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Home My WebLink About219-150LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 5 files Mitquq 1 (50-103-20808-0000) 202000498 Mitquq-1 Capillary Pressure 23-Feb-2023 202000498 Mitquq-1 CoCw FF_3-Jan-2023 202000498 Mitquq-1 RSWC CEC 14-Nov-2022 2000498 Mitquq-1 HPMI Data 22-Dec-2022 202000498 Mitquq-1 CoCw FFRI 23-Feb-2023 Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@santos.com DATE: 2/28/2023 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: External Request Internal Request TRANSMISSION METHOD: CD Thumb Drive Email SharePoint Hardcopy Other- FTP REASON FOR TRANSMITTAL: Approved Approved with Comments For Approval Information Only For Your Review For Your Use To Be Returned With Our Comments Required pursuant to 20 AAC 25.071 COMMENTS: From:Heusser, Heather A (DNR) To:Guhl, Meredith D (OGC) Subject:RE: Mitquq 1 and Mitquq 1 ST1, PTD 219-150 and 219-151, Extended Confidentiality Requested? Date:Monday, May 2, 2022 12:10:52 PM Good afternoon Meredith, I confirmed this morning that neither the DNR Commissioner or DOG Director received and requests for extended confidentiality on these wells. Thank you, Heather Ann Heusser Natural Resource Specialist IV State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage AK 99501-3560 heather.heusser@alaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Tuesday, April 19, 2022 7:29 AM To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Subject: Mitquq 1 and Mitquq 1 ST1, PTD 219-150 and 219-151, Extended Confidentiality Requested? Good Morning Heather, Oil Search (Alaska) LLC’s Mitquq 1 (PTD 219-150, API 50-103-20808-00-00) and Mitquq 1 ST1 (PTD 219-151, API 50-103-20808-01-00) are due for release from the two year confidentiality period after May 2, 2022. Has Oil Search requested extended confidentiality for these wells? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:Mudlog, NGI/SS/ZAIT, CMR/HNGS/PEX/NEXT, XPT, RSWC, MDT, XPT, MDT, MSCT/LWD GR/RES/SONIC/NEU/DENYesYesYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC5/14/2020 Electronic File: Job44508 - Nanushuk.xls33101EDDigital DataC5/14/2020 Electronic File: Job44569 - Alpine C.xls33101EDDigital DataC5/14/2020 Electronic File: Job44141_Mitquq 1 ST00BP00.xls33101EDDigital DataC5/14/2020 Electronic File: Job44208_Mitquq 1 ST00BP00.xls33101EDDigital DataC5/14/2020 Electronic File: ROSL-200203-001 Mitquq-1 Int 3-9-20 4,564.50ft AS0456.xls33101EDDigital DataC5/14/2020 Electronic File: ROSL-200203-002 Mitquq-1 Int 3-9-20 4,639.70ft AS0457.xls33101EDDigital DataC5/14/2020 Electronic File: ROSL-200203-003 Mitquq-1 TD 3-18-20 7,559.06ft AS0458.xls33101EDDigital DataC5/14/2020 Electronic File: Mitquq 1 TD -Alpine C- Corelab PVT Final Validation Report 202001014-5020038336.xlsx33101EDDigital DataC5/14/2020 Electronic File: 202001014-05-5020048360 1 TD PVT Report.xlsx33101EDDigital DataC5/14/2020 Electronic File: Mitquq 1 PVT - Nanushuk- Final validation report.xlsx33101EDDigital DataC5/14/2020 Electronic File: Mitquq 1 TD -Alpine C- Corelab PVT Final Validation Report 202001014-5020038336.xlsx33101EDDigital DataC5/14/2020 Electronic File: Mitquq 1 Core Summary.docx33102EDDigital DataC5/14/2020147 8110 Electronic Data Set, Filename: OilSearch_Mitquq_1_DMD_R1-5_8110ft.las33103EDDigital DataMonday, December 21, 2020AOGCCPage 1 of 23Mitquq 1 Core Summary.docx DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/202043826 43830 Electronic Data Set, Filename: OilSearch_Mitquq_1_DMT_R01.las33103EDDigital DataC5/14/202043832 43841 Electronic Data Set, Filename: OilSearch_Mitquq_1_DMT_R02.las33103EDDigital DataC5/14/202043842 43845 Electronic Data Set, Filename: OilSearch_Mitquq_1_DMT_R03.las33103EDDigital DataC5/14/202043852 43855 Electronic Data Set, Filename: OilSearch_Mitquq_1_DMT_R04.las33103EDDigital DataC5/14/202043858 43860 Electronic Data Set, Filename: OilSearch_Mitquq_1_DMT_R05.las33103EDDigital DataC5/14/202094 8110 Electronic Data Set, Filename: OilSearch_Mitquq_1_LWD_R1-5_8110ft_SANDSTONE.las33103EDDigital DataC5/14/202094 8110 Electronic Data Set, Filename: OilSearch_Mitquq_1_LWD_R1-5_8110ft_SANDSTONE_RM.las33103EDDigital DataC5/14/202094 2450 Electronic Data Set, Filename: OilSearch_Mitquq_1_sonicVISION_R02_Processed_94_2450ft.las33103EDDigital DataC5/14/20202450 4830 Electronic Data Set, Filename: OilSearch_Mitquq_1_R3_8.5in_SonicScope675_DTCO_2450-4830ft.las33103EDDigital DataC5/14/20204832 6810 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run4_8.5in_SonicScope675_DTCO_4832-6810ft.las33103EDDigital DataC5/14/20206704 7052 Electronic Data Set, Filename: OilSearch_Mitquq_1_R05_6.125inch_SonicScope475_6704ft_7052ft_LAS.las33103EDDigital DataC5/14/20206704 7052 Electronic Data Set, Filename: OilSearch_Mitquq 1_R05_6.125inch_SonicScope475_QP_6704ft_7052ft_LAS.las33103EDDigital DataC5/14/20202495 6950 Electronic Data Set, Filename: OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_LAS.las33103EDDigital DataC5/14/20206789 8026 Electronic Data Set, Filename: OilSearch_Mitquq_1_R06_6.125in_DTCO_6789ft_8026ft.las33103EDDigital DataMonday, December 21, 2020AOGCCPage 2 of 23,OilSearch Mitquq1LWDR1-_qq__ _5_8110ft_SANDSTONE_RM.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20206789 8026 Electronic Data Set, Filename: OilSearch_Alaska_Mitquq_1_R06_6.125in_SScope475_DRILL_QP_6789ft_8026ft.las33103EDDigital DataC5/14/2020 Electronic File: Mitquq SLB DD EOWR.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_LWD_RM_8110ft.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_LWD_RM_8110ft.html33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R3_8.5in_SonicScope675_DTCO_2450-4830ft.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run4_8.5in_SonicScope675_DTCO_4832-6810ft.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R05_6.125inch_SonicScope475_6704ft_7052ft_DLIS.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_R05_6.125inch_SonicScope475_QP_6704ft_7052ft_DLIS.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_DLIS.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R06_6.125in_DTCO_6789ft_8026ft.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Alaska_Mitquq_1_R06_6.125in_SScope475_DRILL_QP_6789ft_8026ft.dlis33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_EOW.doc33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_EOW.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DMD_R1-5_8110ft.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DMT_R01.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DMT_R02.Pdf33103EDDigital DataMonday, December 21, 2020AOGCCPage 3 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_DMT_R03.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DMT_R04.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DMT_R05.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_Density_Image_2MD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_Density_Image_2TVD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_Density_Image_5MD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_Density_Image_5TVD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_SERVICE_2MD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_SERVICE_2TVD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_SERVICE_5MD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_VISION_SERVICE_5TVD.Pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_sonicVISION_R02_Processed_94_2450ft_5MD.pdf33103EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_R3_8.5in_SonicScope675_DTCO_2450-4830ft.pdf33103EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_R3_8.5in_SonicScope675_DTCO_Rt_vs_Rm_2450-4830ft.pdf33103EDDigital DataMonday, December 21, 2020AOGCCPage 4 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run4_8.5in_SonicScope675_DTCO_4832-6810ft.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run4_8.5in_SonicScope675_DTCO_Rt_vs_Rm_4832-6810ft.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R05_6.125nch_SonicScope475_6704ft_7052ft_PDF.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_R05_6.125inch_SonicScope475_QP_6704ft_7052ft_PDF.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_PDF.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_PPT.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_PPT.pptx33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R06_6.125in_DTCO_6789ft_8026ft_240_MD.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_R06_6.125in_DTCO_Rt_vs_Rm_6789ft_8026ft_240_MD.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Alaska_Mitquq_1_R06_6.125in_SScope475_DRILL_QP_6789ft_8026ft.pdf33103EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ASP Final Survey - NAD27.pdf33103EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ASP Final Survey - NAD27.xlsx33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ASP Final Survey - NAD27.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ASP Final Survey - NAD27.xlsx33103EDDigital DataMonday, December 21, 2020AOGCCPage 5 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ASP Final Survey - NAD83.pdf33103EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ASP Final Survey - NAD83.xlsx33103EDDigital DataC5/14/2020 Electronic File: Mitquq 1 show reports.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Final_Well_Report.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Isotubes_Inventory.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Sample_Inventory.pdf33104EDDigital DataC5/14/2020 Electronic File: Mitquq 1 Compiled DGRs.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DrillGas_time_31Dec2020_08Feb2020_LAS.zip33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_DrillingLog_8110ftTD_2in.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_GasRatioLog_8110ftTD_2in.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_MasterLog7053ftTD_TVD.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_MasterLog_8110ftTD_MD.pdf33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_MasterLog_8110ft_5inch_MD.pdf33104EDDigital DataC5/14/2020 Electronic File: Mitquq 1 Prognosis.docx33104EDDigital DataDF128 8111 Electronic Data Set, Filename: OilSearch_Mitquq_1_DrillGas_depth_8110ftTD.las33104EDDigital DataDF128 8110 Electronic Data Set, Filename: OilSearch_Mitquq_1_Gas_IN-OUT_LAS_8110ftTD.las33104EDDigital DataMonday, December 21, 2020AOGCCPage 6 of 23,OilSearch_Mitquq_1_DrillGas_depth_8110ftTD.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoDF128 8110 Electronic Data Set, Filename: OilSearch_Mitquq_1_Litholog_8110ftTD.las33104EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Plug_Correlation_Pass.dlis33105EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Plug_Plug_Setting_Record.dlis33105EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Plug_Setting_Record_5in_MD.Pdf33105EDDigital DataC5/14/20202260 6720 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1A_Main_Log_Down.las33106EDDigital DataC5/14/2020365 6780 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1A_Main_Log_Up.las33106EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1A_Main_Log_Down.dlis33106EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1A_Main_Log_Up.dlis33106EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1A_Caliper_5in_MD.Pdf33106EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1A_NGI_5in_MD.Pdf33106EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1A_Sonic_Scanner_5in_MD.Pdf33106EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1A_ZAIT_5in_MD.Pdf33106EDDigital DataC5/14/20204213 6600 Electronic Data Set, Filename: OilSearch_Mitquq 1_QGEO_Dip_Interpretation_4205_6600ftMD.las33107EDDigital DataC5/14/20204509 6600 Electronic Data Set, Filename: OilSearch_Mitquq 1_QGEO_Sandcount_BIN_Pc_CumulativeThickness_PseudoGR_4509_6600ftMD.las33107EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_SandCount_Zones.xlsx33107EDDigital DataMonday, December 21, 2020AOGCCPage 7 of 23,OilSearch_Mitquq_1_Litholog_8110ftTD.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq 1_QGEO_PROCESSED_IMAGES_4205_6600ftMD.dlis33107EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_QGEO_Interpretation_4205_6600ftMD_5in.pdf33107EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_QGEO_Interpretation_4205_6600ftMD_60in.pdf33107EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_QGEO_SandCount_5in_4509_6600ft MD.pdf33107EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_QGEO_SandCount_60in_4509_6600ft MD.pdf33107EDDigital DataC5/14/20202495 6780 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1A_39in_RtScanner_1DInversion_2495-6780ft.las33108EDDigital DataC5/14/20202495 6780 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1A_54in_RtScanner_1DInversion_2495-6780ft.las33108EDDigital DataC5/14/20202495 6780 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1A_72in__RtScanner_1DInversion_2495-6780ft.las33108EDDigital DataC5/14/2020364 6780 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1A_LSA_15Jan20.las33108EDDigital DataC5/14/20202495 6780 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1A_RtScanner_1DInversion_2495-6780ft.las33108EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1A_LSA_15Jan20.dlis33108EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1A_LSA_15Jan20.pdf33108EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1A_RtScanner_1DInversion_2495-6780ft.pdf33108EDDigital DataC5/14/20202510 6700 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1A_SonicScanner_Aniso_2510-6700ft.las33109EDDigital DataMonday, December 21, 2020AOGCCPage 8 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1A_SonicScanner_Aniso_2510-6700ft.dlis33109EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1A_SonicScanner_Aniso_2510-6700ft.pdf33109EDDigital DataC5/14/20204230 6650 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1B_CMR_4230_6650ft.las33110EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_CMR_4230_6650ft.dlis33110EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_CMR_4230_6650ft_Depth Match.dlis33110EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_CMR_4230_6650ft.pdf33110EDDigital DataC5/14/20204294 6707 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1B_LithoScanner_RBF_CEC.las33111EDDigital DataC5/14/20204295 6707 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run1B_LithoScanner_SPEC_TOC_4295_6707ft.las33111EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_LithoScanner_RBF_CEC.dlis33111EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_LithoScanner_SPEC_TOC_4295_6707ft.dlis33111EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_LithoScanner_RBF_CEC.pdf33111EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1B_LithoScanner_SPEC_TOC_4295_6707ft.pdf33111EDDigital DataC5/14/20206718 4275 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1B_Main_Pass_Up_6600-4300.las33112EDDigital DataMonday, December 21, 2020AOGCCPage 9 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20204661 2466 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1B_Repeat_Pass_Up_4600-2495.las33112EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1B_Main_Pass_Up_6600-4300.dlis33112EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1B_Repeat_Pass_Up_4600-2495.dlis33112EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1B_CMR_5in_MD.Pdf33112EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1B_HNGS_5in_MD.Pdf33112EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1B_NEXT_5in_MD.Pdf33112EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1B_PEX_5in_MD.Pdf33112EDDigital DataC5/14/20200 558 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta002_XPT.las33113EDDigital DataC5/14/20200 277 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta003_XPT.las33113EDDigital DataC5/14/20200 295 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta004_XPT.las33113EDDigital DataC5/14/20200 208 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta005_XPT.las33113EDDigital DataC5/14/20200 1358 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta006_XPT.las33113EDDigital DataC5/14/20200 765 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta007_XPT.las33113EDDigital DataC5/14/20200 2984 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta008_XPT.las33113EDDigital DataC5/14/20200 1969 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta009_XPT.las33113EDDigital DataC5/14/20200 402 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta010_XPT.las33113EDDigital DataMonday, December 21, 2020AOGCCPage 10 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20200 2014 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta011_XPT.las33113EDDigital DataC5/14/20200 2448 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta012_XPT.las33113EDDigital DataC5/14/20200 1860 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta013_XPT.las33113EDDigital DataC5/14/20200 1659 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta014_XPT.las33113EDDigital DataC5/14/20200 1249 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta015_XPT.las33113EDDigital DataC5/14/20200 1677 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta016_XPT.las33113EDDigital DataC5/14/20200 1563 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta017_XPT.las33113EDDigital DataC5/14/20200 658 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta018_XPT.las33113EDDigital DataC5/14/20200 1173 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta019_XPT.las33113EDDigital DataC5/14/20200 844 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta020_XPT.las33113EDDigital DataC5/14/20200 1232 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta021_XPT.las33113EDDigital DataC5/14/20200 1165 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta022_XPT.las33113EDDigital DataC5/14/20200 75 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta023_XPT.las33113EDDigital DataC5/14/20200 373 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta024_XPT.las33113EDDigital DataC5/14/20200 493 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta025_XPT.las33113EDDigital DataC5/14/20200 1122 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta026_XPT.las33113EDDigital DataC5/14/20200 1144 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta027_XPT.las33113EDDigital DataC5/14/20200 573 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta028_XPT.las33113EDDigital DataMonday, December 21, 2020AOGCCPage 11 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20200 229 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta029_XPT.las33113EDDigital DataC5/14/20200 1003 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta030_XPT.las33113EDDigital DataC5/14/20200 1312 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta031_XPT.las33113EDDigital DataC5/14/20200 454 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta032_XPT.las33113EDDigital DataC5/14/20200 409 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta033_XPT.las33113EDDigital DataC5/14/20200 509 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta034_XPT.las33113EDDigital DataC5/14/20200 356 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta035_XPT.las33113EDDigital DataC5/14/20200 379 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta036_XPT.las33113EDDigital DataC5/14/20200 1455 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta037_XPT.las33113EDDigital DataC5/14/20200 1268 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta038_XPT.las33113EDDigital DataC5/14/20200 327 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta039_XPT.las33113EDDigital DataC5/14/20200 1619 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta040_XPT.las33113EDDigital DataC5/14/20200 2807 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta041_XPT.las33113EDDigital DataC5/14/20200 1209 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta042_XPT.las33113EDDigital DataC5/14/20200 1185 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta043_XPT.las33113EDDigital DataC5/14/20200 1906 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta044_XPT.las33113EDDigital DataC5/14/20200 395 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_1C_Sta045_XPT.las33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1C_XPT_Correlation Log 1.dlis33113EDDigital DataMonday, December 21, 2020AOGCCPage 12 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1C_XPT_Correlation Log 2.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1C_XPT_Correlation Log 3.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1C_XPT_Correlation Log 4.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1C_XPT_Correlation Log 5.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta002_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta003_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta004_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta005_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta006_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta007_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta008_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta009_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta010_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta011_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta012_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta013_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta014_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta015_XPT.dlis33113EDDigital DataMonday, December 21, 2020AOGCCPage 13 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta016_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta017_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta018_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta019_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta020_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta021_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta022_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta023_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta024_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta025_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta026_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta027_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta028_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta029_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta030_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta031_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta032_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta033_XPT.dlis33113EDDigital DataMonday, December 21, 2020AOGCCPage 14 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta034_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta035_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta036_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta037_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta038_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta039_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta040_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta041_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta042_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta043_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta044_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_Sta045_XPT.dlis33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1C_XPT_5in_MD.pdf33113EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1D_8.5in_XPT_MDT_Data_Evaluation_Report.pdf33114EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1D_8.5in_XPT_MDT_Pretests_Plots.pdf33114EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run1D_8.5in_XPT_MDT_Test_Point_Table.xlsx33114EDDigital DataC5/14/20200 48585 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 1D_Coring Station Log.las33115EDDigital DataMonday, December 21, 2020AOGCCPage 15 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20206441 5953 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 1D_Correlation Log 1.las33115EDDigital DataC5/14/20205452 4562 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 1D_Correlation Log 2.las33115EDDigital DataC5/14/20204746 2724 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 1D_Correlation Log 3.las33115EDDigital DataC5/14/20202632 18 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 1D_Correlation Log 4.las33115EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1D_Coring Station Log.dlis33115EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1D_Correlation Log 1.dlis33115EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1D_Correlation Log 2.dlis33115EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1D_Correlation Log 3.dlis33115EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 1D_Correlation Log 4.dlis33115EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_1D_XLROCK_5in_MD.Pdf33115EDDigital DataC5/14/20200 13701 Electronic Data Set, Filename: Oil_Search_Mitquq_1_Run_1E_Sta004_MDT_EDTA.las33116EDDigital DataC5/14/20200 13283 Electronic Data Set, Filename: Oil_Search_Mitquq_1_Run_1E_Sta005_MDT_EDTA.las33116EDDigital DataC5/14/20200 11254 Electronic Data Set, Filename: Oil_Search_Mitquq_1_Run_1E_Sta006_MDT_EDTA.las33116EDDigital DataC5/14/20200 16728 Electronic Data Set, Filename: Oil_Search_Mitquq_1_Run_1E_Sta007_MDT_EDTA.las33116EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_Run_1E_Sta004_MDT_EDTA.dlis33116EDDigital DataMonday, December 21, 2020AOGCCPage 16 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: Oil_Search_Mitquq_1_Run_1E_Sta005_MDT_EDTA.dlis33116EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_Run_1E_Sta006_MDT_EDTA.dlis33116EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_Run_1E_Sta007_MDT_EDTA.dlis33116EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_Run_1E_MDT.pdf33116EDDigital DataC5/14/20207344 7883 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 1.las33117EDDigital DataC5/14/20207735 7862 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 2.las33117EDDigital DataC5/14/20207469 7608 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 3.las33117EDDigital DataC5/14/20206925 7051 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 4.las33117EDDigital DataC5/14/20200 851 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta002_XPT.las33117EDDigital DataC5/14/20200 770 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta003_XPT.las33117EDDigital DataC5/14/20200 473 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta004_XPT.las33117EDDigital DataC5/14/20200 927 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta005_XPT.las33117EDDigital DataC5/14/20200 810 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta006_XPT.las33117EDDigital DataC5/14/20200 417 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta007_XPT.las33117EDDigital DataC5/14/20200 523 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta008_XPT.las33117EDDigital DataC5/14/20200 610 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta009_XPT.las33117EDDigital DataC5/14/20200 485 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta010_XPT.las33117EDDigital DataMonday, December 21, 2020AOGCCPage 17 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20200 514 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta011_XPT.las33117EDDigital DataC5/14/20200 493 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta012_XPT.las33117EDDigital DataC5/14/20200 615 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta013_XPT.las33117EDDigital DataC5/14/20200 555 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta014_XPT.las33117EDDigital DataC5/14/20200 548 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta015_XPT.las33117EDDigital DataC5/14/20200 528 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta016_XPT.las33117EDDigital DataC5/14/20200 634 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta017_XPT.las33117EDDigital DataC5/14/20200 602 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta018_XPT.las33117EDDigital DataC5/14/20200 461 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta019_XPT.las33117EDDigital DataC5/14/20200 245 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta020_XPT.las33117EDDigital DataC5/14/20200 440 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta021_XPT.las33117EDDigital DataC5/14/20200 547 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta022_XPT.las33117EDDigital DataC5/14/20200 793 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta023_XPT.las33117EDDigital DataC5/14/20200 593 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta024_XPT.las33117EDDigital DataC5/14/20200 906 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta025_XPT.las33117EDDigital DataC5/14/20200 1047 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta026_XPT.las33117EDDigital DataC5/14/20200 735 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2A_Sta027_XPT.las33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run2A_B_6.125in_XPT_MDT_Data_Eval_Rpt.pdf33117EDDigital DataMonday, December 21, 2020AOGCCPage 18 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run2A_XPT_5in_MD.pdf33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 1.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 2.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 3.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2A_XPT Correlation Log 4.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta002_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta003_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta004_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta005_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta006_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta007_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta008_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta009_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta010_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta011_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta012_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta013_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta014_XPT.dlis33117EDDigital DataMonday, December 21, 2020AOGCCPage 19 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta015_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta016_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta017_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta018_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta019_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta020_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta021_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta022_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta023_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta024_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta025_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta026_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2A_Sta027_XPT.dlis33117EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run2A_B_6.125in_Test_Point_Table.xlsx33118EDDigital DataC5/14/20207475 7717 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 1.las33119EDDigital DataC5/14/20207424 7574 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 2.las33119EDDigital DataC5/14/20200 15621 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2B_Sta002_MDT_EDTA.las33119EDDigital DataMonday, December 21, 2020AOGCCPage 20 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoC5/14/20200 11779 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2B_Sta003_MDT_EDTA.las33119EDDigital DataC5/14/20200 15855 Electronic Data Set, Filename: OilSearch_Mitquq_1_Run_2B_Sta004_MDT_EDTA.las33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run2A_B_6.125in_Pressure_Time_Plots.pdf33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2B_MDT_5in_MD.pdf33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 1.dlis33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 2.dlis33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2B_Sta002_MDT_EDTA.dlis33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2B_Sta003_MDT_EDTA.dlis33119EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2B_Sta004_MDT_EDTA.dlis33119EDDigital DataC5/14/20207597 7834 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 1.las33120EDDigital DataC5/14/20207468 7559 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 2.las33120EDDigital DataC5/14/20206986 7402 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 3.las33120EDDigital DataC5/14/20200 12843 Electronic Data Set, Filename: OilSearch_Mitquq 1_Run 2C_MSCT Station Log.las33120EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_Run_2C_MSCT_5in_MD.Pdf33120EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 1.dlis33120EDDigital DataMonday, December 21, 2020AOGCCPage 21 of 23 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 2.dlis33120EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 3.dlis33120EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq 1_Run 2C_MSCT Station Log.dlis33120EDDigital DataDF10/30/2020 Electronic File: 2000498 Mitquq-1 RSWC RCAL 26-Aug-2020.xlsx34153EDDigital DataDF10/30/2020 Electronic File: 6012.2-6325.9_(1.5).jpg34153EDDigital DataDF10/30/2020 Electronic File: XRD Results - 2000498G_Oil Search (Alaska)_Mitquq 1 RSWC.xls34153EDDigital DataDF10/30/2020 Electronic File: 2519.5-4565.4_(1.5).jpg34153EDDigital DataDF10/30/2020 Electronic File: 4576.2-4661.5_(1.5).jpg34153EDDigital DataDF10/30/2020 Electronic File: 4669.6-4742.3_(1.5).jpg34153EDDigital DataDF10/30/2020 Electronic File: 4749.7-5289.5_(1.5).jpg34153EDDigital DataDF10/30/2020 Electronic File: 6331.1-6381.3_(1.5).jpg34153EDDigital DataDF10/30/2020 Electronic File: 6982.97-7532.00_(1.0).jpg34153EDDigital DataDF10/30/2020 Electronic File: 7536.04-7558.98_(1.0).jpg34153EDDigital DataDF10/30/2020 Electronic File: 7562.05-7853.02_(1.0).jpg34153EDDigital Data3/11/2020130 811110 1734CuttingsSidewall Core:Routine Core AnalysisCore DescriptionCore PhotosMonday, December 21, 2020AOGCCPage 22 of 236012.2-6325.9_(1.5).jpgXRD Results - 2000498G_Oil Search (Alaska)_Mitquq 1 RSWC.xls2519.5-4565.4_(1.5).jpg2000498 Mitquq-1 RSWC RCAL 26-Aug-2020.xlsx4576.2-4661.5_(1.5).jpg4669.6-4742.3_(1.5).jpg4749.7-5289.5_(1.5).jpg6331.1-6381.3_(1.5).jpg6982.97-7532.00_(1.0).jpg7536.04-7558.98_(1.0).jpg7562.05-7853.02_(1.0).jpg DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-00-00Well Name/No. MITQUQ 1Completion StatusP&ACompletion Date2/7/2020Permit to Drill2191500Operator Oil Search (Alaska), LLCMD8110TVD7053Current StatusP&A12/21/2020UICNoINFORMATION 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:2/7/2020Release Date:5/2/2022Monday, December 21, 2020AOGCCPage 23 of 23M. Guhl1/7/2021 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 file Mitquq 1 (50-103-20808-0000) Resubmission with corrected las2 format: OilSearch_Mitquq_1_Litholog_8110ftTD Received by:_____________________________ Date: _____________ Please sign and return one copy to: Oil Search Alaska ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@oilsearch.com DATE: 1/7/2021 From: Shannon Koh Oil Search Alaska LLC P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ☒External Request ☐Internal Request TRANSMISSION METHOD: ☐CD ☐Thumb Drive ☒Email ☐SharePoint ☐Hardcopy ☐Other REASON FOR TRANSMITTAL: ☐Approved ☐Approved with Comments ☐For Approval ☐Information Only ☐For Your Review ☐For Your Use ☐To Be Returned ☐With Our Comments ☒Required pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) Received by the AOGCC 01/07/2021 PTD: 2191500 E-Set: 33104 Abby Bell 01/07/2021 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 file Mitquq 1 (50-103-20808-0000) Resubmission with corrected las2 format: Mitquq_1_Mudlog Received by:_____________________________ Date: _____________ Please sign and return one copy to: Oil Search Alaska ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@oilsearch.com DATE: 12/22/2020 From: Shannon Koh Oil Search Alaska LLC