL DECOMP INSPECT & L/D ESP. 11:00 - 13:00 2.00 CLEAN DECOMP CLEAR FLOOR. CHANGE OUT HANDLING TOOLS. INSTALL WEAR BUSHING. 13:00 - 15:30 2.50 CLEAN DECOMP P/U 3 3/4" MILL. 14 JTS 2 3/8" DP 7" CASING SCRAPER & 3 1/2" DP. TIH TO 3000'. 15:30 - 16:30 1.00 CLEAN DECOMP MIX & PUMP SWEEP. REVERSE OUT TO CLEAN UP WELLBORE. 16:30 - 18:00 1.50 CLEAN DECOMP P/U 3 1/2" DP & RIH TO 5000'. 18:00 - 19:00 1.00 CLEAN DECOMP MIX & PUMP SWEEP. REVERSE OUT TO CLEAN UP WELLBORE. 19:00 - 20:30 1.50 CLEAN DECOMP P/U 3 1/2" DP & RIH TO 7000'. 20:30 - 21:30 1.00 CLEAN DECOMP MIX & PUMP SWEEP. REVERSE OUT TO CLEAN UP WELLBORE. 21:30 - 23:00 1.50 CLEAN DECOMP P/U 3 1/2" DP 8, RIH TO 9000'. 23:00 - 00:00 1.00 CLEAN DECOMP MIX & PUMP SWEEP. REVERSE OUT TO CLEAN UP WELLBORE. 1/28/2001 00:00 - 01:30 1.50 CLEAN DECOMP P/U 31/2" DP & TRIP IN HOLE TO 11000'. 01:30 - 03:00 1.50 CLEAN DECOMP :MIX 8, PUMP SWEEP. REVERSE OUT TO CLEAN UP WELLBORE. 03:00 - 04:00 1.00 CLEAN DECOMP P/U 3 1/2" DP & TRIP IN HOLE TAG UP @ 12243'. 04:00 - 08:00 4.00 CLEAN DECOMP REVERSE & WASH DOWN BY SINGLES TO 12481'. TAGGED UP ! HARD. ROTATE & WASH DOWN TO 12500'. PUMP 20 BBL SWEEPS. 08:00 - 09:30 1.50 CLEAN DECOMP GIRO & WASH DOWN TO 12560' LOSING RETURNS 17.5 BBLS/10 MIN. 09:30 - 14:30 5.00 CLEAN DECOMP PULL UP TO 12470'. REDUCE MUD WT F/10 PPG TO 9.6 PPG IN 2 STAGES. MONITOR WELL. 14:30 - 17:00 2.50 CLEAN DECOMP WASH & REVERSE CIRCULATE FROM 12560 TO 12643'. TAGGED UP HARD. TOOK WT & WOULD'NT WASH DEEPER. 17:00 - 22:00 5.00 CLEAN DECOMP PUMPED 40 BBL SWEEP & SWEPT HOLE UNTIL CLEAN. MONITOR WELL. REDUCE MW TO 9.5 PPG. FLUID LOSS 20 BPH. PREPARE TO POOH. 22:00- 00:00 2.00 CLEAN DECOMP POOH & LDDP. 1/29/2001 00:00 - 04:30 4.50 CLEAN DECOMP POOH & LD DRILL STRING. 04:30 - 05:00 0.50 CLEAN DECOMP L/D BHA. 05:00 - 07:00 2.00 CLEAN DECOMP PULL WEAR BUSHING. R/D DP HANDLING TOOLS. 07:00 - 09:00 2.00 RUNCO~I COMP M/U SERVICE ESP. M/U CABLE TO ESP 09:00 - 14:00 5.00 RUNCO~! COMP RIH W/2 7~8" COMPLETION STRING TO 8000'. FLUSH PUMP EVERY 4000'. 14:00 - 16:30 2.50 RUNCO~4 COMP SPLICE ESP CABLE. 16:30 - 19:00 2.50 RUNCOI~4 COMP RIH W/2 7~8" COMPLETION STRING TO 12114'. FLUSHED PUMP. 19:00 - 19:30 0.50 RUNCO~4 COMP M/U LANDING JT & TBG HANGER. 19:30 o 21:00 1.50 RUNCOI~4 COMP MAKE SPLICE IN ESP CABLE. CONNECT & CHECK PENETRATOR. ,21:00 - 21:30 0.50 RUNCOI~ COMP LAND HANGER. P/U WT 90K. S.O WT 38K. RILDS. 21:30 - 22:00 0.50 RUNCOI~q COMP SET TWO VALVE TEST SAME & DRAIN STACK. 22:00 - 23:00 1.00 WHSUR COMP N/D BOPE. 23:00 - 00:00 1.00 WHSUR COMP N/U X-MAS TREE. 1/30/2001 00:00 - 00:30 0.50 WHSUR COMP PRESSURE TEST TREE & ADAPTER TO 5000 PSI, OK. Printed: 2/6/2001 2:26:39 PM Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: REPAIR Start: 1/25/2001 End: 1/30/2001 Contractor Name: NABORS Rig Release: 1/30/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES : :~ate'~:~:~ :~ro~ ~:~:: ~u-rS:: :~h~ Description of Operations 1/30/2001 00:30 - 01:30 1.00 WHSUR COMP PULL TWC VALVE & INSTALL BPV. 01:30 - 02:00 0.50 WHSUR COMP SECURE WELL. CLEAN CELLAR. RELEASE RIG @ 0200 HRS, 1-30-01. FEB Alaska Oil & Gas Cons, Gomm~ss~on AnchoFage : Printed: 2/6/2001 2:26:39 PM To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001, Porcupine Dr. Anchorage, Alaska 99501 ' MWD Formation Evaluation Logs - MPF-81, AK-MM-00054 December 15, 2000 MPF-81: ~" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22959-00 /i" x 5" TVD Resistivity and Gamma Ray Logs' 50-029-22959-00 /2" x 5" MD Neutron & Density Logs: 50-029-22959-00 J2" x 5" TVD Neutron & Density Logs: 50-029-22959-00 d' Blueline ~-1 Rolled Sepia q Blueline ~,I Rolled Sepia ~4 Blueline ,/1 Rolled Sepia Blueline Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 9, 2000 RE: MWD Formation Evaluation Logs MPF-81, AK-MM-00054 ,t~--~6, LDWG formatted Disc with verification listing. API#' 50-029-22959-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: 119]0 t Signedt~_~~ STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION COMMisSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-066 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1 ~ I 50- 029-22959-00 4. Location of well at surface ~"~.n~,.,.~; ~-;~,~:'~' 9. Unit or Lease Name 1967' NSL, 3029' WEL, SEC. 06, T13N, R10E, UM At top of productive interval ! -'~'~-'--~-, i. Milne Point Unit 3590' SNL, 4651' WEL, SEC. 12, T13N, R09E, UM At total depth i.~.~..~ ~ ,,, 10. Well Number 3605' SNL, 4690' WEL, SEC. 12, T13N, R09E, UM ~ :;~. · MPF-81 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Kuparuk River Sands KBE = 40' ADL 388235 12. Date Spudded5/30/2000 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'6/14/2000 8/12/2000 I15' water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 12790 7206 FTI 12701 7118 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, PWD, DEN, NEU 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 54.5# K-55 Surface 110' 30" 260 sx Amtic Set (Approx.) 9-5/8" 40# L-80 28' 7515' 12-1/4" 980 sx AS 3 - Lite, 205 sx Class 'G' 7" 26# L-80 26' 12422' 8-1/2" 156 sx Class 'G' 4-1/2" 12.6# L-80 12231' 12789' 6-1/8" 79 sx Class 'G' 24. Perforations open to, Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 12106' MD 'rVD MD TVD 12550' - 12570' 6969' - 6989' 12550' - 12570' 6969' - 6989' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Frac 'A' Sand, 12550' - 12570' 156,000 # of 16/20 Carbolite behind pipe Freeze Protect with 66 bbls of Dead Crude 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 18, 2000 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure I CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. , ~ CORE DATA ....... ~ ~ ~.~'"-[i~ ~,~'-""':~ ~'~ ~'! '"', Brief description of lithology, poros~t~p~~~!~s~and presence of oil, gas or water. Submit core chips. : Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Base HRZ 12186' 6610' Kuparuk D 12389' 6810' Kuparuk B 12482' 6902' Kuparuk A 12522' 6941' Kuparuk A3 12529' 6948' Kurparuk A2 12546' 6965' Kuparuk A1 12578' 6997' M iluveach 12631' 7049' OWC 12602' 7020' 3'1. List of Attachmentsl ' ~u'~nrna'ry ~f Dail'y'Drilling Reportsl Su'rve~s, Formation Inter:grity T~st ' ' ,,, 32. I hereby certify that'the foregoing is true and correct to the best of' my knowi'edge Signed TerrieHubble ~"~~ {~~ Title Technical Assistant Date MPF-81 200-066 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP AMOCO .... .-., ,,., Page 1 of 7 ;~ ',.~ -': : i ~';..:~ Operation _ Summa Report "" ....... '""" "' Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: ORIG DRILLING Start: 5/28/2000 End: 6/17/2000 Contractor Name: DOYON Rig Release: 6/17/2000 Group: RIG Rig Name: DOYON 141 Rig Number: 141 Date From, To Hours Activity Code Phase Description of Operations 5/28/2000 !00:00 - 10:00 10.00; RIGU 'PRE Finish spotting modules, pipe shed, and rock washer. 10:00 - 12:30 I 2.50 RIGU PRE R/u steam hydraulic, air, and water lines. Berm and spot cuttings to i ~ rock washer. Commission top drive with Varco rep. ~ 12:30 - 14:30 I 2.00 RIGU PRE Adjust kelly hose and clamps. Reposition "deadline" side of drilling line. 14:30 - 16:00 ; 1.50: DIVRTR PRE PJSM. N/U diverter. Base flange, spool, hydril and riser. Start taking : on mud to pits @ 1600 hrs.. High line power was online at 1600 hrs, i ., also. accepted rig at 1400 hrs. i 16:00 - 20:30 i 4.50' DIVRTR PRE N/D riser and modify same. Add 14" to riser. ~20:30 - 22:30 2.00 DIVRTR PRE : Nipple up diverter system and test same. Jeff Jones with AOGCC 'witnessed test. , ~,22:30 - 00:00 1.50~ RIGU PRE Finish commisioning top drive. Prime pumps, test mud lines, stand pipe ! ' '~and IBOP 3000 psi. Load pipe shed with 225 jts of 5" drill pipe. 5/29/2000 00:00 - 14:00 14.00 RIGU PRE Finish making up 5" drill pipe and 5" hwdp and standing back in derrick. / 14:00 - 14:30 ! 0.501RIGU PRE Service top drive. ~14:30 - 16:30 , 2.00~ RIGU 'TDRV : PRE Adjust link tilt spacing for mousehole and derrick board. Remove i ; , :, i toeboard from derrick for modification. 16:30 - 17:00 : 0.50~ DRILL SURF Caliper bha and load on rig floor. 117:00 - 17:30 ' 0.50' DRILL SURF Pre spud meeting with all hands. ~17:30 - 20:00 ! 2.50 ~ DRILL SURF Make up bha #1 and tag ice in conductor. [20:00 - 22:00 i 2.001 DRILL CIRC ;SURF Auger on cuttings tank failed. Replace tank. 122:00 - 00:00 i 2.001 DRILL TDRV SURF Attempt to make connection with top drive. Back up jaws would not ~ : · bite. Trouble shoot system. 5/30/2000 00:00 - 02:30 2.50 DRILL TDRV SURF Continue trouble shooting top drive. Found broken wire and replaced ~; i i same with spare. 02:30 - 00:00 21.501 DRILL : ;SURF Spud in at 110'. Drill and slide from 110'-1580'. Art-6.5 hrs; Ast-5.5 hrs. , ! Ran gyro to 780' until we got a clean survey with MWD. 5/31/2000 ~; 00:00 - 08:30 i 8-501 DRILL SURF Drill 1580'-2478'. Art- 1.5 Hrs; AST-4.0 Hrs. :08:30 - 09:00 ~ 0.50 DRILL .SURF Circulate hole clean. 09:00 - 10:00 ~ 1.001 DRILL SURF 8 stand wiper trip to 1700'. No problems. ;10:00 - 19:00 i 9.00i DRILL ~SURF Drill 2478'-3503'. Art-6.0 hrs; Ast-1.25 hrs. ~19:00 - 20:30 i 1.50 DRILL i SURF Circulate hole clean. Two b/u. ,20:30 - 22:30 '. 2.001 DRILL !SURF '20 stand wiper trip to 1640'. No problems tripping out or in hole. '22:30 - 00:00 1.50! DRILL ~SURF Drill 3503'-3592'. Art-.5 hrs. Ast-.75 hrs. 6/1/2000 ~ 00:00 - 19:00 : 19.00 DRILL SURF Drill 3592'-5545'(1953'). Art- 8.5 hrs;Ast-5 hrs. ~'~ 119:00 - 20:30 , 1.501 DRILL i SURF Circulate hole clean. 20:30 - 22:00 i 1.50':. DRILL I SURF 22 stand wiper trip to 3500'. No problems. ;, 22:00 - 00:00 , 2.001 DRILL . SURF Drill 5455'-5630'(175'). Art-.5 hrs; Asr-1.0 hrs. 0~' 6/2/2000 00:00 - 00:00 24.00 ~; DRILL ~SURF Drill 5630'-731 Art-8.5 hrs; Asr-8.5 hrs. 6/3/2000 ~ 00:00 - 02:00 i 2.00. DRILL :SURF Drill 7310'-7530'. Art-2 hrs. TD per geologist and ode. ' "02:00 - 04:00 ~. 2.00i DRILL SURF Circulate hole clean. : 04:00 - 10:30 ~ 6.501 DRILL I SURF 70 Stand wiper trip to 1000'. Wash and ream through tight spots from ~ ~ j 2216'-1800'. No problems in the permafrost. Trip in hole -no problems. ; 10:30 - 14:00 ' 3.501 DRILL : SURF Circulate and condition mud to run casing. i14:00- 14:30; 0.50, DRILL i i SURF Drop ESS. Pump pill. 114:30 - 18:30 i 4.00i DRILL i SURF Check well for flow and pooh to bha. i 18:30 - 20:00 . 1.50; ~ ~ ' DRILL SURF Lid bha. Bit was in good shape. ;20:00 - 22:00 2.001 CASE i SURF Clear rig floor. Make up Frank's fill up tool. Change bails and rig up ~ . ' i casing equipment '22:00 - 22:30 ' 0.50: CASE ' ' SURF ' Pre job safety meeting with all personnel. i22:30 - 00:00 . 1.50 CASE . 'SURF Run 9-5/8" 40# L-80 BTC casing. 6/4/2000 '00:00 - 06:30 [ 6.50! CASE i ., SURF · Finish running 185 jts 9-5/8" L-80 40# casing. Printed: 8/10/2000 11:09:09 AM Page 2 of 7 SU mary ration m Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date tFrom-To 6/4/2000 06:30 - 09:30 09:30 - 10:00 10:00 - 14:30 6~5~2000 6/6/2000 6/7/2000 6/8/2000 6~9~2000 14:30- 15:30 15:30- 18:00 18:00 - 19:30 19:30 - 23:00 23:00 - 00:00 00:00 - 08:00 08:00 08:30 10:30 12:00 13:00 13:30 18:30 19:30 21:00 23:00 23:30 00:00 19:00 20:30 22:00 00:00 00:00 00:00 13:00 15:00 18:30 19:30 20:00 22:30 - 08:30 - 10:30 - 12:00 - 13:00 - 13:30 - 18:30 - 19:30 - 21:00 - 23:00 - 23:30 - 00:00 - 19:00 - 20:30 - 22:00 - 00:00 - 00:00 - 00:00 - 13:00 - 15:00 - 18:30 - 19:30 - 20:00 - 22:30 - 00:00 6/10/2000 00:00 - 01:00 01:00 - 02:00 02:00 - 08:00 08:00 - 09:30 09:30 - 11:30 11:30- 12:30 MPF-81 MPF-81 ORIG DRILLING DOYON DOYON 141 3.00 CASE 0.50 CEMT 4.50 CEMT 1.00 CEMT 2.50 DIVRTR 1.50 WHSUR 3.50 BOPSUR 1.00 RIGU 8.00 BOPSUR 0.50 BOPSUR 2.00 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 5.00 DRILL 1.00 DRILL 1.50, DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 19.00 DRILL 1.50 DRILL 1.50 DRILL 2.00 DRILL 24.00 DRILL 24.00 DRILL 13.00 DRILL 2.00 DRILL 3.50 DRILL 1.00 DRILL 0.50 DRILL 2.50 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL 6.00 DRILL 1.50 DRILL 2.00 DRILL 1.00 CASE CIRC Phase SURF SURF SURF SURF SURF SURF SURF .SURF SURF SURF INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Spud Date: 5/30/2000 Start: 5/28/2000 End: 6/17/2000 Rig Release: 6/17/2000 Group: RIG Rig Number: 141 Description of Operations Rig up cement head and break circulation slow and bring rate to 8 bpm with 540 psi. No losses. Pre job safety meeting with all personnel. Test lines 3500 psi. Pump 10 bbls unweighted preflush and 75 bbls 10.5 ppg spacer. Mix and pump 980sxs Artic set Lite @ 10.7 ppg(770 bbls) and 205 sxs Clas "G" @ 15.8 ppg(42 bbls) .Follow with 20 bls water and then displace with rig pumps Toal displacement 563 bbls. Bump plug to 2500 psi. Floats held. ClP @ 1430. Rig down casing equipment and flush stack.. Clear rig floor. Nipple down diverter system and lines. Nipple up FMC Gen V wellhead and test same 1000 psi. Nipple up 13-5/8" 5M Bop, choke line, kill lines and bell nipple. Level derrick Test bop's. Test all rams, choke, kill lines 250/5000 psi. Test annular 250/3500 psi. HCR failed -replaced and retested-ok. Pull test plug and install wear ring. Make up 8-1/2 directional bha and test same. Trip in hole 2500' picking up 5" drill pipe. Slip and cut drill line Adjust brakes. Finish tripping in hole to float collar. Pressure test casing 3500 psi for 30 minutes-ok. Repair leak on gooseneck. Drill float collar, cement, float shoe and 30 ft new flormation to 7560'. Art- .5 hrs. Ckirculate bottoms. Mud wt in and out = 8.4 ppg. Perform FIT with 8.4 ppg mud and 675 psi. EMW=I 1.5 ppg. Drill and slide as needed 7560'-9189'. Art-11.0 hrs; Ast-3.5 hrs. Pump sweeps as needed. Pump sweep and circulate hole clean. Monitor well and pump pill. 19 stand wiper trip to casing shoe. No problems. Tih. Wash and ream last stand to bottom -no problems. Drill 9189'-9430'. Art-1.5 hrs Drill 9430%10,870'. Art-5.75 hrs; Ast-8.75 hrs. Drill 10,875'-11,875' per directional plan. Art-4 hrs; Ast-14.5 hrs. Drill to 12,430'. Art-7 hrs; Ast-3 hrs. TD per geologist. Pump 50 bbls weighted fiber hi-vis sweep. No increase in cuttings when sweep reached surface. Monitor well. Pump pill. Wiper trip to casing shoe. No problems Good hole fill. Slip and cut drill line. Circulate bottoms up at shoe. No increase in cuttings. Trip in hole. Wash and ream last stand to bottom. No problems tih. Drill to 12,435'. Rat hole for casing. Pump 50 bbl hi-vis weighted fiber sweep. Circulate hole clean at 90 rpms, 550 gpm, 2500 psi. No excessive amount of cuttings came back with sweep. Finish circulating hole clean. Drop ESS and spot 100 bbls of conditioned mud on bottom. Pull 20 stands wet. Pump dry job. POOh to BHA. L/D 5 hwdp, jars, 3 dc, MWD, stab, motor and bit. PJSM. Pull wear ring, set test plug. Change top rams to 7" and test doors 1000 psi. Rig up Frank's fill up tool. Change bails and rig up casing equipment. Printed: 8/10/2000 11:09:09 AM oPerations summary Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Event Name: ORIG DRILLING Contractor Name: DOYON Rig Name: DOYON 141 6/10/2000 11:30- 12:30 1.00 CASE INT1 12:30 - 13:00 0.50 CASE INT1 13:00- 19:00 6.00 CASE INT1 Start: 5/28/2000 Rig Release: 6/17/2000 Rig Number: 141 Spud Date: 5/30/2000 End: 6/17/2000 Group: RIG Description of Operations Pre job safety meeting with all personnel Run 7" 26# L-80 BTC Mod casing to 7500'. 6/11/2000 6/12/2000 19:00 - 20:00 1.00 CASE INT1 20:00- 00:00 4.00 CASE INT1 00:00 - 00:30 0.50 CASE INT1 00:30 - 03:00 2.50 CASE INT1 03:00 - 05:30 2.50 ! CASE INT1 05:30 - 07:00 1.50 CASE INT1 07:00 - 09:00 2.00 CASE INT1 09:00 - 10:30 1.50 BOPSUR INT1 10:30- 14:00 3.50 BOPSUR INT1 14:00 - 14:30 0.50 BOPSUR INT1 14:30 - 20:00 5.50 RIGD INT1 20:00 - 21:00 1.00 RIGD DPSY INT1 21:00 - 00:00 3.00 RIGD INT1 00:00 - 03:00 3.00 RIGD INT1 03:00 - 04:00 1.00 RIGD INT1 04:00 - 07:00 3.00 DRILL PROD1 07:00- 10:00 3.00 DRILL iPROD1 10:00 - 10:30 0.50 DRILL PROD1 10:30 - 11:30 1.00 DRILL PROD1 11:30-00:00 12.50 DRILL PROD1 6/13/2000 00:00 - 03:00 3.00 DRILL PROD1 Circulate bottoms up at the casing shoe with 70 spm(294 gpm), 800 psi. 150k up/ 95 K down. Continue running in hole with 7" casing. Total of 304 jts run, landed casing at 12,422'. No problems. Lay down Frank's fill up tool and make up cement head with plugs. Break circulation slow and increase rate from 3 bpm to 7 bpm with 1100 psi. Full returns with no losses. Reciprocate casing 280k up and 110K down. PJSM. test lines 3500 psi. Pump 15 bbls pre-flush and 50 bbls weighted spacer. Mix and pump 32 bbls 15.8 ppg cement. Drop top plug and pump 10 bbls water. Dsplace with rig pumps. Bump plug 3000 psi. Floats held. Reciprocated casing entire job. Full returns. Lay down landing jt, clear rig floor and lay down casing equipment. Set 7" pack off and test same 5000 psi for 10 minutes-ok. Install variable rams(3-1/2" x 6") in the top and 3-1/2" in the bottom. Bop test. Test annular 250/3500 psi. test choe manifold, kill line, all rams and valves 250/5000 psi. John spaulding with aogcc waived i witnessing test. Pull test plug and install wear ring. PJSM. Install mouse hole and lay down 5" drill pipe from derrick. Repair coupling on p~pe skate. Continue laying down drill pipe from derrick Finish laying down 5" drill pipe from derrick. Rig up 3-1/2" handling tools and load pipe shed with bha and drill pipe. Make up 6-1/8" bit, 4-3/4" motor, MWD/LWD, 3 nmag dc, jars. Strap drill pipe. Change saver sub on top drive to 3-1/2" IF Service top drive. Test MWD-OK. Pick up 15 jts and stand back in derrick. Pick up, drift, aand rattle each jt of 3-1/2" drill pipe and trip in hole. Break circulation every 1000'. Finished picking up 3-1/2" drill pipe and rattle each joint. Break circulation every 1000'. 03:00 - 04:30 1.50 DRILL PROD1 Logged with Sperry Sun LWD and tied into previous logs. Tagged float collar at 12340'. 04:30 - 05:00 0.50 DRILL PROD1 Tested 7" casing with rig pumps to 3500 psi for 30 minutes. Good test. 05:00 - 07:30 2.50 DRILL ; PROD1 Drilled float collar and cement to 12362'. 07:30 - 09:30 2.00 DRILL ClRC PROD1 Removed kelly hose and tighten unions due to leaks. Tested kelly hose to 4500 psi OK. 09:30 - 11:00 1.50 DRILL PROD1 Drilled cement and shoe and cleaned out old hole to 12435'. 11:00-12:30 1.50 DRILL PROD1 Displace hole with 11.5 ppg mud. 12:30 - 13:30 1.00 DRILL PROD1 Rotary drilled new formation from 12435'-12465'. Printed: 8/10/2000 11:09:09 AM Legal Well Name: MPF-81 Common Well Name: MPF-81 Event Name: ORIG DRILLING Contractor Name: DOYON Rig Name: DOYON 141 Date From,To Hours ActiVin]Code PhaSe 6/13/2000 12:30- 13:30 1.00 DRILL PROD1 13:30- 14:30 1.00 DRILL PROD1 14:30- 15:00 0.50 DRILL PROD1 15:00- 18:00 3.00~ DRILL PROD1 18:00- 18:30 0.50 DRILL PROD1 18:30 - 19:00 0.50 DRILL TDRV PROD1 19:00 - 00:00 5.00 DRILL PROD1 00:00 - DRILL PROD1 Spud Date: 5/30/2000 Start: 5/28/2000 End: 6/17/2000 Rig Release: 6/17/2000 Group: RIG Rig Number: 141 ...... Description of Operations Circulated and conditioned hole for LOT. Rigged up Dowell pump truck and tested lines to 5000 psi. Performed LOT. Pumped 5 bbls at 1/2 bpm and formation broke back at 3000 psi. Shut down pumps and held pressure to 15 minutes. Pressure began to stabilize around 2000 psi. Bled off pressure and recovered 4 bbls of mud. Lost I bbl to formation. LOT: 11.5 ppg mud, shoe depth 6843', leak off pressure 3000 psi, EMW 19.9 ppg. Rotary drill and survey from 12465'-12509'. Service rig - Top drive. Replaced lines on Top Drive. Rotary drill and survey from 12509'-12681'. .......................... 06:00 hrs Update ............................. 00:00-04:00 Rotary drill and survey from 12681'-12790'. Geologist called TD of hole section. 