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219-151
LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 10 files Mitquq 1 ST1 (50-103-20808-0100) x 2001222GA_Santos_Limited_Mitquq-1 _ST01_XRD-2023-OCT- 23.xlsx x 2001222GB_Mitquq-1 ST01_SEM_11-Dec-2023.pdf x 2001222GB_Santos Limited_Mitquq-1 ST01_XRD-2023-OCT- 30.xlsx x 2001222GC_Santos Limited_Mitquq-1 ST01_XRD-2023-DEC- 15.xlsx x 202001222_Mitquq-1 ST01_HPMI_18-Dec-2023.xlsx x 202300415_Oil Search (Mitquq-1 ST1) - M-S TCS, M-C, ULT Summary_25-May-2023 v2.xlsx x 202300415_Oil Search (Mitquq-1 ST1) - Sample Photos Spreadsheet_26-May-2023.xlsx x 20231229 2001222_Mitquq-1 ST01_PDP_21-Dec-2023.xlsx x 2300415_Mitquq-1_ST01_(Geo_Mechanics)_Plug_CT_31- March-2023.pdf x Vertical Permeability - Mitquq-1 ST01_RCA_14-Jun-23.xlsx Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh shannon.koh@santos.com DATE: 1/16/2024 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 PTD: 219-151 T38270 1/16/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.16 10:38:54 -09'00' LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 7 files Mitquq 1 ST1 (50-103-20808-0100) #70 Mitquq ST1 4305.5 Ash_AgeCalcML_DetailedDataTable #70 Mitquq ST1 4305.5 Ash_AgeCalcML_DataTable 4304.5'_concordia-plot 4304.5'_discordia-line Background data- Lease_et_al_2022 Lease_et_al_2022_Supp TableS1-one-page_new 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: 2/15/2023 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: LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 2 files Mitquq 1 ST1 (50-103-20808-0100) Mitquq_1ST1_Flow_Test_Samples_Validation_Tests_202002530- 5022098341 Mitquq_1ST1_Flow_Test_Samples_Validation_Tests_202002530- 5022098341 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: 12/2/2022 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: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c)Public as of 5/2/2022 By Meredith Guhl at 1:25 pm, Dec 02, 2022 219-151 T37355 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.02 13:27:21 -09'00' 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. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:Mudlog,NGI/SS/ZAIT,CMR/HNGS/PEX/NEXT,XPT,ORA,GR/USITL,GR/VSI-4,GR/VSI-20,GR/RES/GR/SONICYesYesYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC5/14/2020 Electronic File: Job44674.xls33121EDDigital DataC5/14/2020 Electronic File: Job44375_Mitquq 1 ST1.xls33121EDDigital DataC5/14/2020 Electronic File: ROSL-200401-002 Mitquq 1 ST1 4-1-20 4,438.67ft AS0460.xls33121EDDigital DataC5/14/2020 Electronic File: ROSL-200303-001 Mitquq 1 ST1 55GEO 4381.80ft.xls33121EDDigital DataC5/14/2020 Electronic File: ROSL-200303-001 Mitquq 1 ST1 55GEO 4381ft.xls33121EDDigital DataC5/14/2020 Electronic File: ROSL-200303-002 Mitquq 1 ST1 91GEO 4413ft.xls33121EDDigital DataC5/14/2020 Electronic File: ROSL-200303-003 Mitquq 1 ST1 275GEO 4590ft.xls33121EDDigital DataC5/14/2020 Electronic File: ROSL-200303-004 Mitquq 1 ST1 344GEO 4651ft.xls33121EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ST1 PVT Validation Final Report.xlsx33121EDDigital DataC5/14/2020 Electronic File: Alaska Field Coring Report Mitquq 1 ST1 Core 1.pdf33122EDDigital DataC5/14/2020 Electronic File: Alaska Field Coring Report Mitquq 1 ST1 Core 2.pdf33122EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ST1 Core Data.docx33122EDDigital DataC5/14/2020 Electronic File: Mitquq Coring End of Well Report.pdf33122EDDigital DataC5/14/2020 Electronic File: 4291.0-4309.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4291.0-4309.0__c1.jpg33122EDDigital DataThursday, December 17, 2020AOGCCPage 1 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: 4309.0-4327.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4309.0-4327.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4327.0-4345.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4327.0-4345.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4345.0-4363.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4345.0-4363.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4363.0-4381.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4363.0-4381.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4381.0-4399.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4381.0-4399.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4399.0-4417.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4399.0-4417.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4417.0-4435.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4417.0-4435.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4435.0-4453.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4435.0-4453.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4453.0-4471.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4453.0-4471.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4471.0-4472.7.jpg33122EDDigital DataC5/14/2020 Electronic File: 4471.0-4472.7uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4472.7-4490.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4472.7-4490.0__c2.jpg33122EDDigital DataC5/14/2020 Electronic File: 4490.0-4508.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4490.0-4508.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4508.0-4526.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4508.0-4526.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4526.0-4544.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4526.0-4544.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4544.0-4562.0.jpg33122EDDigital DataThursday, December 17, 2020AOGCCPage 2 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: 4544.0-4562.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4562.0-4580.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4562.0-4580.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4580.0-4598.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4580.0-4598.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4598.0-4616.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4598.0-4616.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4616.0-4634.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4616.0-4634.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4634.0-4652.0.jpg33122EDDigital DataC5/14/2020 Electronic File: 4634.0-4652.0uv.jpg33122EDDigital DataC5/14/2020 Electronic File: 4652.0-4653.9.jpg33122EDDigital DataC5/14/2020 Electronic File: 4652.0-4653.9uv.jpg33122EDDigital DataC5/14/2020150 5250 Electronic Data Set, Filename: Mitquq_1_ST1_DMD_R1-3_5250ft.las33123EDDigital DataC5/14/202043826 43830 Electronic Data Set, Filename: Mitquq_1_ST1_DMT_R01.las33123EDDigital DataC5/14/202043867 43872 Electronic Data Set, Filename: Mitquq_1_ST1_DMT_R02.las33123EDDigital DataC5/14/202043873 43876 Electronic Data Set, Filename: Mitquq_1_ST1_DMT_R03.las33123EDDigital DataC5/14/2020248 5250 Electronic Data Set, Filename: Mitquq_1_ST1_LWD_R1-3_5250ft_RT.las33123EDDigital DataC5/14/202094 5250 Electronic Data Set, Filename: Mitquq_1_ST1_LWD_R1-3_5250ft.las33123EDDigital DataC5/14/20202310 4205 Electronic Data Set, Filename: Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft.las33123EDDigital DataC5/14/20204190 4480 Electronic Data Set, Filename: Mitquq_1ST1_R8_8.5in_sonicVISION675_DTCO_4190-4480ft.las33123EDDigital DataC5/14/2020 Electronic File: Mitquq SLB DD EOWR.pdf33123EDDigital DataThursday, December 17, 2020AOGCCPage 3 of 26,Mitquq_1_ST1_LWD_R1-3_5250ft.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: Mitquq_1_ST1_LWD_RM_5250ft.dlis33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_LWD_RM_5250ft.html33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft.dlis33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_R8_8.5in_sonicVISION675_DTCO_4190-4480ft.dlis33123EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_EOW.doc33123EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_EOW.pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_DMD_R1-3_5250ft.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_DMT_R01.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_DMT_R02.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_DMT_R03.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_VISION_Sonic_2MD.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_VISION_Sonic_2TVD.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_VISION_Sonic_5MD.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_VISION_Sonic_5TVD.Pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft.pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft_QC_Rt_vs_Rm.pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_R8_8.5in_sonicVISION675_DTCO_4190-4480ft.pdf33123EDDigital DataThursday, December 17, 2020AOGCCPage 4 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: Mitquq 1 ST1 ASP Final Survey - NAD27.pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ST1 ASP Final Survey - NAD27.xlsx33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_ASP Final Survey - NAD27.pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_ASP Final Survey - NAD27.xlsx33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_ASP Final Survey - NAD83.pdf33123EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_ASP Final Survey - NAD83.xlsx33123EDDigital DataC5/14/20205208 27 Electronic Data Set, Filename: Mitquq 1ST1_Run_3A_NGI_MAST_ZAIT_CAL.las33124EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1_Run_3A_NGI_MAST_ZAIT_CAL.dlis33124EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3A_5in_MSIP_15Feb20.Pdf33124EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3A_5in_NGI_15Feb20.Pdf33124EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3A_5in_ZAIT_15Feb20.Pdf33124EDDigital DataC5/14/20204659 2338 Electronic Data Set, Filename: Mitquq_1ST1_Run 3B_NEXT-PEX-HNGS-CMR_Repeat_Pass.las33125EDDigital DataC5/14/20205213 4040 Electronic Data Set, Filename: Mitquq_1ST1_Run_3B_NEXT-PEX-HNGS-CMR_Main_Pass.las33125EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_Run_3B_NEXT-PEX-HNGS-CMR_Main_Pass.dlis33125EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_Run_3B_NEXT-PEX-HNGS-CMR_Repeat_Pass_.dlis33125EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3B_5in_CMR_15Feb20.Pdf33125EDDigital DataThursday, December 17, 2020AOGCCPage 5 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3B_5in_HNGS_15Feb20.Pdf33125EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3B_5in_NEXT_15Feb20.Pdf33125EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3B_5in_PEX_15Feb20.Pdf33125EDDigital DataC5/14/20200 191 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3CSta055_XPT.las33126EDDigital DataC5/14/20200 211 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta001_XPT.las33126EDDigital DataC5/14/20200 276 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta002_XPT.las33126EDDigital DataC5/14/20200 739 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta003_XPT.las33126EDDigital DataC5/14/20200 1025 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta004_XPT.las33126EDDigital DataC5/14/20200 446 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta005_XPT.las33126EDDigital DataC5/14/20200 1363 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta006_XPT.las33126EDDigital DataC5/14/20200 1621 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta007_XPT.las33126EDDigital DataC5/14/20200 475 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta008_XPT.las33126EDDigital DataC5/14/20200 1872 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta009_XPT.las33126EDDigital DataThursday, December 17, 2020AOGCCPage 6 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/20200 747 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta010_XPT.las33126EDDigital DataC5/14/20200 818 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta011_XPT.las33126EDDigital DataC5/14/20200 779 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta012_XPT.las33126EDDigital DataC5/14/20200 371 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta013_XPT.las33126EDDigital DataC5/14/20200 748 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta014_XPT.las33126EDDigital DataC5/14/20200 322 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta015_XPT.las33126EDDigital DataC5/14/20200 1155 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta016_XPT.las33126EDDigital DataC5/14/20200 502 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta017_XPT.las33126EDDigital DataC5/14/20200 1636 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta018_XPT.las33126EDDigital DataC5/14/20200 1486 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta019_XPT.las33126EDDigital DataC5/14/20200 459 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta020_XPT.las33126EDDigital DataC5/14/20200 2708 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta021_XPT.las33126EDDigital DataC5/14/20200 74 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta022_XPT.las33126EDDigital DataThursday, December 17, 2020AOGCCPage 7 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/20200 1099 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta023_XPT.las33126EDDigital DataC5/14/20200 1030 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta024_XPT.las33126EDDigital DataC5/14/20200 1409 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta025_XPT.las33126EDDigital DataC5/14/20200 2182 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta026_XPT.las33126EDDigital DataC5/14/20200 1280 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta027_XPT.las33126EDDigital DataC5/14/20200 316 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta028_XPT.las33126EDDigital DataC5/14/20200 1013 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta029_XPT.las33126EDDigital DataC5/14/20200 2385 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta030_XPT.las33126EDDigital DataC5/14/20200 364 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta031_XPT.las33126EDDigital DataC5/14/20200 259 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta032_XPT.las33126EDDigital DataC5/14/20200 2310 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta033_XPT.las33126EDDigital DataC5/14/20200 306 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta034_XPT.las33126EDDigital DataC5/14/20200 1642 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta035_XPT.las33126EDDigital DataThursday, December 17, 2020AOGCCPage 8 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/20200 2769 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta036_XPT.las33126EDDigital DataC5/14/20200 897 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta037_XPT.las33126EDDigital DataC5/14/20200 2130 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta038_XPT.las33126EDDigital DataC5/14/20200 186 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta039_XPT.las33126EDDigital DataC5/14/20200 305 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta040_XPT.las33126EDDigital DataC5/14/20200 1611 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta041_XPT.las33126EDDigital DataC5/14/20200 1758 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta042_XPT.las33126EDDigital DataC5/14/20200 1280 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta043_XPT.las33126EDDigital DataC5/14/20200 867 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta044_XPT.las33126EDDigital DataC5/14/20200 21 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta045_XPT.las33126EDDigital DataC5/14/20200 1578 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta046_XPT.las33126EDDigital DataC5/14/20200 162 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta047_XPT.las33126EDDigital DataC5/14/20200 255 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta048_XPT.las33126EDDigital DataThursday, December 17, 2020AOGCCPage 9 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/20200 1593 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta049_XPT.las33126EDDigital DataC5/14/20200 21 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta050_XPT.las33126EDDigital DataC5/14/20200 170 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta051_XPT.las33126EDDigital DataC5/14/20200 1203 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta052_XPT.las33126EDDigital DataC5/14/20200 986 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta053_XPT.las33126EDDigital DataC5/14/20200 221 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3C_Sta054_XPT.las33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_5in_XPT_15Feb20.pdf33126EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3C_Sta006_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3C_Sta010_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3C_Sta012_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta001_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta002_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta003_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta004_XPT.dlis33126EDDigital DataThursday, December 17, 2020AOGCCPage 10 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta005_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta007_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta008_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta009_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta011_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta013_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta014_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta016_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta018_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta020_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta022_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta024_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta025_XPT.dlis33126EDDigital DataThursday, December 17, 2020AOGCCPage 11 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta026_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta027_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta028_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta029_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta030_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta031_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta032_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta033_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta034_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta035_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta036_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta037_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta038_XPT.dlis33126EDDigital DataThursday, December 17, 2020AOGCCPage 12 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta039_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta040_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta041_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta042_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta043_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta044_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta045_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta046_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta047_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta048_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta049_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta050_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta051_XPT.dlis33126EDDigital DataThursday, December 17, 2020AOGCCPage 13 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta052_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta053_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta054_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_Sta055_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_ST1_Run_3C_Sta015_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_ST1_Run_3C_Sta017_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_ST1_Run_3C_Sta019_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_ST1_Run_3C_Sta021_XPT.dlis33126EDDigital DataC5/14/2020 Electronic File: Oil_Search_Mitquq_1_ST1_Run_3C_Sta023_XPT.dlis33126EDDigital DataC5/14/20204495 4100 Electronic Data Set, Filename: Mitquq_1_ST1_Run 3D_ORA_Correlation Log.las33127EDDigital DataC5/14/20200 14301 Electronic Data Set, Filename: Mitquq_1_ST1_Run 3D_ORA_Sta001.las33127EDDigital DataC5/14/20200 7214 Electronic Data Set, Filename: Mitquq_1_ST1_Run 3D_ORA_Sta002.las33127EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3D_5in_ORA-GR_16Feb20.Pdf33127EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3D_ORA_Correlation Log.dlis33127EDDigital DataThursday, December 17, 2020AOGCCPage 14 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3D_ORA_Sta001.dlis33127EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3D_ORA_Sta002.dlis33127EDDigital DataC5/14/20202497 5089 Electronic Data Set, Filename: Mitquq 1ST1_QGEO_Dip_Interpretation_2500_5091ftMD.las33128EDDigital DataC5/14/20204300 5088 Electronic Data Set, Filename: Mitquq 1ST1_QGEO_Sandcount_BIN_Pc_CumulativeThickness_PseudoGR_4300_5088ftMD.las33128EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq1_ST1_SandCount Zones.xlsx33128EDDigital DataC5/14/2020 Electronic File: Mitquq1ST1_QGEO_PROCESSED_IMAGES_2500_5092 ftMD.dlis33128EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq1_ST1_QGEO_Image_Interpretation_5in_2500_5092 ftMD.pdf33128EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq1_ST1_QGEO_Image_Interpretation_60in_2500_5092 ftMD.pdf33128EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq1_ST1_QGEO_Sand_Counting_20in_4300_5088 ftMD.pdf33128EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq1_ST1_QGEO_Sand_Counting_5in_4300_5088 ftMD.pdf33128EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq1_ST1_QGEO_Sand_Counting_60in_4300_5088 ftMD.pdf33128EDDigital DataC5/14/20202500 5118 Electronic Data Set, Filename: Mitquq_1_ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.las33129EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.dlis33129EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.pdf33129EDDigital DataThursday, December 17, 2020AOGCCPage 15 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/20204079 5146 Electronic Data Set, Filename: Mitquq 1ST1_Run_3B_8.5in_CMR_Depth_Shifted_NGI.las33130EDDigital DataC5/14/20204144 5144 Electronic Data Set, Filename: Mitquq 1ST1_Run_3B_8.5in_CMR_Processed_4144_5150ft.las33130EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_8.5in_CMR_Advisor_4144_5150ft.pdf33130EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_8.5in_CMR_Processed_4144_5150ft.dlis33130EDDigital DataC5/14/20204144 5200 Electronic Data Set, Filename: Mitquq_1ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.las33131EDDigital DataC5/14/20204144 5200 Electronic Data Set, Filename: Mitquq_1ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.las33131EDDigital DataC5/14/20204144 5200 Electronic Data Set, Filename: Mitquq_1ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.las33131EDDigital DataC5/14/20204144 5200 Electronic Data Set, Filename: Mitquq_1ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.las33131EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.dlis33131EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.pdf33131EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.pdf33131EDDigital DataC5/14/2020 Electronic File: Mitquq_1ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.dlis33131EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.pdf33131EDDigital DataThursday, December 17, 2020AOGCCPage 16 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.pdf33131EDDigital DataC5/14/2020558 5214 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Run_3B_LSA_558-5214ft.las33132EDDigital DataC5/14/20202495 5190 Electronic Data Set, Filename: Mitquq 1ST1_Run_3B_RTScanner_1D_Inversion_Best_2495-5190ft.las33132EDDigital DataC5/14/20202495 5190 Electronic Data Set, Filename: Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_39_2495-5190ft.las33132EDDigital DataC5/14/20202495 5190 Electronic Data Set, Filename: Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_54_2495-5190ft.las33132EDDigital DataC5/14/20202495 5190 Electronic Data Set, Filename: Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_72_2495-5190ft.las33132EDDigital DataC5/14/20202495 5190 Electronic Data Set, Filename: Mitquq_1_ST1_Run_3B_RTScanner_Data_2495-5190ft.las33132EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_LSA_558-5214ft.pdf33132EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3B_LSA_558-5214ft.dlis33132EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_2495-5190ft.pdf33132EDDigital DataC5/14/2020 Electronic File: Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_2495-5190ft.dlis33132EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_8.5in_Ora_Testing_Report.pdf33133EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_8.5in_XPT_Pressure_Results.pdf33133EDDigital DataThursday, December 17, 2020AOGCCPage 17 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_3C_8.5in_XPT_Test_Point_Table.xlsx33133EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1_Run_4A_USIT-CBL_Main_Pass.dlis33134EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1_Run_4A_USIT-CBL_Repeat Pass.dlis33134EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_4A_5in_CBL_22Feb20.Pdf33134EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_4A_5in_USIT_22Feb20.Pdf33134EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_4A_Cement_Evaluation_Log_25Feb20.pdf33134EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_4A_Cement_Evaluation_Report_25Feb20.pdf33134EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Run_4E_4.5in_HSD_Gun_23Feb20.Pdf33135EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1_Run_4E_Confirmation Pass_23Feb20.dlis33135EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1_Run_4E_Shooting_Pass_23Feb20.dlis33135EDDigital DataC5/14/2020128 5250 Electronic Data Set, Filename: OilSearch_Mitquq_1_ST1_Drillgas_Depth_128_5250.las33136EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ST1 show reports.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Final Well Report.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Isotubes_Inventory.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Mudlogging_Sample_Inventory.pdf33136EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ST1 Compiled DGRs.pdf33136EDDigital DataThursday, December 17, 2020AOGCCPage 18 of 26,OilSearch_Mitquq_1_ST1_Drillgas_Depth_128_5250.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_Drillgas_Time_08Feb2020_20Feb2020_LAS.zip33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_DrillingLog_5250ft_MD.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_GasRatioLog_5250ft_MD.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_MasterLog_5250ft_5inMD.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_MasterLog_5250ft_MD.pdf33136EDDigital DataC5/14/2020 Electronic File: OilSearch_Mitquq_1_ST1_MasterLog_5250ft_TVD.pdf33136EDDigital DataC5/14/2020 Electronic File: Mitquq 1 ST1 Prognosis.docx33136EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1 Final Well Test Field Report.xlsx33137EDDigital DataC5/14/2020 Electronic File: Mitquq 1ST1 Final Well Test Report.pdf33137EDDigital DataC8/4/2020 Electronic File: Mitquq 1ST1 PVT.xlsx33137EDDigital DataDF10/30/2020 Electronic File: 2001222 Brine Throughput Sample 280S 04-30-2020 .xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 CEC by Conductometric Titration Final.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Data1.05-29-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Data2.05-29-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Data3.05-29-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Data4.05-29-20.xlsm34154EDDigital DataThursday, December 17, 2020AOGCCPage 19 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoDF10/30/2020 Electronic File: 2001222 HPMI Qv Corrected Data1.06-10-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Qv Corrected Data2.06-10-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Qv Corrected Data3.06-10-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 HPMI Qv Corrected Data4.06-10-20.xlsm34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 (8) Kw (EP-NMR Set) 27-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 014S Post SS Rel-K RCA 23-Jul-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 047S SS KgKo Final Data 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 047S SS KwKo Final with 1 Bump 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 063S SS KgKo Final Data 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 063S SS KwKo Final with 1 Bump 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 153S SS KgKo Final Data 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 153S SS KwKo Final with 1 Bump 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 280S SS KgKo Final Data 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 Centrifuge (4) A-B Pc data 10-27-2020.xls34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 Centrifuge A-B Pc 7-23-2020.xls34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 CoCw FF 27-Jul-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 CoCw FFRI 25-Aug-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 CoCw FFRI 27-Oct-2020.xlsx34154EDDigital DataThursday, December 17, 2020AOGCCPage 20 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 Compiled Raw Data 23-Jul-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 KgKoKwKo Raw Data 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 Kw (EP-NMR Set)10-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 NMRT1 Jul-31-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 NMRT2 Jul-31-2020.xls34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 RCA (Final) 18-Sep-20.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 Rw-Core 25-Sept-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 SS KgKo Final Data 014S 23-Jul-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 SS KgKoKwKo Summary 23-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 SS KgKoKwKo Summary 7-July-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 Mitquq-1 ST01 SS KwKo Final with 1 Bump 014S 22-Jul-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 2001222 NMR As Received Data Summary (SS Rel-K samples).xls34154EDDigital DataDF10/30/2020 Electronic File: 2001222 OSA Triaxial Test Results Summary(plug)06.16.2020.xls34154EDDigital DataDF10/30/2020 Electronic File: 2001222 OSA Triaxial Test Results Summary.xls34154EDDigital DataDF10/30/2020 Electronic File: 2001222GXRD Oil Search Alaska Mitquq-1 ST01.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 202001222_Mitquq-1 ST01_SCAL_RCA SS Set_7-9-2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 202001222_SCAL_EP & NMR Set_6.30.2020.xlsx34154EDDigital DataDF10/30/2020 Electronic File: 202001222_SCAL_RCA_ Pc Set 6.30.2020.xlsx34154EDDigital DataThursday, December 17, 2020AOGCCPage 21 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoDF10/30/2020 Electronic File: 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REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoDF10/30/2020 Electronic File: 4589-98uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4598-07uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4607-16uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4616-25uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4625-34uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4634-43uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4643-52uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4652-53.87uv.tif34154EDDigital DataDF10/30/2020 Electronic File: 4291.0-4309.0uv.jpg34154EDDigital DataDF10/30/2020 Electronic File: 4309.0-4327.0uv.jpg34154EDDigital DataDF10/30/2020 Electronic File: 4327.0-4345.0uv.jpg34154EDDigital DataDF10/30/2020 Electronic File: 4345.0-4363.0uv.jpg34154EDDigital DataDF10/30/2020 Electronic 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DataDF10/30/2020 Electronic File: 4616.0-4634.0uv.jpg34154EDDigital DataDF10/30/2020 Electronic File: 4634.0-4652.0uv.jpg34154EDDigital DataThursday, December 17, 2020AOGCCPage 24 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments: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:4/2/2020Release Date:5/2/2022DF10/30/2020 Electronic File: 4652.0-4653.9uv.jpg34154EDDigital Data3/11/20202410 525041735Cuttings3/16/20204291 465441737Core ChipsConventional CoreCore ChipsRoutine Core AnalysisCore PhotosCore DescriptionSpecial Core AnalysisThursday, December 17, 2020AOGCCPage 25 of 26 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20808-01-00Well Name/No. MITQUQ 1 ST1Completion StatusP&ACompletion Date4/2/2020Permit to Drill2191510Operator Oil Search (Alaska), LLCMD5250TVD4809Current StatusP&A12/17/2020UICNoCompliance Reviewed By:Date:Thursday, December 17, 2020AOGCCPage 26 of 26M. Guhl1/7/2021 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 file Mitquq 1ST1 (50-103-20808-0100) Resubmission with corrected las2 format: OilSearch_Mitquq_1_ST1_Litholog_5250ftTD 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) PTD: 2191510 E-Set: 33136 Received by the AOGCC 01/07/2021 Abby Bell 01/07/2021 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 file Mitquq 1ST1 (50-103-20808-0100) Resubmission with corrected las2 format: Mitquq_1_ST1_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: 2191510 E-Set: 33136 Received by the AOGCC 12/22/2020 Abby Bell 12/24/2020 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 4 files Mitquq 1ST1 (50-103-20808-0100) 2001222 Mitquq-1 ST01 NMR T1 100% Sw & Swi 28-Aug-2020.xlsx 2001222 Mitquq-1 ST01 NMR T2 100% Sw & Swi 28-Aug-2020.xls 2001222 Mitquq-1 ST01 NMRT1 29-Oct-2020.xlsx 2001222 Mitquq-1 ST01 NMRT2 29-Oct-2020.xls 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: 12/11/2020 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 12/14/2020 PTD: 2191510 E-Set: 34379 Abby Bell 12/14/2020 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 October 29, 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 1ST1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Mitquq ST1 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 February 1, 2021. 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 1ST1 50-103-20808-0100 NMR T1/T2 measurements MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��� �I Zz, DATE: 8/25/2020 P. I. Supervisor T FROM: Austin McLeod SUBJECT: Location Inspection Petroleum Inspector Mitquq 1 ST1 - Oil Search (Alaska) LLC PTD 2191510, 8/25/2020: 1 met up with Oil Search Alaska representative Sherard Lier to witness the location clearances of the two abandoned wells. We flew to Mitquq 1 ST1 via helicopter. The helicopter hovered close to the ground so pictures could be taken. We flew around the vicinity of the drillsite and found nothing out of the ordinary. The Mitquq 1 ST1 location appeared fine with no issues noted on the tundra. The only thing apparent was that birds and caribou had been walking around the mound over the abandoned well. Attachments: Pictures (2) 2020-0825_Location_Clear_Mitquq 1ST 1 _am. docx Page 1 of 2 ca U O 0 F- -� ao F• U c L Q U N Q N d c L n O)OV UQ C N N O v O N 0 a- 00 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 1ST1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Mitquq ST1 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 1ST1 50-103-20808-0100 Conventional Core Laboratory Studies- Porosity & Permeability – Core Lab – estimated November 2020 Mitquq 1ST1 50-103-20808-0100 SCAL Program for whole core plugs – estimated November 2020 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 Excel spreadsheet Mitquq 1ST1 (50-103-20808-0100) -Mitquq 1ST1 PVT 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: 8/4/2020 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 08/04/2020 PTD: 2191510 E-Set: 33137 Abby Bell 08/04/2020 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.: 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 828.08' FEL 3000.85', Sec. 3, T11N, R7E, UM GL: 49.21 BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: FSL 1055.78', FEL 3546.95', Sec. 3, 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 4798' 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 Please see attached report from Schlumberger 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 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, TUBING RECORD 4514'3-1/2" 9.2# L-80 SIZE DEPTH SET (MD) 4488' PACKER SET (MD/TVD) BOTTOM 973 sks ArcticCem 235 sks Class G. Stage 1: 70 sks Type I/II 197 sks Class G Stage 2: 141 sks Type I/II 80 sks Class G 8-1/2" Surface STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil Search Alaska WAG Gas 4/2/2020 Mitquq 1 ST1 ADL 0393876 219-151 / 319-553 / 320-109 / 320-099 12/25/2019 2/14/2020 P&A to Surface 77.61 5970921.247 1584' MD / 1584' TVD LONS-005 2600' MD / 2600' TVD 5250' MD / 4809' TVD PO Box 240927 Anchorage, AK 99524-0927 458809.2644 458264.0183 Undefined 50-103-20808-01-00 12-1/4" Grouted to surface HOLE SIZE AMOUNT PULLED 20" 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 459506.6393 5970621.16 CEMENTING RECORDTOP SETTING DEPTH MD Surface SETTING DEPTH TVD 5971151.931 Mudlog, Wireline Run 3A: NGI/SS/ZAIT, Run 3B: CMR/HNGS/PEX/NEXT, Run 3C: XPT, Run 3D ORA, Run 4A: GR/USITL, Run 4B GR/VSI-4, Run 4C GR/VSI-20, GR/Perf, LWD GR/RES/GR/SONIC TOP N/A Surface CASING WT. PER FT.GRADE 2495' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Per 20 AAC 25.283 (i)(2) attach electronic information 26#Surface 628 3/16/2020 Flow Tubing 84# 40# 126.5' Surface 5236' Surface 292591 Water-Bbl: PRODUCTION TEST 3/3/2020 Date of Test:Oil-Bbl: Sr Res EngSr Pet GeoSr Pet Eng 40/64th1265 410 5631570 334303 28.9 Oil-Bbl:Water-Bbl: 771 Gas-Oil Ratio:Choke Size: Gas Lift Mitquq 1 ST1 was a slanted well completion that consisted of a perforated zone for stimulation. Perforation zone: Top 4,547' MD/4,273' TBD - Bottom 4,552' MD/4,277' TVD. Perforation size and number: 4-1/2", 60 Degree Phasing, 12 SPF, 5 ft length, EH Diameter Avg 0.38 in. Date Perforated: 02/23/2020. Date Stimulation 1: 03/01/2020 Date Stimulation 2: 03/12/2020 dB P (att WA 1b D S G Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 12:04 pm, Jun 03, 2020 +(: State of Alaska G Abandonment Date 4/2/2020 HEW RBDMS HEW 6/3/2020 DLB 06/04/2020 CDW 6/4/2020 DSR-6/3/2020 USIT / CBL 2/22/20 SFD 6/10/2020 Aband.: Abandoned gls 6/23/20 Conventional Core(s): Yes No Sidewall Cores: Conventional cores taken from Nanushuk 9 4291' - 4654' Please see attached core summary / Core photos will be submitted with log data 30. MD TVD Surface Surface 1584' 1584' Top of Productive Interval 4336' 4114' 3748' 3663' 4218' 4035' 4332' 4110' Well Test Sumary is attached 5006' 4620' Full Well Test Report will be submitted with log data 5250' 4809' 31. List of Attachments: 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: 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. Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary; Wellbore Schematic; Well Test Summary; Frac Report; Casing Cut_Plate Photos 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 Formation at total depth: Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Permafrost - Top Nanushuk 8 Nanushuk 8 Seabee Nanushuk Nanushuk 9 SS 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 inc lination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Signature w/Date: 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 Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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. TPI (Top of Producing Interval). 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. 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. No No NNN Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 2020-Jun-03 11:04 2020-Jun-03 11:04 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface:FSL 531.60', FEL 2302.37', Sec. 3, T11N, R7E, UM Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): FSL 828.08' FEL 3000.85', Sec. 3, T11N, R7E, UM GL: 49.21 BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: FSL 1055.78', FEL 3546.95', Sec. 3, 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 4798' 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 Please see attached report from Schlumberger 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 Undefined N/A 28.9 Oil-Bbl:Water-Bbl: 1424.18 Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet GeoSr Pet Eng 32/64279.56 0.418 7874.2 279.56188 Gas Lift Mitquq 1 ST1 was a slanted well completion that consisted of a perforated zone for stimulation. Perforation zone: Top 4,547' MD/4,273' TBD - Bottom 4,552' MD/4,277' TVD. Perforation size and number: 4-1/2", 60 Degree Phasing, 12 SPF, 5 ft length, EH Diameter Avg 0.38 in. Date Perforated: 02/23/2020. Date Stimulation 1: 03/01/2020 Date Stimulation 2: 03/12/2020 948131 Water-Bbl: PRODUCTION TEST 3/3/2020 Date of Test:Oil-Bbl: 407 3/3/2020 Flow Tubing 84# 40# 126.5' Surface 5236' Surface Per 20 AAC 25.283 (i)(2) attach electronic information 26#Surface Surface CASING WT. PER FT.GRADE 2495' 458809.2644 458264.0183 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 5971151.931 Mudlog, Wireline Run 3A: NGI/SS/ZAIT, Run 3B: CMR/HNGS/PEX/NEXT, Run 3C: XPT, Run 3D ORA, Run 4A: GR/USITL, Run 4B GR/VSI-4, Run 4C GR/VSI-20, GR/Perf, LWD GR/RES/GR/SONIC TOP 5250' MD / 4809' TVD Surface 12-1/4" Grouted to surface 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 459506.6393 5970621.16 CEMENTING RECORD 5970921.247 1584' MD / 1584' TVD LONS-005 PO Box 240927 Anchorage, AK 99524-0927 4/2/2020 50-103-20808-01-00 Mitquq 1 ST1 ADL 0393876 219-151 / 319-553 / 320-109 / 320-099 12/25/2019 2/14/2020 P&A to Surface 77.61 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil Search Alaska WAG Gas 2600' MD / 2600' TVD 20" BOTTOM 973 sks ArcticCem 235 sks Class G. Stage 1: 70 sks Type I/II 197 sks Class G Stage 2: 141 sks Type I/II 80 sks Class G 8-1/2" 4514'3-1/2" 9.2# L-80 SIZE DEPTH SET (MD) 4488' PACKER SET (MD/TVD)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, TUBING RECORDo essssss NoNo (att 597115 Zone G s d 1 0 p L Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 1:33 pm, May 19, 2020 State of Alaska RBDMS HEW 5/22/2020 Abandonment Date 4/2/2020 HEW 2/9/2020 MDG G Superceded Conventional Core(s): Yes No Sidewall Cores: Conventional cores taken from Nanushuk 9 4291' - 4654' Please see attached core summary / Core photos will be submitted with log data 30. MD TVD Surface Surface 1584' 1584' Top of Productive Interval 4336' 4114' 3748' 3663' 4218' 4035' 4332' 4110' Well Test Sumary is attached 5006' 4620' Full Well Test Report will be submitted with log data 5250' 4809' 31. List of Attachments: 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: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 separ ately 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. 