P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ☒External Request ☐Internal Request TRANSMISSION METHOD: ☐CD ☐Thumb Drive ☒Email ☐SharePoint ☐Hardcopy ☐Other REASON FOR TRANSMITTAL: ☐Approved ☐Approved with Comments ☐For Approval ☐Information Only ☐For Your Review ☐For Your Use ☐To Be Returned ☐With Our Comments ☒Required pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) PTD: 2191500 E-Set: 33104 Received by the AOGCC 12/22/2020 Abby Bell 12/24/2020 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION Mitquq 1 (50-103-20808-0000) Detail listing on following pages Received by:_____________________________ Date: _____________ Please sign and return one copy to: Oil Search Alaska ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@oilsearch.com DATE: 10/29/2020 From: Shannon Koh Oil Search Alaska LLC P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ☒External Request ☐Internal Request TRANSMISSION METHOD: ☐CD ☐Thumb Drive ☐Email ☐SharePoint ☐Hardcopy ☒Other- FTP REASON FOR TRANSMITTAL: ☐Approved ☐Approved with Comments ☐For Approval ☐Information Only ☐For Your Review ☐For Your Use ☐To Be Returned ☐With Our Comments ☒Required pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) Received by the AOGCC 10/30/2020 PTD: 2191500 E-Set:34153 Abby Bell 11/02/2020 LETTER OF TRANSMITTAL RSWC ├───Geology │ XRD Results - 2000498G_Oil Search (Alaska)_Mitquq 1 RSWC.xls │ ├───Photography │ 2519.5-4565.4_(1.5).jpg │ 4576.2-4661.5_(1.5).jpg │ 4669.6-4742.3_(1.5).jpg │ 4749.7-5289.5_(1.5).jpg │ 6012.2-6325.9_(1.5).jpg.rb5eyjv.partial │ 6331.1-6381.3_(1.5).jpg │ 6982.97-7532.00_(1.0).jpg │ 7536.04-7558.98_(1.0).jpg │ 7562.05-7853.02_(1.0).jpg │ └───Routine 2000498 Mitquq-1 RSWC RCAL 26-Aug-2020.xlsx Oil Search Alaska, LLC Anchorage office P.O. Box 240927 Anchorage, AK 99524 Tel: +1 907 275 6900 Fax: +1 907 275 6930 www.oilsearch.com August 4, 2020 Alaska Department of Natural Resources Division of Oil and Gas Attn: Resource Evaluation 550 W 7th Ave., Suite 1100 Anchorage, AK 99501 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501 RE: Mitquq 1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Mitquq 1 well program, has completed its 2019-2020 drilling season. OSA has submitted required data under separate cover, pursuant to Lease and regulatory requirements. Some of the information required is still being processed and will not be ready for submittal in the timeframe required. We have provided a list of this additional data on the following page. OSA respectfully requests an extension of the submittal requirements for 90 days. OSA will submit the additional data required no later than November 1, 2020. If you have any questions regarding this request, please do not hesitate to contact us. Sincerely, Chris Colbert Exploration Petrophysicist 2 Well Name Well API # Description of Data Mitquq 1 50-103-20808-0000 Conventional Core Laboratory Studies- Porosity & Permeability – Core Lab – estimated November 2020 Mitquq 1 50-103-20808-0000 Analysis of Core Samples – Core Lab – estimated November 2020 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION Mitquq 1 (50-103-20808-0000) Detail listing on following pages Received by:_____________________________ Date: _____________ Please sign and return one copy to: Oil Search Alaska ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@oilsearch.com DATE: 5/14/2020 From: Shannon Koh Oil Search Alaska LLC P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܈ Thumb Drive ܆Email ܆SharePoint ܆Hardcopy ܆Other REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܆Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܈Required pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) State of Alaska By Meredith Guhl at 9:11 am, May 14, 2020 PTD: 2191500 E-Set: 33101-33120 Abby Bell 05/18/2020 LETTER OF TRANSMITTAL جؐؐؐAnalyses ؒ جؐؐؐFlash Gas ؒ ؒ Job44508 - Nanushuk.xls ؒ ؒ Job44569 - Alpine C.xls ؒ ؒ ؒ جؐؐؐMud Gas ؒ ؒ Job44141_Mitquq 1 ST00BP00.xls ؒ ؒ Job44208_Mitquq 1 ST00BP00.xls ؒ ؒ ؒ جؐؐؐOil Samples - Gas Chromatogram ؒ ؒ ROSL-200203-001 Mitquq-1 Int 3-9-20 4,564.50ft AS0456.xls ؒ ؒ ROSL-200203-002 Mitquq-1 Int 3-9-20 4,639.70ft AS0457.xls ؒ ؒ ROSL-200203-003 Mitquq-1 TD 3-18-20 7,559.06ft AS0458.xls ؒ ؒ ؒ ؤؐؐؐPVT ؒ ؒ Mitquq 1 TD -Alpine C- Corelab PVT Final Validation Report 202001014-5020038336.xlsx ؒ ؒ ؒ جؐؐؐPVT ؒ ؒ 202001014-05-5020048360 1 TD PVT Report.xlsx ؒ ؒ ؒ ؤؐؐؐValidationtest ؒ Mitquq 1 PVT - Nanushuk- Final validation report.xlsx ؒ Mitquq 1 TD -Alpine C- Corelab PVT Final Validation Report 202001014-5020038336.xlsx ؒ جؐؐؐCore Data ؒ Core Sample Analysis - extension letter requested.txt ؒ Core Studies - extension letter requested.txt ؒ Mitquq 1 Core Data.docx ؒ جؐؐؐDirectional Survey ؒ Mitquq 1 ASP Final Survey - NAD27.pdf ؒ جؐؐؐExtension Request Letter ؒ Mitquq 1_Request for Extension - Data Submittal.pdf ؒ جؐؐؐGeology ؒ جؐؐؐFinal Well Report T33101 T33102 LETTER OF TRANSMITTAL ؒ ؒ OilSearch_Mitquq_1_Final_Well_Report.pdf ؒ ؒ ؒ جؐؐؐGeological Reports ؒ ؒ Mitquq 1 Compiled DGRs.pdf ؒ ؒ ؒ جؐؐؐMudlogging Final Data ؒ ؒ OilSearch_Mitquq_1_DrillGas_depth_8110ftTD.las ؒ ؒ OilSearch_Mitquq_1_DrillGas_time_31Dec2020_08Feb2020_LAS.zip ؒ ؒ OilSearch_Mitquq_1_DrillingLog_8110ftTD_2in.pdf ؒ ؒ OilSearch_Mitquq_1_GasRatioLog_8110ftTD_2in.pdf ؒ ؒ OilSearch_Mitquq_1_Gas_IN-OUT_LAS_8110ftTD.las ؒ ؒ OilSearch_Mitquq_1_Isotubes_Inventory.pdf ؒ ؒ OilSearch_Mitquq_1_Litholog_8110ftTD.las ؒ ؒ OilSearch_Mitquq_1_MasterLog7053ftTD_TVD.pdf ؒ ؒ OilSearch_Mitquq_1_MasterLog_8110ftTD_MD.pdf ؒ ؒ OilSearch_Mitquq_1_MasterLog_8110ft_5inch_MD.pdf ؒ ؒ OilSearch_Mitquq_1_Sample_Inventory.pdf ؒ ؒ ؒ جؐؐؐOil, Gas, and Gas Hydrate Shows List ؒ ؒ Mitquq 1 show reports.pdf ؒ ؒ ؒ ؤؐؐؐWell Prognosis ؒ Mitquq 1 Prognosis.docx ؒ جؐؐؐLog Digital Data and Plots (LWD and WL) ؒ جؐؐؐLWD ؒ ؒ جؐؐؐDigital Data ؒ ؒ ؒ جؐؐؐDLIS Data ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_LWD_RM_8110ft.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_LWD_RM_8110ft.html ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐLAS Data ؒ ؒ ؒ ؒ جؐؐؐDrilling Mechanics ؒ ؒ ؒ ؒ ؒ جؐؐؐDepth Data ؒ ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMD_R1-5_8110ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐTime Data T33104 T33103 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R01.las ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R02.las ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R03.las ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R04.las ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R05.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐLWD Real Time Data ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_LWD_R1-5_8110ft_SANDSTONE.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLWD Recorded Mode Data ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_LWD_R1-5_8110ft_SANDSTONE.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLWD Processed Data ؒ ؒ ؒ ؤؐؐؐSonic ؒ ؒ ؒ جؐؐؐR2_12.25in_94-2450ft_MD ؒ ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_sonicVISION_R02_Processed_94_2450ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐR3_8.5in_2450-4830ft_MD ؒ ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R3_8.5in_SonicScope675_DTCO_2450-4830ft.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R3_8.5in_SonicScope675_DTCO_2450-4830ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐR4_8.5in_4832-6810ft_MD ؒ ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ جؐؐؐR5_6.125in_6704-7052ft_MD ؒ ؒ ؒ ؒ جؐؐؐDTCO ؒ ؒ ؒ ؒ جؐؐؐQP ؒ ؒ ؒ ؒ ؤؐؐؐTOC ؒ ؒ ؒ ؤؐؐؐR6_6.125in_6789-8026ft_MD ؒ ؒ ؒ جؐؐؐDTCO ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R06_6.125in_DTCO_6789ft_8026ft.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R06_6.125in_DTCO_6789ft_8026ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐQP ؒ ؒ ؤؐؐؐPlots ؒ ؒ ؒ Compiled DD Report in ST1 folder.txt LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ ؒ جؐؐؐEOW Letter ؒ ؒ ؒ OilSearch_Mitquq_1_EOW.doc ؒ ؒ ؒ OilSearch_Mitquq_1_EOW.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐLog Data ؒ ؒ ؒ جؐؐؐDrilling Mechanics ؒ ؒ ؒ ؒ جؐؐؐDepth Data ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMD_R1-5_8110ft.pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐTime Data ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R01.Pdf ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R02.Pdf ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R03.Pdf ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R04.Pdf ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_DMT_R05.Pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLWD Logs ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_Density_Image_2MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_Density_Image_2TVD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_Density_Image_5MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_Density_Image_5TVD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_SERVICE_2MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_SERVICE_2TVD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_SERVICE_5MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_VISION_SERVICE_5TVD.Pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐLWD Processed Data ؒ ؒ ؒ ؤؐؐؐSonic ؒ ؒ ؒ جؐؐؐR2_12.25in_94-2450ft_MD ؒ ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_sonicVISION_R02_Processed_94_2450ft_5MD.pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐR3_8.5in_2450-4830ft_MD ؒ ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1_R3_8.5in_SonicScope675_DTCO_2450-4830ft.pdf ؒ ؒ ؒ ؒ LETTER OF TRANSMITTAL ؒ ؒ ؒ جؐؐؐR4_8.5in_4832-6810ft_MD ؒ ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run4_8.5in_SonicScope675_DTCO_4832-6810ft.pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐR5_6.125in_6704-7052ft_MD ؒ ؒ ؒ ؒ جؐؐؐDTCO ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R05_6.125nch_SonicScope475_6704ft_7052ft_PDF.pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐQP ؒ ؒ ؒ ؒ ؤؐؐؐTOC ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_PDF.pdf ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_PPT.pdf ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R5_8.5in_SonicScope475_TOC_2495ft_6950ft_PPT.pptx ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐR6_6.125in_6789-8026ft_MD ؒ ؒ ؒ جؐؐؐDTCO ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_R06_6.125in_DTCO_6789ft_8026ft_240_MD.pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐQP ؒ ؒ ؤؐؐؐSurvey Data ؒ ؒ OilSearch_Mitquq_1_ASP Final Survey - NAD27.pdf ؒ ؒ OilSearch_Mitquq_1_ASP Final Survey - NAD27.xlsx ؒ ؒ OilSearch_Mitquq_1_ASP Final Survey - NAD83.pdf ؒ ؒ OilSearch_Mitquq_1_ASP Final Survey - NAD83.xlsx ؒ ؒ ؒ ؤؐؐؐWireline ؒ جؐؐؐDigital data ؒ ؒ جؐؐؐCased_Hole ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Plug_Setting_Record_02-Feb-2020 ؒ ؒ ؒ OilSearch_Mitquq_1_Plug_Correlation_Pass.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_Plug_Plug_Setting_Record.dlis ؒ ؒ ؒ ؒ ؒ جؐؐؐRun1_OH_8.5in ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_NGI-SS-ZAIT_15Jan20 ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_Main_Log_Down.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_Main_Log_Down.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_Main_Log_Up.dlis T33105 T33106 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_Main_Log_Up.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1B_CMR-HNGS-NEXT-PEX_15Jan20 ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1C_XPT_16Jan20 ؒ ؒ ؒ ؒ جؐؐؐDLIS Data ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta002_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta003_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta004_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta005_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta006_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta007_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta008_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta009_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta010_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta011_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta012_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta013_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta014_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta015_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta016_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta017_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta018_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta019_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta020_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta021_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta022_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta023_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta024_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta025_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta026_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta027_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta028_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta029_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta030_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta031_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta032_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta033_XPT.dlis T33112 T33113 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta034_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta035_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta036_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta037_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta038_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta039_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta040_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta041_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta042_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta043_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta044_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta045_XPT.dlis ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLAS Data ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta002_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta003_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta004_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta005_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta006_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta007_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta008_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta009_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta010_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta011_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta012_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta013_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta014_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta015_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta016_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta017_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta018_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta019_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta020_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta021_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta022_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta023_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta024_XPT.las LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta025_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta026_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta027_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta028_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta029_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta030_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta031_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta032_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta033_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta034_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta035_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta036_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta037_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta038_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta039_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta040_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta041_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta042_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta043_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta044_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_Sta045_XPT.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1D_XLRock_17Jan20 ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Coring Station Log.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Coring Station Log.las ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 1.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 1.las ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 2.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 2.las ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 3.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 3.las ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 4.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 1D_Correlation Log 4.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run1E_MDT_17Jan20 ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta004_MDT_EDTA.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta004_MDT_EDTA.las T33115 T33116 LETTER OF TRANSMITTAL ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta005_MDT_EDTA.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta005_MDT_EDTA.las ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta006_MDT_EDTA.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta006_MDT_EDTA.las ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta007_MDT_EDTA.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_Run_1E_Sta007_MDT_EDTA.las ؒ ؒ ؒ ؒ ؒ جؐؐؐRun1_Processed ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_8.5in_Processed_QuantaGEO_15Jan20 ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_8.5in_Processed_RT_Scanner_15Jan20 ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_8.5in_Processed_SonicScanner_15Jan20 ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1B_8.5in_Processed_CMR_15Jan20 ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run1B_CMR_4230_6650ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1B_8.5in_Processed_LithoScanner_15Jan20 ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run1D_8.5in_Processed_MDT-XPT_16Jan20 ؒ ؒ جؐؐؐRun2_OH_6.125in ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run2A_XPT_30Jan20 ؒ ؒ ؒ ؒ جؐؐؐDLIS Data ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta002_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta003_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta004_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta005_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta006_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta007_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta008_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta009_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta010_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta011_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta012_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta013_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta014_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta015_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta016_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta017_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta018_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta019_XPT.dlis T33107 T33108 T33109 T33110 T33111 T33114 T33117 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta020_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta021_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta022_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta023_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta024_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta025_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta026_XPT.dlis ؒ ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta027_XPT.dlis ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLAS Data ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta002_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta003_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta004_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta005_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta006_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta007_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta008_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta009_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta010_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta011_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta012_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta013_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta014_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta015_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta016_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta017_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta018_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta019_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta020_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta021_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta022_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta023_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta024_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta025_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta026_XPT.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2A_Sta027_XPT.las ؒ ؒ ؒ ؒ LETTER OF TRANSMITTAL ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run2B_MDT_30Jan20 ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 1.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 1.las ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 2.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2B_MDT_Correlation Log 2.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_Sta002_MDT_EDTA.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_Sta002_MDT_EDTA.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_Sta003_MDT_EDTA.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_Sta003_MDT_EDTA.las ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_Sta004_MDT_EDTA.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_Sta004_MDT_EDTA.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run2C_MSCT_31Jan20 ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 1.dlis ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 1.las ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 2.dlis ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 2.las ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 3.dlis ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Correlation Log 3.las ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Station Log.dlis ؒ ؒ ؒ OilSearch_Mitquq 1_Run 2C_MSCT Station Log.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐRun2_Processed ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run2A-B_6.125in_Processed_XPT-MDT_30Jan20 ؒ ؤؐؐؐPlots ؒ جؐؐؐCased_Hole ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Plug_Setting_Record_02-Feb-2020 ؒ ؒ OilSearch_Mitquq_1_Plug_Setting_Record_5in_MD.Pdf ؒ ؒ ؒ جؐؐؐRun1_OH_8.5in ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_NGI-SS-ZAIT_15Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_Caliper_5in_MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_NGI_5in_MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_Sonic_Scanner_5in_MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1A_ZAIT_5in_MD.Pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1B_CMR-HNGS-NEXT-PEX_15Jan20 T33118 LETTER OF TRANSMITTAL ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1B_CMR_5in_MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1B_HNGS_5in_MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1B_NEXT_5in_MD.Pdf ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1B_PEX_5in_MD.Pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1C_XPT_16Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1C_XPT_5in_MD.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1D_XLRock_17Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run_1D_XLROCK_5in_MD.Pdf ؒ ؒ ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run1E_MDT_17Jan20 ؒ ؒ Oil_Search_Mitquq_1_Run_1E_MDT.pdf ؒ ؒ ؒ جؐؐؐRun1_Processed ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_8.5in_Processed_QuantaGEO_15Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_SandCount_Zones.xlsx ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_8.5in_Processed_RT_Scanner_15Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run1A_LSA_15Jan20.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1A_8.5in_Processed_SonicScanner_15Jan20 ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1B_8.5in_Processed_CMR_15Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run1B_CMR_4230_6650ft.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run1B_8.5in_Processed_LithoScanner_15Jan20 ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run1D_8.5in_Processed_MDT-XPT_16Jan20 ؒ جؐؐؐRun2_OH_6.125in ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run2A_XPT_30Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run2A_XPT_5in_MD.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐOilSearch_Mitquq_1_Run2B_MDT_30Jan20 ؒ ؒ ؒ OilSearch_Mitquq_1_Run_2B_MDT_5in_MD.pdf ؒ ؒ ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_Run2C_MSCT_31Jan20 ؒ ؒ OilSearch_Mitquq_1_Run_2C_MSCT_5in_MD.Pdf ؒ ؒ T33119 T33120 LETTER OF TRANSMITTAL ؒ ؤؐؐؐRun2_Processed ؒ ؤؐؐؐOilSearch_Mitquq_1_Run2A-B_6.125in_Processed_XPT-MDT_30Jan20 ؒ ؤؐؐؐWell Testing None.txt Hand Delivery Receipt I have received a USB Drive from Oil Search Alaska containing Final Well Data pursuant to 20 AAC 25.071 for Mitquq 1, Mitquq 1ST1, and Stirrup 1 Wells. ______________________________________________ AOGCC Representative Name and Signature ______________________________________________ Date State of Alaska By Meredith Guhl at 9:05 am, May 14, 2020 May 14, 2020 219-150 219-151 219-153 Meredith Guhl Digitally signed by Meredith Guhl Date: 2020.05.14 09:06:05 -08'00' Oil Search Alaska, LLC Anchorage office 3721 B St. Suite 240927 Anchorage, AK 99524 Tel: +1 907 275 6900 Fax: +1 907 275 6930 www.oilsearch.com May 1, 2020 Alaska Department of Natural Resources Division of Oil and Gas Attn: Resource Evaluation 550 W 7th Ave., Suite 1100 Anchorage, AK 99501 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501 RE: Mitquq 1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Mitquq 1 well program, has completed its 2019-2020 drilling season. OSA has submitted required data under separate cover, pursuant to Lease and regulatory requirements. Some of the information required is still being processed and will not be ready for submittal in the timeframe required. We have provided a list of this additional data on the following page. OSA respectfully requests an extension of the submittal requirements for 90 days. OSA will submit the additional data required no later than August 1, 2020. If you have any questions regarding this request, please do not hesitate to contact us. Sincerely, Vaughan Williams Senior Operations Geologist 2 Well Name Well API # Description of Data Mitquq 1 50-103-20808-0000 Conventional Core Laboratory Studies- Porosity & Permeability – Core Lab – estimated August 2020 Mitquq 1 50-103-20808-0000 Analysis of Core Samples – Core Lab – estimated August 2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 2/7/2020 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface:FSL 531.60',FEL 2302.37' Sec. 3 T11N, R7E, UM Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): FSL 355.03', FEL 1255.09' Sec. 3, T11N, R7E, UM GL: 49.21' BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: FSL 76.35', FWL 704.52' Sec. 2, T11N, R7E, UM 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI:x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth:x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: Please see attached list of logs obtained 23. BOTTOM 16" J-55 126.5' 9-5/8"L-80 2495' 7" L-80 5916' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production:Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Mudlog, Wireline Run 1A: NGI/SS/ZAIT, Run 1B: CMR/HNGS/PEX/NEXT, Run 1C: XPT, Run 1D: RSWC, Run 1E MDT, Run 2A XPT, Run 2B MDT, Run 2C MSCT, LWD GR/RES/Sonic,NEU/DEN Sr Res EngSr Pet GeoSr Pet Eng Undefined N/A Oil-Bbl:Water-Bbl: Gas-Oil Ratio:Choke Size: Flow Tubing Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 26#Surface 84# 40# 126.5' Surface 6879' CASING WT. PER FT.GRADE 460553.2582 462511.8177 TOP SETTING DEPTH MD Surface Surface 12-1/4" Grouted to surface Surface 459506.6393 5970621.16 973 sks ArcticCem 235 sks Class G. 1/29/2020 CEMENTING RECORD 5970439.201 1584' MD / 1584' TVD SETTING DEPTH TVD 5970150.476 LONS 19-005 12/25/2019 8110' MD / 7053' TVD 4100' MD / 3838' TVD 77.61' HOLE SIZE AMOUNT PULLED 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 PO Box 240927 Anchorage, AK 99524-0927 TOP 219-150 / 320-021 50-103-20808-00-00 Mitquq 1 ADL 0393876 / ADL 0393875 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil Search Alaska WAG Gas N/A 20" BOTTOM 8110' MD3-1/2", 9.2#, L-80 SIZE DEPTH SET (MD) 4488' MD / 4228' TVD PACKER SET (MD/TVD) TUBING RECORD 148 sks Type I/II Lead 76 sks Class G Tail8-1/2" Surface 2495' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, WA 1b D S op and B m; Perf G No (atta 25 050 Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Jody Colombie at 9:13 am, May 01, 2020 State of Alaska Abandon Date 2/7/2020 HEW RBDMS HEW 5/1/2020 Exploratory Abandoned w_G DLB 05/01/2020 DSR-5/1/2020 2690' gls NOTE: 7" cut and pulled at 2690' to sidetrack well. gls 5/4/20 Conventional Core(s): Yes No Sidewall Cores: Sidewall Cores taken from Middle Schrader Bluff 2520'; Nanushuk 9 4519' - 5290'; Nanushuk 8 6012' - 6039'; Torok 6283' - 6381' Please see attached core summary / Core photos will be submitted with log data 30. MD TVD Surface Surface 1584' 1584' Top of Productive Interval 4505' 4113' 29' 29' 2097' 2097' 2485' 2485' 2555' 2554' 3777' 3622' 4418' 4054' 4505' 4113' 5523' 4810' 6266' 5390' HRZ 6649' 5715' Kuparuk C Sandstone 6990' 6014' LCU 6997' 6020' Alpine C Sandstone 7522' 6503' Nuiqsut Sandstone 7801' 6765' 8110' 7053' 31. List of Attachments: Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary & Photos; Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Garret Staudinger Contact Name: Garret Staudinger Authorized Title: Senior Drilling Engineer Contact Email:garret.staudinger@oilsearch.com Authorized Contact Phone: 907-440-6892 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Nanushuk Nanushuk 9 The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Nanushuk 8 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. INSTRUCTIONS Formation at total depth: Signature w/Date: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Torok Nuiqsut Lower Schrader Bluff Prince Creek Seabee TPI (Top of Producing Interval). Middle Schrader Bluff MCU If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base No No N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 05/01/2020 2020-May-01 08:01 see box 28. 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SUPERCEDED Conventional Core(s): Yes No Sidewall Cores: Please see attached core summary and photos Extension request submitted for description and lab analysis 30. MD TVD Surface Surface 1584' 1584' Top of Productive Interval 4505' 4113' 29' 29' 2097' 2097' 2485' 2485' 2555' 2554' 3777' 3622' 4418' 4054' 4505' 4113' 5523' 4810' 6266' 5390' HRZ 6649' 5715' Kuparuk C Sandstone 6990' 6014' LCU 6997' 6020' Alpine C Sandstone 7522' 6503' Nuiqsut Sandstone 7801' 6765' 8110' 7053' 31. List of Attachments: Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary & Photos; Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Garret Staudinger Contact Name: Garret Staudinger Authorized Title: Senior Drilling Engineer Contact Email:garret.staudinger@oilsearch.com Authorized Contact Phone: 907-440-6892 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Nanushuk Nanushuk 9 The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Nanushuk 8 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. INSTRUCTIONS Formation at total depth: Signature w/Date: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Torok Nuiqsut Lower Schrader Bluff Prince Creek Seabee TPI (Top of Producing Interval). Middle Schrader Bluff MCU If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment g g 04/30/2020 2020-Apr-30 07:32 Superseded SUPERCEDED 6XUIDFH&DVLQJ /%7& ó´+ROH 0'79' 0LWTXT :HOO6FKHPDWLF 8SGDWHG$SULOWK ´&RQGXFWRU 0'79' ò´%+.$# 0' 79' ò³/,%7 6DFULILFLDO7XELQJ 2+ RLQFOLQDWLRQ 7' 0' 79' ,QWHUPHGLDWH&DVLQJ /9DP7RS+& ò´+ROH 0' 79' 72&# 0' 79' a DERYHWRS1DQ &,%3# 0'79' OH section P &A with sacrificial tbg 7" casing cut and pulled for sidetrack to Mitquq 1 ST _____________________________ Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/14/2019 12/15/2019 0 The camp is completely set and bermed, the Annex is set and does not need bermed. Conductor is set and cemented. Cellar set and welded to the conductor, finished at 23:00. 12/15/2019 12/16/2019 0 Camp Mobilization All lift stations in place. Camp generator running and all lines running camp. Crew working late to get lift stations and water lines connected. Rig Mobilization 7ES subbase departed 1F pad @ 20:00 hrs as per Conoco Phillips and traveled 10.3 miles to pass by CPF-3 @ 03:15 hrs. Mitquq Well Work Cellar ring welded. Installed and welded cement nipples to conductor. Cut off conductor @ 74- 9/16" from survey mark. Install landing ring assembly. Level out landing ring. Install starting head - witness 500 psi test for 5 min - good test. Install spacer spool. Install diverter offset T and set 21 -1/4" annular. 12/16/2019 12/17/2019 0 Rig Mobilization Moved 7ES all day. 7ES pits and shop completed the trip from 1F to Mitquq 1 pad. 7ES pits broke through ice 2 miles from construction pad - environmental notified - damage inspected by environmental - no tundra damage. Road undergoing repairs - 4-6 hour estimated repair time. Camp Mobilization Augustine rig up is complete. Water sample sent to Deadhorse for testing. Catering team will be called out to prep camp for occupancy as water test allows. 12/17/2019 12/18/2019 0 Crews spent majority of day waiting on Phase 2 weather conditions to subside completely. Repairs on ice road took place throughout the day. 12/18/2019 12/19/2019 0 7ES Rig Up 7ES subbase arrived on location. Pit module spotted in place. 7ES 90% bermed in. 7ES derrick raised and bridled down. Camp Rig Up Catering team arrived on location. 12/19/2019 12/20/2019 0 Camp Rig Up Set up Fairbanks Camp and install Arctic Entry. Dressed berms and installed sewer lines. Set up Augustine Camp and prepare for occupancy. 7ES Rig Up Begin installing 7ES diverter lines. 12/20/2019 12/21/2019 0 Continue rigging up sewer lines and communications for 7ES, Fairbanks and Augustine Camps. Fluid tanks staged at Mitquq. 40' x 30' Shop transported from Deadhorse to Mitquq. Cleaning up Augustine Camp to prepare for occupancy, and setting up offices at Fairbanks Camp 12/21/2019 12/22/2019 0 Set up 105 shop. Started up SLB and Baroid out buildings. Rigged up tank farm and connected pump electronics, and accept load of dry mud product. Comms at Augustine Camp installed; Fairbanks Camp fabrication complete - comms installation appx. 70% complete. AOGCC given 48 hr notice at noon (12:00) on 12/21 regarding upcoming diverter test. Brian Bixby @ AOGCC replied to notice. 