04:00-05:30 Pumped high vis weighted pill and circulated and conditioned hole for short trip. 05:30-06:00 Making short to shoe at 12422'. ~/14/2000 00:00 - 04:00 4.00 DRILL PROD1 04:00 - 06:30 2.50 DRILL PROD1 06:30 - 07:00 0.50 DRILL PROD1 07:00- 09:00 2.00 DRILL PROD1 09:00- 09:30 0.50 DRILL PROD1 09:30- 14:00 4.50 DRILL PROD1 14:00 - 14:30 0.50 DRILL PROD1 14:30- 16:30 2.00 DRILL PROD1 16:30- 19:00 2.50 DRILL PROD1 Rotary drill and survey from 12681'-12790'. Geologist called TD of hole section. Pumped 35 bbl high vis weighted pill and circulated hole clean. Check flow-negative. Short tripped to 7" casing shoe at 12422' and back to bottom with no problems. Pick up weight 190K slack off weight 110K. Pumped another 35 bbl high vis weighted sweep and circulated hole clean. Dropped ESS survey tool and pumped down hole. Check flow-negative. Pulled out of hole to shoe. Pumped dry job. Continued pulling out of hole to 3500'. Lube rig and service top drive. Pulled out of hole standing 3-1/2" drill pipe in derrick. Removed source from LWD and downloaded same. Stood back HWDP in derrick and laid down remainder of BHA. Recovered Sperry ESS tool Printed: 8/10/2000 11:09:09 AM O Page 5 of 7 operations summary : Report Legal Well Name: MPF-81 Common Well Name: MPF-81 Event Name: ORIG DRILLING Contractor Name: DOYON Rig Name: DOYON 141 Date From-To [Hours ACtivity~ PhaSe 6/14/2000 16:30- 19:00 2.50 DRILL PROD1 Start: 5/28/2000 Rig Release: 6/17/2000 Rig Number: 141 Spud Date: 5/30/2000 End: 6/17/2000 Group: RIG Description of Operations and survey indicates that instrumentl did not reach bottom. 19:00- 19:30 0.50 CASE PROD1 Rigged up elevators and casing tongs for 4-1/2" liner job. 19:30 - 20:00 0.50 CASE PROD1 Conducted safety meeting with all personnel and discussed liner running procedures. 20:00 - 22:00 2.00 CASE PROD1 Ran in hole with with float equipment, 13 jts (559') of 4-1/2" 12.6# L-80 IBT modified liner and Baker HMC liner hanger and ZXP packer. Broke circulation after picking up liner hanger and circulated liner volume. Liner weight 5K. 22:00 - 00:00 2.00 CASE PROD1 Tripped in hole with 4-1/2" liner on 3-1/2" drill pipe filling every row to 4229'. 00:00 - CASE PROD1 ........................... 05:00 HR UPDATE ......................... 00:00-06:00 Finished running in hole with 4-1/2" liner to shoe at 12422'. 6/15/2000 00:00 - 05:30 5.50 CASE 05:30 - 06:30 1.00~ CASE ;PROD1 PROD1 Finished running in hole with 4-1/2" liner to shoe at 12422'. Made up Baker plug dropping/cementing manifold and laid on skate. Broke circulation and circulated complete liner and drill pipe volume. 06:30 - 08:00 1.50 CASE PROD1 Ran in hole with with 4-1/5" liner to bottom at 12790' with no problems. Good hole. 175K pick up 103K slack off. 08:00 - 12:30 4.50 CASE PROD1 Broke circulation at I bpm at 750 psi. Slowly increased pumps to 4 bpm at 2060 psi. Worked pipe in 20' stroke while circulating. 170K pick up 106 K slack off. Circulated 3 complete annulus volumes. No mud losses. 12:30 - 13:30 1.00 CEMT PROD1 Rigged up Dowell cementing equipment. Held pre-job safety meeting. Pumped 5 bbls water, tested lines to 4500 psi and pumped additional 5 bbls water. Pumped 50 bbls of B45 viscosified spacer weighted to 12.0 ppg. Mixed and pumped 79 sxs (16.3 bbls) of Class G cement with .27% D065 (disperant)+.25% D167 (Fluid Loss)+.1 gal/sx D047(antifoam)+ .27% D800 retarder. Flushed cement lines. 13:30 - 14:30 1.00 CEMT PROD1 Pumped out drill pipe dart with 13bbls of 11.7 ppg brine and finished displacing cement with 11.5 ppg mud. Displaced cement at 4 to 5 bpm at 2400 psi. Slowed down and witnessed dart latch in liner wiper plug. Bumped plug at 1345 hrs with 3500 psi. Bled off pressure and switched to Dowell and pressured up on string to 4500 psi and set liner hanger and packer. Bled off pressure and floats held. Plug bumped with 96% efficiency. Released from hanger and sat 50K down on ZXP packer. 14:30- 15:30 1.00 CEMT 15:30- 17:00 1.50 CEMT PROD1 PROD1 Reversed out with full returns. Reversed out 6 bbls of cement and 50 bbls of spacer and 10 bbls of water. Reversed two complete drill pipe volume. Circulated out the long way to assure the ID of drill pipe is clean. Printed: 8/10/2000 11:09:09 AM Legal Well Name: MPF-81 Common Well Name: MPF-81 Event Name: ORIG DRILLING Contractor Name: DOYON Rig Name: DOYON 141 Date From. _ ~ I ~-'T° Hours Activi~ CodeI Phase 6/15/2000 15:30 - 17:00 1.50 CEMT PROD1 17:00 - 18:00 1.00 CEMT PROD1 18:00- 18:30 0.50 CEMT PROD1 Start: 5/28/2000 Rig Release: 6/17/2000 Rig Number: 141 Spud Date: 5/30/2000 End: 6/17/2000 Group: RIG Description of Operations Check flow-negative. Pulled 3 stands. Broke out cementing manifold and laid out. Conducted PJSM on cutting drill line. 18:30 - 19:30 1.00 CEMT PROD1 Cut and slip 60' of drill line. 19:30 - 00:00 4.50 CEMT PROD1 Pulled out of hole and stood 50 stands of 3-1/2" drill pipe in the derrick and continued to lay down 3-1/2" drill pipe to 7335'. 6/16/2000 00:00 - CEMT PROD1 00:00- 03:00 3.00 CEMT 03:00 - 03:30 0.50 RUNCOM 03:30 - 04:00 0.50 RUNCOM 04:00 - 06:00 2.00 RUNCOM 06:00 - 06:30 0.50 RUNCOM 06:30 - 14:30 8.00 RUNCOM 14:30- 15:00 0.50 RUNCOM 15:00- 16:00 1.00 RUNCOM 16:00 - 16:30 0.50 RUNCOM PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 .......................... 06:00 Update ................................ 00:00-03:00 Finished laying down 3-1/2" drill pipe and Baker setting tool. 03:00-03:30 Pulled wear bushing. ~03:30-04:00 Held pre-job safety meeting on running 4-1/2" frac string. Rigged up casing tools to run string. 04:00-06:00 Made up 4-1/2" wireline re-entry guide and began running 4-1/2" 12.6# L-80 IBC Mod frac string. Finished laying down 3-1/2" drill pipe and Baker setting tool. Pulled wear bushing. Held pre-job safety meeting on running 4-1/2" frac string. Rigged up casing tools to run string. Made up 4-1/2" wireline re-entry guide and ran in hole with 4-1/2" 12.6# L-80 IBC Mod tubing. Held PJSM and performed rig service on drawworks and top drive. Finished running 301 jts of 4-1/2" 12.6# L-80 IBC Mod tubing to top of 4-1/2" liner at 12230'. Changed out bails on top drive. Circulated bottoms up. Closed top pipe rams and pressure tested casing and liner lap with i3500 psi for 30 minutes. Good test. Recorded test on chart recorder. 16:30 - 19:30 3.00 RUNCOM 19:30- 21:O0 1.50 RUNCOM PROD1 PROD1 Displace 11.5 ppg mud with seawater. Reciprocated pipe during displacement. Displaced wellbore with 2 complete hole volumes. Laid down 3 joints of tubing and made up hanger. Landed hanger. Run in lock down screws. Installed TWC. Pressure tested TWC with 300 psi. Printed: 8/10/2000 11:09:09 AM Page 7 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/16/2000 MPF-81 MPF-81 ORIG DRILLING DOYON DOYON 141 FrOm-To Hours Activity Code Phase 21:00 - 22:30 1.50 BOPSUR PROD1 22:30 - 00:00 1.50 WHSUR PROD1 00:00 - WHSUR PROD1 6/17/2000 00:00 - 01:00 1.00, WHSUR PROD1 01:00 - 02:30 1.50 DEMOB PROD1 02:30 - 03:00 0.50 WHSUR PROD1 03:00 - 05:00 2.00 DEMOB PROD1 Spud Date: 5/30/2000 Start: 5/28/2000 End: 6/17/2000 Rig Release: 6/17/2000 Group: RIG Rig Number: 141 Description of Operations Nipple down BOPs. Nipple up tubing head adapter and 4-1/16" 5000# tree. Test adapter flange and tree to 5000 psi. .............................. 06:00 hfs Update ......................... 00:00-01:00 Pull TWC and rigged up to displace. 01:00-02:30 Reversed 90 bbls of diesel down annulus for freeze protection to 2200' TVD. U-tubed diesel. 02:30-03:00 Set BPV and secured tree. Clean up Cellar. 03:00 05:00 Clean pits and suck out cellar with super sucker. RIG RELEASED 05:00 HRS. 05:00-06:00 Move rig. Pulled TWC and rigged up to freeze protect. Reversed 90 bbls of diesel down annulus for freeze protection to 2200' TVD. U-tubed diesel. Install BPV in tubing hanger and secure tree. Clean up cellar. Clean mud tanks and suck out cellar with super sucker. RIG RELEASED 05:00 HRS 06/17/2000. Printed: 8/10/2000 11:09:09 AM Legal Name: MPF-81 Common Name: MPF-81 6/4/2000 FIT 7,515.0 (ft) 4,165.0 (ft) 9.10 (ppg) 530 (psi) 2,499 (psi) 11.55 (ppg) 6/5/2000 FIT 7,515.0 (ft) 4,165.0 (ft) 8.40 (ppg) 675 (psi) 2,492 (psi) 11.52 (ppg) 6/13/2000 LOT 12,465.0 (ft) 6,843.0 (ft) 11.50 (ppg) 3,000 (psi) 7,088 (psi) 19.94 (ppg) · · : .. . . · ,. Printed: 6/24/2000 11:16:57 AM Well Name: MPF-81 Field: Milne Point Unit / Kuparuk River Sands APl: 50-029-22959-00 Permit: 200-066 NON-RIG WORK SUMMARY 06~20~00 Arrived location Held pre-job safety meeting, RIH with Gyro. Did not tag bottom with the Gyro do to the difficulty slickline had with there gauge run. Started Gyro @ 12,550' elm. POH completed Gyro to surface. RU 20' 3-3/8" gun, pressure tested lubricator to 2500 psi. start down hole tagged up in liner approx. 12,505' made several attempts to work gun through heavy brine unable to work gun past 12,508' elmd. POH RU smaller tools 1-11/16 with 2-1/8" rollers RIH to 12,604' elmd. Able to log the perf interval. Tied into the MDW 6/14/00 continue POH with GR/CCL to 6500' md. POH lay down equip, for night. 06/21/00 Arrived location Held pre-job safety meeting , Pressure tested lubricator 3000 psi. start down hole with gamma ray and 2.5" 6 spf-BH charge 20' gun dropped through perf intervals logged up and tied into collars and liner hanger from GR/CCL log 6/20/00, correlated perf intervals to the GR/CCL and made a shift down of 2', CCL to top shot was 3.5' spotted CCL at 12,547.5 fired gun, all shots fired from 12,550' to 12,570' log off, tubing pressure increased to 500 psi. and continued to climb slowly. POH RD perf gun, confirm all shots fired. RU gauges (sapphire) quartz gauges were not available. RIH to mid perfs at 12,558' elmd. Starting pressure was 3967 psi. formation slightly overpressured while tools were run in the hole. Pressures starting to drop off. Fast at first but leveled off at 1 psi. for every 8 minutes, Stayed on bottom for one hour. Ending pressure was 3954 psi. POH RD SWS. 06/23/00 MIRU pressure test equipment. RIH with jet nozzle. Dry tag TD at 12,640' ctmd. Jet wash perfs taking returns up 4 Y2" tubing to flow-back tank. Circulate bottoms up. Pump 17 bbls. of 5% HCL acid. Wash perfs. Attempt to displace acid to perfs but could not establish adequate injection rate (0.4 bpm @ 2300 psig). Lay remaining acid across perfs. POH. MU Baker tools and SWS guns. RIH with 20' gun. ( 3 3/8", 6 SPF, random orientation) Tie in with tubing tail, adjust counter. Position and shoot gun 1. (12550- 12570). Perform injectivity test at 0.5 b/m 350 psi. 1 b/m 1600 psi and building. POH. RDMO 06/24/00 After the first perforation run, we could not pump into the well with 4000 psi. CT was called out to clean out the heavy weight brine out across the perforation that was left by the drilling rig. The second perforation run was made with the CT and perforation where still tight. A 96 bbl water injectivity test using was done to ensure that the perforation were open enough for the data frac. A 200 bbl data frac was pumped, but we nearly screen out on gel when the leading edge hit the perfs; like we were sweeping wellbore debris into the perfs. Rate was dropped to 15 bpm to prevent tripping the pumps out. Pressure was breaking back - increase rate with pressure drop. Got to 36 bpm. Since near the end of the treatment held at 36 bpm to get steady rate for NWFP calcs. We did not slow the rate down as planned before the gel hit the perforation due to high STP. Since steady rate was not achieved, a second data frac was performed. The second data frac was pumped as plan. Again we didn't slow down the rate for wellbore fluids to leak off to ensure that we didn't repeat the same as the first data. MPF-81, Non Rig Work Summary Page 2 The data frac information was sent to town for analysis and compared with slope results. The frac was re-designed. The proppant schedule ramped was ramped based The 1, 4 and 7 ppg stages were a modified ramp to flatten the ramp effect. When the 7 ppg stage was on perfs, thing were going smooth so we decided to pump excess proppant. When 137 bbls of the so called 11 ppg proppant was through the perforations, a wellbore screen out occurred. We were 34 bbls short of finishing the treatment O6~27~OO MIRU. RIH reversing out frac sand. Find small amount of sand in high angle portion of hole at 8800' MD. Pumping at 1.3-1.5 b/m full returns. Tag up at 11240. Small bridge. Break through. See another small bridge at top of perforation (12250). Continue to reverse out to solid TD of 12628 ctmd. Make three passes across perfs to ensure all sand out. Pull into tailpipe. Perform flow check. Well appears to be flowing. Pump down coil while POH with well flowing. OOH. Monitor well. Average flow rate 2500 b/d. RDMO. Turn well over to APC to flowback. Legal Well Name: MPF-81 :, :...; Common Well Name: MPF-81 Spud Date: 5/30/2000 Event Name: COMPLETION StaK: 8/8/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES 8/8/2000 06:00 - 09:30 3.50 MOB COMP Move on, spot rig & berm up around rig.(moved from F-53 to F 81. 09:30 - 11:30 2.00 MOB COMP Raise & scope derrick. UD Beaver slide. 11:30 - 13:00 1.50 MOB COMP Erect ~ntainment. Spot tiger tank. Hook up lines. ACCEPT RIG ~ 1300 HRS 8-8-00. 13:00 - 15:00 2.00 MOB COMP ~U mud lines. Take on fluid. 15:00 - 17:00 2.00 MOB COMP ~U HCR & lines in ~llar. ~U & pull BPV. SITP 800 psi. 17:00 - 18:00 1.00 MOB COMP Pressure test lines to 3500 psi. 18:00 - 19:00 1.00 MOB COMP ~U remote control line to tree. 19:00 - 00:00 5.00 MOB COMP Reveme circulate w/KCL ~r & Hi-Vis pills to clean sand out of tbg. 8/9/2000 00:00 - 03:00 3.00' CLaN COMP Reveme cumulate ~ 4 bpm w/kCI ~r. 03:00 - 08:30 5.50 CLaN COMP ~U slickline eq. & RIH w/2.5" bailer, stopped ~ 2846' Recovered bailer full of frac sd. 08:30 - 12:30 4.00 CLEAN COMP Pump 50 bbl sweep. Reveme out frac sd. Waited on fluid 2 hrs. 12:30 - 17:00 4.50 CLaN COMP Pump 10.2¢ kill fluid w/50 bbl hi-vis sweep ahead. 17:00 - 18:00 1.00 CLaN COMP Obsewe well. Well dead & on slight vacum. Circ & record loss rate of 72 BPH. 18:00 - 23:30 5.50 CLEAN COMP Wait on 9.~ brine ~r. Load tbg in pipe shed. Strap & rabbit same. 23:30 - 00:00 0.50 CLEAN COMP Redu~ MW to 1~ by diluting w/9.~ brine ~r. - 0.00 CLEAN COMP 8/10/2000 00:00 - 02:00 2.00 CLEAN COMP Decrease MW from 10.1+ to 10.0 with dilution of 9.9 mud 02:00 - 03:00 1.00 CLEAN COMP Obsewe well. Well dead. Hole staying full. Check cim fluid loss. 1 bpm loss at 5 bpm circ rate. 03:00 - 05:00 2.00 CLaN COMP Mix and pump 50 bbl sweep. At 5 bpm 800 psi, losing 65 bfph. Sweep pmdu~d no sand. Hole stayed full. 05:00 - 08:30 3.50 CLaN COMP RU slickline unit. RIH w/2 1/2" biler, tbg clear to 12,544' WLM. RD slickline unit. 08:30 - 09:00 0.50 BOPSU~ COMP Install and test ~C to 2500 psi. 09:00 - 10:00 1.00 BOPSUR COMP ND xmas tree. 10:00 - 13:00 3.00 BOPSUR COMP NU BOPE 13:00 - 16:30 3.50 BOPSUR COMP Pressure testing BOPE. LP 250 psi, HP 3500 psi. Annular 2500 psi. Test witnessed by Jeff Jones AOGCC. 16:30 - 18:30 2.00 BOPSUF COMP Lubri~te out ~C RU and FP 9 5/8"X7" annulus w/22 bbl METH and 45 bbls dead crude. 18:30 - 20:00 1.50 WHSUR COMP PU landing jt. BO hanger bolts and pull hanger. Pull ~. w/110K. 20:00 - 21:00 1.00 PULL COMP Clear floor. POOH & LD 4 1/2 frac string. 21:00 - 21:30 0.50 PULL COMP Secure ~llar rig ama for high winds. 21:30 - 22:30 1.00 PULL COMP POOH and LD 4 1/2 frac string. 22:30 - 23:00 0.50 PULL COMP Tie back ESP ~ble sheave and secure due to high winds. 23:00 - 00:00 1.00 PULL COMP POOH and LD 4 1/2 frac string 8/11/2000 00:00 - 07:00 7.00 PULL COMP POOH & MD 4 1/2" frac string. 07:00 - 08:00 1.00 PULL COMP Rig down 4 1/2" tbg handling equip. Clear off drill floor. 08:00 - 09:00 1.00 RUNCO~ COMP Load remaining 2 W8" tbg in pipe shed. P/U GLMs & pups etc. 09:00 - 09:30 0.50 RUNCO~ COMP ~U to run ~mpletion string. 09:30 - 00:00 14.50 RUNCO~I COMP Run ESP & 2 7/8" tbg string. (See completion summaw sheet for details) 8/12/2000 00:00 - 03:30 3.50 RUNCO~I COMP Run completion assy. ran 385 jts tbg. Set ~ 12106 ff. (see tbg summaw repo~ for details) 03:30 - 04:00 0.50 RUNCO~ COMP Make up landing jt& hanger, dross penetrator. 04:00 - 06:00 2.00' RUNCOk COMP Make up & spli~ esp ~ble to connector. 06:00 - 06:30 0.50 RUNCO~ COMP Land & est tbg hanger to 2500 psi, OK. 06:30 - 08:00 1.50 BOPSUF COMP Drain & N/D BOP stack. 08:00 - 09:00 1.00 WHSUR COMP N/U & adapter flange & X-mas tree. 09:00 - 09:30 0.50 WHSUR COMP Test hanger seals & tree body to 5000 psi, OK. Final elect check on Printed: 8/2412000 1:07:41 PM Legal Well Name: MPF-81 Common Well Name: MPF-81 Spud Date: 5~30~2000 Event Name: COMPLETION Start: 8~8~2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES ": '. '~t~:i:.::i !(~&~;~!~:~ !i .~i: DeSCriptiOn of OPerations ,., 8/12/2000 09:00 - 09:30 0.50 WHSUR COMP ESP equip. 09:30 - 10:00 0.50 WHSUR COMP Secure well & clean pits. RELEASR RIG @ 1000 HRS 8-12-00. , . · ::, · .. i . f ...- ...: , ..... -,,, · .: Printed: 8/24/2000 1:07:41 PM North Slope Alaska Alaska State Plane 4 Milne Point MPF MPF-81 Surveyed: 15 June, 1900 ORIGINAL SURVEY REPORT 19 June, 2000 Your Ref: AP1-500292295900 Surface Coordinates: 6035417.63 N, 541534.68 E (70° 30' 27.6603" N, 149° 39' 36.6300" W) Kelly Bushing: 40'OOft above Mean Sea Level DRILLING SERVICES S.rvoy Ref: svy9104 AIIA! J.l~l I~*r{34~I Sperry-Sun Drifting Services Survey Report for MPF-81 Your Ref: API-500292295900 Surveyed: 15 June, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 635.00 2.500 216.800 594.91 634.91 760.87 5.224 214.933 720.49 760.49 854.35 5.799 217.049 813.53 853.53 942.34 8.584 219.882 900.82 940.82 1036.28 11.893 220.966 993.26 1033,26 1127.~4 14.043 227.477 1082,38 1122.38 1220.99 16.323 226.868 1172.37 1212.37 1312.77 18.279 217.247 1260.01 1300.01 1403.51 20.393 212.883 1345.63 1385.63 1494.15 19.558 212.453 1430.82 1470.82 1591.94 21.701 214,882 1522.34 1562.34 1683.12 23.523 217.949 1606.51 1646.51 1777.25 24.263 218.915 1692.57 1732.57 1868.58 22.276 218.414 1776.47 1816.47 1961.93 25.830 220.522 1861.70 1901.70 2052.76 32.120 220.849 1941.12 1981.12 2149.39 37.538 219.919 2020.41 2060.41 2241.76 42.612 219.404 2091.07 2131.07 2334.99 47.079 218.807 2157.15 2197.15 2427.83 49.935 219.245 2218.66 2258.66 2519.72 50.192 219.986 2277.65 2317.65 2614.14 50.568 220.441 2337.86 2377.86 2706.39 55.224 218.700 2393.49 2433.49 2797.78 59.484 218.655 2442,78 2482.78 2890.52 63.118 218.922 2487.31 2527.31 4,77 S 0.66 E 11.67 S 4,26 W 18.93 S 9,55 W 27.52 S 16.44W 40.21S 27.28W 54.83 S 41.64W 71.43 S 59,54W 91.72 S 77,67W 116.32 S 94,87W 142.39 S 111.59W 171.04 S 130,71W 199.22 S 151,55W 229.08 S 175,25W 257.24 S 197,79W 286.58 S 222,01W 319.92 S 250.69W 361.96 S 286.41W 407.73 S 324.34W 458.74 S 365,78W 512.76 S 409.57W 567.03 S 454.50W 622.57 S 501,46W 679.29 S 548.28W 739.35 S 596.36W 802.74 S 647,31W 6035412.86 N 541535.37 E 6035405.94 N 541530.48 E 6035398.65 N 541525.24 E 6035390.02 N 541518.40 E 6035377,27 N 541507.62 E 6035362.57 N 541493.35 E 6035345.86 N 541475.54 E 6035325.48 N 541457.52 E 6035300.78 N 541440.46 E 6035274.62 N 541423.89 E 6035245.87 N 541404.93 E 6035217.57 N 541384.25 E 6035187.58 N 541360.72 E 6035159.28 N 541338.33 E 6035129.82 N 541314.28 E 6035096.32 N 541285.79 E 6035054.08 N 541250.30 E 6035008.09 N 541212.63 E 6034956.85 N 541171.47 E 6034902.59 N 541127.98 E 6034848.07 N 541083.36 E 6034792.26 N 541036,71 E 6034735.29 N 540990.21 E 6034674.96 N 540942.46 E 6034611.28 N 540891.86 E Dogleg Rate (°/100ft) 2.166 0,652 3.190 3.528 2.839 2.451 3,770 2.820 0.935 2.359 2.380 0.889 2.186 3.916 6.927 5.634 5.505 4.813 3.096 0.679 0.544 5.266 4.662 3.927 Alaska State Plane 4 Milne Point MPF Vertical Section (fi) Comment 2.50 10.68 19.36 30.13 46.56 66.93 91.30 118.17 147,06 176.49 209.42 243.38 280.62 315.90 353.21 396.51 450.77 509.10 573.47 641.54 710.67 782.17 854.31 929.54 1009.10 7imon lo C~yro(lala Ill IFI'I 19 June, 2000-13:44 -2- Conllnl/od... DrlllOuo.