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. 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. 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. TPI (Top of Producing Interval). 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 inc lination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Signature w/Date: 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 TESTS Permafrost - Top Nanushuk 8 Nanushuk 8 Seabee Nanushuk Nanushuk 9 SS 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. Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary & Photos; Wellbore Schematic; Well Test Summary; Frac Report; Casing Cut_Plate Photos 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 Formation at total depth: Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 04/30/2020 2020-Apr-30 15:13 Superceded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uperseded 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 4336' 4114' 3748' 3663' 4218' 4035' 4332' 4110' Please see attached Well Test Summary 5006' 4620' 5250' 4809' 31. List of Attachments: 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: 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. Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary & Photos; Wellbore Schematic; Well Test Summary; Frac Report; Casing Cut_Plate Photos 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 Formation at total depth: Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Permafrost - Top Nanushuk 8 Nanushuk 8 Seabee Nanushuk Nanushuk 9 SS 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. Signature w/Date: 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 Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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. TPI (Top of Producing Interval). 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. 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. STS s NoNNNNNNNN s sss N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 04/30/2020 2020-Apr-30 07:35 Superseded Surface Casing 9-5/8" 40# L80 BTC 12-¼” Hole 2,495' MD/TVD Production Casing 7" 26# L80 Vam Top HC 8 ½” Hole 5,236' MD/4,798' TVD Mitquq 1 ST1 Post Drill P&A Schematic 3-½” 9.2# L80 Vam Top Tubing GLM, 3-½” 3024' MD/3,018' TVD Open Mandrel (GLV pulled) Standing Valve landed in 3-½”, ‘XN’ Landing Nipple 4,505' MD/4,241' TVD 3-½” X 7" Packer 4488' MD/4228' TVD 3-½”. 2.813" Polish Bore ‘X’ Landing Nipple 530' MD/TVD Updated April 23rd 2020 ES-IPC Stage Cement Tool 2450' MD 16” Conductor 126.5' MD/TVD No cement squeezed into Perforations ~4,547'- 4,552'' MD/ 4,275' TVD, 40.96° Inc. WLEG 4514' MD/4248' TVD P&A Cement Tubing Punch 4477 - 4480' MD/TVD Cement Plug 1: 4477-3294 (1183' plug) Cement Plug 2: 3024' - surface Tubing P/T Gauges 4,458' MD/4,206' TVD & 4,470' MD/4,215' TVD 3-½”, ‘XN’ Landing Nipple 4,505' MD/4241' TVD 3-½” ‘X’ Landing Nipple 4,445' MD/4,196' TVD 6XUIDFH&DVLQJ /%7& ó´+ROH 0'79' 3URGXFWLRQ&DVLQJ/9DP7RS+& ò´+ROH 0' 79' 0LWTXT67 :HOO6FKHPDWLF ò´ /9DP7RS7XELQJ */0ò´ 0' 79' 7XELQJ37*DXJHV 0' 79' 0' 79' ò´µ;1¶/DQGLQJ1LSSOH 0' 79' ò´;3DFNHU 0' 79' ò´3ROLVK%RUHµ;¶/DQGLQJ1LSSOH 0'79' ò´µ;¶/DQGLQJ1LSSOH 0' 79' 8SGDWHG$SULOWK (6,3&6WDJH&HPHQW7RRO 0' ´&RQGXFWRU 0'79' &RUH 3HUIRUDWLRQ,QWHUYDO 0' 79' ,QF 67.LFN2II# 0'79' ò´%+.$# 0' 79' ò³ /,%7 6DFULILFLDO7XELQJ 2+ RLQFOLQDWLRQ 7' 0' 79' :/(* 0' 79' (QGRI7XELQJ 0' 79' /9DP7RS+& ò´+ROH 0' 79' FDVLQJFXW# 0' ST1 Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 2/8/2020 2/9/2020 2,405 113.00 10.20 Pull out of hole w/cement stinger. Pick up BHA #8. Shallow hole test - good test. RIH and tag kick of plug. Wait on cement compressive strength increase. RIH and dress top of kick off plug. Begin time drill at 3 ft/hr increasing to 6 ft/hr. 2/9/2020 2/10/2020 2,518 873.00 10.20 Time drill through kick off interval at 10 ft/hr decreasing to 3 ft/hr. Kick off confirmed at 2500' MD. Rotary drill ahead - 8 1/2" sidetrack to 3391' MD. 2/10/2020 2/11/2020 3,391 900.00 10.25 Drilled 8 1/2" side track to corepoint at 4291' MD. Circulate hole clean. POOH, rack back BHA, and lay down smart tools. Start BOPE testing - AOGCC witness waived. 2/11/2020 2/12/2020 4,291 180.00 10.30 Test BOPE to 250 psi low, 3500 psi high for 5 minutes each - witness waived by AOGCC rep. Pick up coring BHA as per Halliburton coring rep. Run in hole filling pipe every 10 stands. Core 180' section of formation to 4471' MD. 2/12/2020 2/13/2020 4,471 54.00 10.30 POOH with coring BHA #1 to surface and lay down core as per CoreLab and OSA oversight - successful operation. Pick up coring BHA #2 and RIH filling pipe every 10 stands. Begin coring at 4471' MD. 2/13/2020 2/14/2020 4,525 126.00 10.30 Continue coring with Coring BHA #2 at 4651' MD. POOH with Coring BHA #2 and lay down core as per CoreLab and OSA oversight - successful operation. Pick up Drilling BHA #9 (8 1/2" production hole) and RIH. 2/14/2020 2/15/2020 4,651 599.00 10.40 RIH and mad pass coring section to 4651' MD. Drill ahead 8 1/2" hole section from 4651' MD to TD at 5250' MD. Circulate hole clean. Trip out of hole. Lay down MWD/LWD BHA 2/15/2020 2/16/2020 5,250 0.00 10.40 Complete laying down MWD/LWD BHA. Rig up and Perform wireline logging runs #1 and #2 on 8 1/2" production open hole section. RIH and begin logging run #3 2/16/2020 2/17/2020 5,250 0.00 10.35 Complete wireline logging run #3. M/U and begin wireline logging run #4 on 8 1/2" production hole section 2/17/2020 2/18/2020 5,250 0.00 10.40 Complete wireline logging run #4 on 8 1/2" production hole section. POOH and R/D SLB wireline. Test BOPE to 250 psi low, 3500 psi high for 5 minutes each - Witness Waived by AOGCC Rep Matt Herrera. P/U BHA #10 8 1/2" cleanout BHA, and RIH to 4626' MD. Begin circulating through gas buster and RIH to clean out production hole section. 2/18/2020 2/19/2020 5,250 0.00 10.40 Continue to cleanout 8 1/2" production hole and circulating through gas buster. Trip out of hole, and lay down cleanout BHA. Rig up to run 7" casing. Change out to 7" fixed rams, and test. Begin running 7" L-80 26 #/ft casing. Install floating centralizers on casing joints per running order. 2/19/2020 2/20/2020 5,250 0.00 10.40 Continue M/U and run 7" casing from 2237' MD to 5250' MD. Rig up for cement job. Pump 2 Stage cement Job with 68.1 total bbls of cement pumped for Stage 1, and 75.5 total bbls of cement pumped for Stage 2 with full returns of mud push to surface, and cement traces. Rig down cementers equipment. M/U and prepare to test packoff. 2/20/2020 2/21/2020 5,250 0.00 10.40 Change rams to 2 7/8" x 5" VBR uppers. Test VBR's and Annular with 3 1/2" and 4" test joints. P/U and RIH with BHA #11 - 7" casing cement cleanout to 2394' MD Test casing to 1500 PSI for 5 min. Drill and dress cement from 2394' MD to 2422' MD. Drill out ESIPC stage tool at 2434' MD. Test casing to 3500 PSI for 30 min - good test. RIH to 4300' MD to ream casing for packer setting, and ream/clean cement to 4750' MD. Ream/Wash down from 4750' MD to 5098' MD. Circulate and condition hole to prepare to displace to 9.6 ppg brine. 2/21/2020 2/22/2020 5,250 0.00 9.60 Clean pill pit and trip tank. Displace well to 9.6 ppg KCL Brine with 189 BBLs of KCL, 40 BBL Hi- Vis spacer, and 45 BBL BaraKlean soap pill. Offload 10.4 ppg MOBM, begin cleaning pits, and R/D MWD/LWD surface sensors and cables, and Mud Logger sensors and equipment. TOOH from 5078' MD laying down drill pipe to shed. RIH to 3495' MD with drillpipe from derrick. Pump 20 BBL BaraKlean soap pill down drill pipe. Flush and blow down surface equipment and TOOH from 3495' MD laying down drill pipe to shed. 2/22/2020 2/23/2020 5,250 0.00 9.60 Complete laying down drill pipe and BHA #11. Rig up and perform wireline logging runs #1 and #2 in 7" production casing. RIH and begin logging run #3 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 4 Well Name Mitquq 1 Wellbore Name Sidetrack 1 PTD # 219-151 Start Drill Date 2/8/2020 End Drill Date 4/9/2020 Continue M/U and run 7" casing from 2237' MD to 5250' MD. Rig up for cement job. Pump 2ggpjp Stage cement Job with 68.1 total bbls of cement pumped for Stage 1, and 75.5 total bbls ofgppg, cement pumped for Stage 2 with full returns of mud push to surface, and cement traces. Rigpp g down cementers equipment. Sidetrack well. g RIH and dress top of kick off plug. TD at 5250 ft cement 7" casing p TD at 5250' MD. Bop test M. USIT and CBL Drill out ES and test casing to 3500 psi Core well ygp Begin running 7" L-80 26 #/ft casing. Test BOPE to 250 psi low, 3500 psi high for 5 minutes each r. Kick off confirmed at 2500' MD. Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 2/23/2020 2/24/2020 5,250 0.00 9.60 Complete wireline logging runs #3 and #4 per program. M/U and RIH wireline run #5 with perforation gun and perforate per program. L/D perforation gun and R/D SLB Wireline. Void and flush stack with BOP Flushing Tool. R/U Halliburton and Weatherford tools for tubing, and TEC spooling unit, and begin P/U and RIH with 3 1/2" completion tubing, packer and downhole gauges per tubing running order. 2/24/2020 2/25/2020 5,250 0.00 9.60 Continue to make up 3 1/2" completion tubing to TD at 4,514' MD per running order. Land tubing, R/U slickline and lubricator, freeze protect well, and set and test tubing packer. Test Tubing and IA - Good Tests. Set and test XN-plug and X-plug with slickline - Good Tests. 2/25/2020 2/26/2020 5,250 0.00 9.60 Rig down Halliburton lubricator and slickline. Install TWC per Vetco rep. Nipple down BOPE and nipple up frac tree. Rig up Little Red to test frac tree - Good Test. Pits cleaned. Clean and prepare rig and rig equipment for Demobe. 2/26/2020 2/27/2020 5,250 0.00 9.60 Continue to clean up rig and prepare rig and pad for 7ES DeMobe. Conduct 9-5/8" x 7" Annulus (OA) Pressure test to 1000 psi for 30 mins. = Good Test. Inspect tires for pending rig move. Disconnect Pit Sub from Drilling Module. Lay down derrick on drilling module, and move drilling module off of wellhead. Stage 7ES at entrance to Mitquq ice pad to prepare to drive down ice road to 272 Construction Pad 2/27/2020 2/28/2020 5,250 0.00 9.60 Rig De-Mobilization: Transport 7ES drill module from Mitquq 1 location to mile 17.1 per route inspection. Well Test Operations: Rig up flow back equipment and flare equipment. Continue rig up of tank farm scaffolding. Frac 75% rigged up, 3 out of 5 frac tanks heated. 2/28/2020 2/29/2020 5,250 0.00 9.60 Well Test Operations: RIH with slickline unit and pull two way check and both x-plugs in preparation for fracing operations. Rig De-Mobilization Drill module arrive at 3Q pad and set on rig mats and herculite. Pit module depart Mitquq location for 3Q pad ~22:00hrs. 2/29/2020 3/1/2020 5,250 0.00 9.60 Well Test Operations: Continue rigging up for frac operations. Continue rigging up for well test operations. Rig De-Mobilization: Pit module arrive at 3Q. Berm in 7ES. Continue moving rig shop and misc loads to 3Q pad. 3/1/2020 3/2/2020 5,250 0.00 9.60 Perform frac job on ST1. Slickline operations. 3/2/2020 3/3/2020 5,250 0.00 9.60 Continue rig up for flowback operations. Start of well test delayed due to extreme cold temperatures. 3/3/2020 3/4/2020 5,250 0.00 9.60 Open up well and begin well test clean up flow period. 3/4/2020 3/5/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/5/2020 3/6/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/6/2020 3/7/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/7/2020 3/8/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/8/2020 3/9/2020 5,250 0.00 9.60 Shut in well. Freeze protect PTS flowback spread. Prepare for Re-Frac as frac crew arrives on location. Operations Summary Report - State Page 2 of 4 Rig De-Mobilization: Rig up Frac Crew p Continue rigging up for frac operations. Land tubing set packer and MIT-IA and MIT-T Continue to make up 3 1/2" completion tubing to TD at 4,514' MD per running order. Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 3/9/2020 3/10/2020 5,250 0.00 9.60 Drift and tag bottom with slickline, set EVO plug, pull GLV, freeze protect IA, install dummy valve, pull EVO plug, rig down slickline. Rig up frac operations shack- tie into internet. Finish filling frac tanks. Begin warming frac tanks to temperature. 95% of frac crew arrived on location. 3/10/2020 3/11/2020 5,250 0.00 9.60 Finish warming all frac water to temperature. 100% of crew and equipment on location. Pump repair at SLB shop 100% complete. Continue rigging up frac equipment. 3/11/2020 3/12/2020 5,250 0.00 9.60 Finish rigging up repaired pump. Prepare for pressure testing. During pressure test 4" HP hydraulic valve failed. No reportable spill - fluid captured in secondary containment. Determined to be too late in day to test new valve on site and perform frac job. 2 tested 4" HP hydraulic valves scheduled to arrive in morning. 3/12/2020 3/13/2020 5,250 0.00 9.60 Perform frac job on ST1. Slickline operations. L/D due to high winds and wait on weather. (Phase 2 Conditions) 3/13/2020 3/14/2020 5,250 0.00 9.60 Continue to wait on weather. (Phase 3 Conditions) 3/14/2020 3/15/2020 5,250 0.00 9.60 Continue to wait on weather. (Phase 3 Conditions) 3/15/2020 3/16/2020 5,250 0.00 9.60 Complete slickline operations delayed by Phase Weather. Commence repairs and rig up of well test equipment. Clear drifts around pad and well-test equipment, tank farm, and flare for upcoming well test. 3/16/2020 3/17/2020 5,250 0.00 9.60 Open up well and begin well test clean up flow period. 3/17/2020 3/18/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/18/2020 3/19/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/19/2020 3/20/2020 5,250 0.00 9.60 Continue flowing well for clean up period as per plan. 3/20/2020 3/21/2020 5,250 0.00 9.60 Finish flowing well for clean up period. Rig up to take samples per program. Shut in well per planned shut in period, and monitor. 3/21/2020 3/22/2020 5,250 0.00 9.60 Monitor shut in well for planned shut in period. 3/22/2020 3/23/2020 5,250 0.00 9.60 Monitor shut in well for planned shut in period. 3/23/2020 3/24/2020 5,250 0.00 9.60 Monitor shut in well for planned shut in period. 3/24/2020 3/25/2020 5,250 0.00 9.60 Monitor shut in well for planned shut in period. 3/25/2020 3/26/2020 5,250 0.00 9.60 Monitor shut in well for planned shut in period. 3/26/2020 3/27/2020 5,250 0.00 9.60 Monitor shut in well for planned shut in period. 3/27/2020 3/28/2020 5,250 0.00 9.60 Perform downhole slickline tag. 3/28/2020 3/29/2020 5,250 0.00 9.60 Perform max flow test as per OSA testing procedures. 3/29/2020 3/30/2020 5,250 0.00 9.60 Shut in @ 02:15 hrs - Final shut in. R/D and B/D flowback lines. Pump kill weight fluid and set X and XN plugs with slickline. Set TWC and swap frac tree to dry hole tree. Pressure test dry hole tree - good test. RIH with slickline and punch holes in tubing for kill weight circulation. Circulate 235 bbls 9.6 ppg NaCL brine down tubing to IA followed by 10 bbls diesel. 48 hr. Notification to AOGCC for P&A Test Witness given @ 16:23 hrs - Requested time 08:00 hrs 03-31-2020 Operations Summary Report - State Page 3 of 4 Frac Well ST1 Prep well for Abandonment Shut in @ 02:15 hrs - Final shut in. R/D and B/D flowback lines. Pump kill weight fluid and set X@pg and XN plugs with slickline. Set TWC and swap frac tree to dry hole tree. Pressure test dry holepg p y y tree - good test. RIH with slickline and punch holes in tubing for kill weight circulation. Circulategpgg 235 bbls 9.6 ppg NaCL brine down tubing to IA followed by 10 bbls diesel. Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 3/30/2020 3/31/2020 5,250 9.60 Pull PXN and XN tubing profiles with Halliburton slickline. Halliburton cement pump plug 1 cement job. RIH with gauge ring to cement top at 3294' MD. RIH and pull GLV. Wait on cement. RIH with sample bailer and take cement sample - POOH. Pressure test cement plug 1 to 2000 psi tubing and IA - AOGCC Rep Witness - good test. Rig down and stage slickline equipment and unit on heavy truck line. Rig up HES cement and pump cement plug #2. Achieved good cement to surface. 3/31/2020 4/1/2020 0 9.60 Rig down and demobilize equipment off of Mitquq pad. Lynden 400 bbl uprights and tank farm equipment 100% rigged down and demobilized. PTS flowback equipment 100% rigged down and 95% demobilized from location. Wellhouse is 100% rigged down and waiting on tractor to demobilize from location. Waiting on Wachs Guillotine saw to cut off wellhead. Request to AOGCC inspector for inspection to be pushed to 04/02/2020 @ 12:00 hrs - approved. 4/1/2020 4/2/2020 0 9.60 Rig up Wachs Super D Guillotine saw to wellhead and cut through all casing strings. Remove wellhead - cement to surface in tubing and IA. 9-5/8"x7" annulus hard tagged at 7' 6" depth from cut. Notify AOGCC rep of operation status - permission given to top up annulus with cement in preparation for morning inspection. Continue rig down and demobilization of equipment on pad. 4/2/2020 4/3/2020 0 9.60 AOGCC representative witnessed top of cement and gave state approval to weld abandonment plate onto well. After plate installation, top of well measured 6' below tundra grade. Cellar pulled and original overburden soil backfilled in. 4/3/2020 4/4/2020 0 9.60 Continue rig down and demobilization of equipment, and cleaning of Mitquq pad. -Rig down and demobilize communications shelter. -Rig down and demobilize Afognak office camp. -Continue demobilization of misc rolling stock on pad as released from service. -DUS and Nabors crew continue preparing Augustine for rig down and demobilization. 4/4/2020 4/5/2020 0 9.60 Continue rig down and demobilization of equipment, and cleaning of Mitquq pad. -DUS hand over Augustine to Nabors for completion of blow down and rig down operations. -Demobilize remaining generators and rig mats off location. 4/5/2020 4/6/2020 0 9.60 Augustine camp modules 100% separated and spread on pad. 100% of the double stacked camp modules transported to Deadhorse. 50% of the single stack camp modules transported to Deadhorse 4/6/2020 4/7/2020 0 9.60 Augustine camp 100% transported off location en route to Deadhorse. Drill pad cleared. All delineators to drill pad pulled and road to drill pad closed off. Ice Road Supt, AFC foreman, Drilling Supt, Field Environmental, and Subsistence Rep all sign off on pad close out form. Augustine camp begin reassembly for storage in Deadhorse. 4/7/2020 4/8/2020 0 9.60 Clean and Prepare 272 Construction Pad: -Clear 272 construction pad and access road of snow following phase 2 conditions. -Organize 272 construction pad in preparation for demobilization. -Transport of AFC shop postponed due to prolonged phase 2 conditions. Augustine Camp Storage - Deadhorse: -Set in remaining camp modules - Augustine camp demobe complete. 4/8/2020 4/9/2020 0 9.60 Rig down and transport AFC shop from construction pad to Deadhorse. DUS and Parker Drilling continue to prepare Parker 272 camp for transport to Deadhorse. 4/9/2020 4/10/2020 0 9.60 Demobilize and Transport Equipment Off 272 Pad: -Separate 272 camp modules and begin transport to Deadhorse - 272 camp off location @ 11:45 hrs. -Transport remaining equipment off location. -Pad signed off and road bermed off @ 15:00 hrs *** Final Daily Drilling Report for Mitquq 1/Mitquq 1 ST1 *** Operations Summary Report - State Page 4 of 4 plug #1 and #2 set and tested Pull PXN and XN tubing profiles with Halliburton slickline. Halliburton cement pump plug 1gp p pp g cement job. RIH with gauge ring to cement top at 3294' MD. RIH and pull GLV. Wait on cement.jgggp p RIH with sample bailer and take cement sample - POOH. Pressure test cement plug 1 to 2000pp pg psi tubing and IA - AOGCC Rep Witness - good test. Rig down and stage slickline equipment andpg p g g g qp unit on heavy truck line. Rig up HES cement and pump cement plug #2. Achieved good cement cut wellhead Rig up Wachs Super D Guillotine saw to wellhead and cut through all casing strings. Removegp wellhead Mitquq1ST1CoreSummaryPage1of1 StartEndingTotalRemovedSectionsTotal WellCore#Depth(MD)Depth(MD)Length(ft)Start(MD)End(MD)Length(ft)FormationLithologysummaryHydrocarbonsMitquq1ST1142914472.75181.75430143021Nanushuk9LaminatedsandstonesandshalesOil4340.64341.40.84433.054434.05124472.754653.87181.124519.145200.9Nanushuk9LaminatedsandstonesandshalesOilCoreTotalLength(ft)=362.87 DŝƚƋƵƋϭ^dϭŽƌĞ^ƵŵŵĂƌLJ WĂŐĞϭŽĨϭ ^ƚĂƌƚ ŶĚŝŶŐ dŽƚĂů ZĞŵŽǀĞĚ^ĞĐƚŝŽŶƐ dŽƚĂů tĞůů ŽƌĞ η ĞƉƚŚ;DͿ ĞƉƚŚ;DͿ >ĞŶŐƚŚ;ĨƚͿ ^ƚĂƌƚ;DͿ ŶĚ;DͿ >ĞŶŐƚŚ ;ĨƚͿ DŝƚƋƵƋϭ ^dϭ ϭ ϰϮϵϭ͘Ϭ ϰϰϳϮ͘ϳϱ ϭϴϭ͘ϳϱ ϰϯϬϭ͘ϬϬ ϰϯϬϮ͘ϬϬ ϭ͘Ϭ ϰϯϰϬ͘ϲϬ ϰϯϰϭ͘ϰϬ Ϭ͘ϴ ϰϰϯϯ͘Ϭϱ ϰϰϯϰ͘Ϭϱ ϭ͘Ϭ Ϯ ϰϰϳϮ͘ϳϱ ϰϲϱϯ͘ϴϳ ϭϴϭ͘ϭϮ ϰϱϭϵ͘ϭϬ ϰϱϮϬ͘ϬϬ Ϭ͘ϵ ŽƌĞdŽƚĂů>ĞŶŐƚŚ;ĨƚͿс ϯϲϮ͘ϴϳ Superseded ůŝĞŶƚ͗ Kŝů^ĞĂƌĐŚůĂƐŬĂ&ŝĞůĚ͗ DŝƚƋƵƋtĞůů͗ DŝƚƋƵƋϭ^ƚͲϭ&ŽƌŵĂƚŝŽŶ͗ EĂŶƵƐŚƵŬϵdĞƐƚdLJƉĞ͗ džƉůŽƌĂƚŝŽŶWƌŽĚƵĐƚŝŽŶDĞƚŚŽĚ͗EĂƚƵƌĂů&ůŽǁͬ'ĂƐ>ŝĨƚ'KWdη͗ ϮϭϵͲϭϱϬƵƌĂƚŝŽŶŚŽŬĞ^ŝnjĞdƵďŝŶŐWƌĞƐƐƵƌĞdƵďŝŶŐdĞŵƉ͘ /ŶŶĞƌ KƵƚĞƌ^ĞƉĂƌĂƚŽƌWƌĞƐƐƵƌĞ^ĞƉĂƌĂƚŽƌdĞŵƉ͘ĂƚĞdŝŵĞ;ϮϰŚƌͿĂƚĞdŝŵĞ;ϮϰŚƌͿ;ŚŽƵƌƐͿDĂdž;ϲϰƚŚͿǀŐ;ƉƐŝŐͿǀŐ;ĚĞŐ&ͿŶŶƵůƵƐ;ƉƐŝŐͿŶŶƵůƵƐ;ƉƐŝŐͿǀŐ;ƉƐŝŐͿKŝů>ĞŐǀŐ;ĚĞŐ&Ϳ'KZ;ƐĐĨͬƐƚďͿ'ĂƐ;DDƐĐĨͬĚͿKŝů;ďďůͬĚͿtĂƚĞƌ;ďďůͬĚͿ ŵƵůƐŝŽŶ;ďďůͬĚͿ'ĂƐ;ŵŵƐĐĨͿKŝů;ďďůƐͿtĂƚĞƌ;ďďůƐͿ ŵƵůƐŝŽŶ;ďďůƐͿWĞƌŝŽĚϭ͗&ƌĂĐϭ͕ůĞĂŶƵƉͬDĂŝŶ&ůŽǁ ϬϯͬϬϯͬϮϬ ϳ͗ϬϬ ϬϯͬϬϴͬϮϬ ϭϴ͗ϬϬ ϭϯϭ ϯϮ ϭϴϴ ϰϭ ϰϬϳ Ϭ ϳϱ ϭϬϬ ϳϴ͘Ϯϳ Ϭ͘Ϭϭ ϭϳϯ͘ϲϴ ϱϭ͘ϮϮ ϭϲ͘ϱϴ Ϭ͘ϬϳϰϮ ϵϰϴ͘ϬϬ Ϯϳϵ͘ϱϲ ϵϬ͘ϰϴWĞƌŝŽĚϮ͗ƵŝůĚƵƉ ϬϯͬϬϴͬϮϬ ϭϴ͗ϬϬ ϬϯͬϭϲͬϮϬ ϭϰ͗ϬϬ ϭϴϴ о о о о о о о о о о о оооо оWĞƌŝŽĚϯ͗&ƌĂĐϮ͕ůĞĂŶƵƉͬDĂŝŶ&ůŽǁ ϬϯͬϭϲͬϮϬ ϭϰ͗ϬϬ ϬϯͬϮϬͬϮϬϵ͗ϬϬ ϵϭ ϰϬ ϯϬϯ ϲϭ ϲϮϴ Ϭ ϭϮϯ ϭϬϰ ϱϯϲ͘ϳϲϳ Ϭ͘ϰϭ ϳϳϭ͘ϰϭ ϯϯϯ͘ϱϱ Ϭ͘ϳϰ ϭ͘ϱϳ ϮϵϮϰ͘ϵϮ ϭϮϲϰ͘ϳϭ Ϯ͘ϴϮWĞƌŝŽĚϰ͗ƵŝůĚƵƉ ϬϯͬϮϬͬϮϬ ϵ͗ϬϬ ϬϯͬϮϴͬϮϬ ϭϮ͗ϬϬ ϭϵϱ о о о о о о о о о о о о ооо оWĞƌŝŽĚϱ͗DĂdžZĂƚĞ ϬϯͬϮϴͬϮϬ ϭϮ͗ϬϬ ϬϯͬϮϵͬϮϬ Ϯ͗ϯϬ ϭϰ͘ϱ ϭϮϴ Ϯϲϵ ϱϮ ϱϴϳ Ϭ ϭϯϬ ϴϵ ϰϴϲ͘ϭϱ Ϭ͘ϲϵ ϭϰϮϰ͘ϭϴ ϲϭ͘ϭϯ ϴ͘ϱϲ Ϭ͘ϰϭϴϯ ϴϲϬ͘ϰϰ ϯϲ͘ϵϯ ϱ͘ϭϳKϮ;DĂdžŝŵƵŵͿ ϬƉƉŵ DĞĂƐƵƌĞĚ'ĂƐ Ϯ͘ϬϲϮϱ DDƐĐĨ,Ϯ^;DĂdžŝŵƵŵͿ ϬƉƉŵ DĞĂƐƵƌĞĚKŝů ϰϳϯϯ͘ϯϲ ďďůƐ'ĂƐ^ƉĞĐŝĨŝĐ'ƌĂǀŝƚLJ;ǀĞƌĂŐĞͿ Ϭ͘ϵϰϮ ŝƌсϭ DĞĂƐƵƌĞĚtĂƚĞƌ ϭϱϴϭ͘ϮϬďďůƐKŝů^ƉĞĐŝĨŝĐ'ƌĂǀŝƚLJ;ǀĞƌĂŐĞͿϮϴ͘ϵΣW/DĞĂƐƵƌĞĚ ŵƵůƐŝŽŶϵϴ͘ϰϳ ďďůƐ'KZ ϰϯϲ ;ƐĐĨͬƐƚďͿtĞůůĞĨĨůƵĞŶƚƐǁĞƌĞĨůŽǁĞĚŝŶƚŽĂƚŵŽƐƉŚĞƌŝĐƚĂŶŬƐ͕ĂůůĨůƵŝĚƌĂƚĞƐĂŶĚĂĐĐƵŵƵůĂƚŝǀĞƚŽƚĂůƐǁĞƌĞĐĂůĐƵůĂƚĞĚďĂƐĞĚŽŶƚĂŶŬƐƚƌĂƉƐĂŶĚ^ΘtƐƉŝŶŽƵƚƐƚĂŬĞŶĂƚƚŚĞƐĞƉĂƌĂƚŽƌŝŶůĞƚ͘'ĂƐǁĂƐĨůĂƌĞĚƚŽĂƚŵŽƐƉŚĞƌĞƚŚƌŽƵŐŚĂϭϬϬĨŽŽƚĨůĂƌĞƐƚĂĐŬ͘hDh>d/s sK>hD ^t >>WZD d Z^DŝƚƋƵƋϭ^ƚͲϭtĞůůdĞƐƚ^ƵŵŵĂƌLJ^ƚĂƌƚ ŶĚWƌŽĐĞƐƐWĞƌŝŽĚƵŵƵůĂƚŝǀĞdŽƚĂůƐĂůĐƵůĂƚĞĚϮϰͲ,ŽƵƌZĂƚĞ K'&ƌŽŵϭϬͲϰϬϳ tĞůůŽŵƉůĞƚŝŽŶZĞƉŽƌƚ ŽdžϮϮͲ>ŽŐƐKďƚĂŝŶĞĚ tĞůů͗DŝƚƋƵƋϭ^dϭ WdηϮϭϵͲϭϱϭͬ^ƵŶĚƌLJηΖƐϯϭϵͲϱϱϯ͕ϯϮϬͲϭϬϵ͕ϯϮϬͲϬϵϵ >t ^ƵŝƚĞͬdŽŽůƐͲ>t , ĂƚĞ/Ŷ ĂƚĞKƵƚ ĞƉƚŚ/Ŷ ĞƉƚŚKƵƚ E'ZͲZ ^Ͳ'ZͲ^ŽŶŝĐ ηϴ ϮͬϴͬϮϬϮϬ ϮͬϭϬͬϮϬϮϬ ϮϱϬϬΖ ϰϮϵϭΖ E'ZͲZ ^Ͳ'ZͲ^ŽŶŝĐ ηϭϭ ϮͬϭϯͬϮϬϮϬ ϮͬϭϱͬϮϬϮϬ ϰϲϱϮΖ ϱϮϱϬΖ DƵĚůŽŐ /ŶƚĞƌǀĂů ^ĐĂůĞ ϭ͟DƵĚ>ŽŐD ϬʹϱϮϱϬĨƚ ϭͬϲϬϬ ϭ͟DƵĚ>ŽŐds ϬʹϰϴϬϴĨƚ ϭͬϲϬϬ ϱ͟DƵĚ>ŽŐD ϬʹϱϮϱϬĨƚ ϭͬϮϰϬ ϭ͟ ŶŐŝŶĞĞƌŝŶŐ>ŽŐD ϬʹϱϮϱϬĨƚ ϭͬϲϬϬ ϭ͟'ĂƐ>ŽŐD ϬʹϱϮϱϬĨƚ ϭͬϲϬϬ tŝƌĞůŝŶĞ ZƵŶ dŽŽů^ƵŝƚĞ ,d DdŽƉ DĂƐĞ ĂƚĞ ƵƌĂƚŝŽŶ &ĂŝůƵƌĞͬ/ŶĐŝĚĞŶƚƐͬŽŵŵĞŶƚƐ ϯE'/Ͳ^^Ͳ/dͲ WĞƚƌŽŵĂĐ Ϯ͕ϰϵϱ͛ ϱ͕ϮϬϬ͛ ϮͬϭϱͬϮϬϮϬ ϵ͗ϱϬŚƌƐ EŽŶĞ ϯ DZͲ,E'^Ͳ W yͲE ydͲ WĞƚƌŽŵĂĐ Ϯ͕ϰϵϱ͛ ϱ͕ϮϬϬ͛ ϮͬϭϱͬϮϬϮϬ ϴ͗ϬϯŚƌƐ EŽŶĞ ϯyWdͲ WĞƚƌŽŵĂĐ ϰ͕ϯϯϱ͛ ϰ͕ϴϰϭ͛ ϮͬϭϱͲϭϲͬϮϬϮϬ Ϯϭ͗ϰϱŚƌƐ ϱϮƚĞƐƚƐ͘ ϯKZͲ WĞƚƌŽŵĂĐ ϰ͕ϯϱϭ͛ ϰ͕ϰϯϳ͛ ϮͬϭϲͲϭϳͬϮϬϮϬ ϮϬ͗ϮϯŚƌƐ ϮƐĂŵƉůĞƐƚĂƚŝŽŶƐ͘ŽůůĞĐƚĞĚϰƐĂŵƉůĞƐ͗ϮĂƚ ϰ͕ϯϱϭ͕͛ϮĂƚϰ͕ϰϯϳ͛͘'ŽƚƐƚƵĐŬĐŽŵŝŶŐŽƵƚƚ ϰ͕ϰϯϳ͛͘ĂŶĐĞůĞĚƚŚŝƌĚƐƚĂƚŝŽŶ͘ ϰ 'ZͲh^/d> ϭϭϰ Ϯϵϳ͛ ϱ͕Ϭϱϳ͛ ϮͬϮϮͬϮϬϮϬ ϰ͗ϭϬŚƌƐ EŽŶĞ ϰ 'ZͲs^/Ͳϰ ^ƵƌĨĂĐĞ ϱ͕ϬϮϬ͛ ϮͬϮϮͬϮϬϮϬ ϲ͗ϯϳŚƌƐ EŽŶĞ ϰ 'ZͲs^/ͲϮϬ ^ƵƌĨĂĐĞ ϱ͕ϬϮϬ͛ ϮͬϮϮͲϮϯͬϮϬϮϬ Ϭ͘ϯϳϮϵϭϲϲϲϳ tĂůŬͲĂǁĂLJ͕ϰϲƉŽŝŶƚƐ Schlumberger-Private FracCAT Treatment Report: Mitquq 1 ST1 Well : Mitquq 1 ST1 Field : Pikka East Formation : Nanushuk Well Location : County : Prudhoe Bay State : Alaska Country : United States Prepared for Client : OilSearch Alaska Client Rep : Scott Leahy Date Prepared : March 4, 2020 Prepared by Name : Alexander Martinez Division : Schlumberger Phone : 561 389 5006 Pressure (All Zones) Initial Wellhead Pressure (psi) 43 Initial BH ISIP (psi) 2,760 Maximum Treating Pressure (psi) 3,118 Final BH ISIP (psi) 2,787 Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbls) 886.7 Total YF122ST Past Wellhead (bbls) 574.1 Total WF122 Past Wellhead (bbls) 145.7 Total FP past WH (bbls) 65.9 Total 16/20 Carbolite Pumped (lbs) 74,620 Total Proppant in Formation (lbs.) 73,430 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103 (gal) 28 28 M275 (lbs.) 30 12 J580 (lbs.) 692 650 J475 (lbs.) 165 165 L065 (gal) 60 60 B484 (gal) 2.12 0.64 J532 (gal) 173 173 J511 (lbs) 260 79 J450 (gal) 16 10 M002 (lbs) 15 15 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private Summary: On March 1st, 2020, Schlumberger performed a DataFrac and fracturing treatment on Oil Search’s Mitquq 1 ST1 well. The crew began firing equipment at 5am and throughout the morning of the job Schlumberger encountered several cold-weather issues, related to the frac pumps. There was a standby pump on location that was eventually swapped out with one of the problematic pumps, and we moved forward with 4 functioning frac pumps for the 20 bbl/min job. With 4 pumps on location, we had more than enough hhp on location to pump the job. Following a successful pressure test at 11:30am, Little Red Services went to pressure test their line on the IA and ran into issues. One of them being the spring-loaded pop-off (provided by SLB) popped-off at 3,500psi rather than the 2,900 that it was set to. SLB brought a backup pop-off that was swapped out so LRS could continue with the pressure tests. Once lines were pressure tested everyone gathered for a safety meeting. DataFrac: During the shutdown period after the FP displacement, LAS lines were ran out to begin priming and this is when the SLB operator found that two of the LAS discharge lines had ice plugs in them, this took approximately 30 mins to thaw out. During this time, SLB and the client elected to pump into the well twice in a effort to keep lines warm and the linear gel from freezing. The DataFrac went as planned. Freeze protect fluid was used on flush as the client was expecting to be shutdown for a while to analyze pressure decline and redesign the main fracture treatment. Fluid efficiency was found to be extremely high and the client elected to move forward with a 70k lbs stage. Main Treatment: The crew brought pumps on line to 15 bbl/min to verify good crosslink, once verified the rate was increased to 20 bbl/min. The first half of the frac went as planned, BHP displayed height growth which was to be expected. The maximum planned proppant concentration was 10PPA, this was also when the sand chief operator had to switch from bin 1 to bin 2 and the proppant hopper on the POD ran low causing the slurry density to oscillate as the POD proppant gate was opening and closing, searching for the correct slurry density. Once we had reached the desired amount of proppant, sand was cut at the chief, allowing the hopper to empty. The client had expressed interest in switching to freeze protect immediately after proppant was cut on surface in order to maximize the amount of freeze protect in the well, (to help with lifting it after the frac). The shallow design of the well meant that flush volume was just over 40bbls and the client wanted a 4 bbl underflush. The plan was to pump a volume of 36bbls of freeze protect on flush. Once the switch was made from crosslinked gel/sand to freeze protect a few pumps began jacking-off, this was noticed as treating pressure dropped by 800psi. According to the POD operator, discharge pressure was constant during the swap from gel to freeze protect. Knowing this, the drop in pressure was mostly likely caused by the pumps “cleaning up” the high proppant concentration with low viscous freeze protect fluid and only occurred for a moment. Slurry rate on freeze protect fluid can only be measured by pump proximity switches and when the pumps cavitate the computer still calculates as if the pumps were pumping at their normal efficiency, thus throwing off the “JOB_SLURRY” total. Final flush was called off of physical straps on the freeze protect transport. A measured 47 bbls of freeze protect was pumped from the transport. Surface line volume was estimated to be 10bbls, meaning 37 bbls made it into the well. It was estimated that we ended up with a 3-5bbl underflush. Once the frac fleet was rigged-down, slickline got on the well and ran in and tagged top of sand approximately 250ft above the bottom of the well, inside the 7” casing. 250ft of 7”, 26# casing equates to a little less than 5,400 lbs of 16/20 CarboLite in the bottom of the well. Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private Job Plots: Pressure Test Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private DataFrac FP DISP Warming lines Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private 16:23:08 16:43:58 17:04:48 17:25:38 17:46:28 Time - hh:mm:ss 0 500 1000 1500 2000 2500 3000 3500 Tr. Press - psi0 5 10 15 20 25 Slurry Rate - bbl/min0 5 10 15 20 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Disp FP Mitquq © Schlumberger 1994-2016 OilSearch Alaska Mitquq 1 ST1 01-Mar-2020 Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private Section 1: DataFrac As Measured Pump Schedule As Measured Pump Schedule Step # Step Name Slurry Volum e (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 FP Displace 30.4 4.1 7.5 WF122 1277 0 0 0 2 Shutdown 0 0 0 WF122 0 0 0 0 3 Warming Lines 14.7 3.9 4.1 WF122 617 0 0 0 4 Shutdown 0 0 0 WF122 0 0 0 0 5 Warming Lines 15.2 3.9 3.9 WF122 638 0 0 0 6 Shutdown 0 0 0 WF122 0 0 0 0 7 XL Check 30.7 14.2 2.9 WF122 1289 0 0 0 8 Calibration 150 19.8 7.7 YF122ST 6300 0 0 0 9 FP Flush 38.9 19 2.1 Freeze Protect 1634 0 0 0 Stage Pressures & Rates Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 FP Displace 4.1 4.6 1377 2128 286 2 Shutdown 0 0 805 1054 650 3 Warming Lines 3.9 4.2 1295 1590 688 4 Shutdown 0 0 689 1007 593 5 Warming Lines 3.9 4.2 1251 1471 668 6 Shutdown 0 0 857 1027 799 7 XL Check 14.2 20.2 1596 2087 740 8 Calibration 19.8 20.0 2259 2440 1594 9 FP Flush 19 20.7 2580 3321 905 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 279.9 28.2 11756 0 Average Treating Pressure: 1412 psi Maximum Treating Pressure: 3321 psi Minimum Treating Pressure: 286 psi Average Injection Rate: 10.8 bbl/min Maximum Injection Rate: 20.7 bbl/min Average Horsepower: 456.9 hhp Maximum Horsepower: 1309 hhp Maximum Prop Concentration: 0.0 PPA Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private Section 1: Main Treatment As Measured Pump Schedule As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 FP Displace 32.0 4.5 7.3 WF122 1344 0.0 0.0 0 2 XL Check 23.0 13.6 1.9 WF122 954 0.0 0.0 0 3 PAD 90.0 19.8 4.5 YF122ST 3777 0.0 0.0 0 4 1.0 PPA 50.1 20.0 2.5 YF122ST 2028 16/20 CarboLite (USA) 1.3 0.9 1742 5 2.0 PPA 50.0 20.0 2.5 YF122ST 1937 16/20 CarboLite (USA) 2.1 1.9 3731 6 4.0 PPA 70.5 20.0 3.5 YF122ST 2530 16/20 CarboLite (USA) 4.1 3.9 9833 7 6.0 PPA 80.8 20.0 4.0 YF122ST 2698 16/20 CarboLite (USA) 6.1 5.9 15876 8 8.0 PPA 90.4 19.9 4.5 YF122ST 2822 16/20 CarboLite (USA) 8.7 7.9 22312 9 10.0 PPA 73 19.8 3.5 YF122ST 2192 16/20 CarboLite (USA) 12.6 9.9 19983 10 FLUSH 47 19.9 2.4 Freeze Protect 1974 16/20 CarboLite (USA) 7.2 0.0 115 Stage Pressures & Rates Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 FP Displace 4.5 4.6 1517 1649 615 2 Shutdown 13.6 15.0 1857 2043 727 3 PAD 19.8 20.2 2162 2268 1772 4 1.0 PPA 20.0 20.1 2109 2192 2010 5 2.0 PPA 20.0 20.1 1876 2010 1794 6 4.0 PPA 20.0 20.2 1821 1880 1782 7 6.0 PPA 20.0 20.2 1978 2070 1858 8 8.0 PPA 19.9 20.0 2187 2264 2032 9 10.0 PPA 19.8 20.7 2246 2292 1962 10 FLUSH 19.9 20.5 2116 3118 217 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 606.8 37.2 22607 73591 Average Treating Pressure: 2034 psi Maximum Treating Pressure: 3118 psi Minimum Treating Pressure: 217 psi Average Injection Rate: 18.9 bbl/min Maximum Injection Rate: 20.7 bbl/min Average Horsepower: 952.7 hhp Maximum Horsepower: 1532.2 hhp Maximum Prop Concentration: 12.6 PPA Client : OilSearch Well : Mitquq ST1 Formation : Nanushuk District : PAK Country : United States Schlumberger-Private Section 2: Job Messages Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 Reset Executed Steps 0 0 0.0 0.0 0.0 2 Reset Executed Steps 0 0 0.0 0.0 0.0 3 16:28:25 Matched pressure 655 1435 0.0 0.0 0.0 4 16:28:52 Start FP Displace Automatically 622 1568 0.0 0.0 0.0 5 16:28:52 Start Propped Frac Automatically 622 1568 0.0 0.0 0.0 6 16:28:52 Start Mitquq 0219 Automatically 622 1568 0.0 0.0 0.0 7 16:28:59 Started Pumping 621 1601 0.0 0.0 0.0 8 16:29:13 Activated Extend Stage 618 1687 0.0 0.0 0.0 9 16:42:37 Deactivated Extend Stage 785 2602 32.0 0.0 0.0 10 16:42:38 Start Shutdown Automatically 785 2602 32.0 0.0 0.0 11 16:49:21 Activated Extend Stage 2058 2634 36.3 13.7 0.0 12 16:50:20 Stage at Perfs: FP Displace 1838 2619 51.0 15.0 0.0 13 16:50:36 Deactivated Extend Stage 1761 2634 55.0 15.0 0.0 14 16:50:36 Start PAD Manually 1761 2634 55.0 15.0 0.0 15 16:52:03 Stage at Perfs: Shutdown 2119 2599 83.1 20.2 0.0 16 16:53:12 Stage at Perfs: PAD 2262 2595 106.2 20.0 0.0 17 16:55:09 Start 1.0 PPA Automatically 2174 2590 145.3 20.2 0.0 18 16:55:09 Started Pumping Prop 2174 2590 145.3 20.2 0.0 19 16:57:39 Start 2.0 PPA Automatically 2012 2604 195.2 20.0 1.0 20 16:57:42 Stage at Perfs: 1.0 PPA 2003 2603 196.2 20.0 1.0 21 17:00:09 Start 4.0 PPA Automatically 1802 2608 245.1 20.0 2.0 22 17:00:12 Stage at Perfs: 2.0 PPA 1793 2608 246.1 20.0 2.0 23 17:02:42 Stage at Perfs: 4.0 PPA 1855 2621 296.1 20.0 4.0 24 17:03:41 Start 6.0 PPA Automatically 1866 2595 315.8 20.0 4.0 25 17:06:14 Stage at Perfs: 6.0 PPA 2042 2618 366.7 19.9 5.9 26 17:07:44 Start 8.0 PPA Automatically 2066 2594 396.6 20.0 6.1 27 17:10:18 Stage at Perfs: 8.0 PPA 2242 2616 447.7 19.9 8.0 28 17:12:16 Start 10.0 PPA Automatically 2226 2617 486.9 19.9 7.9 29 17:12:20 Activated Extend Stage 2240 2618 488.2 19.9 7.8 30 17:14:51 Stage at Perfs: 10.0 PPA 2256 2600 538.0 19.6 10.0 31 17:15:44 Deactivated Extend Stage 1503 2576 555.7 20.6 2.8 32 17:15:44 Start FLUSH Manually 1503 2576 555.7 20.6 2.8 33 17:17:56 Stage at Perfs: FLUSH 3050 2599 599.9 20.1 -3.1 34 17:21:59 Stopped Pumping Prop 1033 2530 606.8 0.1 -2.9 35 17:22:33 Monitoring pressures 1031 2518 606.8 0.0 0.0 36 18:12:23 Well is closed 677 9 606.8 0.0 0.0 37 18:12:32 Bleeding off pressure 670 10 606.8 0.0 0.0 38 18:13:21 Pressure is gone -113 9 606.8 0.0 0.0 39 18:13:29 End of job -114 9 606.8 0.0 0.0 Schlumberger-Private Pressure (All Zones) Initial Wellhead Pressure (psi) 291 DataFrac BH ISIP (psi) 2,780 Maximum Treating Pressure (psi) 3,554 Final BH ISIP (psi) 2,825 Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbls) 2054.4 Total YF125ST Past Wellhead (bbls) 1486.0 Total WF115 Past Wellhead (bbls) 183.9 Total FP past WH (bbls) 36 Total WF125 Past Wellhead (bbls) 92.3 Total Proppant Pumped (lbs.) 252,065 Total 16/20 CarboLite Pumped (lbs) 230,440 Total Estimated Proppant in Formation (lbs.) 250,097 Total 12/18 CarboLite Pumped (lbs.) 21,625 Total 12/18 CarboLite Left in hopper (lbs.) 1,535 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103 (gal) 69 69 M275 (lbs.) 30 25 J580 (lbs.) 1894 1820 J475 (lbs.) 440 440 L065 (gal) 144 144 B484 (gal) 3.17 2.35 J532 (gal) 375 375 J511 (lbs) 260 187 J450 (gal) 44 33 M002 (lbs) 31 31 Schlumberger-Private Schlumberger-Private 09:57:04 10:05:24 10:13:44 10:22:04 10:30:24 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 5 10 15 20 25 30 35 40 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Pressure Test © Schlumberger 1994-2016 Oil Search Mitquq ST1 Re Frac 03-12-2020 Schlumberger-Private 11:07:04 11:44:34 12:22:04 12:59:34 13:37:04 Time - hh:mm:ss 0 1000 2000 3000 4000 Tr. Press - psi0 5 10 15 20 25 30 35 40 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Match WH Press Displace FP LG Injection Test Data Frac Main Treatment © Schlumberger 1994-2016 Oil Search Mitquq ST1 Re Frac 03-12-2020 DataFrac:: Pre--Injection Tests Schlumberger-Private 13:33:44 14:02:54 14:32:04 15:01:14 15:30:24 Time - hh:mm:ss 0 1000 2000 3000 4000 Tr. Press - psi0 5 10 15 20 25 30 35 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 22 24 26 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Main Treatment © Schlumberger 1994-2016 Oil Search Mitquq ST1 Re Frac 03-12-2020 Schlumberger-Private 1 Load Hole 19.6 5.7 3.6 WF115 822 0 0 0 2 Shutdown 0 5.7 0 WF115 0 0 0 0 3 LG Injection 12.8 12.8 1.6 WF115 524 0 0 0 4 LG Injection 151.5 19.4 8.3 WF115 6363 0 0 0 5 XL Check 15.4 15.1 1.2 WF125 634 0 0 0 6 DataFrac 250 29.4 8.5 YF125ST 10492 0 0 0 7 LG Disp 30 24.7 1.3 WF125 1256 0 0 0 8 Freeze Prote 16 20 0.8 Freeze Protect 672 0 0 0 9 Warm Lines 21.5 8 3.6 WF125 916 0 0 0 10 XL Check 9.1 13.4 0.9 WF125 371 0 0 0 11 PAD 200 29.4 6.8 YF125ST 8391 0 0 0 12 1.0 PPA 100 30 3.3 YF125ST 4028 CarboLite 16/20 1.2 1 3901 13 2.0 PPA 150 29.9 5 YF125ST 5797 CarboLite 16/20 2.1 2 11479 14 4.0 PPA 226 28 8.1 YF125ST 8077 CarboLite 16/20 4.3 4 32268 15 6.0 PPA 251.8 27 9.3 YF125ST 8370 CarboLite 16/20 6.3 6 50381 16 8.0 PPA 251.8 25 10.1 YF125ST 7821 CarboLite 16/20 8.3 8 62890 17 10.0 PPA 237 23 10.3 YF125ST 6910 CarboLite 16/20 10.4 10 69521 18 12.0 PPA 65.5 20.1 3.5 YF125ST 1897 CarboLite 12/18 13.7 11.5 21625 19 XL Flush 15.0 16.8 0.3 YF125ST 630 0.8 0.1 0 20 LG Flush 16.3 16.8 0.3 WF125 685 0.0 0.0 0 21 Freeze Protect 20.0 18.7 2.5 Freeze Protect 840 0 0 0 Schlumberger-Private Schlumberger-Private Schlumberger-Private Schlumberger-Private Schlumberger-Private Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date: 3/12/2020State: AlaskaCounty/Parish North Slope BoroughAPI Number:50103208080100Operator Name: Oil Search AlaskaWell Name and Number:Mitquq 1 ST1Longitude: -150.328447765576Latitude: 70.3306645723066Long/Lat Projection: Production Type: True Vertical Depth (TVD): 4275Total Water Volume (gal)*: 102380 Hydraulic Fracturing Fluid Composition Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments YF122ST:WF122:YF125ST:WF125:WF115 Schlumberger Enzyme Breaker B484, Surfactant , Stabilizing Agent, Breaker J475, Crosslinker, Gel J580, Scale Inhibitor, Additive, Bactericide, Propping Agent Water (Including Mix Water Supplied by Client)* CAS Not Assigned 71.95467% Ceramic materials and wares, chemicals 66402-68-4 97.79040% 27.42564% Guar gum 9000-30-0 0.73986% 0.20749% 1, 2, 3 - Propanetriol 56-81-5 0.33619% 0.09428% Sodium tetraborate decahydrate 1303-96-4 0.27237% 0.07639% Diammonium peroxodisulphate 7727-54-0 0.14816% 0.04155% 2,2`,2"-nitrilotriethanol 102-71-6 0.14195% 0.03981% Ethylene glycol 107-21-1 0.12248% 0.03435% 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.11456% 0.03213% Sorbitol 50-70-4 0.07988% 0.02240% PROPAN-2-OL 67-63-0 0.04555% 0.01278% Schlumberger-Private Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments 2-butoxyethanol 111-76-2 0.04555% 0.01278% Ethoxylated C11 Alcohol 34398-01-1 0.04184% 0.01173% Vinylidene chloride/methylacrylate copolymer 25038-72-6 0.03212% 0.00901% Sodium chloride 7647-14-5 0.02314% 0.00649% Ethoxylated Alcohol 68131-39-5 0.02271% 0.00637% Sodium hydroxide 1310-73-2 0.01443% 0.00405% Calcium Chloride 10043-52-4 0.01169% 0.00328% Diatomaceous earth, calcined 91053-39-3 0.00556% 0.00156% Undecanol 112-42-5 0.00364% 0.00102% Non-crystalline silica (impurity) 7631-86-9 0.00185% 0.00052% 2,2''-oxydiethanol (impurity) 111-46-6 0.00124% 0.00035% Magnesium nitrate 10377-60-3 0.00111% 0.00031% Magnesium silicate hydrate (talc) 14807-96-6 0.00098% 0.00028% 5-chloro-2-methyl-2h-isothiazolol-3-one 26172-55-4 0.00060% 0.00017% Magnesium chloride 7786-30-3 0.00056% 0.00016% poly(tetrafluoroethylene) 9002-84-0 0.00042% 0.00012% Potassium chloride (impurity) 7447-40-7 0.00037% 0.00010% 2-methyl-2h-isothiazol-3-one 2682-20-4 0.00018% 0.00005% Sodium citrate 68-04-2 0.00015% 0.00004% Acetic acid, potassium salt 127-08-2 0.00014% 0.00004% Cristobalite 14464-46-1 0.00011% 0.00003% Quartz, Crystalline silica 14808-60-7 0.00011% 0.00003% Hemicellulase enzyme 9012-54-8 0.00008% 0.00002% Acetic acid (impurity) 64-19-7 0.00002% 0.00001% 1,2-benzisothiazolin-3-one 2634-33-5 < 0.00001% < 0.00001% Schlumberger-Private † Proprietary Technology * Total Water Volume sources may include fresh water, produced water, and/or recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Report ID: RPT-65941 (Generated on 3/30/2020 11:58 AM) All component information listed was obtained from the supplier’s Safety Data Sheets (SDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the SDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an SDS is subject to 29 CFR 1910.1200(i) and Appendix D. The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC-Chemicals as of the date of the document was produced. 