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Home My WebLink About219-153From: Heusser, Heather A (DNR) To: Guhl, Meredith D (OGC) Subject: RE: Stirrup 1, PTD 219-153, Extended Confidentiality Requested? Date: Monday, May 2, 2022 12:11:21 PM Good afternoon Meredith, I confirmed this morning that neither the DNR Commissioner or DOG Director received and requests for extended confidentiality on this well. 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. heusserPalaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Tuesday, April 19, 2022 7:27 AM To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Subject: Stirrup 1, PTD 219-153, Extended Confidentiality Requested? Good Morning Heather, Oil Search (Alaska) LLC's Stirrup 1 well, PTD 219-153, API 50-103-20809-00-00, is due for release from the two year confidentiality period after May 1, 2022. Has Oil Search requested extended confidentiality for this well? 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.euhlPalaska.g_ov. DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 MD 4960 TVD 4960 Completion Date 4/1/2020 REQUIRED INFORMATION Mud Log Yes Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 Completion Status P&A Current Status P&A UIC No 1-J Inclination survey required and submitted Samples Yes Bireetieaal-Survey Ne DATA INFORMATION List of Logs Obtained: GR/Res/Sonic,GR/SS/NGI/ZAIT,GR/CMR/HNGS/PEX/NEXT,PressureXPT, FluidORA, SidewallXLrocks (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200301-001 Stirrup1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200301-002 Stirrup1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200301-003 Stirrup1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200301-004 Stirrup1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200301-005 Stirrup1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200301-006 Stirrup1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: Job44675.xls ED C 33089 Digital Data 5/14/2020 Electronic File: Job44373_Stirrup-1.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200401-001 Stirrup 1 4- 1-20 4326.35ft ASO459.xls ED C 33089 Digital Data 5/14/2020 Electronic File: Stirrup 1 PVT validation final report.xlsx ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-001 Stirrup #1 6 3,606.40ft XAS0006.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-002 Stirrup #1 16 3,647.1 Oft XAS0007.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-003 Stirrup #1 18 3,654.20ft XAS0008.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-004 Stirrup #1 23 3,682.40ft XAS0009.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-005 Stirrup #1 28 3,702.50ft XAS0010.xls ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-006 Stirrup #1 38 3,829.60ft XAS0011.xls AOGCC Page 1 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33089 Digital Data 5/14/2020 Electronic File: ROSL-200201-007 Stirrup #1 43 3,909.40ft XAS0012.xls ED C 33090 Digital Data 5/14/2020 Electronic File: Stirrup 1 Conventional Core Inventory.xlsx ED C 33090 Digital Data 5/14/2020 Electronic File: 4218.0-4236.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4218.0-4236.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4218.0-4236.0_c1.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4236.0-4254.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4236.0-4254.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4236.0-4254.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4254.0-4272.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4254.0-4272.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4254.0-4272.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4272.0-4290.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4272.0-4290.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4272.0-4290.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4290.0-4308.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4290.0-4308.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4290.0-4308.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4308.0-4326.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4308.0-4326.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4308.0-4326.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4326.0-4344.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4326.0-4344.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4326.0-4344.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4344.0-4362.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4344.0-4362.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4344.0-4362.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4362.0-4380.0.jpg AOGCC Page 2 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33090 Digital Data 5/14/2020 Electronic File: 4362.0-4380.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4362.0-4380.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4380.0-4398.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4380.0-4398.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4380.0-4398.0_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4398.0-4398.5.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4398.0-4398.5uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4398.0-4398.5_dry.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4398.5-4416.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4398.5-4416.0_c2.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4416.0-4434.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4416.0-4434.Ouv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4434.0-4452.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4434.0-4452.Ouv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4452.0-4470.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4452.0-4470.Ouv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4470.0-4488.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4470.0-4488.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4488.0-4506.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4488.0-4506.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4506.0-4524.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4506.0-4524.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4524.0-4542.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4524.0-4542.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4542.0-4560.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4542.0-4560.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4560.0-4578.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4560.0-4578.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4578.0-4578.5.jpg AOGCC Page 3 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33090 Digital Data 5/14/2020 Electronic File: 4578.0-4578.5uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4578.5-4595.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4578.5-4595.0_c3.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4595.0-4613.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4595.0-4613.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4613.0-4631.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4613.0-4631.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4631.0-4649.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4631.0-4649.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4649.0-4667.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4649.0-4667.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4667.0-4685.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4667.0-4685.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4685.0-4703.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4685.0-4703.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4703.0-4721.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4703.0-4721.Ouv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4721.0-4739.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4721.0-4739.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4739.0-4757.0.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4739.0-4757.0uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4757.0-4758.9.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: 4757.0-4758.9uv.jpg ED C 33090 Digital Data 5/14/2020 Electronic File: Alaska Field Coring Report #1 Stirrup-1.pdf ED C 33090 Digital Data 5/14/2020 Electronic File: Alaska Field Coring Report #2 Stirrup-1.pdf ED C 33090 Digital Data 5/14/2020 Electronic File: Alaska Field Coring Report #3 Stirrup-1.pdf AOGCC Page 4 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33090 Digital Data 5/14/2020 Electronic File: Stirrup-1—Run-1 E_5in_XLROCK_SWC.xlsx ED C 33091 Digital Data 136 4960 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Sti rrup_1 _DM D_R1-3_4960ft.las ED C 33091 Digital Data 43857 43863 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _DMT_R01.Ias ED C 33091 Digital Data 43871 43873 5/14/2020 Electronic Data Set, Filename: 0ilSearch_Stirrup_1 _DMT_R02.las ED C 33091 Digital Data 43876 43879 5/14/2020 Electronic Data Set, Filename: 0ilSearch_Stirrup_1 _DMT_R03.las ED C 33091 Digital Data 475 4960 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Sti rrup_1 _LW D_R1-3_4960ft.las ED C 33091 Digital Data 100 2614 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup- 1 R1 12.25in SonicVision825 Drill DTCO 100ft -2614ft.las ED C 33091 Digital Data 100 4960 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Stirrup_1 _LW D_R1-3_4960ft.las ED C 33091 Digital Data 2605 4140 5/14/2020 Electronic Data Set, Filename: Oil Sea rch_Stirrup_1_R2_8.5in_SonicScope675_ Drill DTCO 2605ft-4140ft.las ED C 33091 Digital Data 4040 4880 5/14/2020 Electronic Data Set, Filename: Oil Sea rch_Stirrup_1_R3_8.5in_SonicScope675_ Drill Ream DTCO 4040ft 4880ft.las ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup- 1 R1 12.25in SonicVision825 Drill DTCO 100ft -2614ft.dlis ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_LWD_RM_4960ft.dlis ED C 33091 Digital Data 5/14/2020 Electronic File: Oi ISea rch_Sti rrup_1 _LW D_RM_4960ft. htm I ED C 33091 Digital Data 5/14/2020 Electronic File: Oil Sea rch_Stirrup_1_R2_8.5in_SonicScope675_ Drill DTCO 2605ft-4140ft.dlis ED C 33091 Digital Data 5/14/2020 Electronic File: Oil Sea rch_Stirrup_1_R3_8.5in_SonicScope675_ Drill Ream DTCO 4040ft 4880ft.dlis ED C 33091 Digital Data 5/14/2020 Electronic File: 3H Stirrup 1 ASP NAD27 Final Survey.pdf AOGCC Page 5 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33091 Digital Data 5/14/2020 Electronic File: 3H Stirrup 1 ASP NAD83 Final Survey.pdf ED C 33091 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup_1_ASP Final Survey - NAD27.xlsx ED C 33091 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup_1_ASP Final Survey - NAD83.xlsx ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_DMD_R1- 3_4960ft.Pdf ED C 33091 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup_1 _DMT_R01.Pdf ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _DMT_R02.Pdf ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _DMT_R03.Pdf ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup- 1 R1 12.25in SonicVision825 Drill DTCO 100ft -2614ft.pdf ED C 33091 Digital Data 5/14/2020 Electronic File: Oil Sea rch_Stirrup_1_R2_8.5in_SonicScope675_ D ri I I_DT C O_2605ft-4140ft. pd f ED C 33091 Digital Data 5/14/2020 Electronic File: Oil Sea rch_Stirrup_1_R3_8.5in_SonicScope675_ Drill_Ream_DTCO_4040ft 4880ft.pdf ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _VISION_SERVICE_2MD.pd f ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _VISION_SERVICE_2TVD.p df ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _VISION_SERVICE_5MD.pd f ED C 33091 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _VISION_SERVICE_5TVD.p df ED C 33092 Digital Data 128 4960 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Sti rrup_1 _Dril IGas_depth_4960ft_17F eb202O.las AOGCC Page 6 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_DailyMudlogRpts.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Final_Well_Report.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _GasRpt_17Feb2020.x1s ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1Show Reports.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: Stirrup 1 Compiled DGRs.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_DrillGas_time_Jan27th to Feb18th 2020.zip ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_DriIli ngLog_4960ft_17Feb20 20_Final.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: Oi ISearch_Sti rrup_1 _GasRatioLog_4960ft_17Feb 2020_Final.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: Oil Sea rch_Stirrup_1_MasterLog5in_4960ft_17Fe b2020_Final.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch Stirrup_1_MasterLogTVD_4960ft_17F eb2020_Final.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: Oi ISea rch_Sti rrup_1 _MasterLog_4960ft_17Feb20 20_Final.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OiISea rch_Stirrup_1 _PressureLog_4960ft_17Feb 2020_Final.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1Sample _Inventory.pdf ED C 33092 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Sample_Inventory.xlsx ED C 33092 Digital Data 5/14/2020 Electronic File: Stirrup-1 Prognosis.pdf ED C 33093 Digital Data 2707 4874 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_QGE0_Dip_lnterpretation_2705_4875 ftMD.las AOGCC Page 7 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33093 Digital Data 3420 4874 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_QGEO_Sandcount_BIN _Pc_CumulativeThickn ess PseudoGR 3420 4874 ftMD.las ED C 33093 Digital Data 4952 2480 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Sti rrup_1 _Run 1 A_ZAIT_PPC_MAST_ NGIT Main.las ED C 33093 Digital Data 4964 4448 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Sti rrup_1 _Run 1 A_ZAIT_PPC_MAST_ NGIT_Repeat.las ED C 33093 Digital Data 2558 4894 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_1 A_8.5in_SScan_PnS AN 12558-4894ft.las ED C 33093 Digital Data 2480 4952 5/14/2020 Electronic Data Set, Filename: Oi ISea rch_Sti rrup_1 _Ru n_1 A_LSA_2479- 4952ft.las ED C 33093 Digital Data 2700 4944 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1_Run_1A_RTScanner_1 D_In version Best 2700-4943ft.las ED C 33093 Digital Data 2700 4944 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_1 A_RTScanner_39_1 D Inversion 2700-4943ft.las ED C 33093 Digital Data 2700 4944 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_1 A_RTScanner_54_1 D Inversion 2700-4943ft.las ED C 33093 Digital Data 2700 4944 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_1 A_RTScanner_72_1 D Inversion 2700-4943ft.las ED C 33093 Digital Data 2700 4944 5/14/2020 Electronic Data Set, Filename: OiISea rch_Stirrup_1 _Run_1 A_RTScanner_Data_ 2700-4943ft.las ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup1_SandCount Zones.xlsx ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1 QGEO PROCESSED IMAGES 2705 4875ft MD.dlis ED C 33093 Digital Data 5/14/2020 Electronic File: Oi ISearch_Sti rrup_1 _Run 1 A_ZAIT_PPC_MAST_ NGIT Main.dlis AOGCC Page 8 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run 1 A_ZAIT_PPC_MAST_ NGIT_Repeat.dlis ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_1 A_8.5in_SScan_PnS AN 12558-4894ft.d lis ED C 33093 Digital Data 5/14/2020 Electronic File: Oi ISea rch_Sti rrup_1 _Ru n_1 A_LSA_2479- 4952ft.dlis ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1A_RTScanner_1 D_In version 2700-4943ft.dlis ED C 33093 Digital Data 5/14/2020 Electronic File: Oi I Sea rch_Sti rru p 1 _QG EO_I nterpretatio n_5i n_27 05_4875 ftMD.pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup1_QGEO_Interpretation_60in_2 705_4875 ftMD.pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup1_QGEO_Sand_Counting_20in _3420_4874 ftMD.pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup1_QGEO_Sand_Counting_5in_ 3420_4874 ftMD.pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup1_QGEO_Sand_Counting_60in _3420_4874 ftMD.pdf ED C 33093 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup1Run 1 A_ Caliper_5in_18Feb2 0. Pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1Run 1 A_MAST_2in_18Feb2 0. Pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1Run 1 A_MAST_5in_18Feb2 0. Pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1Run 1 A_NGI_20in_18Feb20. Pdf AOGCC Page 9 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run 1 A_NGI_60in_18Feb20. Pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run1 A_ZAIT_2in_18Feb20. Pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run1 A_ZAIT_5in_18Feb20. Pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_1 A_8.5in_SScan_PnS _AN I_2558-4894ft. pdf ED C 33093 Digital Data 5/14/2020 Electronic File: Oi ISea rch_Sti rrup_1 _Ru n_1 A_LSA_2479- 4952ft. pdf ED C 33093 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1A_RTScanner_1 D_In version_2700-4943ft. pdf ED C 33094 Digital Data 2498 4949 5/14/2020 Electronic Data Set, Filename: 0ilSearch_Stirrup1Run1 B_NEXT_HDRS_HGN S HNGC HNGS CMRT Main.las ED C 33094 Digital Data 4619 4948 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1_Run1 B_NEXT_HDRS_HGN S_H N GC_H N GS_CM RT_Repeat.las ED C 33094 Digital Data 2700 4891 5/14/2020 Electronic Data Set, Filename: 0ilSearch_Stirrup1Run_1 B_CMR_2700- 4891 ft.las ED C 33094 Digital Data 2530 4890 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1_Run_1 B_CMR_Depth_Shift ed.las ED C 33094 Digital Data 2700 4940 5/14/2020 Electronic Data Set, Filename: 0ilSearch_Stirrup1Run_1 B_LithoScanner_RBF CEC 2700-4940ft.las ED C 33094 Digital Data 2700 4940 5/14/2020 Electronic Data Set, Filename: 0ilSearch_Stirrup1Run_1 B_LithoScanner_SP EC TOC 2700-4940ft.las ED C 33094 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup1Run1 B_NEXT_HDRS_HGN S HNGC HNGS CMRT Main.dlis AOGCC Page 10 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run1 B_NEXT_HDRS_HGN S_HNGC_HNGS_CMRT_Repeat.dlis ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 B_CMR_2700- 4891 ft.d lis ED C 33094 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup1Run_1 B_LithoScanner_RBF CEC 2700-4940ft.dlis ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run1 B_CMR_2in_18Feb20. Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run1 B_CMR_5in_18Feb20. Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run1 B_HNGS_2in_18Feb2 0. Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run1 B_HNGS_5in_18Feb2 0. Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 Run 1 B_NEXT_2in_18Feb20 .Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 Run 1 B_NEXT_5in_18Feb20 .Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 Run 1 B_PEX_2in_18Feb20. Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 Run 1 B_PEX_5in_18Feb20. Pdf ED C 33094 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 B_CMR_2700- 4891 ft. pdf ED C 33094 Digital Data 5/14/2020 Electronic File: 0ilSearch_Stirrup1Run_1 B_LithoScanner_RBF _CEC_2700-4940ft.pdf AOGCC Page 11 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A ED C 33094 Digital Data ED C 33095 Digital Data 0 485 ED C 33095 Digital Data 0 246 ED C 33095 Digital Data 0 1544 ED C 33095 Digital Data 0 269 ED C 33095 Digital Data 0 2233 ED C 33095 Digital Data 0 181 ED C 33095 Digital Data 0 143 ED C 33095 Digital Data 0 190 ED C 33095 Digital Data 0 642 ED C 33095 Digital Data 0 598 ED C 33095 Digital Data 0 175 ED C 33095 Digital Data 0 152 ED C 33095 Digital Data 0 157 ED C 33095 Digital Data 0 1527 ED C 33095 Digital Data 0 1145 ED C 33095 Digital Data 0 185 ED C 33095 Digital Data 0 1754 API No. 50-103-20809-00-00 Current Status P&A UIC No 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 B_LithoScanner_SP EC_TOC_2700-4940ft. pdf 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta002_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta003_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta004_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta005_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta006_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta007_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta008_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta009_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta010_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta011_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta012_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta013_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta014_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta015_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta016_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta017_XPT.las 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta018_XPT.las AOGCC Page 12 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC MD 4960 TVD 4960 ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data AOGCC API No. 50-103-20809-00-00 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No 0 1568 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta019_XPT.las 0 1232 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta020_XPT.las 0 219 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta021_XPT.las 0 239 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta022_XPT.las 0 969 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta023_XPT.las 0 1121 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta024_XPT.las 0 1343 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta025_XPT.las 0 1267 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta026_XPT.las 0 794 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta027_XPT.las 0 1002 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta028_XPT.las 0 1282 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta029_XPT.las 0 139 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta030_XPT.las 0 226 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta031_XPT.las 0 204 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta032_XPT.las 0 180 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta033_XPT.las 0 173 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta034_XPT.las 0 174 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta035_XPT.las 0 228 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta036_XPT.las Page 13 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC MD 4960 TVD 4960 ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data AOGCC API No. 50-103-20809-00-00 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No 0 135 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta037_XPT.las 0 170 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta038_XPT.las 0 137 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta039_XPT.las 0 144 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta040_XPT.las 0 144 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta041_XPT.las 0 127 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta042_XPT.las 0 161 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta043_XPT.las 0 1296 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta044_XPT.las 0 224 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta045_XPT.las 0 363 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta046_XPT.las 0 275 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta047_XPT.las 0 1099 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta048_XPT.las 0 738 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta049_XPT.las 0 679 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta050_XPT.las 0 341 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta051_XPT.las 0 1330 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta052_XPT.las 0 1298 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta053_XPT.las 0 400 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1—Run 1C_Sta054_XPT.las Page 14 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC MD 4960 TVD 4960 ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data ED C 33095 Digital Data AOGCC API No. 50-103-20809-00-00 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No 0 803 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta055_XPT.las 0 1415 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta056_XPT.las 0 965 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta057_XPT.las 0 1077 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta058_XPT.las 0 560 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta059_XPT.las 0 1574 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta060_XPT.las 0 745 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta061_XPT.las 0 1679 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta062_XPT.las 0 2105 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta063_XPT.las 0 277 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta064_XPT.las 0 189 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta065_XPT.las 0 182 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta066_XPT.las 0 1230 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1C_Sta067_XPT.las 4214 4374 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1 Run 1 C XPT Correlation Pass 1.1as 4362 4510 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1 Run 1 C XPT Correlation Pass 2.1as 3523 3728 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1 Run 1 C XPT Correlation Pass 3.1as 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta002 XPT.dlis 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta003 XPT.dlis Page 15 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta004 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta005 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta006 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta007 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta008 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta009 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta010 XPT.dIis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta011 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta012 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta013 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta014 XPT.dIis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta015 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta016 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta017 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta018 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta019 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta020 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta021 XPT.dlis AOGCC Page 16 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta022 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta023 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta024 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta025 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta026 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta027 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta028 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta029 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta030 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta031 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta032 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta033 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta034 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta035 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta036 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta037 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta038 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta039 XPT.dlis AOGCC Page 17 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta040 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta041 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta042 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta043 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta044 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta045 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta046 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta047 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta048 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta049 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta050 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta051 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta052 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta053 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta054 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta055 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta056 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta057 XPT.dlis AOGCC Page 18 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta058 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta059 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta060 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta061 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta062 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta063 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta064 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta065 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta066 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C Sta067 XPT.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C XPT Correlation Pass 1.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C XPT Correlation Pass 2.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1C XPT Correlation Pass 3.dlis ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1 C_5in_XPT_19Feb20.pdf ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1C- 1 D_8.5in_XPT-ORA_Report.pdf ED C 33095 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 C_8.5in_XPT_Pressu reTimePlots.pdf ED C 33096 Digital Data 4378 4026 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1-Run ID —Correlation Pass ORA.las ED C 33096 Digital Data 0 6635 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1 D_Sta001_ORA.las AOGCC Page 19 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33096 Digital Data 0 4272 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1 D_Sta002_ORA.las ED C 33096 Digital Data 0 4143 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup 1_Run 1 D_Sta003_ORA.las ED C 33096 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 D_5in_ORA_19Feb2 0. Pdf ED C 33096 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run ID —Correlation Pass ORA.dlis ED C 33096 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1D Sta001 ORA.dlis ED C 33096 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1D Sta002 ORA.dlis ED C 33096 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup 1_Run 1D Sta003 ORA.dlis ED C 33097 Digital Data 0 24442 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1_Run_1 E_XLROCK_Coring_ Station Log.las ED C 33097 Digital Data 3964 3516 5/14/2020 Electronic Data Set, Filename: OiISea rch_Stirrup_1_Run_1 E_XLROCK_Correlati on Log.las ED C 33097 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 E_5in_XLROCK_20F eb20. Pdf ED C 33097 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 E_XLROCK_Coring Station Log.dlis ED C 33097 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1_Run_1 E_XLROCK_Correlati on Log.dlis ED C 33098 Digital Data 4818 284 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_2A_USIT- CBL Main Pass.las ED C 33098 Digital Data 4819 4464 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_2A_USIT- CBL_Repeat_Pass.las AOGCC Page 20 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33098 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2A_USIT-CBL_Main Pass.dlis ED C 33098 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2A_USIT- CBL_Repeat_Pass.dlis ED C 33098 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2A_5in_CBL_26Feb20 .Pdf ED C 33098 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2A_5in_USIT_26Feb2 0. Pdf ED C 33098 Digital Data 5/14/2020 Electronic File: Oil Sea rch_Stirrup_1_Run_2A_Cement_Evaluatio n_Log.pdf ED C 33098 Digital Data 5/14/2020 Electronic File: OiISea rch_Stirrup_1 _Run_2A_Cement_Eval_Rep ort.pdf ED C 33099 Digital Data 4516 4128 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Confir mation Pass.las ED C 33099 Digital Data 504 4558 5/14/2020 Electronic Data Set, Filename: Oi ISearch_Sti rrup_1 _Ru n_2D_HSD_CCL_Log_D own.las ED C 33099 Digital Data 4157 262 5/14/2020 Electronic Data Set, Filename: OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Shooti ng_Pass.las ED C 33099 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2D_4.5in_HSD_26Feb 20.Pdf ED C 33099 Digital Data 5/14/2020 Electronic File: Oi ISearch_Sti rrup_1 _Run_2D_5in_CCL_26Feb20 .Pdf ED C 33099 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Confir mation Pass.dlis ED C 33099 Digital Data 5/14/2020 Electronic File: Oi ISearch_Sti rrup_1 _Run_2D_HSD_CCL_Log_D own.dlis AOGCC Page 21 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED C 33099 Digital Data 5/14/2020 Electronic File: OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Shooti ng_Pass.dlis ED C 33100 Digital Data 5/14/2020 Electronic File: Stirrup 1 Final Well Test Field Report.xlsx ED C 33100 Digital Data 5/14/2020 Electronic File: Stirrup1 Final Report.pdf ED C 33100 Digital Data 8/4/2020 Electronic File: Stirrup 1 PVT.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 CEC by Conductometric Titration Final 6-10-20.