~t 1.05.040 Sperry-Sun Drilling Services Survey Report for MPF-81 Your Ref: API-500292295900 Surveyed: 15 June, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2985.41 63.764 218.434 2529,74 2569.74 3078.95 64.069 218.163 2570.87 2610.87 3171,70 66.174 218.272 2609.88 2649,88 3264.50 67.923 218.331 2645.99 2685.99 3357.32 68.509 218.460 2680.51 2720.51 3448.95 68.827 219.364 2713.84 2753.84 3541.43 70.530 218.517 2745,96 2785.96 3634.06 71.754 217.896 2775.90 2815.90 3727.93 71.606 217.505 2805.41 2845.41 3820.32 71.539 216.451 2834.61 2874.61 3913.62 71.784 216.680 2863.97 2903.97 4006.10 70.045 215.851 2894.21 2934.21 4098.68 71.772 215,318 2924.49 2964.49 4191.41 70.825 215,190 2954.22 2994.22 4284,96 69.796 216,361 2985.74 3025,74 4377.81 67.901 216.757 3019.24 3059.24 4470.74 68.979 217.351 3053,39 3093.39 4563.35 67.719 218.877 3087.56 3127.56 4656.17 68.312 218.533 3122.31 3162.31 4750,30 69.415 218.636 3156.25 3196.25 4842.71 68.132 218.978 3189.71 3229.71 4935.63 68.745 219,647 3223.85 3263.85 5028.46 69.977 219.009 3256.57 3296.57 5121.40 69.767 219.227 3288.56 3328,56 5213.90 68.563 219.078 3321.46 3361.46 869.00 S 700,36W 934,94 S 752,42W 1001.04 S 804.48W 1067.95 S 857,32W 1135.65 S 910.97W 1202.06 S 964,58W 1269,52 S 1019,08W 1338.40 S 1073.30W 1408.90 S 1127,79W 1478.92 S 1180,52W 1550.06 S 1233.28W 1620,52 S 1284,97W 1691.66 S 1335,88W 1763.39 S 1386.58W 1834.85 S 1438.07W 1904.40 S 1489.64W 1973.38 $ 1541,72W 2041,10 S 1594.84W 2108.27 S 1648.66W 2176.90 $ 1703.42W 2244.02 S 1757,40W 2310.88 S 1812.15W 2378.08 S 1867.20W 2445,78 S 1922.26W 2512.82 S 1976.84W 6034544,72 N 540839.19 6034478.50 N 540787.50 6034412.11 N 540735.81 6034344.90 N 540683.34 6034276.90 N 540630.07 6034210.19 N 540576.83 6034142.44 N 540522.71 6034073.25 N 540468.88 6034002.44 N 540414.78 6033932.13 N 540362.45 6033860,70 N 540310.09 6033789.95 N 540258.79 6033718.52 N 540208.28 6033646.52 N 540157,98 6033574.77 N 540106.90 6033504.93 N 540055.71 6033435.66 N 540004.02 6033367.65 N 539951.27 6033300.18 N 539897.83 6033231.24 N 539843.46 6033163.82 N 539789.85 6033096.65 N 539735.48 6033029.15 N 539680,80 6032961.14 N 539626.12 6032893.80 N 539571.92 Dogleg Rate (°/100ft) Alaska State Plane 4 Milne Point MPF Vertical Section (fi) E 0.822 1092.09 E 0.417 1174.12 E 2.272 1256.25 E 1.890 1339.50 E 0.643 1423.8~1 E 0.982 1507.40 E 2.032 1592.28 E 1.466 1677.84 E 0.426 1764.64 E 1.085 1849.77 E 0.351 1935.62 E 2.062 2020.23 E 1.943 2104.66 E 1.030 2189.29 E 1.612 2274.37 E 2.079 2358.31 E 1.303 2442,27 E 2.049 2526.25 E 0.725 2610.41 E 1.176 2696.23 E 1.431 2780.50 E 0.940 2865.20 E 1.475 2950.34 E 0.316 3035.80 E 1.310 3120 4~ Comment 19 June, 2000 - 13:44 -3- Conllnllnd,.. DrlllQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPF-81 Your Ref: AP1-$00292295900 Surveyed: 15 June, 1900 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (fi) (ft) (ft) (ft) 5306~9 69.329 219.161 3354.90 3394.90 5399.10 71.105 218.192 3386.07 3426.07 5491.46 70.268 219.150 3416.62 3456.62 5584.64 70.496 220.486 3447.91 3487.91 5679.16 71.133 221.117 3478.97 3518.97 5772.10 69.492 219.737 3510.28 3550.28 5885.25 70.853 219.990 3541.87 3581.87 5959.03 69.835 219.222 3573.42 3613.42 6051.85 68.077 218.363 3606.75 3646.75 6143.45 68.185 218.588 3640.87 3680.87 6237.81 68.221 218.729 3675.91 3715.91 6331.82 68.423 220.267 3710.63 3750.63 6425.42 69.458 220.561 3744.27 3784.27 6516.22 68.143 219.820 3777.10 3817.10 6610.18 69.136 222.770 3811.33 3851.33 6703.74 70.370 226.332 3843.72 3883.72 6793.40 70.790 230.458 3873.54 3913.54 6887.86 70.170 233.986 3905.11 3945.11 6980.60 69.519 235.872 3937.07 3977.07 7071.38 68.526 239.560 3969.58 4009.58 7163.90 70.541 242.817 4001.93 4041.93 7256.78 68.403 243.185 4034.50 4074.50 7350.47 68.814 242.529 4068.68 4108.68 7442.79 70.258 244.721 4100.95 4140.95 7477.73 70.718 245.457 4112.62 4152.62 2580.22 S 2031.66W 2647.88 S 2085,81W 2715.94 S 2140.28W 2783.35 S 2196.48W 2850.92 S 2254.81W 2917.53 S 2311.56W 2984.79 S 2367.72W 3052.83 S 2424,03W 3120.34 S 2478.30W 3186.89 S 2531.19W 3255.31S 2585.92W 3322.72 S 2641,48W 3389.22 S 2698.11W 3453.89 S 2752.74W 3519.62 S 2810.49W 3582.15 S 2872.06W 3638.28 S 2935.28W 3692.81S 3005.63W 3742.83 S 3076.88W 3788.10 S 3148.52W 3829.86 S 3224.46W 3869.34 S 3301.95W 3909.14 S 3379.58W 3947.55 S 3457.07W 3961.43 S 3486.94W 6032826,09 N 539517.48 E 6032758.12 N 539463.70 E 6032689.77 N 539409.62 E 6032622.04 N 539353.80 E 6032554.14 N 539295.84 E 6032487.22 N 539239.47 E 6032419.65 N 539183.68 E 6032351.30 N 539127.76 E 6032283.48 N 539073.87 E 6032216.64 N 539021.35 E 6032147.91 N 538967.00 E 6032080.20 N 538911.81 E 6032013.38 N 538855.56 E 6031948.41 N 538801.29 E 6031882.36 N 538743.91 E 6031819.48 N 538682.69 E 6031763.00 N 538619.79 E 6031708.07 N 538549.74 E 6031657.65 N 538478.78 E 6031611.98 N 538407.39 E 6031569.81N 538331.69 E 6031529.89 N 538254.41 E 6031489.65 N 538177.01 E 6031450.81N 538099.74 E 6031436.77 N 538069.95 E Dogleg Rate (°/100fi) 0.827 2.167 1.334 1.373 0.923 2.252 1.483 1.332 2.082 0.257 0.144 1.535 1.144 1.636 3.109 3.808 4.365 3.581 2.034 3.948 3.952 2.332 0.786 2.719 2.382 Alaska State Plane 4 Milne Point MPF Vertical Section (fi) Comment 3205.57 3290.31 3375.54 3461.71 3549.63 3635.71 3721.75 3808.39 3893.13 3976.19 4061.85 4147.53 4233.45 4316.67 4402.97 4490.21 4574.67 4663.66 4750.49 4834.61 4919.R4 5004.R4 5090.14 5174.46 5206.37 19 June, 2000 - 13:44 -4- Conill,led.. DrlilO~loet 1.05.04e Sperry-Sun Drilling Services Survey Report for MPF-81 Your Ref: API-500292295900 Surveyed: 15 June, 1900 North Slope Alaska Measured Depth (ft)~ Incl. 7531.75 7623.30 7714.37 7806.26 7899.71 7993.32 8o86.74 8179.39 8274.89 8365.73 8459.66 8551.16 8645.24 8738.79 8832.26 8921.75 9014.23 9106.64 9198.93 9291.89 9375.95 9480.12 9573.73 9666.39 9758.56 71.225 71.853 72.207 70.244 68.123 67.942 69,598 70.562 70.611 70,298 70.884 72.527 73.691 74.140 74.634 72.998 72.693 70.042 69.259 69.236 69.203 68.776 69.755 71.643 71.582 Azim. 245.8O5 245.172 243.971 242.809 241.614 241.141 241.541 242.929 241.665 240.632 241.357 246.265 250.096 247.784 247.061 246.154 243.711 244.357 244.259 243.041 242.936 242.093 241.730 244.744 244.708 Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4130.24 4170.24 3982.50 S 3533.45W 6031415.44 N 4159.23 4199.23 4018.52 S 3612,47W 6031378,97 N 4187.33 4227.33 4055.72 S 3690.70W 6031341.34 N 4216.90 4256.90 4094.68 S 3768.48W 6031301.94 N 4250.11 4290.11 4135.40 S 3845.75W 6031260,80 N 4285.13 4325.13 4176,98 S 3921.96W 6031218.78 N 4318.95 4358,95 4218.74 S 3998,37W 6031176.60 N 4350.52 4390.52 4259.32 S 4075.44W 6031135.59 N 4382.26 4422.26 4301,19 S 4155.19W 6031093.28 N 4412.66 4452.66 4342.50 S 4230.17W 6031051.55 N 4443.87 4483.87 4385.45 S 4307,65W 6031008.16 N 4472.61 4512.61 4423,76 S 4385.58W 6030969.42 N 4499.95 4539.95 4457,20 S 4469.13W 6030935.51N 4525.87 4565.87 4489.50 S 4553.01W 6030902.74 N 4551.03 4591.03 4524,07 S 4636.13W 6030867.71 N 4575.97 4615.97 4558.18 S 4715,01W 6030833,15 N 4603.25 4643.25 4595.62 S 4795,05W 6030795.27 N 4632.78 4672,78 4633.96 S 4873.76W 6030756.49 N 4664.87 4704.87 4671,47 S 4951.74W 6030718.54 N 4697.81 4737.81 4710.06 S 5029.63W 6030679.53 N 4727.63 4767.63 4745.75 S 5099.65W 6030643.44 N 4764.98 4804,98 4790.63 S 5185.92W 6030598.08 N 4798.12 4838.12 4831.85 S 5263,15W 6030556.43 N 4828.75 4868.75 4871.21 S 5341.23W 6030516.63 N 4857.83 4897.83 4908.55 S 5420.32W 6030478.85 N 538023.55 537944.74 537866.72 537789,15 537712.11 537636.14 537559.96 537483.11 537403.61 537328.86 537251.62 537173.9O 537090.54 537006.84 536923,92 536845.23 E 536765,40 E 536686.90 E 536609,14 E 536531.46 E 536461.64 536375.63 536298.62 536220.77 536141.89 Dogleg Rate (°/100ft) 1.119 0.949 1.313 2.449 2.565 0.507 1.817 1.751 1.249 1.126 0.959 5.400 4.088 2.423 0.913 2.071 2.546 2.944 0.854 1.225 0.123 0.859 1.107 3.684 0.076 Alaska State Plane 4 Milne Point MPF Vertical Section (fi) Comment 5255.73 5339.72 5423.R4 5508.73 5594.34 5679.67 5765.27 5850.63 5938.88 6023.09 6110.27 6194.87 6280.74 6366.14 6452.39 6535.06 6620.73 6705.96 6790.08 6874.82 6951.63 7046.84 7132.74 7218.11 7302.99 June, 2000 - 13:44 -5- Contlnuncl. . DrlllQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPF-81 Your Ref: API-500292295900 Surveyed: 15 June, 1900 North Slope Alaska Measured Depth (ft) Incl. 9852.42 9946.37 10039.72 10130.6O 10223.88 10316.93 10410.09 10502.78 10594.53 10686.90 10780.66 10872.47 10965.52 11060.02 11152.90 11245.02 11339.07 11431.71 11525.18 11615.34 11708.52 11801.25 1187424 11987.20 12081.02 71.604 71.471 69.593 66.519 63.286 61.944 60.965 58.467 55.376 52.063 49.552 45.633 42.401 38.338 34.549 30.559 28.026 24.391 22.142 18.079 12.601 9.855 8.916 8.735 8.228 Azim. 244.180 243.299 243.262 240.912 239.151 238.543 241.152 243.760 247.430 246.215 245.012 244.073 244.742 247.802 250.714 256.962 255.274 253.002 245.109 236,857 235.052 237.556 245.710 246.047 246.917 Sub-Sea Depth (ft) 4887.47 4917.22 4948.33 4982.29 5021.85 5064.65 5109.18 5155.92 5206.00 5260.66 5319.90 5381.81 5448.71 5520.70 5595.41 5673.07 5755.08 5838.19 5924,07 6008.74 6098.56 6189.51 6281.26 6373.12 6465.91 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 4927.47 4957.22 4988.33 5022.29 5061.85 5104.65 5149.18 5195.92 5246.00 5300.66 5359.90 5421.81 5488.71 5560.70 5635.41 5713.07 5795.08 5878.19 5964.07 6048.74 6138.56 6229.51 6321.26 6413.12 6505.91 4946.97 S 5500.66W 6030439.98 N 536061.76 E 4986.40 S 5580.58W 6030400.11 N 535982.07 E 5025.97 S 5659.19W 6030360.10 N 535903.68 E 5065.41 S 5733.67W 6030320.25 N 535829.42 E 5107.58 S 5806.85W 6030277.66 N 535756.48 E 5150.32 S 5877.55W 6030234.53 N 535686.01 E 5191.43 S 5948.30W 6030193.03 N 535615.50 E 5228.45 S 6019.25W 6030155.60 N 535544.76 E 5260.25 S 6089.21W 6030123.42 N 535474.97 E 5289.53 S 6157.66W 6030093.75 N 535406.69 E 5319.52 S 6223.84W 6030063.40 N 535340.68 E 5348.64 S 6285.04W 6030033.94 N 535279.64 E 5376.57 S 6343.34W 6030005.68 N 535221.50 E 5401.25 S 6399.32W 6029980.68 N 535165.66 E 5420.84 S 6450.88W 6029960.80 N 535114.21 E 5434.76 S 6498.38W 6029946.62 N 535066.79 E 5445.78 S 6543.05W 6029935.36 N 535022.18 E 5456.90 S 6582.41W 6029924.01 N 534982.89 E 5469.97 S 6616.85W 6029910.75 N 534948.51 E 5484.77 S 6644.00W 6029895.79 N 534921.45 E 5498.51S 6664.45W 6029881.94 N 534901.08 E 5508.57 S 6679.44W 6029871.81 N 534886.14 E 5515.80 S 6692.73W 6029864.50 N 534872.90 E 5521.63 S 6705.74W 6029858.60 N 534859.91 E 5527.15 S 6718.43W 6029853.00 N 534847.26 E Dogleg Rate ("/lOOft) 0.534 0.901 2.012 4.146 3.864 1.555 2.675 3,628 4.751 3.740 2.857 4.335 3.509 4.783 4.484 5.659 2.833 4.070 4.108 5.486 5.901 3.007 1.748 0.202 0.557 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) Comment 7389.52 7476.36 7562.28 7644.92 7728.27 7810.07 7890.87 7969,24 8043.55 8115.09 8185.32 8251.14 8313.97 8372.94 8425.27 8470.R7 8512.43 8549.96 8584.90 8615.29 8639.82 8657.79 8672.66 8686.43 8699.75 C, onttnu~d. . . 19 June, 2000 - 13:44 - 6- . , .... :, :i., . DtlllQue,wt 1.05.04e Sperry-Sun Drilling Services Survey Report for MPF-81 Your Ref: API-500292295900 Surveyed: 15 June, 1900 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 12173.72 8.758 244.220 6557.59 6597.59 5532.82 S 6730.89W 12266.93 9.148 245.585 6649.67 6689.67 5538,97 S 6744,02W 12347.09 9.284 246.718 6728.79 6768.79 5544,16 S 6755.76W 12494.44 9.860 249.570 6874.09 6914.09 5553.26 S 6778,51W 12526.95 9.900 250.800 6906.12 6946.12 5555.15 S 6783,75W 12590.27 9.240 251.150 6968.56 7008.56 5558.59 S 6793,71W 12686.85 8.550 249.780 7063.98 7103.98 5563.57 S 6807,78W 12728.68 8.760 246.300 7105.33 7145.33 5565.93 S 6813.61W 12730.11 8.470 245.620 7106.74 7146.74 5566.02 S 6813.81W 12790.00 8.470 245.620 7165.98 7205,98 5569.66 S 6821,85W 6029847.26 N 534834,83 E 6029841.04 N 534821.73 E 6029835.78 N 534810.02 E 6029826.55 N 534787.33 E 6029824.63 N 534782.09 E 6029821.15 N 534772.16 E 6029816.08 N 534758,11E 6029813.69 N 534752.29 E 6029813.60 N 534752.10 E 6029809,92 N 534744.08 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.628° (19-Jun-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 230,770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12790.00ft., The Bottom Hole Displacement is 8806.74ft., in the Direction of 230.770° (True). Dogleg Rate (°/100ft) 0.715 0.476 0,283 0.506 0,661 1.046 0.747 1.349 21.494 0.000 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) Comment 8712.99 8727.05 8739.43 8762.80 8768.06 8777.94 8792.00 8798.01 8798.21 8806.74 La.si S~mrvey Stallorl Projected 1'1 ) Contfllued. . 19 June, 2000 - 13:44 - 7- DrillQue.~t 1.05.04e North Slope Alaska Sperry-Sun Drilling Services Survey Report for MPF-81 Your Ref: API-500292295900 Surveyed: 15 June, 1900 Alaska State Plane 4 Milne Point MPF Comments Measured Depth (ft) 635.00 12730.11 1279o.0o Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 634.91 4.77 s 0.66 E 7146.74 5566.02 S 6813.81 W 7205.98 5569.66 S 6821.85 W Comment Tie-on to Gyrodata Orient Last Survey Station Projected TD Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 760.87 760.49 To Measured Vertical Depth Depth (ft) (ft) 760.87 760.49 12790.00 7205.98 Survey Tool Description AK-1 BP_HG IFR 19 J[me, 2000 - 13:44 - 8 - DrlllQt~e.~ t I. 05. 04e B.P. EXPLORATION F PAD, WELL NO. MPF-81 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 4.5" TUBING Survey date: 20- JUNE, 2000 Job number: AK0600GCE514 CONTENTS JOB NUMBER: AK0600GCE514 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0600GCE514 Tool 789 was run in WELL# MPF-81 on SCHLUMBERGER 7/32" wireline inside 4.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER' AK0600GCE514 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JAMES GILMORE OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK0600GCE514 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER · LOCATION: F PAD WELL: MPF-81 LATITUDE: 70.505 N LONGITUDE: 149.1W SURVEY DATE: SURVEY TYPE: 20 - JUNE, 2000 GYRO CONTINUOUS DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 44.0' 12550' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-12550' APl NUMBER: TARGET DIRECTION: 050-029-22959 230.78 GRID CORRECTION: N/A CALCULATION METHOD: SURVEYOR: MINIMUM CURVATURE TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyrodata Directional Survey for B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 Run Date: 9/28/00 4:39:46 PM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.00 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed WellDirection: 230.780 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POiNT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDiNATES feet 0.0 0.00 0.00 0.00 100.0 0.51 107.81 0.51 200.0 0.54 100.48 0.07 300.0 0.41 80.93 0.21 400.0 0.20 191.22 0.51 0.0 -44.0 0.0 100.0 56.0 -0.2 200.0 156.0 -0.8 300.0 256.0 -1.4 400.0 356.0 -1.6 0.0 0.0 0.4 107.8 1.4 105.3 2.2 100.3 2.5 101.7 0.00 N 0.14 S 0.36 S 0.39 S 0.50 S 0.00 E 0.42 E 1.31 E 2.12 E 2.44 E 500.0 1.18 203.40 0.99 600.0 1.43 212.21 0.32 700.0 3.65 218.62 2.23 800.0 5.23 215.34 1.61 900.0 6.94 216.91 1.71 500.0 456.0 -0.5 600.0 556.0 1.6 699.9 655.9 5.9 799.5 755.5 13.4 899.0 855.0 23.7 2.6 3.7 7.4 14.8 25.3 129.2 165.8 193.6 205.4 209.9 1.62 3.63 7.17 13.38 21.94 1.99 E 0.92 E 1.74W 6.36W 12.63W 1000.0 10.29 220.98 3.40 1050.0 12.17 223.21 3.84 1100.0 13.53 223.87 2.75 1150.0 14.49 224.02 1.91 1200.0 15.66 223.11 2.40 997.8 953.8 38.3 40.2 1046.9 1002.9 48.0 49.8 1095.6 1051.6 59.0 60.8 1144.1 1100.1 71.0 72.8 1192.4 1148.4 83.9 85.8 213.4 215.1 216.7 217.9 218.7 33.51 40.73 48.79 57.50 66.93 22.12W 28.66W 36.32W 44.72W 53.68W 1250.0 16.81 221.15 2.55 1300.0 18.17 217.41 3.53 1350.0 19.11 214.30 2.74 1400.0 19.84 212.34 1.94 1450.0 19.86 211.97 0.26 1240.4 1196.4 97.7 99.8 1288.1 1244.1 112.4 114.8 1335.5 1291.5 127.9 130.7 1382.6 1338.6 143.8 147.3 1429.7 1385,7 159.9 164.2 219.2 219.2 218.8 218.2 217.5 77.30 88.94 101.89 115.82 130.19 63.05W 72.54W 81.89W 91.04W 100.08W 1500.0 20.00 211.77 0.32 1550.0 20.96 213.04 2.11 1600.0 21.94 214.43 2.20 1650.0 22.94 216.44 2.53 1700.0 23.54 217.56 1.48 1476.7 1432.7 176.0 181.2 1523.5 1479.5 192.6 198.6 1570.0 1526.0 210.1 216.9 1616.3 1572.3 228.5 236.0 1662.2 1618.2 247.6 255.7 217.0 216.6 216.4 216.3 216.4 144.67 159.44 174.64 190.18 205.94 109.08W 118.46W 128.61W 139.68W 151.56W 1750.0 23.77 217.84 0.52 1800.0 23.60 218.19 0.44 1708.0 1664.0 267.2 275.8 216.4 1753.8 1709.8 286.8 295.8 216.6 221.81S 237.64 S 163.83W 176.20W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 1850.0 22.83 217.84 1.57 1900.0 22.83 217.89 0.04 1950.0 24.26 218.66 2.92 1799.7 1755.7 306.0 1845.8 1801.8 324.9 1891.7 1847.7 344.4 315.5 216.6 334.9 216.7 35419 216.8 253.17 S 268.48 S 284.16 S 188.34W 200.24W 212.62W 2000.0 28.70 219.61 8.93 2050.0 31.89 219.79 6.38 2100.0 34.00 219.62' 4.23 2150.0 37.11 218.64 6.32 2200.0 39.17 218.43 4.13 1936.4 1892.4 366.2 377.2 1979.6 1935.6 391.0 402.4 2021.5 1977.5 417.7 429.5 2062.2 2018.2 446.1 '458.6 2101.5 2057.5 476.3 489.5 216.9 217.1 217.3 217.4 217.5 301.43 S 320.84 S 341.76 S 364.31S 388.47 S 226.70W 242.81W 260.17W 278.51W 297.75W 2250.0 42.87 218.58 7.41 2300.0 45.07 218.33 4.41 2350.0 47.11 217.86 4.14 2400.0 48.92 218.05 3.62 2450.0 50.06 218.36 2.34 2139.2 2095.2 508.4 522.3 2175.2 2131.2 542.3 557.0 2209.9 2165.9 577.4 593.0 2243.3 2199.3 613.7 630.1 2275.8 2231.8 650.8 668.2 217.5 217.6 217.6 217.6 217.7 414.14 S 441.33 S 469.68 S 498.98 S 528.85 S 318.18W 339.77W 361.99W 384.84W 408.36W 2500.0 50.43 218.69 0.90 2550.0 50.54 219.06 0.60 2600.0 50.81 219.36 0.72 2650.0 51.34 219.44 1.06 2700.0 54.19 218.44 5.92 2307.8 2263.8 688.3 706.6 2339.6 2295.6 726.1 745.2 2371.3 2327.3 764.0 783.8 2402.7 2358.7 802.1 822.7 2432.9 2388.9 841.0 862.5 217.7 217.8 217.9 217.9 218.0 558.92 S 588.95 S 618.93 S 648.98 S 679.94 S 432.30W 456.51W 480.96W 505.65W 530.67W 2750.0 56.52 217.80 4.78 2800.0 59.18 217.49 5.35 2850.0 60.97 217.43 3.58 2900.0 63.20 217.62 4.47 2950.0 63.95 217.65 1.49 2461.4 2417.4 881.2 903.6 2488.0 2444.0 922.4 946.0 2512.9 2468.9. 964.6 989.3 2536.3 2492.3 1007.6 1033.5 2558.6 2514.6 1051.2 1078.3 218.0 218.0 217.9 217.9 217.9 712.30 S 745.82 S 780.22 S 815.26 S 850.72 S 556.06W 581.91W 608.26W 635.17W 662.51W 3000.0 64.11 217.71 0.35 3050.0 64.11 217.81 0.17 3100.0 64.62 217.89 1.03 3150.0 65.69 217.81 2.14 2580.5 2536.5 1095.0 1123.2 2602.3 2558.3 1138.8 1168.2 2623.9 2579.9 1182.7 1213.3 2644.9 2600.9 1226.9 1258.6 217.9 217.9 217.9 217.9 886.29 S 921.86 S 957.45 S 993.28 S 689.99W 717.53W 745.19W 773.03W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 3200.0 66.75 217.83 2.13 3250.0 67.58 217.81 1.66 3300.0 68.18 217.87 1.21 3350.0 68.58 218.19 0.99 3400.0 68.55 218.60 0.77 3450.0 69.07 218.75 1.07 3500.0 69.65 218.74 1.16 3550.0 70.67 217.82 2.68 3600.0 71.54 217.39 1.93 3650.0 71.98 217.42 0.87 3700.0 72.17 217.51 0.42 3750.0 71.35 216.47 2.56 3800.0 71.54 216.02 0.94 3850.0 71.65 215.94 0.28 3900.0 71.91 215.92 0.51 3950.0 71.97 215.98 0.15 4000.0 70.66 215.25 2.95 4050.0 70.66 214.88 0.70 4100.0 71.68 214.77 2.06 4150.0 72.52 214.61 1.71 4200.0 70.98 214.16 3.20 4250.0 70.82 214.26 0.36 4300.0 69.92 214.90 2.17 4350.0 69.53 215.54 1.43 4400.0 68.07 216.26 3.22 4450.0 68.56 216.37 0.99 2665.1 2621.1 1271.5 1304.4 217.9 2684.5 2640.5 1316.4 1350.5 217.9 2703.3 2659.3 1361.6 1396.8 217.9 2721.7 2677.7 1406.9 1443.3 217.9 2740.0 2696.0 1452.4 1489.8 217.9 2758.1 2714.1 1498.0 1536.4 217.9 2775.7 2731.7 1543.7 1583.2 218.0 2792.7 2748.7 1589.6 1630.3 218.0 2808.9 2764.9 1635.7 1677.6 218.0 2824.5 2780.5 1681.9 1725.0 217.9 2839.9 2795.9 1728.2 1772.6 217.9 2855.6 2811.6 1774.3 2871.5 2827.5 1820.2 2887.3 2843.3 1866.1 2902.9 2858.9 1912.0 2918.4 2874.4 1957.9 2934.4 2890.4 2003.6 2951.0 2907.0 2049.0 2967.1 2923.1 2094.5 2982.5 2938.5 2140.3 2998.1 2954.1 2185.8 3014.5 2970.5 2231.1 3031.3 2987.3 2276.3 3048.6 3004.6 . 