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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 9:34 am, May 14, 2020 Abby Bell 05/18/2020 PTD: 2191510 E-Set: 33121-33137 LETTER OF TRANSMITTAL جؐؐؐAnalyses ؒ جؐؐؐFlash Gas ؒ ؒ Job44674.xls ؒ ؒ ؒ جؐؐؐMud Gas ؒ ؒ Job44375_Mitquq 1 ST1.xls ؒ ؒ ؒ جؐؐؐOil Samples - Gas Chromatogram ؒ ؒ ؒ ROSL-200401-002 Mitquq 1 ST1 4-1-20 4,438.67ft AS0460.xls ؒ ؒ ؒ ؒ ؒ ؤؐؐؐCore Plug Oil Extractions ؒ ؒ ROSL-200303-001 Mitquq 1 ST1 55GEO 4381.80ft.xls ؒ ؒ ROSL-200303-001 Mitquq 1 ST1 55GEO 4381ft.xls ؒ ؒ ROSL-200303-002 Mitquq 1 ST1 91GEO 4413ft.xls ؒ ؒ ROSL-200303-003 Mitquq 1 ST1 275GEO 4590ft.xls ؒ ؒ ROSL-200303-004 Mitquq 1 ST1 344GEO 4651ft.xls ؒ ؒ ؒ ؤؐؐؐPVT ؒ Mitquq 1 ST1 PVT Validation Final Report.xlsx ؒ جؐؐؐCore Data ؒ ؒ Alaska Field Coring Report Mitquq 1 ST1 Core 1.pdf ؒ ؒ Alaska Field Coring Report Mitquq 1 ST1 Core 2.pdf ؒ ؒ Conventional core lab studies - requested extension request.txt ؒ ؒ Fluid sample analysis - requested extension request.txt ؒ ؒ Mitquq 1 ST1 Core Data.docx ؒ ؒ Mitquq Coring End of Well Report.pdf ؒ ؒ SCAL program for whole core plugs- requested extension request.txt ؒ ؒ ؒ ؤؐؐؐCore photos ؒ 4291.0-4309.0uv.jpg ؒ 4291.0-4309.0__c1.jpg ؒ 4309.0-4327.0.jpg ؒ 4309.0-4327.0uv.jpg ؒ 4327.0-4345.0.jpg ؒ 4327.0-4345.0uv.jpg ؒ 4345.0-4363.0.jpg T33121 T33122 LETTER OF TRANSMITTAL ؒ 4345.0-4363.0uv.jpg ؒ 4363.0-4381.0.jpg ؒ 4363.0-4381.0uv.jpg ؒ 4381.0-4399.0.jpg ؒ 4381.0-4399.0uv.jpg ؒ 4399.0-4417.0.jpg ؒ 4399.0-4417.0uv.jpg ؒ 4417.0-4435.0.jpg ؒ 4417.0-4435.0uv.jpg ؒ 4435.0-4453.0.jpg ؒ 4435.0-4453.0uv.jpg ؒ 4453.0-4471.0.jpg ؒ 4453.0-4471.0uv.jpg ؒ 4471.0-4472.7.jpg ؒ 4471.0-4472.7uv.jpg ؒ 4472.7-4490.0uv.jpg ؒ 4472.7-4490.0__c2.jpg ؒ 4490.0-4508.0.jpg ؒ 4490.0-4508.0uv.jpg ؒ 4508.0-4526.0.jpg ؒ 4508.0-4526.0uv.jpg ؒ 4526.0-4544.0.jpg ؒ 4526.0-4544.0uv.jpg ؒ 4544.0-4562.0.jpg ؒ 4544.0-4562.0uv.jpg ؒ 4562.0-4580.0.jpg ؒ 4562.0-4580.0uv.jpg ؒ 4580.0-4598.0.jpg ؒ 4580.0-4598.0uv.jpg ؒ 4598.0-4616.0.jpg ؒ 4598.0-4616.0uv.jpg ؒ 4616.0-4634.0.jpg ؒ 4616.0-4634.0uv.jpg ؒ 4634.0-4652.0.jpg ؒ 4634.0-4652.0uv.jpg ؒ 4652.0-4653.9.jpg ؒ 4652.0-4653.9uv.jpg LETTER OF TRANSMITTAL ؒ جؐؐؐDirectional Survey ؒ Mitquq 1 ST1 ASP Final Survey - NAD27.pdf ؒ Mitquq 1 ST1 ASP Final Survey - NAD27.xlsx ؒ جؐؐؐGeology ؒ جؐؐؐFinal Well Report ؒ ؒ OilSearch_Mitquq_1_ST1_Final Well Report.pdf ؒ ؒ ؒ جؐؐؐGeological Reports ؒ ؒ Mitquq 1 ST1 Compiled DGRs.pdf ؒ ؒ ؒ جؐؐؐMudlogging Final Data ؒ ؒ OilSearch_Mitquq_1_ST1_Drillgas_Depth_128_5250.las ؒ ؒ OilSearch_Mitquq_1_ST1_Drillgas_Time_08Feb2020_20Feb2020_LAS.zip ؒ ؒ OilSearch_Mitquq_1_ST1_DrillingLog_5250ft_MD.pdf ؒ ؒ OilSearch_Mitquq_1_ST1_GasRatioLog_5250ft_MD.pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Gas_IN-OUT_LAS_5250ftTD.las ؒ ؒ OilSearch_Mitquq_1_ST1_Isotubes_Inventory.pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Litholog_5250ftTD.las ؒ ؒ OilSearch_Mitquq_1_ST1_MasterLog_5250ft_5inMD.pdf ؒ ؒ OilSearch_Mitquq_1_ST1_MasterLog_5250ft_MD.pdf ؒ ؒ OilSearch_Mitquq_1_ST1_MasterLog_5250ft_TVD.pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Mudlogging_Sample_Inventory.pdf ؒ ؒ ؒ جؐؐؐOil, Gas and Gas Hydrate Shows List ؒ ؒ Mitquq 1 ST1 show reports.pdf ؒ ؒ ؒ ؤؐؐؐWell Prognosis ؒ Mitquq 1 ST1 Prognosis.docx ؒ جؐؐؐLog Digital Data and Plots (LWD and WL) جؐؐؐLWD ؒ جؐؐؐDigital Data ؒ ؒ جؐؐؐDLIS Data ؒ ؒ ؒ Mitquq_1_ST1_LWD_RM_5250ft.dlis ؒ ؒ ؒ Mitquq_1_ST1_LWD_RM_5250ft.html T33136 T33123 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ ؒ جؐؐؐLAS Data ؒ ؒ ؒ جؐؐؐDrilling Mechanics ؒ ؒ ؒ ؒ جؐؐؐDepth Data ؒ ؒ ؒ ؒ ؒ Mitquq_1_ST1_DMD_R1-3_5250ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐTime Data ؒ ؒ ؒ ؒ Mitquq_1_ST1_DMT_R01.las ؒ ؒ ؒ ؒ Mitquq_1_ST1_DMT_R02.las ؒ ؒ ؒ ؒ Mitquq_1_ST1_DMT_R03.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐLWD Real Time Data ؒ ؒ ؒ ؒ Mitquq_1_ST1_LWD_R1-3_5250ft_RT.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLWD Recorded Mode Data ؒ ؒ ؒ Mitquq_1_ST1_LWD_R1-3_5250ft.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLWD Processed Data ؒ ؒ ؤؐؐؐSonic ؒ ؒ جؐؐؐR7_8.5in_2310-4205ft_MD ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft.dlis ؒ ؒ ؒ Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐR8_8.5in_4190_4480ft_MD ؒ ؒ ؤؐؐؐDTCO ؒ ؒ Mitquq_1ST1_R8_8.5in_sonicVISION675_DTCO_4190-4480ft.dlis ؒ ؒ Mitquq_1ST1_R8_8.5in_sonicVISION675_DTCO_4190-4480ft.las ؒ ؒ ؒ ؤؐؐؐPlots ؒ ؒ Mitquq SLB DD EOWR.pdf ؒ ؒ ؒ جؐؐؐEOW Letter ؒ ؒ OilSearch_Mitquq_1_ST1_EOW.doc ؒ ؒ OilSearch_Mitquq_1_ST1_EOW.pdf ؒ ؒ ؒ جؐؐؐLog Data LETTER OF TRANSMITTAL ؒ ؒ جؐؐؐDrilling Mechanics ؒ ؒ ؒ جؐؐؐDepth Data ؒ ؒ ؒ ؒ Mitquq_1ST1_DMD_R1-3_5250ft.Pdf ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐTime Data ؒ ؒ ؒ Mitquq_1ST1_DMT_R01.Pdf ؒ ؒ ؒ Mitquq_1ST1_DMT_R02.Pdf ؒ ؒ ؒ Mitquq_1ST1_DMT_R03.Pdf ؒ ؒ ؒ ؒ ؒ ؤؐؐؐLWD Logs ؒ ؒ Mitquq_1ST1_VISION_Sonic_2MD.Pdf ؒ ؒ Mitquq_1ST1_VISION_Sonic_2TVD.Pdf ؒ ؒ Mitquq_1ST1_VISION_Sonic_5MD.Pdf ؒ ؒ Mitquq_1ST1_VISION_Sonic_5TVD.Pdf ؒ ؒ ؒ جؐؐؐLWD Processed Data ؒ ؒ ؤؐؐؐSonic ؒ ؒ جؐؐؐR7_8.5in_2310-4205ft_MD ؒ ؒ ؒ ؤؐؐؐDTCO ؒ ؒ ؒ Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft.pdf ؒ ؒ ؒ Mitquq_1ST1_R7_8.5in_sonicVISION_DTCO_2310-4205ft_QC_Rt_vs_Rm.pdf ؒ ؒ ؒ ؒ ؒ ؤؐؐؐR8_8.5in_4190_4480ft_MD ؒ ؒ ؤؐؐؐDTCO ؒ ؒ Mitquq_1ST1_R8_8.5in_sonicVISION675_DTCO_4190-4480ft.pdf ؒ ؒ ؒ ؤؐؐؐSurvey Data ؒ Mitquq_1ST1_ASP Final Survey - NAD27.pdf ؒ Mitquq_1ST1_ASP Final Survey - NAD27.xlsx ؒ Mitquq_1ST1_ASP Final Survey - NAD83.pdf ؒ Mitquq_1ST1_ASP Final Survey - NAD83.xlsx ؒ ؤؐؐؐWL جؐؐؐDigital Data ؒ جؐؐؐCased_hole ؒ ؒ جؐؐؐCH Processed ؒ ؒ ؒ ؤؐؐؐMitquq_1ST1_Run_4C_Processed_VSP_Results LETTER OF TRANSMITTAL ؒ ؒ ؒ جؐؐؐ4B ZVSP-4 ؒ ؒ ؒ ؒ ؤؐؐؐSEGY ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Corridor_Stack_8-40Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Corridor_Stack_8-50Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Corridor_Stack_8-60Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Corridor_Stack_8-70Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Corridor_Stack_8-96Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-40Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-50Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-60Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-70Hz.segy ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-96Hz.segy ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐ4C WVSP-20 ؒ ؒ ؒ ؒ Requested Extension letter.txt ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐConcise ؒ ؒ ؒ Mitquq1ST1_CheckshotReport_P.xlsx ؒ ؒ ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_4A_USIT-CBL_22Feb20 ؒ ؒ ؒ Mitquq 1ST1_Run_4A_USIT-CBL_Main_Pass.dlis ؒ ؒ ؒ Mitquq 1ST1_Run_4A_USIT-CBL_Repeat Pass.dlis ؒ ؒ ؒ ؒ ؒ ؤؐؐؐMitquq_1_ST1_Run_4E_HSD_Gun_23Feb20 ؒ ؒ Mitquq 1ST1_Run_4E_Confirmation Pass_23Feb20.dlis ؒ ؒ Mitquq 1ST1_Run_4E_Shooting_Pass_23Feb20.dlis ؒ ؒ ؒ جؐؐؐRun3_OH ؒ ؒ جؐؐؐMitquq 1ST1_Run_3A_NGI-SS-ZAIT_15Feb20 ؒ ؒ ؒ Mitquq 1ST1_Run_3A_NGI_MAST_ZAIT_CAL.dlis ؒ ؒ ؒ Mitquq 1ST1_Run_3A_NGI_MAST_ZAIT_CAL.las ؒ ؒ ؒ ؒ ؒ جؐؐؐMitquq 1ST1_Run_3B_CMR-HNGS-PEX-NEXT ؒ ؒ ؒ Mitquq_1ST1_Run 3B_NEXT-PEX-HNGS-CMR_Repeat_Pass.las ؒ ؒ ؒ Mitquq_1ST1_Run_3B_NEXT-PEX-HNGS-CMR_Main_Pass.dlis ؒ ؒ ؒ Mitquq_1ST1_Run_3B_NEXT-PEX-HNGS-CMR_Main_Pass.las ؒ ؒ ؒ Mitquq_1ST1_Run_3B_NEXT-PEX-HNGS-CMR_Repeat_Pass_.dlis T33124 T33125 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ ؒ جؐؐؐMitquq 1ST1_Run_3C_XPT_15Feb20 ؒ ؒ ؒ جؐؐؐCustomer DLIS ؒ ؒ ؒ ؒ Mitquq_1_ST1_Run_3C_Sta006_XPT.dlis ؒ ؒ ؒ ؒ Mitquq_1_ST1_Run_3C_Sta010_XPT.dlis ؒ ؒ ؒ ؒ Mitquq_1_ST1_Run_3C_Sta012_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta001_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta002_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta003_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta004_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta005_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta007_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta008_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta009_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta011_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta013_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta014_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta016_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta018_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta020_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta022_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta024_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta025_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta026_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta027_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta028_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta029_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta030_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta031_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta032_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta033_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta034_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta035_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta036_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta037_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta038_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta039_XPT.dlis T33126 LETTER OF TRANSMITTAL ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta040_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta041_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta042_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta043_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta044_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta045_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta046_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta047_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta048_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta049_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta050_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta051_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta052_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta053_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta054_XPT.dlis ؒ ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta055_XPT.dlis ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta015_XPT.dlis ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta017_XPT.dlis ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta019_XPT.dlis ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta021_XPT.dlis ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta023_XPT.dlis ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐCustomer LAS ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3CSta055_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta001_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta002_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta003_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta004_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta005_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta006_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta007_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta008_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta009_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta010_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta011_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta012_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta013_XPT.las LETTER OF TRANSMITTAL ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta014_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta015_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta016_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta017_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta018_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta019_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta020_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta021_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta022_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta023_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta024_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta025_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta026_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta027_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta028_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta029_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta030_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta031_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta032_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta033_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta034_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta035_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta036_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta037_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta038_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta039_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta040_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta041_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta042_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta043_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta044_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta045_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta046_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta047_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta048_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta049_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta050_XPT.las LETTER OF TRANSMITTAL ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta051_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta052_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta053_XPT.las ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta054_XPT.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐMitquq 1ST1_Run_3D_ORA-GR_16Feb20 ؒ ؒ Mitquq_1_ST1_Run 3D_ORA_Correlation Log.las ؒ ؒ Mitquq_1_ST1_Run 3D_ORA_Sta001.las ؒ ؒ Mitquq_1_ST1_Run 3D_ORA_Sta002.las ؒ ؒ Mitquq_1_ST1_Run_3D_ORA_Correlation Log.dlis ؒ ؒ Mitquq_1_ST1_Run_3D_ORA_Sta001.dlis ؒ ؒ Mitquq_1_ST1_Run_3D_ORA_Sta002.dlis ؒ ؒ ؒ ؤؐؐؐRun3_Processed ؒ جؐؐؐMitquq_1_ST1_Run_3A_Processed_QGEO ؒ ؒ Mitquq 1ST1_QGEO_Dip_Interpretation_2500_5091ftMD.las ؒ ؒ Mitquq 1ST1_QGEO_Sandcount_BIN_Pc_CumulativeThickness_PseudoGR_4300_5088ftMD.las ؒ ؒ Mitquq1ST1_QGEO_PROCESSED_IMAGES_2500_5092 ftMD.dlis ؒ ؒ OilSearch_Mitquq1_ST1_SandCount Zones.xlsx ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_3A_Processed_SonicScanner ؒ ؒ Mitquq 1ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.dlis ؒ ؒ Mitquq_1_ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.las ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_3B_Processed_CMR ؒ ؒ Mitquq 1ST1_Run_3B_8.5in_CMR_Depth_Shifted_NGI.las ؒ ؒ Mitquq 1ST1_Run_3B_8.5in_CMR_Processed_4144_5150ft.las ؒ ؒ Mitquq_1_ST1_Run_3B_8.5in_CMR_Processed_4144_5150ft.dlis ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_3B_Processed_LithoScanner ؒ ؒ Mitquq_1ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.dlis ؒ ؒ Mitquq_1ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.las ؒ ؒ Mitquq_1ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.las ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_3B_Processed_RTScanner ؒ ؒ Mitquq 1ST1_Run_3B_RTScanner_1D_Inversion_Best_2495-5190ft.las T33127 T33128 T33129 T33130 T33131 T33132 LETTER OF TRANSMITTAL ؒ ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_2495-5190ft.dlis ؒ ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_39_2495-5190ft.las ؒ ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_54_2495-5190ft.las ؒ ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_72_2495-5190ft.las ؒ ؒ Mitquq_1_ST1_Run_3B_RTScanner_Data_2495-5190ft.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3B_LSA_558-5214ft.dlis ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3B_LSA_558-5214ft.las ؒ ؒ ؒ ؤؐؐؐMitquq_1_ST1_Run_3C_Processed_XPT-Ora19 ؒ OilSearch_Mitquq_1_ST1_Run_3C_8.5in_XPT_Test_Point_Table.xlsx ؒ ؤؐؐؐPlots جؐؐؐCased_hole ؒ جؐؐؐCH Processed ؒ ؒ جؐؐؐMitquq_1_ST1_Run_4A_Processed_Cement_Results ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_4A_Cement_Evaluation_Log_25Feb20.pdf ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_4A_Cement_Evaluation_Report_25Feb20.pdf ؒ ؒ ؒ ؒ ؒ ؤؐؐؐMitquq_1_ST1_Run_4C_Processed_VSP_Results ؒ ؒ جؐؐؐ4B ZVSP-4 ؒ ؒ ؒ جؐؐؐCHECKSHOT ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_CheckshotReport_P.pdf ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_CheckshotReport_P.prn ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_CheckshotReport_P.xlsx ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐREPORT ؒ ؒ ؒ ؒ Oil_Search_Mitquq_1ST1_WSR_ZVSP_Report.pptx ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐSEGY ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Corridor_Stack_8-40Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Corridor_Stack_8-50Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Corridor_Stack_8-60Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Corridor_Stack_8-70Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Corridor_Stack_8-96Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-40Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-50Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-60Hz.segy T33133 LETTER OF TRANSMITTAL ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-70Hz.segy ؒ ؒ ؒ Mitquq_1ST1_ZVSP_Synthetic_Seismogram_8-96Hz.segy ؒ ؒ ؒ ؒ ؒ جؐؐؐ4C WVSP-20 ؒ ؒ ؒ Requested extension letter.txt ؒ ؒ ؒ ؒ ؒ جؐؐؐConcise ؒ ؒ ؒ OilSearch_Mitquq1ST1_CheckshotReport_P.pdf ؒ ؒ ؒ OilSearch_Mitquq1ST1_CheckshotReport_P.xlsx ؒ ؒ ؒ OilSearch_Mitquq1ST1_ObserversNotes.xls ؒ ؒ ؒ OilSearch_Mitquq1ST1_ZVSP_WVSP_Report.pdf ؒ ؒ ؒ OilSearch_Mitquq1ST1_ZVSP_WVSP_Report.pptx ؒ ؒ ؒ ؒ ؒ ؤؐؐؐFinal full reports not available yet ؒ جؐؐؐOilSearch_Mitquq_1_ST1_Run_4A_USIT-CBL_22Feb20 ؒ ؒ Mitquq_1_ST1_Run_4A_USIT-CBL_Repeat Pass.dlis ؒ ؒ OilSearch_Mitquq_1_ST1_Run_4A_5in_CBL_22Feb20.Pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Run_4A_5in_USIT_22Feb20.Pdf ؒ ؒ Mitquq_1_ST1_Run_4A_USIT-CBL_Main_Pass.dlis ؒ ؒ ؒ ؤؐؐؐOilSearch_Mitquq_1_ST1_Run_4E_HSD_Gun_23Feb20 ؒ Mitquq_1_ST1_Run_4E_Confirmation Pass_23Feb20.dlis ؒ Mitquq_1_ST1_Run_4E_Shooting_Pass_23Feb20.dlis ؒ OilSearch_Mitquq_1_ST1_Run_4E_4.5in_HSD_Gun_23Feb20.Pdf ؒ جؐؐؐRun3_OH_8.5in ؒ جؐؐؐMitquq_1_ST1_Run_3A_NGI-SS-ZAIT_15Feb20 ؒ ؒ Mitquq_1_ST1_Run_3A_NGI_MAST_ZAIT_CAL_15Feb20.dlis ؒ ؒ Mitquq_1_ST1_Run_3A_NGI_MAST_ZAIT_CAL_15Feb20.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3A_5in_MSIP_15Feb20.Pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3A_5in_NGI_15Feb20.Pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3A_5in_ZAIT_15Feb20.Pdf ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_3B_CMR-HNGS-PEX-NEXT ؒ ؒ Mitquq_1 ST1_Run_3B_NEXT-PEX-HNGS-CMR_Repeat_Pass.dlis ؒ ؒ Mitquq_1_ST1_Run 3B_NEXT-PEX-HNGS-CMR_Repeat_Pass.las ؒ ؒ Mitquq_1_ST1_Run_3B_NEXT-PEX-HNGS-CMR_Main_Pass.dlis T33134 T33135 LETTER OF TRANSMITTAL ؒ ؒ Mitquq_1_ST1_Run_3B_NEXT-PEX-HNGS-CMR_Main_Pass.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3B_5in_CMR_15Feb20.Pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3B_5in_HNGS_15Feb20.Pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3B_5in_NEXT_15Feb20.Pdf ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3B_5in_PEX_15Feb20.Pdf ؒ ؒ ؒ جؐؐؐMitquq_1_ST1_Run_3C_XPT_15Feb20 ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_5in_XPT_15Feb20.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐCustomer DLIS ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta001_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta002_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta003_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta004_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta005_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta007_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta008_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta009_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta011_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta013_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta014_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta016_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta018_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta020_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta022_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta024_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta025_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta026_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta027_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta028_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta029_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta030_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta031_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta032_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta033_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta034_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta035_XPT.dlis LETTER OF TRANSMITTAL ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta036_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta037_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta038_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta039_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta040_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta041_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta042_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta043_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta044_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta045_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta046_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta047_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta048_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta049_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta050_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta051_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta052_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta053_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta054_XPT.dlis ؒ ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta055_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta006_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta010_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta012_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta015_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta017_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta019_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta021_XPT.dlis ؒ ؒ ؒ Oil_Search_Mitquq_1_ST1_Run_3C_Sta023_XPT.dlis ؒ ؒ ؒ ؒ ؒ ؤؐؐؐCustomer LAS ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3CSta055_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta001_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta002_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta003_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta004_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta005_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta006_XPT.las LETTER OF TRANSMITTAL ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta007_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta008_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta009_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta010_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta011_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta012_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta013_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta014_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta015_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta016_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta017_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta018_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta019_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta020_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta021_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta022_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta023_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta024_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta025_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta026_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta027_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta028_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta029_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta030_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta031_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta032_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta033_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta034_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta035_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta036_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta037_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta038_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta039_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta040_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta041_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta042_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta043_XPT.las LETTER OF TRANSMITTAL ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta044_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta045_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta046_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta047_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta048_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta049_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta050_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta051_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta052_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta053_XPT.las ؒ ؒ OilSearch_Mitquq_1_ST1_Run_3C_Sta054_XPT.las ؒ ؒ ؒ ؤؐؐؐMitquq_1_ST1_Run_3D_ORA-GR_16Feb20 ؒ Mitquq_1_ST1_Run 3D_ORA_Correlation Log.las ؒ Mitquq_1_ST1_Run 3D_ORA_Sta001.las ؒ Mitquq_1_ST1_Run 3D_ORA_Sta002.las ؒ Mitquq_1_ST1_Run_3D_ORA_Correlation Log.dlis ؒ Mitquq_1_ST1_Run_3D_ORA_Sta001.dlis ؒ Mitquq_1_ST1_Run_3D_ORA_Sta002.dlis ؒ OilSearch_Mitquq_1_ST1_Run_3D_5in_ORA-GR_16Feb20.Pdf ؒ ؤؐؐؐRun3_Processed جؐؐؐMitquq_1_ST1_Run_3A_Processed_QGEO_28Feb20 ؒ Mitquq 1ST1_QGEO_Sandcount_BIN_Pc_CumulativeThickness_PseudoGR_4300_5088ftMD.las ؒ Mitquq 1_ST1_QGEO_Dip_Interpretation_2500_5091ftMD.las ؒ OilSearch_Mitquq1_ST1_QGEO_Image_Interpretation_5in_2500_5092 ftMD.pdf ؒ OilSearch_Mitquq1_ST1_QGEO_Image_Interpretation_60in_2500_5092 ftMD.pdf ؒ OilSearch_Mitquq1_ST1_QGEO_PROCESSED_IMAGES_2500_5092 ftMD.dlis ؒ OilSearch_Mitquq1_ST1_QGEO_Sand_Counting_20in_4300_5088 ftMD.pdf ؒ OilSearch_Mitquq1_ST1_QGEO_Sand_Counting_5in_4300_5088 ftMD.pdf ؒ OilSearch_Mitquq1_ST1_QGEO_Sand_Counting_60in_4300_5088 ftMD.pdf ؒ OilSearch_Mitquq1_ST1_SandCount Zones.xlsx ؒ جؐؐؐMitquq_1_ST1_Run_3A_Processed_SonicScanner_21Feb20 ؒ Mitquq_1ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.dlis ؒ Mitquq_1ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.las LETTER OF TRANSMITTAL ؒ Mitquq_1ST1_Run_3A_SonicScanner_PnS-Aniso_2500-5118ft.pdf ؒ جؐؐؐMitquq_1_ST1_Run_3B_Processed_CMR_15Feb20 ؒ Mitquq_1_ST1_Run_3B_8.5in_CMR_Advisor_4144_5150ft.pdf ؒ Mitquq_1_ST1_Run_3B_8.5in_CMR_Depth_Shifted_NGI.las ؒ Mitquq_1_ST1_Run_3B_8.5in_CMR_Processed_4144_5150ft.dlis ؒ Mitquq_1_ST1_Run_3B_8.5in_CMR_Processed_4144_5150ft.las ؒ جؐؐؐMitquq_1_ST1_Run_3B_Processed_LithoScanner_18Feb20 ؒ Mitquq_1_ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.dlis ؒ Mitquq_1_ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.las ؒ Mitquq_1_ST1_Run_3B_LithoScanner_RBF_CEC_4144-5200ft.pdf ؒ Mitquq_1_ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.las ؒ Mitquq_1_ST1_Run_3B_Lithoscanner_SPEC_TOC_4144-5200ft.pdf ؒ جؐؐؐMitquq_1_ST1_Run_3B_Processed_RTScanner_15Feb20 ؒ Mitquq_1_ST1_Run_3B_LSA_558-5214ft.dlis ؒ Mitquq_1_ST1_Run_3B_LSA_558-5214ft.las ؒ Mitquq_1_ST1_Run_3B_LSA_558-5214ft.pdf ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_2495-5190ft.dlis ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_2495-5190ft.pdf ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_39_2495-5190ft.las ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_54_2495-5190ft.las ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_72_2495-5190ft.las ؒ Mitquq_1_ST1_Run_3B_RTScanner_1D_Inversion_Best_2495-5190ft.las ؒ Mitquq_1_ST1_Run_3B_RTScanner_Data_2495-5190ft.las ؒ ؤؐؐؐMitquq_1_ST1_Run_3C_Processed_XPT-Ora19Feb20 OilSearch_Mitquq_1_ST1_Run_3C_8.5in_Ora_Testing_Report.pdf OilSearch_Mitquq_1_ST1_Run_3C_8.5in_XPT_Pressure_Results.pdf OilSearch_Mitquq_1_ST1_Run_3C_8.5in_XPT_Test_Point_Table.xlsx ؒ ؤؐؐؐWell Testing Mitquq 1ST1 Final Well Test Field Report.xlsx Mitquq 1ST1 Final Well Test Report.pdf T33137 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 1ST1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Mitquq ST1 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 1ST1 50-103-20808-0100 Conventional Core Laboratory Studies- Porosity & Permeability – Core Lab – estimated August 2020 Mitquq 1ST1 50-103-20808-0100 Analysis of Fluid Samples – Core Lab – estimated August 2020 Mitquq 1ST1 50-103-20808-0100 SCAL Program for whole core plugs – estimated August 2020 Mitquq 1ST1 50-103-20808-0100 WVSP-20 Data Set – estimated May 30, 2020 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � 4((I(Mzx DATE: 4/2/2020 P. I. Supervisor � I FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector Mitquq 1 ST1 Oil Search PTD 219-151; Sundry 320-099 4/2/2020: 1 traveled out to the ice pad where Mitquq #1 ST1 exploration well is located for a wellhead cutoff and marker plate inspection. Vance Yoakum was on location representing Oil Search for this inspection. The wellhead was cut below the minimum required depth and there was hard cement at surface in all casing strings. The marker plate had the correct information on it and was easily readable. Vance supplied me with a few photos after cutting off the wellhead prior to topping it off which are attached. Attachments: Photos (4) 2020-0402_Surface_Abandon_Mitquq 1-ST 1 _ll.docx Pagel of 3 e yr O C co Q � U X N r � G n a� ca N J � J ao . U Cr Q G � lZ �ey �1 t� �T m N. ,. .� �� � �: ,:" . _,�' .� �� ��. ��� �i . +� � U O ^O H N c�U. L. N O O O N O N MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �q�C� DATE: March 30, 2020 P.I. Supervisor % SUBJECT: Well Bore Plug & Abandonment Mitquq 1 ST1 FROM: Lou Laubenstein Oil Search _ Petroleum Inspector PTD 2191510; Sundry 320-099 Section: 3 Township: 11 N Range: 7E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 5250 ft MD Lease No.: ADL 0393876 Operator Rep: Vance Yoakum Suspend: P&A: X Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 16" -O.D. Shoe@ 128 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 2495 - Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 5236 - Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3.5" O.D. Tail@ 4513 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Retainer 4505 ft MD- 3293 ft MD- Wireline tag Initial 15 min 3n min 45 min Result Tubing 2251 2170 2118 IA 2215 2135 2083 P OA Initial 15 min '10 min 45 min Result Tubing IA OA Remarks: I arrived on location to witness a tag and pressure test on first plug in the abandonment of Mitquq 1 ST1. Wireline was used to perform the tag and included a bailer with 2501b of weight in the string. Top of cement was tagged @ 3293 feet MD. The bailer returned with a good sample of cement. A 2000 psi, 30 minute pressure test was completed without any issues and had a passing result. Attachments: none rev. 11-28-18 2020-0330_Plug_Verification_M itquq 1-ST1 _II 0l,l--lSl 1-7- -3 --7-- LETTER OF TRANSMITTAL I/ ►v IV Search DATE: 3/16/2020 To: From: Shannon Koh Meredith Guhl Oil Search Alaska LLC AOGCC 333 W. 7th Avenue, Suite 100 900 E. Benson Blvd., Level 6 Anchorage, AK 99501 Anchorage, AK 99508 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑CD ❑Thumb Drive ®External Request ❑Email ❑SharePoint ❑Internal Request ®Hardcopy []Other REASON FOR TRANSMITTAL: ❑To Be Returned ❑Approved ❑Information Only [--]With Our Comments ❑Approved with Comments El For Your Review ®Required pursuant to 20 AAC 25.071 El For Approval ❑For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) nFTAn QTY DESCRIPTION 4 Boxes of Core Chip Samples MITQUQ 1ST1 (50-103-20808-0100) Details on following pages 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 RI LIAR 16 2020 t`I► t Core L.ah na[xvon orta¢nnor ECoc#: 7568 Date: 15 Mar 2020 External Chain of Custody Record 6316 Windfern Road Houston, TX 77040 Phone: 1-713-328-2673 Fax: Contact: Daniel Burch Phone: +1 713 328 2471 EMail: Daniel. Burch@corelab.com *Please check the Notes at the bottom for important information. Client: OIL SEARCH (ALASKA), LLC P.O. BOX 240927 ANCHORAGE AK States 99524-0927 Contact: Water O'Hayer Phone: Job( 202001222) has 363 Samples Well: Mitquq-1 ST01 Client Ref# Depthl (ft) 1 4291.00 2 4292.00 3 4293.15 4 4294.00 5 4295.10 6 4296.15 7 4297.00 8 4298.15 9 4299.00 10 4300.00 11 4301.00 12 4302.00 13 4303.00 14 4304.00 15 4305.00 16 4306.00 17 4307.20 18 4308.35 19 4309.00 20 4310.00 21 4311.00 22 4312.00 23 4313.25 24 4314.15 25 4315.00 26 4316.15 27 4317.20 28 4318.00 29 4319.20 Depth2(ft) Length Consignee: AOGCC United 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Contact: Meredith Guhl Phone: Sample Type CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK CHUNK Page 1 of 8 4320.00 CHUNK 4321.00 CHUNK 4322.10 CHUNK 4323.00 CHUNK 4324.00 CHUNK 4325.15 CHUNK 4326.00 CHUNK 4327.00 CHUNK 4328.35 CHUNK 4329.00 CHUNK 4330.00 CHUNK 4331.35 CHUNK 4332.00 CHUNK 4333.00 CHUNK 4334.10 CHUNK 4335.35 CHUNK 4336.00 CHUNK 4337.00 CHUNK 4338.00 CHUNK 4339.00 CHUNK 4340.45 CHUNK 4341.40 CHUNK 4342.00 CHUNK 4343.00 CHUNK 4344.00 CHUNK 4345.00 CHUNK 4346.00 CHUNK 4347.00 CHUNK 4348.00 CHUNK 4349.00 CHUNK 4350.00 CHUNK 4351.00 CHUNK 4352.20 CHUNK 4353.00 CHUNK 4354.00 CHUNK 4355.00 CHUNK 4356.00 CHUNK 4357.00 CHUNK 4358.20 CHUNK 4359.00 CHUNK 4360.00 CHUNK 4361.00 CHUNK 4362.00 CHUNK 4363.00 CHUNK 4364.00 CHUNK 4365.00 CHUNK 4366.00 CHUNK 4367.00 CHUNK 4368.00 CHUNK 4369.00 CHUNK 4370.10 CHUNK 4371.00 CHUNK 4372.00 CHUNK 4373.00 CHUNK 4374.45 CHUNK 4375.00 CHUNK Page 2 of 8 4376.00 CHUNK 4377.00 CHUNK 4378.00 CHUNK 4379.50 CHUNK 4380.80 CHUNK 4381.00 CHUNK 4382.05 CHUNK 4383.00 CHUNK 4384.00 CHUNK 4385.00 CHUNK 4386.00 CHUNK 4387.00 CHUNK 4388.00 CHUNK 4389.00 CHUNK 4390.00 CHUNK 4391.00 CHUNK 4392.20 CHUNK 4393.00 CHUNK 4394.00 CHUNK 4395.00 CHUNK 4396.00 CHUNK 4397.30 CHUNK 4398.20 CHUNK 4399.00 CHUNK 4400.00 CHUNK 4401.00 CHUNK 4402.00 CHUNK 4403.00 CHUNK 4404.00 CHUNK 4405.00 CHUNK 4406.00 CHUNK 4407.00 CHUNK 4408.00 CHUNK 4409.00 CHUNK 4410.00 CHUNK 4411.00 CHUNK 4412.00 CHUNK 4413.00 CHUNK 4414.00 CHUNK 4415.00 CHUNK 4416.05 CHUNK 4417.00 CHUNK 4418.00 CHUNK 4419.00 CHUNK 4420.00 CHUNK 4421.30 CHUNK 4422.20 CHUNK 4423.00 CHUNK 4424.00 CHUNK 4425.00 CHUNK 4426.00 CHUNK 4427.00 CHUNK 4428.00 CHUNK 4429.00 CHUNK 4430.15 CHUNK 4431.00 CHUNK Page 3 of 8 4432.00 CHUNK 4433.05 CHUNK 4434.05 CHUNK 4435.00 CHUNK 4436.00 CHUNK 4437.00 CHUNK 4438.00 CHUNK 4439.00 CHUNK 4440.00 CHUNK 4441.00 CHUNK 4442.40 CHUNK 4443.15 CHUNK 4444.00 CHUNK 4445.00 CHUNK 4446.00 CHUNK 4447.00 CHUNK 4448.05 CHUNK 4449.00 CHUNK 4450.00 CHUNK 4451.00 CHUNK 4452.10 CHUNK 4453.00 CHUNK 4454.00 CHUNK 4455.00 CHUNK 4456.00 CHUNK 4457.10 CHUNK 4458.00 CHUNK 4459.00 CHUNK 4460.05 CHUNK 4461.00 CHUNK 4462.00 CHUNK 4463.00 CHUNK 4464.00 CHUNK 4465.00 CHUNK 4466.35 CHUNK 4467.00 CHUNK 4468.00 CHUNK 4469.00 CHUNK 4470.00 CHUNK 4471.00 CHUNK 4472.75 CHUNK 4473.00 CHUNK 4474.00 CHUNK 4475.00 CHUNK 4476.00 CHUNK 4477.10 CHUNK 4478.00 CHUNK 4479.40 CHUNK 4480.00 CHUNK 4481.00 CHUNK 4482.00 CHUNK 4483.20 CHUNK 4484.00 CHUNK 4485.00 CHUNK 4486.00 CHUNK 4487.00 CHUNK Page 4 of 8 4488.00 CHUNK 4489.00 CHUNK 4490.00 CHUNK 4491.00 CHUNK 4492.00 CHUNK 4493.00 CHUNK 4494.05 CHUNK 4495.30 CHUNK 4496.00 CHUNK 4497.25 CHUNK 4498.20 CHUNK 4499.00 CHUNK 4500.00 CHUNK 4501.20 CHUNK 4502.00 CHUNK 4503.35 CHUNK 4504.05 CHUNK 4505.40 CHUNK 4506.05 CHUNK 4507.05 CHUNK 4508.00 CHUNK 4509.00 CHUNK 4510.15 CHUNK 4511.00 CHUNK 4512.00 CHUNK 4513.00 CHUNK 4514.00 CHUNK 4515.00 CHUNK 4516.20 CHUNK 4517.00 CHUNK 4518.05 CHUNK 4519.10 CHUNK 4520.00 CHUNK 4521.00 CHUNK 4522.00 CHUNK 4523.00 CHUNK 4524.00 CHUNK 4525.00 CHUNK 4526.00 CHUNK 4527.00 CHUNK 4528.00 CHUNK 4529.00 CHUNK 4530.00 CHUNK 4531.00 CHUNK 4532.00 CHUNK 4533.00 CHUNK 4534.05 CHUNK 4535.00 CHUNK 4536.15 CHUNK 4537.15 CHUNK 4538.00 CHUNK 4539.20 CHUNK 4540.00 CHUNK 4541.00 CHUNK 4542.30 CHUNK 4543.00 CHUNK Page 5 of 8 4544.00 CHUNK 4545.30 CHUNK 4546.35 CHUNK 4547.00 CHUNK 4548.00 CHUNK 4549.05 CHUNK 4550.00 CHUNK 4551.20 CHUNK 4552.00 CHUNK 4553.00 CHUNK 4554.00 CHUNK 4555.00 CHUNK 4556.00 CHUNK 4557.00 CHUNK 4558.00 CHUNK 4559.00 CHUNK 4560.00 CHUNK 4561.00 CHUNK 4562.00 CHUNK 4563.35 CHUNK 4564.05 CHUNK 4565.00 CHUNK 4566.00 CHUNK 4567.00 CHUNK 4568.00 CHUNK 4569.45 CHUNK 4570.05 CHUNK 4571.00 CHUNK 4572.25 CHUNK 4573.20 CHUNK 4574.00 CHUNK 4575.00 CHUNK 4576.00 CHUNK 4577.00 CHUNK 4578.00 CHUNK 4579.50 CHUNK 4580.00 CHUNK 4581.00 CHUNK 4582.00 CHUNK 4583.00 CHUNK 4584.10 CHUNK 4585.25 CHUNK 4586.00 CHUNK 4587.55 CHUNK 4588.10 CHUNK 4589.00 CHUNK 4590.25 CHUNK 4591.15 CHUNK 4592.00 CHUNK 4593.00 CHUNK 4594.00 CHUNK 4595.00 CHUNK 4596.00 CHUNK 4597.00 CHUNK 4598.00 CHUNK 4599.25 CHUNK Page 6 of 8 310 311 312 313 314 315 316 317 318 319 320 321 322 323 324 325 326 327 328 329 330 331 332 333 334 335 336 337 338 339 340 341 342 343 344 345 346 347 348 349 350 351 352 353 354 355 356 357 358 359 360 361 362 363 4600.25 CHUNK 4601.00 CHUNK 4602.40 CHUNK 4603.00 CHUNK 4604.00 CHUNK 4605.00 CHUNK 4606.00 CHUNK 4607.00 CHUNK 4608.35 CHUNK 4609.00 CHUNK 4610.00 CHUNK 4611.00 CHUNK 4612.30 CHUNK 4613.00 CHUNK 4614.00 CHUNK 4615.00 CHUNK 4616.00 CHUNK 4617.00 CHUNK 4618.00 CHUNK 4619.00 CHUNK 4620.50 CHUNK 4621.00 CHUNK 4622.00 CHUNK 4623.15 CHUNK 4624.00 CHUNK 4625.00 CHUNK 4626.20 CHUNK 4627.00 CHUNK 4628.00 CHUNK 4629.00 CHUNK 4630.00 CHUNK 4631.00 CHUNK 4632.10 CHUNK 4633.40 CHUNK 4634.00 CHUNK 4635.20 CHUNK 4636.00 CHUNK 4637.00 CHUNK 4638.00 CHUNK 4639.00 CHUNK 4640.00 CHUNK 4641.10 CHUNK 4642.00 CHUNK 4643.00 CHUNK 4644.00 CHUNK 4645.00 CHUNK 4646.00 CHUNK 4647.00 CHUNK 4648.15 CHUNK 4649.00 CHUNK 4650.35 CHUNK 4651.00 CHUNK 4652.00 CHUNK 4653.80 CHUNK Total: Sample:363 Page 7 of 8 Prepared By : Daniel Burch Please sign, date, & return copy to Core L, ✓ia e-mail, fax, or mail. Date : 15 Mar 2020 Total Samples : 363; Total Boxes : 0; Total Pallets : 0 Received By Notes : State of Alaska Chip Samples —1-111", � Date: 3' 1 ' 7z Page 8 of 8 LETTER OF TRANSMITTAL (A 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. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99508 TRANSMISSION TYPE: TRANSMISSION METHOD: NExternal Request El CD ❑ Thumb Drive ❑Internal Request ❑Email ❑SharePoint NHardcopy ❑Other REASON FOR TRANSMITTAL: ❑Approved ❑Information Only ❑To Be Returned ❑Approved with Comments ❑For Your Review ❑with Our Comments ❑For Approval El For Your Use NRequired pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION MITQUQ 1ST1 (50-103-20808-0100) 4 Boxes of Dry Samples Details on following page Received by: Date: 3 I 2-0I�pJ DS Ple si 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 MAR 11 2020 AOGCC LETTER OF TRANSMITTAL (P Oil Search Number of Owned Total Box No. Description Samples By Frequency Depth (ft) Weight Ibs 1 of 4 Washed & dried 30 AOGCC 4' to 2414' 2410-3250 6.00 samples in envelopes 26' to 2440' 30' to 3250' 2 of 4 Washed & dried 30 AOGCC 30' 3250-4150 6.00 samples in envelopes 3 of 4 Washed & dried 30 AOGCC 30' to 4270' 4150-4570 6.00 samples in envelopes 20' to 4290' 10' to 4430' 8' to 4438' 22' to 4470' 10' to 4570' 4 of 4 Washed & dried 28 AOGCC 10' to 4650' 4570-5250 6.00 samples in envelopes 30' to 5250' THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Marc Kuck Senior Drilling Manager Oil Search Alaska PO Box 240927 Anchorage, AK 99524-0927 Re: Exploratory Field, Exploratory Pool, Mitquq 1 ST1 Permit to Drill Number: 219-151 Sundry Number: 320-109 Dear Mr. Kuck: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov 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, Daniel T. Seamount, Jr. Commissioner RBDMS(46w MAR 1 31010 DATED this 6 day of March, 2020. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAr gs 7Rn LIAR 0 9 2020 ,* f 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 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: Refrac ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:$ /✓ Oil Search Alaska Exploratory Q Development ❑ Stratigraphic ❑ Service ❑ 219-151 3. Address: 6. API Number: PO Box 240927 Anchorage, AK 99524-0927 03-20808-01-00 7. If perforating: 8. Well N e and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Mitquq 1 ST1 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLfl393876 • A �j$ cj'C 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): 5,250 4,808 4,547 4,275 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 Production 5,236' 7" 5,236' 4,798' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: (ft): 4,547 - 4,552 4,275 3-1/2" L80 rublrigMD 4,513 Packers and SSSV Type: Halliburton PHL Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): No SSSV 4,488' MD/4,228' TVD 12. Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory Q Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/10/2020 OIL❑ WINJ ❑ WDSPL ❑ Suspended ❑ 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: Marc Kuck Contact Name: Marc Kuck Authorized Title: Senior Engineering Manager Contact Email: marc.kuck oilsearch.com art "a- KULVC 3 � ZcZc Contact Phone:907-375-46000 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 320—� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: gBDMSL -J "1 LJ MAR 13 2020 Post Initial Injection MIT Req'd? Yes EJ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION J 0 Date: LI Form 10-403 Revised 4/2017 13/1 0 Approved application is valid for 12 months from the date of approval ORIGINAL s5c Submit Form and Attachments in Duplicate _(:;c, r 5 � 31vc.-,11,0U - 1) (0) Oil Search Mitquq 1 ST1 Sundry Application Requirements 1. Affidavit of Notice —Attachment A 2. Plat showing well location, as well as %z mile radius around well with all well penetrations, fractures, and faults within that radius — Attachments B and F 3. Identification of freshwater aquifers within % mile radius — There are no known underground sources of drinking water within a half mile radius of the current proposed well bore trajectory for Mitquq 1 ST1. At the Mitquq 1 ST1 location, the Permafrost interval extends down to approximately 1S00 ft and therefore, no known shallow aquifers are located at the Mitquq 1 ST1 location. 4. Plan for freshwater sampling — There are no known freshwater wells proximal to the proposed operations, therefore no water sampling is planned. 5. Detailed casing and cementing information —Attachment C 6. Assessment of casing and cementing operations — Assessment of casing and cementing operations will be performed after cementing operations are complete. 7. Casing and tubing pressure test information — Pressure testing will be performed upon completion of the well's lateral section. 8. Pressure ratings for wellbore, wellhead, BOPE and treating head — Attachment D 9. a-d Lithological and geological descriptions of each zone —Attachment E and below Nanushuk Reservoir Interval Lithologic Description: The Nanushuk Formation reservoir lithology is a thick accumulation of shallow marine outer -shelf sandstone deposits. The formation sandstone is laminated and grades into the silty -shale dominated Torok Formation immediately beneath it. The sandstones are fine-grained to very fine grained. The prograding sandstone unit at the top of the reservoir is overlain by a transgressive zone compromised of shales and siltstones which constitutes a seal. The fracture gradient for this sealing shale is 15.8-16.2 ppg. Depth & Thickness: 4382ft MD/4091ft TVDSS, —400ft TVT Upper Confining Unit: Seabee Formation Lithologic Description: The Seabee Formation immediately overlies the Nanushuk Formation. The base of the Seebee is the shale wall facies which is a marine flooding surface composed of condensed mudstone facies deposited during a maximum transgression and creates a good regional seal. Distant volcanism occurred during its deposition resulting in numerous bentonite interbeds. The overall Seabee Formation is a thick shale/claystone dominated unit which represents the distal deep -water slope and basinal deposits. The claystones within the Seebee Formation are described as medium grey to dark grey, soft and mushy to slightly firm, locally partings along laminations, commonly micas and scattered very fine lithic grains. Grading to weakly fissile shale. The fracture gradient for this sealing shale is 15.6-15.8 ppg. Depth & Thickness: 3196ft MD/3110ft TVDSS, —8SOft TVT Lower Confinine Units: Torok Formation Lithologic Description: The Torok Formation underlie the target reservoir Nanushuk Formation and are dominantly comprised of claystones and silty shales and thick shale sequences. The formation grades from silty shales in the shallower section to shale at the base of the Torok Formation. The shales are described in offset wells as very fine grained medium dark grey to dark brownish and greyish black. Soft to easily friable, occasionally firm. Tabular to platy cuttings with very well -developed laminations. Very organic overall with layers of organic/carbonaceous material. The fracture gradient for this sealing shale is 16.4-16.6ppg. Depth & Thickness: 5200 MD/5135 TVDSS, —250ft TVT Lower Confinine Units: Hue Shale (HR Lithologic Description: The Hue Shale/HRZ is a very condensed distal shale that is equivalent in time to the Torok and Nanushuk Formations. The shale is described in offset wells as very dark with slight brownish hues. The shale is firm to increasingly hard and dense with local abundant organic debris and carbonaceous material. It is a regionally present formation and is consistently 200-250ft thick. The fracture gradient for this sealing shale is 16.5-17.Oppg. Depth & Thickness: 5900TVDSS, —100ft TVT e. Estimated fracture pressure for each zone listed below: Held IA IA PRV (psi) GORY (psi) Pump Trip Pressure Pressure (psi) (psi) Job 2,600 2,900 5,400 5,000 Treatment MD Perf TVD Perf Max Frac Frac Y2 Max Rate Max Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. (psi) (PPA) Job Max 4,547 4,275 274.2 219.0 30 3,635 10 10. Mechanical condition of wells transecting the confining zones — No wells within 1/2-mile radius of Mitquq 1 ST1. Please see attachment B as reference. 11. Location of faults and fractures in wellbore % mile radius — Based on the seismic and well data covering the Mitquq 1 ST1 location, there is one identified fault interpreted to be located within a half mile radius of the wellbore trajectory. Seismic interpretation of the Nanushuk 9 reservoir and internal interpretation surfaces has determined that there are no faults of seismic resolution within the half mile radius (Attachment F). Oil Search does not expect that any hydraulic fractures during the stimulation of Mitquq 1 ST1 will intersect any faults near the wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, Oil Search will flush and terminate the stage immediately. 12. Detailed proposed fracturing program —Attachments G & H 13. Flowback procedure — Attachment I Section (b) Casing Pressure Test — We will not be treating through production or intermediate casing strings. Section (c) Fracture String Pressure Test — Attachment J Section (d) Pressure Relieve Valve —Attachment K Proposed Wellbore Schematic —Attachment L Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones, who, being duly sworn according to law, deposes and says: 1. 1, Timothy Jones, am the Land Manager for Oil Search (Alaska), LLC and a Registered Professional Landman #84167. 2. The Owners, Landowners, Surface Owners and Operators, as defined in relevant state statutes and regulations, identified in the attached Notice of Operations are correct to the best of my knowledge. 3. The well location in the attached Exhibit A was taken from Oil Search (Alaska), LLC's Permit to Drill submitted to AOGCC. 4. The attached Notice of Operations was sent to the identified Owners, Landowners, Surface Owners and Operators by certified mail. Further the affiaik sayeth naught. ^I 1 - Timothy Jon s RPL #84167 UNITED STATES OF AMERICA § STATE OF ALASKA jVV/q Date ll= Subscribed and sworn to before me on the day of December, 2019. E LIRETTE Notary Public Public f Alaska My commission expires:xpires Jul 21, 2023 Attachment A (P Oil Search December 4, 2019 Owners, Landowners, Surface Owners and Operators See Distribution List Colville River Area North Slope Basin, Alaska Re: Notice of Operations under 20 AAC 25.283 of Oil Search (Alaska), LLC's Sundry Application for a Fracture Stimulation for the Proposed Mitquq 1 STl Sidetrack Well Dear Owner, Landowner, Surface Owner and/or Operator Oil Search (Alaska), LLC (OSA) is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the proposed Mitquq 1 ST1 sidetrack well. This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(1)(A) and 20 AAC 25.283(a)(1)(B). The complete application is available for review upon request. If you wish to review the application, please contact Tim Jones, Land Manager, at the following: Tim Jones Land Manager Oil Search (Alaska), LLC PO Box 240927 Anchorage, AK 99524 Direct: 907-375-4624 tim.iones@oilsearch.com OSA, through a search of the public record, has identified you as an Owner, Landowner, Surface Owner or Operator (as defined in AOGCC regulations) within''/: mile of the proposed Mitquq 1 ST1 sidetrack well trajectory and fracture stimulation. Please contact me should you require additional information. LandM er Oil Search Alaska, LLC Anchorage office Tel _ +t 907 375 4600 PO Box 240927 Fax +1 907 375 4630 Anchorage. AK 99524.0927 www o ]search corn Attachment A Distribution List: Alaska Division of Oil and Gas ASK Exploration, LLC Oil Search (Alaska), LLC Repsol E&P USA Inc. (1) Oil Search Attachment A (1) Oil Search Contact Information: State of Alaska Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 ASRC Exploration, LLC Attn: Teresa Imm 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Oil Search (Alaska), LLC 510 L Street, Suite 310 Anchorage, AK 99501 Repsol E&P USA Inc. Attn: Dennis Henderson 2455 Technology Forest Blvd. The Woodlands, TX 77381 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 CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL Attachment A ADL 391910 _ - _ �, , �. -•- --�-_ Operator: ASRC Subsurface Owner: ADNi Surface Owner; State ASRC: 100% i — + — U011N007E02 U01IN007E01 UO11N007E04 U011N007E03 + ADL 391023 / \ Operator.ASRC 1 \ Subsurface Omer: ADNR $ Surface Owner: State 1 MITQUQ I BHL ASRC: 100% t, -__ 1 -A- MITQUQ 1 S L '----____- ADL3 875 +-___ MITQUQ 1 STI BHL i Operator: OI SEARCH ` .r...� jr,..4.»,....... Subsurface ner:ADNR/ \ ADL 393876 surface er state ask,1% \ Operator OIL SEARCH REPSO ; 49 Subsurface Owner: ADNR Surface Owner: State / ♦ OSA 51% REPSOL: 49% J / or \ \ / r \ / N007E09 �" U011 U01 1 N007E 10 + + + _ — — U011N007E12 U011N007EI1 ADL 391910 i Operator ASRC Subsurface Owner: ADNR Surface Owner: State + ASRC: 100% n 1 C i ADL 393564 Operator. 6RPC U011 N007E16- S Surfac ce Owner. ADNR Surface owner: state U01 1 N007E 15 U01 1 N007E 14 U01 1 N007E 13 CARACOL 52.5% _ TP NS DEV: 47.5% I _ _ j 0.5-MILE BUFFER ® r _ _ I ---- -- WELL PATHLINE OIL SEARCH ALASKA LLC. 2018-2019 EXPLORATION CAMPAIGN � SECTION Mitquq 1 Well Area • BOTTOM HOLE Oil Search ICE ROADS/PADS N 0 400 800 ®Feet GCS: NAD 1927 StatePlane Alaska 4 FIPS 5004 ��) SURFACE HOLE _ LEASE BOUNDARY W Attachment B ®Meters DATE: 12/3/2019. REV: 1.0. By: JB S 0 100 200 Document name' OPS-19-20-W-PE-M Mitqugl rrocSuntlry iCer n Service Oil Search Alaska, LLC For: Garret Staudinger Mitquq-1 7" Two -Stage Production Job Date: February 19w, 2020 Sincerely, Savannah Afoa Attachment C Leal Notice Warning Disclaimer Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. Limitations of Liability Except as expressly set forth herein, there are no representations or warranties by Halliburton, express or implied, including implied warranties of merchantability and/or fitness for a particular purpose. In no event will Halliburton or its suppliers be liable for consequential, incidental, special, punitive or exemplary damages (including, without limitation, loss of data, profits, use of hardware, or software). Customer accepts full responsibility for any investment made based on results from the Software. Any interpretations, analyses or modeling of any data, including, but not limited to Customer data, and any recommendation or decisions based upon such interpretations, analyses or modeling are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and assumptions are not infallible, and with respect to which professional may differ. Accordingly, Halliburton cannot and does not warrant the accuracy, correctness or completeness of any such interpretation, recommendation, modeling or other products of the Software Product. As such, any interpretation, recommendation or modeling resulting from the Software for the purpose of any drilling, well treatment, production or financial decision will be at the sole risk of Customer. Under no circumstances will Halliburton or its suppliers be liable for any damages. V) 2015 1lalliburton. All Rights Reserved Attachment C HALLIBURTON Table of Contents Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job 1.0 Executive Summary..................................................................................................................................... 4 2.0 Job Information............................................................................................................................................ 5 2.1 First Stage Job Actuals.................................................................................................................................................................................................................5 2.2 Second Stage Job Actuals.............................................................................................................................................................................................................5 3.0 Real -Time Job Summary ............................................................................................................................. 6 4.0 Job Chart ...................................................................................................................................................... 9 4.1 First Stage Job Chart .....................................................................................................................................................................................................................9 4.2 First Stage Displacement............................................................................................................................................................................................................10 4.3 Inflate Packer and Open Tool.....................................................................................................................................................................................................11 4.4 Inflate Packer..............................................................................................................................................................................................................................12 4.5 Second Stage Job Chart..............................................................................................................................................................................................................13 4.6 Second Stage Displacement........................._.............................................................................................................................................................................14 5.0 Lab Results................................................................................................................................................. 15 5.1 12.0# First Stage Lead Bulk Test Results...................................................................................................................................................................................15 5.2 15.3# First Stage Tail Bulk Test Results.....................................................................................................................................................................................19 5.3 12.0# Second Stage Lead Bulk Test Results...............................................................................................................................................................................22 5.4 15.3# Second Stage Tail Bulk Test Results.................................................................................................................................................................................25 Page 3 iCem' Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 1.0 Executive Summary Mr. Staudinger, Customer: Oil Search Alaska, LLC Job: Mitquq-17" Two -Stage Production Cement Job Halliburton appreciates the opportunity to perform the cementing services on Mitquq ST-1. The service supervisor arrived on location at 11:30 on February 18`h, 2020 in order to run the shoe track and ESIPC in hole. On February 19' casing was TD'd at 4,960' MD There was a safety meeting held on the rig with all relevant personnel in preparation for the cement job and the job began at 14:01 with HAL filling lines with 5 bbl of fresh water. A low pressure test was conducted to test the eKOs to 1000 psi followed by a high pressure test to 4000 psi. Both pressure tests were successful. When pressure was bled off the job commenced with 34 bbl of 11.5 ppg Tuned Prime Spacer pumped at 2.7 bpm, after which the bypass plug was dropped as witnessed by the company man. The cement unit then began pumping 27.3 bbl of lead cement. The average density was 12.0 ppg and it was pumped at 2.8 bpm. This was followed by 43.4 bbl of 15.3 lb/gal tail cement. The unit shutdown after tail cement to drop the shutoff plug as witnessed by the company man and then came back online with 5 bbl of fresh water to clear lines. Pumping was switched to the rig and 189.7 bbl of 10.4 lb/gal MOBM was pumped to complete displacement. FCP was 800 psi and pressure was increased to 1250 psi. The floats were checked and were holding so the rig began to inflate the packer. No pressure drops were noticed, so pressure was held at 2100 psi for 3 minutes. There was approximately 60 psi that bled off during this time, indicating that the packer was inflating. Pressure was increased to 2200 psi and held for 6 minutes during which time another 20 psi bled off. Pressure was increased to 2404 psi when pressure bled off, indicating that the rupture disks had burst and the tool was open for the second stage cement job. A total of 2.6 bbl of fluid was used while inflating the packer. All of the spacer was circulated to surface as well as trace amounts of cement. The second stage began at 19:50 with HAL pumping 30.4 bbl of 11.4 ppg Tuned Prime Spacer pumped at 2.6 bpm followed by 60.2 bbl of lead cement. The average density was 12.0 ppg and it was pumped at 3.4 bpm. HAL then pumped 17.6 bbl of tail cement. The first 6 bbl were pumped at an average density of 14.2 ppg while bringing cement to density, and the final 11.6 bbl was pumped at an average density of 15.2 ppg. There was a shutdown after drop the closing plug as witnessed by the company man and then came back online with 5 bbl of fresh water to clear lines. Pumping was switched to the rig and 80 bbl of 10.4 lb/gal MOBM was pumped to complete displacement. FCP was 550 psi when the plug landed and the tool was shifted closed at 1300 psi. The rig bled pressure off to check for flowback and there was none, indicating that the tool was closed. The job was ended at 21:15. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton Energy Services again thanks you for the opportunity to perform services work on this well. We hope to be your solutions provider for future projects. Thank You, Savannah Afoa Technical Professional — Cement and Casing Equipment 6900 Arctic Blvd. Anchorage, AK 99518 Email: savannah. afoa6bluilliburton.com Mobile: +1 907-223-9423 Office: +1 907-273-3568 "Design and Deliver Dependable Barriers Tailored to Minimize Risk and Maximize Production" Page 4 iCem�Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 2.0 Job inforination 2.1 First Stage Job Actuals Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Fluid Target Volume Actual Volume Average Density Target Density Avera a Rate bbls bbls b m 11.5# Tuned Prime Spacer 30 34.0 11.5 11.5 2.7 12.0# Lead Cement 30.6 27.3 12.0 12.0 2.8 15.3# Tail Cement 37.5 43.4 15.3 15.3 2.6 2.2 Second Stage Job Actuals Page 5 Fluid Target Volume Actual Volume Average Density Target Density Average Rate (bbls) bbls) ( ) ( ) (b m) 11.5# Tuned Prime Spacer 30 30.4 11.4 11.5 2.6 12.0# Lead Cement 59 60.2 12.0 12.0 3.4 15.3# Tail Cement 15.5 17.6 14.9 15.3 2.7 iCem" Service (v. 4.2.393) Created: Wednesday, May 10", 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job 3.0 Real-Timc Job Summary Seq. Graph Label Date Time DS Pump Press DH Density Comb Pump Pump Stg Tot Comments No. Rate (psi) (ppg) (bbl/min) (bbl) 22 Start Job 2/19/2020 14:01:01 -4.95 0.51 0.00 0.00 23 Fill Lines 2/19/2020 14:02:32 -5.15 0.51 0.00 0.00 Fill Lines 5 BBL fresh water. 24 Low Pressure Test 2/19/2020 14:07:18 144.18 8.89 0.52 5.08 1000 PSI. Electronic kickouts functioned. 25 High Pressure Test 2/19/2020 14:10:42 3890.02 9.12 0.00 5.12 4000 PSI 26 Pump Spacer 2/19/2020 14:21:33 -2.02 8.68 1.48 0.02 Pump 30 BBL Tuned Prime Spacer. 11.S PPG, 1.18 CUFT/SK, 27 Drop Bypass Plug 2/19/2020 14:36:13 79.11 11.63 0.00 1.21 28 Pump Lead 2/19/2020 14:46:16 26.77 12.07 0.00 1.21 30.6 BBL, 12 PPG, 2.19CUFT/SK, 11.77GAL/SK 29 Pump Tail 2/19/2020 14:57:14 622.68 14.44 3.15 5.62 37.5 BBL, 15.3 PPG, 1.24 CUFT/SK, 5.59 GAL/SK 30 Drop Shut Off Plug 2/19/2020 15:11:45 17.07 15.43 0.00 43.40 31 HES Pumps S BBL Fresh Water 2/19/2020 15:15:31 809.98 14.85 4.78 0.36 5 BBL fresh water is pumped following the shut off plug, then swap to rig for remaining displacement. 32 Rig Pumps Remaining Displacement 2/19/2020 15:19:00 -3.22 8.64 0.00 5.44 5 BPM, slow to 3 BPM when each plug passes through tool. 33 End Job 2/19/2020 15:21:42 -3.62 0.28 0.00 5.44 34 Bump Plug 2/19/2020 16:07:00 Total Displacement: 5 BBL fresh + 3288 rig strokes. Stroke Factor:.0577 iCerr' Service (v. 4.2.393) Page 6 Created: Wednesday, May 101h, 2017 Attachment C HALLIBURTON Customer: oil search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job FCP: 800 PSI @ 3 BPM, Pressure up to 1250 after bump and hold 5 min. 35 Check Floats 2/19/2020 16:07:00 Floats Holding Slowly walk pressure up 2046 PSI hold for 3 minutes. then 36 Inflate Packer 2/19/2020 16:16:00 pressure to 2175 and hold for 6 minutes. About 50 psi drop witnessed in this time. Slowly walk up to rupture PSI of 2175 and begin to circulate. 37 Rupture Disks and Circulate 2/19/2020 16:25:00 30 BBL Spacer and trace Cement circulated to surface. Second Stage Pre Job Safety 38 _ 2/19/2020 18:15:00 Meeting 39 Standby While Rig Changes Screens 2/19/2020 19:33:49 40 Start Job 2/19/2020 19:48:49 -5.98 0.15 0.00 0.00 41 Pump Spacer 2/19/2020 20:03:37 -4.41 0.16 0.00 0.00 30 BBL, 11.5PPG, 1.18 CUFT/SK 42 Pump Lead Cement 2/19/2020 20:15:17 213.79 11.70 2.79 0.47 59 BBL, 12 PPG, 2.4 CUFT/SK, 14.23 GAL/SK 43 Pump Tail Cement 2/19/2020 20:32:37 113.58 12.70 1.86 0.02 44 Drop Closing Plug 2/19/2020 20:41:09 16.13 15.26 0.00 17.63 Halliburton starts displacement with 5 BBI Fresh Water and 45 HIES Pumps S Fresh Behind Plug 2/19/2020 20:44:10 188.75 15.09 2.62 17.80 then swaps to rig for remaining displacement. Rig Pumps Remainder of 46 2/19/2020 20:46:00 -1.04 8.35 0.00 22.78 5 BPM, 600 PSI, Average. Displacement 47 End Job 2/19/2020 20:50:08 -5.97 -0.11 0.00 0.00 iCem' Service (v. 4.2.393) Page 7 - Created: Wednesday, May 10'h, 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-17" Two -Stage Production Cement Job Bump Closing Plug and Shift ESIPC Final Displacement: S BBL Water+ 1525 Strokes 48 Closed 2/19/2020 21:08:39 -5.26 -0.20 1.01 8.94 FCP: 550 PSI @ 3 BPM Tool shifts closed at 1300 PSI Release Pressure and Check For 49 Flow 2/19/2020 21:15:05 No Flow, ESIPC is closed. Page 8 iCem Service (v. 4.2.393) Created: Wednesday, May 10t^, 2017 Attachment C HALLIBURTON 4.0 Job Chart 4.1 First Stage Jab Chart Page 9 Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job -f P•ST STAGE CBNIEI•�T um:ca m.�oao m:;3so -csooc �s:ae.+c rsssso , .m izem �> G�—� Pr:ss •Ps: r- Gbsry :.Gp =c'nb �mP P.e':.zt.Ti.+� F�mG i r' � ,C_. iCem' Service (v. 4.2.393) Created: Wednesday, May loth, 2017 Attachment C HALLIBURTQN 4.2 First Stage Displacement 1400 1200 1000 800 600 400 200 Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job First Stage Displacement 200 180 160 140 120 100 80 60 40 20 0 - "r 0 ti O 01 W h lD �fl M N c-I O ch W h W V1 V M N - O M W h W ul C M N c-I O M 00 h lD Vl d' M N .-I O M Co h O N M N- O Ql W h l0 M Ln c-1 h M a) Ln O lD N W CY O lD N W C M Ln rl h M M Ln M oo T O �D N W�* O w N h M m Ln .-1 h M Ql ill . lD N W V c-I rl N N M �fl ill lD h h W W M O O M V M ul W h h W W Ol O O N M M d' cp Vl M W h h co W M O O � � � c �� N N N N N N N N N N N N N N N N N M M M M M -Well Head Pressure 2 (psi) -Rate Volume Page 10 iCem Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 4.3 Inflate Packer and Open-TaeL 2400 2200 2000 1800 1600 1400 1200 1000 m n Nur, of m r\ � Ln m m r' - Ln or, m n - Ln m m r` - Ln m m r - Ln on m r - un m m r - Ln or, m r N Ln or, m n c-+ Ln m m .-1 N Ln n OJ m ti N V Ln LD 00 m - N m Ln lD 00 m O N m Ln to r� m O N M'T lD � m 0 m ct u7 r" 00 O- m V Ln r, 00 O - N zr ' N N N N N N N M M m m m m m 't zt Zzr V ct Ct 'T U In Ln Ln Ln V ul lD lD l0 lD 1D lD lD r\ r' r' r, Page 11 Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Inflate Packer and Open Tool Series4—Series5—Series7 Series8 3.5 3 2.5 2 1.5 1 0.5 0 iCem' Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIGURTQN 4.4 Inflate Packer 2200 2100 2000 1900 1800 1700 1600 ' .� Ln m m r, Ln m m n� Ln m m r ' � m m r` - �) m m r` ti) m m r` N to m m r` ti u) m m r` , Ln m m r` ,-, Ln rn m r` in m m w m c-I N q In 'O w m rl N m V) Uo co O N m m 'o r` 0) O N m "r to r, Cr, O �-i m � l0 r' Oo O c-I M to r\ W O Ln N �' zr V V 'r C v) �n V1 tf1 1p lD 1p l0 ip 1p 1p n n r` r` Page 12 Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Inflate Packer and Open Tool Series4 -Series5 -Series7 Series8 3.5 3 2.5 2 1.5 1 0.5 0 iCem Service (v. 4.2.393) Created: Wednesday, May 10t", 2017 Attachment C HALLIBURTQN 4.5 Second Stage Job Chart Page 13 Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job SK011D STAGE CEMENT 20,95L0 20'.t S:M 2.320 2G:31-A 2Pd000 2trnb'20 u t4;2C20 cA.e'i.T..0 2/t9/2C2C lflC000-, D5 ono Prz,, '.Ps. D-+P_"Fa Itl-111 Ri stg at iCemi Service (v. 4.2.393) Created: Wednesday, May 101", 2017 Attachment C HALLIBURTON 4.6 Second Stage Displacement Customer: Oil Search Alaska, LLC Job: Mitquq-17" Two -Stage Production Cement Job Second Stage Displacement 2000 100 1800 A 90 1600 80 1400 70 1200 60 1000 50 800 40 600 30 400 20 200 10 0 0 r-I M In n rn .� M V1 n 00 .ti m 111 n Ql M ul n Ql .-� M 0 n 0o 0 M Lc n Q1 'o M N n of rl M W n Ol W M V1 n 0 0 0 M in n m M lO 01 N lD of N Ll1 00 N tf1 W c-I O� N U) n O dO n O M to O M X W N to O N Ln e0 NLn -- .-I Cf 00 rl n O n O m to O m lD 41 N c-I N c-I N N N m M m Q ct C V1 Vl lIl l0 l0 lD n n n W CO W 00 pl Q7 pl O O O �--� f-i �--� N N N m M M �}' t11 U1 Ln to to Lo �o n -Stand Pipe Pressure (psi) -Flow (bpm) Volume Page 14 Kern Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 5.0 Lab Results 5.1 12.0# First Stage Lead Bulk Test Results Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job HALLIMURTON Lab Results- Lead West Coast, Prudhoe Bay Request/Slurry 2616380/1 Rig Name Date 14/FEB/2020 Submitted By Savannah Afoa Job Type Production Casing Bulk Plant Prudhoe Bay, AK USA Customer Oil Search Ltd. Location Greater Prudhoe Bay Well Mitquq ST-1 NN ell Information Casing/Liner Size 7 in Depth MD 5255 ft BHST 57°C i 135°F Hole Size 8.5 in Depth TVD 4900 ft BHCT 41°C i 105°F Pressure 3800 psi Drilling Fluid Information I Mud Supplier Name Baroid Mud Trade Name Density 10.2 lbm/gal Conc UOM Cement/Additive MP 100 % BWOC Standard Type 1 11.77 gal/sack Fresh Water 0.2 % BWOC Thixotropic Additive PB 0.2 % BWOC Defoamer PB 0.07 % BWOC Flow Enhancer PB 0.3 % BWOC Fluid Loss Additive PB 0.2 % BWOC Retarder PB 4 % BWOC Light Weight Additive PB 0.1 % BWOC Suspension Additive PB Bulk Test for OSA Mitquq ST-1 First Stage Lead Sample Type Sample Lot No. Date Bulk Blend 18.02.20 SL#1434 Lab 07.02.20 Lab Sink Bulk Blend 18.02.20 SL#1434 Bulk Blend 18.02.20 SL#1434 Bulk Blend 18.02.20 SL#1434 Bulk Blend 18.02.20 SL#1434 Bulk Blend 18.0220 SL#1434 Bulk Blend 18.02.20 SL#1434 Bulk Blend 18.02.20 SL#1434 Cement Properties Slurry Density 12 Ibm/gal Slurry Yield 2.19 ft3/sack Water Requirement 11.77 gal/sack Total Mix Fluid 11.77 gal/sack Water Source Fresh Water Water Chloride Operation:I Mixability (0 - 5) - 0 is not mixable, Request Test TD:37260329 17/FEB/2020 Mixability rating (0 - 5) Avg rpm mixing under load (-12,000) Blend addition time (sec) @ 4,000 RPM 5 12000 7 Slurry mixes well. Page 15 lCemService (v. 4.2.393) Created: Wednesday, May 10", 2017 Attachment C HALLIBLIRT[]N Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Thickening Time - ON -OFF -ON, Request Test ID:37267869 18/FEB/2020 Test Temp Pressure Batch Mix Reached in 30 Be 50 Be 70 Be Start Be Stirring Static Peak Terminati Terminati (degF) (psi) (min) (min) (hh:min) (hh:min) (hh:min) before stop Period reading on time on Be (mins) (min) (BC) (hh:min) Inc zvnn Q.nn n en <n In c n."I oc I Fields I Values Project Name 112-00PPG Production Ca SW Version 11.0 it PRUDHOE BAY Fields Values Rig Casing/Liner Size Job Type production cxasing Cement Weight Type 1 Comments Light Weight Date Time 2/17/2020 1221-56-478 Temp. Units degF Events Results 30.00 Bc 02h:20m 40-00 Bc 06h25m 50.00 Bc 07h:02m 70.00 Bc 08h:49m 130- 130- -100 -6200 120- 120- -90 -5500 110- 110- -60 -5000 100- 100- -4500 LL 90-- 90 -70 u_ -4000 d so- y Bo-o v 3 -60 = 3500 'm A 70-" 70- N N u a w -50 -3000 E 60- a 60- ~ a �0 -2500 N 50-H 50- -40 _ p 2000 �i 40- 40- -30 -1500 30- 30 -20 -1000 20- 20- -10 -500 10- 10- OD.00 01.00 02.00 03.00 04:00 05.-00 06:00 07:00 08:00 09:00 09:30 •fanny' (hh:mm) Data File,E:N01DE03AB PRU-11TestData137260330 ta.tdms Comments Light Weight Page 16 iCem' Service (v. 4.2.393) Created: Wednesday, May 10`^, 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job UCA Comp. Strength, Request Test ID:37267595 20/FEB/2020 End Temp Pressure 50 psi 100 psi 500 psi 8hr CS 12 hr CS 16 hr CS 24 hr CS 48 hr CS 72 hr CS End CS End Time (degF) (psi) (hh:mm) (hh:mm) (hh:mm) (psi) (psi) (psi) (psi) (psi) (psi) (psi) (hrs) 75 3000 14:02 17:19 58:57 0 17 81 187 422 578 578 72 PRUDHOEBAY Values Fields Values Events Results Name 12.000production casing Job Type production casing 50.00 PSI 14h:02m 37267595 Cement Type standart type 1 100.00 PSI 17h:19m t ID 2616380/1 Cement Weight Light Weight 5W.00 P51 58h:57m by Ip Test Date 211712020 1000.00 PSI NaN 90- 60- TO - 60- 3 y 50- y 5 is A � d u E 40- m H � 30- 20 - to- 0- 00:00 05:00 10:00 15:00 20:00 25:00 30:00 35:00 40:00 45:00 50:00 55:00 60:00 65:00 70:00 75:00 80:00 -fanle Elapsed Time (hh:mm) Data File C:�Documents and Settingn�UCA%My Documents�DATAl37267595-1.tdms Comments Page 17 Ker' Service (v. 4.2.393) Created: Wednesday, May 10'h, 2017 Attachment C HALLIBURTON UCA Comp. Strength, Request Test ID:37267596 Customer: Oil Search Alaska, LLC Job: Mitquq-17" Two -Stage Production Cement Job 20/FEB/2020 End Temp Pressure 50 psi 100 psi 500 psi 8hr CS 12 hr CS 16 hr CS 24 hr CS 48 hr CS 72 hr CS End CS End Time (degF) (psi) (hh:mm) (hh:mm) (hh:mm) (psi) (psi) (psi) (psi) (psi) (psi) (psi) (hrs) 135 3000 5:00 6:06 14:57 197 394 529 654 778 844 844 72 PRUDHOEBAY Fields Values Fields Values Events ResuRs Project Name 12000 production casing Job Type production casing 50.00 PSI 05h:00m Test ID 37267596 Cement Type staNDARD TYPE 1 100.00 PSI 06h:06m Request ID 261638011 Cement Weight Light Weight i 500.00 PSI 14h:57m Tested by Ip oil sandsI, Test Date 211712020 j 1000.00 PSI NaN Customer Test Time 10: 17 PM 08h:00m 197.75 Well No 'I Temp, Units degF I 12h:00m 393.91 Rig Pressure Units PSI 24h; 00m 654.04 CasingJLiner Size 48h:00m 778.86 I50- 40- -1000 140 - -900 Temp 130- 35- Soni 120 - -800 30 - 110 - -700 too- 25 - Tran e C 90 - 7 o V -600 °• n 80- E n m Z: 20 - - -500 c 70 - N E m F 60 - 1 -400 N 50 - -300 40- 10- 30 - -200 20- 5- -100 10- 0- 0' __--_ _0 00:00 05:00 10:00 15A0 20:00 25:00 30:00 35:00 40:00 45:00 50:00 55:00 66:00 65:00 70:00 75:00 80:00 ® •fann Elapsed Time (hh:mm) Data File C:%Documents and Settings%UCAft Docum®nts%DATA%37267596-I.tdms Comments Page 18 iCem" Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 5.2 15.3# First Stage Tail Bulk Test Results Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job HALLIBURTON Lab Results- Tail West Coast, Prudhoe Bay Job Information Request/Slurry 2616381/1 Rig Name Date 14/FEB/2020 Submitted By Savannah Afoa Job Type Production Casing Bulk Plant Prudhoe Bay, AK USA Customer Oil Search Ltd. Location Greater Prudhoe Bay Well Mitquq STA Well Information Casing/Liner Size 7 in Depth MD 5255 ft BHST 57°C / 135°F Hole Size 8.5 in Depth TVD 4900 ft BHCT 41 °C / l05°F Pressure 3800 psi Mud Supplier Name Baroid Mud Trade Name Density 10.2 lbm/gal :cement Information -Tail Design Cone UOM Cement/Additive MP Sample Type Sample Lot No. Cement Properties Date Slurry Density 15.3 Ibm/gal 100 % BWOC Mitsubishi Premium G Bulk Blend 18.02.20 SL41435 Slurry Yield 1.24 113/sack 5.59 gal/sack Fresh Water Lab 07.02.20 Lab Sink Water Requirement 5.59 gal/sack 0.2 % BWOC Defoamer PB Bulk Blend 18.02.20 SL#1435 Total Mix Fluid 5.59 gal/sack 0.07 % BWOC Flow Enhancer PB Bulk Blend 18.02.20 SL#1435 0.6 % BWOC Fluid Loss Additive PB Bulk Blend 18.02.20 SL#1435 0.4 % BWOC Retarder PB Bulk Blend 18.02.20 SL#1435 Water Source Fresh Water 0.2 % BWOC Expansion Additive PB Bulk Blend 18.02.20 SL#1435 Water Chloride Slurry Comments Bulk testing for OSA Mitquq-ST I Production First Stage Tail Operation Test Results Request ID 2616381/1 Mixability (0 - 5) - 0 is not mixable, Request Test ID:37260333 Mixability rating (0 - 5) Avg rpm mixing under load (-12,000) 5 12000 Slurry mixes well. Weight up was not scanned for bulk cement. 739.13 g used. Page 19 17/FEB/2020 Blend addition time (sec) A 4,000 RPM 11 iCerri" Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Thickening Time - ON -OFF -ON, Request Test ID:37267622 18/FEB/2020 Test Pressure Batch Reached 30 Be 50 Be 70 Be 100 Be Start Be Stirring Static Peak Terminati Terminati Temp (psi) Mix (min) in (min) (hh:min) (hh:min) (hh:min) (hh:min) before Period reading on time on Be (degF) stop (min) (BC) (hh:min) (mins) Inc 2Ann n cn c.nc c.ic cn, c.,e „c cn — - .- - . Fields Values Project Name 15-300 PPG Production C SW Version 1-0 Test ID 2616381-1 tt Request ID pru-3 Tested by AM Customer OIL SEARCH Well No M-1 PRUDHOE BAY Fields — Values — Rig NABORS71ES Casing/Liner Size 7 Job Type 1ST TAIL Cement Weight G Comments Standard Date Time 2/17/2020 12:00:02.417 Temp. Units degF Events Results 30-00 Bc 05h:05m 40-00 Bc 05h:10m 50-00 Bc 05h:15m 70.00 Bc 05h:21m 100-00 BC 05h:25m 120- 120- _ -115 -6200 - 110- 110- - -100 -5500 100- 100- -5000 90- 90- 90 -4600 80-u, 80- -80 4000 70- 70- 0- -70 3500 m a 60- y 60- -60 m 3000 'm E a F50-F so- -50 N W-2600 40-0 40- -40 ° -2000 y 30- 30- -30 -1500 20- 20- -20 -1000 10- 10- -10 -500 0- 0- ,,,,,,, ,,,,,,,,, ,,,,,,,—,,,,,,,,, ,,,,,.,,, , ,,,,,, ,,,,,,,,, , ,.,,, ,,,,,,,,,-,� ,,,,,, „,C. -- 200 00:00 0010 01-00 01:30 02:00 02:30 03:00 03:30 04:00 04:30 05:00 05:30 06:00 06:30 •fann® (hh:mm) Data File'E:\01DE0391 PRU-3\TestData\2616381 1att.tdms Comments Standard Page 20 iCern' Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job UCA Comp. Strength, Request Test ID:37267593 20/FEB/2020 End Temp Pressure 50 psi 100 psi 500 psi 1000 8hr CS 12 fir CS 16 fir CS 24 fir CS 48 fir CS End CS End Time (degF) (psi) (hh:mm) (hh:mm) (hh:mm) psi(hh:mm (psi) (psi) (psi) (psi) (psi) (psi) (hrs) 135 3000 5:29 5:45 7:49 10:33 536 1205 1613 2104 2634 2747 56.5 Values Customer Well No 150 - 140 - 130 - 120 - 110 - 100 - C 90-^ o 3 80- m a 70 - — E 60— 50 - 40 - 30 - 20 - 10- 0- 00:00 05:00 10:00 15:00 20-00. 25:00 30:00 35:00 40:00 45:00 50:00 55:00 60:00 65:00 Cann® Elapsed Time (hh:mm) - - - -- - Data File C1Documents and Settings%UCA1My Documents%DATA137267593.tdms Comments PRUDHOEBAY Values ' Events PRODUCTION CASING 50.00 PSI rpe G 100.00 PSI 'eight Standard 500.00 PSI 2/17/2020 1000.00 PSI 536.27 1205.19 Page 21 lCem' Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 5.3 12.0# Second Stage Lead Bulk Test Results HALLIBURTON West Coast, Prudhoe Bay Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Lab Results- Lead Job Information Request/Slurry 2616382/1 Rig Name Date 14/FEB/2020 Submitted By Savannah Afoa Job Type Production Casing Bulk Plant Prudhoe Bay, AK USA Customer Oil Search Ltd. Location Greater Prudhoe Bay Well Mitquq ST-1 Well Information Casing/Liner Size 7 in Depth MD 2500 ft BHST 16°C / 60oF Hole Size 8.5 in Depth TVD 2500 ft BHCT 27°C / 80°F Pressure 1750 psi Drilling Mud Supplier Name Baroid Mud Trade Name Density 10.2 lbm/gal Cone UOM Cement/Additive MP 100 % BWOC Standard Type I 14.23 gal/sack Fresh Water 1.3 % BWOC Accelerator PB 1.3 %BWOC Accelerator PB 0.3 % BWOC Thixotropic Additive PB 0.2 %BWOC Defoamer PB 0.07 % BWOC Flow Enhancer PB Sample Type Sample Lot No. Date Bulk Blend 18.02.20 SL#1436 Lab 07.02.20 Lab Sink Bulk Blend 18.02.20 SL#1436 Bulk Blend 18.02.20 SL#1436 Bulk Blend 18.02.20 SL#1436 Bulk Blend 18.02.20 SL#1436 Bulk Blend 18.02.20 SL#1436 Bulk testing for OSA Mitquq-ST 1 Production Second Stage Lead Operation Test Results Request ID 2616382/1 Mixability (0 - 5) - 0 is not mixable, Request Test ID:37260336 Mixability rating (0 - 5) 5 Page 22 Cement Properties Slurry Density 12 Ibm/gal Slurry Yield 2.4 ft3/sack Water Requirement 14.23 gal/sack Total Mix Fluid 14.23 gal/sack Water Source Fresh Water Water Chloride Avg rpm mixing under load (-12,000) 12000 17/FEB/2020 iCem' Service (v. 4.2.393) Created: Wednesday, May 101h, 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 T' Two -Stage Production Cement Job Thickening Time - ON -OFF -ON, Request Test 1D:37267946 18/FEB/2020 Test Temp Pressure Batch Mix Reached in 30 Be 50 Be 70 Be Start Be Stirring Static Peak Terminati Terminati (degF) (psi) (min) (min) (hh:min) (hh:min) (hh:min) before stop Period reading on time on Be (mins) (min) (BC) (hh:min) 80 1750 0 35 5:29 5:56 6:17 8 60 30 25.6 7:37 91.1 PRUDHOE BAY Values Events Results Fields Values Fields sdsd Project Name 12.00 PPG Production Ce Rig NABORS 7ES 30.00 Bc 05h:29m SW Version 1.0 Casing/Liner Size 7 40.00 Bc 05h:41 m Test ID 2616382-1 a TT Job Type 2ND LEAD 50.00 Bc 05h:56m Request ID PRU-2 Cement Weight 1 70.00 Bc 06h:17m Tested by AM Comments Light Weight 100.00 Bc 00h:00m Customer OIL SEARCH Date Time 2/17/2020 14:12:15.423 Well No M-1 I Temp. Units degF 100- 100 100 -3000 -2800 90- 90- 1-90 -2600 i 80- 80- -80 -2400 -2200 LL 70- 70- -70 -2000 n. 1800 3 60- 2 3 60- -60 0 a,-1600 "0 50- 2 50- W -50 ;0; -1400 w E -1200 v 40-F°-' 40- -40 aJ v 1000 — 3 O 30- 30- -30 -800 -600 20- 20- 1-20 -400 10- 10 -10 -200 -0 0- 0- ......„.„..„...„.„........„ „„ „ „.........„.„ .„„ ....,„.............. .............. .............. ........... .......... -0 200 00:00 00:30 01:00 01:30 02:00 02:30 03:00 03:30 04:00 04:30 05:00 05:30 06:00 06:30 07:00 07:40 fanny (hh:mm) Data File E:\01DE0387PRU-2\TestData\2616382-1aTT.tdms Comments tight Weight Page 23 icenl Service (v. 4.2.393) Created: Wednesday, May 10t", 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 T' Two -Stage Production Cement Job UCA Comp. Strength, Request Test ID:37260337 20/FEB/2020 End Temp Pressure 50 psi 100 psi 8hr CS (psi) 12 hr CS 16 hr CS 24 hr CS 48 hr CS End CS End Time (degF) (psi) (hh:mm) (hh:mm) (psi) (psi) (psi) (psi) (psi) (hrs) 60 3000 14:01 19:25 0 25 68 138 321 382 57 PRUDHOEBAY Fields Values Fields Values Events [25. Project Name 12.00 PPG PRODUCTION CASING Job Type 2ND LEAD 50.00 PSI Test ID 2616382-1 UCA Cement Type I 100.00 PSI Request ID UCA 3 Cement Weight Light Weight 500.00 PSI Tested by AM Test Date 2/17/2020 1000.00 PSI Customer OIL SEARCH Test Time 10:30 PM 08h:00m Wen No M-1 I Temp. Units degF 12h:00m NABORS 7E5 I Pressure Units PSI 24h:00m Casing/Liner Size 7 ! 