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Home My WebLink About204-119Nolan 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: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' 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: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' 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: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT I-14 JBR 01/26/2026 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 2 7/8" and 4 1/2" joints. They tested and had floor valves for both sizes on the floor. C-6 valve failed, it was replaced and tested good. Test Results TEST DATA Rig Rep:WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:C.A. Demoski Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2041190 DATE:11/21/2025 Type Operation:WRKOV Annular: 250/2000Type Test:WKLY Valves: 250/2000 Rams: 250/2000 Test Pressures:Inspection No:bopRCN251123151228 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 818 Sundry No: 325-676 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 3 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" x 5 " V 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 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 3 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1850 200 PSI Attained P19 Full Pressure Attained P55 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2363 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P7 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0        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: Cement Sqz & Conv. to WSW 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,863' N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi NB Liner 6,590psi OA Liner 7,500psi OB 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 WSW 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 4,033' (3) Baker ZXP LTP and N/A 6,784 MD/ 3,780 TVD, 7,276 MD/ 3,913 TVD & 7,493 MD/ 3,972 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 9,885' Perforation Depth MD (ft): 9,740' See Schematic 2,620' 4.5" See Schematic 9,863'2,381' 4-1/2" 3,837'4.5" 78' 20" 10-3/4" 7-5/8" 2,665' 4"2,966' 7,585' MD N/A 7,910psi 5,210psi 6,890psi 2,286' 3,994' 3,979' 2,699' 7,618' Length Size Proposed Pools: 112' 112' 12.66# / L-80 / Vam Top TVD Burst 6,730' 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 204-119 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23214-00-00 Hilcorp Alaska LLC C.O. 477B AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 11/10/2025 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 MILNE PT UNIT I-14 4,033' 9,863' 4,033' 818 N/A Milne Point Schrader Bluff Oil Tertiary Underf WTRSP OOOt 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: 2025.11.17 16:04:37 - 09'00' Taylor Wellman (2143) 325-706 By Grace Christianson at 8:20 am, Nov 18, 2025 SFD W SW Conv. to W SW SB Pool: DSR-11/19/25SFD 11/18/2025 10-404 MGR20NOV2025 * BOPE pressure test to 2000 psi. 24 hour notice to AOGCC to witness. * CBL to AOGCC upon completion of logging. 11/21/25 - o o - - - - - AOGCC requests ~100' MD minimum of cement above top of perforations. - mgr (NOTE: SFD estimates TOC at 4,520' MD.) * CBL to AOGCC upon completion of logging. - mgr Note: Shallowest proposed perfs span the 10-3/4" surface casing shoe that was cemented to surface with 96 bbls of cement returns. SFD _____________________________________________________________________________________ Revised By: TDF 11/23/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD =9,863(MD) / TD = 4,033(TVD) 20 7-5/8 12 13 10-3/4 13 14 15 TOC @ 6,473 SLM PBTD =9,863(MD) / TD = 4,033(TVD) 6 7 Orig. KB Elev.: 68.16 Doyon 14 13 3 4 5 8 9 10 11 16 1 2 Tubing Cut @ 6,430 SLM 1111131333333333331113333333313333313113 111111133333333333133331111111333333333331333313333313 OB Lateral l NB Lateral OA Lateral OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4 Liner NB 9.5 / L-80 / IBT 3.548 6,773 9,740 4-1/2 Liner OA 12.6 / L-80 / IBT 3.960 7,265 9,885 4-1/2 Liner OB 12.6 / L-80 / IBT 3.960 7,482 9,863 TUBING DETAIL 4-1/2 Kill String 12.6 / L-80 / EZ-GO HT 3.958 Surface 6,730 JEWELRY DETAIL No Depth Item 1 6,707 X -Nipple 2 6,728 Mule Shoe Bottom @ 6,730 3 6,773 NB Lateral Tie Back Sleeve 4 6,784 NB Lateral ZXP Liner Top Packer 5 6,799 NB Lateral LEM #2 (Lateral Entry Module) 6 6,809 NB Lateral Hook Wall, Hanger above 7-5/8 Window 7 6,826 NB Lateral Hook Wall, Hanger below 7-5/8 Window 8 6,845 NB Lateral Swell Packer 9 7,265 OA Lateral Tie Back Sleeve 10 7,276 OA Lateral ZXP Liner Top Packer 11 7,311 OA Lateral LEM #1 (Lateral Entry Module) 12 7,319 OA Lateral Hook Wall, Hanger above 7-5/8 Window 13 7,336 OA Lateral Hook Wall, Hanger below 7-5/8 Window 14 7,482 OB Lateral Tie Back Sleeve 15 7,493 OB Lateral ZXP Liner Top Packer 16 7,500 OB Lateral 7-5/8 x 5-1/2 HMC Liner Hanger 17 9,740 NB Lateral 4-1/2 Btm of Guide Shoe 18 9,885 OA Lateral 4-1/2 Btm of Guide Shoe 19 9,863 OB Lateral 4-1/2 Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 750 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 76.0 deg @ 6,710 MD 60 deg @ 2,491 MD WELLHEAD Tree 2-9/16 5M FMC Wellhead 11 x 11 5M FMC Gen 5, w/ 2-7/8 FMC Tubing. 2-7/8 EUE 8rd on T&B, 2.5 CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 8/28/2004 ESP Replacement by Nabors 4ES 8/26/2007 Install Kill String ASR#1 9/28/2020 Suspended by ASR#1 11/4/2020 LATERAL WINDOW DETAIL Top of NB Window @ 6,814 MD; Bottom @ 6,826 MD; Angle @ top of window is 75 deg Top of OA Window @ 7,324 MD; Bottom @ 7,336 MD; Angle @ top of window is 73 deg TOC estimated by Operator at 4,479' MD. SFD _____________________________________________________________________________________ Revised By: RJL 11/14/2025 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 Med Excluder Screen Slotted Liner Slotted Liner TD =9,863(MD) / TD = 4,033(TVD) 20 7-5/8 9 10 12 13 10-3/4 13 TOC @ X,XXX MD PBTD =9,863(MD) / TD = 4,033(TVD) 6 7 Orig. KB Elev.:68.16 Doyon 14 13 3 4 & 5 8 11 1 2 Tubing Cut @ 6,280 SLM 11111133333133113333333 1113333331311333333 OB Lateral l NB OA Lateral OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4 Liner NB 9.5 / L-80 / IBT 3.548 6,773 9,740 4-1/2 Liner OA 12.6 / L-80 / IBT 3.960 7,265 9,885 4-1/2 Liner OB 12.6 / L-80 / IBT 3.960 7,482 9,863 TUBING DETAIL 4-1/2 Upper Comp 12.6# / L-80 / TXP-BTC 0.0152 Surface ±X,XXX 4-1/2 Lower Comp 12.6# / L-80 / JFR Bear 0.0152 ±X,XXX ±X,XXX 4-1/2 Kill String 12.6 / L-80 / EZ-GO HT 3.958 6,430 6,730 JEWELRY DETAIL No Depth Item 1 ±X,XXX Discharge Head: 2 ±X,XXX Pump: 3 ±X,XXX Gas Separator: 4 ±X,XXX Upper Tandem Seal: 5 ±X,XXX Lower Tandem Seal: 6 ±X,XXX Motor: 7 ±X,XXX Sensor w/ 6 Fin Centralizer Bottom @ ±X,XXX 8 ±X,XXX 7-5/8 Packer 9 ±X,XXX Screens 10 ±X,XXX 7-5/8 Packer 11 ±X,XXX Screens 12 ±X,XXX 7-5/8 Packer 13 - Suspended lower Completion and Laterals OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 750 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 76.0 deg @ 6,710 MD 60 deg @ 2,491 MD WELLHEAD Tree 2-9/165M FMC Wellhead 11 x 11 5M FMC Gen 5, w/ 2-7/8 FMC Tubing. 2-7/8 EUE 8rd on T&B, 2.5 CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 8/28/2004 ESP Replacement by Nabors 4ES 8/26/2007 Install Kill String ASR#1 9/28/2020 Suspended by ASR#1 11/4/2020 LATERAL WINDOW DETAIL Top of NB Window @ 6,814 MD; Bottom @ 6,826 MD; Angle @ top of window is 75 deg Top of OA Window @ 7,324 MD; Bottom @ 7,336 MD; Angle @ top of window is 73 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Prince Creek ±2,655 ±2,704 ±2,201 ±2,220 ±49 Future Open ±2,763 ±2,812 ±2,311 ±2,329 ±49 Future Open ±2,950 ±3,021 ±2,383 ±2,410 ±71 Future Open ±3,147 ±3,576 ±2,457 ±2,612 ±429 Future Open 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 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: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurv MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' 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: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20251117 2045 APPROVAL MP I-14 PTD: 204-119 - Sundry revision 325-676 Date:Monday, November 17, 2025 8:57:40 AM Attachments:MPU I-14_RWO Convert to WSW 2025 v08 COP.docx From: Rixse, Melvin G (OGC) Sent: Friday, November 14, 2025 8:45 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Taylor Wellman <twellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: MP I-14 PTD: 204-119 Sundry revision 325-676 Ryan, Hilcorp is approved to proceed as described below and in the attached word document to assure isolation. Note: The SB has previously assured reservoir abandonment. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Friday, November 14, 2025 5:26 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: MP I-14 PTD: 204-119 Mel- As discussed, it looks like we damaged the casing when we jet cut the tubing at 6,280’ MD. Attached is the change of procedure steps 50-59. I will get the COP submitted and in the AOGCC inbox as well. Change of Program: Cement plug over casing leak: 50. RIH 2-7/8” PH-6 workstring to 6,280’. 51. RU cementer, pressure test and circulate a balance plug. 52. PU above the cement. 53. Reverse out. 54. PU to the sump packer and circulate clean. 55. Trip in 500’ above the cement plug 56. WOC 57. TIH tag cement, witnessed by AOGCC 58. Pressure test to 1500 psi for 30 min charted witnessed by AOGCC 59. TOOH. Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20251117 2045 APPROVAL MP I-14 PTD: 204-119 - Sundry revision 325-676 Date:Monday, November 17, 2025 8:57:40 AM Attachments:MPU I-14_RWO Convert to WSW 2025 v08 COP.docx From: Rixse, Melvin G (OGC) Sent: Friday, November 14, 2025 8:45 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Taylor Wellman <twellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: MP I-14 PTD: 204-119 Sundry revision 325-676 Ryan, Hilcorp is approved to proceed as described below and in the attached word document to assure isolation. Note: The SB has previously assured reservoir abandonment. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Friday, November 14, 2025 5:26 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: MP I-14 PTD: 204-119 Mel- As discussed, it looks like we damaged the casing when we jet cut the tubing at 6,280’ MD. Attached is the change of procedure steps 50-59. I will get the COP submitted and in the AOGCC inbox as well. Change of Program: Cement plug over casing leak: 50. RIH 2-7/8” PH-6 workstring to 6,280’. 51. RU cementer, pressure test and circulate a balance plug. 52. PU above the cement. 53. Reverse out. 54. PU to the sump packer and circulate clean. 55. Trip in 500’ above the cement plug 56. WOC 57. TIH tag cement, witnessed by AOGCC 58. Pressure test to 1500 psi for 30 min charted witnessed by AOGCC 59. TOOH. Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PTD 204-119 Sundry 325-676 MPU I-14 BOPE flow cross change APPROVED Date:Thursday, November 6, 2025 3:50:16 PM Attachments:image001.png From: Rixse, Melvin G (OGC) Sent: Thursday, November 6, 2025 3:49 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Tom Fouts <tfouts@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: PTD 204-119 Sundry 325-676 MPU I-14 BOPE flow cross change APPROVED Ryan, Hilcorp is approved to configure the BOPE flow cross as per the drawing you included below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Tom Fouts, AOGCC Inspectors From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Thursday, November 6, 2025 8:25 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com> Subject: I-14 BOP schematic Mel- The BOP schematic in the Sundry shows a HCR valve on the kill line. Our actual BOP configuration has a manual valve. I have attached our current BOP configuration here. Current: Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Cement Sqz & Conv. to WSW 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,863' N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi NB Liner 6,590psi OA Liner 7,500psi OB 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 WSW 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 4,033' (3) Baker ZXP LTP and N/A 6,784 MD/ 3,780 TVD, 7,276 MD/ 3,913 TVD & 7,493 MD/ 3,972 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 9,885' Perforation Depth MD (ft): 9,740' See Schematic 2,620' 4.5" See Schematic 9,863'2,381' 4-1/2" 3,837'4.5" 78' 20" 10-3/4" 7-5/8" 2,665' 4"2,966' 7,585' MD N/A 7,910psi 5,210psi 6,890psi 2,286' 3,994' 3,979' 2,699' 7,618' Length Size Proposed Pools: 112' 112' 12.66# / L-80 / Vam Top TVD Burst 6,730' 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 204-119 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23214-00-00 Hilcorp Alaska LLC C.O. 477B AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 11/10/2025 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 MILNE PT UNIT I-14 4,033' 9,863' 4,033' 818 N/A Milne Point Schrader Bluff Oil Tertiary Underf WTRSP OOOOOOOOO 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 3:53 pm, Oct 31, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.10.31 15:17:19 - 08'00' Taylor Wellman (2143) 325-676 Cement Sqz & SB Oil Pool: SFD 11/5/2025 SFD Conv. to WSW * BOPE test to 2000 psi. 24 hour notice to AOGCC. * CBL to AOGCC for review immediately upon completion of log for review of OA isolation and planned perforations. 10-404 MGR05NOV25JLC 11/5/2025 11/05/25 - o o - - - - - CBL to AOGCC for review upon completion. - mgr _____________________________________________________________________________________ Revised By: TDF 11/23/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD =9,863(MD) / TD = 4,033(TVD) 20 7-5/8 12 13 10-3/4 13 14 15 TOC @ 6,473 SLM PBTD =9,863(MD) / TD = 4,033(TVD) 6 7 Orig. KB Elev.: 68.16 Doyon 14 13 3 4 5 8 9 10 11 16 1 2 Tubing Cut @ 6,430 SLM 1111131333333333331113333333313333313113 111111133333333333133331111111333333333331333313333313 OB Lateral l NB Lateral OA Lateral OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4 Liner NB 9.5 / L-80 / IBT 3.548 6,773 9,740 4-1/2 Liner OA 12.6 / L-80 / IBT 3.960 7,265 9,885 4-1/2 Liner OB 12.6 / L-80 / IBT 3.960 7,482 9,863 TUBING DETAIL 4-1/2 Kill String 12.6 / L-80 / EZ-GO HT 3.958 Surface 6,730 JEWELRY DETAIL No Depth Item 1 6,707 X -Nipple 2 6,728 Mule Shoe Bottom @ 6,730 3 6,773 NB Lateral Tie Back Sleeve 4 6,784 NB Lateral ZXP Liner Top Packer 5 6,799 NB Lateral LEM #2 (Lateral Entry Module) 6 6,809 NB Lateral Hook Wall, Hanger above 7-5/8 Window 7 6,826 NB Lateral Hook Wall, Hanger below 7-5/8 Window 8 6,845 NB Lateral Swell Packer 9 7,265 OA Lateral Tie Back Sleeve 10 7,276 OA Lateral ZXP Liner Top Packer 11 7,311 OA Lateral LEM #1 (Lateral Entry Module) 12 7,319 OA Lateral Hook Wall, Hanger above 7-5/8 Window 13 7,336 OA Lateral Hook Wall, Hanger below 7-5/8 Window 14 7,482 OB Lateral Tie Back Sleeve 15 7,493 OB Lateral ZXP Liner Top Packer 16 7,500 OB Lateral 7-5/8 x 5-1/2 HMC Liner Hanger 17 9,740 NB Lateral 4-1/2 Btm of Guide Shoe 18 9,885 OA Lateral 4-1/2 Btm of Guide Shoe 19 9,863 OB Lateral 4-1/2 Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 750 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 76.0 deg @ 6,710 MD 60 deg @ 2,491 MD WELLHEAD Tree 2-9/16 5M FMC Wellhead 11 x 11 5M FMC Gen 5, w/ 2-7/8 FMC Tubing. 2-7/8 EUE 8rd on T&B, 2.5 CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 8/28/2004 ESP Replacement by Nabors 4ES 8/26/2007 Install Kill String ASR#1 9/28/2020 Suspended by ASR#1 11/4/2020 LATERAL WINDOW DETAIL Top of NB Window @ 6,814 MD; Bottom @ 6,826 MD; Angle @ top of window is 75 deg Top of OA Window @ 7,324 MD; Bottom @ 7,336 MD; Angle @ top of window is 73 deg NOTE: Operator estimates TOC for 7-5/8" casing is ~4,500' MD and SFD concurs. SFD 11/5/2025 _____________________________________________________________________________________ Revised By: RJL 10/31/2025 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 Med Excluder Screen Slotted Liner Slotted Liner TD =9,863(MD) / TD = 4,033(TVD) 20 7-5/8 9 10 12 13 10-3/4 13 TOC @ 6,473 SLM PBTD =9,863(MD) / TD = 4,033(TVD) 6 7 Orig. KB Elev.:68.16 Doyon 14 13 3 4 & 5 8 11 1 2 Tubing Cut @ 6,430 SLM 11111133333133113333333 1113333331311333333 OB Lateral l NB OA Lateral OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4 Liner NB 9.5 / L-80 / IBT 3.548 6,773 9,740 4-1/2 Liner OA 12.6 / L-80 / IBT 3.960 7,265 9,885 4-1/2 Liner OB 12.6 / L-80 / IBT 3.960 7,482 9,863 TUBING DETAIL 4-1/2 Upper Comp 12.6# / L-80 / TXP-BTC 0.0152 Surface ±X,XXX 4-1/2 Lower Comp 12.6# / L-80 / JFR Bear 0.0152 ±X,XXX ±X,XXX 4-1/2 Kill String 12.6 / L-80 / EZ-GO HT 3.958 6,430 6,730 JEWELRY DETAIL No Depth Item 1 ±X,XXX Discharge Head: 2 ±X,XXX Pump: 3 ±X,XXX Gas Separator: 4 ±X,XXX Upper Tandem Seal: 5 ±X,XXX Lower Tandem Seal: 6 ±X,XXX Motor: 7 ±X,XXX Sensor w/ 6 Fin Centralizer Bottom @ ±X,XXX 8 ±X,XXX 7-5/8 Packer 9 ±X,XXX Screens 10 ±X,XXX 7-5/8 Packer 11 ±X,XXX Screens 12 ±X,XXX 7-5/8 Packer 13 - Suspended lower Completion and Laterals OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 750 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 76.0 deg @ 6,710 MD 60 deg @ 2,491 MD WELLHEAD Tree 2-9/165M FMC Wellhead 11 x 11 5M FMC Gen 5, w/ 2-7/8 FMC Tubing. 2-7/8 EUE 8rd on T&B, 2.5 CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 8/28/2004 ESP Replacement by Nabors 4ES 8/26/2007 Install Kill String ASR#1 9/28/2020 Suspended by ASR#1 11/4/2020 LATERAL WINDOW DETAIL Top of NB Window @ 6,814 MD; Bottom @ 6,826 MD; Angle @ top of window is 75 deg Top of OA Window @ 7,324 MD; Bottom @ 7,336 MD; Angle @ top of window is 73 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Prince Creek ±2,655 ±2,704 ±2,201 ±2,220 ±49 Future Open ±2,763 ±2,812 ±2,311 ±2,329 ±49 Future Open ±2,950 ±3,021 ±2,383 ±2,410 ±71 Future Open ±3,147 ±3,576 ±2,457 ±2,612 ±429 Future Open NOTE: Operator estimates TOC for 7-5/8" casing is ~4,500' MD and SFD concurs. So, likely no exterior cement exists across any proposed Prince Creek perforations. SFD 11/5/2025 Milne Point ASR Rig 1 BOPE 2025 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 Blin d11'- 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 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Ryan Lewis To:Davies, Stephen F (OGC) Cc:Rixse, Melvin G (OGC); Dewhurst, Andrew D (OGC); Starns, Ted C (OGC) Subject:RE: [EXTERNAL] MPU_I-14 (PTD 204-119, Sundry 325-676) - Questions Date:Tuesday, November 4, 2025 6:18:46 AM Attachments:image003.png image004.png image005.png Steve You bring up a very good Point and you are correct, the GR signature at the base of I-14 is likely suppressed due to the surface casing shoe. However, on some other wells at I-pad that do not have surface casing set around this depth, such as neighboring I-06 and I-32, it appears there is a 6-10 TVD thick siltier sand package. The reason we are including this sand is to help ensure we get enough water out of this well and we dont see much downside to including this smaller package in our completion. Thanks, RL From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, November 3, 2025 3:40 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: RE: [EXTERNAL] MPU_I-14 (PTD 204-119, Sundry 325-676) - Questions Ryan, One follow-up question. In this well, 13-1/2" surface hole was drilled to 2,710' MD and 10-3/4" surface casing set to 2,699' MD. Hilcorp's shallowest proposed perforation interval is 2,655' to 2,704' MD, which spans the casing shoe and part of the underlying rathole interval. On the well log, there appears to be a sand at and just above the shoe (below). Since casing points are typically set in competent, very-fine grained sediments, I'm generally wary of apparent sands at casing points--especially shallow ones--and typically attribute sand-like gamma-ray responses in the vicinity of casing points / rathole to hole washout caused by prolonged circulating. Since this well was not mud logged, what evidence does Hilcorp have to suggest that the interval from 2,655' to 2,704' MD is indeed a Prince Creek water sand? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov From: Davies, Stephen F (OGC) Sent: Monday, November 3, 2025 2:55 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: RE: [EXTERNAL] MPU_I-14 (PTD 204-119, Sundry 325-676) - Questions Thank you, Ryan. I agree with your estimated TOC = 4,497 MD: I subtracted roughly a barrel of cement to account for the short section of rathole beneath the casing shoe and calculated an estimated top of cement at about 4,520' MD. I'd appreciate it if you could label the proposed schematic drawing accordingly. Thanks Again for Your Help and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Monday, November 3, 2025 1:21 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] MPU_I-14 (PTD 204-119, Sundry 325-676) - Questions The cement top depicted should actually be +-900 below the bottom perf. I can correct that on the proposed schematic. Thanks, RL From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, November 3, 2025 12:51 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] MPU_I-14 (PTD 204-119, Sundry 325-676) - Questions CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Ryan, Okay, my confusion is cleared up: The previous Sundry Application (325-688) for MPU I-14 was withdrawn, and this new Sundry Application (325-676) was submitted in its place on October 31st. In this new application, I notice that the depth for the top of cement outside of the 7-5/8" casing string is not provided on the current or proposed wellbore schematic drawings. Could Hilcorp please provide a depth for the top of that cement and how that depth was determined? AOGCC's well log inventory does not list a cement evaluation log for this well, so if such a log has been recorded, could Hilcorp please provide an image of that log in .pdf format for AOGCC's archives? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793- 1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regardand the recipient should carry out such virus and other checks as it considers appropriate. 1 Christianson, Grace K (OGC) From:Rixse, Melvin G (OGC) Sent:Thursday, October 23, 2025 8:53 AM To:Taylor Wellman Cc:Erik Nelson - (C); Dewhurst, Andrew D (OGC); Christianson, Grace K (OGC) Subject:RE: ASR Schedule and MPU I-14 PTD 204-119 Attachments:Hilcorp_MPU_I-14_received_091625_review.pdf Taylor, Erik, AOGCC will return this sundry for MPU I-14 with the expectation that it will be resubmitted with the AOGCC requirements made in the below email. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 O ice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Andy, Grace From: Rixse, Melvin G (OGC) Sent: Wednesday, October 22, 2025 11:17 AM To: 'Taylor Wellman' <twellman@hilcorp.com> Cc: Erik Nelson - (C) <erik.nelson@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: ASR Schedule and MPU I-14 PTD 204-119 Taylor, Commissioners have agreed that WSWs can be perforated above the surface casing shoe as long as cement isolation is assured at the perforations and conrmed with a CBL, the hydrocarbons below are properly abandoned, and there is no risk of drawing down uids in an uncemented annulus above. A revised sundry complying with the above requirements could be approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 O ice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). 2 From: Rixse, Melvin G (OGC) Sent: Saturday, October 11, 2025 4:01 PM To: Taylor Wellman <twellman@hilcorp.com> Subject: RE: ASR Schedule and MPU I-14 PTD 204-119 Taylor I will address with commissioners on Monday or Tuesday. I cannot assure agreement but will make it a priority. Mel From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, October 9, 2025 2:17 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Ryan Lewis <Ryan.Lewis@hilcorp.com> Subject: ASR Schedule and MPU I-14 PTD 204-119 Mel, Thank you for mee ng with us on Monday. We recognize the need to have met on this one and the addi onal review that was warrented. As you know Gravel Packs have more coordina on than a standard ESP RWO that we are juggling. I-14 would be our highest priority sundry to ask for review on to keep us moving forward. Our current schedule has ASR moving there in about 7 days. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Julieanna Potter - (C) <julieanna.potter@hilcorp.com> Sent: Wednesday, October 8, 2025 5:20 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; jack.lau@alaska.gov Cc: Victoria Loepp <victoria.loepp@alaska.gov>; jim.regg <jim.regg@alaska.gov>; steve.davies@alaska.gov; andrew.dewhurst@alaska.gov Subject: Hilcorp Alaska, LLC_AOGCC Weekly Operations Summary for 10/1-10/7 and RWO/Drilling Schedules Mel, Bryan, and Jack, Please ind attached to this email: Hilcorp Alaska, LLC Weekly Operations Summary; Current Rig Workover schedule; and CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Current Drilling Rig PTD Priority List Please let me know if you have any questions. Thank you, Julieanna Julieanna Potter | Hilcorp Alaska, LLC | Drilling Special Projects 3800 Centerpoint Dr., Suite 1400 | Anchorage, Alaska 99503 O: 907.777.8444 | C: 907.715.7060 | julieanna.potter@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Dewhurst, Andrew D (OGC) From:Ryan Lewis <ryan.lewis@hilcorp.com> Sent:Wednesday, 8 October, 2025 12:46 To:Rixse, Melvin G (OGC) Cc:Dewhurst, Andrew D (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL] MPU I-14 PTD 204-119 Sundry to convert from SB producer to water source well Attachments:MPU I-14 WSW perforating in Surface Casing.docx Follow Up Flag:Follow up Flag Status:Flagged All- Thank you again for your time this week. Attached is a letter detailing our thoughts on perforating the surface casing for WSWs. Thanks, RL From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, September 23, 2025 5:06 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL] MPU I-14 PTD 204-119 Sundry to convert from SB producer to water source well Ryan, AOGCC has decided to be consistent with sister state regulatory agencies to not allow operative perforations in surface casing for production or injection. It is AOGCCs position that surface casing is universally understood to protect ground water and provide an anchor for BOPE. Additionally, the surface casing FIT/LOT is documented as a quantitative barrier for maximum pressures that can be placed on the OA for the uids contained in that annulus. The sundry to convert this well to a source water well with perforations 44 above the surface casing shoe is problematic. Would Hilcorp consider converting this well without perforations above the surface casing shoe? Also, I dont see where Hilcorp is con rming that the new perforations will be isolated with cement. From comments in the sundry, it appears that there may be signi cant quantities of dissolved CO2 in the source water. Is this correct? Could this e ect OA integrity in any way? Regulation 20 AAC 25.030. Casing and cementing (c)(5) states: production casing must be set and cemented through, into, or just above the production interval. Can this well be con gured to comply? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 A variance to the regulations described above have been approved in the past for MPU water source wells, but they do not assure they would be approved going forward. Hilcorp is welcome to describe how a variance might be approved with the above considerations. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 O ice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Andy Dewhurst, Dave Roby The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Convert to WSW 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,863' N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi NB Liner 6,590psi OA Liner 7,500psi OB 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 WSW 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 4,033' (3) Baker ZXP LTP and N/A 6,784 MD/ 3,780 TVD, 7,276 MD/ 3,913 TVD & 7,493 MD/ 3,972 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 9,885' Perforation Depth MD (ft): 9,740' See Schematic 2,620' 4.5" See Schematic 9,863'2,381' 4-1/2" 3,837'4.5" 78' 20" 10-3/4" 7-5/8" 2,665' 4"2,966' 7,585' MD N/A 7,910psi 5,210psi 6,890psi 2,286' 3,994' 3,979' 2,699' 7,618' Length Size Proposed Pools: 112' 112' 12.66# / L-80 / Vam Top TVD Burst 6,730' 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 204-119 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23214-00-00 Hilcorp Alaska LLC C.O. 477B AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/23/2025 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 MILNE PT UNIT I-14 4,033' 9,863' 4,033' 818 N/A Milne Point Schrader Bluff Oil Tertiary Underf WTRSP Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:24 am, Sep 16, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.09.15 16:19:09 - 08'00' Taylor Wellman (2143) 325-564 DSR-9/24/25 NOT APPROVED 10/23/25 - o o - - - - _____________________________________________________________________________________ Revised By: TDF 11/23/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD =9,863(MD) / TD = 4,033(TVD) 20 7-5/8 12 13 10-3/4 13 14 15 TOC @ 6,473 SLM PBTD =9,863(MD) / TD = 4,033(TVD) 6 7 Orig. KB Elev.: 68.16 Doyon 14 13 3 4 5 8 9 10 11 16 1 2 Tubing Cut @ 6,430 SLM 1111131333333333333133333333331113133311 111113333333333333133311111333333333333131133331331 OB Lateral l NB Lateral OA Lateral OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4 Liner NB 9.5 / L-80 / IBT 3.548 6,773 9,740 4-1/2 Liner OA 12.6 / L-80 / IBT 3.960 7,265 9,885 4-1/2 Liner OB 12.6 / L-80 / IBT 3.960 7,482 9,863 TUBING DETAIL 4-1/2 Kill String 12.6 / L-80 / EZ-GO HT 3.958 Surface 6,730 JEWELRY DETAIL No Depth Item 1 6,707 X -Nipple 2 6,728 Mule Shoe Bottom @ 6,730 3 6,773 NB Lateral Tie Back Sleeve 4 6,784 NB Lateral ZXP Liner Top Packer 5 6,799 NB Lateral LEM #2 (Lateral Entry Module) 6 6,809 NB Lateral Hook Wall, Hanger above 7-5/8 Window 7 6,826 NB Lateral Hook Wall, Hanger below 7-5/8 Window 8 6,845 NB Lateral Swell Packer 9 7,265 OA Lateral Tie Back Sleeve 10 7,276 OA Lateral ZXP Liner Top Packer 11 7,311 OA Lateral LEM #1 (Lateral Entry Module) 12 7,319 OA Lateral Hook Wall, Hanger above 7-5/8 Window 13 7,336 OA Lateral Hook Wall, Hanger below 7-5/8 Window 14 7,482 OB Lateral Tie Back Sleeve 15 7,493 OB Lateral ZXP Liner Top Packer 16 7,500 OB Lateral 7-5/8 x 5-1/2 HMC Liner Hanger 17 9,740 NB Lateral 4-1/2 Btm of Guide Shoe 18 9,885 OA Lateral 4-1/2 Btm of Guide Shoe 19 9,863 OB Lateral 4-1/2 Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 750 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 76.0 deg @ 6,710 MD 60 deg @ 2,491 MD WELLHEAD Tree 2-9/16 5M FMC Wellhead 11 x 11 5M FMC Gen 5, w/ 2-7/8 FMC Tubing. 2-7/8 EUE 8rd on T&B, 2.5 CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 8/28/2004 ESP Replacement by Nabors 4ES 8/26/2007 Install Kill String ASR#1 9/28/2020 Suspended by ASR#1 11/4/2020 LATERAL WINDOW DETAIL Top of NB Window @ 6,814 MD; Bottom @ 6,826 MD; Angle @ top of window is 75 deg Top of OA Window @ 7,324 MD; Bottom @ 7,336 MD; Angle @ top of window is 73 deg _____________________________________________________________________________________ Revised By: TDF 9/9/2025 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 Med Excluder Screen Slotted Liner Slotted Liner TD =9,863(MD) / TD = 4,033(TVD) 20 7-5/8 9 10 12 13 10-3/4 13 TOC @ 6,473 SLM PBTD =9,863(MD) / TD = 4,033(TVD) 6 7 Orig. KB Elev.:68.16 Doyon 14 13 3 4 & 5 8 11 1 2 Tubing Cut @ 6,430 SLM 11111333333311333333133 11333333133113333313 OB Lateral l NB OA Lateral OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4 Liner NB 9.5 / L-80 / IBT 3.548 6,773 9,740 4-1/2 Liner OA 12.6 / L-80 / IBT 3.960 7,265 9,885 4-1/2 Liner OB 12.6 / L-80 / IBT 3.960 7,482 9,863 TUBING DETAIL 4-1/2 Upper Comp 12.6# / L-80 / TXP-BTC 0.0152 Surface ±X,XXX 4-1/2 Lower Comp 12.6# / L-80 / JFR Bear 0.0152 ±X,XXX ±X,XXX 4-1/2 Kill String 12.6 / L-80 / EZ-GO HT 3.958 6,430 6,730 JEWELRY DETAIL No Depth Item 1 ±X,XXX Discharge Head: 2 ±X,XXX Pump: 3 ±X,XXX Gas Separator: 4 ±X,XXX Upper Tandem Seal: 5 ±X,XXX Lower Tandem Seal: 6 ±X,XXX Motor: 7 ±X,XXX Sensor w/ 6 Fin Centralizer Bottom @ ±X,XXX 8 ±X,XXX 7-5/8 Packer 9 ±X,XXX Screens 10 ±X,XXX 7-5/8 Packer 11 ±X,XXX Screens 12 ±X,XXX 7-5/8 Packer 13 - Suspended lower Completion and Laterals OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 750 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 76.0 deg @ 6,710 MD 60 deg @ 2,491 MD WELLHEAD Tree 2-9/165M FMC Wellhead 11 x 11 5M FMC Gen 5, w/ 2-7/8 FMC Tubing. 2-7/8 EUE 8rd on T&B, 2.5 CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 8/28/2004 ESP Replacement by Nabors 4ES 8/26/2007 Install Kill String ASR#1 9/28/2020 Suspended by ASR#1 11/4/2020 LATERAL WINDOW DETAIL Top of NB Window @ 6,814 MD; Bottom @ 6,826 MD; Angle @ top of window is 75 deg Top of OA Window @ 7,324 MD; Bottom @ 7,336 MD; Angle @ top of window is 73 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Prince Creek ±2,655 ±2,704 ±2,201 ±2,220 ±49 Future Open ±2,763 ±2,812 ±2,311 ±2,329 ±49 Future Open ±2,950 ±3,021 ±2,383 ±2,410 ±71 Future Open ±3,147 ±3,576 ±2,457 ±2,612 ±429 Future Open Milne Point ASR Rig 1 BOPE 2025 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 Blin d11'- 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 To: Alaska Oil & Gas Conservation Commission From: Ryan Lewis Operations Engineer Date: 10/7/2025 Re: MPU I-14 Water Source Well (WSW) Hilcorp is converting MPU I-14 PTD 204-119 to a Water source well (WSW). Part of the conversion will require perforating into the surface casing to access the freshwater zones behind the surface casing. Our current campaign consists of recompleting 5 existing wells to WSWs, 3 of them are planned to have perforations in the surface casing. Long term development we estimate will have 6-8 WSWs that will require perforatingthe surface casing. The number of future WSWs is driven by the amount of water needed for polymer Monobore hydrocarbon production wells are not a completion design that Hilcorp uses to drill and complete new wells. If Hilcorp were to drill a WSW, amonobore would be the proposedcasing design to reach lower salinity formations (example M-06 PTD 219-113). Current monobore WSWs perforated in the surface casing include M-04 PTD 219-038, M-06 PTD 219-113, F-02 PTD 196-070, F-21 PTD 196-135, F-58 PTD 196-156, F-77 PTD 196-136 and E-23 PTD 195-094. MPU E-23 is the closest analog well and similar -14. 