2321.5 3066.7 3022.7 2366.6 3085.2 3041.2 2411.5 1820.1 217.9 1867.5 217.9 1914.9 217.8 1962.4 217.8 2009.9 217.7 2057.2 217.7 2104.3 217.6 2151.6 217.6 2199.1 217.5 2246.5 217.4 2293.7 217.4 2340.8 217.3 2387.6 217.3 2434.2 217.2 2480.7 217.2 HORIZONTAL COORDINATES ~et 1029.42 S 1065.82 S 1102.40 S 1139.02 S 1175.50 S 1211.89 S 1248.38 S 1285.30 S 1322.78 S 1360.50 S 1398.26 S 1436.19 S 1474.41 S 1512.81 S 1551.26 S 1589.75 S 1628.25 S 1666.86 S 1705.71 S 1744.83 S 1784.02 S 1823.09 S 1861.87 S 1900.18 S 1937.94 S 1975.38 S 801.09W 829.35 W 857.76W 886.40W 915.30W 944.43 W 973.72W 1002.85 W 1031.72W 1060.57W 1089.51W 1118.08W 1146.11W 1173.98 W 1201.85W 1229.76W 1257.34W 1284.45 W 1311.47W 1338.55W 1365.37W 1391.93W 1418.66W 1445.70W 1473.04 W 1500.55 W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 4500.0 69.36 216.38 1.61 4550.0 68.42 217.22 2.46 4600.0 67.88 217.81 1.53 4650.0 68.10 218.12 0.72 4700.0 68.79 218.17 1.37 4750.0 69.54 218.25 1.52 4800.0 70.00 218.22 0.92 4850.0 68.45 218.14 3.10 4900.0 68.43 218.36 0.41 4950.0 68.92 218.33 0.98 5000.0 69.47 218.25 1.12 5050.0 70.37 218.16 1.81 5100.0 70.66 218.40 0.73 5150.0 70.10 218.80 1.34 5200.0 69.53 218.59 1.21 5250.0 68.87 218.06 1.66 5300.0 69.26 218.08 0.78 5350.0 69.80 218.14 1.08 5400.0 70.77 218.10 1.95 5450.0 71.64 218.14 1.74 5500.0 70.74 218.26 1.82 5550.0 71.27 218.48 1.14 5600.0 70.40 219.32 2.35 5650.0 70.99 219.49 1.21 5700.0 71.29 219.46 0.61 5750.0 70.24 218.94 2.31 5800.0 69.42 218.76 1.68 A Gyrodata Directional Survey VERTICAL SUB SEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. 3103.1 3059.1 2456.7 3121.1 3077.1 2502.0 3139.8 3095.8 2547.2 3158.5 3114.5 2592.4 3176.9 3132.9 2637.8 3194.6 3150.6 2683.4 3211.9 3167.9 2729.2 3229.7 3185.7 2774.8 3248.0 3204.0 2820.2 3266.2 3222.2 2865.7 3284.0 3240.0 2911.3 3301.2 3257.2 2957.1 3317.8 3273.8 3003.1 3334.6 3290.6 3049.2 3351.9 3307.9 3095.1 3369.6 3325.6 3140.7 3387.5 3343.5 3186.3 3405.0 3361.0 3232.0 3421.9 3377.9 3277.9 3438.0 3394.0 3324.1 3454.1 3410.1 3370.3 3470.4 3426.4 3416.4 3486.8 3442.8 3462.6 3503.3 3459.3 3508.9 3519.5 3475.5 3555.3 3535.9 3491.9 3601.6 3553.2 3509.2 3647.5 2527.3 217.2 2574.0 217.2 2620.4 217.2 2666.7 217.2 2713.2 217.2 2760.0 217.2 2806.9 217.3 2853.6 217.3 2900.1 217.3 2946.7 217.3 2993.4 217.3 3040.4 217.3 3087.5 217.4 3134.6 217.4 3181.5 217.4 3228.2 217.4 3274.9 217.4 3321.8 217.4 3368.8 217.4 3416.2 217.4 3463.5 217.5 3510.8 217.5 3558.0 217.5 3605.1 217.5 3652.4 217.5 3699.6 217.6 3746.5 217.6 HORIZONTAL COORD~ATES ~et 2012.95 S 2050.30 S 2087.11 S 2123.66 S 2160.23 S 2196.95 S 2233.81 S 2270.55 S 2307.07 S 2343.60 S 2380.29 S 2417.19 S 2454.19 S 2491.00 S 2527.62 S 2564.29 S 2601.06 S 2637.92 S 2674.95 S 2712.19 S 2749.38 S 2786.45 S 2823.21 S 2859.67 S 2896.19 S 2932.78 S 2969.33 S 1528.23 W 1556.17W 1584.43 W 1612.94W 1641.66W 1670.57 W 1699.60W 1728.50W 1757.28W 1786.18W 1815.14W 1844.18W 1873.38W 1902.77 W 1932.10W 1961.09 W 1989.88W 2018.79W 2047.85 W 2077.06W 2106.33 W 2135.68W 2165.33W 2195.29W 2225.36W 2255.20W 2284.64 W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 5850.0 70.22 218.78 1.60 5900.0 71.16 218.78 1.88 5950.0 70.32 218.15 2.05 3570.4 3526.4 3693.4 3587.0 3543.0 3739.5 3603.5 3559.5 3785.6 3793.5 217.6 3840.6 217.6 3887.8 217.6 3005.92 S 3042.71S 3079.66 S 2314.02W 2343.58W 2372.94W 6000.0 70.06 217.82 0.81 6050.0 68.51 217.62 3.13 6100.0 68.36 217.83 0.50 6150.0 68.23 217.56 0.57 6200.0 68.28 217.16 0.76 3620.4 3576.4 3831.5 3934.9 217.6 3638.1 3594.1 3877.1 3981.6 217.6 3656.5 3612.5 3922.4 4028.1 217.6 3675.0 3631.0 3967.6 4074.6 217.6 3693.5 3649.5 4012.8 4121.0 217.6 3116.74 S 3153.73 S 3190.51 S 3227.27 S 3264.19 S 2401.89W 2430.50W 2458.95W 2487.36W 2515.54W 6250.0 68.18 217.78 1.18 6300.0 68.16 218.67 1.65 6350.0 68.76 219.05 1.39 6400.0 69.00 219.32 0.70 6450.0 69.76 219.47 1.54 3712.0 3668.0 4058.0 3730.6 3686.6 4103.3 3749.0 3705.0 4148.8 3767.0 3723.0 4194.5 3784.6 3740.6 4240.4 4167.5 217.6 4213.9 217.6 4260.4 217.6 4307.0 217.7 4353.8 217.7 3301.04 S 3337.51S 3373.72 S 3409.87 S 3446.04 S 2543.79W 2572.51W 2601.69W 2631.16W 2660.86W 6500.0 68.93 219.05 1.83 6550.0 68.54 218.69 1.04 6600.0 68.89 220.22 2.94 6650.0 69.82 222.26 4.24 6700.0 70.24 224.67 4.61 3802.2 3758.2 4286.2 3820.4 3776.4 4331.8 3838.5 3794.5 4377.5 3856.1 3812.1 4423.6 3873.2 3829.2 4470.2 4400.5 217.7 4447.1 217.7 4493.7 217.7 4540.4 217.8 4587.1 217.8 3482.26 S 3518.54 S 3554.51S 3589.69 S 3623.79 S 2690.47W 2719.71W 2749.31W 2780.16W 2812.48W 6750.0 70.85 226.15 3.05 6800.0 70.95 228.51 4.47 6850.0 70.87 230.63 4.00 6900.0 70.33 232.75 4.15 6950.0 70.52 233.88 2.16 3889.9 3845.9 4517.2 3906.2 3862.2 4564.3 3922.6 3878.6 4611.6 3939.2 3895.2 4658.7 3955.9 3911.9 4705.8 4633.9 217.9 4680.5 218.0 4726.8 218.1 4772.6 218.2 4818.1 '218.4 3656.89 S 3688.90 S 3719.54 S 3748.78 S 3776.92 S 2846.06W 2880.80W 2916.76W 2953.76W 2991.54W 7000.0 69.87 234.86 2.26 7050.0 69.17 236.13 2.75 7100.0 68.91 237.95 3.44 7150.0 69.93 239.97 4.31 3972.9 3928.9 4752.7 4863.4 218.5 3990.4 3946.4 4799.4 4908.2 218.7 4008.3 3964.3 4845.8 4952.5 218.9 4025.9 3981.9 4892.1 4996.5 219.0 3804.33 S 3830.86 S 3856.26 S 3880.39 S 3029.78W 3068.37W 3107.55W 3147.65W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 7200.0 70.89 241.44 3.36 4042.6 3998.6 4938.5 7250.0 69.24 241.97 3.46 7300.0 68.38 242.18 1.77 7350.0 68.85 241.82 1.17 7400.0 69.14 242.11 0.79 7450.0 70.15 243.55 3.37 7500.0 70.53 244.03 1.18 7550.0 70.93 244.17 0.84 7600.0 71.64 243.86 1.53 7650.0 71.81 243.27 1.18 7700.0 72.19 242.60 1.48 7750.0 71.88 241.96 1.36 7800.0 70.98 241.54 1.97 7850.0 68.36 240.96 5.36 7900.0 68.21 240.49 0.92 7950.0 67.64 240.11 1.35 8000.0 67.78 239.52 1.12 8050.0 67.91 239.20 0.65 8100.0 69.27 240.49 3.61 8150.0 70.11 241.72 2.86 8200.0 70.49 241.22 1.20 8250.0 70.58 240.75 0.91 8300.0 70.60 240.48 0.50 8350.0 70.26 239.98 1.17 8400.0 70.09 239.47 1.01 8450.0 70.42 239.93 1.08 CLOSURE DIST. AZIMUTH feet deg. 5040.3 219.2 4059.7 4015.7 4984.7 5083.8 219.4 4077.7 4033.7 5030.4 5126.9 219.6 4096.0 4052.0 5076.1 5169.9 219.8 4113.9 4069.9 5121.9 5213.2 220.0 4131.3 4087.3 5167.7 5256.5 220.2 4148.1 4104.1 5213.6 4164.6 4120.6 5259.5 4180.7 4136.7 5305.6 4196.3 4152.3 5351.9 4211.8 4167.8 5398.4 4227.2 4183.2 5445.0 4243.1 4199.1 5491.5 4260.5 4216.5 5537.6 4279.0 4235.0 5583.4 4297.8 4253.8 5629.1 4316.8 4272.8 5674.8 4335.6 4291.6 5720.6 4353.9 4309.9 5766.5 4371.2 4327.2 5812.6 4388.1 4344.1 5858.9 4404.8 4360.8 5905.3 4421.4 4377.4 5951.8 4438.1 4394.1 5998.2 4455.1 4411.1 6044.7 4472.0 4428.0 6091.2 5299.7 220.4 5342.9 220.6 5386.4 220.8 5430.2 221.0 5474.4 221.2 5518.8 221.4 5563.3 221.6 5607.4 221.7 5651.4 221.9 5695.4 222.0 5739.4 222.2 5783.7 222.3 5828.1 222.4 5872.5 222.6 5917.1 222.7 5961.9 222.9 6006.8 223.0 6051.8 223.1 6O96.9 223.3 6142.1 223.4 HO~ZONTAL COORDINATES Let 3903.44 S 3925.72 S 3947.55 S 3969.41 S 3991.35 S 4012.75 S 4033.55 S 4054.17 S 4074.91 S 4096.O5 S 4117.69 S 4139.82 S 4162.25 S 4184.80 S 4207.51 S 4230.47 S 4253.73 S 4277.32 S 4300.70 S 4323.36 S 4345.84 S 4368.71 S 4391.85 S 4415.24 S 4438.95 S 4462.69 S 3188.73 W 3230.12W 3271.31W 3312.42W 3353.62W 3395.32W 3437.56W 3480.02 W 3522.59W 3565.10W 3607.44 W 3649.55W 3691.30W 3732.40W 3772.92W 3813.17W 3853.16W 3893.00W 3933.25W 3974.30 W 4015.66W 4056.88W 4097.97W 4138.87W 4179.49W 4220.12W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FiELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 8500.0 71.12 242.88 5.75 8550.0 72.19 244.98 4.52 8600.0 73.03 248.36 6.67 8650.0 73.55 249.07 1.70 8700.0 73.81 248.59 1.06 4488.4 4444.4 6137.6 4504.2 4460.2 6183.8 4519.1 4475.1 6229.7 4533.5 4489.5 6275.2 4547.6 4503.6 6320.9 6187.0 223.5 6231.5 223.7 6275.4 223.9 6318.9 224.0 6362.5 224.2 4485.28 S 4506.13 S 4525.02 S 4542.40 S 4559.73 S 4261.57W 4304.20W 4348.01W 4392.63W 4437.37W 8750.0 74.12 246.69 3.70 8800.0 74.57 245.96 1.68 8850.0 74.35 245.72 0.64 8900.0 74.32 245.29 0.82 8950.0 72.81 244.27 3.61 4561.4 4517.4 6366.8 4574.9 4530.9 6413.2 4588.3 4544.3 6459.7 4601.8 4557.8 6506.3 4615.9 4571.9 6552.8 6406.6 224.4 6451.3 224.6 6496.2 224.7 6541.2 224.9 6586.3 225.0 4578.01S 4597.34 S 4617.06 S 4637.02 S 4657.45 S 4481.81W 4525.91W 4569.86W 4613.67W 4657.06W 9000.0 72.70 243.75 1.03 9050.0 72.26 243.27 1.25 9100.0 71.55 243.23 1.43 9150.0 68.81 243.00 5.50 9200.0 69.01 242.93 0.43 4630.7 4586.7 6599.3 4645.8 4601.8 6645.8 4661.3 4617.3 6692.2 4678.3 4634.3 6738.2 4696.2 4652.2 6783.8 6631.5 225.1 6676.8 225.3 6722.0 225.4 6766.8 225.5 6811.3 225.6 4678.37 S 4699.64 S 4721.04 S 4742.30 S 4763.51S 4699.98W 4742.65W 4785.09W 4827.04W 4868.60W 9250.0 69.13 242.89 0.25 9300.0 69.05 242.37 0.99 9350.0 69.03 242.16 0.39 9400.0 69.12 241.60 1.06 9450.0 68.92 241.05 1.11 4714.1 4670.1 6829.4 6855.9 225.7 4732.0 4688.0 6875.2 6900.6 225.9 4749.8 4705.8 6920.9 6945.4 226.0 4767.7 4723.7 6966.7 6990.4 226.1 4785.6 4741.6 7012.6 7035.4 226.2 4784.77 S 4806.25 S 4827.98 S 4849.99 S 4872.39 S 4910.17W 4951.65W 4992.98W 5034.17W 5075.13W 9500.0 68.61 240.49 1.20 9550.0 68.50 240.24 0.53 9600.0 69.92 241.86 4.16 9650.0 70.65 242.46 1.84 9700.0 71.69 243.73 3.18 4803.7 4759.7 7058.5 4822.0 4778.0 7104.4 4839.7 4795.7 7150.4 4856.6 4812.6 7196.6 4872.7 4828.7 7242.8 7O80.5 226.3 7125.7 226.4 7170.9 226.4 7216.2 226.5 7261.6 226.7 4895.15 S 4918.16 S 4940.78 S 4962.76 S 4984.18 S 5115.80W 5156.25W 5197.15W 5238.77 W 5280.97 W 9750.0 71.45 243.61 0.53 9800.0 71.57 243.23 0.75 4888.6 4844.6 7289.0 7307.0 226.8 4904.4 4860.4 7335.3 7352.4 226.9 5005.22 S 5026.44 S 5323.48W 5365.89W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 9850.0 71.59 242.93 0.57 9900.0 71.49 242.40 1.02 9950.0 71.22 241.93 1.04 10000.0 71.29 241.60 0.64 10050.0 69.58 241.29 3.46 10100.0 68.29 240.73 2.79 10150.0 66.06 239.70 4.84 10200.0 64.91 238.71 2.92 10250.0 62.83 237.95 4.39 10300.0 62.70 237.64 0.61 10350.0 61.48 238.93 3.33 10400.0 61.29 239.97 1.88 10450.0 59.99 241.81 4.13 10500.0 59.48 242.80 1.99 10550.0 57.08 244.44 5.56 10600.0 55.68 245.50 3.31 10650.0 53.54 245.42 4.27 10700.0 51.99 244.49 3.44 10750.0 50.85 243.61 2.65 10800.0 48.78 243.92 4.18 10850.0 47.24 243.54 3.13 10900.0 44.30 242.84 5.98 10950.0 43.49 242.93 1.61 11000.0 40.76 245.09 6.20 11050.0 39.63 245.57 2.33 11100.0 37.02 247.23 5.61 11150.0 35.65 248.73 3.28 A Gyrodata Directional Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. 4920.2 4876.2 7381.6 4936.0 4892.0 7428.1 4952.0 4908.0 7474.5 4968.1 4924.1 7521.0 4984.8 4940.8 7567.3 5002.8 4958.8 7613.2 5022.2 4978.2 7658.7 5042.9 4998.9 7703.7 7398.0 227.0 7443.6 227.1 7489.4 227.2 7535.2 227.3 7580.9 227.3 7626.2 227.4 7671.2 227.5 7715.7 227.6 5065.0 5021.0 7748.2 7759.8 227.6 5087.8 5043.8 7792.3 7803.6 227.7 5111.3 5067.3 7836.1 7847.0 227.8 5135.2 5091.2 7879.5 7890.0 227.8 5159.7 5115.7 7922.4 7932.5 227.9 5184.9 5140.9 7964.7 7974.3 228.0 5211.2 5167.2 8006.1 8015.3 228.0 5238.9 5194.9 8046.5 8055.1 228.1 5267.8 5223.8 8085.9 8094.0 228.2 5298.1 5254.1 8124.5 8132.2 228.3 5329.3 5285.3 8162.6 5361.5 5317.5 8199.8 5395.0 5351.0 8236.0 5429.9 5385.9 8271.0 5465.9 5421.9 8304.9 5503.0 5459.0 8337.5 5541.2 5497.2 8368.8 5580.4 5536.4 8398.6 5620.7 5576.7 8426.9 8169.8 228.4 8206.6 228.4 8242.5 228.5 8277.1 228.6 8310.7 228.6 8343.1 228.7 8374.0 228.8 8403.5 228.8 8431.5 228.9 HORIZONTAL COORDINATES feet 5047.91S 5069.69 S 5091.81S 5114.21S 5136.73 S 5159.34 S 5182.23 S 5205.52 S 5229.09 S 5252.78 S 5276.01S 5298.32 S 5319.52 S 5339.59 S 5358.49 S 5376.11S' 5393.04 S 5409.89 S 5426.99 S 5443.87 S 5460.32 S 5476.47 S 5492.27 S 5506.98 S 5520.45 S 5532.88 S 5543.99 S 5408.19W 5450.32W 5492.22W 5533.93W 5575.31W 5616.12W 5656.12W '5695.19W 5733.40W 5771.01W .5808.60W " 5846.40W 5884.47W 5922.70W 5960.80W 5998.52W 6035.59W 6071.66W 6106.80W 6141.07W 6174.39W 6206.37W 6237.22W 6267.35W 6296.67W 6325.08W 6352.54W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 11200.0 32.62 252.27 7.23 5662.1 5618.1 8453.3 8457.6 229.0 11250.0 30.77 255.53 5.05 5704.6 5660.6 8477.5 11300.0 28.90 256.18 3.79 5748.0 5704.0 8500.0 11350.0 27.91 254.21 2.72 5792.0 5748.0 8521.7 11400.0 25.95 252.77 4.13 5836.5 5792.5 8542.6 11450.0 23.75 250.93 4.66 5881.9 5837.9 8562.2 11500.0 22.96 246.97 3.52 11550.0 21.07 242.30 5.15 11600.0 19.08 237.87 5.00 11650.0 16.44 234.64 5.64 11700.0 13.64 233.38 5.64 11750.0 10.64 236.31 6.11 11800.0 9.79 238.37 1.87 11850.0 9.43 240.94 1.12 11900.0 9.00 245.28 1.63 11950.0 8.90 245.93 0.29 12000.0 8.84 246.63 0.25 12050.0 8.60 246.93 0.49 12100.0 8.14 246.84 0.92 12150.0 8.12 246.53 0.09 12200.0 9.00 244.96 1.81 12250.0 9.34 243.74 0.79 12300.0 8.88 245.07 1.02 12350.0 9.23 246.79 0.88 12400.0 9.30 248.31 0.51 12450.0 9.53 250.99 0.99 8481.4 229.0 8503.6 229.1 8525.0 229.2 8545.6 229.2 8565.0 229.3 5927.8 5883.8 8581.0 8583.7 229.3 5974.2 5930.2 8599.1 8601.7 229.4 6021.1 5977.1 8616.1 8618.6 229.4 6068.7 6024.7 8631.2 8633.7 229.4 6117.0 6073.0 8644.2 8646.6 229.4 6165.9 6121.9 8654.7 6215.1 6171.1 8663.5 6264.4 6220.4 8671.7 6313.8 6269.8 8679.5 6363.2 6319.2 8687.0 6412.6 6368.6 8694.5 6462.0 6418.0 8701.8 6511.4 6467.4 8708.7 6560.9 6516.9 8715.5 6610.4 6566.4 8722.7 6659.7 6615.7 8730.5 6709.1 6665.1 8738.2 6758.5 6714.5 8745.8 6807.8 6763.8 8753.5 6857.2 6813.2 8761.2 8657.1 229.4 8665.9 229.4 8674.1 229.4 8681.9 229.5 8689.3 229.5 8696.7 229.5 8704.0 229.5 8710.9 229.5 8717.7 229.5 8724.8 229.5 8732.5 229.5 874O.2 229.6 8747.7 229.6 8755.4 229.6 8763.1 229.6 HORIZONTAL COORDINATES ~et 5553.38 S 5560.68 S 5566.76 S 5572.83 S 5579.26 S 5585.79 S 5592.89 S 5600.89 S 5609.41 S 5617.85 S 5625.46 S 5631.54 S 5636.33 S 5640.55 S 5644.18 S 5647.39 S 5650.49 S 5653.48 S 5656.33 S 5659.13 S 5662.19 S 5665.64 S 5669.07 S 5672.27 S 5675.35 S 5678.19 S 6378.96W 6404.18 W 6428.30W 6451.29 W 6473.00 W 6492.97 W 6511.47 W 6528.40W 6543.28W 6555.97W 6566.47W 6575.04 W ' 6582.50 W 6589.70W 6596.83 W 6603.91 W 6610.97W 6617.93W 6624.62W 6631.11W 6637.90W 6645.08 W 6652.22 W 6659.41 W 6666.85 W 6674.52W 10 A Gyrodata Directional'Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 12500.0 9.87 251.40 0.69 12550.0 9.88 251.26 0.05 Final Station Closure: 6906.5 6862.5 8769.1 8770.9 229.6 6955.7 6911.7 8777.2 8778.9 229.7 Distance: 8778.86 ft Az:' 229.65 deg. HORIZONTAL COORDINATES feet 5680.91 S 5683.65 S 6682.50W 6690.62W 11 A Gyrodata Directional Survey for B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS Run Date: 10/2/00 3:11:14 PM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.00 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed WellDirection: 230.780 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet -44.0 0.00 0.00 0.00 56.0 0.51 107.81 0.51 156.0 0.54 100.48 0.07 256.0 0.41 80.93 0.21 356.0 0.20 191.22 0.51 0.0 0.0 0.0 0.0 100.0 -0.2 0.4 107.8 200.0 -0.8 1.4 105.3 300.0 -1.4 2.2 100.3 400.0 -1.6 2.5 101.7 0.00 N 0.14 S 0.36 S 0.39 S 0.50 S 0.00 E 0.42 E 1.31 E 2.12 E 2.44 E 456.0 1.18 203.40 0.99 556.0 1.43 212.21 0.32 655.9 3.65 218.62 2.23 755.5 5.23 215.34 1.61 855.0 6.94 216.91 1.71 500.0 -0.5 2.6 129.2 600.0 1.6 3.7 165.8 699.9 5.9 7.4 193.6 799.5 13.4 14.8 205.4 899.0 23.7 25.3 209.9 1.62 3.63 7.17 13.38 21.94 1.99 E 0.92 E 1.74W 6.36W 12.63W 953.8 10.29 220.98 3.40 1002.9 12.17 223.21 3.84 1051.6 13.53 223.87 2.75 1100.1 14.49 224.02 1.91 1148.4 15.66 223.11 2.40 997.8 38.3 40.2 213.4 33.51 1046.9 48.0 49.8 215.1 40.73 1095.6 59.0 60.8 216.7 48.79 1144.1 71.0 72.8 217.9 57.50 1192.4 83.9 85.8 218.7 66.93 22.12W 28.66W 36.32W 44.72W 53.68W 1196.4 16.81 221.15 2.55 1244.1 18.17 217.41 3.53 1291.5 19.11 214.30 2.74 1338.6 19.84 212.34 1.94 1385.7 19.86 211.97 0.26 1240.4 97.7 99.8 219.2 1288.1 112.4 114.8 219.2 1335.5 127.9 130.7 218.8 1382.6 143.8 147.3 218.2 1429.7 159.9 164.2 217.5 77.30 88.94 101.89 115.82 130.19 63.05W 72.54W 81.89W 91.04W 100.08W 1432.7 20.00 211.77 0.32 1479.5 20.96 213.04 2.11 1526.0 21.94 214.43 2.20 1572.3 22.94 216.44 2.53 1618.2 23.54 217.56 1.48 1476.7 176.0 181.2 217.0 1523.5 192.6 198.6 216.6 1570.0 210.1 216.9 216.4 1616.3 228.5 236.0 216.3 1662.2 247.6 255.7 216.4 144.67 159.44 174.64 190.18 205.94 109.08W 118.46W 128.61W 139.68W 151.56W 1664.0 23.77 217.84 0.52 1709.8 23.60 218.19 0.44 1708.0 267.2 275.8 216.4 1753.8 286.8 295.8 216.6 221.81S 237.64 S 163.83W 176.20W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS A Gyrodata Directional Survey SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 1755.7 22.83 217.84 1.57 1801.8 22.83 217.89 0.04 1847.7 24.26 218.66 2.92 1799.7 306.0 315.5 216.6 1845.8 324.9 334.9 216.7 1891.7 344.4 354.9 216.8 253.17 S 268.48 S 284.16 S 188.34W 200.24W 212.62W 1892.4 28.70 219.61 8.93 1935.6 31.89 219.79 6.38 1977.5 34.00 219.62 4.23 2018.2 37.11 218.64 6.32 2057.5 39.17 218.43 4.13 1936.4 366.2 377.2 216.9 1979.6 391.0 402.4 217.1 2021.5 417.7 429.5 217.3 2062.2 446.1 458.6 217.4 2101.5 476.3 489.5 217.5 301.43 S 320.84 S 341.76 S 364.31S 388.47 S 226.70W 242.81W 260.17W 278.51W 297.75W 2095.2 42.87 218.58 7.41 2131.2 45.07 218.33 4.41 2165.9 47.11 217.86 4.14 2199.3 48.92 218.05 3.62 2231.8 50.06 218.36 2.34 2139.2 508.4 522.3 217.5 2175:2 542.3 557.0 217.6 2209.9 577.4 593.0 217.6 2243.3 613.7 630.1 217.6 2275.8 650.8 668.2 217.7 414.14 S 441.33 S 469.68 S 498.98 S 528.85 S 318.18W 339.77W 361.99W 384.84W 408.36W 2263.8 50.43 218.69 0.90 2295.6 50.54 219.06 0.60 2327.3 50.81 219.36 0.72 2358.7 51.34 219.44 1.06 2388.9 54.19 218.44 5.92 2307.8 688.3 706.6 217.7 2339.6 726.1 745.2 217.8 2371.3 764.0 783.8 217.9 2402.7 802.1 822.7 217.9 2432.9 841.0 862.5 218.0 558.92 S 588.95 S 618.93 S 648.98 S 679.94 S 432.30W 456.51W 480.96W 505.65W 530.67W 2417.4 56.52 217.80 4.78 2444.0 59.18 217.49 5.35 2468.9 60.97 217.43 3.58 2492.3 63.20 217.62 4.47 2514.6 63.95 217.65 1.49 2461.4 881.2 903.6 218.0 2488.0 922.4 946.0 218.0 2512.9 964.6 989.3 217.9 2536.3 1007.6 1033.5 217.9 2558.6 1051.2 1078.3 217.9 712.30 S 745.82 S 780.22 S 815.26 S 850.72 S 556.06W 581.91W 608.26W 635.17W 662.51W 2536.5 64.11 ~ 217.71 0.35 2558.3 64.11 217.81 0.17 2579.9 64.62 217.89 1.03 2600.9 65.69 217.81 2.14 2580.5 1095.0 1123.2 217.9 886.29 S 2602.3 1138.8 1168.2 217.9 921.86 S 2623.9 1182.7 1213.3 217.9 957.45 S 2644.9 1226.9 1258.6 217.9 993.28 S 689.99W 717.53W 745.19W 773.03W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 2621.1 66.75 217.83 2.13 2640.5 67.58 217.81 1.66 2659.3 68.18 217.87 1.21 2677.7 68.58 218.19 0.99 2696.0 68.55 218.60 0.77 2714.1 69.07 218.75 1.07 2731.7 69.65 218.74 1.16 2748.7 70.67 217.82 2.68 2764.9 71.54 217.39 1.93 2780.5 71.98 217.42 0.87 2795.9 72.17 217.51 0.42 2811.6 71.35 216.47 2.56 2827.5 71.54 216.02 0.94 2843.3 71.65 215.94 0.28 2858.9 71.91 215.92 0.51 2874.4 71.97 215.98 0.15 2890.4 70.66 215.25 2.95 2907.0 70.66 214.88 0.70 2923.1 71.68 214.77 2.06 2938.5 72.52 214.61 1.71 2954.1 70.98 214.16 3.20 2970.5 70.82 214.26 0.36 2987.3 69.92 214.90 2.17 3004.6 69.53 215.54 1.43 3022.7 68.07 216.26 3.22 3041.2 68.56 216.37 0.99 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 2665.1 1271.5 1304.4 217.9 2684.5 1316.4 1350.5 217.9 2703.3 1361.6 1396.8 217.9 2721.7 1406.9 1443.3 217.9 2740.0 1452.4 1489.8 217.9 2758.1 1498.0 1536.4 217.9 2775.7 1543.7 1583.2 218.0 2792.7 1589.6 1630.3 218.0 2808.9 1635.7 1677.6 218.0 2824.5 1681.9 1725.0 217.9 2839.9 1728.2 1772.6 217.9 2855.6 1774.3 1820.1 217.9 2871.5 1820.2 1867.5 217.9 2887.3 1866.1 1914.9 217.8 2902.9 1912.0 1962.4 217.8 2918.4 1957.9 2009.9 217.7 2934.4 2003.6 2057.2 217.7 2951.0 2049.0 2104.3 217.6 2967.1 2094.5 2151.6 217.6 2982.5 