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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, May 21, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 03-36B PRUDHOE BAY UNIT 03-36B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/21/2024 03-36B 50-029-22340-02-00 219-152-0 G SPT 8488 2191520 2122 2865 2867 2859 2851 179 388 307 270 4YRTST P Sully Sullivan 4/1/2024 This well has an OOA that was 0 psi throughout the test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 03-36B Inspection Date: Tubing OA Packer Depth 0 2345 2265 2239IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240401141745 BBL Pumped:2.4 BBL Returned:2.1 Tuesday, May 21, 2024 Page 1 of 1 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN 3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV /LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$& )LHOG3RRO V $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ 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If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU 03-36B Convert WAG to GI Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-152 50-029-22340-02-00 N/A ADL 0028327 & 0028328 16923 Conductor Surface Intermediate Production Liner 8878 76 3943 4534 8640 7521 16834 20" 13-3/8" 9-5/8" 7" 4-1/2" 8883 49 - 125 48 - 3991 46 - 4580 45 - 9564 9400 - 16921 49 - 125 48 - 3746 46 - 4127 45 - 8685 8555 - 8878 520 2260 4760 5410 7500 2300 5020 6870 7240 8430 12091 - 12208 4-1/2"12.6# 13Cr85 43 - 94068931 - 8857 Structural 4-1/2" HES TNT Perm Packer 4-1/2" MCX 9315, 2012 8488, 2012 Date: Bo York Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 10/11/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. None None By Meredith Guhl at 1:31 pm, Sep 30, 2021 321-522 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.29 10:13:23 -08'00' Bo York 10-404 DLB 10/01/2021 DSR-9/30/21MGR11OCT2021 X dts 10/11/2021 JLC 10/11/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.11 13:32:29 -08'00' RBDMS HEW 10/12/2021 MEMORANDUM TO: Jim Regg,tel /, P.I.Supervisor '\�G 41 jszo FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 6, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 03-368 PRUDHOE BAY UNIT 03-36B Sm: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT 03-36B API Well Number 50-029-22340-02-00 Inspector Name: Austin McLeod Permit Number: 219-152-0 Inspection Date: 4/3/2020 InSp Num: mitSAM200404072102 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 03-368 = Type Inj G • TVD 8488 - Tubing 2389 - 2399 ' 2400 2400 ' 2191520 'Type Test sPT Test psi 2122 IA 363 3000 - 2954 - 2943 Pumped: 2.5 BBL Returned: 2.5 OA 160 344 313 - 298 - Val iNnAL. —IPF P 1 Notes: Monday, April 6, 2020 Page I of I DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD/GR/RES, MWD/GR/RES/DEN/NEU, CMT EVALNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC4/6/20209360 14442 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run03_MEM_9570-14441_Depth.las32425EDDigital DataC4/6/202014366 15074 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run04_MEM_14441-15074_Depth.las32425EDDigital DataC4/6/202014942 15299 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run05_MEM_15074-15298_Depth.las32425EDDigital DataC4/6/202015224 16923 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run06_MEM_15299-16923_Depth.las32425EDDigital DataC4/6/20204574 16923 Electronic Data Set, Filename: 03-36B_BH_LTK_MEM_Composite Drilling Depth Data.las32425EDDigital DataC4/6/20204542 9570 Electronic Data Set, Filename: 03-36B_BH_OTK(8.5)_Run02_MEM_4516-9570_Depth.las32425EDDigital DataC4/6/20209451 14442 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run03_RLT_9570-14441_Depth.las32425EDDigital DataC4/6/202014358 15074 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run04_RLT_14441-15074_Depth.las32425EDDigital DataC4/6/202014982 15299 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run05_RLT_15074-15299_Depth.las32425EDDigital DataMonday, May 4, 2020AOGCCPage 1 of 903-,36B_BH_LTK_MEM_Composite Drilling Depth __Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/202015224 16923 Electronic Data Set, Filename: 03-36B_BH_LTK(6.125)_Run06_RLT_15299-16923_Depth.las32425EDDigital DataC4/6/20204574 16923 Electronic Data Set, Filename: 03-36B_BH_LTK_RLT_Composite Drilling Depth Data.las32425EDDigital DataC4/6/20204555 9570 Electronic Data Set, Filename: 03-36B_BH_OTK(8.5)_Run02_RLT_4614-9570_Depth.las32425EDDigital DataC4/6/20204541 16923 Electronic Data Set, Filename: 03-36B_BH_OTK-VSS_RLT-MEM_Composite Drilling Mechanics Depth.las32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_EOW_Letter.docx32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_EOW_Letter.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_2MD_Memory Drilling Log.cgm32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_2TVDSS_Memory Drilling Log.cgm32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_5MD_Memory Drilling Log.cgm32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_5TVDSS_Memory Drilling Log.cgm32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS_RLT-MEM_Composite Drilling Depth Log.cgm32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run01_AK_Depth Control Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run02_AK_Depth Control Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run03_AK_Depth Control Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run04_AK_Depth Control Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run05_AK_Depth Control Report.pdf32425EDDigital DataMonday, May 4, 2020AOGCCPage 2 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/2020 Electronic File: 03-36B_BH_Run06_AK_Depth Control Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_Mem_9570-14441_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run04_MEM_14441-15074_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_MEM_15074-15298_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_MEM_15299-16923_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_MEM_Composite Drilling Depth Data.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_MEM_4516-9570_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_RLT_9570-14441_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_RLT_15074-15299_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_RLT_15299-16923_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.126)_Run04_RLT_14441-15074_Depth.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_RLT_Composite Drilling Depth Data.dls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_RLT_4516-9570_Depth.dls32425EDDigital DataMonday, May 4, 2020AOGCCPage 3 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/2020 Electronic File: 03-36B_BHI_Mud Resistivity Report.xls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_2MD_Memory Drilling Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_2TVDSS_Memory Drilling Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_5MD_Memory Drilling Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_5TVDSS_Memory Drilling Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_2MD_MEM_4614-9570_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_2TVDSS_MEM_4074-8616_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_5MD_MEM_4614-9570_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_5TVDSS_MEM_4074-8616_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_2MD_MEM_9570-14441_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_2TVDSS_MEM_8616-8840_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_5MD_MEM_9570-14441_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_5TVDSS_MEM_8616-8840_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run04_2MD_MEM_14441-15074_Log.pdf32425EDDigital DataMonday, May 4, 2020AOGCCPage 4 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run04_5MD_MEM_14441-15074_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: Read Me.txt32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_2MD_MEM_15074-15298_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_2TVDSS_MEM_8835-8845_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_5MD_MEM_15074-15298_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_5TVDSS_MEM_8835-8845_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_2MD_Mem_15299-16923_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_2TVDSS_Mem_8845-8804_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_5MD_Mem_15299-16923_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_5TVDSS_Mem_8845-8804_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_2MD_Memory Drilling Log.cgm.meta.PDF32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_2TVDSS_Memory Drilling Log.cgm.meta.PDF32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_5MD_Memory Drilling Log.cgm.meta.PDF32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK_5TVDSS_Memory Drilling Log.cgm.meta.PDF32425EDDigital DataMonday, May 4, 2020AOGCCPage 5 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_2MD_RLT_4614-9570_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_2TVDSS_RLT_4074-8616_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_5MD_RLT_4614-9570_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK(8.5)_Run02_5TVDSS_RLT_4074-8616_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_2MD_RLT_9570-14441_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_2TVDSS_RLT_8616-8840_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_5MD_RLT_9570-14441_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run03_5TVDSS_RLT_8616-8840_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run04_2MD_RLT_14441-15074_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run04_5MD_RLT_14441-15074_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: Read Me.txt32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_2MD_RLT_15074-15299_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_2TVDSS_RLT_8834-8845_Log.pdf32425EDDigital DataMonday, May 4, 2020AOGCCPage 6 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_5MD_RLT_15074-15299_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run05_5TVDSS_RLT_8834-8845_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_2MD_RLT_15299-16923_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_2TVDSS_RLT_8804-8853_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_5MD_RLT_15299-16923_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_LTK(6.125)_Run06_5TVDSS_RLT_8804-8853_Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS_RLT-MEM_Composite Drilling Mechanics_Depth log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS(6.125)_Run03_MEM_RLT_9570-14441_Time Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS(6.125)_Run04_MEM_RLT_14441-15075_Time Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS(6.125)_Run05_MEM_RLT_15075-15298_Time Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS(6.125)_Run06_MEM-RLT_15299-16923_Time Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS(8.5)_Run01_MEM_RLT_4580-4614_Time Log.