6/22/23 the Kuparuk formation was P&Adand hydrocarbon zones isolated with cement tag at 11,017 SLM recovering ~1 cup of cement and PT to 2,500 psi state witnessed. Then moved up hole and perforated through the 7production casing and 9-5/8 surface casing converting it to a WSW. MPU I-14: 11/04/2020 zones isolated with cement tag at 6,473 SLM recovering ~1/2 cup of cement and PT to 1,500 psi state witnessed. This well (and all other planned WSW recompletions) lie within the existing MPU Aquifer ExemptionOrder boundary (AEO-2). The end-of-life plan for abandonment would include: o Squeezing cement through the gravel pack into the perforations o Punching the 7-5/8 casing just above the gravel pack and circulate cement up the 7-5/8 x 10-3/4 annulus. o Surface cement plug o that appropriate cement tags and pressure tests are performed as per 20 AAC 25.112. We do appreciate your time and consideration on this matter as it pertains to freshwater zones and the perforating the surface casing. Surface casing and protection of the freshwater zones are something we are well aligned in, and we have worked to mitigate the risks of perforating the surface casing. Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susGDC250902173655 Well Pressures (psi): Date Inspected:9/2/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:11/4/2020 #320-376 Tubing:0 IA:250 OA:60 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/31/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT I-14 Permit Number:2041190 Wellhead Condition The wellhead is in good condition. Surrounding Surface Condition Good clean gravel pad Condition of Cellar Full of water. No signs of hydrocarbons seen. Comments Well location verified by well-site pad map Supervisor Comments Photos (6) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025            2025-0902_Suspend_MPU_I-14_photos_gc Page 1 of 3 Suspended Well Inspection – MPU I-14 PTD 2041190 AOGCC Inspection Rpt # susGDC250902173655 Photos by AOGCC Inspector G. Cook 9/2/2025 2025-0902_Suspend_MPU_I-14_photos_gc Page 2 of 3 IA Pressure Gauge Tree Cap Pressure Gauge (Tbg Pressure) 2025-0902_Suspend_MPU_I-14_photos_gc Page 3 of 3 OA Pressure Gauge Well Cellar 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Coil Cleanout w/ N2 Performed: Suspend Perforate Other Stimulate Alter Casing Pump Cement Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,863 feet N/A feet true vertical 4,033 feet N/A feet Effective Depth measured 9,863 feet feet true vertical 4,033 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / EZ GO HT 6,730' 3,767' Packers and SSSV (type, measured and true vertical depth)(3) Baker ZXP LTP 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 7,500psi 7,500psi 777-8405 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,430psi Collapse N/A 4,790psi 6,590psi Burst N/A 5,210psi 6,890psi 7,910psi 2,470psi 20" 10-3/4" 7-5/8" 4" 8,430psi 2,286' 3,994' 3,979'9,740' 9,885' Casing Conductor OB Liner 2,381' Length 78' 2,665' 7,585' Surface Production Casing Pressure Tubing Pressure N/A measured 2,966' 2,620' N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: Chad Helgeson chelgeson@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-119 50-029-23214-00-00 Plugs ADL0025517 & ADL0025906 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Size MILNE PT UNIT I-14 Gas-Mcf Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) NB Liner OA Liner TVD 112' Oil-Bbl measured true vertical Packer 4.5" 4.5" 3,780, 3,913 & 3,972 6,784, 7,275 & 7,493 WINJ WAG Water-Bbl MD 112' 2,699' 7,618' 9,863' 4,033' 3,837' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:35 pm, Aug 24, 2021 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2021.08.24 15:20:05 -08'00' Chad Helgeson (1517) DSR-8/25/21MGR01SEP2021 RBDMS HEW 8/25/2021 SFD 8/24/2021 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 60 OA 275 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm Follow Up Actions Needed: Hilcorp 204-119 Condition of Surrounding Surface Location: 09/18/20 320-376 REVIEWED BY: Other (specify in comments) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Matt Herrera 07/25/21 Yes Jon ArendMP I-14 (907) 670-3320 Yes Onshore 07/24/21 Initial Good. No Leaks. Valves and gauges operational Good. No Stains or subsidence None Signs/Wellhead good WBS Pictures Area map Yes PLB 12/2014 MP I-14 Suspended Well Inspection 7-25-21 _____________________________________________________________________________________ Revised By: TDF 11/23/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 12 13 10-3/4” 13 14 15 TOC @ 6,473’ SLM PBTD =9,863’ (MD) / TD = 4,033’(TVD) 6 7 Orig. KB Elev.: 68.16’ Doyon 14 13 3 4 5 8 9 10 11 16 1 2 Tubing Cut @ 6,430‘ SLM 111113113333333333331113133333331333333311 1111111333333333331131111111111333333333331333333133113 “OB” Lateral l “NB” Lateral “OA” Lateral “OB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / EZ-GO HT 3.958 Surface 6,730’ JEWELRY DETAIL No Depth Item 1 6,707’ X -Nipple 2 6,728’ Mule Shoe –Bottom @ 6,730’ 3 6,773’ NB Lateral Tie Back Sleeve 4 6,784’ NB Lateral ZXP Liner Top Packer 5 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 6 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 7 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 8 6,845’ NB Lateral Swell Packer 9 7,265’ OA Lateral Tie Back Sleeve 10 7,276’ OA Lateral ZXP Liner Top Packer 11 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 12 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 13 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 14 7,482’ OB Lateral Tie Back Sleeve 15 7,493’ OB Lateral ZXP Liner Top Packer 16 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 17 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 18 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 19 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 Install Kill String ASR#1 – 9/28/2020 Suspended by ASR#1 – 11/4/2020 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg 13 12 11 8 7 4 6 3 5 2 9 1 10 14 15 17 191618 353637383940 20 23 2128 MILNE POINT I PAD Sec. 33 ADL25906 U013N010E MILNE POINT UNIT F B CL S EJ I KH A MINE CFP D G M MINE N S&K MOOSE PAD TEXACO MILNE POINT UNIT MPU I PAD LOCATION MAP Date: December 2020 Map Author: HAK - MRA Map 11 of 23 Map Center Coordinates: LAT: 70.436121 LON: -149.582601 NAD 1983 Decimal Degrees Map Imagery Date: 8/2020 (QSI) 1 inch = 125 feet 1500 FeetMap Scale 1: Well I-14 Su�pended Well Inspection Revlew Report ' |nspectNo: su»MFH210726130818 Date Inspected: 7/25/2021 . Inspector: Matt Herrera Type of Inspection Well Name: M|LNEPTUN|T|'14 Permit Number: 2041190 - SuspensinnApArova|� Sundry - # 320-376 - Suspension Date: 11/4/2020 ' Location Verified? W |fVerified, How? Other (specify incomments) Offshore? 11 Initial Date AOG[[Notified: 7/24/2021 ' Operator: Hi|corpA|aska, LLC Operator Rep: Jon Arend Wellbore 0aDramAvail? PhniusTaken? Well Pressures (psi): Tubing: O Fluid in Cellar? [] |A: 60 BPV|nstaUed? 0A: 275 VRP|ug(s)Installed? Wellhead Condition Good. novisible leaks onflanges orconnections. All Master, swab and rasingvalves operational. Gauges were zeroed and ^' re -pressured and verified operational. NoSSV installed [ondihonofCellar Good, very slight amoutufrainwater, nosheen. Notrash u/debris ~ SonoundinpSurfaceCondition ' Good, gravel around cellar clean with novisible stains nrsubsidence. Comments Well location verified by drill site map. Barricade around well head. Well sign hanging ontree with correct pertinent well ~^ information. Supervisor Comments Photos (2)attached Wednesday, July 28'2O21 Suspended Well Inspection — MPU 1-14 AOGCC Inspect # susMFH210726130818 PTD 2041190 Photo by AOGCC Inspector M. Herrera 7/25/2021 WELL: MPI -14 ML' 00 `' OWNER Milne Point Unit OPERATOR HILCORP Alaska, LLC API NUMBER 50-029-23214-00-00 SUR. LOCATION SW 1/4, Sec. 33, T13N. R10E F !. DRILLING PERMrr 204-119 2021-0725_Suspend_MPU_I-14_photos. docx Page 1 of I Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 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: 01/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-14 (PTD 204-119) COIL FLAG 10/12/2020 Please include current contact information if different from above. PTD: 2041190 E-Set: 34583 Received by the AOGCC 01/19/2021 Abby Bell 01/19/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 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: 01/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-14 (PTD 204-119) COIL FLAG 10/11/2020 Please include current contact information if different from above. PTD: 2041190 E-Set: 34582 Abby Bell 01/19/2021 Received by the AOGCC 01/19/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 34.80 BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 112' 10-3/4" K-55 2,286' 7-5/8"K-55/L-80 3,994' 4" L-80 3,979' 4-1/2" L-81 3,837' 4-1/2" L-82 4,033' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Oil-Bbl: Water-Bbl: Sr Res EngSr Pet Geo Water-Bbl: PRODUCTION TEST Sr Pet Eng Flow Tubing Date of Test: Oil-Bbl: Electric Submerible Pump Per 20 AAC 25.283 (i)(2) attach electronic information Gas-Oil Ratio:Choke Size: Surface 3,777' 92 45.5 112' Surface 7,618' 9.5 June 21, 3396 TOP SETTING DEPTH MD Surface 6,773' 6011440.654 Surface 2,699' 29.7 9,740' 9-7/8" 6-3/4" Surface 3-1/2" 260 sx Arctic Set (Approx.) Surface 42" 6013649.783 N/A TOP suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A / N/A 1,800' (Approx.) N/A / N/A CASING N/A 546688.0467 ADL0025517 & ADL00259069,863 / 4,033' 9,863 / 4,033'551314.8984 6009460.655 MILNE POINT / SCHRADER BLUFF OIL4,539' NSL, 3,379' WEL, SEC. 32, T13N, R10E, UM (OB) 1,292' NSL, 3,470' WEL, SEC. 29, T13N, R10E, UM (OB) 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 11/4/2020 August 2, 2004 50-029-23214-00-00 August 11, 2004 MILNE PT UNIT I-14 204-119 / 320-376 2,438' NSL, 4,055' WEL, SEC. 33, T13N, R10E, UM 68.16 Uncemented Slotted Liner BOTTOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas DEPTH SET (MD) N/A PACKER SET (MD/TVD) 12.6 7,265' 7,482' 12.6 6-3/4" 9,885' 750 sx Class 'G' 3,910' 3,970' 6,7304-1/2" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Uncemented Slotted Liner6-3/4" TUBING RECORD Uncemented Slotted Liner 9,863' HOLE SIZE AMOUNT PULLED 316 sx AS Lite, 259 sx Class 'G' CEMENTING RECORDWT. PER FT.GRADE SETTING DEPTH TVD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 10:04 am, Nov 25, 2020 2348' 4359' RBDMS HEW 11/30/2020 Suspension Date 11/4/2020 HEW xG SFD 12/1/2020 DSR-12/2/2020MGR24DEC2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1,800' (Approx.) 1,719' Top of Productive Interval 6,900' 3,803' 6,735' 3,768' 6,763' 3,775' 6,836' 3,794' 6,859' 3,800' 6,934' 3,820' 6,981' 3,832' 7,001' 3,838' 7,032' 3,846' 7,045' 3,849' 7,211' 3,894' 7,334' 3,930' 7,445' 3,961' 7,586' 3,990' 7,691' 3,999' 8,154' 4,023' 8,927' 4,000' 9,237' 4,034' 9,679' 4,043' Schrader Bluff 31. List of Attachments: Wellbore schematic and operation summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Chad Helgesen Contact Name: Abhijeet Tambe Operations manager Contact Email:Abhijeet.Tambe@hilcorp.com Authorized Contact Phone:777-8485 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. SBA5 Formation at total depth: SBF1-NB SBF2-NA SBF12 SBE3-ND SBF21 SBF24-MF INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. TSBB-OB SBE2-NE SBE1-NF TSBD-OA TSBC The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). TSBB-OB SBE4-NC SBE41 TSBB-OB SBA5 TSBB-OB Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Chad A Helgeson 2020.11.25 12:26:22 -06'00' _____________________________________________________________________________________ Revised By: TDF 11/23/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 12 13 10-3/4” 13 14 15 TOC @ 6,473’ SLM PBTD =9,863’ (MD) / TD = 4,033’(TVD) 6 7 Orig. KB Elev.: 68.16’ Doyon 14 13 3 4 5 8 9 10 11 16 1 2 Tubing Cut @ 6,430‘ SLM 11111313333333333331133333133333311313131 111113333333333331333331111133333333333313333113331333 “OB” Lateral l “NB” Lateral “OA” Lateral “OB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / EZ-GO HT 3.958 Surface 6,730’ JEWELRY DETAIL No Depth Item 1 6,707’ X -Nipple 2 6,728’ Mule Shoe –Bottom @ 6,730’ 3 6,773’ NB Lateral Tie Back Sleeve 4 6,784’ NB Lateral ZXP Liner Top Packer 5 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 6 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 7 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 8 6,845’ NB Lateral Swell Packer 9 7,265’ OA Lateral Tie Back Sleeve 10 7,276’ OA Lateral ZXP Liner Top Packer 11 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 12 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 13 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 14 7,482’ OB Lateral Tie Back Sleeve 15 7,493’ OB Lateral ZXP Liner Top Packer 16 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 17 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 18 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 19 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 Install Kill String ASR#1 – 9/28/2020 Suspended by ASR#1 – 11/4/2020 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 Slickline 50-029-23214-00-00 204-119 9/17/2020 9/29/2020 9/18/2020 - Friday No operations to report. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/17/2020 - Thursday WELL O/L ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 2,500H. RAN KJ, 2-7/8" OK-6 W/ 1-1/4" JDC (steel) 3 TIMES & PULLED BK-DGLV FROM ST# 1 @ 6,181' SLM (6,173' MD), ALL PACKING RECOVERED, REFER TO JOB LOG FOR RUN DETAILS. PULLED BEK-OGLV FROM ST# 2 @ 131' SLM (146' MD), ALL PACKING RECOVERED. SET BK-DGLV IN ST# 2 @ 131' SLM (146' MD), SAW 1' OF TRAVEL, SHEARED OFF CLEAN. 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 Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 ASR#1 50-029-23214-00-00 204-119 9/17/2020 9/29/2020 9/25/2020 - Friday No operations to report. 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/24/2020 - Thursday No operations to report. Rig Down off of I-14 and mobilize equipment to A-pad for short term storage. Continue to RD. ND BOP, NU tree on I-14. Continue with equipment loadout to A-pad. Wells Group assists in well kill. Monitor well, conduct bleed, well dead. Install BPV with test dart. Clear location of well ki ll equipment. Remove secondary IA valve. ND Tree. Stage in Mud Boat, begin staging trailers and equipment on location. 9/26/2020 - Saturday POH with ESP Assembly on 2-7/8" tubing. Lay down ESP assembly. Clear and clean rig floor of equipment. Change out equipment in preparation to RIH with 4-1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. RIH with 4-1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. Continue to RIH with 4- 1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. Significant slack-off at ~6,540' md. Attempt to work pipe down. Consult with team and Day Supervisor. RU Power Swivel to Top Drive. Set torque limits to 2,000 ft/lbs. Rotate and reciprocate pipe in small movements. Able to make 2-3' gains with each rotation and reciprocation attempt. Work down with 2 joints (66') before normal calculated hanging weight is seen. Continue to MU with Power Swivel but able to move down with slow and steady set down weight. Begin to see Slack Off at makeup on Joint 202, ~6,710' md. Tag at 9' in. Make 6 pickups and setdowns to confirm tag. On fifth pickup, rotate while setting down to ensure Muleshoe is not hanging up and observe same slackoff at same depths. Pick up, stop rotation, use 5' stick to measure for space out. Lay down jts 202 and 201, MU pup jts and hanger, land assembly. PUW ~58k, SO ~32k. Calculated air string weight hanging off hanger 85k. Run in Lockdown Screws, secure well. Begin Rig Down operations. 9/29/2020 - Tuesday 9/27/2020 - Sunday Conduct PJSM with crew, conduct equipment and fluid checks;Complete rigging up. Monitor while fluid packing lines, all good. Fluid pack to BOP, no leaks. Conduct Shell test of 13-5/8" BOP to 250 psi low / 2,500 psi high. Troubleshoot bleed off, reconduct test and good test. Test BOP to 250 psi low / 2,000 psi high per Sundry with 2-7/8" and 4-1/2" test joints. Test Fire and Gas alarms. Conduct drawdown test. Test completed. Clear and clean rig floor of BOP test equipment. Stage in equipment for pulling completion. Bleed IA in preparation for pulling BPV. Conduct Sundry meeting with Day crew. Bleed IA and confirm 0 psi. Attempt to pull BPV and note some pressure underneath. Pump tubing volume through BPV taking returns through IA. Tubing on vacuum. Pull BPV. BOLDS. Unseat tubing hanger and pull to the floor. PUW = 45k. Cut and secure both ESP and heat trace cables. POOH laying down 2-7/8" 6.5# EUE tubing. Spool ESP cable and heat trace cable. 9/28/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 ASR#1 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 No operations to report. (Pressure test RU. 250/2500psi) Pumped 25 bbls criesel down IA. Pumped 25 bbls criesel down TBG. Tags hung. Centrilift Pull Report. 10/3/2020 - Saturday No operations to report. 10/6/2020 - Tuesday 10/4/2020 - Sunday No operations to report. 10/5/2020 - Monday 10/2/2020 - Friday No operations to report. 9/30/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/1/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 CTU 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 Log with READ GC/CCL from 7,700' to 6,780.2' and paint flag. Continue logging to 6,500'. POOH and verify good data. MU 4.5" Alph cement retainer and RIH to flag depth. Correct to element of cement retainer. PUH to setting depth of 7,560'. Pump 1/2" aluminum ball to set retainer. Ball landed and sheared at 40.8 bbls away. Set 10k down to confirm set. Perform injectivity test through retainer. R/U and pressure test cement pump and lines. Pump 43.1 bbls of 15.8 ppg class G cement. Pump all cement away and unsting from retainer with 20k overpull. Displace cement with Powervis and POOH. M/U 2nd cement retainer BHA. RIH and correct depth at EOP flag. RIH past setting depth and PUH to 7,250'. Drop 1/2" aluminum ball to set retainer. Set 10k down and confim retainer is set. Perform injectivity test. Pump 45 bbls of 15.8 ppg class G cement. Unsting from retainer at 39k up weight. POOH. MU READ 40 arm caliper for log of final retainer setting depth. MIRU Test BOPE to 250 low / 4,000 high. Continue operations 10/11/2020. 10/10/2020 - Saturday MU BOT Milling BHA and RIH. Stop at EOP flag at 6,481.07' and correct depth. Tag on depth at 6,801', PU and start milling. Had several stalls but eventualy milled through restriction. Backreamed to 6,790', shut down the pump and dry drifted through clean. RIH to tag fill and start FCO. Clean out to 7,700'. POOH while freeze protecting coil. Noted damaged cutters on gauge of mill. M/U and RIH with READ GR CCL logging BHA. Begin logging up from 7,700' ctmd. 10/13/2020 - Tuesday 10/11/2020 - Sunday RIH with 3.61 OD Drift Nozzle and READ Gamma CCL Logging Tools. Tag LEM at 6,804' made several attempts to get past. Log up to 6,500', make 1 more attempt to pass through LEM without success. Discuss options with Wells Foreman and OE and POOH to drift for Caliper tools. MU 2.75" Drift with Stingers and RIH. Ran past 6,804' clean. Continue RIH and tagged in lower LEM. Attempt to get jet through possible bridge and we are cleaning out fill. Decision made to POOH for a motor & mill to clean up upper LEM to pass retainers and clean out fill to 7,700'. 10/12/2020 - Monday 10/9/2020 - Friday No operations to report. 10/7/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/8/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 CTU 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 10/16/2020 - Friday No operations to report. 10/14/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Caliper log from 6,900' to 6,500' and paint EOP corelation flag. POOH and confirm good data. MU and RIH with 4-1/2" Alpha cement retainer. Correct at flag depth and set retainer at 6,803'. Drop 1/2" aluminum ball and set retainer at 41.5 bbls. Set 10k down and confirm set. MU and PT cement pump. Batch and test 45 bbls of 14.0 ppg Squeezecrete. Pump 41 bbls of 14.0 ppg Squeezecrete through retainer at 1.0 bpm and note increasing pressure as cement filled lateral. Unsting from retainer and leave 0.5 bbls of cement on top of retainer. POOH. MU and RIH with 2.50" BDJSN w/0.75" hole. Displace backside with KCL followed by diesel. Displace coil with KCL taking returns from tubing. Begin pumping 15.8 ppg class G cement down coil w/fresh water spacers. Pump 1 bbl cement around nozzle and begin taking returns from IA 1:1 with 40bbl gauge tank. Pump 13.1 bbls behind tubing and swap to take returns from tubing. @ 1 bpm. POOH laying in cement 1:1 to 6,398.2'. RBIH and contaminate to 6,500' ctmd. Pump .81" ball. Contaminated and washed down to 6,490' ctmd. POOH washing/contaminating at 80% with Powervis 10/15/2020 - Thursday No operations to report. No operations to report. No operations to report. 10/17/2020 - Saturday No operations to report. 10/20/2020 - Tuesday 10/18/2020 - Sunday No operations to report. 10/19/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 Slick line 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 No operations to report. No operations to report. 11/7/2020 - Saturday No operations to report. 11/10/2020 - Tuesday 11/8/2020 - Sunday No operations to report. 11/9/2020 - Monday 11/6/2020 - Friday No operations to report. 11/4/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. DRIFT TBG WITH 3.25" CENT, 5'x2.5" DRIVE DOWN BAILER (mule shoe ball) TO 6,473' SLM (recovered ~1/2 cup cement, state witnessed). PERFORM STATE WITNESS MIT-T 1,500psi WITH TRIPLEX (pass, see log for details). PERFORM STATE WITNESS MIT-IA 1,500psi WITH TRIPLEX (pass, see log for details). LOG TBG WITH HES MEMORY CCL-PRESSURE-TEMP TOOL FROM 6,470' SLM TO 6,270' SLM (good data). CUT TBG AT 6,430' SLM WITH HES MEMORY JET CUTTER. RDMO, CLOSE PERMIT W/PAD-OP. 11/5/2020 - Thursday No operations to report. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Coil Cleanout w/ N2 Performed: Suspend Perforate Other Stimulate Alter Casing Pump Cement Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Kill String 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 9,863 feet N/A feet true vertical 4,033 feet N/A feet Effective Depth measured 9,863 feet feet true vertical 4,033 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.75 / L-80 / EZ GO HT 6,730' 3,767' Packers and SSSV (type, measured and true vertical depth)(3) Baker ZXP LTP 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 13 Water-Bbl MD 112' 2,699' 7,618' 9,863' 4,033' 3,837' 0 Oil-Bbl measured true vertical Packer 4.5" 4.5" 3,780, 3,913 & 3,972 6,784, 7,275 & 7,493 Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 NB Liner OA Liner TVD 112' 3. Address: 4. Well Class Before Work: 216 Representative Daily Average Production or Injection Data 219367 Size MILNE PT UNIT I-14 Gas-Mcf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-119 50-029-23214-00-00 Plugs ADL0025517 & ADL0025906 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-367 0 Authorized Signature with date: Authorized Name: Abhijeet Tambe Abhijeet.Tambe@hilcorp.com 20 280 Casing Pressure Tubing Pressure 0 N/A measured 2,966' 2,620' N/A Casing Conductor OB Liner 2,381' Length 78' 2,665' 7,585' Surface Production 20" 10-3/4" 7-5/8" 4" 8,430psi 2,286' 3,994' 3,979'9,740' 9,885' 4,790psi 6,590psi Burst N/A 5,210psi 6,890psi 7,910psi 2,470psi 7,500psi 7,500psi 777-8485 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,430psi Collapse N/A PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:03 pm, Nov 12, 2020 Chad A Helgeson 2020.11.12 15:03:53 -09'00'DSR-11/13/2020 SFD 11/17/2020RBDMS HEW 11/13/2020 MGR13NOV2020 _____________________________________________________________________________________ Revised By: TDF 11/9/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/29/2020 PTD: 204-119 20 21 19Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 14 15 10-3/4” 13 16 17 PBTD =9,863’ (MD) / TD = 4,033’(TVD) 8 9 Orig. KB Elev.: 68.16’ Doyon 14 13 5 6 7 10 11 12 13 18 1 2 3 4 1111113133333333333113111113113333333333331113133333331333333311 1111111333333333331131111111111333333333331333333133113 “OA” Lateral “OB” Lateral “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.75 / L-80 / EZ-GO HT 3.958 Surface 6,730’ JEWELRY DETAIL No Depth Item 1 6,707’ X –Nipple w/ 3.813” Profile 2 6,708’ 4-1/2" 12.75# EZ-GO Pup Jt w/ Perforations 3 6,718’ No-Go: 4-1/2" pup w/fluted 6.70" no-go and (4) 3/8" brass shear screws 4 6,728’ Mule Shoe – Bottom @ 6,730’ 5 6,773’ NB Lateral Tie Back Sleeve 6 6,784’ NB Lateral ZXP Liner Top Packer 7 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 8 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 9 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 10 6,845’ NB Lateral Swell Packer 11 7,265’ OA Lateral Tie Back Sleeve 12 7,276’ OA Lateral ZXP Liner Top Packer 13 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 14 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 15 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 16 7,482’ OB Lateral Tie Back Sleeve 17 7,493’ OB Lateral ZXP Liner Top Packer 18 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 19 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 20 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 21 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 Install Kill String by ASR –9/29/2020 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 Slickline 50-029-23214-00-00 204-119 9/17/2020 9/29/2020 9/18/2020 - Friday No operations to report. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/17/2020 - Thursday WELL O/L ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 2,500H. RAN KJ, 2-7/8" OK-6 W/ 1-1/4" JDC (steel) 3 TIMES & PULLED BK-DGLV FROM ST# 1 @ 6,181' SLM (6,173' MD), ALL PACKING RECOVERED, REFER TO JOB LOG FOR RUN DETAILS. PULLED BEK-OGLV FROM ST# 2 @ 131' SLM (146' MD), ALL PACKING RECOVERED. SET BK-DGLV IN ST# 2 @ 131' SLM (146' MD), SAW 1' OF TRAVEL, SHEARED OFF CLEAN. 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 Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 ASR#1 50-029-23214-00-00 204-119 9/17/2020 9/29/2020 9/25/2020 - Friday No operations to report. 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/24/2020 - Thursday No operations to report. Rig Down off of I-14 and mobilize equipment to A-pad for short term storage. Continue to RD. ND BOP, NU tree on I-14. Continue with equipment loadout to A-pad. Wells Group assists in well kill. Monitor well, conduct bleed, well dead. Install BPV with test dart. Clear location of well kill equipment. Remove secondary IA valve. ND Tree. Stage in Mud Boat, begin staging trailers and equipment on location. 9/26/2020 - Saturday POH with ESP Assembly on 2-7/8" tubing. Lay down ESP assembly. Clear and clean rig floor of equipment. Change out equipment in preparation to RIH with 4-1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. RIH with 4-1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. Continue to RIH with 4- 1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. Significant slack-off at ~6,540' md. Attempt to work pipe down. Consult with team and Day Supervisor. RU Power Swivel to Top Drive. Set torque limits to 2,000 ft/lbs. Rotate and reciprocate pipe in small movements. Able to make 2-3' gains with each rotation and reciprocation attempt. Work down with 2 joints (66') before normal calculated hanging weight is seen. Continue to MU with Power Swivel but able to move down with slow and steady set down weight. Begin to see Slack Off at makeup on Joint 202, ~6,710' md. Tag at 9' in. Make 6 pickups and setdowns to confirm tag. On fifth pickup, rotate while setting down to ensure Muleshoe is not hanging up and observe same slackoff at same depths. Pick up, stop rotation, use 5' stick to measure for space out. Lay down jts 202 and 201, MU pup jts and hanger, land assembly. PUW ~58k, SO ~32k. Calculated air string weight hanging off hanger 85k. Run in Lockdown Screws, secure well. Begin Rig Down operations. 9/29/2020 - Tuesday 9/27/2020 - Sunday Conduct PJSM with crew, conduct equipment and fluid checks;Complete rigging up. Monitor while fluid packing lines, all good. Fluid pack to BOP, no leaks. Conduct Shell test of 13-5/8" BOP to 250 psi low / 2,500 psi high. Troubleshoot bleed off, reconduct test and good test. Test BOP to 250 psi low / 2,000 psi high per Sundry with 2-7/8" and 4-1/2" test joints. Test Fire and Gas alarms. Conduct drawdown test. Test completed. Clear and clean rig floor of BOP test equipment. Stage in equipment for pulling completion. Bleed IA in preparation for pulling BPV. Conduct Sundry meeting with Day crew. Bleed IA and confirm 0 psi. Attempt to pull BPV and note some pressure underneath. Pump tubing volume through BPV taking returns through IA. Tubing on vacuum. Pull BPV. BOLDS. Unseat tubing hanger and pull to the floor. PUW = 45k. Cut and secure both ESP and heat trace cables. POOH laying down 2-7/8" 6.5# EUE tubing. Spool ESP cable and heat trace cable. 9/28/2020 - Monday MEMORANDUM TO: Jim Regg P. 1. Supervisor FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 4, 2020 SUBJECT: Plug Verification MPU 1-14 Hilcorp Alaska LLC PTD 2041190; Sundry 320-376 Section: 33 Township: 13N Range: 10E Drilling Rig: NA Rig Elevation: NA Total Depth: 9863 ft MD Operator Rep: Josh McNeal Suspend: X .✓ Casing/Tubing Data (depths are MD): Conductor: 20" -O.D. Shoe@ 112 Feet Surface: 10 3/4" O.D. Shoe@ 2669 Feet Intermediate: Feet O.D. Shoe@ Feet Feet Production: 7 5/8" O.D. Shoe@ 7618 Feet Liner: 41/2" O.D. Shoe@ 9885 Feet Tubing: 41/2" O.D. Tail@ 6776 Feet Plugging Data: Test Data Meridian: Umiat Lease No.: ADL 25906 P&A: T pe Plug Casing Removal: Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Tbg Cut@ na Feet T pe Plug Founded on Depth Btm Depth Top MW Above verinea Tubing Retainer 6803 ft MD 6473 ft MD" Wireline tag 0 P OA 240 240 240 240 1. + _l I r, min 4n min 45 min Result Tubing 1685 1622 1584 1573 " IA IA 0 0 0 0 P OA 240 240 240 240 I..4;_1 1 G _in '2n min At; min RP.Slllt Tubing 300 350 350 IA 1682 1604- 1582 P OA 240 - 240 240 Remarks: I traveled out to Milne Pt. Unit 1-14 for a plug verification. Well is to be suspended. Wireline tag tool string consisted of weight bars and a 5' x 2.5" drive down bailer: 275 lbs hanging weight. Tagged top of cement @ 6,473 ft MD. Chippy cement sample in bailer. Pressure tests of tubing and IA charted - both pass. rev. 11-28-18 2020-1104_Plug_Verification_MPU_I-14_ae 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Coil Cleanout w/ N2 Suspend Perforate Other Stimulate Pull Tubing Pump Cement Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Cut 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): 9,863'N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi NB Liner 6,590psi OA Liner 7,500psi OB 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:Abhijeet.Tambe@hilcorp.com Contact Phone: 777-8485 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 Abhijeet Tambe MILNE POINT / SCHRADER BLUFF OIL COMMISSION USE ONLY Authorized Name: 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 204-119 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23214-00-00 Hilcorp Alaska LLC Length Size 4,033' 9,863' 4,033' 639 N/A MILNE PT UNIT I-14 112'112' 12.66# / L-80 / Vam Top TVD Burst ±6,776 8,430psi MD N/A 2,966'7,910psi 5,210psi 6,890psi 2,286' 3,994' 3,979' 4.5" 2,699' 7,618' 4.5" 78'20" 10-3/4" 7-5/8" 2,665' 4" 2,620' 7,585' Authorized Signature: TBD 9,863'2,381' 4-1/2" 4,033' Perforation Depth MD (ft): See Schematic 3,837' See Schematic C.O. 477.05 9/11/2020 (3) Baker ZXP LTP and N/A 6,784 MD/ 3,780 TVD, 7,276 MD/ 3,913 TVD & 7,493 MD/ 3,972 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. 