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 HPMI Data1.05-27- 20.xlsm ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 HPMI Data2.05-27- 20.xlsm ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 HPMI Data3.05-27- 20.xlsm ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 HPMI Qv Corrected Data1.06-10-20.xlsm ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 HPMI Qv Corrected Data2.06-10-20.xlsm ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 HPMI Qv Corrected Data3.06-10-20.xlsm ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 NMR As Received Data Summary (SS Rel-K samples).xls ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup (5) Kw 27-Jul- 2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup 1 Centrifuge A-B Pc 7-24-2020.xls ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup Compiled Raw Data 06-July-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup Compiled Raw Data 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup Post -Test SS Rel-K RCA 24-Jul-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 014S 06-July-2020.xlsx AOGCC Page 22 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 044S 24-July-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 044S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 077S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 161S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 189S 24-July-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 189S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKo 223S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKoKwKo Summary 06-July-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KgKoKwKo Summary 24-July-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KwKo 077S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KwKo 161S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KwKo 223S 26-Aug-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KwKo Final with 1 Bump 044S 24-July-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup SS KwKo Final with 1 Bump 189S 24-Jul-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup-1 CoCw FF 27- Jul-2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup-1 NMRT1 Jul-31- 2020.xlsx ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup-1 NMRT2 Jul-31- 2020.xls ED DF 34152 Digital Data 10/30/2020 Electronic File: 2000980 Stirrup-1 RCA 29-Sep- 20.xlsx AOGCC Page 23 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/17/2020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 MD 4960 TVD 4960 Completion Date 4/1/2020 ED DF 34152 Digital Data ED DF 34152 Digital Data ED DF 34152 Digital Data ED DF 34152 Digital Data ED DF 34152 Digital Data ED DF 34152 Digital Data ED DF 34152 Digital Data ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF ED DF AOGCC 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data 34152 Digital Data Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 Completion Status P&A Page 24 of 27 Current Status P&A UIC No 10/30/2020 Electronic File: 2000980 Stirrup-1 Tracer RCAL 12-Aug-2020.xlsx 10/30/2020 Electronic File: 2000980GXRD Oil Search Alaska Stirrup-1.xlsx 10/30/2020 Electronic File: 2001530 Stirrup #1 RSWC RCAL 29-Jul-2020.xlsx 10/30/2020 Electronic File: 202000980_SCAL_EP & NMR Set_6.30.2020.xlsx 10/30/2020 Electronic File: 202000980 SCAL Pc Set 6.30.2020.xlsx 10/30/2020 Electronic File: 202000980_Stirrup_SCAL-RCA SS Set 7-9-2020.xlsx 10/30/2020 Electronic File: XRD Results - 200153OG Oil Search (Alaska)_Stirrup #1 RSWC.xls 10/30/2020 Electronic File: 3577.6-3626.8.jpg 10/30/2020 Electronic File: 3629.4-3674.9.jpg 10/30/2020 Electronic File: 3679.6-3717.2.jpg 10/30/2020 Electronic File: 3721.6-3853.0.jpg 10/30/2020 Electronic File: 3913.3-3959.0.jpg 10/30/2020 Electronic File: 4218.0-4236.0_c1.jpg 10/30/2020 Electronic File: 4236.0-4254.0.jpg 10/30/2020 Electronic File: 4254.0-4272.0.jpg 10/30/2020 Electronic File: 4272.0-4290.0.jpg 10/30/2020 Electronic File: 4290.0-4308.0.jpg 10/30/2020 Electronic File: 4308.0-4326.0.jpg 10/30/2020 Electronic File: 4326.0-4344.0.jpg 10/30/2020 Electronic File: 4344.0-4362.0.jpg 10/30/2020 Electronic File: 4362.0-4380.0.jpg 10/30/2020 Electronic File: 4380.0-4398.0.jpg 10/30/2020 Electronic File: 4398.0-4398.5.jpg 10/30/2020 Electronic File: 4398.5-4416.0_c2.jpg 10/30/2020 Electronic File: 4416.0-4434.0.jpg Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED DF 34152 Digital Data 10/30/2020 Electronic File: 4434.0-4452.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4452.0-4470.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4470.0-4488.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4488.0-4506.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4506.0-4524.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4524.0-4542.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4542.0-4560.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4560.0-4578.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4578.0-4578.5.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4578.5-4595.0_c3.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4595.0-4613.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4613.0-4631.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4631.0-4649.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4649.0-4667.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4667.0-4685.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4685.0-4703.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4703.0-4721.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4721.0-4739.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4739.0-4757.0.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4757.0-4758.9.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4218.0-4236.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4236.0-4254.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4254.0-4272.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4272.0-4290.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4290.0-4308.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4308.0-4326.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4326.0-4344.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4344.0-4362.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4362.0-4380.0uv.jpg AOGCC Page 25 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC API No. 50-103-20809-00-00 MD 4960 TVD 4960 Completion Date 4/1/2020 Completion Status P&A Current Status P&A UIC No ED DF 34152 Digital Data 10/30/2020 Electronic File: 4380.0-4398.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4398.0-4398.5uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4398.5-4416.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4416.0-4434.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4434.0-4452.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4452.0-4470.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4470.0-4488.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4488.0-4506.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4506.0-4524.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4524.0-4542.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4542.0-4560.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4560.0-4578.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4578.0-4578.5uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4578.5-4595.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4595.0-4613.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4613.0-4631.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4631.0-4649.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4649.0-4667.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4667.0-4685.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4685.0-4703.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4703.0-4721.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4721.0-4739.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4739.0-4757.0uv.jpg ED DF 34152 Digital Data 10/30/2020 Electronic File: 4757.0-4758.9uv.jpg Well Cores/Samples Information: Sample Interval Total Set Name Start Stop Boxes Received Number Comments Cuttings 114 4960 7 3/11/2020 1736 Core Chips 4218 4759 5 3/16/2020 1738 AOGCC Page 26 of 27 Thursday, December 17, 2020 DATA SUBMITTAL COMPLIANCE REPORT 12/1712020 Permit to Drill 2191530 Well Name/No. STIRRUP 1 Operator Oil Search (Alaska), LLC MD 4960 TVD 4960 Completion Date 4/1/2020 Conventional Core ./ Core Chips ✓Routine Core Analysis V Core Photos V Core Description V Special Core Analysis Completion Status P&A Current Status P&A Sidewalall Core: Routine Core Analysis Core Description JCore Photos API No. 50-103-20809-00-00 UIC No INFORMATION RECEIVED Completion Report D Directional / Inclination Data OY Mud Logs, Image Files, Digital Datd / NA Core Chips (DNA Production Test Information ( NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files YO Core Photographs ( NA Geologic Markers/Tops O Daily Operations Summary D Cuttings Samples 0 NA Laboratory Analyses 0 NA COMPLIANCE HISTORY Completion Date: 4/1/2020 Release Date: 5/1/2022 Description Comments: Compliance Reviewed By: M. Guhl Date Comments Date: 1 /7/2021 AOGCC Page 27 of 27 Thursday, December 17, 2020 PTD: 2191530 LETTER OF TRANSMITTAL Oil Search DATE: 1/7/2021 To: From: Meredith Guhl Shannon Koh AOGCC Oil Search Alaska LLC 333 W. 7th Avenue, Suite 100 P.O. Box 240927 Anchorage, AK 99501 Anchorage, AK 99524-0927 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑X External Request ❑CD ❑Thumb Drive ❑Internal Request DEmail ❑SharePoint ❑Hardcopy ❑Other REASON FOR TRANSMITTAL: ❑To Be Returned ❑❑ Approved Information Only [-]With Our Comments ❑Approved with Comments [--]For Your Review 0 Required pursuant to 20 AAC 25.071 ❑ For Approval ❑ For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION Stirrup 1 (50-103-20809-0000) Resubmission with corrected las2 format: 1 file STIRRUP_1_LithologicalData_ASCI I_depth_4960ft_17Feb2020_Final Received by the AOGCC 01/07/2021 Received by: Abby Bell Date: 01 /07/2021 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 PTD: 2191530 E-Set: 33092 LETTER OF TRANSMITTAL (Al Oil Search DATE: 12/22/2020 To: From: Meredith Guhl Shannon Koh AOGCC Oil Search Alaska LLC 333 W. 7th Avenue, Suite 100 P.O. Box 240927 Anchorage, AK 99501 Anchorage, AK 99524-0927 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑X External Request ❑CD ❑Thumb Drive ❑Internal Request ❑XEmail ❑SharePoint ❑Hardcopy ❑Other REASON FOR TRANSMITTAL: ❑To Be Returned ❑❑ Approved Information Only [-]With Our Comments ❑Approved with Comments [--]For Your Review ❑X Required pursuant to 20 AAC 25.071 ❑ For Approval ❑ For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION Stirrup 1 (50-103-20809-0000) Resubmission with corrected last format: 1 file Stirrup-1_Mudlog Received by the AOGCC 12/22/2020 Received by: Abby Bell Date: 12/24/2020 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 PTD: 2191530 LETTER OF TRANSMITTAL 0 Oil Search DATE: 12/11/2020 To: From: Meredith Guhl Shannon Koh AOGCC Oil Search Alaska LLC 333 W. 7th Avenue, Suite 100 P.O. Box 240927 Anchorage, AK 99501 Anchorage, AK 99524-0927 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑X External Request ❑CD ❑Thumb Drive ❑Internal Request ❑Email ❑SharePoint ❑Hardcopy ❑X Other - FTP REASON FOR TRANSMITTAL: ❑To Be Returned ❑❑ Approved Information Only [-]With Our Comments ❑Approved with Comments [--]For Your Review ❑X Required pursuant to 20 AAC 25.071 ❑ For Approval ❑ For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION Stirrup 1 (50-103-20809-0000) 5 files Centrifuge 2000980 Stirrup (179S) centrifuge A-B Pc 11-30-2020.xls 2000980 Stirrup -1 (4) Centrifuge A-B Pc 10-27-2020.xls Electrical Properties 2000980 Stirrup-1 CoCw FFRI 27-Oct-2020.xlsx NMR 2000980 Stirrup-1 NMRT1 100% Sw & Swi 29-Oct-2020.xlsx 2000980 Stirrup-1 NMRT2 100% Sw & Swi 29-Oct-2020.xls Received by: Abby Bell Date: 12/14/2020 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 Received by the AOGCC 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: Stirrup 1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Stirrup 1 well program, has completed its 2019-2020 drilling season. OSA has submitted required data under separate cover, pursuant to Lease and regulatory requirements. Some of the information required is still being processed and will not be ready for submittal in the timeframe required. We have provided a list of this additional data on the following page. OSA respectfully requests an extension of the submittal requirements for 90 days. OSA will submit the additional data required no later than February 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 Stirrup 1 50-103-20809-0000 NMR T1/T2 measurements, Saturation exponent, and Air- Brine centrifuge Pc. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg a ��Nz DATE: 8/25/2020 P. I. Supervisor (I FROM: Austin McLeod SUBJECT: Location Inspection Petroleum Inspector Stirrup 1 Oil Search (Alaska) LLC PTD 2191530 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 Stirrup-1 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 Stirup-1 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 _Stirrup- 1 _am. docx Page 1 of 2 Location Clearance — Stirrup 1 (PTD 2091530) Photos by AOGCC Inspector A. McLeod 8/25/2020 Stirrup 1 2020-0825_Location_Clear_Stirrup-1 _am.docx Page 2 of 2 PTD: 2191530 E-Set: 33100 LETTER OF TRANSMITTAL Oil Search DATE: 8/4/2020 To: From: Meredith Guhl Shannon Koh AOGCC Oil Search Alaska LLC 333 W. 7th Avenue, Suite 100 P.O. Box 240927 Anchorage, AK 99501 Anchorage, AK 99524-0927 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑X External Request ❑CD ❑ Thumb Drive ❑Internal Request ❑Email ❑SharePoint ❑ Hardcopy ❑X Other - FTP REASON FOR TRANSMITTAL: ❑To Be Returned ❑Approved [:]Information Only ❑Approved with Comments ❑ For Your Review ❑ With Our Comments ❑X Required pursuant to 20 AAC 25.071 ❑ For Approval ❑ For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION 1 Excel spreadsheet Stirrup 1 (50-103-20809-0000) - Stirrup 1 PVT Received by the AOGCC 08/04/2020 Received by: Abby Bell Date: 08/04/2020 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 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: Stirrup 1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Stirrup 1 well program, has completed its 2019-2020 drilling season. OSA has submitted required data under separate cover, pursuant to Lease and regulatory requirements. Some of the information required is still being processed and will not be ready for submittal in the timeframe required. We have provided a list of this additional data on the following page. OSA respectfully requests an extension of the submittal requirements for 90 days. OSA will submit the additional data required no later than November 1, 2020. If you have any questions regarding this request, please do not hesitate to contact us. Sincerely, Chris Colbert Exploration Petrophysicist 2 Well Name Well API # Description of Data Stirrup 1 50-103-20809-0000 Conventional Core Laboratory Studies- Porosity & Permeability – Core Lab – estimated November 2020 Stirrup 1 50-103-20809-0000 SCAL Program for whole core plugs- estimated November 2020 From: Williams. Rob To: Schwartz, Guy L (CED) Cc: Tiroack. Robert; Davis. Rachel Subject: RE: Stirrup 1 10-407 (PTO 219-153) Date: Thursday, June 25, 2020 9:41:40 AM Morning Guy, Good observation on the surface job. The numbers in the cementing spreadsheet are correct. The cement volumes are based on the weigh -back cement numbers that Halliburton took when receiving the excess cement back into the plant. The discrepancy between the daily reports and the numbers in the spreadsheet was due to incorrect reporting on the DDR. I clarified with the drilling supervisor that was on Stirrup after the cement job that he had 357bbis of lead pumped in his tally book rather than the 457bbls that was initially reported. The miss here is that I didn't update the daily reports in our WellView reporting software. This does mean that based on the records pumped and returned that we did have near gauge surface hole. Remember that we drilled surface hole with a rotary steerable rather than a bent motor and base permafrost was only 684' on Stirrup. We also experienced a number of pack off events coming out of the hole so I do think we had something close to gauge hole. The cement returns we estimated were just that an estimate; once we got cement back to surface we took returns to the cellar which was then sucked out using super suckers. For this reason, the return volume estimate is not as accurate is it would be as if we took it back to a dedicated pit or tank. Here's the numbers from the Halliburton post -job report. Let me know if you would like to discuss, I am around today and available on 907 830 2209. -.I 1nh \ctwlr Fluid Target Volume Actual Volume Average Density Target Densih Average Rate bMs (bbl,) ( ) ( ) (b m) 10:5#Cleans aver 6n 62 10.7 IU 3.b 1.0# [-end Cement 351A 10,9 11.0 5.0 15.8# Tail Cement 47.77 44.5 1 15.8 15.8 2.1 • Lead cemm.l volume based on weigb-back or semm.t and aysrage &k to of I 1 ppg. 744 ska were brought back tg the 14LL l ilay. so 756 A. were pumped dounhole. - Awaits Open ilolc Ewess Cakulalion Volume of Cement pumped: 351 A bbl lead cement + 44.5 bbl tail cemrot = 395.9_W Open Hole Length. 2694 (t - 120 0 conductor = 2574 It Conductor Anualus volume: 120 II.0.1286 hbu11= j14 b¢j Gauge Open Hole volume 2574 It - 0.0558 bbL'0 = 143,6 b61 V'olunm Pumped Ic0 in Open Hok: 395.9 hbl - 244 bbl ytmM returns - 15.4 bbl eon&oor annulus volume = O S bbl Aecrege Open Hole rxcess: 136.5 ISM V 143.6 bbl- 0.45 Open hot. volume wn lust under 2-it, a ee —ralle ROB WILLIAMS I SENIOR DRILLING ENGINEER I OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 1 Mob: +1 907 830 2209 Email: rob wi11 arns(rpoilsearch cQm I web: www.oilsearch.com From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Monday, June 22, 2020 1:20 PM To: Williams, Rob <Rob.Williams@oilsearch.com> Cc: Tirpack, Robert <Robert.Tirpack@oilsearch.com> Subject: [EXTERNAL] RE: Stirrup 1 10-407 (PTD 219-153) It is a little unusual to get a that much cement (244 bbls) back for surface hole in the arctic. That means you had a gauge hole in permafrost if the volumes are correct on spreadsheet. 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 ((,uvaschwartzCdalaska.aav). From: Schwartz, Guy L (CED) Sent: Monday, June 22, 2020 12:35 PM To: Williams, Rob <rob.williams(@oilsearch.com> Subject: Stirrup 1 10-407 (PTD 219-153) Rob, The daily reports and the cementing summary don't agree on the volume of cement pumped on the surface casing (9 5/8") Can you clarify the correct volumes. Also were 244 bbls of cement recovered? Is spreadsheet correct? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4S33 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.schwartz4olaska.aov). 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 *#***###**#*#*************#*#****###########*#**********#**********#*##############****#******#*#*##******#**** State of Alaska RECEIVED CONFIDENTIAL By Meredith Guhl at 9:35 am, May 14, 2020 LETTER OF TRANSMITTAL na Conrrh PTD: 2191530 E-Set: 00111:101SPO 1111 DATE: 5/14/2020 To: From: Meredith Guhl Shannon Koh AOGCC Oil Search Alaska LLC 333 W. 7th Avenue, Suite 100 P.O. Box 240927 Anchorage, AK 99501 Anchorage, AK 99524-0927 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑X External Request ❑CD © Thumb Drive ❑Internal Request ❑Email ❑SharePoint ❑Hardcopy ❑Other REASON FOR TRANSMITTAL: ❑To Be Returned ❑❑ Approved Information Only ❑With Our Comments ❑Approved with Comments El For Your Review 0Required pursuant to 20 AAC 25.071 ❑ For Approval ❑ For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION Stirrup 1 (50-103-20809-0000) Detail listing on following pages Received by: Abby Bell Please sign and return one copy to: Date: 05/18/2020 Oil Search Alaska ATTN:Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh(@oilsearch.com LETTER OF TRANSMITTAL Analyses T33089 Core Plug Extract HRGC ROSL-200301-001 Stirrup1.xls ROSL-200301-002 Stirrup1.xls ROSL-200301-003 Stirrup1.xls ROSL-200301-004 Stirrup1.xls ROSL-200301-005 Stirrup1.xls ROSL-200301-006 Stirrup1.xls —Flash Gas Job44675.xls Mud Gas Job44373_Stirrup-1.xls Oil Samples - Gas Chromatogram ROSL-200401-001 Stirrup 1 4-1-20 4326.35ft AS0459.xls —PVT Stirrup 1 PVT validation final report.xlsx SWC Extract HRGC ROSL-200201-001 Stirrup #1 6 3,606.40ft XAS0006.xIs ROSL-200201-002 Stirrup #1 16 3,647.10ft XAS0007.xls ROSL-200201-003 Stirrup #1 18 3,654.20ft XAS0008.xls ROSL-200201-004 Stirrup #1 23 3,682.40ft XAS0009.xls ROSL-200201-005 Stirrup #1 28 3,702.50ft XAS0010.xls ROSL-200201-006 Stirrup #1 38 3,829.60ft XAS0011.xls ROSL-200201-007 Stirrup #1 43 3,909.40ft XAS0012.xls —Core Data T33090 Conventional Cores Core Inventory Stirrup 1 Conventional Core Inventory.xlsx —Core Photos 4218.0-4236.Ouv.jpg QD Oil Search LETTER OF TRANSMITTAL 4218.0-4236.0_d ry. j pg 4218.0-4236.0_c 1. j pg 4236.0-4254.0.jpg 4236.0-4254.Ouv.jpg 4236.0-4254.0_d ry. j pg 4254.0-4272.0.jpg 4254.0-4272.Ouv.jpg 4254.0-4272.0_d ry. j pg 4272.0-4290.0.jpg 4272.0-4290.Ouv.jpg 4272.0-4290.0_d ry. j pg 4290.0-4308.0.jpg 4290.0-4308.Ouv.jpg 4290.0-4308.0_d ry. j pg 4308.0-4326.0.jpg 4308.0-4326.Ouv.jpg 4308.0-4326.0_d ry. j pg 4326.0-4344.0.jpg 4326.0-4344.Ouv.jpg 4326.0-4344.0_d ry. j pg 4344.0-4362.0.j pg 4344.0-4362.0uv.jpg 4344.0-4362.0_d ry. j pg 4362.0-4380.0.jpg 4362.0-4380.Ouv.jpg 4362.0-4380.0_d ry. j pg 4380.0-4398.0.jpg 4380.0-4398.Ouv.jpg 4380.0-4398.0_d ry. j pg 4398.0-4398.5.jpg 4398.0-4398.5uv.jpg 4398.0-4398.5_d ry. j pg 4398.5-4416.Ouv.jpg 4398.5-4416.0_c2.j pg 4416.0-4434.0.j pg 4416.0-4434.Ouv. j pg 4434.0-4452.0.jpg (P Oil Search LETTER OF TRANSMITTAL 4434.0-4452.Ouv.jpg 4452.0-4470.0.jpg 4452.0-4470.Ouv.jpg 4470.0-4488.0.jpg 4470.0-4488.Ouv.j pg 4488.0-4506.0.jpg 4488.0-4506.Ouv.jpg 4506.0-4524.0.jpg 4506.0-4524.Ouv. j pg 4524.0-4542.0.j pg 4524.0-4542.Ouv. j pg 4542.0-4560.0.jpg 4542.0-4560.Ouv.jpg 4560.0-4578.0.jpg 4560.0-4578.Ouv.jpg 4578.0-4578.5.jpg 4578.0-4578.5uv.jpg 4578.5-4595.Ouv.jpg 4578.5-4595.0_c3. j pg 4595.0-4613.0.jpg 4595.0-4613.Ouv.jpg 4613.0-4631.0.j pg 4613.0-4631.Ouv.jpg 4631.0-4649.0.jpg 4631.0-4649.Ouv.jpg 4649.0-4667.0.jpg 4649.0-4667.Ouv.jpg 4667.0-4685.0.jpg 4667.0-4685.Ouv.jpg 4685.0-4703.0.jpg 4685.0-4703.Ouv.jpg 4703.0-4721.0.jpg 4703.0-4721.Ouv.jpg 4721.0-4739.0.jpg 4721.0-4739.Ouv.jpg 4739.0-4757.0.jpg 4739.0-4757.Ouv.jpg (P Oil Search LETTER OF TRANSMITTAL 4757.0-4758.9.jpg 4757.0-4758.9uv.jpg Core Reports Alaska Field Coring Report #1 Stirrup-1.pdf Alaska Field Coring Report #2 Stirrup-1.pdf Alaska Field Coring Report #3 Stirrup-1.pdf SWC Stirrup_1_Run_1 E_5in_XLROCK_SWC.xlsx Directional Survey 3H Stirrup 1 ASP NAD27 Final Survey.pdf 3H Stirrup 1 ASP NAD83 Final Survey.pdf OilSearch_Stirrup_1_ASP Final Survey - NAD27.xlsx 0ilSearch_Stirrup_1_ASP Final Survey - NAD83.xlsx iExtension Request Letter Stirrup 1_Request for Extension - Data Submittal.pdf Geology T33092 Final Well Report OilSearch_Stirrup_1_Final Well_Report.pdf iGeological Reports Stirrup 1 Compiled DGRs.pdf �Mudlogging Final Data 0ilSearch_Stirrup_1_DailyMud log Rpts.pdf 0ilSearch_Stirrup_1 _DrillGas_depth _4960ft_17Feb2020.las OilSearch_Stirrup_1_DrillGas time_Jan27th to Feb18th 2020.zip OilSearch_Stirrup_1 _Drilling Log _4960ft_17Feb2020_Final.pdf 0iISea rch_Stirrup_1 —Gas Ratio Log_4960ft_17Feb2020_Final.pdf 0ilSearch_Stirrup_1_GasRpt_17Feb2020.xls 0ilSearch_Stirrup_1_MasterLog5in_4960ft_17Feb2020_Final.pdf 0iISea rch_Stirrup_1 _MasterLogTVD_4960ft_17Feb2020_Final. pdf OilSearch_Stirrup_1_MasterLog_4960ft_17Feb2020_Final.pdf (P Oil Search LETTER OF TRANSMITTAL OilSearch_Stirru p_1_PressureLog_4960ft_17Feb2020_Final. pdf OilSearch_Stirrup_1_Sam ple_Inventory.pdf OilSearch_Stirrup_1_Sam ple_Inventory.xlsx —Oil, Gas and Gas Hydrate Shows List OilSearch_Stirrup_1_Show Reports.pdf Well Prognosis Stirrup-1 Prognosis.pdf Log Digital Data and Plots (LWD and WL) T33091 LWD iDigital Data Drilling Mechanics Depth Data OilSearch_Stirrup_1_DMD_R1-3_4960ft.las Time Data OilSearch_Stirrup_1 _DMT_R01.las OilSearch_Stirrup_1 _DMT_R02.las OilSearch_Stirrup_1 _DMT_R03.las i —LWD Real Time Data OilSearch_Stirrup_1 _LW D_R1-3_4960ft.las LWD Recorded Mode Data V) Oil Search OilSearch_Stirrup-1 _R1 _12.25in_SonicVision825_Drill_DTCO_100ft-2614ft.dlis OilSearch_Stirrup-1 _R1 _12.25in_SonicVision825_Drill_DTCO_100ft-2614ft.las OilSearch_Stirrup_1 _LW D_R1-3_4960ft.las OilSearch_Stirrup_1 _LW D_RM_4960ft.dlis OilSearch_Stirrup_1_LW D_RM_4960ft.html 0iISea rch_Stirrup_1 _R2_8.5in_SonicScope675_Drill_DTCO_2605ft-4140ft.dIis 0iISea rch_Stirrup_1 _R2_8.5in_SonicScope675_Drill_DTCO_2605ft-4140ft.Ias 0iISea rch_Stirrup_1_R3_8.5in_SonicScope675_Drill_Ream_DTCO_4040ft 4880ft.dIis 0iISea rch_Stirru p_1 _R3_8.5in_SonicScope675_Drill_Ream_DTCO_4040ft_4880ft.1 as Plots V) LETTER OF TRANSMITTAL Oil Search Drilling Mechanics Depth Data OilSearch_Stirrup_1_DMD_R1-3_4960ft.Pdf Time Data 0ilSearch_Stirrup_1 _DMT_R01. Pdf OilSearch_Stirrup_1_DMT_R02.Pdf OilSearch_Stirrup_1_DMT_R03.Pdf LWD Logs OilSearch_Stirrup-1 _R1 _12.25in_SonicVision825_Drill_DTCO_100ft-2614ft. pdf 0iISea rch_Stirrup_1 _R2_8.5in_SonicScope675_Drill_DTCO_2605ft-4140ft. pdf 0iISea rch_Stirrup_1 _R3_8.5in_SonicScope675_Drill_Ream_DTCO_4040ft_4880ft. pdf OilSearch_Stirrup_1_VISION_SERVICE_2MD.pdf OilSearch_Stirrup_1_VISION_SERVICE_2TVD.pdf OilSearch_Stirrup_1_VISION_SERVICE_5MD.pdf OilSearch_Stirrup_1_VISION_SERVICE_5TVD.pdf Wireline Digital Data LWD iDLIS Data OilSearch_Stirrup_1 _LW D_RM_4960ft.dlis OilSearch_Stirrup_1_LW D_RM_4960ft.html LAS Data Drilling Mechanics Depth Data OilSearch_Stirrup_1 _DMD_R1-3_4960ft.las I I Time Data OilSearch_Stirrup_1 _DMT_R01.las OilSearch_Stirrup_l _DMT_R02.las OilSearch_Stirrup_1 _DMT_R03.las I LWD Real Time Data OilSearch_Stirrup_1 _LWD_R1-3_4960ft.las (8) LETTER OF TRANSMITTAL Oil Search LWD Recorded Mode Data Oil Sea rch_Stirru p_1 _LW D_R1-3_4960ft.las WL T33093 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1C_Sta003_XPT.las V) Oil Search LETTER OF TRANSMITTAL OilSearch_Stirrup 1_Run 1C_Sta004_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta005_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta006_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta007_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta008_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta009_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta010_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta011_XPT.las OilSearch_Stirrup 1-Run 1C_Sta012_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta013_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta014_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta015_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta016_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta017_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta018_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta019_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta020_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta021_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta022_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta023_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta024_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta025_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta026_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta027_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta028_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta029_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta030_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta031_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta032_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta033_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta034_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta035_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta036_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta037_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta038_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta039_XPT.Ias OilSearch_Stirrup 1-Run 1C_Sta040_XPT.Ias V) Oil Search LETTER OF TRANSMITTAL OilSearch_Stirrup 1_Run 1C_Sta041_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta042_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta043_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta044_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta045_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta046_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta047_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta048_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta049_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta050_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta051_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta052_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta053_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta054_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta055_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta056_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta057_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta058_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta059_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta060_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta061_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta062_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta063_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta064_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta065_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta066_XPT.Ias OilSearch_Stirrup 1_Run 1C_Sta067_XPT.Ias OilSearch_Stirrup 1_Run 1C_XPT_Correlation Pass 1.1as OilSearch_Stirrup 1_Run 1C_XPT_Correlation Pass 2.1as OilSearch_Stirrup 1_Run 1C_XPT_Correlation Pass 3.1as Stirrup_1_Run_1 D_ORA T33096 OilSearch_Stirrup 1_Run 1 D_Correlation Pass_ORA.dlis OilSearch_Stirrup 1_Run 1 D_Correlation Pass_ORA.Ias OilSearch_Stirrup 1_Run 1 D_Sta001_ORA.dlis OilSearch_Stirrup 1_Run 1 D_Sta001_ORA.Ias OilSearch_Stirrup 1_Run 1 D_Sta002_ORA.dlis V) Oil Search LETTER OF TRANSMITTAL OilSearch_Stirrup 1_Run 1 D_Sta002_ORA.las OilSearch_Stirrup 1_Run 1 D_Sta003_ORA.dlis OilSearch_Stirrup 1_Run 1 D_Sta003_ORA.las —Stirrup_1_Run_1 E_ XLROCK T33097 OilSearch_Stirrup_1_Run_1E_XLROCK_Coring Station Log.dlis OilSearch_Stirrup_1_Run_1 E_XLROCK_Coring_Station Log.las OilSearch_Stirrup_1_Run_1 E_XLROCK_Correlation Log.dlis OilSearch_Stirrup_1_Run_1E_XLROCK_Correlation Log.las �Stirrup_1_Run_2A_USIT_CBL T33098 OilSearch_Stirrup_1_Run_2A_USIT-CBL_Main Pass.dlis OilSearch_Stirrup_1_Run_2A USIT-CBL_Main_Pass.las OilSearch_Stirrup_1_Run_2A USIT-CBL_Repeat_Pass.dlis OilSearch_Stirrup_1_Run_2A USIT-CBL_Repeat_Pass.las Stirrup_1_Run_2D_HSD_CCL T33099 OilSearch_Stirrup_1_Run_2D_HSD_CCL_Confirmation_Pass.dlis OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Confirmation_Pass.las OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Log_Down.dlis OilSearch_Stirrup_1 _Run_2D_HSD_CCL_Log_Down.las OilSearch_Stirrup_1_Run_2D_HSD_CCL_Shooting_Pass.dlis OilSearch_Stirrup_1_Run_2D_HSD_CCL_Shooting_Pass.las Plots —OilSearch_Stirrup_1_Run_2A USIT-CBL OilSearch_Stirrup_1_Run_2A_5in_CBL_26Feb20.Pdf OilSearch_Stirrup_1_Run_2A_5in_USIT_26Feb20.Pdf OilSearch_Stirrup_1_Run_2A Cement_Evaluation_Log.pdf OilSearch_Stirrup_1_Run_2A_Cement Eval_Report.pdf —OilSearch_Stirru p_1 _Run_2D_HSD_CCL OilSearch_Stirrup_1_Run_2D_4.5in_HSD_26Feb20.Pdf OilSearch_Stirrup_1_Run_2D_5in_CCL_26Feb20.Pdf Stirrup_1_Run_1A NGI-MAST-ZAIT 0iISea rch_Stirrup1_QGEO_lnterpretation_5in_2705_4875 ftMD.pdf V) Oil Search LETTER OF TRANSMITTAL V) Oil Search OilSearch_Stirrup1_QGEO_Interpretation_60in_2705_4875 ftMD.pdf OilSearch_Stirrup1_QGEO_Sand_Counting_20in_3420_4874 ftMD.pdf OilSearch_Stirrup1_QGEO_Sand_Counting_5in_3420_4874 ftMD.pdf OilSearch_Stirrup1_QGEO_Sand_Counting_60in_3420_4874 ftMD.pdf OilSearch_Stirrup_1 Run 1A Caliper_5in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1A MAST_2in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1A MAST_5in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1A NGI_20in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1A NGI_60in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1A ZAIT_2in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1A ZAIT_5in_18Feb20.Pdf OilSearch_Stirrup_1_Run_1A 8.5in_SScan_PnS ANI_2558-4894ft.pdf OilSearch_Stirrup_1_Run_1A LSA 2479-4952ft.pdf OilSearch_Stirrup_1_Run_1A_RTScanner 1 D_Inversion_2700-4943ft.pdf -Stirrup_1_Run_1 B_NEXT-PEX-HNGS-CMR OilSearch_Stirrup_1_Run1 B_CMR_2in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1 B_CMR_5in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1B_HNGS_2in_18Feb20.Pdf OilSearch_Stirrup_1_Run1B_HNGS_5in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1 B_NEXT_2in_18Feb20.Pdf OilSearch_Stirrup_1 Run 1 B_NEXT_5in_18Feb20.Pdf OilSearch_Stirrup_1 _Run 1 B_PEX_2in_18Feb20.Pdf OilSearch_Stirrup_1 Run 1 B_PEX_5in_18Feb20.Pdf OilSearch_Stirrup_1_Run_1 B_CMR_2700-4891ft.pdf OilSearch_Stirrup_1_Run_1B_LithoScanner RBF_CEC_2700-4940ft.pdf OilSearch_Stirrup_1_Run_1 B_LithoScanner SPEC_TOC_2700-494Oft.pdf Stirrup_1_Run_1 C_XPT OilSearch_Stirrup 1_Run 1C_5in_XPT_19Feb20.pdf OilSearch_Stirrup_1_Run_1C-1D_8.5in_XPT-ORA Report.pdf OilSearch_Stirrup_1_Run_1C_8.5in_XPT_PressureTimePlots.pdf Stirrup_1_Run_1 D_ORA OilSearch_Stirrup_1_Run_1D_5in_ORA_19Feb20.Pdf Stirrup_1_Run_1 E_ XLROCK LETTER OF TRANSMITTAL OilSearch_Stirrup_1_Run_1 E_5in_XLROCK_20Feb20.Pdf Well Testing T33100 Stirrup 1 Final Well Test Field Report.xlsx Stirrup1 Final Report.pdf QD Oil Search State of Alaska CONFIDENTIAL ALASKA STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED By Samantha Carlisle at 1:34 pm, May 19, 2020 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 0 ' Suspended❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory 0 GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Oil Search Alaska Aband.: 4/1/2020 ' 219-153 / 319-552 / 320-120 3. Address: 7. Date Spudded: 15. API Number: PO Box 240927 Anchorage, AK 99524-0927 1 /27/2020 50-103-20809-00-00 4a. Location of Well (Governmental Section): 3 DLB 8. Date TD Reached: 16. Well Name and Number: Surface: FNL 784.49', FEL 2173.11', Sec. 8, T8N, R8E, UM 2/17/2020 Stirrup 1 Top of Productive Interval: 9. Ref Elevations: KB: 53.8' 17. Field / Pool(s): FNL 784.68', FEL 2172.99', Sec. 8, T8N, R3E, UM ' GL: 34.4' BF: Undefined Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: FNL 786.28' FEL 2173.70', Sec. 8, T8N, R3E, UM P&A to Surface ADL 392044 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 320371.1869 y- 5876285.335 Zone- 4 ` 4960' MD / 4960' TVD LONS 19-006 TPI: x- 320371.307 y- 5876285.135 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 320370.5668 y- 5876283.555 Zone- 4 N/A 684' MD / 684' TVD 5. Directional or Inclination Survey: Yes 0 (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) N/A 22. Logs Obtained: 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, 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 Please see below the list of logs (full detailed list is attached) Mudlog (From 114ft to 4960ft MD) LWD Logs: GR/Res/Sonic (114ft to 4960ft MD) Wireline Logs: GR/SS/NGI/ZAIT, GR/CMR/HNGS/PEX/NEXT, Pressure Tests (XPT), Fluid Samples (ORA), Sidewall Cores (XLRock) CBL and USIT 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 84# X52 Surface 114' Surface 114' 20" Grouted to Surface 9-5/8" 40# L-80 Surface 2693' Surface 2693' 12-1/4" 756 sks ArcticCem 215 sks Class G 7" 26# L-80 Surface 4949' Surface 4949' 8-1/2" Stage 1: 43 sks Type 1 179 sks Class G Stage 2: 196 sks Type I 2 sks Class G 24. Open to production or injection? , Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 3-1/2" 9.2# L80 4266' MD 4240' MD / 4240' TVD Stirrup 1 was a vertical well completion that consisted of a perforated zone for stimulation. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Perforation zone: Top 4,325' MD/TVD - Bottom 4,345' MD/TVD. Perforation size and number: 4-1/2", 60 Degree Phasing, 6 SPF, 20 ft length, Was hydraulic fracturing used during completion? Yes p No ❑ Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED EH Diameter Avg 0.32 in. Abandonment Date Date Perforated: 02/26/2020. 