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_OTK-VSS(8.5)_Run02_MEM_RLT_4614-9570_Time Log.pdf32425EDDigital DataMonday, May 4, 2020AOGCCPage 7 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesC4/6/2020 Electronic File: 03-36B_BH_Run01_Rig Activity Code Time.xlsx32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run02_Rig Activity Code Time.xlsx32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run03_Rig Activity Code Time.xlsx32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run04_Rig Activity Code Time.xlsx32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run05_Rig Activity Code Time.xlsx32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Run06_Rig Activity Code Time.xlsx32425EDDigital DataC4/6/2020 Electronic File: BHI Rig Activity Codes description.xls32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_ADV_Final Survey Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Final Surveys Report.csv32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Final Surveys Report.pdf32425EDDigital DataC4/6/2020 Electronic File: 03-36B_BH_Final Surveys Report.txt32425EDDigital DataC4/6/2020 Electronic File: AOGCC - Offsets within 500ft - 03-36B Final Survey.pdf32425EDDigital Data0 0 2191520 PRUDHOE BAY UNIT 03-36B LOG HEADERS32425LogLog Header ScansDF4/30/2020 Electronic File: 03-36B_RBT_26FEB20.pdf32856EDDigital DataDF4/30/2020 Electronic File: 03-36B_RBT_26FEB20_FreePipe.dlis32856EDDigital DataDF4/30/2020 Electronic File: 03-36B_RBT_26FEB20_img.tiff32856EDDigital DataDF4/30/2020 Electronic File: 03-36B_RBT_26FEB20_Main.dlis32856EDDigital DataDF4/30/2020 Electronic File: 03-36B_RBT_26FEB20_Repeat.dlis32856EDDigital Data0 0 2191520 PRUDHOE BAY UNIT 03-36B LOG HEADERS32856LogLog Header ScansMonday, May 4, 2020AOGCCPage 8 of 9 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22340-02-00Well Name/No. PRUDHOE BAY UNIT 03-36BCompletion StatusWAGINCompletion Date3/18/2020Permit to Drill2191520Operator BP Exploration (Alaska) Inc.MD16923TVD8878Current StatusWAGIN5/4/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:3/18/2020Release Date:12/6/2019Monday, May 4, 2020AOGCCPage 9 of 9M. Guhl5/4/2020 1a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service 5 BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 219-152 2/8/2020 2/22/2020 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 906' FSL, 899' FWL, Sec. 11, T10N, R15E, UM 1794' FSL, 2247' FWL, Sec. 11, T10N, R15E, UM 1663' FSL, 2627' FEL, Sec. 03, T10N, R15E, UM Surface: x- y- Zone -714172 5936972 ASP 4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG 5 WDSPL No. of Completions: 3/18/2020 15. 50-029-22340-02-00 16. PBU 03-36B Well Name and Number: 16834' / 8883' 26.80 17. TPI:y- Zone -715493 ASP 4x-5937898 Total Depth: x-y-Zone -710469 ASP 45942906 16923' / 8878' 2012' / 2012' DNR Approval Number:19. 74-017 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR / RES, MWD / GR / RES / DEN / NEU, Cement Evaluation CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 9-5/8" 7" 4-1/2" 94# 68# 47# 26# 12.6# NT-80 NT80S L-80 13Cr85 49' 46' 45' 9400' 4580' 9564' 16921' 49' 46' 45' 8555' 8685' 4127' 8878' 6-1/8" 8-1/2"x9-7/ 12-1/4" 281 cu ft Arctic Set 1210 sx Class 'G' 741 sx LiteCrete, 116 sx Class 'G' 806 sx Acid Soluble Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# 13Cr85 9406' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: March 31, 2020 Gas Injection Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 100' Open to production or injection?Yes 5 No 24. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9656' 8756' 13306' 8920' 16215' 8924' 10186' 8970' 13419' 8920' 16700' 8893' 10302' 8969' 13881' 8919' 16808' 8885' 10835' 8958' 13991' 8917' 10951' 8956' 14500' 8913' 11443' 8947' 14610' 8913' 11559' 8943' 15010' 8908' 12091' 8931' 15120' 8909' 12208' 8930' 15436' 8925' 12699' 8920' 15546' 8926' 12816' 8920' 16106' 8926' NT60LE 125'30"20" 13-3/8"48'3991'16"1517 sx CS III, 400 sx Class 'G', 165 sx CS II48'3746' 9315' / 8488' Freeze Protect w/ 5 Bbls Diesel Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 125' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028327 & 028328 Other 12. SSSV Depth (MD/TVD): FracPort Sleeves 2/24/2020 Ref Elevations BF 26.80 (attached)5 KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 76.80 Water Depth, if Offshore:13. N/A One API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, 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 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 4580' / 4127' 1900' (Approx.) Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 6:24 pm, Apr 16, 2020 Completion Date 3/18/2020 HEW RBDMS HEW 4/17/2020 G MGR24APR20 DSR-4/17/2020DLB 04/20/2020 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Minge, David Contact Email: David.Minge@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 9075645279 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level 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. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. 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. 5618' 7150' 7612' 9289' 9530' 9557' 9593' 9750' 9846' 9949' 4967' 6483' 6943' 8467' 8658' 8680' 8708' 8820' 8876' 8923' Ugnu West Sak Colville Mudstone HRZ Base of HRZ Shublik / LCU Sadlerochit - Zone 4B 42SB - Zone 4A CGL - Zone 3 Base of CGL - Zone 2C Zone 2C 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 9949'8923' Top of Productive Interval 9593'8708' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31.List of Attachments:LOT / FIT Summary, Summary of Daily Drilling Reports, Summary of Post-Rig Work, Survey, Cement Report, Wellbore Schematic'LDJUDP 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. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.04.16 16:37:03 -08'00' Test Date Test Type Test Depth (TMD-Ft) Test Depth (TVD-Ft) AMW (ppg) Surface Pressure (psi) Leak Off Pressure (BHP) (psi) EMW (ppg) 02/08/20 LOT 4,580.00 4,127.29 9.30 975.00 2,969.24 13.85 Well Name: 03-36B BP AMERICA LOT / FIT Summary Page 1 of 1 !"! # !$ % &'('&& )% 2 3 4 '0 &/& 5)% ' *''-++-&6 4 7 4 % 889!0 3!83-*( ) 5 3&/&:/0(57;# < 6 $ 4 -;&= 1 % #57;$ ) 7> % 7 ;! 7"7 #$ % 7 &'*'&& 89% 0= 9 89%!! 8! 8% " 891!! ?!@ "% 8 %8! 8 ! 8 6!%3. 9!%% 1! 896!@ 0=-*-- 6! 0= 6!@ 891 !6A % !!,!+0=-* &'='&& 6! 0= 6!@ 891 !6 "!,! !% -&0-& 6! 0= ! 6!%3 13 8! ! 8! !! 89 !@ 8933 88 ?6!%8"%%8 ! 89363%6!%8"%%8 ! *0--& 893 0= 9 893! 8! 8% 8B=*!11 8% 891!! 8936 8% 3 !3"3" 8 1!8 ! 66 %6C36 %68 ! 8 8 ! ! ! 3 898 ! .8 . 6 ! 89 1!! 8 "89" 3 63%C6 A36 "!! 891!! 89" -=& %8%?"! 38! 8%%!."9 8%8. ! ! ! !% 8@ 8 % ! 6"8! ? 6 893 !9.!1186!3"!. 8 !!1? 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" #$ % & '(')('' *& '('+('' 4 5 # 6 (2##'0' 7*& ( )((.,,.'! # 6# 8 # 6 ##c: 2 5 95.)+ * 7 5'0';02+78<$ = ! % 6 < 3 & $78<% * 8> & 8 < 8"8 $% & 8 "5# ./,'2 95&#A" # ":# 9! :##9:& '2'' #5! '('+('' "5# ./,'2 95 "&#A" # #9:5 " #&& # B 9& .2. #5! "5# ./,'2 #9:5& "& #B 9& )193 #.1!9$% # B&A $5& % #5# # )193 #1 !9$B95 9:" % &5## 9! :##9:& LLL##9:3# ! ;)LLL 2). #5! * .11.!)(.1('' ACTIVITYDATE SUMMARY 2/28/2020 T/I/O/OO= 0/0/0/0 POST PARKER 272 R/D IA Piggyback Temp#03 & installed tapped blind. Torqued IA Tapped blind to 253ft lbs. R/D OA Piggyback Temp#102 & installed tapped blind. Torqued OA Tapped blind to 253ft lbs. R/D OOA Piggyback Temp # 30 & installed tapped blind. Torqued OOA Tapped blind to 253ft lbs. PT'd IA Blind against gate to 2500psi. PT'd OA Blind against gate to 2500psi. PT'd OOA Blind against gate to 2500psi. R/D Dry hole Temp valve #126. Installed new upper production tree. Torqued THA x MV to 553 ft lbs. Torqued MV x SSV to 752 ft lbs. R/U CIW lubricator 839 w/ 4" H Pulling tool. PT'd tree against TWC Low 300psi, High 5000psi. Pulled 4" H TWC #444 @ 130". R/D CIW lubricator & installed tree cap. PT'd tree cap to 500 psi. RDMO ***Job Complete*** FWHP= 0/0/0/0 3/3/2020 T/I/O = Vac/0/130/80. Temp = SI. Eval Frozen Tbg/IA. TBG FL @ surface. IA FL @ surface. Pumped 2 bbls 100% Meoh into the IA taking 1 to 1 returns to BT from the tubing. Pumped 2 bbls 100% Meoh to tubing taking 1 to 1 returns from the IA. Max well pressure was 100 psi during pumping. Final WHPs = 40/50/130/80. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 17:40. 3/4/2020 T/I/O= 41/56/119 Temp= S/I Circ out Brine / Freeze Protect (SIDETRACK) Pre-heat diesel to 90*, Pumped 3 bbls 60/40 down hard line to verify flow path to OTT and IA. Pumped 85 bbls 90* diesel down TBG taking returns up IA to OTT, pumped 2 bbls 60/40 down hard line to FP, U-tube TxIA for 30 min. Tags hung, DSO notified of well status . WV,SV,SSV= C MV=O IA,OA= OTG FWHP's=65/72/147 3/15/2020 ***WELL S/I ON ARRIVAL*** (Sidetrack) SWCP 4516 RIG UP ***CONTINUE JOB ON 03/16/2020*** 3/15/2020 T/I/O = 0/0/136 Temp - SI. LRS Unit #46 Assist SLB Slickline (SIDETRACK). Pumped 5 BBL's of DSL to pressure test the flowline to 2000 psi, lost 77 psi in 30 minutes. *** JOB CONTINUED ON 16-MAR-2020**** 3/16/2020 *** Job continued from 03/15/2020*** Assist SLB with Packer Set (SIDETRACK). MIT- T to 3867 psi ***PASS*** MIT-IA to 3915 psi ***PASS*** Pumped 2.5 bbls 60/40 into the hardline to verify flowpath to OTT. Pumped 5 bbls 60/40, 176 bbls 120* 1% KCL, 185 bbls 120* CI KCL into IA, tanking returns up the TBG to the OTT. Pumped 85 bbls 80* Diesel into IA for FP. U-Tubed for IA x TBG for 1 hour. Pumped 2.3 bbls DSL down Tbg for MIT-T. Took Tbg to 4008 psi. Tbg lost 95 psi in the 1st 15 mins and 46 psi in 2nd 15 mins for a total loss of 141psi in 30 min test. PASS Pumped 3.3 bbls DSL down IA for MIT-IA. Took IA to 4016 psi. IA lost 73 psi in the 1st 15 mins and 28 psi in the 2nd 15 mins for a total loss of 101 psi in 30 mins tes. PASS. Slickline in control of well per LRS departure. FWHP's=70/50/120/100 SV,WV,SSV=C MV=O IA,OA,OOA=OTG ***Tags hung on MV and IA ***AFE sign already on well Daily Report of Well Operations PBU 03-36B Daily Report of Well Operations PBU 03-36B 3/16/2020 ***CONTINUE JOB FROM 03/15/2020*** (sidetrack) LRS CIRCED IN FLUIDS FOR PACKER SET DEPLOY BALL & ROD ON 4-1/2" RHC-M BODY AT 9,349' MD LRS SET 7" x 4-1/2" HES TNT PACKER AT 9,315' MD LRS PERFORMED SUCCESSFUL MIT-T TO 3,867psi LRS PERFORMED SUCCESSFUL MIT-IA TO 3,915psi PULL BALL & ROD & 4-1/2" RHC-M BODY FROM 9,349' MD ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 3/17/2020 CTU#9 1.75" CT. Job Scope: Drift / Open Slv's & Acidize. MIRU CTU. MU & RIH w/ Baker 3.79" "NCS Drift" BHA. Rih while circulating safelube. Hard Tag at 14981'. Unable to get thru pumping and not pumping. Pooh laying in 1% KCL w/ Safelube + F103. Freeze Protect Coil. Make up NCS Shifting Tools. ***Continue Job on 3/18/20 WSR*** 3/18/2020 CTU#9 1.75" CT. Job Scope: Drift / Open Slv's & Acidize RIH w/ NCS Shifting Tools. Take pipe displacement while rih. Locate top two Slv's and correct depth. Open Slv #17. Pump 21 bbls of 15% HCl in 2 stages with pre, mid, and post injectivity tests. Open Sleeve #18 (with sleeve #17 isolated) and pump 28 bbls of 15% HCl in 2 stages with pre, mid, and post injectivity tests. RIH so BHA is below sleeves and perform final injectivity test into both sleeves. During test well exhibited "charging" of formation and stable injectivy of 1.3 bpm at 2000 psi. Target was 2.0 bpm at 2000 psi. Discuss results with APE. Set BHA in open sleeve #18, with #17 isolated, and perform HPB of 3000 psi. Pressure never broke down and rate was slowly decreased to maintain 3000 psi until stable at 1.6 bpm. Decision to POOH. FP Well and RDMO. ****Job Complete*** 3/25/2020 ***WELL S/I ON ARRIVAL***(sidetrack) DRIFT W/ 2.30" CENT, 1 1/2" S BAILER, STOP @ 9,900' SLM (no issues) RAN SBHPS PER PROGRAM, USED +40' CORRECTION FROM TUBING TALLY (see data tab) BRUSHED SSSV NIPPLE @ 2012' MD SET 4-1/2" MCX SER#BPX-473 (1.125" bean, secondary lock down) CHECK SET INDICATED GOOD SET ***WELL S/I ON DEPARTURE*** 3/28/2020 T/I/O=0/0/155 Temp=SI Injectivity Test (SIDETRACK) Arrive on location rig up and pressure test. ***WSR Continued on 03-29-2020*** 3/29/2020 ***WSR Continued from 03-28-2020*** Pumped 10 bbls 60/40 followed by 40 bbls DSL and 5 bbl 60/40 spacer. Pumped 460 bbls 1% KCL to establish injectivity. Refer to log for details. After 15 minute shutdown performed step rate test: .5 BPM ~ 515 psi 1.0 BPM ~ 1120 psi 1.5 BPM ~ 1570 psi 2.0 BPM ~ 1840 psi 2.5 BPM ~ 2020 psi. Pumped 2 bbls 60/40 followed by 38 bbls DSL down TBG for FP. Valve Positions=SV, WV,SSV closed MV open CV's OTG FWHP=0/0/300 Daily Report of Well Operations PBU 03-36B 3/31/2020 T/I/O = 2800/30/500. Temp = 114°. Assist Ops (POI). On MI Inj. IA, OA & OOA FLs @ surface. Monitored WHPs & bled annuli as needed. WHPs = 2780/750/240/40. SV, WV,SSV, MV = O. IA, OA, OOA = OTG. ***Job in progress. Continued on 4/1/20 AWGRS*** 4/1/2020 ***Job in progress. Continued from 3/31/20 AWGRS*** T/I/O/OO = 2780/750/240/40. Temp = 114°. Assist OPs w/ POI. On MI inj. Continued to monitor WHPs & bleed annuli as needed. Final WHPs = 2770/360/200/50. SV = C. WV, SSV, MV = O. IA, OA, OOA = OTG. 4/2/2020 T/I/O/OO = 2770/790/310/250. Temp = 122°.IA FL (pre AOGCC MIT). On MI. IA, OA, OOA FLs @ surface. SV = C. WV, SSV, MV = O. 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"' ( ) *+ ) $ , , - ' ( !"#"$#%&'( - )* + ', -* . ) !"#"$#%&'( ) / ! ( 3)5+ 3)5102 ,3)51 2 3)5"' ( '!! 46+4% 46.4%+ .6"%.#"+% # ! 46+&% 46."#%"& .6".%"".%." - ! (/ ' ,. 6="% &6&##%+4 6+%+# 6#%# F !* WELL NAME Date : Shoe @ :FC @ :Top Liner @ : Type: Type : Type : Type : Type : XYes No Yes X No Yes X No Yes X No Yes X No Date : Volume lost during displacement (bbls) : Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : 9 bbl Reciprocated? % Returns during job : 95 Cement returns to surface? Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : Method Used To Determine TOC : CBLFIRST STAGE9564' MD 9478' MD Preflush (Spacer) Density (ppg) : Casing Rotated? N/A 23.9Unislurry LiteCrete Volume (bbls): 186 Yield : 1.41 Cement In Place At : 0.68 2/13/2020 Estimated TOC : 4600' MD 0 Volume (actual / calculated) : 209.4 FCP (psi) : 1105 Pump used for disp : Rig Plug Bumped? Bump press : 1615 2-Jan Sacks : 115.6780603 6 Post Flush (Spacer) N/A Yield : 1.16 Displacement : LSND Density (ppg) : 10.6 Rate (bpm) : 15.8 40 13 Lead Slurry MUDPUSH II Density (ppg) : 11 Volume pumped (bbls) : Sacks : 740.6361702 Mixing / Pumping Rate (bpm) : 6 Tail Slurry Remarks: 03-36Bi CEMENT REPORT 7" Intermediate 2/13/2020 Hole Size :9-7/8"Casing Size :7" WELL NAME Date : Shoe @ : FC @ :Top Liner @ : Type: Type : Type : Type : Type : XYes No Yes X No Yes X No X Yes No X Yes No Date : Volume lost during displacement (bbls) : Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : 12 bbl Reciprocated?% Returns during job :95 Cement returns to surface?Spacer returns?Vol to Sur : Density (ppg) :Rate (bpm) : Volume (bbls) : Method Used To Determine TOC :Returns to surface at bottoms up from liner topFIRST STAGE16921' MD 16877' MD Preflush (Spacer) Density (ppg) : Casing Rotated? 9400' MD 179Acid Soluble N/A Volume (bbls): Yield : Cement In Place At :0.24 2/26/2020 Estimated TOC :9,400 40 bbl Volume (actual / calculated) :209.4 FCP (psi) :3100 Pump used for disp : Cement Plug Bumped?Bump press :3600 3 Sacks : 797.6154762 3 Post Flush (Spacer) N/A Yield : 1.26 Displacement : Quickdril-N Density (ppg) :8.7 Rate (bpm) : 15 30 Lead Slurry MUDPUSH II Density (ppg) :12 Volume pumped (bbls) : Sacks : #DIV/0!Mixing / Pumping Rate (bpm) : Tail Slurry Remarks: 03-36Bi CEMENT REPORT 4 1/2" Production 2/26/2020 Hole Size :6-1/8"Casing Size :4-1/2" Date: 4/30/2020 Transmittal Number: 93754 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 The digital zip file for the well log package listed below is being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format 03-36B 02/26/2020 Schlumberger Radial Bond Tool Cement Log Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ DNR https://drop.state.ak.us/drop/ Received by the AOGCC 04/30/2020 PTD: 2191520 E-Set: 32856 Date: 4/3/2020 Transmittal Number: 93739 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Digital zip files for the well log packages listed below are being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format 03-20B 3/13/2020 Baker Hughes Gamma Ray, Multiple Propagation Resistivity Ray 2” & 5” MD & TVDSS, Memory Logs; Final Deviation Survey Data Zip File 03-27A 3/04/2020 Baker Hughes Gamma Ray, Multiple Propagation Resistivity Ray 2” & 5” MD & TVDSS, Memory Logs; Final Deviation Survey Data Zip File 03-36B 2/23/2020 Baker Hughes Compensated Bulk Density, Neutron Porosity, Multiple Propagation Resistivity, Gamma Ray 2” & 5” MD & TVDSS, Memory Logs; Final Deviation Survey Data Zip File J-31 1/29/2020 Baker Hughes Compensated Bulk Density, Neutron Porosity, Multiple Propagation Resistivity, Gamma Ray 2” & 5” MD & TVDSS, Memory Logs; Final Deviation Survey Data Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ DNR https://drop.state.ak.us/drop/ Received by the AOGCC 04/06/2020 PTD: 2191520 E-Set: 32425 THE STATE V 0 1 10111 GOVERNOR MIKE DUNLEAVY David Bjork Senior Completion Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-36B BP Exploration (Alaska), Inc. Permit to Drill Number: 219-152 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Surface Location: 906' FSL, 899' FWL, SEC. 11, TION, RI 5E, UM Bottomhole Location: 1552' FSL, 2645' FEL, SEC. 03, TI ON, R15E, UM Dear Mr. Bjork: Enclosed is the approved application for the permit to redrill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jer m rice Cha DATED this �; day of December, 2019. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMISS, PERMIT TO DRILL 20 AAC 25.005 E I V E D NOV 01 2019 1a. Type of Work:1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG 0 ' Service - Disp❑ 1c. Specify if well is proposed for: Drill ❑ Lateral C3Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ElSingle Zone 0 Coalbe str es ❑ Redrill 0 , Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket RI Single Well ❑ 11 Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 PBU 03-36B Address: 3. 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchoracie. AK 99519-6612 MD: 16836' ' TVD: 8895' PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028327 & 028328 Surface: 906' FSL, 899' FWL, Sec. 11, T10N, R15E, UM ° 8. DNR Approval Number: 13. Approximate spud date: Top of Productive Horizon: 1788' FSL, 2257' FWL, Sec. 11, T10N, R15E, UM 74-017 January 10, 2020 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 1552' FSL, 2645' FEL, Sec. 03, T10N, R15E, UM 18300 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 74.15 feet 15. Distance to Nearest Well Open to Same Pool: Surface: x- 714172 ' y- 5936972 Zone - ASP 4 GL Elevation above MSL: 27.00 " feet 270 16. Deviated wells: Kickoff Depth: 4553 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 degrees Downhole: 3325 • Surface: 2433 ' 18 Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantitv, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD(including stage data 9-7/8" 7^ 26# L-80 VamTop HC 9558' Surface Surface 9558' 8681' 657 sx LiteCrete. 124 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 7428' 9408' 8561' 16836' 8895' 755 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 10423, Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 15365 9043 12600,12980,14180,14650 10423 8552 None Casing Length Size Cement Volume MD TVD Conductor/Structural 76 20" 281 cu ft Arctic Set 31 - 107 31 -107 Surface 3943 13-3/8" 1517 sx CS III, 400 sx Class'G' 165 sx CS II 30-3973 30-3728 Intermediate 4728 9-5/8" 1210 sx Class'G' 28-4756 28-4230 Liner 5989 T' 579 sx LiteCrete. 166 sx Class'G' 4599 - 10588 4132-8662 Liner 4947 4-1/2" 605 sx Class'G' 10416 - 15363 8548-9043 Perforation Depth MD (ft): 12300 - 15110 Perforation Depth TVD (ft): 9036-9047 Hydraulic Fracture planned? Yes ❑ No 0 ° 20. Attachments Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21 Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Nocas. Noel from without prior written approval. Authorized Name Bjork, David Contact Email Noel.NocasC5_bp.com Authorized Title Senior Completion Engineer Contact Phone +1 9075645027 Authorized Signature. Date Commission Use Only Permit to Drill " API : 50-029-22340-02-00 Permit Approval See cover letter for other Number—! / ! G Date: 1 requirements: Con itions of approval : If box is checked, well may not be used to ex 1 re for, (rest, or produce coalbed methane, gash rate , or gas contained in shales: �jGp � ��� �tg � 0th tib — Sam Iles rreq'd: Yes ❑ No C Mud log req'd: Yes ❑ No H2S measures Yes 11 No ❑ Directional svy req'd: Yes in/ No E❑ ex Spacing do req'd: Yes ❑ No [3 Inclination -only svy req'd: Yes ❑ No 12 `Post initial injection MIT req'd: Yes El El ae � '� J „ 1� � �-�4 CCC3 ai Y11eK."� � - 49ti.! �C'.a.S 4�e, S`'JAPP V a.r�by: OVE BY Approved COMMISSIONER Im THE COMMISSION Date:�a 0 Form 10-401 Revised 5/2 T is permit is valid for 24 monthOR4614k. C 25.005(g)) Submit Form and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Noel Nocas, ODE Date: October 31, 2019 RE: 03-36B Permit to Drill The 03-36B well is scheduled to be drilled by Parker 272 in January 2020. The proposed 03-36B sidetrack will be a horizontal injector targeting the 26P "Victor" Package in the Sadlerochit. The planned well is a two string sidetrack design using 7" intermediate casing and 4-1/2" production liner. The intermediate casing will be set at the top of the Shublik limestone, and the injection interval will be completed with a cemented liner using sliding sleeves. The maximum anticipated surface pressure from the Ivishak with a full column of gas from TD to surface is 2,433 psi (assumes 7.17 ppg EMW most likely pore pressure and a 0.1 psi/ft gas gradient). The well will be drilled by Parker 272 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams will be tested to 5000psi initially, and 4000psi on subsequent tests. The annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. If there are any questions concerning 03-36B, please do not hesitate to use the contact information below. Noel Nocas Office: (907) 564-5027 Cell: (907) 229-9532 Email: noel.nocas@bp.com Attachments: Well Bore Schematic Proposed Pre -Rig Schematic Proposed Completion Directional Package BOPE Schematic As -Staked Survey Area Review Map 03-36B PTD 1 10/31/2019 Planned Well Summary Well 03-36B Well Injector Target Sadlerochit Type Objective Current Status Injector (Shut -In) Estimated Start Date: 1 01/10/20 Time to Complete: 26 Da s Appx.Northing Northing Easting Offsets TRS Surface 5936971.55 714172.22 899 FWL F1ON15ESec11 Locationf�� 10N 15E Sec 11 Nearest Property Line: 906' FSL Nearest Well within Pool: Planned KOP: 4480'-4550'MD Planned TD: 16,836' MD / 8,820' TVDss Rig: Parker 272 GL -RT: 47.15 RTE ref MSL : 74.15 Directional - BHGE WP08A Maximum Hole Angle: Northing Easting TVDss Offsets TRS TSAD 5937891.83 715503.50 8630' 2257' FWL 10N 15E Sec 11 Nearest Property Line: 18,300' Nearest Well within Pool: -270' 1788' FSL BHL 5942795.56 710453.83 8820' 2645' FEL 10N 15E Sec 3 1552' FSL Planned KOP: 4480'-4550'MD Planned TD: 16,836' MD / 8,820' TVDss Rig: Parker 272 GL -RT: 47.15 RTE ref MSL : 74.15 Directional - BHGE WP08A Maximum Hole Angle: -51' in the intermediate section -94° in the production section All offset wells pass BP anti -collision scan criteria, but some offsets Close Approach Wells: must be shut-in to pass scan criteria - reference "Surface and Anti - Collision Issues" section. Survey Program: Reference attached directional program Nearest Property Line: 18,300' Nearest Well within Pool: -270' Hydraulic Fracture Planned? No 03-36B PTD 2 10/31/2019 Formation Tops and Pore Pressure Estimate Formation Estimated Formation Top TVDss Most Likely Pore Pressure EMW SV3 3610 8.4 SV2 3810 8.4 SV1 4243 8.4 UG4 4900 9.3 UG3 5028 9.3 UG1 5878 9.3 WS3 6389 9 WS2 6603 9 CM3 6867 9.3 CM2 7343 9.8 CM1 8032 10 HRZ 8391 10 TSHU 8596 7.12 TSAD 8627 7.13 42N 8733 7.14 42P 8770 7.15 TCGL 8800 7.16 BCGL 8847 7.16 25N 8890 7.17 24N 8917 7.17 /4 , l - z,.3 r 03-36B PTD 3 10/31/2019 Casing/Tubing Program Hole Size Casing / WVFt Grade Conn Length Top Bottom 8.8-9.8 - Tbg O.D. 20-30 UG4 - CM3 9.6-10.0, 10-20 MD / TVDss MD / TVDss 42" 20" 94# NT60LE - 80' Surface 108'/ 80' 16" 13-3/8" 68# NT -80 CYHE 3977' Surface 3977'/3675' 12-1/4" 9-5/8" 47# NT -80S NSCC 4553' Surface 4553'/ 4036' 9-7/8" 7" 26# L-80 Vam Top HC 9558' Surface 9558'/ 8,607' 6-1/8" 4-1/2" 12.6# 13Cr-85 Vam Top 7428' 9408'/8487' 16,836'/ 8820' (150' lap) Tubing 4-1/2" 12.6# 13Cr-85 Vam Top 9408' Surface 9408'/ 8487' (-5' into liner PBR) Mud Program Intermediate Mud Properties: LSND Depth Interval Density PV (cp) YP Ibt 9-5/8" Window - SV 1 8.8-9.8 - 10-20 20-30 UG4 - CM3 9.6-10.0, 10-20 20-30 CM2 - CM1 10.1 -10.3, 10-20 20-30 HRZ - TD 10.3-11.0. 10-20 20-30 Production Mud Properties: Water Based Pol mer Fluid Depth Interval Density PV (cp) YP Ib/ OOftz 7" Shoe - TD 1 8.5-9.0 <12 1 12-20 Logging Program Intermediate Drilling: Dir/GR/RES Open Hole: None Cased Hole: Cement Bond Lo Production Drilling: Dir/GR/RES/NEU/DEN Oen Hole: None Cased Hole: None 03-36B PTD 4 10/31/2019 Cement Program Intermediate Lead Oen hole volume + 10% excess Basis Lead TOC Target 500 ft MD above Top UG4 Basis Tail Oen hole volume + 10% excess + 80 ft shoe track assumes 150' of 8-1/2" pilot hole Tail TOC 500 ft MD above casing shoe Spacer 50 bbls 12.0 ppg Mud Push II Total Cement Lead 203.7 bbls, 1144 cuft, 657 sks of 11.5 ppg LiteCRETE — 1.74 cuft/sk Volume Tail 25.6 bbls, 144 cuft, 124 sks 15.8 ppg Class G — 1.16 cuft/sk Temp BHST 177° F Production Lead N/A Lead TOC N/A Basis Tail Open hole volume + 30% excess + 80 ft shoe track + liner lap + 200'4" DP x 7" LNR annulus Tail TOC Top of liner Spacer 40 bbls 12.0 ppg Mud Push II Total Cement Lead N/A Volume Tail 169.5 bbls, 952 cuft, 755 sks of 15.0 ppg Class G w/ CaCO3— 1.26 cuft/sk Temp BHST 185° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: The following wells will be shut-in for reservoir pressure purposes while drilling: • 03-12A • 16-14C • 09-16 • 09-38 • 09-31 D • 03-10A Anti -Collision: All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria: • 03-01A: Shut-in at surface during production section drilling Offset Well Ownership Information All offset wells identified within 200 ft of the proposed wellbore are operated by BP. Hydrogen Sulfide Reference "Drilling Critical Issues" section. Faults Reference "Drilling Critical Issues" section. Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. 03-36B PTD 5 10/31/2019 I • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul Class I waste to DS -04 and/or Pad 3 for disposal. Contact the GPB Environmental Advisors (659-5893) for guidance. Well Control The 8-1/2x9-7/8" and 6-1/8" hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below and requirements, BOP equipment will be tested to 4000 psi. BOP test frequency for 03-36B will be 7 days during sundry operations and 14 days during drilling operations with function test every 7 days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. 8-1/2x9-7/8" Intermediate Interval Maximum anticipated BHP 3183 psi at the TSHU at 8,596' TVDss 7.12 ppg EM Maximum surface pressure 2,323 psi at the TSHU 0.10psi/ft gas gradient to surface Kick tolerance 25 bbls with 12.3 ppg frac gradient. Kick tolerance Assumes 7.12 ppg pore pressure in the TSHU + 0.5 ppg kick Integrity Test — 6-1/8" hole intensity and 10.