12/22/2019 12/23/2019 0 Load pipeshed with 4" Drill Pipe (DP). Spot cuttings box on location. Load pipeshed wih 4" + 5" HWDP, Working on Gas monitoring system in Pits, Secure diverter line in preparation for upcoming Diverter Test. Receive 1 load LSND Mud - roll mud in tank, and testing tank pump system in tank farm. Pre Spud meeting at 22:00 with OSA Personnel 12/23/2019 12/24/2019 0 Complete installation of berm under pipe shed. Remove Kelly Hose from top of Stand Pipe. Install Schlumberger Pressure Sensor and Cable. Pick up drill pipe, jars and 5" HWDP and rack back in derrick. Update given to AOGCC for 9;00 (12/24/2019). Fill rig tanks with fresh water for dilution. Received 700 bbl of 12.5 ppg KW mud for storage in upright tanks. Received 280 bbl of 10.5 ppg spud mud. Operations Summary Report - State Well Name Mitquq 1 Wellbore Name Sidetrack 1 PTD # 219-151 Start Drill Date 2/8/2020 End Drill Date 4/9/2020 Page 1 of 5 Well Name Mitquq 1 Wellbore Name Original Hole PTD # 219-150 Start Drill Date 12/14/2019 End Drill Date 2/7/2020 p; complete. AOGCC givenpp pppg 48 hr notice at noon (12:00) on 12/21 regarding upcoming diverter test. Brian Bixby @ AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/24/2019 12/25/2019 0 Continue completing work on the rig - adjust rotary tong weight buckets, install diverter signs, bull rail for rig offices and cuttings box steam lines. Move 9 5/8" landing jt into pipeshed. Transfer 10.5 ppg spud mud from tanks to pits, and rig up cuttings steam loop. AOGGC witness (B. Bixby) on location to witness function test of 20" diverter bag, knife valve, H2S, LEL alarms, pit volume flow and show test and koomey drawdown test. Both boilers went down due to a load of dirty water taken on. Shut in boilers, pull steam straps, blow down system, clean boiler feed pumps and refire (2 hrs NPT). Install steam traps in heaters, clean boiler feed pumps, calibrate block height, R/U steam to warm mud lines, and circulate mud through the lines to 2500 psi. conduct shallow gas drill. P/U BHA#1 with 12 1/4" Smith XR+ for rotary drilling 12/25/2019 12/26/2019 126 474.31 10.50 RIH with BHA#1 and tag ice at 96' MD. Wash down to 126' MD, establish drilling parameters, and begin rotary drilling ahead from 126' MD to 600.3' MD with dumb iron on BHA #1. Circulate Hole clean. POOH and Lay down BHA #1. Run hole fill pump, transfer BHA #2 from DS to ODS on rig and load DS with 9 5/9" casing. Wait on Weather, and process casing in pipeshed. 12/26/2019 12/27/2019 600 0.00 10.50 Continue to Wait on Weather. Complete preparations and maintenance of rig and rig boiler #2. Process 9 5/8" casing in pipeshed. Calibrate block position for SLB and P/U BHA #2. Verify flow - OK. Begin trip in hole to MAD Pass previous drill section. 12/27/2019 12/28/2019 600 624.20 10.50 Run in hole with BHA #2 to 140' MD. Took weight on bit. M/U 4" HWDP and wash down from 140' MD to 290' MD. Attempt to shoot survey. Change out MWD sensor to standpipe and verifiy survey = OK. Continue to wash down to 600' MD. Begin rotary drilling ahead from 600' MD to 1224' MD 12/28/2019 12/29/2019 1,225 52.50 10.45 Circulate and condition hole while troubleshooting MWD communications and tool. Continue circulating and conditioning hole, and reciprocating pipe while troubleshooting modem in MWD shack. Trip out of hole. Remove IBOP, service top drive, install new IBOP and saver sub. Run in hole, MAD Pass from 1024' MD to 1224' MD. Resume rotary drilling from 1224 MD to 1277' MD 12/29/2019 12/30/2019 1,277 1,004.00 10.50 Continue rotary drilling ahead from 1277' MD to 1992' MD. Blow air through contingency KW F line to upright = OK. Observe noise from top drive - POOH to 1896' MD to service top drive. Inspect torque boost; found not working. remove and cover mounting surface. RIH to continue rotary drilling ahead from 1992' MD to 2281' MD. 12/30/2019 12/31/2019 2,281 224.00 10.55 Continue rotary drilling ahead from 2281' MD to 2505' MD. Circulate 2 bottoms up while reciprocating pipe. Minimal cuttings return to surface. Tight spot at 1797' MD while tripping out of hole. Work pipe from 1734' MD - 1829' MD and 1352' MD - 1256' MD until shakers return clean. Ream/wash drill string back to bottom and encounter 20' of fill. Circulate bottoms up and condition hole while reciprocating pipe. Clean up hole, and trip out of hole to lay down drill pipe, and HWDP. Begin laying down MWD/LWD. 12/31/2019 1/1/2020 2,505 0.00 10.50 Lay down MWD/LWD BHA and Bit. Rig up to run 9 5/8" casing. Hold PJSM w/all hands and Weatherford casing crew. Run 9 5/8" L-80 40 #/ft casing. Install bow spring centralizer per running order every other joint. Run casing and land hanger to set casing at 2495' MD. No losses observed while running casing. Circulate and condition hole through Volant tool. Rig down and check valves on conductor and load plugs in cement head. M/U to landing joint and M/U cement line to head. Circulate and condition through cement head and prepare to start cement pump job. 1/1/2020 1/2/2020 2,505 0.00 10.55 Circulate through cement head while troubleshooting HES truck pump. Change out HES truck. Hold PJSM for all hands for cement job. Pump 436 bbl Arcticset Lite lead cement, and 49 bbl Class G cement tail with returns to surface. Rig down cementers equipment, and begin cleaning rig and flushing/blowing down riser, lines, pumps and pits. Notify AOGCC at 14:00 of upcoming BOP test. (48 HR NOTICE) Start to nipple down diverter system. 1/2/2020 1/3/2020 2,505 0.00 Nipple down diverter system, load out spud mud, load out spike fluid, clean pit equipment. Clean hanger profile, install seal sub and vg seal. Install new wellhead and torque bolts, pressure test seals to 1500 psi for 10 minutes. Install 11"x13-5/8" 5K adapter spool and torque. N/U BOP stack to wellhead. Clean trip tank, dress #2 mud pump with 5" liners. Cont. N/U BOP, install 4" fixed rams in single gate, install blind shear rams and 2-7/8"x5" VBR's in double gate. Cont cleaning pits, dressing mud pumps, and spotting cuttings dryer. Operations Summary Report - State Page 2 of 5 . Rig up to run 9 5/8" casing. pp AOGGC witness (B. Bixby)ppg p p , g p g p ( y on location to witness function test of 20" diverter bag, knife valve, H2S, LEL alarms, pit volume gpg Run casing and land hanger to set casing at 2495' MD. Run in hole with BHA #2 to 140' MD. Nipple down diverter system, lo CMT surface casing. Continue rotary drilling ahead from 1277' MD to 1992' MD. Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 1/3/2020 1/4/2020 2,505 0.00 Finish installation of shear rams. Install turnbuckles and kill line on BOP stack. C/O liners and swabs on #1 mp t/5". Install IA/OA valves in cellar. Service top drive, Cont swab install on #2 mp. Cont welding on cuttings chute. Install wear bushing. Install riser and flowline. P/U drill pipe, drift w/2-3/8" drift, proceed to M/U 17 stds. 1/4/2020 1/5/2020 2,505 0.00 10.80 P/U 26 stds of 4" drill pipe. Prep surface equipment for BOP test. Pressure test casing shoe with WBM to 3000 psi for 30 min - good test. Dummy run 7" casing hanger - good run. P/U and set test plug. Start BOP test on 4" test jt, 250 psi low/5000 psi high - witness by AOGCC representative and Subsea Solutions representative. 1/5/2020 1/6/2020 2,505 0.00 10.80 Test BOPE to 250 psi low/5000 psi high for 5 min each - test witnessed by AOGCC rep. Perform accumulator drawdown to 250 psi low/3500 psi high - test witnessed by AOGCC rep. Test pvt, gain/loss, trip and flow alarms - witnessed by AOGCC rep. Take on 290 bbls OBM to pits. Pull test plug, drain stack, set 9-1/8" wear ring. P/U BHA #3. RIH w/4" dp t/2365' MD, tag cement w/10k WOB. 1/6/2020 1/7/2020 2,505 0.00 10.75 WOW due to equipment issues related to cold weather conditions (-45 DegF). Work pipe in hole, work on trucks, maintain boilers, R/U air to Halliburton. Break circulation and displace well from water based spud mud to MOBM taking returns to cellar box through 2" spool outlets. Circ and condition mud. Pressure test 9-5/8" surface casing w/OBM t/3000 psi for 30 min - good test. Well kill drill w/crew & obtain SPR's. 1/7/2020 1/8/2020 2,505 310.00 10.75 Perform choke drill with crew. Drill out float equipment, shoe track, and rathole. Drill 20' new formation and perform LOT to 12.4 ppg EMW. Notified AOGCC rep and received permission to drill ahead as per program with LOT. Circulate and condition mud. Drill ahead 8 1/2" pilot hole. 1/8/2020 1/9/2020 2,815 816.00 10.70 Drill 8 1/2" hole to 3631’ MD. Pressure loss. Pump out of hole to surface casing shoe to repair washed out components on pump #2. 1/9/2020 1/10/2020 3,631 289.00 10.80 Replace fluid end and pod on MP #2. Re-assemble MP #2 to spec. Drill 8-1/2" intermediate hole to 3920' MD. 1/10/2020 1/11/2020 3,920 999.00 10.75 Drill 8-1/2" intermediate hole to 4919' MD. Pressure losses observed. Determined to be pumps. Decision made to POH for repairs. Circulate bottoms up x3. POOH to surface. 1/11/2020 1/12/2020 4,919 0.00 10.75 POH on elevators. Rack back 5" HWDP. L/D smart tools. Change out all three fluid ends on pump #1. Change out the third fluid end on pump #2. Monitor well through trip tank - hole static. 1/12/2020 1/13/2020 4,919 10.80 Monitor hole with trip tank - no gains, no losses. Re-assemble and redress both mud pumps with 5" liners. Pressure test both mud pumps - good test. Test BOPE to 250 psi low, 3500 psi high for 5 minutes each - witnessed by AOGCC Rep. Pick up BHA #4 and RIH to 1053' MD. 1/13/2020 1/14/2020 4,919 1,304.00 10.90 Shallow hole test on BHA #4 @ 1100' MD - good test. TIH to bottom, CBU x2. Directional drill 8 1/2" intermediate hole to 6223' MD. 1/14/2020 1/15/2020 6,223 663.00 11.05 Directional drill 8 1/2" intermediate hole to TD of 6886' MD. Circulate bottoms up 3 times. Trip out of hole to smart tools. 1/15/2020 1/16/2020 6,886 0.00 10.80 POOH and lay down BHA #4. Rig up SLB wireline equipment. Perform wireline logging #1 and #2 on intermediate open hole section. 1/16/2020 1/17/2020 6,886 0.00 10.80 Perform wireline logging run #2 and #3 on intermediate open hole section. 1/17/2020 1/18/2020 6,886 0.00 10.80 Perform wireline logging run #4 and #5 on intermediate open hole section. 1/18/2020 1/19/2020 6,886 0.00 10.80 Continue wireline logging run #5. POOH with wireline logging tools after working tool free from tight spot. L/D wireline tools, and prepare to conduct BOP Test. Begin BOP Test. Operations Summary Report - State Page 3 of 5 Test BOPE to 250 psi low/5000 psi high for 5 min each BOPE TEST Drill 20' newqp , , formation and perform LOT to 12.4 ppg EMW. Notified AOGCC rep and received permission to FIT Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 1/19/2020 1/20/2020 6,886 0.00 10.90 Complete BOP Test (AOGCC Witness Waived). Service Rig, and P/U clean-out BHA. RIH with cleanout BHA and begin circulating and conditioning mud 1/20/2020 1/21/2020 6,886 0.00 10.90 Continue to cleanout intermediate hole to prepare to run casing. Pump LCM pill prior to trip out of hole. 1/21/2020 1/22/2020 6,886 0.00 10.90 Trip out of hole, and lay down cleanout BHA. Rig up to run 7" casing. Change out to 7" casing rams, and test. Begin running 7" L-80 26 #/ft casing. Install bow spring centralizer per running order every other joint. 1/22/2020 1/23/2020 6,886 0.00 10.85 M/U and run 7" casing from 1241' MD to 2481' MD. Circulate and condition with no returns. Discuss plan forward with town, and continue to run 7" casing and landing joint to 6879' MD. Rig up for cement job. Pump 77 total bbls of cement with no returns to surface. Final lift pressure = 525 psi. Cement in Place @ 20:20 hrs. Rig down cementers equipment. Set and test packoff. 1/23/2020 1/24/2020 6,886 0.00 10.80 Inject down 9 5/8" x 7" annulus. Replace 7" upper rams with 2 7/8" x 5" VBR rams, and test BOP. P/U BHA #6 and RIH, picking up drill pipe 1x1. Log 7" casing with Sonic LWD while RIH. Circulate and weight up drill mud from 10.8 to 11.7 ppg. 1/24/2020 1/25/2020 6,886 217.00 11.70 Circulate and weight up mud from 10.8 ppg to 11.7 ppg Test 7" casing to 3500 psi for 30 min.Drill out cement and shoe. Perform FIT @ 6878' MD. Continue drilling ahead to 7103' MD. TOOH with BHA #6 1/25/2020 1/26/2020 7,103 0.00 11.70 Trip out of hole with BHA #6. Trip in with mule shoe on 4" DP to 5392' MD. P/U and M/U Baker Retrievamatic Packer, and continue to RIH on 4" DP to 7055' MD. Circulate and condition drill mud for negative inflow test. 1/26/2020 1/27/2020 7,103 0.00 11.00 Perform Negative Test - confirmed no flow (Test Passed). Unseat packer, and POOH to surface racking back drillpipe. R/U and start BOP test. (Witness Waived - 18:00 hrs) 1/27/2020 1/28/2020 7,103 0.00 10.85 Complete BOP Test (AOGCC Witness Waived). P/U BHA #8 to drill 6 1/8" production hole. Trip out of hole to re-program MWD. Attempt to change out saver sub - top drive will not break out of drillpipe joint/saver sub at 32K (left hand torque). Steam connection while inspecting top drive brake and rotational torque. 1/28/2020 1/29/2020 7,103 336.00 10.75 Break out saver sub from top drive, P/U new lower safety valve, and test. L/D one joint of 4" drillpipe and P/U new joint. TIH to 6880' MD. Circulate bottoms up and condition mud to 10.7 ppg. Mad pass at 170 ft/min, and ream ahead from 6880' MD to tag bottom at 7103' MD. Drill ahead from 7103' MD to 7439' MD 1/29/2020 1/30/2020 7,509 601.00 10.75 Continue drilling ahead 6 1/8" hole section from 7439' MD to TD at 8110' MD. Circulate hole clean Trip out of hole. Lay down MWD/LWD, remove sources. 1/30/2020 1/31/2020 8,110 0.00 10.70 L/D BHA #8. R/U SLB wireline. Wireline log #1 on 6 1/8" production hole - complete. Wireline log #2 on 6 1/8" production hole - started. 1/31/2020 2/1/2020 8,110 0.00 10.70 Wireline log #2 on 6 1/8" production hole - complete. Wireline log #3 on 6 1/8" production hole - complete. Test VBR's and Annular with 3 1/2" test joint. Begin RIH with 3 1/2" cement sacrificial string. 2/1/2020 2/2/2020 8,110 0.00 10.85 RIH with 3 1/2" sacrificial tubing to bottom hole. Circulate and condition hole prior to cement job via chokes. Pump lower cement plug release from BHKA tool. Send 25 bbl spacer to cuttings box. 2/2/2020 2/3/2020 2,705 -5,420.00 10.85 RIH with SLB wireline and set 7" bridge plug at 2705’ MD. RIH with 7" casing cutter on 4" drill pipe, space out on depth and cut 7" casing at 2690’ MD. Attempt to circulate and condition mud with limited pump rates due to losses. 2/3/2020 2/4/2020 2,690 0.00 10.90 Re-establish returns up drillpipe by 7" casing annulus after cutting 7" casing. POH on elevators to 1733' MD and shear out pump out sub @ 2540 psi. Circulate and condition mud. POH to surface and lay down casing cutter BHA. Start BOPE test - witness waived by AOGCC rep. Operations Summary Report - State Page 4 of 5 ggj no returns to surface. OH logs set 7" bridge plug at 2705’ MD. Test 7" casing to 3500 psi for 30 min. P&A with tubing. pppg Perform FIT @ 6878' MD. CMT 7" Rig up to run 7" casing. Continue drilling ahead 6 1/8" hole section from 7439' MD to TD at 8110' MD. Perform Negative Test RIH with 3 1/2" sacrificial tubing to bottom hole. Circulate and condition hole prior to cement jobg via chokes. Pump lower cement plug release from BHKA too Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 2/4/2020 2/5/2020 2,690 0.00 10.90 Test BOPE 250 psi low, 3500 psi high 5 min each with 4" and 7" test joints. Pull 7" casing from cut point to surface and lay down same. Begin RIH with mule shoe on 4" drill pipe to CIBP depth. 2/5/2020 2/6/2020 2,690 0.00 10.20 RIH to CIBP depth. Continue circulating and conditioning mud to displace from 10.8 ppg to 10.2 ppg MOBM. Shut in and conduct exhale test to confirm wellbore breathing. Closely monitor and control wellbore breathing rates and volumes while conditioning mud to 10.2 ppg. 2/6/2020 2/7/2020 2,690 0.00 10.20 Closely monitor and control wellbore breathing while circulating and conditioning hole. MW in 10.2 ppg | MW out: 10.2 ppg 2/7/2020 2/8/2020 2,705 -300.00 10.20 Closely monitor and control wellbore breathing while circulating and conditioning hole. MW in 10.2 ppg | MW out: 10.2 ppg. Rig up cementers and pump balanced kick off plug as per cement program. Operations Summary Report - State Page 5 of 5 K'&ƌŽŵϭϬͲϰϬϳ tĞůůŽŵƉůĞƚŝŽŶZĞƉŽƌƚ ŽǆϮϮͲ>ŽŐƐKďƚĂŝŶĞĚ tĞůů͗DŝƚƋƵƋϭ WdηϮϭϵͲϭϱϬͬ^ƵŶĚƌǇηϯϮϬͲϬϮϭ >t ^ƵŝƚĞͬdŽŽůƐͲ>t , ĂƚĞ/Ŷ ĂƚĞKƵƚ ĞƉƚŚ/Ŷ ĞƉƚŚKƵƚ E'ZͲZ^Ͳ'ZͲ^ŽŶŝĐ ηϮ ϭϮͬϮϲͬϮϬϭϵ ϭϮͬϯϭͬϮϬϭϵ ϲϬϬΖ ϮϱϬϱΖ 'ZͲZ^Ͳ^ŽŶŝĐ ηϯ ϭͬϱͬϮϬϮϬ ϭͬϭϭͬϮϬϮϬ ϮϱϬϱΖ ϰϵϭϵΖ E'ZͲZ^Ͳ'ZͲ^ŽŶŝĐ ηϰ ϭͬϭϮͬϮϬϮϬ ϭͬϭϱͬϮϬϮϬ ϰϵϭϵΖ ϲϴϴϲΖ 'ZͲZ^Ͳ^ŽŶŝĐ ηϲ ϭͬϮϯͬϮϬϮϬ ϭͬϮϱͬϮϬϮϬ ϲϴϴϲΖ ϳϭϬϯΖ E'ZͲZ^Ͳ'ZͲ^ŽŶŝĐͲEhͲE ηϳ ϭͬϮϴͬϮϬϮϬ ϭͬϯϬͬϮϬϮϬ ϳϭϬϯΖ ϴϭϭϬΖ DƵĚůŽŐ /ŶƚĞƌǀĂů ^ĐĂůĞ ϭ͟DƵĚ>ŽŐD ϬʹϴϭϭϬĨƚ ϭͬϲϬϬ ϭ͟DƵĚ>ŽŐds ϬʹϳϬϱϯĨƚ ϭͬϲϬϬ ϱ͟DƵĚ>ŽŐD ϬʹϴϭϭϬĨƚ ϭͬϮϰϬ ϭ͟ŶŐŝŶĞĞƌŝŶŐ>ŽŐD ϬʹϴϭϭϬĨƚ ϭͬϲϬϬ ϭ͟'ĂƐ>ŽŐD ϬʹϴϭϭϬĨƚ ϭͬϲϬϬ tŝƌĞůŝŶĞ ZƵŶ dŽŽů^ƵŝƚĞ ,d DdŽƉ DĂƐĞ ĂƚĞ ƵƌĂƚŝŽŶ &ĂŝůƵƌĞͬ/ŶĐŝĚĞŶƚƐͬŽŵŵĞŶƚƐ ϭE'/Ͳ^^Ͳ/dͲ WĞƚƌŽŵĂĐ ϭϰϬ Ϯ͕ϰϵϱ͛ ϲ͕ϲϬϬ͛ ϭͬϭϱͬϮϬϮϬ ϭϬ͗ϯϬŚƌƐ EŽĐŽŵŵƐǁŝƚŚŚĞĂĚƚĞŶƐŝŽŶĂƚƐƵƌĨĂĐĞ͕ĐŚĂŶŐĞ ŽƵƚũĂƌƐĂŶĚƐǁŝǀĞů ϭ DZͲ,E'^Ͳ WyͲEydͲ WĞƚƌŽŵĂĐ ϭϰϬ Ϯ͕ϰϵϱ͛ ϲ͕ϲϬϬ͛ ϭͬϭϱͲϭϲͬϮϬϮϬ ϭϬ͗ϯϬŚƌƐ EŽŶĞ ϭyWdͲ WĞƚƌŽŵĂĐ ϭϰϬ ϰ͕ϱϮϬ͛ ϲ͕ϯϵϱ͛ ϭͬϭϲͬϮϬϮϬ Ϯϯ͗ϯϬŚƌƐ ŽŵƉůĞƚĞĚϮϯ͕ĐƵƚϭϯĨƌŽŵŽƌŝŐŝŶĂůƉůĂŶĚƵĞƚŽ ƚŝŵĞ͘ ϭy>ZK<Ͳ WĞƚƌŽŵĂĐ ϭϰϬ ϰ͕ϱϭϴ͘ϲ͛ ϲϯϴϭ͘ϯ͛ ϭͬϭϳͬϮϬϮϬ Ϯϭ͗ϯϬŚƌƐ Ƶƚϱϭ͕ƌĞĐŽǀĞƌĞĚϱϬ ϭDdͲ WĞƚƌŽŵĂĐ ϭϰϬ ϰ͕ϱϲϰ͛ ϲ͕ϯϰϮ͘ϭ͛ ϭͬϭϳͲϭϴͬϮϬϮϬ ϮϮ͗ϯϬŚƌƐ ϱ^ĂŵƉůĞƐƚĂƚŝŽŶƐ͕ĐŽůůĞĐƚĞĚĨůƵŝĚĨƌŽŵϰ ƐƚĂƚŝŽŶƐ͕ƐŬŝƉƉĞĚƐƚĂƚŝŽŶϱĂĨƚĞƌŵĂǆƚĞŶƐŝŽŶ ƉƵůůĂĨƚĞƌƐƚĂƚŝŽŶϰ Ϯ yWd ϳ͕ϮϱϮ ϳ͕ϴϱϯ͛ ϭͬϯϬͬϮϬϮϬ ϭϬ͗ϬϬŚƌƐ ϮϲŐŽŽĚƚĞƐƚ͕ϮďĂĚƚĞƐƚƐ͕ůŽƐƚƐĞĂůƐ͘ Ϯ Dd ϳ͕ϱϯϮ͛ ϳ͕ϱϳϱ͛ ϭͬϯϬͲϯϭͬϮϬϮϬ ϭϳ͗ϬϬŚƌƐ ϯ^ĂŵƉůĞƐƐƚĂƚŝŽŶƐ͕ĐŽůůĞĐƚĞĚϲƐĂŵƉůĞƐ͗ϯĂƚ ϳ͕ϱϱϵ͕͛ϭĂƚϳ͕ϱϯϮ͕͛ĂŶĚϮĂƚϳ͕ϱϳϱ͛ Ϯ D^d ϳ͕ϴϱϯ͛ ϲ͕ϵϴϯ͛ ϭͬϯϭͬϮϬϮϬ ϴ͗ϭϱŚƌƐ ϮϳĐŽƌĞƐƚĂŬĞŶͬϮϳĐŽƌĞƐƌĞĐŽǀĞƌĞĚ Mitquq 1 Core Summary Page 1 of 3 Mitquq 1 8.5” Intermediate Hole XLRock SWC’s Core Number Core Depth (Ft) Core Start Time Core Start Date Total Time Drilling (Sec) Core Recovery Core Length Formation 1 6381.46 5:41:35 17-Jan-20 440 Recovered Not recorded Torok 2 6375.4 5:58:40 17-Jan-20 397.25 Recovered Not recorded Torok 3 6365.53 6:12:31 17-Jan-20 107.26 Recovered Not recorded Torok 4 6341.43 6:31:25 17-Jan-20 224.7 Recovered Not recorded Torok 5 6332.99 6:45:41 17-Jan-20 196.93 Recovered Not recorded Torok 6 6326.01 7:00:02 17-Jan-20 179.33 Recovered Not recorded Torok 7 6317.14 7:16:02 17-Jan-20 112.58 Recovered Not recorded Torok 8 6309.48 7:32:45 17-Jan-20 297.86 Recovered Not recorded Torok 9 6291.92 7:47:45 17-Jan-20 275.71 Recovered Not recorded Torok 10 6283.17 8:02:41 17-Jan-20 351.49 Recovered Not recorded Torok 11 6039.01 8:36:26 17-Jan-20 321.41 Recovered Not recorded Nanushuk 8 12 6029.08 8:48:21 17-Jan-20 327.1 Recovered Not recorded Nanushuk 8 13 6020.63 9:01:47 17-Jan-20 377.28 Recovered Not recorded Nanushuk 8 14 6012.17 9:15:40 17-Jan-20 364.29 Recovered Not recorded Nanushuk 8 15 5289.52 9:56:16 17-Jan-20 283.01 Recovered Not recorded Nanushuk 9 16 4971.43 10:14:56 17-Jan-20 230.66 Recovered Not recorded Nanushuk 9 17 4925.83 10:25:41 17-Jan-20 253.44 Recovered Not recorded Nanushuk 9 18 4910.08 10:38:50 17-Jan-20 278.53 Recovered Not recorded Nanushuk 9 19 4854.21 10:52:26 17-Jan-20 215.17 Recovered Not recorded Nanushuk 9 20 4819.75 11:01:04 17-Jan-20 247.36 Recovered Not recorded Nanushuk 9 21 4791.38 11:16:05 17-Jan-20 303.17 Recovered Not recorded Nanushuk 9 22 4766.96 11:26:39 17-Jan-20 355.78 Recovered Not recorded Nanushuk 9 23 4749.63 11:38:46 17-Jan-20 247.42 Recovered Not recorded Nanushuk 9 24 4742.29 11:46:56 17-Jan-20 272.7 Recovered Not recorded Nanushuk 9 25 4735.08 11:55:19 17-Jan-20 273.98 Recovered Not recorded Nanushuk 9 26 4731.57 12:06:23 17-Jan-20 228.61 Recovered Not recorded Nanushuk 9 27 4725.39 12:13:49 17-Jan-20 246.34 Recovered Not recorded Nanushuk 9 28 4710.72 12:22:23 17-Jan-20 254.4 Recovered Not recorded Nanushuk 9 29 4697.72 12:31:34 17-Jan-20 260.54 Recovered Not recorded Nanushuk 9 Mitquq 1 Core Summary Page 2 of 3 30 4682.18 12:40:30 17-Jan-20 303.17 Recovered Not recorded Nanushuk 9 31 4679.04 12:55:23 17-Jan-20 279.87 Recovered Not recorded Nanushuk 9 32 4669.6 13:04:30 17-Jan-20 322.5 Recovered Not recorded Nanushuk 9 33 4661.33 13:14:51 17-Jan-20 297.41 Recovered Not recorded Nanushuk 9 34 4653.38 13:26:01 17-Jan-20 317.44 Recovered Not recorded Nanushuk 9 35 4645.85 13:38:03 17-Jan-20 299.97 Not Recovered Nanushuk 9 36 4636.55 13:47:23 17-Jan-20 298.75 Recovered Not recorded Nanushuk 9 37 4633.23 13:57:11 17-Jan-20 343.23 Recovered Not recorded Nanushuk 9 38 4621.17 14:19:58 17-Jan-20 227.14 Recovered Not recorded Nanushuk 9 39 4608.66 14:29:45 17-Jan-20 268.03 Recovered Not recorded Nanushuk 9 40 4599.2 14:38:40 17-Jan-20 288.96 Recovered Not recorded Nanushuk 9 41 4593.4 14:50:00 17-Jan-20 273.92 Recovered Not recorded Nanushuk 9 42 4576.23 14:59:21 17-Jan-20 113.34 Recovered Not recorded Nanushuk 9 43 4565.42 15:11:07 17-Jan-20 239.94 Recovered Not recorded Nanushuk 9 44 4557.73 15:22:47 17-Jan-20 222.14 Recovered Not recorded Nanushuk 9 45 4546.23 15:30:31 17-Jan-20 282.43 Recovered Not recorded Nanushuk 9 46 4539.4 15:39:28 17-Jan-20 237.95 Recovered Not recorded Nanushuk 9 47 4533.31 15:48:43 17-Jan-20 239.81 Recovered Not recorded Nanushuk 9 48 4529.66 16:00:30 17-Jan-20 268.93 Recovered Not recorded Nanushuk 9 49 4527.49 16:12:30 17-Jan-20 56.83 Recovered Not recorded Nanushuk 9 50 4518.52 16:25:41 17-Jan-20 222.08 Recovered Not recorded Nanushuk 9 51 2519.59 17:44:27 17-Jan-20 331.52 Recovered Not recorded Middle Schrader Bluff Mitquq 1 Core Summary Page 3 of 3 Mitquq 1 6.125” Production Hole MSCT SWC’s Core Number Core Depth (Ft) Core Start Time Core Start Date Total Time Drilling (Sec) Core Recovery Core Length 1 7853.02 8:53:38 31-Jan-20 145.95 Present 5.5 cm Nuiqsut SS 2 7836.97 8:59:43 31-Jan-20 101.14 Present 5.5 cm Nuiqsut SS 3 7834.02 9:04:27 31-Jan-20 134 Present 5.5 cm Nuiqsut SS 4 7824.04 9:09:57 31-Jan-20 111.81 Present 5.7 cm Nuiqsut SS 5 7579.12 9:18:09 31-Jan-20 221.91 Present 5.5 cm Alpine C SS 6 7575.02 9:25:08 31-Jan-20 116.08 Present 4.2 cm Alpine C SS 7 7568.12 9:30:04 31-Jan-20 154.49 Present 5.4 cm Alpine C SS 8 7565.05 9:35:53 31-Jan-20 116.93 Present 5.5 cm Alpine C SS 9 7562.05 9:40:44 31-Jan-20 134.43 Present 5.3 cm Alpine C SS 10 7558.98 9:48:11 31-Jan-20 71.69 Present 5.5 cm Alpine C SS 11 7556.09 9:52:23 31-Jan-20 84.07 Present 5.5 cm Alpine C SS 12 7552.97 9:57:09 31-Jan-20 107.12 Present 5.5 cm Alpine C SS 13 7550.08 10:01:55 31-Jan-20 81.94 Present 5.5 cm Alpine C SS 14 7547.13 10:08:39 31-Jan-20 55.9 Present 5.3 cm Alpine C SS 15 7543.99 10:12:23 31-Jan-20 101.57 Present 5.3 cm Alpine C SS 16 7540.97 10:16:57 31-Jan-20 90.05 Present 5.5 cm Alpine C SS 17 7538.59 10:21:34 31-Jan-20 129.73 Present 5.5 cm Alpine C SS 18 7536.04 10:26:40 31-Jan-20 84.07 Present 5.5 cm Alpine C SS 19 7532 10:31:04 31-Jan-20 131.44 Present 5.0 cm Alpine C SS 20 7529.97 10:36:20 31-Jan-20 92.18 Present 5.5 cm Alpine C SS 21 7527.71 10:41:03 31-Jan-20 128.88 Present 5.4 cm Alpine C SS 22 7525.07 10:46:37 31-Jan-20 51.21 Present 5.5 cm Alpine C SS 23 7488.77 10:51:33 31-Jan-20 89.62 Present 5.5 cm Kuparuk C SS 24 7004.54 11:08:44 31-Jan-20 116.93 Present 5.5 cm Kuparuk C SS 25 6992.99 11:13:52 31-Jan-20 79.8 Present 5.5 cm Kuparuk C SS 26 6991.52 11:18:22 31-Jan-20 114.37 Present 5.5 cm Kuparuk C SS 27 6982.97 11:23:36 31-Jan-20 120.34 Present 5.5 cm Kuparuk C SS DŝƚƋƵƋϭŽƌĞ^ƵŵŵĂƌǇ WĂŐĞϭŽĨϯ DŝƚƋƵƋϭϴ͘ϱ͟/ŶƚĞƌŵĞĚŝĂƚĞ,ŽůĞ ŽƌĞ EƵŵďĞƌ ŽƌĞ ĞƉƚŚ ;&ƚͿ ŽƌĞ ^ƚĂƌƚ dŝŵĞ ŽƌĞ^ƚĂƌƚ ĂƚĞ dŽƚĂů dŝŵĞ ƌŝůůŝŶŐ ;^ĞĐͿ ŽƌĞ ZĞĐŽǀĞƌǇ ŽƌĞ>ĞŶŐƚŚ ϭ ϲϯϴϭ͘ϰϲ ϱ͗ϰϭ͗ϯϱ ϭϳͲ:ĂŶͲϮϬ ϰϰϬ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯ ϲϯϳϱ͘ϰ ϱ͗ϱϴ͗ϰϬ ϭϳͲ:ĂŶͲϮϬ ϯϵϳ͘Ϯϱ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯ ϲϯϲϱ͘ϱϯ ϲ͗ϭϮ͗ϯϭ ϭϳͲ:ĂŶͲϮϬ ϭϬϳ͘Ϯϲ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰ ϲϯϰϭ͘ϰϯ ϲ͗ϯϭ͗Ϯϱ ϭϳͲ:ĂŶͲϮϬ ϮϮϰ͘ϳ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϱ ϲϯϯϮ͘ϵϵ ϲ͗ϰϱ͗ϰϭ ϭϳͲ:ĂŶͲϮϬ ϭϵϲ͘ϵϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϲ ϲϯϮϲ͘Ϭϭ ϳ͗ϬϬ͗ϬϮ ϭϳͲ:ĂŶͲϮϬ ϭϳϵ͘ϯϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϳ ϲϯϭϳ͘ϭϰ ϳ͗ϭϲ͗ϬϮ ϭϳͲ:ĂŶͲϮϬ ϭϭϮ͘ϱϴ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϴ ϲϯϬϵ͘ϰϴ ϳ͗ϯϮ͗ϰϱ ϭϳͲ:ĂŶͲϮϬ Ϯϵϳ͘ϴϲ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϵ ϲϮϵϭ͘ϵϮ ϳ͗ϰϳ͗ϰϱ ϭϳͲ:ĂŶͲϮϬ Ϯϳϱ͘ϳϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϬ ϲϮϴϯ͘ϭϳ ϴ͗ϬϮ͗ϰϭ ϭϳͲ:ĂŶͲϮϬ ϯϱϭ͘ϰϵ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϭ ϲϬϯϵ͘Ϭϭ ϴ͗ϯϲ͗Ϯϲ ϭϳͲ:ĂŶͲϮϬ ϯϮϭ͘ϰϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϮ ϲϬϮϵ͘Ϭϴ ϴ͗ϰϴ͗Ϯϭ ϭϳͲ:ĂŶͲϮϬ ϯϮϳ͘ϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϯ ϲϬϮϬ͘ϲϯ ϵ͗Ϭϭ͗ϰϳ ϭϳͲ:ĂŶͲϮϬ ϯϳϳ͘Ϯϴ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϰ ϲϬϭϮ͘ϭϳ ϵ͗ϭϱ͗ϰϬ ϭϳͲ:ĂŶͲϮϬ ϯϲϰ͘Ϯϵ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϱ ϱϮϴϵ͘ϱϮ ϵ͗ϱϲ͗ϭϲ ϭϳͲ:ĂŶͲϮϬ Ϯϴϯ͘Ϭϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϲ ϰϵϳϭ͘ϰϯ ϭϬ͗ϭϰ͗ϱϲ ϭϳͲ:ĂŶͲϮϬ ϮϯϬ͘ϲϲ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϳ ϰϵϮϱ͘ϴϯ ϭϬ͗Ϯϱ͗ϰϭ ϭϳͲ:ĂŶͲϮϬ Ϯϱϯ͘ϰϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϴ ϰϵϭϬ͘Ϭϴ ϭϬ͗ϯϴ͗ϱϬ ϭϳͲ:ĂŶͲϮϬ Ϯϳϴ͘ϱϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϭϵ ϰϴϱϰ͘Ϯϭ ϭϬ͗ϱϮ͗Ϯϲ ϭϳͲ:ĂŶͲϮϬ Ϯϭϱ͘ϭϳ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϮϬ ϰϴϭϵ͘ϳϱ ϭϭ͗Ϭϭ͗Ϭϰ ϭϳͲ:ĂŶͲϮϬ Ϯϰϳ͘ϯϲ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϭ ϰϳϵϭ͘ϯϴ ϭϭ͗ϭϲ͗Ϭϱ ϭϳͲ:ĂŶͲϮϬ ϯϬϯ͘ϭϳ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϮϮ ϰϳϲϲ͘ϵϲ ϭϭ͗Ϯϲ͗ϯϵ ϭϳͲ:ĂŶͲϮϬ ϯϱϱ͘ϳϴ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϯ ϰϳϰϵ͘ϲϯ ϭϭ͗ϯϴ͗ϰϲ ϭϳͲ:ĂŶͲϮϬ Ϯϰϳ͘ϰϮ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϰ ϰϳϰϮ͘Ϯϵ ϭϭ͗ϰϲ͗ϱϲ ϭϳͲ:ĂŶͲϮϬ ϮϳϮ͘ϳ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϱ ϰϳϯϱ͘Ϭϴ ϭϭ͗ϱϱ͗ϭϵ ϭϳͲ:ĂŶͲϮϬ Ϯϳϯ͘ϵϴ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϲ ϰϳϯϭ͘ϱϳ ϭϮ͗Ϭϲ͗Ϯϯ ϭϳͲ:ĂŶͲϮϬ ϮϮϴ͘ϲϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϳ ϰϳϮϱ͘ϯϵ ϭϮ͗ϭϯ͗ϰϵ ϭϳͲ:ĂŶͲϮϬ Ϯϰϲ͘ϯϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϴ ϰϳϭϬ͘ϳϮ ϭϮ͗ϮϮ͗Ϯϯ ϭϳͲ:ĂŶͲϮϬ Ϯϱϰ͘ϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ Ϯϵ ϰϲϵϳ͘ϳϮ ϭϮ͗ϯϭ͗ϯϰ ϭϳͲ:ĂŶͲϮϬ ϮϲϬ͘ϱϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϬ ϰϲϴϮ͘ϭϴ ϭϮ͗ϰϬ͗ϯϬ ϭϳͲ:ĂŶͲϮϬ ϯϬϯ͘ϭϳ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ DŝƚƋƵƋϭŽƌĞ^ƵŵŵĂƌǇ WĂŐĞϮŽĨϯ ϯϭ ϰϲϳϵ͘Ϭϰ ϭϮ͗ϱϱ͗Ϯϯ ϭϳͲ:ĂŶͲϮϬ Ϯϳϵ͘ϴϳ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϮ ϰϲϲϵ͘ϲ ϭϯ͗Ϭϰ͗ϯϬ ϭϳͲ:ĂŶͲϮϬ ϯϮϮ͘ϱ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϯ ϰϲϲϭ͘ϯϯ ϭϯ͗ϭϰ͗ϱϭ ϭϳͲ:ĂŶͲϮϬ Ϯϵϳ͘ϰϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϰ ϰϲϱϯ͘ϯϴ ϭϯ͗Ϯϲ͗Ϭϭ ϭϳͲ:ĂŶͲϮϬ ϯϭϳ͘ϰϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϱ ϰϲϰϱ͘ϴϱ ϭϯ͗ϯϴ͗Ϭϯ ϭϳͲ:ĂŶͲϮϬ Ϯϵϵ͘ϵϳ EŽƚ ZĞĐŽǀĞƌĞĚ ϯϲ ϰϲϯϲ͘ϱϱ ϭϯ͗ϰϳ͗Ϯϯ ϭϳͲ:ĂŶͲϮϬ Ϯϵϴ͘ϳϱ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϳ ϰϲϯϯ͘Ϯϯ ϭϯ͗ϱϳ͗ϭϭ ϭϳͲ:ĂŶͲϮϬ ϯϰϯ͘Ϯϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϴ ϰϲϮϭ͘ϭϳ ϭϰ͗ϭϵ͗ϱϴ ϭϳͲ:ĂŶͲϮϬ ϮϮϳ͘ϭϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϯϵ ϰϲϬϴ͘ϲϲ ϭϰ͗Ϯϵ͗ϰϱ ϭϳͲ:ĂŶͲϮϬ Ϯϲϴ͘Ϭϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϬ ϰϱϵϵ͘Ϯ ϭϰ͗ϯϴ͗ϰϬ ϭϳͲ:ĂŶͲϮϬ Ϯϴϴ͘ϵϲ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϭ ϰϱϵϯ͘ϰ ϭϰ͗ϱϬ͗ϬϬ ϭϳͲ:ĂŶͲϮϬ Ϯϳϯ͘ϵϮ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϮ ϰϱϳϲ͘Ϯϯ ϭϰ͗ϱϵ͗Ϯϭ ϭϳͲ:ĂŶͲϮϬ ϭϭϯ͘ϯϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϯ ϰϱϲϱ͘ϰϮ ϭϱ͗ϭϭ͗Ϭϳ ϭϳͲ:ĂŶͲϮϬ Ϯϯϵ͘ϵϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϰ ϰϱϱϳ͘ϳϯ ϭϱ͗ϮϮ͗ϰϳ ϭϳͲ:ĂŶͲϮϬ ϮϮϮ͘ϭϰ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϱ ϰϱϰϲ͘Ϯϯ ϭϱ͗ϯϬ͗ϯϭ ϭϳͲ:ĂŶͲϮϬ ϮϴϮ͘ϰϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϲ ϰϱϯϵ͘ϰ ϭϱ͗ϯϵ͗Ϯϴ ϭϳͲ:ĂŶͲϮϬ Ϯϯϳ͘ϵϱ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϳ ϰϱϯϯ͘ϯϭ ϭϱ͗ϰϴ͗ϰϯ ϭϳͲ:ĂŶͲϮϬ Ϯϯϵ͘ϴϭ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϴ ϰϱϮϵ͘ϲϲ ϭϲ͗ϬϬ͗ϯϬ ϭϳͲ:ĂŶͲϮϬ Ϯϲϴ͘ϵϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϰϵ ϰϱϮϳ͘ϰϵ ϭϲ͗ϭϮ͗ϯϬ ϭϳͲ:ĂŶͲϮϬ ϱϲ͘ϴϯ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϱϬ ϰϱϭϴ͘ϱϮ ϭϲ͗Ϯϱ͗ϰϭ ϭϳͲ:ĂŶͲϮϬ ϮϮϮ͘Ϭϴ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ ϱϭ Ϯϱϭϵ͘ϱϵ ϭϳ͗ϰϰ͗Ϯϳ ϭϳͲ:ĂŶͲϮϬ ϯϯϭ͘ϱϮ ZĞĐŽǀĞƌĞĚ EŽƚƌĞĐŽƌĚĞĚ DŝƚƋƵƋϭŽƌĞ^ƵŵŵĂƌǇ WĂŐĞϯŽĨϯ DŝƚƋƵƋϭϲ͘ϭϮϱ͟WƌŽĚƵĐƚŝŽŶ,ŽůĞ ŽƌĞ EƵŵďĞƌ ŽƌĞ ĞƉƚŚ ;&ƚͿ ŽƌĞ ^ƚĂƌƚ dŝŵĞ ŽƌĞ^ƚĂƌƚ ĂƚĞ dŽƚĂů dŝŵĞ ƌŝůůŝŶŐ ;^ĞĐͿ ŽƌĞ ZĞĐŽǀĞƌǇŽƌĞ>ĞŶŐƚŚ ϭ ϳϴϱϯ͘ϬϮ ϴ͗ϱϯ͗ϯϴ ϯϭͲ:ĂŶͲϮϬ ϭϰϱ͘ϵϱ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯ ϳϴϯϲ͘ϵϳ ϴ͗ϱϵ͗ϰϯ ϯϭͲ:ĂŶͲϮϬ ϭϬϭ͘ϭϰ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϯ ϳϴϯϰ͘ϬϮ ϵ͗Ϭϰ͗Ϯϳ ϯϭͲ:ĂŶͲϮϬ ϭϯϰ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϰ ϳϴϮϰ͘Ϭϰ ϵ͗Ϭϵ͗ϱϳ ϯϭͲ:ĂŶͲϮϬ ϭϭϭ͘ϴϭ WƌĞƐĞŶƚ ϱ͘ϳĐŵ ϱ ϳϱϳϵ͘ϭϮ ϵ͗ϭϴ͗Ϭϵ ϯϭͲ:ĂŶͲϮϬ ϮϮϭ͘ϵϭ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϲ ϳϱϳϱ͘ϬϮ ϵ͗Ϯϱ͗Ϭϴ ϯϭͲ:ĂŶͲϮϬ ϭϭϲ͘Ϭϴ WƌĞƐĞŶƚ ϰ͘ϮĐŵ ϳ ϳϱϲϴ͘ϭϮ ϵ͗ϯϬ͗Ϭϰ ϯϭͲ:ĂŶͲϮϬ ϭϱϰ͘ϰϵ WƌĞƐĞŶƚ ϱ͘ϰĐŵ ϴ ϳϱϲϱ͘Ϭϱ ϵ͗ϯϱ͗ϱϯ ϯϭͲ:ĂŶͲϮϬ ϭϭϲ͘ϵϯ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϵ ϳϱϲϮ͘Ϭϱ ϵ͗ϰϬ͗ϰϰ ϯϭͲ:ĂŶͲϮϬ ϭϯϰ͘ϰϯ WƌĞƐĞŶƚ ϱ͘ϯĐŵ ϭϬ ϳϱϱϴ͘ϵϴ ϵ͗ϰϴ͗ϭϭ ϯϭͲ:ĂŶͲϮϬ ϳϭ͘ϲϵ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϭ ϳϱϱϲ͘Ϭϵ ϵ͗ϱϮ͗Ϯϯ ϯϭͲ:ĂŶͲϮϬ ϴϰ͘Ϭϳ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϮ ϳϱϱϮ͘ϵϳ ϵ͗ϱϳ͗Ϭϵ ϯϭͲ:ĂŶͲϮϬ ϭϬϳ͘ϭϮ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϯ ϳϱϱϬ͘Ϭϴ ϭϬ͗Ϭϭ͗ϱϱ ϯϭͲ:ĂŶͲϮϬ ϴϭ͘ϵϰ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϰ ϳϱϰϳ͘ϭϯ ϭϬ͗Ϭϴ͗ϯϵ ϯϭͲ:ĂŶͲϮϬ ϱϱ͘ϵ WƌĞƐĞŶƚ ϱ͘ϯĐŵ ϭϱ ϳϱϰϯ͘ϵϵ ϭϬ͗ϭϮ͗Ϯϯ ϯϭͲ:ĂŶͲϮϬ ϭϬϭ͘ϱϳ WƌĞƐĞŶƚ ϱ͘ϯĐŵ ϭϲ ϳϱϰϬ͘ϵϳ ϭϬ͗ϭϲ͗ϱϳ ϯϭͲ:ĂŶͲϮϬ ϵϬ͘Ϭϱ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϳ ϳϱϯϴ͘ϱϵ ϭϬ͗Ϯϭ͗ϯϰ ϯϭͲ:ĂŶͲϮϬ ϭϮϵ͘ϳϯ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϴ ϳϱϯϲ͘Ϭϰ ϭϬ͗Ϯϲ͗ϰϬ ϯϭͲ:ĂŶͲϮϬ ϴϰ͘Ϭϳ WƌĞƐĞŶƚ ϱ͘ϱĐŵ ϭϵ ϳϱϯϮ ϭϬ͗ϯϭ͗Ϭϰ ϯϭͲ:ĂŶͲϮϬ ϭϯϭ͘ϰϰ WƌĞƐĞŶƚ ϱ͘ϬĐŵ ϮϬ ϳϱϮϵ͘ϵϳ ϭϬ͗ϯϲ͗ϮϬ ϯϭͲ:ĂŶͲϮϬ ϵϮ͘ϭϴ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯϭ ϳϱϮϳ͘ϳϭ ϭϬ͗ϰϭ͗Ϭϯ ϯϭͲ:ĂŶͲϮϬ ϭϮϴ͘ϴϴ WƌĞƐĞŶƚ ϱ͘ϰĐŵ ϮϮ ϳϱϮϱ͘Ϭϳ ϭϬ͗ϰϲ͗ϯϳ ϯϭͲ:ĂŶͲϮϬ ϱϭ͘Ϯϭ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯϯ ϳϰϴϴ͘ϳϳ ϭϬ͗ϱϭ͗ϯϯ ϯϭͲ:ĂŶͲϮϬ ϴϵ͘ϲϮ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯϰ ϳϬϬϰ͘ϱϰ ϭϭ͗Ϭϴ͗ϰϰ ϯϭͲ:ĂŶͲϮϬ ϭϭϲ͘ϵϯ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯϱ ϲϵϵϮ͘ϵϵ ϭϭ͗ϭϯ͗ϱϮ ϯϭͲ:ĂŶͲϮϬ ϳϵ͘ϴ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯϲ ϲϵϵϭ͘ϱϮ ϭϭ͗ϭϴ͗ϮϮ ϯϭͲ:ĂŶͲϮϬ ϭϭϰ͘ϯϳ WƌĞƐĞŶƚ ϱ͘ϱĐŵ Ϯϳ ϲϵϴϮ͘ϵϳ ϭϭ͗Ϯϯ͗ϯϲ ϯϭͲ:ĂŶͲϮϬ ϭϮϬ͘ϯϰ WƌĞƐĞŶƚ ϱ͘ϱĐŵ 0LWTXT6XUYH\*HRGHWLF5HSRUW'HI6XUYH\&RPPHQWV0'IW,QFO$]LP7UXH79'66IW79'IW96(&IW$+'IW&ORVXUHIW16IW(:IW'/6IW1RUWKLQJIW86(DVWLQJIW86/DWLWXGH/RQJLWXGH57( 1$ 9-5/8"2495.000.98 94.46 2417.37 2494.98 2.21 5.79 2.21 -0.55 2.14 2.12 5970620.61 459508.78 70.33066591 -150.32842481 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Schwartz, Guy L (CED) From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Thursday, February 6, 2020 9:58 AM To: Schwartz, Guy L (CED) Cc: Tirpack, Robert; Johnson, Vern Subject: RE: PTD 219-151 Mitquq 1 ST1 Mud Weight Change Guy, Per our conversation this morning, below is a summary of exhale test and results from yesterday's reduction in mud weight from 10.8pp9 to 10.2ppg MOBM. - Tripped to bottom with mule shoe on drill pipe and conditioned wellbore to 10.8ppg MOBM, losses at —10 bph at 8bpm flow rate. Wellbore would breath back similar volume to what we pumped away when pumps were off - Displaced well to 10.2ppg MOBM, max gas observed at 1720 units (17.2%) Shut in well and perform exhale test. Exhale 20 bbls through choke in 5-10 bbl increments. Observed shut in pressures decreasing and confirmed wellbore breathing. - Circulate through wide open choke and mud weight increased to 10.5ppg due to 10.8-11.0ppg mud that was breathing back from formation - Open annular and monitor well - Circulated 10.2ppg mud down well and observed max gas from breathing at 4800 units. - Close annular and continue to circulate at 3 bpm through wide open choke for six hours. - Shut down pumps and monitor well while opening annular. - Continue to circulate 10.2ppg MOBM at 2-3 bpm, taking returns down flowline. o Well breathing back at —6 bph while circulating o Gas appears to be entrained in the mud system and remains at 800-900 units (no bubbling observed in bell nipple, possum belly, or pits) o Total returns from breathing over the past —30 hours is 250 bbls (lost 1100+ bbls while drilling 8-1/2" intermediate hole section) We plan to continue allowing well to breath back with 10.2ppg mud in the well, and will hopefully relieve the overpressure that we induced on the formation with the heavier mud weight. I will keep you updated on how the well progresses through the day, and get your approval before we pump the cement kick off plug. Also, per our conversation can you please confirm that a re -test on the annular is not required by the AOGCC. Please let me know if you have any questions or require any additional information. Thanks, Garret GARRET STAUDINGER I SENIOR DRILLING ENGINEER ! OIL SEARCH LIMITED PO Box 240927, Anchorage, AK 99524-0927 Mob: +1 907 440 6892 Tel: +� g07 375 4666 Email: garret staudinger&oilsearch corn I Web: www.oilsearch.com From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Tuesday, February 4, 2020 7:02 PM To: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Production Hole 2475' — 6130' MD Mud Type Mineral Oil Based Mud Mud Properties: Mud Weight 10 10.2 ppg Funnel Vis 50-80 seconds PV 20-37 yP 15-25 API Fluid Loss n/a HPHT Fluid Loss < 5 ml/30min pH n/a M BT n/a Electrical Stability > 600 Oil:Water Ratio 80:20 Water Phase Salinity 250-270k Low Gravity Solids < 6.5% I appreciate the help and let me know if you have any questions. Regards, Garret GARRET STAUDINGER I SENIOR DRILLING ENGINEER OIL SEARCH LIMITED PO Box 240927, Anchorage, AK 99524-0927 Mob: +1 907 440 6892 I Tel: +1 907 375 4666 Email: garret.staudinger(a)oilsearch.com I Web: www.oilsearch.com ************************************************************************************* ************************** This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail ************************************************************************************* ************************** ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail ************************************************************************************************** ************* LWD vs Wireline Resistivity to Identify (1) Fluid Loss Zones Oil Search Loss zones were investigated using the LWD shallow resistivity vs. Wireline shallow resistivity. Invasion zones highlighted, where shallow resistivity increases in the wireline vs. LWD data. )) 4 zones identified where this occurs in the 8.5" hole section, between 2500'— 3050'MD 1 - 2500-2520'MD 3 - 2940'MD 91W1061011MINGITUD, WeW MITQUQ-1 Resistivity 1106 2 LN RT 1 14 RT 1 11;R' 2 '2x NP . 