4/1/2020 Please see attached report from Schlumberger Date Stimulation: 03/07/2020 HEW 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 3/8/2020 Gas Lift / Natural Flow Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas -Oil Ratio: 3/8/2020 Test Period 2584.8 1770 1110.72 58/64 685 31.5 Flow Tubing Casinq Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 539 1041 24-Hour Rate 11969.37 4-.M 1349 MDG 846.26 37.5 Sr Pet Eng 9 s Sr Pet GeoDLB 05/26/2020 1 Sr Res Eng G Form 10-407 Revised 3/2020 5/22/2020 Submit within 30 days of Completion, Suspension, or Abandonment RBDMS HEW CDW 5/27/2020 SFD 6/10/2020 28. CORE DATA Conventional Core(s): Yes 0 No ❑ Sidewall Cores: Yes 0 No ❑ 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. Conventional Cores taken from Nanushuk 0 from 4218' to 4758'. Sidewall Cores taken from Nanushuk 0 from 3913' - 3959'; Nanushuk 1 3910'; Nanushuk 2 3800' - 3853'; Nanushuk 3 3764'; Nanushuk 4 3697' - 3729'; Nanushuk 5 3666' - 3693'; Nanushuk 6 3578' - 3660' Please see attached core summaries / Core photos will be submitted with log data 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No ❑ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 684' 684' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 4315' 4315' information, including reports, per 20 AAC 25.071. Prince Creek 19, 19, Middle Schrader Bluff 864' 864' Lower Schrader Bluff 1304' 1304' Well Test Sumary is attached Tuluvak 1777' 1777' Full Well Test Report will be submitted with log data Seabee 2507' 2507' Top Nanushuk 3423' 3423' Nanushuk 6 3575' 3575' Nanushuk 5 3660' 3660' Nanushuk 4 3696' 3696' Nanushuk 3 3742' 3742' Nanushuk 2 3796' 3796' Nanushuk 1 3902' 3902' Nanushuk 0.5 4074' 4074' Nanushuk 0.5 4243' 4243' Nanushuk 0 base transgression 4314' 4314' Nanushuk Oa 4408' 4408' Torok 4751' 4751' Formation at total depth: Torok 1 4960' 1 4960' 31. List of Attachments: Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary Wellbore Schematic; Well Test Summary; Frac Report; Casing Cut Plate Photos 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 resultsper 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Rob Williams Contact Name: Rob Williams Authorized Title: Senior Drilling Engineer Contact Email: rob.williams@_oiLsearch.com Authorized ko-& 'kra a'nw. 04/30/2020 Contact Phone: 907-830-2209 Signature w/Date: 2020-Apr-30 19:13 INSTRUCTIONS General: 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. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. 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. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 312020 Submit within 30 days of Completion, Suspension, or Abandonment Superseded STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory 0 Service ❑ Stratigraphic Test ❑ 2. Operator Name: Oil Search Alaska 6. Date Comp., Susp., or Aband.: 4/1/2020 14. Permit to Drill Number / Sundry: 219-153 / 319-552 / 320-120 3. Address: PO Box 240927 Anchorage, AK 99524-0927 7. Date Spudded: 1/27/2020 15. API Number: 50-103-20809-00-00 4a. Location of Well (Governmental Section): Surface: FNL 784.49', FEL 2173.1 V, Sec. 8, T8N, R8E, UM Top of Productive Interval: FNL 784.68', FEL 2172.99', Sec. 8, T8N, R8E, UM Total Depth: FNL 786.28' FEL 2173.70', Sec. 8, T8N, R8E, UM 8. Date TD Reached: 2/17/2020 16. Well Name and Number: Stirrup 1 9. Ref Elevations: KB: 53.8' GL: 34.4' BF: 17. Field / Pool(s): Undefined 10. Plug Back Depth MD/TVD: P&A to Surface 18. Property Designation: ADL 392044 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 320371.1869 y- 5876285.335 Zone- 4 TPI: x- 320371.307 y- 5876285.135 Zone- 4 Total Depth: x- 320370.5668 y- 5876283.555 Zone- 4 11. Total Depth MD/TVD: 4960' MD / 4960' TVD 19. DNR Approval Number: LONS 19-006 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 684' MD / 684' TVD 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ Submit electronic information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: 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, 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 Please see attached list of logs. 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 84# X52 Surface 114' Surface 114' 20" Grouted to Surface 9-5/8" 40# L-80 Surface 2693' Surface 2693' 12-1/4" 756 sks ArcticCem 215 sks Class G 7" 26# L-80 Surface 4949' Surface 4949' 8-1/2" Stage 1: 43 sks Type I 179 sks Class G Stage 2: 196 sks Type I 2 sks Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Stirrup 1 was a vertical well completion that consisted of a perforated zone for stimulation. Perforation zone: Top 4,325' MD/TVD -Bottom 4,345' MD/TVD. Perforation size and number: 4-1/2", 60 Degree Phasing, 6 SPF, 20 ft length, EH Diameter Avg 0.32 in. Date Perforated: 02/26/2020. Date Stimulation: 03/07/2020 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 9.2# L80 4266' MD 4240' MD / 4240' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes 0 No El Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Please see attached report from Schlumberger 27. PRODUCTION TEST Date First Production: 3/8/2020 Method of Operation (Flowing, gas lift, etc.): Gas Lift / Natural Flow Date of Test: 3/8/2020 Hours Tested: Production for Test Period Oil-Bbl: 2584.8 Gas-MCF: 1770 Water-Bbl: 1110.72 Choke Size: 58/64 Gas -Oil Ratio: 685 31.5 Flow Tubing Press. 539 Casinq Press: 1041 Calculated 24-Hour Rate Oil-Bbl: 1969.37 Gas-MCF: 1.35 Water-Bbl: 846.26 Oil Gravity - API (corr): 37.5 Sr Pet Eng I Sr Pet Geo Sr Res Eng Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Superseded 28. CORE DATA Conventional Core(s): Yes 0 No ❑ Sidewall Cores: Yes 0 No ❑ 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. Please see attached core summary and photos Extension request submitted for description and lab analysis 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No ❑ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 684' 684' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 4315' 4315' information, including reports, per 20 AAC 25.071. Prince Creek 19, 19, Middle Schrader Bluff 864' 864' Lower Schrader Bluff 1304' 1304' Please see attached Well Test Summary Tuluvak 1777' 1777' Seabee 2507' 2507' Top Nanushuk 3423' 3423' Nanushuk 6 3575' 3575' Nanushuk 5 3660' 3660' Nanushuk 4 3696' 3696' Nanushuk 3 3742' 3742' Nanushuk 2 3796' 3796' Nanushuk 1 3902' 3902' Nanushuk 0.5 4074' 4074' Nanushuk 0.5 4243' 4243' Nanushuk 0 base transgression 4314' 4314' Nanushuk Oa 4408' 4408' Torok 4751' 4751' Formation at total depth: Torok 1 4960' 1 4960' 31. List of Attachments: Summary of Daily Operations; Casing & Cement Summaries; Definitive Surveys; Core Summary & Photos; Wellbore Schematic; Well Test Summary; Frac Report; Casing Cut Plate Photos 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 resultsper 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Rob Williams Contact Name: Rob Williams Authorized Title: Senior Drilling Engineer Contact Email: rob.williaims@o'ilsearch.com Authorized vb 04/30/2020 Contact Phone: 907-830-2209 Signature w/Date: 2020-Apr-30 07:41 INSTRUCTIONS General: 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. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Stirrup 1 0 Post -drill Well Schematic Oil Search Updated Feb. 27t" 2020 !t AM 2 170101 00 V L16" Conductor 11 4'MD/TVD 500 3-'/2". 2.813" Polish Bore `X' Landing Nipple - 403' MD/TVD 3-'/2" cable clamps: — t0ao Slot: 0.433" ('/4") Encap gauge line 3-1/2" 9.2# L80 Vam Top Tubing 2000 — Surface Casing 9-5/8" 40# L80 BTC 2693' MD/TVD 12 '/4" Hole 2,701' MD/TVD - -- - 250D o 0 0 ES -Cementer Stage Cement Tool 2829' MD/TVD L - a 3000 — 3500 — 4GOD - - 4500 saga Limestone clay Sand Fine Sandstone . Claystone Y Tuff Sandstone GLM, 3-t/2" 3977' MD/TVD 3-'/2" `X' Landing Nipple 4197' MD/TVD Tubing P/T Gauges 4210' & 4222' MD/TVD 3-'/2" x 7" PH Packer 4240' MD/TVD 3-'/2", 'XN' Landing Nipple 4257' MD/TVD WLEG 4265' MD/TVD End of Tubing 4266' MD/TVD Perforations 4325'-4345' MD/TVD Production Casing 7" 26# L80 Vam Top HC 4949' MD/TVD 81/2" Hole 4960' MD/TVD Stirrup 1 Post -drill Well Schematic ftMD 117WDt.OrY Actual P&A 500 16" Conductor 114' MD/TVD 0 Oil Search Updated Apr. 16t" 2020 3-1/2". 2.813" Polish Bore 'X' Landing Nipple 403' MD/TVD 3-1/2" cable clamps: Slot: 0.433" ('/4") Encap gauge line 3-'/2" 9.2# L80 Vam Top Tubing Cement Plug 2: 3585'-surface Surface Casing 9-5/8" 40# L80 BTC 2693' MD/TVD 12 1/4" Hole 2,701' MD/TVD ES -Cementer Stage Cement Tool 2829' MD/TVD ♦_Tubing Punch 3394 — 3404' MD/TVD (3375 - 3385' SLM) Cement Plug 1: —4235 - 3728' (507' plug) �-- GLM, 3-'/2" 3977' MD/TVD 3-'/2" 'X' Landing Nipple 4197' MD/TVD Tubing P/T Gauges 4210' & 4222' MD/TVD Tubing Punch 4235 - 4238' MD/TVD 3-'/2" x 7" PH Packer 4240' MD/TVD Standing Valve landed in 3-'/2", 'XN' Landing Nipple 4257' MD/TVD 10bbls cement squeezed into — 4500 Perforations 4325'-4345' MD/TVD Production Casing 7" 26# L80 Vam Top HC 5�4i} Limestone ■ clay Sand 4949' MD/TVD Fine Sandstone ■ Claystone Tuff 8'/2" Hole 4960' MD/TVD Sandstone General Core Summary Report Company: Oil Search Alaska Well: Stirrup 1 Confidential Field: Undefined Run 5: 1 E Toolstring: XLROCK Timestamps are in UTC-0000 Equipment: MSCT-F:MCEC-C File Code:MCEC-CA Serial Number:5001 Marker Number Core Number Descent Number Core Depth MD (FT) Drill Start Time Total Drilling Time (s) Marker Core Recovery Remarks Formation 3 2 1 3958.97 07:08:22 20-Feb-2020 245.57 Present Recovered Nanushuk0 4 3 1 3942.85 07:17:24 20-Feb-2020 211.90 Present Recovered Nanushuk 0 5 4 1 3938.97 07:27:10 20-Feb-2020 219.78 Present Recovered Nanushuk 0 6 5 1 3926.74 07:35:33 20-Feb-2020 201.09 Present Recovered Nanushuk 0 7 6 1 3923.01 07:43:37 20-Feb-2020 154.18 Present Recovered Nanushuk 0 8 7 1 3918.86 07:52:01 20-Feb-2020 155.58 Present Recovered Nanushuk 0 9 8 1 3913.33 07:58:59 20-Feb-2020 180.74 Present Recovered Nanushuk 0 10 9 1 3909.53 08:06:19 20-Feb-2020 182.21 Present Recovered Nanushuk 1 11 10 1 3852.98 08:23:49 20-Feb-2020 263.62 Present Recovered Nanushuk 2 12 11 1 3843.66 1 08:37:12 20-Feb-2020 225.47 Present Recovered Nanushuk 2 13 12 1 3839.87 08:54:06 20-Feb-2020 222.14 Present Recovered Nanushuk 2 14 13 1 3836.27 09:01:17 20-Feb-2020 185.86 Present Recovered Nanushuk 2 15 14 1 3829.65 09:08:03 20-Feb-2020 217.92 Present Recovered Nanushuk 2 16 15 1 3801.96 09:15:48 20-Feb-2020 184.70 Present Recovered Nanushuk 2 17 16 1 3799.81 09:23:56 20-Feb-2020 126.85 Present Recovered Nanushuk 2 18 17 1 3763.83 09:32:14 20-Feb-2020 272.00 Present Recovered Nanushuk 3 19 18 1 3728.65 109:41:51 20-Feb-2020 213.06 Present Recovered Nanushuk 4 20 19 1 3721.68 09:51:43 20-Feb-2020 272.96 Present Recovered Nanushuk 4 21 20 1 3717.15 10:00:46 20-Feb-2020 170.75 Present Recovered Nanushuk 4 22 21 1 3711.36 10:07:53 20-Feb-2020 289.86 Present Recovered Nanushuk 4 23 22 1 3708.73 10:19:28 20-Feb-2020 220.35 Present Recovered Nanushuk 4 24 23 1 3704.37 10:27:02 20-Feb-2020 348.54 Present Recovered Nanushuk 4 25 24 1 3702.34 10:38:06 20-Feb-2020 164.03 Present Recovered Nanushuk 4 26 25 1 3697.47 10:45:45 20-Feb-2020 157.18 Present Recovered Nanushuk 4 27 26 1 3692.96 10:53:33 20-Feb-2020 181.82 Present Recovered Nanushuk 5 28 27 1 3690.27 11:01:24 20-Feb-2020 179.39 Present Recovered Nanushuk 5 29 28 1 3685.73 11:08:50 20-Feb-2020 177.02 Present Recovered Nanushuk 5 30 29 1 3682.42 11:15:54 20-Feb-2020 161.73 Present Recovered Nanushuk 5 31 30 1 3679.67 11:22:29 20-Feb-2020 238.85 Present Recovered Nanushuk 5 32 31 1 3674.77 11:29:49 20-Feb-2020 171.90 Present Recovered Nanushuk 5 33 32 1 3665.76 11:36:53 20-Feb-2020 131.71 Present Recovered Nanushuk 5 34 33 1 3659.57 11:42:56 20-Feb-2020 119.55 Present Recovered Nanushuk 6 35 34 1 3654.25 11:49:16 20-Feb-2020 145.34 Present Recovered Nanushuk 6 36 35 1 3648.91 11:55:21 20-Feb-2020 206.98 Present Recovered Nanushuk 6 37 36 1 3647.07 12:02:09 20-Feb-2020 221.31 Present Recovered Nanushuk 6 38 37 1 3642.80 12:09:20 20-Feb-2020 211.01 Present Not Recovered Double Marker Nanushuk 6 39 38 1 3642.80 12:15:21 20-Feb-2020 34.56 Present Recovered Nanushuk 6 40 39 1 3638.60 12:19:59 20-Feb-2020 126.72 Present Recovered Nanushuk 6 41 40 1 3634.48 12:25:21 20-Feb-2020 143.62 Present Recovered Nanushuk 6 42 41 1 3631.64 12:31:27 20-Feb-2020 151.42 Present Recovered Nanushuk 6 43 42 1 3629.39 12:37:28 20-Feb-2020 197.70 Present Recovered Nanushuk 6 44 43 1 3626.85 12:45:26 20-Feb-2020 160.64 Present Recovered Nanushuk 6 45 44 1 3618.00 12:51:34 20-Feb-2020 170.88 Present Recovered Nanushuk 6 46 45 1 3614.13 112:58:01 20-Feb-2020 154.56 Present Recovered Nanushuk 6 47 46 1 3611.35 13:04:33 20-Feb-2020 155.14 Present Recovered Nanushuk 6 48 47 1 3606.48 13:10:42 20-Feb-2020 154.37 Present Recovered Nanushuk 6 49 48 1 3602.98 13:16:24 20-Feb-2020 147.84 Present Recovered Nanushuk 6 50 49 1 3594.12 13:23:56 20-Feb-2020 164.16 Present Recovered Nanushuk 6 51 50 1 3586.09 13:30:16 20-Feb-2020 169.79 Present Recovered Nanushuk 6 52 51 1 3583.14 13:37:02 20-Feb-2020 140.16 Present Recovered Nanushuk 6 53 52 1 3577.58 1 13:43:01 20-Feb-2020 217.34 Present Recovered Nanushuk6 Total 51 record(s) Schlumberger-Private Core Core Barrel Length Depth In Depth Out Cut length Recovered Length Recovery Hours ROP Formation Lithology Summary Hydrocarbons # ft ft ft ft ft % Hr m/hr 1 180.0 4218 4397.99 180 180.55 100.3 2.90 62.07 Nanushuk 0 Laminated sandstones and shales Oil 2 180.0 4398 4577.99 180 180 100.0 3.30 54.55 Nanushuk 0 Laminated sandstones and shales Oil 3 180.0 1 4578 4757.99 180 1 180.4 100.2 3.40 1 52.94 1 Nanushuk 0 Laminated sandstones and shales N/A Whole Core Total Length (ft) =1 541.0 Superseded Core Core Barrel Length Depth In Depth Out Cut length Recovered Length Recovery Hours ROP Formation # ft ft ft ft ft % Hr m/hr 1 180.0 4218 4397.99 180 180.55 100.3 2.90 62.07 Nanushuk 0 2 180.0 4398 4577.99 180 180 100.0 3.30 54.55 Nanushuk 0 3 180.0 4578 4757.99 180 180.4 100.2 3.40 52.94 1 Nanushuk 0 Whole Core Total Length (ft) Stirrup 1 St-1 Well Test Summary Client: Oil Search Alaska Field: Stirrup Well: Srirrup 1 St-1 Formation: Nanushuk OA Test Type: Exploration Production Method: Natural Flow / Gas Lift AGOCC PTD #: 219-153 Process Period Start Time Date (24 hr) End Time Date (24 hr) Duration (hours) Choke Size Final (64th) Tubing Pressure Avg (psig) Tubing Temp. Avg (deg F) Inner Annulus (psig) Outer Annulus (prig) Separator Pressure Avg (psig) Separator Temp. Oil Leg Avg (deg F) GOR (scf/stb) Calculated 24-Hour Rate Gas Oil Water Emulsion (MMscf/d) (bbl/d) (bbl/d) (bbl/d) Cumulative Totals Gas Oil Water Emulsion (mmscf) (bbls) (bbls) (bbls) Period 1: Clean up 03/08/20 8:00 03/09/20 15:30 31.5 58 539 78 1041 0 173.7 80.3 684.77 1.35 1969.37 846.26 128.78 1.77 2584.80 1110.72 169.02 Period 2: Build up 03/09/20 15:30 03/11/20 11:30 44 - - - - - - - - - - - - - - - - Period 3: Main flow 1 1 03/11/20 11:30 03/13/20 4:30 1 41 22 394 64 1223 7 1 154.4 1 89.2 151.26 0.20 1340.55 125.44 4.82 0.3464 2290.10 214.30 8.23 Period 4: Build up 03/13/20 4:30 03/16/20 13:30 57 - - - - - - - - I - - - - - - - - Period 5: Main flow 2 03/16/20 13:30 03/20/20 14:00 96.5 22 431 64 1223 15 167.1 86 411.52 0.23 558.188 89.51 3.22 0.9236 2244.38 359.89 12.94 Period 6: Build up 03/20/20 14:00 03/27/20 6:00 160 - - - - - - - - - - - - - - - - Period 7: Max Rate 03/27/20 6:00 03/27/20 17:00 11 128 361.0 82 1055.0 27 139.2 43 443.7981 0.99 2234.92 566.86 37.90 0.4546 1024.34 259.81 17.37 WELL PARAMETERS CUMULATIVE VOLUMES CO2 (Maximum) 1 ppm Measured Gas 3.4946 MMscf 1-12S (Maximum) 0 ppm Measured Oil 8143.62 bbls Gas Specific Gravity (Average) 0.795 Air = 1 Measured Water 1944.72 bbls Oil Specific Gravity (Average) 37.5° API Measured Emulsion 207.56 bbls GOR 429 (scf/stb) Well effluents were flowed into atmospheric tanks, all fluid rates and accumulative totals were calculated based on tank straps and BS&W spin outs taken at the separator inlet. Gas was flared to atmosphere through a 100 foot flarestack. ® Operations Summary Report - State Oil Search Well Name Wellbore Name PTD # Start Drill Date End Drill Date Stirrup 1 1 Original Hole 219-153 1/13/2020 4/15/2020 Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 1/13/2020 1/14/2020 0 Rig Up Camp Maher and Thompson on Stirrup 1 location. 1/14/2020 1/15/2020 0 Mobilize Doyon Arctic Fox to Stirrup 1 location. Continue to Rig Up Camp Maher and Thompson. 1/15/2020 1/16/2020 0 Continue mobilizing Arctic Fox Rig to location. Prepare camps for occupancy. Continue rigging up NSTI comms on drillsite. Mobilize medical clinic to site. -Arctic Fox Rig: 90% loads on site, 0% rigged up Maher Camp: 100% loads on site, 95% rigged up Thompson Camp: 100% loads on site, 50% rigged up NSTI Communications: 40% rigged up Drilling 3rd Party: 0% loads on site, 0% rigged up 1/16/2020 1/17/2020 0 Mobilize Doyon Rig Crews to site & house in Camp Maher. Wait on Spine Road to be cleared before transporting impassable rig loads to site. Continue hook up comms on location. -Arctic Fox Rig: 90% loads on site, 0% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 60% rigged up NSTI Communications: 60% rigged up Drilling 3rd Party: 0% loads on site, 0% rigged up 1/17/2020 1/18/2020 0 Wait on Spine Road to be cleared before transporting impassable rig loads to site. Continue RU Camp Thompson. Offload & set office modules. Continue hook up comms on location. -Arctic Fox Rig: 90% loads on site, 0% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 70% rigged up NSTI Communications: 70% rigged up Drilling 3rd Party: 0% loads on site, 0% rigged up 1/18/2020 1/19/2020 0 Wait on Spine Road to be cleared before transporting impassable rig loads to site. Spine road open 19:00 hrs. Begin transporting 6 rig loads. Rig on site @ 05:00. Prep to RU Arctic Fox rig. Continue RU Camp Thompson & office complex. Continue hook up comms on location. -Arctic Fox Rig: 100% loads on site, 0% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 80% rigged up Office Camp 100% loads on site, 75% rigged up NSTI Communications: 90% rigged up Drilling 3rd Party: 0% loads on site, 0% rigged up 1/19/2020 1/20/2020 0 Begin RU Arctic Fox rig. Continue RU Camp Thompson & office complex. Continue hook up comms on location. -Arctic Fox Rig: 100% loads on site, 85% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 85% rigged up Office Camp 100% loads on site, 85% rigged up NSTI Communications: 92% rigged up Drilling 3rd Party: 0% loads on site, 0% rigged up 1/20/2020 1/21/2020 0 Continue RU Arctic Fox rig. Continue RU Camp Thompson & office complex. Continue hook up comms on location. -Arctic Fox Rig: 100% loads on site, 90% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 90% rigged up Office Camp 100% loads on site, 90% rigged up NSTI Communications: 93% rigged up Drilling 3rd Party: 20% loads on site, 10% rigged up Page 1 of 9 ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 1/21/2020 1/22/2020 0 Continue RU Arctic Fox rig. Continue RU Camp Thompson & office complex. Continue hook up comms on location. -Arctic Fox Rig: 100% loads on site, 93% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 93% rigged up Office Camp 100% loads on site, 93% rigged up NSTI Communications: 93% rigged up Drilling 3rd Party: 40% loads on site, 40% rigged up 1/22/2020 1/23/2020 0 Continue RU Arctic Fox rig. Continue RU Camp Thompson & office complex. Continue hook up comms on location. -Arctic Fox Rig: 100% loads on site, 97% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 93% rigged up Office Camp 100% loads on site, 93% rigged up NSTI Communications: 93% rigged up Drilling 3rd Party: 60% loads on site, 60% rigged up Rig accepted by OSA @ 00:00 hrs1-23-20 1/23/2020 1/24/2020 0 Continue RU Arctic Fox rig. Continue RU Camp Thompson & office complex. Continue hook up comms on location. -Arctic Fox Rig: 100% loads on site, 98% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 94% rigged up Office Camp 100% loads on site, 97% rigged up NSTI Communications: 93% rigged up Drilling 3rd Party: 70% loads on site, 70% rigged up 1/24/2020 1/25/2020 0 Continue RU Arctic Fox rig & prep for drilling. Perform diverter function test. - Test witnessed by AOGCC representative, Matt Hererra. Continue RU 3rd party equipment & Camp Thompson. Continue hook up comms on location. Hold 2nd Pre -Spud meeting w/ OSA Leadership & 3rd party reps @ 08:00 hrs. -Arctic Fox Rig: 100% loads on site, 99% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 95% rigged up Office Camp 100% loads on site, 97% rigged up NSTI Communications: 93% rigged up Drilling 3rd Party: 80% loads on site, 90% rigged up 1/25/2020 1/26/2020 0 10.50 Continue RU Arctic Fox rig & prep for drilling. Continue RU 3rd party equipment & Camp Thompson. Continue hook up comms & gai-tronics on location. -Arctic Fox Rig: 100% loads on site, 99% rigged up Maher Camp: 100% loads on site, 100% rigged up Thompson Camp: 100% loads on site, 96% rigged up Office Camp 100% loads on site, 99% rigged up NSTI Communications: 97% rigged up Drilling 3rd Parry: 100% loads on site, 98% rigged up 1/26/2020 1/27/2020 0 10.50 Continue prep Arctic Fox rig & prep for drilling. Continue RU 3rd party equipment & Camp Thompson. Continue hook up comms & gai-tronics on location. 1/27/2020 1/28/2020 0 1,000.00 10.45 CO knife valve on diverter. Test per AOGCC requirements. - Contact AOGCC office @ 6am to confirm approval to drill ahead.- Verbal approval from AOGCC inspector Matt Hererra to drill ahead. MU BHA#1. Test surface lines. Drill 12 1/4" surface hole to 500' MD. Pump 10 bbl hi vis sweep. Circulate & condition hole. Check well for flow. Static. POOH. LD BHA #1. Begin PU BHA #2. Spud well. Page 2 of 9 ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (Ib/gal) Summary 1/28/2020 1/29/2020 500 416.00 10.50 Continue PU BHA #2 . MAD pass f/ 178' U 475' per SLB. POOH on elevators f/ 412' t/ 164'. MU 6 3/4" collars, jars & 5" HWDP. Drill 12 1/4" surface hole f/ 500' t / 534' MD. Troubleshoot MWD signal. Drill 12 1/4" surface hole f/ 534' t / 782' MD. Observed over pressure on SPP. Troubleshoot surface equipment. Circulate @ 185 GPM while working pipe. Found ice plug in #2 std. MU #3 stand. Drill 12 1/4" surface hole f/ 782' t /916' MD - Maintaining 680 bbls KWM in tank farm. 1/29/2020 1/30/2020 916 704.00 10.50 Drill 12 1/4" surface hole f/ 916't /1620' MD Maintaining 680 bbls KWM in tank farm. Perform spill drill with crews. 1/30/2020 1/31/2020 1,620 931.00 10.41 Drill 12 1/4" surface hole f/ 1,620' MD t/ 2,551' MD. - Maintaining 680 bbls KWM in tank farm. 1/31/2020 2/1/2020 2,551 150.00 10.60 Drill 12 1/4" hole f/ 2,551' to surface hole TD at 2,701' MD/TVD. Pump hi-vis sweep and CBU x2. Pump out of hole to 2,331' MD. Lose returns. Work pipe, regain returns and TIH to 2,701' MD. CBU x1.5. Pump out of hole to 2,039' MD. Lose returns. Work pipe. Unable to regain returns. POOH on elevators to 1,01V MD. -All losses dynamic, no static losses. TD surface hole. lose returns Total volume lost to hole: 210 bbls Maintaining 680 bbls KWM in tank farm. 2/1/2020 2/2/2020 2,701 0.00 10.50 POOH with 12 1/4" drilling BHA to top of 5" HWDP. RIH and perform wiper trip and tag bottom. Circulate hole clean. POOH and begin laying down BHA. 2/2/2020 2/3/2020 2,701 0.00 10.55 Finish laying down 12 114" drilling BHA. Clear and clean rig floor. R/U casing equipment. Run 9 5/8", 40#, L-80 surface casing to 2693.38' MD. 2/3/2020 2/4/2020 2,701 0.00 10.50 Land casing hanger. Stage up pumps and circulate. Rig up Halliburton cementing equipment and pump surface cement job per procedure. Rig up Halliburton cementing equipment and pump surface cement job per procedure. Pump 457 bbls 11.0ppg ArcticCem lead (yield 2.61cu.ft/sk), 44.5bbls 15.8ppg tail (yield 1.16 cu.ft/sk), displace with 191.4bbls 10.5ppg spud mud. Full returns throughout cement job, switch to tail slurry after lead cement observed at surface. Plug bumped, floats held. Rig down cementing equipment. Nipple down diverter assembly and diverter line. Cement 9 5/8 surface casing 'Notified AOGCC of upcoming 48hr BOP test. 2/4/2020 2/5/2020 2,701 0.00 Remove diverter tee. Install wellhead. Test hanger seal sub. Install 24" spacer spool and install BOP. Clean surface pits and prepare for arrival of OBM. Rig up BOS solids control equipment. 2/5/2020 2/6/2020 2,701 0.00 Continue nippling up BOP. Modify choke line connections and install. Wrap choke line with steam hose and hook up steam. Hook up pressure testing pump, lines, and manifold and insulate. Offload WBM kill weight fluid into vac trucks. 2/6/2020 2/7/2020 2,701 0.00 Prep and rig up for testing BOP's. Shell test BOP. Perform 7" casing hanger dummy run. Begin testing BOP's. Determine incorrect kill line flow block installed. Order replacement and wait on parts from Deadhorse. AOGCC inspector Jeff Jones and Subsea Solutions rep Chris Russell on location for witnessing BOP test. BOP test 2/7/2020 2/8/2020 2,701 0.00 10.30 Install flowblock, cushion, and kill line. Shell test BOP's. Hook up BOS solids control equipment to rig power and BSS tank farm to genset. Begin testing BOP's. Perform tests 1-14 (good tests). After test 14, choke and kill line froze up. Shut down testing and thaw out lines. . AOGCC Inspector Jeff Jones on location to witness BOP test. 2/8/2020 2/9/2020 2,701 10.32 Finish testing BOP's. Rig down testing equipment. Pull test joint and set wear ring. Rig up cuttings box rail system and containment. Continue rigging up BOS equipment. Begin to M/U BHA #3. RIH and tag obstruction at 34' MD. L/D BHA. M/U cleanout assembly and attempt to wash down. Kelly hose frozen. Break off kelly hose at topdrive and steam hose. Page 3 of 9 ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (Ib/gal) Summary 2/9/2020 2/10/2020 2,701 0.00 10.25 Steam ice from kelly hose. RIH with cleanout assembly to 635' MD. CBU. POOH and L/D cleanout assembly. M/U and RIH with 8 1/2" RSS ARC SonicScope BHA and tag top of cement at 2,551' MD. Wash down to 2,571' MD. Circulate and condition mud. Displace mud to 10.3 ppg OBM. R/U casing testing equipment and test casing - good test. Begin drilling out cement. 2/10/2020 2/11/2020 2,701 183.00 10.30 Drill out shoe track and 25' of new formation. Monitor well. Rig up and perform FIT, EMW=18.4 ppg. Drill 8 1/2" production hole from 2,726' to 2,884' MD. Rock washer auger motor broken. Wait on parts. MIT casing and do FIT to 18.4 ppg 2/11/2020 2/12/2020 2,884 1,334.00 10.30 Install rockwasher auger motor. RIH. Drill 8 1/2" production hole section from 2,889'to core point at 4,218' MD/TVD. CBU. Flow check well - well static. POOH to 3,314' MD. 2/12/2020 2/13/2020 4,218 0.00 10.35 POOH and lay down BHA #4. Load tools for first coring run. M/U coring BHA per Halliburton coring procedure. RIH with coring BHA to 4,216' MD. * Sent in 48 hour notification to AOGCC for upcoming BOP test on 2/14/2020 18:00 hrs. 2/13/2020 2/14/2020 4,218 180.00 10.40 CBU w/ coring BHA f/ 4185' t/ 4216'. Drop 1.25" ball & pump down. Tag btm of hole @ 4218' w/ no fill. Core drill f/ 4218 t/ 4398'. POOH w/ core BHA per trip schedule f/ 4342' t/ 690'. At 690', spaced out on 4" HWDP for 30 mins per OSA program. POOH w/ core BHA per trip schedule f/ 690' t/ 192'. Open & break down internal core barrel. Full core recovery. Lower core barrels to pipe shed. Commence processing recovered core. Install new internal core barrels. PU BHA#6 for core run #2. TIH second core BHA t/ 988'. * Sent in 48 hour notification to AOGCC for upcoming BOP test on 2/15/2020 18:00 hrs. 2/14/2020 2/15/2020 4,398 180.00 10.40 Continue TIH w/ BHA #6 / core run #2 f/ 988' t/ 4217'. Wash down f/ 4217' t/ 4398'. Drop 1.25" ball & pump down. Core drill f/ 4398' t/ 4578'. CBU. Monitor well 15 min - Static. POOH w/ core BHA per trip schedule f/ 4530' t/ 690'. At 690', spaced out on 4" HWDP for 30 mins per OSA program. POOH w/ core BHA per trip schedule f/ 690' t/ 192'. - Hold PJSM. Begin break down internal core barrels per Halliburton Rep 2/15/2020 2/16/2020 4,578 0.00 10.40 Break down internal core barrels per Halliburton Rep. Lower core barrels to pipe shed. 100% core recovered. Corelab processed cores in pipe shed. Prep for BOP test. Pull wear bushing & set test plug. RU BOP test equipment. Test BOPs per AOGCC PTD. All tests charted & performed with 4" test jt @ 250/ 3500 PSI for 5 mins each.* AOGCC Inspector Matt Herrera on location to witness BOP test. Rig down test equipment. Pull test plug & install wear bushing. MU Coring BHA #7 for 3rd 180' core run t/ 929'. TIH w/ Coring BHA #7 for core run #3 f/ 929' t/ 4469'. 2/16/2020 2/17/2020 4,578 180.00 10.40 Continue TIH w/ Coring BHA #7 w/ 180' core barrels for core run #3 f/ 4460' t/ 4469'. Wash down f/ 4469' t/ 4578'. Drop 1.25" ball & pump down. Establish parameters. Core drill f/ 4578' t/ 4758'. PU off bottom w/ 18K overpull. CBU while reciprocating pipe (no rotation) f/ 4745' t/ 4700'. Monitor well 15 min.- Static. POOH w/ core BHA per trip schedule f/ 4700' t/ 690'. At 690', monitor well at top of 4" HWDP for 30 mins per OSA program. LD internal & external core barrels per Halliburton Core Techs. Lower core barrels to pipe shed. 100% core recovered. (-180') Corelab Techs process & package cores. Send down all coring tools & equipment. RD coring equipment in pipe shed. Remove core barrels from pipe shed. 2/17/2020 2/18/2020 4,758 202.00 10.30 M/U 8 1/2" RSS BHA#8 w/ARC SonicScope per SLB DID w/ 5" and 4" HWDP to 881'. RIH while PU 10 jts of 4" DP to 1165'. Perform SPT on MWD. Continue RIH from 1165' to 4136' MD. Perform MAD Pass f/ 4136' t/ 4758' per SLB MWD.. Drill 8 1/2" production hole section from 4758' to 4960'. (8 1/2" hole TD). CBU x 2 till shakers cleaned up. Flow check well for 15 minutes. Pump dry job. POOH on elevators f/ 4831' t/ 3061'. * Load & ship 9 totes cores w/ Lynden trucking (60T), escorted by expediter, to Prudhoe per Geology. TD at 4960 ft 2/18/2020 2/19/2020 4,960 0.00 10.40 POOH on elevators f/ 3061' t/ 2230'. Service Rig & top drive. Continue POOH on elevators f/ 2230' t/ 908'. Monitor well 15 mins - Static. L/D 8 1/2" RSS BHA #8 per SLB DD. Rig up SLB wireline & assemble wireline tools. RIH w Run #1 GR- SS- NGI - ZAIT BHA. POOH w/ wireline Run #1 @ 1800 FPH. LD Wireline Run #1 BHA. PU Wireline #2 GR-CMR-PEX-LithoScanner- HNGS BHA. Power up all tools to confirm operational. RIH w/ wireline Run # 2. POOH w/ wireline Run #2 @ 400 FPH. Page 4 of 9 Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 2/19/2020 2/20/2020 4,960 0.00 10.35 Finish POOH w/ wireline Run #2 GR-CMR-PEX-LithoScanner-HNGS BHA. MU wireline Run #3 GR-XPT tools. Perform wireline Run #3 GR-XPT BHA. POOH w/ wireline Run #3 GR-XPT BHA. MU wireline Run #4 GR-ORAtools. Perform wireline Run #4 GR-ORA BHA. 2/20/2020 2/21/2020 4,960 0.00 10.35 Finish POOH w/ wireline Run #4 GR-ORA BHA. MU wireline Run #5: GR-Sidewall Cores (XL Rock) Perform wireline Run #5: GR-Sidewall Cores (XL Rock). 50 out 50 samples collected. LD wireline BHA#5. RD wireline equipment per Schlumberger. PU & MU 8 1/2" Clean Out BHA#9 to 751' MD. RIH w/ 8 1/2" Clean Out BHA #9 f/ 751' t/ 2648'. CBU. Slip & Cut drill line. Continue RIH w/ 8 1/2" Clean Out BHA #9 f/ 2648' t/ 3723'. * Sent in 48 hour notification to AOGCC for upcoming BOP test on 2/22/2020 06:00 hrs. 2/21/2020 2/22/2020 4,960 0.00 10.35 RIH w/ 8 1/2" Clean Out BHA#9 f / 3723' t/ 4740'. RU & Circulate out gas from well through choke. Max gas 3812 units. RIH f/ 4740' t/ 4921'. Wash do t/ 4960' TD. Circulate BU x 4 while working pipe f/ 4960' t/ 4855'. Max gas 1628 units down to 278 units after circ. POOH on elevators, racking back 4" HWDP. LID 5" HWDP, Jars, Collars, Stabilizers & bit. Pull wear bushing w/ GE Vetco Grey Rep. Set test plug. CO upper pipe rams f/ 2 7/8" x 5" U 7" for casing run. RU 7" & 4" test jts w/ XOs. RU all test equipment. Shell test all BOP equipment. Sent in 48 hour notification to AOGCC for upcoming BOP test on 2/22/2020 06:00 hrs. ** Test witness waived by Bob Noble AOGCC Representative. 2/22/2020 2/23/2020 4,960 0.00 10.35 Complete RU all BOP test equipment. Test BOPs per AOGCC PTD. Tests charted & performed @ 250/ 3500 PSI for 5 mins. -Lower IBOP failed. * Test witness waived by Bob Noble AOGCC Inspector. R & R IBOP valves. Re -Test upper & lower IBOPs @ 250/ 3500 PSI for 5 mins. * Good tests. RD test equipment. RU Weatherford casing tools & equipment for 7" casing run. Run 7", 26#, L-80 Vam Top HC casing to 2065' MD. 2/23/2020 2/24/2020 4,960 0.00 10.40 Run 7", 26#, L-80 Vam Top HC casing f/ 2065' t/ 4948.69'. MU and land casing hanger in wellhead. Total of 1.5bbls of mud lost while running casing. Circulate BU. RD casing handling equipment & CRT. RU cement head, manifold & hose. Continue CBU while waiting on cement truck mechanical issue. Hold PJSM. Perform 7" casing stage 1 cement job per program: pump 30bbls 11.5 spacer, 15.4bbis of 12.Oppg lead cement (2.19 ft3/sack yield), 44.5bbls of 15.3ppg tail slurry (1.24ft3/sack yield), displace with 186bbls 10.3ppg MOBM ICP 400psi, FCP 988psi. Noted 22bbls losses on final displacement. Bump plug on calculated strokes, check floats - holding. CIP 17:00 hrs. Increase to 3262 PSI to open ES cementer. CBU, 5bbls cement returns observed at surface. Continue to circulate while WOC and prep for 2nd stage cement job. Loaded & shipped out MWD unit & tools, 60% BOS equipment. cement 7" casing .. 1st stage 2/24/2020 2/25/2020 4,960 0.00 10.25 Perform 7" casing stage 2 cement job per program: pump 30bbls 11.5 spacer, 80.6bbls of 12.Oppg lead cement (2.4 ft3/sack yield), 22.3bbls of 15.3ppg tail slurry (1.24ft3/sack yield), displace with 110bbls 10.3ppg MOBM FCP 630psi. Full returns, no losses, 30bbls spacer and 22bbls cement returned to surface. Bump plug 30 strokes over calculated, pressure up to 1800psi to close stage tool. Check for flow - none, tool is closed. CIP 05:00 hrs. RD cementers. Test 7" wellhead csg packoff. Good test. Change out upper rams to 2 7/8" x 5" VBRs. Test upper VBRs and annular preventer.- Good tests. Install 6.375" wear bushing. PU & MU 6 1/8" Clean Out BHA. RIH. Tag top of ES cementer @ 2830'. Drill plug @ 40-80 RPM, 1-3K TQ. Continue to wash down to 2845'. * Loaded & shipped Weatherford 7" csg handling equipment, 100%BOS equipment, 100% dragon rails, 60% mud product, assorted XOs / tools and 290 bbls 10.3 PPG MOBM. 2/25/2020 2/26/2020 4,960 0.00 9.60 Work 6 1/8" BHA f/ 2232' t/ top of baffle adapter at 4818". CBU. Displace well f/ 10.3 PPG MOBM t/ 9.6 PPG brine. POOH while LID drill pipe into pipe shed f/4804' U 695'. LID 4" HWDP & 6 1/8" Clean Out BHA. RU SLB wireline unit & equipment. Hold PJSM w/ SLB wireline crew. * Loaded & shipped 7" casing, Little Red 1502 manifold parts, assorted tools, & 100% 10.3 PPG MOBM. USIT LOG 2/26/2020 2/27/2020 4,960 0.00 9.60 Perform wireline run #1- USIT log to 4810', wireline run #2- VSP stationary log and wireline run #3- VSP walk away log per Geology. RU & test 7" casing to 3623 PSI. Held test pressure for 30 mins and charted. RIH w/ perf guns, correlate depth and perforate f/ 4325' t/ 4345'. Pull up hole 100'. Monitor well 15 mins - Static. Begin POOH w/ wireline. * Loaded & shipped SLB logging connex, Baroid mud products, & assorted tools. Page 5 of 9 ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (Ib/gal) Summary 2/27/2020 2/28/2020 4,960 0.00 9.60 Finish rigging down wireline equipment. Test VBR's with 3 1/2" test joint. RIH with 3 1/2" 9.2# L- 80 Vam Top production tubing and completion to 4,265' MD. Land hanger and pressure test hanger seals - good test. Pressure test surface lines. 