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi / 250 psi. Planned completion fluids Annular test to 3,500 psi / 250 psi Integrity Test — 8.-1/2x9-7/8" LOT after drilling 20'-50' of new hole hole 7" Casing Test 4,000 psi surface pressure 6-1/8" Production Interval Maximum anticipated BHP 3,325 psi in the Ivishak at 8,917' TVDss 7.17 ppg EM Maximum surface pressure 2,433 psi 0.10psi/ft gas gradient to surface Kick tolerance N/A — See Variance Requests Planned BOP test pressure Rams test to 4,000 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 6-1/8" hole N/A — See Variance Requests 4-1/2" Liner Top Packer 4,000 psi surface pressure Planned completion fluids 8.5 ppg seawater / —2000' TVDss diesel 03-36B PTD 6 10/31/2019 Variance Requests 1. Due to the geometry of the production interval, it is requested to set the production packer approximately 550 ft MD above the top sliding sleeve (zone 4). This is a variance from 20 AAC 25.412. 2. Production Hole FIT: Given that the planned depth of the intermediate casing is at the top of the target reservoir (Ivishak), and our production hole planned well path does not depart from the Ivishak — a variance from 20 AAq.2_5.030(f) is requested to forgo the planned FIT in production hole. If there are proble uring the intermediate cement job (i.e. losses) which _ jeopardize the ability to meet AOGCC or BP cementing reauirements. or there is U-tube upon drilling out the shoe — this Variance will not apply. Per AOGCC requirements, the 7 casing will also be logged. r 03-36B PTD 7 10/31/2019 Drill and Complete Operations Summary Pre -Rig Operations 1. See Sundry Rig Operations 1. MIRU Parker 272. 2. Test BPV from below. 3. Nipple down dry hole tree. Nipple up BOPE and test to 4,000 psi (annular to 3,500 psi). Top down configuration: annular, 4-1/2" x 7" VBRs, Blind Shear, mud cross, 2-7/8" x 5" VBRs ,4e4 CL ,7e CJ �T/r1�S 4. Pull BPV. Circulate out freeze protect with 8.5 ppg seawater. 5. Pull 4-1/2" tubing from the pre -rig cut at 4,600' MD. 6. Split wellhead at tubing spool / casing spool break. Change secondary (upper) 9-5/8" packoff seals. 7. Install new casing spool. Test 9-5/8" packoff to 3,500 psi. 8. Nipple up BOPE. (Nipple up old tubing spool to new casing spool). Test break. 9. Run 9-5/8" mechanical whipstock and 8-1/2" window milling assembly. Orient and set the whipstock on the tubing stub. -------------------------------End of Sundry / Start of Permit to Drill ------------------------------- 10. Mill window in 9-5/8" casing plus 20'-50' of new formation. -n�_� 11. Perform LOT. POOH. 16,C,, 7-,.L (dA`T-O 4C4 %GL 12. Drill 8-1/2" x 9-7/8" intermediate hole to TD. POOH. 13. Run 7" casing to TD and cement. C �,,,��, �,�,, �'� �✓ 14. Test casing to 4000 psi. 15. Change upper BOP rams to 2-7/8" x 5" VBRs and test to 4,000 psi. 16. MU 6-1/8" production BHA with 4" DP and drill shoe track 17. Drill to production TD. Perform wiper trip. POOH. 18. Run 4-1/2" liner to TD and cement. Set hanger and liner top packer. Displace well to seawater. POOH. 19. Test liner / liner top packer to 4000 psi. (if possible test liner prior to cement setting) 20. Log 7" Casing. — C_ Is %-- `%--o A- 0 Ci—C C- 21. Run and land 4-1/2" completion. 22. Reverse circulate seawater with corrosion inhibitor followed by Freeze protect. Drop ball and rod and set production packer. Individually test tubing and IA to 4000 psi. 23. Set TWC and test to 3,500 psi. 24. Nipple down BOPE. Nipple up adapter and dry hole tree and test to 4,500 psi. 25. RDMO Parker 272. Post -Rig Operations: 1 V Pull TWC/Tree work as needed 2 SL Pull B&R 3 C Shift/Acidize sleeves to establish MI injection as needed 03-36B PTD 8 10/31/2019 03-36B Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Intermediate Hole 1: The UG4 is expected to be a 9.3 ppg EMW. The CMI, CM2 and CM3 are expected to be 10ppg, 9.8ppg and 9.3ppg EMW respectively. Formation pressures will be controlled with a 9.6 — 9.8 ppg mud to drill to within 200' MD of the CM3. At this point, there will be a weight up to 10.2 — 11.0 ppg to drill the rest of the interval to TD. - B. Production Hole: The Ivishak is expected to be at a 7.17 ppg EMW. Reservoir pressures will be controlled by using 8.5 — 9.0 ppg water based mud. II. Lost Circulation/Breathing A. Intermediate Hole 1: There are no expected fault crossings in the first intermediate hole. However, breathing has been known to occur in the Colville on other Drill Sites in Prudhoe Bay as a result of high ECD's. B. Production Hole: There are 3 expected fault crossings in the production hole. The loss risk for these wells is considered Low III. Fault Locations H25 Level Fault Name MD NDss Throw Direction Lateral position Lost Circulation Formation Intersect Intersect and Magnitude Uncertainty Potential fault 1 12549 8855 0-15' DTS 300' low fault 2 139SS 8846 0-10' DTS 200' low fault 4 15165 8848 0-15' DTN 200' low IV. Integrity Testing Test Point Test Depth Testtype EMW (lb/gal) 9-5/8" Window 20'-50' from the 9-5/8" shoe LOT 12.3 ppg 7" Shoe N/A N/A N/A V. Hydrogen Sulfide DS03 is considered an H2S site. Recent H2S data from the pad is as follows VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria: • 03-01: Shut-in at surface prior to production section drilling CONSULT THE DS03 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 03-36B PTD 9 10/31/2019 H25 Level Well Name (P11n1) Readina Date Comments Parent well (if sidetrack) 03-36A 100 Est. H2S of MI Gas #1 Closest SHL well H2S level 03-14B 175 2/8/2019 Nearest Producer @ Surface #2 Closest SHL well H2S level 03-08 60 2/1/2019 Nearest Producer @ Surface #1 Closest BHL well H2S level 03-01A 40 1/20/2019 —500' away #2 Closest BHL well H25 level 03-28 12 1/11/2019 —500' away #3 Closest BHL well H2S level 09-28B 325 5/3/2019 —500' away #4 Closest BHL well 1-12S level 03-03 350 4/27/2019 —500' away Max. recorded H2S on pad/facility 03-29 650 2/10/2016 VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria: • 03-01: Shut-in at surface prior to production section drilling CONSULT THE DS03 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 03-36B PTD 9 10/31/2019 TREE= 4-1/16" CIW WELLHEAD: 135_/8" FMC ACTUATOR BAKER OKB. BBV 602 BF_ ELEV = 30' KOP= 2700' Max Angle = 91'@ 13142' Datum MD= -- ^- 10888' Datum TVD = 8800' SS 20" CONDUCTOR, 94#, NT60LE, D = 19.124" 13-3/8" CSG, 68#, NT -80 CY HE, D = 12.415" 03-36A SAf NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI *** WELL REQUIRES A SSS V WHEN ON MI **** WELL ANGLE > 70* @ 11116' �4 "* MAX DOGLEG: 12.9° @ 11365' *" 108' 2254' 4-1 /2" HES X NP, ID = 3.813" I 397T I TOP OF 7" LNR 4599' 9-5/8" WHIPSTOCK (04/12/07) 4756' 9-5/8" CSG, 47#, NT -80S NSCC, D = 8.681"^4756 9-5/8" EZSV (04/12/07) 4777' Minimum ID= 3.725" @ 10423' 4-1/2" HES XN NIPPLE TOP OF 4-1/2- LNR 1-t_10416' 4-1/2" TBG, 12.6#, L-80 TC11, .0152 bpf, D = 3.958" 10435' 7" LNR, 26#, L-80 BTGM, .0383 bpf, D = 6276 10588' PERFORATION SUMMARY REF LOG: SLB USITON 05/02/07 ANGLE AT TOP PERF: 88" @ 12300' Note: Refer tD Production DB for hstorical perfdata SIZE SPF INTERVAL n/Sgz SHOT SQZ 2-7/8" 6 12300 -12330 C 0523/17 10449' 2-7/8" 6 12817-12842 C 05/13/15 2-7/8" 6 12842 -12892 C 05/12/15 2-7/8" 6 12892 -12917 C 05/10/15 2-78" 6 13230 -13290 C 0224/14 2-7/8" 6 13290 -13320 C 0223/14 2-7/8" 6 13750 -13850 C 09/14/12 2-7/8" 6 13800 -13825 C 09/13/15 2-7/8" 6 13825-13850 C 09/11112 3-38" 6 14330-14355 C 04/11/11 3-3/8" 6 14355 -14380 C 04/11/11 2-7/8" 6 14460-14490 C 02/12/09 2-7/8" 6 14490 -14510 C 02/08//09 3-3/8" 6 14517 -14542 C 04/11/11 2-718" 6 15010-15110 C 05/04/07 PBTD — 15274' 4-12" LNR, 12.6#, L-80 TCA, .0152 bpf, D = 3.958" 1 15363' 2900' H EST TOP OF CBVENT 4599 9-5/8" X 7" HR ZXP LTP, D = 6.29" 4622' 9-5/8" X 7" FLEX LOCK HGR, D = 6.30" MLLOUT WINDOW (03-36A) 475�-4777' 10317' j--� 4-1/2" HES X NP, D = 3.813" 10379' I—i7" X 4-1 /2" BKR S-3 PKR D = 3.870" 10402' J --j 4-1 /2" HES X NP, D = 3.813" 1 10416' -j 12' BKR TBBACK D = 5250" 10423' 4-1/2" HES XN NP, ID = 3.725" 10423' 4-12" PXN PLUG (0123/19) 1042$' 7" X 5" HR ZXP LTP, ID = 4.350" 10435' 4-12" WLEG, D = 3.958" 10439' 7" X 5" FLEX -LOCK HGR, D = 4.350" 10449' S" X 4-1/2" XO, D = 3.920" 11849' 5-314" SW�L PKR D = 3.958" 12416' j—j 5-3/4" SWELL PKR, D = 3.958" 12600'CTM 4-1/2" WFDCBP(OS/23/17) 12980'CTM 1-14-1/2" CBP (05/10/15) 1302W S-3/4" SWELL PKR D = 3.958" 13620' CTM �4-12^ WFD CBP (02/23114) 13624' 5-3/4" SWELL PKR, D = 3.958" 14180'CTM 4-1/2"CIBP(09/13/12) 14228' 53/4' SWELL PKR, ID = 3.958" 14650' 4-1/2" WFD CBP (02/08/09) 14830' 53/4' SWELL PKR, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/29/93 ORIGINAL COMPLETION 05/14/15 ALM/ PJC SET CBP/ADPERF 5810-0/13 05/06/07 N7ES SIDETRACK 03-36A 06/15/15 PJC CSG/ LNR/ PERFS CORRECTIONS 06/05/07 STG/PJC DRLG DRAFT CORRECTIONS 0524/17 MSS/JMD SET CBP/ADPERFS 0523/17 02/16/09 TAR/SV SET CBP /ADPERF (02/12/09) 1120/18 TTS/JMD CORRECTION TO TOP OF LNR SIZE 09/18/12 RRW/JMC CBP & ADPERF 09/1314/12 0128/19 CJWJMD SET PXN PLUG 0123119 02/25/14 TTP/ PJC CPB/ ADPERFS (0223 - 24/14) D CORRECTION TO 123119 PLUG PRUDHOE BAY UNIT WELL: 03-36A PERMIT No:'2070200 API No: 50-029-22340-01 11, TI ON, R1 5E, 910' FSL 8 899' BP Exploration (Alaska) TREE= 4-1/16" CNV WELLHEAD 13-5/8" FMC ACTUATOR -- - BAKER M8. ELEV = 94#, NT60LE, BF. ELEV = _60.2' J 30' KOP = 2700' Max Angle= 91" @ Datum MD = 2-718" Datum TVD= 8 PROPOE. J P&A 13142' 800' SIZE 20" CONDUCTOR, 10888' z 94#, NT60LE, SOZ 2-7/8" D = 19.124" 12300-12330 13-3/8' CSG, 68#, NT -80 CYHE, D = 12.415" 06/15/15 PJC I 108' I 1 3977' 