2140.3 2199.1 217.5 2998.1 2185.8 2246.5 217.4 3014.5 2231.1 2293.7 217.4 3031.3 2276.3 2340.8 217.3 3048.6 2321.5 2387.6 217.3 3066.7 2366.6 2434.2 217.2 3085.2 2411.5 2480.7 217.2 HORIZONTAL COORDINATES feet 1029.42 S 1065.82 S 1102.40 S 1139.02 S 1175.50 S 1211.89 S 1248.38 S 1285.30 S 1322.78 S 1360.50 S 1398.26 S 1436.19 S 1474.41S 1512.81S 1551.26 S 1589.75 S 1628.25 S 1666.86 S 1705.71S 1744.83 S 1784.02 S 1823.09 S 1861.87 S 1900.18 S 1937.94 S 1975.38 S 801.09W 829.35 W 857.76W 886.40W 915.30W 944.43 W 973.72W 1002.85W 1031.72W 1060.57W 1089.51W 1118.08W 1146.11W 1173.98W 1201.85W 1229.76W 1257.34W 1284.45W 1311.47W 1338.55W 1365.37W 1391.93W 1418.66W 1445.70W 1473.04W 1500.55W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS A Gyrodata Directional Survey SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 3059.1 69.36 216.38 1.61 3077.1 68.42 217.22 2.46 3095.8 67.88 217.81 1.53 3114.5 68.10 218.12 0.72 3132.9 68.79 218.17 1.37 3103.1 2456.7 2527.3 217.2 3121.1 2502.0 2574.0 217.2 3139.8 2547.2 2620.4 217.2 3158.5 2592.4 2666.7 217.2 3176.9 2637.8 2713.2 217.2 2012.95 S 2050.30 S 2087.11S 2123.66 S 2160.23 S 1528.23W 1556.17W 1584.43W 1612.94W 1641.66W 3150.6 69.54 218.25 1.52 3167.9 70.00 218.22 0.92 3185.7 68.45 218.14 3.10 3204.0 68.43 218.36 0.41 3222.2 68.92 218.33 0.98 3194.6 2683.4 2760.0 217.2 3211.9 2729.2 2806.9 217.3 3229.7 2774.8 2853.6 217.3 3248.0 2820.2 2900.1 217.3 3266.2 2865.7 2946.7 217.3 2196.95 S 2233.81S 2270.55 S 2307.07 S 2343.60 S 1670.57W 1699.60W 1728.50W 1757.28W 1786.18W 3240.0 69.47 218.25 1.12 3257.2 70.37 218.16 1.81 3273.8 70.66 218.40 0.73 3290.6 70.10 218.80 1.34 3307.9 69.53 218.59 1.21 3284.0 2911.3 2993.4 217.3 3301.2 2957.1 3040.4 217.3 3317.8 3003.1 3087.5 217.4 3334.6 3049.2 3134.6 217.4 3351.9 3095.1 3181.5 217.4 2380.29 S 2417.19 S 2454.19 S 2491.00 S 2527.62 S 1815.14W 1844.18W 1873.38W 1902.77W 1932.10W 3325.6 68.87 218.06 1.66 3343.5 69.26 218.08 0.78 3361.0 69.80 218.14 1.08 3377.9 70.77 218.10 1.95 3394.0 71.64 218.14 1.74 3369.6 3140.7 3228.2 217.4 3387.5 3186.3 3274.9 217.4 3405.0 3232.0 3321.8 217.4 3421.9 3277.9 3368.8 217.4 3438.0 3324.1 3416.2 217.4 2564.29 S 2601.06 S 2637.92 S 2674.95 S 2712.19 S 1961.09W 1989.88W 2018.79W 2047.85W 2077.06W 3410.1 70.74 218.26 1.82 3426.4 71.27 218.48 1.14 3442.8 70.40 219.32 2.35 3459.3 70.99 219.49 1.21 3475.5 71.29 219.46 0.61 3454.1 3370.3 3463.5 217.5 3470.4 3416.4 3510.8 217.5 3486.8 3462.6 3558.0 217.5 3503.3 3508.9 3605.1 217.5 3519.5 3555.3 3652.4 217.5 2749.38 S 2786.45 S 2823.21S 2859.67 S 2896.19 S 2106.33W 2135.68W 2165.33W 2195.29W 2225.36W 3491.9 70.24 218.94 2.31 3509.2 69.42 218.76 1.68 3535.9 3601.6 3699.6 217.6 3553.2 3647.5 3746.5 217.6 2932.78 S 2969.33 S 2255.20W 2284.64W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 3526.4 70.22 218.78 1.60 3543.0 71.16 218.78 1.88 3559.5 70.32 218.15 2.05 3576.4 70.06 217.82 0.81 3594.1 68.51 217.62 3.13 3612.5 68.36 217.83 .0.50 3631.0 68.23 217.56 0.57 3649.5 68.28 217.16 0.76 3668.0 68.18 217.78 1.18 3686.6 68.16 218.67 1.65 3705.0 68.76 219.05 1.39 3723.0 69.00 219.32 0.70 3740.6 69.76 219.47 1.54 3758.2 68.93 219.05 1.83 3776.4 68.54 218.69 1.04 3794.5 68.89 220.22 2.94 3812.1 69.82 222.26 4.24 3829.2 70.24 224.67 4.61 3845.9 70.85 226.15 3.05 3862.2 70.95 228.51 4.47 3878.6 70.87 230.63 4.00 3895.2 70.33 232.75 4.15 3911.9 70.52 233.88 2.16 3928.9 69.87 234.86 2.26 3946.4 69.17 236.13 2.75 3964.3 68.91 237.95 3.44 3981.9 69.93 239.97 4.31 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 3570.4 3693.4 3793.5 217.6 3587.0 3739.5 3840.6 217.6 3603.5 3785.6 3887.8 217.6 3620.4 3831.5 3934.9 217.6 3638.1 3877.1 3981.6 217.6 3656.5 3922.4 4028.1 217.6 3675.0 3967.6 4074.6 217.6 3693.5 4012.8 4121.0 217.6 3712.0 4058.0 4167.5 217.6 3730.6 4103.3 4213.9 217.6 3749.0 4148.8 4260.4 217.6 3767.0 4194.5 4307.0 217.7 3784.6 4240.4 4353.8 217.7 3802.2 4286.2 4400.5 217.7 3820.4 4331.8 4447.1 217.7 3838.5 4377.5 4493.7 217.7 3856.1 4423.6 4540.4 217.8 3873.2 4470.2 4587.1 217.8 3889.9 4517.2 4633.9 217.9 3906.2 4564.3 4680.5 218.0 3922.6 4611.6 4726.8 218.1 3939.2 4658.7 4772.6 218.2 3955.9 4705.8 4818.1 218.4 3972.9 4752.7 4863.4 218.5 3990.4 4799.4 4908.2 218.7 4008.3 4845.8 4952.5 218.9 4025.9 4892.1 4996.5 219.0 HORIZONTAL COORDINATES ~et 3005.92 S 3042.71 S 3079.66 S 3116.74 S 3153.73 S 3190.51 S 3227.27 S 3264.19 S 3301.04 S 3337.51 S 3373.72 S 3409.87 S 3446.04 S 3482.26 S 3518.54 S 3554.51 S 3589.69 S 3623.79 S 3656.89 S 3688.9O S 3719.54 S 3748.78 S 3776.92 S 3804.33 S 3830.86 S 3856.26 S 3880.39 S 2314.02W 2343.58W 2372.94W 2401.89W 2430.50W 2458.95W 2487.36W 2515.54W 2543.79W 2572.51W 2601.69W 2631.16W 2660.86W 2690.47W 2719.71W 2749.31W 2780.16W 2812.48W 2846.06W 2880.80W 2916.76W 2953.76W 2991.54W 3029.78W 3068.37W 3107.55W 3147.65W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 3998.6 70.89 241.44 3.36 4015.7 69.24 241.97 3.46 4033.7 68.38 242.18 1.77 4052.0 68.85 241.82 1.17 4069.9 69.14 242.11 0.79 4087.3 70.15 243.55 3.37 4104.1 70.53 244.03 1.18 4120.6 70.93 244.17 0.84 4136.7 71.64 243.86 1.53 4152.3 71.81 243.27 1.18 4167.8 72.19 242.60 1.48 4183.2 71.88 241.96 1.36 4199.1 70.98 241.54 1.97 4216.5 68.36 240.96 5.36 4235.0 68.21 240.49 0.92 4253.8 67.64 240.11 1.35 4272.8 67.78 239.52 1.12 4291.6 67.91 239.20 0.65 4309.9 69.27 240.49 3.61 4327.2 70.11 241.72 2.86 4344.1 70.49 241.22 1.20 4360.8 70.58 240.75 0.91 4377.4 70.60 240.48 0.50 4394.1 70.26 239.98 1.17 4411.1 70.09 239.47 1.01 4428.0 70.42 239.93 1.08 A Gyrodata Directional Survey, VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 4042.6 4938.5 5040.3 219.2 4059.7 4984.7 5083.8 219.4 4077.7 5030.4 5126.9 219.6 4096.0 5076.1 5169.9 219.8 4113.9 5121.9 5213.2 220.0 4131.3 5167.7 5256.5 220.2 4148.1 5213.6 5299.7 220.4 4164.6 5259.5 5342.9 220.6 4180.7 5305.6 5386.4 220.8 4196.3 5351.9 5430.2 221.0 4211.8 5398.4 5474.4 221.2 4227.2 5445.0 5518.8 221.4 4243.1 5491.5 5563.3 221.6 4260.5 5537.6 5607.4 221.7 4279.0 5583.4 5651.4 221.9 4297.8 5629.1 5695.4 222.0 4316.8 5674.8 5739.4 222.2 4335.6 5720.6 5783.7 222.3 4353.9 5766.5 5828.1 222.4 4371.2 5812.6 5872.5 222.6 4388.1 5858.9 5917.1 222.7 4404.8 5905.3 5961.9 222.9 4421.4 5951.8 6006.8 223.0 4438.1 5998.2 6051.8 223.1 4455.1 6044.7 6096.9 223.3 4472.0 6091.2 6142.1 223.4 HORIZONTAL COORDINATES feet 3903.44 S 3925.72 S 3947.55 S 3969.41S 3991.35 S 4012.75 S 4033.55 S 4054.17 S 4074.91S 4096.05 S 4117.69 S 4139.82 S 4162.25 S 4184.80 S 4207.51S 4230.47 S 4253.73 S 4277.32 S 4300.70 S 4323.36 S 4345.84 S 4368.71S 4391.85 S 4415.24 S 4438.95 S 4462.69 S 3188.73W 3230..12W 3271.31W 3312.42W 3353.62W 3395.32W 3437.56W 3480.02W 3522.59W 3565.10W 3607.44W 3649.55W 3691.30W 3732.40W 3772.92W 3813.17W 3853.16W 3893.00W 3933.25 W 3974.30 W 4015.66W 4056.88 W 4097.97W 4138.87W 4179.49 W 4220.12W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 4444.4 71.12 242.88 5.75 4460.2 72.19 244.98 4.52 4475.1 73.03 248.36 6.67 4489.5 73.55 249.07 1.70 4503.6 73.81 248.59 1.06 4488.4 6137.6 6187.0 223.5 4504.2 6183.8 6231.5 223.7 4519.1 6229.7 6275.4 223.9 4533.5 6275.2 6318.9 224.0 4547.6 6320.9 6362.5 224.2 4485.28 S 4506.13 S 4525.02 S 4542.40 S 4559.73 S 4261.57W 4304.20 W 4348.01 W 4392.63 W 4437.37W 4517.4 74.12 246.69 3.70 4530.9 74.57 245.96 1.68 4544.3 74.35 245.72 0.64 4557.8 74.32 245.29 0.82 4571.9 72.81 244.27 3.61 4586.7 72.70 243.75 1.03 4601.8 72.26 243.27 1.25 4617.3 71.55 243.23 1.43 4634.3 68.81 243.00 5.50 4652.2 69.01 242.93 0.43 4561.4 6366.8 6406.6 224.4 4574.9 6413.2 6451.3 224.6 4588.3 6459.7 6496.2 224.7 4601.8 6506.3 6541.2 224.9 4615.9 6552.8 6586.3 225.0 4630.7 6599.3 6631.5 225.1 4645.8 6645.8 6676.8 225.3 4661.3 6692.2 6722.0 225.4 4678.3 6738.2 6766.8 225.5 4696.2 6783.8 6811.3 225.6 4578.01S 4597.34 S 4617.06 S 4637.02 S 4657.45 S 4678.37 S 4699.64 S 4721.04 S 4742.30 S 4763.51S 4481.81W 4525.91W 4569.86W 4613.67W 4657.06W 4699.98W 4742.65W 4785.09W 4827.04W 4868.60W 4670.1 69.13 242.89 0.25 4688.0 69.05 242.37 0.99 4705.8 69.03 242.16 0.39 4723.7 69.12 241.60 1.06 4741.6 68.92 241.05 1.11 4714.1 6829.4 6855.9 225.7 4732.0 6875.2 6900.6 225.9 4749.8 6920.9 6945.4 226.0 4767.7 6966.7 6990.4 226.1 4785.6 7012.6 7035.4 226.2 4784.77 S 4806.25 S 4827.98 S 4849.99 S 4872.39 S 4910.17W 4951.65W 4992.98W 5034.17W 5075.13W 4759.7 68.61 240.49 1.20 4778.0 68.50 240.24 0.53 4795.7 69.92 241.86 4.16 4812.6 70.65 242.46 1.84 4828.7 71.69 243.73 3.18 4803.7 7058.5 7080.5 226.3 4822.0 7104.4 7125.7 226.4 4839.7 7150.4 7170.9 226.4 4856.6 7196.6 7216.2 226.5 4872.7 7242.8 7261.6 226.7 4895.15 S 4918.16 S 4940.78 S 4962.76 S 4984.18 S 5115.80W 5156.25W 5197.15W 5238.77W 5280.97W 4844.6 71.45 243.61 0.53 4888.6 7289.0 7307.0 226.8 4860.4 71.57 243.23 0.75 4904.4 7335.3 7352.4 226.9 5005.22 S 5026.44 S 5323.48W 5365.89W A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 4876.2 71.59 242.93 0.57 4892.0 71.49 242.40 1.02 4908.0 71.22 241.93 1.04 4920.2 7381.6 7398.0 227.0 4936.0 7428.1 7443.6 227.1 4952.0 7474.5 7489.4 227.2 5047.91S 5069.69 S 5091.81S 5408.19W 5450.32W 5492.22W 4924.1 71.29 241.60 0.64 4940.8 69.58 241.29 3.46 4958.8 68.29 240.73 2.79 4978.2 66.06 239.70 4.84 4998.9 64.91 238.71 2.92 4968.1 7521.0 7535.2 227.3 4984.8 7567.3 7580.9 227.3 5002.8 7613.2 7626.2 227.4 5022.2 7658.7 7671.2 227.5 5042.9 7703.7 7715.7 227.6 5114.21S 5136.73 S 5159.34 S 5182.23 S 5205.52 S 5533.93W 5575.31W 5616.12W 5656.12W 5695.19W 5021.0 62.83 237.95 4.39 5043.8 62.70 237.64 0.61 5067.3 61.48 238.93 3.33 5091.2 61.29 239.97 1.88 5115.7 59.99 241.81 4.13 5065.0 7748.2 7759.8 227.6 5087.8 7792.3 7803.6 227.7 5111.3 7836.1 7847.0 227.8 5135.2 7879.5 7890.0 227.8 5159.7 7922.4 7932.5 227.9 5229.09 S 5252.78 S 5276.01S 5298.32 S 5319.52 S 5733.40W 5771.01W 5808.60W 5846.40W 5884.47W 5140.9 59.48 242.80 1.99 5167.2 57.08 244.44 5.56 5194.9 55.68 245.50 3.31 5223.8 53.54 245.42 4.27 5254.1 51.99 244.49 3.44 5184.9 7964.7 7974.3 228.0 5211.2 8006.1 8015.3 228.0 5238.9 8046.5 8055.1 228.1 5267.8 8085.9 8094.0 228.2 5298.1 8124.5 8132.2 228.3 5339.59 S 5358.49 S 5376.11S 5393.04 S 5409.89 S 5922.70W 5960.80W 5998.52W 6035.59W 6071.66W 5285.3 50.85 243.61 2.65 5317.5 48.78 243.92 4.18 5351.0 47.24 243.54 3.13 5385.9 44.30 242.84 5.98 5421.9 43.49 242.93 1.61 5329.3 8162.6 8169.8 228.4 5361.5 8199.8 8206.6 228.4 5395.0 8236.0 8242.5 228.5 5429.9 8271.0 8277.1 228.6 5465.9 8304.9 8310.7 228.6 5426.99 S 5443.87 S 5460.32 S 5476.47 S 5492.27 S 6106.80W 6141.07W 6174.39W 6206.37W 6237.22W 5459.0 40.76 245.09 6.20 5497.2 39.63 245.57 2.33 5536.4 37.02 247.23 5.61 5576.7 35.65 248.73 3.28 5503.0 8337.5 8343.1 228.7 5541.2 8368.8 8374.0 228.8 5580.4 8398.6 8403.5 228.8 5620.7 8426.9 8431.5 228.9 5506.98 S 5520.45 S 5532.88 S 5543.99 S 6267.35W 6296.67W 6325.08W 6352.54W B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 5618.1 32.62 252.27 7.23 5660.6 30.77 255.53 5.05 5704.0 28.90 256.18 3.79 5748.0 27.91 254.21 2.72 5792.5 25.95 252.77 4.13 5837.9 23.75 250.93 4.66 5883.8 22.96 246.97 3.52 5930.2 21.07 242.30 5.15 5977.1 19.08 237.87 5.00 6024.7 16.44 234.64 5.64 6073.0 13.64 233.38 5.64 6121.9 10.64 236.31 6.11 6171.1 9.79 238.37 1.87 6220.4 9.43 240.94 1.12 6269.8 9.00 245.28 1.63 6319.2 8.90 245.93 0.29 6368.6 8.84 246.63 0.25 6418.0 8.60 246.93 0.49 6467.4 8.14 246.84 0.92 6516.9 8.12 246.53 0.09 6566.4 9.00 244.96 1.81 6615.7 9.34 243.74 0.79 6665.1 8.88 245.07 1.02 6714.5 9.23 246.79 0.88 6763.8 9.30 248.31 0.51 6813.2 9.53 250.99 0.99 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 5662.1 8453.3 8457.6 229.0 5704.6 8477.5 8481.4 229.0 5748.0 8500.0 8503.6 229.1 5792.0 8521.7 8525.0 229.2 5836.5 8542.6 8545.6 229.2 5881.9 8562.2 8565.0 229.3 5927.8 8581.0 8583.7 229.3 5974.2 8599.1 8601.7 229.4 6021.1 8616.1 8618.6 229.4 6068,7 8631.2 8633.7 229.4 6117.0 8644.2 8646.6 229.4 6165.9 8654.7 8657.1 229.4 6215.1 8663.5 8665.9 229.4 6264.4 8671.7 8674.1 229.4 6313.8 8679.5 8681.9 229.5 6363.2 8687.0 8689.3 229.5 6412.6 8694.5 8696.7 229.5 6462.0 8701.8 8704.0 229.5 6511.4 8708.7 8710.9 229.5 6560.9 8715.5 8717.7 229.5 6610.4 8722.7 8724.8 229.5 6659.7 8730.5 8732.5 229.5 6709.1 8738.2 8740.2 229.6 6758.5 8745.8 8747.7 229.6 6807.8 8753.5 8755.4 229.6 6857.2 8761.2 8763.1 229.6 HORIZONTAL COORDINATES feet 5553.38 S 5560.68 S 5566.76 S 5572.83 S 5579.26 S 5585.79 S 5592.89 S 5600.89 S 5609.41 S 5617.85 S 5625.46 S 5631.54 S 5636.33 S 5640.55 S 5644.18 S 5647.39 S 5650.49 S 5653.48 S 5656.33 S 5659.13 S 5662.19 S 5665.64 S 5669.07 S 5672.27 S 5675.35 S 5678.19 S 6378.96W 6404.18W 6428.30W 6451.29W 6473.00W 6492.97W 6511.47W 6528.40W 6543.28W 6555.97W 6566.47W 6575.04W 6582.50W 6589.70W 6596.83W 6603.91W 6610.97W 6617.93W 6624.62W 6631.11W 6637.90W 6645.08W 6652.22W 6659.41W 6666.85W 6674.52W 10 A Gyrodata Directional Survey B.P. Exploration Well: MPF-81, 4.5" Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK0600GCE514SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet. deg. 6862.5 9.87 251.40 0.69 6911.7 9.88 251.26 0.05 6906.5 8769.1 8770,9 229.6 6955.7 8777.2 8778.9 229.7 FinalStation Closure: Distance: 8778.86 ft Az: 229.65 deg. HORIZONTAL COORDINATES feet 5680.91 S 5683.65 S 6682.50W 6690.62W 11 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER' AK0600GCE514 TOOL NUMBER' 789 MAXIMUM GYRO TEMPERATURE ' 82.94 C MAXIMUM AMBIENT TEMPERATURE · 72.49 C MAXIMUM INCLINATION' 74.57 AVERAGE AZIMUTH ' 201.82 WlRELINE REZERO VALUE ' ADD 32' REZERO ERROR/K' N/A CALIBRATION USED FOR FIELD SURVEY' 2833 CALIBRATION USED FOR FINAL SURVEY' 2833 PRE JOB MASS BALANCE OFFSET CHECK: -.76 POST JOB MASS BALANCE OFFSET CHECW · -.86 USED .00 CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG · UPON COMPLETION OF SURVEY' OK OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 12494 9.86 249.57 6914.3 -5553.2 -6777.9 FINAL SURVEY 12500 9.87 251.40 6906.5 -5680.9 -6682.5 FUNCTION TEST JOB NUMBER' AK0600GCE514 5 Survey stations were collected at the measured depth shown belOw. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft I 2 3 4 5 1100 13.49 13.49 13.49 13.49 13.49 AZIMUTH M.D. ft 1 2 3 4 5 1100 223.72 223.69 223.87 223.91 223.84 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK0600GCE514 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 789 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0172 POWER SUPPLY C0237 PRINTER C0242 INTERFACE A0527 A0107 A0079 A0143 BACKUP TOOL No. 795 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0084 POWER SUPPLY C0159 PRINTER C0212 INTERFACE A0433 A0085 A0029 A0165 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.5" HOUSING W/ECCENTRIC BAR AND ROLLERS ON BOTTOM TOTAL LENGTH OF TOOL: 26' MAXIMUM O.D.: 3.5" INCHES TOTAL WEIGHT OF TOOL: 250 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK0600GCE514 MONDAY, 06/19/00 11:15 TO SLOPE 13:00 ARRIVE SLOPE 23:00 CHECK TOOLS/O.K./ TUESDAY,06/20/00 06:00 07:15 08:30 08:45 11:30 13:45 14:30 16:00 20:00 22:30 24:00 TO LOCATION ARRIVE LOCATION MU TOOL/WARM UP TOOL/PICK UP TOOL/RIH SURVEY IN TO 12550' SURVEY OUT/ LD TOOL. BD TOOL RETURN TO ATLAS CHECK TOOLS/PROCESS SURVEY RETURN TO MILNE POINT W/RESULTS DEADHORSE WEDNESDAY,06/21/00 07:00 STANDBY FOR NEXT JOB. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Chairman ,~/~.. THRU: Blair Wondzell ~,~ P.I. Supervisor Petroleum Inspect6g NON- CONFIDENTIAL DATE: Aug, 10, 2000 SUBJECT: Blowout Preventer Test Nabors AK. Drlg. 4-ES BPX/F-Pad Milne Point # F-81 200-066 Kuparuk River FieldlMPU Operator Rep.: Tom Abbott Contractor Rep.: Gene Sweat Test Pressures Rams: 250/3500 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P ,,, Housekeeping: P Rig cond: P PTD On Location P Hazard: P Standing Order: P Op. phone: 659-4154 Rig phone: 659-4563 Op. e-mail: pbudrlgrig4es@bp.com Rig e-mail: pburig4estp@bp.com Annular: 250/3500 Choke: 250~3500 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 N/T Pit Level Indicators P P Lower Kelly 1 N/T Flow Indicator P F Ball Type 1 P Meth Gas Detector P P Inside BOP 1 P H2S Gas Detector P P BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 135/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 2 7/8x5 P Quantity P/F System Pressure 3000 P Lower Pipe Rams N/A No. Valves 11 P After Closure 1700 P Blind Rams 1 B/S P Man. Chokes 1 P 200 psi Attained 65 sec. P Choke Ln. Valves 1 3 1/8 P Hyd. Chokes 1 P Full Pressure 3.2 min. P HCR Valves 2 3 1/8 P Blind Covers (All Stations): P Kill Line Valves 1 3 1/8 P N2 Bottles (avg.): 4@ 1550 P Check Valve N/A Test Details Thursday, August 10, 2000: I traveled to BPX's MPU # F-81 well that was being worked over by Nabors Rig 4-ES where I witnessed the initial BOPE test. The rig personnel were ready to test on my arrival and performed the tests in a safe and proficient manner. The testing lasted 3 hours with four failures. The flow alarm at the driller's console failed to activate the audible alarm, but was repaired and passed the re-test. The accumulator readback pressure gauge on the rig floor did not indicate accurate pressure, due to a failed transducer. The accumulator unit had a leaking 4-way valve and the annular pressure gauge on the trait was inoperable. These items will be repaired and re-tested prior to continued operations. The upper and lower Kelly valves were not tested at this time because the Kelly will not be used during the completion of this well, but will be tested and documented before it's next use. A random test of the gas detectors was performed with no failures. I presented Tom Abbott (BPX Rep.) and Gene Sweat (Nabors Drlg. Rep.) with a draft copy of the H2S Preparation Checklist for comments and consideration, and we discussed it at length. Summary: I witnessed the initial BOPE test on Nabors Rig 4-ES performing a pump change on BPX's MPU # F-81. Problems were encountered with the accumulator pressure gauges, a 4-way valve and the audible flow alarm at the driller's console. Total Test Time: 3 hrs. Number of failures: cc: MPU Drilling Engineer 4 Attachments: 0 Vu28s6f8.xls 8/14/00 C%'~,~Lqlii *::.] o_;i-..] ~1 Geo~uesf 3~d0 Arcfic BlYd Ancherege, AK ~$03 ,A, TTH: Sherrie NO. 281 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 6/27/00 Well Job # Log Description Date BL Sepia CD MPF-81 !PRODUCTION LOG 000621 1 1 MPJ-15 ~. ~(0"~,c{ 20227 RST 000511 1 . 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: dUN 2T ZOO0 .... r',,mmin_e, inll Alaska Oil & Gas uu,,o ............ Anchorage Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al-tN: Sherrie MPF-81 Permit to Drill Subject: MPF-81 Permit to Drill Date: Tue, 23 May 2000 03:00:37 +0100 From: "Triolo, Mike T" <TrioloMT~BP.com> To: "'Blair Wondzell'" <blair_wondzell~admin.state.ak.us> CC: "Mallary, Chuck (ARCO)" <MallarCR~BP.com>, "Hubble, Terrie L (NANA)" <HubbleTL~BP.com> Blair, As per our telephone conversation on 5/22/00 @ 4:20 pm I am requesting the MPF-81 Permit to Drill to be approved by~.[_25/00. This request is due to actual rig modifications taking substantiali~--i*ess time to complete then originally expected and the subsequent desire to start early. Thanks in advance for your understanding. Michael (Mik) Triolo BP Amoco/SSD Operations Drilling Engineer MB 8-1 900 East Benson Blvd. Anchorage, Ak. 99508 Work phone: 564-5774 Pager: 275-9875 1 of 1 5/23/00 9:37 AM ALASI~A OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chuck Mallary Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-81 BP Exploration (Alaska) Inc. Permit No: 200-066 Sur Loc: 1967'NSL, 3029'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc. 1676'NSL, 4703'WEL, Sec. 12, T 13N, R09E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ ~ %/x day of May, 2000 dlf/Enclosurcs cc~ Dcparllncn! of Fish & Galne. Habitat Section w/o encl. Department of Environmental Conservation xv/o encl. STATE OF ALASKA ALASKA _ AND GAS CONSERVATION COMM 51ON ~/i ~,~ ~ PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 29.5' Milne Point Unit / Kuparuk 3. Address 6. Property Designation River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 388235 ~.. 