2/28/2020 2/29/2020 4,960 0.00 9.60 Pressure up to 1500 psi to set packer, could not get MIT-T. Pull ball and rod and RHC and replace with XN. MIT-T (good test). MIT -IA (good test). Set X plug (pressure tested), set TWCV in tubing hanger. RDMO slickline and start nippling down BOPE. MIT -IA / tubing Run tubing and packer 2/29/2020 3/1/2020 4,960 0.00 9.60 Nipple down BOPE. Nipple up frac tree. Pressure test to 7,500 PSI - good test. Prepare rig for RDMO. Load out 3rd party support equipment to Deadhorse. Continue to rig up PTS testing equipment. * Doyon Arctic Fox rig released from well operations at 19:00 02/29/2020. Rig 20% rigged down, 0% off location. Release rig (Arctic Fox) 3/1/2020 3/2/2020 4,960 0.00 9.60 Scope in and lay down derrick. Break out and lay down rig modules with crane and prepare for transport. Pressure test hardlines on flowback spread with PTS and LRS - good tests. * Rig 85% rigged down, 0% off location. Lynden tank farm 100% rigged up. PTS 90% rigged up. SLB frac equipment 20% rigged up. 3/2/2020 3/3/2020 4,960 0.00 9.60 Continue breaking out rig modules and spotting on pad. Load modules on trailers and prepare for transport - trucks shut down due to cold temperatures. Clean containment under rig footprint. Take on seawater to frac tanks and begin heating up. Wrap and insulate flowback lines. *Rig 100% rigged down, 0% off location. Lynden tank farm 100% rigged up, PTS equipment 95% rigged up. SLB frac equipment 30% rigged up. 3/3/2020 3/4/2020 4,960 0.00 9.60 Load rig modules on trailers. Pick up matting boards and clean containment under rig footprint. Load out rig modules to Deadhorse. Spot matting boards around well cellar and erect scaffolding. R/U Halliburton slickline. RIH and pull X and XN plugs. Tag TD @ 4,806' WLMD. Swap otis connection to 4.5" 1502 for frac. R/D slickline. PTS performed general equipment maintenance. * Rig 100% rigged down, 95% off location. Lynden tank farm 100% rigged up, PTS equipment 95% rigged up, SLB frac equipment 30% rigged up. 3/4/2020 3/5/2020 4,960 0.00 9.60 Load out remaining rig equipment to Deadhorse. Spot SLB frac equipment on pad. Set wellhouse over cellar. Begin rigging up PTS equipment to wellhead. Reassemble rig in Deadhorse. * Rig 100% rigged down, 100% off location, Lynden tank farm 100% rigged up, PTS equipment 95% rigged up, SLB frac equipment 40% rigged up. 3/5/2020 3/6/2020 4,960 0.00 9.60 Spot SLB frac equipment on pad and begin rigging up. Hook up flowline to well and pressure test - good test. Perform general maintenance on PTS and tank farm equipment. Continue reassembling rig in Deadhorse. * Rig 30% rigged up in Deadhorse, Lynden tank farm 100% rigged up, PTS equipment 100% rigged up, SLB frac equipment 100% rigged up. 3/6/2020 3/7/2020 4,960 0.00 9.60 Finish rigging up SLB frac equipment. PTS changed out flow meter and performed pre flow checklist. Reassemble rig in Deadhorse. * Rig 80% rigged up in Deadhorse, Lynden tank farm 100% rigged up, PTS equipment 100% rigged up, SLB frac equipment 100% rigged up. 3/7/2020 3/8/2020 4,960 0.00 9.60 Finish rig up for frac operations. Pump data and primary frac jobs per OSA procedure. Change out dummy GLV for 28/64th OV with slickline. Drift and tag at 4,544' SLMD. Continue reassembling rig in Deadhorse - 90% rigged up. Frac well 3/8/2020 3/9/2020 4,960 0.00 9. Rig down slickline equipment. Perform pre -flow checklist. Open up well and begin well test clean up period. Continue reassembling rig in Deadhorse - 95% rigged up. 3/9/2020 3/10/2020 4,960 0.00 9.60 Finish well test clean up period. Close well in and begin initial pressure build up period as per OSA procedure. Doyon Arctic Fox rig 100% rigged up in Deadhorse - rig released from demobe 23:59 03/09/2020. Page 6 of 9 ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (Ib/gal) Summary 3/10/2020 3/11/2020 4,960 0.00 9.60 Continue initial pressure build up period as per OSA procedure. R/U slickline. RIH and set 3 1/2" X-Lock with DHSIT. R/D slickline. DHSIT set to close on 03/16/2020 at 19:27. Set to open on 03/22/2020 at 19:27. Tag frac sand at 4,504' KB. 1.4 bbls of fill since last tag. Flow test well. 3/11/2020 3/12/2020 4,960 0.00 9.60 Finish initial pressure build up period as per OSA procedure. Troubleshoot flare igniter. Bring well on at 11:00. Begin steady state flow test as per OSA procedure. 3/12/2020 3/13/2020 4,960 0.00 9.60 Continue steady state flow test as per OSA procedure. 3/13/2020 3/14/2020 4,960 0.00 9.60 Continue steady state flow test as per OSA procedure. Discontinue and suspend steady state flow test as per OSA procedure due to severe weather conditions. 3/14/2020 3/15/2020 4,960 0.00 9.60 Suspend steady state flow test until weather permits. 3/15/2020 3/16/2020 4,960 0.00 9.60 Completed slickline runs to recover downhole shut in tool and check for fill/tag bottom. PTS, ASRC & Nanuq crews clearing test area & pad of heavy snow. 3/16/2020 3/17/2020 4,960 0.00 9.60 Completed slickline run to set downhole shut in tool. Scheduled shut @ 13:38 / 3.20.20. Scheduled open @ 13:38 / 3.26.20. Continue steady state flow test as per OSA procedure. PTS, ASRC & Nanuq crews clearing test area, pad & camp perimeters of heavy snow. 3/17/2020 3/18/2020 4,960 0.00 9.60 Continue steady state flow test as per OSA procedure. 3/18/2020 3/19/2020 4,960 0.00 9.60 Continue steady state flow test as per OSA procedure. 3/19/2020 3/20/2020 4,960 0.00 9.60 Continue steady state flow test as per OSA procedure. 3/20/2020 3/21/2020 4,960 0.00 9.60 Continue steady state flow test as per OSA procedure. Downhole shut in tool shut @ 13:38 / 3.20.20. Begin well shut in monitoring period per OSA procedure. 3/21/2020 3/22/2020 4,960 0.00 9.60 Continue well shut in monitoring period per OSA procedure. 3/22/2020 3/23/2020 4,960 0.00 9.60 Continue well shut in monitoring period per OSA procedure. 3/23/2020 3/24/2020 4,960 0.00 9.60 Continue well shut in monitoring period per OSA procedure. 3/24/2020 3/25/2020 4,960 0.00 9.60 Continue well shut in monitoring period per OSA procedure. 3/25/2020 3/26/2020 4,960 0.00 9.60 Continue well shut in monitoring period per OSA procedure. 3/26/2020 3/27/2020 4,960 0.00 9.60 Continue well shut in monitoring period per OSA procedure. At 13:40 hrs, downhole shut in tool opened & equalized. RIH and tag Paraffin at 353' wlm with GS, POOH. Brush and Flush Paraffin from 353' to 950' wlm while pumping 18 bbls of 160' diesel. RIH & latch DHSIT @ 4197' MD. Tag fill at 4545' wlm (4513' KB corrected). 3/27/2020 3/28/2020 4,960 0.00 9.60 Prepare for Max flow well test. Hold PJSM w/ all involved personnel. Perform Max flow test per OSA procedure. Blow down PTS lines w/ nitrogen. Begin RD PTS & Lynden well test equipment. 3/28/2020 3/29/2020 4,960 0.00 9.60 Continue to rig down PTS well test package and Lynden tank farm. RIH W/ 2.25" Centralizer, TEL & 1.75" sand bailer, Locate TTL @ at 4529' wlm, 4500' KB (corrected)Pump 30 bbls BARAscrub down tubing @ .75 bpm, followed by 60 bbls of 9.6 ppb Kcl for well kill and 7 bbls of MEOH for FP (allowed to U-Tube). Gauge tubing with 2.80" GR and set plug in XN @ 4257' KB. Pulled OV and circulated well out w/ 219 bbls of 9.6 ppb Kcl. Set dummy valve and pressure tested tubing to 2732 psi (good test). Set plug in X nipple @ 403' KB and pressure test to 2000 psi (good test). Set TWCV. set tubing plugs Page 7 of 9 ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (Ib/gal) Summary 3/29/2020 3/30/2020 4,960 0.00 9.60 Change out frac. tree with dry hole/P&A tree, pressure test as per program (good test). Pulled TWC and rigged up slickline. Pulled 3-1/2" XX-plug @403' KB. Ran correlation pass w/ maxfire tool & drift to XXN plug @4257' KB (good data). Ran maxfire & Tx 2" tubing punch (0 phase, 4spf) 3' of shots/13 shots total in 7' carrier. Gun fired on depth 4230' KB. LRS perform CMIT-TAA to 2000psi (good test). Pulled XXN plug @4257' KB. Rigged up Halliburton cement unit, pump cement plug #1 as per program: 10bbls fresh water, 12.3bbls of 15.8ppg (1.15ft3/sk) slurry, drop standing valve (confirmed release from surface), 19.Obbls of 15.8ppg (1.15ft3/sk), drop wiper ball, 18bbls displacement, pressure spike seen when standing valve seated, open IA valve to take returns. LRS pump final 3.4bbls diesel to freeze protect tubing. Close master and IA valves. Flush all surface lines. Cement in place by 20:00. pump Cement plug #1 3/30/2020 3/31/2020 4,960 0.00 9.60 Ran correlation pass with Maxfire tool and drift to 3174' SLM (suspect stringers in tubing), take calibration data (good). Ran 2.72" GR, work through 3174' SL, tag at 3385' SLM. Pick up weights sticky, decision made to not go deeper. Ran Maxfire tool with Tx 2" tubing punch (0 phase, 4spf) 3' of shots in 7' carrier (13 shots total), gun fired on depth of 3375' SLM. Circulated 3bbls of diesel to confirm holes in tubing. Completed 2000psi AOGCC State witnessed CMIT TAA (good). Rigged up and pumped cement plug 2 as per program: pumped 10bbls water, 164bbls of 15.8ppg (1.15ft3/sk) slurry. Cement to surface after 132bbls pumped, sample taken after 147bbls pumped (15.8ppg cement returns), continued to pump full 164bbls cement. Cement in place at 16:30. Continued to load out and clean up Stirrup 1 pad. Cement plug #2 3/31/2020 4/1/2020 4,960 0.00 9.60 Installed Wachs Guillotine cutter, cut off wellhead 24" below fluted landing ring. Good cement was to surface in the Tubing, IA and conductor. OA had low strength cement quality with a 4" channel of no cement, production casing and tubing to subsided 2" once cut. AOGCC inspector (Lou Laubenstein) gave verbal approval to top off 2' void in conductor with cement. Cleaned out OA cement channel and conductor, completed top up cement job. Continue RD, load out & cleaning stirrup pad. Cut wellhead 4/1/2020 4/2/2020 4,960 0.00 9.60 AOGCC representative (Lou Laubenstein) witnessed top of cement, and gave State approval to weld abandonment plate onto well. Once the plate was installed, the top of the well measured 7' below grade. Pulled cellar box and back filled hole. Continue Load out equipment & cleaning stirrup pad. 75% equipment, tools & supplies demobed. 100% PTS equipment demobed. Demobed cellar box to OSA storage. ASRC demobed & transport Delta shop. 4/2/2020 4/3/2020 4,960 0.00 9.60 Continue load out equipment & cleaning stirrup pad. 95% site equipment, tools & supplies demobed. 10:00 walkthrough Maher camp w/ DRFS, & OSA. - Doyon accepted & OSA released Maher Camp. PrepThompson & Maher camps, Liberty office & support equipment for demobe. 4/3/2020 4/4/2020 4,960 0.00 9.60 Continue load out equipment, supplies & cleaning stirrup pad. 95% site equipment, tools & supplies demobed. Continue prepThompson & Maher camps, Liberty office & support equipment for demobe. Personnel move f/ Stirrup to 2P. 4/4/2020 4/5/2020 4,960 0.00 9.60 Continue load out equipment, supplies & cleaning Stirrup pad. Continue prep Thompson & Maher camps, Liberty office & support equipment for demobe. Break down & stage Maher camp units. Transport 0/11 units Load out & transport 2/3 NSTI connexes. 4/5/2020 4/6/2020 4,960 0.00 9.60 Continue load out equipment, supplies & cleaning Stirrup pad. Continue prep Thompson & Maher camps for demobe. Transport 8/13 Maher units off Stirrup site. Prep, demobe & transport Liberty office. 100% Liberty units transported off Stirrup site. 4/6/2020 4/7/2020 4,960 0.00 9.60 Continue load out equipment, supplies & cleaning Stirrup pad. Continue prep Thompson & Maher camps for demobe. Transport 12/13 Maher units off Stirrup site. Page 8 of 9 CMIT (reservoir plug test ) 2000 psi ® Operations Summary Report - State Oil Search Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 4/7/2020 4/8/2020 4,960 0.00 9.60 Clear ice road & Stirrup pad after Phase 2 weather. Continue prep Thompson camp for demobe. Transport last Maher module off Stirrup site. Maher camp 100% demobed. 4/8/2020 4/9/2020 4,960 0.00 9.60 Continue prep Thompson camp for demobe. NSTI remove comms from Thompson camp. Big G remove power from Thompson camp. RU generator to NSTI tower for field comms. Continue cleaning & demobe prep on Stirrup pad. 4/9/2020 4/10/2020 4,960 0.00 9.60 Continue prep Thompson camp for demobe. Separate & stage Thompson camp modules. Begin transporting modules off Stirrup pad. Stage rig mats for transport. Continue Stirrup ice road & pad maintenance. 4/10/2020 4/11/2020 4,960 0.00 9.60 Continue demobe Thompson camp & Stirrup location. Transported 31/-40 Thompson camp loads to date. (78%) Begin demobe & transporting loads from 2P. Continue Stirrup ice road & pad maintenance / cleanup. 4/11/2020 4/12/2020 4,960 0.00 9.60 Continue demobe Thompson camp & equipment on Stirrup location.. Thompson camp 100% demobed. RD & transport NSTI comms tower & connex. Continue Stirrup ice road & pad maintenance / cleanup. 4/12/2020 4/13/2020 4,960 0.00 9.60 Continue demobe Stirrup location. Stirrup location 100% demobed, cleared & cleaned. Complete pulling delineators from Stirrup ice road. Ice road 100% cleared & closed. Continue demobe & transporting loads from 2P. 4/13/2020 4/14/2020 4,960 0.00 9.60 Prep Parker 273 camp & 2P pad for demobe. - Breakfast last meal at P273 on 4-13-20 -All Stirrup 1 support crews moving out by noon 4-13- 20. RD & transport NSTI comms & tower. RD & transport AFC shop. RD & transport medical connex. Medic depart w/ pharmaceuticals in heated van. Trench & snow berm ice road. -- Ice road closed. 4/14/2020 4/15/2020 4,960 0.00 9.60 Continue clean & prep Parker 273 camp for demobe. - Continue demobe 2P pad. 4/15/2020 4/16/2020 4,960 0.00 9.60 OSA/ DUS perform Parker 273 camp final walk through- approved. Demobe & transport P273 camp from 2P to Deadhorse. P273 camp 100% demobed. Demobe & transport MagTec Envirovac and equipment from 2P pad. Clean & clear 2P pad. 2P pad 100% demobed. Final DDR for Stirrup 1 submitted_4-15-20 Page 9 of 9 AOGCC From 10-407 Well Completion Report Box 22 - Logs Obtained Well: Stirrup 1 PTD & Sundry #'s 219-153 / 319-552 / 320-120 LW D BHA Run Section (in) Bit size (in) Date In Date Out MDRT In MDRTOut Max Temp(ft) Suite/Tools Sensor (distance to bit) Comments (ft) (deg F) 1 1 12.5 12.5 27/01/2020 27/01/2020 114 500 None (Dumb Iron) N/A Dumb Iron Power Drive X6 (Nearbit GR) 6.94', D&17.74' 2 2 12.5 12.5 27/01/2020 02/02/2020 139 2,701 122.0 GR-RES-SONIC arcVISION APWD 25.58', Res 28.18', GR 28.35' Drilled to surface hole TD Telescope D&I 52.72 ; sonicVISION Sonic 86.87' 3 3 8.5 8.5 02/05/2020 02/06/2020 None (Dumb Iron) N/A Clean out run - Dumb Iron Power Drive X6 (Nearbit GR) 9.56', D&I 10.16' 4 4 8.5 8.5 02/09/2020 02/12/2020 2,701 4,218 133.0 GR-RES-SONIC arcVISION APWD 25.43', Res 27.76', GR 27.93' Drilled to Core point Telescope D&I 52.44' ; sonicSCOPE Sonic 85.52' 5 5 8.5 (Core 1) 8.5 02/12/2020 02/13/2020 4,218 4,398 Coring Tools N/A Coring Operation 1 6 6 8.5(Core2) 8.5 02/13/2020 02/14/2020 4,398 4,578 Coring Tools N/A Coring Operation 7 7 8.5(Core3) 8.5 02/15/2020 02/16/2020 4,578 4,758 Coring Tools N/A Coring Operation Power Drive X6 (Nearbit GR) 9.56', D&I 10.16' 8 8 8.5 8.5 02/17/2020 02/18/2021 4,218 4,960 115.0 GR-RES-SONIC arcVISION APWD 25.43', Res 27.76', GR 27.93' Drilled to TD. MADPass cored zone. Telescope D&I 52.44' ; sonicSCOPE Sonic 85.52' 9 9 8.5 8.5 02/21/2021 02/21/2021 None (Dumb Iron) N/A Rotary wiper trip Clean Out BHA 2-Two Stabilizers and 2 NMDC from derrick 10 10 8.5 61/8" 02/24/2021 02/25/2021 None (Dumb Iron) N/A 61/8" cleanout 7"casing Wireline Hole Size (in) Cased/Open Hole Run Tool Suite Max BHT (deg F) Top (ft MD) Base (ft MD) Date Duration (hr:min) Comments 8.5 Open Hole SA GR-MSIP(Sonic Scanner) -Resistivity 113 2,700' 4,960' 2/18/2020 6:25hrs None 8.5 Open Hole 1B GR-PEX (Dens/Neutron)-CMR- 113 2,700' 4,960' 2/18/2020 09:00hrs None 8.5 Open Hole SC GR-XPT (Formation Pressures) 110 2,700' 4,960' 2/19/2020 19:05hrs 65 total tests; 23 good data points 8.5 Open Hole 1D GR-ORA(Fluid Sampling) 110 2,700' 4,960' 2/19-20/2020 8:45hrs 3 Sample stations, collected fluid from all 3 stations, 8.5 Open Hole 1E GR-XL Rock (Sidewall Cores) 110 2,700' 4,960' 2/20/2020 30:08hrs Cut 50, recovered 50 8.5 Cased Hole 2A GR-CCL-USIT (Cement Evaluation Log) 110 0 4,810' 2/26/2020 5:24hrs Re -spot unit. 8.5 Cased Hole 2B VSI-4 (Borehole Seismic) 110 0 4,800 2/26/2020 4:41hrs None 8.5 Cased Hole 2C VSI-20 Walk Away (Borehole Seismic) 130 0 4,800 2/26/2020 8:21hrs None 8.5 Cased Hole 2D 4.5" HSD Gun (Perforations) 110 0 4,345 2/26/2020 4:13hrs None SCMUMMIer FracCAT Treatment Report: Stirrup 1 Well : Stirrup 1 Field : Horseshoe Formation : Nanushuk Well Location County : Prudhoe Bay State : Alaska Country : United States Prepared for Client : Oil Search Alaska Client Rep : Scott Leahy Date Prepared : March 7, 2020 Prepared by Name : Alexander Martinez Division : Schlumberger Phone : 561 389 5006 Pressure (All Zones) I Initial Wellhead Pressure (psi) 89 Initial BH ISIP (psi) 7801 Maximum Treating Pressure (psi) Treatment Totals (All Zones As Per FracCAT) 3,997 Final BH ISIP (psi) 2,805 Total Slurry Pumped (Water+Adds+Proppant) bbls 1558.4 Total YF122ST Past Wellhead (bbls) 1233.3 Total WF122 Past Wellhead (bbls) 83.4 Total FP past WH (bbls) 47.4 Total 16/20 Carbolite Pumped (Ibs) 124,680 Total Estimated Proppant in Formation (Ibs.) 182,415 Total 16/20 CarboBOND Lite Pumped (Ibs) 60,800 Total Proppant Pumped (Ibs) 185,480 Total Chemical Additives F103 (gal) Invoiced 54 Past WH 54 I Invoiced A M275 (Ibs.) 48 Past WH -1 39 J580 (Ibs.) 1270 1217 J475 (Ibs.) 330 330 L065 (gal) 108 108 B484 (gal) 2.12 1.6 J532 (gal) 287 287 J511 (Ibs) 220 178 J450 (gal)* 54 27 M002 (Ibs)* 26 26 S123 (gal) 48 48 L401 (gal) 10 0 *J450 mixed at 50% and pumped at 1 gpt *M002 mixed at 0.5lb/gal and pumped at 1gpt 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 of 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. Schlumberger-Private schlumbergep Summary: Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States On March 711, 2020, Schlumberger performed a DataFrac and fracturing treatment on Oil Search's Stirrup 1 well. The crew began firing equipment at 5:30am, had a morning meeting at 6:15. The crew started priming pumps at7:30 and was successfully pressure tested by 9:00. The well was opened just after 9:30 to begin the DataFrac process. The crew was preparing for the main frac around 12:00pm and was clearing snow/ice from inside of the proppant hopper when the sight glass on the hopper broke on the Road side of the blender. At this time the road side slinger had already been flooded with water and had to be freeze protected again before switching over to the deck side slinger for the treatment. The main treatment began just after 1 pm and went smooth up to the 8PPA step when pump #2 shutdown. We would find out later that the pump went offline due to a fuel delivery problem and the low-pressure fuel pump was determined to be the cause. To compensate, the pump operator increased the rate with the remaining pumps to achieve 25 bbl/min. On the last bit of 8PPA proppant was switched from 16/20 CarboLite to 16/20 CarboBOND Lite and then ramped up to 10PPA. The blender was maxed out at 25 bbl/min and 9.7PPA so the decision was made to drop rate to 23 bbl/min so the blender could keep up with proppant. Rate was dropped further to 20 bbl/min and 18 bbl/min while on the 10PPA step. Once on flush, rate was again dropped to 15 bbl/min and just before shutting down it was dropped to 12 bbl/min. There was an estimated underflush volume of 5.6 bbls with 98.3% proppant placement into formation. Schlumberger-Private schlumbergep Job Plots: Stirrup 1: Pressure Test 700 M 500 400 300 Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States — Tr. Press Oil Search Alaska Stirrup 1 — BHP 7-Mar-2020 — Annulus Press — Slurry Rate — Prop Con — BH Prop Con 08:32:01 08:42:26 08:52:51 09:03:16 Time - hh:mm:ss © Schlumberger 1994-2016 30 r16 25 10 5 i0 09:13:41 14 12 10 8 6 4 2 0 Schlumberger Schlumberger-Private schlumbergep 500 400 300 200 100 Stirrup 1: DataFrac — Tr. Press — BHP — Annulus Press — Slurry Rate Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States Oil Search Alaska Stirrup 1 7-Mar-2020 0 — Prop Con — BH Prop Con 0- FP Disp 0- 0- 0-1 0 :35:22 10.17.02 10-58.42 11:40:22 122 © Schlumberger 1994-2016 Time - hh:mm:ss 30 2:02 16 14 25 12 20 CD 10 15 8 6 10 4 5 2 0 0 Scblumbepgep Schlumberger-Private schlumbergep FRac treatment Stirrup 1: Main Treatment © Schlumberger 1994-2016 Time - hh:mm:ss Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States — Tr. Press Oil Search Alaska Stirrup 1 — BHP 7-Mar-2020 — Annulus Press — Slurry Rate 30 16 14 25 12 20 SQ 10 15 8 EE � 6 10 4 5 2 0 r:19 0 Schlumberger Schlumberger-Private schlumbergep Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States Section 1: DataFrac As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass # Name (bbl) (bbl/min) (min) (gal) Con C(PPA) (PPA) (Ib) 1 Disp FP 20.4 5.4 4.1 WF122 1 0. 0.0 0 2 Shutdown 0.0 4.q 0.0 WF122 1 0 0.0 0.0 0 Crosslink 3 Check 13.6 11.8 1.4 WF122 562 0.0 0.0 0 4 XL 223.7 24.7 9.1 YF122ST F 9390 0.0 0.0 0 DataFrac 5 1 LG Flush 25.0 25.0 1.0 WF122 1036 0.0 0.0 0 6 FP Flush 20.4 24.8 0.9 Freeze Protect 875 1 0. 0.0 0 7 FP Displace 24.4 5. 4.8 WF122 1024 0. 0.0 0 Step # Step Name Stage Pressures & Average Slurry Maximum Slurry Rate Rate (bbl/min) (bbl/min) Rates Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Disp FP 5.4 5.7 1346 1423 591 1 2 Shutdown 4.8 0.0 1065 591 591 Crosslink Ch 11.8 15.4 1964 2206 591 1 L DataFrac 24.7 25.4 3291 3997 2102 5 LG Flush 25.0 25.1 2773 2820 2680 6 FP Flush 24.8 25.0 2661 2817 572 FP Displace 5.4 5.5 1862 1950 572 Average Treating Pressure: 2929 psi Maximum Treating Pressure: 3997 psi Minimum Treating Pressure: 572 psi Average Injection Rate: 21.5 bbl/min Maximum Injection Rate: 25.4 bbl/min Average Horsepower: 1650.0 hhp Maximum Horsepower: 2467.8 hhp Maximum Prop Concentration: 0.0 PPA Schlumberger-Private schlumbergep Section 2: DataFrac Job Messages Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States # Time Message Message Log Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 16:37:20 Reset Executed Steps 0 0 0.0 0.0 0.01 2 16:37:20 Reset Executed Steps 0 0 0.0 0.0 0.0 3 6:57:49 Getting equipmentfired up 01 01 0.0 0.0 0.0 4 7:09:15 LRS is heating our freeze protect 0 OI 0.0 0.0 0.01 5 7:28:03 Vac trucks are in place 0 01 0.0 0.0 0.0 6 7:28:13 Freeze protect is being rigged up 0 0 0.0 0.0 0.01 7 7:53:19 Getting POD primed up on FP 1 4 0.0 0.0 0.0 8 7:53:53 Getting lined up to flood the lines with FP 2 3 0.0 0.0 0.01 9 7:54:30 Flooding the lines with FP 4 4 0.0 0.0 0.0 10 7:57:24 Priming pumps 39 4 0.0 0.0 0.0 11 8:23:07 Changing to a different transducer for TR PSI 2 253 3 0.0 0.0 0.01 12 8:26:12 Going to warm lines up and then line up to PT 249 3 0.0 0.0 0.0 13 8:30:21 Narming the lines 28 3 0.0 0.0 0.01 14 8:33:00 Getting lined up for the PT 501 3 0.0 0.0 0.0 15 8:37:00 Coming up for low PT 2582 3 0.0 0.0 0.0 16 8:38:22 Coming up for check valve test 2383 4 0.0 0.0 0.01 17 8:43:09 Doing check check valve test 4243 4 0.0 0.0 0.0 1 18 8:43:18 Check valve is good 4234 4 0.0 0.0 0.01 19 8:44:24 Coming up for high PT 4173 4 0.0 0.0 0.0 1 20 8:50:40 Bumping pressure back up 6474 4 0.0 0.0 0.01 21 8:55:52 Good PT 6580 4 0.0 0.0 0.0 22 8:56:05 Going to mix up 221b gel 6570 4 0.0 0.0 0.0 23 8:56:54 Bleeding pressure off 6534 4 0.0 0.0 0.0 24 8:57:57 Getting gathered up for safety meeting 38 4 0.0 0.0 0.0 25 8:58:19 Mixing 484 56 4 0. 0.0 0.0 26 9:33:22 PJSM is done 43 6 0. 0.0 0.0 27 9:37:36 Guys are getting in their places 48 7 0. 0.0 0.0 28 9:45:17 Priming up POD on gel fluid 45 251 0. 0.0 0.0 29 9:48:00 Matching well head pressure 2079 250 0. 0.0 0.0 30 9:49:02 Opening the well 13 2495 0. 0.0 31 9:49:30 Well is open 99 2497 0. 0.0 32 9:50:21 Start Disp FP Automatically 90 249 0. 0.0 1000 33 9:50:21 tart Diagnostic Automatically 90 249 0. 0.0 34 9:50:21 tart Stage 1 PAD 90 249 0. 0.0 35 9:50:29 Started Pumping 839 252 0. 1.5 0.0 36 9:50:37 Activated Extend Stage 1502 2550 0. 1.4 0.0 37 10:05:56 Deactivated Extend Stage 590 2518 20.4 0.0 0.0 38 10:05:57 Start Shutdown Automatically 821 2523 20.4 0.0 0.0 39 10:05:58 Start Crosslink Ch Manually 871 2527 20.4 1.4 0.0 40 10:06:18 Activated Extend Stage 1568 2541 21.6 5.0 0.0 41 10:07:19 Deactivated Extend Stage 2102 2582 34.0 15.2 0.0 42 10:07:19 Start XL DataFrac Manually 2102 2582 34.0 15.2 0.0 43 10:08:10 Stage at Perfs: Disp FP 2732 2603 51.2 25.0 0.0 44 10:08:59 Stage at Perfs: Crosslink Ch 3577 2584 71.6 24.9 0.0 45 10:09:31 Stage at Perfs: XL DataFrac 3981 2565 84.9 25.0 0.0 46 10:13:34 Activated Extend Stage 3163 2581 186.5 25.0 0.0 47 10:16:24 Deactivated Extend Stage 2824 2611 257.41 25.0 0.0 Schlumberger-Private schlumbergep Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States Time Message Message Log Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 48 10:16:25 Start LG Flush Automatically 2830 2601 257.8 25.0 0.0 49 10:17:25 Start FP Flush Automatically 2814 2608 282.8 25.0 0.0 50 10:17:27 Activated Extend Stage 28481 2610 283.6 25.0 0.0 51 10:18:56 Down for data frac 1074 2551 303.2 0.0 0.0 52 10:19:27 Will be down for about 1.5 hours 1063 2548 303.2 0.0 0.0 53 10:21:01 Closed in our ground valve and bleed PSI to bring down the POD 1042 2530 303.2 0.0 0.0 54 10:22:25 Getting FP transport filled 1044 2513 303.2 0.0 0.0 55 11:18:36 One hour down 873 2152 303.2 0.0 0.0 56 11:34:28 FP transport still being topped off 829 2106 303.2 0.0 0.0 57 11:47:28 LRS is done filling FP transport 790 2075 303.2 0.0 0.0 58 11:57:02 Getting the transport rigged back up 758 2055 303.2 0.0 0.0 59 12:05:43 Stopped pumping to warm lines and to displace FP 7311 2038 303.2 0.0 0.0 60 12:08:15 Priming the POD up on FP 723 2033 303.2 0.0 0.0 61 12:12:58 Warming the lines 711 2067 303.2 0.0 0.0 62 12:17:25 Priming POD up on gelled fluid 694 2490 303.2 0.0 0.0 63 12:23:36 Have to swap to the deck side 676 2473 303.2 0.0 0.0 64 12:25:43 Have to FP road side of POD 670 2468 303.2 0.0 0.0 65 12:48:32 Getting lined up to displace FP 590 2427 303.2 0.0 0.0 66 12:51:34 Matching well head psi 585 2467 303.2 0.0 0.0 67 12:52:23 Opening the 4 inch ground valve 577 2466 303.2 0.0 0.0 68 12:53:16 Started Pumping 576 2465 303.2 0.0 0.0 69 12:53:32 Well is open 574 2464 303.2 0.0 0.0 70 12:53:56 Deactivated Extend Stage 572 2463 303.2 0.0 0.0 71 12:53:57 Start FP Displace Automatically 571 2463 303.2 0.0 0.0 72 12:53:58 Activated Extend Stage 730 2466 303.2 0.0 0.0 73 12:55:12 Stage at Perfs: LG Flush 1896 2507 308.4 5.4 0.0 74 12:59:04 IDown for FP Displacment 1128 2521 327.6 0.0 0.0 75 12:59:42 Rolling out and priming up LAS hoses 1105 2531 327.6 0.0 0.0 76 13:08:44 IDeactivated Extend Stage 1040 25611 327.6 0.0 0.0 Schlumberger-Private schlumbergep Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States Section 3: Main Treatment As Measured Pump Schedule MeasuredAs Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass # Name (bbl) (bbl/min) (min) (gal) (PPA) (lb) (PPA) 1 PAD 200 24 8.8 YF122ST 8382 0 0 0 2 1.0 PPA 99.9 2q 4 YF122ST 40191 CarboLite 16/20 1.11 1 4107 3 2.0 PPA 124.8 25 5 YF122ST 4821 CarboLite 16/20 2.2 2 9712 4 4.0 PPA 175.6 25 7 YF122ST 6279 CarboLite 16/20 4.1 3.9 25416 5 6.0 PPA 201.2 25 8 YF122ST 6690 CarboLite 16/20 6.1 5.9 40832 6 8.0 PPA 176.4 24.5 7.2 YF122ST 5485 CarboLite 16/20 9.1 7.9 44613 7 8.0 PPA 34.2 25 1.4 YF122ST 1049 CarboBOND Lite 16/20 8 8 8524 8 10.0 PPA 181.7 22.2 8.3 YF122ST 5258 CarboBOND Lite 16/20 11.8 9.8 52276 9 Flush 10.1 18.1 0.3 YF122 426 0.0 0 0 Freeeoze 10 Pr 27 14.9 2.3 Freeze Protect 1138 0 0 0 Step # Step Name Stage Pressures & Average Slurry Maximum Slurry Rate Rate (bbl/min) (bbl/min) Rates Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD 24.0 25.2 2937 3406 1039 1.0 PPA 25.0 25.1 2430 2601 2315 0 PPA 5.0 5.2 305 2326 2289 0 PPA 5.0 5.2 501 2579 2284 5 .0 PPA 1.0 5.0 5.2 796 2852 2571 0 PPA 4.5 12.2 5.2 15.3 881 1051 3000 2245 PPA 5.0 967 3032 2910 10.0 PPA 5.2 711 3157 2040 Flush 18.1 18.1 2096 2040 10 Freeze Pro 14.9 118.2 1690 2099 983 Average Treating Pressure: 2669 psi Maximum Treating Pressure: 3406 psi Minimum Treating Pressure: 983 psi Average Injection Rate: 24.0 bbl/min Maximum Injection Rate: 25.3 bbl/min Average Horsepower: 1580.5 h h p Maximum Horsepower: 1936.5 hhp Maximum Prop Concentration: 11.8 PPA Schlumberger-Private schlumbergep Section 4: Main Treatment Job Messages Client: Oil Search Well: Stirrup Formation: Nanushuk District: PAK Country: United States # Time Message Message Log Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:08:45 Start PAD Automatically 1039 2561 0.0 0.0 0.01 2 13:08:45 Start Propped Frac Automatically 1039 2561 0.0 0.0 0.0 3 13:09:39 Stage at Perfs: FP Flush 32241 2582 5.8 14.5 0.0 4 13:10:46 Stage at Perfs: FP Displace 2973 2602 26.7 24.9 0.01 5 13:11:45 Stage at Perfs: PAD 3119 2623 51.4 25.2 0.0 6 13:17:42 Start 1.0 PPA Automatically 2597 2618 200.2 25.0 0.01 7 13:17:42 Started Pumping Prop 2597 2618 200.2 25.0 0.0 8 13:19:44 Stage at Perfs:1.0 PPA 2410 2625 251.0 25.1 1.OI 9 13:21:42 Start 2.0 PPA Automatically 23081 2624 300.2 25.0 1.0 10 13:23:44 Stage at Perfs: 2.0 PPA 2322 2628 351.1 25.0 2.0 11 13:26:41 Start 4.0 PPA Automatically 2317 2608 424.7 25.0 2.OI 12 13:28:43 Stage at Perfs: 4.0 PPA 2512 2590 475.5 25.0 4.0 1 13 13:33:42 Start 6.0 PPA Automatically 2571 2608 600.3 25.0 4.11 14 13:35:44 Stage at Perfs: 6.0 PPA 2820 2602 651.1 25.0 6.0 15 13:41:45 Start 8.OPPA Automatically 2828 2619 801.7 25.1 6.1 16 13:42:41 Activated Extend Stage 2905 2613 825.1 25.1 8.OI 17 13:43:47 Stage at Perfs: 8.0 PPA 2955 2588 852.5 24.9 8.0 18 13:48:58 Deactivated Extend Stage 2941 2625 977.8 24.9 8.OI 19 13:48:58 Start 8.0 PPA Manually 2941 2625 977.8 24.9 8.0 20 13:50:20 Start 10.0 PPA Automatically 30591 2576 1012.0 24.8 8.11 21 13:50:21 Activated Extend Stage 3060 2582 1012.4 24.8 8.1 22 13:51:00 Stage at Perfs: 8.0 PPA 3150 2583 1028.7 25.0 9.6 23 13:52:25 tage at Perfs:10.0 PPA 2866 2575 1062.9 22.8 10.9 24 13:58:36 eactivated Extend Stage 2026 260 1193.1 18.1 0.3 25 13:58:38 tart Flush Manually Ictivated 2035 2605 1193.7 18.1 0.2 26 13:58:55 tart Freeze Pro Automatically 2102 2597 1198.8 18.2 -0.0 27 13:59:00 Extend Stage 2088 2594 1200.3 18.0 -0.1 28 13:59:06 Stopped Pumping Prop 2040 2592 1202.1 17.9 -0.1 29 14:02:06 Down on the pumps 1003 2540 1230.8 0.0 0.0 30 14:02:18 Closing our ground valve 10011 2538 1230.8 0.0 0.0 31 14:02:31 Watching pressure for 30 to 45 minutes 995 2534 1230.1 0.0 0.0 32 14:04:42 Stopped pumping so that we can clean out a pump 980 2504 1230.N 0.0 0.0 33 14:30:14 Bringing down the IA to 500- shut it in 924 2235 1230.1 0.0 0.0 34 14:32:16 Opening our ground valve 922 857 1230. 0.0 0.0 35 14:33:17 Shutting in the well 930 505 1230. 0.0 0.0 36 14:34:36 Pressure is gone 65 510 1230.1 0.0 0.0 37 14:34:41 End of job 66 510 1230.q 0.0 0.0 38 14:34:51 Beginning our clean up 64 5101 1230. 