1 TOP OF 7" LNR 4599- 19-5/8- WHPSTOCK (04112107) 4756' 9-5/8" CSG, 47#, NT -80S NSCC, D = 8.681" —4756 9-5/8" EzsV (o4/12/o7) 4777 Minimum ID= 3.725" @ 10423' 4-1/2" HES XN NIPPLE ITBG PUNCH ITOP OF4-1/2" LNR I 10416' 4-1/2" TBG, 12.6#, L-80 TC11, .0152 bpf, D = 3.958" 1043b' 7" LNR 26#, L-80 BTC -M, .0383 bpf, D = 6.276"10588' PERFORATION SUMMARY REF LOG: SLB USIT ON 051()1J07 ANGLE AT TOP PERF: 88" @ 12300' NDte: Refer to Production DB for histoncal perfdata SIZE SPF I NMRVAL z SHOT SOZ 2-7/8" 6 12300-12330 C 05/23/17 06/15/15 PJC 2-718" 6 12817 -12842 C 05/13/15 11/20/18 TTS/JMD CORRECTION TO TOP OF LNR SIZE 2-7/8" 6 12842 -12892 C 05/12/15 2-7/8" 6 12892 -12917 C 05/10/15 2-7/8" 6 13230-13290 C 02/24/14 2-7/8" 6 13290 -13320 C 02/23/14 2-71W 6 13750 -13850 C 09/14/12 2-7/8" 6 13800 -13825 C 09/13/15 2-7/8" 6 13825 -13850 C 09/11/12 3318" 6 14330-14355 C 04/11/11 3318" 6 14355-14380 C 04/11/11 2-7/8" 6 14460-14490 C 02/12/09 2-7/8" 6 14490 -14510 C 02/081/09 33/8" 6 14517 -14542 C 04/11/11 2-7/8" 6 15010 -15110 C 05/04/07 PBTD —L15274' 4-1/2" LNR, 12.6#, L-80 TCII, _0152 bpf, ID = 3.958" 15363' 03-36A SAF NOTES: 1-12S READINGS AVERAGE 125 ppm r. HEN ON MI *** WELL REQUIRES A SSSV WHEN ON MI **— WELL ANGLE > 70° @ 11116' *** MAX DOGLEG: 12.9° 0 11365° *** 2254' 4-12" HES X NP, D = 3.813° 2900' I� EST TOP OF CBuIBNT (O6/20!06) v460R)° 4599' 9-5/8" X 7" HR ZXP LTP, D = 629" 4622' 9-5/8" X 7' FLDC LOCK HGR, D = 6.30' MLLOUT WINDOW (03-36A) 4756' - 4777' 9069° -Frac PLUG ( 7-- 10317- I --d 4-1/2" HES X NP, D = 3.813" 10379° j 7' X 4-1 /2" BKR S-3 PKR, D = 3.870" 10402' 4-12' HES X NP, D = 3.813' 10416' -�12' BKR TEBACK, D = 5.250' 10423' 4 1/2- HES XN NP, D = 3.725' 1 10428' 17- X 5" HR ZXP LTP, D = 4.350- 10436' 4 12' WLEG, D = 3.958" 10439' 7' X 5" FLEX -LOCK HGR D = 4.350" 5•x4-vr xo, D = 3 920 -'® TOP DPZ3 = 10569' 11849' 5-3/4' SWELL PKR, D = 3.958" 12415' S-3/4' SWELL PCR, D = 3.958' 12600'CTM 4-1/2" WFD CBP (0523117) 13020' 5-3/4' SWELL PCR D = 3.958" 13620' CTM 13624' -4-1/2' WFD CDP (02123/14) 5-314' SWFJ_L PKR D = 3.958" 14180'CTM 4-1/2' CBP(09/13/12) 1rj22$' 5314° SWELL PKR, ID = 3.958" 14650' 4-1/2" WFD CBP (02/08!09) 14830' 5314" SWELL PKR, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 04129193 ORIGINAL COMPLETION 01/28/19 CJN/JMD SET PXN PLUG (01123/19) 05/06/07 N7ES SIDETRACK (03-36A) 04/14/19 JBB/JMD4 CORRECTION TO 1/23/19 PLUG 05/14/15 ALFvV PJC SFr CEP/ ADPERF (5810-5/13) 06/26/19 DM(JMJ PROPOSED P&A 06/15/15 PJC CSG/ LNR/ PERFS CORRECTIONS 05/24/17 MSS/JMD, SET CBP/ADPERFS (05/23/17) 11/20/18 TTS/JMD CORRECTION TO TOP OF LNR SIZE PRUDHOE BAY UNIT WELL' 03-36A PERMIT No: 2070200 AP No 50-029-22340-01 SEC 11, TION, R15E, 910' FSL & 899' FWL BP Exploration (Alaska) TREE= 4-1/16" CNV WELLHEAD = 13-5/8" FMC ACTUATOR= BAKER OKB. ELEV = 60.2' REF ELEV = BF. ELEV = ----30- MES KOP = 2700' Max Angle = _' Datum MD _ - Datum TV D = 8800' SS PROPOL .__O REV 2 20" CONDUCTOR 108' 94#, NTWLE, D = 19.124' 13-3/8" CSG, 68#, NT -80 CYHE, 3977' D = 12.415" 9-5/8" SLB WHIPSTOCK 4553' 9-5/8" CSG, 47#, NT -80S NSCC, D = 8.681' 4553' EST TOC Minimum ID= " @ ' 03-36B SAF NOTES: 1-12S READINGS AVERAGE 125 ppm wrlEN ON MI *** WELL REQUIRES A SSS V WHEN ON MI **** WELL ANGLE > 70* @ ' *** MAX DOGLEG: 0 A -'***CR TBG & LNR 4-1J2" HES X NP, D = 3.813" 2900' EST TOP OF CEMENT (06120/06) TOP OF 4-1/2- LNR I 9408' 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP, �— .0152 bpf, D = 3.958" 7" LNR, 26#, L-80 VAM TOP HC, .0383 bpf, D = 6.276^ 14 9558' PBTD 16756' 4-1/2" LNR, 12.6#, 13CR-85 HTTC, 16836' .0152 bpf, D = 3.958" MLLOUT WINDOW (03-36B) _' - _' 41/2" HES X NP, D = 3.813" -17" X 4-112" HES TNT PKR, D = 3.870" 4-112° HES X NP, D = 3.813" 4-112" HES X NP, D = 3.813" 9408'-1 7" X 5" WFD LTP w /HGR & TIEBACK SLEEVE, D = 4-112' VVLEG, D = 3.958" ELMD TT NOT LOGGED ND DEPM S64TSZ ACRAL SZ 01C 617E 24 05/06/07 MES SIDETRACK (03-36A) 23 SIDETRACK(03-36B) 06/10/19 JMD 22 106113/191 JMD I BUILT PROPOSED REV 1 21 JMD I BUILT PROPOS® REV 2 20 19 16 17 16 15 14 13 12 11 10 9 11 7 6 5 4 3 2 1 v=urcn �=uwa� DATE REV BY COMENTS DATE REV BY COMIENTS 04/29/93 ORIGINAL COMPLETION 05/06/07 MES SIDETRACK (03-36A) 1_1_ SIDETRACK(03-36B) 06/10/19 JMD BUILT PROPOSED 106113/191 JMD I BUILT PROPOSED REV 1 106/26/191 JMD I BUILT PROPOS® REV 2 PRIDHOE BAY UNIT VVELL: 03-366 PST Nb_ API No: 50-029-22340-02 SEC 11, T1 OR R1 5F 910' FSL & 899' FWL BP Exploration (Alaska) o M 00 0 0 o N m ¢ � N o M¢ a o N pJ ry O Q M M ¢ 0 -0aO+ FL m F F ag m a a n m f N F- a FU'� v a a f' a F 0< o e N x u O lO �n�,o„ aif d OJ d N in ti ti n ._ a ._ c a 073 d N N o\f 01 N .� o p n ~ 8 CD O n \vi \ 10 \ \ a .- N \ 2 M M Z 6 Z N N d Z Z N 6 N W N M n N Z y F- 17 - N� m a o N N V Y om N x p] r 2 u N .. w ul m vl u A A 3: u N N N m 0 "O '� m •n N x x x V Yl N N~ ' V CR O G d d N N 8 N H ao a° i%1 S n O W h H N N 1OD .�-I O mm p IP O E M L N ~ Qai N OG N N M M ti N a M 'q0 M C an n LL VO1 L G H V 1 O N N N M \ C pap Q N n G N C N Q O C N Q �"� W O N a N W O N m �..� Q M Z' H CO n E 6 al w V1 n m\ H N E V m .ni 1 n ap M a N+ O Z O m N Z O Z O Ot n N W n a Z O eOr1 v\t .ti y .moi .d-. ry W N .nl a 3 .�-i u C "'� v p7i v v v a d M O pp M n Y Y M Y lD U Y V N U A O C o V �epj-I�� 11 IpIr�'0�� V //0��0�� V m m d 6 m i O Y M 72 d U 9 U U U Y Y X ?p Y gni, v C N V d C pi T. dJ N A d1 M, 10 \ M N c d F_ 0C <C oC Co v pppp od7 oC ad7 d co d 0 pL vl O O1 pb d O pb N o c¢ O 2 d E O E O O O O m O u u u o u \ F- v" \ \ F- C F- m \ F- F- F- F- a O F F- n 12 F- ry O W C Z O 6 Z O Z O W f u W 2 Z O W 2 W f W i W N W G W .Oi W p71 W .ti c 'O OD C O u W O 'CI v C vvi C ao W F C y d O C d a E w pp y pp _ L 0 V1 y N d a d d d d d d N d Ol pNp pp N d d d pNp N 00 d 6 O a N OO 0: C C C Lrl o '" v a n a O (D y o\y y 0 O a F O O O a s a c v m wc 0 2 O O .3 v w "O v pEi fpa w w d w pE,a�+l0 w w'"Of w w d N U 6 N d N d Ol d d a F- d u J d d d d V N 0 F- d u M ry d d d Q `o rOU ,"p 0 ,� `o o` ro rO 0 0 0. `o ° v o m e v v d w w w w w�' a v M E o C O C, v in O in iii O O i O O O o O CE_d O L VEO_OJ O CE Ow lu o .C. o o .E _d. 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O u) O u) O u) O u) O u) O u) O u) O u) o u) o u) O N O u) O u) o N O u) O u) o u) O u) O u) O O O O O O O O O O O O O O O O O O O O Cl) M Cl) Cl) Cl) M M Cl) M Cl) Cl) M Cl) Cl) M M Cl) M Cl) M a Q m Q(�i m m rNi n (o v (o co (o (o oLor)i Lo vo) Lov0) o o o 0 Q m Cl) V u) V m V Cl) u) V u) m N Cl) m n m N n m O m N O cq m O m O m O m m N IR m .- m m �p m oo co �V Um m o V c � M c V c E co N Q O m A Lm Z m C M M c m O O O Z a 0 0 a 0O o rn 0 :2o m N CO o o Cl) m O o co n O o O o N m 0 o o o O o N m N o o O O Q 0 j O O O O N O m O O m O O O CO m j m o O o O o O (Oo m m r � cc m J W m J cD N N c0') V CO V m N coo n 7 Q$ m m w o W Z a) O. of W () o m 0 o o O cm c m m a a mm N rn M p c I a 0 d o '1N` Lo) _ - o 0 0 0 0 0 0 0 0 0 0 0 0 0 o o O O O o o 0 0 0 0 0 o 0 O 0 o 0 0 0 0 o o O O O o O o 0 U� 0 'n m D O O O O O O O O O O m 0 C3 O O0 O O co m m p 3 ri �- ca o o 0 o o 0 o o o o o o o o D o o o 0 o o o o o 0 0 0 0 o o o O O O O o 0 0 0 0 o o O o 0 O o UO O o o O O o O o O O - - - O O O O O N N � ZQ ; U � :3 p O o v v � G O rn O O N CO u) M M o r` C m m V M m NN m r r n Z Q N m M V" m O m m 'd' r` m m m m �- m M m u) v) r` m m m m u) r N M m m m 7 M m m n M m m v o o N u) NN 3 CL s U V [p 6 o N m v m M u) N m o N N a m m M m m Y Y Y u) C N V m u) n V O) M m M M m N M N u) m O O O N m 0 m v m n n m m m M u) u) R o � m M O M C4 O O c II' V V v V 4f ? 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O O N O O O O O O O O N N O 0 O O Q O O o o O o O o m vi o O m M O Ol 0 O 0 O 0 O 0 O 0 m ai OL O o O o m Ch O cs O o 0 0 m M y J o 0 Z 0 0 m m 0 O 0 m o N N o M 0 '4 0 m 0 m o r m r p o m o m m a o O 0 r 0 N o M n M p o ? o u) I[) O O '- p r r r r � to Im C o Q z m m m A 0o 0. co) p a o n N U7 M u) O O O o O o O O O O O o O o O O O o O O O o 0 M 0 V o m O O o 0 N 0 M o o 0 M o m a N Ql CL) t m m OD m 00 m 00 O O O O O O O O O O O O O 0) O m a M O m N M N 0) N m N m N m N m N m m Y LO ca F V 0 4. 0 O 0 o o O O o o 0 0 0 O 0 O 0 o 0 o o O O O O O o 0 O U7 o Un 0 U7 0 U7 0 Un 0 Lq 0 (Q 0 (n 0 U� 0 Un 0 U? � U Z F N N N O O O O O O O O O O N N N N N N N N N N N N (J U Q m 7 3 Q J O n n m a 7 N N NN (D n n Z Q n m U7 V m m N M N m V m n 0 O U) M M m N M N M N m V m N m M O M Cl) Ui M O N O m n N V N N 3 U O 0) V m M V N M U) N 0 r U) m M V O M m M M M .- (n M Cl) m O V O m N M n T m V (D m n N Cl) O m m m M In In Y M Y Y E (O O E C ig �-- N M M r M m O M U) O M (D m N m cc N m n N O n N N m N M U) N U) V N (O M N M M N c0 N N O N N N V O O m M m cc N m m n O n V m m U) Z Z N N N g g C •8 a a w R= w n N r- n n rl r- r- r- n rl r r- P, N rn rn r- I,- N r= � is r- is N m N M 0 O m V (O O n (O n N c0 m m V M O m (O O M n M M m co m O mm V M V V V V) n N m CD V M V7 m U) m CO n n m m O M9 N n M m n m m U7 U? m V C C N n C n O cc CD N m 000 m M M V M In m O 000 O r N N U7 N n N co M Cl) m a c0 a M V) N (p r0 (mp n M m O m V p M Cl) m M Cl) m M M m M M m M Cl) M Cl) M M O V O V O O V O V O V O O V O V O V O V O V O V O O V O V O V V Z U) V) Ui U) M U) at N M U) M U) m U) m N m U) M U7 m U) m (n M U) M U) 0) V) M U) M U) M U7 M U) M N M U) m (n M U) m O m o m C m C (m) m 3 V n m O n M m U7 N CO V CO N M N M m M co;::M M n 0 m w m m M n U7 V m V M N M r n M O m V n m U� N V m M O m N n M m V M M O M M00 M mM co M M O w w m U 0) U m K T m n m U7 M m m M O N _ O N M N n CO U) V V lO N (O n V n m n n u7_ U7 at N O LO O O .-- n M N O M (p M n V co V m U Q>> w M . 