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1967' NSL, 3029' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 1677' NSL, 4670' WEL, SEC. 12, T13N, R09E, UM MPF-81 Number 2S100302630-277 At total depth 9. Approximate spud date 1676' NSL, 4703' WEL, SEC. 12, T13N, R09E, UM 06/01/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355023, 575' MDI No Close Approach 1920 12822' MD / 7189' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' MD Maximum Hole Angle 72 o Maximum surface 3447 psig, At total depth (TVD) 7001' / 4252 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Weiqht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 30" 20" 54.5# K-55 Welded 78', Surface Surface 78' 78' ;~60 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 7460 30' 30' 7468' 4146' 965 sx AS 3 - Liter 204 sx Class 'G' 8-1/2" 7" 26# L-80 BTC 12520' 30' 30' 12523' 6896' 157 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 BTC 500' 12320' 6698' 12822' 7189' 49 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner RECEIVED 05 2000 Perforation depth: measured Alaska 0il & Gas Cons, C0mmissi0~ true vertical Al!Cfl01'~e 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Michael Trio/o, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that th/e~re/~~/true/a~l' c~rrect to the best of my knowledge . . Signed Chuck Mallary ~.~ Title Senior Drilling Engineer Date ' 7 '" Permit Number - , I APl Number _ ~k_,/--'"' _ I Annroval Date I See cover letter ,~Z~ - ~~:~ I 50- 4:)~--'~'-''' ,-:~.,~--?.~'-' 4::)(~ I "'~ I for other requirements Conditions of Approval: Samples Required r-I Yes ,l~,No Mud Log Required [] Yes j~o Hydrogen Sulfide Measures [] Yes .,~"'No Directional Survey Required ,J~,Yes [] No Required Working Pressure for BOPE I-! 2K; r"l 3K; D 4K; ~5K; I-'1 10K; r-115K Other: ORIGINAL SIGNED BY by order of Approved By D Taylor Seamount Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate 9-518" Centralizer Placement: 1. Run (1) bow spring centralizer per joint on the first 15 joints. 2. Centralizers should be attached between a tool joint and a stop collar. 3. Run 1 Bow Spring centralizer on either side of the Port collar. 7" Centralizer Placement: 1. 2. 4-1/2" Centralizer Placement: 1. 2. Other Cement Considerations: 1. 2. 3. Run (1) rigid straight vane centralizer per joint on the first 25 joints. Centralizers should be attached between a tool joint and a stop collar. Run (1) rigid straight vane centralizer per joint, do not run any in the liner lap. Cent. should be run to float in the center of the joint between two stop collars. Mix the slurries on the fly (Batch mix if < 100 bbl). Confirm blends and calculations at the rig site. There will be a TAM Port Collar in the 9-5/8" casing at 1,000' MD for a surface cement contingency plan in the event cement does not reach surface on the primary job. If cement does not reach surface, an inner-string will be run with a port collar shifting tool to engage the port collar and pump the second stage cement job to obtain cement to surface. Survey and Logging Program: Surface Hole: Dir/GR~Ei~-~ [ .~'!~ i'~/~ i--- Intermediate Hole: Dir/GR/Res/PWD(real time) ;.i,':.Y 05 2000 Production Hole: DirlGRIReslDenlNeu(DenlNeu recorded only) ,Anch0ra_~e Perforating' Will be perforated Post-Rig via E.line conveyed 2-7/8" guns, Locations Kuparuk A Sands Perf Interval: Approximately 20' of perfs for limited entry frac Gun Size / Type: 2-7/8" (SWS), 6 SPF, 60° phasing, big hole charges Delivery: E-line Under Balance: 1,000 psi BHP: 4,252 @ 7,000' TVDss BHT: 165°F MPF-81 Operations Snapshot Summary Drill and Case Program' 1. MIRU Doyon 141. 2. NU 21-1/4" diverter, pick up 5" DP 3. MU 12-1/4" BHA, spud in drill to planned Surface hole TD (7,468' md). 4. Run 9-5/8", 40#, L-80, BTC casing and cement to surface. 5. ND diverter, NU Gen 5 wellhead & 13-5/8" BOP, test. 6. MU 8-1/2" BHA, drill out float equipment plus 30' of new formation, perform FIT (minimum 11.5 ppg EMW). 7. Drill to planned Intermediate hole TD (12,523' md). 8. Run 7", 26#, L-80, BTC casing and cement to 1,000' above the Kuparuk formation. 9. MU 6-1/8" BHA, drill out float equipment plus 30' of new formation, perform FIT (minimum 12.6 ppg EMW). 10. Drill to planned Production hole TD (12,822' md). 11. Run 4-1/2", 12.6#, L-80, BTC casing and cement (bring cement over Liner Top Paker). 12. Run 4 W', 12.6#, L-80, IBT workstring assembly. 13. Install TWC. 14. ND BOP, NU tree, test to 5,000 15. Remove TWC, install BPV, freeze protect and set packer. 16. RD, move offwell. Version #2, 5/4/00 5 "Drill-Out" FIT's will be specified in the well plan Post Rig Work Program: 1. Perforate 2. Frac 3. Coil clean-out 4. Frac flowback 5. Chemical cut 4.5" workstring above liner top packer 6. Set shear out plug in XN profile 4ES Completion Program: 1. MIRU Nabors4ES 2. Pull 4.5" workstring 3. Run Dual ESP completion on 2-7/8", 8rd EUE tubing 4. Freeze protect 5. ND/NU release Rig Post Ri_~ Work Program: 1. Pump out shear out plug Formation Integrity Test Procedure: 1. Determine the required surface pressure. 2. In the case of a surface casing shoe, a PPG EMW should be sufficient unless the well plan notes differently. 3. Test the casing prior to drilling out the float collar. i) Run the mud pump at a constant 0.25--0.5 bpm and record results. One-stroke pressure readings are recommended, but in all cases record pressures in at least five-stroke increments. If the pressures are increasing rapidly enough to make this reading too large, take pressure readings at 30-second intervals. Plot the results for reference during the following LOT. ii) When the required test pressure is reached, suspend pumping and hold the test pressure for thirty minutes. Check that the test is being accurately recorded on a chart. 4. Drill remaining cement, float collar, float shoe and 20-ft to 50-ft of new hole. i) Note: In cases where mud weight will be reduced at a minimum of 0.5 PPG after drilling out for the next hole interval, a drill out formation integrity test may be used. In this case, the 20-ft to 50-ft of new hole will be exposed to the higher mud weight and a flow check performed for a minimum of 10 minutes. If no losses are observed during the flow check, a conventional FIT is not required. The drill out FIT may only be used if stated as such in the drilling permit for the respective well. 5. Circulate and condition mud to a constant mud weight and rheology. 6. Pull into the casing shoe. 7. Close a blowout preventer. 8. Run the mud pump at a constant 0.25 to 0.5 bpm. 9. Match the pump rate to the one used during the previous casing pressure test. 10. Stop the pump when the required test pressure is reached. 11. Close appropriate valves if surface leaks are suspected. 12. Hold and record the pressure every 30 seconds for 10 minutes minimum. 13. In the event that the pressure continues to bleed off without becoming constant continue to hold and record the pressures at 30 second intervals for another 5 minutes. Surface equipment should be checked for leaks and if any found the test redone. 14. Check to ensure that the chart recorder is accurately recording the test. 15. Bleed back mud from the well and compare with the volume pumped. Record volume in trip tank or cement tanks. 16. Document the FIT results on the IADC sheet and on next morning report. For consistency among rigs, use the Excel spreadsheet LOT Version 5.0 (on the Drilling File Server in the LOT folder) to plot the casing and leak off tests. Immediately send the leak-off test plot and pressure recorder charts to the office to be stored with the rest of the reports in the well file. If there is any question about the interpretation of the FIT results, inform the drilling superintendent before drilling ahead Version #2, 5/4/00 6 ~ ~.hared ~ ~ervices ~~k-'~a ~rilling RECEIVED ~ i,:,'? 05 2000 Alaska Oil & Gas Cons, Comn~issiori ~cflorage MPF-81 Grassroots Producer Permit Endorsed y: ~ Ops. Drilling Engineer Date Senior Drilling Engineer Version #2, 5/4/00 1 IWell Name: I MPF-81 Well Plan Summary Type of Well (producer or Injector): I Oil Producer Surface Location: Target Start (T1): Intermediate Bottom Hole Location: (TD) 1,967' NSL, 3,029' WEL, Sec. 06, T13N, R10E X: 541,534.68 Y = 6,035,417.63 1,677' NSL, 4,670' WEL, Sec. 12, T13N, R09E, UM X: 534,763 Y: 6,029,813 Z: 6,895' TVDss 1,676' NSL, 4,703' WEL, Sec. 12, T13N, R09E, UM X = 534,730 Y = 6,029,812 Z = 7,153' TVDss I AFE Number: I 337182 ] I Rig: J Doyon 141 Estimated Start Date: J June 1, 2000 I I Operating days to complete: I 24.69 MD I 12,822' I ITvDrkb: I7,189' I J KBE: 129.5' Well Design (conventional, slim hole, etc.): ] Conventional Producer (grass roots well) !Objective: Drill 12-1/4" hole out of 20" conductor, build angle to 69° hold tangent for 4,200' to base of the Schrader Bluff Reservoir (7,468' MD; 4,105' TVDss). Run and cement 9- 5/8" surface pipe to surface, drill out with 8-1/2" hole, continue to hold tangent for 2,600', at which time start dropping angle to 12° to be lined out above the top Kuparuk B-sand (12,523' MD; 6,856' TVDss). Run and cement 7" Intermediate casing, drill out with 6-1/8" bit to TD 12,822' MD; 7,149 TVDss, run and cement 4- 1/2" production liner. Will complete the well with 4 W', 12.6.#, L-80 tbg with packer for a post rig perforation and frac job. The well is designed for oil production from the Kuparuk A sands. Asset Production/Injection Forecast: Estimated Reserves: 1.08 MMSTBO Expected Initial Rate: 900 BOPD/1800 BFPD Expected 6 month avg: 850 BOPD Well Information: Well Name: APl Number: Well Type (proposed): BHP: BHT: Mechanical Condition: MPF-81 Cellar box: RKB to Cellar box: Rig Elevation: Conductor: MPF-81 Oil Producer 4,185 psi @ 6,895' TVDss, top Kuparuk A sands (est. from offset wells) ~11.7ppg EMW 165°F @ 7,000' TVDss Elevation above MSL: 11.0' 29.5' (Estimated) RKB + MSL = 41.5' 78' of 20", 54.5#, K-55 ¢',: 7 0 5 2.000 Anchorage Version #2, 5/4/00 2 Drilling Program Overview Surface and Anti-Collision Issues: Surface Shut-in Wells: None required. Close Approach Wells: Well Name None NONE - All wells may flow. ICurrent Status I Production Priority Precautions , I Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 4,252 psi, 7,001' TVDss (estimated) 11.7 ppg Max Exp Surface Pressure 3,447ps~ (.115 psi/ff gas gradient) BOPE Rating 5,000 psi WP (Entire stack & valves) Planned BOPE Test Pres. 5,000/250 psi Rams and Valves 5,000/250 psi Annular Note: The wellbore will be drilled from surface to the Base Schrader Bluff through a 21-1/4", 2,000 psi surface diverter stack (expected Schrader resersoir pressure: 1,721-1,840 psi). The diverter will be removed and an 13-5/8", 5M BOP stack will be installed and tested prior to running in the hole with the 8-1/2" drilling assembly. Mud Program: A detailed Baroid mud program is included with the well plan. In summary, an LSND water based mud system will be used for this well. Follow the attached LCM Decision Matrix for this well in the event losses occur. Surface Hole: 12 1/4" Hole to 7,468' TMD (9 5/8" Casing) (Deep Set Surface - No Gas Hydrates Anticipated) Suggested Mud Properties Ranqes ~ ~ ~ Density Funnel Yield 10 Sec 10 Min pH APl Solids ~ '~,~,,,¢'~,,,.,, ,~, (ppg) Viscosity Point Gels Gels Filtrate (% LGS) 8.6 50 15 8 10 9 8 <9 ~i,~,¥ 05 2..000 to to to to to to to 9.6 150 35 15 30 10 15 AJask¢ f~i & Oas Co~'!;!~ Intermediate Hole: 8 1/2" Hole to 12,523' TMD (7" Casing) Suggested Mud Properties Ranqes Density Funnel Yield 10 Sec 10 Min pH APl HTHP Solids (ppg) Viscosity Point Gels Gels Filtrate Flit. (cc's) (% LGS) 8.6 35 6 3 7 8.5 6-12 <6 to to to to to to to 9.6 45 20 10 20 9.5 4-6 10-12 (f/top HRZ) Production Hole: 6 1/8" Hole to 12,822' TMD (4 1/2" Liner) Suggested Mud Properties Ranqes Density Funnel Yield (ppg) Viscosity Point 11.5 45 20 to to to 12.1 55 30 10 Sec 10 Min pH APl HTHP Solids Gels Gels Filtrate Flit. (cc's) (% LGS) 6 7 8.5 4 10 <6 to to to to to 10 12 9.5 6 12 (200 deg. F) As the plan is currently, we will drill out of the 7" casing with an 11.5 ppg mud weight and adjust that mud weight as required by actual open hole conditions. Waste Disposal: No annular injection is allowed at Milne point. All drilling waste will be hauled to KRU 'IR' pad or PBU Drillsite 4. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be prepared. Version #2, 5/4/00 3 Formation Markers' Formation Tops MD TVDss Pore EMW (ppg) Comments Pressure (psi) ~ . . .,.~ .~ Base Permafrost 1896 1800 Top Schrader 6611 3825 1721 8.65 Base Schrader 7420 4090 1840 8.65 Top HR~TUDZ 12024 6368 Base HRZ 12095 6437 KLGM 12182 6522 TKUD (Kup Caprock) 12351 6687 3344 9.6 Pick 7" casing point by depth when at bottom of D shale, top of B sand inte¢ace Expected D shale thickness is 165' ~D Kuparuk C NP This zone ~s not expected to be present. Kuparuk B 12524 6856 3428 9.6 Do not enter more than 10' into B sand, there may be silts that could be over- pressured to the same pressure as expected in the A sand.. Kuparuk A 12563 6895 3948-4185 11.0-11.7 T~3 12571 6902 3950-4190 11.0-11.7 T~2 12587 6918 3960-4200 11.0-11.7 T~I 12617 6947 3977-4215 11.0-11.7 Miluveach 12672 7001 4010-4252 11.0-11.7 TD 12822 7149 TMLV + 150' MD Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Casing Casing Top Hole Btm Tbg O.D. Length MD/TVDrkb MD/TVDrkb 12-1/4" 9-5/8" 40# L-80 BTC 7,460' 30'/30' 7,468'/4,146' 8-1/2" 7" 26# L-80 BTC 12,520' 30'/30' 12,523'/6,896' 6-1/8" 4-1/2" 12.6# L-80 BTC 500' 12,32076,698' 12,822'/7,189' Cement Calculations: casing Size 19-518", 40#, BTC I Basisl 80' shoe jts, 30% excess ~n open hole, 250% ~n permafrost (12-1/4" hole), cement to surface. I Shoe Depth: 7,468' MD (4,146' TVDrkb), ' Total Cement Volume: I Spacer I 75 bbls of B45 Viscosified (1.5%) Spacer Weighted to 10 PPg. Lead 965 sxs (763.2 bbls), ArcticSet 3 - Lite, Yield 4.44 ft3/sx, mix fluid 20.1 gps, 10.7 ppg Tail 204 sxs (42.2 bbls), Class 'G' + 0.3% D65 + 0.5% S001 + 0.40% D167 + 0.2% D46, Yield 1.16 ft3/sx, mix fluid 5.08 gps, 15.8 ppg Temp BHST ~90u F from SOR, BHCT 65° F estimated by Dowell ICasing Size I 7", 26#, BTC I Basis 80' shoe jts, 30% excess ~n open hole, cement to 1,000' above shoe. Shoe Depth: 12,523' MD (6,896' TVDrkb), ITotalCementVolume: I Spacer 150bblsofB45ViscosifiedSpacerWeightedto1.0ppgoverMW. Tail 157 sxs (33 bbls), Class 'G' + 0.27% D65 + 0.25% D167 + 0.25% DS00 + 0.1 gps D47, Yield 1.16 ft3/sx, mix fluid 4.991 gps, 15.8 ppg Temp BHST ~170v F from SOR, BHCT 140° F estimated by Dowell JLiner Size 14-112", 12.6#, BTC J BasisI 80' shoe jts, 30% excess in open hole, cement to above LTPkr. I TD: 12,822' MD (7,189' TVDrkb), Liner Top Paker: 12,320' MD (6,698' TVDrkb) Total Cement Volume: Spacer I 30 bbls of B45 Viscosified Spacer Weighted to 1.0 ppg over MW. TailI 49 sxs (11 bbls), Class 'G'+ 0.27% D65 + 0.25% D167 + 0.27% D800 + 0.1 gps D47, Yield 1.16 ft3/sx, mix fluid 4.991 gps, 15.8 ppg Temp BHST ~170° F from SOR, BHCT 140u F estimated by Dowell Version #2, 5/4/00 4 filc:///Untitlcd Summary of Drillin~ Hazards Abnormal pressures are present both in and sometimes above the Kuparuk reservoir zone and have required significantly higher mud weights then originally expected. There has never been any hydrates, shallow gas, or unexpected shallow hydrocarbon problems on F-pad. Lost circulation is unlikely. We do not expect stuck pipe. This Pad is not a designated H2S pad. See the detailed analysis for more information. MPF-81 Drilling Hazards and Contingencies I. Well Control A. At the end of the 8-1/2" Intermediate hole, we will be drilling close to the interface between the Kuparuk D shale and the Kuparuk B sand for the 7" casing shoe. The 7" casing landing point will be determined by depth based on changes in GR/Res curves associated with entering into the top of the Kuparuk D shale and then stopping at a predetermined depth so that the bit is near the B sand/D-shale interface. A recent study of the D shale interval shows a continuous thickness of 165' TvD throughout the area, therefore the 7" casing point will be set to avoid any contact with the B sand interval, but covering as much of the D shale as possible. We will be crossing a major fault before the 7" casing point, prior to entering the HRZ. Therefore, it will be possible to have a good indication stratigraphy wise where we are after we cross the fault before we are in any danger of entering the B sand. II. Kick tolerance A. It has been assumed that the Kuparuk interval is over pressured. Therefore the proposed top set of the reservoir has been planned as described above. Several kick tolerance calculations were made, see results below: . . . Surface Casing (9-5/8" Shoe): a) The kick tolerance with 9.6 ppg mud is at least 78 bbls. This assumes a fracture gradient of 11.5 ppg back at the 9-5/8" shoe. Higher fracture gradients and deeper weak points give even larger kick tolerances. b) The maximum pressure which can be safely tolerated is 9.8 ppg. This was derived by back solving for the pore pressure which results in a 56 bbl kick tolerance with 9.6 ppg mud in the hole. This assumes that the weak point is the 9-5/8" casing shoe, and the highest frac gradient of 11.5 ppg EMW. The reason why the 11.5 frac gradient has been selected is due to the breathing threshold of the interval between the Schrader and the HRZ commonly called the Seabee (Colville) interval. Intermediate Casing (7" Shoe): a) If the Kuparuk pressure is 11.7 ppg (maximum anticipated pressure), the kick tolerance with 11.5 ppg mud is infinite. This assumes a fracture gradient of 12.6 ppg back at the 7" shoe. This is the minimum frac gradient that must be obtained in order to drill this well. b) If the Kuparuk is penetrated with 11.5 ppg mud and the pressure is equal to the most recent pressure of F-80 (10.4 ppg EMW, minimum anticipated pressure), the kick tolerance is also infinite. c) If the Kuparuk pressure is 11.1 ppg (anticipated pressure), the kick tolerance with 11.5 ppg mud is infinite. This assumes a fracture gradient of 12.6 ppg back at the 7" shoe. d) The maximum reservoir pressure which can be safely tolerated is 11.7 ppg. This was derived by back solving for the pore pressure which results with a infinite kick tolerance with 11.5 ppg mud in the hole. This assumes that the weak point is the 7" casing shoe, and the highest frac gradient of 12.6 ppg EMW. The 12.6 frac gradient has been selected because it is the minimum frac gradient needed to handle the highest expected reservoir pressure. On MPL-36 an FIT was conducted in 1997 in the D-shale at the 7" casing shoe to 16 ppg. In summary, the MPF-81 grassroots well has adequate kick tolerance in the intermediate hole with a interval pressure of up to 9.8 ppg. Continued drilling operations are not advised if the interval pressure exceeds 9.8 ppg. At interval pressures above 9.8 ppg breathing or lost circulation can be expected while circulating out a kick. The well has adequate kick tolerance in the production hole with a reservoir pressure of up to 11.7 ppg. Continued drilling operations are not advised if the Kuparuk formation pressure exceeds 11.7 ppg with a shoe frac gradient of 12.6 ppg or lower. Version 2.0 MPF-81 Hazards and Contingencies Page ! of 3 III. Lost Circulation/Breathing ^. We do not expect to have lost circulation on this well, however there is a potential for losses while drilling through the major fault we will be crossing directly above the HRZ. The lost circulation potential is Iow for MPF-81. Most lost circulation events at 'F' pad have been related to breathing and lifting cement behind production casing. 