0.0 0.0 Schlumberger-Private ydraulic Fracturing Fluid Product Component Information Disclosure 3/7/2020 Fracture Date: State: Alaska County/Parish North Slope Borough API Number: 5010320809000 Operator Name: Oil Search Alaska Well Name and Number: Stirrup 1 Longitude: -151.43862106724 Latitude: 70.0674341848346 Long/Lat Projection: Production Type: True Vertical Depth (TVD): 4325 Total Water Volume (gal)*: 54864 raulic Fracturing Fluid Composition Trade Name I Supplier F122ST:WF122 Schlumberger Maximum Maximum Chemical Ingredient Ingredient Purpose Ingredients Abstract Service Concentration Concentration Number (CAS #) in Additive in HF Fluid (% by mass)** (% by mass)** nzyme Breaker B484, Water (Including Mix CAS Not 70.707540/( urfactant , Stabilizing Water Supplied by Assigned gent, Breaker J475, Client)* rosslinker, Gel J580, cale Inhibitor, Additive, actericide, Activator , ropping Agent Ceramic materials and 66402-68-4 97.78506% 28.643650/( wares, chemicals (Guar gum I9000-30-0 0.64000%I 0.18747% 1, 2, 3 - Propanetriol I56-81-5 I 0.30915%I 0.09056% Sodium tetraborate 1303-96-4 0.25043% 0.07336% decahydrate �Diammonium 7727-54-0 0.14188% 0.041560/, peroxodisulphate I2,2`,2"-nitrilotriethanol 102-71-6 0.13732%I 0.040230/, PROPAN-2-01- I67-63-0 0.12900%I 0.037790/, (Ethylene glycol I107-21-1 0.11384%I 0.033350/, 2-Propenoic acid, 129898-01-7 0.10648% 0.03119% polymer with sodium phosphinate ISorbitol 150-70-4 1 0.09384%1 0.027490/c Comments .Du I IUI I IUC15'CI-rI IVd IC Trade Name Supplier Purpose Maximum Maximum Chemical Ingredient Ingredient Ingredients Abstract Service Concentration Concentration Number (CAS #) in Additive in HF Fluid (% by mass)** (% by mass)** A1cohols, c11-15- 68131-40-8 0.08447% 0.024740X secondary, ethoxylated 2-butoxyethanol I111-76-2 0.04452%I 0.01304% Ethoxylated C11 Alcohol 34398-01-1 0.04089% 0.011980X Vinylidene 25038-72-6 0.03076% 0.00901 % chloride/methylacrylate copolymer Ethoxylated Alcohol I68131-39-5 I 0.02219%I 0.00650% Sodium chloride I7647-14-5 0.02150%I 0.00630% Sodium hydroxide I1310-73-2 I 0.01428%I 0.00418% Calcium Chloride I10043-52-4 0.01087%I 0.00318% Diatomaceous earth, 91053-39-3 0.01028% 0.00301 % calcined Undecanol I112-42-5 0.00356%I 0.001040X Magnesium nitrate I10377-60-3 0.00206%I 0.00060% Non -crystalline silica 7631-86-9 0.00160% 0.000470X (impurity) 2,2"-oxydiethanol 111-46-6 0.00115% 0.000340X (impurity) 5-chloro-2-methyl-2h- �261172-55-4 0.00110% 0.000320X sothiazolol-3-one Magnesium chloride I7786-30-3 I 0.00103%I 0.00030% Magnesium silicate 14807-96-6 0.00094% 0.000280X hydrate (talc) poly(tetrafluoroethylene) 9002-84-0 0.00040% 0.000120X Potassium chloride 7447-40-7 0.00034% 0.00010% (impurity) 2-methyl-2h-isothiazol-3- 2682-20-4 0.00033% 0.00010% cne Cristobalite I14464-46-1 0.00021 %I 0.000060X Quartz, Crystalline silica I14808-60-7 0.00021 %I 0.000060X Sodium citrate I68-04-2 0.00014%I 0.000040X Acetic acid, potassium 127-08-2 0.00013% 0.000040X salt Hemicellulase enzyme I9012-54-8 0.00007%I 0.000020X Acetic acid (impurity) I64-19-7 0.00002%I 0.00001 % 1,2-benzisothiazolin-3- 2634-33-5 < 0.00001 % < 0.00001 % one Comments ,)cniumoerger-rrivate 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% rt ID: RPT-65943 (Generated on 3/30/2020 12:01 PM) I component information listed was obtained from the supplier's Safety Data Sheets (SDS). As such, the Operator is not responsible for inaccurate and/or complete information. Any questions regarding the content of the SDS should be directed to the supplier who provided it. The Occupational Safety and ealth Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", -ade 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 opendix D. e evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was own to GRC-Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. Schlumberger-Private Hydraulic Fracturing INSCLOSUPE FIND A WELL ABOUT PROIECr BY STATE PARTNERS INote: Gicking the Fr Fa—, FIND A WELL finis will. open a new window ) ac Focus Chemical Disclosure Reg try 0 erator Disclosure Lists 1 Dashboard API Number well Name Status Job Start Date Job Fnd Date Displaying Date Mod 20 v of 4 Records Submit Date 50-103-20793-01-00 Pikka 8 ST1 Submitted 3/2/2019 3/4/2019 4/29/2019 3:42 PM 4/29/2019 50-103-20793-01-OD Pikka C STI Submitted 3/10/2019 3/10/2019 5/2/2019 12:42 PM 5/2/2019 5D-103-20865-01-00 Mitquq I STI Submitted 3/1/2020 3/12/2020 4/24/2020 2:55 PM 4/24/2020 5D-103-20809-00-00 Stirrup 1 Submitted 3/7/2020 3/7/2020 4/24/2020 2:56 PM 4/24/2020 ■ Use Terms I ® Copyright GWPC 8 10GCC, 2010 0) Oil Search Stirrup 1 Survey Geodetic Report Schlumherger (Def Survey) Report Date: March 17, 2020 - 01:06 PM Survey / DLS Computation: Minimum Curvature / Lubinski Client: Oil Search Vertical Section Azimuth: 0.000 ° (True North) Field: NPR NAD27Z4 Vertical Section Origin: 0.000 it, 0.000 ft Structure / Slot: Stirrup 1 / Stirrup-1 TVD Reference Datum: Rotary Table Well: Stirrup 1 TVD Reference Elevation: 54.570 above Unknown ft Borehole: Stirrup 1 Ground Elevation: 36.000 ft above Unknown API#: 501032080900 Magnetic Declination: 15.573 ° Survey Name: Stirrup 1 Total Gravity Field Strength: 1001.9854mgn (9.80665 Based) Survey Date: February 17, 2020 Gravity Model: DOX Tort / AHD / DDI / ERD Ratio: 5.477' / 5.780 ft / 1.500 / 0.001 Total Magnetic Field Strength: 57183.312 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angle: 80.469 ° Location Let / Long: N 70° 4' 2.73267°, W 151 ° 26' 19.03739" Declination Date: December 31, 2019 Location Grid N/E Y/X: N 5876285.338 ftUS, E 320371.187 ftUS Magnetic Declination Model: BGGM 2019 CRS Grid Convergence Angle: -1.3525 ° North Reference: True North Grid Scale Factor: 0.99993666 Grid Convergence Used: 0.0000 ° Version / Patch: 2.10.782.0 Total Corr Mag North ->True North: 15.5732 ° Loral Cnnrd Refarenrerl To- Wall Haar) Comments MD Iftl Incl Azim True TVDSS (ft) TVD (ft) VSEC (ft) AHD (ftl Closure (ftl NS (Rl EW (ftl DLS (°N OORI Northing (ftUSI Easting (ftUSI Latitude (°1 Longitude 1°l RTE 0.00 0.00 0.00 -54.57 0.00 0.00 0.00 0.00 01 0.00 N/A 5876285.34 320371.19 70.067425714 -151.43862150 18.57 0.00 0.00 -36.00 18.57 0.00 0.00 0.00 0.00 0.00 0.00 5876285.34 320371.19 70.06742574 -151.43862150 126.05 0.31 77.10 71.48 126.05 0.06 0.29 0.29 0.06 0.28 0.29 5876285.40 320371.47 70.06742592 -151.43861923 174.73 0.09 65.59 120.16 174.73 0.11 0.46 0.46 0.11 0.45 0.46 5876285.44 320371.64 70.06742604 -151.43861792 235.78 0.11 1.84 181.21 235.78 0.19 0.56 0.53 0.19 0.49 0.18 5876285.51 320371.68 70.06742626 -151.43861756 360.71 0.09 255.38 306.14 360.71 0.28 0.72 0.49 0.28 0.40 0.13 5876285.61 320371.59 70.06742652 -151.43861829 483.87 0.13 309.45 429.30 483.87 0.35 0.94 0.40 0.35 0.20 0.09 5876285.68 320371.39 70.06742669 -151.43861990 542.01 0.08 38.56 487.44 542.01 0.42 1.03 0.46 0.42 0.17 0.26 5876285.76 320371.37 70.06742689 -151.43862010 600.71 0.10 319.95 546.14 600.71 0.49 1.11 0.52 0.49 0.17 0.20 5876285.83 320371.37 70.06742709 -151.43862016 660.89 0.09 199.53 606.32 660.89 0.49 1.17 0.50 0.49 0.12 0.27 5876285.82 320371.32 70.06742708 -151.43862056 724.30 0.06 189.45 669.73 724.30 0.41 1.26 0.42 0.41 0.09 0.05 5876285.74 320371.29 70.06742686 -151.43862074 787.47 0.09 348.40 732.90 787.47 0.42 1.30 0.43 0.42 0.08 0.23 5876285.76 320371.28 70.06742690 -151.43862086 851.48 0.03 307.50 796.91 851.48 0.48 1.37 0.49 0.48 0.06 0.11 5876285.82 320371.25 70.06742706 -151.43862105 914.21 0.06 69.13 859.64 914.21 0.51 1.40 0.51 0.51 0.07 0.13 5876285.84 320371.27 70.06742712 -151.43862091 978.79 0.06 62.54 924.22 978.79 0.53 1.47 0.55 0.53 0.14 0.01 5876285.87 320371.33 70.06742720 -151.43862041 1041.07 0.04 130.81 986.50 1041.07 0.53 1.52 0.56 0.53 0.18 0.09 5876285.87 320371.38 70.06742720 -151.43862005 1105.51 0.06 160.46 1050.94 1105.51 0.49 1.57 0.53 0.49 0.21 0.05 5876285.82 320371.41 70.06742707 -151.43861982 1168.43 0.00 16.83 1113.86 1168.43 0.46 1.61 0.51 0.46 0.22 0.10 5876285.79 320371.42 70.06742699 -151.43861974 1231.52 0.03 170.88 1176.95 1231.52 0.44 1.62 0.49 0.44 0.22 0.05 5876285.77 320371.42 70.06742694 -151.43861971 1294.35 0.06 195.00 1239.78 1294.35 0.39 1.67 0.45 0.39 0.22 0.06 5876285.73 320371.41 70.06742681 -151.43861976 1356.32 0.03 335.48 1301.75 1356.32 0.38 1.70 0.43 0.38 0.20 0.14 5876285.71 320371.40 70.06742677 -151.43861988 1419.04 0.00 16.83 1364.47 1419.04 0.39 1.72 0.44 0.39 0.19 0.05 5876285.72 320371.39 70.06742681 -151.43861994 1485.69 0.09 148.60 1431.12 1485.69 0.35 1.77 0.41 0.35 0.22 0.14 5876285.68 320371.42 70.06742669 -151.43861972 1546.18 0.04 199.93 1491.61 1546.18 0.29 1.84 0.37 0.29 0.24 0.12 5876285.62 320371.43 70.06742652 -151.43861958 1610.84 0.06 193.16 1556.27 1610.84 0.23 1.89 0.32 0.23 0.22 0.03 5876285.56 320371.42 70.06742637 -151.43861970 1673.40 0.06 269.70 1618.83 1673.40 0.20 1.95 0.27 0.20 0.18 0.12 5876285.53 320371.38 70.06742629 -151.43862002 1736.70 0.06 279.15 1682.13 1736.70 0.20 2.02 0.24 0.20 0.12 0.02 5876285.54 320371.31 70.06742630 -151.43862055 1800.61 0.03 357.52 1746.04 1800.61 0.23 2.06 0.24 0.23 0.08 0.10 5876285.56 320371.28 70.06742636 -151.43862082 1862.68 0.03 303.02 1808.11 1862.68 0.25 2.09 0.26 0.25 0.07 0.04 5876285.59 320371.26 70.06742643 -151.43862094 1927.40 0.03 172.94 1872.83 1927.40 0.24 2.11 0.25 0.24 0.06 0.08 5876285.58 320371.25 70.06742641 -151.43862103 1990.61 0.06 260.49 1936.04 1990.61 0.22 2.15 0.22 0.22 0.03 0.10 5876285.56 320371.22 70.06742635 -151.43862128 2052.82 0.06 165.82 1998.25 2052.82 0.19 2.21 0.19 0.19 0.00 0.14 5876285.52 320371.19 70.06742625 -151.43862147 2116.03 0.04 117.47 2061.46 2116.03 0.14 2.26 0.15 0.14 0.03 0.07 5876285.48 320371.22 70.06742613 -151.43862125 2242.30 0.00 16.83 2187.73 2242.30 0.12 2.30 0.14 0.12 0.07 0.03 5876285.46 320371.26 70.06742608 -151.43862094 2303.98 0.06 319.75 2249.41 2303.98 0.15 2.33 0.16 0.15 0.05 0.10 5876285.48 320371.24 70.06742614 -151.43862110 2366.62 0.06 65.20 2312.05 2366.62 0.19 2.38 0.19 0.19 0.06 0.15 5876285.52 320371.25 70.06742625 -151.43862104 2431.03 0.09 7.03 2376.46 2431.03 0.25 2.46 0.27 0.25 0.09 0.12 5876285.59 320371.29 70.06742643 -151.43862074 NPR NAD83Z4\Stirrup 1\Stirrup 1\Stirrup 1\Stirrup 1 Drilling Office 2.10.782.0 SchIumberger-Private 3/17/2020 1:11 PM Page 1 of 2 Comments MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Iftl 0 (°I (ftl Iftl Iftl (ftl (ftl Iftl (ftl (°I100ft1 (ftUSI (ftUSI (°1 (°1 2495.41 0.06 96.24 2440.84 2495.41 0.30 2.53 0.33 0.30 0.13 0.17 5876285.63 320371.33 70.06742655-151.43862042 2558.56 0.09 213.51 2503.99 2558.56 0.25 2.59 0.29 0.25 0.14 0.20 5876285.59 320371.33 70.06742643-151.43862038 2621.32 0.04 48.47 2566.75 2621.32 0.23 2.63 0.26 0.23 0.13 0.21 5876285.56 320371.32 70.06742636-151.43862047 9-518" 2693.00 0.01 316.99 2638.43 2693.00 0.25 2.66 0.29 0.25 0.14 0.06 5876285.58 320371.34 70.06742642-151.43862036 2751.21 0.04 262.72 2696.64 2751.21 0.25 2.68 0.28 0.25 0.12 0.06 5876285.69 320371.31 70.06742642-151.43862055 2816.24 0.10 238.77 2761.67 2816.24 0.22 2.76 0.22 0.22 0.05 0.10 5876285.55 320371.24 70.06742634-151.43862112 2879.06 0.04 150.69 2824.49 2879.06 0.17 2.83 0.17 0.17 0.01 0.17 5876285.51 320371.20 70.06742621-151.43862141 2942.50 0.08 164.45 2887.93 2942.50 0.11 2.89 0.11 0.11 0.03 0.07 5876285.45 320371.22 70.06742604-151.43862123 3003.87 0.06 178.13 2949.30 3003.87 0.03 2.97 0.06 0.03 0.05 0.04 5876285.37 320371.23 70.06742584-151.43862113 3068.30 0.06 29.75 3013.73 3068.30 0.03 3.01 0.07 0.03 0.06 0.18 5876285.37 320371.26 70.06742582-151.43862099 3131.69 0.04 40.96 3077.12 3131.69 0.08 3.06 0.12 0.08 0.09 0.03 5876285.41 320371.28 70.06742595-151.43862074 3193.52 0.00 15.66 3138.95 3193.52 0.09 3.08 0.14 0.09 0.11 0.06 5876285.43 320371.30 70.06742599-151.43862063 3256.74 0.00 15.66 3202.17 3256.74 0.09 3.08 0.14 0.09 0.11 0.00 5876285.43 320371.30 70.06742599-151.43862063 3319.69 0.03 293.22 3265.12 3319.69 0.10 3.10 0.14 0.10 0.09 0.05 5876285.43 320371.28 70.06742601-151.43862075 3383.94 0.09 324.60 3329.37 3383.94 0.15 3.17 0.15 0.15 0.05 0.10 5876285.48 320371.24 70.06742614-151.43862110 3446.94 0.03 225.25 3392.37 3446.94 0.18 3.22 0.18 0.18 0.01 0.16 5876285.51 320371.20 70.06742622-151.43862143 3510.82 0.04 281.80 3456.25 3510.82 0.17 3.26 0.17 0.17 -0.03 0.05 5876285.51 320371.17 70.06742620-151.43862170 3572.71 0.04 24.95 3518.14 3572.71 0.19 3.29 0.20 0.19 -0.04 0.10 5876285.53 320371.15 70.06742627-151.43862179 3635.29 0.04 78.33 3580.72 3635.29 0.22 3.33 0.22 0.22 -0.01 0.06 5876285.55 320371.19 70.06742633-151.43862155 3699.24 0.06 83.77 3644.67 3699.24 0.22 3.39 0.23 0.22 0.05 0.03 5876285.56 320371.24 70.06742635-151.43862111 3763.22 0.06 154.13 3708.65 3763.22 0.20 3.45 0.22 0.20 0.10 0.11 5876285.53 320371.29 70.06742628-151.43862072 3826.23 0.06 126.60 3771.66 3826.23 0.15 3.51 0.20 0.15 0.14 0.05 5876285.48 320371.33 70.06742615-151.43862040 3889.72 0.00 15.66 3835.15 3889.72 0.13 3.54 0.21 0.13 0.16 0.09 5876285.46 320371.35 70.06742609-151.43862018 3952.34 0.06 106.58 3897.77 3952.34 0.12 3.58 0.23 0.12 0.20 0.10 5876285.45 320371.39 70.06742607 -151.43861993 4016.16 0.06 79.72 3961.59 4016.16 0.12 3.64 0.28 0.12 0.26 0.04 5876285.45 320371.46 70.06742606 -151.43861941 4079.00 0.06 114.45 4024.43 4079.00 0.11 3.71 0.34 0.11 0.32 0.06 5876285.44 320371.51 70.06742604 -151.43861891 4142.15 0.03 154.37 4087.58 4142.15 0.08 3.75 0.37 0.08 0.36 0.07 5876285.41 320371.65 70.06742596 -151.43861861 4204.96 0.06 107.79 4150.39 4204.96 0.05 3.80 0.40 0.05 0.40 0.07 5876285.38 320371.59 70.06742589 -151.43861831 4268.68 0.16 193.47 4214.11 4268.68 -0.04 3.91 0.41 -0.04 0.41 0.26 5876285.29 320371.60 70.06742563 -151.43861822 4333.04 0.10 216.71 4278.47 4333.04 -0.17 4.05 0.40 -0.17 0.35 0.12 5876285.15 320371.54 70.06742526 -151.43861865 4396.39 0.17 222.24 4341.82 4396.39 -0.29 4.20 0.39 -0.29 0.26 0.11 5876285.04 320371.44 70.06742495 -151.43861943 4460.40 0.21 191.52 4405.83 4460.40 -0.47 4.41 0.50 -0.47 0.17 0.17 5876284.86 320371.36 70.06742445 -151.43862012 4523.32 0.24 199.74 4468.75 4523.32 -0.71 4.65 0.72 -0.71 0.10 0.07 5876284.62 320371.27 70.06742380 -151.43862066 4586.47 0.26 196.62 4531.90 4586.47 -0.97 4.93 0.97 -0.97 0.02 0.04 5876284.37 320371.18 70.06742308 -151.43862135 4649.67 0.24 199.49 4595.09 4649.66 -1.23 5.20 1.24 -1.23 -0.07 0.04 5876284.11 320371.09 70.06742237 -151.43862203 4711.70 0.33 213.63 4657.12 4711.69 -1.51 5.51 1.52 -1.51 -0.21 0.18 5876283.84 320370.94 70.06742163 -151.43862317 4775.26 0.06 169.99 4720.68 4775.25 -1.69 5.72 1.72 -1.69 -0.30 0.46 5876283.65 320370.84 70.06742112 -151.43862394 4837.14 0.03 251.68 4782.56 4837.13 -1.73 5.76 1.76 -1.73 -0.31 0.10 5876283.62 320370.83 70.06742102 -151.43862402 4901.99 0.00 15.66 4847.41 4901.98 -1.73 5.78 1.76 -1.73 -0.33 0.05 5876283.61 320370.82 70.06742101 -151.43862414 4960.00 0.00 15.66 4905.42 4959.99 -1.73 5.78 1.76 -1.73 -0.33 0.00 5876283.61 320370.82 70.06742101 -151.43862414 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 Description Part (ft) (ft) (ft) (in) (in) Survey Tool Type Borehole I Survey 1 0.000 2558.560 Act Stns 12.250 9.625 SLB_MWD-STD Stirrup 1 / Stirrup 1 1 2558.560 4901.990 Act Stns 8.500 7.000 SLB_MW D-STD Stirrup 1 / Stirrup 1 1 4901.990 4960.000 Act Stns 8.500 7.000 SLB_BLIND+TREND Stirrup 1 / Stirrup 1 Final Definitive Survey Verified and Signed -off SLB DE: Client Representative: Date: NPR NAD83Z4\Stirrup 1\Stirrup 1\Stirrup 1\Stirrup 1 Drilling Office 2.10.782.0 Sch I u rn be rge r- Private 3/17/2020 1:11 PM Page 2 of 2 W m z 0 w 0 Oil Search Alaska CASING & CEMENTING REPORT Permit to Drill (PTD) 219-153 Lease & Well No. ADL 392044 / API 50-103-20809-00-00 Stirrup 1 Date 03-Feb-20 County North Slope State Alaska Co Supv. Tom Boyd / Paul Smith CASING RECORD OH TO MD 2701 TVD 2701 Shoe Depth: MD 2693 TVD 2693 PBTD: MD 2608 TVD 2608 Casing (Or Liner) Detail (should match casing tally) Setting Depths No. of As. Size Wt. Grade THD Eqpmnt Mfg Length Bottom Top Float Shoe 9 5/8 40.00 L80 BTC HES 1.65 2,693.00 2,691.35 Casing (1-2) 9 5/8 40.00 L80 BTC TSA 82.83 2,691.35 2,608.52 Float Collar 9 5/8 40.00 L80 BTC HES 1.27 2,608.52 2,607.25 Casing(3-6) 9 5/8 40.00 L80 BTC TSA 167.21 2,607.25 2,440.04 Pup Jt. 9 5/8 40.00 L80 BTC Unique Mach. 9.82 2,440.04 2,430.22 Casing (7-64) 9 5/8 40.00 L80 BTC TSA 2,401.97 2,430.22 28.25 Hanger Pup 9 5/8 40.00 L80 BTC Unique Mach. 3.57 28.25 24.68 Csg Hanger 9 5/8 GE 0.29 24.68 24.39 Landing Jt. 9 5/8 40.00 L80 BTC TSA 24.77 24.39 -0.38 Totals 2,693.38 Csg Supv. Wt. On Hook: 103k Ibs PU Type Float Collar: Sngl Vlv NR L80 BTC No. Hrs to Run: 15.5 Wt. On Slips: Type of Shoe: Sngl Vlv ,L80, BTC Casing Crew: Weatherford I Description: 10.5ppg WBM r hanger Info (Make/Model): na Liner top Packer?: Yes No r hanger test pressure: na Lnr Hgr Tech ralizer Placement: 1 Der every two ioints to surface lush (Spacer) Clean Spacer Density (ppg) 10.5 Volume pumped (BBLs) 62.0 i Slurry .. ArticCem Yield (Ft3/sack): 2.61 3ity (ppg) 10.9 Volume (BBLs/sacks): 351.4 bbls Mixing / Pumping Rate (bpm): 5.0 Slurry .. Class G Yield (Ft3/sack): 1.16 city (ppg) 15.8 Volume (BBLs/sacks): 44.5 bbls Mixing / Pumping Rate (bpm): 2.1 t Flush (Spacer) Fresh Water Density (ppg) 8.3 Rate (bpm): 6.0 Volume: 10.0 dacement: WBM Density (ppg) 10.5 Rate (bpm): 6.0 Volume (actual / calculated): 191.4 bbls (psi): 567 Pump used for disp: Rig Pump Plug Bumped? X Yes No Bump press 1128 psi ng Rotated? Yes X No Reciprocated? Yes X No % Returns during job 100 ant returns to surface? X Yes -No Spacer returns? X Yes _ No Vol to Surf: 244 bbls wJ / ant In Place At: 13:58 Date: 3-Feb-2020 Estimated TOC: Surface iod Used To Determine TOC: Cement returns for surface lush (Spacer) .. Density (ppg) i Slurry city (ppg) Volume (BBLs/sacks): Slurry 3ity (ppg) Volume (BBLs/sacks): t Flush (Spacer) Cmtg Supv. Savannah Afoa Volume pumped (BBLs) Yield (Ft3/sack): Mixing / Pumping Rate (bpm): Yield (Ft3/sack): Mixing / Pumping Rate (bpm) Density (ppg) Rate (bpm): Volume: ilacement: Density (ppg) Rate (bpm): Volume (actual / calculated): _ (psi): Pump used for disp: Plug Bumped? _Yes No Bump press ngRotated? Yes _No Reciprocated? Yes _No % Returns during job ant returns to surface? _Yes _No Spacer returns? _Yes _No Vol to Surf: ent In Place At: Date: Estimated TOC: iod Used To Determine TOC: Remarks: Cmtg Supv. ok gauge hole volume is 150 MIS. / g I S 1 st stage 2nd stage Oil Search Alaska CASING & CEMENTING REPORT Permit to Drill (PTD) 219-153 Lease & Well No. ADL 392044 / API 50-103-20809-00-00 Stirrup 1 Date 22-Feb-20 County North Slope State Alaska Co Supv. Tom Boyd / Paul Smith CASING RECORD OH TO MD 4960 TVD 4960 Shoe Depth: MD 4949 TVD 4949 PBTD: MD 4819 TVD 4819 Casing (Or Liner) Detail (should match casing tally) Setting Depths No. of Jts. Size Wt. Grade THD Eqpmnt Mfg Length Bottom Top Float Shoe 7" 26.0 L80 VT HC HES 2.87 4,948.70 4,945.83 Csg (1-2) 7" 26.0 L80 VT HC TSA 82.45 4,945.83 4,863.38 Float Collar 7" 26.0 L80 VT HC HES 1.77 4,863.38 4,861.61 Csg (3) 7" 26.0 L80 VT HC TSA 41.44 4,861.61 4,820.17 Baffle Adapt. 7" 26.0 L80 VT HC HES 1.47 4,820.17 4,818.70 Csg (4-51) 7" 26.0 L80 VT HC TSA 1,977.03 4,818.70 2,841.67 Pup Jt. 7" 26.0 L80 VT HC 1 9.90 2,841.67 2,831.77 ES -Cementer 7" 26.0 L80 VT HC HES 3.02 2,831.77 2,828.75 Pup Jt. 7" 26.0 L80 VT HC 9.89 2,828.75 2,818.86 Csg (52-125) 7" 26.0 L80 VT HC TSA 2,793.87 2,818.86 24.99 Pup Jt. 7" 26.0 L80 VT HC 3.00 1 24.99 1 21.99 Csg Hanger 7" 26.0 L80 VT HC 0.22 21.99 21.77 Landing Jt. 7" 26.0 L80 VT HC 21.76 21.77 0.01 Totals 4,948.69 Csg Supv. Wt. On Hook: 125 k Ibs PU Type Float Collar: Single Vlv. HES FC. No. Hrs to Run: 18.0 Wt. On Slips: Type of Shoe: TOCN Eccentric Casing Crew: Weatherford t Description: 10.3ppg MOBM r hanger Info (Make/Model): n/a Liner top Packer?: _Yes X No r hanger test pressure: n/a Lnr Hgr Tech tralizer Placement: One per every two joints ats. 1-71). Preflush (Spacer) Type: Tuned Prime Spacer Density (ppg) Lead Slurry Type: Type I Density (ppg) 12.4 Volume (BBLs/sacks): Tail Slurry 11.5 Volume pumped (BBLs) Yield (Ft3/sack): 2.19 30.0 Mixing / Pumping Rate (bpm): 1.8 Type: Class G Yield (Ft3/sack): 1.24 Density (ppg) 15.3 Volume (BBLs/sacks): 39.5 Mixing / Pumping Rate (bpm): 3.3 Post Flush (Spacer) Type: Fresh Water Density (ppg) 8.3 Rate (bpm): 3.0 Volume: 5.0 a M Displacement: Type: MOBM Density (ppg) 10.3 Rate (bpm): 5.0 Volume (actual / salsuFated): 186.0 FCP (psi): 750 Pump used for disp: Rig Pump Plug Bumped? X Yes No Bump press 1250 Casing Rotated? Yes X No Reciprocated? _Yes X No % Returns during job 91 Cement returns to surface? X Yes -No Spacer returns? X Yes _ No Vol to Surf: 5.0 bbls cement Cement In Place At: 17:00 Date: 23-Feb-20 Estimated TOC: 3050' MD/TVD Method Used To Determine TOC: USIT Wireline Log Cmtg Supv. Savannah Afoa Preflush (Spacer) Type: Tuned Prime Lead Slurry Type: Type I Density (ppg) 12.0 Tail Slurry w Type: Class G Density (ppg) 11.5 Volume pumped (BBLs) Volume (BBLs/sacks): Yield (Ft3/sack): Yield (Ft3/sack): 30.0 2.4 Mixing / Pumping Rate (bpm): 2.9 1.24 Density (ppg) 15.3 Volume (BBLs/sacks): 20.2 bbls Mixing / Pumping Rate (bpm): 2.7 0 Post Flush (Spacer) z Type: Fresh Water Density (ppg) 8.3 Rate (bpm): 3 Volume: 5 bbls 0 w Displacement: Type: MOBM Density (ppg) 10.3 Rate (bpm): 5.0 Volume (actual / salsulated): 83.0 bbls FCP (psi): 630 Pump used for disp: Rig Pump Plug Bumped? X Yes No Bump press 1800 Casing Rotated? Yes X No Reciprocated? _Yes X No % Returns during job 100 Cement returns to surface? X Yes _No Spacer returns? X Yes _ No Vol to Surf: 22.0 bbls cement Cement In Place At: 5:09 Date: 24-Feb-20 Estimated TOC: Surface Method Used To Determine TOC: Cement returns to surface Remarks: First and second stage cement jobs pumped as planned. Cmtg Supv. Savannah Afoa USIT log run Oil Search Alaska CASING & CEMENTING REPORT Permit to Drill (PTD) 219-153 Lease & Well No. ADL 392044 / API 50-103-20809-00-00 Stirrup 1 Date 29-Mar-20 County North Slope State Alaska Co Supv. Tom Boyd / Paul Smith CASING RECORD P&A TO MD 4960 TVD 4960 Shoe Depth: MD 4949 TVD 4949 PBTD: MD 4819 TVD 4819 DetailCasing (Or Liner) -. No. of As. Size wt. Grade THD Eqpmnt Mfg Length Wt. On Hook: Wt. On Slips: Description: - hanger Info (Make/Model): hanger test pressure: ralizer Placement: Type Float Collar: Type of Shoe: Csg Supv. No. Hrs to Run: Casing Crew: Liner top Packer?: Lnr Hgr Tech Yes No Preflush (Spacer) Type: Fresh Water Density (ppg) 8.3 Volume pumped (BBLs) 10 Squeeze Slurry Type: Class G Yield (Ft3/sack): 1.15 Density (ppg) 15.8 Volume (BBLs/sacks): 12.8 bbls Mixing / Pumping Rate (bpm): 3.2 Tail Slurry Type: Class G Yield (Ft3/sack): 1.15 Density (ppg) 15.8 Volume (BBLs/sacks): 18.6 bbls Mixing / Pumping Rate (bpm): 3.9 a. Post Flush (Spacer) W Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Fresh Water Density (ppg) 8.3 Rate (bpm): 6.0 Volume (actual / calculated): 21.4 FCP (psi): 495 Pump used for disp: Cement Pump Plug Bumped? Yes No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 100 Cement returns to surface? _Yes X No Spacer returns? _Yes X No Vol to Surf: Cement In Place At: 20:00 Date: 29-Mar-20 Estimated TOC: 3728' MD Method Used To Determine TOC: Calculated Cmtg Supv. Savannah Afoa Preflush (Spacer) Type: Fresh Water Density (ppg) 8.3 Volume pumped (BBLs) 10.0 Lead Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type: Class G Yield (Ft3/sack): 1.15 J Density (ppg) 15.8 Volume (BBLs/sacks): 143.3 bbls Mixing / Pumping Rate (bpm): 4.6 a Post Flush (Spacer) 0 p Type: Density (ppg) Rate (bpm): Volume: U w Displacement: Type: N/A Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): 600 Pump used for disp: Cement Pump Plug Bumped? _Yes No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 100 Cement returns to surface? X Yes -No Spacer returns? X Yes _ No Vol to Surf: 32.5bbls cement Cement In Place At: 16:37 Date: 01-Apr-19 Estimated TOC: Surface Method Used To Determine TOC: Cement returns to surface Cmtg Supv. Savannah Afoa Remarks: First plug squeezed 10bbls cement into perforations before circulating tubing and casing reservoir abandonment plug in place. P&A Sundry # 320-120 Plug #1 plug #2 Oil Search Stirrup 1 Casing Cut & Plate Marker Photos Stirrup 1 Casing Cut Cemented to Surface Page 1 of 2 Oil Search Stirrup 1 Casing Cut & Plate Marker Photos P&A Plate Marker Backfill Page 2 of 2 Hand Delivery Receipt I have received a USB Drive from Oil Search Alaska containing Final Well Data pursuant to 20 AAC 25.071 for Mitquq 1, Mitquq 1ST1, and Stirrup 1 Wells. ______________________________________________ AOGCC Representative Name and Signature ______________________________________________ Date State of Alaska By Meredith Guhl at 9:05 am, May 14, 2020 May 14, 2020 219-150 219-151 219-153 Meredith Guhl Digitally signed by Meredith Guhl Date: 2020.05.14 09:06:05 -08'00' Oil Search Alaska, LLC Anchorage office 3721 B St. Suite 240927 Anchorage, AK 99524 Tel: +1 907 275 6900 Fax: +1 907 275 6930 www.oilsearch.com May 1, 2020 Alaska Department of Natural Resources Division of Oil and Gas Attn: Resource Evaluation 550 W 7th Ave., Suite 1100 Anchorage, AK 99501 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501 RE: Stirrup 1 Well Data – Request for Submittal Extension To Whom it May Concern: Oil Search (Alaska), LLC (OSA), as Operator of the Stirrup 1 well program, has completed its 2019-2020 drilling season. OSA has submitted required data under separate cover, pursuant to Lease and regulatory requirements. Some of the information required is still being processed and will not be ready for submittal in the timeframe required. We have provided a list of this additional data on the following page. OSA respectfully requests an extension of the submittal requirements for 90 days. OSA will submit the additional data required no later than August 1, 2020. If you have any questions regarding this request, please do not hesitate to contact us. Sincerely, Vaughan Williams Senior Operations Geologist 2 Well Name Well API # Description of Data Stirrup 1 50-103-20809-0000 Conventional Core Laboratory Studies- Porosity & Permeability – Core Lab – estimated August 2020 Stirrup 1 50-103-20809-0000 Analysis of Fluid Samples – Core Lab – estimated August 2020 Stirrup 1 50-103-20809-0000 SCAL Program for whole core plugs- estimated August 2020 MEMORANDUM TO: Jim Regg P. I. Supervisor I State of Alaska Alaska Oil and Gas Conservation Commission 4[Gj(&rL0 DATE: 4/1/2020 FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector Stirrup 1 Oil Search PTD 2191530; Sundry 320-120 4/1/2020: 1 traveled out to the Stirrup 1 exploration well for a surface cutoff and marker plate inspection. Jared Brake with Oil Search was on location for this inspection. I witnessed the cutoff casing to be bellow the required minimum depth and hard cement in all annuli at surface. The marker plate had all the proper and correct information on it, everything looked good and in order. The operator supplied me with two photos of the cutoff wellhead prior to topping the annulus off with cement (attached). Attachments: Photos (5) 2020-0401 _Surface_Abandon_Stirrup-1 _11.docx Page 1 of 4 IR 00 0) N n O � � � D 02) CL 00 n= 53 CD I o fn r r= sy � c m " CDv 5' N L X W CD W � o CD CD O CD C1 2020-0401 _Surface_Abandon_Stirrup-1 _11. docx Page 3 of 4 Stirrup 1 API #: 50-103-20809-00-00 Location: 782.43' FNL, 2,172.78' FEL, SEC 8, T8N, 133E, UM Permit to Drill #: 219-153 2020-0401 _Surface_Abandon_Stirrup-1_11. docx Page 4 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: March 30, 2020 P.I. Supervisor�� iJ it Z I SUBJECT: Well Bore Plug & Abandonment Sturrip 1 FROM: Lou Laubenstein Oil Search , Petroleum Inspector PTD 2191530; Sundry 320-120 Section: 8 Township: 8N Range: 3E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 4,960 ft MD ' Lease No.: ADL 392044 Operator Rep: Jared Brake Suspend: P&A: X -- Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 16" O.D. Shoe@ 113 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 2,693 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 4,949 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 4,266 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above ventied Fullbore Retainer 4257 ft MDR N/A 9.6 ppg - N/A Ini+inl 1 r, min -in min 45 min Result Tubing 2133 2085 2062 IA 1886 1839 1815 P OA 35 35 35 ini+ini 15 min 3n min 45 min Result Tubing IA OA Remarks: I arrived on location for a Combo MIT TxIA on cement plug #1. The tag was done prior to notice for test - not required to be witnessed in sundry approvl - depth not available. The CMIT TxIA passed without any issue. Attachments: none rev. 11-28-18 2020-0330_Plug_Verification_Stirrup-1_II March 13, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval PTD: 219-153 Stirrup 1 Oil Search (Alaska), LLC Stirrup 1 Exploration Well North Slope, Alaska Dear Sir/Madam, (0) Oil Search RECEIVED By Samantha Carlisle at 1:27 pm, Mar 16, 2020 Oil Search (Alaska), LLC hereby applies for an Application for Sundry Approval to Plug and Abandon the Stirrup 1 Well (PTD 219-153) at the conclusion of the flow test. The well is located within state lease acreage on state lands. The Stirrup 1 well has been drilled as a vertical well to TD of 4,960' MDITVD. Upon completion of a flow test evaluation it is requested that the well be plugged back to surface with a series of cement plugs. AI 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) 830-2209 or rob.williamsC@.oilsearch.com. Respectfully, 7'� v Rob Williams Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-403 Application for Sundry Approvals Stirrup 1 Well P&A Procedure and Schematics 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DTS 3/18/20 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 t. Type of Request: Abandon El • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Oil Search Alaska Exploratory Development ❑ Stratigraphic ❑ Service ❑ 219-153 • 3. Address: 900 E Benson Boulevard 6. API Number. Anchorage, AK 99508 50-103-20809-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NIA Stirrup 1 Will planned perforations require a spacing exception? Yes ❑ No 121 9. Property Designation (Lease Number): 10. FieldlPool(s): ADL 392044 ' 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): 4,960' 4.960' 4,325' 4,325' Casing Length Size MD TVD Burst Collapse Structural Conductor 89, 16" 113, 113' 2,840 psi 1,410 psi Surface 2,669' 9-5/8" 2.693' 2693' 5,750 psi 3.090 psi Intermediate Production 4,927' 7• 4,949' 4,949' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,325 - 4,345 4,325 - 4,345 3-1I2" L80 4,266 Packers and SSSV Type: Halliburton PHL Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): 4,240' MDITVD No SSSV 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑� ' Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 301h March 2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 ' 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: Rob Williams Contact Name: Rob Williams Authorized Title: Senior Drilling Engineer Contact Email: rob.williamsCcDoilsearch.com ]� Contact Phone: 907 830-2209 Authorized Signature: /�Z, )C.^y.�� Date: 13th March 2020 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 320-120 Plug Integrity 1� BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Fall 2020 Other: *Photo document casing cutoff and welded plate. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No g Subsequent Form Required: 1 0-407 Jessie L. Chmielowski D,y,caily,,gnedbyJ,,,,,L ch,,,I,,,ki APPROVED BY Approved by: Nte:2020.03.1910:021D-0so0 COMMISSIONER THE COMMISSION Date: 3/19/2020 DSR-3/17/2020 GLS 3/17/20 SFD 3/17/2020 CDW 3/17/2020 Submit Form and Form 1 OA03 Revised 412017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Oil Search Stirrup 1 P&A Program Overview 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 and kill well with 20bbl BARASCRUB LVT wash pill and-80bbls 9.6ppg NaCl kill weight brine. 3. Monitor tubing head pressure for 30min to confirm that well is dead. 4. Rig up slickline and test lubricator to 250/2700psi for 5/5mins. 5. Make up and RIM with 2.7" OD drift run/sample bailer toolstring. Tag bottom, take sample POOH. 6. Make up and RIH with PXN plug setting toolstring. Set PXN plug in XN nipple at 4257'. POOH. 7. Make up and RIH with PXN prong setting toolstring. Set PXN prong in PXN plug at 4257'. POOH. 8. Pressure test PXN plug and prong to 2500psi for 5mins. 9. Make up and RIH with X plug setting toolstring. Set X plug in X nipple at 403'. POOH. 10. Pressure test X plug to 2500psi for 5mins. 11. Rig dawn slickline. 12. Set 4" TWC valve in wellhead. 13. Nipple down frac tree. Nipple up dry hole tree and test to 2700psi for 5mins against TWC. 14, Retrieve TWC from wellhead. 15. Rig up slickline and test lubricator to 250/2700psi for 5/5mins. 16. Make up and RIH with X plug retrieval toolstring. Latch and pull X plug from X nipple at 403' and POOH. 17. Make up and RIH with GLV catcher sub toolstring. Set GLV catcher sub on top of PX prong at -4250' and POOH. 18. Make up and RIH with GLV toolstring. Pull orifice GLV at 3977' and POOH. 19. Forward circulate from tubing to 7" x 3-1/2" IA with-210bbls of 9.6ppg brine (-1.5x tubing and annulus volume) to fill the 7" x 3-1/2" IA with 9.6ppg brine. 20. Make up and RIH with GLV toolstring. Set dummy GLV at 3977' and POOH. 21. Make up and RIH with GLV catcher sub retrieval toolstring. Latch and pull GLV catcher sub from top of PX prong at -4250' and POOH. 22. Make up and RIH with MaxFire P/T gauges toolstring. Take P/T calibration readings and POOH. 23. Make up and RIH with 3' of MaxFire tubing punches. Tag top of PX prong for depth marker and pick up to position charges on depth (just above production packer). Wait for charges to fire and POOH. 24. Forward circulate from tubing to 7" x 3-1/2" IA with 9.6ppg brine. Break circulation and circulate sufficient volume to verify flow path and holes in tubing. Oil Search 25. Pressure test 7" casing against PX plug to 2000psi for 30mins. 26. Make up and RIH with PXN prong retrieval toolstring. Latch and pull prong from PXN plug at 4257' and POOH. 27. Make up and RIH with PXN plug retrieval toolstring. Latch and pull PXN plug from XN nipple at 4257' and POOH. 28. Rig down slickline, rig up Halliburton Cement Unit. 29. Establish injection parameters (rates and pressures) with 9.6ppg brine at 2, 3 and 4 bbls/min. 30. Pump cement plug 1 as follows: Bullhead 10.0 bbls of water - Bullhead 12.3 bbls 15.8ppg Slurry Drop 2.5" OD Standing Valve (to land in XN nipple in end of tubing for a cement base) Bullhead 19.0 bbls 15.8ppg Slurry Plug #1 - Drop 4" foam wiper ball - Bullhead 3.0 bbls of water - Bullhead 5.0 bbls of 9.6ppg brine for initial displacement - Squeeze 10.0 bbls of cement into perforations by continuing to pump 9.6ppg brine. If formation locks up go to next step to open IA valve. - Open 7" x 3-1/2" IA Valve - Forward circulate 9.6ppg brine for continued displacement adjust volume based on how much cement was squeezed away. - Forward circulate 3.0 bbls of diesel for final displacement - Shut in dry hole tree and 7" x 3-1/2" IA valves (to prevent cement from U-tubing) 31. Wait on cement. 32. Rig up slickline and test lubricator to 250/2700psi for 5/5mins. 33. Make up and RIH with 1.75" OD sample bailer with MaxFire P/T gauges toolstring. Tag top of cement, take sample, take P/T calibration readings and POOH. 34. Make up and RIH with 3' of MaxFire tubing punches. Tag top of cement (calculated at 3608' base case) and position charges -20' above. Wait for charges to fire and POOH. 35. Forward circulate from tubing to 7" x 3-1/2" IA with 9.6ppg brine. Break circulation and circulate sufficient volume to verify flow path and holes in tubing. 36. Pressure test tubing and 7" x 3-1/2" IA (combo test) against cement plug 1 to 2000psi for CMIT 30mins. AOGCC Inspector to witness pressure test. Witnessed 37. Rig down slickline, rig up Halliburton Cement Unit. 38. Break circulation and then proceed to pump cement plug 2. Circulate 15.8ppg Slurry into tubing and 7" x 3-1/2" IA- recalculate volume based on tubing punch depth (max.-149.7bbls) Displace with line volume of water to clean cementing lines through to the dry hole tree. Reverse out through manifold and/or vacuum clean any remaining surface pump lines. QD Oil Search 39. Wait on cement. 40. Rig up Guillotine Saw and cut off wellhead through 16" x 9-5/8" x 7" x 3-1/2" casing/tubing strings. 41. AOGCC Inspector to witness TOC in tubing/annulus prior to any cement top up in tubing or annuli. 42. Top off any annulus or tubing with Portland sack cement. 43. 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. 44. Pull cellar and back fill hole. 45. Demob and clean up location. *Site Clearance required in Fall 2020 Oil Search Abandonment Cement Plugs Plug Depths TOC annulus: 3728' MD/TVD; TOC tubing: 3608' MD/TVD Base: 4235' MD/TVD Assumes 10bbls cement is squeezed away refer attachment A for other scenarios. Slurry 31.4 bbls, 176 tuft, 153 sks of 15.8 ppg Class G, Yield: 1.15 cuft/sk Includes squeeze volume of 12.3bbls; plug volume 19.Obbls Cement Temp BHST 114' F at 4236' 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. TOC: 26' MD (surface). Base: 3585' MD/TVD ' Plug Depths Assumes 10bbls cement is squeezed away. Base of cement will change with TOC tag depth and tubing punch depth Slurry 149.7 bbls, 841 tuft, 731 sks of 15.8 ppg Class G, Yield: 1.15 tuft/sk Temp BHST 101° F at 3585' TVD Cement Verification Plug #2 Method Monitor returns at surface and pump pressure during cement job. Plug 2 planned to be placed 20' above Plug 1 TOC tag inside tubing Circulate plug in place from tubing to 7" x 3-1/2" IA through holes punched in Notes tubing. Set as balanced cement plug. 20% excess used to ensure cement to surface 0) Oil Search Stirrup 1 Current Well Schematic Stirrup 1 110 Post -drill Well Schematic Oil Search Updated Feb. 27u' 2020 L16" Conductor 114' MDITVD 500 3-'/z". 2.813" Polish Bore'X' Landing Nipple 403' MD/TVD 1000 1500 2000 2500 3000 3500 4000 4500 I 5000 ® Limestone ■ Clay Sand Fine Sandstone ■ Claystone TO .' Sandstone 3-'/�' cable clamps: Slot: 0.433" (1/4") Encap gauge line 3'/2" 9.2# L80 Vam Top Tubing Surface Casing 9-5/8" 40# L80 BTC 2693' MDITVD 12-'/4" Hole 2,701' MDITVD ES -Cementer Stage Cement Tool 2829' MDITVD GLM, 3-'/z" 3977' MDITVD 3-'/2" 'X' Landing Nipple 4197' M D/TVD Tubing P/T Gauges 4210' & 4222' MD/TVD 3-'/2" x 7" PHL Packer 4240' MD/TVD 3-'/z', 'XN' Landing Nipple 4257' MDITVD WLEG 4265' MDITVD End of Tubing 4266' MDITVD Perforations 4325'-4345' MD/TVD Production Casing 7" 26# L80 Vam Top HC 4949' MDIND 8 1/2" Hole 4960' MDIND Oil Search Stirrup 1 Planned P&A Well Schematic Stirrup 1 Post -drill Well Schematic 0i1 Search Updated Mar. 12u' 2020 „h,o ,,,"I.