7 7 7 7 N N N N N N7. N N N J F Z 0 O W 7 O C2 n m O O Cl) M m m N Vm n N m V , m n O V U) m m m m — O V V N m m N m m N N n n m V V7 M U) T r ccn m ccoo 04 V m) O m O m V m N V Mn m m (VO OD M O r- N m m O CU n m m m M m O r r N N M M M V V U) Ul m n n m M O N N N N N N Cl) Cl) M M M co M Cl) M Cl) Cl) Cl) Cl) M Cl) co M V V m � Z C d m m LL7 V N M m ON N Uf OR V — U) V m n N O COOO M N r O n O N M V (9 V O O U) U7 r m M Cl)N M U) O M Ol U) LO m VV U7 m U] m M N m M U7 m N U) m N m U) 00 O U7 cc O) V Octm m V m V m 00 V OD n V cc n V 00 m V c0 U) V m U7 V m U') V cDm V V V V m M V m Cl) V m V V m V V m O) VJ o m 00 m OD m m co m 00 m co co m 00 m m N CO m c0 m co N m 00 m CL M m n m M M m V O m U) M n m m m n M U) M N m 0 (O V M M N N M M U7 N n N N '0 m m n V O M n M (D U) M U] m LO IR m O M9 m _ m m m O N m n V m 0 GoGo N M m N m m N m m N m m N m m N M m N m m N m m N m m N M m N M m N m m N M m N M m N O m N m m M m m m M m m m M m m m M m m m m m m M U) O Cl) m M co O Cl) O O co O M O O co O M O O M O Cl) O O M O M O O M O M O O Cl) O M O O M O M O O co O Cl) O O M O Cl) O O M O co O O M O M Cl) U) V O Cl) Cl) O n O Cl) M U) m O M Cl) O N .- M m m N Cl) Cl) U) V M Cl) O n Cl) M Ln M M M O N 0N') M LQ V N N O n mCN N N m IL (m U)N M n M O) M M M M M M M MM M M m M M M m M m M M M M M 0) M M Cl? 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O O O O N O O O O O N N O O O O O O o N O D O W N o O O O Q O O O m O O O O O W N O O O O O O O m o O n O O O o m Om Om O m O O O O M -01 O OOOOM0 O m O N O O O O O O N M V V N W r Oct m O .- r N M M V W W r Q V V C N N N N N N t0 t0 W N m W W W W W W W W W W c . ?. a rn c o c)au)3� ❑ a CD m 0) N W (n d tD N Q Oo 0 0 y L L c N N O O w O y 07 O — Y 0) z u Or'f d C_ CI U N LL V Co 2 m O m m w N m a 6 0 0 0 0 U ri ri o 0 J rL Z w Q W z Q y 7 0 O O Q o rm IL v v a o ro E A N lo m I� IL O N m m CL 04 0 y m Cl) M Z y� r_ r N N `O a s Z Q v Y � V m � Cl) h m m r� Y Y En c v v Z Z E N N o_ o Q Q J 3 p a a ~ w w M CD m 0) N W (n d E z LO t , m p y m m N m 0 d tD N Q U 7 C C r 0)m L L c N N w O y 07 O — z u Or'f d C_ CI U N 4 Cu U m O m m w N m a 6 Q y w (D vO ri ri J rL Z w Q W m m 0 O O_ o rm IL Q) o ro E A N lo m I� T m O N m m CL oco m V1 cL" 'n Lo m Cl) Z y� C (B Z ID C O m M o d (mD o N N m m m m z o o a o Q p m co v am o) m m ,la m m F 3 d E z LO t , m p y m m N m 0 Q a ca Y U) m Q Ln Ln Q m co rn m Q m m o rm IL v ._ c E A oco m Z ID C O m M o d (o a z o o a o p O � M T O m m0 it OOD m M Q m m o 0 T c ai a z a m c p O- ry 0 m m C Im C 0 cQ m m m W R c)C.in3:3Q a 0 d E z LO t , m p y m m N m 0 In n M n 0 m M o o m M (n o (n (n (n v o v M nm OD 0 OD 0 o w 0 m O M (()(D M v O 10 O O" N M M N O N v o m n O n (O m M O (n In m m v O M w O N n n m O O In N (O O N M n O m n O N N N m OJ m a to v n O N to (O N a n In m m 0) v N m M N 1C) N N M N N N m m m m (O M M M m n n N N ('� n On � N lA N W 3 r .- ' r r � r r r r r � � � � N 04 N N M M Cl) W C O O U v O n n v v M (O O (O M OD n n n v n O n v N M OD v w M OD w M t6 1f1 O OD n O m O (O O 10 m m m n (n W M (O OD O m n m OD N in co n M 10 In N 1n m m M O O N CD O W r M In O O N m (n 10 m v n M m v m n o O m O O O ON O N 10 n n n N co O (n n M 1() v OD O N O N N N N N N N N N co Cl) M n co !b m Nn M v m O] N M (O O M l0 v CO v N m N N N N M M v v iA (O N T a m ro o 1n ro M v m n n N n N n n m M M m M v m n ro o n v v o Q n O) OD M N n O 00 � � n e- � � N O v m M n � n M MN 1() 10 0) v r- 1!) `I W m (O 10 rN O O v O (n V n OD O N v m v v v n aD m (A n OD (O M M M N N N N N N M N 1 q O O � � � � N v (O m � M (O (O n m O m m m m O O m m m O O m m Oct J m W � v v v v v v v (O O OD n !A m !a OD CD CO OD !n aD OD 0) OD aD 07 OD OD OD ao O aD OD 0 Q N M d N (n M O O O O W N O O O O O N N N N N N N N N N N N N N (O E A Z m v m O o 0 o v (q m m m (c m rn OD m OR m m a0 OR OR OD OD OD la m cc!n v Q o m o Ni m m m ci ri ao o ao o tb n au m ci ci ri ri ri ai m (o ci ci ri �i ro L (O Z (0 m_ T Go v LO n e- N f0 10 n o m v m M M m n n v M M M m m N M M Q M q 4, q v_ In (n In (n (p n (� m m � (n an ( v v N � m M n m c o v— M m O m M A J M W m� v v v v v v v co n r- n m m m m o O O N N M v 1() (O (6 Co O zcL oCD o N O C O a o y L Ua<n3o a 0 m a m Lo O toO O U) U) g O U 0 Q- E to 2 N N N N N N T m O O O v v M O 6 m m O m O co CO o OD C6 M6 m co co n O 6 O O M O N O O O pp In M M CD (M 0) M nU� v O O M N y�y a L tO n N n OD M (O� 1( O � V N m M � O N0 O M � In �R t0 n m (A O m O D U O m 0LL mLL � m m m m 0 m 0 0 m O m I- (p LL LL h h O H v U "O U U a F LL U F F U F LL v O .0 O L O O L OL O O O L O O O O L O O O O L O L O O O O O O L o0 -r- N 0 L LO N v N O O 6 LO 6 (7 ('7 M O N 07 N O L 0 0) O . — O •-0 O O O O O N N 10 m o N O N N O n « m O J J J O J n O 70 70 O U U d U m J J J M OJ !n E O O v❑❑,2❑ O O 7 N m !n O > > M N m m 1n N O M 7 O m (0 m 10 O m O ❑ v❑ m❑❑ v O m (A E m a r r v r r v r r v v v v v c r r r r r r r r r r r v r m '6 U W W 2 14,0 W 140 ,10 B a0 20 W a0 W l«0 (YO�0 14D Y6 «0 W W W YO W r0 N ❑ U Q H Y (n (n (n (n (n cA cn tD (n tD N (n (A (n f0 (A to cn (n (n in U) In to rn rn (n H In n M n 0 m M o o m M (n o (n (n (n v o v M nm OD 0 OD 0 o w 0 m O M (()(D M v O 10 O O" N M M N O N v o m n O n (O m M O (n In m m v O M w O N n n m O O In N (O O N M n O m n O N N N m OJ m a to v n O N to (O N a n In m m 0) v N m M N 1C) N N M N N N m m m m (O M M M m n n N N ('� n On � N lA N W 3 r .- ' r r � r r r r r � � � � N 04 N N M M Cl) W C O O U v O n n v v M (O O (O M OD n n n v n O n v N M OD v w M OD w M t6 1f1 O OD n O m O (O O 10 m m m n (n W M (O OD O m n m OD N in co n M 10 In N 1n m m M O O N CD O W r M In O O N m (n 10 m v n M m v m n o O m O O O ON O N 10 n n n N co O (n n M 1() v OD O N O N N N N N N N N N co Cl) M n co !b m Nn M v m O] N M (O O M l0 v CO v N m N N N N M M v v iA (O N T a m ro o 1n ro M v m n n N n N n n m M M m M v m n ro o n v v o Q n O) OD M N n O 00 � � n e- � � N O v m M n � n M MN 1() 10 0) v r- 1!) `I W m (O 10 rN O O v O (n V n OD O N v m v v v n aD m (A n OD (O M M M N N N N N N M N 1 q O O � � � � N v (O m � M (O (O n m O m m m m O O m m m O O m m Oct J m W � v v v v v v v (O O OD n !A m !a OD CD CO OD !n aD OD 0) OD aD 07 OD OD OD ao O aD OD 0 Q N M d N (n M O O O O W N O O O O O N N N N N N N N N N N N N N (O E A Z m v m O o 0 o v (q m m m (c m rn OD m OR m m a0 OR OR OD OD OD la m cc!n v Q o m o Ni m m m ci ri ao o ao o tb n au m ci ci ri ri ri ai m (o ci ci ri �i ro L (O Z (0 m_ T Go v LO n e- N f0 10 n o m v m M M m n n v M M M m m N M M Q M q 4, q v_ In (n In (n (p n (� m m � (n an ( v v N � m M n m c o v— M m O m M A J M W m� v v v v v v v co n r- n m m m m o O O N N M v 1() (O (6 Co O zcL oCD o N O C O a o y L Ua<n3o a 0 m a m Lo O toO O U) U) g O U 0 Q- E Cl }� Q Iƒ ( } \ 2 7 S 4-- ) %f ƒ \\ -t6 04 04 §§} Eui ) \ j } } \ § } � J ■ \��kƒk ]�222a t E / a � / _ \ . \ } \ < § co / \\ }/g\}\ » 3 � \ c (e# -Z -o � \ u(La4&no, ) North America - ALASKA - BP PBU 03 03-36 PLAN 03-36B 03-36B WP08A Anticollision Summary Report 28 October, 2019 Baker Hughes b BP Baker p Anticollision Report Hughes Company: North America - ALASKA - BP Project: PBU Reference Site: 03 Site Error: O.00usft Reference Well: 03-36 Well Error: O.00usft Reference Wellbore PLAN 03-36B Reference Design: 03-36B WP08A Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 03-36 PLAN KB P272 @ 74.15usft PLAN KB P272 @ 74.15usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 03-366 WP08A Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 4,480.95 to 16,836.46usft Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 1879 Error Surface: Pedal Curve Survey Tool Program Date 10/27/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 75.85 4,480.95 1 : Schlumberger GCT multishot (03-36) GCT -MS Schlumberger GCT multishot 4,480.95 5,000.00 03-368 WP08A (PLAN 03-36B) BLIND Blind drilling 5,000.00 9,558.00 03-366 WP08A (PLAN 03-36B) MWD MWD - Standard 5,000.00 9,558.00 03-36B WPOBA (PLAN 03-36B) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 9,558.00 16,804.96 03-36B WP08A (PLAN 03-36B) MWD MWD - Standard 9,558.00 16,836.45 03-366 WP08A (PLAN 03-36B) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 1028/2019 12:16:59AM Page 2 of 4 COMPASS 5000.15 Build 90 by BP Baker Anticollision Report Hughes Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 03-36 Project: PBU TVD Reference: PLAN KB P272 @ 74.15usft Reference Site: 03 MD Reference: PLAN KB P272 @ 74.15usft Site Error: 0.00usft North Reference: True Reference Well: 03-36 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore PLAN 03-36B Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: 03-368 WP08A Offset TVD Reference: Offset Datum Summary Reference offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Pian Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) 03 03-01 - 03-01 - 03-01 14,012.35 9,725.00 522.37 340.55 182.19 Pass - Major Risk 03 -01 -03 -01A -03-01A 13,623.50 10,175.00 185.62 43.16 149.95 Pass - Minor 1/200 03-03 - 03-03 - 03-03 10,871.99 8,950.00 1,024.51 141.67 883.01 Pass - Major Risk 03-04 - 03-04 - 03-04 6,354.72 6,525.00 403.95 133.12 279.56 Pass - Major Risk 03-07 - 03-07 - 03-07 Out of range 03-07 - 03-07A - 03-07A Out of range 03-08 - 03-08 - 03-08 Out of range 03-09 - 03-09 - 03-09 16,779.76 10,400.00 1,770.09 525.61 1,299.42 Pass - Major Risk 03-10 - 03-10 - 03-10 11,704.23 9,450.00 1,063.75 243.86 829.88 Pass - Major Risk 03-10 - 03-10A- 03-10A 11,710.39 9,325.00 1,075.15 242.70 840.56 Pass - Major Risk 03-11 - 03-11 - 03-11 Out of range 03-12 - 03-12 - 03-12 8,066.22 7,750.00 163.85 132.05 36.63 Pass - Major Risk 03-12 - 03-12A - 03-12A 8,066.22 7,750.00 163.85 131.77 36.91 Pass - Major Risk 03-13 - 03-13 - 03-13 4,480.95 5,150.00 