48h:00m 321 90 - 80 - 70 - 60- IL N o S u50-y E `u = E40-C d � 30- 20 - to- 0- ® 00:00 05:00 10:00 15.00 20.00 25:00 30:00 35:00 40:00 45:00 50:00 55:00 60:00 65:00 •fann Elapsed Time (hh:mm) Data File C:�Documents and Settingski IrA%My nr¢uments%DATA(2616382-1 UCA.tdms Comments SL#1436 BULK CEMENT AND TAP WATER Page 24 iC1em" Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON 5.4 15.3# Second Stage Tail Bulk Test Results Customer: Oil Search Alaska, LLC Job: Mitquq-17" Two -Stage Production Cement Job HALLIBURTON Lab Results- Tail West Coast, Prudhoe Bay Job Information Request/Slurry 2616383/1 Rig Name Date 14/FEB/2020 Submitted By Savannah Afoa Job Type Production Casing Bulk Plant Prudhoe Bay, AK USA Customer Oil Search Ltd. Location Greater Prudhoe Bay Well Mitquq ST-1 Casing/Liner Size 7 in Depth MD BHST 21°C / 70oF Hole Size 8.5 in Depth TVD BHCT 27°C / 80°F Pressure 2320 psi Mud Supplier Name Baroid Mud Trade Name Density 10.5 Ibnt/gal Information - Tail DesignCement Conc UOM Cement/Additive MP Sample Type Sample Lot No. Cement Properties Date Slurry Density 15.3 Ibm/gal 100 % BWOC Mitsubishi Premium G Bulk Blend 18,02.20 SL#1437 Slurry Yield 1.24 113/sack 5.6 gal/sack Fresh Water Lab 07.02.20 Lab Sink Water Requirement 5.6 gal/sack 0.2 % BWOC Defoamer PB Bulk Blend 18.02.20 SL#1437 Total Mix Fluid 5.6 gal/sack 0.07 % BWOC Flow Enhancer PB Bulk Blend 18.02.20 SL#1437 0.6 % BWOC Fluid Loss Additive PB Bulk Blend 18.02.20 SL#1437 0.2 % BWOC Expansion Additive PB Bulk Blend 18.02.20 SL#1437 Water Source Fresh Water 0.2 % BWOC Retarder PB Bulk Blend 18.02.20 SL#1437 Water Chloride Slurry Comments Bulk testing for OSA Mitquq-ST I Production Second Stage Tail Operation , Mixability (0 - 5) - 0 is not mixable, Request Test ID:37260339 17/FEB/2020 Mixability rating (0 - 5) Avg rpm mixing under load (-12,000) Blend addition time (see) @ 4,000 RPM 5 12000 11 iCem" Service (v. 4.2.393) Page 25 Created: Wednesday, May 1011, 2017 Attachment C HALLIBURTON Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job Thickening Time - ON -OFF -ON, Request Test [D:37260341 18/FEB/2020 Test Temp Pressure Batch Mix Reached in 30 Be 50 Be 70 Be 100 Be Start Be Stirring Static Terminati Terminati (degF) (psi) (min) (min) (hh:min) (hh:min) (hh:min) (hh:min) before stop Period on time on Be (rains) (min) (hh:min) 80 2320 0 35 2:15 3:06 3:13 3:21 15.2 60 15 4:34 124 _ PRUDHOE BAY Values NABORS 7ES 7 2ND STAGE G Standard 2/18/2020 00:38:34-914 Events 30.00 Bc 40.00 Bc 50.00 Bc 70.00 Bc 100.00 Bc Fields Values Fields Results Project Name 15.3 PPG Production Cas Rig 02h:15m SW Version 1.0 Casing/Liner Size 02h:52m Test ID 2616383-1 TT Job Type 03h:06m Request ID PRU-1 Cement Weight 03h:13m Tested by AM Comments 03h:21m Customer OIL SEARCH Date Time Well No M-1 Temp. Units IdegF 100- 100- -140 -3800 90- 90- -130 -3550 9-120 -3300 80- 80- a 110 -3050 -2800 a 70-_70- -100 -2550 d L` w Pi-90 t7-2300 60- 60 0 m -80 I•-2050 E50 a 50 -70 9 -1800 40 w 40 -60 0-1550 W 1300 — 6 p-50 w 30- 30- -40 -1050 -800 20- 20- -30 550 10- 10- 11 -20 -300 -10 -50 0- 0- 00.00 ,,,, :„ ,,,,- 00:20 00:40 01.00 01:20 01.40 02-00 02:20 02.40 03:00 03.20 D3 4D 04 00 04:20 04:40 200 .fanny (hh:mm) Data File E.\01DE03AB PRU-1\TestData\2616383-1 TT.tdms Comments Standard Page 26 iCeRi Service (v. 4.2.393) Created: Wednesday, May 10th, 2017 Attachment C HALLIBURTON UCA Comp. Strength, Request Test 1D:37260340 End Temp Pressure 50 psi 100 psi 500 psi 1000 8hr CS (degF) (psi) (hh:mm) (hh:mm) (hh:mm) psi(hh:mm (psi) 70 3000 11:26 12:50 22:01 34:02 0 Page 27 Customer: Oil Search Alaska, LLC Job: Mitquq-1 7" Two -Stage Production Cement Job 20/FEB/2020 12 hr CS 16 hr CS 24 hr CS 48 hr CS End CS End Time (psi) (psi) (psi) (psi) (psi) (hrs) 68 232 589 1425 1625 57 iCem' Service (v. 4.2.393) Created: Wednesday, May 1011, 2017 Attachment C 43.0" 4-1/16" 10M 4-1116" 10M 43.0" 4-1/16" 1 OM 3" 1502 WECO 78.4" 189.1" - 43.0" i 10M 4" 1002 - WECO 9-1/2" (4-ACME)OTIS 4-1/16" 5M r 4-1/16" 10M 4-1/16" 10M - 2-1/16" 5M 4-1/16" 10M 3" FEMALE 1502 WECO I I L _ "CASING 9- 9-5/B" CASING CASING 4-1/2"%3-1/2"TUBING tl�tl '-� CONTROL LINE _ Pressure Control BA ER 16" x 9-5/8" x 7" x 4-1/2 x 3-1/2" 5/10M MB-230 Multibowl Assembly, FUR With MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet aGEcompany GPBETARr NGTGE DRAWN BY: DRAWING NO.: ywrlgm ggrT aaker Hugnea.a GE company, uc lunp.oksnae wanyGa?rgnn re rvee. -ne imorma'an con�aree in uis emmani is mnp»Y mM4emial ana OR 20240898 pmpnalary properly of Baker Hughes c�M itc aRi�ialea. It is to be useJ enlyMNe Oanafn of BakerHugMatanE may ncl be 4stribuietl. trvsminetl, repmEuwtl. allereE (REVIEWED BY: (Rev. Sht. of oru»ntar eny purpo»ximoui lna eapreaa vrtinen con»nl al Baker H�glm. A 1 1 I DIMENSIONS ARE APPRG%IMATE.NGT FOR MPNVFACTURAPPROVED BY: na_'NG USE � 248EP19 PIKKA B Attachment D OIL SEARCH ALASKA MITQUQ 1 ST1: PROGNOSIS W)Oil Search ERA ACE F.41,14 vn rtwD LU'HOLOGY CA5(A•:. CDM?AE.Nrl _ �a • 1E" �}k}ey .•� i J Permafrost — iif11] ilk• t _ Non- .„r�,�� Reservoir t Non - Reservoir l two v ; _ i:tnt,e�waAM U Non_ Reservoir Woo sna)e [Z� Con merate sand 8m+ri �] Tuff BUcstone Attachment E Redacted M. Guhl 5/6/2022 Schlumbeplep FracCADE* STIMULATION PROPOSAL Operator Oil Search Well Mitquq Field Pikka East Formation Nanushuk County North Slope State Alaska Country United States Prepared for Scott Leahy Service Point PRUDHOE BAY Proposal No. Business Phone 1907 659 2434 Date Prepared 3/8/2020 FAX No. 1907 659 2538 Prepared by Mike Hyatt Phone 907-273-4748 E-Mail Address MHyatt@slb.com "Mark of Schlumberger Oisclalmer Notice: This information is presented in good f ith, but no warranty is given by and Schlumberger assumes no liabilityfor advice or recommendations made concerning results o be obtained from the use of any product or service The results given are estimates based on calculations produced by a computer model including various assumptions on the well to and treatment. The results depend on inp t data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assume ors and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and ence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator s responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is notto be inferred. Attachment G Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay Country United States Schlumherger Section 1: Zone Data Formation Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Grad. (psi/ft) Insitu Stress (psi) Young's Modulus (psi) Poisson's Ratio Toughness (psi.inO.5) TOP NAN SHALE 4049.6 4.0 0.708 2868 8.120E+5 0.33 100 TOP NAN SHALE 4053.6 3.4 0.721 2924 7.660E+5 0.33 100 TOP NAN DS 4057.0 7.5 0.659 2676 9.470E+5 0.31 700 TOP NAN CS 4064.5 5.1 0.653 2656 9.050E+5 0.30 1200 TOP NAN SILT 4069.6 4.5 0.691 2812 8.090E+5 0.32 1000 TOP NAN DS 4074.1 8.4 0.651 2655 9.900E+5 0.29 700 TOP NAN SILT 4082.5 13.1 0.680 2779 1.070E+6 0.31 1000 TOP NAN SILT 4095.6 5.0 0.686 2811 1.050E+6 0.32 1000 TOP NAN SILT 4100.6 4.5 0.675 2769 9.930E+5 0.33 1000 TOP NAN CS 4105.1 8.0 0.628 2580 9.120E+5 0.31 1200 TOP NAN 9 CS 4113.1 4.1 0.623 2565 1.200E+6 0.30 1200 NAN 9 CS 4117.2 14.4 0.604 2493 1.080E+6 0.29 1200 NAN 9 CS 4131.6 13.0 0.612 2533 1.110E+6 0.29 1200 NAN 9 CS 4144.6 15.0 0.620 2574 1.150E+6 0.30 1200 NAN 9 CS 4159.6 16.0 0.622 2592 1.170E+6 0.30 1200 NAN 9 CS 4175.6 7.0 0.619 2588 1.140E+6 0.30 1200 NAN 9 CS 4182.6 13.0 0.628 2631 1.160E+6 0.30 1200 NAN 9 CS 4195.6 19.0 0.634 2666 1.180E+6 0.30 1200 NAN 9 CS 4214.6 10.3 0.629 2653 1.160E+6 0.30 1200 NAN 9 CS 4224.9 9.7 0.614 2598 1.180E+6 0.30 1200 NAN 9 CS 4234.6 6.0 0.636 2696 1.280E+6 0.30 1200 NAN 9 CS 4240.6 11.0 0.628 2667 1.260E+6 0.30 1200 NAN 9 CS 4251.6 7.0 0.620 2640 1.230E+6 0.30 1200 NAN 9 CS 4258.6 7.3 0.641 2731 1.290E+6 0.30 1200 NAN 9 CS 4265.9 6.7 0.620 2647 1.350E+6 0.30 1200 NAN 9 CS 4272.6 14.3 0.620 2653 1.270E+6 0.30 1200 NAN 9 DS 4286.9 7.7 0.647 2775 1.420E+6 0.30 700 NAN 9 CS 4294.6 7.0 0.619 2661 1.280E+6 0.30 1200 NAN 9 CS 4301.6 20.1 0.621 2678 1.270E+6 0.30 1200 NAN 9 DS 4321.7 4.9 0.647 2798 1.360E+6 0.30 700 NAN 9 CS 4326.6 11.0 0.630 2729 1.270E+6 0.30 1200 NAN 9 CS 4337.6 14.0 0.630 2737 1.300E+6 0.30 1200 NAN 9 CS 4351.6 13.0 0.651 2837 1.310E+6 0.30 1200 Attachment G Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay Country United States Schlumberger, Formation Transmissibility Properties Zone Name Top TVD (ft) Net Height (ft) Perm (md) Porosity M Res. Pressure (psi) TOP NAN SHALE 4049.6 0.1 0.001 22.6 2021 TOP NAN SHALE 4053.6 0.1 0.001 23.2 2023 TOP NAN DS 4057.0 5.2 1.000 21.1 2025 TOP NAN CS 4064.5 5.1 1.000 18.5 1 2029 TOP NAN SILT 4069.6 1.8 1.000 20.8 2031 TOP NAN DS 4074.1 5.9 1.000 20.0 2034 TOP NAN SILT 4082.5 5.2 1.000 19.7 1977 TOP NAN SILT 4095.6 2.0 1.000 19.1 1902 TOP NAN SILT 4100.6 1.8 1.000 19.1 1863 TOP NAN CS 4105.1 8.0 13.000 21.3 1817 TOP NAN 9 CS 4113.1 4.1 30.000 22.2 1806 NAN 9 CS 4117.2 14.4 25.000 22.1 1810 NAN 9 CS 4131.6 13.0 20.000 21.6 1816 NAN 9 CS 4144.6 15.0 13.000 20.8 1823 NAN 9 CS 4159.6 16.0 13.000 20.9 1829 NAN 9 CS 4175.6 7.0 16.000 20.8 1834 NAN 9 CS 4182.6 13.0 11.000 20.5 1839 NAN 9 CS 4195.6 19.0 8.000 20.2 1846 NAN 9 CS 4214.6 10.3 10.000 20.3 1852 NAN 9 CS 4224.9 9.7 9.000 20.2 1857 NAN 9 CS 4234.6 6.0 6.500 19.3 1860 NAN 9 CS 4240.6 11.0 7.500 19.9 1864 NAN 9 CS 4251.6 7.0 9.500 20.5 1868 NAN 9 CS 4258.6 7.3 9.300 20.1 1871 NAN 9 CS 4265.9 6.7 3.700 18.9 1874 NAN 9 CS 4272.6 14.3 8.600 20.1 1879 NAN 9 DS 4286.9 5.4 8.800 19.6 1884 NAN 9 CS 4294.6 7.0 16.000 20.8 1887 NAN 9 CS 4301.6 20.1 10.000 20.1 1893 NAN 9 OS 4321.7 3.4 10.000 20.2 1898 NAN 9 CS 4326.6 11.0 11.000 20.4 1902 NAN 9 CS 4337.6 14.0 8.600 20.2 1 07 NAN 9 CS 4351.6 13.0 17.000 20.8 1 13 Attachment G Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay Country United States Schlumhergcr Section 2: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 219.0 ft with an average conductivity (Kfw) of 15451 md.ft. Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (bbl) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 30.0 YF125ST 200 20.0 0.00 1.0 PPA 30.0 YF125ST 96 20.0 16/20 C-Lite 1.00 2.0 PPA 30.0 YF125ST 138 20.0 16/20 C-Lite 2.00 4.0 PPA 28.0 YF125ST 191 20.0 16/20 C-Lite 4.00 6.0 PPA 27.0 YF125ST 198 20.0 16/20 C-Lite 6.00 8.0 PPA 25.0 YF125ST 185 20.0 16/20 C-Lite 8.00 9.0 PPA 20.0 YF125ST 90 20.0 16/20 C-Lite 9.00 10.0 PPA 20.0 YF125ST 76 20.0 12/18 C-Lite 10.00 FLUSH 2O.0 WF125 40 30.0 1 0.00 Please note that this pumping schedule is under -displaced by 5.0 bbl. Fluid Totals " 1174 bbl of YF125ST 40 bbl of WF125 Proppant Totals 193700 lb of 16/20 C-Lite 32100 lb of 12/18 C-Lite Pad Percentages % PAD Clean 17.0 % PAD Dirty 14.2 Attachment Schlumberger-Private IL io t (b`7 Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay Country United States Schlumhergcr Job Execution Step Name Step Fluid Volume (bbl) Cum. Fluid Volume (bbl) Step Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (Ib) Cum. Prop. (Ib) Avg. Surface Pressure (psi) Step Time (min) Cum. Time (min) PAD 200 200 200.0 200.0 0 0 3119 6.7 6.7 1.0 PPA 96 296 100.0 300.0 4023 4023 3097 3.3 10.0 2.0 PPA 138 434 150.0 450.0 11583 15607 3123 5.0 15.0 4.0 PPA 191 625 225.0 675.0 32155 47761 3314 8.0 23.0 6.0 PPA 198 823 250.0 925.0 49867 97628 3495 9.3 32.3 8.0 PPA 185 1008 250.0 1175.0 62170 159798 3459 10.0 42.3 9.0 PPA 90 1098 125.0 1300.0 33870 193668 3037 6.3 48.5 10.0 PPA 76 1174 110.0 1410.0 32107 225776 2492 5.5 54.0 FLUSH 40 1214 1 40.1 1450.1 0 22577 2133 2.0 56.0 Attachment Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay Country United States Schlumhergcr Section 3: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD------. 4272.6 ft Initial Fracture Bottom TVD 4286.9 ft Propped Fracture Half -Length ------- _---- _ 219.0 ft EOJ Hyd Height at Well- ----------------------- 274.2 ft Average Propped Width------------------------ 0.220 in Net Pressure---------------------------------------- 127 psi Max Surface Pressure-- -------------------- _--- 3635 psi Simulation Results by Fracture Segment From (ft) To (ft) Prop. Conc. at End of Pumping (PPA) Propped Width (in) Propped Height (ft) Frac. Prop. Conc. (Ib/ft2) Frac. Gel Conc. (lb/mgal) Fracture Conductivity (md.ft) 0.0 54.8 11.6 0.241 201.4 2.16 205.7 20381 54.8 109.5 12.1 0.253 255.E 2.29 1 199.5 1 19116 109.5 164.3 11.2 0.237 241.9 2.16 203.9 14621 164.3 219.0 8.8 0.164 219.1 1.76 509.7 9530 Attachment Schlumberger-Private Schlumberger Client: Oil Search Alaska Well: Mitquq Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -Job Well Completed: 2/14/2020 Date Prepared: 11/19/2019 2:17 PM Report ID: RPT-64247 Name & Volume WF120:YF120ST 67,200 Gal Additive Additive Description B484 Enzyme Breaker B484 Concentration VolumeFluid 0.03 Gal / 1000 Gal 1.7 Gal F103 Surfactant J450 Stabilizing Agent 1 Gal / 1000 Gal 67.2 Gal 0.5 Gal / 1000 Gal 33.6 Gal J475 Breaker 3 Lb / 1000 Gal 201.6 Lb J511 Stabilizing Agent 2.7 Lb / 1000 Gal 182.7 Lb 1532 Crosslinker J580 Gelling Agent 5.4 Gal / 1000 Gal 365.4 Gal 20 Lb / 1000 Gal 1,344.0 Lb L065 Scale Inhibitor 2 Gal / 1000 Gal 134.4 Gal M002 Additive 0.5 Lb / 1000 Gal 30.4 Lb M27S Bactericide 0.4 Lb / 1000 Gal 24.0 Lb S522-1218 Propping Agent S522-1620 Propping Agent varied concentrations 32,000.0 Lb varied concentrations 193,000.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number _ - 66402-68-4 Chemical Name Water (Including Mix Water Supplied by Client)* Mass Fraction - 71 % Ceramic materials and wares, chemicals " 29 % 9000-30-0 Guar gum 1, 2, 3 - Propanetriol Sodium tetraborate decahydrate 2,2',2"-nitrilotriethanol Ethylene glycol 2-Propenoic acid, polymer with sodium phosphinate Sorbitol Diammoniumperoxodisulphate < 1 % 56-81-5 < 0.1 < 0.1 <0.1 _% < 0.1 % < 0.1 % < 0.1 % _ 1303-96-4 102-71-6 107-21-1 129898-01-7 50-70-4 7727-54-0 <0.1 % 67-63-0 Propan-2-ol <0.1 % 111-76-2 2-butoxyethanol < 0.1 % 34398-01-1 Ethoxylated C11 Alcohol < 0.1 % 68131-39-5 Ethoxylated Alcohol < 0.01 % 7647-14-5 25038-72-6 Sodium chloride Vinylidene chloride/methylacrylate copolymer <0.01 % <0,01 % 1310-73-2 Sodium hydroxide <0.01 % 10043-52-4 Calcium Chloride <0.01 % 91053-39-3 112-42-5 Diatomaceous earth, calcined Undecanol < 0.01 % <0.01 % 7631-86-9 Non -crystalline silica (impurity) <0.001 % 111-46-6 2,2"-oxydiethanol(impurity) < 0.001 % 10377-60-3 Magnesium nitrate <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 14807-96-6 Magnesium silicate hydrate (talc) < 0.001 % 7447-40-7 Potassium chloride (impurity) <0.001 % 9002-84-0 poly(tetrafluoroethylene) < 0.0001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 127-08-2 Acetic acid, potassium salt < 0.0001 % <0.0001 % 68-04-2 Sodium citrate Quartz, Crystalline silica Cristobalite Hemicellulase enzyme Acetic acid (impurity) 1,2-benzisothiazolin-3-one 14808-60-7 < 0.0001 % _ 1446_4-46-1 9012-54-8 64-19-7 <0.0001 % <0.0001 % < 0.0001 % 2634-33-5 <0.00001 % Attachment H 0 Schlumberger2019. Used by Oil Search Alaska by permission. Page: 1 / 2 5chlumherger Client: Oil Search Alaska Well: Mitquq Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -Job Well Completed: 2/14/2020 Date Prepared: 11/19/2019 2:17 PM ReportID: RPT-64247 Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third -parties. • The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC-Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. O Schlumberger 2019. Used by 0il Search Alaska by permission. Attachment Page: 2/2 Mitquq 1 ST-1 Clean-up and Test Summary TABLE OF FLOW PERIODS (15.5 Day) PurposeFlow / Build Up Table Duration Bring weIIon slowly (16/64th) via adjustable choke, adjust as necessary to achive stable flow. Monitor As Required returns for proppant and adjust choke as necessay Clean -Up & Initial Flow ^'24 - 48 to avoid damage to proppant pack and to minimize errosion to surface equipment. The OS Resevoir Engineer will determine when the well is clean and advise choke changes/rates for initial flow period. Initial Pressure Build Up —24 Shut in for Build-up / Analysis Well Test (Main Flow) Conduct 6 day flow test as per table below or as 3 rd Party Oil & Gas Samples for Clean-up PVT, EOR, & SCAL Initial Flow will be taken at the 144 Separator as per Main Flow Reservoir Engineer's direction Max Rate Rate# Flow Rate BBL/D Duration (hours) 1 1500 24 2 2000 24 SI 0 24 3 800 144 S I 0 144 4 1 4500 1 12 NOTE: Main flow period Rates and periods are indicative and will depend on may be extended (TBC) clean-up, drawdown, and reservoir properties Final Build -Up Period 144 Shut in for Build-up / Analysis Max Flow (If time allows) 12 Conduct Max Flow Test as directed by OS Reservoir Per regulation 20 AA 25.235 (d) 6, Oil Search is requesting AOGCC permission to flare the produced gas for the duration of the exploration well production test. Estimated total volume of gas per the estimated well test volumes above is approximately 6.2 MMscf Attachment I Well Cleanup - Operational Summary: • Estimates Time: 24 — 48 hours or as dictated by Oil Search Reservoir Engineer. • Target Clean-up Flow Rate: 50 — 1500 BPD w/ some gas • Target Post Clean-up Flow Rate: Up to 2000 BPD & 1.2 mmscf/d • Choke Setting: Use adjustable choke to achieve a flow rate at approximately 100 psi per hour drawdown or until well is stable. Watch BS&W and adjust drawdown rate as needed. The OSA Reservoir Engineer or OSA Well Test Supervisor will advise choke changes based on well performance and solids production. • Proppant Production: Proppant production is expected and will managed by bringing on the well slowly and beaning up choke based on well performance and bottoms up solids production. • Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure is 2,000 psi, bleed down as necessary. • N2Injection Rate: As per contingency Newell kick-off procedures if required. • Methanol Injection Rate: McOH will be injected into the well via the inner annulus to prevent the formation of hydrates. Injection rates will vary based on produced water volumes. • Sampling: As per sampling table below. ffmr Srrfmfe lnb numbot/ samprinp i Collection t,rrrod Tpe Analysis F'ogUcMV Lowflm Vnaxne Camrncarts Container Vendor Ut, lieu LH w aecrosari, � }?rn nnte C7uke IsX rnl Carr hr�, PH dc•_ur-tIr. she•nral: it Tub: r) �,. L'' Hau^fy Sc3a.-ator 1ID3mi 84 PIS 0} _zI vty Hck. Sc•paratar NA Na PIS CI.'uride� IbCrrtiuJttaore cw� Ranarcr Harry Scp3rtar N, N�. PIS tr.�.ii5 -3 acs .ample 4 •}, C J, Hc_s r Sopartar NA Tub^ I lcvi le LU AWL +educe NA PIS tc every 12 hrs rrro1]IS ubte z•reti aRei 3 �r�nti.�vtiur Dwelt Attachment I Main Flow- Operational Summary: • Estimates Time: ^-144 hours or as directed by OS Reservoir Engineer. • Main Flow Period: Up to 800 BPD & up to .500 mmscf/d • Choke Setting: Bring the well on slowly using the PTS adjustable choke, OSA Engineer will advise drawdown targets based on observation from initial flow. Step open choke until desired flow rate is achieved, then switch to a positive choke. The OSA Reservoir Engineer & OSA Well Test Supervisor will advise target rates and choke changes. • Proppant Production: Minimal proppant production is expected. • Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure will be 2,000 psi., bleed as required. • Downhole Shut-in Valve: A programable down -hole shut-in valve has been installed. • Sampling: As per sampling table below Surface• •ling Progra Flow Sample Lab Number/ Location Volume Sampling Collection Comments Period Type Analysis Frequency Container Vendor Utilize EB as necessary, BS&W wC' 30 minute Choke 100 ml Centrifuge PTS document chemicals in Solids% Tube job log Oil API Hourly Separator 100 ml PTS Gravity Salinity H20/o, Hourly Separator NA NA PTS Perform hourly eras pH, H2O production allows Gas Every T Ranarex Separator NA NA PTS _ Gravity hrs Q Glass C Sample H2S, CO2 Hourly Separator NA NA PTS c Tube Dead DOT Ten containers total Mid flow Facilities Stock Tank 50 Gal Approved PTS (7- Fa ci litee s,3 Co re Crude period p 5-gal Steel studies) 3rd Party Sampling (PVT) Flow Study Sample Volume Period PVT, EOR, Surface Matched sets taken at same time period (3 sets -Facilities, 10 sets-SubSurf.) Flash (13) 735cc Prolight cylinders (each filled with >500cc oil) (13) 20-liter Luxfercylinders (each filled with 20litergas) Document sampling location, time, pressure, and temperature Wettability Surface (4) 1-litre polyproplyene (non -pressurized) T1 Contingency Downhole OStudy Sample Volume GGCS PVT, EOR, Downhole 7200cc (Volume dependant upon MDT sampling results -to be clarified by OS SCAL Reservoir Fluid Reservoir Engineer. Facilities requires 1500cc minimum, prefers 3000 cc) Metering Standard Fluid Rates & Volumes - Tank Straps will be used for all reported fluid rates & Volumes, in addition there will be turbine meters on the oil and water legs of the separator for reference. Gas Rates & Volumes - A Daniels differential pressure flow meter. Attachment I Mitquq STl Fracturing Procedure Held IA IA PRV (psi) GORV (psi) Pump Trip Pressure Pressure (psi) (psi) Job 2,600 2,900 5,400 5,000 Treatment MD Perf TVD Perf Max Frac Frac Y. Max Rate Max Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. 1 (PPA) Job Max 4,547 4,275 274.2 219.0 30 3,635 10 u MAWP = 5,700 psi, GORV = 5,400 psi, IA Pressure Max psi = 2,600 psi, IA PRV = 2,900 psi 1. MIRU Schlumberger frac equipment and treating line to the frac tree. 2. R/U to the annulus valve and isolate the pressure relief valve. . 3. Pressure test IA line to 3,100 psi. , 4. Open line to annular PRV and verify relief at 2,900 psi. 5. Open the casing valve and proceed to pressure up the 7" x 3 % annulus to 2,600 psi. 6. Prime up the frac pumps. - 7. Isolate the GORV on the treating line and pressure test the treating line to 6,500 psi. 8. Upon successful pressure test, bleed off pressure and open the GORV on the treating line. 9. Open well head and pump DataFRAC. 10. Shut down and isolate the wellhead pressure gauge from the pumps if necessary. 11. Monitor the bottom hole, wellhead, and annulus pressures until closure is observed. 12. Modify PAD volume and/or schedule if necessary. 13. Pump frac treatment as referenced in attachment G. 14. Upon�omppletion of frac, isolate well head, bleed off line pressure, rig down frac equipment, and demobilize frac equipment from wellsite. Attachment J CT Mitquq 1 ST1 Well Schematic 16" Conductor 128' MD/TVD (A Oil Search Updated Feb 2Wh, 2020 3-'/z". 2.813" Polish Bore 'X' Landing Nipple 530' MD/TVD 3 '/z" 9.2# L80 Vam Top Tubing Surface Casing 9-5/8" 40# L80 BTC ESIPC Stage Cement Tool 2,450' MD 12-'/4" Hole 2,495' MD/TVD Ifl V-, GLM, 3-'/2" 3,024' MD/3,018' TVD 3-'/z"'X' Landing Nipple 4,445' MD/4,196' TVD ST1 Kick Off @ Tubing P/T Gauges 2600' MD/TVD 4,458' MD/4,206' TVD & 4,470' MD/4,215' TVD 7" casing cut @ 2,625' MD 3-%", 'XN' Landing Nipple 4,505' MD/4241' TVD 3-'/2" BHKA @ 4,100' MD/3,838' TVD 360' Core . R 13-'/2" X 7" Packer 3-'/2" 9.2# L-80 IBT 4,488' MD/4,228' TVD Sacrificial Tubing WLEG 4,513' MD/4,247' TVD End of Tubing 4,514' MD/4,248' TVD Planned Perforations —4,547- 4,552' MD/ 4,275' TVD, 40.96° Inc. Production Casing 7" 26# L80 Vam Top HC 7" 26# L80 Vam Top HC 8'/2" Hole 6,886' MD/5.922' TVD \ ` 6-1/8" OH \\ 200 inclination TD: 81 10'MD / 7052' TVD 8'/z" Hole 5,236' MD/4,798' TVD Attachment L Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, March 10, 2020 1:03 PM To: 'Kuck, Marc' Cc: Davis, Rachel; Staudinger, Garret Subject: RE: Mitquq Re-frac data (PTD 219-151) Marc, We have the sundry hand and are processing. You have verbal APPROVAL to refrac the well Mitquq 1 ST1 as proposed in the sundry application (#320-109). You should receive the hardcopy approval shortly. Regards, 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 (Guv.schwartz@alaska.ciov). From: Kuck, Marc <Marc.Kuck@oilsearch.com> Sent: Tuesday, March 10, 2020 11:11 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Davis, Rachel <Rachel.Davis@oilsearch.com>; Staudinger, Garret <Garret.Staudinger@oilsearch.com> Subject: RE: Mitquq Re-frac data Hello Guy, Just wanted to drop you an update. Rachel sent in a new updated sundry application with the operational information we discussed earlier. Our plan is to continue taking our separated oil to eni and the slop/solids to Conocophillips. We are planning to frac tomorrow so an expedited approval would be greatly appreciated if possible. Thanks and regards, Marc From: Kuck, Marc Sent: March 8, 2020 6:57 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: Mitquq Re-frac data Hi Guy, ,Please see attached information for the ,, ac work we plan to continue performing on uur Mitquq ST1 exploration well. If you have any additional questions, or require more information, just let me know. We plan on executing this work as early as Tuesday or possibly Wednesday this week. Thanks and regards, Marc MARC D KUCK COMPLETIONS MANAGER OIL SEARCH LIMITED PO Box 240927, Anchorage, Alaska 99524-0927 Tel: 907 375-4669 1 Mob: 907 242-6942 Email: marc.kuck(a2oi1search.com 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 ************************************************************************************************** ************* THE STATE 01ALAS-K-A- 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 ST1 Permit to Drill Number: 219-151 Sundry Number: 320-099 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 www.00gcc.alaska.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, oc1 rice DATED this day of March, 2020. RBDMS-! '" MAR 0 5 2020 DECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS MAR 3 2020 .0d-5 3 / -�- 1 z e AOGCC 1. Type of Request: Abandon 0 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 r Exploratory � � Development ❑ 219-151 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 240927 Anchorage, AK 99524-0927 50-103-20808-01-00 7. If oerforatino: •.,,. What Regulation or Conservation Order governs well spacing in this pool? A Will planned perforations require a spacing exception? Yes ❑ No . V-11 ,vmuc anu INUrrluer: Mitquq 1 ST1 ' 9. Property Designation (Lease Number): ADL 0393876 /,4Q"2_938,�6 10. Field/Pool(s): Undefined 11. PRESENT WELL CONDITION SUMMARY Total Depth MD ift): 5,250 Total Depth TVD (ft): 4,808 Effective Depth MD: 4,547 Effective Depth TVD: 4,275 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 Production 5,236' 7" 5,236' 4,798' 7,240 psi 5,410 psi Perforation Depth MD ift): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,547 - 4,552 4,275 3-1/2" L80 4,513 Packers and SSSV Type: Halliburton PHL Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): No SSSV 4,488' MD/4,228' TVD 12. Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory El Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15th March 2020 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 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: qarret.staudingerpoilsearch.com Authorized Contact Phone: 907-440-6892 3/� Signature: Date: ! o COMMISSION USE ONLY Conditions of approv Notify Commission so that a representative may witness Sundry Number: O Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance SLi. r►,. Other: ��10fa _ 7—c� v —0 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMBI � MAn 0 5 2020 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 1 Q Approved by: C J�l APPROVED BY COMMISSIONER THE COMMISSION nata l �{ 1 C&ki RIG`NAB 3 0I l�c� w 3����3/w Form 10 403 Revised 4/2017 p ved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate �Mg .3/3/-;L0 March 3, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval PTD: 219-151 Mitquq 1 ST1 Oil Search (Alaska), LLC Mitquq 1 ST1 Exploration Well North Slope, Alaska Dear Sir/Madam, Oil Search (Alaska), LLC hereby applies for an Application for Sundry Approval to Plug and Abandon the Mitquq 1 ST1 well (PTD 219-151) at the conclusion of the flow test. The well is located within state lease acreage on state lands. The Mitquq 1 ST1 has been drilled to TD of 5,250' MD/4,808' TVD. Upon completion of a flow test evaluation it is requested that the well be plugged back to surface with a series of cement plugs. All hydrocarbon bearing zones in the well will be cemented as detailed in the attached procedure. The well will be permanently plugged and abandoned per AOGCC requirements. If there are any questions and/or additional information desired, please contact me at (907) 440-6892 or garret.staudinger(o)oilsearch.com. Respectfully, Garret Staudinger Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-403 Application for Sundry Approval Mitquq 1 ST1 Mitquq 1 ST1 P&A Procedure Mitquq 1 ST1 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 Mitgug 1 ST1 P&A Program Overview r 5 1. Rig up and test Little Red Pumping Unit with pump lines and fluids return lines to frac tree. Spot and rig up fluid return tanks. 2. Bullhead 9.6ppg NaCl kill weight brine down IA to GLM to displace nitrogen from IA to tubing. Kwiv' 3. Bullhead and kill well with 20bbl BARASCRUB LVT wash pill and 9.6ppg NaCl kill weight brine. 4. Monitor tubing head pressure for 30min to confirm that well is dead. 5. Rig up slickline and test lubricator to 250/2500psi for 5/5mins. 6. Make up and RIH with 2.7" OD drift run/sample bailer toolstring. Tag PBTD, take sample POOH. 7. Make up and RIH with PXN plug setting toolstring. Set PXN plug in XN nipple and then POOH. 'OK 1,4 8. Make up and RIH with PXN prong setting toolstring. Set PXN prong in PXN plug and then POOH. 9. Pressure test PXN plug and prong to 2500psi for 5mins. 10. Make up and RIH with X plug setting toolstring. Set X plug in X nipple at -500' and then POOH. i 11. Pressure test X plug to 2500psi for 5mins. 12. Rig down slickline. 13. Set 4" TWC valve in wellhead. hGks- 14. Nipple down frac tree. Nipple up dry hole tree and test to 3500psi for 5mins against TWC. Ri up TWC dry rod and retrieve TWC from wellhead. 16. Rig up slickline and test lubricator to 250/1000psi for 5/5mins. 17. Make up and RIH with X plug retrieval toolstring. Latch and pull X plug in X nipple at -500' and oa'�4 then POOH. irollf 18. Make up and RIH with MaxFire P/T gauges toolstring. Take P/T calibration readings and POOH. 19. Make up and RIH with 3' of MaxFire tubing punches (2" OD carrier, 7' OAL with 3' of loaded shots, 13 shots total, 0.33" entry hole). Tag XN No -Go. Pull up to position charges on depth (just above production packer). Wait for charges to fire and POOH. 20. Forward circulate from tubing to 7" x 3-1/2" IA with 9.6ppg brine (-1.5x tubing and annulus volume) to confirm holes in tubing and fill the 7" x 3-1/2" IA with 9.6ppg brine. , /` e (2 of 21. Make up and RIH with PXN prong retrieval toolstring. Latch and pull prong from PXN plug and then POOH. 22. Make up and RIH with PXN plug retrieval toolstring. Latch and pull PXN plug from XN nipple and then POOH. 23. Rig down slickline, rig up Halliburton Cement Unit. Oil Search ee 24. Pump cement plug 1 as follows: / (d -% V Bullhead squeeze volume of 15.8ppg Slurry d �� S 4, - Drop 2.5" OD standing valve (to land in XN nipple in end of tubing for a cement base) l Bullhead plug volume of 15.8ppg Slurry ��LS Drop 4" foam wiper ball Bullhead 9.6ppg brine for initial displacement (to land standing valve in end of tubing) Open 7" x 3-1/2" IA Valve L u.'het," - Forward circulate 9.6ppg brine for final displacement J5i3L-s , r ^-- h�.-�.P L -3 25. Wait on cement. (l 26. Rig up slickline and test lubricator to 250/1000psi for 5/5mins. 27. Make up and RIH with 1.75" OD sample bailer toolstring. Tag top of cement, take sample and POOH. 28. Make up and RIH with GLV toolstring. Pull orifice GLV from mandrel at 3024' and POOH. %' 9. Pressure test tubing and 7" x 3-1/2" IA against cement plug 1 to 2000ps f r 30mins. AOGCC L Inspector to witness pressure test. 30. Rig down slickline, rig up Halliburton Cement Unit. 31. Break circulation and then proceed to pump cement plug 2. Circulate 15.8ppg Slurry into tubing and taking returns up the IA to tank, continue pumping ^ until 15.8ppg cement is returned at tank. (t� Displace with line volume of water to clean cementing lines through the squeeze manifold to tanks. 32. Wait on cement. 33. Nipple down dry hole tree from wellhead. 34. Rig up Guillotine Saw and cut off wellhead through 16" x 9-5/8" x 7" x 3-1/2" casing/tubing strings, 35. Top off any annulus or tubing with Portland sack cement. CC 36. AOGCC Inspector to witness TOC in tubing/annuli. 37. Weld on final P&A well cover plate to 16" conductor as per 20 AAC 25.120. Document casing cutoff and welded plate condition with photos. 38. Pull and back fill cellar hole. �`0C 39. Demob and clean up location. X .5 ; _�Z (C �c r- e try t �l �r— G Z--G Abandonment Cement Plugs Plug Depths TOC: 3880' MD/3692' TVD Base: 4477' MD/4094' TVD 32.5 bbls, 183 cuft, 159 sks of 15.8 ppg Class G, Yield: 1.15 cuft/sk Slurry Squeeze volume: 11.6bbls; plug volume 20.9bbls Cement Temp BHST 115° F at 4094' TVD Plug #1 Verification Tag TOC inside tubing with slickline. Pressure test tubing and annulus to 2000psi. Method Bullhead cement down tubing, squeeze 10bbls into perforations, open 7" x 3-1/2" Notes IA valves and circulate remaining cement into tubing and annulus. Plug Depths TOC: 28' MD (surface). Base: 3024' MD/3014' TVD Slurry 136 bbls, 766 cuft, 667 sks of 15.8 ppg Class G, Yield: 1.15 cult/sk Temp BHST 86° F at 3014' TVD Cement Verification Monitor returns at surface and pump pressure during cement job. Plug #2 Method Circulate plug in place from tubing to 7" x 3-1/2" IA through open gas lift mandrel. Note Set as balanced cement plug. 30% excess used to ensure cement to surface Oil Search Mitquq 1 ST1 Current Well Schematic Mitquq 1 ST1 Well Schematic Oil Search Updated Feb 261t1, 2020 16" Conductor , ` J( 128' MD/TVD r ` 3-'/". 2.813" Polish Bore 'X'Landing Nipple 11 41 530' MDiTVD Surface Casing 9-5/8" 40# L80 BTC 12-1/." Hole 2,495' MDITVD 3-'— 'X' Landing Nipple 4,445' hAD/4,196' TVD Tubing P/T Gauges 4.458' IvID'4,206' TVD 4,470' hAD 4.215' TVD 3-1/:",'XN Landing Nipple 4,505' MD.,4241' TVD 360' Core 3 %" 9.2# L80 Vam Top Tubing ESIPC Stage Cement Tool 2,450' MD GLM, 3,024' 1vlD13,018' TVD ST1 Kick Oft @ 2600' rilD/TVD 7" casing cut @ 2,625' MD 3-Y" BHKA @ 4,100' IvID;3,838' TVD 13-1/i' X 7" Packer 3-`/-` 9.2# L-80 IBT 4,488' MD/4.228' TVD Sacrificial Tubing_ WLEG 4,513' MD'4,247' ND End of Tubing 4,5l 4' 61D'4.248' TVD Planned Perforations -4,547- 4,552' MD/ 4,275' TVD, 40.96° Inc. Production Casing 7" 26# L80 Vam Top HC 7" 26?i L80 Vam Top HC 81/2" Hole 8'G" Hole 5,236' MD14,798' TVD 6.886' tv1D;5.922' TVD 6-118" OH J 20' inclination TD: 81 10'MD / 7052' TVD Q) Oil Search Mitquq 1 ST1 Planned P&A Well Schematic Mitquq 1 ST 1 0 Proposed P&A Schematic Oil Search Updated Feb. 27"' 2019 16" Conductor 128' MDtTVD 3-'/--`. 2.813" Polish Bore 'XLanding Nipple 530' MD,'TVD Cement Plug 2: 3000' - surface 3 '/Z 9.2# L80 Vam Top Tubing ES-IPC Stage Cement Toot 2450' MD Surface Casing 9-518" 40# L80 BTC o 0 12 'i." Hole 2,495' MD/TVD GLtvt, 3'/z 3024' MD13.018' TVD z Open Mandrel (GLV pulled) fL I 3 SYD _ Cement Plu 1: 4477-3880 (597' plug) '(�' I � S Tubing Punch 4477 - 4480' MD?TVD 3 f"'X' Landing Nipple \` r 4,445' MDl4,196' TVD Standing Valve landed iri Tubing PIT Gauges 3-1/5 'XN Landing Nipple 4,458' MD/4,206' TVD & 4,505' MD'4.241' TVD 4.470' MD/4,215' TVD 3-Y:" X 7" Packer 4488' MD/4228' TVD Landing Nipple 4,505' h1D/4241' TVD VVLEG 4514' MD(4248' TVD 10 bbls cement squeezed into Perforations-4,547'- 4.552" MD/ 4,275' TVD, 40.W Inc_ Production Casing 7" 26# L80 Vam Top HC 8'/V' Hole 5,236' MDI4,798' TVD E P&A Cement THE STATE 9 0 a I 46111wMalk GOVERNOR MIKE DUNLEAVY Marc Kuck Senior Engineering Manager Oil Search Alaska 900 E Benson Blvd Anchorage, AK 99508 Re: Exploratory Field, Exploratory Pool, Mitquq 1 ST1 Permit to Drill Number: 219-151 Sundry Number: 319-553 Dear Mr. Kuck: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.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, l,� O JsiVel. Chmielowski Commissioner DATED this 21-day of February, 2020. RBDMSL*44 MAR 0 2 2020 SCANNED MAR 3 ` 2020 DEC - 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /yO GCC APPLICATION FOR SUNDRY APPROVALS gn Aar•. 9F qRn 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: Flow Test ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Oil Search Alaska Exploratory 0 Development ❑ Stratigraphic ❑ Service ❑ 3. Address: 900 E Benson Boulevard 6. API Number: Anchorage, AK 99508 50- 1 0 3 ^--W 3o ¢ _ o 1 (J 1 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Mltquq 1 ST1 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 393876 /85,M aundefined 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 80' 16" 108' 33' 3060 1450 Surface 2,475' 9-5/8" 2,475' 2,400' 7930 4760 Intermediate Production 6,130' 7" 6,130' 5,633' 7240 7800 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,377'-4,382' 4,158' 3-1/2", 9.2# L-80, Vamtop 4,345' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: 2/20/2020 Commencing Operations: ❑ ❑ WDSPL OIL ✓ WINJ ❑ Suspended ❑ 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: Marc Kuck Contact Name: Marc Kuck Authorized Title: Senior Engineering Manager Contact Email: marc.kuck@oilsearch.com Contact Phone: 907-375-4600 C Authorized Signature:,_i Data: z COMMISSION LrSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: AA5 C' j ,'emu .� n 'ZiV "` �'� �`"` �'L Z-E) rt.&� 2 S z J �L /_% jam} //✓^) {`�' Post Initial Injection MrReq'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No IV Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: CA4421 �� 2�'�� RBDMSL� MAR 0 2 2020 � Approved PP RloGlo Submit Form and Form 10-403 Revised 4/201 a lica N. AtL� ate of approval. Attachments in Duplicate T ` 6 21Z`4;W (1) Oil Search Mitquq 1 ST1 Sundry Application Requirements 1. Affidavit of Notice —Attachment A 2. Plat showing well location, as well as % mile radius around well with all well penetrations, fractures, and faults within that radius —Attachments B and F 3. Identification of freshwater aquifers within % mile radius —There are no known underground sources of drinking water within a half mile radius of the current proposed well bore trajectory for Mitquq 1 ST1. At the Mitquq 1 ST1 location, the Permafrost interval extends down to approximately 1500 ft and therefore, no known shallow aquifers are located at the Mitquq 1 ST1 location. 4. Plan for freshwater sampling — There are no known freshwater wells proximal to the proposed operations, therefore no water sampling is planned. 5. Detailed casing and cementing information —Attachment C 6. Assessment of casing and cementing operations — Assessment of casing and cementing e operations will be performed after cementing operations are complete. 7. Casing and tubing pressure test information — Pressure testing will be performed upon o completion of the well's lateral section. 8. Pressure ratings for wellbore, wellhead, BOPE and treating head — Attachment D 9. a-d Lithological and geological descriptions of each zone —Attachment E and below Nanushuk Reservoir Interval Lithologic Description: The Nanushuk Formation reservoir lithology is a thick accumulation of shallow marine outer -shelf sandstone deposits. The formation sandstone is laminated and grades into the silty -shale dominated Torok Formation immediately beneath it. The sandstones are fine-grained to very fine grained. The prograding sandstone unit at the top of the reservoir is overlain by a transgressive zone compromised of shales and siltstones which constitutes a seal. The fracture gradient for this sealing shale is 15.8-16.2 ppg. Depth & Thickness: 4382ft MD/4091ft TVDSS, —400ft TVt) Upper Confining Unit: Seabee Formation Lithologic Description: The Seabee Formation immediately overlies the Nanushuk Formation. The base of the Seebee is the shale wall facies which is a marine flooding surface composed of condensed mudstone facies deposited during a maximum transgression and creates a good regional seal. Distant volcanism occurred during its deposition resulting in numerous bentonite interbeds. The overall Seabee Formation is a thick shale/claystone dominated unit which represents the distal deep -water slope and basinal deposits. The claystones within the Seebee Formation are described as medium grey to dark grey, soft and mushy to slightly firm, locally partings along laminations, commonly micas and scattered very fine lithic grains. Grading to weakly fissile shale. The fracture gradient for this sealing shale is 15.6-15.8 ppg. Depth & Thickness: 3196ft MD/3110ft TVDSS, —850ft TVT Lower Confining Units: Torok Formation Lithologic Description: The Torok Formation underlie the target reservoir Nanushuk Formation and are dominantly comprised of claystones and silty shales and thick shale sequences. The formation grades from silty shales in the shallower section to shale at the base of the Torok Formation. The shales are described in offset wells as very fine grained medium dark grey to dark brownish and greyish black. Soft to easily friable, occasionally firm. Tabular to platy cuttings with very well -developed laminations. Very organic overall with layers of organic/carbonaceous material. The fracture gradient for this sealing shale is 16.4-16.6ppg. Depth & Thickness: 5200 MD/5135 TVDSS, "250ft TVT Lower Confining Units: Hue Shale (HRZ) Lithologic Description: The Hue Shale/HRZ is a very condensed distal shale that is equivalent in time to the Torok and Nanushuk Formations. The shale is described in offset wells as very dark with slight brownish hues. The shale is firm to increasingly hard and dense with local abundant organic debris and carbonaceous material. It is a regionally present formation and is consistently 200-250ft thick. The fracture gradient for this sealing shale is 16.5-17.Oppg. Depth & Thickness: 5900TVDSS, —100ft TVT e. Estimated fracture pressure for each zone listed below: Held IA IA PRV (psi) GORV (psi) Pump Trip Pressure Pressure (psi) (psi) Job 2,600 2,900 5,400 5,000 Treatment MD Perf TVD Perf Max Frac Frac % Max Rate Max Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. (psi) (PPA) Job Max 4,388 4,155 187.9 214.5 25 2,851 10 10. Mechanical condition of wells transecting the confining zones — No wells within 1/2-mile radius of Mitquq 1 ST1. Please see attachment B as reference. 11. Location of faults and fractures in wellbore % mile radius — Based on the seismic and well data covering the Mitquq 1 ST1 location, there is one identified fault interpreted to be located within a half mile radius of the wellbore trajectory. Seismic interpretation of the Nanushuk 9 reservoir and internal interpretation surfaces has determined that there are no faults of seismic resolution within the half mile radius (Attachment F). Oil Search does not expect that any hydraulic fractures during the stimulation of Mitquq 1 ST1 will intersect any faults near the wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, Oil Search will flush and terminate the stage immediately. 