„AV Planned P&A 500 r! U 1000 Plug ,sao 2000 fi m , 2500 0 014. -' a` v L1 16" Conductor 114' MDITVD 3-'/2". 2.813" Polish Bore'XLanding Nipple 403' MDITVD 3-'/2' cable clamps: Slot: 0.433" ('/4") Encap gauge line 3-1/2" 9.2# L80 Vam Top Tubing --Cement Plug 2: 3585'-surface Surface Casing 9-5/8" 40# L80 BTC 2693' MDITVD 12-1/4" Hole 2,701' MDITVD ES -Cementer Stage Cement Tool 2829' MDITVD t I` Tubing Punch 3585 - 3588 MDITVD U 3000 —Cement Plug 1: 4235 - 3728' (507' plug) j GLM, 3-'/2" 3977' MDITVD 3-1/2" 'X' Landing Nipple 4197' M D/TVD 3500 PLu 1 g Tubing PIT Gauges 4210' & 4222' MDITVD k ? -Tubing Punch 4235 - 4238' MDITVD 4000 3-'/2" x 7" PHL Packer 4240' MDITVD Standing Valve landed in 3-'/2", 'XN' Landing Nipple 4257' MDITVD - 10bbls cement squeezed into 4500 ' ' - _ Perforations 4325'-4345' MDITVD 5000 Production Casing 7" 26# L80 Vam Top HC ITI Limestone clay sand 4949' MDITVD Fine sandstone ■ Vaystone ,v Tuft 8 1 /2" Hole 4960' MDITVD Sandstone Cement must cover the oil-bearing sandstone encountered between 3810' and 3840' MD. SFD 3/17/20 LETTER OF TRANSMITTAL a is-rs3 QD1 �-38 Oil Search DATE: 3/16/2020 From: To: Shannon Koh Meredith Guhl Oil Search Alaska LLC AOGCC 333 W. 7t' Avenue, Suite 100 900 E. Benson Blvd., Level 6 Anchorage, AK 99501 Anchorage, AK 99508 TRANSMISSION TYPE: TRANSMISSION METHOD: ®External Request ❑CD ❑ Thumb Drive ❑Internal Request ❑Email ❑SharePoint ®Hardcopy ❑Other REASON FOR TRANSMITTAL: ❑To Be Returned ❑❑ Approved Information Only [--]With Our Comments ❑Approved with Comments [--]For Your Review ®Required pursuant to 20 AAC 25.071 ❑ For Approval El For Your Use COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION 5 Boxes of Core Chip Samples STIRRUP 1 (50-103-20809-0000) Details on following pages C Received by:Date: Please sign nd return one copy to: Oil Search Alaska ATTN:Shannon Koh 900 E. Benson Blvd., Level 6, Anchorage, AK 99508 907-375-4607 phone shannon.koh@oilsearch.com 311('fZL-::,2��5 - MAR J, 6 2020 Core Lab RESERVOIR OPIf1ELEATIOM ECoc#: 7569 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 Oil Search (Alaska), LLC Anchorage AK United States 99501 Contact: Rory San Fillipo Phone: Job(202000980) has 541 Samples Well: Stirrup Client Ref# Depthl (ft) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 4218.00 4219.50 4220.35 4221.00 4222.35 4223.25 4224.00 4225.20 4226.00 4227.00 4228.00 4229.00 4230.00 4231.20 4232.30 4233.00 4234.00 4235.00 4236.00 4237.00 4238.30 4239.00 4240.20 4241.65 4242.00 4243.50 4244.15 4245.00 4246.00 Depth2(ft) Length Consignee: AOGCC 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 11 4247.00 CHUNK 4248.00 CHUNK 4249.35 CHUNK 4250.25 CHUNK 4251.00 CHUNK 4252.35 CHUNK 4253.00 CHUNK 4254.00 CHUNK 4255.20 CHUNK 4256.40 CHUNK 4257.00 CHUNK 4258.20 CHUNK 4259.45 CHUNK 4260.00 CHUNK 4261.10 CHUNK 4262.00 CHUNK 4263.00 CHUNK 4264.40 CHUNK 4265.15 CHUNK 4266.00 CHUNK 4267.25 CHUNK 4268.45 CHUNK 4269.00 CHUNK 4270.40 CHUNK 4271.25 CHUNK 4272.00 CHUNK 4273.20 CHUNK 4274.00 CHUNK 4275.00 CHUNK 4276.35 CHUNK 4277.65 CHUNK 4278.00 CHUNK 4279.50 CHUNK 4280.65 CHUNK 4281.00 CHUNK 4282.00 CHUNK 4283.20 CHUNK 4284.00 CHUNK 4285.35 CHUNK 4286.10 CHUNK 4287.00 CHUNK 4288.35 CHUNK 4289.65 CHUNK 4290.00 CHUNK 4291.25 CHUNK 4292.00 CHUNK 4293.00 CHUNK 4294.30 CHUNK 4295.30 CHUNK 4296.00 CHUNK 4297.20 CHUNK 4298.15 CHUNK 4299.00 CHUNK 4300.15 CHUNK 4301.30 CHUNK 4302.00 CHUNK Page 2 of 11 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 4303.30 CHUNK 4304.60 CHUNK 4305.00 CHUNK 4306.20 CHUNK 4307.70 CHUNK 4308.00 CHUNK 4309.00 CHUNK 4310.10 CHUNK 4311.00 CHUNK 4312.00 CHUNK 4313.25 CHUNK 4314.00 CHUNK 4315.10 CHUNK 4316.10 CHUNK 4317.00 CHUNK 4318.10 CHUNK 4319.70 CHUNK 4320.00 CHUNK 4321.50 CHUNK 4322.50 CHUNK 4323.00 CHUNK 4324.65 CHUNK 4325.65 CHUNK 4326.00 CHUNK 4327.40 CHUNK 4328.20 CHUNK 4329.00 CHUNK 4330.00 CHUNK 4331.00 CHUNK 4332.00 CHUNK 4333.35 CHUNK 4334.10 CHUNK 4335.00 CHUNK 4336.30 CHUNK 4337.40 CHUNK 4338.00 CHUNK 4339.50 CHUNK 4340.00 CHUNK 4341.00 CHUNK 4342.15 CHUNK 4343.25 CHUNK 4344.00 CHUNK 4345.15 CHUNK 4346.00 CHUNK 4347.00 CHUNK 4348.00 CHUNK 4349.00 CHUNK 4350.00 CHUNK 4351.55 CHUNK 4352.80 CHUNK 4353.00 CHUNK 4354.50 CHUNK 4355.20 CHUNK 4356.00 CHUNK 4357.00 CHUNK 4358.15 CHUNK Page 3 of 11 194 195 196 197 4359.00 CHUNK 4360.50 CHUNK 4361.00 CHUNK 4362.00 CHUNK 4363.00 CHUNK 4364.20 CHUNK 4365.00 CHUNK 4366.00 CHUNK 4367.35 CHUNK 4368.00 CHUNK 4369.55 CHUNK 4370.50 CHUNK 4371.00 CHUNK 4372.50 CHUNK 4373.20 CHUNK 4374.00 CHUNK 4375.25 CHUNK 4376.40 CHUNK 4377.10 CHUNK 4378.45 CHUNK 4379.35 CHUNK 4380.00 CHUNK 4381.15 CHUNK 4382.00 CHUNK 4383.05 CHUNK 4384.15 CHUNK 4385.20 CHUNK 4386.00 CHUNK 4387.00 CHUNK 4388.50 CHUNK 4389.00 CHUNK 4390.00 CHUNK 4391.05 CHUNK 4392.00 CHUNK 4393.05 CHUNK 4394.20 CHUNK 4395.00 CHUNK 4396.35 CHUNK 4397.80 CHUNK 4398.55 CHUNK 4399.00 CHUNK 4400.00 CHUNK 4401.00 CHUNK 4402.10 CHUNK 4403.00 CHUNK 4404.00 CHUNK 4405.45 CHUNK 4406.00 CHUNK 4407.00 CHUNK 4408.30 CHUNK 4409.00 CHUNK 4410.00 CHUNK 4411.70 CHUNK 4412.05 CHUNK 4413.10 CHUNK 4414.00 CHUNK Page 4 of 11 4415.00 CHUNK 4416.00 CHUNK 4417.15 CHUNK 4418.00 CHUNK 4419.00 CHUNK 4420.00 CHUNK 4421.00 CHUNK 4422.35 CHUNK 4423.30 CHUNK 4424.00 CHUNK 4425.00 CHUNK 4426.45 CHUNK 4427.00 CHUNK 4428.50 CHUNK 4429.00 CHUNK 4430.00 CHUNK 4431.50 CHUNK 4432.00 CHUNK 4433.00 CHUNK 4434.40 CHUNK 4435.80 CHUNK 4436.05 CHUNK 4437.35 CHUNK 4438.15 CHUNK 4439.00 CHUNK 4440.15 CHUNK 4441.05 CHUNK 4442.00 CHUNK 4443.25 CHUNK 4444.20 CHUNK 4445.00 CHUNK 4446.65 CHUNK 4447.65 CHUNK 4448.00 CHUNK 4449.45 CHUNK 4450.45 CHUNK 4451.00 CHUNK 4452.10 CHUNK 4453.45 CHUNK 4454.00 CHUNK 4455.25 CHUNK 4456.15 CHUNK 4457.00 CHUNK 4458.00 CHUNK 4459.00 CHUNK 4460.00 CHUNK 4461.35 CHUNK 4462.00 CHUNK 4463.00 CHUNK 4464.00 CHUNK 4465.65 CHUNK 4466.00 CHUNK 4467.00 CHUNK 4468.25 CHUNK 4469.00 CHUNK 4470.65 CHUNK Page 5of11 4471.65 CHUNK 4472.00 CHUNK 4473.35 CHUNK 4474.70 CHUNK 4475.00 CHUNK 4476.75 CHUNK 4477.20 CHUNK 4478.00 CHUNK 4479.20 CHUNK 4480.50 CHUNK 4481.00 CHUNK 4482.40 CHUNK 4483.90 CHUNK 4484.70 CHUNK 4485.65 CHUNK 4486.10 CHUNK 4487.00 CHUNK 4488.00 CHUNK 4489.90 CHUNK 4490.15 CHUNK 4491.10 CHUNK 4492.00 CHUNK 4493.00 CHUNK 4494.10 CHUNK 4495.30 CHUNK 4496.00 CHUNK 4497.40 CHUNK 4498.10 CHUNK 4499.00 CHUNK 4500.60 CHUNK 4501.80 CHUNK 4502.05 CHUNK 4503.25 CHUNK 4504.00 CHUNK 4505.00 CHUNK 4506.35 CHUNK 4507.00 CHUNK 4508.80 CHUNK 4509.35 CHUNK 4510.20 CHUNK 4511.00 CHUNK 4512.85 CHUNK 4513.35 CHUNK 4514.00 CHUNK 4515.35 CHUNK 4516.85 CHUNK 4517.00 CHUNK 4518.65 CHUNK 4519.15 CHUNK 4520.00 CHUNK 4521.55 CHUNK 4522.10 CHUNK 4523.00 CHUNK 4524.30 CHUNK 4525.15 CHUNK 4526.00 CHUNK Page 6 of 11 310 311 312 313 314 315 316 317 318 319 320 321 322 323 324 325 326 327 328 329 330 331 332 333 334 335 336 337 338 339 340 341 342 343 344 345 346 347 348 349 350 351 352 353 354 355 356 357 358 359 360 361 362 363 364 365 4527.10 CHUNK 4528.00 CHUNK 4529.00 CHUNK 4530.50 CHUNK 4531.15 CHUNK 4532.00 CHUNK 4533.00 CHUNK 4534.10 CHUNK 4535.00 CHUNK 4536.00 CHUNK 4537.00 CHUNK 4538.50 CHUNK 4539.00 CHUNK 4540.65 CHUNK 4541.00 CHUNK 4542.35 CHUNK 4543.20 CHUNK 4544.05 CHUNK 4545.10 CHUNK 4546.10 CHUNK 4547.00 CHUNK 4548.55 CHUNK 4549.00 CHUNK 4550.00 CHUNK 4551.15 CHUNK 4552.10 CHUNK 4553.55 CHUNK 4554.20 CHUNK 4555.00 CHUNK 4556.00 CHUNK 4557.50 CHUNK 4558.20 CHUNK 4559.50 CHUNK 4560.25 CHUNK 4561.05 CHUNK 4562.00 CHUNK 4563.40 CHUNK 4564.60 CHUNK 4565.00 CHUNK 4566.00 CHUNK 4567.00 CHUNK 4568.00 CHUNK 4569.00 CHUNK 4570.15 CHUNK 4571.00 CHUNK 4572.45 CHUNK 4573.10 CHUNK 4574.00 CHUNK 4575.10 CHUNK 4576.00 CHUNK 4577.00 CHUNK 4578.90 CHUNK 4579.60 CHUNK 4580.00 CHUNK 4581.45 CHUNK 4582.20 CHUNK Page 7 of 11 4583.00 CHUNK 4584.00 CHUNK 4585.20 CHUNK 4586.00 CHUNK 4587.30 CHUNK 4588.60 CHUNK 4589.00 CHUNK 4590.00 CHUNK 4591.25 CHUNK 4592.00 CHUNK 4593.10 CHUNK 4594.35 CHUNK 4595.00 CHUNK 4596.25 CHUNK 4597.15 CHUNK 4598.00 CHUNK 4599.50 CHUNK 4600.20 CHUNK 4601.00 CHUNK 4602.10 CHUNK 4603.15 CHUNK 4604.45 CHUNK 4605.00 CHUNK 4606.00 CHUNK 4607.00 CHUNK 4608.00 CHUNK 4609.30 CHUNK 4610.55 CHUNK 4611.00 CHUNK 4612.00 CHUNK 4613.00 CHUNK 4614.00 CHUNK 4615.00 CHUNK 4616.00 CHUNK 4617.40 CHUNK 4618.30 CHUNK 4619.00 CHUNK 4620.65 CHUNK 4621.15 CHUNK 4622.00 CHUNK 4623.30 CHUNK 4624.20 CHUNK 4625.00 CHUNK 4626.00 CHUNK 4627.20 CHUNK 4628.00 CHUNK 4629.15 CHUNK 4630.00 CHUNK 4631.00 CHUNK 4632.30 CHUNK 4633.00 CHUNK 4634.00 CHUNK 4635.00 CHUNK 4636.20 CHUNK 4637.30 CHUNK 4638.25 CHUNK Page 8 of 11 4639.05 CHUNK 4640.00 CHUNK 4641.05 CHUNK 4642.10 CHUNK 4643.00 CHUNK 4644.25 CHUNK 4645.00 CHUNK 4646.00 CHUNK 4647.00 CHUNK 4648.15 CHUNK 4649.85 CHUNK 4650.10 CHUNK 4651.10 CHUNK 4652.00 CHUNK 4653.25 CHUNK 4654.10 CHUNK 4655.75 CHUNK 4656.65 CHUNK 4657.00 CHUNK 4658.85 CHUNK 4659.45 CHUNK 4660.00 CHUNK 4661.00 CHUNK 4662.25 CHUNK 4663.10 CHUNK 4664.00 CHUNK 4665.00 CHUNK 4666.05 CHUNK 4667.45 CHUNK 4668.00 CHUNK 4669.35 CHUNK 4670.00 CHUNK 4671.15 CHUNK 4672.30 CHUNK 4673.00 CHUNK 4674.00 CHUNK 4675.10 CHUNK 4676.00 CHUNK 4677.45 CHUNK 4678.00 CHUNK 4679.00 CHUNK 4680.20 CHUNK 4681.05 CHUNK 4682.00 CHUNK 4683.10 CHUNK 4684.00 CHUNK 4685.00 CHUNK 4686.00 CHUNK 4687.00 CHUNK 4688.30 CHUNK 4689.05 CHUNK 4690.25 CHUNK 4691.60 CHUNK 4692.20 CHUNK 4693.35 CHUNK 4694.00 CHUNK Page 9 of 11 531 532 533 4695.15 CHUNK 4696.10 CHUNK 4697.35 CHUNK 4698.00 CHUNK 4699.25 CHUNK 4700.00 CHUNK 4701.30 CHUNK 4702.15 CHUNK 4703.00 CHUNK 4704.20 CHUNK 4705.95 CHUNK 4706.00 CHUNK 4707.25 CHUNK 4708.30 CHUNK 4709.00 CHUNK 4710.40 CHUNK 4711.65 CHUNK 4712.00 CHUNK 4713.05 CHUNK 4714.50 CHUNK 4715.00 CHUNK 4716.10 CHUNK 4717.95 CHUNK 4718.00 CHUNK 4719.00 CHUNK 4720.95 CHUNK 4721.00 CHUNK 4722.05 CHUNK 4723.00 CHUNK 4724.00 CHUNK 4725.45 CHUNK 4726.95 CHUNK 4727.00 CHUNK 4728.35 CHUNK 4729.55 CHUNK 4730.00 CHUNK 4731.20 CHUNK 4732.85 CHUNK 4733.00 CHUNK 4734.20 CHUNK 4735.65 CHUNK 4736.85 CHUNK 4737.25 CHUNK 4738.00 CHUNK 4739.00 CHUNK 4740.70 CHUNK 4741.00 CHUNK 4742.00 CHUNK 4743.25 CHUNK 4744.95 CHUNK 4745.15 CHUNK 4746.00 CHUNK 4747.25 CHUNK 4748.00 CHUNK 4749.40 CHUNK 4750.55 CHUNK Page 10 of 11 534 4751.00 CHUNK 535 4752.40 CHUNK 536 4753.10 CHUNK 537 4754.00 CHUNK 538 4755.25 CHUNK 539 4756.00 CHUNK 540 4757.00 CHUNK 541 4758.65 CHUNK Total: Sample:541 Prepared By : Daniel Burch Please sign, date, & return copy to Core Lab via e-mail, fax, or mail. Date : 15 Mar 2020 Total Samples : 541; Total Boxes : 0; Total Pallets : 0 Received By: 1� /�� Date: Y Y Notes : State of Alaska chip samples Page 11 of 11 LETTER OF TRANSMITTAL QP Oil Search DATE: 2/28/2020 From: To: Shannon Koh Meredith Guhl Oil Search Alaska LLC AOGCC 900 E. Benson Blvd., Level 6 333 W. 71h Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99508 TRANSMISSION TYPE: TRANSMISSION METHOD: ❑X External Request ❑CD El Thumb Drive ❑Internal Request ❑Email ❑SharePoint ©Hardcopy ❑Other REASON FOR TRANSMITTAL: ❑Approved []Information Only ❑To Be Returned ❑Approved with Comments ❑For Your Review ❑with Our Comments []For Approval ❑For Your Use NRequired pursuant to 20 AAC 25.071 COMMENTS: CONFIDENTIAL DATA TRANSMITTAL PER AS 31.05.035(c) DETAIL CITY DESCRIPTION STIRRUP 1 (50-103-20809-0000) 7 Boxes of Dry Samples Details on following page Received by: Date: tease 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 0) Oil Search Box # Qty containers Type Sampling Frequency Sample interval 1 30 30' 114'-970' 2 30 30' 970'-1870' 3 28 30' 1870'-2701' 4 30 30' 2701'-3600' AOGCC Washed & Dried 5 30 30' (3600'-4110') 10' (4110'-4240') 3600'-4240' 6 30 10' 4240'-4540' 7 29 10'(4540'-4758') 30'(4758'-4960') 4540' 4960' THE STATE VI a V I IS] W441k GOVERNOR MIKE DUNLEAVY Marc Kuck Senior Engineering Manager Oil Search Alaska 900 E Benson Blvd. Anchorage, AK 99508 Re: Exploratory Field, Exploratory Pool, Stirrup 1 Permit to Drill Number: 219-153 Sundry Number: 319-552 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, e . Price ha DATED this J day of March, 2020. IBDMS.l MAR 0 4 2020 r STATE OF ALASKA DEC — 5 jff9 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Q 20 AAC 25.280'" 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 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill mLer, Oil Search Alaska Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑ J 3. Address: 900 E Benson Boulevard 6. API Number: Anchorage, AK 99508 50- ' b , `7 _ — (� 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Stirrup 1 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 392044 Undefined I 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 120' 16" 120' 120' 3060 1450 Surface 2,650' 9-5/8" 2,650' 2,650' 7930 4760 Intermediate Production 6,000' 7" 6,000' 6,000' 7240 7800 Liner MD (: Perforation Depth ft)tion PertoraDepth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,387' - 4,407' 4,387' - 4,407' 3-1/2", 9.2# L-80 , Vamtop 14,365' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary ❑ Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ - Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/7/2020 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 ✓/' 7 Contact Phone: 907-375-4600 ) Authorized Signature: f / df �—� Date: / 2 L ` 1Ci COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ p p j� c r jc / Other: , /JD I.A_C.. 3BD1U SA(' �' M �1 tWEB-P`, I I /0 ��,�t�. Z' ,t,4<— 'S Post Initial Injection MIT Req'd? Yes ❑ No LJ / ii� ) yn Spacing Exception Required? j /j / V�/^ I� E� ri P 9 P q Yes ❑ No � Subsequent Form Required: 1 � � � � C /� L APPROVED BY mil`L^ Approved by: COMMISSIONER THE COMMISSION f� /t Date: J c7r CW 7- /ou )Ye, eGINIAoLthe Submit .� Form and Form 10-403 Revised 412017 Approved appl O v li date of approval. Attachments in Duplicate 0 4 2020 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), LLCs Sundry Application for a Fracture Stimulation for the Proposed Stirrup 1 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 Stirrup 1 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 Stirrup 1 well trajectory and fracture stimulation. Please contact me should you require additional Tim Jon Land Ma 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 corn Attachment A Distribution List: Alaska Division of Oil and Gas Oil Search (Alaska), LLC Repsol E&P USA Inc. NW 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 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 Tel: +1 907 375 4600 Fax: +1 907 375 4630 www.oilsearch.com CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL Attachment A Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones, who, being duly sworn according to law, deposes and says: 1. I, 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 affiat* sayeth naught. Timothy Jon RPL #84167 UNITED STATES OF AMERICA § STATE OF ALASKA STEPH LlAETTE Notary Public State of Alaska My Commission Expires Jul 21, 2023 Date Subscribed and sworn to before me on the day of December, 2019. ` 7 Notary Public My commission expires: I? 4 ( • ? I Attachment A (0) Oil Search Stirrup 1 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 Stirrup-1. At the Stirrup-1 location, the Permafrost interval extends down to approximately 630-850 ft and therefore, no known shallow aquifers (typically found down to 400ft depth) are located at the Stirrup-1 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. Casine and tubinE nrPrsurP tPSt information— Prprriiro tortina Mill ho nnrfnrm r1 u .. �., ____...._....__._.. ..,......,,._......., ,b .,,.... 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 shoreface and deltaic sandstone deposits. In near -offset analogue fields, the formation sandstone is massive in the upper section to highly laminated in the lower section and grades into the silty -shale dominated Torok Formation immediately beneath it. The sandstones are very fine-grained to fine grained degrading to siltstone with depth. The sandstone unit at the top of the reservoir is likely overlain by a transgressive zone compromised of shales and siltstones which constitutes a seal. The fracture gradient for this sealing shale is 16.1— 16.4 ppg. Depth & Thickness: 3505ft MD/3451ft TVDSS,—1234ft 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 sequence composed of condensed mudstone facies deposited during a maximum transgression and creates a good regional seal. Distant volcanism coeval with Seabee deposition resulted in numerous bentonite interbeds. The Seabee Formation is predominately shale/claystone deposited in distal deep -water slope and basinal environtments. The claystones within the Seebee Formation are 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 15.7 —16.1 ppg. Depth & Thickness: 2558ft MD/2504ft TVDSS, —947ft TVT Lower Confining Units: Torok Formation Lithologic Description: The Torok Formation underlies the target reservoir and comprises claystones, silty shales and shale sequences. The formation grades vertically from silty shale to shale at the base. 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 16.4-17.3 ppg. Depth & Thickness: 4739 MD/4685 TVDSS, "3110ft 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 200-300ft thick. The fracture gradient for this sealing shale is 17.3 ppg. Depth & Thickness: 7823 TVDSS, —260ft 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 Y. Max Rate Max Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. (psi) (PPA) Job Max 4,335 4,335 249.4 226.3 25 3,585 10 10. Mechanical condition of wells transecting the confining zones — No wells within 1/2- mile radius of Stirrup 1. 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 Stirrup-1 location, there are no known faults or fracture zones interpreted to be located within a half mile radius of the planned Stirrup-1 wellbore. Seismic interpretation of the Nanushuk reservoir and internal interpretation surfaces has determined that there are no faults of seismic resolution within the half mile radius (Attachment F). Furthermore, the use of seismic attribute analysis supports the structural interpretation. The coherency attribute which identifies structural fabric that is associated with faults and fractures suggests that there are no faults located within a half mile radius of Stirrup-1 wellbore trajectory (Attachment F). Oil Search does not expect that any hydraulic fractures during the stimulation of Stirrup- 1 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 U008N003E05 0008N003E06 0008N003E04 0008N003E03 ♦`` III , I Operator: OIL SEARCH STIRRUP 1 SHL { Subsurface Owner: AONR Surface Owner. State , REPSOL: 49% ` � f z � / 0008N003E07 / 0008N003E08 0008N003E09 0008N003E 10 7 _ ADL 392043 Operator: OIL SEARCH Subsurface Owner ADNR / Surface Owner: State OSA: 51 REPSOL: 49% U008N003E 18 0008N003E17 0008 3E16 0008N003E15 OIL SEARCH ALASKA { _ _ � 0.5-MILE BUFFER LEASE BOUNDARY 201 s-2o19 EXPLORATION CAMPAIGN SURFACE HOLE SECTION Stirrup 1 Well Area Oil Search ICE ROADS/PADS N0 400 800 ®Feet GCS: NAD 1927 StatePlane Alaska 4 FIPS 5004 W Attachment B E ®Meters DATE: 12/3/2019. REV I.O.By: JB �Ao 3 0 100 200 Document name: OP5-19-2aW-PE-M_Stinupl trac5undry 7" Production Casing Section Overview 7" 26# L80 Vam Top HC Casing Burst Collapse Tensile ID Drift ID Connection Optimal Make- Make -Up (Psi) (Psi) (klbs) (in) (in) OD up Torque Loss (in) (ft-lbs) (in) 7240 5410 604 6.276 6.151 7.000 11950 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 —2750' (100' outside 9-5/8" shoe) Tail Open hole volume + 30% excess + 120 ft shoe track Tail TOC —3807' MD/TVD. 600' MD/TVD above top of Nanushuk Oa formation Spacer 30 bbls of 11.3 ppg Clean Spacer Total Cement Lead 31 bbls, 174 cult, 82 sks of 12.0 ppg ExtendaCem, Yield: 2.13 cuft/sk Volume Tail 70 bbls, 391 cult, 315 sks 15.3 ppg ExpandaCem Class G —1.24 cuft/sk Temp BHST 149° 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 + 10% excess Basis Lead TOC Surface Tail Open hole volume + 30% excess + Cased hole volume + 10% excess Tail TOC 500' TVD/MD above 9-5/8" casing shoe (stage tool 100' outside shoe) Spacer 30 bbls of 11.3 ppg Clean Spacer Total Cement Lead 66 bbls, 371 cult, 154 sks of 12.0 ppg VariCem, Yield: 2.40 cult/sk Volume Tail 19 bbls, 108 cult, 87 sks 15.3 ppg ExpandaCem Class G — 1.24 cuft/sk Temp BHST 81° 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 w' i Production Casing Proposed Cementing Program 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 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 10.5 ppg MOBM ix. 11.5 ppg Tuned Spacer (to sit across stage tool) x. Final displacement with 10.5 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 Top Cement 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 based on actual well depths. c) Do not pump over the calculated displacement plus half of the three joint shoe volume plus 0.2bbs for mud compressibility (-2.3bbls % shoe + 0.2bbls mud compressibility =—2.5bbls 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. Attachment C 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. 3. Wait on first stage tail cement to reach 50psi compressive strength (-5hrs). 4. Proceed to pump the second stage cement job as per Halliburton Cementing Program. a) Stage 2 is planned to be pumped as follows: L 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. 10.5 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 Plus. 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 based on actual well depths. 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. 5. Rig down Halliburton cement head and lines. 6. Back out and retrieve the casing hanger running tool. Attachment C J9-1/2" (4-ACME)OTIS 4-1/16" 5M 4-1/16" 10M M 3" FEMALE O BA ER 16" x 9-5/8" x 7" x 4-1/2 x 3-1/2" 5/10M MB-230 Multibowl Assembly, u R I ► 01 With MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet BAT GE company cavrmuoHraalo"BIETnnr HoncE Cep"rryN 3017Beb"HupMe,e OE mmOenY. LLC(unpulXaMEwI). NIrIXXb rea eE. TN YXarinNm mnWied In Mb EewnvXbavnpen/mnMrXW eY O�erWery>^eeHY of Baler HUXlws aM Me eXlbbc X4 bEe mE mNbre penelirt of Baker HupBn eM mryrq be JaVlbuOeE. p�vmi�4E.2p,otluwtl, el�eE a mtl N enY XuTeae wXXeul the mPma riXtln wnami W BNd HuyXs r-Irl" n Attachment D OIL SEARCH ALASKA STIRRUP-1 PROGNOSIS ® Oil Search ERA AGE Formation ftMD LITHOLOGY FM TOPS ftMD/ftTVDSS FLUID TYPE W F a Prince Creek Fin. 0 500 nnce reek in. Lower..chrader Blu fM ;Non -Reservoir u uva m. . droca• ea ee inc !Non -Reservoir anus u m. oro m ocar ;Non -Reservoir 0 W U Q U Middle Schrader Bluff Fin 1000 1500 R e <n Lower Schrader Bluff / MCU - u R hs TuluvakFm. 2000 Seabee Fm. 3000 3500 4000 = r — - ` Nanu%huk Fm 4500 5000 5500 6000a'yA 6500 Torok Fin -- - _- -_ - - Shale Carbonaceous Material Siltstone Conglomerate Sand Sand L] Tuff Shell Fragments This is a prognosed stratigraphic column for the Stirrup-1 well. This column gives information about the bulk lithology by zone. Additionally this column identifies the distinct permeable zones that Stirrup-1 is likely to encounter. This column relates to the lithology description in the Frac Sundry. This description shows the absence of a drinking water aquifer and the potential for hydrocarbon bearing zones in the overburden and reservoir section. Attachment E b Q O A w CO LO O O 4 u7 p4 O G rp if1 M Cn CO ca v a 0 cn CU CO v O O C7 Sf+ W W cr A O 4 LJ� U O O U U, CO W U, 0 c.� 0 This is a seismic coherency map extracted along the Nanushuk 0 top structure map. This map identifies faults and other geologic features. There is a % mile radius around the Stirrup-1 well location. This maps demonstrates the absence of geologic faults within a % mile radius of Stirrup-l. Attachment F Redacted M. Guhl 5/6/2022 Schlumbeplep FracCADE* STIMULATION PROPOSAL Operator Well Field Formation Well Location County State Country Prepared for Scott Leahy Date Prepared 11-21-2019 Prepared by Phone E-Mail Address *Mark of Schlumberger Oil Search Stirrup Pikka Nanushuk Alaska United States Service Point Prudhoe Bay, Alaska Business Phone 1907 659 2434 FAX No. 1907 659 2538 Mike Hyatt 9072734748 MHyatt@slb.com Disclaimer Notice This information is presented In goad 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, maybe 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 bythe treatment proposed herein it is the Operator's respGrandelityto notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 daysfrom 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 S Well Stirrup chlcmbcrgcr Formation Nanushuk District Prudhoe Bay, Alaska 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) NAN 1 SHALE 3971.0 23.0 0.759 3022 1.178E+6 0.28 100 NAN 1 SHALE 3994.0 5.0 0.740 2957 1.177E+6 0.27 100 NAN 1 SILTY 3999.0 26.5 0.724 2906 1.442E+6 0.27 1000 BASE NAN 1 4025.5 9.9 0.760 3065 1.279E+6 0.29 100 NAN 0.5 TOP 4035.5 3.5 0.813 3282 1.140E+6 0.31 100 NAN 0.5 U DS 4039.0 23.0 0.695 2817 1.881E+6 0.25 700 NAN 0.5 SS 4062.0 8.3 0.722 2937 1.699E+6 0.26 1000 NAN 0.5 SS 4070.3 20.2 0.706 2882 1.746E+6 0.25 1000 NAN 0.5 DS 4090.5 29.3 0.682 2799 1.765E+6 0.25 700 NAN 0.5 DS 4119.9 24.0 0.698 2883 1.812E+6 0.25 700 NAN 0.5 4143.9 10.1 0.676 2806 1.805E+6 0.25 1200 NAN 0.5 4154.0 26.0 0.636 2651 1.749E+6 0.25 1200 NAN 0.5 L CS 4180.0 8.0 0.661 2765 2.023E+6 0.24 1200 NAN 0.5 L SS 4188.0 22.0 0.715 3000 1.856E+6 0.26 1000 NAN 0 TOP 4210.0 10.0 0.696 2932 1.851E+6 0.25 700 NAN 0 CS 4220.0 10.0 0.649 2741 1.663E+6 0.26 1200 NAN 0 CS 4230.0 36.8 0.626 2660 1.758E+6 0.24 1200 NAN 0 BASE TN 4266.8 13.2 0.648 2771 2.383E+6 0.24 1200 NAN O B CS 4280.0 9.9 0.662 2835 2.385E+6 0.24 1200 NAN 0 B DS 4289.9 4.2 0.693 2974 2.137E+6 0.25 700 NAN 0 B CS 4294.0 12.0 0.659 2833 2.126E+6 0.24 1200 NAN 0 B DS 4306.0 22.1 0.693 2990 1.965E+6 0.25 700 NAN 0 B SS 4328.1 3.1 0.733 3172 1.802E+6 0.27 1000 NAN 0 B CS 4331.3 16.6 0.614 ' 2665 1.660E+6 0.24 1200 NAN 0 B CS 4347.9 14.0 0.650 2831 2.007E+6 0.24 1200 NAN 0 B DS 4361.8 17.2 0.668 2919 1.921 E+6 0.24 700 NAN 0 B DS 4379.0 11.0 0.686 3009 1.738E+6 0.25 700 NAN OA TOP 4390.0 14.8 0.631 2776 1.848E+6 0.23 1200 NAN OA U DS 4404.8 38.7 0.678 3000 2.069E+6 0.24 700 NAN OA U DS 4443.4 39.6 0.695 3102 2.001E+6 0.25 700 NAN OA SS 4483.0 11.0 0.718 3224 1.917E+6 0.26 1000 NAN OA SS 4494.0 14.0 0.704 3170 2.009E+6 0.25 1000 NAN OA SS 4508.0 18.2 0.695 3140 2.103E+6 0.26 1000 NAN OA DS 4526.2 7.1 0.669 3030 2.189E+6 0.24 700 NAN OA CS 4533.3 6.7 0.566 - 2567 2.472E+6 0.22 1200 NAN OA CS 4540.0 59.2 0.595 2721 1.759E+6 0.24 1200 NAN OA CS 4599.2 10.8 0.618 2844 2.203E+6 0.23 1200 Attachment G Schlumberger-Private Client Oil Search Schlumbcrgcr Well Stirrup Formation Nanushuk District Prudhoe Bay, Alaska Formation Transmissibility Properties Zone Name Top TVD (ft) Net Height (ft) Perm (md) Porosity 1%) Res. Pressure (psi) Gas Sat. M Oil Sat. 1%) Water Sat. M NAN 1 SHALE 3971.0 0.1 0.001 18.5 2071 65.0 10.0 25.0 NAN 1 SHALE 3994.0 0.1 0.001 1 20.1 2078 65.0 10.0 25.0 NAN 1 SILTY 3999.0 10.6 0.001 16.4 2086 65.0 10.0 25.0 BASE NAN 1 4025.5 0.1 0.001 19.2 2096 65.0 10.0 25.0 NAN 0.5 TOP 4035.5 0.1 0.001 18.0 2099 65.0 10.0 25.0 NAN 0.5 U DS 4039.0 16.1 7.000 14.7 2098 j 65.0 10.0 25.0 NAN 0.5 SS 4062.0 3.3 7.000 14.7 2097 65.0 10.0 25.0 NAN 0.5 SS 4070.3 8.1 7.000 15.6 2096 65.0 10.0 25.0 NAN 0.5 DS 4090.5 20.5 5.300 16.5 2095 65.0 10.0 25.0 NAN 0.5 DS 4119.9 16.8 2.700 16.1 2092 65.0 10.0 25.0 NAN 0.5 4143.9 10.1 10.000 16.6 2091 65.0 10.0 25.0 NAN 0.5 4154.0 26.0 10.500 17.8 2089 65.0 10.0 25.0 NAN 0.5 L CS 4180.0 8.0 2.000 14.3 2088 65.0 10.0 25.0 NAN 0.5 L SS 4188.0 8.8 1.000 12.9 2086 65.0 10.0 25.0 NAN 0TOP 4210.0 7.0 2.500 15.1 2085 65.0 10.0 25.0 NAN 0 CS 4220.0 10.0 15.000 16.9 2084 65.0 10.0 25.0 NAN 0 CS 4230.0 36.8 15.000 17.7 2081 65.0 10.0 25.0 NAN 0 BASE TN 4266.8 13.2 2.000 14.9 2078 65.0 10.0 25.0 NAN 0 B CS 4280.0 9.9 4.000 16.7 2077 65.0 10.0 25.0 NAN 0 B DS 4289.9 2.9 5.000 17.8 2076 65.0 10.0 25.0 NAN 0 B CS 4294.0 12.0 2.000 14.6 2075 65.0 10.0 25.0 NAN 0 B DS 4306.0 15.5 1.000 13.9 2073 65.0 10.0 25.0 NAN 0 B SS 4328.1 1.2 0.500 13.6 2071 65.0 10.0 25.0 NAN 0 B CS 4331.3 16.6 30.00 0 20.4 2070 65.0 10.0 25.0 NAN 0 B CS 4347.9 13.0 5.000 16.8 2068 65.0 10.0 25.0 NAN 0 B DS 4361.8 12.0 5.500 16.5 2066 65.0 10.0 25.0 NAN 0 B DS 4379.0 7.7 7.000 17.2 2064 65.0 10.0 25.0 NAN OATOP 4390.0 14.8 22.000 19.7 2062 65.0 10.0 25.0 NAN OA U DS 4404.8 27.1 3.000 15.6 2058 65.0 10.0 25.0 NAN OA U DS 4443.4 27.7 1.000 14.2 2051 65.0 10.0 25.0 NAN OA SS 4483.0 4.4 0.500 13.0 2047 65.0 10.0 25.0 NAN OA SS 4494.0 5.6 0.300 13.3 2045 65.0 10.0 25.0 NAN OA SS 4508.0 7.3 0.100 12.5 2042 65.0 10.0 25.0 NAN OA DS 4526.2 5.0 1.000 13.1 2040 65.0 10.0 25.0 NAN OA CS 4533.3 6.7 10.000 17.0 2041 65.0 10.0 25.0 NAN OA CS 4540.0 59.2 25.000 19.5 2056 65.0 10.0 1 25.0 NAN OA CS 4599.2 10.8 5.000 16.5 2072 65.0 110.0 25.0 Attachment G Schlumberger-Private Client Oil Search Schildergcr Well Stirrup Formation Nanushuk District Prudhoe Bay, Alaska Section 2: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (Xr) of 226.3 ft with an average conductivity (K,w) of 10995 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 175 20.0 0.00 1.0 PPA 25.0 YF120ST 120 20.0 CarboLite 16/20 1.00 2.0 PPA 25.0 YF120ST 129 20.0 CarboLite 16/20 2.00 4.0 PPA 25.0 YF120ST 191 20.0 CarboLite 16/20 4.00 6.0 PPA 25.0 YF120ST 178 20.0 CarboLite 16/20 6.00 8.0 PPA 25.0 YF120ST 185 20.0 CarboLite 16/20 8.00 10.0 PPA 25.0 YF120ST 103 20.0 16/20 CarboBond Lite 10.00 FLUSH 25.0 WF120 37 30.0 0.00 Please note thatthis pumping schedule is under -displaced by 5.0 bbl. Fluid Totals 1081 bbl of YF120ST 37 bbl of WF120 Proppant Totals 1581001b of CarboLite 16/20 40000lb of 16/20 CarboBond Lite Pad Percentages % PAD Clean 16.2 % PAD Dirty 1 13.6 Attachment G Schlu mberger-Private Client Oil Search Well Stirrup Formation Nanushuk District Prudhoe Bay, Alaska Schlumhcrgcr 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. (lb) Avg. Surface Pressure (psi) Step Time (min) Cum. Time (min) PAD 175 175 175 175.0 0 0 2773 7.0 7.0 1.0 PPA 120 295 125 300.0 5029 5029 2710 5.0 12.0 2.0 PPA 129 423 140 440.0 10811 15840 2716 5.6 17.6 4.0 PPA 191 615 225 664.9 32155 47995 2943 9.0 26.6 6.0 PPA 178 793 225 889.7 44880 92875 3228 9.0 35.6 8.0 PPA 185 978 250 1139.5 65295 158170 3447 10.0 45.6 10.0 PPA 103 1081 150 1 1289.3 40000 198170 3546 6.0 51.6 FLUSH 37 1117 37 1326.0 0 198170 )" 2947 1.5 53.0 Attachment G Schlumberger-Private Client Oil Search SGhl�� rger Well Stirrup Formation Nanushuk District Prudhoe Bay, Alaska 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 ---- _-------------------- 4331.3 ft Initial Fracture Bottom TVD____________________ 4347.9 ft Propped Fracture Half -Length________________ 226.3 ft EOJ Hyd Height at Well_________________________ 249.4 ft Average Propped Width______________________ 0.215 in Net Pressure _____________________ 420 psi Max Surface Pressure___________________________ 3585 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 56.6 11.2 0.262 168.4 2.33 183.1 7943 56.6 113.2 11.6 1 0.268 231.5 2.40 188.3 9133 113.2 169.8 12.3 0.242 212.1 2.17 220.5 17098 169.8 226.3 3.3 0.115 137.3 1.24 286.9 8083 Attachment G Schlumberger-Private Schlumherger Client: Oil Search Alaska Well: Stirrup Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -Job Well Completed: 3/14/2020 Date Prepared: 11/19/2019 2:19 PM Report ID: RPT-64248 Name & Volume WF120:YF120ST 64,050 Gal Additive B484 DescriptionFluid Additive Enzyme Breaker B484 0.03 Gal / 1000 Gal Volume 1.6 Gal F103 Surfactant 1 Gal / 1000 Gal 64.1 Gal J450 Stabilizing Agent 0.5 Gal / 1000 Gal 32.0 Gal J475 Breaker 3 Lb / 1000 Gal 192.1 Lb J511 Stabilizing Agent 2.7 Lb / 1000 Gal 173.2 Lb J532 Crosslinker 5.4 Gal/ 1000 Gal 346.5 Gal J580 Gelling Agent 20 Lb/1000Gal 1,281.0 Lb L065 Scale Inhibitor 2 Gal / 1000 Gal 128.1 Gal M002 Additive 0.5 lb / 1000 Gal 28.9 Lb M275 Bactericide 0.3 Lb / 1000 Gal 19.2 Lb S123 Activator 0.5 Gal / 1000 Gal 32.4 Gal S522-1620 Propping Agent varied concentrations 160,000.0 Lb S526-1620 Propping Agent varied concentrations 40,000.0 Lb The total volume listed inthe 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 - 72 % 66402-68-4 Ceramic materials and wares, chemicals - 27 % 9000-30-0 Guargum <1 % 56-81-5 1, 2, 3 - Propanetriol < 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 % 67-63-0 Propan-2-ol <0.1 % 50-70-4 Sorbitol < 0.1 % 7727-54-0 Diammonium peroxodisulphate <0.1 % 68131-40-8 Alcohols, c11-15-secondary, ethoxylated < 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 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 (impurity) <0.001 % 10377-60-3 Magnesium nitrate <0.001 % 14807-96-6 Magnesium silicate hydrate (talc) <0.001 % 26172-55-4 5-chloro-2-meth I-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <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 Hemicellulase enzyme <0.0001 % 64-19-7 Acetic acid (impurity) < 0.0001 % 2634-33-5 1,2-benzisothiazolin-3-one Total < 0,00001 % 00% 0Schlumber er2019.Usedb Oil Search Alaska Attachment H g y y permission. Page: 1/ 2 Schlumberger Client: Oil Search Alaska Well: Stirrup Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -Job Well Completed: 3/14/2020 Date Prepared: 11/19/2019 2:19 PM Report ID: RPT-64248 . 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-Chemlcols 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 Stirrup 1 ST-1 Clean-up and Test Summary TABLE OF FLOW PERIODS (15.5 Day) 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 to avoid damage to proppant pack and to minimize —24 - 48 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 IShut in for Build-up /Analysis Well Test (Main Flow) I Conduct 6 day flow test as per table below or as 3 rd Party Oil & Gas Samples for PVT, EOR, & SCAL will be taken at the Separator as per Reservoir Engineer's direction Clean-uF Initial Floes 144 Main Flo" Max Rate Rate# Flow Rate BBL/D Duration (hours) 1 1500 24 2 2500 24 SI 0 24 3 800 144 SI 0 144 4 1 6000 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 8.9 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 2500 BPD & 2.5 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: As per sampling table below. Surface• Flow Somple Lab 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 (1 Oil API Hourly Separator 1000ml Nalgene PTS Gravity Bottle Salinity H2O % Hourly Separator NA NA PTS Perform hourly or as Chlorides H20 production allows C Ranarex Gas Hourly Separator NA NA PTS .a 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 .800 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• . • Program Flow Sample Lab Number/ Cacoilon Volume Sampling Collection Comments Period Type I Analysis Frequency Container Vendor WC, Centrifuge Utilize EB as necessary, BS&W 30minute Choke 100ml PTS document chemicals in Solids Tube job log Oil API Hourly Separator 100ml PTS Gravity Salinity H20%, Hourly Separator NA NA PTS Perform hourly or as pH. H2O production allows T Ranarex Gas Eve ry4 Separator NA NA PTS _ Gravity hrs Q Glass C Sample H2S, CO2 Hourly Separator NA NA PTS c Tube Dead Mid flow DOT Ten containers total Crude Facilities period Stock Tank 5OGal Approved PTS (7-Facilities, 3 Core p S-gal Steel studies) Party Flow • Period Study Sample Volume 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 Luxfer cylinders (each filled with 201iter gas) Document sampling location, time, pressure, and temperature Lu Wettability Surface (4) 1-litre polyproplyene (non -pressurized) TContingencyDownhole Sample Study Sample Volume PVT, EOR, Downhole 7200cc (Volume dependant upon MDTsampling results -to be clarified by OS SCAL Reservoir Reservoir Engineer. Facilities requires 1SOOccminimum, prefers 3000cc) 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 Stirrup 1 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. Qom, 3. RIH with E-line perforation guns and perforate the 7" 26# @—4,387'-4,407' MD (Actual e placement TBD after drilling) �- Ic_� &' 44 il3 y ;" 4. RIH with 3-1/2" 9.2# completion and jewelry. — �, ., 5. Landing tubing hanger and test upper and lower seals to 250 psi/5min and 5,000 psi/30 min. Chart pressure test. 6. Bull head freeze protect into annulus—1,500' TVD. /'1Cv/Z e 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. m t i —T (5,700 psi MAWP — 2,600 psi IA)*1.1 = 3,410 psi (Testing tubing to 3,500 psi) MIT 9. Slowly increase IA pressure to 3,100 psi and hold for 30 min. Chart pressure test. MIT -IA, annulus integrity test per AOGCC. AGc,C_C 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—1,500' TVD. 13. RIH and set #1 XN plug @—4,348' 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. �y V 20. Drilling Rig demob. 