1,715.97 209.31 1,520.43 Pass - Major Risk 03-14 - 03-14 - 03-14 Out of range 03-14 - 03-14A - 03-14A Out of range 03-14 - 03-14B - 03-14B Out of range 03-14 - 03-14BL1 - 03-14BL1 Out of range 03-26 - 03-26 - 03-26 6,387.94 6,725.00 662.73 458.50 204.72 Pass - Major Risk 03-27 - 03-27 - 03-27 13,192.80 10,175.00 1,419.20 284.51 1,153.74 Pass - Major Risk 03-28 - 03-28 - 03-28 16,295.73 11,800.00 805.72 500.95 321.25 Pass - Major Risk 03-31 - 03-31 - 03-31 12,793.10 9,825.00 781.12 266.60 516.92 Pass - Major Risk 03-31 - 03-31 A - 03-31A 12,538.65 9,800.00 582.37 257.67 331.38 Pass - Major Risk 03-32 - 03-32 - 03-32 10,372.61 9,375.00 772.90 147.36 630.87 Pass - Major Risk 03-32 - 03-32A - 03-32A 10,444.93 9,475.00 444.07 139.95 311.38 Pass - Major Risk 03-33 - 03-33 - 03-33 6,790.00 6,950.00 485.16 418.01 72.98 Pass - Major Risk 03-33 - 03-33A- 03-33A 6,790.00 6,950.00 485.16 418.01 72.98 Pass - Major Risk 03-33 - 03-33B - 03-33B 6,794.19 6,950.00 485.42 418.70 72.95 Pass - Major Risk 03-33 - 03-33C - 03-33C 6,794.19 6,950.00 485.42 418.70 72.95 Pass - Major Risk 03-35 - 03-35 - 03-35 4,486.44 4,625.00 407.54 102.14 309.86 Pass - Major Risk 03-35 - PLAN 03-35A - 03-35A WP01 4,486.44 4,625.00 407.54 102.14 309.86 Pass - Major Risk 03-36 - 03-36 - 03-36 4,787.63 4,775.00 15.94 0.00 15.94 Pass - NOERRORS 03-36 - 03-36A - 03-36A 4,792.05 4,775.00 16.75 0.36 16.75 Pass - NOERRORS 09 09-03 - 09-03A - 09-03A 10,272.15 12,375.00 233.61 134.19 135.64 Pass - Major Risk 09-03 - 09-03A - Plan#7 09-03A Approved 10,264.80 12,325.00 237.09 146.85 132.66 Pass - Major Risk 09-16 - 09-16 - 09-16 16,105.95 12,589.00 997.49 799.99 254.13 Pass - Major Risk 09-28 - 09-28 - 09-28 16,808.13 10,675.00 1,692.82 486.26 1,346.67 Pass - Major Risk 09-28 - 09-28A - 09-28A 16,796.19 10,650.00 1,708.00 514.46 1,345.85 Pass - Major Risk 09-28 - 09-28B - 09-28B 16,796.19 10,650.00 1,708.00 514.46 1,345.85 Pass - Major Risk 09-28 - 09-28B - 09-28B WP03 16,796.19 10,650.00 1,708.00 514.46 1,345.85 Pass - Major Risk 09-38 - 09-38 - 09-38 16,682.58 11,375.00 1,055.50 513.86 585.75 Pass - Major Risk 16 16-14 - 16-14C - 16-14C 9,751.11 16,908.00 515.20 225.53 295.80 Pass - Major Risk 16-26 - 16-26APB2 - DEAP Defin Out of range EX LAKEST-01 LAKEST-01 - LAKEST-01 - LAKEST-01 Out of range EX SD311016 SD311016 - SD311016 - SD311016 Out of range 10/2812019 12:18:59AM Page 3 of 4 COMPASS 5000.15 Build 90 bBP Baker S p Anticollision Report Hughes Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 03-36 Project: PBU ND Reference: PLAN KB P272 @ 74.15usft Reference Site: 03 MD Reference: PLAN KB P272 @ 74.15usft Site Error: 0.00usft North Reference: True Reference Well: 03-36 Survey Calculation Method: Minimum Curvature Well Error: O.00usft Output errors are at 1.00 sigma Reference Wellbore PLAN 03-36B Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: 03-36B WP08A Offset TVD Reference: Offset Datum Reference Depths are relative to PLAN KB P272 @ 74.15usft Coordinates are relative to: 03-36 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Usa AK Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 1.63° U) 1500 0 0 c 0 m cu a. cn 1000 P aa) U O a 500 U Ladder Plot 0 0 3000 ' 03-01,03-01,03-01 V3 -*- 03-03,03-03,03-03 V1 $ 03-04,03-04,03-04V1 - 03-07,03-07,03-07V1 03-07,03-07A, 03-07A V8 03-08,03-08,03-08 V1 $ 03-09,03-09,03-09 V1 $ 03-10,03-10,03-10V1 -F 03-10,03-1 OA, 03-1IDA VO $ 03-11,03-11,03-11 V5 i 6000 L E Gq�M D 12000 15000 18000 n -d- 03-14, 03-1413, 03-146 V0 -i&— 03-36,03-36A, 03-36A V5 i 6000 L E Gq�M D 12000 15000 18000 Measured Deppth(3000 us�n) -d- 03-14, 03-1413, 03-146 V0 -i&— 03-36,03-36A, 03-36A V5 -�- 03-26,03-26,03126 V4 $ 09-03,09-03A,Plan#709-03A Approved VO 03-27,03-27,03-27 V1 $- 09-16,09-16,09-16 V1 $ 03-28,03-28,03-28 V1 09-28,09-28,09-28V1 03-31,03-31,03-31 V1 $ 09-28, 09-28A, 09-28A V 1 03-31,03-31 A, 03-31 A VO -- 09-28,09-2813, 09-28B VO $ 03-32,03-32,03-32 V4 $ 09-28,09-28B4O9-28BWP03 VO 03-32,03-32A,03-32AV1 $ 09-38,09-38,09-38Vi $ 03-33,03-33,03-33V2 $ . 16 -14,16 -14C,16 -14C VO 0 03 -33,03 -33A,03 -33A V1 $ 16-26,16-26APB2, REAP Dein V1 10/28/2019 12:18: 59AM Page 4 of 4 COMPASS 5000.15 Build 90 � c t � uTQ m JN m �a v Mm 4n Y w Oz �z E C) a un - 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Cylinder North Results Limited by: Maximum centre distance of 200 Error Surface: Pedal Curve Survey Tool Program Date 10/28/2019 From To Offset (usft) (usft) Survey (Wellbore) Tool Name 75.85 4,480.95 1 : Schlumberger GCT multishot (03-36) GCT -MS 4,480.95 5,000.00 03-36B WP08A Plus 500ft MD (PLAN 03-3 BLIND 5,000.00 9,558.00 03-36B WP08A Plus 500ft MD (PLAN 03-3 MWD 5,000.00 9,558.00 03-36B WP08A Plus 500ft MD (PLAN 03-3 MWD+IFR+MS-WOCA 9,558.00 17,336.46 03-36B WP08A Plus 500ft MD (PLAN 03-3 MWD 9,558.00 17,336.46 03-36B WP08A Plus 500ft MD (PLAN 03-3 MWD+IFR+MS-WOCA Summary Description Schlumberger GCT multshot Blind drilling MWD - Standard MWD + IFR + Multi Station W/O Crustal MWD - Standard MWD + IFR + Multi Station W/O Crustal 16 EX LAKEST-01 EX SD311016 Baker Hughes 10/28/2019 2.07.49AM Page 2 of 2 COMPASS 5000 15 Build 90 Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well • Wellbore - Design (usft) (usft) (usft) 03 03-01 - 03-01A- 03-01A 13,686.24 10,100.00 196.44 03-11 - 03-11 - 03-11 2,609.15 2,625.00 138.88 03-12 - 03-12 - 03-12 2,185.33 2,175.00 39.72 03 -12 -03 -12A -03-12A 2,185.33 2,175.00 39.72 03-13 - 03-13 - 03-13 1,884.10 1,875.00 63.93 03-14 - 03-14 - 03-14 2,482.58 2,475.00 195.11 03-14 - 03-14A - 03-14A 2,464.90 2,450.00 194.80 03-14 - 03-14B - 03-148 2,464.90 2,450.00 194.80 03-14 - 03-14131-1 - 03-14BL1 2,464.90 2,450.00 194.80 03-35 - 03-35 - 03-35 3,937.05 3,950.00 98.25 03-35 - PLAN 03-35A - 03-35A WP01 3,937.05 3,950.00 98.25 03-36 - 03-36 - 03-36 4,787.63 4,775.00 15.94 D3-36 - 03-36A - 03-36A 7,190.08 7,375.00 111.33 03-36 - PLAN 03-36B - 03-366 WP08A 11,850.00 11,850.00 0.22 09 09-28 - 09-28B - 09-28B 17,260.65 13,400.00 198.52 09-28 - 09-28B - 09-28B WP03 17,331.58 13,225.00 166.38 16 EX LAKEST-01 EX SD311016 Baker Hughes 10/28/2019 2.07.49AM Page 2 of 2 COMPASS 5000 15 Build 90 U 03 � z m 0000 rcoc mom .,m �\ww $cc e �a � � Nw. a��� "zzz• ovzi vzi� nn3s u�i vzi u�i ZNiI n n�NNN /�y/�e� 3N I z n m U On HH n n n\ ,2 2 I N I I rf l A J H Y ' I cae iae 8G saK ma k4- ann Nnn n� gy I _ z z. U"ice ca �m Wg m .27 K ('�MO M030 0 _ \. 8Yf130 '1 0tM19M1 I - Y ,LZ n V U.11 -,ll .Z/l OL -.LZ .Z/l 9-,ZY 0 O (3kft XOWe30) ,SY'9Y Davies, Stephen F (CED) From: Nocas, Noel <Noel.Nocas@bp.com> Sent: Thursday, November 7, 2019 2:56 PM To: Davies, Stephen F (CED) Cc: Lastufka, Joseph N Subject: RE: PBU 03-36B (Permit 219-152) - Request Attachments: with 16-14C 03-36B AOR - AOGCC.xlsx Mr. Davies, Apologies for the delay. Attached you will find the updated AOR with 16-14C added. Thank you for your time and attention, please do not hesitate to contact me with any questions. I am available via email or phone if anything comes up. Best, Noel Noel Nocas Drilling Engineer— BP Alaska noel.nocas@bp.com bp.com o. 907-564-5027 c. 907-229-9532 From: Nocas, Noel Sent: Tuesday, November 5, 2019 4:05 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Lastufka, Joseph N <Joseph.Lastufka @bp.com> Subject: RE: PBU 03-36B (Permit 219-152) - Request Hi Steve, There is no plan to pre -produce on 03-36B. I am working on checking the 16-14C well to see if it is within AOR, I will respond to this shortly. Thank you for your time and attention, Noel Noel Nocas Drilling Engineer— BP Alaska noel.nocas@bp.com o. 907-564-5027 c. 907-229-9532 From: Davies, Stephen F (CED) <steve.davies@alaska.pov> Sent: Monday, November 4, 2019 3:20 PM To: Nocas, Noel <Noel.Nocas@bp.com> Cc: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: RE: PBU 03-36B (Permit 219-152) - Request Noel, In addition to the question regarding pre -production, below, I have another: Does PBU 16-14C lie within the Area of Review for PBU 03-36B? If so, please add a row to the AOR spreadsheet for PBU 16-14C. Thank you, 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 (CED) Sent: Monday, November 4, 2019 2:59 PM To: Nocas, Noel <Noel.NocasPbp.com> Cc: Lastufka, Joseph N <Joseph.Lastufka @bp.com> Subject: RE: PBU 03-36B (Permit 219-152) - Request Noel, Excellent. Yes. Will this well be pre -produced for an extended period of time, or will it be flowed back briefly just for clean up? Thank you, 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: Nocas, Noel <Noel.Nocas@bp.com> Sent: Monday, November 4, 2019 2:15 PM To: Davies, Stephen F (CED) <steve.davies@alaska.Fov>; Lastufka, Joseph N <Joseph.Lastufka @bp.com> Subject: RE: PBU 03-36B (Permit 219-152) - Request Steve, Apologies for the small text. Does this work? Best, Noel Noel Nocas Drilling Engineer— BP Alaska noel.nocas@bp.com o. 907-564-5027 c. 907-229-9532 From: Davies, Stephen F (CED) <steve.davies@alaska. ov> Sent: Monday, November 4, 2019 1:50 PM To: Nocas, Noel <Noel,Nocas@bp.com>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: PBU 03-36B (Permit 219-152) - Request Hi Noel, Hi Joe: The 03-36B AOR spreadsheet that is printed out on a single page is just barely legible unless one resorts to a magnifying glass. Could you please send me a new version that is printed out on two pages? Or a copy of the spreadsheet so that I can print it at a larger scale and font size? Thank you, 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. TRANSMITTAL LETTER CHECKLIST WELL NAME: �/t-� 368 PTD: ,J Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 6���VGc Cyt POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015