9,885' 9,740' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.11 18:36:37 -05'00' By Samantha Carlisle at 3:56 pm, Sep 11, 2020 320-376 SFD 9/11/2020MGR16SEP20 AOGCC to witness pressure test abandonment plug to 1500 psi and tag of cement (~ 6200' MD). First on-site inspection by AOGCC within 1 calendar year per 20 AAC 25.110(e). X DSR-9/15/2020 DSR-9/15/2020 10-407 DSR-9/15/2020 X Comm. 9/18/2020 dts 9/18/2020 JLC 9/18/2020 RBDMS HEW 9/21/2020 Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 Well Name:MPU I-14 API Number:50-029-23214-00 Current Status:Shut-In (ESP removed)Pad:I-Pad Estimated Start Date:09-17-2020 Rig:Coiled Tubing Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-119 First Call Engineer:Abhijeet Tambe (907) 777-8485 (O) (907) 331-9184 (M) Second Call Engineer:Ian Toomey (907) 777-8343 (O) (907) 903-3987 (M) AFE Number:Job Type:Reservoir Abandonment Current Bottom Hole Pressure:1,039 psi @ 4,000 TVD NB+OA+OB SBHP (08/16/2017 SI gauge reading) 4.99 PPG Maximum Expected BHP:1,039 psi @ 4,000’ TVD (EMW: 4.99 ppg) MPSP:639 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 76° at 6,710’ MD Max Dogleg:7.6°/100ft at 2,013’ MD Brief Well Summary: MPU producer I-14 was drilled and completed as a Schrader Bluff producer in August 2004. OB and OA laterals were completed with 4-1/2” slotted liner while NB lateral was completed with 4” Baker Med Excluder Screens. ESP was changed out in 2007 and has been on production with the same ESP making approximately 200 bopd and 400 bwpd. Notes Regarding Wellbore Condition x 4-1/2” work string with mule shoe, perforated pup & X nipple stabbed into NB Tie Back sleeve at 6,773’ MD (Sundry 320-367). Objective: The purpose of this work is to abandon/isolate both Schrader intervals (N and O sands) with cement. The Schrader NB/OA/OB intervals needs to be abandoned for the new wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s. Coil Tubing Procedure: 1. MIRU Coiled Tubing Unit w/ 2.0” coil and spot ancillary equipment. 2. Fill source tank w/source water. 3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. c. No AOGCC notification required. d. Record BOPE test results on 10-424 form and submit within 5 days of test. 4. RIH w/ CCL memory logging carrier in conjunction with TEL/Nipple locator and 3.56” or equivalent jet swirl nozzle to ~7,540’ MD. Wash down as needed. a.Contingency: : If unable to reach bottom, RIH w/ 2.0” to 3.25” mill and extended reach cleanout BHA and cleanout to PBTD using 8.5 ppg 1% KCl w/liquid foamer and mix with Nitrogen. b. Depth is critical for setting the top cement retainer (above NB lateral) and by running TEL/nipple locator along with GR/CCL will help with tie-in and verification. Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 c. Min ID = 3.688” (LEM #2 @ 6,799’ & LEM #1 @ 7,311’ MD). 5. Mark CT as necessary for future runs and log OOH. Flag X nipple also and watch for the 3.688” profiles (slight over pull while pulling through LEMs) 6. Log up to 6,700’ and POOH. 7. LD CCL memory logging carrier. Abandoning OB Lateral (Slotted Liner) 8. MU 4-1/2” One Trip cement retainer and cementing nozzle and RIH. Correct depth at flag. a. Objective is to cement OB lateral. 9. Set Cement Retainer mid blank pipe joint at ±7,530’ MD – above OB lateral. a. Set down weight onto retainer to confirm set. 10. Establish injection through CT & cement retainer to ensure we have injection rate prior to the cement job. 11. Begin to mix 15.8 ppg retarded class G cement. Once blend is ready, pump ± 40 bbls of class G cement down the coil tubing. a. This cement slurry is slightly retarded as a contingency. If there is communication with the OH through the junction, cement could channel up on the back side and travel behind CT. Having slightly retarded cement gives us an opportunity to unsting from the retainer and POOH without getting stuck. b. Use freshwater spacers as needed around the cement. c. Target is to get all of 40 bbls of cement pumped through the retainer (4-1/2” slotted liner volume from retainer = 36 bbls) d. Do not exceed 1,000 psi above circulating pressure while pumping cement. e. If pressure starts to build up and unable to pump cement, unsting from the retainer and bullhead the cement away. In this scenario, cement could go into OB or into OA lateral above. After pumping cement away, contaminate cement to ±7,400’ as the next retainer will be set at ±7,306’ MD. 12. Once target cement volume is pumped through retainer or CT pressure exceeds 1,000 psi, come off the pumps and unsting from the retainer. Allow ~1/2 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle stopping at 7,308’ to flag pipe. 13. Circulate coil tubing clean and POOH. Watch for and verify TEL/Nipple Profile locator at landmark features like 3.688” Seal Bores, Tubing Tail and X Nipple. Abandoning OA lateral (slotted liner) 14. MU 4-1/2” One Trip cement retainer and cementing nozzle and RIH. Note:Cement retainer (FH) running tool needs to be redressed prior to RIH. 15. Using the same flag from previous run, set Cement Retainer mid blank pipe joint at ±7,306’ MD – above LEM1 (OA lateral). a. Set down weight onto retainer to confirm set. Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 16. Establish injection through CT & cement retainer to ensure we have injection rate prior to the cement job. 17. Begin to mix 15.8 ppg class G cement. Once blend is ready, pump ± 50 bbls of class G cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. Target is to get all of 50 bbls of cement pumped through the retainer (4-1/2” slotted liner volume from retainer = 45 bbls) c. Do not exceed 1,000 psi above circulating pressure while pumping cement. d. If pressure starts to build up and unable to pump cement, unsting from the retainer and bullhead the cement away. In this scenario, cement could go into OA or into NB lateral above. After pumping cement away, contaminate cement to ±7,000’ as the next retainer will be set at ±6,800’ MD 18. Once targetcement volume is pumped through retainer or CT pressure exceeds 1,000 psi, come off the pumps and unsting from the retainer. Allow ~1/2 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle stopping at 6,807’ to flag pipe. 19. POOH and circulate coil tubing clean as needed. Watch for and verify TEL/Nipple Profile locator at landmark features like 3.688” Seal Bores, Tubing Tail and X Nipple. Abandoning NB lateral (Screens) 20. MU 4-1/2” One Trip cement retainer and cementing nozzle and RIH. Note:Cement retainer (FH) running tool needs to be redressed prior to RIH. 21. Using the flag from previous run, set Cement Retainer in 9.80” section of the 4-1/2” (between 6,799’ and 6,807’ MD – above LEM2 (NB lateral). a. Set down weight onto retainer to confirm set. b. Pump down CTxT annulus to ~100 psi to confirm that retainer is fully set 22. Begin to mix Microfine Cement. Once blend is ready, pump ± 55 bbls of Microfine cement down the coil tubing. a. Use freshwater spacers as needed around the cement. Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 b. Target is to get all of 55 bbls of cement pumped through the retainer (4-1/2” Med Excluder screens volume from retainer = 52 bbls) c. Do not exceed 1000 psi above circulating pressure. 23. Once target minimum cement volume is pumped through retainer or CT pressure exceeds 1,000 psi, come off the pumps and unsting from the retainer. Allow ~1/2 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle. b. There is a perforated joint below the X-nipple in the 4-1/2” work string that will enable us to pump (fullbore) the AOGCC required cement plug to isolate Schrader Bluff. So we do not want to cover those holes by laying too much cement above the retainer. 24. POOH and circulate coil tubing clean as needed. 25. RD CT unit. Fullbore / Slickline / Wireline Procedure – reservoir abandonment cement plug 26. RU cementers. 27. Establish circulation down 4-1/2” work string, through the perforated joint in the tail pipe and up the annulus. 28. Pressure test the casing and tubing (jug test) to 1,500 psi, and ensure the cement retainers are holding pressure 29. Mix and pump 20 bbls of 15.8 Class G cement followed with xx bbls of water and freeze protect fluid to spot cement above packer for 500ft cap in tubing and casing. a. 7-5/8” X 4-1/2” ann. Cap = 0.0246 bbls/ft. Cement volume = 0.0246 X 500 ft = 12.3 bbls 30. Wait on cement to gain 1,000 psi compressive strength. 31. RU slickline, RIH, tag TOC expected at +/- 6,200ft. 32. Pressure test tubing and IA to 1,500 psi for 30 min charted. Note: Notify AOGCC prior to the pressure test. 33. RU wireline, RIH and cut the tubing just above TOC. RD wireline. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Coil BOPE Schematic 5. N2 procedures and schematic for contingency. MPU I-14 is mechanically sound and will be secured with a cement plug that isolates hydrocarbon zone (Schrader Bluff) completely. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The main reason for ‘suspension’ is to preserve the future utility of the wellbore for possible sidetracking opportunity to enhance drainage. Thank you. Abhijeet Tambe | Sr. Operations Engineer |Hilcorp Alaska, LLC O: (907) 777-8485 | C: (907)331-9184 | Abhijeet.Tambe@hilcorp.com 3800 Centerpoint Drive, Suite 1400 | Anchorage, AK 99503 _____________________________________________________________________________________ Revised By: TDF 9/1/2020 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 8/26/2007 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 12 13 10-3/4” 13 14 15 PBTD =9,863’ (MD) / TD = 4,033’(TVD) 6 7 Orig. KB Elev.: 68.16’ Doyon 14 13 3 4 5 8 9 10 11 16 1 2 1111113133333333333113111113113333333333331113133333331333333311 1111111333333333331131111111111333333333331333333133113 “OA” Lateral “OB” Lateral “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / Vam Top 3.548 Surface ±6,776’ JEWELRY DETAIL No Depth Item 1 ±6,752 X -Nipple 2 ±6,772 Mule Shoe – Bottom @ ±6,773 3 6,773’ NB Lateral Tie Back Sleeve 4 6,784’ NB Lateral ZXP Liner Top Packer 5 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 6 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 7 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 8 6,845’ NB Lateral Swell Packer 9 7,265’ OA Lateral Tie Back Sleeve 10 7,276’ OA Lateral ZXP Liner Top Packer 11 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 12 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 13 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 14 7,482’ OB Lateral Tie Back Sleeve 15 7,493’ OB Lateral ZXP Liner Top Packer 16 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 17 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 18 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 19 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg CURRENT DSR 9/15/2020 _____________________________________________________________________________________ Revised By: TDF 9/11/2020 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 8/26/2007 PTD: 204-119 16 17 15Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 10 11 10-3/4” 13 12 13Cement Retainer1 ±7,530’ PBTD =9,863’ (MD) / TD = 4,033’(TVD) 4 5 Orig. KB Elev.: 68.16’ Doyon 14 13 1 2 3 6 7 8 9 14 Cement Retainer 2 ±7,306’ Cement Retainer3 between ±6,799’ to ±6,807’ TOC @ ±6,700’ Tubing cut just above TOC “OA” Lateral 10 11 13 4 5 14 “OA” L “OB” Lateral “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 2.441 Surface 6,389’ JEWELRY DETAIL No Depth Item 1 6,773’ NB Lateral Tie Back Sleeve 2 6,784’ NB Lateral ZXP Liner Top Packer 3 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 4 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 5 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 6 6,845’ NB Lateral Swell Packer 7 7,265’ OA Lateral Tie Back Sleeve 8 7,276’ OA Lateral ZXP Liner Top Packer 9 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 10 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 11 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 12 7,482’ OB Lateral Tie Back Sleeve 13 7,493’ OB Lateral ZXP Liner Top Packer 14 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 15 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 16 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 17 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg Milne Point ASR Rig 1 BOPE 2020 Updated 1/09/2020 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 Coil Tubing BOP Milne Point Unit Revised: 1/8/2020 Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind Blind Lubricator 4 1/16 15M Slip Slip Shear Shear Pipe Pipe Manual Gate 2 1/8 5M 2.00" Stripper Crossover spool 4 1/16 15M X 4 1/16 10M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union Crossover spool 4 1/16 10M X 4 1/16 5M To injection head Kill Port Plug Valve 2" / 10K Manual Plug Valve 2" / 10K Manual Kill Port STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Coil Tubing Unit Fluid Flow Diagram Cleanout w/ Nitrogen & Foam Updated 9/22/16 LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Check Valve Manual Choke Pressure Gauge 500 BBL KILL TANK Choke Manifold P 400 BBL UPRIGHT P Open VBR BLIND COIL PUMP 400 BBL UPRIGHT Open Closed Open Open Open Open Open Open Open P SW or KCL W/ FOAMER OR FRIC TION REDUCER 50 BBL FREEZE PROTECT TANK SW or KCL W/ FOAMER OR FRIC TION REDUCER To Flowline NITROGEN PUMP & TANK P COIL UNIT WITH 1.5” to 2.0” COIL 400 BBL UPRIGHT SEAWATER W/ DEFOAMER TRIPLEX 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 Kill String 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): 9,863'N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi NB Liner 6,590psi OA Liner 7,500psi OB 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:Abhijeet.Tambe@hilcorp.com Contact Phone: 777-8485 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 3,837' See Schematic C.O. 477.05 9/2/2020 (3) Baker ZXP LTP and N/A 6,784 MD/ 3,780 TVD, 7,276 MD/ 3,913 TVD & 7,493 MD/ 3,972 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. 9,885' 9,740' 2,620' 7,585' Authorized Signature: 9/9/2020 9,863'2,381' 2-7/8" 4,033' Perforation Depth MD (ft): See Schematic 4.5" 2,699' 7,618' 4.5" 78' 20" 10-3/4" 7-5/8" 2,665' 4"2,966'7,910psi 5,210psi 6,890psi 2,286' 3,994' 3,979' MILNE PT UNIT I-14 112'112' 6.5# / L-80 / EUE8Rd TVD Burst 6,389' 8,430psi MD N/A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23214-00-00 Hilcorp Alaska LLC Length Size 4,033'9,863'4,033'639 N/A Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 204-119 Abhijeet Tambe MILNE POINT / SCHRADER BLUFF OIL COMMISSION USE ONLY Authorized Name: 8,430psi Tubing Grade: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.02 14:40:36 -08'00' By Samantha Carlisle at 3:13 pm, Sep 02, 2020 320-367 DLB 09/02/2020 10-404 DSR-9/2/2020 X BOPE test to 2000 psi. MGR08SEP20Comm 9/9/2020 dts 9/9/2020 JLC 9/9/2020 RBDMS HEW 9/9/2020 Pull ESP & Suspend Well Well: MPU I-14 Date: 09-02-2020 Well Name:MPU I-14 API Number:50-029-23214-00 Current Status:ESP Producer Pad:I-Pad Estimated Start Date:09-09-2020 Rig:ASR Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-119 First Call Engineer:Abhijeet Tambe (907) 777-8485 (O) (907) 331-9184 (M) Second Call Engineer:Ian Toomey (907) 777-8343 (O) (907) 903-3987 (M) AFE Number:Job Type:Pull ESP & suspend well Current Bottom Hole Pressure:1,039 psi @ 4,000 TVD NB+OA+OB SBHP (08/16/17 SI gauge reading)4.99 PPG Maximum Expected BHP:1,039 psi @ 4,000’ TVD (EMW: 4.99 ppg) MPSP:639 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 76° at 6,710’ MD Max Dogleg:7.6°/100ft at 2,013’ MD BPV Profile:2-1/2” CIW Type H Brief Well Summary: MPU producer I-14 was drilled and completed as a Schrader Bluff producer in August 2004. OB and OA laterals were completed with 4-1/2” slotted liner while NB lateral was completed with 4” Baker Med Excluder Screens. ESP was changed out in 2007 and has been on production with the same ESP making approximately 200 bopd and 400 bwpd. Notes Regarding Wellbore Condition x 2-7/8” tubing passed MITT to 2000 psi on 12/13/2007. Objective: The purpose of this work is to pull the ESP with the ASR rig and suspend the well. The Schrader NB/OA/OB intervals need to be abandoned for the new wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s. A new 10-403 will be submitted for reservoir abandonment with coil tubing at a later date. Pre-Rig Procedure: 1. RU Slickline unit. 2. Pull OV from GLM at 146’ and install DV. 3. Pull DV from GLM @ 6,173’ MD. Leave pocket open. 4. RD Slickline Unit. 5. RU LRS and PT lines. 6. Bleed pressure off well (tubing and IA) to tank. Shoot fluid level in well. 7. Bullhead 38 bbls of 8.3 source water down tubing to the formation. 8. Pump 1 IA volume (265 bbls) with 8.3 source water down IA. 9. Clear and level pad area in front of well. Spot rig mats and containment. 10. RD well house and flowlines. Clear and level area around well. 11. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. Pull ESP & Suspend Well Well: MPU I-14 Date: 09-02-2020 a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 12. RD LRS. 13. RU crane. Set BPV. ND Tree. Install the plug off tool into the BPV. 14. NU BOPE. RD Crane. 15. RU BOPE house. Spot mud boat. RWO Procedure: 16. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 17. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with 8.3 source water prior to pulling BPV. 18. Set TWC. 19. Test BOPE to 250/3,000 psi and annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR #1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR’s and annular with 2-7/8” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking 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. 20. RU to pull 2-7/8” ESP completion. 21. Pull the plug off tool, check for pressure under the BPV, if needed kill the well with 8.3 ppg source water and pull the BPV. 22. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. PU: 47K and SO: 35K lb recorded when landed by Nabors 4ES in 2007 in brine during ESP change out. 23. Cut and secure cables. Lay down the landing joint and tubing hanger. RU to pull ESP cable and heat trace cable over sheaves to spooling units. a. Inspect the tubing hanger and note any corrosion or damage. Pull ESP & Suspend Well Well: MPU I-14 Date: 09-02-2020 Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 24. POOH laying down 2-7/8” tubing spooling ESP cable and removing all jewelry as it presents itself. Lay down ESP components. a. From surface to 6,344’ there is ESP cable b. From surface to 3,450’ there is heat trace cable c. Cables clamped with 50 LaSalle clamps Equipment Disposition Tubing hanger Visually inspect on site then reuse, restock or junk Tubing & Pup joints Junk Gaslift Mandrels/Nipple Junk ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Capillary Tubing Junk LaSalle Clamps, Protectorlizers, etc Visually inspect on site then reuse, restock or junk 25. RIH w/ 4-1/2” used tubing to ± 6,773’ MD. a. Note: will not run a seal assembly. RIH with a mule shoe/entry guide to enter tie back sleeve. 26. Tag tie back sleeve, PU above tie back to be able to circulate. 27. Pump corrosion inhibited brine (±130 bbls 1% KCl + CI) and freeze protect fluid down the IA (±60 bbls freeze protect) to 2,100’ MD. 28. Tag no-go, PU 2’-3’ and space out to land. Note: Baker tie back sealbore is 3.3’ long w/3.875” ID. 29. Land tubing hanger. RILDS. Lay down landing joint. Note: PU (Pick Up) and SO (Slack Off) weights on tally. 30. Set BPV. Post-Rig Procedure: 31. RD mud boat. RD BOPE house. Move to next well location. 32. RU crane. ND BOPE. Install plug off tool. 33. NU the tubing head adapter and 4” 5M tree. PT tubing hanger void to 500/5,000 psi. PT the tree to 250/5000 psi. 34. Pull plug off tool and BPV. 35. RD crane. Move returns tank and rig mats to next well location. 36. Replace gauge(s) if removed. 37. Freeze protect tubing (Tbg ±20 bbls freeze protect) for upcoming coiled tubing operations. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: TDF 8/20/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 8/26/2007 PTD: 204-119 26 27 25Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 20 21 10-3/4” 13 22 23 “OA” Lateral PBTD =9,863’ (MD) / TD = 4,033’(TVD) “OB” Lateral 14 15 Orig. KB Elev.: 68.16’ Doyon 14 13 “NB” Lateral 11 12 13 16 17 18 19 24 3 1 Min ID = 2.25” 2 5 6 7 & 8 9 10 4 Min ID = 3.688” Min ID = 3.688” Min ID = 3.940” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 2.441 Surface 6,389’ JEWELRY DETAIL No Depth Item 1 146’ Sta #2: GLM – Camco KBMG 2-7/8” x 1” –OGLV set 7/31/2004 BEK Latch 2 6,173’ Sta #1: GLM – Camco KBMG 2-7/8” x 1” –DGLV set 7/31/2004 SBK-2C Latch 3 6,324’ 2-7/8” XN Profile (Packing Bore Min ID = 2.205”) 4 6,334.9’ Discharge Head: GPDIS 5 6,335’ Pump: 6 6,353’ Gas Separator: 7 6,358’ Upper Tandem Seal 8 6,365’ Lower Tandem Seal 9 6,372’ Motor 10 6,387’ Centralizer w/ Pump Mate XTO Sensor –Bottom @ 6,389’ 11 6,773’ NB Lateral Tie Back Sleeve 12 6,784’ NB Lateral ZXP Liner Top Packer 13 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 14 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 15 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 16 6,845’ NB Lateral Swell Packer 17 7,265’ OA Lateral Tie Back Sleeve 18 7,276’ OA Lateral ZXP Liner Top Packer 19 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 20 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 21 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 22 7,482’ OB Lateral Tie Back Sleeve 23 7,493’ OB Lateral ZXP Liner Top Packer 24 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 25 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 26 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 27 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg _____________________________________________________________________________________ Revised By: TDF 9/1/2020 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 8/26/2007 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 12 13 10-3/4” 13 14 15 PBTD =9,863’ (MD) / TD = 4,033’(TVD) 6 7 Orig. KB Elev.: 68.16’ Doyon 14 13 3 4 5 8 9 10 11 16 1 2 1111113333333333331133311111313333333333331133333133333311313131 111113333333333331333331111133333333333313333113331333 “OA” Lateral “OB” Lateral “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / Vam Top 3.548 Surface ±6,776’ JEWELRY DETAIL No Depth Item 1 ±6,752 X -Nipple 2 ±6,772 Mule Shoe – Bottom @ ±6,773 3 6,773’ NB Lateral Tie Back Sleeve 4 6,784’ NB Lateral ZXP Liner Top Packer 5 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 6 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 7 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 8 6,845’ NB Lateral Swell Packer 9 7,265’ OA Lateral Tie Back Sleeve 10 7,276’ OA Lateral ZXP Liner Top Packer 11 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 12 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 13 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 14 7,482’ OB Lateral Tie Back Sleeve 15 7,493’ OB Lateral ZXP Liner Top Packer 16 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 17 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 18 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 19 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg Milne Point ASR Rig 1 BOPE 2020 Updated 1/09/2020 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 Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: 9/2/2020Subject: Changes to Approved Sundry Procedure for Well MP L-14Sundry #: 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 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d..D!:-- 1 U1 Well History File Identifier o Two-sided 1111111111111111111 Organizing (done) o Rescan Needed 111111111111111I111 RESCAN ~Ior Items: o Greyscale Items: DIGITAL DATA ~skettes, No.3 o Other, NolType: BY: ~ Date c¡ 130/ (J b I I OVERSIZED (Scannable) o Maps: o Other Items Scannable by a large Scanner OVERSIZED (Non-Scannable) o logs of various kinds: o Other:: W1f 151 1111111111I11111111 151 mP + q = TOTAL PAGES ~ q IP (Count does not include cover sheet) 151 1111111111111111111 o Poor Quality Originals: o Other: NOTES: Project Proofing BY: ~ Date: Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: J 00 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES BY: ~ Date: q /30/0 G:> Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 111, P NO BY: Maria Date: 151 11111111111I11 "III Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111" III BY: Maria Date: 151 Comments about this file: Quality Checked III 1111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 SLANNEDFEB ii 7 202 December 30, 2011 Mr. Tom Maunder 0 ` 1 iq Alaska Oil and Gas Conservation Commission 333 West 7 Avenue l — � 11 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -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, Q� Mehreen Vazir BPXA, Well Integrity Coordinator • 0 I I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI -09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 '">" MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 • • ~... -, -~.__. MICROFILMED 03/01/2008 DO NOT PLACE r ~,~, _ _$ k~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~- .. STATE OF ALASKA .. 9-/;'.0; A~ Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED SEP 1 4 2007 1~laska Oil & Gas Cons. Commission 1. Operations Performed: Anchorage 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 204·119 / 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23214-00-00 / 7. KB Elevation (ft): KBE = 68.16' - 9. Well Name and Number: MPI·14 I 8. Property Designation: 10. Field 1 Pool(s): / ADL 025517 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 9863 ( feet true vertical 4033 ( feet Plugs (measured) N/A Effective depth: measured 9863 < feet Junk (measured) N/A true vertical 4033 / feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1530 520 Surface 2664' 10-3/4" 2699' 2286' 5210 2480 Intermediate Production 7585' 7-518" 7618' 3994' 6890 4790 Liner 2381' 4-112" 7482' - 9863' 3970' - 4033' 8430 7500 Perforation Depth MD (ft): Slotted Liner 7614' - 9696' SCANNED SEP 272007 Perforation Depth TVD (ft): Slotted Liner 3994' - 4043' 2-7/8",6.5# L-80 6389' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker ZXP Liner Top Packer 7493' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBOMS BFl SEP 2 520D7 13. ReDresentative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure TubinQ Pressure Prior to well operation: 127 7 115 350 317 Subsequent to operation: 251 15 209 360 313 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after work: o Exploratory ~ Development o Service ~ Daily Report of Well Operations 16. Well Status after 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 Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Technical Assistant Sig~e ~~ Prepared By Name/Number: Phone 564-4750 DatJj1-JlI-D 7 Sondra Stewman, 564-4750 Form 10-404'""Rãvised 04/2006 Submit Original Only ORIGINAL k~ 1'1-,\ ¿~tØl Tree: 2-9/16" - 5M FMC . Wellhead: 11" x 11" 5M FM - Gen 5, W 2-7/8" FMC Tbg. 2-7/8" EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#1ft, H-40 OJ:Ð 103/4" Howco Float Shoe 12698' I 75/8" 29.7 ppf, L-80. BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) KOP @ 500' 50+ degree from 2300' Max hole angle = 76 degrees @ 6710' MD Window in 75/8" Casing @ 6814' - 6826' Well Angle @ window = ??' Baker Tie Back Sleeve 6773' Baker ZXP Liner Top Packer 6784' 4-1/2" Hook Hanger "LEM" 6799' Window in 75/8" Casing @ 7324' - 7336' Well Angle @ window = ??' Baker Tie Back Sleeve 7265' Baker ZXP Liner Top Packer 7276' ..4 V 7-5/8" Weatherford Float Collar 7533' 7 -5/8" Weatherford Float Shoe 7618' Baker Tie Back Sleeve 7482' Baker ZXP Liner Top Packer 7493' DATE 08/28/04 08/26/07 REV. BY J. Cubbon L. Hulme COMMENTS Drilled & Completed Doyon 14 ESP change out - Nabors 4ES MPI-14)LI¡ LZ. eBelev. = 68.00' (Doyon 14) N B Lateral OA Lateral OB Lateral Cameo 2-7/8" x1" KBMG Gas lift mandrel 146' Cameo 2-7/8" x1" KBMG Gas lift mandrel 6173' HES XN-Nipple (2.250" id) 6323' Pump Section, 82 stg. GC2900 AR 1:1 6335' Gas Separator Model - GRSFTX BAR H6 Tandem Seal Section, Series 513 GSB3 DB SB/SB PFSNFSA CL5 6353' 6358' Motor, 110 KMH-A 2152 volt / 31 amp, 6372 ' PumpMate XTO w/6 fin centralizer 6385' 6 3/4" Hole td @ 9768' Baker Float shoe 9738' 55 jts. - 4",9.5# L-SO, IBT Blanks and 30 jts Baker Med Excluder Screen 67ì3'-9-&') I Swell Pkr 6845' - 6869' 6 3/4" Hole td @ 9910' Btm Baker Float Shoe 9883' 44 jts. - 4 1/2" Slotted Liner 1 ZIÞ'5' 17 jts, 12.6# L-SO IBT (~9'-9885') 6 3/4" Hole td @ 9863' B1m HES Type V Float Shoe 9861' 30 jts. - 4 1/2" Slotted Liner 26 jts, 12.6# L-80 IBT (7482'-9863') MILNE POINT UNIT WELL 1-14 -a3alt¡- Q)-CD API NO: 50-029-_ ~~ La "30- 0'2.'1- Z~aI4·<..s:ð-oO L<" 'SC-cx..y - 3 t4- [-00 BP EXPLORATION (AK) . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 8/19/2007 8/26/2007 Spud Date: 8/2/2004 End: 8/26/2007 8/21/2007 06:00 - 09:00 3.00 RIGD P PRE PTSM. Begin rigging down, preparing for truck arrival. Layover derrick. 09:00 - 15:30 6.50 MOB ,N PRE Move rig from Nabors Deadhorse yard to MPI-14. Encountered two flat tires on sub base. Replace same and continue rig move. 15:30 - 00:00 8.50 MOB P PRE Continue move to MPI-14. 8/22/2007 00:00 - 16:00 16.00 MOB P PRE Continue move from Nabors Deadhorse yard to MPI-14. Rig on location @ 1600-hrs. 16:00 - 18:00 2.00 RIGU P PRE Spot sub base, pits and pipe shed. Laid Herculite and bermed rig. 18:00 - 20:00 2.00 RIGU P PRE Held "Safety Stand Up" meeting with personnel from both rig crews. Meeting also attended by BP and Nabors management, and MPU ops and HSE personnel. Continued with pre-tour meeting and crew change. 20:00 - 21 :00 1.00 RIGU P PRE PJSM. Raised derrick. 21 :00 - 00:00 3.00 RIGU P PRE Unstrung and restrung scoping lines. 8/23/2007 00:00 - 01 :00 1.00 RIGU P PRE Scoped derrick. Accepted rig @ 01 :00 hrs 8/23/2007. 01 :00 - 03:30 2.50 KilL P DECOMP RU lines to tree. Spotted and bermed tiger tank. RU lines to tank and tested to 4000 psi. 03:30 - 05:00 1.50 KilL P DECOMP Filled pits with 120F heated brine. ß,IdJubricator, pulled BPV. 05:00 - 11 :30 6.50 KILL N RREP DECOMP Replacing pulsation dampener on mud pump. Housekeeping. 11:00-11:30 0.50 KilL P DECOMP PJSM - All crew: Kill well. Review well kill procedure and I assign tasks to crew. 11:30-12:15 0.75' KILL P DECOMP Obtain well parameters - SITP = 530-psi, SICP = 690-psi, OAP = 140-psi. Begin bleeding well off to Tiger Tank. Bled tubing off to 430-psi and commenced pumping brine down tubing @ 4.0-BPM and bleeding off IA to tank. Pumped 57-Bbls. down tubing. Pressure decreased to 90-psi with no returns from IA. Lined up circulating manifold to bullhead down IA. 12:15 - 13:15 1.00 KilL P DECOMP Initial pressures - SITP = Vac, SICP = 10, OAP = 140. Bullhead brine down IA - 5 BPM @ 160 psi. Controlled OA BUR from 140 to 450 psi with venting to bleed tank. SSV never reached over pressure range. Pumped 360 bbls down casing (6295 strokes). Bled OAP from 450 to 0 psi in 2 minutes (gas). Final pressures - SITP = Vac, SICP = Vac, OAP = O. 13:15 - 13:45 0.50 KILL P DECOMP Monitor well head pressures - SITP = Vac, SICP = Vac, OAP = 20. OAP increased 20 psi in 30 minutes. Clean up rig floor. Bring equipment to floor. 13:45 - 14:00 0.25 DHB P DECOMP PJSM - All crew: Set TWC. FMC wellhead technician drifted 3" 10-RD. x 2-7/8" EUE 8RD XO and lopso-opso for TWC. FMC wellhead technician dry rod set TWC in TBG HGR. 14:00 - 16:00 2.00 DHB P DECOMP PIT TWC from below - Pumped 50-Bbls. @ 5.0-BPM to test TWC from below. Gained O-psi. Well on vacuum. tested TWC from above to 3500-psi. Charted both tests for 10-minutes. 16:00 - 17:00 1.00 DHB P DECOMP Rig down test equipment. Prepare to nipple down Tree. 17:00 - 19:00 2.00 WHSUR P DECOMP Nipple down Tree. Set same aside for reuse. Held crew change. Performed pre-tour checks. 19:00 - 00:00 5.00 BOPSU P DECOMP PJSM. NU BOPE. Installed 2-7/8" x 5" VBRs. 8/24/2007 00:00 - 00:30 0.50 BOPSU P DECOMP Continued NU BOPE; installed landings on stack. 00:30 - 03:30 3.00 BOPSU P DECOMP PJSM. Tested BOPE to 250 psi low /3500 psi high. Test witnessed by J. Crisp, AOGCC. Observed gas bubbling up Printed: 9/14/2007 10:06:30 AM . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 8/19/2007 8/26/2007 Spud Date: 8/2/2004 End: 8/26/2007 tubing, past TWC. Added 106 bbls brine to IA. Pumped 3 bpm at 50 psi. Gas bubbling subsided; continuing minor gas leakage past TWC. 04: 15 - 07:00 2.75 OECOMP Continued testing BOPE. Completed BOPE testing @ 0645-hrs. BO/LD 2-7/8" test joint. 07:00 - 07:30 0.50 PULL P OECOMP Crews changed - PTSM. Prepare to rig up lubricator and Lopso-Opso to pull TWC. 07:30 - 08:30 1.00 PUll P DECOMP PJSM with Veco valve crew. Bullhead 70 bbls down CSG @ 4 BPM (1185 strokes). 08:30 - 09:30 1.00 PUll P DECOMP Land lubricator extension with Halliburton valve in HGR. MU Veco lubricator an pressure test to 500 psi. Pull TWC. TBG I went on Vac. FL on CSG @ 1000'. 09:30 - 10:00 I 0.50 PULL P DECOMP LD lubricator and lubricator extension. Stab into HGR with landing joint and TIW valve. 10:00 - 10:30 0.50 PULL P DECOMP Pulled HGR free @ 50K - 45K to floor. Disconnect ESP cable and RU Centrlift and lD 2 7/8" TBG HGR. Test & tie cable to unit. 10:30 - 18:00 7.50 PULL P DECOMP POH with 2 718" ESP completion. Recovered 110 LaSalle clamps, 3 flat guards, 5 protectolizers, 65 stands and 4 singles 2-7/8" tubing, 3 GLM, X nipple, and pup jts. 18:00 - 19:00 1.00 PULL IP DECOMP Held crew change and pre-tour meeting. Performed pre-tour RUNCO~P checks. Continued LO ESP ass'y. 19:00 - 20:00 1.00 RUNCMP Cleared and cleaned rig floor. 20:00 - 21 :00 1.00 RUNCO P RUNCMP PU swivel and kelly. Torqued kelly connections. 21 :00 - 00:00 3.00 RUNCO P RUNCMP PUMU ESP assembly per Centrilift representative. 8/25/2007 00:00 - 00:30 0.50 RUNCOMP RUNCMP Continued PUMU ESP ass'y on 2-7/8" tubing. MU X nipple, PU I 4 singles and GLM. 00:30 - 02:45 2.25 RUNCOip RUNCMP RIH 29 stnds 2-7/8" tubing. Installed 50 LaSalle clamps. 02:45 - 04:00 1.25 RUNCO P RUNCMP RU to install heat trace. 04:00 - 06:30 2.50 RUNCO P RUNCMP RIH with 2-7/8" tubing and heat trace. 32 of 65 stands run @ 05:30 hrs. RIH with heat trace at 3 stands/hr. Flushed ESP ass'y with 12 bbls brine @ 1 bpm and 120 psi. 06:30 - 07:00 0.50 RUNCO RUNCMP PJSM. Performed pre-tour checks. Serviced rig. 07:00 - 18:00 11.00 RUNCO RUNCMP Continued RIH with 2-7/8" tubing, heat trace and ESP cable. Flushed completion string with brine each 1000'. 18:00 - 18:30 0.50 RUNCO RUNCMP PJSM. Performed pre-tour checks. Serviced rig. 18:30 - 21 :00 2.50 RUNCO RUNCMP Continued RIH with ESP ass'y on 2-7/8" tubing. 