2 WR RESS 2 22:c — —22 "S. —2430— — 245C 2BM 2Z5O — XX CONFIDENTIAL — Mitquq 1 / Mitquq 1 ST1 Daily Update 6 February 2020 Schwartz, Guy L (CED) From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Thursday, January 23, 2020 4:30 PM To: Schwartz, Guy L (CED) Cc: Tirpack, Robert Subject: PTD #219-150 Mitquq 1 7" intermediate cement job Follow Up Flag: Follow up Flag Status: Flagged Guy, Yesterday we ran in the hole with 7" casing with no returns while running casing. The suspected loss zone was between 2500-3000' MD based on resistivity log data and what we've seen during drilling operations. We cemented casing last night with a targeted TOC of 4000' MD (500' MD above Nanushuk 9). Results of cement job are as follows: - Landed casing on bottom and flushed annulus volume from bottom up to suspected loss zone at 3000' MD with 75 bbls of 10.8ppg mud - Pumped 58 bbls of 12.Oppg lead cement at 5 bpm - Pumped 19 bbls of 15.3ppg tail cement at 5 bpm - As cement exited shoe, initial circulation pressure at 5 bpm was 525 psi - Final circulating pressure at 5 bpm was 900 psi - Reduced rate to 3 bpm, 750 psi prior to plug bump - Bumped plug at 3 bpm, 800 psi on calculated strokes - Checked floats and they held We had no returns during the cement job, but did get a good indication of lift pressure. Halliburton utilized post job data to remodel the cement job with a loss zone at 3,000' MD, and the modelling indicated a TOC of—3,731' MD. As discussed earlier, we are currently running in hole with a sonic LWD tool on the drilling BHA, logging TOC data from 9- 5/8" surface casing shoe (2495' MD) to TD of the 7". We will also acquire the sonic data across the shoe track and drill this first section down to the base of the Kuparuk. We will provide the sonic log data when we get out of the hole with the BHA. Please let me know if you have any questions. Thanks, Garret From: Davis, Rachel <Rachel.Davis@oilsearch.com> Sent: Thursday, January 23, 2020 9:19 AM To: guy.schwartz@alaska.gov Cc: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Subject: PTD #219-150 Mitquq 1 Update Jan 22, 2020 Morning, Please see operational updates for Mitquq 1 below for January 22, 2020 Mitquq 1 24hr Summary to midnight on Jan 22, 2020 M/U and run 7" casing from 1241' MD to 2481' MD. Circulate and condition with no returns. Discuss plan forward with town, and continue to run 7" casing and landing joint to 6879' MD. Rig up for cement job. Pump as planned with no returns to surface. Rig down cementers equipment. Set and test packoff. Please let us know if you have any questions! Thanks, RACHEL DAVIS TECHNICAL ASSISTANT OIL SEARCH ALASKA PO Box 240927 Anchorage, AK 99524-0927 USA Tel: (907) 375-4678 Email: rachel.davis(d-)oilsearch.com I Web: www.oilsearch.com ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail ************************************************************************************************** ************* 2 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Monday, January 27, 2020 1:51 PM To: Staudinger, Garret Cc: Tirpack, Robert Subject: RE: PTD #219-150 Mitquq 1 Negative Test results Garret, Based on the results of the negative drawdown test (no inflow at 10.1 ppg EMW) on the Kuparuk Sands you have approval to reduce the mud weight to 10.7 ppg for drilling ahead. (original plan was 11.0 ppg) Regards, Guy Schwartz Sr. Petroleum Engineer ACIGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Monday, January 27, 2020 10:33 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com> Subject: PTD #219-150 Mitquq 1 Negative Test results Guy, We performed a negative test on the Kuparuk formation yesterday. 7" casing was set and cemented to base of the HRZ, the shoe track and 20' of new formation was drilled out, and a FIT was completed to 14.Oppg EMW. After this we drilled through the Kuparuk and tripped out of hole for negative test assembly. Negative test was performed with mule shoe positioned —50' from bottom, and Baker service packer set at —1650' MD. Operational summary of the test is below. Formation Testing: Negative Test to 10.1 ppg EMW: - Set 25K down weight to set TST3 Baker Retrievamatic Packer per Baker Rep at 1650' MD (middle element) - Close annular BOP, line up and pump down IA to test packer from above at 500 psi for 15 min. Chart test = good - Bleed off pressure, and put 200 psi on IA. PU to shift packer bypass port open. Observe 60 psi bleed -off. - R/U circulating assembly, and flood line to rig floor with 6.9 ppg LVT base oil. - Pump 15.2 bbl LVT down drill pipe: ICP 380 psi, 45 gpm, 19 SPM, FCP 664 psi - Slack -off to Close bypass port. - Monitor DP pressure for 15 min = 520 psi (initial test pressure). - Bleed off 10 gal: pressure drop to 284 psi. - Monitor DP pressure for 15 min; increase to 370 psi. - Suspected Thermal Expansion (Mud Temp: 52 deg. F) - Bleed off 5 gal: pressure drop to 284 psi. - Monitor DP pressure for 15 min; increase to 320 psi. - Bleed off 5 gal: pressure drop to 205 psi. - Monitor DP pressure for 15 min; increase to 230 psi. - Bleed off 5 gal: pressure drop to 110 psi. - Monitor DP pressure for 15 min; increase to 130 psi. - Bleed off 6 gal: pressure drop to 0 psi. - Monitor drill pipe for 30 minutes: No Flow observed. 31 gallons total bleed back. - Negative Test: PASS - Equalize pressure over packer. Unset packer and rotate to reset to tripping mode. - Displace LVT out of drill pipe and circulate and condition 11.7ppg MOBM. Based on the results from the negative test to 10.1 ppg EMW, we are planning to reduce mud weight to 10.7ppg when we get back on bottom with the drilling BHA (versus our original plan of reducing to 11.0ppg mud weight). This still gives us sufficient overbalance (>150 psi) to the Kuparuk and Alpine, and reduced the risk for excessive ECDs and inducing losses while drilling. Please let me know if you are okay with this change in mud weight, and also if you have any other questions or concerns. Thanks, Garret GARRET STAUDINGER I SENIOR DRILLING ENGINEER OIL SEARCH LIMITED PO Box 240927, Anchorage, AK 99524-0927 Mob: +1 907 440 6892 Tel: +1 907 375 4666 Email: garret.staudingerC@oilsearch.com I Web: www.oilsearch.com ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail ************************************************************************************************** ************* +- _.. ,. GR_102 SSND MD RT GR_102 SSND MD RESS GRM_X_W_RT SSND MD P34H RT SSND GR_100 SSND MD RT 600 gAPI 150.00 11600 000 gAPI 150.00 t.1600 omca onm m:ao.a000 000 PI 150.00 1:1800 oxoo wm m: 000 oa4o 1 t600 000 gAPI 1500' 1 i600 -:44o aaao C RT GR_ARC_RT P16H_RT COW o:o.. e0.00 gAPI 150.00 oz949 onm.m 300.9W0 GRAM 20026 :oa> 200z6 _�.. zo0z CWIe. c�r luf 2002E 2002.6 30 rj I 1 z0 10 10 2100 2100 21 - -- 40 � I 2 1 �S 30 20 '.. 2 2200 —r�� 2200 20 30 x� + 1 40 230 _ - - -- zaao -- 2300 230 - - t dle:rra r bluff ;Middle Schrader Bluff i 4 _ 240 00 2400 40 - — - 80 ! wr hrader Bluff 120- i ae a Lwr , r 1u' LgTj - - eo ) MCu 50 `+ i I � I 250 25 9 250o zsoo 50 Lwr ch er IU Lwr c ra er lu �y 7 I Tuluva 60 I 1 ulirva� 80 280 Tull va 60 �� 600 2600 - i 70 j to I I II t i 270 27 - 2700 2700 270 20 so 6 ! i., l Lwr c r lu e 280 280 30 - 2800 2600 10 l Lwr Schrader Bluff " I � 9G li 1 40 203 29 290 -- zaoo 2900 - 290 I I I I 00 60 I 3a i j 7 TI Tuluvak 300 300 --- o00 3000 300 T I ,4 I I to 3098 4 . j 3098.4 �yta I (, (30984) ,:n 30984 3098 4 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, January 7, 2020 4:31 PM To: 'Staudinger, Garret' Subject: RE: PTD 219-150 Mitquq 1 9-5/8 csg LOT data Garret, With a 210 psi Leak off value you get about 12.37 ppg EMW test. This is a bit below the minimum value specified in the PTD (12.8 ppg) . Normally getting a good LOT/FIT has not been a problem in this area. Based on good hard cement in the shoe track and the surface job going as planned you have approval to drill ahead. Make sure you are vigilant on the geology markers and keep TD above the Kuparuk as planned for this hole section. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.govov). From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Tuesday, January 7, 2020 3:58 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: PTD 219-150 Mitquq 19-5/8 csg LOT data Guy, Please see attached surface casing cement job post report, HES cement unit LOT data, and LOT test plot. Let me know if you have any questions. Thanks, Garret GARRET STAUDINGER I SENIOR DRILLING ENGINEER OIL SEARCH LIMITED PO Box 240927, Anchorage, AK 99524-0927 Mob: +1 907 440 6892 1 Tel: +1 907 375 4666 Email: garret.staudinger(aDoilsearch.com I Web: www.oilsearch.com ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail 75 Test 1 Well: Mitquq 1 Rig: Nabors 7ES Date: January 7, 2020 Mud Pronerties Co. Men: Otto / Weaver / Franks Last Csg Size: 9-5/8" 40# Shoe MD: 2495 Shoe TVD: 2495 Type: OBM WL : Solids: 1.9% LGS MW : 10.75 HT -HP: PH: Visc : API FC : MBT: PV/YP : 30 / 16 Alkalinity: Chl: Gels(0/10/30) : Temp (F) Hydrostatic @ Shoe 1395 Ipsi LOT Pressure psi Final Pressure psi Bbls Csa test LOT BbIs Ttfl Pressure pumped psi 0.00 0.20 93 i 0.40 256 190 0.60 525 224 0.80 810 730 1.00 103C 1.2r 1190 235 1.40 1366 -15 1.60 1561 1.80 1773 2.00 1988 2.20 2239 2.40 2481 2.60 2739 2.80 Y `' 12.8 266 18.5 1005 Shut in LOT Csa test Comments: Mins Pressure Pressure ' shut in L___psLi__Jl psi 0 180 1 170 2 160 3 151 4 147 5 143 2990 10 2960 15 2930 20 2900 25 2880 30 2860 300 200 a L N N L a 100 0 0 1 2 3 4 5 6 7 8 Volume Pumped (Bbls) LETTER OF TRANSMITTAL VNI Oil Search DATE: 2/28/2020 From: To: Shannon Koh Meredith Guhl Oil Search Alaska LLC AOGCC 900 E. Benson Blvd., Level 6 333 W. 71h Avenue, Suite 100 Anchorage, AK 99508 Anchorage, AK 99501 TRANSMISSION TYPE: TRANSMISSION METHOD: ®External Request ❑CD ❑ Thumb Drive ❑Internal Request ❑Email ❑SharePoint ©Hardcopy ❑ Other REASON FOR TRANSMITTAL: ❑To Be Returned ❑Approved ❑Information Only ❑With Our Comments ❑Approved with Comments El For Your Review ❑For Approval [-]For Your Use ©Required pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION MITQUQ 1 (50-103-20808-0000) 10 Boxes of Dry Samples Details on following page Received by: Date: Please sign and return one copy to: Oil Search Alaska ATTN: Shannon Koh 900 E. Benson Blvd., Level 6, Anchorage, AK 99508 907-375-4607 phone shannon.koh@oilsearch.com 311�oI2-a �L-�3"ems 'RECEIVED MAR 11 2020 LETTER OF TRANSMITTAL Box No. Number of Owned Total Weight Description Samples By Depth (ft) (lbs) 1 of 10 Washed & dried samples 30 AOGCC 130-1030 6.00 in envelopes 2 of 10 Washed & dried samples 30 AOGCC 1030-1930 6.00 in envelopes 3 of 10 Washed & dried samples 30 AOGCC 1930-2830 6.00 in envelopes 4 of 10 Washed & dried samples 30 AOGCC 2830-3730 6.00 in envelopes 5 of 10 Washed & dried samples 30 AOGCC 3730-4540 6.00 in envelopes 6 of 10 Washed & dried samples 30 AOGCC 4540-5140 6.00 in envelopes 7 of 10 Washed & dried samples 30 AOGCC 5140-6030 6.00 in envelopes 8 of 10 Washed & dried samples 30 AOGCC 6030-6730 6.00 in envelopes 9 of 10 Washed & dried samples 30 AOGCC 6730-7560 6.00 in envelopes 10 of 10 Washed & dried samples 27 AOGCC 7560-8111 6.00 in envelopes THE STATE 01ALAS-Kt1 GOVERNOR MIKE DUNLEAVY Garret Staudinger Senior Drilling Engineer Oil Search Alaska PO Box 240927 Anchorage, AK 99524-0927 Re: Exploratory Field, Exploratory Pool, Mitquq 1 Permit to Drill Number: 219-150 Sundry Number: 320-021 Dear Mr. Staudinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wwwi.00gcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i", Je e M. rice C Ir DATED this JVday of January, 2020. -4BDMS&� w JAN 3 12020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AA(` 9r Wn 'AN 16 A0GCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Oil Search Alaska Exploratory El • Development ❑ Stratigraphic ❑ Service ❑ 219-150 3. Address: 6. API Number: PO Box 240927 Anchorage, AK 99524-0927 50-103-20808-00-00 7. If perforating: N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Mitquq 1 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 0393876 / ADL 0393875 Undefined 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Length Size MD TVD Burst Collapse Structural Conductor 128' 16" 128' 128' 3,060 psi 1,450 psi Surface 2,495' 9-5/8" 2,495' 2,495' 5,750 psi 3,090 psi Intermediate 6,886' 7" 6,886' 5,923' 7,240 psi 5,410 psi Production 8,250' 6-1/8" OH 8,250' 7,175' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary ❑� Wellbore schematic ❑� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 ' Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: / Commencing Operations: 'IQ` kXt.. ,2,B 1020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended EN,/ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned _ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Garret Staudinger Contact Name: Garret Staudinger Authorized Title: Senior Drilling Engineer Contact Email: arret.staudlrl er oilsearch.com / Contact Phone: 907-440-6892 ti/(�'�/ z-Ozo Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ((( f Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other:J� 3 B D M S JAN 3 12020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ l , Spacing Exception Required? Yes Nood Subsequent Form Required: ❑ APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: �P� Fo m - 3 Revised 4/2017 ,,3« ORIGINAL Approved application is valid for 12 months from the date of approval r7. Submit Form and Attachments in Duplicate (1) Oil Search January 15, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval Oil Search (Alaska), LLC Mitquq 1 Exploration Well (PTD 219-150) North Slope, Alaska Dear Sir/Madam, Oil Search (Alaska), LLC hereby applies for an Application for Sundry Approval to P&A and plugback the Mitquq 1 wellbore in anticipation of drilling Mitquq 1 ST1 (PTD 219-151), an exploratory oil test well on the North Slope. The well is located within state lease acreage on state lands. The Mitquq 1 well will be drilled to TD of—8,250' MD. Upon completion of evaluation it is requested that the well be plugged back to +/- 100' inside the surface casing shoe in anticipation of sidetracking. All hydrocarbon bearing zones below that point in Mitquq 1 will be cemented. If there are any questions and/or additional information desired, please contact me at (907) 440-6892 or garret. staudinger(cDoiIsea rch.com. Respectfully, Garret Staudinger Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-403 Application for Sundry Approval Mitquq 1 Mitquq 1 P&A Procedure Mitquq 1 P&A Schematic Oil Search (Alaska) LLC Anchorage office Tel: +1 907 375 4600 PO Box 240927 Fax: +1 907 375 4630 Anchorage, AK 99524-0927 www.oilsearch.com Mitquq 1 Plugback for Sidetrack Procedure 1. PU -4250' of 3-1/2" 9.2# IBT sacrificial tubing with BHKA disconnect a. Mitquq 1 wellbore will be plug and abandoned with 3-1/2" sacrificial cement stinger and a BHKA disconnect. Top of BHKA will be -4000' MD (-500' above top Nanushuk 9). Cement will be placed inside and outside the sacrificial cement stinger. 7— S r o 2. RIH and tag bottom while circulating to confirm depth. �' ,} `'� H 5 e `J-' 3. Pump the 14.0 ppg Type I/II cement slurry abandonment plug from TD to BHKA depth. L_�. c 5 & c; ,3 4. When plug bumps, release from BHKA and circulate out excess cement. nVJ 5. POOH and LD BHKA running tool. Y 6. Rig up wireline and tag two � Qf abandonment plug. Pressure test 7" casing and abandonment b plug to 2500 psi for 30 min. / (fAa-+t / 5t,,b =4--k- 4-s 4 11C, e-c._ C P 7. Set bridge plug in casing at -2670' MD (below 7" casing cut depth) with wireline. Cv �D�0 8. Make up casing cutter on drillpipe and cut 7" casing at -2645' MD (150' outside 9-5/8" shoe). 9. Pull 7" casi� ger and lay down 7" casing from cut depth. a G 10. Run in hole with drillpipe and place 17.0 ppg Class G balanced kick off plug on 7" casing stub to 100' inside surface casing shoe. .—.7 2, L( b 43 c- C-� 1--L-7-- 11. POOH with drill pipe to 300' above TOC. 12. Drop 6" foam wiper ball and circulate drill pipe clean. 13. If kick-off cement plug was pumped as planned (full returns, mixed and pumped per plan) then proceed to POOH to surface. Kick-off plug will be planned to be tagged with 8-1/2" drilling BHA. (� Abandonment Cement Plug Hole 3-1/2" Sacrificial Stinger in 6-1/8" Open Hole & 7" 26# L80 Vam Top HC Casing Basis Plug Back Open hole volume + 30% excess Cased Hole volume Plug Back TOC 4,000' MD/3,773' TVD (-500' MD above top of Nanushuk 9) Spacer 40 bbls of 12.5 ppg Tuned Spacer Plug Back Cement Volume Cement bls, 847 cuft, 557 sks o 14.0 ppg Type 1/11, Yield: 1.52 cuft/sk t 5 Temp BHST 180' F Verification Method Circulate excess cement off top of sacrificial cement stinger. Notes Job will be mixed on the fly Balanced plug set with 3-1/2" 9.2# L80 IBT sacrificial tubing with 3-1/2" BHKA Kick Off Cement Plug Hole 8-1/2" Open Hole & 9-5/8" 40# L80 BTC Casing Kick Off Plug Open hole volume + 30% excess + 9-5/8" casing volume Basis Kick Off Plug TOC 2,395' MD/TVD (-100' inside 9-5/8" casing) Kick Off Plug BOC —2,670' MD/TVD (7" Bridge Plug Set Depth) Spacer 30 bbls of 12.5 ppg Tuned Spacer Kick Off Plug Cement 24 bbls, 135 cuft, 136 sks of 17.0 ppg Class G, Yield: 0.99 cuft/sk Cement Volume Temp BHST 61° F Verification Method Tag with 8-1/2" sidetrack BHA Notes Balanced cement plug set with 4" DP Mitquq 1 Proposed P&A Well Schematic 16" Conductor 128' MD/TVD Surface Casing 9-5/8" 40# L80 BTC 12 '/4" Hole 2,495' MD/TVD 41 14.Oppg Type 1/II P&A Cement Plug TOC @ 4000' MD (-500' above top Nang) 12.Oppg VariCem Lead Cement TOC @ 4000' MD (-500' above top Nang) 15.3ppg ExpandaCem Tail Cement TOC @ 6386' MID --� (500' above shoe) (A Oil Search Updated Jan. 151h 2020 17.Oppg Class G Kick -Off Cement Plug TOC @ 2395' MD 7" CIBP @ 2670' MD/TVD 2 3-'/z' BHKA @ 4000' MD / 3773' TVD 3-1/2" 9.2# L-80 IBT Sacrificial Tubing Intermediate Casing P S � "� 7" 26# L80 Vam Top HG �\� 8 1/2" Hole 6,886' MD / 5,923' TVD �C_ 3 6-1/8" OH 200 inclination TD: 8250' MD / 7175' TVD -4- loy �3.(0 6tL-- u U G le''a 14 . 0 3(,Z S( 13(oL( f-- .oZsg dt 36,1 �q�1 x 1. Z./ c -' Z .iJ e `'� L_ T 3017. Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist 1 in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then`' it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engin6ers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Schwartz, Guy L (CED) From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Thursday, January 23, 2020 1:12 PM To: Schwartz, Guy L (CED) Subject: RE: P &A sundry Mitquq 1 (PTD 219-150) Hey Guy, I re -checked my numbers and I was using an incorrect ID for the 7" casing. With 30% excess in OH (6886' — 8250' MD), I calculate a volume of 157 bbis. So this comes out a lot closer to the number you calculated. Thanks, Garret From: Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Sent: Thursday, January 23, 2020 10:46 AM To: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Subject: [EXTERNAL] P &A sundry Mitquq 1 (PTD 219-150) Garret, Can you recheck the cement volume for the first plug with the sacrificial tubing. I get 160 bbis (using 30% excess in OH and about 14 bbls displacement due to the 3 % tubing) vs 151 bbl. Not a big deal but would like to make sure you are circulating cement off the top when you disconnect. Would rather have extra cement pumped that too little. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or (Guy Schwartz@alaska.c;ov). ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail ************************************************************************************************** ************* THE STATE GOVERNOR MIKE DUNLEAVY Garret Staudinger Senior Drilling Engineer Oil Search Alaska 900 E Benson Blvd. Anchorage, AK 99508 Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279,1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Exploratory Field, Exploratory Pool, Mitquq 1 Oil Search Alaska Permit to Drill Number: 219-150 Surface Location: 531.27' FNS, 2302.42' FEL, SEC. 3, Tl 1N, R7E, UM Bottomhole Location: 43.54' FSL, 742.86' FWL, SEC. 2, T11N, R7E, UM Dear Mr. Staudinger: Enclosed is the approved application for the permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 approvals 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use. 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, Daniel T. Seamount, Jr. Commissioner DATED this 1 % dly of December, 2019. E EIVED NOV 0 7 2019 STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC PERMIT TO DRILL II /�/ 20 AAC 25.005 �riv'K4�r s 7C� 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑✓ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11. Well Name and Number: Oil Search Alaska Bond No. NUSCGS025100 Mitquq 1 3. Address: 900 E Benson Bouldevard 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99508 MD: 8,250' TVD: 7,175' Undefined 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 531.27' FSL, 2302.42' FEL, Sec 3, T1IN, R7E, UM ADI-41393876 D , 1 3 O 7Z5 Top of Productive Horizon: 13. Approximate Spud Date: B. DNR Approval Number: ONY 353.5' FSL, 1191.81' FEL, Sec 3, T11N, R7E, UM LONS 19-005(Pending) 1st January 2020 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 43.54' FSL, 742.86' FWL, Sec 2, T11 N. R7E, UM 2560 Acres 2,977 W 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 75.3' 15. Distance to Nearest Well Open Surface: x-459506.64 y- 5970621.16 Zone- GL / BF Elevation above MSL (ft): 47.3' to Same Pool: N/A 16. Deviated wells: Kickoff depth: 2500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 47 degrees Downhole: 3,S7*psi 'zi4'L-J Surface: IW46-m 34)4' , 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 16" 84# X-52 Welded 80' 0' 0' 108' 33' Grouted to surface 12-1/4" 9-5/8" 40# L-80 BTC 2,475' 0' 0' 2,475' 2,400' 11.0ppg Lead: uft 15.8ppg Tail: 268cuft68cuft 8-1/2" 7" 26# L-80 Vam Top HC 6,933' 0' 0' 6,933' 5,954' 12.Oppg Lead: 219cuft j 15.3ppg Tail: 263cuft 6-1/8" 1 OH �Gt 33 '7( 7.5 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): ` Hydraulic Fracture planned? Yes ❑ No ❑ 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program ❑ Time v. Depth Plot O Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25,050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Rachel Davis Authorized Name: Garret Staudinger Contact Email: rachel.davis oilsearch.com Authorized Title: Senior Drilling Engineer Contact Phone: 907-375-4678 Authorized Signature: Date: 1 ` %/ 1�A Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: .2 1 q - 1 50- 110 0Q -. Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed t ane. qas hydrates, or gas contained in shales: Other. �,� y C) e ✓ / Samples req'd: Yes NO I Mud log req'd: Yes VNo ❑ H2S measures: Yes ❑ No Directional svy req'd: Yes S/ No ❑ 2 _`S ©O 1.5 c �� ' ` ' Spacing exception req'd: Yes ❑ L1�' Inclination Nov -only svy req'd: Yes ❑ No Z 7�1 n,/ Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY J2-% I Approved COMMISSIONER THE COMMISSION Date: J Form 10-41 Revised 512017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ��-1-7 ORIGINAL November 6, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill Oil Search (Alaska), LLC Mitquq 1 and Mitquq 1 ST1 Exploration Wells North Slope, Alaska Dear Sir/Madam, Oil Search (Alaska), LLC hereby applies for a Permit to Drill an exploratory oil test well on the North Slope of Alaska. The Mitquq 1 well is a deviated wellbore targeting the Nanushuk 9, Torok, Kuparuk C, and Nuiqsut formations. The Mitquq 1 ST1 well is a deviated wellbore targeting the Nanushuk 9 and Torok formations. Both wellbores are located within state lease acreage on state lands. Depending on winter weather conditions and ice road construction, the approximate spud date is anticipated to be mid to late December 2019. Oil Search at this time anticipates using Nabors Rig 7-ES to drill this well. Well testing is planned for the sidetrack and will be addressed in a sundry permit application. Plug and abandon operations for each wellbore will also be addressed in a separate sundry permit application. Please find enclosed for your review Form 10-401 Permit to Drill with a supporting Application for Permit to Drill containing information as required by 20 AAC 25.005 for each wellbore. In compliance with 20 AAC 25.061 Well Site Surveys, a Shallow Hazard Study covering the Mitquq 1 area has been included in the application. If there are any questions and/or additional information desired, please contact me at (907) 440-6892 or garret. staudinger(c�oilsearch.com. Respectfully, Garret Staudinger Senior Drilling Engineer Oil Search (Alaska), LLC Oil Search (Alaska) LLC Anchorage office Tel: +1 907 375 4600 PO Box 240927 Fax: +1 907 375 4630 Anchorage, AK 99524-0927 www.oilsearch.com 4) Oil Search Enclosures: Form 10-401 Permit to Drill Mitquq 1 Application for Permit to Drill Mitquq 1 Well Form 10-401 Permit to Drill Mitquq 1 ST1 Application for Permit to Drill Mitquq 1 ST1 Well WIP Oil Search Attachment 11: Well Schematic Mitquq 1 0 Pre -drill Well Schematic Oil Search Updated Nov. 5t° 2019 16" Conductor J 128' MD/TVD Surface Casing N errE , 1,/;C i 9-5/8" 40# L80 BTC 12-'/4" Hole 2,475' MD 7" EZSV @ 'j 2650' MDrrVD ,Cr� 3-'/:"BHKA@ I Sob n 5 v 4100' MD / 3838' TVD TOC @ 4100' MD / 3838' TVD (-500' above top Nan9) Sacrificial Tubing t 3.L rr —� Intermediate Casing 7" 26# L80 Vam Top HC uP �'aill 8-'/2" Hole K `� Coc J 6,933' MD t 5,954' TVD 6-1/8" OH 20' inclination TD: 8250' MD / 7175' TVD ` Mitquq 1 Permit to Drill Rev3_20191106 - 40 - 06-Nov-19 Oil Search Attachment 13: Wellhead Diagram aaFe E • I __.. ,, _____asm•cns wn . '--PCASNG �:,r.!-,•r newt �_ 1� �C(Mf(k(k l xE °�- e-,rrtn-acMEloT�s c,ne• sin n-a;,s• tarn Pressure Control B EIR 16' x 9-51tr x 7" x 4-1/2 x 3-1/2" 5110M M6-230 Multibowl Assembly, T�UGHES with MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet a GE compa� Mitquq 1 Permit to Drill Rev3_20191106 - 42 - 06-Nov-19 OR Search 1 Application for Permit to Drill Mitgug 1 Well Mitquq 1 Permit to Drill Rev3_20191106 - 1 - 06-Nov-19 W Oil Search Table of Contents Applicationfor Permit to Drill.........................................................................................................................3 1. Well Name......................................................................................................................................3 2. Location Summary ..........................................................................................................................3 3. Blowout Prevention Equipment Information.................................................................................4 4. Drilling Hazards Information...........................................................................................................5 S. Procedure for Conducting Formation Integrity Tests.....................................................................6 6. Casing and Cementing Program.....................................................................................................6 7. Diverter System Information..........................................................................................................7 8. Drilling Fluid Program.....................................................................................................................7 9. Abnormally Pressured Formation Information..............................................................................8 10. Seismic Analysis............................................................................................................................ 8 11. Seabed Condition Analysis............................................................................................................ 9 12. Evidence of Bonding.....................................................................................................................9 13. Proposed Drilling Program...........................................................................................................9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal................................................12 Attachments..................................................................................................................................................13 Attachment 1: Location Maps..........................................................................................................14 Attachment 2: Directional Plan........................................................................................................19 Attachment 3: BOPE Equipment...................................................................................................... 28 Attachment4: Drilling Hazards.........................................................................................................31 Attachment 5: Leak Off Test Procedure...........................................................................................32 Attachment 6: Cement Summary..................................................................................................... 33 Attachment 7: Rig Fluid System........................................................................................................34 Attachment 8: Prognosed Formation Tops......................................................................................36 Attachment 9: Pore Pressure Fracture Gradient Plot......................................................................37 Attachment 10: Independent 3rd Party Pore Pressure Fracture Gradient Plot................................38 Attachment 11: Well Schematic.......................................................................................................40 Attachment 12: Formation Evaluation Program..............................................................................41 Attachment 13: Wellhead Diagram..................................................................................................42 Attachment 14: Days vs. Depth Plot.................................................................................................43 Attachment 15: Shallow Hazards Assessment.................................................................................44 Mitquq 1 Permit to Drill Rev3_20191106 -2- 06-Nov-19 W Oil Search Application for Permit to Drill 1. Well Name 20 AA 25.005 (f): Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as Mitquq 1. This will be an exploratory well. 2. Location Summary 20 AA 25.005 (c) (2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; and Location at Surface Reference to Government Section Lines 531.27' FSL, 2302.42' FEL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,970,621.159 E 459,506,638 Rig KB Elevation 28.0' above ground level Ground Level 47.277' above MSL Location at Top of Productive Interval Reference to Government Section Lines 353.5' FSL, 1191.81' FEL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,970,437.348 E 460,616.518 Measured Depth, Rig KB (MD) 4,593' Total Vertical Depth, Rig KB (TVD) 4,174' Total vertical Depth, Subsea (TVDSS) 4,099' Location at Bottom of Productive Interval Reference to Government Section Lines 43.54' FSL, 742.86' FWL, Sec 2, T11N, R7E, UM NAD 27 Coordinate System N 5,970,117.367 E 462,549.836 Measured Depth, Rig KB (MD) 8,250' Total Vertical Depth, Rig KB (TVD) 7,175' Total vertical Depth, Subsea (TVDSS) 7,100' Mitquq 1 Permit to Drill Rev3_20191106 -3- 06-Nov-19 W Oil Search (D) other information required by 20 AAC 25.050(b); 20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plot drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 2: Directional Plan for further details. (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail, or (B) state that the applicant is the only affected owner. There are no other wells within 200 feet of the proposed Mitquq 1 well. The applicant is the only affected owner. Included in Attachment 2 is an anti -collision scan from Mitquq 1 well location 3. Blowout Prevention Equipment Information 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; BOP test frequency for Mitquq 1 will be 7-days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 7-day BOP test period should not be requested. Nabors 7ES BOP Equipment: BOP Equipment • Hydril annular BOP, model GK, 13-5/8" x 5000 psi • Hydril double gate, 13-5/8" x 5000 psi • Mud cross, 13-5/8" x 5000 psi with 2 ea. 3-1/8" x 5000 psi side outlets • Choke Line, 3" x 5000 psi with 3" manual and HCR valve • Kill Line, 2" x 5000 psi with 2-1/16" manual and HCR valve • Hydril single gate, 13-5/8" x 5000 psi Choke Manifold • Cameron, 3" x 5000 psi working pressure with Swaco super choke and Dreco mud/gas separator BOP Closing Unit • Hydril model 165, 165 gallon, 220 gallon reservoir. Twelve 15 gallon bottles, four nitrogen backup. Equipped with 1 electric and 2 air pumps with emergency power. PLC controlled. Please refer to Attachment 3: BOPE Equipment for further details. Mitquq 1 Permit to Drill Rev3_20191106 - 4 - 06-Nov-19 Oil Search 4. Drilling Hazards Information 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure, 8-1/2" Intermediate Hole Pressure Data Maximum anticipated BHP 2,444 psi in the Torok at 5,341' TVD V (8.8ppg EMW top Torok formation) Maximum surface pressure 1,975 psi from the Torok (0.10 psi/ft gas gradient to surface, 5341' TVD) Rams test to 3,500 psi / 250 psi Planned BOP test pressure Annular test to 2,500 psi / 250 psi [Test pressure driven by annular pressure during frac job] Integrity Test — 8-1/2" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 3,000 psi surface pressure [Test pressure driven by 50% of surface casing yield] 6-1/8" Production Hole Pressure Data Maximum anticipated BHP 3,668 psi in the Kuparuk C at 6,028' TVD (11.7ppg EMW top Kuparuk C formation) Maximum surface pressure 3,065 psi from the Kuparuk C (0.10 psi/ft gas gradient to surface, 6028' TVD) Rams test to 3,500 psi / 250 psi Planned BOP test pressure Annular test to 2,500 psi / 250 psi [Test pressure driven by Maximum Surface Pressure] Integrity Test — 6-1/8" hole FIT after drilling 20'-50' of new hole 7" Casing Test 3,500 psi surface pressure [Test pressure driven by Maximum Surface Pressure] (e) data on potential gas zones; and There is no expected gas zones in the well. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please refer to Attachment 15: Shallow Hazards Assessment Please refer to Attachment 4: Drilling Hazards Mitquq 1 Permit to Drill Rev3_20191106 - 5 - 06-Nov-19 t� 0) Oil Search 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment 5: Leak Off Test Procedure. 6. Casing and Cementing Program 20 AAC 25.005 (c) (2) A complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed,• Casing/Tubing Program Liner I Top Bottom Hole Size Tbg O.D. Wt/Ft Grade Conn Length MD MD i Cement Program TVDss 20" 16" 84# X-52 Welded 80' Surface 128' / 53' Grouted to Surface 11.0ppg Lead: 526bbls, 2953cuft, 1130sks 12-1/4" 9 5/8" 40# L-80 BTC 2,475' Surface 2,475' / ArcticCem, Yield: 2.61 cuft/sk2,400' 15.8ppg Tail: 48bbls, 268cuft, 227sks Type 1/11 —1.18 cult/sk 12.Oppg Lead: 39bbls, 219cuft, 91sks Mitquq 1 7" 26# L-80 VAM TOP 6,933' Surface 6,933' / VariCem, Yield: 2.40 cult/sk 8 1/2„ HC 5,954' 15.3ppg Tail: 47bbls, 263cuft, 212sks ExpandaCem Class G — 1.24 cult/sk Mitquq 1 OH _ To be abandoned with 3-1/2" sacrificial 6-1/8" stin er. Abandonment sund to follow. Stage 1: 12.Oppg Lead: 21bbls, 118cuft, 55sks ExtendaCem, Yield: 2.13 cult/sk Tail: 85bbls, 477cuft, 385sks Mitqu15.3ppg 1ST1 7" 26# L-80 VAM TOP 6,130' Surface 6,130' / ExpandaCem Class G —1.24 cuft/sk 8--1/21/2" HC 5,633' Stage 2: 12.Oppg Lead: 87bbls, 488cuft, 203sks VariCem, Yield: 2.40 cult/sk 15.3ppg Tail: 25bbls, 140cuft, 113sks ExpandaCem Class G — 1.24 cult/sk Tubing 3-1/2" 9.2# L-80 VAM TOP 4,345' Surface 4,345' / 4,046' n/a Please refer to Attachment 6: Cement Summary for further details. Mitquq 1 Permit to Drill Rev3_20191106 -6- 06-Nov-19 Oil Search 7. Diverter System Information 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Nabors 7ES Diverter Equipment: • Hydril annular BOP, model GK, 21 1/4" x 2000 psi, flanged • Diverter Spool 21 1/4" x 2000 psi with 16" flanged sidearm connection. Interlocked knife/gate valves. • 16" Diverter Line Please refer to Attachment 3: BOPE Equipment for further details. 8. Drilling Fluid Program 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Surface Hole 120' — 2475' MD Intermediate Hole 2475' — 6933' MD Production Hole 6933' — 8250' MD Mud Type Water based Spud Mineral Oil Based Mineral Oil Based Mud Mud Mud Mud Properties: Mud Weight 10.5ppg ✓ 10.7-11.0ppg 1z, /l -? Funnel Vis 85-275 seconds 50-80 seconds 50-80 seconds PV 10-30 20-37 20-37 yP 30-45 15-25 15-25 API Fluid Loss < 14 ml/30min n/a n/a HPHT Fluid Loss n/a < 5 ml/30min < 5 ml/30min pH 8.6-10.5 n/a n/a M BT 20-30 n/a n/a Electrical Stability n/a > 600 > 600 Oil:Water Ratio n/a 80:20 80:20 Water Phase n/a 250-270k 250-270k Salinity < 10% < 6.5% < 6.5% Low Gravity Solids A copy of drilling fluid system on Nabors rig 7ES is contained in Attachment 7: Rig Fluid System. Mitquq 1 Permit to Drill Rev3_20191106 -7- 06-Nov-19 9. Abnormally Pressured Formation Information 20 AA 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Please refer to Attachment 8: Prognosed Formation Tops, Attachment 9: Pore Pressure Fracture Gradient Plot, and Attachment 10: Independent P Party Pore Pressure Fracture Gradient Plot. 10. Seismic Analysis 20 AA 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AA 25.061(a), Please refer to Attachment 15: Shallow Hazard Assessment Mitquq 1 Permit to Drill Rev3_20191106 - 8 - 06-Nov-19 0) Oil Search 11. Seabed Condition Analysis 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); The Mitquq 1 Well is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 have been met; Oil Search Alaska is currently preparing to increase its bond amount already on file with the commission in accordance with updated AOGCC regulations. Evidence of bonding will be forthcoming. 