1. In the event we do occur losses, follow the attached LOST CIRCULATION DECISION MATRIX provided by Baroid. Break circulation slowly in all instances and get up to recommended circulating rate slowly for placing cement. 2. Breathing is well documented at Milne Point between the Schrader Bluff and the HRZ when ECD's reach 11.5 ppg. Hydraulics modeling for MPF-81 predicts a clean hole ECD of 10.5 ~ 10.6 ppg with a TD mud weight of 9.6 ppg. 3. If well bore breathing occurs on MPF-81, the Shared Services Drilling RP "Well Bore Breathing" will be followed. As stated in that RP, it is SSD policy that any flow from the well will be treated as a well control problem until a definitive well bore breathing diagnosis is made. IV. Reservoir Pressure A. Past drilling in the area documents several instances of over pressure in wells drilled from 'F & L' pads to BHL's in adjacent fault blocks. Abnormal pressures are present both in and sometimes above the Kuparuk zone and have required significantly higher mud weights then originally expected. These high pressure intervals are suspected to be as a result of water and gas injection from the Greater Kuparuk Area. Due to this inherent risk, it has been decided to top set the reservoir with the 7" intermediate casing in the D shale and weight up and drill the Kuparuk interval. B. MPF-81 is expected to be abnormally pressured to between 3,800 - 4,250 psi or 10.4 - 11.7 ppg. Recent empirical data supporting this conclusion includes two April 2000 extrapolated shut-in bottom hole pressures (from PHD) of 3,798 and 3,808 psi and the initial SBHP of 4250 in March 1998. This data is supported by material balance calculations. The MPF-81 hydraulic unit (302) is believed to be bounded by sealing and partially sealing faults (see attached 'MPF-81 Proposed Tract 22 Producer'S. If this subsurface interpretation is correct, MPF-80 in the NW adjacent hydraulic unit (301) may have already partially depleated this unit, thus we would expect the pressure to be closer to that of F-80. If there is no communication between these two hydraulic units, then it is possible to see either a virgin reservoir pressure of 3500 psi or over-pressured as described above. C. From an abnormal pressure and well control standpoint, the primary risk associated with the MPF-81 well would be if there were over-pressured silt stringers in the Kuparuk D shale like on MPC-12A. Geologic interpretation suggests that this will not be the case as there is no evidence of any silt stringers in the D shale on any of the nearby penetrations and during the recent drilling of MPF-80. V. VI. A. Stuck Pipe According to the Pad Data Sheet, several wells have had stuck pipe incidents at the approximate interface between the Kalubik and the D shale, only one incident resulted in a plug back and sidetrack, the rest came free and drilling was resumed. The well plan incorporates stuck pipe prevention primarily via the mud program: weighting up to 9.6 ppg above the 'D'-Shale and dropping the HTHP both are designed to stabilize the lower shales and prevent stuck pipe. The mud program and drilling practices, especially hole cleaning, are fundamental to stuck pipe prevention for all Milne Point wells. B. If pipe does get stuck, go immediately to the SURE manual, determine the stuck pipe mechanism, and follow the recommendations in the SURE manual. DO NOT JAR UP if packed-off! Pad Data Sheet A. Please Read the F-Pad Data Sheet Thoroughly. I i,:.¥ 05 2000 Version 2.0 MPF-81 Hazards and Contingencies Page 2 of 3 VII. Hole Cleaning and Hole conditions: A. This well has a 4,200' 70° tangent section above the 9-5/8" casing setting point and a 2,600' 71° tangent section coming out of the 9-5/8" shoe, and then dropping off into the reservoir. Good hole cleaning practices and ECD management will be critical in ensuring that formation cuttings are removed from the well. While drilling, utilize PWD to monitor hole cleaning efficiency. B. Monitor and record torque and drag data closely to check against modeling to help determine what level of differential sticking or cuttings beds may be occurring during drilling. VIII. Hydrogen Sulfide A. MPF-Pad is not a designated H2S Pad. IX. Faults A. The planned directional trajectory crosses one fault, but the well is above the HRZ at this crossing. The fault is believed to have a significantly large throw but is believed to be of little concern from a drilling standpoint. The well trajectory has been designed to intersect the fault as close to the optimal intersection angle (90°) to avoid any formation unconsolidation problems. X. Close Approach A. There are no down hole or surface close approach issues with the MPF-81 WP #6 directional trajectory. No well shut-in's or down hole securing operations are required to safely drill the well. Version 2.0 MPF-81 Hazards and Contingencies Page 3 of 3 TREE: 4" FMC, 5M WELLHEAD: FMC Gen 5, 5M Tubing Hanger: 10" x 4-1/2" with 4" adaptor flange Proposed MPU F-81 - Post Drilling Rig Rev. A Based on Well Plan # 6-2 DOY©N 141: Orig. KB Elev. = Orig. GL Elev. = Conductor Caing 20" 54.5 ppf, K-55 29.5' 11' KOP @ ~400' MAX HOLE Angle ~70 to 72° AT ~3137 to 10,000' MD Surface Casing I 9-5/8", 40 ppf, L-80 ~7,468' 4-1/2" 12.6 ppf, IBT, L-80, Work String 2000 Stimulation Summary_ not performed yet Perforation Summary Interval (TVD) Kup 'A' Sand not shot yet DATE !2-15-00 REV. BY COMMENTS TC ~roposed Post Drilling Rig Completion Drilling Rig will leave 4-1/2" work string and seawater in the well. Perfs, SBHP, Frac, Cleanout, Frac flow back, and TD tag will all be performed without a rig on the well. Nabors 4ES will then move on to remove the 4-1/2" work string and install the initial ESP completion Gas Lift Mandrel w/dummy valve 7" Baker So3 packer 4.5 ....XN" nipple 4.5" WLEG ~ Liner Packer 1"~12,300,1 Liner Hanger ~ 7" 26 ppf, L-60, Mod. Btrc. prod. casing 4.5" 12.6 ppf, L-80, ITC - Mod Liner 4.5' Landing Collar (PBTD) 4.5" float collar 4.5" float shoe 2,822'I MILNE POINT UNIT WELL No.: F-81 APl' 50-029-XXXXX BP EXPLORATION 6,035.580 6,036,e08 6.035,500 6,035,000 6,034,500 .6,03~,808 6,833,588 6,833,808 6.032.500 6.832.880 6.831.500 6.031.000 6.830,588 6.838.880 6.829.508 I I x,,, ;6875- I 6" 690q~ 6.829.888 ' MPF ® , \ ~6909 . '~ ~ 925 6875 6. 828. 588 t \ G. 836.5~ G.83G.SE 6,835.5~ G.B35.SE G.834.5~ 6.83'~l.8~ 6.033.5~ 6,833.8~ 6. 032.5~ ¢.831 .$[ 02~. 5~ 028. S~ 531.888 531.588 53Z,888 532.588 533,886 533,588 53'~, 888 53q, 588 535,888 535,588 536,888 536,588 537.888 537,500 BP EXPLORATION (ALA~dU lNG:. FEET 0 588 1000 FEET STRTUTE MILES g · 1 .2 SIRTUTE NILES I r I MPF-81 PROPOSED TRRCT-22 PRODUCER TKUR DEPTH STRUCTURE CI - 25 FT Proposed Completion MPU F-81 TREE: 2-9/16" FMC 5M Rev. A Based on Well Plan # 6-2 WELLHEAD: FMC Gan 5, 5M ....... DOYON 141: Tubing hanger: 2-7/8" w/2 ESP Orig. KB Elev. = 29.5' penetrators [ Orig. GL Elev. = 11' Conductor Caing 20" 54.4 ppf, K-55 II sidepocketCamc° 2 7/8"XKBMMI" GLM MAX HOLE Angle -70 to 72°~. Camco 2 7/8" x 1 . I " AT-3137 to 10,000' MD sidepocket KBMM GLM · Surface Casing , ~ s~ 9-5/8", 40 ppf. L-80 I -7468' He "X" Nipple (2.313" id ) Camco 2 7/8" x 1" . t Dual ESP Crossover Block sidepocket KBMM GLM I 7604' I Has "X" Nipple (1.875" id ) Cenblllft 21 Itg. FCNP~H FPMTAR 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. cenl~llt400 8e~la~ Tandem Gaa Cenlltla 400 Cenldl~ FMH 222~ v, lt, 3g am~ PHD 'a~-FIn 8taler I ! GPMTAR t:1 0 , CenlHIIf KMH M., 1. HP, I 2145 velt, 52 ant~ Cenldllt HL PHD va~-FIn ~lablllzer I 12,200';' J [~ ILiner Packer 1~12,300' Stimulation Summary Liner Hanger Frac. N100,000 Proppant I Perforation Summary 7" 26 ppf, L-80, Mod. Btrc. prod. casing Size SPF Interval (TVD) Kup 'A' Sand ~-7/8 6 -12,650-~2,670 20' total _~ _-= 4.5" 12.6 ppf, L-80, ITC - Mod Liner ,~. 4.5" Landing (PBTD) 1~12,822,I Collar 4.5" float collar 4.5" float shoe , DATE REV. BY COMMENTS MILNE POINT UNIT' :~-15-00 TC Proposed initial Completion WELL No,: F-81 APl' 50-029-XXXXX ,,, , BP EXPLORATION (AK) I STUDDED TCP/FLANGED BO1TOW FI. ANGE/FI.~NGE BX .160 ,~ s/~'. scoo PS,. m' ,P~ OPERATORS HYDRIL PiPE RAW BOP STACK ELEVATION ~..__~ 1§' FLG'D VENT UNE SURFACE OlVERTER CONFIGURATION ACCUMULATOR: KOOMEY, TYPE-80, 180 GAL, 6 STATION TRIPLEX PUMPi 600 VAC, 20 HP AIR PUMP: NL SHAFFER ,ACCUMULATOR MANIFOLD 20 BO1FLES, 11 GALLONS EACH NITROGEN BACKUP BOTTLES "" / / ~ ~o~LEs, ~2s cu. rt., ~ ~o~o k .L ) ~ I ~DOED ~P/~GED BORON - ~ I ~/~u~ ~m s,c~) ) VALVE LEGENb BYPASS KILL CHOKE 801-FOM RAMS BLIND RAMS TOP PiPE RAMS , , ANNULAR I),~NIFCLD PREqSURFJIA¢CUWU~TO~' PRESSUREIANNULAR mRES---'gR[ 0 0 J~,lC. ~E OFC.~FAS~' o REMOTE PANEL IN ~OGHOU~F- AND. U~LITY MODULE Doyon RIG 141 BOP ,~¥~,TEM AND CONTROL North Slope Alaska Alaska State Plane 4 Milne Point MPF D~I~[QuE~S:~ MPF-81 :~ ~ 1200 - 2400 - 3600 - 4800 - 6000 - .- 7200 - liegin Dir @ 1.000°/100ft: 396.50ft MD, 396.50ft TVD crease in Dir Rate @ 1.500°/100ft: 596.50ft MD, 596.46ft TVD crease in Dir Rate @ 2.000°/100ft: 896.50ft MD, 895.56ff TVD ncrease in Dir Rate @ 2.500°/100ft: 1196.50ft MD, 1191.31ft TVD 1896.50ft MD, 1841.18ft TVD Current Well Properties Well: MPF~I Horizontal Coordinates: Ref. Global Coordinates: 6035417.63 N, 54153&68 E Ref. Structure Reference: 5404.71 N, 9750.61 E Ref. Geographical Coordinates: 70° 30' 27.6603" N, 149° 39' 36.6300" W RKB Elevation: 40.50ft above Mean Sea Level 40.50ft above Structure Reference North Reference: True North Units: Feet 'D~r' @'4.DUO'II OOTt' .~ 2'1~r3.515'ff MD; "2046.'50fl q'V[Y ............................................................. Base Permafi'ost - 1840.50 TVD Proposal Data for MPF-8'I Wp6-2 Vertical Odgin: MPF-81 Horizontal Origin: MPF-81 Measurement Units: ft North Reference: True North Dogleg severity: Degrees per 100fl Vertical Section Azimuth: 230.784° Vertical Section Descdp0on: MPF-61 Vertical Section Odgin: 0.00 N,0.00 E Measured Incl. Azim. VerticalNorthings Eastings Vertical Dogleg Depth Depth SectionRate 0.00 0,0000.320 0.00 0.00 N 0.00 E 0.00 29.50 0.0000.320 29.50 0.00 N 0.00 E 0,00 1).0011 396.50 0.0000.320 396.50 0.00 N 0.00 E 0.00 0.000 596.50 2.000218.000596.46 2.75 S 2.15 W 3.40 1.000 896.50 6.500218.000895.56 20.27 S 15.83 W 25.08 1.500 1196.5012.500 218.0001191.31 59.27 S 46.30W 73.34 2.000 1896.5030.000 218.0001841,18 258.41 S 201.89 W319,80 2.5011 2133.583¢1.000 218.0002046.50 351.82 S 274.88 W435.41111.000 3133.5870.000 218.0002676.31 943.29 S 736.98 W1167.384.000 6589.167O.000 218.0003858.19 3502.10 S2736.14 W 4334.060.000 7223.2771.800 244.8034069.11 3871.16 S3199.70 W 4926.544,000 10024.39 71.8011 244.8034944.00 5004.04 S5607.48 W 7508.280.000 11859.01 12.175 244.7766246.96 5503.38 S6668.52 W 8646.043,250 12563.40 12A75244.7766935.50 5566.68 S6802.91 W 8790.190,0110 12671.62 11.092 244.7767041.50 5575.98 S6822.65 W 8811.361.000 12821.62 9.592244.7767189.06 5587.46 S6847.01 W 8837.49t.0110 MD, 2676.31ft TVD 2000 Dir @ 4.000°/100ft: 6589.16ft MD, 3858.19ft TVD ; ~uGg.Tl'ff TVD ...................................................................... Top Schrader - 3865..50 TVD 9 5/8" Casing - 7467.84 MD, 4135.50 TVD OWC- 3990.50 7'VD Base Schrader- 4130,50 7'VI.) Dir @ 3.250°/100ft: 10024.39ft MD, 4944.00ft TVD ..................................................................................................................................................................... '5566.5~8'S~ ~$02.'g1' }¢' ........ MPF-81 Target 2 7193.50 TVD 5567.50S, 6835.92 Dir: 11859.01ft MD, 6246.96ft TVD Liner - 12523.50 MD, 6896.50 TVD ................... [,op H.i~%.:: TU!)_~ -_~4~1.¢,,50 TVD ................. oase HRZ - 04//.301113 .................. KLGM - 6562.50 TVD 'Begin Dir @ 1.000°/100ft: 12563.40ft MD 6935.50ft TVD ............... E'KUD (Ku/~artt[~- Cat'rock) - 6727.50 7'V~ Kuparuk B - 6896.50 TVD ................. K.u. paruk .4 - 6935.50 I'VD '."-"'.'!:!!'.".'-!'.' TKA3 - 69{2.50 TVD TKA2 - 6938.50 TVD TIC41 - 6987.50 TVI) Miluveuch - 7041.50 TI'D Total Depth: 12821.62ft MD. 7189.06ft TVD 4 1/2" Liner - 12821.62 MD, 7189.06 TVD I I I I I I I I I 0 1200 2400 3600 4800 6000 7200 8400 9600 Scale: linch = 1200ft Vertical Section Section Azimuth: 230.784° (True North) North Slope Alaska Alaska State Plane 4 Milne Point MPF MPF-81 ~ -1000 - -2000 -- 1:-3000 - Z -4000 - -5000 - -6000 - Scale: linch = 1000ft -7000 -6000 I I Eastings -5000 -4000 -3000 I I I -2000 -1000 I / J [.)ir ~1 DOg 1 it 3 5j D 3 0 · e'vi 00 : ' 0 ' 6. D Increase in ~i}~Pate ~(¢1.500°/100ft: 59~.~0ff ~4~, ~9~.4~f~ t~¥[ Increase in Dir Rate@ 2.000°/100ft: 896.50ft MD, 895.56ft TVD Increase in Dir Rate @ 2.500°/100ft: 1196.50ft MD, 1191.31ff TVD End Dir: 1896.50ft MD, 1841.18ft TVD Begin Dir @ 4.000°/100ft: 2133.58ft MD, 2046.50ft TVD \ End Dir: 3133.58ft MD, 2676.31ft TVD Begin Dir @ 4.000°/100fl: 6589.16ft MD, 3858.19fl TVD End Dir: 7223.27ft MD, 4069.1 lft TVD 9 5/8" Casing - 7467.84 MD, 4145.50 TVD MPF-81 TI 6935.50 TVD 5566. 68 S, 6802. 91 W Begin Dir @ 3.250°/100ft: 10024.39ft MD, 4944.00ft TVD End Dir: 11859.01ft MD, 6246.96ft TVD 7" Liner - 12523.50 MD, 6896.50 TVD Begin Dir @ 1.000°/100ft: 12563.40ft MD, 6935.50ft TVD Total Depth: 12821.62ft MD, 7189.06ft TVD 4 1/2" Liner - 12821.62 MD, 7189.06 TVD MPF-81 Target 2 7193.50 TVD 5567.50S, 6835.92 IV I I I -7000 -6000 -5000 Scale: linch = 1000ft I -4000 I -3000 Eastinqs 2000 1 I I -2000 -1000 0 Reference is True North -0 - -1000 - -2000 --3000 1: O Z -- -4000 - -5000 --6000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (f~) (ft) 0.00 0.000 0.000 -40.50 29.50 0.000 0.000 -11.00 200.00 0.000 0.000 159.50 396.50 0.000 0.000 356.00 400.00 0.035 218.000 359.50 500.00 1.035 218.000 459.49 596.50 2.000 218.000 555.96 600.00 2.052 218.000 700.00 3.552 218.000 800.00 5.052 218.000 896.50 6.500 218.000 559.46 659.33 759.05 855.06 900.00 6.570 218.000 858.53 1000.00 8.570 218.000 957.66 1100.00 10.570 218.000 1056.26 1196.50 12.500 218.000 1150.81 Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 1200.00 12.587 218.000 1154.22 1300.00 15.087 218.000 1251.31 1400.00 17.587 218.000 1347.27 1500.00 20.087 218.000 1441.91 1600.00 22.587 218.000 1535.04 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~) (~) (~) (~) (~) 0.00 0.00 N 0.00 E 6035417.63 N 541534.68 E 29.50 0.00 N 0.00 E 6035417.63 N 541534.68 E 200.00 0.00 N 0.00 E 6035417.63 N 541534.68 E 396.50 0.00 N 0.00 E 6035417.63 N 541534.68 E 400.00 0.00 N 0.00 E 6035417.63 N 541534.68 E 499.99 0.74 S 0.58W 6035416.89 N 541534.11 E 596.46 2,75 S 2.15W 6035414.87 N 541532.55 E 599.96 2.85 S 2.23W 6035414.77 N 541532.47 E 699.83 6.70 S 5.24W 6035410.90 N 541529.48 E 799.55 12.61S 9.85W 6035404.96 N 541524.90 E 895.56 20.27 S 15.83W 6035397.28 N 541518.96 E 899.03 20.58 S 16.08W 6035396.96 N 541518.72 E 998.16 30.96 S 24.19W 6035386.54 N 541510.67 E 1096.76 44.06 S 34.42W 6035373.38 N 541500.50 E 1191.31 59.27 S 46.30W 6035358.11 N 541488.71 E 1194.72 59.86 S 46.77W 6035357.51N 541488.24 E 1291.81 78.71 S 61.49W 6035338.58 N 541473.63 E 1387.77 100.87 S 78.81W 6035316.32 N 541456.43 E 1482.41 126.32 S 98.69W 6035290.76 N 541436.70 E 1575.54 154.99 S 121.09W 6035261.97 N 541414.46 E Dogleg Rate (°/i00~) 0.o00 0.000 0.00o 1.000 1.000 1.000 1.500 1.500 1.500 1.500 2.000 2.000 2.000 2.000 2.50O 2.500 2.500 2.500 2.500 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) 0.00 0.00 0.00 0.00 0.00 0.91 3.40 3.52 8.29 15.61 25.08 25.47 38.31 54.53 73.34 74.09 97.41 124.84 156.32 191.80 Comment Beqin Dir ~ 1.000°/100ft: 396.50ft MD, 396.50ft TVD Increase in Dir Rate ~ 1.500°/100ft: 596.50ff MD, 596.46ft TVD Increase in Dir Rate ~ 2.000°/100ft: 896.50f[ MD, 895.56ft TVD Increase in Dir Rate ~ 2.500°/100ft: 1196.5'0'ft MD, 1191.31ft TVD Continued... 4 May, 2000 - 8:37 - 1 - DrillQuest 1.05.05a .T 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (fi) 1700.00 25.087 218.000 1626.51 1800.00 27.587 218.000 1716.12 1895.71 29.980 218.000 1800.00 1896.50 30.000 218.000 1800.68 2000.00 30.000 218.000 1890.31 2133.58 30.000 218.000 2006.00 2200.00 32.657 218.000 2062.73 2300.00 36.657 218.000 2144.97 2400.00 40.657 218.000 2223.04 2500.00 44.657 218.000 2296.57 2600.00 48.657 218.000 2365.19 2700.00 52.657 218.000 2428.58 2800.00 56.657 218.000 2486.41 2900.00 60.657 218.000 2538.42 3000.00 64.657 218.000 2584.34 3100.00 68.657 218.000 2623.96 3133.58 70.000 218.000 2635.81 3200.00 70.000 218.000 2658.53 3400.00 70.000 218.000 2726.93 3600.00 70.000 218.000 2795.34 3800.00 70.000 218.000 2863.74 4000.00 70.000 218.000 2932.15 4200.00 70.000 218.000 3000.55 4400.00 70.000 218.000 3068.95 4600.00 70.000 218.000 3137.36 Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings (~) (~) (~) (~) (~) 1667.01 186.83 S 145.97W 6035229.99 N 541389.76 E 1756.62 221.79 S 173.28W 6035194.88 N 541362.64 E 1840.50 258.10 S 201.65W 6035158.40 N 541334.47 E 1841.18 258.41 S 201.89W 6035158.09 N 541334.23 E 1930.81 299.19 S 233.75W 6035117.14 N 541302.60 E 2046.50 351.82 S 274.88W 6035064.27 N 541261.78 E 2103.23 379.03 S 296.13W 6035036.95 N 541240.67 E 2185.47 423.84 S 331.14W 6034991.95 N 541205.92 E 2263.54 473.05 S 369.59W 6034942.52 N 541167.74 E 2337.07 526.43 S 411.30W 6034888.90 N 541126.33 E 2405.69 583.73 S 456.06W 6034831.36 N 541081.89 E 2469.08 644.66 S 503.66W 6034770.16 N 541034.63 E 2526.91 708.93 S 553.87W 6034705.62 N 540984.78 E 2578.92 776.21S 606.44W 6034638.04 N 540932.58 E 2624.84 846.20 S 661.12W 6034567.75 N 540878.30 E 2664.46 918.53 S 717.64W 6034495.10 N 540822.19 E 2676.31 943.29 S 736.98W 6034470.23 N 540802.99 E 2699.03 992.47 S 775.40W 6034420.84 N 540764.84 E 2767.43 1140.57 S 891.11W 6034272.10 N 540649.96 E 2835.84 1288.67 S 1006.82W 6034123.35 N 540535.08 E 2904.24 1436.77 S 1122.52W 6033974.61 N 540420.21 E 2972.65 1584.86 S 1238.23W 6033825.87 N 540305.33 E 3041.05 1732.96 S 1353.94W 6033677.13 N 540190.45 E 3109.45 1881.06 S 1469.64W 6033528.38 N 540075.58 E 3177.86 2029.16 S 1585.35W 6033379.64 N 539960.70 E Dogleg Rate (°/lOOn) 2.500 2.500 2.500 2.500 0.000 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPF Ve~ical Section (fi) 231.21 274.48 319.42 319.80 370.27 435.40 469.08 524.52 585.43 651.49 722.40 797.81 877.34 960.61 1047.22 1136.74 1167.38 1228.24 1411.52 1594.80 1778.08 1961.36 2144.64 2327.92 2511.20 Comment Base Permafrost End Dir' 1896.50ft MD, 1841.18ft TVD Beqin Dir ~.4.000°/100ft: 2133.58ft [viD, 2046.50ft TVD End Dir' 3133.58ft MD, 2676.31ft TVD Continued... 