21 :00 - 22:00 1.00 RUNCO RUNCMP PUMU tubing hanger. Spaced out for cable and heat trace splices. 22:00 - 00:00 2.00 RUNCO RUNCMP Spliced heat trace. 8/26/2007 00:00 - 01 :00 1.00 RUNCO RUNCMP Continued splicing heat trace. 01 :00 - 03:30 2.50 RUNCO RUNCMP Spliced ESP top connector. 03:30 - 05:00 1.50 RUNCO RUNCMP Established parameters: PU 47k Ib, SO 35k lb. landed tubing I hanger. RILDS. Set TWC and tested from above and below to I 1000 psi for 10 minutes. BOPSU~ P 05:00 - 08:00 3.00 RUNCMP NO BOPE. 08:00 - 09:30 1.50 WHSUR P RUNCMP Nipple up and test Tree to 5000-psi. Centrilift perform final ESP conductivity tests. Good test. 09:30 - 11 :00 1.50 WHSUR P RUNCMP PUMU lubricator to top of Tree. PIT lubricator to 500-psi. Pul TWC. Set BPV. Release rig @ 1100-hrs. 10:30 - 14:00 3.50 RIGD P POST lower derrick. Rig down sub base, pipe shed and pits. Prepare to move off well. Rig off location @ 1400-hrs. Printed: 9/14/2007 10:06:30 AM J.- 1 ;;r- DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Perm it to Drill 2041190 Well NamelNo. MILNE PT UNIT 581-14 Operator 8P EXPLORATION (ALASKA) INC MD 9863-'" TVD 4033 / Completion Date 8/27/2004·'" Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: mwd, gr, res, ifr / casandra, abi Well Log Information: Log/ Data Type Electr Digital Dataset Med/Frmt Number D Asc Name Directional Survey Directional Survey Log Log Run Scale Media No D Asc Directional Survey Directional Survey Directional Survey Directional Survey Induction/Resistivity LIS Verification D Asc ~-D Tap IV I I£' D Tap µt ~ I~ D r-~ Tap I ~ C Lis I I L__.______.~_~__ Well Cores/Samples Information: 12788 12789 Induction/Resistivity LIS Verification LIS Verification 12790 Induction/Resistivity 13578 Induction/Resistivity Name Interval Start Stop Received Sent S¡7Vtð ).~~'i API No. 50-029-23214-00-00 ._-,~-~-~--~---_._-~,.._- UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval Start Stop 8305 9863 8305 9863 7685 9267 7685 9267 o 8427 o 8427 66 9805 66 9805 66 66 66 66 109 8369 Open 8369 Open 8392 Open 8392 Open 9863 Open Received Comments 10/5/2004 IIFR SURVEY,FlNAL,----l I 10/5/2004 IIFR SURVEY, FINAL, 1 I 10/5/2004 IIFR SURVEY FINAL, PB2 I IIFR PB2 I IIFR PB1 I IIFR PB1 1 mwd/gr/ewr4/rop I mwd/gr/ewr4/rop DSN I 12788 I 10/20/2004 MWD/GR/EWR4/ABIIROP I 10/20/2004 MWD/GRlEWR4/ABI/ROP/ .11 DSN 12789 I 10/20/2004 MWD/GR/EWR4/ABIIROP/! DSN 12790 I I 10/20/2004 MWD/GR/EWR4/ABIIROP/ I DSN 12790 I 2/22/2006 ROP DGR EWR plus I Graphics / PB 1 109-8427 ROP DGR EWR plus I Graphics / PB 2 109-9450 I ROP DGR EWR plus I Graphics J OHI CH Open Open Open Open Open Open Open Open 10/7/2004 10/7/2004 10/20/2004 10/20/2004 Sample Set Number Comments . . Permitto Drill 2041190 MD 9863 TVD 4033 ADDITIONAL INFORM~'lON Well Cored? y~ Chips Received? ~ Analysis Received? ~ ---_..__.~.- _.~._--~----~--" Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Well Name/No. MILNE PT UNIT 5B 1-14 API No. 50-029-23214-00-00 Operator BP EXPLORATION (ALASKA) INC Completion Date 8/27/2004 Completion Status 1-01L UIC N Current Status 1-01L Daily History Received? fS)N (VN Formation Tops --- ~-"---- ~ Date: :.2> ¥=~~ . . . . WELL LOG TRANSMITTAL d'ò4- - Ilg To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 I 851ß RE: MWD Formation Evaluation Logs MPI-14 + PB1 + PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPI-14 + PBl + PB2: LAS Data & Digital Log Images: 50-029-23214-00, 70, 71 1 CD Rom ~ :J l~ðl[1 . . ~ i-{Ie¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 18, 2004 RE: MWD Formation Evaluation Logs MPI-14, AK-MW-3214396 1 LIS fonnatted Disc with verification listing. llPI#: 50-029-23214-00 tf )~lgg PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: /0 to ¡; ( I / . . ~&t:f-rI9 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 18, 2004 RE: MWD Fonnation Evaluation Logs MPI-14 PBI, AK-MW-32 I 4396 1 LIS fonnatted Disc with verification listing. ~I#: 50-029-23214-70 1 \ ~ l g~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: 1& /zo !o( I , . . ~o'f-IIC¡ /2. 7? Q WELL WG TRANSMI1TAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 18, 2004 RE: MWD Fonnation Evaluation Logs :MPI-14 PB2, AK-MW-3214396 1 LIS fonnatted Disc with verification listing. API#: 50-029-23214-71 ¥ \ ~l q D PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date# ... ,,# . STATE OF ALASKA . AlASI(.A; AND GAS CONSERVATION COMN . IONC'¡::~ WELL COMPLETION OR RECOMPLETION REPORT AND L'<'Ò'''~'",·,J OCT 1 !~ 2004 1a. Well Status: œt Oil o Gas o Plugged o Abandoned o Suspended o WAG AI !Þ, 't)(~t.~~. .... !.;.¡;Wf1 ,3 ,,~" ,.q.n/ 20AAC 25.105 20AAC 25.110 181 DeVe!li¥i¥;WÒ~~ag Expl<:>ratory OGINJ OWINJ o WDSPL No. of Completions One Other o StratigrapHIc '" Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 8/27/2004 /' 204-119 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/2/2004 - 50- 029-23214-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 8/11/2004 r MPI·14 2348' NSL, 4055' WEL, SEC. 33, T13N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4359' NSL, 3379' WEL, SEC. 32, T13N, R10E, UM (0 B) KBE = 68.16' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ rvD) 1292' NSL, 3470' WEL, SEC. 29, T13N, R10E, UM (0 B) 9863 + 4033 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+rvD) 16. Property Designation: Surface: 551315 # 6009461 - Zone- ASP4 ' 9863 + 4033 ¡ Ft ADL 025517 x- y- TPI: x- 546693 y- 6011442 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 546581 - y- 6013654 - Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, jf offshore 20. Thickness of Permafrost 181 Yes ONo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , ABI 2. CASING, LINER AND CEMENTING RECORD ./~~ri~~· ~ETTU\IGDef:'TH~9 ·.·.§EtTINGDEPTti.··T\ID ....·..~?£ti ./ .'/ ···Wl'.Pe,BfÌ...·. G~bE .....'" Þûf..t.¡è& TOP ßQ!TOM TO? I BoTtØM /. 20" 94# H-40 34' 112' 34' 112' 42" ?60 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 2699' 35' 2286' 13-1/2" 316 sx AS Lite, 259 sx Class 'G' 7-518" 29.7# L-80 33' 7618' 33' 3994' 9-7/8" 750 sx Class 'G' 4-1/2" 12.6# L-80 7482' 9863' 3970' 4033' 6-3/4" Uncemented Slotted LIner 23. Perforations open to Production (MD + rvD of T~ and 24;. .. /1 )/ilING .... Bottom Interval, Size and Number; if none, state none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 12.6#, L-80 6398' N/A MD rvD MD rvD 2~. ,,;...:;~ rf+"";I ~;....... /i 7614' - 9696' 3994' - 4043' ·····/8'?''''· PB\YI;,1'!'.· DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 15 Bbls of Diesel and 75 Bbls of Dead Crude 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 27,2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR all -BSl GAs-McF W A TER-Bsl CHOKE SIZE I GAS-all RATIO 10/2/2004 6 TEST PeRIOD .. 1225 779 5 636 Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF W A TER-Bsl all GRAVITY-API (caRR) Press. 24-HoUR RATE 4900 3116 20 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach9~~fJ,~-t¡lt~J¡~t, if necessary). SUbm' oore ch;ps" . none state "none"" I "" OM"" ",,' I 1 , Dß-'- t None ORIGINAL L~~óf C9v " Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 1{ JiQM$ ~~Â 28. GEOLOGIC MARKERS NAME MD TVD SBF2-NA . SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE . SBE1-NF ' TSBD-OA TSBC TSBB-OB ~ SBAS - TSBB-OB SBAS TSBB-OB TSBB-OB 673S' 6763' 6836' 68S9' 6934' 6981' 7001' 7032' 7045' 7211' 7334' 7445' 7586' 7691' 8154' 8927' 9237' 9679' 3768' 377S' 3794' 3800' 3820' 3832' 3838' 3846' 3849' 3894' 3930' 3961' 3990' 3999' 4023' 4000' 4034' 4043' 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service report and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title Technical Assistant 204-119 Permit No. I A roval 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. MPI-14 Well Number Date 1 0 -- \ (o-Oy. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Tree: 2-9/16" - 5M FMC Wellhead: 11" x 11" 5M FM. Gen 5, W 2-7/8" FMC Tbg. EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/11, H-40 !J1Ð " Note" 103/4" 45.5 ppf L-80 & K-55 BTC-M (Drift ID = 10.050, cap. = .0981 bpf) Collapse / Internal Yield K-55 2090 psi. / 3580 psi. L-80 2480 psi. / 5210 psi. K-55 159' thru 2,536' 103/4" Howco Float Shoe 12698' I 75/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) KOP @ 500' 50+ degree from 2300' Max hole an91e = 76 degrees @ 6710' MD Window in 75/8" Casing @ 6814' - 6826' Well Angle @ window = 17° Baker Tie Back Sleeve 6773' Baker ZXP Liner Top Packer 6784' 4-1/2" Hook Hanger "LEM" 6799' Window in 75/8" Casing @ 7324' - 7336' Well Angle @ window = ??O Baker Tie Back Sleeve 7265' Baker ZXP Liner Top Packer 7276' .4 V 7-5/8" Weatherford Float Collar 7533' 7-5/8" Weatherford Float Shoe 7618' Baker Tie Back Sleeve 7482' Baker ZXP Liner Top Packer 7493' DATE 08/28/04 MPI-14 NB Lateral OA Lateral OB Lateral REV. BY COMMENTS J. Cubbon Drilled & Completed Doyon 14 Orig. KB elev. = 68.00' (Doyon 14) . Cameo 2-7/8" x1" KBMG Gas lift mandrel 146' Cameo 2-7/8" x1' KBMG Gas lift mandrel 2167' Cameo 2-7/8" x1" KBMG Gas lift mandrel 6170' HES XN-Nipple (2.250" id) 6321' Pump Section, 74 stg. GC2900 GPMTAR 1:1 6342' Tandem Intake - Gas Separator 6358' Model - GRSFTXARH6 Tandem Seal Section, Series 513 I 6363' GSB3 DB UT/L T HL H6 PFS AFLAS IHSN ' Motor, 171 KMH 2390 volt /44 amp, 6377 ' PumpMate w/6 fin centralizer 6392' 6 3/4" Hole td @ 9768' Baker Float shoe 9738' 55 jts. - 4", 9.5# L-80, IBT Blanks and 30 its Baker Med Excluder Screen 6773'-9739') / Swell Pkr 6845' - 6869' 63/4" Hole td @ 9910' Btm Baker Floal Shoe 9883' 44 jts. " 4 1/2" Slotted Liner 17 its, 12.6# L-80 IBT (7319'-9884') 6 3/4" Hole td @ 9863' Blm HES Type V Float Shoe 9861' 30 jts. - 4 1/2" Slotted Liner 26 its, 12.6# L-80 IBT (7482'-9863') MILNE POINT UNIT WELL 1-14 API NO: 50-029-2041190 BP EXPLORATIQN (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/1/2004 22:00 - 00:00 2.00 MOB P PRE R/D floor, Skid rig floor, Prepare for Move to MP-14 8/2/2004 00:00 - 03:30 3.50 MOB P PRE Pull off MPI-17,Move rig down pad to MPI-14, spot over well 03:30 - 04:30 1.00 MOB P PRE Skid rig floor,spot rock washer, spot water tank, Rigging up, Rig accepted @ 04:30 8/2/2004 04:30 - 07:00 2.50 RIGU P PRE Nipple up Diverter, take on H2o, 07:00 - 07:30 0.50 DRILL P SURF Clear floor of unneeded tool 07:30 - 17:30 10.00 DRILL P SURF Picking up drill pipe from pipe shed and standing in derrick, mixing spud mud 17:30 - 19:30 2.00 DRILL P SURF Picking up Bit, Motor 19:30 - 20:30 1.00 DRILL P SURF Pre Spud meeting with crews, fünctlon test diverter, fill hole, check lines, the right to witness test was wavier by Chuck Sheav$AOOGC. 20:30 - 22:00 1.50 DRILL P SURF Spud well ,Drill to 257', Run Gyro every 100ft. 22:00 - 23:00 1.00 DRILL P SURF Poh pick up Flex Dcs, Rih 23:00 - 00:00 1.00 DRILL P SURF Drill 257 to 347' with 60 rpms, 420 GPM, 1000 psi, run Gyro ever 100 ft., AST .57 ART .93 8/3/2004 00:00 - 21 :00 21.00 DRILL P SURF Directional Drill from 347' to 1972' - WOB 5 to 15 - RPM 60 - TO on 6k - off 2k - GPM 420 - PP on 11620 - off 1420 - PU 90- SO 85 - ROT 87 21 :00 - 22:00 1.00 DRILL P SURF CBU 3 X - RPM 70 - GPM 450 - PP 1700 - Flow check - Well static 22:00 - 23:00 1.00 DRILL P SURF Pump out to HWT @ from 1972 to 442' - Hole good no problems 23:00 - 23:30 0.50 DRILL P SURF RIH from 442' to 1877' - Precauctionary wash from 1877' to 1972' - tight @ 835 - no reaming or pumping required 23:30 - 00:00 0.50 DRILL P SURF Directional Drill from 1972' to 2030' - WOB 15 to 30 - RPM 60- TO on 6k - off 2k - GPM 420 - PP on 1620 - off 1420 - PU 90- SO 85 - ROT 87 8/4/2004 00:00 - 07:00 7.00 DRILL P SURF Directional Drill from 2030' to 2710' - TD 13.5" Hole - WOB 15 to 25 - RPM 60 - TO on 6k - off 3k - GPM 500 - PP on 2270 - off 2140 - PU 100 - SO 80 - ROT 90 07:00 - 09:00 2.00 CASE P SURF CBU 3 X - GPM 510 - RPM 80 - TO 3 - ICP 2140 FCP 2030 09:00 - 10:30 1.50 CASE P SURF Flow Check - Pump out from 2710' to HWT 442' - Pump at drlg rate 500 gpm - 10:30 - 11 :30 1.00 CASE P SURF RIH from 442' to 2644' - Precauctionary wash from 2644' to 2710' - No problems 11 :30 - 13:30 2.00 CASE P SURF CBU 3 X - GPM 510 - PP 2080 - RPM 80 - TO 3 k - Flow check 13:30 - 14:30 1.00 CASE P SURF Pump out from 2710' to HWT @ 442' 14:30 - 16:00 1.50 CASE P SURF Stand back 5" HWT - Lay down 8" BHA 16:00 - 16:30 0.50 CASE P SURF Clear rig floor 16:30 - 18:00 1.50 CASE P SURF Rig up casing tools to run 10 3/4" casing - PJSM 18:00 - 21 :00 3.00 CASE P SURF Pick up 103/4" shoe joints - Check floats - Con't running 10 3M" 45.5# L-80 and K-55 casing total of 63 joints to 2657' 21 :00 - 21 :30 0.50 CASE P SURF Make up Landing joint and hanger - RIH from 2657' to 2699' land on hanger - Lay down Franks fill up tool - Make up Schlumberger Dowell cementing head and cementing lines - PU 180 - So 115 21 :30 - 23:30 2.00 CASE P SURF CBU 2 casing volumes condition mud for cement job - PJSM for cementing - Stage up pump rate from 3 BPM to 8 BPM - PP 260 psi 23:30 - 00:00 0.50 CEMT P SURF Give to Schlumberger Pump 5 bbls water Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/4/2004 23:30 - 00:00 0.50 CEMT P SURF Test lines to 3500 psi Pump 25 bbls water - @ 4 bpm - 200 psi - one gallon dye last 5 bbls pumped Give to Rig - pump 30 bbls treated water Schlumberger pump 20 bbls CW-100 - @ 5 bpm - 300 psi 75 bbls Mud Push mixed at 10.3 ppg - @ 4.5 bpm - 210 psi - Drop bottom plug last 5 bbls pumped 8/5/2004 00:00 - 02:00 2.00 CEMT P SURF Mix and pump 250 bbls "ASL" @ 10.7 ppg - Yield 4.44 cf/sx cement - @ 6 bpm - 350 psi - Dye back after pumping 240 bbls Mix and pump 54 bbls Class G cement @ 15.8 ppg - Yield 1.17 cf/sx cement - @ 3 bpm - 300 psi Drop top plug Pump 30 bbls water - @ 6 bpm - 230 psi Give to rig - Displaced with mud 219 bbls - @ 7 bpm - 300 psi - Cement back to surface after displacing 153 bbls Bump plug with 1500 psi - Hold for 3 mins - Bleed off - Floats holding - CIP @ 02:00 hrs - Total cement back 96 bbls 02:00 - 03:00 1.00 CASE P SURF Flush Annular / riser - Rig down cementing lines - Cement head - Lay down Landing joint 03:00 - 04:00 1.00 CASE P SURF Clear rig floor of cementing equipment - Casing tools - 04:00 - 05:00 1.00 CASE P SURF Nipple down Divertor System 05:00 - 06:00 1.00 CASE P SURF Nipple up FMC metal to metal seal well head - test to 1000 psi for 10 mins- 06:00 - 09:00 3.00 CASE P SURF Nipple up BOP's 09:00 - 10:00 1.00 CASE P SURF Install test plug - Rig up test equipment 10:00 - 13:30 3.50 CASE P SURF Tat BOP's - Test Annular to 250 low - 2500 high for 5 mins each test - Test Rams - Choke manifold - Manual Kill/ Choke valves - HCR Kill / Choke valves - (HCR Choke valve failed low test) - Upper / Lower IBOP - Floor safety valves - 250 low- 3500 high 5 mins each test - Perform Accumulator test - Lou Grimaldi with AOOCC witness testing of BOP's - Derrick inspection performed 13:30 - 16:00 2.50 CASE N RREP SURF Change out Choke HCR valve 16:00 - 16:30 0.50 CASE P SURF Test Choke HCR to 250 low 3500 high for 5 mins each test - Test choke line on same test - Test good 16:30 - 17:00 0.50 CASE P SURF Rig down testing equipment - Pull test plug - Install long bowl protector - Close annulus valves 17:00 - 18:00 1.00 CASE P SURF Rig up test recorder - Close Blind rams - Test casing to 2000 psi for 30 mins record on chart - Test good - Rig down test equipment 18:00 - 20:00 2.00 CASE P SURF Make up 9 7/8" BHA - Orient - Pick up 61/2" flex DC's - Surface test MWD 20:00 - 20:30 0.50 CASE P SURF RIH to 2614' - tag float collar - Fill pipe every 25 stands 20:30 - 21 :00 0.50 DRILL P SURF Drill float equipment from 2614' to 2699' - Clean out 10' rat hole from 2699' to 2710' 21 :00 - 22:00 1.00 DRILL P SURF Circulate out cement - Displace to 8.9 ppg mud 22:00 - 22:30 0.50 DRILL P INT1 Drill from 2710' to 2730' 22:30 - 23:30 1.00 CASE P SURF CBU - Condition mud for FIT - GPM 500 - PP 1425 - RPM 60- Rig up to FIT 23:30 - 00:00 0.50 EV AL P SURF Perform FIT - 2699' MD - 2286' TVD - Mud weight 8.9 - Surface pressure 310 = EMW 11.5 8/6/2004 00:00 - 00:30 0.50 CASE P SURF Rig down test equipment - SPR on pumps Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/6/2004 00:30 - 16:00 15.50 DRILL P INTi Directional Drill from 2730' to 5046' - WOB 15 to 30 - RPM 80 - TO on 7 - off 5 - GPM 502 - PP on 2040 - off 1710 - PU 120- SO 80 - ROT 100 16:00 - 17:30 1.50 DRILL P INT1 CBU 3 X - GPM 502 - PP 1750 17:30 - 19:30 2.00 DRILL P INT1 Pump to shoe from 5046' to 2636' - No Problems - Pump out at drlg rate 19:30 - 20:00 0.50 DRILL P INT1 CBU at shoe - GPM 502 - PP 1450 - Thick mud - Lots of cuttings - some clay balls - lost + 35 bbls over shakers 20:00 - 21 :00 1.00 DRILL P INTi Cut drlg line - Rig service - Top drive service 21 :00 - 21 :30 0.50 DRILL P INT1 RIH from 2636' to 4951' - Precauctionary wash from 4951' to 5046' - No problems 21 :30 - 00:00 2.50 DRILL P INT1 Directional Drill from 5046' to 5335' - WOB 15 to 20 - RPM 80 - TO on 7k - off 5k - GPM 508 - PP on 2070 - off 1870 - PU 130- SO 78 - ROT 100 8/7/2004 00:00 - 10:00 10.00 DRILL P INT1 Directional Drill from 5335' to 6390' - WOB 15 to 25 - RPM 80- TO on 8 - off 6.5 - GPM 502 - PP on 2330 - off 2020 - PU 140- SO 82 - ROT 105 10:00 - 11 :00 1.00 EVAL N DPRB INT1 MWD not getting good detection - Mad Pass from 6295' to 6390' 11 :00 - 00:00 13.00 DRILL P INT1 Directional Drill from 6390' to 7256' - WOB 15 to 25 - RPM 80- TO on 10 - off 7 - GPM 502 - PP on 2800 - off 2550 - PU 145- SO 80 - ROT 105 - From 7100' to 7256' - Detection not good - Mad pass required on each connection - Top NA sand 6772' MD 3768' TVD - Base NA sand 6862' MD 3802' TVD - Top of Window for NB sand 6821' MD 8/8/2004 00:00 - 07:00 7.00 DRILL P INTi Directional Drill from 7256' to 7625' - TD 9 7/8" hole - WOB 15 to 30 - RPM 80 - TO on 10 - off 7 - GPM 529 - PP on 2650 - off 2300 - PU 145 - SO 80 - ROT 105 - From 7256' to 7625' Detection not good - Mad pass required on each connection - Top OAsand 7331' . TVD 3929' 07:00 - 09:00 2.00 CASE P INTi CBU 3 X RPM 100 - TO 7K - GPM 502 - PP 2530 09:00 - 11 :00 2.00 CASE P INT1 Pump out to from 7625' to last short trip depth @ 5000' at drlg rate 500 gpm 11 :00 - 11 :30 0.50 CASE P INT1 CBU - GPM 500 - PP 2220 11 :30 - 12:30 1.00 CASE P INT1 RIH from 5000' to 7545' - Precauctionary wash from 7545' to 7625' 12:30 - 15:00 2.50 CASE P INT1 CBU 3 X - RPM 100 - TO 7K - GPM 502 - PP 2500 15:00 - 18:00 3.00 CASE P INTi Pump out from 7625' to shoe @ 2650' - Pump at drlg rate 500 gpm 18:00 - 18:30 0.50 CASE P INT1 CBU @ shoe - Flow check - Pump dry job 18:30 - 19:00 0.50 CASE P INT1 POH to BHA 19:00 - 20:00 1.00 CASE P INT1 Lay down 5" HWT - BHA 20:00 - 22:00 2.00 CASE P INT1 Pull wear ring - Install test plug - Change DP rams to Casing rams - Test door seals to 1500 psi - Pull test plug - Rig up casing tools - PJSM 22:00 - 00:00 2.00 CASE P INT1 Pick up float equipment - check floats - Con't RIH with 7 5/8" casing @ 1100' 8/9/2004 00:00 - 01 :00 1.00 CASE P INT1 Con't running 7 5/8" 29.7# L-80 BTC-M casing to 2697' 01 :00 - 01 :30 0.50 CASE P INT1 Circulate casing volume 124 bbls / 1241 strokes - 6 bpm @ 340 psi 01 :30 - 05:30 4.00 CASE P INT1 Con't running 7 5/8" casing to 7581' - Make up landing joint / hanger - RIH land casing at 7618' 05:30 - 06:00 0.50 CASE P INTi Rig down Franks fill up tool - Make up Dowell Schlumberger Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/9/2004 05:30 - 06:00 0.50 CASE P INT1 cementing head - Cementing lines 06:00 - 10:00 4.00 CASE P INT1 Reciprocate string while circulating - Circulate condition mud for cement job - Stage up pump from 4 bpm to 6 bpm - ICP 420 - FCP 250 - PU 250 - SO 85 10:00 - 12:00 2.00 CEMT P INT1 Give to Dowell Schlumberger Pump 5 bbls water Test lines to 4000 psi Pump 25 bbls CW-100 - 4.5 bpm @ 380 psi Pump 45 bbls Alpha spacer mixed at 10.3 ppg - 4 bpm @ 350 psi Drop bottom plug Mix and pump 155 bbls Class "G" yield 1.16 cf/sx 750 sxs at 15.8 ppg - 5.6 bpm @ 580 psi Drop top plug Displace with 354 bbls oil base mud - 6 bpm @ 400 psi - Slow to 3 bpm last 16 bbls pumped @ 800 psi - (~ reciprocating string atter 165 bþls displaced due to increase of drag IJP fliOm 270 to 325 and decrease in slack off from 95 to 70) Bump plug with 1800 psi - 1000 psi over circulating pressure Bleed off pressure - Floats holding - CIP 12:00 hrs 12:00 - 14:00 2.00 CASE P INT1 Rig down Dowell cementing head and cementing lines - Flush BOP stack - Blow down lines - Blow oil base mud out of landing joint - Lay down landing joint - lay down casg elevators - long bails - clear rig floor 14:00 - 14:30 0.50 CASE P INT1 Install FMC pack-off - Test to 5K for 10 mins - Test good 14:30 - 16:30 2.00 CASE P INT1 Install test plug - Change casing rams back to pipe rams - Test to 250 low -3500 high for 5 mins each test - Pull test plug - Install WØIÞ" ring - ~annuIus valves 16:30 - 18:00 1.50 CASE P INT1 Make up BHA - Orient - Surface test MWD 18:00 - 20:00 2.00 CASE P INT1 RIH - Tag up 7530' 20:00 - 21 :00 1.00 CASE P INT1 Break Circulation - Test casing to 2500 psi for 30 mins - record on chart 21 :00 - 21 :30 0_50 DRILL P INT1 Drill shoe track from 7530' to 7618' - Drill 20' new hole from 7625' to 7645' 21 :30 - 22:30 1.00 CASE P INT1 Circulate hole clean for FIT - Pump 5903 stks 588 bbls to clean upwell 22:30 - 23:00 0.50 EVAL P INT1 Perform FIT - Mud weight 9.05 ppg - MD 7618' - TVD 3996 - Surface pressure 510 psi = EMW 11.51 ppg 23:00 - 00:00 1.00 DRILL P PROD1 Directional Drill 63/4" OB Lateral from 7645' to 7659' - WOB 0 to 5 - RPM 85 - TO on 4 - off 3.5 - GPM 251 - PP on 2430 - off 2320 - PU 125 - SO 82 - ROT 101 8/10/2004 00:00 - 07:30 7.50 DRILL P PROD1 Directional Drill from 7659' to 8427' - WOB 0 to 5 - RPM 80 - TO on 5 - off 4 - GPM 250 - PP on 2640 - off 2480 - PU 124- SO 75 - ROT 96 - Went out.bottom of pay@ 7760' - Drilling ahead Iookir1g for 08 Sand 07:30 - 08:30 1.00 STKOH P PROD1 Circulate - Conference call with town - RPM 80 Tq 4K - GPM 250 - PP 2480 08:30 - 09:30 1.00 STKOH P PROD1 PumpotJt @ drilling rate to 7700' for open hole sidetrack # 1 in 08 Lateral 09:30 - 10:00 0.50 STKOH P PROD1 Cot trough from 7700' to 7720' for sidetrack # 1 in 08 Lateral t:;- 10:00 - 00:00 14.00 DRILL P PROD1 Open hole side track # 1 - Directional Drill from 7700' to 9290' - WOB 0 to 5 - RPM 80 - TO on 5 - off 4 - GPM 250 - PP on Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/10/2004 10:00 - 00:00 14.00 DRILL P PROD1 2990 - off 2770 - PU 135 - SO 50 - ROT 95 -W_outboltom of pay @ 8637' - Drilling ahead looking for OB sand 8/11/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Directional Drill from 9290' to 9450'" WOB 0 to 5 - RPM 80- TO on 5 - off 4 - GPM 251 - PP on 2990 - off 2770 - PU 135 - SO 50 - ROT 95 - Drilling ahead looking for OB sand 01 :00 - 01 :30 0.50 STKOH P PROD1 Circulate - for trip out to open hole side track # 2 in OB Lateral 01 :30 - 02:30 1.00 STKOH P PROD1 Pump out to 8328' at drlg rate 02:30 - 03:00 0.50 STKOH P PROD1 Cuttirlg trough 8328' to 8340' for open hole sidetrack # 2 in OB Lateral 03:00 - 05:30 2.50 DRILL P PROD1 Open hole side track # 2 - 8340' time drill to 8360' - COuld not get side tracked started - Move to new location - Cut trough from 8360' to 8375' 05:30 - 06:00 0.50 DRILL P PROD1 Time drill from 8375' to 8400' 06:00 - 18:00 12.00 DRILL P PROD1 Directional Drill from 8400' to 9863' - TD OB Lateral - WOB 0 to 5 - RPM 80 - TO on 7 - off 5 - GPM 251 - PP on 2725 - off 2550 - PU 145 - SO 65 - ROT 100 18:00 - 20:30 2.50 DRILL P PROD1 CBU 3 X - GPM 250 - PP 2740 - RPM 85 - TO 5 20:30 - 23:00 2.50 DRILL P PROD1 Pump out from 9863' to 7900' - Pump at drlg rate - Work sidetrack at 8375 - Back ream through it work string across it - Run check shot below it all ok - 7900' hole packing off - Pull from 7900' to 7600' without pump - 23:00 - 00:00 1.00 DRILL P PROD1 CBU 2 X - very little cuttings circulated out - GPM 250 - RPM 80 - PP 2700 psi 8/12/2004 00:00 - 00:30 0.50 CASE P PROD1 Circulate hole clean - GPM 250 - PP 2700 00:30 - 01 :30 1.00 CASE P PROD1 Rig Service 01 :30 - 05:30 4.00 CASE P PROD1 RIH to 7700 - Taking weight - Pick up orient to low side - RIH from 7700 to 8427' - Taking weight - Pick up run survey @ 8425' 102 angle - 11'1 old hole -Pull back to 7700' orient to straight low side - RIH to 8450 taking weight - Pick up to 8425' - Run survey - orginal hole 102 degrees - redrill hole 92 degrees - Check shot 91.6 - Con't RIH washing and reaming from 8425' to 8500' - Con't RIH from 8500' to 9482' - Taking weight - Wash from 9482' to 9863' 05:30 - 08:00 2.50 CASE P PROD1 CBU 3 X - Clean up hole - GPM 254 - PP 2700 - RPM 80 - TO 5K 08:00 - 12:30 4.50 CASE P PROD1 Flow check - Well static - Pump out at drill rate - R~across side tracks 8375' and 7720' serveral times to insure we can get back into new holes - Con't pump to shoe - CBU at shoe 12:30 - 13:30 1.00 CASE P PROD1 RIH - No problems 13:30 - 16:00 2.50 CASE P PROD1 CBU 3 X - GPM 254 - PP 2700 - RPM 80 - TO 5 K 16:00 - 17:30 1.50 CASE P PROD1 Flow check - Well static - Pump to shoe at drlg rate from 9863' to 7618' Pump at drlg rate - No Problems 17:30 - 18:30 1.00 CASE P PROD1 CBU - Flow check - Well static 18:30 - 20:30 2.00 CASE P PROD1 POOH from 7618' to 5248' -HOIefllJ ~ - flow check - well static 20:30 - 22:00 1.50 CASE P PROD1 RIH to shOe 7618' - L08t 6 bbls on trip in 22:00 - 22:30 0.50 CASE P PROD1 CBU - Flow check - Well static 22:30 - 00:00 1.50 CASE P PROD1 POH from 7618' to 7600' - W'-'tWIiIbbing- Pump out from 7600' to 6178' - Pump at 3 bpm 8/13/2004 00:00 - 04:00 4.00 CASE P PROD1 Pump out from 6178' to 1250' BHA - Hole swabbing - Con't POH without pump from 1250' to 268' BHA 04:00 - 05:00 1.00 CASE P PROD1 Stand back BHA - Down load MWD - break bit - flush motor - 05:00 - 05:30 0.50 CASE P PROD1 Clear rig floor Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/13/2004 05:30 - 06:30 1.00 CASE P PROD1 Rig up casing tools to run 41/2" Slotted liner 06:30 - 09:00 2.50 CASE P PROD1 Pick up 4 1/2" Slotted liner - Make up Baker Hanger / ZXP top packer 09:00 - 14:30 5.50 CASE P PROD1 Run 4 1/2" slotted liner in hole on 4" DP 14:30 - 15:30 1.00 CASE P PROD1 Tag bottom @ 9863' - Drop ball pump same down @ 4 bpm at 740 psi - Pressue up to 2000 psi - Slack off to 60K - Verify hanger set - Bleed psi to zero - Pressure up to 3000 psi - Stage up pressure to 5000 psi - No Indication of ZXP shear - Bleed off pressure to zero - Close Hydril - Pump down kill line - Pressure up annulus to 1500 psi - Good test - Bleed off pressure - Open Hydril - Rotate 15 turns to right with 5K TO - Pressure up to 500 psi - Pick up to 10' -Loss 500 psi - Pick up weight 10K less 15:30 - 16:00 0.50 CASE P PROD1 Clear rig floor - Monitor well - Well static 16:00 - 21 :30 5.50 CASE P PROD1 POH from 7455' to 7425' hole swabbing - Pump out with 4 bpm from 7425' to Baker running tool 21 :30 - 22:00 0.50 CASE P PROD1 Change out handling equipment to 3.5" - Service break running tool - Retrieve ball from ball seat 22:00 - 22:30 0.50 CASE P PROD1 Clean rig floor 22:30 - 23:00 0.50 STWHIP P PROD2 Moblize Milling BHA assembly to rig floor 23:00 - 00:00 1.00 STWHIP P PROD2 Pick up 3 1/2" HWT - 4 3/4" Drill collars - Stand back in derrick ~~ 8/14/2004 00:00 - 02:00 2.00 STWHIP P PROD2 Make up Whipstock assembly 02:00 - 05:30 3.50 STWHIP P PROD2 RIH with whipstock assembly - Fill every 25 stds 05:30 - 06:00 0.50 STWHIP P PROD2 Broke circulation and oriented whipstock 25 degrees left of high side. Set BTM anchor. Picked up to assure anchor was latched. Set down and sheared off disconnect bolt. 06:00 - 08:00 2.00 STWHIP P PROD2 Milled window from 7324' to 7336'. Exited slide at 7336' and milled formation to 7347'. WOM 3K. 100 RPM, 7-8K ftlbs, 275 gpm at 1860 psi. Pumped sweep to help clean hole. 08:00 - 09:30 1.50 STWHIP P PROD2 Pump sweep and circulated 2 bottoms up. Reciprocated and rotated through window with 6K ftlbs torque at 1860 psi with 275 gpm. 09:30 - 12:00 2.50 STWHIP P PROD2 Monitor well. Pulled out of hole and laid down milling assembly. 12:00 - 13:00 1.00 STWHIP P PROD2 Stand back 31/2" HWP and 43/4" spiral DC's in mast - LD down MWD - Bumper jars - Mills 13:00 - 13:30 0.50 STWHIP P PROD2 Clean - clear floor 13:30 - 14:00 0.50 STWHIP P PROD2 Flush stack - Activate rams - Flush stack 14:00 - 15:00 1.00 STWHIP P PROD2 MU BHA - RIH with 4 3/4" Flex DC's - Jars - Surface test MWD - Good test 15:00 - 17:30 2.50 STWHIP P PROD2 RIH for 267' - to 7276' - fill DP @ 2663',5066',7276. 17:30 - 19:00 1.50 STWHIP P PROD2 Cut drlg line - Top drive service - Rig service 19:00 - 20:30 1.50 STWHIP P PROD2 Orient 10 degrees left of high side - side through window without pumping or rotating 20:30 - 21 :00 0.50 DRILL P PROD2 Directional Drill from 7347' to 7466' - WOB 5 - RPM (sliding) - TO on NA - off 5K - GPM 250 - PP on 2300 - off 2170 - PU 130 - SO 85 - ROT 105 - ABI failed - POH for new Motor 21 :00 - 22:00 1.00 DRILL N DFAL PROD2 Circ to clear BHA - Pump out from 7466' to 7372' - Shut down pump - Pull through window from 7372' to 7276' - CBU - RPM 40 - TO 5K - GPM 250 @ 2200 psi - Flow check - Well Static 22:00 - 00:00 2.00 DRILL N DFAL PROD2 POH for new Motor - From 7267' to 1034 8/15/2004 00:00 - 00:30 0.50 DRILL N DFAL PROD2 POH from 1034' to 269' @ HWT 00:30 - 01 :30 1.00 DRILL N DFAL PROD2 Stand back BHA - Change out motor - Surface test @ 255 gpm - @ 1300 psi Printed: 8/30/2004 9:44:42 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/1/2004 8/27/2004 Spud Date: 8/2/2004 End: 8/15/2004 01 :30 - 04:30 3.00 DRILL N DFAL PROD2 RIH from 269' to 7285' - Fill pipe every 25 stds - Orient bit left of high side - RIH - to 7467' 04:30 - 17:30 13.00 DRILL P PROD2 Directional Drill from 7467' to 8825' - WOB 5 - RPM 80 - TO on 5.5 - off 4.5 - GPM 254 - PP on 2520 - off 2420 - PU 140 - SO 70 - ROT 100 17:30 - 20:30 3.00 DRILL P PROD2 CBU 4 X - Circulate hole clean for short trip to shoe - Flow check - Well Static 20:30 - 23:00 2.50 DRILL P PROD2 Pump out from 8825' to 7367' - Tight packing off @ 8150' to 8080' - 7980' to 7939' - 7783' to 7767' - 7645' to 7625' - Pull with out pump through window from 7367' to 7272' - Pump out at drlg rate 23:00 - 00:00 1.00 DRILL P PROD2 CBU at shoe - GPM 250 - PP 2240 - RPM 80 - TO 5K - Lots of cuttings back - Lots of fine sand with cuttings 8/16/2004 00:00 - 00:30 0.50 DRILL P PROD2 Con't circulate hole clean - service rig I top drive - 5822 total stks to clean hole from 7272' - Orient to high side 00:30 - 01 :30 1.00 DRILL P PROD2 RIH from 7272' to 8730' - Precauctionary wash from 8730' to 8825' 01 :30 - 12:30 11.00 DRILL P PROD2 Directional Drill from 8825' to 9910' - TD OA Lateral - WOB 5 - RPM 80 - TO 7 - off 6 - GPM 254 - PP on 2600 - off 2480 - PU 140 - SO 85 - ROT 105 12:30 - 15:30 3.00 CASE P PROD2 CBU 3 X - RPM 80 - TO 5K - GPM 254 - PP 2480 - Flow check - Well Static 15:30 - 19:00 3.50 CASE P PROD2 Pump out from 9910' to 9100' - Pump at drlg rate - Back ream from 9100' to 7374' - Some light packing off seen through 9300' to 9100' - Pull through window without pump from 7374' to 7278' 19:00 - 20:00 1.00 CASE P PROD2 CBU - GPM 254 - PP 2250 - RPM 80 - TO 5K - Lots of cuttings with fine sand over shakers - Flow check - Well static 20:00 - 21 :00 1.00 CASE P PROD2 RIH from 7278' to 9815' - Precauctionary wash from 9815' to 9910' 21 :00 - 23:30 2.50 CASE P PROD2 CBU 3 X - RPM 80 - TO 5K - GPM 254 - PP 2480 - Flow check - Well Static 23:30 - 00:00 0.50 CASE P PROD2 Pump to shoe from 9910' to 9198' - Pump at drlg rate 8/17/2004 00:00 - 02:00 2.00 CASE P PROD2 Pump out to shoe from 9198' to 7368' - Pump at drlg rate - shut down pump - Pull through window - from 7368' to 7272' - No Problems on trip out 02:00 - 04:00 2.00 CASE P PROD2 CBU - Pump sweep - Pump Versa sweep to thin mud to pull whipstock - GPM 254- RPM 80 - TO 5K - 4500 strokes to clean up hole 04:00 - 06:30 2.50 CASE P PROD2 POH for whipstock retrieving tool from 7272' 06:30 - 07:30 1.00 CASE P PROD2 Stand back BHA 07:30 - 09:00 1.50 CASE P PROD2 Clear floor, Make up whipstock retrival BHA, surface test MWD 09:00 - 11 :00 2.00 CASE P PROD2 Trip in to 7330 11 :00 - 12:00 1.00 CASE P PROD2 Orient and hook, whipstock pull free with 240K 12:00 - 13:00 1.00 CASE P PROD2 Circ bottoms up with 263 Gals min 1850 psi 13:00 - 17:00 4.00 CASE P PROD2 POH, pulled at reduced rate fl swabbing, hole~Wü 10 Bbls snort 17:00 - 19:30 2.50 CASE P PROD2 Stand back 3 1/2 pipe and 4 3/4 dc, lay down whipstock and tail pipe assembly 19:30 - 20:00 0.50 CASE P PROD2 Clean floor of tail pipe jewelery 20:00 - 20:30 0.50 CASE P PROD2 MohItor well, flowing 1 to 1 1/2 bbls hr. 20:30 - 23:30 3.00 CASE N DPRB PROD2 Pick up Johnny Wacker, and float sub, Tripping in to 7,470' with drill pipe, fill pipe 2400, 4800,74ØO.inåtalTIW valve one Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/17/2004 20:30 - 23:30 3.00 CASE N DPRB PROD2 it. down, gained 8 bbls over calcufated displacement on trip In. 23:30 - 00:00 0.50 CASE N DPRB PROD2 Clre, got gas to surf8cé immediately. mud cut to 8.5 8/18/2004 00:00 - 03:00 3.00 CASE N DPRB PROD2 Circ, Condition mud, raise mud wt to 9.2. loœ of gas on bottoms. some crude oil 03:00 - 03:30 0.50 CASE N DPRB PROD2 MOnitor well, well dead 03:30 - 04:30 1.00 CASE P PROD2 Slip and cut drill line 04:30 - 08:00 3.50 CASE N DPRB PROD2 POH 08:00 - 09:00 1.00 CASE P PROD2 Clear floor, Rig up to Pickup 4 1/2 Slotted Liner, PJSM 09:00 - 11 :00 2.00 CASE P PROD2 Picking up 4 1/2 Slotted liner and Baker Hook wall hanger, Total of 44 jts Slotted, 17 its solid 11 :00 - 15:30 4.50 CASE P PROD2 Tripping in with Liner, Took three attempts to exit window, liner wt @ 7324' window P/U 120K, S/O 90K, liner wt on bottom P/u 135k,S/0 85K, Shoe @ 9884', top of hook wall hanger 7319' 15:30 - 16:00 0.50 CASE P PROD2 Hook liner @ 7324', unhooked liner and went pass window, pull back and re hooked 16:00 - 17:00 1.00 CASE P PROD2 Drop ball pumped down @ 127 gpm 530 psi, pressure up to 3000psi to release from liner, pulled up to 7290' to verify release, lost 10k pickup wt., pressure up to 4,000 psi with test pump to shear ball 17:00 - 18:30 1.50 CASE P PROD2 Circ bottoms up 254gpm 1080 psi, flow check well, hole static 18:30 - 22:00 3.50 CASE P PROD2 POH with running tools, lay down same, clear floor 22:00 - 23:00 1.00 CASE P PROD2 Rig up to test, pull wear ring 23:00 - 23:30 0.50 CASE P PROD2 Test Bops and manifold 250psi-3500psi per test, 5 min. per test, test Hydril 250-2500psi, 5 min per test., the right to witness.testwaswaVied by·Chuck Scheve AOOGC., Her valve on choke line failed on high test. 23:30 - 00:00 0.50 CASE N RREP PROD2 Removing HCR valve 8/19/2004 00:00 - 01 :30 1.50 CASE N RREP PROD2 Change out HCR valve 01 :30 - 04:30 3.00 CASE P PROD2 Finish testing Bops and manifold 250psi-3500psi per test, 5 min. per test, test Hydril 250-2500psi, 5 min per test., the right to witness test was wavier by Chuck Scheve AOOGC. 