13. Proposed Drilling Program 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (13) a copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to Mitquq 1/ST1 is listed below. Please refer to Attachments 11-14 for a Well Schematic, Formation Evaluation Program, Wellhead Diagram and Days vs Depth Plot. Proposed Drilling Program Mitgug 1 X4.i a 16" conductor to -128' MD/TVD. Cement to surface. Install Cellar. / rig up Nabors Rig 7ES. ellhead landing rin on 16" co ductor. p spacer spools and iverte over the 16" conductor. VerifyX ine is 5' away from a pote ial ource of ignition and beyond theure.test diverter and knife alve as per AOGCC regulations. Prosnotice for witnessing diverter e 6. Pick up 4" drill pipe, fill pit ith sp d mud and prepare for surface up 12-1/4" motor BHA with WD and L D tools. 7. Spud well and drill vertical hole section as per well plan to 2475' MD/TVD. Make Mitquq 1 Permit to Drill Rev3_20191106 - 9 - 06-Nov-19 k! r c.tk'— Mitquq 1 and Mitquq 1 ST1 Drilling Program Overview Mitquq 1 1. Drill/drive 16" conductor to —128' MD/TVD. Cement to surface. Install Cellar. 2. Move in / rig up Nabors Rig 7ES. 3. Install wellhead landing ring on 16" conductor. 4. Nipple up spacer spools and diverter over the 16" conductor. Verify that the diverter line is at least 75' away from a potential source of ignition and beyond the drill rig substructure. 5. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC 48hrs notice for witnessing diverter test. 6. Pick up 4" drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up 12- 1/4" RSS BHA with MWD and LWD tools. 7. Spud well and drill vertical hole section as per well plan to 2475' MD/TVD. Make directional corrections and wiper trips as required. Circulate and condition hole and then POOH. 8. Run 9-5/8" surface casing as per casing tally and land on pre -installed landing ring. Circulate and condition mud prior to commencing cement job r__4 Sf w b cw. 6 c �� 9. Cement 9-5/8" casing as per cement program. Adequate excess cement will be pumped to ensure surface casing is cemented to surface. ,__3p10. Nipple down diverter and nipple up BOPE and test to 250 00 psi as per AOGCC regulations. Provide AOGCC 48hrs notice for witnessing BOP test. 11. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH, clean out to top of float e%ment and displace well to 10.7p„ pg MOBM. Pressure test casing to 3000 psi for 30 min.` 12. Drill out shoe track and 20 - 50' of new formation. Perform leak off test and submit results to AOGCC. OT _ 12. g Pp, L T J ✓ 13. Directionally drill 8-1/2" intermediate hole section to TD at base HRZ at —6933' MD / 5954' TVD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH. 14. Rig up wireline and complete open hole wireline as per formation evaluation program. 15. Run 7" production casing as per casing tally, land casing on wellhead mandrel hanger. Circulate and condition mud prior to commencing cement job. 16. Cement 7" casing with single stage cement job as per cement program. Monitor returns during displacement. 17. Make up 6-1/8" RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to 11.7ppg MOBM. Pressure test casing to 3500 psi for 30 min. 18. Drill out shoe track and 20 - 50' of new formation. Perform formation integrity test and submit 'A results to AOGCC. n 1 L_ - i 3. Z rP �_ 19. Directionally drill 6-1/8" hole section as per well plan to base of Kuparuk at —7127' MD / 6128' TVD. �40 Y / 20. POOH to 7" casing shoe. Perform inflow test on 6-1/8" open hole section to 10.5ppg EMW using drilling BHA. If inflow test is successful, displace well to 11.Oppg MOBM. 21. Continue directionally drilling 6-1/8" hole section as per well plan to TD at —8250' MD / 7175' TVD. Perform wiper trips as required. POOH. WIL- 22. Rig up wireline and complete open hole wireline as per formation evaluation program. 0 H ` 23. Apply for Sundry Permit to P&A Mitquq 1 wellbore. Mitquq 1 wellbore will be plug and abandoned with 3-1/2" sacrificial cement stinger and a BHKA disconnect. Top of BHKA will be �. 6 —4100' MD (-500' above top Nanushuk 9). Cement will be placed inside and outside the sacrificial cemen stinger. 5elegse from9 BHKA and circulate out excess cement. 0 �o�^ 24. Rig up wireline and tag top of abandonment pl%g. Pressure test 7" casing and abandonment 'futco plug to 1500 psi for 30 min. L or 25. Set bridge plug in casing at —2650' MD (below 7" casing cut depth). �-p 26. Make up casing cutter on drillpipe and cut 7" casing at —2625' MD (150' outside 9-5/8" shoe). 27. Pull 7" casing hanger and lay down 7" casing from cut depth. 28. Run in hole with drillpipe and place balanced kick off plug on 7" casing stub to 100' inside surface casing shoe. 3 � ` m -o ro �- / Mitgug 1ST1 PI �5 / 29. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH, clean out to top of cement kick off plug. 30. Kick off cement plug below surface casing shoe and directionally drill 8-1/2" production hole �,Pf to core point at —4400' MD / 4166' TVD. Perform wiper trips as required. Circulate and condition hole. POOH. I 31. Make up 8-1/2" coring assembly and run in hole. Circulate and condition hole prior to dropping coring ball. 32. Drop ball and cut core as per coring program. Make connections with coring assembly and continue coring. At the end of the core run, pick up to break core and then POOH as per coring trip schedule to allow the core to off gas. 33. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH and MAD pass coring interval. Drill 8- 1/2" hole to well TD as per well plan to 6130' MD / 5708' TVD. Circulate and condition hole and then POOH. 34. Rig up wireline and complete open hole wireline as per formation evaluation program. 35. Run 7" production casing as per casing tally, land casing on wellhead mandrel hanger. Circulate and condition mud prior to commencing cement job. 36. Cement 7" casing with two stage cement job as per cement program. Monitor for cement returns when stage tool is opened. Monitor for cement returns to surface when second stage is pumped. 37. Make up 6-1/8" clean out BHA. RIH, drill out staged cement tool and perform negative test on 7" casing. Clean out to 7" shoe track. Displace well to 9.5ppg brine. 38. Pressure test 7" casing to 3500psi for 30mins. POOH. 39. Rig up wireline and complete cased hole ce=nt evaluation and VSP logs. 40. Prepare for completion operations. C6Lr� n 5w�(J�._ �l Oil Search directional corrections and wiper trips as required. Circulate and condition hole d then POOH. 8. Run 9-5/8" surface casing as per casing tally and land on pre -installed land' g ring. Circulate and condition mud prior to commencing cement job. 9. Cement 9-5/8" casing as per cement program. Adequate excess cem nt will be pumped to ensure surface casing is cemented to surface. 10. Nipple own diverter and nipple up BOPE and test to 250 / 350 psi as per AOGCC regulation Provide AOGCC 48hrs notice for witnessing BOP st. 11. Makeup 8-1/ 'RSS BHA with MWD and LWD tools. RIH, c an out to top of float equipment and place well to 10.7ppg MOBM. Pressur test casing to 3000 psi for 30 min. 12. Drill out shoe track a 20 - 50' of new formation. P orm leak off test and submit results to AOGCC. 13. Directionally drill 8-1/2" in rmediate hole secti to TD at base HRZ at —6933' MD / 5954' TVD. Perform wiper trips as quired. Circulate nd condition hole to run casing. POOH. 14. Rig up wireline and complete op hole wire ne as per formation evaluation program. 15. Run 7" production casing as per case tall ,land casing on wellhead mandrel hanger. Circulate and condition mud prior to c encing cement job. 16. Cement 7" casing with single stage ce job as per cement program. Monitor returns during displacement. Pressure test c ing t 500 psi for 30 min on plu �iCk 17. Makeup 6-1/8" RSS BHA with MW and LWD ols. RIH, clean out to top of float equipment and displace well to 1 .1ppg MOBM. 18. Drill out shoe track and 20 - 50' f new formation. P orm formation integrity test and submit results to AOGCC. 19. Directionally drill 6-1/8" hol section as per well plan to T at "'8250' MD / 7175' TVD. Perform wiper trips as req fired. POOH. 20. Rig up wireline and com lete open hole wireline as per formati evaluation program. 21. Apply for Sundry Per to P&A Mitquq 1 wellbore. Mitquq 1 well re will be plug and abandoned with 3-1/ " sacrificial cement stinger and a BHKA discon ct. Top of BHKA will be —4100' MD (-50 above top Nanushuk 9). Cement will be placed i ide and outside the sacrificial cem nt stinger. Release from BHKA and circulate out exce cement. 22. Rig up wireline a d tag top of abandonment plug. P�r�z ab abandonment ug to 1500 psi for 30 min. 23. Set bridge plu in casing at —2650' MD (below 7" casing cut dept h - 7 24. Make up ca ng cutter on drillpipe and cut 7" casing at —2625' MD (150' outside 9 /8" shoe). 25. Pull 7" ca ng hanger and lay down 7" casing from cut depth. 26. Run in h le with drillpipe and place balanced kick off plug on 7" casing stub to 100' i side surface asing shoe. Mitquq 1 Permit to Drill Rev3_20191106 - 10 - 06-Nov-19 Oil Search Mitgug 15T1 27. Make up 8-1 " RSS BHA with MWD and LWD tools. RIH clean out to top of cement kick off plug. 28. Kickoff cement plu elow surface casing shoe an directionally drill 8-1/2" production hole to core point at — 00' MD / 4166' TVD. P form wiper trips as required. Circulate and condition hole. POO 29. Make up 8-1/2" coring asse ly and run i ole. Circulate and condition hole prior to dropping coring ball. 30. Drop ball and cut core as per corin p gram. Make connections with coring assembly and continue coring. At the end of the c run, pick up to break core and then POOH as per coring trip schedule to allow the c re t off gas. 31. Make up 8-1/2" RSS BHA with WD and L D tools. RIH and MAD pass coring interval. Drill 8-1/2" hole to well TD as per ell plan to 61 ' MD / 5708' TVD. Circulate and condition hole and then POOH. 32. Rig up wireline and comp to open hole wireline as er formation evaluation program. 33. Run 7" production casi g as per casing tally, land casin n wellhead mandrel hanger. Circulate and conditi mud prior to commencing cemen 'ob. 34. Cement 7" casing ith two stage cement job as per cement p ram. Monitor for cement returns when sta a tool is opened. Monitor for cement returns t surface when second stage is pumpe . 35. Make up 6-1/ " clean out BHA. RIH, drill out staged cement tool and pe orm negative test on 7" casin Clean out to 7" shoe track. Displace well to 9.5ppg brine. 36. Pressure st 7" casing to 3500psi for 30mins. POOH. 37. Rig up ireline and complete cased hole cement evaluation and VSP logs. 38. Prep a for completion operations. Mitquq 1 Permit to Drill Rev3_20191106 - 11 - 06-Nov-19 Oil Search 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. Water -based and oil based drilling muds and cuttings will typically be hauled directly offsite via truck as it is generated. Contractual arrangements have been made with other operators on the North Slope to utilize their waste injection/disposal facilities (Class 1 and Class 2) at Prudhoe Bay, Kuparuk and Milne Point. If waste cannot be hauled directly offsite, it may be stored temporarily in drilling waste cuttings bins or a bermed cuttings storage cell in accordance with a drilling waste temporary storage plan approved by Alaska Department of Conservation (ADEC) Solid Waste Program until it can be transported for proper disposal. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. Mitquq 1 Permit to Drill Rev3_20191106 - 12 - 06-Nov-19 Oil Search Attachments Mitquq 1 Permit to Drill Rev3_20191106 - 13 - 06-Nov-19 tAh wly Oil Search Attachment 1: Location Maps Mitquq 1 Permit to Drill Rev3_20191106 - 14 - 06-Nov-19 I I I I I I I I GREATER MOOSES `- -----' TOOTH I -- I � NUIQSUT I I I L-- I I I 1 I i I I r_—_—_---____ I I I I PiKKA ; I / I i Pikka C I ' Q-5 t t I PLACER Q3 r I I Q-301 I I — Mitquq 1 I / Q-B I I I I -- I^ w saK 1 I `,.t y\ IJ I I ; I Ltk CORNERS AK 14 I I _ .♦I j j I MusTAN / I,_...—� NdAKS --\ --- - -T I - L---- VEncH I , ` KUPARUK RIVER _ I J I I W SAK'ri —1 I W vAkW L_ / ' I / I W 1-26 e e � MILNE PO1N ' s I I 1R t t: I IQ ..._ 3 IStirrup l, i -" _ I r I --I . HS-1 t I MS 5 j I ' I I I I K-1 ® 2011-2019 DRILLED WELLS EXPLORATION ICE ROADS EXPLORATION DRILL SITE — n L _ PRODUCTION UNIT — NS EXISTING GRAVEL ROADS C—� NS EXISTING FACILITY Q NPR -A BOUNDARY -- NS EXISTING PIPELINES �_J OIL SEARCH LEASES N WE OIL SEARCH ALASKA U.C. 2019-2020 EXPLORATION CAMPAIGN PROPOSED CAMPAIGN OVERVIEW MOBS D 1 2 GCS: SlaleP--1ka 4HIPS —4feel ®,E: Project Locatio n ' ti Oil Search R NnD1983 v/5/3RIP. REV: I.R. BY: JR ®Gomelars I me:OPSI9-1OGfNwS kaRootlfOGCCI �^�. AS -STAKED MITQUQ 1 LOCATION T Co 1 - a� 7q- T11N NAD-83(2011)( EPOCH:2010.0000) Alaska State Plane Zone 4 DD 2 US Survey FT a WELL N 5,970,370.93' E 1,599,539.38' CD4 t LOCATION EL 47.28' (NAVD88 Utilizing Geoid12B) �w NAD-83(2011)( EPOCH:2010.0000) 0 — N 70o19'49.287" T1ON W 150°19'53.637" I �IASRCMINE SITE NAD-27 Alaska State Plane Zone 4 NUICSUIT , . US Survey FT � I N 5,970,621.16' E 459,506.64' J� T1oN T9N NAD-27 N 70'19'50.402" VICINITY MAP W 150°19'42.392" T11 N. R7E SCALE: V 6 MILES SEC.3 NOTES 1. DATE OF FIELD SURVEY AUGUST 5, 2019. 2. BASIS OF COORDINATES PER OPUS PROPOSED SOLUTION OF STATIC GPS OBSERVATIONS 35' WIDE ICE ROAD ON AUGUST 5, 2019. 3. WELL LOCATED WITHIN PROTRACTED SEC 3, T11 N, R7E, UMIAT MERIDIAN. 531' FROM SOUTH SECTION LINE 2302' FROM EAST SECTION LINE MITQUQ 1 4. ICE PAD LOCATED WITHIN PROTRACTED SEC / (AS -STAKED 3 AND 10, T11 N, R7E, UMIAT MERIDIAN. WELL LOCATION) PROPOSED ICE PAD 1,000, X 1,000, E Nis"101 o_ 500 / (P n � N O m Ln o r? o SEC. 3, T11N, R7E, U. M. 'o a a c SEC. 10, T11N, R7E, U. M. s 0 � 1 0p0 ' £ Sh°r4y d 0 150 300 Si5`,01, ti p SCALE IN FEET MMIR41K' MITQUQ 1 EXPLORATORY WELL PROPOSED ICE PAD RECONFIGURATION U M I A Q & AS -STAKED WELL LOCATION o��wWs+a.�wc Oil Search NORTH SLOPE, ALASKA 6700 Arctic Spur Road Anchorage, AK 99516 DATE: 10/29/2019 DRAWN BY FM / MMHN SHEET: 1 OF 1 (9071677-8220 SCALE: AS SHOWN CHECKED BY: KJP JOB No: 80209.19 IUI'S DIMENSION_LINE SECTION 2019-2020 EXPLORATION CAMPAIGN ■r)�C/j/�!�' O� WELL SURFACE HOLE L _t LEASE OUTLINE yyN}}�� MITQUQ 1 WELL PLAN Oil Search WELLTRAJECTORY TOWNSHIP W1S4►zt8 0®Feet GCS: NAD 1927 StatePlone Alaska 4 FIPS 5004 ��ll��jjLL��((jj ®Meters DATE: 9/24/2019. REV: 2.0. By: JB S 0 100 200 Document name: OPS-19-20-W-M_Mitqugl_wellPlan NAD27 WELL LOCATION 0 EQUIPMENT OUTLINES = ICE PAD/ICE ROAD OUTLINES --ICE ROAD CENTERLINE -- DIVERTER ® 30-FT OFFSET SECTION 4v f�.S: � • 4 ��vt Pjar e� Well f r !I safety Stimulation Well Test RIG � Truck Staging t rye / ,.temP storaoe Area O{{ice t I R. on5e 't` i\1 RaSP f,V%V Cam © �r fuel storage Camp p CommsA a ; Annex Shop OIL SEARCH ALASKA I.I.C. N 2019-2020 Exploration Campaign MITQUQ 1 DRILL SITE OVERVIEW (Nabors 7ES Rig) 0 20 40 Oil Search Figure X ®Meters GCS: NAD 1927 S1atePlane Alaska 4 FIPS 5004 ®Feet DATE: 2019-09-24. REV'. 2.0. By: JB 0 50 100 Dowmenfname: OPS-19-20-P-PE-M POO_Mitqual NAD27 Oil Search Attachment 2: Directional Plan Mitquq 1 Permit to Drill Rev3_20191106 - 19 - 06-Nov-19 Oil Search Mitquq-1 wp02 v6 Proposal Geodetic Report Schlumberger (Def Plan) _ ......... Client: .................,�.+.. Oil Search ^vy • u�a u uyuuuuu: Vertical Section Azimuth: ornsai 99.084' (True North) Field: NS West Vertical Section Orlgln: 0.000 ft, 0.000 It Structure I Slot: Mitquq.1 - NAD27 / Mitquq-1 TVD Reference Datum: Rotary Table Well: Mitquq-1 TVD Reference Elevation: 75.277 ft above MSL Borehole: Mitquq-1 Ground Elevation: 47.277 It above MSL API#: 50103oucxa00 Magnetic Declination: 16.145 ° Survey Name: Mitquq-1 wp02 v6 Total Gravity Field Strength: 1002.0008mgn (9.80665 Based) Survey Date: November 06, 2019 Gravity Model: DOX Tort / AHD I DDI / ERD Ratio: 73.948' / 3112.312 It / 5.423 / 0.434 Total Magnetic Field Strength: 57357.165 nT Coordinate Reference System: NAD27 Alaska State Plana, Zone 04, US Feet Magnetic Dip Angle: 80.732 ° Locatlon Lot / Long: N 70° 19' 50.40263', W 150' 19' 42.39178- Declination Date: December, 31, 2019 Location Grid N/E y/X: N 5970621.161 ftUS, E 4595D6.640 ftUS Magnetic Declination Model: BGGM 2019 CRS Grid Convergence Angle: -0.3093' North Reference: True North Grid Scale Factor: 0.99990186 Grid Convergence Used: 0.0000' Version I Patch: 2.10.782.0 Total Corr Mag NorthaTrus North: 16.1445' Local Coord Referenced To: Well Head Commanta MD Inc] Ai. True TVDSS TVD VSEC NS EW TF DLS Directional Northing Eaating Latitude Longitude Easting (ft) l°I 19 (ft) (ft) (ft) (ft) (ft) 1°I ('/10011) Difficulty Indera MUS) (ftUS) (N/S • • ^) (E/W °' ^) (ftUS) RTE 0.00 0.00 0.00 -75.28 0.00 0.00 0.00 O.DO 99.09M WA 0.00 5970621.16 459506.64 N 701950.40 W 1501942.39 459506.64 Base Permafrost 1525.28 0.00 99.09 1450.00 1525.28 0.00 0.00 0.00 99.09M 0.00 0.00 5970621.16 459506.64 N 70 19 50.40 W 150 /9 42.39 459506.64 Mid Schrader Bluff 2075.28 0.00 99.09 2000.00 2075.28 0.00 0.00 0.00 99.09M 0.00 0.00 5970621.16 459506.64 N 701950.40 W150/94Z39 459506.64 MCU 2410.28 0.00 99.09 2335.00 24f0.28 0.00 0.00 0.00 99.09M 0.00 0.00 5970621.16 459506.64 N 701950.40 IN150194Z39 459506.64 9.518-Cog 2475.28 0.00 99.09 2400.00 2475.28 0.00 0.00 0.00 99.09M 0.00 0.00 5970621.16 459506.64 N 701950.40 IN ISO 1942.39 459506.64 KOP Cry 4/100 2500.00 0.00 99.09 2424.72 2500.00 0.00 0.00 0.00 99.09M 0.00 0.00 5970621.16 459506.64 N 70 19 50.40 W 150 19 42.39 459506.64 Lower Schrader Bluff 2550.29 2.01 99.09 2475.00 2550.28 a88 -0.14 0.87 99.09M 4.00 0.25 5970621.02 459507.51 N 70 19 50.40 W 150 19 42.37 459507.51 2600.00 4.00 99,09 2524.64 2599.92 3.49 -0.55 3.44 99.09M 4.00 1.14 5970620.59 459510.08 N 701950.40 W 150 19 42.29 459510.08 Tuluvak 2627.44 5.09 99.09 2652.00 262Z28 5.66 -0.89 5.59 HS 4.00 1.46 5970620.24 459SIZ22 N 701950.39 W1501942.23 459512.22 2700.00 7.99 99.09 2624.07 2699.35 13.93 -2.20 13.75 HS 4.00 2.05 5970618.89 459520.38 N 70 19 50.38 W 150 19 41.99 459520.38 2800.00 11.99 99.09 2722.54 2797.82 31.28 -4.94 30.88 HS 4.00 2.57 5970616.06 459537.49 N 70 19 50.35 W 150 19 41.49 459537.49 2900.D0 15.99 99.09 2819.55 2894.83 55.44 -8.75 54.75 HS 4.00 2.95 5970612.11 459561.33 N 70 19 50.32 W 150 19 40.79 459561.33 3000.00 19.98 99.09 2914,65 2989.92 86.31 -13.63 85.23 HS 4DO 3.24 5970607.07 459591.79 N 701950.27 W 150 19 39.90 459591.79 3100.00 23.98 99.09 3007.36 3082.64 123.74 -19.54 122.19 HS 4.00 3.47 5970600.96 459628.71 N 70 19 50.21 W 150 19 38.82 459628.71 3200.00 27.98 99.09 3097.24 3172.51 167.53 -26.45 165.43 HS 4.00 3.67 5970593.82 459671.91 N 70 19 50.14 W 150 19 37.56 459671.91 3300.00 31.97 99.09 3183.84 3259.12 217.49 -34.34 214.76 HS 4.00 3.85 5970585.66 459721.19 N 7019 50.06 W 15019 36.12 459721.19 3400.00 35.97 99.09 3266.76 3342.03 273.35 -43.16 269.92 HS 4.00 4.00 5970576.54 459776.30 N 70 19 49.98 W 150 19 34.51 459776.30 3500.00 39.97 99.09 3345.58 3420.85 334.86 -52.88 330.66 HS 4.00 4.14 5970566.50 459836.98 N 70 19 49.88 W 150 19 32.74 459836.98 3600.00 43.96 99.09 3419.91 3495.19 401.72 -63.43 396.68 HS 4.00 4.26 5970555.59 459902.93 N 70 19 49.78 W 150 19 30.81 459902.93 End Cry 3675.31 46.97 99.09 3472.72 3548.00 455AO -71.91 449.68 HS 4.00 4.35 5970546.83 459955.89 N 701949.70 W 150 19 29.26 459955.89 Nanuhuk Formation 4415.82 46.97 99.09 3978.00 4053.28 996.74 -157.39 984.24 HS 0.00 4.71 5970458.47 460489.92 N 701948.85 W1501913.66 460489.92 Nanuhuk 9 Sandstone 4593.16 46.97 99.09 4099.00 4174.28 1126.38 -177.86 1112.25 HS 0.00 4.77 5970437.31 460617.80 N 70 19 48.65 W 150 19 9.92 460617.80 Cry 1.161100 5261.05 46.97 99.09 4554.72 4630.00 1614.64 -254.96 1594.38 LS 0.00 4.94 5970367.62 461099.46 N 70 19 47.89 W 150 18 55.84 461099.46 5300.00 46.52 99.09 4581.42 4656.69 1643.01 -259.44 1622.40 LS 1.16 4.95 5970352.99 461127.45 N 701947.85 W 150 18 55.03 461127.45 5400.00 45.36 99.09 4650.95 4726.23 1714.87 .270.79 1693.36 LS 1.16 4.98 5970341.26 461193 34 N 70 19 47.74 W 150 18 52.95 461198.34 Nanuhuk 8 5479.13 44.44 99.09 4707.00 4782.26 1770.72 -27R61 1748.51 LS 1.16 5.00 5970332.15 461253.44 N 70 19 47.65 W 150 18 51.34 461253.44 5500.DO 44.20 99.09 4721.93 4797.21 1785.31 -281.91 1762.91 LS 1.16 5.01 5970329.77 461267.83 N 701947.63 W 150 18 50.92 461267.83 5600.00 43,04 99.09 4794.33 4869.60 1854.29 -292.81 1831.03 LS 1,16 5.04 5970318.51 461335.88 N 701947.52 W 150 18 48.93 461335.88 5700.0, 41.88 99.08 4868.10 4943.38 1921.80 -303.46 1897.69 LS 1.16 5.06 5970307.49 461402.47 N 70 19 47.42 W 150 18 46.99 461402.47 5800.00 40.72 99.08 4943.23 5010.51 1987.79 -313.88 1962.85 LS 1.16 5.09 5970296.72 461467.57 N 70 19 47.31 W 150 18 45.09 461467.57 59D0.00 39.55 99.08 5019.68 5094.96 2052.25 324.06 2026.50 LS 1.16 5.11 5970286.20 461531.16 N 70 19 47.21 W 150 IS 43.23 461531.16 6GW 00 38.39 99,08 5097,43 5172.70 2115.15 -333.99 2088.61 LS 1.16 5.13 5970275.93 451593.21 N 701947.11 W 150 18 41.41 461593.21 :100.00 37.23 99.08 5176.43 5251.70 2176.45 -343.67 2149,15 LS 1.16 5.16 5970265.93 461653.69 N 701947.02 W 150 18 39.65 461653.69 200'00 3607 99.08 5256.65 5331.93 2236.15 353.10 2208.09 LS 1.16 SAS 5970256.19 461712.67 N 701946.93 W 150 10 37.93 461712.57 Torok (Na") 6211.56 35.94 99.08 5266.00 5341.28 224Z94 354.17 2214.80 LS 1.16 5.18 5970255.08 461719.28 N 70 19 46.92 W 150 18 37.73 461719.28 6300.01) 34.91 99.08 5338.07 5413.35 2294.20 -362.26 2265.42 LS 1.16 5.20 5970248.71 461769.85 N 701946.54 W 1501836.25 461769.85 6400.00 33.75 99.08 5420.65 5495.93 2350.60 -371.17 2321.11 LS 1.16 5.22 5970237.51 461825.48 N 701946.75 W 150 18 34.63 461825.48 6500.DD 32.59 99,08 5504.35 5579.63 2405.31 -379.80 2375.13 LS 1.16 5.24 5970228.58 461879.45 N 701946.66 W 150 18 33.05 461879.45 6600.00 31.43 99,08 5589.15 5664.43 2458.31 -388.17 2427.47 LS 1.16 6.25 5970219.93 461931.74 N 70 19 46.58 W 150 18 31.52 461931.74 6700.DO 30.27 99.08 5675.00 5750.28 2509.58 396.27 2478.10 LS 1.16 5.27 5970211.66 461982.32 N 70 19 46.50 W 150 18 30.04 461982.32 HRZ 6701.15 30.25 99.08 5676.00 5751.28 2510.17-396.36 2478.68 LS 1.16 5.27 5970211,47 46198289 N 70 19 46.50 W1501830.03 461982.89 NS West\Mitquq-1\Mitquq-1\Mitquq-1\Mitquq-1 wp02 v5 Drilling Office2.10.544.0 Schlumberger-Private 11 /6/2019 9:41 AM Page 1 of Comments MD Ind A.I. True TVDSS TVD VSEC NS EW TF DLS Directional Northing Eating Latitude Longitude Eastin9 (ft) (°) (°I (fill (it) (ft) (it) (ft) (°) (°1100ft) Difficulty Index (ftUS) RUS) (NIS °' ") (EIW °' •) MUS) 6800.00 29.11 99.08 5761,88 5837.15 2559.11 404.08 2527.00 LS 1.16 5.29 5970203.48 462031.17 N 701946.42 W 150 18 28.62 462031.17 6900.00 27.94 99.08 5849,74 5925.01 2606.86 411.62 2574.16 LS 1.18 5.30 5970195.69 462078.28 N 70 19 46.35 W 150 18 27.24 462078.28 7' Csg 6933.00 2756 99.OB 5878.94 5954.22 2622.23 414.05 2589.33 LS 1.16 5.31 5970193.18 462093.44 N 70 19 46.33 W 150 18 26.80 462123.62 7000.00 26.78 99.08 5938.55 6013.82 2652.82 410.88 2619.54 LS 1.16 5.32 5970188.19 462123.62 N 70 19 46.28 W 150 18 25.91 462130.79 Kup C Sandstone 7016.18 26.60 99.08 5953.00 6028.28 2660.09 420.03 2626.72 LS 1.16 5.32 5970187.01 462130.79 N 70 19 46.27 W 150 18 25.70 462167.18 7100.00 25.62 99.08 6028.27 6103.55 2696.98 425.85 2663.14 LS 1.16 5.33 5970180.99 462167.18 N 701946.21 W 150 18 24.64 462178.80 LCU 7127.39 25.30 99.08 6053.00 6128.28 2708.75 427.71 2674. 77 LS 1.16 5.33 5970179.07 462178.80 N 701946.19 W 150 18 24.30 462208.94 7200.00 24.46 99.08 6118.87 6194.15 2739.30 432.53 2704.94 LS 1.16 5.34 5970174.08 462208.94 N 701946.14 W 150 18 23.42 462248.87 7300.00 23.30 99.08 6210.31 6285.58 2779.78 438.92 2744.91 LS 1.16 5.36 5970167.48 462248.87 N 701946.08 W 1501822.25 462286.97 7400.00 22.14 99.08 6302.55 6377.82 2818.41 -445.01 2703.05 LS 1.16 5.37 5970161.18 462286.97 N 701946.02 W 150 18 21.14 462323.22 7500.00 20.98 99.08 6395.55 6470.83 2855.15 450.81 2819.33 LS 1.16 5.38 5970155.18 462323.22 N 701946.96 W 150 18 20.08 462352.28 End Cv/Tilt 7584'1a 20.00 99.08 5474.40 6549,68 2884.61 455.46 2848.43 HS 1.16 5.39 5970150.38 462352.28 N 701945.92 W 150 18 19.23 462355.37 A/pine C 7593.33 20.00 99.08 6483.00 6558.28 2887.74 455.96 2851.52 HS 0.00 5.39 5970149.87 462355.37 N 70 19 45.91 W 150 18 19.14 462379.07 Be.Alpine C 7663.57 20.00 99.08 6549.00 6624.28 2911.76 459.75 2875.24 HS 0.00 5.40 5970145.95 462379.07 N 70 19 45.88 W 150 18 18.45 462576.91 TD 8249.93 20.00 99.08 7100.00 7175.28 3112.31 -491.40 3073.27 0.00 5.42 5970113.23 462576.91 N 701945.56 W 150 18 12.67 Survey Error Model: ISCWSA Rev 0 ° 3-D 95.D00% Confidence 2.7955 sigma .� Survey Program: Description Part MD From MD To EOU Front Hole SizeCasing Diameter Expelled MaxSurvey To.1 Type Borehole 1 Sumy 1 0.000 2470.000 1/100.000 12.250 9.625 SLB MWD+SAG Mitquq.1/Mitquq-1 wp02 v6 1 2470.000 6900.000 1/100.000 8.500 7.000 SLB_MWD+SAG Mitquq-1/Mitquq-1 wp02 v6 1 6900.000 8249.927 1/100.000 6.125 0.000 SLB_MWD+SAG Mtquq-1 / Mftquq-1 wp02 v6 Legal Deecription: Northing (Y) Easting (7L) Surface: 530.8 FSL 2302.6 FEL S3 T11N WE UM 5970621.161 459506.640 BHL: 39 FSL 4510 FEL 2 T11N R7EUM 5970113.230 462576.910 INS West\Mitquq-1\Mitquq-1\Mitquq-1\Mitquq-1 wp02 v5 Drilling office 2.10.544.0 .SchIumberger-Private 11/6/2019 9:41 AM Page 2 of 2 (P Schlumbemp Oil Search Borehole: Well: Field: Structure: Mitquq-1 (P2 v6) Mitquq-1 NS West Mitquq-1 WaWty a Mapnatic Paremat.n auU- NAD53 Alaska Ste, Plane, Zom 04, US FmtModal: SGGM 2019 Dip: 90.732- Date: 31-D-2019 �SL'ornr: Lat: N 7019 48.29 NorNing: 5g970370.93nU Gdd Co- 4.3122' Slot: Mltquq1 WD Ref: RKa(75.26N above MSL) MagDee: 16.145- FS: 57357.16 T GravityFS: 1002.001mgn (9.80665 aa..d) W15015 5].W Eaa0ng: 1599539.39RU Seal.F.a: 0.8888018 Plan: Mitquq4 wp02 v6 -1600 -800 0 800 1600 2400 3200 4000 4800 RTE 0 0MDOND 0 0.00°Ind 0.00°az 0 vsec 800 800 1600 Base Permafrost (1525.277 NDj 9-5/8" Csg 1600 2475 MD 2475 ND 0.00 ° incl 99.09 ° az 0 vsec .._.._.._.._.._.. _.._.._.._.._.._.._.. _.._.._.. _.._.._...._.._. Mid Schrader BIuR (2075.277 ND) _.._.._.._._.._.._.. ..................... .......................................................................................................... 2400 .._.._.. _.._.. _.._.. _.. _.._.._.._.._.._.._.. _.._.._.._. .. .._.._.. MCU (2410.277 ND) _.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.-_.._.. _.._.--- . _.._.._.._.._.._.. _.._.._.._.._.._.._. 2400 owar.SrJuaderBWff 5502Z7. .............. .. TuNvak (2627.277 TVD) _. ._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._ _.._.._.._.._ _ _.._... _.._.._....._.._.._.._.._ ._ _.._ _...._.._.._.._.._.._. KOP Cry 4/100 2500 MD 2500 ND 0.00°Ind 99.09°az 0 vsec i; 3200 3200 c End Cry 0 3675 MD 3548 ND N 46.97 ° ind 99.09 ° az n 455 vsec m 4000 4000 ....................... .. ... .._. Nanuhuk Forma0on (4053.27700000005 NfJ) �� ............................................. _...... ............................................................................ Nanuhuk 9 Sandstone (4174.27700000007 ND) Cry 1.16/100 5261 MD 4630 ND 46.97 - incl 99.09 ° az 1615 vsec .._.._.._.._. Nanuhuk B (479�2)277 ��%U�'._.._.._.._.._.._.._.._.._.._.._.._......._.._.._.._.._.._.._.._....... ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._....._.._.._.._.._.._.._.._.._.._.._.._.._.._.._. 4800 .._.._.. ._.._.. ._.._.._.._.._.._.._. ' _. _. _. _. _. _. _. 7• _. _._. _. _. _. _. _...._. _. _. _.._.._. _.._.._. _. _. " Csg._.._....._.._.._.._.._.._.._.._._.._.._.._.._.._.._.6933 Torok (Nan-6) (5341.277 NDj MD 5954 ND 5600 27.56 ° ind 99.08 " az 5600 2622 vsec .._.._. _.._.._.._.._.._.._ . HRZ (5751.277 ND) .._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._. _CSandstonej6028;277,ND)_.._.._.._.._.._.._.._.._.. 9 LCII ( (6128.277 ND) ------------------------------- ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.. .._.._.._.._.._.._.._.. .._.._. 7584 MD s330 TVb- �� -- -- - -- 20.00 " incl 99.08 - az 6400 2885 vsec 6400 ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._._.._._.._.._.._.._ Mitqug 1 Target_, __.._.._.._.._.._.._.._.._.._.._.._.._......_.._..__.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._. '}1%✓ 158 se ApTeC�'fiZ4.277 ND) .................................... _.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._ PI 9 TO 8250 MD 7175 ND 7200 20.00 ° ind 99.08' az 7200 3112 vsec Mitquq-1 wp02 v6 -1600 -800 0 800 1600 2400 3200 4000 4800 Vertical Section (ft) Azim = 99.08' Scale = 1:1200.00(ft) Origin = ONAS, OE/-W Sct umberger Oil Search Borehole: Well: Field: Struc ture: Mitquq-1 (P2 A) Mitquq-1 NS West 7Mitquq-1 Gravity & Magnetic Parameters ce Location NAD83 Alaska State Plane, Zone 04, US Feet Miscellaneous Model: BGGM 2019 Dip: 80.732° Date: 31-Dec-2019 �S."ornfa: et: N 70 19 4929 Northing: 5970370.93ftU5 Gdd Conv: -0.3122° Slat: Mitquq 1 TVD Ref: RKB(75.28ft above MSL) MagDec: 16.145' FS: 57357.165nT GravltyF5: 1002.001mgn (9.80665 Based) W115019 53.64 Easeng: 1599539.38ftUS Scale Fact: 0.9999019 Plan: Mitquq-1 wp02 v6 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 RTE 0 MD 0 TVD 0.00 ° inc l 0.00 ° az Tue N=0 E=0 Grid �a r Ji 300 K500 MD 2 1t00 N 2500 MD 00 D a9 300 0.00 "rd 99.09 ° az End Cry N=0 E=0 3675 MD 3548 TVD 46.97 ° Incl 99.09 ° az True North -� N=72 E=450 Tol Cort (M->T 16.145') Mag Dec (16 145°) Grid Conv-0.312" 0 0 0o Mitquq-1 wp02 v6 0 0 v II 9-5/8' Csg Mitquq 1 Targe 2475 MD 2475 TVD -300 0.00 ° ind 99.09 ° a: N=o E=0 300 rn z Cm 1.16/100 5261 MD 4630 TVD 46.97 ° ind 99.09 ° a2 7' Csg 600 N=-255 E=1594 6933 MO 5954 ND -600 27.56 ° ind 99.08 ° az W-4 E=2589 End Cry / TO 7584 MD 6550 TVD 20.00 ° incl 99.08 ° az N=455 E=2948 TD -900 8250 MD 7175 TVD _900 20.00 ° ind 99.08 ° a2 N=491 E=3073 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 EW (ft) Scale = 1:400.00(ft) 16000 14000 12000 10000 8000 0 0 0 6000 u m 4000 1n Z 2000 0 -2000 -4000 -6000 (A Schfumherger Oil Search Borehole: Well: Field: Structure: Mitquq-1 wp02 v6 Mitquq-1 NS West Mitquq-1 Gravity 8 Magnatic Parameters Surface Location NAD83 Alaska State Plane, Zone 04, US Feat Miscellaneous Modal: BGGM 2018 Dip: 00.789• Dets. 31-0ec-2019 Let: N 7019 49.29 5970370.9JRU Northing: Grid Gonv: -0.Ji22° i`S99$39.96RD Slol Mltquq 1 TVD Ref: RKB(]5.28ft above MSL) MaOUec: 16.09• FS: 57378.891nT GraMry FS: 1002.001m9n (9.60665 BaaetlJ Lon: W 150 19 53.84 Eaa0n0: Scale Fact: 0.9999019 Plan: Mltquq-1 wp02 16 -16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22000 -16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22000 EW (ft) Scale = 1:4660.00(ft) 16000 14000 12000 10000 8000 6000 4000 2000 0 -2000 -4000 -6000 Mitquq-1 wp02 v6 Anti -Collision Summary Report An.Iyel. D.te-241,7 Tim.: September 25, 21119 -14:15 ".lyN. M.Ihed: NNmN PMne Client Oil Sear& Rahnnp Tre).Nory: Mitquq-1 wp02 v3 (Daf Plan) FbId: NS WeN Dew Inleml: Every 10.00 Measured DeptA (R) 5tngtun: Mitquq-1 Rut, S.t DBM AnfiL glsion Sts."nd 5002 v5. 1/5.2 Slot: MINUq 1 Min Ph: All 1I minima indlo..d. Well: Mitquq-1 Venlon]Palch: 2.10.782.0 Sorahole: Mhquq-1 Dabbese 1 Pre).N: bcalhoM cling-NMh Slope West Scen MD R1n91: 0.000-8249.93M1 ISCWSA03-0 95.WO%Confidence2.7955.igm.W,ubjeciwei.Fer Tni.clon Error MOGI: offset wells, error model venbn Is specified with ea& well napecW*. ORe.I Tre)ectode. Summary ftSelec[len Ldleda Wtllheaddeian%scan: Rssldcled whhin 4926043It Selection filter. DefinhNeSurveys- DefiNOve Plans - Definitive wrv.ys exclude definitive plans -All Nan-0ef Surveys when no Def-Survey Is W Ina b-role- All Non-0ef Plans when no Dsf-Plan Is set in a Wmhde OR.N TryeGory 9. entlon Allow S.P. Conbofiing R.hnn! egi Risk L.v.l AI.R S... CI{t MA5 R EOU R Dev. R Fact. R.I.MO TVD R A d Minor MN., Maj. M. or Pkau 1 mel.-sy) Vie. 10060. 32.81 10%8.4 10030.1 6 4.1 6606,0E 114.58 121.21 0491.50 11J.66 MAS=10.00(m) OSF1.50 131,21 2951.14 330.2E 2943.13 MinPls min - set, .11 11 ].B9 %282 BIB9.42 110.78 0SF1.W 2963.63 2955.59 MINI T IU 6608.46 111.% %28. 109.23 _223.2s 100.1 O9F1.5n OSFI,W 29)045.T] 9 302 2962.09 3DI4.06 Mine _P Min%-0.9F Placer 2 (..I Survey] 0680.14 152. 6557.E 050)2 %. OSF1.59 30%.35 30/1.5) MInPb P.n 10503 930025 92%.1 1121 OSFI.50 211.21 2731.11 Mln%LIOI 9366.01 115.44 W117.71 1249.57 1. OSF1.50 27114.11 21.2.8a mPl-- 9388.4e 120.N 92659 9-.. 111.. 9380.52 122.70 9288. 9215 11541 0SF150 OSFI.50 2.03.M 2813.38 280145 2810.99 MINPT-O£OU Min-.p 908138 189.49 9]84.81 9701.] 7B) OSF1.50 121110 3232.]4 Mnl-OSF 10004.84 19).so 9%2.14 ]fi.e OSF1.50 3384 Z7 3312to MinPl-0.8F Colville 1(Caf SwreY) Pev 1� 701.) 129B2A 13748 30.78 13450.58 )01.Ya 129824312748. 28.7 124:15.50 ,I III 11506. 11015.1 13.4sl OSF1.50 0SF1.50 OSF1.60 2495.00 2501.31 8249.93 2495.68 2501.31 7175.28 Min- M,.Nh F Min- P_ 3 (Oel Survey) Pau 5461.1 32.01 15I60.1 15426. 256-86 1544q.4) 33.61 t5a37. 15616. 1-13 MA3=10.00(m) MAS=10.00(m) fifi.10 %.I. Mnf 15443.70 32.01 1543]2 15410.09 1-42 MAS=10A0Im) 23. 11 23:Il MINPT-O-EOU 15503.10 32.81 15189.fi8 15{]0 12st6 MAS•10.00 (ml 2556.97 255596 MinPt 1 50]]25 J2.81 15023.15 15fi01. 1240,1 15713.28 32.81 15099.12 see", 12fi8.) MAS=10.00Im1 M0.9.1p.00 (m) 2650.19 2639.13 2049.92 268." Mln%4)SF MinM1 F 15767,47 32.81 15154.00 151. 22.4 160.33.99 32.81 18020.03 16001.1 12]6.31 MAS•10.00 1m) MPS=10.00 2712. 2e08.75 2]11.86 2806.37 Min%-0SF MmPN}SF 10089.48 32.81 1807/.99 10050.8 119T (m1 MA3=10.00ill 2320.45 21123.04 Min%4YSF oosu 2A(DN Swwy) PW 2-lit. 32.81 2123877 2120fiSS WA 212132 32.81 21204.1 21180A L.A.2805.17 MAS=tIt.(m1 A9 • I... (m) 1.00 -.85 000 iss (I5 Sudere MInPw 21213.31 32.N 2120a.1 21t BOSO PWI 10.00 I.) I.so IM9.fi0 MINPT4}D-OU 2125545 32.01 21242.88 21222, 18396 21221. .11 21210. 21189. 19%.07 MA,9=10.00(ml MAS•10.00 on 2500]7 2M5.95 250037 253594 MInPt-0SF WnPb 21232.29 32.81 21220.1 21198. 1820.1 MPS=10.00(m) 255922 255920 MInPt-D43F 211.Go 32.01 21317.BB 21296. 19%2 19291.1) 43. 1926141 192/]. 999. MAS=1O001m1 OSF1.50 2640.13 824- 263990 71752. Min%-OSF Knots At" 2 (Del S ,) P.M 21239.78 32,81 21238.17 212M.% WA 21313.1 32.N 2818A0 1-1 10.00 im1 MAS .I0.00Im) 0.00 1638.85 050 10Js.fi5 Sudan MinPtl 21211.3' 12.81 312041 211BOS0 2605.16 MPS=10.1m) 1649.60 1M960 MINPI-0-EOU 2125545 3251 21242.% 21.2. 1019.8 2123228 U111 21310. 211890 1955.07 3251 2122030 211%. 19283 MAS=100D (ml MAS=t0 o31m) MAS=1000 (ml 25003) 2535% 2559.22 2509.3) 25MW 2559.20 Miner-0.9F Mint MmR-OSF 2132160 ]2.a1 2131 ].BB 211%. 19882 MAS=1O00 (ml 2840.13 2039.90 MnR-OSF 19291.t7 03.Sfi 19281.41 192/]. fi%. OSF150 e249.93 71)520 MinPle 5&lumbene7-Private o ry O Separation Factor 1.5 u ry 111) 41da(] pajosvaW Traveling Cylinder Plot NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk N Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2 IT - 280 270 260 North 350 10 190 180 170 TRAVELING CYLINDER PLOT Client Oil Search Field NS West Structure Mitquq-1 Well Mitquq-1 Borehole Mitquq-1 Date 25-Sep-2019 90 100 Oil Search Attachment 3: BOPE Equipment Mitquq 1 Permit to Drill Rev3_20191106 - 28 - 06-Nov-19 9- L af�a I � a w z O ,11-,oz a-f CD z CD Z-,f U 0- CD co T Of LLJ Of Lli Q-- -- a �Qw I oe J Z Z ZW cu N Z Q W J a r � x o g,91/S 0 9-,9Z Z IIj�;' LL w _ Ca- 1 z Fi I O O e �® y O O O CD III; o I I I / o Y Q a¢ Q Q w l.7 W l7 l7 H W Z W o W o FW Z)I ,Z.f w 0<W !nQ Y ¢ n 7N W\ N W YdF7 Yd • J m ❑ Lr) � a Z I J Nm Z F- I N Q � H LO CI 117 Q W N I0r M LLJ J d Y J La d w i a�3 a r ❑ r x J = 0111 Nabors Alaska Drilling Rig - 7ES Material List Item Description A 3-1/8" 5000# Remote Hydraulic Operated Choke B 3-1/8" 5000# Adjustable Choke 1-14 3-1/8" 5000# Manual Gate Valve 15 2-1/16" 5000# Manual Gate Valve Legend a� White Handle Valves a� Normally Open ®Red Handle Valves Normally Closed Date: 10-18-02 Rev. 3 Choke Line From BOP To Flare P1/ To Mud/Gas /"�� Separator To Secondary Choke Line In Cellar I I . Oil Search Attachment 4: Drilling Hazards 12-1/4" Surface Hole Section Hazard Mitigations Conductor Broach Monitor conductor for any indications of broaching. Monitor pit volumes for any losses. Gas Hydrates Keep mud cool, optimize pump rates, minimize any excess circulation. Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Keep mud cool, optimize pump rates, minimize any excess circulation. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Shallow Gas Shallow hazards assessment, sufficient mud weight, on site surveillance (mud loggers, trained drilling personnel). 8-1/2" Production Hole Section Hazard Mitigations Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Drill with oil based mud, maintain mud in specifications, use sufficient mud weight to hold back formations. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight to hold back formations. Abnormal Pore Pressure Pore pressure, fracture gradient prediction study, monitor for abnormal pressure indicators while drilling and tripping (pit levels, cuttings/cavings, gas trends). BOP installed and tested, well control trained personnel. 6-1/8" Production Hole Section Hazard Mitigations Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight to hold back formations. Abnormal Pore Pressure PPFG prediction study, monitor for abnormal pressure indicators while drilling and tripping (pit levels, cuttings/cavings, gas trends). BOP installed and tested, well control trained personnel. Mitquq 1 Permit to Drill Rev3_20191106 - 31 - 06-Nov-19 0) Oil Search Attachment 5: Leak Off Test Procedure 1. Drill out shoe track, cement plus minimum of 20' of new formation. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight -in is equal to mud weight -out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe. 4. Rig up high pressure lines as required to pump down the drill string with cement unit (side entry sub, TIW, lo-torque valve, etc.). Pressure test lines to above expected test pressure. a. Note: a high pressure, low volume pump is required - rig pumps are not suitable. b. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string (with the cement unit). 6. Verify the hole is filled up and close the BOP (annular or upper pipe ram). 7. Perform the LOT or FIT pumping at a constant rate of 0.25bbl/min. Record pump pressures at 0.25bbl increments. 8. Record and plot the volume pumped against pressure until leak -off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak -off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in -situ stress. c. If FIT skip step 9. 9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 11. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to establish the volume of mud lost to the formation. Top up and close the annulus valve between the casing and the previous casing string. 13. Open the BOP. Mitquq 1 Permit to Drill Rev3_20191106 - 32 - 06-Nov-19 0 Oil Search Attachment 6: Cement Summary Surface Casing Cement Casing Size 9-5/8" 40# L-80 BTC Surface Casing Lead Open hole volume + 500% excess in permafrost / 50% excess below permafrost Basis Lead TOC Surface Tail Open hole volume + 50% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Spacer 60 bbls of 10.7 ppg Clean Spacer Total Cement Lead 526 bbls, 2953 cult, 1130 sks of 11.0 ppg ArcticCem, Yield: 2.61 cuft/sk Volume Tail 48 bbls, 268 cult, 227 sks 15.8 ppg Type 1/II —1.18 cuft/sk Temp BHST 70° F Verification Method Cement returns to surface Notes Job will be mixed on the fly Swap to tail cement when lead cement is seen at surface 5+�� Intermediate Casing Cement Casing Size 7" 26# L-80 Vam Top HC Intermediate Casing Lead Open hole volume + 30% excess Lead TOC - ,100' MD / 3,838' TVD (-500' MD above top of Nanushuk 9) Basis Tail Open hole volume + 30% excess + 80 ft shoe track Tail TOC 1,500 ft MD above casing shoe Spacer 30 bbls of 11.5 ppg Clean Spacer Total Cement Lead 39 bbls, 219 cult, 91 sks of 12.0 ppg VariCem, Yield: 2.40 cult/sk Volume Tail 47 bbls, 263 cuft, 212 sks 15.3 ppg ExpandaCem Class G —1.24 cuft/sk Temp BHST 150° F Verification Method None other than monitoring returns during cement job Notes Job will be mixed on the fly Mitquq 1 Permit to Drill Rev3_20191106 - 33 - 06-Nov-19 c.� -roc- I N 0T 6 i � 1 Pam' c 4u 0) Oil Search Attachment 7: Rig Fluid System Mitquq 1 Permit to Drill Rev3_20191106 - 34 - 06-Nov-19 z X \j \)/g) ( §; ,\ 9V �\ r ) ^ ( cw� CD �\/;LJ r�D CO ® _ co � k ■ zz�G ®■ 3 C) ] § &e �� 7 0 00 0 \\ Z ■ ` \ - ///�� - ee /\� e e . ■. 7k# §( ----- ,! � Oil Search Attachment 8: Prognosed Formation Tops Mitquq-1 Deviated Prognosed Tops ftMD ft TVD(KB) ft TVDSS Uncertainty Range Pore Pressure (ppg) Prince Creek Fm 75 75.3 47.3 7.0 Base Permafrost 1525 1525 -1450 +/- 150ft TVD Middle Schrader Bluff 2075 2075 -2000 +/- 65ft TVD MCU 2410 2410 -2335 +/- 65ft TVD 8.6 Lower Schrader Bluff MFS 2550 2550 -2475 +/- 65ft TVD Tuluvak Formation 2627 2627 -2SS2 +/- 100ft TVD 9.9 Seabee Formation 3180 3127 -3080 +/- 100ft TVD 8.7 Nanushuk Formation 4275 4053 -3978 +/- 100ft TVD Nanushuk 9 Sandstone 4481 4174 -4099 +/- 120ft TVD 9.1 Nanushuk 8 5541 4782 -4707 +/- 150ft TVD Torok (Nan-6) 6431 5341 -5266 +/- 150ft TVD 8.8 HRZ 6920 5751 -5676 +/- 150ft TVD 10.0 Kuparuk-C sandstone 7217 6028 -5953 +/- 175ft TVD 11.7 LCU 7317 6128 -6053 +/- 175ft TVD Alpine-C sandstone 7754 6558 -6483 +/- 200ft TVD Base Alpine-C sandstone 7820 6624 -6549 +/- 200ft TVD 9.9 Nuigsut sandstone 7847 6825 -6750- +/- 200ft TVDTo 8250 7175 -7100 +/- 200ft TVD Mitquq 1 Permit to Drill Rev3_20191106 - 36 - 06-Nov-19 0) Oil Search Attachment 9: Pore Pressure Fracture Gradient Plot . . . .. . . . . . .. . . . Mitquq 1 Permit to Drill Rev3_20191106 - 37 - 06-Nov-19 0 Oil Search Attachment 10: Independent 3Id Party Pore Pressure Fracture Gradient Plot Mitquq 1 Permit to Drill Rev3_20191106 - 38 - 06-Nov-19 Mitquq-1 PPFG well plan plot psi and ppg -(q} W(n) Ak ikon Science • After analysing the ten offset wells supplied for Mitquq-1 two pressure cases were derived -a Low and High case. Kookpuk-1, Qugruk-2, and Palm-1 were the key offset wells since these offsets took kicks. Although the kicks were not substantially over pressured they were above the normal to low overpressure of the other offset wells and did present some drilling difficulties. 1 For fracture pressure four cases are supplied: Two each for the Low and High pressure cases but distinct from one another by being related to sandstone and shale fracture pressure. �1 Oil Search Attachment 12: Formation Evaluation Program 12-1/4" Surface Hole LWD Gamma Ray Resistivity Sonic Open Hole Wireline None Cased Hole Wireline None Mitquq 18-1/2" Intermediate Hole Gamma Ray LWD Resistivity Sonic Conventional Core None Density Neutron Induction Resistivity Sonic Spectroscopy Open Hole Wireline* Spectral Gamma Ray Image Log NMR Sidewall Cores Formation Pressures Formation Samples Cased Hole Wireline* None Well Test* None Mitquq 16-1/8" Production Hole Gamma Ray LWD Resistivity Sonic Density Neutron Conventional Core None Sidewall Cores Open Hole Wireline* Formation Pressures Formation Samples Cased Hole Wireline* N/A Well Test* N/A * Logs and well test listed are for a success case discovery, formation evaluation program may be reduced in the event of a dry hole. Mitquq 1 Permit to Drill Rev3_20191106 - 41 - 06-Nov-19 K Mitquq 1/ST1 Days vs. Depth 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 0 r __ 1,000 2,000 3,000 Gt 4,000 t a+ m 5,000 6,000 7,000 H Z 8,000 cfl 7 7 0) Oil Search Attachment 15: Shallow Hazards Assessment Mitquq 1 Permit to Drill Rev3_20191106 - 44 - 06-Nov-19 ,1,01 Search MEtquq 1 and M'Itquq 1 ST1 Shallow Hazards Study [October 2019] Oil Search Limited Incorporated in Papua New Guinea ARBN 055 079 868 Contents 1. Executive Summary 2. Introduction 3. Overburden Stratigraphy 3.1. Permafrost (Prince Creek Formation) 3.2. Schrader Bluff Formation 3.3. Tuluvak Formation 3.4. Seabee Formation 4. Shallow Hazards Assessment 4.1. Gas Hydrates 4.2. Gas Mud Log Analysis and Casing Design 4.3. Log Analysis 4.4. Pore Pressure Fracture Gradient Prediction 4.5. Seismic Analysis 5. Conclusions Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 1. Executive Summary Oil Search Alaska intends to drill Mitquq 1 and Mitquq 1 ST1 during the 2019-2020 winter season. The two wellbores share the same wellbore down to the surface casing depth of 2400' tvdss. This is a depth corresponding to just above the Top Tuluvak. This report will refer to all shallow hazards associated with the surface to TD of 2400' tvdss as the Mitquq 1 shallow hazards. This document summarizes a comprehensive offset -well analysis to quantify shallow hazards at the Mitquq well locations. This study integrates offset well design, gas mud logs, formation pressure, petrophysical well logs and 3D seismic attributes. Near Mitquq 1 and ST1 the risk of encountering shallow gas is low. Three of the near offset wells have surface casing set above the Tuluvak and two of those did not encounter appreciable shallow gas; Placer 1 (7,920 ft), Colville 1 (14,256 ft), while one well did see an influx of gas at the Tuluvak level, Kookpuk 1 (21,648ft) — where the influx was stopped by increasing their mud weight to 10.5ppg. 3D seismic over Mitquq shows no structural trapping mechanism for shallow gas presence, and it is structurally downdip from the known Pikka Tuluvak gas accumulation. There is very low risk for shallow gas at Mitquq 1 based on all available datasets. 2. Introduction The Mitquq 1 well targets the Cretaceous Nanushuk, the Cretaceous Torok, the Jurassic Kuparuk C, and Jurassic Alpine C reservoirs. The Mitquq 1 ST1 is targeting the Cretaceous Nanushuk and the Cretaceous Torok formations. The proposed surface location for the Mitquq 1 and Mitquq 1 ST1 drill -site is east of the Pikka Unit at the following coordinates: Easting (ft) Northing (ft) Surface elevation (ft msl) 1599539.381 5970370.931 47.277' NAD83 State Plane Alaska State Plane 4 FIPS 5004 (US Feet) Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 3 VIL UA.RGN A.LA5KA LLG. 1C-NN31-11P X19-272)EXP. M- A -KW E Af.4- J•. _ AS,- E T i�JE Tt Y a CT€ON MtITGtl1Q 1 WELL PLAN «. ) 4=11 +6M t Oil Search �A .. <Y'E ?.c7i' uxi r T,--: ,'S w'/a 14'%MQ•JaI a_il`cr. Figure 1: Aerial photograph of the Mitquq surface location. Ten miles west of Mitquq, exploration and appraisal wells located along the Colville River have occasionally encountered shallow gas. In some wells, shallow gas has been liberated from gas hydrates associated with the permafrost (Pikka C). In other instances, shallow gas has been identified in the Schrader Bluff and Tuluvak Formations. Along the Pikka trend the Tuluvak Formation locally contains overpressured shallow gas (e.g. Qugruk 2, Qugruk 9, and Kookpuk 1). The shallow gas risk at Mitquq 1 is defined by this integrated study. There are three primary components included in this description; offset well completion design and mud logs, offset well logs and pressure data, and pore pressure fracture gradient prediction. The culmination of these analyses demonstrates the low risk for shallow gas at Mitquq 1. 3. Overburden Stratigraphy 3.1. Permafrost (Prince Creek to Upper Schrader Bluff Formations) The characterization and depth of permafrost near Mitquq is relatively constrained by offset wells. The depth range of base permafrost ranges from approximately 913 ft TVDSS in Pikka B to 1774 ft TVDSS in Palm-1. Permafrost is identified using resistivity and sonic logs (RT>40 ohm.m and DT<135 ps/ft). However, permafrost is more apparent in coarser grained sediments and this contact may be cryptic in shaly sands and shales. This lithologic overprint likely obscures the actual depth of permafrost in many wells. Permafrost is only identifiable in the Prince Creek and Middle Schrader Bluff Formations. At Mitquq 1 base permafrost is predicted at 1450 ft TVDSS +/-150 ft. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 4 (a) Oil Search r "I VTO Pf :0:6 0,: b Z%; ;;�Fj 1"xas; 1) A 2*0 W., t.,:A: I 01-No vlf*rxAK� 'M C". W4 144 k I 00 zyx 2 r; 'Zo 44 :::I'IS 7-4717-_ox $1 Vj C,4 IN ML LO Or- 12 - 71. 3. S. CD CQ S ilk" 6 CV P, 4 .. ......... IN tv CN Figure 2: Mitquq 1 offset wells with base permafrost picked from resistivity. Base permafrost occurs within the Upper Schrader bluff unit in the greater Mitquq area. N ■W..11 %W %F. I %.WL1 %AWI%Al V I I I%AV %,FI 9 %11 11 1%.411 %.P%PL 111 LI 1%0 t11 VLALVI I-IIL%ILA%l CAI %►CA M-011 1%1 L%.FFJ 11 WII I VVIUIIQ. %.P%Jl IL%JUI interval: 20I . Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 3.2. Schrader Bluff Formation In the greater Mitquq area, the Prince Creek Formation unconformably overlies the Upper member of the Schrader Bluff Formation. The Upper Schrader Bluff comprises fluvial influenced delta -top to delta -front facies versus the transgressive distal pro -deltaic Lower Schrader Bluff. The Middle Schrader Bluff includes multiple, coarsening -upward parasequence cycles with intercalated blocky sharp -based, fining -upward depositional packages. The Lower Schrader Bluff Formation is dominated by delta front and pro -delta mudstone and siltstone. The Lower Schrader Bluff is punctuated by a few ash -fall tuff beds, sporadically seen in offset wells. Tuffs can be identified by conspicuously high gamma ray response as well as mudlog descriptions. , tales ri t ii_l'I rG1r" W i�f?tIt r4l^+ F Upper 55chrader Muff t3asr3 Perrrto3le[:xst Middle Schrader Bluff s r,'Di } Ow Schrader Buff 'f; 1 Tuffs Tuff1 �Fi�Ce� t 's i Tuffs Tuff1I— , Top Nanusnfak Nanushuk 8 Figure 4, Mitquq 1 overburden stratigraphy from offset wells. 3.3. Tuluvak Formation .__ .UpW Schrader Bluff —=--Base Perawltrunt %iCU Tufft t_•.vr SChrasd�:r 811,fif Julu rak Is" Tuftl r' oTu€fl Top NanUshLP, Nan*huk 8 In the Mitquq area, the Tuluvak Formation was deposited in a distal delta -front environment and comprises a shale dominated lithology, with small coarsening upward sequences comprising mostly silt and thin sand stringers. Ash fall tuffs are described in most of the offset wells in regular frequency and have been marked on the logs using mudlog descriptions and gamma ray response. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 6 0 Oil Search 3.4. Seabee Formation The Seabee Formation comprises pro -delta mudstone and siltstone deposited in offshore shelf -slope and basin floor environments. The Seabee Formation stratigraphy includes several ash -fall tuffs that can be identified with gamma ray spikes and mudlog descriptions. 4. Shallow Hazards Assessment 4.1. Gas Hydrates Near the base of permafrost there is a risk of gas and/or gas hydrates. Base permafrost at Mitquq 1 is predicted at 1450 ft TVDSS +/-150 ft. The base permafrost will likely occur near the top of the Upper Schrader Bluff Formation in Mitquq 1. The permeable zone below the permafrost could be hydrocarbon bearing. This permeable zone in the Upper and Middle Schrader Bluff is likely to extend to approximately 2100 ft TVDSS. The absolute depth of permafrost and transitional zone will dictate the phase of any hydrocarbons present. The methane hydrate stability profile for Mitquq 1 has been calculated (Figure 5*) using the temperature profile calculated using offset well data (Figure 6). From this calculation, the hydrate stability zone is expected to exist from Base Permafrost (-1450' tvdss) to within the Tuluvak at -2650 tvdss. Below the stability zone there is a risk of free gas where methane hydrate thaws and gas is liberated. Offset wells around Mitquq show very poor reservoir development at this free gas level, indicating the storage capacity for both methane hydrates, and its associated free gas, is low. Methane Hyeirate Stability Profile Calculated for Mitclug �` [�(�y a {I LJ� ° iL`i]I LACER i J d� �eTJ � I V D] f t! ! J rrrww.'�irtha?•��• t oyrsra'T ��$i s.a . . ,, !ce Warer E 5 k ... .. 5 ....... 7 N Free Gas and _ Permafrost Water LVater fce/iydrate Plus j w Gas hydrate s r �+ {� r } 1,% 2/ t7 tGl bll�l�y R f f zone P, �r ,4'/ h Base Hydrate Gas Hydrate S StabYlty Zone Q L t s o f ru R C, l as �J(• ;f Fa?nnagratura(Rrrpraaz Fabranhaitl - Figure 5: Mitquq 1 hydrate stability zone calculation & offset well correlation of potential Schrader Bluff gas hydrates / Tuluvak free gas zone. Assumed temperature gradient beneath base permafrost = 2.60F/100' *Calculation from Kvenvolden, 1993. Gas hydrates — Geological Perspective and Global Change. Review of Geophysics. P. 173-187, Vol.31 Issue 2. May, 1993. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 7 (1) Oil Search Mitquq 1 Estimated Temperature Profile Temperature (°F) 0 25 50 75 100 125 150 175 200 100 y =-75.606x + 969.39 -900 '• Base Permafrost -1900 Cli-2900 ••.., y =-37.736x - 242.45 U) 0 > -3900 m, C -4900 '•• -5900 -6900 -7900 Figure 6. Temperature plot and thermal gradient derived from offset wells KRU 3S-15, Tarn 2L-301, Placer 1, Ataruq 2, Qugruk 1. Permafrost temperature profile derived from data in Collett, T.S. et. al., 1988. Subsurface Temperatures and Gradients on the North Slope, Alaska. US Geological Survey, USMS 019024. 4.2. Gas Mud Log Analysis and Casing Design Gas in the Tuluvak Formation is a primary focus for shallow hazards assessment across the Pikka field. This concern has arisen after the gas -kick event at Qugruk 2. In the Pikka area, the Tuluvak is locally charged with overpressured gas. The Pikka Tuluvak gas trap is a seismically mapped 4-way dip closure (Figure 7). The Mitquq 1 well is located approximately 10 miles east of the Tuluvak overpressured gas accumulation at Pikka. Offset well analysis shows that the Tuluvak near Mitquq 1 does not contain the overpressured gas observed in Pikka. Offset wells demonstrate a very low risk for any Tuluvak gas at the Mitquq 1 location. Offset wells surrounding Mitquq have all topset the Tuluvak Formation (Nearest wells: Placer 1, Placer 2, Colville 1, Ataruq 2, Kookpuk 1, and Palm), with the exception of the Qugruk 2 well. The Tuluvak at Palm 1, Colville 1, and Kookpuk are all at a similar sub -sea depth as Mitquq 1. The Tuluvak at Placer 1, Placer 2, and Placer 3 are slightly up -dip of Mitquq 1. In Placer 1, Placer 2, Placer 3, Colville 1, Ataruq 2, and Palm 1, the Tuluvak Formation was drilled with mud weights ranging from 9.6 - 10.3 ppg without incident. Kookpuk 1 was drilled with a 9.1 ppg through the Tuluvak and had a gas flow that was eventually contained by increasing the mud weight to 10.5 ppg. Qugruk 2 did not top -set the Tuluvak with surface casing, and had a blow out to surface while drilling through the Tuluvak with a 9.1 ppg mud weight. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 8 0 0 0 e, i� (y V? 18f Q0 Oil Search 1552000 1560000 156800u 15 6000 1584000 1592000 1600000 1608000 1618000 1624000 1 Pala 1 9.6# No issues { 1, ,.. �3 *. aY"Won :PI, c5 dWSf°i M tG `'P3st ail e95: �A � QB C) 3gU 1G F k�xa iJ as2i kr, 9.1 # Gas flow 19.5# stopped flaw - ,ti 155200 i5eowo 15680M 157,6000 1584000 1592= 160=0 1608000 1616000 1624000 Figure 7: Map of Top Tuluvak Gas Sand showing outline of gas accumulation on the 4-way dip closure over Pikka encountered in Qugruk 2. Below are the mudlog summaries for the nearest offset wells to Mitquq. The best analogs for overlying stratigraphy and depth to Tuluvak are Placer 1, Placer 2, Placer 3, Colville 1, Palm 1, and Kookpuk 1. Placer 1 and 2 are directly adjacent to one another, and the analysis of those wells is so similar, only Placer 1 is summarized in this report. Particular attention has been paid to the mud weights and gas response in each of the wells as they drilled through the Tuluvak. Reservoir development is also noted, as the presence of a reservoir enhances the likelihood of encountering a gas event. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 9 Placer 1 is the nearest offset well to Mitquq 1, located 1 mile to the west. It is situated structurally up -dip from Mitquq 1 and showed minimal gas mud cut beyond background through the Tuluvak Formation. Placer 1 intersected the Tuluvak from approximately 3000 — 3600 ft MD. The max values of gas mud in the Tuluvak Formation were —100 gas units which equates to approximately 2%. The Tuluvak was drilled with 10.1 ppg mud with no gas influx events. These data suggest a low residual gas saturation at Placer 1. Reservoir development is also poor in the Placer 1 Tuluvak, suggesting a small chance of encountering thick, porous sandstone in this area. ,..:} Yb: < i".,.. �2 ., �i8 - a ;,> ^ i h �:., ♦ ,. ... 4 s « t t ;.��i %i QL %,, P .. � Y M .7 f t'!'Y'• 4NOW �� - -'V. Mx 4.1P:.4P E, .., 3'%f t I t e:"�« s+...b• +•s aF.rnr�rs.c>'r, ��p �• blb vA QaiVU/:A)w'p, ,.�� Top Tuluvak fw{cN.SnvafB: .c.Y_v410K tie b -3016 MD s.H.. s! gas %) ��y • i� 412 4..,. . 5 7 ... otfn+a +`+ wn •tix A lMAi P'rihaNb f 7..f q ^i!"+t' /.• h.' W r.i1gN'N # K'4 'd! �. • �,.# +. ,4..; i� e tli ir".35'"`°� 16e h6 t•� �4 r Lktr Schr�Qr @�1ft ........_._._._._.__._ ?•re +f. fr'gaq�. t 'y. ([`9{' I. !y i w. 4 f 'f:. .r'4 oiiT: f� 4 4 �.�. }� ± L�t 4 � 1 • Fw� may` 4 tft +a ! 9 #, 3 i 1 41 ti 4. 1+1 E xro y.ixn y '`"S'P t i' 1 `5 /okW•�x415C ...t { 1 3 "`''�--mot.,•4 ,�s� has units%' 1 ° ". � � ..- { } P-r A e. �-' r�r i b 1 4 x� .• +• IN, t fj vox 4'4 h4Y�rc.. .. 4. fY -Y t"< �ygE r+ 4 4�A i�r y A�4-f- {s tot t A•+efn�b'g'° . �. f. ,f..t�.. � �,�,Nl 4 7i 1 A'✓. %�'. •^ro-Mj. Aev..H 4p4tA0.kt .� d^ {...r.. •L.r. 11 � fw y i , �✓ �ury '-Wk'b' Y�, y, .{') .1 L w�� ti a 1' �w v®e•' SY IN' ;fbf tyy i �`P'.. I{ ( 2'•'.;.SNY .. ✓rf»:D'M �ti UP Figure 8: Placer 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 10 Rpm Colville 1 intersected the Tuluvak from approximately 2590 — 3050 ft TVDSS; similar to the prognosed depth in Mitquq 1. The max value of gas mud in the Tuluvak Formation was 55 gas units which equates to approximately 1 %. The Tuluvak was drilled with 9.6 ppg mud with no gas influx events. These data suggest very low residual gas saturation at Colville 1. Residual oil saturation likely exists in these sands, as they say oil shows in cuttings, albeit in a low percentage. Reservoir development is fairly poor throughout the Tuluvak Formation in Colville 1, with a few minor siltstones at the top of the formation in the interval where the weak oil shows were seen. Figure 9: Colville 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 11 Palm 1 intersects the Tuluvak from approximately 2780 — 3270 ft MD. The Tuluvak at Palm 1 is situated structurally below the prognosed Tuluvak at Mitquq 1. Palm 1 registered up to 25 gas units in the Tuluvak Formation while drilling with approximately 9.6 ppg mud weight. This is not appreciably above the background gas levels being collected above and below this interval. Minor oil shows were seen at the top of the Tuluvak, in the few siltstones that exist. Reservoir development is overall very poor in this well, with a few minor siltstones at the top and middle of the formation. Resistivity goes down to less than 2 ohm.m through the cleaner sands, indicating they are wet. This data suggests that the Tuluvak is not gas bearing at Palm 1. - --------- .tik f! t 4 i y. t wYi .x i► >i SMt •,.�, a •aa a+.w i+:w WA P-w-%ear wa. t 9 awo �: G, 4 !' ri t •,.._ 'y as +ee A . f3_� ji{ ��ms'M enr„.Faea tsesli t � � g�rt� ....l�vL.✓M'✓�r �a d PfetbrM.JI�MYOP�h! RPM :�. ^� ',„ Top Tul u va 20 gas units (<100 278Q k IDr m MID ; � i 644 AM 1M6{ ntl 9 ;''� r■• � ?�fw�.e.'Scva'ee�i.%Q'°rirw"`ia MCU _'nr Schxacw Bluff r : >Ti r i( } . � � 1 4d l 8J6Li�llHig'i+Y4•iG�v j 4f Io sa,K h. .aea.A+.:H+•.o 7, wn/VTTR m9M.M� NA+ CIA - 6 t ! y orrt•a+aAcl+�s+ rrramm. xj• t i r i . .. �� - � .......a.. _ :,..�..... 'yS _ '�'"f:Vr'+•nf�i'%i�•`�' f f- •. , 3 ' a.a--r• ... .... . , .,�. Ell ' F aro�. ,a•rxeeY�rax' 20 gay �11-tltS� Qio ' 1 3 � „'� � � i _�_,__... "�,w�kix°'i+�cew°0; :✓�"a3°�i' tZ t `'-, „�-�' .. "�" 3 r ... •. ' t _ ivenns.aAr�s'�xa.'i roe..,, Figure 10: Palm 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 12 (0) Oil Search Kookpuk 1 intersects the Tuluvak from approximately 2645 — 3150 ft MD. The Tuluvak at Kookpuk 1 is situated at structurally the same depth as the prognosed Tuluvak at Mitquq 1. Kookpuk 1 registered a gas flow event at the Top Tuluvak of up to 600 units (12%) while drilling with 9.1 ppg mud weight. Mud weight was then increased to 10.6 ppg and the flowing stopped and was controlled for the drilling of the rest of the formation. Well log analysis indicates there is a small sand at the top of the Tuluvak that is hydrocarbon bearing (Figure 12) with a thin 5' interval calculating 50% hydrocarbon staturation. The key difference between the Kookpuk 1 area and the wells closer to Mitquq appear to be the existence of a good top -sealing shale. Kookpuk-1 has an excellent sealing shale in the Lower Shcrader Bluff, and this shale exists over the Pikka Unit as well, which may be contributing to the Tuluvak's ability to hold a hydrocarbon column. Placer 1 and Colville 1 do not have this shale (Figure 13) so the top sealing capacity in the Mitquq area is likely quite low. Kookpuk 1 shows that while thin low -saturation hydrocarbon bearing sands exist in the Tuluvak, they are easily controlled by appropriate mud weights. H! Ntkt� u wr 13rhradpr Bluff , Tullwak sealb ee a, .6 _ lob 441k%?'.LY .4 CP✓'t�t ♦q�♦q r x h Y.w^»wbmtaVe«e rE« •F��Uu, war _iPwikb w5iki�76wi Mr .. .. S t Figure 11: Kookpuk 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 13 (1) Oil Search Well, KOOKPUK 1 Top Uiu V \\ C ,"4'• � i t9-i..:5� i �+r '� S i.1G1 k .rRL t .i n ww Mlf� Z! s 3 All gyp. hyr t� J F. a; r, Figure 12: Kookpuk 1 well log analysis showing a thin hydrocarbon bearing sandstone in the top of the Tuluvak formation. .......... ---- , ., ... ir, �} �.,, ,..,�, w....r mv�s "YfY - "w i'S'. .x*• iY7S Y"P+' r.R-v'-Y°"r'1'CR°� �. n ..,v •. V tr �M\\\�; n \`. i" k • y; ti 23rt! o i a ae ; { ` #2=. r { d $ r r ` r , d, F ? c 20CL _ a� 3i 1f'/, S_ , , i � r vvyy loll i a n 9 wti .o. i F , 3 xi y Figure 13: Stratigraphic cross section hung at the Top Tuluvak from Qugruk 2 in Pikka Field over to the closest offsets to Mitquq 1 showing the thickness of the shale sealing the Tuluvak over the Pikka and Kookpuk 1 gas accumulation does not exist in the Mitquq area. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 14 4.3. Log Analysis Drilling and mud log data suggest that the Tuluvak Formation closest Mitquq 1 does not contain significant gas. The low levels of observed mud gas probably reflect faint, residual gas saturation. Petrophysical logs are consistent with this interpretation. In the up -dip position at Placer 1 showed the highest gas mud cut (-1 %) while the Colville 1 well showed less than 1 % gas cut mud at an equivalent structural position to Mitquq 1. Careful inspection of cross -over between Neutron Porosity and Bulk Density logs shows there is no apparent cross over in any of the nearby offset wells. Kookpuk 1 does show hydrocarbon bearing sandstone (less than 5' thick) at the top of the Tuluvak, beneath a tight streak. There was no neutron log obtained in the well, so crossover could not be determined. 4.4. Pore Pressure Fracture Gradient Prediction Pore pressure and fracture gradient prediction for Mitquq 1 is based on several analogue wells. For the Tuluvak, a gas gradient is extrapolated to match the Qugruk 9 Tuluvak pressure. The Mitquq 1 Tuluvak pore pressure is further constrained by mud weights in the near offset wells Kookpuk 1, Placer 1, Placer 2, Placer 3, Colville 1, and Palm 1. Nanushuk pressures were derived from MDT pressures samples taken in the Pikka field at Qugruk 3, Qugruk 9, Qugruk 8. Torok pressures were derived from offset well mud weights and MDT pressures from Qugruk 1, Qugruk 4, and Qugruk 9A. Kuparuk C pressures derived from offset well mud weights and Placer 1, 3, and Qugruk 1 MDT data. Alpine C pressures derived from offset well mud weights as wel las Q9A MDT pressures. Nuiqsut pressures derived from offset well mud weights and Fiord 5 PB1, Oooguruk 1, Qugruk 1, Ivik 1 MDT and RFT data. Pre -Drill Scoping M.ltquq PPFG Model DRAFT iv.21 Sept. 26, 201.9 0 Oil Search Figure 14: Mitquq 1 pore pressure and fracture gradient prediction expressed in pounds per gallon equivalent. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 15 Redacted M. Guhl 5/6/2022 (0) Oil Search 5. Conclusions The Mitquq 1 overburden comprises two distinct permeable zones; the Schrader Bluff Formation and the Tuluvak Formation. There is a low risk of low-pressure gas or gas hydrates below permafrost in the Schrader Bluff. The risk of gas in the Tuluvak is also low. All offset well data strongly suggest that the Tuluvak at Mitquq 1 is likely to contain water or low saturation gas which can be controlled with appropriate mud weights. This interpretation is based on the following data and interpretation. 1. Casing Design — The seven nearest offset wells have surface casing set above the Tuluvak Formation; Placer 1, Placer 3, Colville 1, Palm 1, Kookpuk 1, and Ataruq 2. Mitquq 1 will also top set the Tuluvak with surface casing. 2. Mud Logs — Gas mud cut from the nearest offset wells showed a maximum of 1 % gas cut at Placer 1, Palm 1, Colville 1. Kookpuk 1 had a gas flow event with a 30% gas cut at the top Tuluvak, while drilling with a low mud weight. 3. Mud Weight — The Tuluvak Formation was drilled with mud weights ranging from 9.1 to 10.3 ppg mud weight in six offset wells; Placer 1, Placer 2, Placer 3, Colville 1, Palm 1, Kookpuk 1, Ataruq 2. Only Kookpuk 1 had a gas flow event, and it was drilling with the lowest mud weight of the group, at 9.1 ppg. All other wells were able to control the Tuluvak with a mud weight equal to or greater than 9.6. 4. Trapping Mechanism — There is no structural trapping mechanism mapped in the area surrounding Mitquq 1. There is nearly monoclinal dip off the 4-way dip closure across the Pikka Unit, where the gas accumulation exists. Also the sub -regional top seal that appears to be across the gas accumulation in Pikka and Kookpuk 1 does not appear to exist in the Mitquq 1 area, as it pinches out W to WSW of Mitquq. 5. Seismic Mapping — Seismic maps of the Tuluvak Formation show the Mitquq area is off structure to the main gas accumulation along the Tuluvak 4-way dip closure over the Pikka Unit. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 17 RECEIVE® STATE OF ALASKA NOV 01 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL //�� ^ 20 AAC 25.005 A ! ^ i .,e r- 1 f _ 1a. Type of Work: 1b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is propose for: Drill El Lateral [IStratigraphic Test ❑ Development -Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑✓ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ if. II Name and Number: Oil Search Alaska Bond No. NUSCGS025' it 3. Address: 900 E Benson Bouldevard 6. Proposed Depth: 12. ield ool(s): Anchorage, AK 99508 MD: 8,250' TVD: ,1 ndefined 4a. Location of Well (Governmental Section): 7. Property Designation: ` Surface: 531.27' FSL, 2302.42' FEL, Sec 3, T11 N, R7E, UM ADL 393876 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 353.5' FSL, 1191.81' FEL, Sec 3, T11N, R7E, UM LONS 19-005(Pending) 1st January 2020 Total Depth: 9. Acres in Prope 14. Distance to Nearest Property: 43.54' FSL, 742.86' FWL, Sec 2, T11 N, R7E, UM 2560 Acres 2,977 W 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevati°�abov M S L (ft): 75.3' 15. Distance to Nearest Well Open Surface: x- 459506.64 y- 5970621.16 Zone- GL / BF EI tio11 above MSL (ft): ' 47.3' to Same Pool: N/A 16. Deviated wells: Kickoff depth: 2500 feet 17. MaAdZIA Potential Pressur in psig (see 20 AAC 25.035) Maximum Hole Angle: 47 degrees q6w-Vole% 3,372 psi Surface: 2,716 psi 18. Casing Program: Specifications Top - Setting pth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Le th iiiiJ MD TVD MD TVD (including stage data) 20" 16" 84# X-52 Welded 0' 108' 33' Grouted to surface 12-1/4" 9-5/8" 40# L-80 BTC 2,4 0' 0' 2,475' 2,400' 11.0ppg Lead: 2,953cuft 15.8ppg Tail: 268cuft 8-1/2" OH 19. PRESENT WELhrCON N SUMMARY (To bepi5rinpleted for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD,(ft): Plugs (measured Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): � 7t Casing Length S1z Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑ 20. Attachments: Property Plat BOP Sketch ❑ Drilling Program g Time v. Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report Dri3ing-Fluid Program El 20 AAC 25.050 requirements❑ 21. Verbal Approval: Comm i ion Representative: Date 22. 1 hereby certifyXthat foregoing is true and the procedure approved herein will not be deviated from withwritten approval. Contact Name: Rachel Davis Authorized Name: Gudinger Contact Email: rachel.davisCo oilsearch.com Authorized Title: Sii Drilling Engineer Contact Phone: 907-375-4678 I I/ I / 1(� Authorized Signature: Date: Commission Use Only Permit to Drill iAPI Number: Permit Approval See cover letter for other Number: 150 50- 1 0 3 - 2, Q,3g--OCL OD Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes [�No❑ Mud log req'd: Yes CRIIINo❑ H,S measures: Yes ❑ No� Directional svy req'd: Yes VNo❑ Spacing exception req'd: Yes ❑ No(R" Inclination -only svy req'd: Yes ❑ No Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 Revised 5/2017 1 his permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ORIGINAL November 1, 2019 Alaska Oil and Gas Conservation Commiss 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permi Oil Search (Ala L Mitquq 1 and Mi uq 1 North Slope, Alaw Dear Sir/M Oiarch (Alaski� LLC SI pe of Afaska. Th itl sut formations orations. Both De ending on wint7weat a ti ipated to be d to late d 'II this we . Well testi appli ation. lug and apain( rml a to/be Drill Exploration Wells E' VE® )V 0 1 2019 AOGCV ill an exp atory oil test well on the North rgeti \eb e nushuk 9, Torok, Kuparuk C, d wt geting the Nanushuk 9 and e ge ostate lands. ca'iti ns an e r d ruction, the approximate spud date is ember 19. it S r at t ime anticipates using Nabors Rig 7-ES' is lanne for he si tra and ill be addressed in a sundry permit options r ch Ilbore will al be addressed in a separate sundry Please find en sed for your revs w Fo 10- 01 Permit to Drill with a supporting Application for Permit (o Drill con ping information as r quire by 2 AAC 25.005 for each wellbore. In compliance with 20 AAC 25 1 Well Site Surveys, a S Ilow Haza Study covering the Mitquq 1 area has been included in th DDlication. ereby applies or a PXrmit to q 1 well is Oeviaje6 wellbore Mitquq 1 STY' yell is a dev I ores are IQZted within sate lythere are any questions and/or additional information desir , please contact me at (907) 440-6892 or garret.staudinger(o,oilsearch.com. Respectfully, \ '\ ul/ Garret Staudinger Senior Drilling Engineer Oil Search (Alaska), LLC Oil Search (Alaska) LLC Anchorage office Tel: +1 907 375 4600 PO Box 240927 Fax: +1 907 375 4630 Anchorage, AK 99524-0927 www.oilsearch.com ORIGINAL (0) Oil Search Enclosures: Form 10-401 Permit to Drill Mitquq 1 Application for Permit to Drill Mitquq 1 Well Form 10-401 Permit to Drill Mitquq 1 ST1 Application for Permit to Drill Mitquq 1 ST1 Well Oil Search QD Oil Search Application for Permit to Drill Mitquq 1 Well Mitquq 1 Permit to Drill Rev1_20191030 - 1 - 01-Nov-19 Oil Search Table of Contents Applicationfor Permit to Drill......................................................................................................................... 