12. Detailed proposed fracturing program — Attachments G & H 13. Flowback procedure —Attachment I Section (b) Casing Pressure Test — We will not be treating through production or intermediate casing strings. Section (c) Fracture String Pressure Test — Attachment J Section (d) Pressure Relieve Valve — Attachment K Proposed Wellbore Schematic —Attachment L Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones, who, being duly sworn according to law, deposes and says: 1. 1, Timothy Jones, am the Land Manager for Oil Search (Alaska), LLC and a Registered Professional Landman #84167. 2. The Owners, Landowners, Surface Owners and Operators, as defined in relevant state statutes and regulations, identified in the attached Notice of Operations are correct to the best of my knowledge. 3. The well location in the attached Exhibit A was taken from Oil Search (Alaska), LLC's Permit to Drill submitted to AOGCC. 4. The attached Notice of Operations was sent to the identified Owners, Landowners, Surface Owners and Operators by certified mail. Further the affi* sayeth naught. Timothy Jon RPL #84167 UNITED STATES OF AMERICA § STATE OF ALASKA STEPH I.IRETTE Notary Public State of Alaska My Commission Expires Jul 21, 2023 Date Subscribed and sworn to before me on the day of December, 2019, ` Notary Public My commission expires: ] - Z ( • L I Attachment A (f) Oil Search December 4, 2019 Owners, Landowners, Surface Owners and Operators See Distribution List Colville River Area North Slope Basin, Alaska Re: Notice of Operations under 20 AAC 25.283 of Oil Search (Alaska), LLC's Sundry Application for a Fracture Stimulation for the Proposed Mitquq 1 ST1 Sidetrack Well Dear Owner, Landowner, Surface Owner and/or Operator, Oil Search (Alaska), LLC (OSA) is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the proposed Mitquq 1 STl sidetrack well. This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(1)(A) and 20 AAC 25.283(a)(1)(B). The complete application is available for review upon request. If you wish to review the application, please contact Tim Jones, Land Manager, at the following: Tim Jones Land Manager Oil Search (Alaska), LLC PO Box 240927 Anchorage, AK 99524 Direct: 907-375-4624 tim.iones@oilsearch.com OSA, through a search of the public record, has identified you as an Owner, Landowner, Surface Owner or Operator (as defined in AOGCC regulations) within % mile of the proposed Mitquq 1 ST1 sidetrack well trajectory and fracture stimulation. Please contact me should you require additional information. SincetMager Tim J Land OII Search Alaska, LLC Anchorage office Tel. +1 907 375 4600 PO Box 240927 Fax +1 907 375 4630 Anchorage, AK 99524-0927 www o lsearch corn Attachment A Distribution List: Alaska Division of Oil and Gas ASRC Exploration, LLC Oil Search (Alaska), LLC Repsol E&P USA Inc. 0) Oil Search Attachment A Contact Information: State of Alaska Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 ASRC Exploration, LLC Attn: Teresa Imm 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Oil Search (Alaska), LLC 510 L Street, Suite 310 Anchorage, AK 99501 Repsol E&P USA Inc. Attn: Dennis Henderson 2455 Technology Forest Blvd. The Woodlands, TX 77381 Oil Search Alaska, LLC Anchorage office PO Box 240927 Anchorage, AK 99524-0927 (1) Oil Search Tel: +1 907 375 4600 Fax: +1 907 375 4630 www.oilsearch.com CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL Attachment A ADL 391910 Operator: ASRC Subsurface Owner: ADNR Surface Owner State ASRC'100% S oo / UO11N007E04 UO11N007E03 UOIIN007E02 " — . UO11N007E01 / ♦ a ADL391023 - Operator: ASRC Subsurface Owner: ADNR t ` Surface Owner: State MRQUO 1 BHL ASPIC 100% \ MITQLIQ 1 S L ADL 393875 _ wauctI I Operator: OIL SEARCH � Subsurface Owner, ADNR / a ADL 393676 Surface Owner: State"Y'`"`""""`"�""d""`"""` Operator: OIL SEARCH 1 OSA: 51 % 1 Subsurface Owner. ADNR / ♦ -" Surface Owner, State ? B ♦� OSA: 51% REPSOL 49 % f U011 N007EO9 U011 N007E10� UO1 1 N007E12 U011N007EII ADL 391910 y OperatorASRC Subsurface Owner: ADNR Surface Owner. State r ASRC 100% . e _ - ADL 393564 Operator: BRPC U011 N007E16 Subsurface Owner: ADNR Surface Owner: State U011 N007E15 U011 N007E14 ;E CARACOL 52.6% ' U011 N007E13 TP INS DEV: 47.5% A It1 1 ® _ _ r I j 0.5_ MILE BUFFER ------ WELL PATHLINE OIL SEARCH AA 2018-2019 EXPLORATIONION CAMPAIGN GN SECTION Mitquq 1 Well Area • BOTTOM HOLE Oil Search ICE ROADS/PADS N 0 400 800 LE ® Feet GCS: NAD 1927 StatePlone Alaska 4 FIPS 5004 (� SURFACE HOLE LEASE BOUNDARY �,11V� ���{IjiSj ®Meters Attachment B DATE: 12/3/2019.REV: I.O.By:JB s 0 100 200 Document name:OPS-19-2D-W-PE-M-Mitqugl_hoc5undry 7" Production Casing Section Overview 7" 26# L80 Vam Top HC Casing Burst Collapse Tensile ID Drift ID Connection Make-up Make -Up (Psi) (Psi) (klbs) (in) (in) OD Torque Loss (in) (ft-lbs) (in) 7,240 5,410 604 6.276 6.151 7.565 11,950 4.776 Production Casing Cement — STAGE 1 Casing 7" 26# L80 Vam Top HC Casing Lead Open hole volume + 30% excess Basis Lead TOC Stage Collar Depth —3200' MD / 3184' TVD (base Tuluvak) Tail Open hole volume + 30% excess + 500 ft shoe track Tail TOC —3900' MD/3870' TVD. 500' MD above top of Nanushuk 9 sandstone Spacer 30bbls of 11.5ppg Tuned Spacer Total Lead 21bbls, 118cuft, 55sks of 12.Oppg ExtendaCem, Yield: 2.132cuft/sk Cement Volume Tail 85bb1s, 477cuft, 385sks of 15.3ppg ExpandaCem Class G, Yield: 1.24cuft/sk Temp BHST 156' F Verification Method Cement returns and wireline CBL [Notes Job will be mixed on the fly Two stage cement job, first stage pumped with top and bottom plugs Production Casing Cement — STAGE 2 Casing 7" 26# L80 Vam Top HC Casing Lead Cased hole volume + 30% excess Basis Lead TOC Surface Tail Open hole volume + 30% excess. Cased hole volume + 30% excess Tail TOC 100' MD above 9-5/8" casing shoe (9-5/8" x 7" annulus) Spacer 30 bbls of 11.5 ppg Tuned Spacer Total Lead 87bbls, 488cuft, 203sks of 12.Oppg VariCem, Yield: 2.40cuft/sk Cement Volume Tail 25bbls, 140cuft, 113sks of 15.3ppg ExpandaCem Class G, Yield:1.2405 cuft/sk Temp BHST 88° F Verification Method Cement returns to surface Notes Job will be mixed on the fly Two stage cement job, second stage pumped with top plug only Attachment C Production Casing Proposed Cementing Program 1.1 Pump the first stage cement job as per Halliburton Cementing Program. a) Stage 1 is planned to be pumped as follows: i. 11.5ppg Tuned Spacer ii. Drop Bypass Plug iii. Reload Cement Head (both first stage plugs don't fit in cement head) iv. 12.Oppg Lead ExtendaCem Slurry (tested with 1 hour shutdown time) v. 15.3ppg Tail ExpandaCem Class G Slurry vi. Drop Shut Off Plug (opens ES -Cementer with 3,300psi plug bump) vii. 5-10bbls water to clean cementing lines viii. Initial displacement with 10.7 ppg MOBM ix. 11.5 ppg Tuned Spacer (to sit across stage tool) x. Final displacement with 10.7 ppg MOBM xi. Land Shut Off Plug on Baffle Adapter, bump plug with 500psi over final circulating pressure. Shut down pumps, bleed off pressure and verify floats are holding. xii. Reload Cement Head with Second Stage Cement Top Plug only. DO NOT load Second Stage Bottom Plug as this will not be dropped. xiii. Pressure up to 3,300 psi (+/-250psi) to shift open ES -Cementer (pressure up against shut off plug landed on baffle adaptor in the shoe track). b) Final volumes will be detailed in the Halliburton Cement Program. c) Do not pump over the calculated displacement plus half the volume of a standard three joint shoe track plus 0.3bbls for mud compressibility (-2.3bbls % standard shoe + 0.3bbls mud compressibility = ^2.6bbls total). If plug does not bump refer to contingency cement procedures. d) Verify floats are holding. If floats have failed refer to contingency cement procedures. 1.2 Once the ES -Cementer stage tool has been opened circulate minimum of 1.5x BU from stage tool depth. Initiate circulation through step rate method. Target 8bpm but limit pump rate if losses are observed. Monitor returns for cement and spacer and attempt to estimate volumes. 1.3 Wait on first stage cement to reach 50 psi compressive strength (-5 hrs). Attachment C 1.4 Proceed to pump the second stage cement job as per Halliburton Cementing Program. a) Stage 2 is planned to be pumped as follows: i. 11.5ppg Tuned Spacer ii. 12.Oppg Lead VariCem Slurry iii. 15.3ppg Tail ExpandaCem Class G Slurry iv. Drop Second Stage Top Plug v. 5-10bbls water to clean cementing lines vi. 10.7 ppg MOBM displacement vii. Land Second Stage Top Plug and pressure up to 1200 psi over final circulating pressure to close the ES -Cementer. Do not exceed 2100psi (max. tool pressure). b) DO NOT DROP Second Stage Bottom Plug. Lesson Learned 2019: 2"d stage bottom plug prematurely closed the ES -cementer and filled the casing with cement. c) Final volumes will be detailed in the Halliburton Cement Program. d) When Second Stage Top Plug lands hold pressure for 2 mins then release pressure and observe for flow back. If no excessive flowback is observed, then tool is closed. If tool is not closed refer to contingency procedures. e) Monitor for cement returns at surface and verify a plan is in place to segregate cement contaminated returns. 1.5 Rig down Halliburton cement head and lines. 1.6 Back out and retrieve the casing hanger running tool. Attachment C In 9-1/2" (4-ACME)OTIS 4-1/16" 5M 4-1/16" 10M M 3" FEMALE :O Pressure Control BA ER 16" x 9-5/8" x 7" x 4-1/2 x 3-1/2" 5/10M MB-230 Multibowl Assembly, UGHES With MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet a GE company COPYWAIGNTB Mt IETMy NOTICE CepywrgM 2B1] Bek« HuOtlea.e OE company, LLC (unpuDllMSJ xak). NI rlBbh IuwW. TM b�ImneDm mihint b Mb tlavnml4 mmpeny cvnMUYisI W On>CMNUY Property of Baker MugDea antl Rs ekliebi Dhbbe uaJ anb Mms bemMal Baker Nupbes aM mry m%baJMbuled, tr�omXbE,rtpetlucaQ akered i«.nr p«Dcee wtlkaul me.ape.. wmm� P.."."a Bak« NUDIm. """` n Attachment D OIL SEARCH ALASKA MITQUQ 1 ST1: PROGNOSIS ooilSearch ERA AGE Formation WD LITHOLOGY CASING COMMENTS Q < � W u d — Pnnce Greek F. 0 400 800 1200 D o , •o' o• . b. o o '. `._ _. _ • ._ I • 16" t E Oase PerPulrosl 1600 2000 2400 Non- Reservoir •9.825" ydrocarbo _ _ _ a kllOtlle SChiatler Rlutt € MC:U -- v lower chraaer Ntt AS -5 Tu1uvkFnr 1W 2800 r 3600 -- Seabee Futmailon Non- � 4000 _ Reservoir U — _ Non -Reservoir ' Top Nanushuk — No ese 'r ToD Nanushukg �.... f 4800 ydrocarboi — S 5200 NanuShuk9 r Non- 5600 E Tnrok,Nan5) woo- - - - Reservoir .7" Shale Conglomerate Sand [:] Sand E] Tuff Siltstone Attachment E Redacted M. Guhl 5/6/2022 Schlumbeplep FracCADE* STIMULATION PROPOSAL Operator : Oil Search Well Mitquq Field Pikka East Formation Nanushuk County North Slope State Alaska Country United States Prepared for Scott Leahy Date Prepared 11-21-2019 Prepared by Phone E-Mail Address `Mark of Schlumberger Service Point Prudhoe Bay, Alaska Business Phone 1 907 659 2434 FAX No. 1907 659 2538 Mike Hyatt 907-273-4748 MHyatt@slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be interred. Attachment G Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay, Alaska schlumberger Section 1: Zone Data Formation Mechanical Properties Zone Name Top TVD Iftl Zone Height (ft) Frac Grad. (psi/ft) Insitu Stress (psi) Young's Modulus (psi) Poisson's Ratio Toughness (psi.inO.5) TOP NAN SHALE 4026.0 5.0 0.704 2838 5.171 E+5 0.32 100 TOP NAN SHALE 4031.0 3.0 0.710 2865 5.211 E+5 0.32 100 TOP NAN SILT 4034.0 6.0 0.661 2667 4.935E+5 0.30 1000 TOP NAN SHALE 4040.0 4.0 0.710 2868 5.800E+5 0.33 100 TOP HAN SHALE 4044.0 3.4 0.723 2924 5.468E+5 0.33 100 TOP NAN DS 4047.4 7.5 0.661 2676 6.766E+5 0.31 700 TOP NAN CS 4054.9 5.1 0.655 2656 6.462E+5 0.30 1200 TOP NAN SILT 4060.0 4.5 0.692 2812 5.776E+5 0.32 1000 TOP NAN DS 4064.5 8.4 0.653 2655 7.070E+5 0.29 700 TOP NAN SILT 4072.9 13.1 0.681 2779 7.608E+5 0.31 1000 TOP NAN SILT 4086.0 5.0 0.686 2805 7.491E+5 0.32 1000 TOP NAN SILT 4091.0 4.5 0.676 2769 7.095E+5 0.33 1000 TOP NAN CS 4095.5 8.0 0.629 2580 6.514E+5 0.31 1200 TOP NAN CS 4103.5 4.1 0.625 2565 8.597E+5 0.30 1200 TOP NAN CS 4107.6 14.4 0.606 2493 7.725E+5 0.29 1200 TOP NAN CS 4122.0 13.0 0.612 2527 7.950E+5 0.29 1200 TOP NAN CS 4135.0 15.0 0.625 2588 8.231E+5 0.30 1200 NAN 9 TOP CS 4150.0 16.0 0.625 2599 8.345E+5 0.30 1200 NAN 9 CS 4166.0 7.0 0.621 2588 8.159E+5 0.30 1200 NAN 9 CS 4173.0 13.0 0.630 2631 8.259E+5 0.30 1200 NAN 9 CS 4186.0 19.0 0.635 2666 8.423E+5 0.30 1200 NAN 9 CS 4205.0 10.3 0.630 2653 8.288E+5 0.30 1200 NAN 9 CS 4215.3 9.7 0.616 2598 8.421 E+5 0.30 1200 NAN 9 CS 4225.0 6.0 0.638 2696 9.143E+5 0.30 1200 NAN 9 CS 4231.0 11.0 0.630 2667 9.022E+5 0.30 1200 NAN 9 CS 4242.0 7.0 0.622 2640 8.779E+5 0.30 1200 NAN 9 CS 4249.0 7.3 0.642 2731 9.186E+5 0.30 1200 NAN 9 CS 4256.3 6.7 0.642 2735 9.673E+5 0.30 1200 NAN 9 CS 4263.0 14.3 0.642 2741 9.088E+5 0.30 1200 NAN 9 DS 4277.3 7.7 0.648 2775 1.014E+6 0.30 700 NAN 9 CS 4285.0 7.0 0.620 2661 9.151E+5 0.30 1200 NAN 9 CS 4292.0 20.1 0.622 2678 9.086E+5 0.30 1200 NAN 9 DS 4312.1 1 4.9 0.649 1 2798 9.686E+5 0.30 700 Attachment G Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay, Alaska schlumhcrgcr Formation Transmissibility Properties Zone Name Top TVD (ft) Net Height Ift) Perm (md) Porosity 1%1 Res. Pressure (psi) Gas Sat. (%) Oil Sat. i%1 Water Sat. (%) TOP NAN SHALE 4026.0 0.1 0.001 22.7 2014 65.0 10.0 25.0 TOP NAN SHALE 4031.0 0.1 0.001 22.6 2016 65.0 10.0 25.0 TOP NAN SILT 4034.0 2.4 1.000 23.9 2018 65.0 10.0 25.0 TOP NAN SHALE 4040.0 0.1 0.001 22.6 2021 65.0 10.0 25.0 TOP HAN SHALE 4044.0 0.1 0.001 23.2 2023 65.0 10.0 25.0 TOP NAN DS 4047.4 5.2 1.000 21.1 2025 65.0 10.0 25.0 TOP NAN CS 4054.9 5.1 1.000 18.5 2029 65.0 10.0 25.0 TOP NAN SILT 4060.0 1.8 1.000 20.8 2031 65.0 10.0 25.0 TOP NAN DS 4064.5 5.9 1.000 20.0 2034 65.0 10.0 25.0 TOP NAN SILT 4072.9 5.2 1.000 19.7 1977 65.0 10.0 25.0 TOP NAN SILT 4086.0 2.0 1.000 19.1 1902 65.0 10.0 25.0 TOP NAN SILT 4091.0 1.8 1.000 19.1 1863 65.0 10.0 25.0 TOP NAN CS 4095.5 8.0 13.000 21.3 1817 65.0 10.0 25.0 TOP NAN CS 4103.5 4.1 30.000 22.2 1806 65.0 10.0 25.0 TOP NAN CS 4107.6 14.4 25.000 22.1 1810 65.0 10.0 25.0 TOP NAN CS 4122.0 13.0 20.000 21.6 1816 65.0 10.0 25.0 TOP NAN CS 4135.0 15.0 13.000 20.8 1823 65.0 10.0 25.0 NAN 9 TOP CS 4150.0 16.0 13.00 0 20.9 1829 65.0 10.0 25.0 NAN 9 CS 4166.0 7.0 16.000 20.8 1834 65.0 10.0 25.0 NAN 9 CS 4173.0 13.0 11.000 20.5 1839 65.0 10.0 25.0 NAN 9 CS 4186.0 19.0 8.000 20.2 1846 65.0 10.0 25.0 NAN 9 CS 4205.0 10.3 10.000 20.3 1852 65.0 10.0 25.0 NAN 9 CS 4215.3 9.7 9.000 20.2 1857 65.0 10.0 25.0 NAN 9 CS 4225.0 6.0 6.500 19.3 1860 65.0 10.0 25.0 NAN 9 CS 4231.0 11.0 7.500 19.9 1864 65.0 10.0 25.0 NAN 9 CS 4242.0 7.0 9.500 20.5 1868 65.0 10.0 25.0 NAN 9 CS 4249.0 7.3 9.300 20.1 1871 65.0 10.0 25.0 NAN 9 CS 4256.3 6.7 3.700 18.9 1874 65.0 10.0 25.0 NAN 9 CS 4263.0 14.3 8.600 20.1 1879 65.0 10.0 25.0 NAN 9 DS 4277.3 5.4 8.800 19.6 1884 65.0 10.0 25.0 NAN 9 CS 4285.0 7.0 16.000 20.8 1887 65.0 10.0 25.0 NAN 9 CS 4292.0 20.1 10.000 20.1 1 1893 65.0 1 10.0 1 25.0 NAN 9 DS 4312.1 3.4 10,000 20.2 1 1898 65.0 1 10.0 1 25.0 Attachment G Schlumberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay, Alaska schlumhurpur Section 2: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 214.5 ft with an average conductivity (Kfw) of 23964 md.ft. Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (bbl) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 25.0 YF120ST 200 20.0 0.00 1.0 PPA 25.0 YF120ST 96 20.0 16/20 C-Lite 1.00 2.0 PPA 25.0 YF120ST 138 20.0 16/20 C-Lite 2.00 4.0 PPA 25.0 YF120ST 191 20.0 16/20 C-Lite 4.00 6.0 PPA 25.0 YF120ST 198 20.0 16/20 C-Lite 6.00 8.0 PPA 25.0 YF120ST 185 20.0 16/20 C-Lite 8.00 9.0 PPA 25.0 YF120ST 90 20.0 16/20 C-Lite 9.00 10.0 PPA 25.0 YF120ST 76 20.0 12/18 C-Lite 10.00 FLUSH 25.0 WF120 34 30.0 0.00 Please note that this pumping schedule is under -displaced by 5.0 bbl. Fluid Totals 1174 bbl of YF120ST 34 bbl of WF120 Proppant Totals 193700 lb of 16/20 C-Lite 32100 lb of 12/18 C-Lite Pad Percentages % PAD Clean 17.0 % PAD Dirty 114.2 Attachment Schlu mberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay, Alaska Schlcmbergcr Job Execution Step Name Step Fluid Volume (bbl) Cum. Fluid Volume (bbl) Step Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (Ib) Cum. Prop. (Ib) Avg. Surface Pressure (psi) Step Time (min) Cum. Time (min) PAD 200 200 200 200.0 0 0 2499 8.0 8.0 1.0 PPA 96 296 100 300.0 4023 4023 2497 4.0 12.0 2.0 PPA 138 434 150 450.0 11583 15607 2466 6.0 18.0 4.0 PPA 191 625 225 675.0 32155 47761 2460 9.0 27.0 6.0 PPA 198 823 250 925.0 49867 97628 2502 10.0 37.0 8.0 PPA 185 1008 250 1175.0 62170 159798 2612 10.0 47.0 9.0 PPA 90 1098 125 1300.0 33870 193668 2698 5.0 52.0 10.0 PPA 76 1174 110 1410.0 32107 225776 2806 4.4 56.4 FLUSH 34 1208 34 1444.2 0 225776 2367 1.4 57.8 Attachment Schlu mberger-Private Client Oil Search Well Mitquq Formation Nanushuk District Prudhoe Bay, Alaska Schlumbergur, Section 3: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD ------------------------- 4150.0 ft Initial Fracture Bottom TVD 4166.0 ft Propped Fracture Half -Length 214.5 ft EOJ Hyd Height at Well_________________________ 187.9 ft Average Propped Width______________________ 0.347 in Net Pressure_. -------- ----------------------------- 230 psi Max Surface Pressure_______________ 2851 psi Simulation Results by Fracture Segment From (ft) To (ft) Prop. Conc. at End of Pumping (PPA) Propped Width (in) Propped Height (ft) Frac. Prop. Conc. (lb/ft2) Frac. Gel Conc. (lb/mgal) Fracture Conductivity (md.ft) 0.0 53.6 10.3 0.380 143.9 3.36 215.7 32442 53.6 107.3 9.8 0.392 173.3 3.54 216.0 26705 107.3 160.9 10.5 0.373 156.2 3.40 220.9 23426 160.9 214.5 5.9 0.268 134.8 2.51 265.9 15672 Attachment G Schlumberger-Private Scblumbuger Client: Oil Search Alaska Well: Mitquq Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -Job Well Completed: 2/14/2020 Date Prepared: 11/19/2019 2:17 PM Report ID: RPT-64247 Name & Volume WF120:YF1205T 67,200 Gal Additive B484 DescriptionFluid Additive Enzyme Breaker B484 0.03 Gal / 1000 Gal Volume 1.7 Gal F103 Surfactant 1 Gal / 1000 Gal 67.2 Gal J450 Stabilizing Agent 0.5 Gal / 1000 Gal 33.6 Gal J475 Breaker 3 Lb / 1000 Gal 201.6 Lb 1511 Stabilizing Agent 2.7 Lb / 1000 Gal 182.7 Lb J532 Crosslinker 5.4 Gal / 1000 Gal 365.4 Gal J580 Gelling Agent 20 Lb / 1000 Gal 1,344.0 -Lb L065 Scale Inhibitor 2 Gal / 1000 Gal 134.4 Gal_ M002 Additive 0.5 Lb / 1000 Gal 30.4 Lb M275 Bactericide 0.4 Lb / 1000 Gal 24.0 Lb 5522-1218 Propping Agent varied concentrations 32,000.0 Lb 5522-1620 Propping Agent varied concentrations 193,000.0 Lb i ne rorot volume ustea in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number - Chemical Name Water (Including Mix Water Supplied by Client)" Mass Fraction - 71 % 66402-68-4 Ceramic materials and wares, chemicals - 29 % 9000-30-0 Guar gum < 1 % 56-81-5 1, 2, 3 - Pro anetriol < 0.1 % 1303-96-4 Sodium tetraborate decahydrate <0.1 % 102-71-6 2,2',2"-nitrilotriethanol < 0.1 % 107-21-1 Ethylene glycol <0.1 % 129898-01-7 2-Propenoic acid, polymer with sodium phosphinate < 0.1 % 50-70-4 Sorbitol <0.1 % 7727-54-0 Diammonium peroxodisulphate <0.1 % 67-63-0 Propan-2-ol < 0.1 % 111-76-2 2-butoxyethanol <0.1 % 34398-01-1 Ethoxylated Cll Alcohol _ < 0.1 % 68131-39-5 Ethoxylated Alcohol < 0.01 % 7647-14-5 Sodium chloride <0.01 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer < 0.01 % 1310-73-2 Sodium hydroxide < 0.01 % 10043-52-4 Calcium Chloride < 0.01 % 91053-39-3 Diatomaceous earth, calcined < 0.01 % 112-42-5 Undecanol <0.01 % 7631-86-9 Non -crystalline silica (impurity) <0.001 % 111-46-6 2,2"-oxydiethanol(impurit) <0.001 % 10377-60-3 Magnesium nitrate <0.001 % 26172-55-4 5-chloro-2-methy1-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 14807-96-6 Magnesium silicate hydrate (talc) <0.001 % 7447-40-7 Potassium chloride (impurity) <0.001 % 9002-84-0 poly(tetrafluoroethylene) < 0.0001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 127-08-2 Acetic acid, potassium salt <0.0001 % 68-04-2 Sodium citrate <0.0001 % 14808-60-7 Quartz, Crystalline silica <0.0001 % 14464-46-1 Cristobalite <0.0001 % 9012-54-8 Hemicellulaseenzyme <0.0001 % 64-19-7 Acetic acid (impurity) <0.0001 % 2634-33-5 1,2-benzisothiazolin-3-one Total <0.00001 % 00% Attachment H ® Schlumberger 2019. Used by Oil Search Alaska by permission. Page: 1 / 2 5chlumherger Client: Oil Search Alaska Well: Mitquq Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -Job Well Completed: 2/14/2020 Date Prepared: 11/19/2019 2:17 PM ReportID: RPT-64247 *Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannotprovide a breakdown ofcomponents that may have been added to the water by third -parties. `The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRGchemicals as of the date of the document was produced. Any new updates will not be reflected in this document. ® Schlumberger 2019. Used by Oil Search Alaska by permission. Attachment H Page: 2 / 2 Mitquq 1 ST-1 Clean-up and Test Summary TABLE OF FLOW PERIODS (15.5 Day) PurposeDuration Flow / Build Up Table (hours) Bring well on slowly (16/64th) via adjustable choke, adjust as necessary to achive stable flow. Monitor As Required returns for proppant and adjust choke as necessay Clean -Up & Initial Flow —24 - 48 to avoid damage to proppant pack and to minimize errosion to surface equipment. The OS Resevoir Engineer will determine when the well is clean and advise choke changes/rates for initial flow period. Initial Pressure Build Up —24 Shut in for Build-up /Analysis Wel I Test (Main Flow) Conduct 6 day flow test as per table below or as 3 rd Party Oil & Gas Samples for Clean-up PVT, EOR, & SCAL Initial Flow will be taken at the Separator as per 144 Main Flow Reservoir Engineer's direction Max Rate Rate# Flow Rate BBL/D Duration (hours) 1 1500 24 2 2000 1 24 S I 0 24 3 800 144 S I 0 144 4 4500 12 NOTE: Main flow period Rates and periods are indicative and will depend on may be extended (TBC) clean-up, drawdown, and reservoir properties Final Build -Up Period 144 Shut in for Build-up / Analysis Max Flow (If time allows) 12 Conduct Max Flow Test as directed by OS Reservoir Per regulation 20AAC25.235 (d) 6, Oil Search is requesting AOGCC permission to flare the produced gas for the duration of the exploration well production test. Estimated total volume of gas per the estimated well test volumes above is approximately 6.2 MMscf,, , Apr, �c Attachment I Well Cleanup - Operational Summary: • Estimates Time: 24 — 48 hours or as dictated by Oil Search Reservoir Engineer. • Target Clean-up Flow Rate: 50 —1500 BPD w/ some gas • Target Post Clean-up Flow Rate: Up to 2000 BPD & 1.2 mmscf/d • Choke Setting: Use adjustable choke to achieve a flow rate at approximately 100 psi per hour drawdown or until well is stable. Watch BS&W and adjust drawdown rate as needed. The OSA Reservoir Engineer or OSA Well Test Supervisor will advise choke changes based on well performance and solids production. • Proppant Production: Proppant production is expected and will managed by bringing on the well slowly and beaning up choke based on well performance and bottoms up solids production. • Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure is 2,000 psi, bleed down as necessary. • Nz Injection Rate: As per contingency N2 well kick-off procedures if required. • Methanol Injection Rate: McOH will be injected into the well via the inner annulus to prevent the formation of hydrates. Injection rates will vary based on produced water volumes. • Sampling: Asper sampling table below. SamplingSurface Flow Sample Lob Number/ Sampling Collection Period Type Analysis Frequency Location Volume Container Vendor Comments Centrifuge Utilize EB as necessary, BS&W, API, WC 30minute Choke 100m1 PTS docurnent chemicals in Tube job log (� Oil API Hourly Separator 1000ml Nalgene PTS Gravity Bottle M al Salinity H2O % Hourly Separator NA NA PTS Perform hourly or as Chlorides H2O production allows i_ Ranarex Gas Hourly Separator NA NA PTS Gravity Glass Hourly to start, reduce Sample HzS, COz Hourly Separator NA NA PTS to every 12 hrs if no H2S Tube observed after 3 consecutive reads. Attachment I Main Flow- Operational Summary: • Estimates Time: —144 hours or as directed by OS Reservoir Engineer. • Main Flow Period: Up to 800 BPD & up to .500 mmscf/d • Choke Setting: Bring the well on slowly using the PTS adjustable choke, OSA Engineer will advise drawdown targets based on observation from initial flow. Step open choke until desired flow rate is achieved, then switch to a positive choke. The OSA Reservoir Engineer & OSA Well Test Supervisor will advise target rates and choke changes. • Proppant Production: Minimal proppant production is expected. • Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure will be 2,000 psi., bleed as required. • Downhole Shut-in Valve: A programable down -hole shut-in valve has been installed. • Sampling: As per sampling table below Surface Sampling Program Flow Sample Lab Number/ Location Volume Sampling Collection Comments Period Type Analysis Frequency Container Vendor Utilize EB as necessary, BS&W WC' 30minute Choke 100m1 Centrifuge pTS document chemicals in Solids% Tube job log Oil API Hourly Separator 100 ml PTS Gravity Salinity H20/, Hourly Separator NA NA PTS Perform hourly or as PH, H2O production allows Gas Every 4 T Ranarex Gravity Y hrs Separator NA NA PTS Q Glass C Sample H2S, CO2 Hourly Separator NA NA PTS !� Tube Dead Mid flow DOT Ten containers total Crude Facilities PTS P eriod Stock Tank 50Gal Approved (7-Facilities,3core 5-gal Steel studies) 3rd Party SaMpling Flow (PVT) Study Sample Volume Period PVT, EOR, Surface Matched sets taken at same time period (3 sets -Facilities, 10sets-SubSurf.) Flash (13) 735cc Prolight cylinders (each filled with >500ccoil) (13) 20-I ite r Luxfer cylinders (each filled with 20 litergas) Document sampling location, time, pressure, and temperature Wettability Surf=(4)I-lteolyproplyene (non -pressurized) TContingency Downhole Sample OStudy `S Sample Volume PVT, EOR, Downhole 7200cc (Volume dependant upon MDTsampling results -to be clarified by OS SCAL Reservoir Fluid Reservoir Engineer. Facilities requires 1500 cc minimum, prefers 3000 cc) Metering Standard Fluid Rates & Volumes - Tank Straps will be used for all reported fluid rates & Volumes, in addition there will be turbine meters on the oil and water legs of the separator for reference. Gas Rates & Volumes - A Daniels differential pressure flow meter. Attachment I Mitquq ST1 Completion Procedure 1. 7" 26# casing tested to 3,500 psi 2. USIT and VSP log has been completed and USIT results has been forward to AOGCC. 3. RIH with E-line perforation guns and perforate the 7" 26# @ ,377'-4,38� (Actual _ placement TBDafterdrilling) �.+,,�,� `1S`17— y S6Z 4. RIH with 3-1/2" 9.2# completion and jewelry. a-z 5 _4-" 5. Landing tubing hanger and test upper and lower seals to 250 psi/5min and 5,000 psi/30 min. Z�- Verkn Chart pressure test. 10 1-L+' 6. Bull head freeze protect into annulus—2,000' TVD. 7. Drop ball and rod to set the retrievable packer. 8. Increase pressure to 3,500 psi to set the packer and hold for 30 minutes. Chart pressure test. MIT-T, tubing integrity test per AOGCC. (5,700 psi MAWP — 2,600 psi IA)*1.1= 3,410 psi (Testing tubing to 3,500 psi) 9. Slowly increase IA pressure to 3,100 psi and hold for 30 min. Chart pressure test. MIT -IA, annulus integrity test per AOGCC. 10. Rig up slickline to two TIW valves to pull ball and rod/RHCM plug and run XX plugs. 11. RIH to retrieve the ball and rod/RHCM plug 12. Shut in annulus, open tubing and bull head freeze protect to—2,000' TVD. 13. RIH and set #1 XN plug @—4,338' XN Landing nipple, and pressure test plug to 2,500 psi and chart for 30 min. 14. RIH and set #2 X plug @ —500' X Landing nipple, and pressure test plug to 2,500 psi and chart for 30 min. 15. Rig down slickline 16. Set TWCV into tubing hanger 17. N/D BOPE Stack and N/U Tree. 18. Fill tree with diesel, Rig up LRS to test tree, test surface lines to 7,500 psi. 19. Test tree and chart to 500 psi for 5 min and 7,000 psi for 15 min. 0. Drillin Rig demo 2 PUII TWCV �i 22. Rig up sickline to retrieve X/XN plugs. 23. Rig down slickline 24. Shut in well and rig down lines. 25. Secure well, prepare for frac operations. Attachment J Mitquq STi Fracturing Procedure Held IA IA PRV (psi) GORV (psi) Pump Trip Pressure Pressure (psi) (psi) Job 1 2,600 2,900 5,400 5,000 Treatment MD Perf TVD Perf Max Frac Frac Y. Max Rate Max Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. (psi) (PPA) Job Max 4,388 4,155 187.9 214.5 25 2,851 30 MAWP = 5,700 psi, GORV = 5,400 psi, IA Pressure Max psi = 2,600 psi, IA PRV = 2,900 psi 1. MIRU Schlumberger frac equipment and treating line to the frac tree. 2. R/U to the annulus valve and isolate the pressure relief valve. 3. Pressure test IA line to 3,100 psi. 4. Open line to annular PRV and verify relief at 2,900 psi. 5. Open the casing valve and proceed to pressure up the 7" x 3 % annulus to 2,600 psi. 6. Prime up the frac pumps. 7. Isolate the GORV on the treating line and pressure test the treating line to 6,500 psi. 8. Upon successful pressure test, bleed off pressure and open the GORV on the treating line. 9. Open well head and pump DataFRAC- 10. Shut down and isolate the wellhead pressure gauge from the pumps if necessary. 11. Monitor the bottom hole, wellhead, and annulus pressures until closure is observed. 12. Modify PAD volume and/or schedule if necessary. 4 L- r% 13. Pump frac treatment as referenced in attachment G. 14. Upon completion of frac, isolate well head, bleed off line pressure, rig down frac equipment, and demobilize frac equipment from wellsite. Mitquq STi Flow Test Procedure 1. Move in and rig up Well Test Surface Equipment as per P&ID and Pad Layout/ Flow Diagram. 2. Perform low pressure air test of 100-120 psi, hold 10 minutes. (N2 will be used if hydrocarbon is present). 3. Pressure test all surface equipment and hardline upstream of the choke manifold to 5,000 psi and hold 15 minutes. Pressure test all downstream flow iron (with exception of flare) to 1000 psi and hold 15 minutes. Cap the gas line to the flare/incinerator and test line with air to 120 psi for 15 minutes. (N2 will be used if hydrocarbons are present) 4. Perform Clean Up Flowback as per procedures 5. Perform Flow Test, Shut In, and Sampling as per procedures 6. Rig down and demobilize equipment. /¢ G C- i^r�, c��=" ' U+v Attachment J Mitquq: HP Line PRV Rigup <�.IA�P.-pPRV Mitquq 1 ST1 Pre -drill Well Schematic 16" Conductor 128' MD/TVD Surface Casing 9-5/8" 40# L80 BTC 12 '/4" Hole 2,475' MD/TVD 3-/2"'X' Landing Nipple 4284' MD/1076' TVD Tubing P/T Gauges 4292' MD/4082' TVD 8 4303' MD/4088' TVD 3-'/z", 'XN' Landing Nipple 4338' MD/4116' TVD 360' Core, Oil Sea (A Oil Search Updated Nov. 5°i 2019 3-/2". 2.813" Polish Bore'X' Landing Nipple 500' MD/TVD 3'/2" 9.2# L80 Vam Top Tubing GLM, 3-'/2" 3000' MD/TVD ES -Cementer Stage Cement Tool 3200' MD ST1 Kick Off @ 2600' MD/TVD 3 '/2' X 7" Packer 4321' MD/4103' TVD :G 4345' MD/4121' TVD N Planned Perforations —4,377- 4,382' MD/ 4,158' TVD, 39.5° Inc. Production Casing 7" 26# L80 Vam Top HC 8 %" Hole 6,130' MD/5708' TVD Mitquq 1 Drilling Program Version B - 8 - 7" casing cut @ 2,625' MD 3-%" BHKA @ 4,100' MD/3,838' TVD 3-/2" 9.2# L-80 IBT Sacrificial Tubing 7" 26# L80 Vam Top HC 8'/," Hole 6,933' MD/5,954' TVD 6-1/8" OH 20' inclination ' TD: 8250' MD / 7175' TVD 11-Nov-2019 Attachment L Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Saturday, February 22, 2020 11:04 PM To: Staudinger, Garret Cc: Kuck, Marc; Kono, Randy Subject: Re: PTD #219-151 Mitquq 1 ST1 Triple combo and Mud Log r� Garrett, You have verbal ar)nroval to proceed with r)erforatine Mitaua 1 ST1 at 4.547-4552 ft_MD. _ Bond log indicates good to average cement in perforation area. Should give adequate zonal isolation for upcoming Frac. As you mentioned below the second stage doesn't show up all. This Doesn't impact fracture stimulation approval but will have be addressed during P &A procedure. Regards Guy Schwartz AOGCC Sent from my Whone On Feb 22, 2020, at 10:45 PM, Staudinger, Garret <Garret.Staudinger@oilsearch.com> wrote: Guy, Requesting verbal approval to perforate from—4,547'-4,552' MD/ 4,275' TVD. Please let us you if you are good with this plan. Thanks, Garret From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Saturday, February 22, 2020 10:21:23 PM To: Guy Schwartz <guy.schwartz@alaska.gov> y Cc: Kuck, Marc <Marc.Kuck@oilsearch.com>; Kono, Randy <Randy.Kono@oilsearch.com>, Subject: Re: PTD #219-151 Mitquq 1 ST1 Triple combo and Mud Log Guy, Attached are the USIT results for the 7" casing cement job. Sorry it took so long to get through, but I wanted to have Schlumberger's expert take a look at the log to confirm all the input parameters were correct prior to sending. In summary, the first stage cement job looks okay but not great through the zone of interest for the frac. The second stage from 2450' to surface is showing almost no bond, and we are really questioning the results on the USIT for this portion of the well. We did have a packer set at 2450' MD, full returns through the cement job, and cement to surface. The walk away VSP log is ongoing, and SLB is saying they will be done in approximately 8 hours. After that our plan was to proceed with the pert run prior to running completion. Please advise if we have approval to proceed with the perforating run. Feel free to give me a call if you have any questions. Thanks, Garret From: Staudinger, Garret Sent: Friday, February 21, 2020 9:38:31 AM To: Guy Schwartz <guy.schwartz@alaska.gov>; Stephen F Davies (steve.davies@alaska.gov) <steve.davies@alaska.gov> Cc: Kuck, Marc <Marc.Kuck@oilsearch.com>; Kono, Randy <Randy.Kono@oilsearch.com> Subject: PTD #219-151 Mitquq 1 ST1 Triple combo and Mud Log Guy / Steve, In preparation for the Frac Sundry, attached are the wireline log data and Mudlog for the Mitquq 1 ST1 wellbore. Note that the wireline triple combo data only includes data from kick off point to TD. We just finished displacing to completion brine, and plan to start our cement evaluation wireline log this evening. I'll be sending that through tomorrow sometime as soon as it gets processed. We will likely be ready to perforate on Sunday sometime. Please let me know if you have any questions or need any additional information. Thanks, Garret GARRET STAUDINGER I SENIOR DRILLING ENGINEER i OIL SEARCH LIMITED PO Box 240927, Anchorage, AK 99524-0927 Mob: +1 907 440 6892 ; Tel: +1 907 375 4666 Email: garret.staudinger(ccboilsearch.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 ************************************************************************************* ************************** r � 0 w m 0 v El 111111111--i-f J. I* J. I* HOT TT LITTLE RED SERVICES INC. swviv" JOB REPORT Company: Oil search Contact: Phone: COMPANY DETAILS JOB DETAILS Email: DATE 2/24/2020 6:05:33PM START TIME 2/24/2020 6:05:33PM Location: MITQUQ END TIME 2/24/2020 6:47:01 PM Operator: Gibson Unit#: 23 Ticket#: Test Type: MIT-T Fluid Pumped #1: Diesel Fluid Pumped #2: Fluid Pumped #3: Fluid Pumped #4: Comments: MIT-T **PASSED** L - Wireless 1 TBG (PSI) 3500 3000 r� i 2500 II� f 2000 f I 1500 1000 I I 500 0 18:05 18:10 18:15 18:20 18:25 18:30 18:35 18:40 18:45 24 Mon Feb 2020 LLITTLE RED SERVICES INC. JOB REPORT COMPANY DETAILS Company: Oil search Email: Contact: Phone: JOB DETAILS DATE February 24, 2020 START TIME 18:53:31 Location: MITQUQ END TIME 19:32:15 Operator: Gibson Unit#: 23 Ticket#: Test Typ : MIT -IA Fluid Pumped #1: Diesel Fluid Pumped #2: Fluid Pumped #3: Fluid Pumped #4: Comments: MIT -IA *'PASSED** SUMMARY GRAPH L - Wireless 1 TBG (PSI) 3000 / 2500 i 2000 / 1500 /I _ I r 1000 500 I 0 18:55 19:00 19:05 19:10 19:15 24 Mon Feb 2020 19:20 19:25 19:30 Report Created: 24-Feb-20 Schwartz, Guy L (CED) From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Monday, February 17, 2020 5:27 PM To: Schwartz, Guy L (CED) Cc: Tirpack, Robert; Johnson, Vern Subject: RE: PTD 219-151 Mitquq 1 ST1 7" Casing stage tool Follow Up Flag: Follow up Flag Status: Flagged Guy, Below are a summary of changes to the 2 stage cement job for the 7" production casing. Changes from original program are in red. The biggest change we are proposing is putting targeted top of cement on the 1st stage to 3000' MD (500' below surface casing shoe) and changing excess cement on both stages to 10% excess. The excess change from 30% to 10% is due to the caliper log that was run on the wireline logging tools. The caliper log indicates gauge hole. Additionally, moving the 1 st stage top to 500' below the surface casing shoe helps reduce excessive pumping pressures during the job that could result in prematurely opening and inflating the packer on the stage tool. Production Casing Cement - STAGE 1 Casing 7" 26# L80 Vam Top HC Casing Lead Open hole volume + 10% 48°6 excess -3000' M D / 2995' TVD Lead TOC Tt4u..44 -3200' n / Basis IV ID Eellar-Depth 3184' T-VD (base Tail Open hole volume + 10% 39°6 excess + 500 ft shoe track ��onn nan1-110 ' �� -3800' MD/3703' TVD. 500' MD above top of Nanushuk Tail TOC 9 sandstone Spacer 30bbls of 11.5ppg Tuned Spacer Total Lead 20bbls, 112cuft, 53sks of 12.Oppg ExtendaCem, Yield: 2.132cuft/sk Cement Volume Tail 41bbls, 230cuft, 185sks of 15.3ppg ExpandaCem Class G, Yield: 1.24cuft/sk Temp BHST 156' F Verification Method Cement returns and wireline CBL Job will be mixed on the fly Notes Two stage cement job, first stage pumped with top and bottom plugs Production Casing Cement - STAGE 2 Casing 7" 26# L80 Vam Top HC Casing Basis Lead Cased hole volume + 3"0 10% excess Lead TOC Surface Tail 4---Me 4. -30 excess. Cased hole volume + 3"0 10% excess Tail TOC 500' MD above stage tool IA8- AA Bz :psi 2 eJ s} Total Cement Volume Spacer 30 bbls of 11.5 ppg Tuned Spacer Lead 59bbls, 331cuft, 138sks of 12.Oppg VariCem, Yield: 2.40cuft/sk Tail 16bbls, 90cuft, 73sk,� of 15.3ppg ExpandaCem Class G, Yield:1.2405 cuft/sk Temp I BHST 88' F I Verification Method I Cement returns to surface I Notes I Job will be mixed on the fly Two stage cement iob. second stage pumped with ton plug only Please let me know if you are in agreement with the proposed changes, and feel free to call anytime if you have any questions. Regards, Garret From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Sunday, February 16, 2020 9:43 AM To: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com>; Johnson, Vern <Vern.Johnson@oilsearch.com> Subject: [EXTERNAL] RE: PTD 219-151 Mitquq 1 ST17" Casing stage tool Garret, You have approval to modify the 7" casing cement program as outlined below. ES cementer placement at approx. 2400 ft inside the 9 5/8" is APPROVED. Forward me any cement volume changes for the two stages if any... they are likely not too different. 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 (Guv.schwartz@alaska.gov). From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Friday, February 14, 20201:42 PM To: Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com>; Johnson, Vern <Vern.Johnson@oilsearch.com> Subject: PTD 219-151 Mitquq 1 ST17" Casing stage tool Guy, Per our conversation today, we are planning to 2 changes for the 7" casing 2"d stage cement job to mitigate potential lost circulation to the weak zone below the 9-5/8" surface casing shoe. 1) Run a 7" ESIPC (combo stage tool / ECP packer) instead of an ES cementer for the 2"d stage cement job on the 7" production casing string. The inflatable packer will provide a hard bottom for the 2"d stage job. 2) Move ESIPC stage tool inside the 9-5/8" casing shoe (stage tool located -2400' MD). Due to the low LOT and presence of a sandy interval just below the shoe, the only way to ensure we don't loose circulation to the formation is to move the inflatable packer inside casing. As a reminder, there is no presence of Tuluvak in this wellbore. Below is a schematic of originally planned design for your reference. Mitquq 1 ST1 Pre -drill Well Schematic 16" Conductor 128' MDR'VD Surface Casing 9-518- 40# L80 eTC 12-%" Hole 2,475' MD/TVD 3-!T'X Landing Nipple 4284' MD;1076' TV0 Tubing PIT Gauge- 4292' MO.4082' TV0 a 4303' MD'4088' TV0 XNLand=ng Ngpple 433Er 0Ac!4116' TVD 360' Core - (P Oil Search Uix1xed Nov 5 20ts 3-'r;" 2 813" Palish Boas X' Landing Mppt,e 500' MD'TVD >16 3-Y," 9.2# L80 Vam Top Tubing t �� GLM, 3 300(r MD,'TVD ES -Cementer Stage Cement Tool 3200' t.10 ST1 Kick Off 4 2600' MDTVD 3-Y,' X 7' Packer 432 V MDl4103` TVD WLEG 4345' MD4121' TVD N Planned Perforations -4,377.4.382' MDR 4,158' TVD. 39.5' Inc. 7' casing cut @ 2.625' MD 3-'.'; BHKA A) 4.100' MD,1.838' TVD Production Casing 1" 260 L80 Vam Top HC 7' 260 L80 Vam Top HC 8 y, Hole 8 ",' Hale 6,130' MD15708' TVD 6.933' h10 5.954' TVD 3- /,- 9 2rt L-80 IBT S_acrifaotl Taking 6-1.v 0H 20' sncl1nalkl-1 TD 8250' MD t 7175' TVD Please let me know if you have any questions or concerns with the proposed changes to the 7" 2nd stage cement job on the production casing string. Regards, 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.staudingerCd)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 3 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, February 18, 2020 2:27 PM To: Staudinger, Garret Cc: Tirpack, Robert; Johnson, Vern; Quay, Walter Subject: RE: PTD 219-151 Mitquq 1 ST1 7" Casing stage tool Garret, You have approval to go to 0% excess on 15t and modify cement program as proposed in the last email. Good luck. 