04:30 - 05:00 0.50 CASE PROD2 Install wear ring 05:00 - 05:30 0.50 CASE P PROD2 Rig up to pickup LEM, PJSM 05:30 - 06:30 1.00 CASE P PROD2 Picking up Seal Assy, 3 its 4.512.6# L-80 Tubing, LEM, Baker seal bore extension, Baker ZXP liner top packer 06:30 - 10:30 4.00 CASE P PROD2 Tripping in with LEM. PU 125K SO 90K 10:30 - 12:00 1.50 CASE P PROD2 Latch LEM, @ 7321 Picked up with 10K over pickup to confirm latch,drop ball pump down 2 bpm 280 psi, pressure up to 4,000 psi to set ZXP packer and release LEM, Test annulus to 2500psi for 15 min., stand back 1 stand, rigged up and shear ball with First Energy pressure to 5200 psi to shear ball, P/U 95K top of liner tie back @ 7265'. 12:00 - 13:30 1.50 CASE P PROD2 Circ bottoms up 250 gpm, 1140 psi 13:30 - 17:00 3.50 CASE P PROD2 Tripping out, hole swabbing, pumped out to 3350', pull out from 3350 to surface, lay down running tools \-~ 17:00 - 20:00 3.00 STWHIP P PROD3 Picking up whipstock, space out pipe. and Bha. surface test MWD 20:00 - 00:00 4.00 STWHIP P PROD3 Tripping in with whipstock to 7158' 8/20/2004 00:00 - 00:30 0.50 STWHIP P PROD3 Orient whipstock to 18 degrees to left, set whipstock with 15K down,shear of whipstock with 35K down, had to make 5 attempts to shear 00:30 - 03:00 2.50 STWHIP P PROD3 Mill window with 279 gals min. 2100 psi, 80-100 rpms, top of window 6814', bottom window, 6826', TD 6839' Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/20/2004 03:00 - 04:30 1.50 STWHIP P PROD3 Circ, Pump sweep, work window 70 rpms, 273 gals min, 2100 psi 04:30 - 07:00 2.50 STWHIP P PROD3 Flow check, POH 07:00 - 07:30 0.50 STWHIP P PROD3 Stand back BHA 07:30 - 08:00 0.50 STWHIP P PROD3 Picked up stack washer,flush BOP stack 08:00 - 09:30 1.50 STWHIP P PROD3 Pick up BHA # 9 09:30 - 12:00 2.50 STWHIP P PROD3 Trip in to 6700' 12:00 - 13:30 1.50 STWHIP P PROD3 Cut and slip drilling line, service top drive 13:30 - 14:00 0.50 STWHIP P PROD3 Orient and slide thru window @ 6814' 14:00 - 20:00 6.00 DRILL P PROD3 Drill from 6838' to 7390' with 3K bit wt. 80 rpms, 2600 psi, 254 gpm., out of sand @ 7214' to 7390' 20:00 - 20:30 0.50 DRILL P PROD3 Circ for side track, Poh to 6986' 20:30 - 21 :30 1.00 DRILL P PROD3 Perform openhole side track @ 7oa0!.,trough 6986' to 7020' 21 :30 - 22:30 1.00 DRILL P PROD3 Time Drill from 7020 to 77063' 22:30 - 00:00 1.50 DRILL P PROD3 Drill from 7063' to 7227' with 3K bit wt. 80 rpms, 2600 psi, 254 gpm. out of sand from 7069' to 7170', AST 3.12, ART 2.15 8/21/2004 00:00 - 11 :00 11.00 DRILL P PROD3 Drill from 7227' to 8331' with 3K bit wt. 80 rpms, 2800 psi, 254 gpm. 11 :00 - 13:30 2.50 DRILL P PROD3 Circ, @ bottoms up with 80 rpms, 263gpm, 2850 psi 13:30 - 14:30 1.00 DRILL P PROD3 Pump out to window with full drilling rate, back ream 35 rpms, pull thru window with out pumping, work side track spot @ 7020', 14:30 - 15:00 0.50 DRILL P PROD3 Monitor well, service top drive 15:00 - 16:00 1.00 DRILL P PROD3 Circ bottoms up 263 gpm, 2570 psi, 35 rpms 16:00 - 17:00 1.00 DRILL P PROD3 Trip to bottom, @ 8331, wash last stand to bottom 17:00 - 00:00 7.00 DRILL P PROD3 Drill from 8331' to 9004' with 3K bit wt. 80 rpms, 3000 psi, 254 gpm., AST 5.1, ART 4.8, TQ 5K 8/22/2004 00:00 - 07:30 7.50 DRILL P PROD3 Drill from 9004' to 9595' with 3K bit wt. 80 rpms, 3100 psi, 275 gpm., out of sand @ 8822' 07:30 - 08:00 0.50 DRILL P PROD3 Cite fêF'SIde track 08:00 - 08:30 0.50 DRILL P PROD3 Pump out to 9006', at full drilling rate 08:30 - 09:00 0.50 DRILL P PROD3 Orient and Trench hole 9013 to 9023' for tow side side track 09:00 - 18:00 9.00 DRILL P PROD3 Drilling from 9024' to 9768' TD with 80 rpms, 3100 psi, 275 gal per min. out of sand 9225 to 9450, back in to sand 9450 to 9688, out of sand 9688 to 9768TD 18:00 - 21 :30 3.50 CASE P PROD3 Circ four bottoms up with 263 gpm.,2900 psi,80 rpms 21 :30 - 00:00 2.50 CASE P PROD3 Pumping out of hole with full drilling rate, 30 rpms, Hole tight, pulling 20 to 25K,over and torque, from 9450 to 9000, pulled slow. 8/23/2004 00:00 - 01 :30 1.50 CASE P PROD3 Pumping out to 6900 with full drilling rate, 30 rpms, pulled in to window with out pumping or rotating 01 :30 - 02:00 0.50 CASE P PROD3 Circ bottoms up @ 6800' 02:00 - 02:30 0.50 CASE P PROD3 Service Top drive 02:30 - 04:00 1.50 CASE P PROD3 RIH to 9768, wash last stand to bottom, went thru both sidetracks, no problems 04:00 - 09:00 5.00 CASE P PROD3 Circ, Three bottoms up with 263 gpm, 2900 psi, 80 rpms, 09:00 - 10:30 1.50 CASE P PROD3 Displace with new 9.2 Oilbase mud, monitor well 10:30 - 11 :30 1.00 CASE P PROD3 Pumping out of hole with full drilling rate, 9768 to 8525' 11 :30 - 13:00 1.50 CASE N RREP PROD3 Change out saver sub on topdrive, circ thru cement line 13:00 - 14:30 1.50 CASE P PROD3 Pumping out of hole with full drilling rate, 8525 to 6892', pull thru window with out pumping to 6764' 14:30 - 15:30 1.00 CASE P PROD3 Circ and rotate 35rpms, 260 gpm. 2300psi, raise mud wt to 9.4 15:30 - 18:00 2.50 CASE P PROD3 Poh to Bha Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: 8/23/2004 18:00 - 19:30 1.50 CASE P PROD3 Stand back SHA, lay down,Motor, Clear floor 19:30 - 20:00 0.50 CASE P PROD3 Download MDW 20:00 - 21 :30 1.50 CASE P PROD3 Picking up whip stock retrieval BHA, surface test MWD 21 :30 - 23:30 2.00 CASE P PROD3 Tripping in with whipstock hook to 6781' 23:30 - 00:00 0.50 CASE P PROD3 Orient 20 degree to left, hook whip stock, jar free after 2 trys. pull to 8781, monitor, well static. 8/24/2004 00:00 - 00:30 0.50 CASE P PROD3 Circ bottoms up @ 6871, no gas cut mud on bottoms up 00:30 - 01 :00 0.50 CASE P PROD3 Monitor well, well static 01 :00 - 04:00 3.00 CASE P PROD3 Poh with whipstock 04:00 - 06:00 2.00 CASE P PROD3 Laying down whipstock, and space out pipe 06:00 - 08:00 2.00 CASE P PROD3 Clear floor, Load pipe shed with screens, rig up to pickup 4" screen liner,PJSM 08:00 - 11 :30 3.50 CASE P PROD3 Picking up 4" liner, Total of 54 jts 4 9.5# L-80 1ST blank pipe, 30 jts 4" C27 Screen pipe, swell packer, hook wall hanger 11 :30 - 20:30 9.00 CASE P PROD3 Tripping in with liner, went thru window first try, went in to side track #1 to 7390, pulled back to 7000' Rotate pipe 1/2 turn, went in right hole. trip in to 9739', We had lots of hanging up of centralizers on window from 7000' ft to 9739', we didn't see sidetrack #2 @ 9020' 20:30 - 21 :00 0.50 CASE P PROD3 Hooked window, on depth, un hook and went pass window, pull back up and rehook window, pick up and un hooked window, went pass window again, picked up and rehooked window, top of hook wall 6809', swell packer 6845', shoe 9739' 21 :00 - 21 :30 0.50 CASE P PROD3 Drop ball, pumped down 127 gpm, 550 psi, pressure up to 2800psi, release liner, lost 10K string, pull up to 6777', shear ball with 4300 psi with test pump, 21 :30 - 22:30 1.00 CASE P PROD3 Circ bottoms up 254 gals min, 1120 psi, monitor well 22:30 - 00:00 1.50 CASE P PROD3 Cut and slip drilling line, service top drive 8/25/2004 00:00 - 03:00 3.00 CASE P PROD3 POH with hook wall running tools, lay down same 03:00 - 03:30 0.50 CASE P PROD3 Rig up to P/U LEM tools, PJSM 03:30 - 05:00 1.50 CASE P PROD3 Picking seals assy, XO jt. 10 jts 4.512.6# L-80 Tubing, LEM,casing swivel,Saker ZXP liner top packer 05:00 - 07:30 2.50 CASE P PROD3 Tripping in with LEM, to 6800' 07:30 - 08:30 1.00 CASE P PROD3 Sting in to hook hanger,Orient Lem ,Locate seal assem. seals, @ 7293, top of LEM 6773' 08:30 - 09:00 0.50 CASE P PROD3 Drop ball. pump to seat @ 3 bbls min. 600 psi, set packer with 3800 ps, release from packer 09:00 - 11 :00 2.00 CASE P PROD3 Pull to 6720' shear ball with test pump 5000 psi, circ bottoms up 4 bbls min., 780 psi 11 :00 - 13:30 2.50 CASE P PROD3 Trip out with LEM running tools, lay down same 13:30 - 14:00 0.50 CASE P PROD3 clear floor 14:00 - 16:30 2.50 CASE P PROD3 Pick up circ. sub, trip in to 6731 16:30 - 20:30 4.00 CASE P PROD3 Displace well with 9.3 brine, pumped 30 bbls LVT, 25 bbls Viscosified 9.3 brine,30 bbls 9.3 brine w/ safesuf 0, 25 bbls Viscosified 9.3 brine, and 9.3 brine 20:30 - 21 :30 1.00 CASE P PROD3 Monitor well, service Rig 21 :30 - 00:00 2.50 CASE P PROD3 Lay down 4" drill pipe 8/26/2004 00:00 - 02:00 2.00 CASE P PROD3 Finish laying down pipe, out of hole 02:00 - 02:30 0.50 CASE P PROD3 Pull wear ring, rig up to lay down pipe out of derrick 02:30 - 05:00 2.50 CASE P PROD3 Laying down pipe out of derrick in mouse hole 05:00 - 07:00 2.00 RUNCO RUNCMP Rigging up to run Tubing, spot spooling unit, PJSM 07:00 - 10:00 3.00 RUNCO RUNCMP I Pick up pump, fill with oil, make up cable, test Printed: 8/30/2004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/1/2004 8/27/2004 Spud Date: 8/2/2004 End: Picking up 2 7/8 L-80 6.5 tubing, to 5673' 18:30 - 21:30 3.00 RUNCMP Splice ESP cable 21 :30 - 22:30 1.00 RUNCMP Picking up 2 7/8 L-80 6.5 IBT tubing, test ever 2,000 ft and fill tubing, TD of pump 6398, Top of pump 6342', XN nipple 6321', glm 6170', glm 2167', glm 148', total 199 jts. Lesalle clamps 106 , P/U 83K, S/o 70K, Blocks 50K 22:30 - 00:00 1.50 RUNCMP Test continuity, M/U to ESP hanger penetrator, retest continuity 8/27/2004 00:00 - 00:30 0.50 RUNCMP Finish M/U to ESP hanger penetrator, retest continuity 00:30 - 02:00 1.50 RUNCMP Install top Lesalle clamp, land tubing and test Two way check to 1000 psi 02:00 - 03:30 1.50 RUNCMP Nipple down BOPS 03:30 - 06:00 2.50 RUNCMP Nipple up FMC 11" X 2 9/16 ESP tubing head Adaper and CIW 2 9/16 5K Tree, Test tree and packoff to 5000 psi 06:00 - 07:00 1.00 RUNCMP Dry rod, TWC valve out, dry rod in BPV. Secure well Rig release for rig move @ 0700 8/27/2004 Printed: 8/30/2004 9:44:42 AM 2,389 (psi) 11.51 (ppg) - Printed: 8/30/2004 9:44;30 AM 510 (psi 9.05 (ppg) 3,996.0 (ft) (f 7,618.0 FIT 8/9/2004 WELL-SERVICE REPORT WELL MPI-14 DATE 8/28/2004 AFE MSD337396 JOB SCOPE NEW WELL POST DAILY WORK FREEZE PROT KEY PERSON FESCO-ANDERSON MINID 0" DEPTH OFT UNIT FESCO 367 DAY SUPV CUBBON NIGHT SUPV CUBBON TTL SIZE 0" DAILY SUMMARY ( Freeze Protect) Freeze Protect TBG With 15 BBLS Diesel, Freeze Protect IA With 75 BBLS Dead Crude. IWHP=OIO/O. FWHP=OIO/O Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 06:00 Dispatched / Travel To Mod-58 06:28 Load Dead Crude 06:56 Load Diesel 07:16 Arrive On Location I Ria-Up 07:25 PT IA To 3500 Psi ^ .m_~v~_~ 07:27 1.0 start crude 350 Down IA 07:34 1.5 10 " 850 Down IA 07:47 1.9 35 " 1100 Down IA 08:09 1.9 75 " 1150 Swap To TBG 08:14 PT TBG To 3800 Psi 08:15 1 start Diesel 1125 Down TBG 08:34 ¡-----~ Shut Down IRDMO Final-> 0 0 0 FLUID SUMMARY 75 BBLS Dead Crude 10 BBLS Diesel 5 BBLS Diesel Paid For On Previous Job SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL BP $0 $3,360 FESCO $650 $1,430 WAREHOUSE $420 $420 TOTAL FIELD ESTIMATE: $1,070 $5,210 . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . 30-Sep-04 DEFINITIVE Re: Distribution of Survey Data for Well MPI-14 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the * .PTT and * .PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,305.37' MD 8,360.00' MD 9,863.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date /oh If) 1- f , / Please call meat 273-3545 if you have any q Regards, William T. Allen Survey Manager AUachment(s) A,&C¡-/i) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-14 Job No. AKZZ3214396, Surveyed: 11 August, 2004 Survey Report 28 September, 2004 Your Ref: API 500292321400 Surface Coordinates: 6009461.02 N, 551315.31 E (70· 26'11.7636" N, 149· 34' 53.8198" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009461.02 N, 51315.31 E (Grid) Surface Coordinates relative to Structure Reference: 325.53 S, 862.60 W (True) Kelly Bushing Elevation: 68. 16ft above Mean Sea Level Kelly Bushing Elevation: 68. 16ft above Project V Reference Kelly Bushing Elevation: 68. 16ft above Structure Reference SpE!!I"'"'I"'"')/-SU:1'1 DFULL'NG 'seRVices A Halliburton Company DEFINITIVE . . Survey Ref: svy1466 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-14 Your Ref: API 500292321400 Job No. AKZZ3214396, Surveyed: 11 August, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8305.37 89.750 351.440 3957.14 4025.30 2683.60 N 4856.19 W 6012111.14 N 546440.77 E 5404.53 Tie On Point 8360.00 92.010 352.570 3956.30 4024.46 2737.68 N 4863.78 W 6012165.17 N 546432.80 E 4.625 5446.36 Window Point 8404.94 91.910 354.620 3954.76 4022.92 2782.31 N 4868.79 W 6012209.77 N 546427.49 E 4.564 5479.95 8452.16 90.930 358.390 3953.59 4021.75 2829.42 N 4871.67 W 6012256.86 N 546424.29 E 8.247 5513.61 8504.36 94.260 358.460 3951.23 4019.39 2881.54 N 4873.10 W 6012308.96 N 546422.49 E 6.381 5549.55 . 8549.48 95.450 2.560 3947.41 4015.57 2926.49 N 4872.71 W 6012353.91 N 546422.58 E 9.430 5579.33 8601.54 93.520 5.380 3943.33 4011.49 2978.26 N 4869.11 W 6012405.70 N 546425.82 E 6.550 5611.30 8645.30 93.890 7.430 3940.51 4008.67 3021.65 N 4864.24 W 6012449.13 N 546430.39 E 4.751 5636.71 8693.63 93.640 7.590 3937.33 4005.49 3069.46 N 4857.94 W 6012496.98 N 546436.37 E 0.614 5664.02 8741.56 94.260 10.190 3934.03 4002.19 3116.70N 4850.55 W 6012544.27 N 546443.43 E 5.564 5690.14 8791.21 94.330 10.960 3930.31 3998.4 7 3165.37 N 4841.46 W 6012593.00 N 546452.18 E 1.553 5715.95 8837.81 91.300 10.180 3928.02 3996.18 3211.12 N 4832.93 W 6012638.81 N 546460.40 E 6.714 5740.22 8886.50 86.480 9,730 3928.97 3997.13 3259.05 N 4824.51 W 6012686.80 N 546468.49 E 9.942 5766.04 8934.27 83.630 8.800 3933.08 4001.24 3306.02 N 4816.85 W 6012733.82 N 546475.83 E 6.273 5791 .77 8982.51 83.070 7.550 3938.67 4006.83 3353.44 N 4810.04 W 6012781.29 N 546482.31 E 2.823 5818.45 9028.19 82.700 6.600 3944.33 4012.49 3398.43 N 4804.45 W 6012826.31 N 546487.59 E 2.217 5844.40 9074.24 82.260 6.560 3950.35 4018.51 3443.78 N 4799.22 W 6012871.70 N 546492.51 E 0.959 5870.86 9124.31 84.430 8.020 3956.16 4024.32 3493.11 N 4792.91 W 6012921.07 N 546498.48 E 5.213 5899.17 9172.85 84.060 7.490 3961.02 4029.18 3540.96 N 4786.39 W 6012968.96 N 546504.66 E 1.327 5926.35 9220.80 86.720 7.660 3964.88 4033.04 3588.33 N 4780.09 W 6013016.38 N 546510.64 E 5.559 5953.37 9268.24 87.340 8.450 3967.34 4035.50 3635.24 N 4773.46 W 6013063.33 N 546516.95 E 2.115 5979.82 9314.64 86.730 7.340 3969.74 4037,90 3681.14 N 4767.09 W 6013109.27 N 546523.00 E 2.727 6005.80 . 9361.90 88.520 8.160 3971.69 4039.85 3727.92 N 4760.72 W 6013156.10 N 546529.05 E 4.165 6032.38 9410.43 88.580 9.000 3972.92 4041.08 3775.90 N 4753.49 W 6013204.12 N 546535.96 E 1.735 6059.10 9458.28 89.690 7.380 3973.65 4041.81 3823.25 N 4746.67 W 6013251.52 N 546542.45 E 4.104 6085.72 9506.37 89.320 6.390 3974.06 4042.22 3870.99 N 4740.91 W 6013299.30 N 546547.88 E 2.198 6113.38 9554.88 88.580 6.540 3974.95 4043.11 3919.18 N 4735.44 W 6013347.53 N 546553.01 E 1.556 6141.57 9602.10 89.750 6.140 3975.64 4043.80 3966.11 N 4730.23 W 6013394.49 N 546557.90 E 2.619 6169.09 9649.14 90.370 6.050 3975.59 4043.75 4012.88 N 4725.24 W 6013441.30 N 546562.57 E 1.332 6196.68 9698.16 91.300 6.120 3974.87 4043.03 4061.62 N 4720.04 W 6013490.07 N 546567.43 E 1.903 6225.43 9747.36 92.900 5.130 3973.07 4041 .23 4110.55 N 4715.22 W 6013539.03 N 546571.92 E 3.823 6254.59 9792.59 94.260 4.840 3970.25 4038.41 4155.52 N 4711.30W 6013584.02 N 546575.53 E 3.074 6281.76 9863.00 94.260 4.840 3965.02 4033.18 - 4225.48 N 4705.37 W 6013654.03 N 546580.97 E 0.000 6324.18 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 28 September, 2004 - 8:55 Page 2 of 3 DrillQuest 3.03.06.006 J Halliburton Sperry-Sun Survey Report for Milne Point MP/- MP/·14 Your Ref: AP/500292321400 Job No. AKZZ3214396, Surveyed: 11 August, 2004 BPXA Milne Point Unit Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 312.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9863.00ft., The Bottom Hole Displacement is 6324. 18ft., in the Direction of 311.924° (True). Comments . Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8305.37 8360.00 9863.00 4025.30 4024.46 4033.18 2683.60 N 2737.68 N 4225.48 N 4856.19 W 4863.78 W 4705.37 W Tie On Point Window Point Projected Survey Survey toolproaram for MPI-14 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 352.00 0.00 351.96 352.00 9863.00 351.96 CB-SS-GYRO (MPI-14PB1) 4033.18 MWD+IIFR+MS (MPI-14PB1) . 28 September, 2004 - 8:55 Page 3 of3 Dri/lQuest 3.03.06.006 . AOGCC RùlJtrT1Jëãson 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well MPI-14 PB1 30-Sep-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 9,450.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date /tJ;7 /tQ¥ "gned . I Please call me at 273-3545 if you have any qu Regards, William T. Allen Survey Manager AUachment(s) a2öt-{- ILof DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-14PB1 . Job No. AKZZ3214396, Surveyed: 10 August, 2004 Survey Report 28 September, 2004 Your Ref: API 500292321470 Surface Coordinates: 6009461.02 N, 551315.31 E (70· 26'11.7636" N, 149· 34' 53.8198" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1009461.02 N, 51315.31 E (Grid) Surface Coordinates relative to Structure Reference: 325.53 S, 862.60 W (True) Kelly Bushing Elevation: 68. 16ft above Mean Sea Level Kelly Bushing Elevation: 68. 16ft above Project V Reference Kelly Bushing Elevation: 68. 16ft above Structure Reference SpE!!r""......y-suf"1 [jAIL.L.ING 'Se.AVlt::e.s A Halliburton Company Survey Ref: svy1442 Halliburton Sperry-Sun Survey Report for Milne Point MPI· MPI-14PB1 Your Ref: API 500292321470 Job No. AKZZ3214396, Surveyed: 10 August, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -68.16 0.00 0.00 N 0.00 E 6009461.02 N 551315.31 E 0.00 CB-SS-GYRO 172.00 0.550 150.000 103.84 172.00 0.71 S 0.41 E 6009460.31 N 551315.73 E 0.320 -0.79 260.00 0.500 16.000 191.84 260.00 0.71 S 0,73 E 6009460.31 N 551316.04 E 1.099 -1.02 352.00 2.500 332.000 283.80 351.96 1.45 N 0.10W 6009462.47 N 551315.20 E 2.357 1.04 MWD+IIFR+MS 383.30 2.710 338.250 315.07 383.23 2.74N 0.70W 6009463.75 N 551314.59 E 1.128 2.35 . 481.48 3.640 331.700 413.1 0 481.26 7.64 N 3.03W 6009468.64 N 551312.22 E 1.015 7.36 577.45 6.250 329.350 508.70 576.86 14.81 N 7.14W 6009475.78 N 551308.07 E 2.727 15.22 673.34 6.830 325.020 603.97 672.13 23.98 N 13.07 W 6009484.91 N 551302.07 E 0.794 25.76 769.07 6.440 316.810 699.06 767.22 32.55 N 20.01 W 6009493.44 N 551295.08 E 1.070 36.65 863.58 8.330 301.410 792.79 860.95 39.99 N 29.48 W 6009500.80 N 551285.55 E 2.879 48.67 960.03 11 .290 283.230 887.84 956,00 45.79 N 44.64 W 6009506.50 N 551270.35 E 4.407 63.82 1054.19 14.670 275.830 979.59 1047.75 49.11 N 65.48 W 6009509.68 N 551249.49 E 3.993 81.53 1149.35 18.900 274.180 1070.67 1138.83 51.46 N 92.85 W 6009511-84 N 551222.10 E 4.473 103.44 1245.73 23.800 270.660 1160.42 1228.58 52.83 N 127.89 W 6009512.96 N 551187.06 E 5.253 130.39 1341.79 25.770 269.990 1247.62 1315.78 53.05 N 168.16W 6009512.91 N 551146.79 E 2.072 160.46 1437.42 25.130 268.940 1333.97 1402.13 52.67 N 209.25 W 6009512.24 N 551105.70 E 0.819 190.74 1532.35 26.140 270.950 1419.56 1487.72 52.64 N 250.31 W 6009511.94 N 551064.64 E 1 .404 221.24 1626.67 29.920 275.650 1502.81 1570.97 55.30 N 294.52 W 6009514.29 N 551020.42 E 4.639 255.87 1722.99 31.520 278.360 1585.62 1653.78 61.33 N 343.34 W 6009519.98 N 550971.56 E 2.196 296.19 1821.73 33.410 277.800 1668.92 1737.08 68.77 N 395.81 W 6009527.07 N 550919.03 E 1.938 340.16 1917.07 34.720 277.740 1747.90 1816.06 75.99 N 448.72 W 6009533.92 N 550866.07 E 1.374 384.31 2013.04 41.800 274.720 1823.22 1891-38 82.31 N 507.76 W 6009539.84 N 550806.99 E 7.628 432.42 . 2109.33 44.470 272.790 1893.48 1961.64 86.59 N 573.44 W 6009543.67 N 550741.28 E 3.093 484_10 2205.61 49.320 272.770 1959.25 2027.41 90.00 N 643.63 W 6009546.59 N 550671.07 E 5.037 538.54 2300.67 52.490 272.700 2019.19 2087.35 93.52 N 717.32 W 6009549.60 N 550597.37 E 3.335 595.65 2396.06 56.210 271.650 2074.78 2142.94 96.45 N 794.76 W 6009551.99 N 550519.90 E 4.001 655.16 2491.36 60.220 272.160 2124.97 2193.13 99.15 N 875.71 W 6009554.14 N 550438.94 E 4.232 717.12 2587.42 63.510 272.410 2170.26 2238.42 102.53 N 960.34 W 6009556.94 N 550354.29 E 3.433 782.27 2654.75 65.080 272.840 2199.46 2267.62 105.31 N 1020.94 W 6009559.30 N 550293.67 E 2.402 829.17 2699.00 65.780 272.070 2217.86 2286,02 107.03 N 1061.14 W 6009560.74 N 550253.46 E 2.238 860.20 2771.93 68.000 270.790 2246.48 2314.64 108.70 N 1128.19 W 6009561.95 N 550186.39 E 3.445 911.14 2868.54 66.920 271.980 2283.52 2351.68 110.85 N 1217.40 W 6009563.49 N 550097.18 E 1.595 978.87 2964.85 67.460 272.610 2320.85 2389.01 114.41 N 1306.10 W 6009566.44 N 550008.45 E 0.823 1047.17 3060.06 68.070 272.850 2356.88 2425.04 118.60 N 1394.13 W 6009570.03 N 549920.40 E 0.682 1115.40 3156.84 68.010 272.420 2393.07 2461.23 122.73 N 1483.79 W 6009573.54 N 549830.71 E 0.417 1184.80 28 September, 2004 - 8:55 Page 2 of5 Dri//Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-14PB1 Your Ref: API 500292321470 Job No. AKZZ3214396, Surveyed: 10 August, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3253.78 68.590 272.910 2428.92 2497.08 126.92 N 1573.77 W 6009577.11 N 549740.71 E 0.761 1254.46 3349.67 69.390 272.720 2463.30 2531.46 131.31 N 1663.17 W 6009580.89 N 549651.27 E 0.855 1323.84 3445.47 69.130 272.460 2497.22 2565.38 135.36 N 1752.67 W 6009584.32 N 549561.75 E 0.372 1393.06 3542.11 68.790 270.870 2531.92 2600.08 137.98 N 1842.83 W 6009586.32 N 549471.58 E 1.575 1461.82 3638.20 67.730 271.260 2567.51 2635.67 139.64 N 1932.07 W 6009587.37 N 549382.33 E 1.166 1529.24 . 3734.05 68.120 270.140 2603.53 2671.69 140.73 N 2020.88 W 6009587.84 N 549293.51 E 1.157 1595.97 3830.05 68.060 270.590 2639.36 2707.52 141.29 N 2109_94 W 6009587.79 N 549204.44 E 0.439 1662.54 3925.72 69.450 269.660 2674.02 2742.18 141.48 N 2199.11 W 6009587.37 N 549115.28 E 1.712 1728.93 4021.98 69.410 269.060 2707.84 2776.00 140.48 N 2289.23 W 6009585.74 N 549025.17 E 0.585 1795.22 4118.02 69.110 269.390 2741.85 2810.01 139.26 N 2379.03 W 6009583.91 N 548935.37 E 0.448 1861.15 4214.06 69.330 269.640 2775.93 2844.09 138.50 N 2468.82 W 6009582.53 N 548845.59 E 0.334 1927.37 4310.52 69.070 269.980 2810.18 2878.34 138.20 N 2559.00 W 6009581.61 N 548755.42 E 0.426 1994.18 4406.79 68.810 269.580 2844.78 2912.94 137.86 N 2648.83 W 6009580.65 N 548665.59 E 0.473 2060.71 4503.38 68.070 269.450 2880.27 2948.43 137.10 N 2738.66 W 6009579.27 N 548575.77 E 0.776 2126.96 4599.49 67.790 269.570 2916.38 2984.54 136.34 N 2827.73 W 6009577.90 N 548486.71 E 0.313 2192.64 4695.08 67.220 271.890 2952.96 3021.12 137.46 N 2916.03 W 6009578.41 N 548398.41 E 2.320 2259.01 4790.89 69.320 273.570 2988.43 3056.59 141.71 N 3004.92 W 6009582.05 N 548309.49 E 2.731 2327.91 4887.18 69.460 277.500 3022.34 3090.50 150.40 N 3094.60 W 6009590.12 N 548219.74 E 3.823 2400.38 4982.81 68.990 280.930 3056.27 3124.43 164.71 N 3182.85 W 6009603.83 N 548131.41 E 3.389 2475.53 5078.71 69.600 284.390 3090.18 3158.34 184.37 N 3270.35 W 6009622.89 N 548043.77 E 3.434 2553.72 5175.32 68.540 288.180 3124.70 3192.86 209.66 N 3356.95 W 6009647.58 N 547957.00 E 3.825 2634.99 5271.29 68.200 292.070 3160.09 3228.25 240.34 N 3440.70 W 6009677.68 N 547873.04 E 3.784 2717.76 . 5367.31 68.940 296.850 3195.19 3263.35 277.35 N 3522.02 W 6009714.13 N 547791.46 E 4.697 2802.95 5463.07 68.480 300.300 3229.97 3298.13 320.01 N 3600.36 W 6009756.25 N 547712.83 E 3.391 2889.72 5559.14 67.620 304.420 3265.89 3334.05 367.68 N 3675.62 W 6009803.41 N 547637.25 E 4.077 2977.54 5654.28 66.660 308.340 3302.86 3371.02 419.66 N 3746.18 W 6009854.90 N 547566.33 E 3.928 3064.77 5751.13 66.950 313.110 3341.03 3409.19 477.72 N 3813.62 W 6009912.49 N 547498.49 E 4.537 3153.73 5848.11 67.620 318.790 3378.50 3446.66 541.99 N 3875.78 W 6009976.33 N 547435.89 E 5.446 3242.93 5944.37 66.610 325.080 3415.97 3484.13 611.76N 3930.44 W 6010045.72 N 547380.76 E 6.110 3330.23 6040.64 65.920 328.260 3454.73 3522.89 685.37 N 3978.85 W 6010119.00 N 547331.83 E 3.108 3415.47 6136.06 65.790 330.870 3493.76 3561.92 760.44 N 4022.96 W 6010193.76 N 547287.22 E 2.500 3498.47 6229.97 67.140 333.370 3531.27 3599.43 836.53 N 4063.21 W 6010269.58 N 547246.45 E 2.832 3579.30 6327.23 66.930 333.070 3569.21 3637.37 916.48 N 4103.55 W 6010349.24 N 547205.55 E 0.357 3662.78 6423.50 66.830 333.310 3607.01 3675.17 995.50 N 4143.49 W 6010427.99 N 547165.07 E 0.252 3745.33 6520.06 74.560 335.050 3638.91 3707.07 1077.48 N 4183.12W 6010509.70 N 547124.88 E 8.184 3829.64 28 September, 2004 . 8:55 Page 3 of5 DrillQuest 3.03.06.006 Halliburlon Sperry-Sun Survey Report for Milne Point MPI- MPI-14P81 Your Ref: API 500292321470 Job No. AKZZ3214396, Surveyed: 10 August, 2004 BPXA Mílne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6615.26 71.620 335.270 3666.60 3734.76 1160.13 N 4221.38 W 6010592.08 N 547086.05 E 3.096 3913.37 6711.99 75.740 334.340 3693.78 3761.94 1244.11 N 4260,89 W 6010675.78 N 547045.96 E 4.358 3998.93 6808.27 74.910 333.740 3718.17 3786.33 1327.85 N 4301.66 W 6010759.24 N 547004.61 E 1.052 4085.26 6904.12 74.530 335.060 3743.43 3811.59 1411.23 N 4341.62 W 6010842.35 N 546964.09 E 1.386 4170.75 7000.37 74.390 335.340 3769.22 3837.38 1495.41 N 4380.51 W 6010926.26 N 546924.61 E 0.316 4255.98 . 7095.66 74.640 334.770 3794.66 3862.82 1578.67 N 4419.24 W 6011009.25 N 546885.31 E 0.633 4340.48 7191.80 73.820 337.480 3820.79 3888.95 1663.27 N 4456.69 W 6011093.58 N 546847.28 E 2.844 4424.91 7289.15 73.050 337.280 3848.55 3916.71 1749.40 N 4492.58 W 6011179.47 N 546810.80 E 0.815 4509.21 7384.01 72.660 335.830 3876.51 3944.67 1832.56 N 4528.64 W 6011262.37 N 546774.17 E 1.517 4591.65 7481.18 77.190 335.240 3901.78 3969.94 1917.93 N 4567.49 W 6011347.48 N 546734.73 E 4.699 4677.66 7561.59 79.960 335.800 3917.70 3985.86 1989.66 N 4600.14 W 6011418.98 N 546701.58 E 3.512 4749.92 7618.00 82.940 337.010 3926.09 3994.25 2040.77 N 4622.4 7 W 6011469.94 N 546678.91 E 5.693 4800.71 7685.53 88.950 336.590 3930.86 3999.02 2102.66 N 4648.99 W 6011531.64 N 546651.96 E 8.921 4861.83 7735.42 90.990 336.500 3930.89 3999.05 2148.42 N 4668.85 W 6011577.27 N 546631.79 E 4.093 4907.21 7781.00 92.780 336.830 3929.39 3997.55 2190.25 N 4686.89 W 6011618.97 N 546613.46 E 3.993 4948.60 7828.84 93.580 336.510 3926.74 3994.90 2234.11 N 4705.81 W 6011662.70 N 546594.24 E 1.801 4992.01 7876.30 93.580 336.310 3923.77 3991.93 2277.52 N 4724.77 W 6011705.98 N 546574.99 E 0.421 5035.14 7925.85 92.900 336.870 3920.97 3989.13 2322.92 N 4744.42 W 6011751.24N 546555.02 E 1.777 5080.13 7972.67 95.010 339.370 3917.74 3985.90 2366.26 N 4761.83 W 6011794.46 N 546537.32 E 6.977 5122.06 8020.44 94.950 342.940 3913.59 3981.75 2411.29 N 4777.20 W 6011839.38 N 546521.64 E 7.446 5163.61 8068.51 95.320 346.490 3909.29 3977 .45 2457.46 N 4789.81 W 6011885.47 N 546508.70 E 7.396 5203.89 8113.57 95.070 346.450 3905.21 3973.37 2501.09 N 4800.31 W 6011929.02 N 546497.90 E 0.562 5240.89 . 8165.06 97,050 346.420 3899.77 3967.93 2550.86 N 4812.32 W 6011978.71 N 546485.55 E 3.846 5283.11 8213.42 98.790 346.040 3893.11 3961.27 2597.38 N 4823.72 W 6012025.15 N 546473.83 E 3.681 5322.71 8260.28 101.750 349.120 3884.76 3952.92 2642.40 N 4833.64 W 6012070.10 N 546463.60 E 9.040 5360.21 8310.59 103.020 349.670 3873.97 3942.13 2690.70 N 4842.69 W 6012118.34 N 546454.22 E 2.741 5399.25 8351.86 102.760 349.120 3864.76 3932.92 2730.24 N 4850.09 W 6012157.83 N 546446.55 E 1 .444 5431.21 8427.00 102.760 349.120 3848.16 3916.32 2802.21 N 4863.92 W 6012229.70 N 546432.22 E 0.000 5489.64 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 312.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8427.00ft., 28 September, 2004 - 8:55 Page 4 of 5 Dril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MP/· MP/·14PB1 Your Ref: AP/500292321470 Job No. AKZZ3214396, Surveyed: 10 August, 2004 BPXA Milne Point Unit The Bottom Hole Displacement is 5613.39n., in the Direction of 299.947° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8427.00 3916.32 2802.21 N 4863.92 W Projected Survey . Survey too/proaram for MPI-14PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 352.00 0.00 351.96 352.00 8427.00 351.96 CB-SS-GYRO 3916,32 MWD+IIFR+MS . 28 September, 2004 - 8:55 Page 50f5 DrillQuest 3.03.06.006 . AOGCC -RlJtmrDeê!lSðl' 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well MPI-14 PB2 c2.c9cf- II? 30-Sep-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDP files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,685.53' MD 7,700.00' MD 9,450.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99 Date Si Please call me at 273-3545 if you have any qu Regards, William T. Allen Survey Manager Attachment(s) DEFINITIVE . Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-14PB2 Job No. AKZZ3214396, Surveyed: 11 August, 2004 Survey Report 2004 28 September, Your Ref: API 500292321471 Surface Coordinates: 6009461.02 N, 551315.31 E (70026'11.7636" N, 149034' 53.8198" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . K? Surface Coordinates relative to Project H Reference: 1009461.02 N, 51315.31 E (Grid) Surface Coordinates relative to Structure Reference: 325.53 S, 862.60 W (True) Kelly Bushing Elevation: 68. 16ft above Mean Sea Level Kelly Bushing Elevation: 68. 16ft above Project V Reference Kelly Bushing Elevation: 68. 16ft above Structure Reference Survey Ref: svy1452 SpE!!............~-SUI'1 DRI LING SERVICES A Halliburton Company Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-14PB2 Your Ref: API 500292321471 Job No. AKZZ3214396, Surveyed: 11 August, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7685.53 88.950 336.590 3930.86 3999.02 2102.66 N 4648.99 W 6011531.64 N 546651.96 E 4863.98 Tie On Point 7700.00 89.540 336.560 3931.05 3999.21 2115.93 N 4654.74 W 6011544.88 N 546646.12 E 4.083 4877.13 Window Point 7734.08 86.600 337.350 3932.20 4000.36 2147.27 N 4668.08 W 6011576.12 N 546632.57 E 8.932 4907.99 7781.12 85.550 337.100 3935.42 4003.58 2190.54 N 4686.24 W 6011619.27 N 546614.11 E 2.294 4950.42 7828.94 85.180 336.300 3939.29 4007.45 2234.32 N 4705.10 W 6011662.91 N 546594.95 E 1.838 4993.69 . 7876.17 87.780 336.540 3942.18 4010.34 2277.52 N 4723.95 W 6011705.98 N 546575.80 E 5.528 5036.58 7923.38 87.530 336.900 3944.12 4012.28 2320.85 N 4742.59 W 6011749.18 N 546556.86 E 0.928 5079.40 7972.76 87.220 336.520 3946.38 4014.54 2366.16 N 4762.10 W 6011794.36 N 546537.04 E 0.993 5124.19 8024.75 86.790 336.450 3949.09 4017.25 2413.77 N 4782.81 W 6011841.82 N 546516.00 E 0.838 5171.41 8068.87 87.280 338.790 3951.38 4019.54 2454.51 N 4799.59 W 6011882.44 N 546498.95 E 5.412 5211.11 8120.42 87.780 343.390 3953.60 4021.76 2503.21 N 4816.27 W 6011931.04 N 546481.93 E 8.968 5256.06 8165.39 88.890 345.360 3954.91 4023.07 2546.50 N 4828.38 W 6011974.24 N 546469.52 E 5.027 5293.99 8216.08 88.700 347.480 3955.97 4024.13 2595.76 N 4840.28 W 6012023.42 N 546457.29 E 4.198 5335.76 8258.76 89.260 349.920 3956.73 4024.89 2637.60 N 4848.64 W 6012065.20 N 546448.64 E 5.865 5369.93 8305.37 89.750 351.440 3957.14 4025.30 2683.60 N 4856.19W 6012111.14 N 546440.77 E 3.426 5406.27 8356.84 92.040 352.400 3956.33 4024.49 2734.54 N 4863.42 W 6012162.04 N 546433.19 E 4.824 5445.69 8407.67 91.600 355.090 3954.72 4022.88 2785.04 N 4868.96 W 6012212.49 N 546427.31 E 5,360 5483.55 8453.36 91.850 359.320 3953.34 4021.50 2830.65 N 4871.18W 6012258.08 N 546424.77 E 9.270 5515.67 8504.62 91.920 2.480 3951.65 4019.81 2881.87 N 4870.38 W 6012309.31 N 546425.22 E 6.163 5549.29 8549.03 91 .730 5.520 3950.24 4018.40 2926.14 N 4867.28 W 6012353.60 N 546428.01 E 6.855 5576.57 8597.91 91.360 6.510 3948.92 4017.08 2974.73 N 4862.16 W 6012402.23 N 546432.80 E 2.162 5605.22 8645.51 91.170 5.900 3947.87 4016.03 3022.04 N 4857.02 W 6012449.57 N 546437.61 E 1.342 5633.00 . 8694.22 89.380 5.150 3947.64 4015.80 3070.52 N 4852.33 W 6012498.08 N 546441.97 E 3.984 5661.90 8741.35 87.840 5.120 3948.78 4016.94 3117.45 N 4848.11 W 6012545.04 N 546445.86 E 3.268 5690.12 8791.02 86.670 6.340 3951.16 4019.32 3166.81 N 4843.16 W 6012594.43 N 546450.48 E 3.401 5719.41 8837.50 86.600 5.920 3953.89 4022.05 3212.95 N 4838.20 W 6012640.60 N 546455.11 E 0.915 5746.55 8885.63 86.290 5.300 3956.87 4025.03 3260.75 N 4833.51 W 6012688.44 N 546459.48 E 1 .438 5774.99 8931.86 86.170 4.720 3959.91 4028.07 3306.71 N 4829.48 W 6012734.42 N 546463.19 E 1.279 5802.70 8980.61 90.310 6.270 3961.41 4029.57 3355.20 N 4824.81 W 6012782.94 N 546467.52 E 9.067 5831.62 9026.04 95.680 5.480 3959.04 4027.20 3400.31 N 4820.17 W 6012828.08 N 546471.86 E 11.947 5858.31 9076.93 101.610 7.170 3951.39 4019.55 3450.29 N 4814.64 W 6012878.10 N 546477.05 E 12.106 5887.58 9123.47 101.640 6.660 3942.01 4010.17 3495.55 N 4809.15 W 6012923.39 N 546482.22 E 1.075 5913.73 9173.56 100.990 6.220 3932.18 4000.34 3544.35 N 4803.64 W 6012972.24 N 546487.40 E 1.558 5942.24 9218.35 100.670 5.540 3923.77 3991.93 3588.11 N 4799.13 W 6013016.03 N 546491.60 E 1.653 5968.12 9267.30 100.430 4.780 3914.80 3982.96 3636.04 N 4794.80 W 6013063.98 N 546495.60 E 1.603 5996.92 28 September, 2004 - 8:55 Page 2 of 3 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI - MPI-14PB2 Your Ref: API 500292321471 Job No. AKZZ3214396, Surveyed: 11 August, 2004 Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9314.12 100.370 4.880 3906.35 3974.51 3681.93 N 4790.93 W 6013109.89 N 546499.16 E 9372.18 99.860 3.410 3896.16 3964.32 3738.93 N 4786.80 W 6013166.93 N 546502.90 E 9450.00 99.860 3.410 3882.83 3950.99 3815.47 N 4782.24 W 6013243.49 N 546506.93 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 311.920' (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9450.00fl., The Bottom Hole Displacement is 6117.81f1., in the Direction of 308.584' (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 7685.53 7700.00 9450.00 2102.66 N 2115.93 N 3815.47 N Tie On Point Window Point Projected Survey 3999.02 3999.21 3950.99 4648.99 W 4654.74 W 4782.24 W Survey tool program for MPI-14PB2 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 352.00 0.00 351.96 352.00 9450.00 351.96 CB-SS-GYRO (MPI-14PB1) 3950.99 MWD+IIFR+MS (MPI-14PB1) Dogleg Rate ('/100ft) 0.246 2.643 0.000 BPXA Vertical Section Comment 6024.69 6059.70 6107.44 Projected Survey . . 