3 1. Well Name...................................................................................................................................... 3 2. Location Summary ..........................................................................................................................3 3. Blowout Prevention Equipment Information.................................................................................4 4. Drilling Hazards Information...........................................................................................................5 5. Procedure for Conducting Formation Integrity Tests.....................................................................5 6. Casing and Cementing Program.....................................................................................................6 7. Diverter System Information..........................................................................................................6 8. Drilling Fluid Program.....................................................................................................................7 9. Abnormally Pressured Formation Information..............................................................................7 10. Seismic Analysis............................................................................................................................7 11. Seabed Condition Analysis............................................................................................................ 8 12. Evidence of Bonding.....................................................................................................................8 13. Proposed Drilling Program...........................................................................................................8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal................................................10 Attachments.................................................................................................................................................. it Attachment 1: Location Maps..........................................................................................................12 Attachment 2: Directional Plan........................................................................................................17 Attachment3: BOPE Equipment......................................................................................................26 Attachment 4: Drilling Hazards.........................................................................................................29 Attachment 5: Leak Off Test Procedure........................................................................................... 30 Attachment 6: Cement Summary.....................................................................................................31 Attachment 7: Rig Fluid System........................................................................................................32 Attachment 8: Prognosed Formation Tops......................................................................................34 Attachment 9: Pore Pressure Fracture Gradient Plot......................................................................35 Attachment 10: Independent 3 d Party Pore Pressure Fracture Gradient Plot ................................36 Attachment 11: Well Schematic.......................................................................................................39 Attachment 12: Formation Evaluation Program..............................................................................40 Attachment 13: Wellhead Diagram..................................................................................................41 Attachment 14: Days vs. Depth Plot.................................................................................................42 Attachment 15: Shallow Hazards Assessment.................................................................................43 Mitquq 1 Permit to Drill Rev1_20191030 -2- 01-Nov-19 Oil Search Application for Permit to Drill 1. Well Name 20 AA 25.005 (f): Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as Mitgug 1. This will be an exploratory well. 2. Location Summary 20 AA 25.005 (c) (2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines, (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; and Location at Surface Reference to Government Section Lines 531.27' FSL, 2302.42' FEL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,970,621.159 E 459,506.638 Rig KB Elevation 28.0' above ground level Ground Level 47.277' above MSL Location at Top of Productive Interval Reference to Government Section Lines 353.5' FSL, 1191.81' FEL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,970,437.348 E 460,616.518 Measured Depth, Rig KB (MD) 4,593' Total Vertical Depth, Rig KB (TVD) 4,174' Total vertical Depth, Subsea (TVDSS) 4,099' Location at Bottom of Productive Interval Reference to Government Section Lines 43.54' FSL, 742.86' FWL, Sec 2, T11N, R7E, UM NAD 27 Coordinate System N 5,970,117.367 E 462,549.836 Measured Depth, Rig KB (MD) 8,250' Total Vertical Depth, Rig KB (TVD) 7,175' Total vertical Depth, Subsea (TVDSS) 7,100' Mitquq 1 Permit to Drill Rev1_20191030 -3- 01-Nov-19 Oil Search (D) other information required by 20 AAC 25.050(b); 20AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 2: Directional Plan for further details. (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. There are no other wells within 200 feet of the proposed Mitqug 1 well. The applicant is the only affected owner. Included in Attachment 2 is an anti -collision scan from Mitquq 1 well location 3. Blowout Prevention Equipment Information 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable, BOP test frequency for Mitquq 1 will be 7-days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 7-day BOP test period should not be requested. Nabors 7ES BOP Equipment: BOP Equipment • Hydril annular BOP, model GK, 13-5/8" x 5000 psi • Hydril double gate, 13-5/8" x 5000 psi • Mud cross, 13-5/8" x 5000 psi with 2 ea. 3-1/8" x 5000 psi side outlets • Choke Line, 3" x 5000 psi with 3" manual and HCR valve • Kill Line, 2" x 5000 psi with 2-1/16" manual and HCR valve • Hydril single gate, 13-5/8" x 5000 psi Choke Manifold Cameron, 3" x 5000 psi working pressure with Swaco super choke and Dreco mud/gas separator BOP Closing Unit • Hydril model 165, 165 gallon, 220 gallon reservoir. Twelve 15 gallon bottles, four nitrogen backup. Equipped with 1 electric and 2 air pumps with emergency power. PLC controlled. Please refer to Attachment 3: BOPE Equipment for further details. Mitquq 1 Permit to Drill Rev1_20191030 - 4 - 01-Nov-19 V) Oil Search 4. Drilling Hazards Information 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure; 8-1/2" Production Hole Pressure Data Maximum anticipated BHP 3,372 psi in the Alpine C at 6,558' TVD (9.9ppg EMW top Alpine C formation) Maximum surface pressure 2,716 psi from the Alpine C (0.10 psi/ft gas gradient to surface, 6558' TVD) Rams test to 3,500 psi / 250 psi Planned BOP test pressure Annular test to 2,500 psi / 250 psi [Test pressure driven by annular pressure during frac job] Integrity Test — 8-1/2" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 3,000 psi surface pressure [Test pressure driven by 50% of surface casing yield] (8) data on potential gas zones, and There is no expected gas zones in the well. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please refer to Attachment 15: Shallow Hazards Assessment Please refer to Attachment 4: Drilling Hazards 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment 5: Leak Off Test Procedure. Mitquq 1 Permit to Drill Rev1_20191030 -5- 01-Nov-19 Oil Search 6. Casing and Cementing Program 20 AAC 25.005 (c) (2) A complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed,• Casing/Tubing Program Hole Size Liner / Tbg O.D. Wt/Ft Grade Conn Length Nap Bottom MD / Cement Program TVDss 20" 16" 84# X-52 Welded 80' Surface 128' / 53' Grouted to Surface 11.0ppg Lead: 526bbls, 2953cuft, 1130sks 12-1/4" 9 5/8" 40# L-80 BTC 2,475' Surface 2,475' / ArcticCem, Yield: 2.61 cult/sk2,400' 15.Bppg Tail: 48bbls, 268cuft, 227sks Type I/II —1.18 cult/sk Mitquq 1 OH To be abandoned with 3-1/2" sacrificial 8-1/2" stinger. Abandonment sundry to follow. Stage 1: 12.Oppg Lead: 21bbls, 118cuft, 55sks ExtendaCem, Yield: 2.13 cult/sk Tail: 85bbls, 477cuft, 385sks Mitqu15.3ppg 1ST1 7" 26# L-80 VAM TOP 6,130' Surface 6,130' / ExpandaCem Class G —1.24 cuft/sk 1/2 8-1/2" HC 5,633' Stage2: 12.Oppg Lead: 87bbls, 488cuft, 203sks VariCem, Yield: 2.40 cult/sk 15.3ppg Tail: 25bb1s, 140cuft, 113sks ExpandaCem Class G —1.24 cuft/sk Tubing 3-1/2" 9.2# L-80 VAM TOP 4,345' Surface 4,345' / 4,046' n/a Please refer to Attachment 6: Cement Summary for further details. 7. Diverter System Information 20 AA C 25.005 (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Nabors 7ES Diverter Equipment: • Hydril annular BOP, model GK, 21 1/4" x 2000 psi, flanged • Diverter Spool 21 1/4" x 2000 psi with 16" flanged sidearm connection. Interlocked knife/gate valves. • 16" Diverter Line Please refer to Attachment 3: BOPE Equipment for further details. Mitquq 1 Permit to Drill Rev1_20191030 -6- 01-Nov-19 8. Drilling Fluid Program 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Surface Hole 120' — 2475' MD Production Hole 2475' — 8250' MD Mud Type Water based Spud Mud Mineral Oil Based Mud Mud Properties: Mud Weight 10.5ppg 10.7-11.0ppg Funnel Vis 85-275 seconds 50-80 seconds PV 10-30 20-37 YP 30-45 15-25 API Fluid Loss < 14 ml/30min n/a HPHT Fluid Loss n/a < 5 ml/30min pH 8.6-10.5 n/a MBT 20-30 n/a Electrical Stability n/a > 600 Oil:Water Ratio n/a 80:20 Water Phase Salinity n/a 250-270k Low Gravity Solids < 10% < 6.5% A copy of drilling fluid system on Nabors rig 7ES is contained in Attachment 7: Rig Fluid System. 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f), Please refer to Attachment 8: Prognosed Formation Tops, Attachment 9: Pore Pressure Fracture Gradient Plot, and Attachment 10: Independent 3`d Party Pore Pressure Fracture Gradient Plot. 10. Seismic Analysis 20 AA C 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a), Please refer to Attachment 15: Shallow Hazard Assessment Mitquq 1 Permit to Drill Rev1_20191030 - 7 - 01-Nov-19 11. Seabed Condition Analysis 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); The Mitquq 1 Well is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 have been met; Oil Search Alaska is currently preparing to increase its bond amount already on file with the commission in accordance with updated AOGCC regulations. Evidence of bonding will be forthcoming. 13. Proposed Drilling Program 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (13) a copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to Mitquq 1/ST1 is listed below. Please refer to Attachments 11-14 for a Well Schematic, Formation Evaluation Program, Wellhead Diagram and Days vs Depth Plot. Proposed Drilling Program Mitquq 1 1. Drill/drive 16" conductor to —128' MD/TVD. Cement to surface. Install Cellar. 2. Move in / rig up Nabors Rig 7ES. 3. Install wellhead landing ring on 16" conductor. 4. Nipple up spacer spools and diverter over the 16" conductor. Verify that the diverter line is at least 75' away from a potential source of ignition and beyond the drill rig substructure. 5. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC 48hrs notice for witnessing diverter test. 6. Pick up 4" drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up 12-1/4" motor BHA with MWD and LWD tools. 7. Spud well and drill vertical hole section as per well plan to 2475' MD/TVD. Make Mitquq 1 Permit to Drill Rev1_20191030 - 8 - 01-Nov-19 0 Oil Search directional corrections and wiper trips as required. Circulate and condition hole and then POOH. 8. Run 9-5/8" surface casing as per casing tally and land on pre -installed landing ring. Circulate and condition mud prior to commencing cement job. 9. Cement 9-5/8" casing as per cement program. Adequate excess cement will be pumped to ensure surface casing is cemented to surface. 10. Nipple down diverter and nipple up BOPE and test to 250 / 3500 psi as per AOGCC regulations. Provide AOGCC 48hrs notice for witnessing BOP test. 11. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to 10.7ppg MOBM. Pressure test casing to 3000 psi for 30 min. 12. Drill out shoe track and 20 - 50' of new formation. Perform leak off test and submit results to AOGCC. 13. Directionally drill 8-1/2" hole section as per well plan to TD at —8250' MD / 7175' TVD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH. 14. Rig up wireline and complete open hole wireline as per formation evaluation program. 15. Apply for Sundry Permit to P&A Mitquq 1 wellbore. Mitquq 1 wellbore will be plug and abandoned with 3-1/2" sacrificial tubing and a BHKA disconnect. Cement will be placed inside and outside the tubing, with sufficient excess to bring cement above BHKA. Release from BHKA and circulate out excess cement. 16. WOC. Top of abandonment plug will be tagged with drillpipe, and a balanced cement kick off plug will be placed on the abandonment plug to the surface casing shoe depth. Mitgug 1ST1 17. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH, clean out to top of cement kick off plug. 18. Kick off cement plug below surface casing shoe and directionally drill 8-1/2" production hole to core point at —4400' MD / 4166' ND. Perform wiper trips as required. Circulate and condition hole. POOH. 19. Make up 8-1/2" coring assembly and run in hole. Circulate and condition hole prior to dropping coring ball. 20. Drop ball and cut core as per coring program. Make connections with coring assembly and continue coring. At the end of the core run, pick up to break core and then POOH as per coring trip schedule to allow the core to off gas. 21. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH and MAD pass coring interval. Drill 8-1/2" hole to well TD as per well plan to 6130' MD / 5708' TVD. Circulate and condition hole and then POOH. 22. Rig up wireline and complete open hole wireline as per formation evaluation program. 23. Run 7" production casing as per casing tally, land casing on wellhead mandrel hanger. Circulate and condition mud prior to commencing cement job. 24. Cement 7" casing with two stage cement job as per cement program. Monitor for cement Mitquq 1 Permit to Drill Rev1_20191030 - 9 - 01-Nov-19 0) Oil Search returns when stage tool is opened. Monitor for cement returns to surface when second stage is pumped. 25. Make up 6-1/8" clean out BHA. RIH, drill out staged cement tool and perform negative test on 7" casing. Clean out to 7" shoe track. Displace well to 9.5ppg brine. 26. Pressure test 7" casing to 3500psi for 30mins. POOH. 27. Rig up wireline and complete cased hole cement evaluation and VSP logs. 28. Prepare for completion operations. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. Water -based and oil based drilling muds and cuttings will typically be hauled directly offsite via truck as it is generated. Contractual arrangements have been made with other operators on the North Slope to utilize their waste injection/disposal facilities (Class 1 and Class 2) at Prudhoe Bay, Kuparuk and Milne Point. If waste cannot be hauled directly offsite, it may be stored temporarily in drilling waste cuttings bins or a bermed cuttings storage cell in accordance with a drilling waste temporary storage plan approved by Alaska Department of Conservation (ADEC) Solid Waste Program until it can be transported for proper disposal. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. Mitquq 1 Permit to Drill Rev1_20191030 - 10 - 01-Nov-19 W) Oil Search Attachments Mitquq 1 Permit to Drill Rev1_20191030 - 11 - 01-Nov-19 Oil Search Attachment 1: Location Maps Mitquq 1 Permit to Drill Rev1_20191030 - 12 - 01-Nov-19 I I cD� � Q•9 I _ 1 �RsrRia I rrosl \ � ®~ I_ _ _ I A I •� ---- MII.NE / PIKKr1 POINS — I / \ * Plkka C I I 1R ss I f I I I t I I I `cl I I I W-11 zw tia ie L ------- ?v KCS I I I i COLVILLE _CO.i IACF Li i _PLACER l I i , 1Y a KIC CL 2 RIVER inao1 I I Mitquq 1 I zr n A 1 ,I MSF 5w"I t---- ' �l Q-g I iC 1 r---------I----- !>wsAtc in Izv .1 IKoc --_-J - E I.MCORNERS . AKII crt IPlkkaB I__I 2F I (w$PPl Mn51 A*k GREATER------ `-�' ,� WIAK5 MOOSES `- i 1-------I--\�_�------ ---- 1S.MIIUVEACHi , \ KUPARUK RIVER TOOTH NUIQSUT _ - - - _ . wr-m i I I I I j I - - - - - - - - - - _ I W SAK 24 I j wSAK ze A- - - - - - - - - - - - - - - - ; If 1 t 1 I Stirrup 1 I L ' I r Hs-1 1 I I I MSS i I I I K-1 ® OIL SEARCH AION CA LLC. P1oject Lacat(on 1 - 1 20OIL SEARCH20 ALA CAMPAIGN 7� 201 I-2019 DRILLED WELLS L _ � PRODUCTION UNIT — NS EXISTING GRAVEL ROADS � , � EXPLORATION ICE ROADS C� NS EXISTING FACILITY NPR -A BOUNDARY N PROPOSED CAMPAIGN OVERVIEW Oil Search 0 EXPLORATION DRILL SITE -- NS EXISTING PIPELINES OIL SEARCH LEASES o s GCS: NAo 11.—I.A.,1e Nafka4FlP5500<Feel w e ®Mue: DAre:visi:oir. xEYa.o. nr:,n ®10—frn D.—.1.-0Ps11-GEKan_k.ewe.J.occcl S o I ] AS -STAKED MITQUQ 1 LOCATION NAD-83(2011)( EPOCH:2010.0000) Alaska State Plane Zone 4 US Survey FT N 5,970,370.93' E 1,599,539.38' EL 47.28' (NAVD88 Utilizing Geoid12B) NAD-83(2011)( EPOCH:2010.0000) N 70°19'49.287" W 150"19'53.637" NAD-27 Alaska State Plane Zone 4 US Survey FT N 5,970,621.16' E 459,506.64' NAD-27 N 70°19'50.402" W 150°19'42.392" NOTES 1. DATE OF FIELD SURVEY AUGUST 5, 2019. 2. BASIS OF COORDINATES PER OPUS SOLUTION OF STATIC GPS OBSERVATIONS ON AUGUST 5, 2019. 3. WELL LOCATED WITHIN PROTRACTED SEC 3, T11N, R7E, UMIAT MERIDIAN. 531' FROM SOUTH SECTION LINE 2302' FROM EAST SECTION LINE 4. ICE PAD LOCATED WITHIN PROTRACTED SEC 3 AND 10, T11N, R7E, UMIAT MERIDIAN. PROPOSED ICE PAD 1,000, X 1,000' N75° 1. 0 7 WE LOCATI 0 o 4 P�ASRC MINE SITE 9 � 1 NUIQSUIT T12N _ I T10N a� T9N = VICINITY MAP T11 N, R7E SCALE: 1" = 6 MILES SEC. 3 PROPOSED 35' WIDE ICE ROAD ),/ MITQUQ 1 WELL LOCATION) 5pV SEC. 3, T11 N, R7E, U. M. e SEC. 10, T11N, R7E, U. M. v 0 ,moo e ,f v 0 150 300 SCALE IN FEET -f,/-j■`,� I! !1 1 MITQUQ 1 EXPLORATORY WELL PROPOSED ICE PAD RECONFIGURATION U m I A Q & AS -STAKED WELL LOCATION o.dpaM.+sW*ew1A I4C Oil Search NORTH SLOPE, ALASKA 6700 Arctic Spur Road Anchorage, AK 99518 DATE: 10/29/2019 DRAWN BY: FM / MMHN SHEET: 1 OF 1 (9071677-8220 SCALE: AS SHOWN CHECKED BY: K,JP JOB No: 80209.19 i PR s OJE—ClAREA °r , t. f Mltqquqq 1 STl SHL X: 458085.518 Y:5971243.024 Nanushuk 9 sandstone X 458764.574 Y:5970945.878 . ,.. Mitq q�q q X:459506.638 j - E a Mitquq 1. MN Y: 5970621.159 nushuk 9 sandstone WIT _ - X 460616.518 Y: 5970437.348 _r, s - - "` .. ----- K 1, , , _ - A �' Mitquq 1 BHL X:462549.836 ' Y:5970117.367 DL i J q 8 , .. a .. ... r t 9 . 4 - N _ a« r..au,u.,.._ 1w�..>.u.�§L]E:u.�..a •�u �i ..,Xa�.:.:.>:.,.wia�a. ..' «.;Sd:A_ i� ... _.L_ • TOPS DIMENSION_LINE SECTION OIL SEARCH ALASKA 2019-2020 EXPLORATION CAMPAIGN ® O WELL SURFACE HOLE 1._1 LEASE OUTLINE N MITQUQ 1 WELL PLAN 0 200 400 Oil Search WELL TRAJECTORY TOWNSHIP W E ® Feet GCS: NAD 1927 StatePlane Alaska 4 FIPS 5004 ® Meters DATE: 9/24/2019. REV: 2.0. By: JB S 0 100 200 Document name: OPS-19-20-W-M_Mitqugl_WellPlan_NAD27 WELL LOCATION EQUIPMENT OUTLINES ICE PAD/ICE ROAD OUTLINES — — ICE ROAD CENTERLINE -- DIVERTER ® 30-FT OFFSET SECTION rr 1,0p01 R .• \are \5 Well Test Truck Staging Well Stimulation RIG i ek © o© 0 ,ae stoa t j V — Off\oe {, EnvIsP\\\ R esPonse Cam p o storage Camp CommsO F ne\ Annex Shop o twWrah , 4 ry i w � e t ti e 1 t 1 i 'k t, ti .i i OIL SEARCH ALASKA I.I.C. N 2019-2020 Exploration Campaign 40 MITQUQ 1 DRILL SITE OVERVIEW (Nabors 7ES Rig) 0 20 40 Oil Search Figure X ®Meters GCS: NAD 1927 S}atePlane Alaska 4 FIPS 5004 ®Feet DATE: 2019-09-24. REV: 2.0. By: A 0 50 100 Document name: OPS-19-20-P-PE-M POO_Mitqugl NAD27 0 Oil Search Attachment 2: Directional Plan Mitquq 1 Permit to Drill Rev1_20191030 - 17 - 01-Nov-19 Oil Search Mitquq-1 wp02 v5 Proposal Geodetic Report Schiumherger (Def Plan) Client: Oil Search rveyr mpurau Vertical Section Azimuth: mnsm 99.084' (True North) Field: NS Wen Vertical Section Origin: 0.000 ft, 0.000It Strun're / Slot: Mitquq-1 - MAD27 / Mitquq-1 TVD Reference Datum: Rotary Table Well: Mitquq-1 Reference Elevation: above MSL 75.277 If abMSL Borehole: Mitquq-1 Ground Elevation: 47.277 ft above MSL API,: 50103-DD Magnetic Declination: 16080 ° Survey Name: Mitquq-1 wpO2 v5 Total G-Ity Field Strength: 1002.0008mgn (9.80665 Based) Survey Data: September 25, 2019 Gravity Model: DOX Tort i AHD I DDI / ERD Ratio: 73.948' / 3112.312 It/ 5.423 / 0.434 Total Magnetic Field Strength: 57378.891 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angle: 80.789 - Location Let I Long: N 70' 19' 50.40263", W 150. 19' 42.39178" Declination Data: December 31,209 Location Grid N/E vIX: N 5970621.161 ftUS, E 459506.64011US Magnetic Declination Model: BGGM 2018 CRS Grid Convergence Angle: -0.3093' North Reference: True North Gntl Scale Factor: 0.99990186 Grid Convergence Used: 0.0000' Version I Patch: 2.10.544.0 Total Con' Mag North ->True North: I Deal rnnrd ReTor .- to 16.0805' Wnll - Comments MD Incl A:Im True TVDSS TVD VSEC NS EW TF DI. Directional Exclusion Exclusion Zone GeoMeg Th Northing Easting (ft) (9 1'1 (11) Iftl (ft) (ft) (ft) (•1 (7t0oft) Dltnculfy Index Zone Alert M l9,e 1 Inn (ftus) (ftU5) RTE 0.00 D.00 0.00 -75.28 0.00 0.00 0.00 0.00 99.09M WA 0.00 9.21 9185.09 5970621.16 459506.64 Rase Permafrost 152S28 0.00 99.09 1450.00 1525.28 0.00 0.00 0.00 99.0914 0.00 0.00 9.21 9186.52 5970621.16 459506.64 Mid Schrader Bluff 2075.28 0.00 99.09 2000.00 2075.28 0.00 0.00 0.00 99.09M 0.00 0.00 9.21 9187.04 5970621.16 459506.64 MCU 2410.28 0.00 99.09 2335.00 2410.28 0.00 0.00 0.00 99.09M 0.00 0.00 9.21 9187.36 5970621.16 459506.64 9-518 casing 2475.28 0.00 99.09 2400.00 2475.28 0.00 0.00 0.00 99.09M 0.00 0.00 9.21 9187.42 5970621.16 459506.64 KOP Cry 4/100 2500.00 0.00 99.09 2424,72 2500.00 0.00 0.00 0.00 99.09M 0.00 0.00 9.21 9187.44 5970621.16 459506.64 Lower SchrdderaluR 2550.29 2.01 99.09 2475.00 2550.28 0.88 -0.14 0.87 99.09M 4.00 0.25 9.18 9160.33 5970621.02 459507.51 2600.00 4.00 99.09 2524.64 2599.92 3.49 -0.55 3.44 99.09M 4.00 1.14 9.58 9548.91 5970620.59 459510.08 Tuluvak 2627.44 5.09 99.09 2552.00 2627.28 5.66 -0.89 5.59 HS 4.00 1.46 9.96 9924.24 5970620.24 459512.22 2700.00 7.99 99.09 2624.07 2699.35 13.93 -2.20 13.75 HS 4.00 2.05 11.41 11367.96 5970618.89 459520.38 2800.00 11.99 99.09 2722.54 2797.82 31.28 4.94 30.88 HS 4.00 2.57 14.16 14040.70 5970616.06 469537.49 2900.00 15.99 99.09 2819,55 2894.83 55.44 -8.75 54.75 HS 4.00 2.95 17.39 17154.43 5970612.11 459561.33 3000.00 19.98 99.09 2914,65 2989.92 86.31 -13.63 85.23 HS 4.00 3.24 20.88 20457.70 5970607.07 459591.79 3100.OD 23.98 99,09 3007.36 3082.64 123.74 .19.54 122.19 HS 4.00 3.47 24.52 23821.37 5970600.96 459628.71 3200.00 27.98 99.09 3097.24 3172.51 167.53 -26.45 165.43 HS 4.00 3.67 28.25 27169.90 5970593.82 459671.91 3300.00 31.97 99.09 3183.84 3259.12 217.49 -34.34 214.76 HS 4.00 3.85 32.04 30453.86 5970585.66 459721.19 .00.00 35.97 99.09 3266.76 3342.03 273.35 43.16 269.92 HS 4.00 4.00 35.87 33637.54 5970576.54 459776.30 3500.00 39.97 89.09 3345.58 3420.85 334.86 -52.88 330.66 HS 4.00 4.14 39.73 36693.03 5970566.50 459836.98 3600.00 43.96 99.09 3419.91 3495.19 401.72 -63.43 396.68 HS 4.00 4.26 43.61 39597.29 5970555.59 459902.93 End Cry 3675.31 46.97 99.09 3472.72 3548.00 455.40 -71.91 449.68 HS 4.00 4.35 46.54 41672.59 5970546.83 459955.89 Nanuhuk Formation 4415.82 46.97 99.09 3978.00 4053.28 996.74 -157.39 984.24 HS 0.00 4.71 46.54 41675.44 5970458.47 460489.92 Nanuhuk 9 Sandstone 4593.16 46.97 99.09 4099.00 4174.28 1126.38 -177.86 1112.25 HS 0.00 4.77 46.54 41676.12 5970437.31 460617.80 Cry 1.16/100 5261.05 46.97 99.09 4554.72 4630.00 1614.64 -254.96 1594.38 LS 0.00 4.94 46.54 41678.69 5970357.62 461099.46 5300.00 46.52 99.09 4581.42 4656.69 1643.01 -259.44 1622.40 LS 1.16 4.95 46.10 41373.46 5970352.99 461127.45 5400.00 45.36 99.09 4650.95 4726.23 1714.87 -270.79 1693.36 LS 1.16 4.98 44.97 40579.27 5970341.26 461198.34 Nanuhuk 8 5479.13 44.44 99.09 4707.00 4782.28 1770.72 -279.61 1748.51 LS 1.16 5.00 44.08 39940.22 5970332.15 461253.44 5500.00 44.20 99.09 4721.93 4797.21 1785.31 -281.91 1762.91 LS 1.16 5.01 43.84 39770.09 5970329.77 461267.83 5600.00 43.04 99,09 4794,33 4869.60 1854.29 -292.81 1831.03 LS 1.16 5D4 42.71 38946.36 5970318.51 461335.88 5700.00 41.88 99.08 4868.10 4943.38 1921.80 303.46 1897.69 LS 1.16 5.06 41.58 38108.53 5970307.49 461402.47 5800.00 40.72 99.08 4943.23 5018.51 1987.79 -313.80 1962.85 LS 1.16 5.09 40.46 37257.08 5970296.72 461467.57 5900.00 39.55 99.08 619.68 5094.96 2052.25 -324.06 2026.50 LS 1.16 5.11 39.33 36392.48 5970286.20 461531.16 6000.01 38.39 9908 5097.43 5172.70 2115.15 -333.99 2088.61 LS 1.16 5.13 38.21 35515.27 5970275.93 46159321 6100.00 37.23 99.08 5176.43 5251.70 2176.45 -343.67 2149.15 LS 1.16 5.16 37.09 34625.97 5970265.93 461653.69 62DO." 36.07 99.08 5256.65 5331.93 2236.15 353.10 2208.09 LS 1.16 5.18 35.97 33725.15 5970256.19 461712.57 Torok (Nan-6) 6211.56 35.94 99.08 5266.00 5341.28 2242.94 354.17 2214.80 LS 1.16 5.18 3S84 33620.34 5970255.08 461719.28 6300.00 34.91 99.08 5338.07 5413.35 22S4.20 -362.26 2265.42 LS 1.16 520 34.85 32813.40 5970246.71 461769.85 6400.00 33.75 99.08 5420.65 5495.93 2350.60 -371.17 2321.11 LS 1.16 5.22 33.74 31891.35 5970237.51 461825.48 6500.00 32.59 99.08 5504.35 5579.63 2405.31 -379.80 2375.13 LS 1.16 5.24 32.62 30959.66 5970228.58 461879.45 6600.00 31.43 99.08 5589.15 5664.43 2458.31 -388.17 2427.47 LS 1.16 5.25 31.52 30019.03 5970219.93 461931.74 6700.00 30.27 99.08 5675.00 5750.28 2509.58 396.27 2478.10 LS 1.16 5.27 30.41 29070.22 5970211.56 461982,32 HRZ 6701.15 30.25 99.08 5676.00 5751.28 2510.17 396.36 2478.68 LS 1.16 5.27 30.40 29059.23 5970211.47 461982.89 NS West\Mitquq-1\Mitquq-1\Mitquq-1\Mitquq-1 wiD02 v5 Drilling Office 2.10.544.0 Schlumberger-Private 9/26/2019 1:58 PM Pagel of 2 comments MD Inc] A.I. True TVDSS TVD VSEC NS EW TF DLS Directional Exclusion Exclusion Zone GeoMag Th Northing Easting (ft) 1°l 1°) (M (ft) Ift) (ft) M) 1°I (°I100ft) Difficulty Index Zone Aloe Angie t•1 (n7) (ftUS) (ftU3) 6800.00 29.11 99.08 5761.88 5037.15 2559.11 404.08 2527.00 LS 1.16 5.29 29.31 28114.04 5970203.48 462031.17 6900.00 27.94 99.08 5649.74 5925.01 2606.86 411.62 2574.16 LS 1.16 5.30 28.22 27151.37 5970195.69 462078.28 7000.00 26.78 99.08 5938.55 6013.82 2652.82 418.88 2619.54 LS 1.16 5.32 27.12 26183.15 5970188.19 462123.62 Kup C Sandstone 7016.18 26.60 99.08 5953.00 6028.28 2660.09 420.03 2626.72 LS 1.16 5.32 26.95 26026.08 5970187.01 462130.79 7100.00 25.62 99.08 6028.27 6103.55 2696.98 425.85 2663.14 LS 1.16 5.33 26.04 25210.45 5970180.99 462167.18 LCU 7127.39 25.30 99.08 6053.00 6128.28 2708.75 427.71 2674.77 LS 1.16 5.33 25.74 24943.38 5970179.07 462178.80 7200.00 24.46 99.08 :118.87 6194.15 2739.30 432.53 2704.94 LS 1.16 5.34 24.96 24234.41 5970174.08 462208.94 7300.00 23.30 99.08 210 .31 6285.58 2779.78 438.92 2744.91 LS 1.16 5.36 23.89 23256.31 5970167.48 462248.87 7400.0. 22.14 99.08 6302.55 6377.82 281BAl 445.01 2783.05 LS 1.16 5.37 22.82 22277.62 5970161.18 462286.97 7500.00 20.98 99.08 6395.55 6470.83 2855.15 450.81 2819.33 LS 1.16 5.38 21.77 21299.95 5970155.18 462323.22 End cri I Tgt 7584.18 20.00 99.08 6474.40 6649.68 2884.61 455.46 2848.43 HS 1.16 5.39 20.89 20479.14 5970150.38 462352.28 Alpine 7593,33 20.00 99.08 6483.00 6558.28 2887.74 455.96 2851.52 HS 0.00 5.39 20.89 20479.17 5970149.87 462355.37 8esa Alpine C 7663.57 20.00 99.08 6549.00 6624.28 2911.76 459.75 2875.24 HS 0.00 5.40 20.89 20479.33 5970145.95 462379.07 M 8249.93 20.00 99.08 7100.00 7175.28 3112.31 491.40 3073.27 0.00 5.42 20.89 20480.73 5970113.23 462576.91 Survey Ertor Modal: ISCW SA Rev 0 - 3-D 95.000% Confidence 2.7955 sigma Survey Program: MD From MD To EOU Fmq Hole Size Casing Diameter Expected Max Description Part (ft) (ft) (ft) Inclination Survey Tool Type Borehole/Survey (In) (In) (deal 7 0.000 2467.000 1/100.000 12.250 9.625 SLB MWD°SAG Mitquq-1/Mitquq-1 Wp02 v5 1 2487.000 8249.927 1/100.000 8.500 .00 00 SLB MWD+SAG Mitquq-1 / Mliquq-vry02 v5 1 NS West\Mitquq-1\Mitquq-1\Mitquq-1\Mitquq-1 wp02 v5 Drilling Office 2.10.544.0 5chlumberger-Private 9126/2019 1:58 PM Page 2of2 Schlumberger Oil Search Borehole: Well: Field: Structure: Mitquq-1 wp02 v5 Mitquq-1 NS West Mitquq-1 GnNly S Magnetk Paramebn Surleee L-0- NADB3 Alaska State Plane, Zone 04, US Feet Mleul Zue Motlal: BGGM 2018 DIP: 11.189' Dab: ]1-0ao-2019 5970370.93RU Le; N 7019 {9.29 NorNing: yy Grb Conr. -0.]122' 22 Slot MUquq 1 TVD Nag: RKB(75.28R above NSL) M.go.: 16.08- FS: 57373.291 nT Gravy FS: 1002.001m9n 19.80665 Baa.M Lon: W 13019 53.64 Eae0n9: 1599539.3BRU Seale Feet 0.99 90 Plan: Mitquq-1 wp02 v5 -1600 -800 0 800 1600 2400 3200 4000 0 RTE 0 O MD O TVD 0.00' Inc] 0.00' az 0 vsec 800 800 1600 Base Permafrost (1525.277 ND) 1600 9-5/0 casing 2475 MD 2475 TVD .._.._.._.._.._.._.._.._.._.._.._.._.._.. _.._.._.. _.. _.._.._.._._.._. .._.._.._.._.._.10D._.iacl-ROM._.az....................... ..... .............. _.................................................................... Mld Schrader Bluff (2075.277 ND) 0 vsec 2400 Iv1CU(24702777VD)........ .............................. ......_.._.._.._._......................... _........................ ,._....,................................................................ -......... 2400 ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._....._.-..-.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._........_....._.._....._...._.._.._..___...._..........._.._.._.._.._.._.._.._.._.._.._.._....._.. aalecl; hradar9WH 55D2Z7.31CDq__.._.._.._.._.._.._. .._.._.___.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..___.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.. Tuluvak (2627,277 ) KOP CN 4/100 2500 MD 2500 ND 0.00 °Intl 99.09 ° az 0 vsec 3200 End Cry 3200 3675 MD 3548 ND 0 46.97 ° inG 99.09' az V 455 vsec CN 1.16/100 5261 MD 4630 ND 11 46.97 ° incl 99.09 ° az m4000 1615 vsec 4000 .........................._....._.._.._..... .... ._.... ........ ................................................................... ......... .. Nanuhukrm Foation (4053.27700000005 TVDj .._.._....._.._.._.._.._.._.. ,r .. .........._....._.._.._.._ . ............................................................................_.._................................_.. anu uk 9 Sandstone (4174.27700000007 ND) O Nanuhuk 8 (4782.277 ND) � -� -� -� -- -� �� -� -' _. _. _. _. _. _._._. _. _. _. _. _. _. _. _. _.._.._. _.._.._.._.._.._.._.._.._.._ 4800 Torok (Nan-ej (5341.277 ND) ........ ............... _......................... ............._............_............................................................ _......................... _................ 5600 5600 . . ......... End Cry / T0t 7584 MD 8550 ND '_.._.._.._.. 20.00 ° Incl 99.08 ° az .._.._.._.._.._.._.._.._.._.._.._.._.._..p.)----------- _.._.._._.._.._.._.._.._.._.._.._..-.._.._.._..-..-..-............................... ._---..-.._.._ _.._.._..-..-..-..-..-.._2886 vgeo......................... .. C Sandstone jD) 277 ND)_.................... ............................................... _.._._........................ ._.............. ..................... (8128.277 ND) L LCU 6400 6400 se Alpe C j824T7 TD 7200 8250 MD 7175 ND Mitquq-1 Wp02 v5 7200 20.00' incl 99.08 ° az 3112 vsec -1600 -800 0 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 99.08° Scale = 1:1120.00(ft) Origin = ON/-S, OFJ-W (P Schtum#erer Oil Search Borehole: Well: Field: Structure: Mitquq-1 wp02 v5 Mitquq-1 NS West ( Mitquq-1 Gravity S Magnetic Parameters ISurface Location NAD83 Alaska State Plane, Zone 04, US Feet Mlscellanwus Model: BGGM 2018 Dip: 80.789° Date: 71 -0ec-2019 Lot: N 7019 49.29 Northing: 5970370.93ftUS Grid Conv: -0.3122° Slot: Mltquq 1 ND Ref: RKB(75.28ft above MSL) MagDoc: 16.08° FS_ 57378.891nT Gravity FS: 1002.001mgn (9_80665 Based) Lon: W 15019 53.64 Easting: 1599539_38ftUS Scale Fact: 0.9999019 Plan: Mtquq-1 wp02 v5 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 Tn,e 600 Gdd Mag 600 9-5/8 casing 0 MI ND 0 MD 0 2475 MD 2475 ND 0.00 ° ind 0.00 " az 0.00 ° incl 99.09 ° az TNe North Tat Con (M->T 16.080°) N=0 E=0 N=0 E=0 Meg Dec (18.080') Gnd Conv (-0.312') 300 300 KOP Cry 4I100 2500 MD 2500 ND 0.00°Ind 99.09°az N=0 E=0 0 0 00 0 Q Mitquq-1 wp02 v5 0 a u d Mitquq 1 Target -300 End Cry -300 � 3676 MO 3548 ND 46.97 ° incl 99.09 ° az N=-72 E=450 z Z Cm 1.161100 5261 MD 4630 ND -600 46.97' Inc] 99.09 ° az N=-255 E=1594 -600 End Cm / Tgt 7584 MD 6550 ND 20.00 ° Inc] 99.08 ° az TD -900 N=455 E=2848 8250 MD 7175 ND -900 20.00 ° ind 99.08 ° az N=-491 E=3073 -1200 -1200 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 EW (ft) Scale = 1:400.00(ft) 0 0 0 o O 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 � W cO0 V N O O q O N 0 O r j O CV 0 (J71'" N Cr Qp +o m pCl co CD u O f Z l I 1 1 LL ( y _ NC ' I Q I I O t0 V n O aji Y —$ — - . a-- > N n Oj o a n r N I �� i �- �m N a' A oo U - — - -- --- 7 0 H . o 9 0 m m e OLO I I 1 I p LL O O r/ N o o ICL ` O O CD (9 3 p m.� I " s m 0 i M i 0 o LL o 0 3 .. __ _ ._.__... o ' O O O O O C.O O O O O O ' O O O O O O O O O O O O O O O O O O O O O O w CN O 00 c0 ' N N q t0 0J)00'099t,4 = aI-S (ll) SN Mitquq-1 wpO2 v5 Anti -Collision Summary Report M yala Dab-24h,The1: Sepfembn25, 2019- 14:15 Analyah Method: clhnl: Oil Saer,il fbhnnu Tnject9ry: FMId: NS West Depth lnteml: SWctun: Mkquq-1 Ruh SN: Slot M9gl q , Mln Ph: WeO: MBquq-1 Verelon/Patch: Borehole: mkqu¢t D_a .l Prefect Scan MO Wn9a: 0.DM-824993A ISCWSA03-D 95A00%Confidenu7.7955ei9nw.baubjocllvsll.For T,eleelon Error Modal: oflael wNle, enx model venlan h alle"W Mi on wall reapacllvelY. OReet TrW-des Summery Ofteat SehNon cftb WMNasd diehnn scat: Rutricled vnNin 49260.438 Sekctonflhn: DefiM Surveys-Defn4hePlans-Daf d.swaysexdudedefr9liYepl- - M Nan-Def Surveys when 110 DefSulw3y fe eel in a borehole. All Non-W Plana when no DefFW, is set h a borehole Normal Plane Mdquq-1 wp02 v5(Daf Plan) Every 10.00 Memund Depth eft) DW MGCOIkiu Sbnderd S002 v5.1/5.2 Nl locd minlme In kol d. 2.10.544.D boalh0oMnftg-North Sbpe West ghat TnJectory 9e nUon Allow Bap. Controllhlp RahnnuT aM Rhk U,V A1.d Staten Ct R MAS E0U R D9 Fact Rula ND TVD D Alert Mho, Max Mae, Placer 1 (Dsf SuneY) PMe 60 ..81 loo. = 8803.40 18606.08 M45=10.00 (m) 33028 330.20 MMl 114.5E 8529.29 819150 1138E 880].11 11].B9 B5282 'M9'A2 110.18 BB0B.48 1935 B52B. M89.13 0322 B6]2.22 130.25 651508 83019 100.1 O t. 0SF1W OSF150 OSF1.50 2851.14 2943 ]3 2.1.. 2955.59 297049 2982.09 3025.7T MinRCICI MINPT-O-EOU MI..-P MkR-0.SF Rmw. z (DOs9rvar7 eae014 15T.9 855]. 350)2 OSFI.50 3055.J5 3041.5] Mr1PM Pei+ 9370. 105.03 930025 W6560 13521 OSF1.50 2740.21 2739.00 MinRC1C1 0385.01 115.41 -1,71 92495] 122.7E Ob11'. 2-71 2T02.& MinRC1C1 9285.9 92b 22 11780 0SF150 280372 2aOl A5 INP7-O-EOU MMInR-0#DP 9J683T 13T.10 9T88.3 9244.8 114.44 OSF1.50 2813,35 2810.89 9891.28 189A9 976161 9]0t.) )8.7 1008 . 1., B05274 90B214 7885 OSF1.50 OSF1S0 -A. 3232.14 33W.21 3312.86 MnROSF Mn-F CON1h 1(Oai survey) Pak 701,7 12982. 1T]/8.0 26.79 OSF1.50 248 W 2.So M_ 13450.50 701.73 12BB2.43 IV48.8 20.] 1N35.50 1190.11 11508. 11015.18 1343 09F150 OSF1.50 2501.31 25%.31 .49,93 1175.20 M'nR-F M'rPM Glanr 3 (Oaf Suwe3{ Pau 15161.E 32.01 15460.t 5128.3 25614386 MA5=1flM Im) SS.1B 55.18 MMN 15M9A] 32.81 1543]. 154189 1404.13 MAS=1... 2244.12 2244.12 MiMb lwo.]0 J2.81 15{]12 1511809 -7,42 MAS=10.W 2-11 2354.11 MINPT-0-EOU 15503AD 32,81 15t09.68 154702 1246.E 7.25 32.81 15623.75 156xA MAS=10.00Imj MAS=10.001m) 2555.87 2555.9E MkR OSF 24B] '0 15719.2E 92.81 15088.92 ISEBOA 1ZE97 MAS-10.00ImJ 2850.18 3819.92 2689.11 2888.5E MnR-0SF MMR-03F 15787A7 32.81 15754.00 15]349 1283.4 t60JJ.99 3291 18089.48 32.81 100T4B9 n06B 8] 118180 MAS=10.00Im) MAS=10.00 (m) MA9=1p.00Im) 2712.44 2711.88 2$111337 282845 2823.84 MnRObF MI.R-OSF Ararat u (D4f.5uYef1 MhR SF Pua. 21239.18 32.81 21 ]9 2120695 WA 21213.2 3281 213M.1 21180A 281E.40 MAS=1000 (mJ M49=10.00(.1 0.00 0.00 1839.0 1639.65 Sudan m- 21213]t 32.81 212011 2118050 2605.17 MA5=1000ImJ 1B4B 60 181980 MINPT-OEOU 21255.45 32.81 21- 21222 18298 21221. 32.91 21210. 211880 1.15 7 MAS=10001m7 --ID (ml 250091 2500.3] 2535.85 2535.94 MmR05F MSPb 20 ]p 211894 1820.3 212J2.2B 32.81 2171 MAS=f0.0o lml 2669 25%n MinPl-65F 21329.60 32.81 ]1788 21298> 1906.2 19291.1 43,5E 1926141 19247E 0999 M4S=10001m7 08F1.50 2640.13 3639.90 .19.93 1175.28 MkROSF ml. Abmg2 (Oaf Suwy) Pau 21239.76 32,81 21230Ti 212 B95 ®22t2132.32.81 212W 1 804 2651W MA5=100.OIm1 00 16]0.9.605 1840 B30B..0B05 an 1111131 21. 