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.gov). From: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Sent: Tuesday, February 18, 2020 10:30 AM To: Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com>; Johnson, Vern <Vern.Johnson@oilsearch.com>; Quay, Walter <Walter.Quay@oilsearch.com> Subject: RE: PTD 219-151 Mitquq 1 ST17" Casing stage tool Guy, Please disregard previous email on cement volume revisions. Per our conversation, our proposed revision to the 7" production casing cementing program is below. Major changes to original program are as follows: 1) Moving stage tool with inflatable packer to 2450' MD (50' inside 9-5/8" casing shoe) 2) Still planning for full coverage of cement on 1st stage job from 7" shoe to stage tool, but reducing excess to 0% based on wireline caliper log data (calipers indicate gauge hole). 3) Changing to standard 120 ft shoe track for 7" casing because decided to shorten TD and not drill through the Torok formation. Production Casing Cement — STAGE 1 Casing 7" 26# L80 Vam Top HC Casing Lead Open hole volume + 0% 38°6 excess Stage Collar Depth —2450' MD/TVD Lead TOC Stagee." Basis Tail Open hole volume + 0% 3"0 excess + 120 ft 5608 ft shoe track 38.00_MD/3703' TVD . 500' MD above top of Nanushuk Tail TOC 9 sandstone Spacer 30bbis of 11.5ppg Tuned Spacer Total Lead 31bbls, 174cuft, 82sks of 12.Oppg ExtendaCem, Yield: 2.132cuft/sk Cement Tail '8bbls, 213cuft, 172sks of 15.3ppg ExpandaCem Class G, Yield: 1.24cuft/sk Volume Temp BHST 156' F Verification Method 1 Cement returns and wireline CBL Notes I Job will be mixed on the fly Two stage cement job, first stage pumped with top and bottom plugs Production Casing Cement — STAGE 2 Casing 7" 26# L80 Vam Top HC Casing Lead Cased hole volume + 10% 3"0 excess Lead TOC Surface Basis Tail 9i3ei volume 4- 30 exees . Cased hole volume + 10%3"0 excess Tail TOC 500' MD above stage tool (with infl, ble packer) ' ' 5 /8" Casing shr,e (9_ c x 7" aARUIHSA 77 Spacer 30 bbls of 11.5 ppg Tuned Spacer Total Lead Jlbbls, 342cuft, 143sks of 12.Oppg VariCem, Yield: 2.40cuft/sk Cement Volume Tail 16bbls, 90cuft, 73sks of 15.3ppg ExpandaCem Class G, Yield:1.2405 cuft/sk Temp BHST 88° F Verification Method Cement returns to surface Notes Job will be mixed on the fly Two stage cement job, second stage pumped with top plug only Please let me know if you are in agreement with the proposed changes or if you have any questions. We plan to start running 7" casing today. Thanks, Garret From: Staudinger, Garret Sent: Monday, February 17, 2020 5:27 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com>; Johnson, Vern <Vern.Johnson@oilsearch.com> Subject: RE: PTD 219-151 Mitquq 1 ST17" Casing stage tool Guy, Below are a summary of changes to the 2 stage cement job for the 7" production casing. Changes from original program are in red. The biggest change we are proposing is putting targeted top of cement on the 1st stage to 3000' MD (500' below surface casing shoe) and changing excess cement on both stages to 10% excess. The excess change from 30% to 10% is due to the caliper log that was run on the wireline logging tools. The caliper log indicates gauge hole. Additionally, moving the 1st stage top to 500' below the surface casing shoe helps reduce excessive pumping pressures during the job that could result in prematurely opening and inflating the packer on the stage tool. Production Casing Cement — STAGE 1 Casing 7" 26# L80 Vam Top HC Casing Lead Open hole volume + ..0° ° e ess Basis Lead TOC —3000' MD / 2995' TVD Tail Open hole volume + 10% 3"0 excess + 500 ft shoe track Tail TOC � -3900' MD/380' Tin —3800' MD/3703' TVD. 500' MD above top of Nanushuk 9 sandstone Spacer 30bbls of 11.5pp Tuned Spacer Total Lead 20bbls, 112cuft, 3sks of 12.Oppg ExtendaCem, Yield: 2.132cuft/sk Cement Volume Tail 41bbls, 230cuft, 5sks of 15.3ppg Expa'ndaCem Class G, Yield: 1.24cuft/sk Temp BHST 156° F Verification Method Cement returns and, wireline CBL Notes Job will be mixed one fly / Two stage cement jobN first stage pumped with top and bottom plugs Production Casi Cement — STAGE 2 Casing 7" 26# L80 Vam Top HC Casing / Lead Cased hole volume + ° 10 excess Lead TOC Surface Basis Tail Cased hole volume + excess Tail TOC 500, MD abov stage tool „ „ Spacer 30 bbls of .5 ppg Tuned Spacer Total Cement Lead 3 59bbls, 1cuft, 138sks of 12.Oppg Var em, Yield: 2.40cuft/sk Volume Tail 16bbls, 0cuft, 73sks of 15.3ppg Expand ern Class G, Yield:1.2405 cuft/sk Temp BHST 8' F Verification Method Cem nt returns to surface Notes lob ill be mixed on the fly Two stage cement job, second stage pumped with top plug only Please let me know if you are in agreement with the proposed changes, and feel free to call anytime if you have any questions. Regards, Garret From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Sunday, February 16, 2020 9:43 AM To: Staudinger, Garret <Garret.Staudinger@oilsearch.com> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com>; Johnson, Vern <Vern.Johnson@oilsearch.com> Subject: [EXTERNAL] RE: PTD 219-151 Mitquq 1 ST17" Casing stage tool Garret, You have approval to modify the 7" casing cement program as outlined below. ES cementer placement at approx. 2400 ft inside the 9 5/8" is APPROVED. Forward me any cement volume changes for the two stages if any... they are likely not too different. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 3 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: Friday, February 14, 2020 1:42 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com>; Johnson, Vern <Vern.Johnson@oilsearch.com> Subject: PTD 219-151 Mitquq 1 ST17" Casing stage tool Guy, Per our conversation today, we are planning to 2 changes for the 7" casing 2nd stage cement job to mitigate potential lost circulation to the weak zone below the 9-5/8" surface casing shoe. 1) Run a 7" ESIPC (combo stage tool / ECP packer) instead of an ES cementer for the 2"d stage cement job on the 7" production casing string. The inflatable packer will provide a hard bottom for the 2nd stage job. 2) Move ESIPC stage tool inside the 9-5/8" casing shoe (stage tool located -2400' MD). Due to the low LOT and presence of a sandy interval just below the shoe, the only way to ensure we don't loose circulation to the formation is to move the inflatable packer inside casing. As a reminder, there is no presence of Tuluvak in this wellbore. Below is a schematic of originally planned design for your reference. Mitquq 1 ST1 Pre -drill Well Schematic 16" Conductor 128, M0(TV0 Surface Casing 9-518" 401E L80 STC 12 Hole 2,475' MDrrVD 3.:%;- A Landing Nipple 4284' k1D 1076' TVD Ttrb,ng PtT Gauges 4297 MDA082' TVD 8 430S MDi4088' TVD 3-'%,', XN' Landing N pple 433-W M0!4116' TVD 360' Core (A Oil Search 1,1rxlalr�l Nov 5 2019 3-:>>' 2 813' Polish Bo+e X' Lancl-N Nipple 500' N4D-,TVD 3-', " 9,20 L80 Vam Top Tubing r GLM, 3-:," 3000' MD'TV0 ES -Cementer Stage Cement Too*Q'@4~ ST1 Kick Off 4 2600' MD�TVD \ 3-'':' X 7' Paonr 432V MD�4103" TVD WLEG 4345' MD!412 t' TVD 1 Planned Perforations -4,377- 4,382' M014,158' TVD, 39.5' Inc - Production Casing 7" 26# L80 Vam Top HC 8 '," Hole 6,130- M015708' TVD 7' casing cut 4 2 625' MO 3'/,"BHKACP / 4 100' MD.3.838' TVD 3-%,, 9 2# L-80 tBT Sacrikt al Tubing 7' 260 L80 Vam Top KC 8 S;` Role 6.933' MD15,954' TVD 6-1,9' OH Y " 20, endnalion TD 8250' h10 ! 7175' TVD Please let me know if you have any questions or concerns with the proposed changes to the 7" 2nd stage cement job on the production casing string. Regards, 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. staud ingerCcDoilsearch. com 1, 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 5 THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY Garret Staudinger Senior Drilling Engineer Oil Search Alaska PO Box 240927 Anchorage, AK 99524 Alaska Oil and Gas Conservation Commission Re: Exploratory Field, Exploratory Pool, Mitquq 1 ST1 Oil Search Alaska Permit to Drill Number: 219-151 Surface Location: 531.27' FSL, 2302.42' FEL, SEC. 3, T11N, R7E, UM Bottomhole Location: 1145.46' FSL, 1553.72' FWL, SEC. 2, T11N, R7E, UM Dear Mr. Staudinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 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. 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 Oil Search Alaska in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or 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, J rem rice a' DATED this day of January, 2020. RECEIVED NOV 0 7 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 A0GCV 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill &- Lateral ❑ Stratigraphic Test ❑ Development -Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill R Reentry ❑ Exploratory - Oil Q Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Oil Search Alaska Bond No. NUSCGS025100 Mitquq 1 ST1 3. Address: 900 E Benson Bouldevard 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99508 MD: 6,130' TVD: 5,708' Undefined 4a. Location of Well (Governmental Section): 7. Property Designation: Z�z 151 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: 852' FSL, 2233.87' FWL, Sec 3, T11N, R7E, UM LONS 19-005(Pending) 28th January 2020 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1145.46' FSL, 1553.72' FWL, Sec 3, T11N, R7E, UM ADL393876 2,560 Acres/ADL393875 2,560 Acres 2,977' W 41b. 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: 2,600 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 40 degrees Downhole: 2,460 psi Surface: 1,922 psi 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: 2,953cuft 15.8ppg Tail: 268cuft 8-1/2" 7" 26# L-80 VAMTOP Fc 6,130' 0' 0' 6,130' 5,633' Stage 1: 12.0 ppg Lead: 118cuft 15.3ppg Tail: 477cuft Stage 2: 12.0 ppg Lead: 488cuft 15.3ppg Tail: 140cuft 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 ❑ Drilling Program ❑ Time v. Depth Plot ❑ 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 f ( t/-7 / � G1 Authorized Signature: ! Date: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: — 50- C) $ — Q Q(� Date: L 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: i ,� (-.)C.I �j j�') � �.; '� � Samples req'd: Yes YNo❑ Mud log req'd: Yes'�No❑ t HZS measures: Yes ❑ No �[-t /� Directional svy req'd: Yes �No ❑ O -> `" K Spacing exception req'd: Yes ❑ No L'� Inclination -only svy req'd: Yes ❑ No /Ae � S / ! Post initial injection MIT req'd: Yes ❑ No ❑ Cf APPROVED BY Approved This Permit is valid for 24 mor f iAqww& of a p'6�I � 25 005 Submit Form and at ORIGINAL IZ/o 3 /1A 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, (8) Oil Search Keceveo Nov 07 2019 AOGCC 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(a-)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 Attachment 11: Well Schematic Mitquq 1 ST1 Pre -drill Well Schematic 16" Conductor 128' MD/TVD Surface Casing 9-5/8" 40# L80 BTC 12!/." Hole 2,475' MD/TVD 3-'/z" 'X' Landing Nipple 4284' MD/1076' TVD Tubing PIT Gauges 4292' MD/4082' TVD & 4303' MD/4088' TVD 3-//z", 'XN' Landing Nipple 4338' MD/4116' TVD 360' Gore ll Oil Search (0 Oil Search Updated Nov 5'" 2019 3 1/z". 2.813" Polish Bore 'X' Landing Nipple 500' MD/TVD 3 %" 9.2# L80 Vam Top Tubing iI L• y , F ,-r4 e 'l-- GLM, 3 1/z' 3000' MD/TVD ES -Cementer Stage Cement Tool 3200' MD STt Kick Off @ 1 2600' MD/TVD i. 7" casing cut @ 2,625' MD i f ow flpU 3-'h" BHKA @ ti 4,100' MD/3,838' TVD �3-%z" X 7" Packer ., 4321' MD/4 TVD 3-%a 9.2# L-80 IBT Sacrificial Tubing WLEG 4345' MD/4121' TVD '\ Planned Perforations —4,377-4,382' MD/ 4,158' TVD, 39.5° Inc. Production Casing 7" 26# L80 Vam Top HC 8'/z" Hole 6,130' MD/5708' TVD 7" 26# L80 Vam Top HC 8'XV Hole 6,933' MD/5,954' TVD 6-1/8" OH ` 20° inclination TD: 8250' MD / 7175' TVD 13.ZPj- Ft7' Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 39 - 06-Nov-19 Attachment 13: Wellhead Diagram k� tfr (4ACME)01YS As/18' S1d IW IATFEF f v s.n•. f�•ziue�NG—�_ it\.,�roNrux �Nb ER 16" x 9-SM" x 7" x 4-1/2 x 3-112" 5i10M MB-230 Multibowl Assembly, 113AKER FWith MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet aOE JUG Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 41 - 06-Nov-19 (1) 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 Application for Permit to Drill Mitgug 1 ST1 Well Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 1 - 06-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................................................11 Attachments..................................................................................................................................................12 Attachment1: Location Maps..........................................................................................................13 Attachment 2: Directional Plan........................................................................................................18 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 3rd Party Pore Pressure Fracture Gradient Plot................................36 Attachment11: Well Schematic.......................................................................................................38 Attachment 12: Formation Evaluation Program..............................................................................39 Attachment 13: Wellhead Diagram..................................................................................................40 Attachment 14: Days vs. Depth Plot.................................................................................................41 Mitquq 1 ST1 Permit to Drill Rev3_20191106 -2- 06-Nov-19 0 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 STl. 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 852' FSL, 2233.87' FWL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,970,945.878 E 458,764.574 Measured Depth, Rig KB (MD) 4,400' Total Vertical Depth, Rig KB (TVD) 4,166' Total vertical Depth, Subsea (TVDSS) 4,091' Location at Bottom of Productive Interval Reference to Government Section Lines 1145.46' FSL, 1553.72' FWL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,971,243.024 E 458,085.518 Measured Depth, Rig KB (MD) 6,130' Total Vertical Depth, Rig KB (TVD) 5,708' Total vertical Depth, Subsea (TVDSS) 5,633' Mitquq 1 ST1 Permit to Drill Rev3_20191106 -3- 06-Nov-19 (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 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 Mitgug ST1 well. The applicant is the only affected owner. Included in Attachment 2 is an anti -collision scan from Mitquq 1 ST1 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 ST1 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 ST1 Permit to Drill Rev3_20191106 - 4 - 06-Nov-19 Oil Search 4. Drilling Hazards Information 20 AA 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 2,460 psi in the Torok at 5,380' TVD (8.8ppg EMW top Torok formation) Maximum surface pressure 1,922 psi from the Torok (0.10 psi/ft gas gradient to surface, 5380' 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 N/A — Existing LOT data from Mitquq 1 wellbore 9-5/8" Casing Test 3,000 psi surface pressure [Test pressure driven by 50% of surface casing yield] 7" Casing Test 3,500 psi surface pressure [Test pressure driven by annular pressure during frac. job] (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 Mitquq 1 PTD Attachment 15: Shallow Hazards Assessment Please refer to Attachment 4: Drilling Hazards 5. Procedure for Conducting Formation Integrity Tests 20 AA 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 ST1 Permit to Drill Rev3_20191106 -5- 06-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 Liner / Bottom Hole Size Tbg O.D. Wt/Ft Grade Conn Length MD 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 cuft/sk 2,400' 15.Bppg 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' 15.3ppgTail: 47bbls, 263cuft, 212sks ExpandaCem Class G —1.24 cuft/sk Mitquq 1 OH _ To be abandoned with 3-1/2" sacrificial 6-1/8" 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 1 ST1 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 cuft/sk Tubing 3-1/2" 9.2# L-80 VAM TOP 4,345' Surface 4 ,046' / 404 n/a Please refer to Attachment 6: Cement Summary for further details. 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. Mitquq 1 ST1 Permit to Drill Rev3_20191106 -6- 06-Nov-19 0) Oil Search 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 Production Hole 2475' — 6130' MD Mud Type Mineral Oil Based Mud Mud Properties: Mud Weight 10.7ppg 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% 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 fora 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 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: (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 Mitquq 1 PTD Attachment 15: Shallow Hazard Assessment Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 7 - 06-Nov-19 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 ST1 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 r1-0 2 (, /S—L-) 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 ST1 Permit to Drill Rev3_20191106 - 8 - 06-Nov-19 OR 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" 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. Pressure test casing to 3500 psi for 30 min on plug bump. 17. Makeup 6-1/8" RSS BHA with MWD and LWD tools. RIH, clean out to top of float l equipment and displace well to 12.1ppg MOBM. 18. Drill out shoe track and 20 - 50' of new formation. Perform formation integrity test and submit results to AOGCC. 19. Directionally drill 6-1/8" hole section as per well plan to TD at —8250' MD / 7175' TVD. Perform wiper trips as required. POOH. 20. Rig up wireline and complete open hole wireline as per formation evaluation program. 21. 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 —4100' MD (-500' above top Nanushuk 9). Cement will be placed inside and outside the sacrificial cement stinger. Release from BHKA and circulate out excess cement. rG 22. Rig up wireline and tag top of abandonment plug. Pressure test 7 casing and abandonment plug to 1500 psi for 30 min. vt 23. Set bridge plug in casing at —2650' MD (below 7" casing cut depth). 24. Make up casing cutter on drillpipe and cut 7" casing at —2625' MD (150' outside 9-5/8" �- �I` shoe). 25. Pull 7" casing hanger and lay down 7" casing from cut depth. 26. Run in hole with drillpipe and place balanced kick off plug on 7" casing stub to surface casing shoe depth Mitquq 1 ST1 Permit to Drill Rev3_20191106 -9- 06-Nov-19 0 Oil Search Mitqug 1 ST1 S 27. Make up 8-1/2" RSS BHA with MWD and LWD tools. RIH, clean out to top of cement kick off plug. 28. Kick off cement plug below surface casing shoe and directionally drill 8-1/2" production D hole to core point at —4400' MD / 4166' TVD. Perform wiper trips as required. Circulate and condition hole. POOH. •- > -eo r FT/Lc7r c,Oe- 29. Make up 8-1/2" coring assembly and run in hole. Circulate and condition hole prior to dropping coring ball. 30. 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. 31. 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' D. Circulate and condition hole and then POOH. i al 5 32. Rig up wireline and complete open hole wireline as per formation evaluation program. 33. Run 7" production casing as per casing tally, land casing on wellhead mandrel hanger. Circulate and condition mud prior to commencing cement job. 34. 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. 35. 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. 36. Pressure test 7" casing to 3500psi for 30mins. POOH. La s 37. Rig up wireline and complete cased hole cement evaluation and VSP 38. Prepare for completion operations. Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 10 - 06-Nov-19 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 ST1 Permit to Drill Rev3_20191106 - 11 - 06-Nov-19 Oil Search Attachments Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 12 - 06-Nov-19 0) Oil Search Attachment 1: Location Maps Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 13 - 06-Nov-19 -----1 ----J � PIKkA I i .✓"E"`s �_---- � � . ti �� a� � I ----- I I cap —t19 1— aRsrwn 1 ND �� I MI�,NEE P6't / I , Pikka C iR I' I ; I I I wSAH ii 1Yf 9G 1N � I ------- I I II - I I ,PLACER .. trRcs COLVILL�we ,.." o RIVER 0-301 I I Mitqug 1 I 11 I lT ,r MSF Z% SWPTi L----I I --I caa I i________________.... -- I, WSAK 18 I ` v 1 rRoc 1 D4 I I I FOUk CORNERS AK 14 *Pikkal8 I --I 1Y_.. zc twisar, \` it ♦I I I E MUSTAIi i I `— Ti-A5RC M5 _—_ �'' ' \ 2K GREATER Y, 3ak s �' ��_---------�'TS.MILUVEACHI ' MOOSES `— i I------� KLTPARI7K RIVER TOOTH NUIQSUT I I wsnk zo I L_ r I A W SAR 36 1 I ri I --------------- Stirrup 1 I MS S I I I I I K1 ® OIL SEARCH ALASKA U.C. Project Location —' PRODUCTION UNIT — NS EXISTING GRAVEL ROADS 2mv-zozo 1xatoRAnoN CAMPAIGN l 2011-2019 DRILLED WELLS L _ J i EXPLORATION ICE ROADS I----� NS EXISTING FACILITY ®NPR -A BOUNDARY N PROPOSED CAMPAIGN OVERVIEW y ---NSEXISTINGPIPELINESi- OIL SEARCH LEASES W U 0 1 2 GCS:NAD1983St—FI..Allka4FIPS5004Fee1 Oil Search EXPLORATION DRILL SITE DON i n 11.Rry 1 o e9 3R ®Glonwters 1—0-9-xo-ceN+n_I—R.d AOGCc1 S 0 I P 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 Geoid I2B) 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" I 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, CD I \ 7� e WE LOCATI o U �ASRC_MINE SITE NUICISUIT T722N T'IN Tr ON -o VICINITY MAP 11N,.1E SCALE: 7" = 6 MILES SEC. 3 PROPOSED 35' WIDE ICE ROAD MITQUQ 1 (AS -STAKED WELL LOCATION) 50p. SEC. 3, T11N, R7E, U. M. SEC. 10, T11N, R7E, U. M. - x 0 _ e ffi OpO'- 5«vL 1� 0 ISO 300 STS° 0o SCALE IN FEET MITQUQ 1 EXPLORATORY WELL 4Ah PROPOSED ICE PAD RECONFIGURATION U 1VI I A Q & AS -STAKED WELL LOCATION Oil Search NORTH SLOPE, ALASKA 6700 Arche Sp Anchorage, AK 9951 A ur Road DATE' 10/29/2019 DRAWN BY,FM / MMHN SHEET: 1 OF 1 (9071677-8220 SCALE: AS SHOWN CHECKED BY: KJP JOB No: 80209.19 Mifqquqq 1 STl BHL 1 RM UM X:458085.518 Y: 5971243.024 !Mitquqq 1 STlr Nanushuk 9 sandstone X: 458764.574 Y:5970945.878 - _%700621.159 Mltquq .638 q _ ' Nanushuk 9 sandstone 1P3L2$�a X:460616.518 Y:5970437,l 348 _^-- �1Uu7 M tqu BHL i qq1 --- M 462549.836 t j _ :5970117,367 aim 3L i OIL SEARCH A pR TOPS DIMENSION_LINE SECTION EXPLORATION CAMPAIGN PAI N WELL SURFACE HOLE L _ LEASE OUTLINE 1 N MITQUQ 1WELL PLAN O 0 200 400 Oil Search WELLTRAJECTORY TOWNSHIP µ E ®Feet GCS: NAD 1927 StatePlone 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 \I C C.. 11�' I "M T a Apo r" ,0 d Well { Sate" F\ate ` Stimulation Well Test RIG Truck Staging t SemP uta9\n9 Waste Stotage p , Area U Ent Igp\\\ Response FUe% Storage Camp Camp sCOMMSAnnex ai Shop Y r' 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: 1111-09-21. REV: 1.0. By: JB 0 50 100 DOcumen,name:OPS-19-20-P-PE-M POO_Mifqugl_NAD27 W) Oil Search Attachment 2: Directional Plan Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 18 - 06-Nov-19 Oil Search Mitquq-1 ST1 wp02 Proposal Geodetic Report (Def Plan) Schlumberher nevvrr mare: aupwn... cu, .0 e - w.0 i rm rvey r u mpura a[- r Lllpm- Client: Oil Search Vertical Seaton Azimuth: 99.084 • (True North) Field: NS West Vertical Section Origin: 0.000 it, 0.000 ft Structure / Slot: Mkquq-1 - NAD27 / Mitquq-1 ND Reference Datum: Rotary Table Wall: Mitquq-1 ND Reference Elevation: 75.277 ft above MSL Borehole: Mitquq-1 ST1 Ground Elevation: 47.277 ft above MSL API#: 50103xxxxx01 Magnetic Declination: 16.080 ° Survey Name: Mitquq-1 ST1 wp02 Total Gravity Field Strength: 1002.0008mgn (9.80665 Based) Survey Date: September 25, 2019 Gravty Model: COX Tort / AHD / DDI / ERD Ratio: 68.658 • 11541.946 it / 5.056 / 0.270 Total Magnetic Field Strength: 57378.891 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feat Magnetic Dip Angle: 80.789' Location Let / Long: N 70. 19' 50.40263", W 150. 19' 42.39178• Declination Data: December 31, 2019 Location Grid WE Y/X: N 5970621.161 ftUS, E 459506.640 ftUS Magnetic Declination Model: BGGM 2018 CRS Grid Convergence Angle: -0.3093' North Reference: True North Grid Scale Factor: 0.99990186 Grid Convergence Used: 0.0000 ° Version / Patch: 2.10.544.0 Total Corr Mag NorthaTme North: 11.010" MD Inel Azlm True NDSS ND VSEC INS EW TF DLS Directional Exclusion Zone Exclusion Zone GeoMag Th Northing Easting Comments (ft) (•) (•) (ft) (ft) (ft) (ft) (ft) (•) (•/100ft) Difficulty Index Alert Angle f,1 (nT) (ftUS) (ftUS) KOP Cry 3/100 2500.00 0.00 99.09 2424.72 2500.00 0.00 0.00 0.00 293.32M N/A 0.00 9.21 9187.44 5970621.16 459506.64 2600.0' 3.00 293.32 2524.68 2599.95 -2.54 1.04 -2.40 293.32M 3.00 0.89 9.32 9292.29 597D622.21 459504.24 2700.00 6.00 293.32 2624.36 2699.63 -10.14 4.14 -9.61 HS 3.00 1.80 10.32 10288.01 5970625.35 459497.06 2800.00 9.00 293.32 2723.49 2798.77 -22.79 9.31 -21.59 HS 3.00 2.33 12.01 11945.13 5970630.58 459485.10 2900.00 12.00 293.32 2821.81 2897.08 -40.45 16.52 -38.33 HS 3.00 2.70 14.13 14016.91 5970637.89 459468.41 3000.00 15.00 293.32 2919.03 2994.31 -63.08 25.76 -59.76 HS 3.00 2.99 16.53 16328.44 5970647.24 459447.02 3100.00 18.00 293.32 3014.90 3090.18 -90.61 37.00 -85.84 HS 300 3.23 19.09 18771.02 5970658.62 459421.01 3200.00 21.00 293.32 3109.16 3184A3 -122.96 50.21 -116.49 HS 3.00 3.43 21.76 21277.59 5970672.00 459390.43 3300.00 24.00 293.32 3201.53 3276.81 -160.05 65.36 -151.63 HS 3.00 3.60 24.50 23804.89 5970687.33 459355.38 3400.00 27.00 293.32 3291.78 3367.06 -201.77 82.40 -191.16 HS 3.00 3.75 27.29 26323.26 5970704.58 459315.95 35DO.00 30.00 293.32 3379.65 3454.93 -248.02 101.29 -234.97 HS 3.00 3.89 30.12 28811.08 5970723.70 459272.24 3600.00 33.00 293.32 3464.91 3540.18 -298.66 121.97 -282.95 HS 3.00 4.01 32.98 31251.60 5970744.64 459224.38 3700.00 36.00 293.32 3547.31 3622.59 -353.55 144.39 334.96 HS 3.00 4.13 35.86 33631.26 5970767.34 459172.50 3800.00 39.00 293.32 3626.64 3701.91 412.55 168.48 -390.95 HS 3.00 4.23 38.76 35938.62 5970791.73 459116.74 End Cry 3810.96 39.33 293.32 3635.13 37JOAl -419.26 171.22 -397.21 HS 3.00 4.24 39.07 36186.66 5970794.51 459110.40 Tgl 4400.30 39.33 293.32 4091.00 4166.28 -781.30 319.07 -740.20 HS 0.00 4.52 39.07 36188.92 5970944.19 458768.24 Drip1.8/100 4500.30 39.33 293.32 4168.35 4243.63 -842.73 344.16 -798.40 LS 0.00 4.56 39.07 36189.31 5970969.59 458710.18 4600.00 37.53 293.32 4246.45 4321.73 -902.80 368.69 -855.31 LS 1.80 4.61 37.34 34823.99 5970994.43 458653.42 4700.00 35.73 293.32 4326.69 4401.97 -960.63 392.31 -910.11 LS 1.80 4.66 35.61 33426.65 5971018.34 458598.76 4800.00 33.93 293.32 4408.77 4484.05 -1016.00 414.92 -962.56 LS 1.80 4.70 33.88 32003.56 5971041.23 458546.43 4900.00 32.13 293.32 4492.60 4567.88 -1068.83 436.50 -1012.62 LS 1.80 4.74 32.15 30557.12 5971063.08 458496.49 5000.00 30.33 293.32 4578.11 4653.38 -1119.09 457.02 -1060.23 LS 1.80 4.78 30.44 29089.99 5971083.86 458449.00 5100.00 28.53 293.32 4665.19 4740.47 -1166.72 476.48 -1105.36 LS 1.80 4.81 28.74 27605.14 5971103.55 458403.98 5200.00 26.73 293.32 4753.78 4829.06 -1211.68 494.84 -1147.95 LS 1.80 4.84 27.04 26105.90 5971122.14 458361.49 5300.00 24.93 293.32 4843.79 4919.06 -1253.92 512.08 -1187.96 LS 1.80 4.87 25.36 24596.11 5971139.60 458321.58 5400.00 23.13 293.32 4935.11 5010.39 -1293.39 528.21 -1225.36 LS 1.80 4.90 23.70 23080.26 5971155.92 458284.27 55DO.00 21.33 293.32 5027.67 5102.95 -1330.07 543.18 -1260.11 LS 1.80 4.93 22.06 21563.68 5971171.08 458249.61 5600.00 19.53 293.32 5121.38 5196.65 -1363.91 557.00 -1292.17 LS 1.80 4.95 20.44 20052.89 5971185.07 458217.63 5700.00 17.73 293.32 5216.13 5291.41 -1394.87 569.65 -1321.51 LS 1.80 4.98 18.85 18555.99 5971197.88 458188.36 5800.00 15.93 293.32 5311.94 5387.12 -1422.94 581.11 -1348.10 LS 1.80 5.00 17.31 17083.32 5971209.48 458161.83 5900.00 14.13 293.32 5408.42 5483.69 -1448.08 591.38 -1371.92 LS 1.80 5.02 15.81 15648.37 5971219.88 458138.07 6000.00 12.33 293.32 5506.76 5581.03 -1470.27 600.44 -1392.94 LS 1.80 5.03 14.39 14269.04 5971229.05 458117.10 6100.00 10.53 293.32 5603.T7 5679.05 -1489.49 608.29 -1411.14 LS 1.80 5.05 13.05 12969.38 5971237.00 458098.94 TO 6129.63 10.00 293.32 5632.92 5708.20 -1494.60 610.38 -1415.99 1.80 5.06 12.68 12604.15 5971239.11 458094.10 Survey Error Model: ISCWSA Rev 0'°° 3-D 95.000%Confidence 2.7955 sigma Survey Program: MD From MD To EOU Freq Hole Size Casing Diameter Expected Ma: Description Part (ft) (ft) (ft) (in) (in) Inclinatlon Survey Too] Type Borehole / Survey meal 1 0.000 2467.000 1/100.000 12,250 9,625 SLB_MWD.SAG Milquq-1 / Mitquq-1 wp02 v5 1 2467.000 2500.000 11100.000 8.500 0000 SLB MWD+SAG Mitquq-1 / Mkquq-1 wp02 v5 1 2500.000 6129.626 1/100.000 30,000 30.000 SLB_MWD+SAG Mitquq-IA/Mitquq-tA wp02 NS West\Mitquq-1 - NAD27\Mitquq-1\Mitquq-1 ST1\Mitquq-1 ST1 wp02 Drilling Office 2.10.544.0 Schlumberger-Private 9/25/2019 5:03 PM Page 1 of 1 - $chlumberger Oil Search Borehole: ll: Field: Structure: Mitquq-1 ST1 T Mitquq-1 NS West Mitquq-1 - B Mapnatic Paramatan Surfua Louaon NAD83 AlasMa Slab Plana, Lena O6, US Fact Mbcallanaoue IG"'t, Modal: 3016 GIP: 80,799' Gale: ]lilac-3019 59T03T0.93GU Let N T50 Lq.39 NoMinp: Grid Conv: -0.31Y3' Slot: Maquq 1 TVG Rei: RKa(75.39ft above MSL) MepDec: 16.06' FS: 5737e.691nT Grevlty FS: 1002001mpn (9.60665 Beaed) Lon: W 15019 53.64 EaaUnp: 55"131-SMU Smla Fact: 0.9999019 Plen: MNquq-i ST1 vry03 2400 -1600 -800 0 800 1600 2400 3200 0 0 800 800 1600 ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.......................................................... Base Permafrost {1525.277 ND) _....................................... _............................................................... 1600 9-5/8 casing 2475 MD 2475 ND .._.._.._.._.._.._.._.._. _.._.._ ._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._. Mid Schrader Bluff (2075.277 ND) _. _. _..._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._..-.._.._.._.._.._ 0.00 ° ind 99.09 ° az 0 vsec 2400 .._.._.._.._.._.._.._.._.._.._.._.._......................................................... .. . ...................... _................................ _........... ................................ _......................... 2400 MCU (2410.277 ND) .......................................................... .._.._.._.._.._.._.. _.._.._.._.._.._.._.. _..._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..___.._._.._.._.._.._.._.._.._............................ o�er$C6U550.277..�1D}.._.._.._.._.._.._.._.._.._.._.._..._.._.._.._.._.._.._.._.._.._.._.._.._.__............. .......... ............ _.... _................... U uva l 1 KOP Cm 31100 ._.._......... ........... ._............ 2500 MD 2500 TVD 0.00 ° ind 99.09 ° az 0 vsec 3200 End Cm 3200 0 3811 MD 3710 TVD 0 39.33 ° ind 293.32 ° az 0 419 vsec m m to 4000 .:-::_:::::-..,.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._:-:e 4000 anusiiuk (4037377 TVD)_.._.._.._.._.._.._.._._. > Nanushuk 9 S`andstone (4166.277 ND Tgt 4400 MD 4166 TVD .._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._. .......... 3933.°Jnil.29332_..az .............................. _....................... _....................... _ ................. ._.._ .,- NaUShuk 8 (4618.277 ND) -781 vsec 4800 •_................... .............. ................... .._.._.._.._.._.._.._.._.._.._.._. _...................................................................... .............................. .................................. ._.._ 4800 Drp 1.81100 4500 MD 4244 TVD 39.33 az ° incl 293.32 ° -843 vsec orok(Nan-6)(5380.277 D) 5600 Mitquq-1 ST1 wp02 5600 _.._.._.._.._.._.._.._.._.._.._.._.._.. .._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._._.._.._.._.._._..__ HRZ (5751.277 ND) ........................ _............... TD 6130 MD 5708 ND S. ndsto11E.. 6.02.6-Z77_Tu.Q,) 00. _Ind.293 32' ..r,......................10 _ez_-._.._..................... ......................... ................... .... __....... ............... LC (6128.277 N ) -1495 vsec .................. 6400 6400 .._.._.._..._�._.._.._.._.._..._.._.:...._l�_...._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._.._._.._.._.._.._.. YR.'-.A p16e �(s4.277 TVD)................ _.. _.._.._._.._.._.._._.._.._. .._.._..___.._.._.._.._.._ Mitquq-1 wp02 v5 7200 7200 -2400 -1600 -800 0 800 1600 2400 3200 Vertical Section (ft) Azim = 99.08' Scale = 1:1000.00(ft) Origin = ON/-S, OE/-W 4) Scl umierger Oil Search Borehole: Well: Field: Structure: Mitquq-1 ST1 wp02 Mitquq-1 NS West Mitquq-1 Gravity & Magnetic Parameters Surface Location NAD83 Alaska State Plane, Zone 04, US Feet Miscellaneous Model: BGGM 2018 Dip: 80.789° Date: 31-Dec-2019 La1: N 70 19 49.29 Northing: 5970370.93ftUS Grid Conv: -0.3122° Slot: Mitquq 1 Plan: ND Ref: RKB(75.28ft above MSL) Mag Dec: 16.08° FS: 57378.891nT GravityFS: 1002.001mgn (9.80665 Based) Lon: IN 150 19 53.64 Easting: 1599539.38ftUS Scale Fact: 0.9999019 Mitquq-1 5T1 wp02 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 TD 6130 MD 5708 TVD 10.00 ° ind 293.32 ° az True N=610E=-1416 Dr 1.8/100 Gntl 4500 MD 4244 ND� 39.33 ° ind 293.32 ° Mag 1000 az 1000 N=344 E=-798 Mitquq-1 ST1 wp02 End Cry True North 3811 MD 3710 ND t Corr (M->T ifi.080°) 39.33 ° incl 293.32 ° az--- Mag Dec (ifi.080°) N=171 E=-397 Gnd Conv (-0.312°) 500 Mitquq 1 T Nan-9 Target 500 KOP Cry 3/100 2500 MD 2500 ND 0.00 ° ind 99.09 ° az p N=0 E=0 0 0 0 u 0 0 m °i Tgt 4400 MD 4166 ND ° ° 9-5/8 casing 39.33 ind 293.32 az 2475 MD 2475 ND N=319 E=-740 0.00 ° incl 99.09 ° az Z N=0 E=0 -500 -500 Mitquq-1 wp02 v5 -1000 -1000 -1500 -1500 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 EW (ft) Scale = 1:600.00(ft) 16000 14000 12000 10000 8000 cr 0 0 0 on 6000 v a� 4000 to Z 2000 0 -2000 -4000 -6000 Sch[umbager Oil Search Borehole: Well: Field: ture: Mitquq-1 ST1 wp02 Mitquq-1 NS West Tuc Mitquq-1 Gravity & Magnetic Parameters Suncce Location NAD83 Alaska State Plane, Zone 04, US Feet Imiscellaneous Model: BGGM 2018 Dip: 80.789Data: 31-Dec-2019 Let: N 1011 41,21 Northing: 59T03T0.93RU 1.599539.3814U Grid Cenv: 4.3122- Sol: Mitquq 1 T D Re/: RKB(75.28M above MSL) Mae Dec: 16.08° FS: 5r3T8.891nT Gravty FS: 1002.001mgn (9.80885 Baeed) Lon: W 150 19 53.61 Eaeting: Scale Fact: 0.9999019 Plan: MHquq-1 STt wp02 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 2200 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22001 EW (ft) Scale = 1:4500.00(ft) 16000 14000 12000 10000 8000 6000 4000 2000 0 -2000 -4000 -6000 Mitquq-1 ST wp02 Anti -Collision Summary Report AnaiYaia Dan241,rnm.: September 25, 2019-163D Analy.is Method: Nurmal Mang Cll.nt Oil Seardl Rater.-Traf..., Mitquq-1 STt Wp02(Def Plan) F1.1d: NS Wsm Depth Interval: Every 10.00 Meesund Dsplh (R) Strvdur9: Mitquq-1 Ru1. 30: Dom mb(C N sbn S+an mm 5002 0.162 Slot Mltqug1 mi. Ph: Nl local mhha lndnaled. W.II: MOquq-1 VII..l Patch: 2.10.544.0 34la11o1.: Mitquq-1 STt Dalabasa 1 Pmf.d: b A1vsMrilBng-North Slope Welt Scan AND Rang.: 2500.00R-61N 63R ISCWSA03-D 95000%Confidence2.7955sigm.,for.ubjectwel.For Tyl.ctory Error MOGI: onset -Us, error model canton 1. speoified M. eIZ Wdl re.pediv , MI Trslectodea Summery orrad S.lactlon Cdterla WNllwed disdreo scan: RMhlclad Whin 47140.12 R Se[ec fihem: DI.&. SMrsy. -DINUti Plans-NftN surveys ezdW. d.fidOve plan. -All Non-Oef Surveys When 10 DsfSurvey Is set In! borehde- All N-00 Plans When no De(Flen Is set In a b shde ORsd Tra(.dory 9. wtisn NIOW S.p. Z1(R Conbolling R.hnnc.T d. Risk-.1 Alert Status C14:t MAS R EOU R Fad. Rule MD TVD R N.D Minor 1 Meor Maor Meor Plow1(MfS9Ny) Pau 8430.] 11,4 9a04.] 9392. 3M.1 0S11.11 25M.00 250000 1040.5 ]01431 135.3 OS11.50 6129.M 5]M.20 Minpb %aver 2 to.f Storey) Pao %19.91 SB.T 9Mt.6 BSM.1 9 279.] OSF1.50 2M091 2M091 Mlnph B047.07 1M. ]844.4 18939 OSF1.50 812928 570783 MinPis GlABa f fDe75urveyl P.y 134M.M 70+84 +2942.30 12748.74 28.78 Oti- 2Mo.00 2600W min- 3]Y1M 12M.3 12855. 12433.18 15.M ;- 1] 1452.42 128M.5 OSF1.M 3895.]5 3818.15 MINPT-QEOU 12379.] 130M.09 1454.61 12M8.02 12M1. 1129 OSFISO OSFLN 3924.69 3MD.16 37soU 3810.35 MInR-0-AOP MIn%-0SF 1M]B.M 11B1.M 128%.M 123%.4 1{. 0SF1.50 599].36 557816 MinM-0SF 1M]].5] 14B1. 12M9.] 123%. 1- 1M]5.0 147f.M 12893.48 12409.19 14.15 11F1.11 OSF1.50 602256 6129.63 1113.11 570820 MinPla MIn%-CIGY -131Det Survey) pay 15151.81 32.81 15438.M 15{18. 1282. 16160.3 ]201 1513]]t 1541]4 1287.is MA3=f0.%(ml MAS=10.%Iml 2500.00 2613.M 25M 00 f513.M MI.MASF 15a69.91 3281 IS46S81 154311 12T74 MAS10%(m) 259825 259821 Mi- MI -1 1-1.]9 32.81 1-ts 143489 -10.%(m) ottis 26 5491.]3 MinN-oF 141B4A1 32.01 14180.87 14151. .142 t91©]2B 114155.31 14140. 91531 MAS=10.%(m) 1-o-10.%lm) 8110.94 .129.63 SBBB.80 5]08.20 M N-1 MnPb A" 2A iD.+Survey) 212M. 3251 Pw 1 B2378 2-7.25 32.11 21292.11 21274' 1571. MAS=(ml MAS=11O00 OM (ml 25%.28 252B.% 25D0.20 2529.% M.- MInP(-OSF 16529.03 138.87 1fi435.1 1M%. 1M.5 OSF150 M52.25 29.6.M MinPl. Aue.q 2 (W Survey) Pe.s 212M. 32.811 21243. 21223. 1823.)H MAS•10.00 (m) 2M0]8 2500.28 Mi.ft 2130T25 32.81 212111 2t2>4 1571. 4M.]4 21383.]7 21]]5. 15M.1 MAS=10.%(ml MPS=10.00 2529.% 2529.% MnM-0.9F 216T7.00 32.81 216M.M 216M.1 1131. (ml MAS•10%Im) 2717.M 2)11.39 MInMASF MinMQSF -4.23 101.] 219M. 31923.91 32B.24 OSF1.M 2826.68 2825.09 MinPb 21221. J2.81 M1210. 21189. 1856.07 MAS•f0.%lml 2535.95 2M5.94 MInPM 212d2.29 32.81 2122o.M 211M. 1828.3 MAS=10.%(m) 2559,22 2558.20 M.nM-O.9F 213XM 3251 21]+)M 212%. 1M2 19281.17 43.5q 19261.41 IB24). 6%. MAS=10%lml OSFISo 2040.13 .41,n 3M9% 717528 MmM-0.3F MinPb Alerup 2 (DO 9urvey) ppy 21 no a 32.11 212M.]] 21208.M WA 21213.2 3281 21204.1 21180.4 %tO40 IM8=1D.Oo (m) MAS•I... (mI O.M M ss5 D00 1608M Su _f 21213.J1 3281 212M.1 211 M.M 36011. 2125545 3381 2124255 222, 1929.8 21221. 32.81 312 0 2 88 1955.07 21232.29 32.11 212211 211" 19253 MAS=1000 (m) MAS=1pOD ImI MAS=10.%(mI MAS=IO,W 1 1849.6il 2M03] 2535.95 22 1B{9.M 25003] 2535.9a 211121 MINPT-0 u Minh-OSF MnPb Minh-OSF 2_7 329M 3211 213128 212% M.2 1929f.ti 43 1938t 6t 1." 1699. MAS:10.%(ml OSF1.50 :1 21 13 8.10 2639.% 71752. M� M-0SF nm- SNlumher6er-PrMh Ct-Ct (ft) 0 10000 20000 30000 5000 15000 25000 0J I I I I I I 1000 2000 a 3000 — N 4000 5000 6000 — Separation Factor EOU-EOU (ft) 0 1 2 3 4 5 0 5000 10000 1500ti 20000 I I _ . l _ __I l I_— I _ ....._. ems. D mi m; m� 3 <3 C2 j C1 Placer 1 — Placer 2 Colville 1 — Placer 3 — Ataruq 2 — Atanxl2A Mitquq-1A wp02 - Mitquq-1 - Mitquq 1 - Mitquq-1 - NS � felt Schlumberger-Private Traveling Cylinder Plot NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2 280 270 260 North 350 10 190 180 170 TRAVELING CYLINDER PLOT Client Oil Search Field NS West Structure Mitquq-1 Well Mitquq-1 Borehole Mitquq-1 ST1 Date 25-Sep-2019 80 90 100 Oil Search Attachment 3: BOPE Equipment Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 26 - 06-Nov-19 BOP CONFIGURATION - ELEVATION HYDRIL 13-5/8' 5KSI TYPE GK - ANNULAR PREVENTER - " HYDRIL 13-5/8' 5KSI DOUBLE GATE UPPER GATE -PIPE RAMS 10' ACT, - LOWER GATE-BLIND/SHEAR 14' ACT, HYDRIL 13-5/8' 5KSI SINGLE GATE - PIPE RAMS 10' ACT, I'I " Ha HYDRIL �_--- PRI ' I'I e i I r TOP OF RIG MAT BOP CONFIGURATIONPLAN ■ 1 ■ � 1 DIVERTER BOP CONFIGURATION - ELEVATION 19 so'm m II TOP OF RIG MAT ����1y-�RR.�RR�� 14.1— /J — p11Rn9 Int. I�RIRAi1�/Yml� 2525 C S Sidle 2200 II 111A l/1M.— MMOT MA 99503-2B39 907-20.1-BOW 7m OIL SEARCH - RIG 7ES 7ES 60P IN SUBSTRUCTURE m aNFASpI mosm NENWN iav 1 e ue9 NIS o it YP 2019 �� 10/1 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 Oil Search Attachment 4: Drilling Hazards 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 ST1 Permit to Drill Rev3_20191106 - 29 - 06-Nov-19 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 ST1 Permit to Drill Rev3_20191106 - 30 - 06-Nov-19 0 Oil Search Attachment 6: Cement Summary Production Casing Cement — STAGE 1 Casing 7" 26# LBO Vam Top HC Casing Lead Open hole volume + 30% excess Lead TOC Stage Collar Depth —3200' (Base Tuluvak) Basis Tail Open hole volume + 30% excess + 500 ft shoe track Tail TOC —3900' MD/3780' TVD. 500' MD above top of Nanushuk 9 sandstone Spacer 30 bbls of 11.5 ppg Clean Spacer Total Lead 21 bbls, 118 cult, 55 sks of 12.0 ppg ExtendaCem, Yield: 2.13 cuft/sk Cement Tail 85 bbls, 477 cult, 385 sks 15.3 ppg p Ex andaCem Class G —1.24 cuft/sk Volume Temp BHST 156° F Verification Method Cement evaluation log Notes Job will be mixed on the fly Production Casing Cement — STAGE 2 Casing 7" 26# LBO Vam Top HC Casing Lead Cased hole volume + 30% excess Lead TOC Surface Basis Tail Open hole volume + 30% excess + Cased hole volume + 30% excess Tail TOC 100' MD above casing shoe (9-5/8" x 7" annulus) Spacer 30 bbls of 11.5 ppg Clean Spacer Total Lead 87 bbls, 488 cult, 203 sks of 12.0 ppg VariCem, Yield: 2.40 cuft/sk Cement Tail 25 bbls, 140 cult, 113 sks 15.3 ppg p Ex andaCem Class G —1.24 cuft/sk Volume Temp BHST 88" F Verification Method Cement evaluation log / Cement to surface Notes Job will be mixed on the fly Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 31 - 06-Nov-19 W1 Oil Search Attachment 7: Rig Fluid System Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 32 - 06-Nov-19 SOLOS MUD DISCHARGE PILL 8' PIT B' FROM BLOWDOWN 50 BBL CENTRIFUGE 16 TAN BL L' TANK SNA00 518 CENIMFUGET(� 9 Z14 U ® Cr LIQUIDS DISCHARGE SUCTION TANK 160 BBL P6 3' MP 2 0o MP I CE CE F-1000 T 1 F-IDOD FROM FUEL TANK SHAKER SHAKER 2" 2" VENT FLOW LINI DITCH DESILTER e• 8' TANK j5TB i6®L BURGESS DEGASSER 12" L. EQU. DESANDER/ H. WIER DEGASSER TANK 167 BBL 4" 8" 8' 8' P7 P3 p4 p5 3„ HOLE FILL LINE 6. 