28 September, 2004 - 8:55 Page 3 of 3 DrillQuest 3.03.06.006 e VD4 1/ or e Winton, Please use this one instead. Pat Archey Sr. Drilling Engr. Wk.-564-5803 Cell 240-8035 ----Original Message---- From: Archey, Pat Sent: Monday, September 20, 2004 11 :00 AM To: Winton Aubert (E-mail) Subject: Surface Casing Grade correction for Milne Point Wells 14, 16, 17 & 19 (J s~ ðr1h oA.' ~o 1,.- This update is to correct the surface casing grade used in Milne Point I-Pad wells MPI-14, MPI-16, MPI-17, MPI-19. There were 3 joints of l-80 casing run at surface and K-55 from that point to TO. Change was as follows: ,o~ \ 1;;'Ç Well Hole Size Casing Size Weight Grade Coupling Winton, MPI-14 13-1/2" 10-3/4" 45.5# K-55 & l-80 BTC-M MPI-16 12-114" 9-5/8" 40# K-55 & l-80 BTC-M MPI-17 13-1/2" 10-3/4" 45.5# K-55 & l-80 BTC-M MPI-19 13-1/2" 10-3/4" 45.5# K-55 & l-80 BTC-M Please let me know if you need anything else. Pat Archey Sr. Drilling Engr. Wk.-564-5803 Cell 240-8035 Content-Type: application/ms-tnef Content-Encoding: base64 . lID~ . ~ FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. P" AVENUE, SUITE 1 00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: MPI-14 BP Exploration (Alaska) Inc. Pennit No: 204-119 Surface Location: 2348' NSL, 4055' WEL, SEC. 33, T13N, Rl OE, UM (OB) Bottomhole Location: 1328' NSL, 3465' WEL, SEe. 29, T13N,RlOE, UM (DB) Dear Mr. Archey: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the penn it in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t witness any required test. Contact the Commission's petroleum field inspector at (907) 659 6 7 ager). Since ly: BY ORDER ~MMISSION DATED thisg~¡~IY, 2004 cc: Department ofFish & Game, Habitat Section wlo encI. Department of Environmental Conservation wlo encl. .;. . STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 ~" .,J, ',' r,) fJ 4 "I, 1a. Type of work BDrill o Redrill rb. Current Well Class o Exploratory II Development Oil . MUltiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5, Bond: B Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 MPI-14 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9880' rvD 4053' Milne Point Unit I Schrader Bluff 4a. Location of Well (Governmental Section): 7. Property Designation: 'S~~M Surface: Þ.\>L 2348' NSL, 4055' WEL, SEC. 33, T13N, R10E, UM i0àS''\()l, ADL 025517 >') k()~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4311' NSL, 3362' WEL, SEC. 32, T13N. R10E, UM (OB) 07/26/04 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1328' NSL, 3465' WEL, SEC. 29, T13N, R10E, UM (OB) 2555 3600' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 551315 y- 6009461 Zone- ASP4 (Height above GL):KBE = 68' feet 1730' away from MPI-10 16. Deviated Wells: Kickoff Depth: 300' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 decrees Downhole: 1739 Surface: 1346 1ª' :"Si z~.. ..'. , '" ·iii . i' 'I'~ 10. ;; .'i'..." i Hole Casino Weiaht Grade Couolina Lenath MD rvD MD rvD {includino staae data} 42" 20" 92# H-40 Welded 109' Surface Surface 109' 109' 60 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC-M 2769' Surface Surface 2769' 2318' 71 sx PF 'L', 255 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 7531' Surface Surface 7531' 3998' 47 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 BTC 2499' 7381' 3961' 9880' 4053' Uncemented Slotted Liner 19, PR¡;S¡;NTWçLLÇONDITIONsuM~ARY(T()' be·compl~~.forR~dnnANø~~~l)tijOPêtati()"š) Total Depth MD (ft): Total Depth rvD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): ..... iY iiii ·y·y,y'%S!Z.E!ii.Y. ii.tti ·...i·i.'.,..;··i..·i.ii.i···"·i·.yi~iyt.. iP%i i.ii'·)"!;.:!,'·' iy Structural r.nnnllctnr C'. ..&. Int .. I Production I inAr Perforation Depth MD (ft): IPerfOration Depth rvD (ft): 20. Attachments B Filing Fee, $100 o BOP Sketch B Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report B Drilling Fluid Program B 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay, 564-4178 Printed Name Pat Archey Title Senior Drilling Engineer Sì nature' I'I _J /J, Phone 564-5803 Date -1 tJ Sondra Stewman. 564-4750 Permit To Drill API Number: Permit Ap r val See cover letter for Number: dO\.......\ - \ \ S. 50- ()'0S- d~(T\ 4 -CJO Date: PJY;';/pif other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Required f DYes ~o Hydrogen Sulfide Measures DYes ~o Directional Survey Required 9š Yes DNo Other: ~ ~ \3- ~ 0. <=> \> \û- "'I"-Q:~ .. ~()? -\~<.,\ \ \\~~ \ \'.C>-\ ~f~'\ \-ü~ \"--\ 'dJ1 S íJ A.,,, o.\> 'Y \C) '0 ~ n Q , h 1 t\1 A I APPROVED BY I?~~~/ ~ Aooroved Bvl :.A./ , VI..... I THE COMMISSION Date r /, U7 Form 10-401 RevrsedO ~ '-- ~bmit Iii Duplicbte I STATE OF ALASKA . ALASKA L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 ~I<, 1'1 b. Current Well Class 0 Exploratory.~J(eIopment Oil, III Mµlöple ZCíne o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: a Blanket 0 Single Well 11. Well Name and Numb~ Bond No. 2S100302630-277 MPI-1Y 6.' Proposed Depth: 'fRi.~,' I }~. Field7pOOI(S): MD 9880" rvD ~ ':;>fI Milne Point it / Schrader Bluff 7. Property Designation: 411 t·?'·"",! ,1t~91'þt ~ ADL 025517'1''1. /J'·f 8. Land Use Permit: 13. ~proximate Spud Date: / 07/26/04 9. Acres in Property: ~ 14. Distance to Nearest Property: ....2560~ z....ç;-S' '7.:;4 3600' 10. KB Elevation / 15. Distance to Nearest Well Within Pool (Height above GL):KBE = 00' feet 1730' away from MPI-10 17. Maximum Anticipated 9'fessures in psig (see 20 AAC 25.035) Downhole: 1739 '/ Surface: 1346' $~~!OgDéDt~~¡ , ,_~<__ _~c"x T()pj ", 7;;; <.8tJl oro ICT,..:S;:¡CKSI M~Th'[)/ MD rvD (jncludina staae data) Sufra I~' Surface 109' l260 sx Arctic Set (ADDrox.) SurbHI:I 2fS9' Surface 2318' 371 sx PF 'L', 255 sx Class 'G' J'753"1' Surface 3998' 747 sx Class 'G' '3S1Wó' 9880' 3961' 4053' Uncemented Slotted Liner ~YV :\ ,-.. \ ~ I h-. ì r .....,r l)Qr:¡:.;IV("\(~ 119. PRESENT WELL CONDITIQN $UMIV ~ Ic.g. it'c<:>'Opleted,forR~ôll ðNDRØ-øotrYoperati6"Ìs) Total Depth MD (ft): Total Depth TVD (ft): Plugs (c.. {.d)\tl~tive Depth MD (ft): Effective Depth rvD (ft): Junk (measured): n"'ó·i"... >.) } >"lð"Mh}} $~ø;. >}»ts».>,;';';:;;;;.,; 1.;I;,,'>1IAf"I,;;;I;'."'> ",1'\114> ,,' Ct... ~t...~ I ~_ ,'\Iiø' / r ,;)/ »V _ir....... I -..~ / "-- ,... '/ / / / III Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: "I/l>~> .It> 7'S'P" 2348' NSL,..)ð62'"WEL, SEC. 33, T13N, R10E, UM ' Top of Productive Horizon: 4311' NSL, 3362' WEL, SEC. 32, T13N, R10E, UM (OB) > Total Depth: 1328' NSL, 3465' WEL, SEC. 29, T13N, R10E, UM (OB) .. 4b. Location of Well (State Base Plan~~rdinateS): þ~ ......oj Surface: x-551315J y'~ì:{'f&1 Zone-ASP: 16. Deviated Wells: Kickoff Depth: 300" feet Maximum Hole Angle: 93 - deQrees > ,> 16. t;;:¡singprograrTI: Size Casino 20" 10-3/4" 7-5/8" 4-1/2" Hole 42" 13-1/2" 9-718" 6-314" Weiaht 92# 45.5# 29.7# 12.6# Grade H-40 L-80 L-80 L-80 CouDlina Welded BTC-M BTC-M BTC Lenath 109' 2769' 7531' 2499' C",.ç~~ð P Liner Perforation Depth MD (ft): IPerfOration Depth rvD (ft): a Drilling Program 0 Time vs Depth Plot o Seabed Report a Drilling Fluid Program o Shallow Hazard Analysis 18120 AAC 25.050 Requirements Date: Contact Walter Quay, 564-4178 20. Attachments a Filing Fee, $100 Q'bOP Sketch o Property Plat P Diverter Sketch 21. Verbal Approval: commissicf'Representative: 22. I hereby certify that the foreg9'f!g is true and correct to the best of my knowledge. Printed Name Pat Archey / Title Senior Drilling Engineer ~ 5 rz..1VJ I . /. ' ,,' " " Permit To D~~ _ " 'iÁ API Number: ð. :2.""''' ì/ / -ú^ Number: ~'-I"'I n 50- 0 z.'7 - 2-~~ or '-' Condmons of;;::pprov : Samples Required 0 Yes ~N 0 Hydrogen Sulfide Measures 0 Yes ~ No Other: s\)C) r~'1. ßa ~ \-t:s-\ GL<::;. ~\CJ..."~~ Signature Phone Prepared By Name/Number: 564-5803 Date 7/7/& c/ Sondra Stewman, 564-4750 ,'. ", , , ' , " " '. Permit Approval See cover letter for Date: other requirements Mud Log Required 0 Yes KNo Directional Survey Required~es 0 No , ADDroved Bv: Form 10-401 Revised 06/2004 APPROVED BY ,.... _ . _ I .. I . I THE COMMISSION U :-< IlJ 11'1 A L Date Submit In Duplicate . . MPI -14 Permit IWell Name: MPI-14 Drill and Complete Plan Summary 7 . . MPI -14 Permit Mud Program: 13-1/2" Surface Hole 0 - 2769' : Densit PV YP API FL H 8.6 - 9.5 10 - 25 30-50 NC-8 8.5 - 9.5 9-7/8" Intermediate Hole 2769 - 7531' : LSND Densit PV YP API FL H Chlorides MBT 9. . -- ---8 t 5 32 HUG- -8-- --9-.0-9..5___ < 1500 < 25 6-3/4" OB Production Hole 7531-- 9880' : MOBM-" Density (ppg PV YP HTHP Oil:Water Electrical Ratio Stabilit 80:20 550 - 900 LSND "'~~ "", ;) <8 9.0 15 -25 20 PV YP HTHP Oil:Water Ratio < 8 80:20 Electrical Stability 550 - 900 9.0 15 -25 20 6-3/4" NB Production Hole (6664-- 9853'): M Density (ppg PV YP HTHP Oil:Water Electrical Ratio Stability 9.0 15 -25 20 <8 80:20 550 - 900 OBM LCM Restrictions: Yes. Use CaC03 as LCM Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU IR. Cement Pro ram: Casin Size 10-3/4"45.5 Ib/tt L-80 BTC Surface Casing Lead Slurry to surface. Excess 100% over gauge hole. To of tail cement 500' MD above casin shoe. Basis Total Cement Volume: 346 bbl Wash S acer Lead Tail Tern Size 7-5/8" 29.7lb/ft L-80 BTC-M Intermediate Casin Top of lead slurry 500' MD above Ugnu sand. \..I(.~-\ ~~Q~ II-"... ?"f1 Basis To of tail slur 500' MD above TUlC. 40% excess over au e. ...../c., Total Cement Volume: 155 bbl Wash 25-bbl water 15-bbl water S acer Tail 8 . . MPI -14 Permit 13-1/2" Section Open Hole: MWD/GR IFRlCASANDRA Sperry InSite Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES IFRlCASANDRA Sperry InSite Cased Hole: N/A 6-3/4" Section Open Hole: MWD/GRlRESI ASI 'il IFRlCASANDRA Sperry InSite Cased Hole: N/A Formation Markers: Formation Tops MDrkb TVDrkb (ft) Pore Pressure (psi) Estimated EMW I (ft) (lb/gal)* BPRF W3.. , 1818.00 760 8.35 TUZC r 5207 .... lJ 3213.00 1366 8.35 U2Du-MA -s182 3448.00 1468 8.35 U2Du-MB1 5807 3458.00 1472 8.35 U~Du-MB2 5960 3518.00 1498 8.35 U2DU-MC 6412 3683.00 1570 8.35 SBF2- Top NA 6635 3763.00 1635 8.51 SBF21-Base NA 6650 3768.00 1637 8.51 SBF1-Top NB 6765 3803.00 1653 8.51 SBF12-Base NB 6841 3823.00 1662 8.51 SBE4-NC 6898 3838.00 1668 8.51 SBE2-NE 6975 3858.00 1677 8.51 SBE1-NF 7127 3898.00 1695 8.51 TSBD- Top OA 7260 3933.00 1710 8.51 TSBC-Base OA 7393 3968.00 1726 8.51 TSBB- Top OB 7531 3998.00 1739 8.51 SBA5-Base OB 4023.00 1750 8.51 ./ NB OWC 3962.00 OA OWC 4008.00 OB OWC 4068.00 9 . . MPI -14 Permit . -I OA 6.75-in NB 12.6# 7,381'/3,961' 9,880'/4,053' 2,612' 7,259'/3,933' 9,871'/3, 3,189' 6,664' 1 3,733 9,853'/3,823' Bottom MD / TVDrkb 109' /109' 2,769' / 2,318' Conn Length Top MD / TVDrkb 0' 0' L-80 Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5" 0' - 2,769' Hughes MXC 1 2 9.875" 2,769 -7,531' POC 3(OB) 6.75" 7,531 ' -9,880' Hycalog OS 146 4(OA) 6.75" 7,259' -9,873' Hyca/og OS 146 5(NB) 6.75" 6,664' -9,853' Hycalog OS 146 10 . . MPI -14 Permit Well Control: Intermediate/Production hole: · Maximum anticipated BHP: 1,739-psi @ 3,998-ft TVDrkb - TSBB-Top OB ./ · Maximum surface pressure: 1,346 psi @ surface ,/ (Based on BlIP and a full column of gas from TD @ D.l-psi/ft) · Planned BOP test pressure: 3,OOO-psi. For this well, approval is sought to change the BOP testing interval from 7 to 14 days. · Integrity test: An FIT to l1.5-lb/gal at the 1O-3/4"shoe. Kick tolerance: 67-bbl with 9.3-lb/gal mud. · Planned completion fluid: MOBM in laterals/9.8 ppg Brine/7.0-lb/gal Diesel (1 ,800-ft tvd). Mf\ltfo' \ 0\ \ DC>.<:,.Q: ~~â Drilling Hazards & Contingencies: · Hydrates have been encountered on I-Pad wells, but are not expected to be a major problem. "' Lost Circulation · We do not expect losses while drilling this well. Expected Pressures · On 2001 drilling, over-pressured Ugnu/Schrader Bluff was encountered. This was most likely caused by 1-10 injector. This well is to remain shut in while drilling. Pad Data Sheet r ' · Please Read the I-Pad Data Sheet thoroughly. Breathing · Not expected or predicted. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · Four fault intersections are prognosed for this well. These are in the Ugnu (6,460' MD), the NE (7,085' MD), OB (8,000' MD) and a second in the OB (9,200' MD). Hydrogen Sulfide ,- · MPI Pad is not designated as an H2S Pad. I-Pad wells <50-ppm H2S reported. latest . samplings: o MPI-06 o MPI-08 o MPI-15 <2 <2 <2 2/ 15/04 2/15/04 2/15/04 Anti-collision Issues · MPI-14 passes the Major Risk Criteria. The closest issue is MPI-13 at 700' with a 30' center to center distance. Distance to Nearest Property · MPI-14 is 3,600-ft from the nearest Milne Point property line. -/ Distance to Nearest Well Within Pool · MPI-14 is 1730' from the Schrader Bluff sand penetration in MPI-1 O. · 11 . . MPI -14 Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20" conductor is installed. 2. NU Diverter Drillina" ' / I 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. s MIRU Doyon 14, ND Tree/NU BOP. Function Test Diverter, PU 4" DP. ..../ . '" Drill 13.5" surface hole. \ ,/ Run and cement 10.75" surface casing. / ND diverter, install wellhead and NU/Test BOP. ~ \\ Drill 9.875" intermediate hole. ~ \>1:. -, ~ Run and cement 7-5/8" intermediate casing. ) Displace to MOBM. Drill 6-3/4" OB horizontal production hole. ) ~/ ~Iotted liner-=--_ _______-----~ Run whipstock and mill ~Aíãteral. Drill 6-3/4" OA horizontal production hole. Retrieve whipstock. Run 4.5" slotted liner and hang off in 7.625" casing Run whipstock and mill window for NB lateral. Drill 6-3/4"~ h~izontal production hole. Retrieve whip~OCk. S~ \\ë:.\--\ "/<;-0'-\ Run 4.5" screens completion liner and hang off in 7.625" casing Displace MOBM with Brine RU and Run 2.875" ESP Completion. ND BOP/NU Tree Freeze Protect. RDMO Doyon 14. 12 . MPI-14 Proposed 9.2 PPG Versapro MOBM below Completion Baker ZXP Liner Top Packer Flexlock Hanger@ -7,40 MD DATE REV. BY 06/14/2004 W. Quay . TREE: 2-9/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M Tubing Head: FMC 11" X 2.875" I Orig KB elev (0-14) = 69' I 109' Cameo 2 7/8" x 1" side pocket KBMM GLM -150' 2-7/8" 6.5 ppf, L-80, EVE production tubing (Drift 10 = 2.347", cap = 0.00579 bpf) Camco 2 7/8" x 1" sidepocket KBMM GLM 2 Jts above ESP 27/8" XN Nipple. 1 Jt above ESP Centrilift ESP Centrilift Tandem Gas Separator Centrilift Tandem Seal Section CenbiJift Motor 140 HP KMH-A 2244 Volt 37 Amp PumpMate & Centralizer 10-314",45.5# L-80 BTC Csg Casing ID 9.950" Casing Drift 9.794" Baker ZXP Liner Top Packer & Hanger @ 5,xxx' MD Baker Hookwall Hanger Window in 7-5/8" casing@ 6,664' MD Well Inclination @ Window = 70° Swell Packer @ -6,700' MD Baker Flexlock Liner Hanger Baker ZXP Liner Top Packer & Hanger @ 5,750' MD 16.664'- 9.853'1 6-3/4" NB Lateral Baker Hookwall Hanger Window in 7-5/8" casing@ 7,259' M Well Inclination @ Window = 75° COMME Proposed Trilateral Milne Point WELL: 1-14 API NO: 50-029- 50-029- 50-029- I _GRID\ - IIII¡ J 2'34'41" I I-PAD PLANT) . +14 .13 .12 .11 .8 .7 .4 .6 .3 .5 .2 .9 .1 .10 34 AREA VICINITY MAP N.T.S. LEGEND +- AS-BUILT CONDUCTOR MPU I-PAD . EXISTING CONDUCTOR NOTES 1. DATE OF SURVEY: DECEMBER 16, 2001 2. REFERENCE FIELD BOOK: MP01-08 PAGE 4. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.9999031 5. HORIZONTAL CONTROL IS BASED ON J MPU I-PAD MONUMENTS 1-1 AND 1-2, 6. ELEVATIONS SHOWN ARE MPU DATUM. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 17, 2001. LOCATED WITHIN PROTRACTED SEC. 33, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL ASP. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(OMS) POSITION(D.DO) BOX ELEV. OFFSETS .i Y= 6,009,461.02 N 1,120.14 70'26'11.764" 70.4366010' 34.8' 2348' FSL 1. 14.,.X= 551,315.31 E 1,020.23 149"34'53.820" 149.5816166" 4055' FEL ;/ ¡/ it DRAWN" Obp COTTON CHECKED DAD OAT£: 12 17/01 DRAVv1NG: FReOI MPI 08-01 MPU I-PAD SHEET, i ff]~rnœo JOB NO SCÞo.l( AS-BUlL T CONDUCTOR 0 2 1 7 0 ISSUE FOR INFORMATION JJC DAD ÞIOIJCtM ourIO lAlilO fiIM\IC'IOM WELL 1-14 1 <:IF 1 10, «Sf rw:IIIŒO tN<( 1':150'± NO. OAtE R(\o1SION BY CHI( irHO!OItAG(. .0(."$1(" !l9S(1J COMPANY DETAILS BP Amooo Calculation Method: Minitnwn Curvature Error System: 1SCWSA Scan Method: Tra." Cylinder NoM ErrorSurfa(:e: EIJiptica]"'Casing Warning Method: Ru]es Based bp o 80 ¡COlli i\ " '2.' \ 160 -= ~ 8 ~ .¡;¡ ! .-- '" " '€ ~ 240 .. 'v <: I- 320 1-' I: 400 o REFERENCE lNFORMA TION Co-ordinate(N'E)Reference: WeIlCentre:PlanMPI·140di11, True North Vertical (TVD) Refetencc: 68.00 68.00 Scctiòn (VS) Refermce: Slot· (O.OON.O.ooE) Measu~~~~~er;::t ~:mum~ture SURVEY PROGRAM Depth Fm Depth To SurveylPlan 33.00 ]000.00 Planned: MPI~14 WPI6 V41 1001100 9880.1 1 Planned: MPI·14 WP16 V4 Datc:_ Date:_ CASING DETAILS No. TVD MD Name 2318.00 2769.17 10314" 3998.00 7531.25 7-5/8" 4053.00 9880.00 41/2" 0$ - Stan Die 1.5/100' : 300' MD, 300"TVD ,.. _____ Start Die 2.5/100'. þ~StanDie31l00' 600' MD, 599.69TVD 800' MD, 798.66'TVD , " I 13/4" ,,',' .. c' I End Die : 19G0'MD,1792.7'TVD Size No. TVDPath MDPath Formation FORMATION TOP DETAILS 10.750 7.625 4.500 - Stan Die4/tOO': 2040.28' MD, 19()()"TVD / ~ . 00 800 EndDir : 276L45'MD,2315.2I'TVD ! , , --~ .--. IUgmi-M - -~ -- - 1600 I 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 1818.00 3213.00 3448.00 3458.00 3518.00 3683.00 3163.00 3168.00 3803.00 3823.00 3838.00 3858.00 3898.00 3933 00 3968.00 3998.00 3555.96 3887.06 4006.51 4053.44 1933.08 BPRF 5207.09 TUZC 5782.05 Ugnu-MA 5807.08 Ugnu-MBI 5960.06 Ugnu-MB2 6411.80 Ugnu-MC 6635.19 SBF2- Top NA 6649.68 SBF21-Base NA 6765.49 SBFI-Top NB 6841.46 SBFI2-Base NB 6898.49 SBE4-NC 6914.53 SBE2-NE 7126.60 SBEI-NF 7259 67 TSBD- Top OA 7392.78 TSBC-Base OA 7531.25 TSBB- Top OB 6060.00 Fault #1 7085.00 Fault #2 8000.00 FBUIt #3 9200.00 Fault #4 Start Die4/100': 4732.09' MD, 3028.83'TVD ..¡j / -"-~-- --. 153f r Bæ A ....lsJ¡ti -TbP Ii' + SE 12; ,.¡ , :... ff:j::::: =:¡= -- --- ,,- 2400 , I .-- __'j' L+ ,[ ".., --(FI';! i/l-t -t-r-:r 'f..... @- Plan: MPI·14 WPI6 (Plan MPJ·14 OdinlMPJ-14) Too' C8.QYRo-MS MW[}-I-JFR+MS Date: 4/24/2004 _.. Created By: Troy Jakabosky Checked: Reviewed: WELL DETAILS ...,. +N/-S ...Ef-W Ncrthing ....... Lafitude Longitude Slo< Plan MP!·14 Odin 1065.7$ 1076.55 6009460.88 551315.07 7O"16'11.762N 149"34'53.827W "'A TARGET DETAILS """" 1VD -f'N/·S +EI·W - ...... Shope MPI_14 Faultf¡ll 3703.00 1337.00 ·5481.53 6010760.00 54S825.OO Polygon MPI-14TI 3803.00 1295.70 ...4275.67 6010727.00 547031.00 Poi~ MPI-14F,ult#2 3888.00 1567.30 .4794.87 6010995.00 S46S I 0.00 Polygon MPI·14 T2 8 3998.00 1965.00 .4592.00 6011394.05 546710.11 Poi,. MPJ·1411 B 4008.00 2340.00 -4749.00 6011767.93 546550.54 Point MPI·14 Oeo Poly 4008.00 1249.94 -4457.01 60]0680.00 546850.00 PoI_ MPI-14Fault#3 4008,00 2466.87 ·5443.15 6011890.00 545855.00 Polygoa MPI-14 T5 B 4033.00 3249.54 480029 6012677.00 546493.00 Point MPI-14T4 4033.00 2887.74 -4835.78 6012315.00 _.00 Poiø: MPI·141i 4OS3.OO 4261.98 -470131 6013690.00 546385.00 Point MP!-14 Fault #4 4053.00 3625.20 .5180.75 6OIJD50.00 546110.00 Polyaort MP!-14T6 4058.00 3711.29 -4155.01 6013145.00 546535.00 Poi", SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 330.00 300.00 0.00 0.00 0.00 330.00 0.00 3 600.00 4.51 330.00 599.69 10.22 -5.90 1.50 330.00 11.24 4 800.00 7.47 289.20 798.66 21.31 -22.12 2.50 283.34 30.70 5 1180.00 18.48 275.00 1168.47 34.73 -105.12 3.00 336.80 101.65 6 1900.00 40.10 275.00 1792.70 65.25 -454.55 3.00 0.00 380.58 7 2040.28 40.10 275.00 1900.00 73.12 -544.56 0.00 0.00 452.56 8 2761.45 68.77 270.96 2315.21 99.55 -1124.30 4.00 -7.82 899.83 9 4732.09 68.77 270.96 3028.83 130.30 -2960.93 0.00 0.00 2281.20 10 6180.19 69.00 333.50 3600.00 805.00 -4030.00 4.00 102.14 3526.40 11 6621.82 69.00 333.50 3758.27 1173.98 -4213.97 0.00 0.00 3910.52 12 6765.49 74.70 332.75 3803.00 1295.70 -4275.67 4_00 -7.28 4037.99 MPI-14 Tl 13 6808.13 74.75 334.51 3814.23 1332.55 -4293.94 4.00 88.60 4076.27 14 7386.68 74.75 334.51 3966.41 1836.41 -4534.13 0.00 0.00 4592.64 15 7531.25 80.00 337.00 3998.00 1965.00 -4592.00 4.00 25.09 4721.88 MPI-14 T2 B 16 7581.25 80.00 337.00 4006.68 2010.33 -4611.24 0.00 0.00 4766.58 17 7765.74 93.15 334.47 4017.67 2177.82 -4686.77 7.26 -10.96 4935.03 18 7789.85 93.15 334.47 4016.35 2199.55 -4697.15 0.00 0.00 4957.31 19 7940.02 93.20 345.00 4008.00 2340.00 -4749.00 7.00 89.46 5090.06 MPI-14 T3 B 20 8076.38 85.13 346.33 4009.99 2471.99 -4782.73 6.00 170.66 5203.71 21 8193.32 85.13 346.33 4019.92 2585.21 -4810.27 0.00 0.00 5300.15 22 8498.50 90.00 4.00 4033.00 2887.74 -4835.78 6.00 75.07 5522.24 MPI-14 T4 23 8527.60 90.43 5.69 4032.89 2916.73 -4833.33 6.00 75.60 5539.89 24 8775.01 90.43 5.69 4031.02 3162.91 -4808.80 0.00 0.00 5687.07 25 8862.09 86.95 5.52 4033.00 3249.54 -4800.29 4.00 -177.23 5738.95 MPI-14 T5 B 26 8872.82 86.53 5.53 4033.61 3260.21 -4799.26 4.00 179.64 5745.35 27 9232.80 86.53 5.53 4055.43 3617.85 -4764.66 0.00 0.00 5959.93 28 9332.7S 90.52 5.50 4058.00 3717.29 -4755.07 4.00 -0.36 6019.60 MPI-14 T6 29 9336.16 90.52 5.64 4057.97 3720.68 -4754.74 4.00 90.00 6021.64 30 .. 9880.11 90.52 5.64 4053.00 4261.98 -4701.31 0.00 0.00 6345.62 MPI-14 T7 ,- End Die: 6180.19' MD, 3600' TVD Start Die 4/1 00' : 6621.82' MD, 37S8.27'TVD End Die: 6808.13' MD, 3814.23' TVD Start Die 41100' : 7386.68' MD, 3966.4I'TVD End Die: 7531.25' MD. 3998' TVD Stan Die 7.26/100': 7581.25' MD, 4006.68'TVD End Die: 7765.74' MD, 4017.67' TVD Start Die 7/100': 7789.85' MD, 4016.35"TVD Start Die 6/100': 7940.02' MD, 4008"TVD End Die: 8076.38' MD, 4009.99' TVD Start Dir6/IOO': 8193.32' MD, 40 I 9.92"TVD End Die : 8527.6' MD. 4032.89' TVD Start Die4?/l00': 8775.01' MD, 4031.02'TVD , , End Die : 8872.82' MD, 4033.61' TVD J-r/ßt1g ¡1.~3~~,3i J;:~~~5g:~~D l -fr¡ _- __:::u :- t¡ta~ï5lpif9880.tI'MD,4OS3'TVD :/.. " ,1/ ::: ::/1;:':4 i:2" ...... -..- -~=lt_r~/¡- ~ttt ~ ,__ ~ II.. lLl --- -,--- -- 1 1- - , ._- j '·!/u . ,1j17'f 1 -M- -1- <>0 J\ Ug'O( U _u_ --!- Fa t - -- -.- " / ,.¡j 11 - - :..+=: --. --. __ __ _~_I!.~ :~f_Sf!D TS\P.IÞ, ___ _ ,__ __::+- U 75 -- -- -- -'jn -T ml õpp n -¡f ;11 ---- 3200 4000 Vertical Section at 312.19' [800ft/in] - -- . - ~r'''' WPl6 - - -1-' ,.. 'R --a--~- --/sf- 4800 5600 I 7200 6400 Plan: MPI-}4 WPt6 (Plan MPI-4 Odil1lMpr·4) Tool Created By: Troy Jakabosky Dale: 4/24/2Q04 CB<iYRQ-MS Checked: Date:--,--- MWD+fFR+MS " . ~ WELL DETAILS ""'" +N'.s +E/·W -"" Eastin¡ Latitude Longitude Slot Pian MPI-J4 Odin tOO: 1076: 600>460.'88 551315.07 70"26'11.762N 149°34'53.827W N'^ SURVEY PROGRAM Depth Fm Depth To SUrJ¡:ylPlan 33.00 1000.00 Planned: MPJ.l4 WPI6 V41 1000.00 988ß.1I P1anoed: MPI-14 WPI6 V41 - FORMATION TOP DETAILS REFERENCE INfORMATION Co.ordinate (NÆ) Reference; Well Centte; PIM MPI-14 Odin. Troe North Vertical (TVO) RefeRnCe; 68.00 68.00 Scçtion (VS) Refererx:e; Slot - (O.OON,O.OOE) M~~~e=~~ COMPANY DETAILS BP^"""" Qlculatioo Method; Minìm\im Curvature =,t~ ~~v~~íkrNonh ErrorSurfaœ: ElJiptical....~ watnins MedJod; Ru1cII Baøød Targe MPI-14TI MPI-14 T2 B MPI-14 T3 B MPI-14 T4 MPI-14 T5 B MPI-]4 T6 MPI-14 T7 So..pe ~ ~on 1ð. 0 'fI Pomt ~ ~ .D Po1ygon Po~ygon Pomt ;:;. __ .,-::D Po~ygon ---- Pomt VSee 0.00 0.00 11.24 30.70 101.65 380.58 452.56 899.83 2281.20 3526.40 3910.52 4037.99 4076.27 4592.64 4721.88 4766.58 4935.03 4957.31 5090.06 5203.71 5300.15 5522.24 5539.89 5687.07 5738.95 5745.35 5959.93 6019.60 6021.64 6345.62 TFaee 0.00 330.00 330.00 283.34 336.80 0.00 0.00 -7.82 0.00 102.14 0.00 -7.28 88.60 0.00 25.09 0.00 -10.96 0.00 89.46 170.66 0.00 75.07 75.60 0.00 77.23 79.64 0.00 -0.36 90.00 0.00 EaSling 545825.00 S47031.00 546510.00 546710.H 546550.54 546850.00 545855.00 546493.00 546460.00 546585.00 546110.00 546535.00 DLeg 0.00 0.00 1.50 2.50 3.00 3.00 0.00 4.00 0.00 4.00 0.00 4.00 4.00 0.00 4.00 0.00 7.26 0.00 7.00 6.00 0.00 6.00 6.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 -"'. 60(0760.00 6010721.00 601099S.00 6011394.05 6011767.93 6Q1068Q.OO 6011890.00 6Q12677.oo 6012315.00 6011690.00 6QBOSQ.OO 6013145.00 SECTION DETAILS +N/-S TARGET DETAILS +E/-W +E/-W 0.00 0.00 -5.90 -22.12 -105.72 -454.55 -544.56 -1124.30 -2960.93 -4030.00 -4213.97 -4275.67 -4293.94 -4534.13 -4592.00 -4611.24 -4686.77 -4697.15 -4749.00 -4782.73 -4810.27 -4835.78 -4833.33 -4808.80 -4800.29 -4799.26 -4764.66 -4755.07 -4754.74 -4701.31 -5481.53 -4275.67 4794.87 ......,,00 4749.00 4457.01 _5443.75 4800.29 -4835.78 -470131 .5180.75 -4755.07 0.00 0.00 10.22 21.31 34.73 65.25 73.12 99.55 ]30.30 805.00 1173.98 1295.70 1332.55 1836.41 1965.00 2010.33 2177.82 2199.55 2340.00 2471.99 2585.21 2887.74 2916.73 3162.91 3249.54 3260.21 3617.85 3717.29 3720.68 4261.98 +N'.s 1337.00 tm.70 tS67.30 19M.OO 2340.00 1249.94 2466.87 1249.54 2887.74 4261.98 362520 3717.29 TVD 1703.00 3803.00 3888.00 3998:00 _,00 _.00 _.00 4033.00 4OJ3.OQ 4053.00 4053.00 4058.00 TVD 33.00 300.00 599.69 798.66 1168.47 1792.70 1900.00 2315.21 3028.83 3600.00 3758.27 3803.00 3814.23 3966.41 3998.00 4006.68 4017.67 4016.35 4008.00 4009.99 4019.92 4033.00 4032.89 4031.02 4033.00 4033.61 4055.43 4058.00 4057.97 4053.00 ""'" MPI-J4 Fault #2 MP¡·l...r2"Ð MPI-14 T1 B MPI-J4 Goo Poly MPI-14Fault#3 MP!-14 TS B MPI-1414 MPl"t4 T7 MP[-!4 Fault #4 MPJ-14T6 Azi 0.00 330.00 330.00 289.20 275.00 275.00 275.00 270.96 270.96 333.50 333.50 332.75 334.51 334.51 337.00 337.00 334.47 334.4 7 345.00 346.33 346.33 4.00 5.69 5.69 5.52 5.53 5.53 5.50 5.64 5.64 Ine 0.00 0.00 4.51 7.47 18.48 40.10 40.10 68.77 68.77 69.00 69.00 74.70 74.75 74.75 80.00 80.00 93.15 93.15 93.20 85.13 85.13 90.00 90.43 90.43 86.95 86.53 86.53 90.52 90.52 90.52 MD 33.00 300.00 600.00 800.00 1180.00 1900.00 2040.28 2761.45 4732.09 6180.19 6621. 82 6765.49 6808.13 7386.68 7531.25 7581.25 7765.74 7789.85 7940.02 8076.38 8193.32 8498.50 8527.60 8775.0 I 8862.09 8872.82 9232.80 9332.75 9336.16 9880.11 See I 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 Formation BPRF TUlC Ugnu-MA Ugnu-MBl Ugnu-MB2 Ugnu-MC SBF2- Top NA SBF21-Base NA SBF]-TopNB SBF12-Base NB SBE4-NC SBE2-NE SBEI-NF TSBD-TopOA TSBC-Base OA TSBB;.11óP'Oa- Fault #1 Fault #2 Fault #3 Fault #4 MDPath 1933.08 5207.09 5782.05 5807.08 5960.06 6411.80 6635.19 6649.68 6765.49 6841.46 6898.49 6974.53 7126.60 7259.67 7392.78 7531.25 6060.00 7085.00 8000.00 9200.00 No. TVDPath 1818.00 3213.00 3448.00 3458.00 3518.00 3683.00 3763.00 3768.00 3803.00 3823.00 3838.00 3858.00 3898.00 3933.00 3968.00 3998.00 3555.96 3887.06 4006.51 4053.44 J ~'r!l?J:>ir : 8527.6' MD, 4032.89' TVD :lTStart Dir 6/100': 8193.32' MD, 40 I 9.92'TVD bp o TVD 4057.97' TVD JIE ~~F -:- ~~I~f~eptl1 : 9880. I l' MD, 4053' .LEnd Dir : 9336.16' MD. ~-~--- -:J +1 ~ If i .~ ,- t """ 11--,· -J-T= + I - :~¡Ià; 480 1 r"-4 r: 320' f I t ï 4006.68TVD ->r-¡ -,-~---~,- End Pir : 7531.25' MD, 3998' TVD -LLIC- r Start Dir4/100': 7386.68' MD, 3966.4ITVD : 8076.38' MD. 4009.99' TVD Start Dir 6/100' : 7940.02' MD, 4008TVD __ Start Dir 7/100' : 7789.85' MD, 4016.35'TVD +- End Dir : 7765.74' MD, 4017.67 TVD .,-- Start Dir 7.26/100': 7581.25' MD, ::tdDir n··V I ~ ,- 'I - t tr·,,· t I ¡ ---i c ~ 8 ~ .t- i§ 240 ~ ~ .:: :; o '" II ,,' Do, ,'''''''' MD, m','''''''' End Dir : 2761.45' MD, 2315.21' TVD \J I f I ,i, Start Dir4/Ioo': 6621.82' ~D, 3758.2~TVD I Start Pir 4/1 00' : 2040.28' MD, \ 900TVD End Dir : 1900' MD, 1792.7' TVD -' - -, ~_.p EndP.. :6180.19 MD,3600 TVD I Start Dir 4/100' : 4732.09' MD, 3028.83'TVD § ,1 4 r 60 Size 10.750 7.625 4.500 Start Dir 3/1 00' : 800' MD, 798.66TVD !' ,,~tar,tr¡ir~.51\00': 600' MD, 599.69'TVD ~ftaft firJ.5/IOO': 300' MD, 300TVD "¡II+I .[ ~ r · i ~-- L'\~ i It ~t! l CASING DETAILS 12~Od.-rrr5rOll~T1 i o. TVD MD Name , I I I 2318.00 2769.17 103/4" 3998.00 7531.25 7-5/8" -800 0 4053.00 9880.00 4 1/2" 12~ -2400 -1600 West(-YEast(+) [800ft/in] ttt I - I L jn ::[, ~ /~ II dtt -3200 ,,~ m TJ+~ Mff{4jftª1: f11~~1'Tl~FLL78f ·"Hlln,u[ I' II, I, t H4iF It#~ I·II~F Ill'Ij4I'a~It#1 l l j--- - - 80' -4000 -.' -4800 -5600 . . Halliburton Company BP Planning Report Company: BP Amoco Date: 4/24/2004 Time: 12:06:29 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPJ-14 Odin. True North Site: MPtlPad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N,0.00E,312.19Azi) Wellpath: MPI-14 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: MPI-14 WP16 Date Composed: 3/29/2004 Version: 41 Principal: Yes Tied-to: From Well Ref. Point Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2003 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6008388.01 ft Latitude: 70 26 1.282 N From: Map Easting: 550245.83 ft Longitude: 149 35 25.422 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.39 deg Well: Plan MPI-14 Odin Slot Name: Well Position: +N/-S 1065.75 ft Northing: 6009460.88 ft ." Latitude: 70 26 11.762 N +EI-W 1076.55 ft Easting : 551315.07 ftf Longitude: 149 34 53.827 W Position Uncertainty: 0.00 ft Wellpath: MPI-14 Drilled From: Well Ref. Point TÌI;-on Depth: 33.00 ft Current Datum: 68.00 Height 68.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/17/2004 Declination: 24.89 deg Field Strength: 57555 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.00 0.00 0.00 312.19 Plan Section Information MD Ind Azim TVD +N/-S +EI-W DLS Build Turn TFO Target ., ft deg deg ft ft ft deg/100ft degl100ft deg/100ft deg 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 330.00 300.00 0.00 0.00 0.00 0.00 0.00 330.00 600.00 4.51 330.00 599.69 10.22 -5.90 1.50 1.50 0.00 330.00 800.00 7.47 289.20 798.66 21.31 -22.12 2.50 1.48 -20.40 283.34 1180.00 18.48 275.00 1168.47 34.73 -105.72 3.00 2.90 -3.74 336.80 1900.00 40.10 275.00 1792.70 65.25 -454.55 3.00 3.00 0.00 0.00 2040.28 40.10 275.00 1900.00 73.12 -544.56 0.00 0.00 0.00 0.00 2761.45 68.77 270.96 2315.21 99.55 -1124.30 4.00 3.98 -0.56 -7.82 4732.09 68.77 270.96 3028.83 130.30 -2960.93 0.00 0.00 0.00 0.00 6180.19 69.00 333.50 3600.00 805.00 -4030.00 4.00 0.02 4.32 102.14 6621.82 69.00 333.50 3758.27 1173.98 -4213.97 0.00 0.02 4.32 0.00 6765.49 74.70 332.75 3803.00 1295.70 -4275.67 4.00 3.97 -0.52 -7.28 MPI-14 T1 6808.13 74.75 334.51 3814.23 1332.55 -4293.94 4.00 0.11 4.14 88.60 7386.68 74.75 334.51 3966.41 1836.41 -4534.13 0.00 0.00 0.00 0.00 7531.25 80.00 337.00 3998.00 1965.00 -4592.00 4.00 3.63 1.72 25.09 MPI-14 T2 B 7581.25 80.00 337.00 4006.68 2010.33 -4611.24 0.00 0.00 0.00 0.00 7765.74 93.15 334.47 4017.67 2177.82 -4686.77 7.26 7.13 -1.37 -10.96 7789.85 93.15 334.47 4016.35 2199.55 -4697.15 0.00 0.00 0.00 0.00 7940.02 93.20 345.00 4008.00 2340.00 -4749.00 7.00 0.03 7.01 89.46 MPI-14 T3 B 8076.38 85.13 346.33 4009.99 2471.99 -4782.73 6.00 -5.92 0.97 170.66 8193.32 85.13 346.33 4019.92 2585.21 -4810.27 0.00 0.00 0.00 0.00 8498.50 90.00 4.00 4033.00 2887.74 -4835.78 6.00 1-60 5.79 75.07 MPI-14 T4 8527.60 90.43 5.69 4032.89 2916.73 -4833.33 6.00 1.49 5.81 75.60 8775.01 90.43 5.69 4031.02 3162.91 -4808.80 0.00 0.00 0.00 0.00 8862.09 86.95 5.52 4033.00 3249.54 -4800.29 4.00 -4.00 -0.19 -177.23 MPI-14 T5 B 8872.82 86.53 5.53 4033.61 3260.21 -4799.26 4.00 -4.00 0.03 179.64 9232.80 86.53 5.53 4055.43 3617.85 -4764.66 0.00 0.00 0.00 0.00 9332.75 90.52 5.50 4058.00 3717.29 -4755.07 4.00 4.00 -0.03 -0.36 MPI-14 T6 9336.16 90.52 5.64 4057.97 3720.68 -4754.74 4.00 0.00 4.00 90.00 · . Halliburton Company BP Planning Report Company: BP Amoco Date: 4/24/2004 Time: 12:06:29 Page: 2 Field: Milne Point ClHlrdinate(NE) Reference: Well: Plan MPI-14 Odin, True North Site: M pt I Pad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N,O.00E,312.19Azi) Wellpath: MPI-14 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E!-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10Oft deg/100ft deg/10Oft deg 9880.11 90.52 5.64 4053.00 4261.98 -4701.31 0.00 0.00 0.00 0.00 MPI-14 T7 Casing Points MD TVD Diameter Hole Size Name ft ft in in 2769.17 2318.00 10.750 13.500 103/4" 7531.25 3998.00 7.625 9.875 7-5/8" 9880.00 4053.00 4.500 6.750 4 1/2" Formations MD TVD Formaûons Lithology Dip Angle Dip Direetion ft ft deg deg 1933.08 1818.00 BPRF 0.00 0.00 5207.09 3213.00 TUZC 0.00 0.00 5782_05 3448.00 Ugnu-MA 0.00 0.00 5807.08 3458.00 Ugnu-MB1 0.00 0.00 5960.06 3518.00 Ugnu-MB2 0.00 0.00 6411.80 3683.00 Ugnu-MC 0.00 0.00 6635.19 3763.00 SBF2-Top NA 0.00 0.00 6649.68 3768.00 SBF21-Base NA 0.00 0.00 6765.49 3803.00 SBF1-Top NB 0.00 0.00 6841.46 3823.00 SBF12-Base NB 0.00 0.00 6898.49 3838.00 SBE4-NC 0.00 0.00 6974.53 3858.00 SBE2-NE 0.00 0.00 7126.60 3898.00 SBE1-NF 0.00 0.00 7259.67 3933.00 TSBD-Top OA 0.00 0.00 7392.78 3968.00 TSBC-Base OA 0.00 0.00 7531.25 3998.00 TSBB-Top OB 0.00 0.00 6060.00 3555.96 Fault #1 0.00 0.00 7085.00 3887.06 Fault #2 0.00 0.00 8000.00 4006.51 Fault #3 0.00 0.00 9200.00 4053.44 Fault #4 0.00 0.00 Targets Map Map <G-- Latitude ---> <-Longitude -> Name Description TVD +N/-S +E!