10.0 MINTSOMu-dP 2545 3322.8Mf7 10.1 200.1 22151315.3B75 .-'F 9 2191222911.. 01mJ 29 1 H71 M1000 2535 MnR-021232,21 29.50 IJ 435 M00 OSF1.50 289 8249.93 7175.28 M-F MMk �n M — LL O RS N Sapara�i�m f n��i"r I r -iSlEpat9110tl Factor W 0- 01 v A d I 111) yldod pomsv%p II Traveling Cylinder Plot NoGo Region EOU's based on: Oriented EOU Dimension -Minor Risk Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2 11117 280 270 260 North 350 10 190 180 170 TRAVELING CYLINDER PLOT Client Oil Search Field NS West Structure Mitquq-1 Well Mitquq-1 Borehole Mitquq-1 Date 25-Sep-2019 90 00 Oil Attachment 3: BOPE Equipment Mitquq 1 Permit to Drill Rev1_20191030 - 26 - 01-Nov-19 b O I > 6 CD n� -- YItl39 AW1021 z ,ll-,oZ < o- - CD U Cl- CD m i i /1 qi - I � �Qw J H j Z Z Z W ru N Z > Q W J a r � x o 0 g,91/S 9-,9Z CD ski I i I =_ ni Ca- 0 0 — CD CD j Q CD LJ i m I �/ CD — -- m �F w LIZ Y W ¢ Q Q Q Q l7 W Lo F W Z _j W o <LW J fn F- W D < z w Aa W Zn Vl � MIT K InQN W N tnW YdFa Yd J a» LA. Na Z I J It7 Z m W M 0� Q \ F- Lo (`7 1Q W I -� l7 I I � 1 J_ 2 K Q (1) Lo 9:1� J d n J >- a w M :n A r o r = J = Nabors Alaska Drilling Rig Material List Item Description A 3-1/8" 5000# Remote Hydraulic Operated Choke B 3-1/8" 5000# Adjustable Choke 1-14 3-1/8" 5000# Manual Gate Valve 15 2-1/16" 5000# Manual Gate Valve 7ES To Mud/Gas �� Separator Oil Search Attachment 4: Drilling Hazards 12-1/4" Surface Hole Section Hazard Mitigations Conductor Broach Monitor conductor for any indications of broaching. Monitor pit volumes for any losses. Gas Hydrates Keep mud cool, optimize pump rates, minimize any excess circulation. Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Keep mud cool, optimize pump rates, minimize any excess circulation. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Shallow Gas Shallow hazards assessment, sufficient mud weight, on site surveillance (mud loggers, trained drilling personnel). 8-1/2" Production Hole Section Hazard Mitigations Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Drill with oil based mud, maintain mud in specifications, use sufficient mud weight to hold back formations. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight to hold back formations. Abnormal Pore Pressure Pore pressure, fracture gradient prediction study, monitor for abnormal pressure indicators while drilling and tripping (pit levels, cuttings/cavings, gas trends). BOP installed and tested, well control trained personnel. Mitquq 1 Permit to Drill Rev1_20191030 - 29 - 01-Nov-19 0) Oil Search Attachment 5: Leak Off Test Procedure 1. Drill out shoe track, cement plus minimum of 20' of new formation. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurised mud balance; c. Confirm that mud weight -in is equal to mud weight -out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe. 4. Rig up high pressure lines as required to pump down the drill string with cement unit (side entry sub, TIW, lo-torque valve, etc.). Pressure test lines to above expected test pressure. a. Note: a high pressure, low volume pump is required - rig pumps are not suitable. b. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string (with the cement unit). 6. Verify the hole is filled up and close the BOP (annular or upper pipe ram). 7. Perform the LOT or FIT pumping at a constant rate of 0.25bbi/min. Record pump pressures at 0.25bbl increments. 8. Record and plot the volume pumped against pressure until leak -off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak -off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilise. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in -situ stress. c. If FIT skip step 9. 9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 11. If the pressure does not stabilise, this may be an indication of a system leak or a poor cement bond. 12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to establish the volume of mud lost to the formation. Top up and close the annulus valve between the casing and the previous casing string. 13. Open the BOP. Mitquq 1 Permit to Drill Rev1_20191030 - 30 - 01-Nov-19 Oil Search Attachment 6: Cement Summary Surface Casing Cement Casing Size 9-5/8" 40# L-80 BTC Surface Casing Lead Open hole volume + 500% excess in permafrost / 50% excess below ermafrost Basis Lead TOC Surface Tail Open hole volume + 50% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Spacer 60 bbls of 10.7 ppg Clean Spacer Total Cement Lead 526 bbls, 2953 cuft, 1130 sks of 11.0 ppg ArcticCem, Yield: 2.61 cuft/sk Volume Tail 48 bbls, 268 cuft, 227 sks 15.8 ppg Type 1/11— 1.18 cuft/sk Temp BHST 70' F Verification Method Cement returns to surface Notes Job will be mixed on the fly Swap to tail cement when lead cement is seen at surface Mitquq 1 Permit to Drill Rev1_20191030 - 31 - 01-Nov-19 Oil Search Attachment 7: Rig Fluid System Mitquq 1 Permit to Drill Rev1_20191030 - 32 - 01-Nov-19 1LM Z B z N8 W w N p O F G 3 j ^a � 00 T J W J IL =o V IL I I 1 1 1 w= of N Oco J - K m � H J NmO W O [ifm O�C-D r in M ff omO w N W Q ow� ® a W ;., Z Y IA v 0 m Q 3 Q ® � i a o ow= � °Ch W = ® m a a z 4v Yy iL � Y m N o � �y ® Q a J w 000 000 1 _ z � O 0 - zm d o _ a -o w � U 7 '�3 If1® ® ®® ® l5c � 000 000 3 O U O rn eD'ZOW-53[\�A`M)]\sJNWvxA53[\bu.a: Oil Search Attachment 8: Prognosed Formation Tops Mitquq-1 Deviated Prognosed Tops WD ft TVD(KB) ft TVDSS Uncertainty Range Pore Pressure (ppg) Prince Creek Fm 75 75.3 47.3 7.0 Base Permafrost 1525 1525 -1450 +/- 150ft TVD Middle Schrader Bluff 2075 2075 -2000 +/- 65ft TVD MCU 2410 2410 -2335 +/- 65ft TVD 8.6 Lower Schrader Bluff MFS 2550 2550 -2475 +/- 65ft TVD Tuluvak Formation 2627 2627 -2552 +/- 100ft TVD 9.9 Seabee Formation 3180 3127 -3080 +/- 100ft TVD 8.7 Nanushuk Formation 4275 4053 -3978 +/- 100ft TVD Nanushuk 9 Sandstone 4481 4174 -4099 +/- 120ft TVD 9.1 Nanushuk 8 5541 4782 -4707 +/- 150ft TVD Torok (Nan-6) 6431 5341 -5266 +/- 150ftTVD 8.8 HRZ 6920 5751 -5676 +/- 150ft TVD Kuparuk-C sandstone 7217 6028 -5953 +/- 175ft TVD 10.0 LCU 7317 6128 -6053 +/- 175ft TVD Alpine-C sandstone 7754 6558 -6483 +/- 200ft TVD Base Alpine-C sandstone 7820 6624 -6549 +/- 200ft TVD Nuiqsut sandstone 7847 6825 -6750 +/- 200ft TVD 9.9 TD 8250 7175 -7100 +/- 200ft TVD Mitquq 1 Permit to Drill Rev1_20191030 - 34 - 01-Nov-19 Oil Search Attachment 9: Pore Pressure Fracture Gradient Plot .e k R W, C Mitquq 1 Permit to Drill Rev1_20191030 - 35 - 01-Nov-19 11 l Oil Attachment 10: Independent 3Id Party Pore Pressure Fracture Gradient Plot Mitquq 1 Permit to Drill Rev1_20191030 - 36 - 01-Nov-19 Mitquq-1 ST1 PPFG High Case ppg ' Mitquq-1 o i x � ,t� �� PV Session: Mitquq V_ IUkb(€tj TNT ImsI w•. L 4Ed Equivalent Mudweight (ppg) calculated from KB 1 AvA ikon S_ Fracture pressures are calculated 1. a Matthews and Kelly. There are two because they relate to sand (yellow) and shale (brown). Hydrocarbon column heights have been incorporated for Nanushuk-9 Mitquq-1 ST1 PPFG Low Case ppg MItqUq-1 0 x PV Session: Mitquq TVD" (M) IWT, Equivalent Mudweight (ppg) calculated from KB .ikon Attachment 11: Well Schematic Mitquq 1 Pre -drill Well Schematic 16" Conductor 128' MD/TVD 0) Oil Search 0 Oil Search Updated Oct. 29" 2019 Surface Casing 9-5/8" 40# L80 BTC 12-Y4" Hole 2,475' MDITVD I i f I I I { I I I I I f I I I I � i 3-1/2" BHKA @ 2900' MD 12895' TVD 3-%>" 9.2# L-80 IBT ` —.: Sacrificial Tubing 8-1/2" OH 20' inclination TD: 8250' MD 17175' TVD Mitquq 1 Permit to Drill Rev1_20191030 - 39 - 01-Nov-19 (0) Search Attachment 12: Formation Evaluation Program 12-1/4" Surface Hole LWD Gamma Ray Resistivity Sonic Open Hole Wireline None Cased Hole Wireline None Mitquq 18-1/2" Production Hole Gamma Ray LWD Resistivity Sonic Density Neutron Conventional Core None Density Neutron Induction Resistivity Sonic Spectroscopy Open Hole Wireline* Spectral Gamma Ray Image Log NMR Sidewall Cores Formation Pressures Formation Samples Cased Hole Wireline* N/A Well Test* N/A * Logs and well test listed are for a success case discovery, formation evaluation program may be reduced in the event of a dry hole. Mitquq 1 Permit to Drill Rev1_20191030 - 40 - 01-Nov-19 Attachment 13: Wellhead Diagram mA T F&AALE allh W-1 Oil Search Pressure Control 16" x 9-5/8' x 7" x 4-1/2 x 3-1/2" 5110M MB-230 Multibawl Assembly, With M8-230 Upper Head and ME-230 Tubing Hanger and K Tubing B AT�UIEGRIH E S �GEr—p,,y Mitquq 1 Permit to Drill Rev120191030 - 41 - 01-Nov-19 0) Oil Search Attachment 14: Days vs. Depth Plot 0 W i 0 n in 0 S 4w SZ n Q V1 c 0 inQ c m r !� o 0 0 0 0 0 0 0 0 0 0 0 0 0 (OW 4) 43daO Mitquq 1 Permit to Drill Rev1_20191030 - 42 - 01-Nov-19 0 0 0 co Oil Search Attachment 15: Shallow Hazards Assessment Mitquq 1 Permit to Drill Rev1_20191030 - 43 - 01-Nov-19 ,1,01 Search MEtquq 1 and M'Itquq 1 ST1 Shallow Hazards Study [October 2019] Oil Search Limited Incorporated in Papua New Guinea ARBN 055 079 868 Contents 1. Executive Summary 2. Introduction 3. Overburden Stratigraphy 3.1. Permafrost (Prince Creek Formation) 3.2. Schrader Bluff Formation 3.3. Tuluvak Formation 3.4. Seabee Formation 4. Shallow Hazards Assessment 4.1. Gas Hydrates 4.2. Gas Mud Log Analysis and Casing Design 4.3. Log Analysis 4.4. Pore Pressure Fracture Gradient Prediction 4.5. Seismic Analysis 5. Conclusions Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 1. Executive Summary Oil Search Alaska intends to drill Mitquq 1 and Mitquq 1 ST1 during the 2019-2020 winter season. The two wellbores share the same wellbore down to the surface casing depth of 2400' tvdss. This is a depth corresponding to just above the Top Tuluvak. This report will refer to all shallow hazards associated with the surface to TD of 2400' tvdss as the Mitquq 1 shallow hazards. This document summarizes a comprehensive offset -well analysis to quantify shallow hazards at the Mitquq well locations. This study integrates offset well design, gas mud logs, formation pressure, petrophysical well logs and 3D seismic attributes. Near Mitquq 1 and ST1 the risk of encountering shallow gas is low. Three of the near offset wells have surface casing set above the Tuluvak and two of those did not encounter appreciable shallow gas; Placer 1 (7,920 ft), Colville 1 (14,256 ft), while one well did see an influx of gas at the Tuluvak level, Kookpuk 1 (21,648ft) — where the influx was stopped by increasing their mud weight to 10.5ppg. 3D seismic over Mitquq shows no structural trapping mechanism for shallow gas presence, and it is structurally downdip from the known Pikka Tuluvak gas accumulation. There is very low risk for shallow gas at Mitquq 1 based on all available datasets. 2. Introduction The Mitquq 1 well targets the Cretaceous Nanushuk, the Cretaceous Torok, the Jurassic Kuparuk C, and Jurassic Alpine C reservoirs. The Mitquq 1 ST1 is targeting the Cretaceous Nanushuk and the Cretaceous Torok formations. The proposed surface location for the Mitquq 1 and Mitquq 1 ST1 drill -site is east of the Pikka Unit at the following coordinates: Easting (ft) Northing (ft) Surface elevation (ft msl) 1599539.381 5970370.931 47.277' NAD83 State Plane Alaska State Plane 4 FIPS 5004 (US Feet) Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 3 VIL UA.RGN A.LA5KA LLG. 1C-NN31-11P X19-272)EXP. M- A -KW E Af.4- J•. _ AS,- E T i�JE Tt Y a CT€ON MtITGtl1Q 1 WELL PLAN «. ) 4=11 +6M t Oil Search �A .. <Y'E ?.c7i' uxi r T,--: ,'S w'/a 14'%MQ•JaI a_il`cr. Figure 1: Aerial photograph of the Mitquq surface location. Ten miles west of Mitquq, exploration and appraisal wells located along the Colville River have occasionally encountered shallow gas. In some wells, shallow gas has been liberated from gas hydrates associated with the permafrost (Pikka C). In other instances, shallow gas has been identified in the Schrader Bluff and Tuluvak Formations. Along the Pikka trend the Tuluvak Formation locally contains overpressured shallow gas (e.g. Qugruk 2, Qugruk 9, and Kookpuk 1). The shallow gas risk at Mitquq 1 is defined by this integrated study. There are three primary components included in this description; offset well completion design and mud logs, offset well logs and pressure data, and pore pressure fracture gradient prediction. The culmination of these analyses demonstrates the low risk for shallow gas at Mitquq 1. 3. Overburden Stratigraphy 3.1. Permafrost (Prince Creek to Upper Schrader Bluff Formations) The characterization and depth of permafrost near Mitquq is relatively constrained by offset wells. The depth range of base permafrost ranges from approximately 913 ft TVDSS in Pikka B to 1774 ft TVDSS in Palm-1. Permafrost is identified using resistivity and sonic logs (RT>40 ohm.m and DT<135 ps/ft). However, permafrost is more apparent in coarser grained sediments and this contact may be cryptic in shaly sands and shales. This lithologic overprint likely obscures the actual depth of permafrost in many wells. Permafrost is only identifiable in the Prince Creek and Middle Schrader Bluff Formations. At Mitquq 1 base permafrost is predicted at 1450 ft TVDSS +/-150 ft. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 4 (a) Oil Search r "I VTO Pf :0:6 0,: b Z%; ;;�Fj 1"xas; 1) A 2*0 W., t.,:A: I 01-No vlf*rxAK� 'M C". W4 144 k I 00 zyx 2 r; 'Zo 44 :::I'IS 7-4717-_ox $1 Vj C,4 IN ML LO Or- 12 - 71. 3. S. CD CQ S ilk" 6 CV P, 4 .. ......... IN tv CN Figure 2: Mitquq 1 offset wells with base permafrost picked from resistivity. Base permafrost occurs within the Upper Schrader bluff unit in the greater Mitquq area. N ■W..11 %W %F. I %.WL1 %AWI%Al V I I I%AV %,FI 9 %11 11 1%.411 %.P%PL 111 LI 1%0 t11 VLALVI I-IIL%ILA%l CAI %►CA M-011 1%1 L%.FFJ 11 WII I VVIUIIQ. %.P%Jl IL%JUI interval: 20I . Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 3.2. Schrader Bluff Formation In the greater Mitquq area, the Prince Creek Formation unconformably overlies the Upper member of the Schrader Bluff Formation. The Upper Schrader Bluff comprises fluvial influenced delta -top to delta -front facies versus the transgressive distal pro -deltaic Lower Schrader Bluff. The Middle Schrader Bluff includes multiple, coarsening -upward parasequence cycles with intercalated blocky sharp -based, fining -upward depositional packages. The Lower Schrader Bluff Formation is dominated by delta front and pro -delta mudstone and siltstone. The Lower Schrader Bluff is punctuated by a few ash -fall tuff beds, sporadically seen in offset wells. Tuffs can be identified by conspicuously high gamma ray response as well as mudlog descriptions. , tales ri t ii_l'I rG1r" W i�f?tIt r4l^+ F Upper 55chrader Muff t3asr3 Perrrto3le[:xst Middle Schrader Bluff s r,'Di } Ow Schrader Buff 'f; 1 Tuffs Tuff1 �Fi�Ce� t 's i Tuffs Tuff1I— , Top Nanusnfak Nanushuk 8 Figure 4, Mitquq 1 overburden stratigraphy from offset wells. 3.3. Tuluvak Formation .__ .UpW Schrader Bluff —=--Base Perawltrunt %iCU Tufft t_•.vr SChrasd�:r 811,fif Julu rak Is" Tuftl r' oTu€fl Top NanUshLP, Nan*huk 8 In the Mitquq area, the Tuluvak Formation was deposited in a distal delta -front environment and comprises a shale dominated lithology, with small coarsening upward sequences comprising mostly silt and thin sand stringers. Ash fall tuffs are described in most of the offset wells in regular frequency and have been marked on the logs using mudlog descriptions and gamma ray response. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 6 0 Oil Search 3.4. Seabee Formation The Seabee Formation comprises pro -delta mudstone and siltstone deposited in offshore shelf -slope and basin floor environments. The Seabee Formation stratigraphy includes several ash -fall tuffs that can be identified with gamma ray spikes and mudlog descriptions. 4. Shallow Hazards Assessment 4.1. Gas Hydrates Near the base of permafrost there is a risk of gas and/or gas hydrates. Base permafrost at Mitquq 1 is predicted at 1450 ft TVDSS +/-150 ft. The base permafrost will likely occur near the top of the Upper Schrader Bluff Formation in Mitquq 1. The permeable zone below the permafrost could be hydrocarbon bearing. This permeable zone in the Upper and Middle Schrader Bluff is likely to extend to approximately 2100 ft TVDSS. The absolute depth of permafrost and transitional zone will dictate the phase of any hydrocarbons present. The methane hydrate stability profile for Mitquq 1 has been calculated (Figure 5*) using the temperature profile calculated using offset well data (Figure 6). From this calculation, the hydrate stability zone is expected to exist from Base Permafrost (-1450' tvdss) to within the Tuluvak at -2650 tvdss. Below the stability zone there is a risk of free gas where methane hydrate thaws and gas is liberated. Offset wells around Mitquq show very poor reservoir development at this free gas level, indicating the storage capacity for both methane hydrates, and its associated free gas, is low. Methane Hyeirate Stability Profile Calculated for Mitclug �` [�(�y a {I LJ� ° iL`i]I LACER i J d� �eTJ � I V D] f t! ! J rrrww.'�irtha?•��• t oyrsra'T ��$i s.a . . ,, !ce Warer E 5 k ... .. 5 ....... 7 N Free Gas and _ Permafrost Water LVater fce/iydrate Plus j w Gas hydrate s r �+ {� r } 1,% 2/ t7 tGl bll�l�y R f f zone P, �r ,4'/ h Base Hydrate Gas Hydrate S StabYlty Zone Q L t s o f ru R C, l as �J(• ;f Fa?nnagratura(Rrrpraaz Fabranhaitl - Figure 5: Mitquq 1 hydrate stability zone calculation & offset well correlation of potential Schrader Bluff gas hydrates / Tuluvak free gas zone. Assumed temperature gradient beneath base permafrost = 2.60F/100' *Calculation from Kvenvolden, 1993. Gas hydrates — Geological Perspective and Global Change. Review of Geophysics. P. 173-187, Vol.31 Issue 2. May, 1993. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 7 (1) Oil Search Mitquq 1 Estimated Temperature Profile Temperature (°F) 0 25 50 75 100 125 150 175 200 100 y =-75.606x + 969.39 -900 '• Base Permafrost -1900 Cli-2900 ••.., y =-37.736x - 242.45 U) 0 > -3900 m, C -4900 '•• -5900 -6900 -7900 Figure 6. Temperature plot and thermal gradient derived from offset wells KRU 3S-15, Tarn 2L-301, Placer 1, Ataruq 2, Qugruk 1. Permafrost temperature profile derived from data in Collett, T.S. et. al., 1988. Subsurface Temperatures and Gradients on the North Slope, Alaska. US Geological Survey, USMS 019024. 4.2. Gas Mud Log Analysis and Casing Design Gas in the Tuluvak Formation is a primary focus for shallow hazards assessment across the Pikka field. This concern has arisen after the gas -kick event at Qugruk 2. In the Pikka area, the Tuluvak is locally charged with overpressured gas. The Pikka Tuluvak gas trap is a seismically mapped 4-way dip closure (Figure 7). The Mitquq 1 well is located approximately 10 miles east of the Tuluvak overpressured gas accumulation at Pikka. Offset well analysis shows that the Tuluvak near Mitquq 1 does not contain the overpressured gas observed in Pikka. Offset wells demonstrate a very low risk for any Tuluvak gas at the Mitquq 1 location. Offset wells surrounding Mitquq have all topset the Tuluvak Formation (Nearest wells: Placer 1, Placer 2, Colville 1, Ataruq 2, Kookpuk 1, and Palm), with the exception of the Qugruk 2 well. The Tuluvak at Palm 1, Colville 1, and Kookpuk are all at a similar sub -sea depth as Mitquq 1. The Tuluvak at Placer 1, Placer 2, and Placer 3 are slightly up -dip of Mitquq 1. In Placer 1, Placer 2, Placer 3, Colville 1, Ataruq 2, and Palm 1, the Tuluvak Formation was drilled with mud weights ranging from 9.6 - 10.3 ppg without incident. Kookpuk 1 was drilled with a 9.1 ppg through the Tuluvak and had a gas flow that was eventually contained by increasing the mud weight to 10.5 ppg. Qugruk 2 did not top -set the Tuluvak with surface casing, and had a blow out to surface while drilling through the Tuluvak with a 9.1 ppg mud weight. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 8 0 0 0 e, i� (y V? 18f Q0 Oil Search 1552000 1560000 156800u 15 6000 1584000 1592000 1600000 1608000 1618000 1624000 1 Pala 1 9.6# No issues { 1, ,.. �3 *. aY"Won :PI, c5 dWSf°i M tG `'P3st ail e95: �A � QB C) 3gU 1G F k�xa iJ as2i kr, 9.1 # Gas flow 19.5# stopped flaw - ,ti 155200 i5eowo 15680M 157,6000 1584000 1592= 160=0 1608000 1616000 1624000 Figure 7: Map of Top Tuluvak Gas Sand showing outline of gas accumulation on the 4-way dip closure over Pikka encountered in Qugruk 2. Below are the mudlog summaries for the nearest offset wells to Mitquq. The best analogs for overlying stratigraphy and depth to Tuluvak are Placer 1, Placer 2, Placer 3, Colville 1, Palm 1, and Kookpuk 1. Placer 1 and 2 are directly adjacent to one another, and the analysis of those wells is so similar, only Placer 1 is summarized in this report. Particular attention has been paid to the mud weights and gas response in each of the wells as they drilled through the Tuluvak. Reservoir development is also noted, as the presence of a reservoir enhances the likelihood of encountering a gas event. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 9 Placer 1 is the nearest offset well to Mitquq 1, located 1 mile to the west. It is situated structurally up -dip from Mitquq 1 and showed minimal gas mud cut beyond background through the Tuluvak Formation. Placer 1 intersected the Tuluvak from approximately 3000 — 3600 ft MD. The max values of gas mud in the Tuluvak Formation were —100 gas units which equates to approximately 2%. The Tuluvak was drilled with 10.1 ppg mud with no gas influx events. These data suggest a low residual gas saturation at Placer 1. Reservoir development is also poor in the Placer 1 Tuluvak, suggesting a small chance of encountering thick, porous sandstone in this area. ,..:} Yb: < i".,.. �2 ., �i8 - a ;,> ^ i h �:., ♦ ,. ... 4 s « t t ;.��i %i QL %,, P .. � Y M .7 f t'!'Y'• 4NOW �� - -'V. Mx 4.1P:.4P E, .., 3'%f t I t e:"�« s+...b• +•s aF.rnr�rs.c>'r, ��p �• blb vA QaiVU/:A)w'p, ,.�� Top Tuluvak fw{cN.SnvafB: .c.Y_v410K tie b -3016 MD s.H.. s! gas %) ��y • i� 412 4..,. . 5 7 ... otfn+a +`+ wn •tix A lMAi P'rihaNb f 7..f q ^i!"+t' /.• h.' W r.i1gN'N # K'4 'd! �. • �,.# +. ,4..; i� e tli ir".35'"`°� 16e h6 t•� �4 r Lktr Schr�Qr @�1ft ........_._._._._.__._ ?•re +f. fr'gaq�. t 'y. ([`9{' I. !y i w. 4 f 'f:. .r'4 oiiT: f� 4 4 �.�. }� ± L�t 4 � 1 • Fw� may` 4 tft +a ! 9 #, 3 i 1 41 ti 4. 1+1 E xro y.ixn y '`"S'P t i' 1 `5 /okW•�x415C ...t { 1 3 "`''�--mot.,•4 ,�s� has units%' 1 ° ". � � ..- { } P-r A e. �-' r�r i b 1 4 x� .• +• IN, t fj vox 4'4 h4Y�rc.. .. 4. fY -Y t"< �ygE r+ 4 4�A i�r y A�4-f- {s tot t A•+efn�b'g'° . �. f. ,f..t�.. � �,�,Nl 4 7i 1 A'✓. %�'. •^ro-Mj. Aev..H 4p4tA0.kt .� d^ {...r.. •L.r. 11 � fw y i , �✓ �ury '-Wk'b' Y�, y, .{') .1 L w�� ti a 1' �w v®e•' SY IN' ;fbf tyy i �`P'.. I{ ( 2'•'.;.SNY .. ✓rf»:D'M �ti UP Figure 8: Placer 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 10 Rpm Colville 1 intersected the Tuluvak from approximately 2590 — 3050 ft TVDSS; similar to the prognosed depth in Mitquq 1. The max value of gas mud in the Tuluvak Formation was 55 gas units which equates to approximately 1 %. The Tuluvak was drilled with 9.6 ppg mud with no gas influx events. These data suggest very low residual gas saturation at Colville 1. Residual oil saturation likely exists in these sands, as they say oil shows in cuttings, albeit in a low percentage. Reservoir development is fairly poor throughout the Tuluvak Formation in Colville 1, with a few minor siltstones at the top of the formation in the interval where the weak oil shows were seen. Figure 9: Colville 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 11 Palm 1 intersects the Tuluvak from approximately 2780 — 3270 ft MD. The Tuluvak at Palm 1 is situated structurally below the prognosed Tuluvak at Mitquq 1. Palm 1 registered up to 25 gas units in the Tuluvak Formation while drilling with approximately 9.6 ppg mud weight. This is not appreciably above the background gas levels being collected above and below this interval. Minor oil shows were seen at the top of the Tuluvak, in the few siltstones that exist. Reservoir development is overall very poor in this well, with a few minor siltstones at the top and middle of the formation. Resistivity goes down to less than 2 ohm.m through the cleaner sands, indicating they are wet. This data suggests that the Tuluvak is not gas bearing at Palm 1. - --------- .tik f! t 4 i y. t wYi .x i► >i SMt •,.�, a •aa a+.w i+:w WA P-w-%ear wa. t 9 awo �: G, 4 !' ri t •,.._ 'y as +ee A . f3_� ji{ ��ms'M enr„.Faea tsesli t � � g�rt� ....l�vL.✓M'✓�r �a d PfetbrM.JI�MYOP�h! RPM :�. ^� ',„ Top Tul u va 20 gas units (<100 278Q k IDr m MID ; � i 644 AM 1M6{ ntl 9 ;''� r■• � ?�fw�.e.'Scva'ee�i.%Q'°rirw"`ia MCU _'nr Schxacw Bluff r : >Ti r i( } . � � 1 4d l 8J6Li�llHig'i+Y4•iG�v j 4f Io sa,K h. .aea.A+.:H+•.o 7, wn/VTTR m9M.M� NA+ CIA - 6 t ! y orrt•a+aAcl+�s+ rrramm. xj• t i r i . .. �� - � .......a.. _ :,..�..... 'yS _ '�'"f:Vr'+•nf�i'%i�•`�' f f- •. , 3 ' a.a--r• ... .... . , .,�. Ell ' F aro�. ,a•rxeeY�rax' 20 gay �11-tltS� Qio ' 1 3 � „'� � � i _�_,__... "�,w�kix°'i+�cew°0; :✓�"a3°�i' tZ t `'-, „�-�' .. "�" 3 r ... •. ' t _ ivenns.aAr�s'�xa.'i roe..,, Figure 10: Palm 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 12 (0) Oil Search Kookpuk 1 intersects the Tuluvak from approximately 2645 — 3150 ft MD. The Tuluvak at Kookpuk 1 is situated at structurally the same depth as the prognosed Tuluvak at Mitquq 1. Kookpuk 1 registered a gas flow event at the Top Tuluvak of up to 600 units (12%) while drilling with 9.1 ppg mud weight. Mud weight was then increased to 10.6 ppg and the flowing stopped and was controlled for the drilling of the rest of the formation. Well log analysis indicates there is a small sand at the top of the Tuluvak that is hydrocarbon bearing (Figure 12) with a thin 5' interval calculating 50% hydrocarbon staturation. The key difference between the Kookpuk 1 area and the wells closer to Mitquq appear to be the existence of a good top -sealing shale. Kookpuk-1 has an excellent sealing shale in the Lower Shcrader Bluff, and this shale exists over the Pikka Unit as well, which may be contributing to the Tuluvak's ability to hold a hydrocarbon column. Placer 1 and Colville 1 do not have this shale (Figure 13) so the top sealing capacity in the Mitquq area is likely quite low. Kookpuk 1 shows that while thin low -saturation hydrocarbon bearing sands exist in the Tuluvak, they are easily controlled by appropriate mud weights. H! Ntkt� u wr 13rhradpr Bluff , Tullwak sealb ee a, .6 _ lob 441k%?'.LY .4 CP✓'t�t ♦q�♦q r x h Y.w^»wbmtaVe«e rE« •F��Uu, war _iPwikb w5iki�76wi Mr .. .. S t Figure 11: Kookpuk 1 Tuluvak Formation gas mud log summary. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 13 (1) Oil Search Well, KOOKPUK 1 Top Uiu V \\ C ,"4'• � i t9-i..:5� i �+r '� S i.1G1 k .rRL t .i n ww Mlf� Z! s 3 All gyp. hyr t� J F. a; r, Figure 12: Kookpuk 1 well log analysis showing a thin hydrocarbon bearing sandstone in the top of the Tuluvak formation. .......... ---- , ., ... ir, �} �.,, ,..,�, w....r mv�s "YfY - "w i'S'. .x*• iY7S Y"P+' r.R-v'-Y°"r'1'CR°� �. n ..,v •. V tr �M\\\�; n \`. i" k • y; ti 23rt! o i a ae ; { ` #2=. r { d $ r r ` r , d, F ? c 20CL _ a� 3i 1f'/, S_ , , i � r vvyy loll i a n 9 wti .o. i F , 3 xi y Figure 13: Stratigraphic cross section hung at the Top Tuluvak from Qugruk 2 in Pikka Field over to the closest offsets to Mitquq 1 showing the thickness of the shale sealing the Tuluvak over the Pikka and Kookpuk 1 gas accumulation does not exist in the Mitquq area. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 14 4.3. Log Analysis Drilling and mud log data suggest that the Tuluvak Formation closest Mitquq 1 does not contain significant gas. The low levels of observed mud gas probably reflect faint, residual gas saturation. Petrophysical logs are consistent with this interpretation. In the up -dip position at Placer 1 showed the highest gas mud cut (-1 %) while the Colville 1 well showed less than 1 % gas cut mud at an equivalent structural position to Mitquq 1. Careful inspection of cross -over between Neutron Porosity and Bulk Density logs shows there is no apparent cross over in any of the nearby offset wells. Kookpuk 1 does show hydrocarbon bearing sandstone (less than 5' thick) at the top of the Tuluvak, beneath a tight streak. There was no neutron log obtained in the well, so crossover could not be determined. 4.4. Pore Pressure Fracture Gradient Prediction Pore pressure and fracture gradient prediction for Mitquq 1 is based on several analogue wells. For the Tuluvak, a gas gradient is extrapolated to match the Qugruk 9 Tuluvak pressure. The Mitquq 1 Tuluvak pore pressure is further constrained by mud weights in the near offset wells Kookpuk 1, Placer 1, Placer 2, Placer 3, Colville 1, and Palm 1. Nanushuk pressures were derived from MDT pressures samples taken in the Pikka field at Qugruk 3, Qugruk 9, Qugruk 8. Torok pressures were derived from offset well mud weights and MDT pressures from Qugruk 1, Qugruk 4, and Qugruk 9A. Kuparuk C pressures derived from offset well mud weights and Placer 1, 3, and Qugruk 1 MDT data. Alpine C pressures derived from offset well mud weights as wel las Q9A MDT pressures. Nuiqsut pressures derived from offset well mud weights and Fiord 5 PB1, Oooguruk 1, Qugruk 1, Ivik 1 MDT and RFT data. Pre -Drill Scoping M.ltquq PPFG Model DRAFT iv.21 Sept. 26, 201.9 0 Oil Search Figure 14: Mitquq 1 pore pressure and fracture gradient prediction expressed in pounds per gallon equivalent. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 15 Redacted M. Guhl 5/6/2022 (0) Oil Search 5. Conclusions The Mitquq 1 overburden comprises two distinct permeable zones; the Schrader Bluff Formation and the Tuluvak Formation. There is a low risk of low-pressure gas or gas hydrates below permafrost in the Schrader Bluff. The risk of gas in the Tuluvak is also low. All offset well data strongly suggest that the Tuluvak at Mitquq 1 is likely to contain water or low saturation gas which can be controlled with appropriate mud weights. This interpretation is based on the following data and interpretation. 1. Casing Design — The seven nearest offset wells have surface casing set above the Tuluvak Formation; Placer 1, Placer 3, Colville 1, Palm 1, Kookpuk 1, and Ataruq 2. Mitquq 1 will also top set the Tuluvak with surface casing. 2. Mud Logs — Gas mud cut from the nearest offset wells showed a maximum of 1 % gas cut at Placer 1, Palm 1, Colville 1. Kookpuk 1 had a gas flow event with a 30% gas cut at the top Tuluvak, while drilling with a low mud weight. 3. Mud Weight — The Tuluvak Formation was drilled with mud weights ranging from 9.1 to 10.3 ppg mud weight in six offset wells; Placer 1, Placer 2, Placer 3, Colville 1, Palm 1, Kookpuk 1, Ataruq 2. Only Kookpuk 1 had a gas flow event, and it was drilling with the lowest mud weight of the group, at 9.1 ppg. All other wells were able to control the Tuluvak with a mud weight equal to or greater than 9.6. 4. Trapping Mechanism — There is no structural trapping mechanism mapped in the area surrounding Mitquq 1. There is nearly monoclinal dip off the 4-way dip closure across the Pikka Unit, where the gas accumulation exists. Also the sub -regional top seal that appears to be across the gas accumulation in Pikka and Kookpuk 1 does not appear to exist in the Mitquq 1 area, as it pinches out W to WSW of Mitquq. 5. Seismic Mapping — Seismic maps of the Tuluvak Formation show the Mitquq area is off structure to the main gas accumulation along the Tuluvak 4-way dip closure over the Pikka Unit. Mitquq 1 and Mitquq 1 ST1 Shallow Hazards - 30 September 2019 17 Kick Tolerance Calculations guy schwartz 5/16/2019 input in yellow areas only Mitquq 1 219-150 MW (Ppg) 11 ppg LOT/FIT (ppg) 13.2 TVD Casing Shoe (ft) 5954 ft TVD If a formation deeper then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 7175 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 6.125 inches Drill Pipe OD (in) 5 inches BHA OD (in) 4.75 inches Lenth of BHA (ft) 250 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.0122 bbl/ft Annular Capacity between OH and DP 0.0145 bbl/ft Annular Capacity between OH and BHA 681.1376 psi Maximum Allowable Surface Pressure 186.55 psi Underbalance due to Kick Intensity 494.5876 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 1047.9 feet Volume of Gas Kick 15.2 bbl CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 12.7 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 12.1 bbl CASE 2 depth Conversion KICK TOLERANCE: 12.1 bbl Compare Cr SF 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume Kick Tolerance Calculations guy schwartz 5/16/2019 input in yellow areas only Mitquq 1 219-150 MW (ppg) 10.7 ppg LOT/FIT (ppg) 13.2 A C) TVD Casing Shoe (ft) 2475 ft TVD If a formation deeper then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 5954 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 8.5 inches Drill Pipe OD (in) 5 inches BHA OD (in) 6.75 inches Lenth of BHA (ft) 250 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.0459 bbl/ft Annular Capacity between OH and DP 0.0259 bbl/ft Annular Capacity between OH and BHA 321.75 psi Maximum Allowable Surface Pressure 154.804 psi Underbalance due to Kick Intensity 166.946 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 365.8 feet Volume of Gas Kick 9.5 bbl CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 16.8 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 8.2 bbl CASE 2 depth Conversion KICK TOLERANCE: 8.2 bbl Compare CASE 1 and w:A4i_ < volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume Schwartz, Guy L (CED) From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Tuesday, November 26, 2019 3:05 PM To: Schwartz, Guy L (CED) Cc: Davis, Rachel; Tirpack, Robert; Davies, Stephen F (CED) Subject: Oil Search Mitquq 1 PTD Attachments: Mitquq 1 Drilling Program Overview Rev 1 20191126.docx Follow Up Flag: Follow up Flag Status: Flagged Guy, As discussed on the phone today, over the past couple of weeks OSA has taken a close look at the pore pressure potential for the Kuparuk-C formation that we plan to drill on the Mitquq 1 wellbore. We now believe most likely pore pressure for the Kuparuk-C is 10.Oppg with the potential high side case at 11.7ppg due to offset injection at—20,000' away. I have attached a revised drilling program overview to outline our new plan to mitigate the potential for over -pressured Kuparuk. In addition, there are a couple other changes based on the feedback for the Stirrup PTD. Below is a summary of the key updates to the Mitquq 1 PTD: 1) Pressure test 7" intermediate casing prior to drilling out rather than on plug bump 2) 6-1/8" production hole drilling a. Drill out 7" casing and through Kuparuk formation with 11.7ppg mud weight b. POOH to 7" casing shoe and perform inflow test on Kuparuk formation to 10.5ppg EMW c. If testis successful, displace well to 11.0ppg mud weight d. Drill ahead to planned TD 3) LOT / FIT information: a. 9-5/8" surface casing shoe: 12.8 ppg minimum LOT required based on a swabbed kick from the Torok in the 8-1/2" hole section b. 7" intermediate casing shoe: 13.2 ppg minimum LOT required to yield infinite kick tolerance in the 6-1/8" hole section Please let me know if you have any questions, or require any additional information. Thanks, Garret GARRET STAUDINGER I SENIOR DRILLING ENGINEER 1 OIL SEARCH LIMITED PO Box 240927, Anchorage, AK 99524-0927 Mob: +1 907 440 6892 I Tel: +1 907 375 4666 Email: garret.staudinger(cDoilsearch.com I Web: www.oilsearch.com ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. 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Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back I Frnrsh Cancel I_ _ Help _ _. _ .__ TRANSMITTAL LETTER CHECKLIST P WELL NAME: HItqaq PTD: 2 l - l ' I LrD O Development Service V6 Exploratory _ Stratigraphic Test Non -Conventional FIELD: l 0-V%L+ 10h 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 I U. d to m q ( v`—� Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, JPer 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