4 May, 2000 - 8:37 - 2 - DrillQuest 1.05,05a 2.000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 4800.00 70.000 218.000 3205.76 5000.00 70.000 218.000 3274.17 5200.00 70.000 218.000 3342.57 5400.00 70.000 218.000 3410.97 5600.00 70.000 218.000 3479.38 5800.00 70.000 218.000 3547.78 6000.00 70.000 218.000 3616.19 6200.00 70.000 218.000 3684.59 6400.00 70.000 218.000 3752.99 6589.16 70.000 218.000 3817.69 6600.00 69.997 218.461 3821.40 6610.53 69.995 218.910 3825.00 6700.00 70.026 222.718 3855.59 6800.00 70.157 226.970 3889.66 6900.00 70.388 231.212 3923.43 6979.64 70.643 234.581 3950.00 7000.00 70.718 235.440 3956.74 7100.00 71.145 239.648 3989.42 7200.00 71.666 243.833 4021.32 7223.27 71.800 244.803 4028.61 7400.00 71.800 244.803 4083.81 7419.81 71.800 244.803 4090.00 7467.84 71.800 244.803 4105.00 7600.00 71.800 244.803 4146.28 7800.00 71.800 244.803 4208.75 Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings (~) (~) (~) (~) (~) 3246.26 2177.25 S 1701.06W 6033230.90 N 539845.82 E 3314.67 2325.35 S 1816.76W 6033082.16 N 539730.95 E 3383.07 2473.45 S 1932.47W 6032933.42 N 539616.07 E 3451.47 2621.55 S 2048.18W 6032784.67 N 539501.19 E 3519.88 2769.64 S 2163.88W 6032635.93 N 539386.32 E 3588.28 2917.74 S 2279.59W 6032487.19 N 539271.44 E 3656.69 3065.84 S 2395.30W 6032338.45 N 539156.56 E 3725.09 3213.94 S 2511.00W 6032189.70 N 539041.69 E 3793.49 3362.03 S 2626.71W 6032040.96 N 538926.81 E 3858.19 3502.10 S 2736.14W 6031900.28 N 538818.16 E 3861.90 3510.11S 2742.45W 6031892.25 N 538811.90 E 3865.50 3517.83 S 2748.63W 6031884.49 N 538805.76 E 3896.09 3581.45 S 2803.57W 6031820.56 N 538751.17 E 3930.16 3648.10 S 2869.86W 6031753.55 N 538685.26 E 3963.93 3709.72 S 2940.98W 6031691.53 N 538614.49 E 3990.50 3755.00 S 3000.85W 6031645.91N 538554.87 E 3997.24 3766.02 S 3016.59W 6031634.80 N 538539.19 E 4029.92 3816.72 S 3096.32W 6031583.66 N 538459.75 E 4061.82 3861.58 S 3179.79W 6031538.33 N 538376.53 E 4069.11 3871.16 S 3199.70W 6031528.65 N 538356.67 E 4124.31 3942.63 S 3351.61W 6031456.32 N 538205.16 E 4130.50 3950.65 S 3368.64W 6031448.21N 538188.18 E 4145.50 3970.07 S 3409.93W 6031428.56 N 538147.00 E 4186.78 4023.52 S 3523.53W 6031374.47 N 538033.70 E 4249.25 4104.41 S 3695.44W 6031292.62 N 537862.24 E Dogleg Rate (°/100~) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4.000 4.000 4.000 4.0O0 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPF Ve~ical Section (fi) 2694.48 2877.76 3061.04 3244.32 3427.60 3610.88 3794.16 3977.44 4160.72 4334.O6 4344.01 4353.68 4436.47 4529.97 4624.03 4699.05 4718.21 4812.04 4905.06 4926.54 5089.43 5107.69 5151.96 5273.77 5458.11 Comment Be.clin Dir (~. 4.000°/100ft: 6589.16ft IV'E), 3858.19ft TVD Top Schrader OWC End Dir: 7223.27ft MD, 4069.1 lft TVD Base Schrader 9 5/8" Casing Continued... 4 May, 2000 - 8:37 - 3 - DrillQuest 1.05.05a 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 8000.00 71.800 244.803 4271.21 8200.00 71.800 244.803 4333.68 8400.00 71.800 244.803 4396.15 8600.00 71.800 244.803 4458.61 8800.00 71.800 244.803 4521.08 9000.00 71.800 244.803 4583.55 9200.00 71.800 244.803 4646.01 9400.00 71.800 244.803 4708.48 9600.00 71.800 244.803 4770.95 9800.00 71.800 244.803 4833.42 10000.00 71.800 244.803 4895.88 10024.39 71.800 244.803 4903.50 10100.00 69.343 244.802 4928.65 10200.00 66.093 244.802 4966.56 10300.00 62.843 244.801 5009.66 10400.00 59.593 244.801 5057.80 10500.00 56.343 244.801 5110.83 10600.00 53.093 244.800 5168.58 10700.00 49.843 244.799 5230.87 10800.00 46.593 244.799 5297.49 10900.00 43.343 244.798 5368.23 11000.00 40.093 244.797 5442.87 11100.00 36.843 244.796 5521.15 11200.00 33.593 244.795 5602.84 11300.00 30.343 244.794 5687.66 Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings (~) (~) (~) (~) (~) 4311.71 4185.30 S 3867.36W 6031210.78 N 537690.78 E 4374.18 4266.18 S 4039.28W 6031128.93 N 537519.32 E 4436.65 4347.07 S 4211.19W 6031047.08 N 537347.86 E 4499.11 4427.96 S 4383.11W 6030965.23 N 537176.40 E 4561.58 4508.85 S 4555.02W 6030883.38 N 537004.94 E 4624.05 4589.74 S 4726.94W 6030801.54 N 536833.48 E 4686.51 4670.62 S 4898.86W 6030719.69 N 536662.02 E 4748.98 4751.51 $ 5070.77W 6030637.84 N 536490.55 E 4811.45 4832.40 S 5242.69W 6030555.99 N 536319.09 E 4873.92 4913.29 S 5414.60W 6030474.15 N 536147.63 E 4936.38 4994.18 S 5586.52W 6030392.30 N 535976.17 E 4944.00 5004.04 S 5607.48W 6030382.32 N 535955.26 E 4969.15 5034.39 S 5672.00W 6030351.60 N 535890.92 E 5007.06 5073.78 S 5755.71W 6030311.74 N 535807.42 E 5050.16 5112.20 S 5837.35W 6030272.88 N 535726.00 E 5098.30 5149.51S 5916.64W 6030235.12 N 535646.92 E 5151.33 5185.60 S 5993.34W 6030198.60 N 535570.43 E 5209.08 5220.35 S 6067.19W 6030163.44 N 535496.77 E 5271.37 5253.65 S 6137.97W 6030129.74 N 535426.18 E 5337.99 5285.40 S 6205.43W 6030097.62 N 535358.90 E 5408.73 5315.49 S 6269.36W 6030067.17 N 535295.13 E 5483.37 5343.82 S 6329.57W 6030038.51 N 535235.09 E 5561.65 5370.30 S 6385.84W 6030011.71N 535178.96 E 5643.34 5394.86 S 6438.02W 6029986.86 N 535126.93 E 5728.16 5417.40 S 6485.91W 6029964.05 N 535079.16 E Dogleg Rate (°/~00~) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3.250 3.250 3.250 3.250 3.250 3.250 3.250 3.250 3.250 3.250 3.250 3.250 3.250 Alaska State Plane 4 Milne Point MPF Ve~ical Section (fi) 5642.44 5826.78 6011.11 6195.45 6379.79 6564.12 6748.46 6932.79 7117.13 7301.46 7485.80 7508.28 7577.46 7667.22 7754.76 7839.78 7922.02 8001.21 8077.10 8149.44 8217.99 8282.55 8342.90 8398.84 8450.21 Comment Beain Dir ~. 3.250°/100ft : 10024.39ft'MD, 4944.00ft TVD Continued... 4 May, 2000 - 8:37 - 4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF.81 Wp6-2 Revised: 4 May, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 11400.00 27.093 244.793 5775.35 11500.00 23.843 244.791 5865.62 11600.00 20.593 244.788 5958.18 11700.00 17.343 244.785 6052.74 11800.00 14.093 244.780 6148.99 11859.01 12.175 244.776 6206.46 12000.00 12.175 244.776 6344.27 12024.27 12.175 244.776 6368.00 12094.86 12.175 244.776 6437.00 12181.82 12.175 244.776 6522.00 12200.00 12.175 244.776 6539.77 12350.61 12.175 244.776 6687.00 12400.00 12.175 244.776 6735.28 12523.50 12.175 244.776 6856.00 12563.40 12.175 244.776 6895.00 12570.56 12.103 244.776 6902.00 12586.92 11.940 244.776 6918.00 12600.00 11.809 244.776 6930.80 12616.54 11.643 244.776 6947.00 12671.62 11.092 244.776 7001.00 12700.00 10.809 244.776 7028.86 12800.00 9.809 244.776 7127.24 12821.62 9.592 244.776 7148.56 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings (~) (~) (~) (~) (~) 5815.85 5437.86 S 6529.38W 6029943.35 N 535035.81 E 5906.12 5456.17 S 6568.28W 6029924.82 N 534997.01 E 5998.68 5472.28 S 6602.49W 6029908.52 N 534962.89 E 6093.24 5486.12 S 6631.89W 6029894.51 N 534933.57 E 6189.49 5497.66 S 6656.39W 6029882.84 N 534909.13 E 6246.96 5503.38 S 6668.52W 6029877.06 N 534897.03 E 6384.77 5516.05 S 6695.42W 6029864.23 N 534870.20 E 6408.50 5518.23 S 6700.05W 6029862.03 N 534865.58 E 6477.50 5524.57 S 6713.52W 6029855.61 N 534852.15 E 6562.50 5532.39 S 6730.11W 6029847.70 N 534835.61 E 6580.27 5534.02 S 6733.58W 6029846.05 N 534832.15 E 6727.50 5547.56 S 6762.31W 6029832.35 N 534803.49 E 6775.78 5552.00 S 6771.74W 6029827.86 N 534794.09 E 6896.50 5563.10 S 6795.30VV 6029816.63 N 534770.59 E 6935.50 5566.68 S 6802.91W 6029813.00 N 534763.00 E 6942.50 5567.32 S 6804.27W 6029812.35 N 534761.64 E 6958.50 5568.77 S 6807.35W 6029810.88 N 534758.57 E 6971.30 5569.92 S 6809.79W 6029809.72 N 534756.14 E 6987.50 5571.35 S 6812.83W 6029808.27 N 534753.11E 7041.50 5575.98 S 6822.65W 6029803.59 N 534743.31E 7069.36 5578.28 S 6827.53W 6029801.27 N 534738.45 E 7167.74 5585.90 S 6843.72W 6029793.55 N 534722.30 E 7189.06 5587.46 S 6847.01W 6029791.98 N 534719.01 E Dogleg Rate (°/100~) 3.25O 3.250 3.250 3.250 3.250 3.250 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 Alaska State Plane 4 Milne Point MPF Ve~ical Section (fi) 8496.82 8538.54 8575.22 8606.75 8633.03 8646.O4 8674.90 8679.86 8694.31 8712.10 8715.82 8746.64 8756.75 8782.02 8790.19 8791.65 8794.95 8797.57 8800.83 8811.36 8816.59 8833.96 8837.49 Comment End Dir: 11859.01ft MD, 6246.96ft TVD Top HRZ / TUDZ Base HRZ KLGM TKUD (Kuparuk Caprock) 7" Liner Kuparuk B Berlin Dir ~. 1.000°/100ft 12563.40ftTVlD, 6935.50ft ~VD Kuparuk A Target- MPF-81 TI TKA3 TKA2 TKA1 Miluveach Total Depth: 12821.62ft MD, 7189.06ft TVD 4 1/2" Liner Continued... 4 May, 2000 - 8:37 - 5 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPF All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPF-81. Northings and Eastings are relative to MPF-81. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPF-81 and calculated along an Azimuth of 230.784° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12821.62ft., The Bottom Hole Displacement is 8837.49ft., in the Direction of 230.784° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 396.50 396.50 0.00 N 0.00 E 596.50 596.46 2.75 S 2.15 W 896.50 895.56 20.27 S 15.83 W 1196.50 1191.31 59.27 S 46.30 W 1896.50 1841.18 258.41 S 201.89 W 2133.58 2046.50 351.82 S 274.88 W 3133.58 2676.31 943.29 S 736.98 W 6589.16 3858.19 3502.10 S 2736.14 W 7223.27 4069.11 3871.16 S 3199.70 W 10024.39 4944.00 5004.04 S 5607.48 W 11859.01 6246.96 5503.38 S 6668.52 W 12563.40 6935.50 5566.68 S 6802.91 W 12821.62 7189.06 5587.46 S 6847.01 W Comment Begin Dir @ 1.000°/100fl: 396.50ft MD, 396.50ft TVD Increase in Dir Rate @ 1.500°/100ff: 596.50ff MD, 596.46ft TVD Increase in Dir Rate @ 2.000°/100ft: 896.50ft MD, 895.56ft TVD Increase in Dir Rate @ 2.500°/100ft: 1196.50ft MD, 1191.31ft TVD End Dir: 1896.50ft MD, 1841.18ft TVD Begin Dir @ 4.000°/100ft: 2133.58ft MD, 2046.50ft TVD End Dir: 3133.58ft MD, 2676.31ft TVD Begin Dir @ 4.000°/100ft: 6589.16ft MD, 3858.19ft 'I-VD End Dir: 7223.27ft MD, 4069.1 lft TVD Begin Dir @ 3.250°/100ft: 10024.39ft MD, 4944.00ft TVD End Dir: 11859.01ft MD, 6246.96ft TVD Begin Dir @ 1.000°/100ft: 12563.40fl MD, 6935.50ft -I-VD Total Depth: 12821.62ft MD, 7189.06ft -I-VD 2000 Continued... 4 May, 2000 - 8:37 - 6 - DriflQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPF Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 1895.71 1840.50 1800.00 258.10 S 201.65 W Base Permafrost 6610.53 3865.50 3825.00 3517.83 S 2748.63 W Top Schrader 6979.64 3990.50 3950.00 3755.00 S 3000.85 W OWC 7419.81 4130.50 4090.00 3950.65 S 3368.64 W Base Schrader 12024.27 6408.50 6368.00 5518.23 S 6700.05 W Top HR7 / TUDZ 12094.86 6477.50 6437.00 5524.57 S 6713.52 W Base HRZ 12181.82 6562.50 6522.00 5532.39 S 6730.11 W KLGM 12350.61 6727.50 6687.00 5547.56 S 6762.31 W TKUD (Kuparuk Caprock) 12523.50 6896.50 6856.00 5563.10 S 6795.30 W Kuparuk B 12563.40 6935.50 6895.00 5566.68 S 6802.91 W Kuparuk A 12570.56 6942.50 6902.00 5567.32 S 6804.27 W TKA3 12586.92 6958.50 6918.00 5568.77 S 6807.35 W TKA2 12616.54 6987.50 6947.00 5571.35 S 6812.83 W TKA1 12671.62 7041.50 7001.00 5575.98 S 6822.65 W Miluveach Continued... 4 May, 2000 - 8:37 - 7- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPF Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> To Measured Depth (ft) 7467.84 12523.50 12821.62 Targets associated with this wellpath Target Name MPF-81 T1 Vertical Depth Casing Detail (ft) 4145.50 9 5/8" Casing 6896.50 7" Liner 7189.06 4 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 Mean Sea Level/Global Coordinates #1 #2 #3 2000 Target Entry Coordinates TVD Northings Eastings (~) (~) (~) 6935.50 5566.68 S 6802.91W 6895.00 6029813.00 N 534763.00 E 70°29'32.8775"N 149° 42'56.8528"W 6935.50 5401.16 S 6894.99W 6935.50 5402.84 S 6595.99W 6935.50 5567.83 S 6596.91W 6935.50 5896.16 S 6897.75W 6895.00 6029978.00 N 534670.00 E 6895.00 6029978.00 N 534969.00 E 6895.00 6029813.00 N 534969.00 E 6895.00 6029483.00 N 534670.00 E Target Shape Polygon Target Type Continued... 4 May, 2000 - 8:37 - 8 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-81 Wp6-2 Revised: 4 May, 2000 North Slope Alaska Target Name Targets associated with this wellpath (Continued) MPF~81 Target 2 Geographical Coordinates #1 #2 #3 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 7193.50 7153.00 70° 29' 34.5047" N 70° 29' 34.4909" N 70° 29' 32.8680" N 70° 29' 29.6361" N 5567.50 S 6029812.00 N 70° 29' 32.8692" N 149° 42' 59.5673" W 149° 42' 50.7670" W 149° 42' 50.7899" W 149° 42' 59.6352" W 6835.92 W 534730.00 E 149° 42' 57.8242" W Alaska State Plane 4 Milne Point MPF Target Target Shape Type Point ,..,., 5 2000 4 May, 2000 - 8:37 - 9 - DrillQuest 1.05.05a 14 1 67~4 4/18/00 0i67634 VEN~R ALASKAST40 00 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 041700 3K041700C 100. O0 100. O0 HANDLI~Q INST' s/h ter~'ie ×4628 CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. ~ 1 OO. OO 100. OO HE A~ACHED ~: .?BP.EXPLORATION (ALASKA).,JNC, :. :.:'P. oilBOx 196612 !i:'.'i::'?.?.: · " "' ANCHORAGE;~ALAS~: 99519-6612 FIRST NATIoNAL:BANK OF ASHLAND : AN]AFFiLIATE OF NATiONAL.:C TY BANK · · CLEVELAND, OHIO :i.::'56-389 412 No. H 1 6 7 6::3 4 CONSOL1DA rED COMMERCIAL:ACCOUNT : O0167634 PAY oNE .HUNDRED?!& ***********--************************************* US DOLLAR STATE.: OF ALASKA~AOGCC 300.1.:: ':~ORCUP IN~ .i~R ~VE::i::.. i: ::!!:":: ;!::~ii: AK 99501 ANCHORAGE DATE AMOUNT 104/18/00 i $100.00 ," ~,r-, ?F=,~h," ~-'0~, ~, aO:~Sct5'-' BOP.[,[, WELL PERMIT CHECKLIST COMPANY FIELD & POOL -~,~'-/'~/"~ WELL NAME ~ ,~/ PROGRAM: exp~ ADMINISTRATION A.~P/~ DATE S': INIT CLASS ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate:'~~ .................. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary:.~... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party.-~ ................. 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .'~, (~L.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. dev V/'redrll ~ serv ~ wellbore seg ~ ann. disposal para req ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ...... ("'~ N ~ 31. Data presented on potential overpressure zones .~/~.~c~F~~ 32. Seismic analysis of shallow gas zones ............ ~~N A~R DAT~ 33. Seabed condition su~ey (if off-shore) ............ ~~ ~'~'~0-_- - ~ __34' ~~C°ntact name/phone for weekly progress repods [explorato~ onl~ ANNU~R DISPOSAL35. With proper cementing records, this plan -- -- (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovew from a pool; and (E) will not circumvent 20 ~C 25.252 or20 ~C 25.412. GEOL--: ENGINEERING: UIC/Annular COMMISSION: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. Sper'ry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Nov 06 14:52:16 2000 Reel Header Service name ............. LISTPE Date ..................... 00/11/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/11/06 Origin ................... STS Tape Name ................ I/NKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MPF-81 500292295900 BP Exploration (Alaska), Inc. Sperry Sun 06-NOV-00 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00054 AK-MM-00054 AK-MM-00054 R. FRENCH T. MCGUIRE J. SACK J. PYRON J. PYRON E. VAUGHN 6 13N 10E 1967 3029 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 27.40 11.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 110.0 8.500 9.625 7530.0 6.125 7.000 12422.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL, DGR, AiqD ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. MWD RUN 3 IS DIRECTIONAL, DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN D. DOUGLAS OF BP EXPLORATION (ALASKA), INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 10/31/00. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL MPF-81 WITH API#: 50-029-22959-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12790'MD, 7206'TVD. SROP = SMOOTHED RATE OF PENETP_ATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PAPJUMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 11.5 PPG MUD FILTRATE SALINITY: 15000 PPM CHLORIDES FORMATION WATER SALINITY: 22000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NCNT FCNT PEF NPHI RHOB DRHO $ START DEPTH 363 0 400 5 7503 0 7503 0 7503 0 7503 0 7503 0 12412 0 12412 0 12412 0 12412 0 12429 5 12429 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH STOP DEPTH 12743.0 12789 5 12750 0 12750 0 12750 0 12750 0 12750 0 12706 0 12706 0 12721 0 12706 0 12721 0 12721 0 EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 363.0 7530.0 2 7530.0 12435.0 3 12435.0 12792.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 68 ROP MWD FT/H 4 t 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD 0HMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM Min 363 0.032 18.59 0 47 0 46 0 45 0 48 0 24 15 33 151.6 14678.9 2.02 -0.059 Max 12789.5 801.25 308.34 1097.5 1633.29 2000 1916.38 99.68 38.51 725.6 34569.2 2.97 0.392 Mean Nsam 6576.25 24854 142.077 24743 88.0444 24761 3.44145 10426 3.69458 10426 7.22443 10426 9.9414 10426 1.84766 10426 25.8224 589 369.106 589 23717.3 589 2.42926 584 0.0373014 584 First Reading 363 400.5 363 7503 7503 7503 7503 7503 12412 12412 12412 12429.5 12429.5 Last Reading 12789.5 12789.5 12743 12750 12750 12750 12750 12750 12706 12706 12706 12721 12721 PEF MWD BARN 2.34 16.32 6.40045 619 12412 12721 First Reading For Entire File .......... 363 Last Reading For Entire File ........... 12789.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 363.0 7492.5 ROP 400.5 7530.0 $ LOG HEADER DATA DATE LOGGED: 03-JUN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 7530.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 71.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PB1500CG8 12.250 110.0 Water Based 9.40 54.0 8.9 6O0 6.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 OR MWD010 API 4 1 68 8 3 .0 104.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 363 7530 3946.5 14335 ROP MWD010 FT/H 0.54 801.25 167.137 14224 GR MWD010 API 18.59 136.34 73.389 14260 First Reading 363 400.5 363 Last Reading 7530 7530 7492.5 First Reading For Entire File .......... 363 Last Reading For Entire File ........... 7530 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 7475.0 GR 7493.0 RPX 7503.0 RPD 7503.0 RPM 7503.0 RPS 7503.0 ROP 7530.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH 12377 0 12388 0 12377 0 12377 0 12377 0 12377 0 12435 0 09-JUN-00 Insite 65.41 Memory 12435.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AlqD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.2 74.6 TOOL NUMBER 1538/1537 1538/1537 8.500 7530.0 Water Based 9.30 46.0 9.1 300 5.4 2.100 1.239 4.000 1.800 71.0 125.0 71.0 71.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 FET MWD020 OHMM HOUR 1 68 1 68 24 28 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 7475 0. 032 33.68 0.47 0.46 0.45 0.48 0.24 Max 12435 496 53 308 34 548 19 1435 26 558 06 1916 38 71.1 Mean Nsam 9955 9921 112.997 9810 108.281 9791 3.03939 9749 3.13624 9749 3.12948 9749 5.68086 9749 1.76395 9800 First Reading 7475 7530.5 7493 7503 7503 7503 7503 7475 Last Reading 12435 12435 12388 12377 12377 12377 12377 12377 First Reading For Entire File .......... 7475 Last Reading For Entire File ........... 12435 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12388.5 12743.0 RPD 12412.0 12750.0 PEF 12412.0 12721.0 RPX 12412.0 12750.0 RPM 12412 0 FET 12412 0 NPHI 12412 0 FCNT 12412 0 NCNT 12412 0 RPS 12412 0 RHOB 12429 5 DRHO 12429 5 ROP 12435 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12750 0 12750 0 12706 0 12706 0 12706 0 12750 0 12721 0 12721 0 12792 0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 14 -JUN- 00 Insite 4.15 Memory 12790.0 8.6 9.9 TOOL NUMBER 1494grv4 14 94grv4 14 94grv4 1494grv4 6.125 12422.0 Water Based 11.50 47.0 8.7 350 2.8 1.700 .859 1.400 1.800 71.0 147.1 68.0 68.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum SpecificatiOn Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 NPHI MWD030 PU-S 4 1 68 FCNT MWD030 CNTS 4 1 68 NCNT MWD030 CNTS 4 1 68 RHOB MWD030 G/CM 4 1 68 DRHO MWD030 G/CM 4 1 68 PEF MWD030 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 12388.5 12792 ROP MWD030 FT/H 2.18 93.31 GR MWD030 API 42.36 145.14 RPX MWD030 OHMM 1.54 1097.5 RPS MWD030 OHMM 1.5 1633.29 RPM MWD030 OHMM 1.51 2000 RPD MWD030 OHMM 1.54 1905.44 FET MWD030 HOUR 0.9 99.68 NPHI MWD030 PU-S 15.33 38.51 FCNT MWD030 CNTS 151.6 725.6 NCNT MWD030 CNTS 14678.9 34569.2 RHOB MWD030 G/CM 2.02 2.97 DRHO MWD030 G/CM -0.059 0.392 PEF MWD030 BARN 2.34 16.32 Mean Nsam 12590.3 808 41.6236 714 103.331 710 9.23121 677 11.7349 677 66.1928 677 71.2945 677 8.20123 677 25.8224 589 369.106 589 23717.3 589 2.42926 584 0.0373014 584 6.40045 619 First Reading 12388.5 12435.5 12388.5 12412 12412 12412 12412 12412 12412 12412 12412 12429.5 12429.5 12412 Last Reading 12792 12792 12743 12750 12750 12750 12750 12750 12706 12706 12706 12721 12721 12721 First Reading For Entire File .......... 12388.5 Last Reading For Entire File ........... 12792 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/11/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/11/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File