-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft MPI-14 Fault#1 3703.00 1337.00 -5481.53 6010760.00 545825.00 70 26 24.891 N 149 37 34.730 W -Polygon 1 3703.00 1337.00 -5481.53 6010760.00 545825.00 70 26 24.891 N 149 37 34.730 W -Polygon 2 3703.00 993.19 -2753.57 6010435.00 548555.00 70 26 21.525 N 149 36 14.650 W MPI-14 T1 3803.00 1295.70 -4275.67 6010727.00 547031.00 70 26 24.493 N 149 36 59.333 W MPI-14 Fault #2 3888.00 1567.30 -4794.87 6010995.00 546510.00 70 2627.161 N 149 37 14.578 W -Polygon 1 3888.00 1567.30 -4794.87 6010995.00 546510.00 70 2627.161 N 149 37 14.578 W -Polygon 2 3888.00 1559.11 -3604.78 6010995.00 547700.00 70 26 27.087 N 149 36 39.643 W MPI-14 T2 B 3998.00 1965.00 -4592.00 6011394.05 546710.11 70 26 31.074 N 149 37 8.630 W MPI-14 T3 8 4008.00 2340.00 -4749.00 6011767.93 546550.54 70 26 34.761 N 149 37 13_246 W MPI-14 Geo Poly 4008.00 1249.94 -4457.01 6010680.00 546850.00 70 26 24.042 N 149 37 4.655 W -Polygon 1 4008.00 1249.94 -4457.01 6010680.00 546850.00 70 26 24.042 N 149 37 4.655 W -Polygon 2 4008.00 1237.01 -4032.05 6010670.00 547275.00 70 26 23.917 N 149 3652.180 W -Polygon 3 4008.00 2475.58 -4528.58 6011905.00 546770.00 70 26 36.095 N 149 37 6.777 W -Polygon 4 4008.00 2906.23 -4615.63 6012335.00 546680.00 70 26 40.330 N 149 37 9.341 W -Polygon 5 4008.00 4300.54 -4491.02 6013730.00 546795.00 70 26 54.044 N 149 37 5.707 W -Polygon 6 4008.00 4308.95 -4841.01 6013736.00 546445.00 70 2654.124 N 149 37 15.985 W -Polygon 7 4008.00 2878.91 -5005.87 6012305.00 546290.00 70 26 40.059 N 149 37 20.798 W -Polygon 8 4008.00 2473.43 -4943.65 6011900.00 546355.00 70 26 36.072 N 149 37 18.963 W -Polygon 9 4008.00 1249.94 -4457.01 6010680.00 546850.00 70 26 24.042 N 149 37 4.655 W - . . Halliburton Company BP Planning Report Company: BP Amoco Date: 4/24/2004 Time: 12:06:29 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Site: M Pt I Pad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.OON,O.00E,312.19Azi) Wellpath: MPI-14 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude ---> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPI-14 Fault #3 4008.00 2466.87 -5443.75 6011890.00 545855.00 70 26 36.004 N 149 37 33.645 W -Polygon 1 4008.00 2466.87 -5443.75 6011890.00 545855.00 70 26 36.004 N 149 37 33.645 W -Polygon 2 4008.00 2402.33 -4784.12 6011830.00 546515.00 70 26 35.374 N 149 37 14.278 W -Polygon 3 4008.00 2067.42 -4076.34 6011500.00 547225.00 70 26 32.084 N 149 3653.494 W MPI-14 T5 B 4033.00 3249.54 -4800.29 6012677.00 546493.00 70 26 43.706 N 149 37 14.769 W MPI-14 T4 4033.00 2887.74 -4835.78 6012315.00 546460.00 70 26 40.147 N 149 37 15.804 W MPI-14 T7 4053.00 4261.98 -4701.31 6013690.00 546585.00 70 26 53.663 N 149 37 11.882 W MPI-14 Fault #4 4053.00 3625.20 -5180.75 6013050.00 546110.00 70 2647.398 N 149 37 25.947 W -Polygon 1 4053.00 3625.20 -5180.75 6013050.00 546110.00 70 26 47.398 N 149 37 25.947 W -Polygon 2 4053.00 3357.58 -4077.46 6012790.00 547215.00 70 26 44.772 N 149 3653.548 W MPI-14 T6 4058.00 3717.29 -4755.07 6013145.00 546535.00 70 26 48.306 N 149 37 13.450 W Survey MD Incl Azim TVD N/S E/W LLEW LLNS Tool/Comment ft deg deg ft ft ft ft ft 33.00 0.00 0.00 33.00 0.00 0.00 -1076.55 -1065.75 CB-GYRO-MS 100.00 0.00 330.00 100.00 0.00 0.00 -1076.55 -1065.75 CB-GYRO-MS 200.00 0.00 330.00 200.00 0.00 0.00 -1076.55 -1065.75 CB-GYRO-MS 300.00 0.00 330.00 300.00 0.00 0.00 -1076.55 -1065.75 CB-GYRO-MS 400.00 1.50 330.00 399_99 1.14 -0.66 -1075.89 -1066.88 CB-GYRO-MS 500.00 3.01 330.00 499.91 4.54 -2.62 -1073.92 -1070.29 CB-GYRO-MS 600.00 4.51 330.00 599.69 10.22 -5.90 -1070.65 -1075_97 CB-GYRO-MS 700.00 5.64 304.37 699.31 16.40 -11.92 -1064.62 -1082.15 CB-GYRO-MS 800.00 7.47 289.20 798.66 21.31 -22.12 -1054.43 -1087.06 CB-GYRO-MS 900.00 10.29 282.58 897.45 25.40 -36.98 -1039.57 -1091.14 CB-GYRO-MS 1000.00 13.19 278.82 995.35 29.09 -56.97 -1019.57 -1094.84 MWD+IFR+MS 1100.00 16.12 276.39 1092.09 32.39 -82.05 -994.50 -1098.13 MWD+IFR+MS 1180.00 18.48 275.00 1168.47 34.73 -105.72 -970.83 -1100.48 MWD+IFR+MS 1200.00 19.08 275.00 1187.40 35.29 -112.13 -964.41 -1101.04 MWD+IFR+MS 1300.00 22.08 275.00 1281.01 38.35 -147.15 -929.40 -1104.10 MWD+IFR+MS 1400.00 25.09 275.00 1372.64 41.84 -187.00 -889.54 -1107.59 MWD+IFR+MS 1500.00 28.09 275.00 1462.06 45.74 -231.58 -844.96 -1111.49 MWD+IFR+MS 1600.00 31.09 275.00 1549.01 50.04 -280.77 -795.78 -1115.79 MWD+IFR+MS 1700.00 34.09 275.00 1633.25 54.74 -334.43 -742.12 -1120.48 MWD+IFR+MS 1800.00 37.10 275.00 1714.55 59.81 -392.40 -684.14 -1125.56 MWD+IFR+MS 1900.00 40.10 275.00 1792.70 65.25 -454.55 -622.00 -1130.99 MWD+IFR+MS 1933.08 40.10 275.00 1818.00 67.10 -475.77 -600.78 -1132.85 BPRF 2000.00 40.10 275.00 1869.19 70.86 -518.71 -557.83 -1136.61 MWD+JFR+MS 2040.28 40.10 275.00 1900.00 73.12 -544.56 -531.99 -1138.87 MWD+IFR+MS 2100.00 42.47 274.52 1944.87 76.39 -583.82 -492.72 -1142.13 MWD+IFR+MS 2200.00 46.44 273.80 2016.24 81.45 -653.66 -422.89 -1147.20 MWD+IFR+MS 2300.00 50.41 273.17 2082.60 85.99 -728.31 -348.24 -1151.74 MWD+JFR+MS 2400.00 54.38 272.61 2143.60 89.98 -807.42 -269.13 -1155.73 MWD+IFR+MS 2500.00 58.36 272.11 2198.97 93.40 -890.59 -185.95 -1159.15 MWD+IFR+MS 2600.00 62.34 271.64 2248.43 96.24 -977.44 -99.11 -1161.98 MWD+IFR+MS 2700.00 66.32 271.21 2291.74 98.48 -1067.52 -9.02 -1164.22 MWD+IFR+MS 2761.45 68.77 270.96 2315.21 99.55 -1124.30 47.75 -1165.30 MWD+IFR+MS 2769.17 68.77 270.96 2318.00 99.67 -1131.49 54.94 -1165.42 103/4" 2800.00 68.77 270.96 2329.17 100.15 -1160.23 83.68 -1165.90 MWD+JFR+MS ; Company: BP Amoco Date: 4/24/2004 Time: 12:06:29 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Site: M Pt I Pad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N,O.00E,312.19Azi) Wellpath: MPI-14 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD N/S EIW LLEW LLNS Tool/Comment ft deg deg ft ft ft ft ft 2900.00 68.77 270.96 2365.38 101.71 -1253.43 176_88 -1167.46 MWD+IFR+MS 3000.00 68. 77 270.96 2401.59 103.27 -1346.63 270.08 -1169.02 MWD+IFR+MS 3100.00 68.77 270.96 2437.80 104.83 -1439.83 363.28 -1170.58 MWD+IFR+MS 3200.00 68.77 270_96 2474.02 106.39 -1533.03 456.48 -1172.14 MWD+IFR+MS 3300.00 68.77 270.96 2510.23 107.95 -1626.23 549.68 -1173.70 MWD+IFR+MS 3400.00 68.77 270.96 2546.44 109.51 -1719.43 642.88 -1175.26 MWD+IFR+MS 3500.00 68.77 270.96 2582.66 111.07 -1812.63 736.08 -1176.82 MWD+IFR+MS 3600.00 68.77 270.96 2618.87 112.63 -1905.83 829.28 -1178.38 MWD+IFR+MS 3700.00 68.77 270.96 2655.08 114.19 -1999.03 922.48 -1179.94 MWD+IFR+MS 3800.00 68.77 270.96 2691.29 115.76 -2092.23 1015.68 -1181.50 MWD+IFR+MS 3900.00 68.77 270.96 2727.51 117.32 -2185.43 1108.88 -1183.06 MWD+IFR+MS 4000.00 68.77 270.96 2763.72 118.88 -2278.63 1202.08 -1184.62 MWD+IFR+MS 4100.00 68. 77 270.96 2799.93 120.44 -2371.83 1295.28 -1186.18 MWD+IFR+MS 4200.00 68.77 270.96 2836.14 122.00 -2465.03 1388.48 -1187.74 MWD+IFR+MS 4300.00 68.77 270.96 2872.36 123.56 -2558.23 1481.68 -1189.30 MWD+IFR+MS 4400.00 68.77 270.96 2908.57 125.12 -2651.43 1574.88 -1190.86 MWD+IFR+MS 4500.00 68.77 270.96 2944.78 126.68 -2744.63 1668.08 -1192.42 MWD+IFR+MS 4600.00 68.77 270.96 2981.00 128.24 -2837.82 1761.28 -1193.98 MWD+IFR+MS 4700.00 68.77 270.96 3017.21 129.80 -2931.02 1854.48 -1195.54 MWD+IFR+MS 4732.09 68. 77 270.96 3028.83 130.30 -2960.93 1884.39 -1196.04 MWD+IFR+MS 4800.00 68.22 273.82 3053.73 132.93 -3024.05 1947.50 -1198.67 MWD+IFR+MS 4900.00 67.51 278.07 3091.42 142.51 -3116.16 2039.61 -1208.25 MWD+IFR+MS 5000.00 66.91 282.36 3130_18 158.84 -3206.86 2130.31 -1224.59 MWD+IFR+MS 5100.00 66.42 286_68 3169.81 181.85 -3295.72 2219.17 -1247.59 MWD+IFR+MS 5200.00 66.05 291.03 3210.12 211.42 -3382.30 2305.76 -1277.16 MWD+IFR+MS 5207.09 66.03 291.34 3213.00 213.76 -3388.35 2311.80 -1279.50 TUZC 5300.00 65.81 295.41 3250.92 247.40 -3466.19 2389.64 -1313.15 MWD+IFR+MS 5400.00 65.70 299.79 3292.00 289.63 -3546.97 2470.42 -1355.37 MWD+IFR+MS 5500.00 65.71 304.18 3333.16 337.89 -3624.24 2547.70 -1403.64 MWD+IFR+MS 5600.00 65.84 308.57 3374.22 391.96 -3697.64 2621.10 -1457.70 MWD+IFR+MS 5700.00 66.10 312.94 3414.95 451.56 -3766.81 2690.26 -1517.31 MWD+IFR+MS 5782.05 66.41 316.51 3448.00 504.40 -3820.16 2743.61 -1570.14 Ugnu-MA 5800.00 66.48 317.28 3455.18 516.41 -3831.40 2754.86 -1582.16 MWD+IFR+MS 5807.08 66.52 317.59 3458.00 521.20 -3835.80 2759.25 -1586.94 Ugnu-MB 1 5900.00 66.99 321.60 3494.69 586.19 -3891.11 2814.56 -1651.94 MWD+IFR+MS 5960.06 67.34 324.18 3518.00 630.34 -3924.50 2847.96 -1696.08 Ugnu-MB2 6000.00 67.61 325.89 3533.30 660.57 -3945.64 2869.10 -1726.31 MWD+IFR+MS 6060.00 68.03 328.44 3555.96 707.25 -3975.76 2899.22 -1772.99 Fault #1 6100.00 68.34 330.13 3570.82 739.17 -3994.73 2918.18 -1804.92 MWD+IFR+MS 6180.19 69.00 333.50 3600.00 805.00 -4030.00 2953.45 -1870.75 MWD+IFR+MS 6200.00 69.00 333.50 3607.10 821.55 -4038.25 2961.70 -1887.30 MWD+IFR+MS 6300.00 69.00 333.50 3642.94 905.10 -4079.91 3003.36 -1970.85 MWD+IFR+MS 6400.00 69.00 333.50 3678.77 988.65 -4121.56 3045.02 -2054.40 MWD+IFR+MS 6411.80 69.00 333.50 3683.00 998.50 -4126.48 3049.93 -2064.25 Ugnu-MC 6467.60 69.00 333.50 3703.00 1045.13 -4149.73 3073.18 -2110.88 MPI-14 Fault#1 6500.00 69.00 333.50 3714.61 1072.20 -4163.22 3086.67 -2137.95 MWD+IFR+MS 6600.00 69.00 333.50 3750.45 1155.75 -4204.88 3128.3.3 -2221.50 MWD+IFR+MS 6621.82 69.00 333.50 3758.27 1173.98 -4213.97 3137.42 -2239.73 MWD+IFR+MS 6635.19 69.53 333.43 3763.00 1185.17 -4219.55 3143.01 -2250.91 SBF2-Top NA 6649.68 70.11 333.35 3768.00 1197.33 -4225.65 3149.10 -2263.07 SBF21-Base NA 6700.00 72.10 333.08 3784.29 1239.82 -4247.10 3170.55 -2305.57 MWD+IFR+MS 6765.49 74.70 332.75 3803.00 1295.70 -4275.67 3199.12 -2361.44 MPI-14 T1 e . Halliburton Company BP Planning Report . , Company: BP Amoco Date: 4/24/2004 Time: 12:06:29 Page: 5 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MP/-14 Odin, True North Site: M Pt f Pad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N,O.00E,312.19Azi) Wellpath: MPf-14 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD N/S EIW LLEW LLNS Tool/Comment ft deg deg ft ft ft ft ft 6808.13 74.75 334.51 3814.23 1332.55 -4293.94 3217.39 -2398.30 MWD+IFR+MS 6841.46 74.75 334.51 3823.00 1361.57 -4307.78 3231.23 -2427.32 SBF12-Base NB 6898.49 74.75 334_51 3838.00 1411.24 -4331.45 3254.91 -2476.99 SBE4-NC 6900.00 74.75 334.51 3838.40 1412.56 -4332.08 3255.53 -2478.30 MWD+IFR+MS 6974.53 74.75 334_51 3858.00 1477.46 -4363.02 3286.47 -2543.21 SBE2-NE 7000.00 74.75 334.51 3864.70 1499.65 -4373.60 3297_05 -2565.39 MWD+IFR+MS 7085.00 74.75 334.51 3887.06 1573.67 -4408.88 3332.34 -2639.42 Fault #2 7088.58 74.75 334.51 3888.00 1576.80 -4410.37 3333.82 -2642.54 MPI-14 Fault #2 7100.00 74.75 334.51 3891.00 1586.74 -4415.11 3338.56 -2652.48 MWD+IFR+MS 7126.60 74.75 334.51 3898.00 1609.91 -4426.15 3349.61 -2675.65 SBE1-NF 7200.00 74.75 334.51 3917.31 1673.83 -4456.62 3380.08 -2739.57 MWD+IFR+MS 7259.67 74.75 334.51 3933.00 1725.79 -4481.40 3404.85 -2791.54 TSBD-Top OA 7300.00 74.75 334.51 3943.61 1760.92 -4498.14 3421.59 -2826.67 MWD+/FR+MS 7386.68 74.75 334.51 3966.41 1836.41 -4534.13 3457.58 -2902.16 MWD+IFR+MS 7392.78 74.97 334.62 3968.00 1841.73 -4536.65 3460.11 -2907.47 TSBC-Base OA 7400.00 75.23 334.75 3969.86 1848.03 -4539.64 3463.09 -2913.78 MWD+IFR+MS 7500.00 78.86 336.47 3992.27 1936.78 -4579.86 3503.32 -3002.52 MWD+IFR+MS 7531.25 80.00 337.00 3998.00 1965.00 -4592.00 3515.45 -3030.75 MPI-14 T2 B 7581.25 80.00 337.00 4006.68 2010.33 -4611.24 3534.69 -3076.08 MWD+IFR+MS 7600.00 81.34 336.74 4009.72 2027.34 -4618.51 3541.96 -3093.09 MWD+IFR+MS 7650.00 84.90 336.05 4015.71 2072.82 -4638.38 3561.83 -3138.56 MWD+IFR+MS 7700.00 88.47 335.37 4018.60 2118.30 -4658.91 3582.37 -3184.05 MWD+IFR+MS 7750.00 92.03 334.69 4018.39 2163.62 -4680.02 3603.47 -3229.37 MWD+IFR+MS 7765.74 93.15 334.47 4017.67 2177.82 -4686.77 3610.22 -3243.57 MWD+IFR+MS 7789.85 93.15 334.47 4016.35 2199.55 -4697.15 3620.60 -3265.30 MWD+/FR+MS 7800.00 93.16 335.18 4015.79 2208.72 -4701.45 3624.91 -3274.47 MWD+IFR+MS 7850.00 93.19 338.69 4013.02 2254.64 -4721.01 3644.46 -3320.39 MWD+IFR+MS 7900.00 93.20 342.19 4010.23 2301.68 -4737.72 3661.17 -3367.43 MWD+IFR+MS 7940.02 93.20 345.00 4008.00 2340.00 -4749.00 3672.45 -3405.75 MPI-14 T3 B 7950.00 92.61 345.10 4007.49 2349.64 -4751.57 3675.02 -3415.38 MWD+IFR+MS 8000.00 89.65 345.58 4006.51 2397.99 -4764.22 3687.67 -3463.74 Fault #3 8050.00 86.69 346.07 4008.11 2446.44 -4776.46 3699.91 -3512.19 MWD+IFR+MS 8076.38 85.13 346.33 4009.99 2471.99 -4782.73 3706.19 -3537.74 MWD+IFR+MS 8100.00 85.13 346.33 4012.00 2494.86 -4788.30 3711.75 -3560.61 MWD+IFR+MS 8193.32 85.13 346.33 4019.92 2585.21 -4810.27 3733.73 -3650.95 MWD+IFR+MS 8200.00 85.23 346.72 4020.49 2591.68 -4811.83 3735.28 -3657.43 MWD+IFR+MS 8250.00 86.01 349.62 4024.31 2640.47 -4822.05 3745.50 -3706.22 MWD+IFR+MS 8300.00 86.80 352.52 4027.44 2689.76 -4829.79 3753.24 -3755.51 MWD+IFR+MS 8350.00 87.60 355.42 4029.88 2739.42 -4835.03 3758.49 -3805.17 MWD+IFR+MS 8400.00 88.40 358.31 4031.63 2789.31 -4837.77 3761.22 -3855.06 MWD+IFR+MS 8450.00 89.21 1.20 4032.67 2839.29 -4837.98 3761.44 -3905.04 MWD+IFR+MS 8498.50 90.00 4.00 4033.00 2887.74 -4835.78 3759.24 -3953.49 MPI-14 T4 8500.00 90.02 4.09 4033.00 2889.23 -4835.68 3759.13 -3954.98 MWD+IFR+MS 8527.60 90.43 5.69 4032.89 2916.73 -4833.33 3756.78 -3982.48 MWD+IFR+MS 8600.00 90.43 5.69 4032.34 2988.77 -4826.15 3749.60 -4054.52 MWD+IFR+MS 8700.00 90.43 5.69 4031.58 3088.28 -4816.23 3739.69 -4154.02 MWD+IFR+MS 8775.01 90.43 5.69 4031.02 3162.91 -4808.80 3732.25 -4228.66 MWD+IFR+MS 8800.00 89.44 5.64 4031.04 3187.78 -4806.33 3729.78 -4253.53 MWD+IFR+MS 8862.09 86.95 5.52 4033.00 3249.54 -4800.29 3723.74 -4315.29 MPI-14 T5 B 8872.82 86.53 5.53 4033.61 3260.21 -4799.26 3722.71 -4325.95 MWD+IFR+MS 8900.00 86.53 5.53 4035.26 3287.21 -4796.65 3720.10 -4352.96 MWD+IFR+MS 9000.00 86.53 5.53 4041.32 3386.56 -4787.04 3710.49 -4452.31 MWD+IFR+MS 9100.00 86.53 5.53 4047.38 3485.91 -4777.43 3700.88 -4551.66 MWD+IFR+MS Halliburton Company BP Planning Report . . . Halliburton Company BP Planning Report Company: BP Amoco Date: 4/24/2004 Time: 12:06:29 Page: 6 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Site: M Pt I Pad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N,O.00E,312.19Azi) Wellpatb: MPI-14 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD N/S E/W LLEW LLNS Tool/Comment ft deg deg ft ft ft ft ft 9200.00 86.53 5.53 4053.44 3585.27 -4767.82 3691.27 -4651.01 Fault #4 9232.80 86.53 5.53 4055.43 3617.85 -4764.66 3688.12 -4683.60 MWD+IFR+MS 9300.00 89.21 5.51 4057.92 3684.69 -4758.21 3681.66 -4750.44 MWD+IFR+MS 9332.75 90.52 5.50 4058.00 3717.29 -4755.07 3678.52 -4783.03 MPI-14 T6 9336.16 90.52 5.64 4057.97 3720.68 -4754.74 3678.19 -4786.43 MWD+IFR+MS 9400.00 90.52 5.64 4057.39 3784.21 -4748.47 3671.92 -4849.96 MWD+IFR+MS 9500.00 90.52 5.64 4056.47 3883.72 -4738.65 3662.10 -4949.47 MWD+IFR+MS 9600.00 90.52 5.64 4055.56 3983.24 -4728.82 3652.28 -5048.98 MWD+IFR+MS 9700.00 90.52 5.64 4054.65 4082.75 -4719.00 3642.46 -5148.50 MWD+IFR+MS 9800.00 90.52 5.64 4053.73 4182.26 -4709.18 3632.63 -5248.01 MWD+IFR+MS 9880.00 90.52 5.64 4053.00 4261.87 -4701.32 3624.78 -5327.62 4 1/2" " 9880.11 90.52 5.64 4053.00 4261.98 -4701.31 3624.77 -5327.73 MPI-14 T7 ""'" PllnMp·J40din WELL DETAILS ANTI-COLLlSION SETTINGS COMPANY DETAILS BP Amoro Calculation MetbxI.: Mínimwn Curvafun, Error System: ISCWSA Scan Method: Trav Cylinder North w~~~ i~i~~C'4sirIg SURVEY PROGRAM Depth Fm Depth To SurveylPlan 33.00 1000.00 PIaMed: MPj·J4 WP16 V4¡ 1000.00 9880.11 p~ MPI·14 WPl6 V41 Tool CB-GYRQ.MS MWD+IFR+MS +NI.s 1065.75 +fj-W 1076.55 - ..."" 5SIJ15.07 Lalitude Lon¡:itude Sloe 70"26'1J.162N J49"J4'S3.8Z7W NlA Interpolation Metbod:MD Depth Range From: 33.00 Maximum Range: 1184.71 Interval: 50.00 To: 9880.1 I Reference: Pian: MPI-I4 WPI6 6009460.88 From Colour ToMD 0 0 0 500 500 1000 1000 1500 1500 2000 50 2000 2500 2500 3000 3000 4000 4000 5000 00 5000 6000 6000 7000 7000 8000 8000 9000 o 9000 10000 10000 11000 11000 12000 2000 13000 000 14000 100 50 0 270 50 100 150 00 50 SECTION DETAILS SO< MD Joc ,<,; TVD +NI.s +EI-W Dl<g TF"" VSO< I 33.00 0.00 0.00 33.00 0.00 0,00 0,00 0,00 0,00 2 300.00 0,00 330.00 300.00 0.00 0.00 0.00 ]]0.00 0,00 3 600.00 4.51 330.00 599.69 10.22 ·5.90 150 330.00 JI.24 4 800.00 7.47 28910 798.66 21.31 ·22.12 250 28334 30.70 5 1180.00 18.48 275.00 ]168.47 34.73 ·105.12 3,00 336.80 101.65 6 1900.00 40,10 275.00 1792.70 6515 -454.55 3,00 0.00 )80.58 7 204018 40.10 275.00 1900.00 73.12 .$4456 0.00 0,00 452.56 . 2761.45 68.77 270.96 23152J 99.55 -1124.30 4,00 .7.82 "'>3 9 4732.09 68.77 270.96 3028.83 ])OJO -2960,93 0,00 0,00 2281.20 10 6180.19 69.00 333.50 3600.00 805.00 -4030.00 4,00 102.14 3526.40 11 6621.82 69,00 333.5{) 3758.27 1173.98 -4213.97 0.00 0,00 3910.52 12 6765.49 74.70 332.75 3803.00 1295.70 -4275.67 4.00 -7.28 4037.99 J 6808.13 74.75 334.51 3814.23 ]3)2.55 -4293.94 4.00 88,60 4076.27 14 7386.68 74.15 334.51 3966.41 1836.41 -4534.13 0.00 0.00 4592.64 15 753].25 80.00 337.00 3998.00 1965.00 -4592.00 4,00 2.5.09 4721.88 16 7581.25 80.00 337.00 4006.68 201033 -4611.24 0.00 0,00 4766.58 17 7765.74 93.15 334.47 4017.67 2]77.82 -4686.77 726 _10.96 4935.03 18 7789.85 93.15 3)4.47 401635 2199.55 -4697.15 0,00 0,00 495731 I. 7940.02 93.20 345.00 4(X)8.oo 2340.00 -4749.00 7,00 89.46 5000.06 20 807638 85.13 34633 4009,99 2471.99 -4782.73 6,00 170.66 5203.71 21 819332 85.13 34633 4019.92 2585.21 -4810.27 0,00 0,00 5300.15 22 8498.50 90,00 4,00 4033.00 2887.74 -4835.78 6.00 75.07 5522.24 2J 8527.60 90.43 5,69 4032.89 2916.73 -483333 6,00 75.60 5539.89 24 8775.01 90.43 5.69 4031.02 3162.91 -4808.80 0.00 0,00 5687.07 25 8862.09 86.95 5.52 4033.00 3249.54 -4800.29 4.00 -177.23 5738.95 26 8872.82 8653 5.53 4033.61 3260.21 -4799.26 4,00 179.64 574535 27 9232.80 86.53 5.53 4055.43 3617.85 -4764.66 0,00 0,00 5959.93 28 9332.75 9052 5.50 4058.00 3717.29 -4755.07 4,00 .oJ6 6019.60 29 9336.16 9052 5,64 4057.97 3720.68 -4754.74 4.00 90.00 6021,64 30 9880.11 9052 5,64 4053.00 4261.98 -4701.31 0.00 0.00 6345.62 WELLPATH DETAILS MPI-14 Rig: Ref: Datum: 68.00 68.00ft V.Section Qigin Origin Angle +N/-S "'EI-W 311.W 0.00 0.00 ~::"VD 33.00 LEGEND - MPI-03 (MP]-03), Major Risk MPI.04A (MPI-04A). Major Risk MPI..04 (MPI-04). Major Risk MPI..04 (MPI-04A), Major Risk MPI-û4 (MPI.04ALI). Major Risk - MPI.04(MPI-04APBI),MajorRisk - MPI-04(MPI-04PBI).MajorRisk -- MPI..Q6 (MPI-06). Major Risk = ~þ::~~t~1:~~~~ - MPI~ (MPI-Q9). Major Risk - MPI-IO(MPI-IO}.MajorRisk - MPJ-¡O(MPf-IOA).MajorRisk - MPI-Il (MPI-I I). Major Risk - MPI-II (MPI-III-I),M¡tjorRisk MPI-Il (MPI-Il), Major Risk MPI-Il (MP]-11L]j. Major Risk MPI-12 (MPI-12PBI). Major Risk MPI-13 (M~I-I3). Major Risk MPI-LoreJel (Plan MPI-Lorelei). Major Risk Plan MPI-17 Thor (Plan MPI-17 LI). Major Risk Plan MPI-17 Thor (Plan MPI-17 L2), Major Risk Plan MPI-17 Thor (plan MPI-I1). MajorRigk Plan MPI-LINK (Plan MPI-LINK), Major Risk - Plan MPI-Tank (Plan MP]-TanJ¡:), Major Risk Plan MPI-Uller (Plan MPI-Uller), Major Risk: Plan MPI_ValhaIla (Plan MPI-ValhaJla). Major Risk: MPJ·20 (MPJ-20), Major Risk MPJ.20 (MPJ-20A), Major Risk Plan MPJ-26 (Plan MPJ-26), Major Risk Plan MPJ-26 (Plan MPJ-26Lt), Major Risk ~~ ~~t~~~~p~~J~~j~~~a~r ~:r Risk MPj·\4 MPI_]4WPI6 T....t MPI-]4 TI MPI-14 T2 B MPI-14 T3 ß MPI_14T4 MPI-14158 MPI_I4T6 MPI-14T7 · . Halliburton Company Anticollision Report Company: BPAmoco Date: 4/24/2004 Time: 11;37:05 Page: J Field: Milne Point Reference Site: MptlPad Co-ordinate(NE) Reference: Well; Plan MPI-14 Odin, True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 68.00 68.0 Reference Wellpath: MPI-14 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/JOOO of reference Reference: Plan: MPI-14 WP16 & NOT PLANNED P )i Jnterpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 33.00 to 9880.11 ft Scan Method: Trav Cylinder North Maximum Radius: 1184.71 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2769.17 2318.00 10.750 13.500 10 3/4" 7531.25 3998.00 7.625 9.875 7-5/8" 9876.00 4053_04 4.500 6.750 4 1/2" Plan: MPI-14 WP16 Date Composed: 3/29/2004 Version: 41 Principal: Yes Tied-to: From Well Ref. Point Summary ~ < Offset Wellpath > Reference Offset Or-Or No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt I Pad MPI-03 MPI-03 V1 457.80 450.00 245.93 16.01 229.91 Pass: Major Risk M Pt I Pad MPI-04A MPI-04A V1 459.39 450.00 183.54 15.08 168.45 Pass; Major Risk M Pt I Pad MPI-04 MPI-04 V5 444.20 450.00 183.03 14.58 168.45 Pass; Major Risk M Pt I Pad MPI-04 MPI-04A V5 444.20 450.00 183.03 14.58 168.45 Pass; Major Risk MPtlPad MPI-04 MPI-04AL 1 V2 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk M pt I Pad MPI-04 MPI-04APB1 V1 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk M Pt I Pad MPI-04 MPI-04PB1 V3 444.20 450.00 183.03 14.58 168.45 Pass; Major Risk M Pt I Pad MPI-06 MPI-06 V10 497_62 500.00 212.20 15.42 196.78 Pass; Major Risk M Pt I Pad MPI-07 MPI-07 V1 497.44 500.00 156.81 18.75 138.05 Pass: Major Risk M pt I Pad MPI-08 MPI-08 V3 613.58 650.00 117.32 15.70 101.62 Pass: Major Risk M pt I Pad MPI-09 MPI-09 V12 353.23 350.00 331.47 10.54 320.93 Pass: Major Risk M pt I Pad MPI-10 MPI-10 V8 3830.53 4300.00 242.55 194.30 48.26 Pass: Major Risk MptlPad MPI-10 MPI-10A V1 2138.74 2500.00 326.57 50.95 275.62 Pass: Major Risk M pt I Pad MPI-11 MPI-11 V4 695.39 700.00 90.49 17.55 72.94 Pass: Major Risk MPtlPad MPI-11 MPI-11L 1 V2 695.39 700.00 90.49 17.55 72.94 Pass: Major Risk M PtI Pad MPI-12 MPI-12 V10 403.62 400.00 63.89 10.20 53.69 Pass: Major Risk MPtlPad MPI-12 MPI-12L 1 V11 403.62 400.00 63.89 10.09 53.80 Pass: Major Risk M pt I Pad MPI-12 MPI-12PB1 V4 403.62 400.00 63.89 10.20 53.69 Pass; Major Risk M pt I Pad MPI-12 Plan MPI-12 A ( Thor T 33.30 28.70 60.14 0.00 60.14 Pass: NO ERRORS M Pt I Pad MPI-13 MPI-13 V6 701.03 700.00 30.05 17.60 12.45 Pass: Major Risk M pt I Pad MPI-Lorelei Plan MPI-Lorelei V1 PI 1467.67 1550.00 114.73 38.37 76.36 Pass; Major Risk M Pt I Pad Plan MPI-14 Odin MPI-14 L1 VO Plan: MPI 2700.00 2700.00 0.00 0.00 0.00 FAIL; NOERRORS M pt I Pad Plan MPI-14 Odin MPI-14 L2 VO Plan; MPI 2700.00 2700.00 0.00 0.00 0.00 FAIL: NOERRORS M pt I Pad Plan MPI-14 Odin Plan MPI-14 PB1 old V1 33.00 33.00 0.00 0.00 0.00 FAIL: NO ERRORS M pt I Pad Plan MPI-17 Thor Plan MPI-17 L 1 VO Plan 6215.78 7750.00 436.31 125.12 311.19 Pass: Major Risk M pt I Pad Plan MPI-17 Thor Plan MPI-17 L2 VO Plan 6169.16 7700.00 371.23 125.15 246.08 Pass: Major Risk M Pt I Pad Plan MPI-17 Thor Plan MPI-17 V5 Plan: M 6080.66 7650.00 245.76 135.86 109.90 Pass; Major Risk M pt I Pad Plan MPI-Freya Plan MPI-Freya VO Plan 3019.53 3200.00 91.94 0.00 91.94 Pass: NOERRORS M PtI Pad Plan MPI-LlNK Plan MPI-LlNK VO Plan: 835.91 900.00 408.81 25.00 383.81 Pass: Major Risk M pt I Pad Plan MPI-Tank Plan MPI-Tank VO Plan: 908.77 950.00 205.01 25.10 179.91 Pass; Major Risk M pt I Pad Plan MPI-Uller Plan MPI-Uller V1 Plan 589.04 600.00 215.63 16.83 198.79 Pass: Major Risk M pt I Pad Plan MPI-Valhalla Plan MPI-Valhalla VO P 6824.31 6650.00 276.69 108.72 167.98 Pass; Major Risk M pt J Pad MPJ-20 MPJ-20 V1 Out of range M PtJ Pad MPJ-20 MPJ-20A V8 Out of range M pt J Pad Plan MPJ-26 Plan MPJ-26 V3 Plan: M Out of range M ptJ Pad Plan MPJ-26 Plan MPJ-26L 1 VO Plan: Out of range MPtJPad Plan MPJ-26 Plan MPJ-26L2 V1 Plan; Out of range M PtJ Pad Plan MPJ-Switch Plan MPJ-Switch VO PIa Out of range GRJ . . Halliburton Company Anticollision Report Company: BP Amoco Date: 4/24/2004 Time: 11 :37:05 Page: 2 Field: Milne Point Reference Site: M PtI Pad Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 68.00 68.0 Reference Wellpath: MPI-14 Db: Oracle Site: M pt I Pad Well: MPI-03 Rule Assigned: Major Risk Wellpath: MPI-03 V1 I nter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglHIDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.50 33.50 20.00 20.00 0.00 0.00 92.93 92.93 240.41 1.02 239_39 Pass 63_50 63.50 50.00 50.00 0.10 0.07 92_93 92.93 240.46 1.80 238.65 Pass 113.50 113.50 100.00 100.00 0.28 0.20 92.94 92.94 240.72 3.27 237.45 Pass 163.50 163.50 150.00 150.00 0.56 0.38 92.96 92.96 241.06 5.13 235.94 Pass 213.50 213.50 200.00 200.00 0.82 0.57 93.01 93.01 241.43 6.98 234.46 Pass 263.49 263.49 250.00 249.99 1.05 0.77 93.07 93.07 241.83 8.78 233.05 Pass 313.04 313.04 300.00 299.99 1.28 0.98 93.14 123.14 242.26 10.59 231.66 Pass 361.34 361.34 350.00 349.99 1.50 1.20 93.32 123.32 242.99 12.40 230.59 Pass 409.61 409.59 400.00 399.98 1.72 1.42 93.64 123.64 244.16 14.21 229.95 Pass 457.80 457.75 450_00 449.97 1.94 - 1.64 94.18 124.18 245.93 16.01 229.91 Pass 505.86 505.76 500.00 499.94 2.16 1.87 94.94 124.94 248.41 17.81 230.59 Pass 553.65 553.46 550.00 549_83 2.38 2.09 96.09 126.09 252.08 19.60 232.48 Pass 600.97 600.65 600.00 599.59 2.59 2.31 97.61 127.91 257.17 21.37 235.80 Pass 645.35 644.89 650.00 649.22 2.73 2.53 99.24 142.30 263.84 22.86 240.99 Pass 689.40 688.76 700.00 698.69 2.86 2.76 100.88 154.34 272.29 24.33 247.97 Pass 733.04 732.17 750.00 747.97 2.96 2.98 102.52 164.14 282.38 25.68 256.70 Pass 776.19 775.04 800.00 797.02 3.06 3.20 104.18 172.10 294.07 26.98 267.10 Pass 818.13 816.63 850.00 845.78 3.17 3.42 105.81 178.16 307.67 28.29 279.38 Pass 858.50 856.54 900.00 894.18 3.29 3.65 107.42 182.59 323.40 29.61 293.79 Pass 897.88 895.37 950.00 942.10 3.42 3.87 109.04 186.35 341.28 30.91 310.37 Pass 936.17 932.98 1000.00 989.47 3.49 4.10 110.65 189.65 361.25 32.02 329.23 Pass 973.44 969.45 1050.00 1036.29 3.56 4.33 112.24 192.59 382.97 33.08 349.88 Pass 1009.67 1004.76 1100.00 1082.57 3.61 4.55 113.78 195.25 406.28 34.07 372.22 Pass 1044.97 1039.01 1150.00 1128.42 3.61 4.78 115.22 197.61 431.09 34_90 396.20 Pass 1079.37 1072.24 1200.00 1173.88 3.62 5.00 116.52 199.70 457.30 35.70 421.60 Pass 1113.02 1104.59 1250.00 1219.10 3.62 5.23 117.71 201.57 484.55 36.47 448.08 Pass 1145.97 1136.09 1300.00 1264.08 3.63 5.45 118.77 203.23 512.74 37.22 475.52 Pass 1177.77 1166.35 1350.00 1308.44 3.63 5.68 119.79 204.75 542.39 37.95 504.43 Pass 1207.76 1194.72 1400.00 1352.05 3.65 5.86 120.78 205.78 573.58 38.54 535.05 Pass 1237.00 1222.25 1450.00 1395.52 3.66 5.93 121.67 206_67 605.54 38.85 566.70 Pass 1265.77 1249.17 1500.00 1439.07 3.67 5.96 122.45 207.45 637.96 39.02 598.94 Pass 1294.24 1275.67 1550.00 1482.84 3.69 5.86 123.13 208.13 670.55 38.90 631.65 Pass 1322.48 1301.79 1600.00 1526.86 3.70 5.76 123.72 208.72 703.22 38.79 664.43 Pass 1350.45 1327.50 1650.00 1571.11 3.72 5.66 124.24 209.24 736.01 38.69 697.32 Pass 1378.08 1352.74 1700.00 1615.50 3.75 5.62 124.69 209.69 768.97 38.71 730.25 Pass 1400.00 1372.64 1750.00 1659.33 3.76 5.71 125.15 210.15 802.99 39.01 763.98 Pass 1430.07 1399.78 1800.00 1702.36 3.79 5.85 125.63 210.63 838.22 39.46 798.76 Pass 1454.64 1421.79 1850.00 1745.01 3.82 6.10 126.08 211.08 874.21 40.14 834.08 Pass 1478.56 1443.09 1900.00 1787.46 3.85 6.33 126.51 211.51 910.75 40.74 870.01 Pass 1500.00 1462.06 1950.00 1829.86 3.87 6.52 126.90 211.90 947.70 41.19 906.51 Pass 1524.87 1483.93 2000.00 1872.24 3.91 6.70 127.24 212.24 985.03 41.66 943.37 Pass 1547.03 1503.27 2050.00 1914.37 3.94 6.88 127.56 212.56 1023.04 42.11 980.92 Pass 1568.37 1521.79 2100.00 1956.19 3.97 7.06 127.85 212.85 1061.79 42.59 1019.20 Pass 1589.14 1539.69 2150.00 1997.91 4.00 7.26 128.11 213.11 1100.99 43.13 1057.86 Pass 1600.00 1549.01 2200.00 2039.59 4.02 7.46 128.35 213.35 1140.62 43.63 1096.99 Pass 1629.10 1573.81 2250.00 2081.09 4.07 7.68 128.56 213.56 1180.56 44.21 1136.34 Pass . . Halliburton Company Anticollision Report Company: BP Amoco Date: 4/24/2004 Time: 11:37:05 Page: 3 Field: Milne Point Reference Site: M PtI Pad Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 68.00 68.0 Reference Wellpatb: MPI-14 Db: Oracle Site: M Pt I Pad Well: MPI-04A Rule Assigned: Major Risk Wellpatb: MPI-04A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.50 33.50 19.90 19.90 0.00 0.00 92.97 92.97 179.66 1.02 178.64 Pass 63.60 63.60 50.00 50.00 0.10 0.07 92.96 92.96 179.67 1.81 177.87 Pass 113.60 113-60 100.00 100.00 0.28 0.18 92.93 92.93 179.73 3.22 176.52 Pass 163.60 163.60 150.00 150.00 0.56 0.31 92_92 92.92 179.86 4.90 174.96 Pass 213.60 213.60 200.00 200.00 0.82 0.44 92.93 92.93 180.06 6.60 173.46 Pass 263.60 263.60 250.00 250.00 1.05 0.61 92.94 92.94 180.30 8.31 171.99 Pass 313.26 313.26 300.00 300.00 1.28 0.79 92.95 122.95 180.59 10.03 170.55 Pass 361.99 361.99 350.00 350.00 1.51 0.98 93.08 123.08 181.15 11.76 169.39 Pass 410.70 410.69 400.00 400.00 1.73 1.16 93.35 123.35 182.10 13.46 168.64 Pass 459.39 459.35 450.00 449.99 1.95 - 1.32 93.54 123.54 183.54 15.08 168.45 Pass 508.05 507.95 500.00 499.95 2.17 1.48 93.59 123.59 185.53 16.72 168.81 Pass 556_65 556.46 550.00 549.82 2.39 1.65 93.35 123.35 188.24 18.38 169.86 Pass 604.93 604.60 600.00 599.56 2.60 1.83 92.81 124.33 191.73 20.02 171.70 Pass 650.96 650.47 650.00 649.18 2.74 2.03 91.96 136.47 196.29 21.47 174.82 Pass 696.67 696.00 700.00 698.68 2.88 2.23 90.80 145.77 202_18 22.92 179.25 Pass 741.95 741.03 750.00 747.98 2.98 2.44 89.32 152.37 209.57 24.27 185.30 Pass 786.67 785.44 800.00 797.03 3.08 2.65 87.56 156.79 218.61 25.60 193.01 Pass 830.07 828.44 850.00 845.78 3.20 2.88 85.60 158.86 229.60 26.99 202.62 Pass 872.37 870.24 900.00 894.18 3.34 3.10 83.57 159.55 242.78 28.38 214.40 Pass 913.89 911.11 950.00 942.37 3.45 3.32 81.64 159.70 257.91 29.69 228.22 Pass 954.59 951.03 1000.00 990.39 3.53 3.54 79.88 159.58 274.85 30.86 243.99 Pass 994.46 989.95 1050.00 1038.16 3.60 3.76 78.20 159.22 293.32 31.97 261.35 Pass 1033.42 1027.82 1100.00 1085.63 3.61 3.97 76.58 158.68 313.25 32.88 280.37 Pass 1071.23 1064.39 1150.00 1132.61 3.62 4.19 74.98 157.98 335.04 33.73 301.31 Pass 1107.75 1099.53 1200.00 1179.01 3.62 4.42 73.42 157.18 358.80 34.57 324.23 Pass 1142.77 1133.04 1250.00 1224.71 3.63 4.66 71.93 156.33 384.79 35.41 349.37 Pass 1176.21 1164.87 1300.00 1269.65 3.63 4.89 70.53 155.47 412.94 36.22 376.71 Pass 1208.89 1195.79 1350.00 1314.30 3.65 5.13 69.32 154.32 442.45 37.01 405.44 Pass 1240.76 1225.78 1400.00 1358.81 3.66 5.36 68.30 153.30 472.99 37.76 435.23 Pass 1271.89 1254.88 1450.00 1403.21 3.67 5.58 67.41 152.41 504.34 38.46 465.88 Pass 1302.27 1283.11 1500.00 1447.49 3.69 5_80 66.64 151.64 536.42 39.13 497.29 Pass 1331.53 1310.13 1550.00 1491.28 3.71 6.04 65.91 150.91 569.66 39.79 529.87 Pass 1359.54 1335.82 1600.00 1534.45 3.73 6.27 65.23 150.23 604.15 40.45 563.71 Pass 1386.28 1360.20 1650.00 1577. 03 3.75 6.52 64.61 149.61 639.92 41.11 598.81 Pass 1411.78 1383.30 1700.00 1619.05 3.77 6.73 64.05 149.05 676.87 41.66 635.21 Pass 1436.56 1405.61 1750.00 1661.04 3_80 6.83 63.58 148.58 714.43 42.01 672.43 Pass 1460.80 1427.29 1800.00 1703.15 3.83 6.88 63.21 148.21 752.40 42.23 710.17 Pass 1484.51 1448.36 1850.00 1745.32 3.85 6.81 62.89 147.89 790.72 42.20 748.52 Pass 1507.67 1468.82 1900.00 1787.47 3.88 6.79 62.62 147.62 829.37 42.25 787.12 Pass 1529.89 1488.32 1950.00 1829.13 3.91 6.88 62.34 147.34 868.72 42.48 826.24 Pass 1551.06 1506.78 2000.00 1870.08 3.94 7.02 62.03 147.03 908.85 42.80 866.06 Pass 1571.01 1524.07 2050.00 1910.14 3.97 7.28 61.71 146.71 949.89 43.33 906.57 Pass 1589.72 1540.19 2100.00 1949.28 4.00 7.52 61.38 146.38 991.81 43.80 948.01 Pass 1600.00 1549.01 2150.00 1988.19 4.02 7.69 61.07 146.07 1034.19 44.14 990.05 Pass 1625.45 1570.71 2200.00 2027.18 4.07 7.81 60.81 145.81 1076.73 44.45 1032.28 Pass 1643.20 1585.74 2250.00 2066.85 4.10 7.81 60.61 145.61 1119.16 44.54 1074.62 Pass 1661.14 1600.85 2300.00 2107.34 4.13 7.83 60.48 145.48 1161.29 44.64 1116.65 Pass . . Halliburton Company Anticollision Report Company: BP Amoco Date: 4/24/2004 Time: 11:37:05 Page: 4 Field: Milne Point Reference Site: MPtlPad Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin. True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 68.00 68.0 Reference Wellpath: MPI-14 Db: Oracle Site: MPtlPad Well: MPI-04 Rule Assigned: Major Risk Wellpath: MPI-04 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFD-HS CasingIHS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.50 33.50 35.50 35.50 0.00 0.00 92.97 92.97 179.66 1.02 178.64 Pass 48.00 48-00 50.00 50.00 0.05 0.03 92.97 92.97 179.66 1.40 178.26 Pass 98.00 98.00 100.00 100.00 0.20 0.14 92.94 92.94 179.71 2.70 177.00 Pass 148.00 148.00 150.00 150.00 0.47 0.27 92.92 92.92 179.81 4.38 175.44 Pass 198.00 198.00 200.00 200.00 0.74 0.39 92.92 92.92 179.99 6.06 173.93 Pass 248.00 248.00 250_00 250.00 0.98 0.56 92.93 92.93 180.22 7.78 172 .44 Pass 298.00 298.00 300.00 300.00 1.21 0.73 92.94 92.94 180.49 9.49 170.99 Pass 346.79 346.79 350.00 350.00 1.44 0.92 93.02 123.02 180.94 11.22 169.71 Pass 395.51 395.50 400.00 400.00 1.66 1.11 93.26 123.26 181.75 12.95 168.81 Pass 444.20 444.17 450.00 449.99 1.88 - 1.27 93.50 123.50 183.03 14.58 168.45 Pass 492.87 492.79 500.00 499.96 2.10 1.43 93.60 123.60 184.84 16.20 168.64 Pass 541.50 541.33 550.00 549.87 2.32 1.60 93.46 123.46 187.31 17.86 169.45 Pass 590.05 589.77 600.00 599.66 2.54 1.77 93.01 123.01 190.56 19.51 171.04 Pass 636.63 636.20 650.00 649.32 2.70 1.97 92.26 132.98 194.73 21.02 173.71 Pass 682.45 681.84 700.00 698.85 2.84 2.16 91.20 143.17 200.19 22.46 177.73 Pass 727.88 727.04 750.00 748.22 2.95 2.37 89.82 150.57 207.09 23.86 183.24 Pass 772.79 771.66 800.00 797.35 3.05 2.59 88.13 155.61 215_60 25.18 190.42 Pass 816.70 815.20 850.00 846.20 3.16 2.81 86.22 158.45 225.94 26.55 199.39 Pass 859.26 857.30 900.00 894.71 3.30 3.03 84.20 159.41 238.44 27.94 210.50 Pass 901.02 898.45 950.00 942.96 3.43 3.25 82.22 159.69 252.99 29.31 223.67 Pass 941.98 938.68 1000.00 991.03 3.50 3.48 80.42 159.64 269.38 30.50 238.88 Pass 982.11 977.92 1050.00 1038.89 3.58 3.69 78.72 159.36 287.40 31.62 255.78 Pass 1021.37 1016.13 1100.00 1086.46 3.61 3.91 77.08 158.86 306.86 32.60 274.25 Pass 1059.57 1053.13 1150.00 1133.62 3.62 4.12 75.47 158.21 328.03 33.47 294.56 Pass 1096.50 1088.73 1200.00 1180.20 3.62 4.34 73.90 157.44 351.17 34.30 316.86 Pass 1132.01 1122.77 1250.00 1226.13 3.63 4.58 72.38 156.59 376.44 35.16 341.28 Pass 1165.93 1155.10 1300.00 1271.29 3.63 4.82 70.95 155.73 403.96 35.98 367.98 Pass 1198.77 1186.24 1350.00 1315.98 3.64 5.05 69.68 154.68 433.13 36.77 396.36 Pass 1230.91 1216.52 1400.00 1360.54 3.66 5.29 68.60 153.60 463.37 37.54 425.82 Pass 1262.26 1245.89 1450.00 1404.97 3.67 5.51 67.68 152.68 494.48 38.24 456.24 Pass 1292.89 1274.41 1500.00 1449.30 3.68 5.73 66.87 151.87 526.31 38.92 487.40 Pass 1322.54 1301.84 1550.00 1493.28 3.70 5.96 66.14 151.14 559.15 39.59 519.56 Pass 1350.94 1327.95 1600.00 1536.65 3.73 6.20 65.44 150.44 593.26 40.23 553.02 Pass 1378.08 1352.73 1650.00 1579.41 3.75 6.45 64.80 149.80 628.63 40.90 587.72 Pass 1403.94 1376.21 1700.00 1621.58 3.77 6.70 64.22 149.22 665.24 41.55 623.69 Pass 1428.89 1398.71 1750.00 1663.52 3.79 6.80 63.72 148.72 702.67 41.90 660.77 Pass 1453.30 1420.59 1800.00 1705.60 3.82 6.90 63.32 148.32 740.51 42.24 698.28 Pass 1477.17 1441.85 1850.00 1747.76 3.84 6.83 62.99 147.99 778.73 42.21 736.52 Pass 1500.00 1462.06 1900.00 1789.94 3.87 6.77 62.70 147.70 817.26 42.18 775.08 Pass 1523.07 1482.35 1950.00 1831.80 3.90 6.85 62.43 147.43 856.36 42.41 813.95 Pass 1544.58 1501.14 2000.00 1872.98 3.93 6.93 62.13 147.13 896.24 42.63 853.62 Pass 1564.92 1518.80 2050.00 1913.35 3.96 7.20 61.82 146.82 936.99 43.16 893.83 Pass 1583.99 1535.26 2100.00 1952.74 3.99 7.47 61.48 146.48 978.66 43.68 934.98 Pass 1600.00 1549.01 2150.00 1991.65 4.02 7.64 61.16 146.16 1020.91 44.04 976.87 Pass 1619.96 1566.05 2200.00 2030.59 4.05 7.81 60.89 145.89 1063.44 44.42 1019.01 Pass 1637.63 1581.04 2250.00 2069.98 4.09 7.81 60.67 145.67 1105.96 44.51 1061.45 Pass 1655.54 1596.15 2300.00 2110.25 4.12 7.81 60.51 145.51 1148.16 44.59 1103.57 Pass I 42 00 VI I 1 49 40 00 VI 149 I 1 49 32 PU 114 - 8 d 204-11 roposed er N PAtrPTH, ~r.