21. Pull TWCV 22. Rig up sickline to retrieve X/XN plugs. !N� 23. Rig down slickline �J( 24. Shut in well and rig down lines. cl 25. Secure well, prepare for frac operations. Attachment J Stirrup 1 Fracturing Procedure Held IA IA PRV (psi) GORV (psi) Pump Trip Pressure Pressure (psi) _ (psi) Job 2,600 2,900 i 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 4,335 4,335 249.4 • 226.3 25 3,585 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 2,900psi. 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 GORY 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. R 9. Open well head and pump Datar FRAC. 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 completion of frac, isolate well head, bleed off line pressure, rig down frac equipment, and demobilize frac equipment from wellsite. Stirrup 1 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. Attachment J Stirrup: HP Line PRV Rigup Stirrup 1 Nanushuk Draft V4 11.13.19 3 %" 9.2 ppf L80 R3 Vamtop Tubing Surf. Casin 9-5/8" 40# L80 F 2,650' MD/T` Planned Perforal -4,W- MD 20', 6spf, 60 degree '/z". 2.813" Polish Bore 'X' Landing Nipple 00' MD/TVD 1-'/2" cable clamps: 'lot: 0.433" ('/4') Encap gauge line ELM, 3-'/2" x 1", 1" Dummy Valve 000' MD/TVD 0° Inc '/2". 2.813" Polish Bore 'X' Landing Nipple--4304' MD/TVD '/2" Tubing P/T Gauges - —4312' MD/TVD W Tubing P/T Gauges - —4323' MD/TVD ''/2" X 7" PHL Retrievable Packer - --4341' MD/TVD '/2 -", 2.813" Polish Bore, 2.75" No -Go `XN' anding Nipple - —4358' MD/TVD /LEG — —4365' MD/TVD /tea ,n-FS "i3Z — '43-1 S-' 26# L80 R3 Vamtop HC 6,000' MD/TVD 8 '/2" Open Hole 0° Inc Confidential Attachment L Davies, Stephen F (CED) From: Williams, Rob <Rob.Williams@oilsearch.com> Sent: Wednesday, February 26, 2020 3:43 PM To: Schwartz, Guy L (CED) Cc: Davies, Stephen F (CED); Kuck, Marc; Kono, Randy Subject: RE: Stirrup 1 (PTD-153) Cement Evaluation Logs Thank you for the verbal approval Guy Perforation interval is confirmed as below: 4325-4345' MD. I spoke to SLB and there was no magnetic CCL tool run on the USIT/CBL log. Instead they use the ultra -sonic tool to create a CCLU which is on the USIT log. Plan for perforating is to correlate back to the first open hole wireline log with GR. The perforation wireline toolstring will include a GR and magnetic CCL so we could also use the USIT CCLU (which was depth shifted back to the first open hole run) if needed but base plan is to use the GR. I would agree that a magnetic CCL on the USIT/CBL log would have been best practice. Thanks for all your help, any issues please let me know. Rob. ROB WILLIAMS I SENIOR DRILLING ENGINEER I OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 1 Mob: +1 907 830 2209 Email: rob.williamsCd)oilsearch.com I Web: www.oilsearch.com From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Wednesday, February 26, 2020 1:51 PM To: Williams, Rob <Rob.Williams@oilsearch.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Kuck, Marc <Marc.Kuck@oilsearch.com>; Kono, Randy <Randy.Kono@oilsearch.com> Subject: [EXTERNAL] RE: Stirrup 1 (PTD-153) Cement Evaluation Logs Rob, Bond logs look good. You have verbal approval to perforate Stirrup 1 from 4325-4345' and as proposed below. You also have approval to run the completion (up to de-mobing the rig) . Send us the MIT -IA and MIT -T charts as soon as completed also. As we discussed please check with SLB about presenting the CCL log. It wasn't on the Mitquq ST well either. Casing Collars are supposed be on all cased hole tie-in logs. There isn't much GR character so would be very useful for tying in the perforation guns. 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.gov). From: Williams, Rob <Rob.Williams@oilsearch.com> Sent: Wednesday, February 26, 2020 10:49 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Kuck, Marc <Marc.Kuck@oilsearch.com>; Kono, Randy <Randy.Kono@oilsearch.com> Subject: Stirrup 1 (PTD-153) Cement Evaluation Logs Hi Guy, Please find attached the field prints of the USIT and CBL logs that were conducted last night. First stage job looks good and the second stage has good cement across the 9-5/8" shoe but the lead slurry appears to be a similar result to Mitquq. The USIT was run about 43hrs after the second stage cement was in place. For reference, depths in the well are as follows: 2693' 9-5/8" shoe 2830' 7" ES -cementer stage tool 4949' 7" shoe, top plug tagged at 4818' The tentative perforation depths planned for Stirrup 1 are 4325 - 4345' MD. We have a couple of meetings today to confirm this depth but this is the current planning if there is a change it should be very minor. I'll confirm the exact perforation interval with you but wanted to get the cement logs through to you so that you have some time today to look at them. Pending this perforation depth confirmation. We would like to request verbal approval to perorate the well and run the 3-1/2" completion as per the frac sundry submitted. Any questions or concerns please let me know. Thanks, Rob. ROB WILLIAMS I SENIOR DRILLING ENGINEER I OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 1 Mob: +1 907 830 2209 Email: rob.williamsCaDoilsearch.com I Web: www.oilsearch.com ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your system. The views expressed by the sender are not necessarily those of Oil Search Limited unless otherwise specifically stated. We use virus scanning software but exclude all liability for viruses or similar in any attachment. Think of our environment before you print this e-mail ************************************************************************************************** ************* ************************************************************************************************** ************* This e-mail may be confidential and/or privileged. Only the intended recipient may access or use it. If you are not the intended recipient, please notify us promptly and delete this e-mail and its attachments from your f rilI`S'y51, -1 V-1 1.11 9 li -! - Iff fit IB l l l Schwartz, Guy L (CED) From: Williams, Rob <Rob.Williams@oilsearch.com> Sent: Tuesday, February 25, 2020 9:05 AM To: Schwartz, Guy L (CED) Cc: Davis, Rachel Subject: PTD #219-153 Stirrup 1 Update Feb 24, 2020 Hi Guy, Please see update on Stirrup below. Summary of Period 0000 to 2400 Hrs on Feb 24th Sir' Perform 7" casing stage 2 cement job per program: pump 30bbls 11.5 spacer, 80.6bbls of 12.Oppg lead cement (2.4 ft3/sack yield), 22.3bbis of 15.3ppg tail slurry (1.24ft3/sack yield), displace with 110bbls 10.3ppg MOBM FCP 630psi. Full returns, no losses, 30bbls spacer and 22bbis cement returned to surface. Bump plug 30 strokes over calculated, pressure up to 1800psi to close stage tool. Check for flow — none, tool is closed. CIP 05:00 hrs. RD cementers. Test 7" wellhead csg packoff. Good test. Change out upper rams to 2 7/8" x 5" VBRs. Test upper VBRs and annular preventer.- Good tests. Install 6.375" wear bushing. PU & MU 6 1/8" Clean Out BHA. RIH. Tag top of ES cementer @ 2830'. Drill plug @ 40-80 RPM, 1-3K TQ. Continue to wash down to 2845'. * Loaded & shipped Weatherford 7" csg handling equipment, 100%BOS equipment, 100% dragon rails, 60% mud product, assorted XOs / tools and 290 bbls 10.3 PPG MOBM. Any questions or concerns please let me know. Thanks, ROB WILLIAMS I SENIOR DRILLING ENGINEER OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 Mob: +1 907 830 2209 Email: rob.williams(ccDoilsearch.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 ************************************************************************************************** ************* Schwartz, Guy L (CED) From: Williams, Rob <Rob.Williams@oilsearch.com> Sent: Monday, February 24, 2020 12:37 PM To: Schwartz, Guy L (CED) Cc: Davis, Rachel Subject: PTD #219-153 Stirrup 1 Update Feb 21-23, 2020 Hi Guy, Please see update on Stirrup below. Details on 7° cement job are below Summary of Period 0000 to 2400 H`rs on Feb 21st RIH w/ 8 1/2" Clean Out BHA #9 f / 3723' t/ 4740'. RU & Circulate out gas from well through choke. Max gas 3812 units. RIH f/ 4740' t/ 4921'. Wash do t/ 4960' TD. Circulate BU x 4 while working pipe f/ 4960' t/ 4855'. Max gas 1628 units down to 278 units after circ. POOH on elevators, racking back 4" HWDP. LD 5" HWDP, Jars, Collars, Stabilizers & bit. Pull wear bushing w/ GE Vetco Grey Rep. Set test plug. CO upper pipe rams f/ 2 7/8" x 5" t/ 7" for casing run. RU 7" & 4" test jts w/ XOs. RU all test equipment. Shell test all BOP equipment. * Sent in 48 hour notification to AOGCC for upcoming BOP test on 2/22/2020 06:00 hrs. ** Test witness waived by Bob Noble AOGCC Representative. Summary of Period 0000 to 2400 Hrs on Feb 22"d Complete RU all BOP test equipment. Test BOPS per AOGCC PTD. Tests charted & performed @ 250/ 3500 PSI for 5 mins. -Lower IBOP failed. * Test witness waived by Bob Noble AOGCC Inspector. R & R IBOP valves. Re -Test upper & lower IBOPs @ 250/ 3500 PSI for 5 mins. * Good tests. RD test equipment. RU Weatherford casing tools & equipment for 7" casing run. Run 7", 26#, L-80 Vam Top HC casing to 2065' MD. r Summary of Period 0000 to 2400 Hrs on Feb 23fd / 3 Sy �`43 c 7 Run 7", 26#, L-80 Vam Top HC casing f/ 2065' t/ 4948.69'. MU and land casing hanger in wellhead. Total of 1.5bbls of mud lost while running casing. Circulate BU. RD casing handling equipment & CRT. RU cement head, manifold & hose. Continue CBU while waiting on cement truck mechanical issue. Hold PJSM. Perform 7" casing stage 1 cement job per program: pump 30bbls 11.5 spacer, 15.4bbis of 12.Oppg lead cement (2.19 ft3/sack yield), 44.5bbls of 15.3ppg tail slurry (1.24ft3/sack yield), displace with 186bbls 10.3ppg MOBM ICP 400psi, FCP 988psi. Noted 22bbls losses on final displacement. Bump plug on calculated strokes, check floats — holding. CIP 17:00 hrs. Increase to 3262 PSI to open ES cementer. CBU, 5bbis cement returns observed at surface. Continue to circulate while WOC and prep for 2nd stage cement job. * Loaded & shipped out MWD unit & tools, 60% BOS equipment. Since midnight last night we have pumped the second stage cement job as follows: Perform 7" casing stage 2 cement job per program: pump 30bbls 11.5 spacer, 80.6bb►s of 12.Oppg lead cement (2.4 ft3/sack yield), 22.3bbls of 15.3ppg tail slurry (1.24ft3/sack yield), displace with 110bbls 10.3ppg MOBM FCP 630psi. Full returns, no losses, 30bbls spacer and 22bbls cement returned to surface. Bump plug 30 strokes over calculated, pressure up to 1800psi to close stage tool. Check for flow — none, tool is closed. CIP 05:00 hrs. Any questions or concerns please let me know. Thanks, Rob. ROB WILLIAMS SENIOR DRILLING ENGINEER I OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 Mob: +1 907 830 2209 Email: rob.williamsCoioilsearch.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 ************************************************************************************************** ************* Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Friday, February 21, 2020 1:56 PM To: Boyer, David L (CED) Subject: FW: PTD #219-153 Stirrup 1 Triple Combo and Mud Log Attachments: stirrup- 1_wr.las; STIRRUP_1_MasterLog_4960ft_18Feb2020.pdf; STIRRUP-1-Basic_WR_Logs-layout.pdf From: Williams, Rob <Rob.Williams@oilsearch.com> Sent: Friday, February 21, 2020 1:53 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Davis, Rachel <Rachel.Davis@oilsearch.com>; Kuck, Marc <Marc.Kuck@oilsearch.com>; Kono, Randy <Randy.Kono@oilsearch.com> Subject: PTD #219-153 Stirrup 1 Triple Combo and Mud Log Hi Guy / Steve, Similar to the Mitquq well, attached is the wireline log data and mudlog for the Stirrup 1 well. The wireline triple combo data includes the data from the 8-1/2" production hole section (no wireline logs in surface hole). The mud log has GR/RES data from surface. We are getting ready to run and cement 7" casing over the weekend. We will provide an update on Monday as to how the casing run goes. We will also provide the cement log (USIT) and MIT for the completion once these are completed. We will likely need a verbal approval to perforate from you once the cement log is complete as we plan to perforate on wireline prior to running the completion string, similar to Mitquq. We anticipate perforating mid -next week sometime. Any issues or concerns please let me know. Thanks, Rob. ROB WILLIAMS I SENIOR DRILLING ENGINEER I OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 1 Mob: +1 907 830 2209 Email: rob.williams((Doilsearch.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 ************************************************************************************************** ************* ^rc --#'1 Regg, James B (CED) From: Boyd, Tom <Tom.Boyd @oilsearch.com> Sent: Monday, January 27, 2020 5:19 AM To: DOA AOGCC Prudhoe Bay; Cook, Guy D (CED); Herrera, Matthew F (CED); jim.reg@alaska.gov; Brooks, Phoebe L (CED) Cc: Williams, Rob; Vaughn, Eddie; US NS Stirrup Wellsite Supervisor Subject: OilSearch Stirrup 1 - Replace Knife valve on Diverter Attachments: DoyonRig 1.ArcticFox_DiverterTest1 _27_20.pdf In preparation to spud the Oil Search Stirrup 1 well, at 20:00 hours (1/26/2020) we flooded the conductor with drilling mud. It was discovered that the knife valve weep_ hole (tattle -tale) was leaking fluid. We drained the riser, functioned the knife valve and raised the closing pressure to 800 psi to retest but the leak continued. We repeated this troubleshooting at 1,000 psi and 1,200 psi with the same results. The diverter knife valve was removed and a photo of the leaking knife valve is attached below. This knife valve was replaced and we then conducted a full diverter test as per AOGCC form 10-425, (the results are attached). The times for the accumulator test and knife valve and annular closing were similar to the test conducted on V the 24th with Inspector Matt Herrera. We then flooded the conductor and the knife valve held. A phone call was then made to our Drilling engineer Rob Williams, 03:30 am on the 272h. Informed him of our findings and progress. He called Guy Swartz with the AOGCC, who said we should contact an Inspector. We then called Guy Cook, who instructed us to send a detailed email describing the events and the completed test form to Jim Regg, the Shared Inspectors email and Phoebe Brooks. We also called the North Slope AOGCC office and left a message. LEAKING KNIFE VALVE (Below) TOM BOYD DRILLING SUPERVISOR OIL SEARCH LIMITED STIRRUP / ARCTIC FOX Tel: +1 (907) 223-7412 Personal Mobile +1 (713) 202-5078 Email: tom.boydCcDoilsearch.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 ************************************************************************************************** ************* ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT INSPECT DATE P.I. SupvJP 7�7LI 1/24/2020 AOGCC INSPECTOR Matt Herrera Comm: Rig on 1 (Arctic Fox) - Coil Tubing Unit? No Rig Contractor EDoyon Rig Representative John Harris Operator each AK Contractor Representative Tom Boyd Well Stirrup #1 - Permit to Drill # 2191530 Sundry Approval # NA Operation Pre -Drilling Inspection Location Stirrup #1 CLOSING UNIT BOP STACK MUD SYSTEM Working Pressure, W/H Flange P Pit Fluid Measurement P - Working Pressure P Working Pressure, BOP Stack P Flow Rate Sensor P - Operating Pressure P Annular Preventer P Mud Gas Separator P Fluid Level/Condition P Pipe Rams NA Degasser P Pressure Gauges P Blind Rams NA Separator Bypass P Sufficient Valves P Locking Devices, Rams NA Gas Detectors P Regulator Bypass P Stack Anchored P Alarms Separate/Distinct P Actuators (4-way valves) P Choke Line P Choke/Kill Line Connections P Blind Ram Handle Cover P Kill Line P Reserve Pits P Control Panel, Driller P Targeted Turns P Trip Tank P Control Panel, Remote P HCR Valve(s) P Firewall P Manual Valves P RIG FLOOR 2 or More Pumps P Flange/Hub Connections P Kelly or TD Valves NA Independent Power Supply P Drilling Spool Outlets P Floor Safety Valves NA N2 Backup P Flow Nipple P Driller's Console P Condition of Equipment L P Control Lines P Flow Monitor P - Flow Rate Indicator P - CHOKE MANIFOLD MISCELLANEOUS Pit Level Indicators P Valves P PPE P Gauges P Remote Hydraulic Choke P Well Control Trained P Gas Detection Monitor P - FOV Upstream of Chokes P Housekeeping P Hydraulic Control Panel P Targeted Turns P Well Control Plan P Kill Sheet Current P Bypass Line P FAILURES: 0 CORRECT BY: COMMENTS Once intial BOP test performed items listed as NA will be inspected 2020-0124_Rig_Doyon 1 _Stirrup-1 _m h rev. 10-04-17 THE STATE 01ALASKC1 GOVERNOR MIKE DUNLEAVY Rob Williams Senior Drilling Engineer Oil Search Alaska 900 E Benson Blvd. Anchorage, AK 99508 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 Re: Exploratory Field, Exploratory Pool, Stirrup 1 Oil Search Alaska Permit to Drill Number: 219-153 Surface Location: 782.43' FNL, 2172.78' FEL, SEC. 8, T8N, R3E, UM Bottomhole Location: 782.43' FNL, 2172.78' FEL, SEC. 8, T8N, R3E, UM Dear Mr. Williams: Enclosed is the approved application for the permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner TA DATED this i 8 day of December, 2019. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL NOV 0 12019 20 AAC 25.005 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if vDII i r s for: Drill El" Lateral ❑ Stratigraphic Test El Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed r es ❑ Redrill ❑ Reentry ❑ Exploratory - Oil FZI Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ . Single Well ❑ 11. Well Name and Number: Oil Search Alaska Bond No. NUSCGS025100 Stirrup 1 3. Address: 900 E Benson Boulevard 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99508 MD: 6000' TVD: 6000' - Undefined 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 782.43' FNL, 2172.78' FEL, Sec 8, T8N, R3E, UM ADL 392044 ' Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 782.43' FNL, 2172.78' FEL, Sec 8, T8N, R3E, UM LONS 19-006(Pending) 31st January 2020 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 782.43' FNL, 2172.78' FEL, Sec 8, T8N, R3E, UM 4419.86 Acres 2172.78' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 53.8' 15. Distance to Nearest Well Open Surface: x- 320371.56 y- 5876287.99 Zone- 41 GL / BF Elevation above MSL (ft): 34.4' to Same Pool: N/A 16. Deviated wells: N/A Kickoff depth: feet , ' ; T7. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: degrebs Downhole: 2683 psi Surface: 2083 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# X56 Welded 120' 0' 0' 120' 120' Grouted to surface 12-1/4" 9-5/8" 40# L80 BTC 2650' 0' 0' 2650'i 2650' 11.0ppg Lead: 3885cuft 15.8ppg Tail: 277cuft 8-1/2" 7" 26# L80 Vam Top HC 6000' 0' 0' 6000' 6000' Stage 1: 12.Oppg Lead: 174cuft 15.3ppg Tail: 391cuft Stage 2:12.Oppg Lead: 371cuft (4,�•�-K 15.3ppg Tail: 108cuft 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 Sketc[E] Drilling Program ❑ Time v. Depth Plot a Shallow Hazard Analysis El Diverter SketchE] Seabed Report ❑ Drilling Fluid Program 0 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: Rob Williams Contact Email: rachel.davis a2 search.com Authorized Title: Senior Drilling Engineer Contact Phone: 907 375 4678 Authorized Signature: f � Date: f 6-t /V • Z C7101 Commission Use Only Permit to Drill Number. �� API Number: Z�� "' " Permit Approval AM I See cover letter for other 50-%L% - =' _l Date: re uirements. q 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: 3 5,e60 ,rt y ` C'] f ' 7 S t Samples req'd: Yes ❑ No ❑ Mud log req'd: Yes [✓� No ❑ 7 H2S measures: Yes ❑ No ❑ Directional svy req'd: Yes ❑ No i 1�Zt 1 -Z S` C' Spacing exception req'd: Yes ❑ No ❑ Inclination -only svy req'd: Yes [ No ❑ L jl Post initial injection MIT req'd: Yes ❑ No ❑ It �L" �� I I APPROVED BY 4 1 Approved O MIS 10 E THE OM S Date. ubmitForm Jhd 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 Stirrup 1 Exploration Well North Slope, Alaska Dear Sir/Madam, I/, Oil Search Nov p 1 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 Stirrup 1 well is a vertical exploration well that targets the Nanushuk Oa formation. The well is 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 January 2020. Oil Search at this time anticipates using the Doyon Arctic Fox rig to drill this well. Well testing is planned for the well and will be addressed in a sundry permit application. At the end of well testing operations, the well is planned to be plugged and abandoned, this 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. In compliance with 20 AAC 25.061 Well Site Surveys, a Shallow Hazard Study covering the Stirrup 1 area has been included in the application. If there are any questions and/or additional information desired, please contact me at (907) 830-2209 or rob.williams(a)oilsearch.com. Respectfully, rf� Rob Williams 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 ORIGINAI.- W) Oil Search Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Stirrup 1 Well Oil Search Attachment 12: Well Schematic Sti rru p 1 Pre -drill Well Schematic Oil Search ftMD Formation Tops Updated Sep. 29 2019 c' 16" Conductor 120' MD/TVD -- 500 ' , •, 3-'/z". 2.813" Polish Bore'X' Landing Nipple 500' MD/TVD Mid e Schrader Iu m 1000 Lower Sc irader u r 6AC - - 1500 - 3 '/2" 9.2# L80 Vam Top Tubing uluva m ��— - 2000 t - 2500----- Surface Casing 9-5/8" 40# L80 BTC 12-'/<" Hole 0 2,650' M D/TVD m DES -Cementer Stage Cement Tool 2750' MD/TVD — 3000 0 GLM, 3-'/2" 3000' MD/TVD J___9�a_b�eem 3-'/z' 'X' Landing Nipple 4304' MD/TVD — 3500 aD Tubing P/T Gauges 4312' & 4323' MD/TVD U 4000 3 '/2' X 7" Packer 4341' MDITVD _ 3-%", 'XN' Landing Nipple 4358' MD/TVD _ - 4500 Nanushuk F m Planned Perforations 4,397'-4,407' MD/TVD — 5000 5500 — 6000 _ _.. Production Casing 7" 26# L80 Vam Top HC 8 %" Hole Shale ■ Carbonaceous Material Sand Tut/ 6,000' M D/TVD l�l Siltstone E.7 conglomerate Sand Shell Fragments Stirrup 1 Permit to Drill - 63 - 01-Nov-19 Oil Search Application for Permit to Drill Stirrup 1 Well Stirrup 1 Permit to Drill - 1 - 01-Nov-19 Oil Search Table of Contents Applicationfor Permit to Drill......................................................................................................................... 3 1. Well Name......................................................................................................................................3 2. Location Summary..........................................................................................................................3 3. Blowout Prevention Equipment Information.................................................................................4 4. Drilling Hazards Information...........................................................................................................5 5. Procedure for Conducting Formation Integrity Tests.....................................................................6 6. Casing and Cementing Program..................................................................................................... 6 7. Diverter System Information..........................................................................................................7 8. Drilling Fluid Program.....................................................................................................................7 9. Abnormally Pressured Formation Information..............................................................................8 10. Seismic Analysis............................................................................................................................8 11. Seabed Condition Analysis............................................................................................................8 12. Evidence of Bonding.....................................................................................................................8 13. Proposed Drilling Program...........................................................................................................9 14. Mud and Cuttings Disposal and Annular Disposal......................................................................10 Attachments..................................................................................................................................................11 Attachment1: Location Maps..........................................................................................................12 Attachment 2: Directional Plan........................................................................................................17 Attachment 3: BOPE Details.............................................................................................................23 Attachment 4: Shallow Hazards Assessment................................................................................... 26 Attachment 5: Drilling Hazards......................................................................................................... 54 Attachment 6: Leak Off Test Procedure: .......................................................................................... 55 Attachment 7: Cement Summary.....................................................................................................56 Attachment 8: Rig Fluid System........................................................................................................ 57 Attachment 9: Prognosed Formation Tops...................................................................................... 59 Attachment 10: Pore Pressure Fracture Gradient Plot....................................................................60 Attachment 11: Independent 3rd Party Pore Pressure Fracture Gradient Plot................................61 Attachment12: Well Schematic.......................................................................................................63 Attachment 13: Formation Evaluation Program.............................................................................. 64 Attachment 14: Wellhead Diagram..................................................................................................65 Attachment 15: Days vs. Depth Plot.................................................................................................66 Stirrup 1 Permit to Drill -2- 01-Nov-19 t 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 Stirrup 1 This will be an exploratory well. 2. Location Summary 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: (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 782.43' FNL, 2172.78' FEL, Sec 8, TBN, R3E, UM NAD 27 Coordinate System N 5,876,287.99 E 320,371.56 Rig KB Elevation 19.4' above ground level Ground Level 34.4' above MSL Location at Top of Productive Interval Reference to Government Section Lines 782.43' FNL, 2172.78' FEL, Sec 8, TBN, R3E, UM NAD 27 Coordinate System N 5,876,287.99 E 320,371.56 Measured Depth, Rig KB (MD) 4,408' Total Vertical Depth, Rig KB (TVD) 4,408' Total vertical Depth, Subsea (TVDSS) 4,354' Location at Bottom of Productive Interval Reference to Government Section Lines 782.43' FNL, 2172.78' FEL, Sec 8, TBN, R3E, UM NAD 27 Coordinate System N 5,876,287.99 E 320,371.56 Measured Depth, Rig KB (MD) 6,000' Total Vertical Depth, Rig KB (TVD) 6,000' Total vertical Depth, Subsea (TVDSS) 5,946' Please refer to Attachment 1: Location Maps for further details. Stirrup 1 Permit to Drill - 3 - 01-Nov-19 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 The proposed well is vertical with no planned deviation. 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 (8) state that the applicant is the only affected owner. There are no other wells within 200 feet of the proposed Stirrup 1 well. The applicant is the only affected owner. Included in Attachment 2 is an anti -collision scan from the Stirrup 1 well location. 3. Blowout Prevention Equipment Information 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; BOP test frequency for Stirrup 1 will be 7-days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 7-day BOP test period should not be requested. Doyon Arctic Fox BOP Equipment: BOP Equipment • Hydril GK annular BOP, 11" x 5000 psi stud x flanged, NACE trim • Hydril V, double gate, manual, 11" x 5000 psi, stud x stud, NACE trim • Mud cross, 11" x 11" x 5000 psi with 2 ea.- 3 1/8" x 5000 psi side outlets, NACE trim • 2 ea. — 3-1/8" x 5000 psi, hydraulically operated gate valves, NACE trim • 2 ea. — 3-1/8" x 5000 psi manual valve, NACE trim • Hydril, V, single gate, manual, 11" x 5000 psi, stud x stud, NACE trim Choke Manifold • 1 ea. - 2 1/16" x 5000 psi, manual gate valve, NACE trim • 13 ea. - 3 1/8" x 5000 psi, manual gate valves, NACE trim 0 1 ea. - 3 1/8" x 5000 psi, manual choke • 1 ea. - 3 1/8" x 5,000 psi, remote operated hydraulic choke • Remote choke control panel, located on the drill floor Stirrup 1 Permit to Drill - 4 - 01-Nov-19 W) Oil Search BOP Closing Unit • Oilco, 6 station, 3000 psi, 180 gallon accumulator unit, with a remote control panel in the doghouse. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back-up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen Please refer to Attachment 3: BOPE Equipment for further details. 4. Drilling Hazards Information 20 AA 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 2,683 psi at 6,000' MD/TVD (8.6ppg EMW base Nanushuk/top Torok formation) Maximum surface pressure 2,083 psi (0.10 psi/ft gas gradient to surface, 6000' MD/TVD) Rams test to 3,500 psi / 250 psi Planned BOP test pressure [Test pressure driven by 7" casing test] Annular test to 2,500 psi / 250 psi Integrity Test — 8-1/2" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 3,000 psi surface pressure [Test pressure driven by 50% of surface casing yield] 7" Casing Test 3,500 psi surface pressure [Test pressure driven by annular pressure during frac. job] (B) data on potential gas zones; and There is no expected gas zones in the well. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please refer to Attachment 4: Shallow Hazards Assessment. Please refer to Attachment 5: Drilling Hazards. Stirrup 1 Permit to Drill - 5 - 01-Nov-19 dAh OR Search 5. Procedure for Conducting Formation Integrity Tests 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: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f), Please refer to Attachment 6: Formation Integrity Test Procedure. 6. Casing and Cementing 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: (6) 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, Casina/Tubina and Cement Proaram Casing / Hole Liner / Top op Bottom Size Tbg Wt/Ft Grade Conn Length MD MD / Cement Program O.D. TVDss 20" 16" 84# X52 Welded 100, Surface 120' / 66' Grouted to Surface 11.0ppg Lead: 692bbls, 3885cuft, 12-1/4" 9-5/8" 40# L-80 BTC 2,650' Surface 2,650' / 1605sks ArcticCem, Yield: 2.42 cult/sk 2,596' 15.8ppg Tail: 49bbls, 277cuft, 234sks Type 1/11-1.17 cuft/sk Stage 1: 12.Oppg Lead: 31bbls, 174cuft, 82sks ExtendaCem, Yield: 2.13 cult/sk 15.3ppg Tail: 70bbls, 391cuft, 315sks 8-1/2" 7" 26# L-80 VAM 6000' Surface 6000' / ExpandaCem Class G —1.24 cuft/sk TOP HC 5946' Stage 2: r 12.Oppg Lead: 66bbls, 371cuft, 154sks VariCem, Yield: 2.40 cult/sk 15.3ppg Tail: 19bbls, 108cuft, 87sks ExpandaCem Class G —1.24 cuft/sk Tubing 3-1/2" 9.2# L-80 TAP 4,377' Surface 441377' / n/a 323 Please refer to Attachment 7: Cement Summary for further details. Stirrup 1 Permit to Drill -6- 01-Nov-19 Oil Search 7. Diverter System Information 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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), Doyon Arctic Fox Diverter Equipment: • Hydril annular BOP, model MSP, 21 1/4" x 2000 psi, flanged, NACE trim • 16" 150psi Hydraulically Operated Knife Valve • 16" Diverter Line • Diverter Spool 21 1/4" x 2000 psi with 1 ea. 16" Outlet Please refer to Attachment 3: BOPE for further details. 8. Drilling Fluid Program 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Surface Hole 120' — 2650' MD/TVD Production Hole 2650' — 6000' MD/TVD Mud Type Water based Spud Mud Mineral Oil Based Mud Mud Properties: Mud Weight 10.5ppg CO.5prg,- ; Funnel Vis 85-175 seconds 50-80 seconds PV 10-25 25-40 YP 30-40 15-25 API Fluid Loss < 12 ml/30min n/a HPHT Fluid Loss n/a < 5 ml/30min pH > 9.0 n/a M BT 20-30 n/a Electrical Stability n/a > 600 Oil:Water Ratio n/a 80:20 Water Phase Salinity n/a 250-270k Low Gravity Solids < 10% < 6.5% A copy of drilling fluid system on the Doyon Arctic Fox rig is contained in Attachment 8: Rig Fluid System. Stirrup 1 Permit to Drill -7- 01-Nov-19 J Oil Search 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f), Please refer to Attachment 9: Prognosed Formation Tops, Attachment 10: Pore Pressure Fracture Gradient Plot and Attachment 11: Independent 3r1 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 Attachment 4: Stirrup 1 Shallow Hazards Assessment. 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, on analysis of seabed conditions as required by 20 AAC 25.061(b); The Stirrup 1 Well is to be drilled from an onshore location 12. Evidence of Bonding 20 AAC 25.005 (c) 7� 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 forth coming. Stirrup 1 Permit to Drill - 8 - 01-Nov-19 OU Search 13. Proposed Drilling Program 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: (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 Stirrup 1 is listed below. Please refer to Attachments 12 -15 for a Well Schematic, Formation Evaluation Program, Wellhead Diagram and Days vs. Depth Plot. Proposed Drilling Program: 1. Drill/drive 16" conductor to —120' MD/TVD. Cement to surface. Install Cellar. 