6 6' 3„ 2„ e• e" 3-3" 3„ n 3. Pln hi 2 3 BRINE250 250 TANKSBO BB BI. TO STANDPIPE MANIFOLD NABORS ALASKA RIG 7ES MUD SYSTEM SCHEMATIC VENT 10' PR/ 2' SPHON POORBOY BREAKER VENT LEGEND DEGASSER SHARER FROM BUTTERFLY VALVE N GATE VALVE D4 3" 3" MUD GUN w/VALVE 2° P TRAP 8" SUCTION VALVE DRECO STYLE c/w BOLT ON FLAT RUBBER SEAL O RECESSED MUD DITCH GATE C—J—Jj 2 MUD HOPPER V 10 HP AGITATOR HEMICAL BARREL Ra 5 HP AGITATOR 10" EQUALIZER PULSATION DAMPER PRESSURE INDICATOR PI PRESSURE SWITCH RELIEF VALVE FLOW ARROW PUMP KEY P� MaNwaY Mw PI — CHARGE/MUD MIX 6x5x14 (14' IMP) 60 HP POSSUM BELLY GUILLOTINE GATE _—� P2 — CHARGE/MUD MIX 6x5x14 (14' IMP) 60 HP P3 — MUD MIX/TRANSFER 6x5x14 (14' IMP) 60 HP P4 — DESILTER 6x5x14 (14' IMP) 100 HP P5 — DESANDER 5x5x14 (14" IMP) 100 HP P6 — CENTRIFUGE SWACO TYPE 11 P7 — TRIP TANK 3x2x13 (13" IMP) 20 HP PR — BRINE GRINDEX 8 HP "N" IMPELLER P9 — BRINE GRINDEX 8 HP "N" IMPELLER P10 — BRINE CRINDEX 8 HP "N' IMPELLER Attachment 8: Prounosed Formation Tops Mitquq-1 ST1 Prognosed Tops ftMD ft TVD(KB) ft TVDSS Uncertainty Range Pore Pressure (ppg) Tuluvak Formation 2627 2627 -2552 +/- 100ft TVD 9.9 Seabee Formation 3196 3157 -3110 +/- 100ft TVD 8.7 Nanushuk Formation 4233 4029 -3962 +/- 100ft TVD Nanushuk 9 Sandstone 4391 4167 -4091 +/- 120ft TVD 9.1 Nanushuk8 4908 4619 -4543 +/-150ft TVD Torok (Nan-6) 5703 5381 -5305 +/- 150ft TVD TD 6129.63 5708.2 -5632.92 +/- 150ft TVD 8.8 Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 34 - 06-Nov-19 Oil Search Attachment 9: Pore Pressure Fracture Gradient Plot Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 35 - 06-Nov-19 0 Oil Search Attachment 10: Independent 311 Party Pore Pressure Fracture Gradient Plot Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 36 - 06-Nov-19 Mitquq-1 PPFG well plan plot psi and ppg A i ko n nce • 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. Attachment 11: Well Schematic Mitquq 1 ST1 Pre -drill Well Schematic 16" Conductor 128' MD/TVD Surface Casing 9-5/8" 40# L80 BTC 12 '/," Hole 2,475' MD/TVD 3-%" 'X' Landing Nipple 4284' MD/1076' TVD Tubing PIT Gauges 4292' MD/4082' TVD & 4303' MD/4088' TVD 3-'W, 'XN' Landing Nipple 4338' MD/4116' TVD 360' Core; ;, Oil Search (A Oil Search Updated Nov. 51" 2019 3-'/z". 2.813" Polish Bore'X' Landing Nipple 500' MD/TVD 3 '/V' 9.2# L80 Vam Top Tubing GLM, 3 /2" 3000' MD/TVD ES -Cementer Stage Cement Tool 3200' MD ST1 Kick Off @ 2600' MD/TVD 3-y," X 7" Packer 4321' MD/4103' TVD G 4345' MD/4121' TVD N Planned Perforations —4,377- 4,382' MD/ 4,158' TVD, 39.5° Inc. Production Casing 7" 26# L80 Vam Top HC 8'/2" Hale 6,130' MD/5708' TVD 7" casing cut @ 2,625' MD 3-'h" BHKA @ 4,100' MD/3,838' TVD 3-Y2*' 9.2# L-80 IBT Sacrificial Tubing 7" 26# L80 Vam Top HC 8'/V Hole 6,933' MD/5,954' TVD 6-1\H"', 20' inclination TD: 8250' MD 17175' TVD Mitquq 1 ST1 Permit to Drill Rev3_20191106 - 38 - 06-Nov-19 Oil Search Attachment 12: Formation Evaluation Program Mitquq 1 ST18-1/2" Production Hole Gamma Ray LWD Resistivity Sonic Conventional Core Up to 360' of 4" conventional core Density Neutron Induction Resistivity Sonic Spectroscopy Open Hole Wireline* Spectral Gamma Ray Image Log NMR Sidewall Cores Formation Pressures Formation Samples Cased Hole Wireline* Borehole Seismic Cement Evaluation Well Test* Single stage fracture stimulation & well test. * 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 ST1 Permit to Drill Rev3_20191106 - 39 - 06-Nov-19 Nw on search Attachment 13: Wellhead Diagram = .4. -ACME)"TIS = ='T 13M ---Pressure Control BAKER JUGHES With MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet K4dquq1GT1Permit mDrill Ruv3_2O1911OO -40- 06'Nm+19 cn 3 0 CD C < W N O 0 rn S 0 T Z 0 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 f 1,000 2,000 3,000 O 4,000 t a. v 5,000 6,000 7,000 8,000 Oil Attachment 12: Formation Evaluation Proqram Mitquq 1 ST18-1/2" Production Hole Gamma Ray LWD Resistivity Sonic Conventional Core Up to 360' of 4" conventional core Density Neutron Induction Resistivity Sonic Spectroscopy Open Hole Wireline* Spectral Gamma Ray Image Log NMR Sidewall Cores Formation Pressures Formation Samples Cased Hole Wireline* Borehole Seismic Cement Evaluation Well Test* Single stage fracture stimulation & well test. * 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 ST1 Permit to Drill Rev3_20191106 - 40 - 06-Nov-19 K cn 3 O CDm w I N O_ 0 rn N 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 a,, 1,000 2,000 3,000 O 4,000 t a m 5,000 6,000 7,000 Z 8,000 :: O RECEIVED STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 NOV 01 2019 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. SpgKt w r: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas El Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil Q Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Oil Search Alaska Bond No. NUSCGS025100 Mitquq 1 STb 3. Address: 900 E Benson Bouldevard 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99508 MD: 6,130' TVD: 5,708' Undefined 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 531.27' FSL, 2302.42' FEL, Sec 3, T11N, R7E, UM ADL 393876 / ADL 393875 Top of Productive Horizon: 8. DNR Approval Number: \ 13. Approximate Spud Date: 852' FSL, 2233.87' FWL, Sec 3, T11N, R7E, UM / LONS 19-005(Pending) ? ' 28th January 2020 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1145.46' FSL, 1553.72' FWL, Sec 3, T11 N, R7E, UM ADL393876 2,560 Acres/ADL39 7� 2, 60 cres 2,977' W 41b. 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 MS L ft). 47.3' to Same Pool: N/A 16. Deviated wells: Kickoff depth: 2,600 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 40 degrees Downhole: 2,460 psi Surface: 1,922 psi 18. Casing Program: Specifications Top - Settin h - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TV 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: 2,953cuft15.8ppg Tail: 268cuft 8-1/2" 7" 26# L-80 VAMTOP HC 6,130' 0' 0' 6,130' 5,633' Stage 1: 12.0 ppg Lead: 118cuft 15.3ppg Tail: 477cuft HfrRedrill Stage 2: 12.0 ppg Lead: 488cuft 15.3ppg Tail: 140cuft 19. PRESENT WELL CONDITION SUMMARY (To be ( ed 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 VTCement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): 1 7 Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ n Nc ❑ 20. Attachments: Property Plat ❑ Sketch ❑ Drilling Program ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ i er Sketch Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements i 21. Verbal Approval: Commission Repres ati . Date 22. 1 hereby certify that the foregoing is tr4b 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: Commission Use Only Permit to Drill i API Number: Permit Approval See cover letter for other Number: (� r 50- d O 4- 0 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 [S?"'No❑ Mud log req'd: Yes [qNo ❑ HZS measures: Yes ❑ No[P"' Directional svy req'd: Yes [�?`No❑ Spacing exception req'd: Yes ❑ No [SK Inclination -only svy req'd: Yes ❑ No [ Post initial injection MIT req'd: Yes ❑ No ❑ d APPROVED BY Approved � t& �vg �� 25 005 at : Submit Form and ReySed512017 This Permit is valid for 24 more of a ORIGINAL November 1, 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 S Explor ells North Slope, Alask 1ECL=1�EL) NOV 2019 0G Gc Dear Sir/Mada Oil Search las ), LL he eby appli for a Permit to Prtlan exploratory oil test well on the North Slope of ask The Mitq 1 well i a deviated wellj)&e targeting the Nanushuk 9, Torok, Kuparuk C, and Nuiqs rmations The Mitquq 1 ST1 w5l," deviated wellbore targeting the Nanushuk 9 and roons. BWwToro ellbores are loc�within state lease acreage on state lands. finding oA,, ' iter weather cgrfditions and ice road construction, the approximate spud date is i ' ate mid to late 2019. Oil Search at this time anticipates using Nabors Rig 7-ES to this well. Well wing is planned for the sidetrack and will be addressed in a sundry permit applic 'on. Plug a abandon operations for each wellbore will also be addressed in a separate sundry permit applicat' Please rfd enclosed for your review Form 10-401 Permit to Drill with a su p to D I containing information as required by 20 AAC 35.005 fore w Ibc AAC 25.061 Well Site Surveys, a Shallow Hazard Stud' cov ri th It uq in the application. If there are any questions and/or additional info a ' n e ' d, please co t or garret.staudinger(a)oilsearch.com. Respectfully, L. �— 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 (g"A plication for Permit In mpliance with 20 area h s been included I t me at (907) 440-6892 ORIGINAL (A 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 0 Oil Search 4) Oil Searcj Application for Permit to Drill Mitgug 1 ST1 Well Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 1 - 01-Nov-19 0) 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..................................................................................................................................................11 Attachment 1: Location Maps..........................................................................................................12 Attachment 2: Directional Plan........................................................................................................17 Attachment 3: BOPE Equipment......................................................................................................25 Attachment 4: Drilling Hazards.........................................................................................................28 Attachment 5: Leak Off Test Procedure...........................................................................................29 Attachment 6: Cement Summary.....................................................................................................30 Attachment 7: Rig Fluid System........................................................................................................31 Attachment 8: Prognosed Formation Tops......................................................................................33 Attachment 9: Pore Pressure Fracture Gradient Plot......................................................................34 Attachment 10: Independent 3 d Party Pore Pressure Fracture Gradient Plot ................................35 Attachment 11: Well Schematic.......................................................................................................38 Attachment 12: Formation Evaluation Program..............................................................................39 Attachment 13: Wellhead Diagram..................................................................................................40 Attachment 14: Days vs. Depth Plot.................................................................................................41 Mitquq 1 ST1 Permit to Drill Rev1_20191030 -2- 01-Nov-19 Oil; Search Application for Permit to Drill 1. Well Name 20 AAC 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 Mitguq 1 STl. This will be an exploratory well. 2. Location Summary 20 AAC 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 852' FSL, 2233.87' FWL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,970,945.878 E 458,764.574 Measured Depth, Rig KB (MD) 4,400' Total Vertical Depth, Rig KB (TVD) 4,166' Total vertical Depth, Subsea (TVDSS) 4,091' Location at Bottom of Productive Interval Reference to Government Section Lines 1145.46' FSL, 1553.72' FWL, Sec 3, T11N, R7E, UM NAD 27 Coordinate System N 5,971,243.024 E 458,085.518 Measured Depth, Rig KB (MD) 6,130' Total Vertical Depth, Rig KB (TVD) 5,708' Total vertical Depth, Subsea (TVDSS) 5,633' Mitquq 1 ST1 Permit to Drill Rev1_20191030 -3- 01-Nov-19 0) 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 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 Mitgug STi well. The applicant is the only affected owner. Included in Attachment 2 is an anti -collision scan from Mitquq 1 ST1 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 ST1 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 ST1 Permit to Drill Rev1_20191030 - 4 - 01-Nov-19 Oil Search 4. Drillinq Hazards Information 20 AA 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 2,460 psi in the Torok at 5,380' TVD (8.8ppg EMW top Torok formation) Maximum surface pressure 1,922 psi from the Torok (0.10 psi/ft gas gradient to surface, 5380' 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 N/A — Existing LOT data from Mitquq 1 wellbore 9-5/8" Casing Test 3,000 psi surface pressure [Test pressure driven by 50% of surface casing yield] 7" Casing Test 3,500 psi surface pressure [Test pressure driven by annular pressure during frac. job] (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 Mitquq 1 PTD Attachment 15: Shallow Hazards Assessment Please refer to Attachment 4: Drilling Hazards 5. Procedure for Conducting Formation Integrity Tests 20 AA 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 ST1 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 Liner / Top Bottom Hole Size Tbg O.D. Wt/Ft Grade Conn Length MD 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' Surface2,400' 2,475' / ArcticCem, Yield: 2.61 cuft/sk 15.8ppg Tail: 48bb1s, 268cuft, 227sks Type 1/11-1.18 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 15.3ppg Tail: 85bbls, 477cuft, 385sks Mitquq 1 7" 26# L-80 VAM TOP 6,130' Surface 6,130' / ExpandaCem Class G —1.24 cuft/sk 8--1/1/2" HC Stage 2: g 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. 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. Mitquq 1 ST1 Permit to Drill Rev1_20191030 -6- 01-Nov-19 0 Off Search 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 Production Hole 2475' — 6130' MD Mud Type Mineral Oil Based Mud Mud Properties: Mud Weight 10.7ppg 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% 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 fora 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 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: (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 Mitquq 1 PTD Attachment 15: Shallow Hazard Assessment Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 7 - 01-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 ST1 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 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 ST1 Permit to Drill Rev1_20191030 - 8 - 01-Nov-19 Q) 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. Mitquq 1 ST1 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' TVD. 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 ST1 Permit to Drill Rev1_20191030 - 9 - 01-Nov-19 0) OR 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 ST1 Permit to Drill Rev1_20191030 - 10 - 01-Nov-19 W) Oil Search Attachments Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 11 - 01-Nov-19 0) Oil Search Attachment 1: Location Maps Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 12 - 01-Nov-19 I I I I r-- I I I I I COLVILLE `= RIVER I I I I Cos I / I /+f I I I GREATER MOOSES- TOOTH NUIQSUT I I I I L-- I I I I I I I I (A Oil Search Cv HS-1 coa I_IQ9 I � I Nos, P1KKA Jr1. Pikka C I 7C I r - Ilt_1-- I asp\ I �I 1 I I ` I 1 I I tPLACER I I I I I r — Q-301 I I I MltgUq 1 I I I I �j Q-B l — IJ i ____—_—__I_____— - w I 1 v T al � MII.NE POIN I ,❑ WSAK,1 2W IiG Jli" L_ I I *Pikkal8 \�I ; I � 2F _ Zyl , IwsPrg -' _ _ Y I — j _ J MustAH / '?S.MIIUv��Hi/� KUPARUX RIVER 1 I I--2L i ----------------------- _I J I i WSAK 13 1 _ _ E W SAK 29 — / ' I ^ W SAK 3R I r1 I I I 2011-2019 DRILLED WELLS L _ ' PRODUCTION UNIT EXPLORATION ICE ROADS NS EXISTING FACILITY 0 EXPLORATION DRILL SITE --' NS EXISTING PIPELINES — NS EXISTING GRAVEL ROADS NPR -A BOUNDARY _2 OIL SEARCH LEASES K-1 OIL SEARCH ALASKA LLC. 2019-2020 EXPLORATION CAMPAIGN PROPOSED CAMPAIGN OVERVIEW N O 1 2 GCS: NAD 1983 S—P--A, J FIPS S00t Feet W E ®Mlles ,B; gJs/IBII. REV: I.B. By:1B ® Glosrlelers pucvmanl mma:OPYl9-�bGFNw� kaRaatlrfOGCCI $ 0 1 2 Project Location 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, T11 N, R7E, UMIAT MERIDIAN. PROPOSED ICE PAD 1,000' X 1,000' - �� WW 0_ co1Ir. _,a of, �� nzN l� T11 N WELL 41 LOCATION { Go T11 N' I � T10N �IASRC MINE SITE NUIQSUIT) Y _ T10N € T9N VICINITY MAP R7E SCALE: 1" = 6 MILES SEC. 3 PROPOSED 35' WIDE ICE ROAD MITQUQ 1 (AS -STAKED WELL LOCATION) O � m SEC. 3, T11 N, R7E, U. M. Ln 0 e SEC. 10, T11N, R7E, U. M. 0 v� 'g 1 0p0' S T Sir po S��wtL 1 � 0 150 300 SCALE IN FEET -j,�,�■`,� 1 MITQUQ 1 EXPLORATORY WELL PROPOSED ICE PAD RECONFIGURATION U M I A Q & AS -STAKED WELL LOCATION o.aw+eera..o.,uc Oil Search NORTH SLOPE, ALASKA 6700 Arctic ad Anchorage, AK Sr99518 DATE: 10/29/2019 DRAWN BY: FM / MMHN SHEET 1 OF 1 19071677-8220 SCALE. AS SHOWN CHECKED BY: K,JP JOB No: 80209.19 1� PROJECT ARE:A� • `J t Ae .� t'f r Mit u 1 STl 1HL qq qq X:458085.518 r Y:5971243.024 + Maims,% 9lsandstone X: 458764.574� Y:5970945.878 cc, rx� X: 459506.638 Y 5970621.159 Mit uy 1 Nanushuk 9 sandstone . .,, TX2d':3A3$7h ---- - _ X:460616.518 Y:59701 348 C t i Mlt �r 3� : 462549.836 ADL1 -_ '3�Tyfli I S M, t MW t;ILAL Jill i i SEC Mai 51 x a ® • TOPS DIMENSION_LINE SECTION LEASE OUTLINE OIL SEARCH ALASKA IX 2019-2020 PLORATION CAMPAIGN MITQUQ 1 WELL PLAN O WELL SURFACE HOLE L _1 TOWNSHIP N 0 200 400 �y ®Feet GCS: NAD 1927 StatePlane Alaska 4 FIPS 5004 Oil Search WELLTRAJECTORY ® Meters DATE: 9/24/2019. REV: 2.0. By: JB S 0 100 200 Document name:OPS-19-20-W-M_Mitqugl_wellPlan_NAD27 Truck ' Staging b me -coop E n g1n9 Wast® Storage Area 4 Off\ce '. on5e E nvISP\1\ ResP Camp o y Storage Camp C� Comms© �ue1 Annex T r r Shop i :1 M t J: d 3 + . W 1 ry i : Y IM1a7• a:,.y, � f., •1 +� �' — 1 x v't9• �. i �k `h. y # '� _. 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 State Plane Alaska 4 FIPS 5004 ®Feet DATE: 2019-09-24. REV: 2.0. By: A 0 50 100 DATE: OPS-19-20-P-PE-M POO_Mitqugl NAD27 W) Oil Search chment 2: Directional Plan Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 17 - 01-Nov-19 40) Oil Search Mitquq-1 ST1 wp02 Proposal Geodetic Report (Def Plan) Schlumbei ger nvvar. �a.e: �avra =. zv m- o�.v rm rvey r mpur mum wrvamre r LuemsM Client: Oil Search Vertical Section Azimuth: 99.084 4 (True North) Field: NS West Vertical Section Origin. 0.000 B, 0.000 ft Structure / Slot: Mhquq-1 - NAD27 / Mitquq-1 TVD Reference Datum: Rotary Table Wall: Mitquq-1 TVD Reference Elevation: 75.277 R above MSL Borehole: MBquq-1 STi Ground Elevation: 47.277 fi above MSL APt4k 50103-01 Magnetic Declination: 16.080' Survey Name: Mitquq-1 ST1 wp02 Total Gravity Field Strength: 1002.0008mgn (9.80665 Based) Survey Data: September 25, 2019 Gravity Model: DOX Tort I AHD / DDI I ERD Ratio: 68.658' / 1541.946 B 15.056 / 0.270 Total Magnetic Field Strength: 57378.891 nT Coordlnate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angle: 80.789 ° Location Let / Long: N 70° 19' 50.40263', W 150' 19' 42.39178" Declination [)ate: December 31, 2019 Location Grid N/E V/X: N 5970621.161 BUS, E 459506.040 ftUS Magnetic Declination Model: BGGM 2018 CRS Grid Convergence Angle: -0.3093 ° North Reference: True North Grid Scale Factor: 0.99990188 Grid Convergence Used: 0.0000 ° Version / Patch: 2.10.544.0 Total Corr Mag North- True North: 16.0805' Local Coord Referenced To: Well Head MD Incl Azlm True TVDSS TVD VSEC NS EW TF DLS Dlrectlonal Exclusion Zone Exclusion Zone G-Msg Th Northing Easting Comments (fi) (°) (°) (fill (fl) (B) (B) (fill (') ('/100ft) DifOculry Index Alert Angle (°l (Th nT) (BUS) (fiUS) KOP Cry 3/100 2500.00 0.00 99.09 2424.72 2600.00 0.00 0.00 0.00 293.32M WA 0.00 9.21 9187.44 5970621.16 459506.64 2600.00 3.00 293.32 2524.68 2599.95 -2.54 1.04 -2.40 293.32M 3.00 0.89 9.32 9292.29 5970622.21 459504.24 2700.00 6.00 293.32 2624.36 2699.63 -10.14 4.14 .9.61 HS 3.00 1.80 10.32 10298.01 5970625.35 459497.08 28D0.00 9.00 293.32 2723.49 2798.77 -22.79 9.31 -21.59 HS 3.00 2.33 12.01 11945-13 5970630.58 459485.10 29D0.00 12.00 293.32 2821.81 2897.08 40.45 16.52 38.33 HS 3.00 2.70 14.13 14016.91 5970637.89 459468.41 30D0.00 15'00 293.32 2919.03 2994.31 -63.08 25.76 59.76 HS 3.00 2.99 16.53 16328.44 5970647.24 459447.02 31 D0.00 18.00 293.32 3014.90 3090.18 -90.61 37.00 -85.84 HS 3.00 3.23 19.09 15771.02 5970658.62 459421.01 3200.00 21.00 293.32 3109.16 3184.43 -122.96 50.21 -116.49 HS 3.00 3.43 21.76 21277.59 5970672.00 459390.43 3300.00 24.00 293.32 3201.53 3276.81 -160.05 65.36 -151.63 HS 3.00 3.60 24.50 23804.89 5970687.33 459355.38 3400.00 27.00 293.32 3291.78 3367.06 -201.77 02.40 -191.16 HS 3.00 3.75 27.29 26323.26 5970704.56 459315.95 3500.00 30.00 293.32 3379.65 3454.93 -248.02 101.29 -234.97 HS 3.00 3.89 30.12 28811.08 5970723.70 459272.24 3600.00 33.00 293.32 3464.91 3540.18 -298.66 121.97 -282.95 HS 3.00 4.01 32.98 31251.60 6970744.64 459224.38 37D0.00 36.00 293.32 3547.31 3622.59 -353.56 144.39 334.96 HS 3.00 4.13 35.86 33631.26 5970767.34 459172.50 3800.00 39.00 293.32 3626.64 3701.91 412.55 168.48 390.85 HS 3.00 4.23 38.76 35938.62 5970791.73 459116.74 End Cry 3810.96 39.33 293.32 3635.13 3710.41 419.26 171.22 -397.21 HS 3.00 4.24 39.07 36186.66 5970794.51 459110.40 Tgt 4400.30 39.33 293.32 4091.00 4165.28 -781.30 319.07 -740.20 HS 0.00 4.52 39.07 36188.92 5970944.19 458768.24 Drp 1.81100 4500.30 39.33 293.32 4168.35 4243.63 .842.73 344.16 -798.40 LS 0.00 4.56 39.07 361 B9.31 5970969.59 458710.18 4600.00 37.53 293.32 4246.45 4321.73 .902.80 368.69 -855.31 LS 1.80 4.61 37.34 34823.99 5970994.43 458653.42 4700.00 35.73 293.32 4326.69 4401.97 -960.63 392.31 -910.11 LS 1.80 4.66 35.61 33426.65 5971018.34 458598.76 4800.00 33.93 293.32 4408.77 4484.06 -1016.00 414.92 -962.56 LS 1.80 4.70 33.88 32003.56 5971041.23 458546.43 4900.00 32.13 293.32 4492.60 4567.88 -1068.83 436.50 -1012.62 LS 1.80 4.74 32.15 30557.12 5971063.08 458496.49 5000.00 30.33 293.32 4578.11 4653.38 -1119.09 457.02 -1060.23 LS 1.80 4.78 30A4 29089.99 5971083.86 458449.00 5100.00 28.53 293.32 4665.19 4740.47 -1166.72 476.48 -1105.36 LS 1.80 4.81 28.74 27605.14 5971103.55 458403.98 5200.00 26.73 293.32 4753.78 4829.06 -1211.68 494.84 -1147.95 LS 1.80 4.84 27.04 26105.90 5911122.14 458361.49 5300.00 24.93 293.32 484379 4919.06 -1263.92 512.08 -1187.96 LS 1.80 4.87 25.36 24596.11 5971139.60 458321.58 5400.00 23.13 293.32 4935:11 5010.39 -1293.39 528.21 -1225.36 LS 1.80 4.90 23.70 23080.26 5971155.92 458284.27 5500.00 21.33 293.32 5027.67 5102.95 -1330.07 543.18 -1260.11 LS 1.80 4.93 22.06 21563.68 5971171.08 458249.61 5600.00 19.53 293.32 5121.38 5196.65 -1363.91 557.00 -1292.17 LS 1.80 4.95 20.44 20052.89 5971185.07 458217.63 5700.00 17.73 293.32 5216.13 5291.41 -1394.87 569.65 -1321.51 LS 1.80 4.98 18.85 18555.99 5971197.88 468188.36 5800.00 15.93 293.32 5311.84 5387.12 -1422.94 581.11 -1348.10 LS 1.80 5.00 17.31 17083.32 5971209.48 458161.83 5900.00 14.13 293.32 6408.42 5483.69 -1448.08 591.38 -1371.92 LS 1.80 5.02 15.81 15648.37 5971219.88 458138.07 6000.00 12.33 293.32 5505.7' 5581.03 -1470.27 600.44 -1392.94 LS 1.80 5.03 14.39 14269.04 5971229.05 458117.10 6100.00 10.53 293.32 5603.77 5679.05 -1489.49 608.29 -1411.14 LS 1.80 5.05 13.05 12969.38 5971237.00 458098.94 TD 6129.63 1..Do 293.32 5632.92 5708.20 -1494.60 610.38 -1415.99 1.80 5.06 12.68 12604.15 5971239.11 458094.10 Survey Error Model: ISCWSA Rev 0 - 3-D 95.000% Confidence 2.7955 sigma Suety Program: DeacAptlon Part(B) MD From MDT. EOU Freq Hole Size Casing Diameter Expected Max (fill (fi) (in) (in) Inclination (deal Survey Tool Type Borehole / Survey 1 0.000 2467.000 11100.000 12.250 9.825 SLB MWD+SAG Mitquq-1 / Mitquq-1 wp02 v5 1 2467.000 2500.000 11100,000 8.500 0.000 SLB_MWD+SAG Mitquq-1 / Mitquq-1 wp02 v5 1 2500.000 6129.626 1/100.000 30.000 30.000 SLB_MWD+SAG Mitquq-lA/Mitquq-1Awp02 NS WeshMitquq-1 - NAD27\Mitquq-1\Mitquq-1 ST1\MRquq-1 ST1 wp02 Drilling Office 2.10.544.0 Schlumberger-Private 9/25/2019 5:03 PM Page 1 of 1 (A scmumbepw Oil Search -2400 -1600 -800 0 800 1600 2400 3200 0 0 800 800 160o .. _.._.. _.._.._.._.._.._.._................................ Base Permafrost(1525.277 ND) ........... _.. _.._.._.._.._.._.._.._.._. _.._.._"_.._.._.._.._.._.._.._ 1600 9-5/8 casing 2475 MD 2475 ND .._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..___. _. Mid Schrader Bluff (2075.277 ND) _. _. _._. --------.._.._.._.._.._.._.0.00 ^ inc 99.09 ° az_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._ 0 vsec 2400 _.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..� . ................ .................................. _........... .............. _........................................... _._.._ 2400 MCU (2410.277 ND) aver.Sgh6ader. yfi.12550°277..I.V0}.•_.._.._.._.._.._.._.._.._.._.._..._...................... _......................... ............. _........... U uva l2 27.2 lVD1 KOP Cm 3/100 .... _......................... _.................. 2500 MD 2500 ND 0.00 ° incl 99.09 ° az 0 vsec 3200 End Cry 3200 0 3811 MD 3710 ND 39.33 ° incl 293.32 ° az o -419 vsec u i4 y ,e 4000 .. 4000 o :::_::_-.._.,_.._.._.._.._.._.._.._.._.._.._.._...._....... :_::_::_::_:: anusFuk(d'03i27TTt7Cf)_.._...._......_.. _ _.._.._..., .,........._._ Nanushuk 9 andstone (4'166.277 ND tM4TSTTgWY--97a M......._.._.._............................... .................. _.................................. ........... Tgt 4400 MD 4166 ND .._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._. .._.._.._.3Q Tl`Jnc1.29392_.az................................ ............................ _.................................. _......... Naushuk 8 (4618.277 ND) -781 vsec 4800 •._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..._.._.._.._.._.._.._.._.._.._.._. ................................ ............... _...................... .... _........................ ............................ _......... 4800 Drp 1.81100 4500 MD 4244 ND 39.33 ° incl 293.32 ° az -843 vsec orok (Nan-6) (5380.277::::: p:::::::..:..:..:..:..:..:..:..:..:..:..:..:..:..:...:..:..:..:...:..:..:..:..:..:_:..:..:..:..:..:..:..:..__:..:..:..:..:..: :..:..:..:..�.:..:..:..:..:::..:..:..:..: 5600 Mitquq-1 STi wp02 5600 _......... .._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._....._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._.._..._.._.._._.._.._._..___.._._.._.._.._ HRZ (5751.277 ND) TD CSaodstone..(Ft42.U7.7..NA1.._.._.._.._.._.._..t000._ina.zs3,3z'. _.._.._._.._.._ _ ........................._____..___..___.._.._.__.._..__.._.._.._.._.� LC (6128.277Nt)-1495vsec """""""""" ........ """�"" 6400 6400 ._..,.._.._�._...._.._.._.._.._zz.._.._.._.pp_...�._.._.._.._.._.._.._......................................................................... seAfpT16e(6 4�WTVD)"_.._.._......................................................................... ._.._.._._.._.._.._.._.._.._.._.._................... ._.._.._.._.._.._.._.._._.._.._.._.................. _....... ...... . __.._.._.................. ___.._._.._._...._.._..................... Mitquq-1 wp02 v5 7200 7200 -2400 -1600 -800 0 800 1600 2400 3200 Vertical Section (ft) Azim = 99.08° Scale = 1:1000.00(ft) Origin = ON/-S, OE/-W Borehole: Well: Field: Structure: Mitquq-1 ST1 Mitquq-1 � NS West Mitquq-1 8 Magnatle Panmahn Sumo Lootlon NADO Alaalu Sbb Plana, Zane 04, US Feat Mbeallanaow IG-1111, Modal: BGGM 2018 Dip: B0.]89• Date: 37-0ao-3019 Lat: N ]0 79 6939 Northing: 59]03]0.93RU g Grid Conv: -0.3123• Slot: MNquq 7 TVD Ret: RKB(]5.28R above MSL) McODao: i6.OB° FS: 57B7B.B91nT GnvRy F5: 1002007m9n (9d0885 Baaad) Lon: W 150 79 53.84 Eutlng: 1599579.38RU yule Fect 0.9999019 Plan: MRquq-1 3T7 wp02 (A Schlumgerger Oil Search Borehole: Well: Field: Mitquq-1 ST1 wp02 Mitquq-1 NS West 777 Mitquq-1 Gravity & Magnetic Parameters Surface Location NAD83 Alaska State Plane, Zone 04, US Feet Miscellaneous Model: BGGM 2018 Dip: 80.789' Date: 31-Dec-2019 Let: N 70 19 49.29 Northing: 5970370.93ftUS Grid Con, -0.3122° Slot: Mitquq 1 Plan: TVD Ref: RKB(75.28ft above MSL) MsgDec: 16.08° FS: 57378.891nT Gravity FS: 1002.001mgn (9.80665 Based) Lon: IN 15019 53.64 Easting: 1599539.38ftUS Scale Fact: 0.9999019 Mitquq-1 STi wp02 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 TD 6130 MD 5708 TVD 10.00 ° ind 293.32 ° az True N=610 E=-1416 Drp 1.8/100 Gnd 4500 MD 4244 TVD 39.33 ° ind 293.32 ° Mag 1000 az 1000 N=344 E=-798 Mitquq-1 ST1 wp02 End Cry True North 3811 MD 3710 TVD Tot Corr (M,T 16.080°) 39.33 ° incl 293.32 Mag Dec (16 080-) N-171 E--397 Grid Conv (-0.312°) 500 Mitquq 1 T Nan-9 Target 500 KOP Cry 31100 2500 MD 2500 TVD 0,00 ° incl 99.09 ° az p O N=0 E=0 0 O D II () 0 N Tgt 4400 MD 4166 TVD ° ° 9-5/8 casing 39.33 incl 293.32 az 2475 MD 2475 TVD CI) N=319 E=-740 0.00 ° incl 99.09 ° az Z N=0 E=0 -500 -500 Mitquq-1 wp02 v5 -1000 -1000 -1500 -1500 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 EW (ft) Scale = 1:600.00(ft) Schlumbuger Oil Search Borehole: Well: Field: Structure: Mitquq-1 ST1 wp02 Mitquq-1 NS West Mitquq-1 Gravity & Magnetic Parameters Surface Location NAD83 Alaska State Plane, Zone 04, US Feet Miacellaneoua Model: BGGM 2018 Dip: 80.700- Data: 31-0 -2019 Let: N 7019 49.29 NORkin.: 59T03T0.93t1U Grid Co— -0.3122° {`'99539.38fi11 Slot: Mitquq 1 TVD Rd: RKB)75.20ft atrova MSL) MagD.c: 1fi.08' FS: 5T3T8.891nT G.vIty FS: 1002.001mgn )9.806fi5 Based) Lon: W 15019 53.64 Eaa[Ing: Sula FaeF 0.9999019 Plan: MKquq-1 ST1 vip02 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22000 16000 _ _ _ _ — _ - -- _ _;...__ __� .__......_..� .__. _.. - 16000 14000 Colville 1 lz000 12000 10000 10000 8000 - 8000 x 0 o 6000 - Placer 2 6000 II 4000 Ataruq 2 4000 Placer 3 L z 2000 Placer 1 Ataruq 2A 2000 p_ __.._ _. _ 0 Mitquq-1 ST1 wp02 -z000 Mitquq 1. -2000 -4000 _ _ _ _ _ -a000 -6000 _ _ -- __. __. w _ _ -6000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22000 EW (ft) Scale = 1:4500.00(ft) Mitquq-1 ST wp02 Anti -Collision Summary Report Analysis DM4hr Tim.: September 25. 2019-1630 AMiyata Method: NormalP .. Client DII Search Rt0arona Tra)e M: Mitquq-1 ST1 w,02 (D.t Plan) FIeM: NS WeM Depth Int.rv.l: Every 10.00 Mee.und Depth (R) SWduro: Milquq-1 R.I. S. D&M M90OPIsion Sl nJ W02 v5. 115.2 Slot: Mltquq 1 min W All local mnlme InlCaled. W.II: mitq" 1 vent../Patch: 2.10.564.0 Borehole: Mitq.q-1 ST1 DWbas0 l Protect: b h-MnlingNMh Slope West Scan MD Rang.: 2500.DOR-6129.63R ISCWSA03-D 95.000%Confidenm2.J955sigma,forsubjWwN.FDr TnisD Eno, Model: D6ad wells, error OnDON_ID, Ksp CM8 uN eadl well rasped Y ORaN Tn)actodea Summery om.t sel.mon cmeNe Wtllhead detente scan: Rublded 8 160.12 R Salec0an filters: ICJ , Definitive Surveys,, eM,nPlana- DMnllive plane Ineyaeadud. Al Non. All NDrvDet Surveys when no Det-Survey la act In a bOnhd0 -All NOn-0<I Plana whin nq Def-Plan Is set In a baehde DRa.t Tra.etory Ss .ntlon Allow S.P Conlrolll.9 R.1YnnwT cto RISE 1s 1 Alert SteNa .1 I MAS R EOD R Dev. h Fed. Rule MD TVD Nert Mlner Ma Or M., Ma Br Pkcm 1 IDelSwveyj 94]0] 114 940d. At92. 3806 OSF1.Mi 2500.00 Z500.00 Put ]0%.1 et JO1D. ]014.31 1352 OSFI.50 6129.59 5J00.20 Mn- Pea, 21-Survey) P_ %10901 50.J 958te 9563.1 9-1 0SF1.50 2500.91 250091 MInPb ] 153. ]944.4 ]8 19. OSFI.50 Wil.28 5707.B3 Min- CON'r0e 1(DNSurveYl P.. 1NSO.SB 701.IM 1290236 1274e 20.79 OSF1.50 2500.00 2100.DO Min 1-1 1 12883 12855. 12423.1E 15.85 1 b>?.lJ 1452A2 OSf1.50 3685.J5 3819.15 MINPT-6C-0U 12603.5 t2P9> 1UHl.09 1454.61 126N,02 12381, 1629 11.2 OSFI SO 0SF1.50 392459 3Bm.16 WI(IH 3810.35 Min-P MinNl F 13878.24 1481.83 1269 . 123%. 14. OSF1.50 599J.36 55JS16 Mine F 130T.5] 1d812 t260O1 12]% 138J5.0 14]1.83 1289].48 12403.19 10% 14.15 D$F1.50 OSF1.50 60 22.% 6139.83 5603.09 SJ08.20 MI.- Mnm_L Placer 3 (Def Surey) paw 150.91.81 32.01 1513050 15110. 1282. MAS-f0.0o (m) 2500.00 2HODO Min-F 15150.3 32.81 1543].J1 1511J. 1287.% MPS=10.00 (ml 2513.56 2513.55 Wi 15a69.91 3251 15a56.81 15{1J.1 11 4 BIAS=1O00 I.) 25N 25 259821 M.nPl-0SF 1{301.J8 32.81 14381.94 1-18.9 9462 MPS=10.%lm) 5908.28 5481.73 MInm1 14181.41 32.81 14111i.11 111W. 91{2 141©]2B 32.01 1d155.31 td110. 9t5.31 MAS=10.00 (m) MAS=t0.DO lm) 8110.9{ 6139.63 5809.80 5]08.20 MinN61 MnPb Al- 7A P. SM1'+y) ® P_ 33.81 21343. 1623.J. 2130].25 32.01 21292.11 212J4 15J1. MAS=10.00 (m) MAS=10.DO (ml 1W 21 2528.% 21DD.21 2529.% MInft MInP1_1 10529.03 q OSF1.50 2952.25 2B1B.d MI.- gbmq 2 (Del Suneyl 'Peu 21258.80 32.01 21243. N123. 1823J1 mA -0.28 2500.28 MIn- 2130J25 J2.91 21292.J1 212]4 15]1. 2t40O]6 32.81 213%.JJ 21J]5. D,.%(m) MPS=10.00(m) MPS=tOD 2521.1 2529.% MinPt-0.5F 1530.1 21-DO 3281 21850.06 218M.1 1t31. DD(m) M]3.1D.%(m) 260398 2J1].1 260393 271 J.39 MInPI-OSF MinP1- 2MY24.23 101. 2t956. 21922.91 329.2 OSF1.50 2-li. 2025.08 MIn_ 21221. 0 I1-988.107 221t218 22112J110].. 332511 MMNA0I %%(lmml 228450.95 2535 2]32 S=I) 258 2:359.20 nMI M%-SF %9.. 2980 BB 19291.1J 41 19261.41 ID244 6N =11000. OSF1.5D .13 IIN9.93 2% ]1]5.26 MrnPl- M_ ADInN 2(Mt Swvo Pus 21.9.11 32.61 212JB.]] 2121M.95 WA MA5=10%On) 0.00 DOD S.- NN3.2 32.81 2120I.1 21180A 640 MAS•IO,W (m) 1639.55 183665 Mi 21213.31 32.81 21204.1 2118D.50 2605.1. MAS=10.00Im) 1849.60 1869.80 MNP EOU 21-.41 3281 21212,1 21221. e]98 32.61 21210. 211894 1956.91 2® 3211 21220.3D 211%. 1928.3 MA9=t00D (m) MA0:10.D0 (m) MA3=10.%(m) 25D03J 2535.95 21122 250D 3] 2535.W 211121 MinP1-OSF MinPb MinP1-OSF 2132900 3201 2t]ti.BB 21196. 9B8 1II- MAS=tD%(ml 2640.13 2839.% Min%-b5F 19291.1] 13.% 19261.41 1924J. DSF150 az 93 7175.28 MInPb 0 0 o— 0 N O a_ Q o L o w o- o— in - Q- Q O O O N O N O N O O _ 111) 41daa p®inseoyy Traveling Cylinder Plot NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2 280 270 260 North 350 10 190 180 170 TRAVELING CYLINDER PLOT Client Oil Search Field NS West Structure Mitquq-1 Well Mitquq-1 Borehole Mitquq-1 ST1 Date 25-Sep-2019 80 90 100 W Oil Search Attachment 3: BOPE Equipment Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 25 - 01-Nov-19 BOP CONFIGURATION - ELEVATION HYDRIL 13-5/8' 5KSI TYPE GK - ANNULAR PREVENTER E_� HYDRIL 13-5/8' 5KSI DOUBLE GATE UPPER GATE -PIPE RAMS 10' ACT. LOWER GATE-BLIND/SHEAR 14' ACT, HYDRIL 13-5/8' 5KSI SINGLE GATE - PIPE RAMS 10' ACT, DIVERTER BOP CONFIGURATION - ELEVATION LEVEL HYDRIL 21-1/4' ANNULA �_--- PREVENTER 1---=� TOP OF RIG MAT *Mgt NO 0 Ktjmkl.,Vg$Tk ■ 1 TOP OF RIG MAT I 2525 Ibi 9�R>r Z C Sb UM90rM1/S�y� dmrvga, 99]-PSI OIL SEARCH — RIG 7ES 7ES 90P IN SUBSTRUCTURE fill 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 �]L White Handle Valves a� Normally Open Red Handle Valves qw Normally Closed Date: 10-18-02 Rev. 3 1 Choke Line From BOP 11 To Flare ��Separator To Mud/Gas To Secondary Choke Line In Cellar Oil Search Attachment 4: Drilling Hazards 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 ST1 Permit to Drill Rev1_20191030 - 28 - 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 0.25bbl/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 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 ST1 Permit to Drill Rev1_20191030 - 29 - 01-Nov-19 Oil Search Attachment 6: Cement Summary Production Casing Cement — STAGE 1 Casing 7" 26# L80 Vam Top HC Casing Lead Open hole volume + 30% excess Lead TOC Stage Collar Depth —3200' (Base Tuluvak) Basis Tail Open hole volume + 30% excess + 500 ft shoe track Tail TOC —3900' MD/3780' TVD. 500' MD above top of Nanushuk 9 sandstone Spacer 30 bbls of 11.5 ppg Clean Spacer Total Cement Lead 21 bbls, 118 cuft, 55 sks of 12.0 ppg ExtendaCem, Yield: 2.13 cuft/sk Volume Tail 85 bbls, 477 cult, 385 sks 15.3 ppg ExpandaCem Class G —1.24 cuft/sk Temp BHST 156° F Verification Method Cement evaluation log Notes Job will be mixed on the fly Production Casing Cement — STAGE 2 Casing 7" 26# L80 Vam Top HC Casing Lead Cased hole volume + 30% excess Lead TOC Surface Basis Tail Open hole volume + 30% excess + Cased hole volume + 30% excess Tail TOC 100' MD above casing shoe (9-5/8" x 7" annulus) Spacer 30 bbls of 11.5 ppg Clean Spacer Total Lead 87 bbls, 488 cuft, 203 sks of 12.0 ppg VariCem, Yield: 2.40 cuft/sk Cement Volume Tail 25 bbls, 140 cuft, 113 sks 15.3 ppg P Ex andaCem Class G —1.24 cuft/sk Temp BHST 88' F Verification Method Cement evaluation log / Cement to surface Notes Job will be mixed on the fly Mitquq 1 ST1 Permit to Drill Rev1_20191030 -30- 01-Nov-19 wil Oil Search Attachment 7: Rig Fluid System Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 31 - 01-Nov-19 SOLOS DISCHARGE PIL IT 50 FROM SLOWDOWN TANK SWACO 518 CENTRIFUGE O® LIQUIDS DISCHARGE SUCTION TANK 160 BBL P6 3 MP 2 CE F-1000 FROM FUEL TANK 'TF9.�,9�l�owiCf 1 MUD DITCH a' a• a• DESILTER a' ® TANKCENTRIFUGE 167 BBL ( #jR TANK TANK 50 BBL L. EQU. 167 BBL 2'A.SSFR L. EQU. DESANDER/ 1. WIER DEGASSER TANK I 167 BBL 3„ 21, BRINE M 250 5 % TANKS BO BO 00 MP 1 0o CE j 4 I� TO STANDPIPE MANIFOLD NABORS ALASKA RIG 7ES MUD SYSTEM SCHEMATIC HOLE 3 FILL LINE VENT R� 2' SPHON POORBOY BRFfiXER VENT LEGEND DEGASSER BUTTERFLY VALVE N GATE VALVE D4 JIMER—FROM 3" 3' MUD GUN w/VALVE �a}® P TRAP 8" SUCTON VALVE DRECO STYLE c/w BOLT ON FLAT RUBBER SEAL 0 RECESSED MUD DRCH GATE C—) 2 MUD HOPPER 10 HP AGITATOR CHEMICAL BARREL 5 HP AGITATOR 1D" EQUALIZER PULSATION DAMPER PRESSURE INDICATOR PI PRESSURE SWITCH PS RELIEF VALVE FLOW ARROW PUMP KEY P# MANWAY Mw P1 - CHARGE/MUD MIX 6604 (14" IMP) 60 HP POSSUM BELLY GUILLOTINE GATE P2 - CHARGE/MUD MIX 6x5x14 (14" IMP) 60 HP P3 - MUD MIX/TRANSFER 6x5x14 (14" IMP) 60 HP P4 - DESILTER 6x5x14 (14" IMP) 100 HP P5 - DESANDER 6x5x14 (14" IMP) 100 HP P6 - CENTRIFUGE SWACO TYPE 11 P7 - TRIP TANK 3x2x13 (13' IMP) 20 HP PB - BRINE GRINDEX 8 HP 'N" IMPELLER P9 - BRINE GRINDEX 8 HP "N" IMPELLER P10 - BRINE GRINDEX 8 HP 'N' IMPELLER Search Attachment 8: Propnosed Formation Tops Mitquq-1 ST1 Prognosed Tops ftMD ft TVD(KB) ft TVDSS Uncertainty Range Pore Pressure (ppg) Tuluvak Formation 2627 2627 -2552 +/- 100ft TVD 9.9 Seabee Formation 3196 3157 -3110 +/- 100ft TVD 8.7 Nanushuk Formation 4233 4029 -3962 +/- 100ft TVD Nanushuk 9 Sandstone 4391 4167 -4091 +/- 120ft TVD 9.1 Nanushuk 8 4908 4619 -4543 +/- 150ft TVD Torok (Nan-6) 5703 5381 -5305 +/- 150ft TVD TD 6129.63 5708.2 -5632.92 +/- 150ft TVD 8.8 Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 33 - 01-Nov-19 Attachment 9: Pore Pressure Fracture Gradient Plot r- R c fJ - .... (gjcjA -) M'ldap 0) Oil Search Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 34 - 01-Nov-19 Oil Search Attachment 10: Independent 311 Partv Pore Pressure Fracture Gradient Plot Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 35 - 01-Nov-19 Mitquq-1 ST1 PPFG High Case ppg W tquq-1 I x - F'TpV Session: Mitquq _ TVDkb(ft) TbV1 (MIJ i.6X^I (`� -� TVDkb fftl Equivalent Mudweight (ppg) calculated from KB o c o o c ti 1 N ikon S, ,,�r,c Fracture pressi—s are calculated ), ,m 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 u i x PV Session: Mitquq TvtlMcb (f1) VWT [Pisl !�'tii f"k�_� Equivalent Mudweight (ppg) calculated from KB 01 AvA ikon Science 0 Oil Search Attachment 11: Well Schematic Mitquq 1 ST1 Pre -drill Well Schematic Oil Search Updated Oct. 29"' 2019 16" Conductor 128. MDITVD Surface Casing 9-5/8" 40# L80 BTC 12 '/." Hole 2,475' MD/TVD 3-'/z". 2.813" Polish Bore'X` Landing Nipple 500' MD/TVD 3 %" 9.2# L80 Vam Top Tubing GLM, 3-Yz" 3000' MDfTVD ES -Cementer Stage Cement Tool 3200' MD 3-1/2"'X' Landing Nipple 42&4' MD/1076' TVD ST1 Kick Off @ Tubing P/T Gauges 2600' MD/TVD 4292' MD/4082' TVD & 4303' MD/4088' TVD 3-1/:", 'XN' Landing Nipple 3-Yz" BHKA @ 4338' MD/4116' TVD 2900' MD / 2895' TVD 360' Core 3-'/V X 7" Packer 4321' MD/4103' TVD 3-%" 9.2# L-80 IBT `/ Sacrificial Tubing WLEG 4345' MD/4121' TVD Planned Perforations 4,377- 4,382' MD/ 4,158' TVD, 39.5° Inc. Production Casing 7" 26# L80 Vam Top HC 8 '/z" Hole 6,130' MD/5708' TVD 8-1/2" OH 20' inclination TD: 8250' MD / 7175' TVD Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 38 - 01-Nov-19 0 Oil Search Attachment 12: Formation Evaluation Pro -gram Mitquq 1 ST18-1/2" Production Hole Gamma Ray LWD Resistivity Sonic Conventional Core Up to 360' of 4" conventional core Density Neutron Induction Resistivity Sonic Spectroscopy Open Hole Wireline* Spectral Gamma Ray Image Log NMR Sidewall Cores Formation Pressures Formation Samples Cased Hole Wireline* Borehole Seismic Cement Evaluation Well Test* Single stage fracture stimulation & well test. * 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 ST1 Permit to Drill Rev1_20191030 - 39 - 01-Nov-19 Attachment 13: Wellhead Diagram 9-W, ("CMEIOTS -06'sm ,HitB" 10M AA S FElATLE U J-t2'.]-�•Z lUOiNG --__� ;-�^`CpN(4(N.t NE Pressure Control EIR 16' x 9-518' x 7" x 4-112 x 3-il2" 5MOM MB-230 Multibowl Assembly, UGII"IIES With MB-230 Upper Head and MB-230 Tubing Manger and K Tubing Bonnet a GE<c+mpany Qp Oil Search Mitquq 1 ST1 Permit to Drill Rev1_20191030 - 40 - 01-Nov-19 K T 3 0 CD 1T N < N O_ IR O Cl) O i. A S 4 L O. 61 O 0 Z 0 a Mitquq 1/ST1 Days vs. Depth 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 Kick Tolerance Calculations guy schwartz 12/23/2019 input in yellow areas only Mitquq 1ST 219-151 MW (ppg) 10.7 ppg LOT/FIT (ppg) 12.8 TVD Casing Shoe (ft) 2400 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) 0.25 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) 5633 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) 4.5 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 0.0505 bbl/ft Annular Capacity between OH and DP 0.0259 bbl/ft Annular Capacity between OH and BHA 262.08 psi Maximum Allowable Surface Pressure 73.229 psi Underbalance due to Kick Intensity 188.851 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 413.8 feet Volume of Gas Kick.' bbl CAS` i Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 20.9 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx bbl " depth Conversion KICK TOLERANCE: 10.4 bbl Compare CASE 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 TRANSMITTAL LETTER CHECKLIST WELL NAME: 1-(7 7 a q S T J_ PTD: Development _ Service `Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: G Xp 1QKA4— 6t-\ 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 pen —nit). 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 V/ (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements mad lO �,�4 L � / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V 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