Ç.. $ I Cù.'^" ORDER OF: " , U ¡ , \..)....J Ot1e~Lcv\ Cired:, G.V\~~~ DOLLARS Fl,rst National k Alaska· " Änchòrage, AK .99501 . M~r'rJ+.çQ€. '-ýYìPI~ I~, U {' ' , ,e ~ ' - ---- . 1:.25 2000bOI:1i1i ....··,b 227·.'. 5b"'"- 0.05 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡?7;?'úC ..-T~/t/ PTD# 20 t/- / /9' V-/ Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS 4'CLUE". APPLIES (OPTIONS) MULTI Tbe permit is for a new weJJbore segment of LATERAL e:xisting well , Permit No, API No. . (1f API number Production. sbould continue to be reponed as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. Pfi.,OT HOLE In accordance witb 20 MC 25.005(1), all (PH) records, data and Jogs acquired for tbe pilot hole must be clearly differentiated 'in both name (name on permit plus PH) and API number (SO - 70/80) from records, data and Jogs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compJiance witb 20 MC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Companv Name) assumes tbe JiabHity of any protest to tbe spacing .eJception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below the permafrost or from where sampJes are first caught and ] 0' sample inter:vaJs through target zones. PTD#: 2041190 Administration Well bore seg Annular Disposal D D Appr Date SFD 7/9/2004 Engineering Appr Date TEM 7/9/2004 ~~~ Geology Appr SFD Date 7/9/2004 Geologic Commissioner: (:J Ì'..s Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB 1-14 Program DEV Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV I PEND GeoArea 890 Unit 11328 On/Off Shore On 1 Pem,itfee attache.d_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease number _appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Surface Ipca_tion A\DL 25_906; Jop_prodJotand TD in_AQL2_55t7 _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nlque weltn_ame_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 We.IUocatedinad_efined-ppol_ _ _ . _ _ Yes_ _ _Schra_derBluffOiIFlool, governed byCOATZ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 5 WelUocaled prpper _dlstance from driJling unilbouod_ai:Y_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WelUocated pr_operdlstance_ from otber wells_ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ Yes 178 ,S_utficient.acreage_ayaitable indrilliog unjt. _ _ _ _ _ _ _ _ _ . . Yes _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Rdeviated, js_ weJlbo.re platiocJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _O-pe(atof onl}' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . . _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ 10 _O-Per_atof bas_apprppriate_ Qond lnJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit can be issued without conserva_tion order Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 Permilcanbelssuedwitboutadmioi!¡t(atille_appmvaL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 13 Can permit be approved before 15-day wait Yes 14 WellJocated wlthin area alld_strataauthorlzed byJlljectiplJ Order # (pullOtl inc_ommellts).(for NA " _ _ _ _ _ _ _ _ 115 _AJlweUsJlvit/linJl4J'Jile_are.a_ofreyiewid_elltified(Fpr~eNjc_ewellonlyL - - - - - - - - - - - - - - _NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 16 Pre-produçed injector; .duratio_n_of pre-pro.ductioo tess_ thall3 months_ (for service well onJy) _ _ NA _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 17 ACMP findjngof Con_sistellcy_h_as beenj~sued forJbis p(olect _ _ _ _ _ _ _ NA WeU drllled from exjsJiog pad_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ e - - - - - - 18 _C_onductor string provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ 19 Surface _ca~ingprotecJ~ alLknowll USQWs _NA _ M aquifer~ exempted 40 cm j 47_. 1021b)(3) _ 20CMTvpladeQuateJo circulate_oncood_ucto(& sur(csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMT vol adeQuateJo tie-in Jong _string to_surf csg_ _ _No _ _ _ _ _ _ _ _ 22 _CMT will coyeraJl koownpfoductiye borizon_s_ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Slolte_dJiller_completton ptallned. Intermediate ce_ment plan_ned 500' abpve any /lydrOC<lrbpos~ _ _ _ _ 23 _C_asillg design~ adeQua_te fpr C,T, B_&perroafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24A.dequateJankage_or fe_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig jSßquippedwith steel_pits. _ No reseJlle_pjt-planoed, AJI wa~te to_Class Jlw_ell(st _ _ _ _ _ _ _ 25 RaJe-drilt hasa 10c4.03 for abandonme_nt beell approved _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ 26 _A.dequatewellbofe~eparation-Pfopo~ed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. _ _ _ _ _ _l?rp~imlt}'anaIYsispertorme_d, Ç!ossaP-Pfo_achesjd_entified._Gyros_avaiJaþleJormagoeticinterfe(ance, _ _ _ _. __ 27 Rdiverter req_uired, does it.meet reguJatioos_ _ Yes _ _ _ _ _ _ _ 28 _Drillillg f!uid_ program schematic_& equip Jistadequate _ Yes _ Maxiroum BHI? 8._5_EMW,_expected _BHP _8A PJa_nned mud weights 9.0 -_ 9..3 for intermediate_hpleand 9.0 In OB._ 29 BOP¡::S,dpthey meet reguJatioo . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes BFI hasJequ_ested to-Pel1ormBQPJe~t~ on a 14- day inJel"llaJ.Approyal recpmmeoded._ _ _ _ _ _ . 30 _BOP¡::press fatillg appropriate; _testlo(puJ psig in _col)1meots)_ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ CalcuJa_ted_MASP., j 346psL P!anlled_BQP' testpre_ssure 3000 psi, _ _ _ _ _ _ ,31Chokeroanjfold compJie~ w/APt RF'-53 (May 64) _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur withoutoperationsbutdown _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ 33 J~ pre~enceof H2S gasprQb_able _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ No_ _ H2S ha_s_notQeeo prpdu_ced on Lp_ad._ Rig js_e_quippedwith sensors_alld alarm_s. _ _ _ _ _ _ _ _ _ _ _ _ _ 34 MecbanicaLc:podiUonpfwellswlthinA\ORyerified(for_servjceweUonly)_ _ _ _ _ _ _. _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ - - - - - ~ - - - - - - - - - - - -- . .. - - - - - - 35 Permit c_all be is~¡ued w/Q hyd(ogen sulfide meas.ures _ _ _ _ _ _ _ _ 36D_ata_pre.seoted on_ pote_ntial pverpre~sure _zones _ _ _ _ _ _ _ _ _ 37 _Seismic.analysjs of sbaJlow gas_zolle.s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38Seabedconditipll SUl"lley _(if off-shpœ) . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Conta_ct namelp/loneJor_weekly progress_reports [e¡cploratpi:Y _onlYl _ _ _ _ _ _ _ _ _ Yes _ __ _ _ _ Yes_ NA __ ___ _NA _ _ _NA_ _ Skip Coyner, BFI,_6/9104; No_H2S_kllown_io Schrader Bluff (eservoJrs aU-Pad._ _ _ _ _ _ _ _ _ _ _ Expected resel"llojr -pre_ssu.re is _8,5_ppg ¡::MW; will be drilled witb 9.0 ppg mud. _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Public w~ 7 /I<f~ e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplìfy finding information. infonnation 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. . Sperry-Sun Drilling Services LIS Scan Utility . cJ..() cf - 1fT $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 15 15:29:34 2004 ~. ¡ }Jg'? Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 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. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .....UNKNOWN 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 MPI-14 500202321400 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003214396 R. FRENCH D. GREEN MWD RUN 2 MW0003214396 R. FRENCH D. GREEN MWD RUN 3 MW0003214396 R. FRENCH D. 9REEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003214396 R. FRENCH D. GREEN MWD RUN 5 MW0003214396 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2348 4055 MSL 0) 68.16 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 109.0 2699.0 7618.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-14 (MWD RUN 5) EXITS FROM MPI-14 PB2 WELLBORE AT 8360 'MD/4025 'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 3 - 5 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 8/26/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. LATERAL WELLBORES WERE SHIFTED/CORRECTED TO THE MAIN MPI-14 WELLBORE. 7. MWD RUNS 1 - 5 REPRESENT WELL MPI-14 WITH API#: 50-029-23214-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9863 'MD/4033 'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name. .... ....... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. ... ..04/10/15 Maximum Physical Record. .65535 File Type.......... .... ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 66.5 109.5 2680.0 2680.0 2680.0 2680.0 2680.0 STOP DEPTH 9805.5 9863.0 9812.5 9812.5 9812.5 9812.5 9812.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 66.5 2710.0 7625.0 7700.5 8360.0 MERGE BASE 2710.0 7625.0 7700.0 8360.0 9863.0 # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction.... .............Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing..................... 60 .1IN Max frames per record... ......... .Undefined Absent value... .................. .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 66.5 2.66 5.71 0.05 0.1 0.06 1 0.1217 Max 9863 4436.19 133.47 1927.17 1899.36 2000 2000 41.7956 Nsam 19594 19508 19479 14266 14266 14266 14266 14266 Mean 4964.75 194.582 69.7392 14.3262 14.6699 21.1346 30.4322 0.970781 First Reading For Entire File...... ....66.5 Last Reading For Entire File.. ..... ....9863 First Reading 66.5 109.5 66.5 2680 2680 2680 2680 2680 Last Reading 9863 9863 9805.5 9812.5 9812.5 9812.5 9812.5 9812.5 . . File Trailer Service name.. .......... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/15 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...... .04/10/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 66.5 109.5 STOP DEPTH 2666.0 2710.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 04-AUG-04 Insite 66.37 Memory 2710.0 109.0 2710.0 .6 63.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120557 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13 . 500 109.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Spud Mud 9.20 128.0 7.5 400 9.0 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . .000 .000 .000 .000 .0 75.2 .0 .0 # 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.....O Logging Direction.. ....... ........Down Optical log depth units.......... .Feet Data Reference Point... ......... ..Undefined Frame Spacing.... ...... .......... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 66.5 2710 1388.25 5288 66.5 2710 ROP MWD010 FT/H 6.12 4436.19 144.853 5202 109.5 2710 GR MWD010 API 23.86 121.62 66.8563 5200 66.5 2666 First Reading For Entire File......... .66.5 Last Reading For Entire File....... ....2710 File Trailer Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .04/10/15 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... ... .04/10/15 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.002 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 2666.5 2680.0 2680.0 2680.0 2680.0 2680.0 2710.5 STOP DEPTH 7588.0 7580.5 7580.5 7580.5 7580.5 7580.5 7625.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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: $ # 08-AUG-04 Insite 66.37 Memory 7625.0 2710.0 7625.0 65.8 80.0 TOOL NUMBER 053519 134760 9.875 2699.0 LSND 9.25 44.0 8.0 250 7.2 6.000 3.960 9.000 6.000 64.0 100.4 64.0 64.0 . Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction..... '" ...... ...Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ..... ..Undefined Absent value.... ...... .......... ..-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 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 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2666.5 7625 5145.75 9918 2666.5 7625 ROP MWD020 FT/H 2.66 615.11 217.283 9830 2710.5 7625 GR MWD020 API 5.71 124.75 67.9886 9844 2666.5 7588 RPX MWD020 OHMM 1. 99 99.27 13.3685 9802 2680 7580.5 RPS MWD020 OHMM 1. 08 117.33 14.19 9802 2680 7580.5 RPM MWD020 OHMM 0.91 2000 16.049 9802 2680 7580.5 RPD MWD020 OHMM 1 2000 23.5247 9802 2680 7580.5 FET MWD020 HOUR 0.1217 41.7956 0.772805 9802 2680 7580.5 First Reading For Entire File.. ....... .2666.5 Last Reading For Entire File......... ..7625 File Trailer Service name......... ....STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/15 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...... .04/10/15 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: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPM RPS GR ROP $ .5000 START DEPTH 7581.0 7581.0 7581.0 7581.0 7581.0 7588.5 7625.5 STOP DEPTH 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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..................O Data Specification Block Type.....O Logging Direction... ...... ........Down Optical log depth units.......... .Feet Data Reference Point..... ........ . Undefined Frame Spacing... .... ...... ...... ..60 .1IN . 10-AUG-04 Insite 66.37 Memory 7700.0 7625.0 7700.0 89.0 103.0 TOOL NUMBER 91360 156401 6.750 7618.0 VersaPro 9.05 69.0 .0 38000 .0 .000 .000 .000 .000 .0 96.8 .0 .0 . . Max frames per record... ... .... ...Undefined Absent value................ ..... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7581 7700 7640.5 239 7581 7700 ROP MWD030 FT/H 9.26 325.65 212.381 150 7625.5 7700 GR MWD030 API 32.59 95.74 56.8237 224 7588.5 7700 RPX MWD030 OHMM 0.05 68.96 21.2779 239 7581 7700 RPS MWD030 OHMM 0.1 1899.36 35.3123 239 7581 7700 RPM MWD030 OHMM 0.06 2000 350.142 239 7581 7700 RPD MWD030 OHMM 2.63 2000 603.109 239 7581 7700 FET MWD030 HOUR 0.319 41. 112 16.2058 239 7581 7700 First Reading For Entire File.. ...... ..7581 Last Reading For Entire File.... ...... .7700 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type.......... .... ..LO Next File Name...... .... .STSLIB.005 Physical EOF File Header Service name.. .......... .STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD ROP GR 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7700.5 7700.5 7700.5 STOP DEPTH 8360.0 8360.0 8360.0 RPX RPM FET RPS $ . 7700.5 7700.5 7700.5 7700.5 8360.0 8360.0 8360.0 8360.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units... .... ....Feet Data Reference Point............. . Undefined Frame Spacing........ ... ........ ..60 .1IN Max frames per record............ .Undefined Absent value............ ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 11-AUG-04 Insite 66.37 Memory 8360.0 7700.0 8360.0 85.2 101.6 TOOL NUMBER 91360 156401 6.750 7618.0 Oil Based 9.10 83.0 .0 36000 .0 .000 .000 .000 .000 .0 104.0 .0 .0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 . . ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7700.5 8360 8030.25 1320 7700.5 8360 ROP MWD040 FT/H 9.16 896.97 190.234 1320 7700.5 8360 GR MWD040 API 40.75 133.47 87.4559 1320 7700.5 8360 RPX MWD040 OHMM 3.95 46.34 9.32436 1320 7700.5 8360 RPS MWD040 OHMM 4.02 44.61 9.10148 1320 7700.5 8360 RPM MWD040 OHMM 4.19 56.66 9.35614 1320 7700.5 8360 RPD MWD040 OHMM 4.4 51. 77 9.18475 1320 7700.5 8360 FET MWD040 HOUR 0.2804 10.5534 0.566225 1320 7700.5 8360 First Reading For Entire File......... .7700.5 Last Reading For Entire File........ ...8360 File Trailer Service name........ .....STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type. .............. .LO Next File Name......... ..STSLIB.006 Physical EOF File Header Service name........... ..STSLIB.006 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPD RPM RPS RPX GR FET $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 8340.5 8360.5 8360.5 8360.5 8360.5 8360.5 8360.5 STOP DEPTH 9863.0 9812.5 9812.5 9812.5 9812.5 9805.5 9812.5 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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.....O Logging Direction............ .....Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing... ................. .60 .1IN Max frames per record... ......... . Undefined Absent value....... ..... ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ll-AUG-04 . Insite 66.37 Memory 9863.0 8360.0 9863.0 82.3 95.5 TOOL NUMBER 91360 156401 6.750 7618.0 Oil Based 9.10 83.0 .0 36000 .0 .000 .000 .000 .000 .0 100.4 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWDOSO HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8340.5 9863 9101.75 3046 8340.5 9863 ROP MWD050 FT/H 8.18 1641. 24 205.211 3043 8340.5 9863 GR MWD050 API 43.94 119.36 73.7967 2891 8360.5 9805.5 RPX MWD050 OHMM 4.54 1927.17 19.2581 2905 8360.5 9812.5 RPS MWD050 OHMM 4.52 1843.56 17.1211 2905 8360.5 9812.5 RPM MWD050 OHMM 4.51 128.93 16.5781 2905 8360.5 9812.5 RPD MWD050 OHMM 4.55 62.94 16.2788 2905 8360.5 9812.5 FET MWD050 HOUR 0.2314 13.9968 0.569205 2905 8360.5 9812.5 First Reading For Entire File.... .... ..8340.5 Last Reading For Entire File. ..........9863 File Trailer Service name....... ......STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record..65535 File Type........ ..... ...LO Next File Name...... .....STSLIB.007 Physical EOF Tape Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name......... ...... . UNKNOWN Continuation Number.... ..01 Next Tape Name..... ......UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. .............. . UNKNOWN Continuation Number..... .01 Next Reel Name.. ........ . UNKNOWN Comments......... ...... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . Sperry-Sun Drilling Services LIS Scan Utility . c104-l/9 $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 15 14:36:35 2004 I dv 1D ~ Reel Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 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. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. ................ ..STS Tape Name........... .....UNKNOWN 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 MPI-14 PB1 500292321470 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003214396 R. FRENCH D. GREEN MWD RUN 2 MW0003214396 R. FRENCH D. GREEN MWD RUN 3 MW0003214396 R. FRENCH D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 l3N 10E 2348 4055 68.16 34.80 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 9.875 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 109.0 2699.0 7618.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-14 PB2 (RUN 4) EXITS FROM THIS WELLBORE AT 7700'MD/3999'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 8/26/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. LATERAL WELLBORES WERE SHIFTED/CORRECTED TO THE MAIN MPI-14 WELLBORE. 7. MWD RUNS 1 - 3 REPRESENT WELL MPI-14 PB1 WITH API#: 50-029-23214-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8427'MD/3916'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number........ ...1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.. .....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD 1 and clipped curves; all bit runs merged. .5000 START DEPTH 66.5 109.5 2680.0 2680.0 STOP DEPTH 8369.5 8426.5 8376.5 8376.5 . RPM RPS RPX $ 2680.0 2680.0 2680.0 8376.5 8376.5 8376.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 66.5 2710.0 7625.0 MERGE BASE 2710.0 7625.0 8426.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction.. ....... .... ....Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record....... ..... .Undefined Absent value. .................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 66.5 8426.5 4246.5 16721 66.5 8426.5 ROP MWD FT/H 2.66 4436.19 192.697 16635 109.5 8426.5 GR MWD API 5.71 133.62 68.7184 16607 66.5 8369.5 RPX MWD OHMM 0.05 99.27 13.2206 11394 2680 8376.5 RPS MWD OHMM 0.1 1899.36 14.1768 11394 2680 8376.5 RPM MWD OHMM 0.06 2000 22.3803 11394 2680 8376.5 RPD MWD OHMM 1 2000 34.1172 11394 2680 8376.5 FET MWD HOUR 0.1217 41. 7956 1. 06489 11394 2680 8376.5 First Reading For Entire File......... .66.5 Last Reading For Entire File.......... .8426.5 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/15 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..... ..04/10/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.. .....STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 66.5 109.5 STOP DEPTH 2666.0 2710.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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: 04-AUG-04 Insite 66.37 Memory 2710.0 109.0 2710.0 .6 63.4 TOOL NUMBER 120557 13.500 109.0 Spud Mud 9.20 128.0 7.5 400 9.0 .000 .000 .000 .000 .0 75.2 .0 .0 . . HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.. ....... ..Feet Data Reference Point............. . Undefined Frame Spacing...... ............ ...60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 66.5 2710 1388.25 5288 66.5 2710 ROP MWD010 FT/H 6.12 4436.19 144.853 5202 109.5 2710 GR MWD010 API 23.86 121.62 66.8563 5200 66.5 2666 First Reading For Entire File... .... ...66.5 Last Reading For Entire File.......... .2710 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation...... .04/10/15 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...... .04/10/15 Maximum Physical Record..65535 File Type.. ............. .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 2 .5000 . FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ START DEPTH 2666.5 2680.0 2680.0 2680.0 2680.0 2680.0 2710.5 STOP DEPTH 7588.0 7580.5 7580.5 7580.5 7580.5 7580.5 7625.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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 .1IN Max frames per record...... .......Undefined Absent value..... ............... ..-999 . 08-AUG-04 Insite 66.37 Memory 7625.0 2710.0 7625.0 65.8 80.0 TOOL NUMBER 053519 134760 9.875 2699.0 LSND 9.25 44.0 8.0 250 7.2 6.000 3.960 9.000 6.000 64.0 100.4 64.0 64.0 . . Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...o 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 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2666.5 7625 5145.75 9918 2666.5 7625 ROP MWD020 FT/H 2.66 615.11 217.283 9830 2710.5 7625 GR MWD020 API 5.71 124.75 67.9886 9844 2666.5 7588 RPX MWD020 OHMM 1. 99 99.27 13 .3685 9802 2680 7580.5 RPS MWD020 OHMM 1. 08 117.33 14.19 9802 2680 7580.5 RPM MWD020 OHMM 0.91 2000 16.049 9802 2680 7580.5 RPD MWD020 OHMM 1 2000 23.5247 9802 2680 7580.5 FET MWD020 HOUR 0.1217 41.7956 0.772805 9802 2680 7580.5 First Reading For Entire File........ ..2666.5 Last Reading For Entire File.... ...... .7625 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/15 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...... .04/10/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET 4 header data for each bit run in separate files. 3 .5000 START DEPTH 7581.0 7581.0 7581.0 7581. 0 7581.0 STOP DEPTH 8376.5 8376.5 8376.5 8376.5 8376.5 . GR ROP $ 7588.5 7625.5 8369.5 8426.5 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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.....O Logging Direction. ........ ....... . Down Optical log depth units........ ...Feet Data Reference Point............. . Undefined Frame Spacing...... ...... ........ .60 .1IN Max frames per record............ . Undefined Absent value............. ........ .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 10-AUG-04 Insite 66.37 Memory 8427.0 7625.0 8427.0 89.0 103.0 TOOL NUMBER 91360 156401 9.875 7618.0 VersaPro 9.05 69.0 .0 38000 .0 .000 .000 .000 .000 .0 .0 .0 .0 Offset o 4 8 Channel 1 2 3 . . RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7581 8426.5 8003.75 1692 7581 8426.5 ROP MWD030 FT/H 8.01 577.57 197.187 1603 7625.5 8426.5 GR MWD030 API 32.59 133.62 79.5092 1563 7588.5 8369.5 RPX MWD030 OHMM 0.05 68.96 12.31 1592 7581 8376.5 RPS MWD030 OHMM 0.1 1899.36 14.0952 1592 7581 8376.5 RPM MWD030 OHMM 0.06 2000 61.3618 1592 7581 8376.5 RPD MWD030 OHMM 2.63 2000 99.3359 1592 7581 8376.5 FET MWD030 HOUR 0.2916 41. 112 2.86328 1592 7581 8376.5 First Reading For Entire File......... .7581 Last Reading For Entire File.......... .8426.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name... ....... .UNKNOWN Comments. ............... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . Sperry-Sun Drilling Services LIS Scan Utility . ~()chl t( $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 15 15:14:13 2004 Reel Header ~" I"'.. , \' ~-1, qtJ Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 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. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin.................. .STS Tape Name............... . UNKNOWN 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 MPI-14 PB2 500292321471 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003214396 R. FRENCH D. GREEN MWD RUN 2 MW0003214396 R. FRENCH D. GREEN MWD RUN 3 MW0003214396 R. FRENCH D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003214396 R. FRENCH D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2348 4055 68.16 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13 .500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 109.0 2699.0 7618.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-14 (MWD RUN 5) EXITS FROM THIS WELLBORE AT 8360'MD/4025'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 3 & 4 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 8/26/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. LATERAL WELLBORES WERE SHIFTED/CORRECTED TO THE MAIN MPI-14 WELLBORE. 7. MWD RUNS 1 - 4 REPRESENT WELL MPI-14 PB2 WITH API#: 50-029-23214-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9450'MD/3951'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name....... ..... .STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type. ............ ...LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 66.5 109.5 2680.0 2680.0 2680.0 2680.0 2680.0 STOP DEPTH 9392.5 9450.0 9399.5 9399.5 9399.5 9399.5 9399.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 66.5 2710.0 7625.0 7700.5 MERGE BASE 2710.0 7625.0 7700.0 9450.0 # 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 .1IN Max frames per record............ . Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 66.5 2.66 5.71 0.05 0.1 0.06 1 0.1217 Max 9450 4436.19 133.47 99.27 1899.36 2000 2000 41.7956 Mean 4758.25 194.287 70.7386 12 . 967 13 .6975 20.6616 30.519 0.96855 First Reading For Entire File..........66.5 Last Reading For Entire File.......... .9450 Nsam 18768 18682 18653 13440 13440 13440 13440 13440 First Reading 66.5 109.5 66.5 2680 2680 2680 2680 2680 Last Reading 9450 9450 9392.5 9399.5 9399.5 9399.5 9399.5 9399.5 . File Trailer Service name..... ........STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/10/15 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...... .04/10/15 Maximum Physical Record..65535 File Type.......... .... ..LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 66.5 109.5 STOP DEPTH 2666.0 2710.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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) 04-AUG-04 Insite 66.37 Memory 2710.0 109.0 2710.0 .6 63.4 TOOL NUMBER 120557 13.500 109.0 Spud Mud 9.20 128.0 7.5 400 9.0 . MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 . .0 75.2 .0 .0 # 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 .1IN Max frames per record.. .......... .Undefined Absent value....... . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWDOI0 GR MWDOI0 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 66.5 2710 1388.25 5288 66.5 2710 ROP MWD010 FT/H 6.12 4436.19 144.853 5202 109.5 2710 GR MWD010 API 23.86 121.62 66.8563 5200 66.5 2666 First Reading For Entire File.... ......66.5 Last Reading For Entire File....... ....2710 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.. ........ .1.0.0 Date of Generation...... .04/10/15 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. .... ..04/10/15 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.002 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 2666.5 2680.0 2680.0 2680.0 2680.0 2680.0 2710.5 STOP DEPTH 7588.0 7580.5 7580.5 7580.5 7580.5 7580.5 7625.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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 08 -AUG-04 Insite 66.37 Memory 7625.0 2710.0 7625.0 65.8 80.0 TOOL NUMBER 053519 134760 9.875 2699.0 LSND 9.25 44.0 8.0 250 7.2 6.000 3.960 9.000 6.000 64.0 100.4 64.0 64.0 . Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point... .......... . Undefined Frame Spacing... ................. .60 .1IN Max frames per record............ . Undefined Absent value.... ................. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 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 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2666.5 7625 5145.75 9918 2666.5 7625 ROP MWD020 FT/H 2.66 615.11 217.283 9830 2710.5 7625 GR MWD020 API 5.71 124.75 67.9886 9844 2666.5 7588 RPX MWD020 OHMM 1. 99 99.27 13.3685 9802 2680 7580.5 RPS MWD020 OHMM 1. 08 117.33 14.19 9802 2680 7580.5 RPM MWD020 OHMM 0.91 2000 16.049 9802 2680 7580.5 RPD MWD020 OHMM 1 2000 23.5247 9802 2680 7580.5 FET MWD020 HOUR 0.1217 41. 7956 0.772805 9802 2680 7580.5 First Reading For Entire File........ ..2666.5 Last Reading For Entire File........ ...7625 File Trailer Service name........ .., ..STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/15 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...... .04/10/15 Maximum Physical Record..65535 File Type........... .... .LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 4 header data for each bit run in separate files. 3 .5000 # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ . START DEPTH 7581.0 7581.0 7581.0 7581.0 7581.0 7588.5 7625.5 STOP DEPTH 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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.....O Logging Direction. ............... . Down Optical log depth units.. ........ .Feet Data Reference Point.... ...... ....Undefined Frame Spacing.. .................. .60 .1IN Max frames per record............ . Undefined . 10-AUG-04 Insite 66.37 Memory 7700.0 7625.0 7700.0 89.0 103.0 TOOL NUMBER 91360 156401 6.750 7618.0 VersaPro 9.05 69.0 .0 38000 .0 .000 .000 .000 .000 .0 96.8 .0 .0 . . Absent value...... ............... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7581 7700 7640.5 239 7581 7700 ROP MWD030 FT/H 9.26 325.65 212.381 150 7625.5 7700 GR MWD030 API 32.59 95.74 56.8237 224 7588.5 7700 RPX MWD030 OHMM 0.05 68.96 21.2779 239 7581 7700 RPS MWD030 OHMM 0.1 1899.36 35.3123 239 7581 7700 RPM MWD030 OHMM 0.06 2000 350.142 239 7581 7700 RPD MWD030 OHMM 2.63 2000 603.109 239 7581 7700 FET MWD030 HOUR 0.319 41.112 16.2058 239 7581 7700 First Reading For Entire File......... .7581 Last Reading For Entire File.......... .7700 File Trailer Service name.. .......... .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.. .....04/10/15 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name....... ..... .STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type... .., ......... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7700.5 7700.5 7700.5 7700.5 STOP DEPTH 9399.5 9399.5 9399.5 9399.5 GR ROP FET $ . 7700.5 7700.5 7700.5 9392.5 9450.0 9399.5 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...... ....... ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 . ll-AUG-04 Insite 66.37 Memory 9450.0 7700.0 9450.0 85.2 101. 6 TOOL NUMBER 91360 156401 6.750 7618.0 Oil Based 9.10 83.0 .0 36000 .0 .000 .000 .000 .000 .0 104.0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 . . GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7700.5 9450 8575.25 3500 7700.5 9450 ROP MWD040 FT/H 7.54 1495.15 202.399 3500 7700.5 9450 GR MWD040 API 40.75 133.47 85.6203 3385 7700.5 9392.5 RPX MWD040 OHMM 2.53 60.62 11.2245 3399 7700.5 9399.5 RPS MWD040 OHMM 2.56 56.08 10.7571 3399 7700.5 9399.5 RPM MWD040 OHMM 2.64 76.49 10.7959 3399 7700.5 9399.5 RPD MWD040 OHMM 3.16 51.77 10.4276 3399 7700.5 9399.5 FET MWD040 HOUR 0.208 10.5534 0.461636 3399 7700.5 9399.5 First Reading For Entire File......... .7700.5 Last Reading For Entire File.......... .9450 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/10/15 Maximum Physical Record. .65535 File Type.. .... ....... ...LO Next File Name... ........STSLIB.006 Physical EOF Tape Trailer Service name....... ......LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. ...... ......LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File