2. Move in and rig up Doyon Arctic Fox Rig on the Stirrup 1 well location. 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. f 7. Spud well and drill vertical hole section as per well plan to ^2650' MD/TVD. Monitor hole conditions for surface hole drilling hazards identified in Attachment 5. Make directional corrections and wiper trips as required. Circulate and condition hole and then POOH. 8. Run 9-5/8" surface casing as per casing tally and land on pre -installed landing ring. Circulate and condition mud prior to commencing cement job. 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 vt,. �nw regulations. Provide AOGCC 48hrs notice for _witnessine 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 10.5ppg 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 q 13. Drill 8-1/2" vertical hole section as per well plan to core point at —4225' MD/TVD. Monitor hole conditions for production hole drilling hazards identified in Attachment 5. Make directional corrections and wiper trips as required. Circulate and condition hole and then POOH. Stirrup 1 Permit to Drill - 9 - 01-Nov-19 GOB Oil Search 14. Make up 8-1/2" coring assembly and run in hole. Circulate and condition hole prior to dropping coring ball. 15. 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. 16. At surface examine core returns and repeat coring runs as required until objectives have been met or allotted time has elapsed. 17. 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 —6000' MD/TVD. Circulate and condition hole and then POOH. 18. Rig up wireline and complete open hole wireline as per formation evaluation program. 19. Run 7" production casing as per casing tally, land casing on wellhead mandrel hanger. Circulate and condition mud prior to commencing cement job. G �� ` 75L-,' " 20. 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. 21. Make up 6-1/8" clean out BHA. RIH, drill out staged cement tool and then clean out to 7" _ shoe track. Displace well to 9.5ppg brine. t �C 22. Pressure test 7" casing to 3500psi for 30mins. POOH. 23. Rig up wireline and complete cased hole cement ev luation and VSP logs. • fv !� 24. Prepare for completion operations. 14. 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. Stirrup 1 Permit to Drill - 10 - 01-Nov-19 Oil Search Attachments Stirrup 1 Permit to Drill - 11 - 01-Nov-19 Oil Search Attachment 1: Location Maps Stirrup 1 Permit to Drill - 12 - 01-Nov-19 I I I I I I I COLVILLE RIVER I I I I I I L c� I I ` I GREATER _ MOOSES I -------I r-` TOOTH i NUIQSUT I I I L-- I I I I I I J,/ I I -------- I I * HS•1 � Q•9 I —I �AIRSTNiP � ----- �` I PIKKr\ / I ..A.. PikkaC I t\L_�—_ I I Q-5 y �r L i PLACER i I _ � I 0 *Q-301 I i Mitquq 1 j WSAX td I jP I �� IJ I I , I FOUR CGRi I I I I I *PikkalB — I ' --- -----1 1S.MILUVEACHj MILNE iH i POIN F S I I W SAKit 2LV tiG riH �— w SaK s KUPARUK RIVER I I L I---------/ _ I I I wr-ot I I I J I I wsax t, wsaKzo 4Ax is �I I �1 OIL SEARCH I.I.C. ION Project Location ® 2011-2019 DRILLED WELLS L _.', PRODUCTION UNIT � NS EXISTING FACILITY — NS EXISTING GRAVEL ROADS NPR BOUNDARY 2019-2020 EXPLORATION ATION C C AMPAIGN PROPOSED CAMPAIGN OVERVIEW � I �r EXPLORATION ICE ROADS O EXPLORATION DRILL SITE ---NSEXISTINGPIPELINES -A ',v,._iOILSEARCHLEASES H w e 0 1 2 GCS: NAD1—Siate1—Alavk,4FWS500/Feat I�Mze: � Oil Search s ®gbmetars n.m ostr sac oomroccci ocu9tvz�q �P1ep 'kNmk,k 0 1 2 +.- AS -STAKED STIRRUP 1 LOCATION NAD-83(2011)EPOCH(2010.0000) Alaska State Plane Zone 4 US Survey FT N 5,876,033.51' E 1,460,409.20' EL 34.38' (NAVD88 Utilizing Geoid12B) NAD-83(2011)EPOCH(2010.0000) N 70°04'01.500" W 151 °26'30.099" NAD-27 Alaska State Plane Zone 4 US Survey FT N 5,876,287.99' E 320,371.56' - NAD-27 N 70°04'02.759" W 151°26'19.028" SEC. 5, T8N, R3E, U. M. SEC. 8, T8N, R3E, U. M. o 500 NUIOSUIT `� RON TSINWELL AT8 OCATION— — VICINITY MAP T8N, R3E SCALE: V = 5 MILES SEC. 8 NOTES 1. DATE OF FIELD SURVEY AUGUST 2 & 4, 2019. 4n 2. BASIS OF COORDINATES PER OPUS SOLUTION OF STATIC GPS OBSERVATIONS ON JULY 2, 2019. 3. WELL LOCATED WITHIN PROTRACTED SEC 8, T8N, R3E, UMIAT MERIDIAN. 782' FROM NORTH SECTION LINE 2173' FROM EAST SECTION LINE n� STIRRUP 1 (AS -STAKED WELL LOCATION) /-•�"""POND PROPOSED 35' WIDE ICE ROAD UMIAQ °~"'�'�"� Oil Search 6700 Arctic Spur Road Anchorage, AK 99518 DATE: (907) 677-8220 SCALE: PROPOSED ICE PAD 1,000' X 1,000' e STIRRUP 1 EXPLORATORY WELL PROPOSED ICE PAD RECONFIGURATION & AS -STAKED WELL LOCATION NORTH SLOPE, ALASKA 10/29/2019 DRAWN BY: FM / MMHN SHEET: AS SHOWN CHECKED BY: KJP JOB No: K Z 150 300 SCALE IN FEET 1 OF 1 80209.19 ® WELL LOCATION 0 EQUIPMENT OUTLINES DICE PAD/ICE ROAD OUTLINES — — ICE ROAD CENTERLINE — - DIVERTER ® 30-FT OFFSET Ile 0 � . Shoe RIG En�O Q O SO se QSatebl F�a�e ResPoo Temp Waste Storage Well Area 1, Well Test Stimulation Office / Shop Equipment / Truck Staging 1 Fuel Storage 1 Camp Camp Comm 0 OIL SEARCH ALASKA I.I.C. N 2019-2020 Exploration Campaign STIRRUP 1 DRILL SITE OVERVIEW (Arctic Fox Rig) 0 20 40 Oil Search Figure X ®Meters GCS: NAD 1927 Sta}ePlane Alaska 4 FIPS 5004 ®Feet DATE: 2019-09-24. REV: 3.2. By JB 0 50 100 Document name: OPS-19-20-P-PE-M_POO_Stirmpl_NAD27 r Stirrup-1 X: 320371.56 Y. 5876287.99 ADL 392044 I ADG 392043 Or d ® OIL SEARCH AASKA I.I.C. WELL SURFACE HOLE SECTION DIMENSION LINE 2019-2020 EXPLORATION 8 APPRAISAL CAMPAIGN TARGET AREA TOWNSHIP L _1 LEASE OUTLINE N STIRRUP 1 WELL PLAN W Oil Search o wo eoo GCS NAD 1927 StatePlane Alaska 4 RIPS 5004 E Metersee} DATE: 11/1/2019. REV:3.0. By: JB S 0 100 zoo Document name: OPS-19-20-W-M_Stirrup l_wellPlan_NAD27 Oil Search Attachment 2: Directional Plan Stirrup 1 Permit to Drill - 17 - 01-Nov-19 Oil Search Stirrup-1 wp03 Proposal Geodetic Report Schlumberger (Def Plan) Client: Oil Search Vertical Section Azimuth: 0.000 ° (True North) , Field: NPR NAD27Z4 Vertical Section Origin: 0.000 ft, 0.000 ft Structure / Slot: Stirrup-1 I Stirrup-1 TVD Reference Datum: Rotary Table Well: Stirrup-1 TVD Reference Elevation: 53.780 it above Unknown Borehole: Stirrup-1 Ground Elevation: 34.380 it above Unknown APW 50103xxxxx00 Magnetic Declination: 15.533' Survey Name: Stirrup-1 wp03 Total Gravity Field Strength: 1001.9854mgn (9.80665 Based) Survey Date: November 01, 2019 Gravity Model: DOX Tort / AHD / DDI / ERD Ratio: 0.000 ° / 0.000 ft / 0.000 10.000 Total Magnetic Field Strength: 57178.995 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angie: 80.466 ° Location Let I Long: N 70' 4' 2.75883•, W 151' 26' 19.02844' Declination Date: January 31, 2020 Location Grid NIE YIX: N 5876287.990 ftUS, E 320371.560 f1US Magnetic Declination Model: BGGM 2019 CRS Grid Convergence Angle: -1.3525' - North Reference: True North Grid Scale Factor: 0.99993666 Grid Convergence Used: 0.0000 ° Version / Patch: 2.10.782.0 Total Corr Mag North• True North: 15.5327 ° Local Coord Referenced To: Well Head Comments MD Incl Azim True TVDSS TVD VSEC NS EW TF DLS Directional Northing Easting Latitude Longitude (ft) (I (I (ft) (ft) (ft) (ft) (ft) (I (°/100ft) Difficulty Index (ftUS) (ftUS) (N/S °' -) (E/W ° "7 RTE 0.00 0.00 0.00 -53.78 0.00 0.00 0.00 0.00 OM NIA 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 200.00 0.00 0.00 146.22 200.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 400.00 0.00 0.00 346.22 400.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 600.00 0.00 0.00 546.22 600.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 Permafrost Base 685.78 0.00 0.00 632.00 685.78 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.75 W 15126 19.03 800.00 0.00 0.00 746.22 800.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 Mid Schrader Bluff 841.78 0.00 0.00 788.00 841.78 0.00 0.00 0.00 0M 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 1000.00 0.00 0.00 946.22 1000.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 1200.00 0.00 0.00 1146.22 1200.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 LowerSchreder Bluff 1317.78 0.00 0.00 1264.00 1317.78 0.00 0.00 0.00 am 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 1400.00 0.00 0.00 1346.22 1400.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 1600.00 0.00 0.00 1546.22 1600.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 1800.00 0.00 0.00 1746.22 1800.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 Tuluvak 1874.78 0.00 0.00 1821.00 1674.78 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 2000.00 0.00 0.00 1946.22 2000.00 0.00 O.DO 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 2200.00 0.00 0.00 2146.22 2200.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 2400.00 0.00 0.00 2346.22 2400.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2,76 W 151 26 19.03 Seabee 2538.78 0.00 0.00 2485.00 2538.78 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 2600.00 0.00 0.00 2546.22 2600.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 9-5r8 casing 2650.00 0.00 0.00 2596.22 2650.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 2800.00 0.00 0.00 2746.22 2800.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 3000.00 0.00 0.00 2946.2.2 3000.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 3200.00 0.00 0.00 3146.2.2 3200.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 Top Nanushuk 3375.78 0.00 0.00 3322.00 3375.78 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 3400.00 0.00 0.00 3346.22 3400.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 3600.00 0.00 0.00 3546.22 3600.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 Nanushuk_3 3794.76 0.00 0.00 3741.00 3794.78 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 3800.00 0.00 0.00 3746.22 3800.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 4000.00 0.00 0.00 3946.22 4000.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 4200.00 0.00 0.00 4146.22 4200.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 Nanushuk 0 4235.78 0.00 0.00 4182.00 4235.76 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 4400.00 0.00 0.00 4346.22 4400.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 Nanushuk Oa 4407.78 0.00 0.00 4354.00 4407.78 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 4600.00 0.00 0.00 4546.22 4600.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 Tomk 4739.76 0.00 0.00 4686.00 4739.78 0.00 0.00 0.00 OM 0.00 0.00 5876267.99 320371.56 N 70 4 2.76 W 15126 19.03 4800.00 0.00 0.00 4746.22 4800.00 0.00 0.00 0.00 OM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 Drilling Office 2.10.782.0 NPR NAD27Z4\Stirrup-1\Stirrup-1\Stirrup-1\Stirrup-1 wp03 11/1/2019 10:16 AM Pagel of 2 Comments MD Incl Az)m True TVDSS TVD VSEC NS EW TF DLS Directional Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (n) (R) (ft) V) (0/100ft) Difficulty Index (ftus) (nus) (WS °' ") (E/W °' ") 5000.00 0.00 0.00 4946.22 5000.00 0.00 0.00 0.00 0M 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 5200.00 0.00 0.00 5146.22 5200.00 0.00 0.00 0.00 0M 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 5400.00 0.00 0.00 5346.22 5400.00 0.00 0.00 0.00 (IM 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 26 19.03 5600.00 0.00 0.00 5546.22 5600.00 0.00 0.00 0.00 0M 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 5800.00 0.00 0.00 5746.22 5800.00 0.00 0.00 0.00 0M 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 15126 19.03 TD 6000.00 0.00 0.00 5946.22 1 6000.00 0.00 0.00 0.00 0.00 0.00 5876287.99 320371.56 N 70 4 2.76 W 151 2619.03 Survey Error Model: ISCWSA Rev 0 ""° 3-D 95.000 % Confidence 2.7955 sigma Survey Program: Description MD From MD To EOU Freq Hole Size Casing Diameter Expected Max Part (ft) (ft) (It) (in) (In) Inclination Survey Tool Type Borehole / Survey (deal 1 0.000 300.000 1/100.000 12.250 9.625 SLB_INC+TREND Stirrup-1 / Stirrup-1 wp03 1 300.000 2650.000 1/100.000 12.250 9.625 SLB_MWD+SAG Stirrup-1 / Stinup-1 wp03 1 2650.000 2750.000 1/100.000 8.500 7.000 SLB_MWD-INC_ONLY _FILLER Stinup-1 / Stirrup-1 wp03 1 2750.000 6000.000 1/100.000 8.500 7.000 SLB_MWD+SAG SOnup-1 / Stirrup-1 wp03 Legal Description: Surface: 4497.1 FSL 2172.9 FEL S8 T8N R3E UM BHL: 4497 FSL 2173 FEL 8 T8N R3EUM Northing (Y) Easting (X) 5876287.990 320371.560 5876287.990 320371.560 Drilling Office 2.10.782.0 NPR NAD27Z4\Stirrup-1\Stirrup-1\Stirrup-1\Stirrup-1 wp03 11/1/2019 10:16 AM Page 2 of 2 Schfumberger Borehole: Well: Field: Structure: Stirrup-1 (P3) Stirrup-1 NPR NAD83Z4 Stirrup-1 & Magnetic Parameters Surface Location NAD83 Alaska State Plane, Zone 04, US Feet Miscellaneous EWty del: BGGM 2018 Dip: 80.531' Date: 31-Dec-2019 Lat: N 70 4 1.50 Northing: 5 76033.51ftU Grid Con,:-1.3554° Slot: Stbrup-1 TVD Ref: Rotary Table(53.78ft above MSL) gDec: 15.663° FS: 57342.819nT Gravity FS: 1001.985mgn (9.80665 Based) Lon: W 15126 30.10 Easting: 1460409.2ftUS Scale Fact: 0.99993681 Plan: Stirrup-1 wp03 33000 27500 22000 16500 s= 0 0 0 11000 rn x z z 5500 0 -5500 -11000 0 5500 11000 16500 22000 27500 33000 38501 0 5500 11000 16500 22000 27500 33000 38500 EW (ft) Scale = 1:7310.00(ft) 27500 22000 16500 11000 5500 0 -5500 -11000 ig D WO LLJ LL 0 LL 8 I r6 0 — tr epar-iri—on F-ionr - 1.5 i rip. —Fadnr- 0 O O 111) qido(] poinspoIN Stirrup-1 wp03 Anti -Collision Summary Report Ar alyale Date-24hr Time: November 01, 2019-10:10 Analysis Method: Normal Plane Client: ON Search Rate.. -Trajectory: S11-p-1 wIP02 (Def Plan) Field: NPR NAD83Z4 Depth Interval: Every 10.00 Measured Depth (R) Structure: Stinup-1 Rule Set: D&M AnfiColtision Standard S002 v5.1/5.2 Slot: S1nup-1 Mln Pus All local minima Indicated. Wall: Sd_ppI Version /Patch: 2.10.782.0 Borehole: Sunup-1 Database l ProJect: IocalhostAnHIn9-NPR Scan MD Range: 0,00R - 6000.00ft ISCWSA03-D 95.ODO%Confide- 2.7956 sigma, for subject wall, For Tradectory Error Model: offset wells, error model version is specified with each well respectively. OReet Trajectories Summary OMeet Selection Criteria Wellhead distance scan: Restricted within 470105 R Selection fitters: Definitive Surveys - Definitive Plans- Definitive surveys e[dude definitive plane - All Nan-Def Surveys when no Def-Survey is set in a borehole - All Non-Def Plans when no Def-Plan is cal in a borehole ORaet Tr4Jeebry Separation Allow Sep. Controlling "*Mnu Tn eeto Rlsk Leval Alert Status CtCt R MAS R EOU R Dev. R Fact. Rule MDR TVD R Ater! Minor MNor Major Molar Pioneer 1 (OefS .Y) pass 2]9555 32.81 27956.4 27922.7 305WAff MAS =10.00(m) 0.00 0.00 MinPts 2]9500 32.81 279M,1 27911.22 1977.93 MAS=10.00 (m) 1fi48.6S 1648.6s MinPts 0 27917.24 2795005 32.61!27938,2 1973.64 MAS=10.00 (m) 1668.68 1668.68 MINPTO-EOU 2]956.W 32.81 2792352 1687.58 MAS=10.00 im) 2-59 2W'S9 MINPTOEOU 27957.23 32.81 27924.42 1652.00 MAS =10.00 (m) J368.57 3368.57 MINPTO♦:OU 32.81 27924.1 1618.42 MAS=10.00Im) 3758.67 3758.57 Min% 32.81 27924.2 1568,U MAS=10.00(m) 4168,57 416857 MinP1s 32,91 27s24.3 M 149597 MAS=10.00(m) 4608.57 4608.57 MinPh 32A11 279237 1435,27 MAS=10.00(m) 5008.5E 5008.56 MlnPts 2]956.s5 32al 27923.84 1424.28 MAS=10.W(m) 5068,56 506856 MINPTO-EOU 2I964.55 34.09 279/1.50 27939.4] 1267.1 OSF1.50 8000.00 6000.00 MInPI.OSF Horseshoe 1A (Det Survey) Pay: 60788.5 32.81 407]5.81 d0]55.7 3659.85 MAS =10.00 (m) 641.13 661.1J MinPts 4078659 32.81 107]5.81 4w55.]e 3458.44 MAS=10.00(m) mi.12 .51.12 MINPTO-EOU 35fi5fi. 60.38 35fi14.di 355950 988.Y2 OSF1.50 4839.9E 4839.96 Minft Horseshoe Hear Survey) P,y. 40]88.5 32.81 40775.81 40]55.7 3459.85 MAS-10ACI(m) 641.13 641, 13 MinPLL 40788,59 32.81 4077581 40755.78 34SBU MAS=10.00(m) 651.12 651A2 MINPTO-EOU 40723. 32.81 407M, 40690.61 2309A6 MAS=10.00(m) 2502.55 2502.55 MInP 40723,25 32.81 40704.57 40690.45 2304.75 MAS-10.00(m) 2512.20 2512.20 MINPTOEOU 41286.21 37.97 41260.5] 412Q 24 1874.35 OSFI,50 4519.89 4519.89 MlrPti 41283 41.7 412S5] 41241.E 1519.43 OSF1.50 5&3122 5831.22 MinP6 Stony HBI 1(Def Survey) Faso 43497. 32.81 434912 43464, 233076.00 MAS =10.0) (m) 28.18 28.18 Minft 43699.53 3261 43486.)1 43466.72 367318 MAS =t0.001m) 399.67 399.87 MINPTOEOU 43513.]4 32.81 d3495 65 d3600.93 2543. MAS=10.00 (m) 2809le 2009.18 MinPl-OSF 43513. 32.81 43495.3 4M80.6 2542.03 MAS=10.00 (m) 2886.55 2886.55 MlnPls 43513.50 32.81 43495.40 43480.69 2541.E MAS=10.00 (m) 2919.48 2919A8 WnPI.OSF 43513.E 32.81 43495. 434139E 2538.0] MA5=10.00 (m) 3039,48 3039,41 Min% 1351369 J2.81 43495.5 43480.88 2537.SB MA5=10.00 (m) 3049.48 3WAS MINPTO-EOU 43513.77 32,81 4?495. 434B0.96 2523.3fi MAS =10.00 (m) 3259.48 3259.46 MINPTO-EOU 43513. 32.81 4.95, 4-80.8 2503.55 MAS =10.00 (m) 3466.1E 3466.18 Minpb 43513,67 32.8111 434952 CM80.86 250208 MAS=10.04) (m) 3479.48 U a.48 MINPTOEOU 43513.61 32.81 43495.0 43080E 247161 MAS =1000(m) 3709,48 3709.48 MinPu 43513.8 32.81 43484. 43480.61 2448,0E MAS = 10,00 (m) 3. AN 3859.48 Minpu 43513.] 32.81 43484.5 43480.91 2392.49 MAS=10.00Im) 4162.53 41W.63 Mine 43513.] 32.81 43094.3 43400.9 2366.62 MAS -10.00 (m) 4289.48 4289.48 MinPu 43513.1 32.81 43494. /34B0.9 2342.92 MAS=10.00 (m) 4399,48 43MAN MiMu 43513.7 32.81 43493. 43460. 2290.86 MAS =10.00 (m) 4629.48 4629.48 MmPta 03513. 32.81 4m 151 43481.0 2253.07 MAS=1000 (m) 47111 4789,48 MInPts 43218.1 38.13 43193.54 43181,97 1866.95 OSF1.50 fi00000 Woo 00 M'n% Oil Search Attachment 3: BOPE Details Stirrup 1 Permit to Drill - 23 - 01-Nov-19 Hydril 11 ", 5M, Annular BI 3.125" ,5 Hydril 11 ", 5M, Double Rai BOP 3" ID Kill 3.125" ,5M, HCR Valve 3.125" ,5M, Gate Valve - Hydril 11", 5M, Single Ram BOP VALVE SURFACE DIVERTER CONFIGURATION alve 21 1/4. 2000 PSI, MSP HYDRIL BOP/DIVERTER STUDDED TOP/FLANGED BOTTOM DNERTER SPOOLS \ 16" 150 PSI HYDR. OPERATED KNIFE GATE VALVE ACCUMULATOR: TRIPLEX PUMP: AIR PUMP: FLUID RESERVOIR: 11 CTI, 6 STATION 1/208 VAC, 20 HP 2/40 : 1, 8GPM, 3,000 PSI 165 GALLON NITROGEN BACKUP BOTTLES 4 BOTTLES VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 1 ANNULAR I.S��i:IlY1119:1�111:{a IS�I49�111�.1(Q:i9:liklll•li EI!1:111�1:✓♦J:IA$.jIJ�♦_i� REMOTE PANEL IN DOGHOUSE AND UTILITY MODULE MATERIAL LIST Item Description A 3-1 /16" 10M Remote Operated Hydraulic Choke B 3-118" 5M Adjustable Choke 1 2-1116" 5M Manual Gate Valve 2-14 3-1/8" 5M Manual Gate Valve LEDGEND White Handle Valves Normally Open Red Handle Valves Normally Closed OeGASSER 0 Oil Search Attachment 4: Shallow Hazards Assessment Stirrup 1 Permit to Drill - 26 - 01-Nov-19 Stirrup-1 Shallow Hazards Study [September 2019] Oil Search Limited Incorporated in Papua New Guinea ARBN 055 079 868 Contents 1. Executive Summary 2. Introduction 3. overburden Stratigraphy 3.1. Permafrost (Prince Creek Formation) 3.2. Schrader Bluff Formation 3.3. Tuluvak Formation 3.4. Seabee Formation 4. Shallow Hazards Assessment 4.1. Gas Hydrates 4.2. Gas Mud Log Analysis and Casing Design 4.3. Log and Pressure Analysis 4.4. Pore Pressure Fracture Gradient Prediction 4.5. Seismic Analysis 5. Conclusions Stirrup-1 Shallow Hazards - 25 September 2019 2 (1) Oil Search 1. Executive Summary Oil Search Alaska intends to drill Stirrup-1 during the 2019-2020 winter season. This document summarizes a comprehensive offset -well analysis to quantify shallow hazards at the Stirrup-1 well location. This study integrates offset well design, gas mud logs, formation pressure, petrophysical well logs and 3D seismic attributes. Near Stirrup-1 the risk of encountering shallow gas is low. Three of the near offset wells have surface casing set below the Tuluvak and did not encounter appreciable shallow gas; Pioneer 1 (27,959ft), Altamura 1 (37,765ft), Flat Top 1 (58,782ft). In Horseshoe 1 (41,282ft) surface casing was set above the Tuluvak out of an abundance of caution. Ultimately, the Tuluvak in Horseshoe 1 was found to be water bearing and normally pressured. Tuluvak Formation pressure near Stirrup-1 are hydrostatic. This is inconsistent with the observed gas excess pressure above the Pikka field. Furthermore, 3D seismic over Stirrup-1 shows no structural trapping mechanism nor attribute derived evidence for shallow gas presence. There is very low risk for shallow gas at Stirrup-1 based on all available datasets. 2. Introduction The Stirrup-1 well targets the Brookian, Cretaceous Nanushuk reservoir. The proposed surface location for the Stirrup-1 drill -site is south of the Colville River at the following coordinates: Easting (ft) Northing (ft) Surface elevation (ft msl) 1,460,409.207 5,876,033.515 34.38 NAD83 StatePlane Alaska 4 FIPS 5004 (US Feet) Stirrup-1 Shallow Hazards - 25 September 2019 3 Figure 1: Aerial photograph of the Stirrup-1 surface location. Thirty miles north of Stirrup-1, exploration and appraisal wells located along the Colville River have occasionally encountered shallow gas. In some wells, shallow gas has been liberated from gas hydrates associated with the permafrost (Pikka C). In other instances, shallow gas has been identified in the Schrader Bluff and Tuluvak Formations. The Pikka field is the closest analogue for Stirrup-1. Along the Pikka trend the Tuluvak Formation locally contains overpressured shallow gas (e.g. Qugruk 2 and Qugruk 9). The shallow gas risk at Stirrup-1 is defined by this integrated study. There are four primary components included in this description; offset well completion design and mud logs, offset well logs and pressure data, pore pressure fracture gradient prediction and seismic amplitude analysis. The culmination of these analyses demonstrates the low risk for shallow gas at Stirrup-1. 3. Overburden Stratigraphy 3.1. Permafrost (Prince Creek Formation) The characterization and depth of permafrost near Stirrup-1 is relatively uncertain. The depth range of base permafrost ranges from approximately 300 ft TVDSS in Altamura 1 to 850 ft TVDSS in Horseshoe 1. Permafrost is identified using resistivity and sonic logs (RT>15 ohm.m and DT<135 ps/ft). However, permafrost is more apparent in coarser grained sediments. The lithologic overprint likely obscures the actual depth of permafrost. Permafrost is only identifiable in the Prince Creek and Middle Schrader Bluff Formations. At Stirrup-1 base permafrost is predicted at 632 ft TVDSS +/-200 ft. Stirrup-1 Shallow Hazards - 25 September 2019 4 RE aE�vous 2 [sSTVD]...... • ALTAIVIURA [SST1da] ................ ... . ........ . ..«� PIai- NEE-- R. 1- -...... s. - s- - T , v. .. ...aj - ....... ...... ....."" ....... . .... .. .. ... . .. ... ..... .. . ........ HORSESHOE ....... ... . ... ... .. .................. ......... ....... ............. 1 [SSTVa] ii Fi i:ns, pbi D<£ rii i ✓ ,.., \dn. R'it" 'i `''�' 7� .vr». S:. fti et p>r ft �s x•-{. 3 gg 3 ' d' •z r , i 2aif \ ;fr 0 too ;M. tw , Base;,t � ♦ 4 i 350 ; 33d$ •ar ; �� f ,t / 45AE i r y w 400 a6W F Raise'd + { 4 F. . i 4W Base N=ytia r' t i r� �- Qr # ;3p .�• , tl 1 ..,,. .r .,_.:,... , y � 55 1 fit#850 1 700, s pap .• • l5 5' l ads �b 3 aU ; i { TWuvak ell~ Base a/rmataw ?343 X" � i OF* � � r low � � w....i 3£�p N...,.., 1� z... \\ti.`, .:x� «� .{i ,; fps € e�.'� ............. ttsxi i alpi£9 i $$ap 1150 S d U aa e✓n.I i:!'. `�`' : i Y $•ylyp. ' �.......,� � $.IL' M � 2:343CP ••..,, �•• { $3fjp � 9 $3t7p � .m t ,,�""•.� �r f3i ,� ? ;,r ' ... a s 13s4 t?i9it ; tsars f 4'i 6 7 N.yi.. tl qh C;onfklemrp ./ $454 rrwnt 14 U) p a 1450 +v. �'PS6J .� QN ' t p SS Nczrs Pa} 1ST Psxrrsgafrsf $ �. f F t 1D y.. .. !Isso} 16W :. Tuft f& " �r 160 f Figure 2: Stirrup-1 offset wells with permafrost petrophysical flags. 3.2. Schrader Bluff Formation In the area near Stirrup-1 the Prince Creek Formation unconformably overlies the Middle member of the Schrader Bluff Formation. The Middle Schrader Bluff comprises fluvial influenced delta -top to delta -front facies versus the transgressive distal pro -deltaic Lower Schrader Bluff. The Middle Schrader Bluff includes multiple, coarsening -upward parasequence cycles with intercalated blocky sharp -based, fining -upward depositional packages. The Lower Schrader Bluff Formation is dominated by delta front and pro -delta mudstone and siltstone. The Lower Schrader Bluff is punctuated by multiple ash -fall tuff beds. Tuffs can be identified by conspicuously high gamma ray response greater than approximately 160 gAPI. Stirrup-1 Shallow Hazards - 25 September 2019 5 (1) Oil Se /� '"�'' ©/� ALTAMURA 1 [SSTVD] � / �''+� yr' �, *PIONEER 1 (SSTliD� w , »j A Stirrup -I (Ssr-A"" * HORSESHOE 1 [SSTVDJ %' .,_ .,.. ..... s:YF 3'Ci `Mi'�!' _ .�.� f { ..�... ... . ,. ...... ;,:' 11i .: ,.� roi,.....�TZfC� sue, ....... _�..._..__.m.� , !!! g� 100 Base Permafrost ,/,, Coiner Schrader &uft 4Y S � .al�\\\\\Q\�\ , S i 4 t 't t 4 �Y s«Yrs �\\\\, \� via } f. � ��; 8 00 f idtit ( �yr�r� se Permafrost�V1 too C �. Wdw S&'ra0es, Muff v Tu3 t3'Vak Format# n /: ; 7 y dt"3. �Jli iYi4$$fa'�iGGJ%i $ :.,•., w.. loot S s y:L s Ito locoQW e t4.tmt ader . f:�.�s 1400 1300 y6y,yµ�yy two 1.500 3 1400 3 a� a 150) \W it, gnat orI # $ WAY t ! IPy" ; ' AitG tK zNtrEat".. va c k FW; 'atYxxA e ##o W . $bra / voix, %� #ice._. - \�• o rr r f wM ....r. Seabee Formation low s 2WJ t9w 631�MAAM y 2:2Q� 27it -, , �$ � f 26 irrsrdltr�7rs. , .ee � y. ,t56 { ormal*n ,• ` ' .. .. Bpi'^ 24i { ~ � -26W e• T 7700 , , . Nanushuk Formation ' ;;� rktl !Jk' iiA�ttgR'! � 2�t � 2700 ' MW3100 xW i Nanushuk 3.�-JIM s 3$0 an c''Mati s24)f1tt, uk: icrr$ton S ` ` i _ �� '� \ M. ,\ a k yvw v I WO 3 At Sh 3 s # WOO "\ turfushk* 3 3700 3700 dFt£'a;� 3W Si � S 5 kli£ � !� f 41W 03.. i 4rtU F'+il'tat4f3tt 412175 di 7 1 34 436 68�1% Figure 3: Stirrup-1 overburden stratigraphy from offset wells. 3.3. Tuluvak Formation The Tuluvak Formation was deposited in a distal delta -front environment and comprises multiple, coarsening -upward parasequence sets with rare blocky sandstones deposited in shallow incised meandering streams. 3.4. Seabee Formation The Seabee Formation comprises pro -delta mudstone and siltstone deposited in offshore shelf -slope and basin floor environments. The Seabee Formation stratigraphy includes several ash -fall tuffs that can be identified with gamma ray spikes above 160 gAPI. Stirrup-1 Shallow Hazards - 25 September 2019 6 4. Shallow Hazards Assessment 4.1. Gas Hydrates Near the base of permafrost there -is a risk of gas and/or gas hydrates. Base permafrost at Stirrup-1 is predicted at 632 ft TVDSS +/-200 ft. In Stirrup-1 base permafrost will likely occur near the top of the Middle Schrader Bluff Formation. The permeable zone below the permafrost could be hydrocarbon bearing. This permeable zone is likely to extend to approximately 1300 ft TVDSS. The absolute depth of permafrost and transitional zone will dictate the phase of any hydrocarbons present. If the permafrost extends beyond approximately 850 ft TVDSS there is a risk of gas hydrates. If base permafrost is closer to the prognosis depth of 632 ft TVDSS, any gas below will be in fluid phase. *PIONEER 1 [SSTVD] 0 VLA T;> I ISSTVD) Sfirrup-1 [SSTVD) Figure 4: Stirrup-1 offset well correlation and potential Schrader Bluff gas zone. Stirrup-1 Shallow Hazards - 25 September 2019 7 : CL W 0 33 164 328 140 .6404 cc i 0.0 Cr 0 CL METHANE � GAS+ICE METHANE HYDRATE+ \ \\\ METHANE HYDRATE4 y i R. iN 15 75 735 1470 7348 W D A` R CL 2�0 1 14096 14 32 50 68 86 104 TEMPERATURE (Fahrenheit) Figure 5: Stirrup-1 Schrader Bluff Formation phase diagram for gas hydrates. 4.2. Gas Mud Log Analysis and Casing Design Gas in the Tuluvak Formation is a primary focus for shallow hazards assessment across the Pikka field. This concern has arisen after the gas -kick event at Qugruk 2. In the Pikka area, the Tuluvak is locally charged with overpressured gas. The Pikka Tuluvak gas trap is a seismically mapped 4-way dip closure. The Stirrup-1 well is located approximately 30 miles southwest of Stirrup-1 Shallow Hazards - 25 September 2019 8 (1) Oil Search the Tuluvak overpressured gas accumulation at Pikka. Offset well analysis clearly shows that the Tuluvak near Stirrup-1 is not in pressure communication with overpressured gas observed in Pikka. Pressure and drilling data from offset wells demonstrates a very low risk for any Tuluvak gas at the Stirrup-1 location. Near Stirrup-1 three offset wells have surface casing set below the Tuluvak Formation (Altamura 1, Pioneer 1, Flat Top 1). The Tuluvak Formation at Pioneer 1 and Flat Top 1 are at the same sub -sea depth as Stirrup-1. The Tuluvak Formation in Altamura 1 is slightly up -dip from Stirrup-1. In all three wells, the Tuluvak Formation was drilled with 10 ppg mud weight. These wells ••._.•:••••-.•-,•,,•••,•',..r...-........,•+...nw,,.vs_-�-.n-.....v»..eornnw..+.:..+utim,..ro..«n•r-..«rave«.rsmvtmw^neevlme.RaX.'.wwuw-n+.arnms..y5Ydt y:rumr w.,'sssM+a,wl.. n.+,ar_.x,-,,..aa _.n.ti.:!.HRit merae.yNLrar.n"btE,t were drilled prior to the Tuluvak gas release incident at Qugruk 2. Horseshoe 1 was drilled after the Qugruk 2 incident. In Horseshoe 1, surface casing was set above the Tuluvak Formation out of an abundance of caution. Formation pressure data collected from the Tuluvak Formation at Horseshoe 1 align with the regional aquifer gradient. �v� wWAIN b< F a 407 /;. Fiaaae �'e;xo':a�k t f ,: rBrri�Hurt R � � ° '..,..,:.....K' ..,..... 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The Tuluvak was drilled with 10 ppg mud with no gas influx events. These data suggest low or residual gas saturation at Altamura 1. Stirrup-1 Shallow Hazards - 25 September 2019 Q i � 4rt / b r ; ;¢ Yd ..:., r• axy � 3a,`t7`$1'%.i '4 � � E �3'� y'r'» m e7 „d.9r °i,. � a5 •� r rY 5J ... .............,.� ........ ............. ....i.,«........,..._gym.,,...._«..,«^.....,..,,,... _..,_,,. MA Rop"ts 0O)w WU / �a79.'�Yb 1 " P4 LLYfK]t%:x.Y': 5mEffid'aYfpra�'d6fp . Rf.9YR�%'a�C,��k 'p Y!4Qc S'1�A d6,](Y: M{,x'jb,•S:QIP :.ee�akx *na may <a %wtr.�kitR xarx t aYh. �T aa>ea urraxY rrae�assrc '. ; ;F{ypp(syd�tp %`x1Nf �F.`,:,. ':' .., * 754 M «YJf %�dLw . eAk°4Tkt� Saab A��'.�7&'[1�'B/�9, MY•M4/u wr'f✓k.Y'!S(R%tL iLcSkt 'nb n 5'.:4tl Ye zM::arv4M �� 'p .x m �. f4d +t)p hQ Mti-A n6 .a6e.Fot ♦l Xr R ). da Mti .w2 2Ya 1p eAl 7'vY•ur..' 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( �.. ✓d.M42a �� ... ... a ,..w...� bh+.YAyer r+Gadt 5 ] eawe ldL'kbk l'r nw; Ya7Cd.!arN �a✓ 1M tEC Parr 4.kh' kn� aw Yxa,a:y, ��Q ��ks4a�M� Y2'kdC-., `i14PW�4 Non -Pad Water xx dRk�o? 9�K "'A d^' i6xrnueC'^ `^ 1A". ...., bNxk"dkd'S`<v>tM Y� •iM.au&.4 e } :a (• Permafrost �YR, kGR!-N« ✓^•, e'xwW a!ar '« p'dK ,.] Ta /AE'%'ta'h]ra4 TPA, T¢4 +pF /wnNd .A L')T?„�Yaf!7WNCtY x.r M.alp 7^ f{ SiiFf '•uM N�rVM �... Tk'/r ^"� bYt %M f�C%4Ox kYekxT xru. Ali ,� ydgv treaMlae5re6 'MK'•aN '',,gy%^'xSb+ah9. R�ac Wr5:KM6tlfkh `sy+a Figure 7: Altamura 1 Tuluvak Formation gas mud log summary. Flat Top 1 intersected the Tuluvak from approximately 1800 — 2500 ft TVDSS; similar to the prognosed depth in Stirrup-1. The max value of gas mud in the Tuluvak Formation was 54 gas units which equates to approximately 1 %. The Tuluvak was drilled with 10 ppg mud with no gas influx events. These data suggest very low residual gas saturation at Flat Top 1. Stirrup-1 Shallow Hazards - 25 September 2019 10 (8) Oil Search Figure 8: Flat Top 1 Tuluvak Formation gas mud log summary. Horseshoe 1 intersects the Tuluvak from approximately 2500 — 3200 ft TVDSS. The Tuluvak at Horseshoe 1 is situated structurally below the prognosed Tuluvak at Stirrup-1. Horseshoe 1 registered 0 gas units in the Tuluvak Formation while drilling with approximately 10.4 ppg mud weight. A formation pressure of 1188 psi was collected in the Tuluvak Formation at 2568 ft ,TVDSS. This pressure equates to 8.89_pR9 and is consistent with a regional aquifer trend. These data strongly suggest that the Tuluvak is normally pressured and water bearing at Horseshoe 1. Stirrup-1 Shallow Hazards - 25 September 2019 11 HORSESHOE 1 [MD ett Ae"r1s � i,7 exaCXuxrn.7cTxx4�34_W9bt-d5i�,saa.»sva.tR,;wr,ss: . V ` ,ft Figure 9: Horseshoe 1 Tuluvak Formation gas mud log summary. (1) Oil Search Romafk% iDryr G+k }jx",. SWV#Y 04U, MA R8pom, 0ow do b R6 fC4 "lox In the area around Stirrup-1 the Tuluvak Formation is oriented along a gently east -dipping homocline. Wells up -dip and down - dip of Stirrup-1 encountered virtually no appreciable gas. The wells located up -dip from Stirrup-1 were drilled with 10 ppg mud and have surface casing was set below the Tuluvak (Altamura 1, Pioneer 1 and Flat Top 1). Down -dip from Stirrup-1 at Horseshoe 1, no gas was observed in the Tuluvak which was drilled with 10.4 ppg mud. In Horseshoe 1 surface casing was set above the Tuluvak. All stratigraphic, structural and drilling data suggest that the Tuluvak atStirrup-1is unlikely to contain gas. Stirrup-1 Shallow Hazards - 25 September 2019 12 Figure 10: Top Tuluvak Formation structure map; depicting gently east -dipping homocline. Stirrup-1 Shallow Hazards - 25 September 2019 13 Figure 11: Tuluvak cross section displayed in TVDSS with highest observed gas mud cut and mud weight. 4.3. Log and Pressure Analysis Drilling and mud log data suggest that the Tuluvak Formation near Stirrup-1 does not contain significant gas. The low levels of observed mud gas probably reflect faint, residual gas saturation. Petrophysical logs are consistent with this interpretation. In the up -dip position Altamura 1 showed the highest gas mud cut (-5%) while Horseshoe 1 showed 0% gas in the down -dip position. Careful inspection of cross -over between Neutron Porosity and Bulk Density logs shows a similar relationship. Altamura 1 shows slight Neutron -Density cross over in the permeable zones that cut 2-5% gas. Flat Top 1 showed a maximum of 1 % gas and has no Neutron -Density cross over. Horseshoe 1 showed no gas and has no Neutron -Density cross over. Furthermore, Horseshoe 1 has the widest separation between these Neutron Porosity and Bulk density logs. Stirrup-1 Shallow Hazards - 25 September 2019 14 Figure 12: Neutron Porosity — Bulk Density log cross over as a function of residual gas saturation from mud logs. Thirty miles northeast of Stirrup-1 above the Pikka field, the Tuluvak is gas bearing within a 4-way dip closure. Pikka Tuluvak gas pressures were measured iin Qugruk 9. These ressures are clearly elevated above the regional .aquifer gradient (1327 psi at 2433 ft TVDSS). Near Stirrup-1, Tuluvak pressure from Horseshoe 1 are consistent with the regional aquifer trend (1188 ,r psi at 2568 ft TVDSS). The Qugruk 9 and Horseshoe 1 pressure cannot be connected by -'a fluid gradient. The overpressured, gas -bearing Tuluvak in northern Pikka is not in pressure communication with the normally pressured, water -bearing Tuluvak at Horeshoe 1. Stirrup-1 Shallow Hazards - 25 September 2019 15 �OpaFR fcAYYllkl lfA�M M 1va% 11A ElPR1Qb ]IRAlI1R1 :001011 �A16yyY# !9gp�0W 1 1, bk �.iFtOf S yON' IC f /, C.rat�iCi� f { WFiF A Ate(-?ak sratiatit3 FW;Xdkl; '! t 30 miles RESERVO o M SOURCE RESERVOIR M M TRAP SOURCE M SEAL TRAP SEAL UK" wk[�V01011 4NtlI14)('+P < Stirrup-1 Tuluvak No TyraT Figure 13: Top Tuluvak Formation structure map and reservoir potential evaluation. The Qugruk 9 Tuluvak gas pressure equates to approximately 10.49 ppg. All the wells around Stirrup-1 were drilled with 10 ppg mud weight. If 10.5 ppg overpressured gas was present in Altamura 1, Pioneer 1 or Flat Top 1, these wells would have been underbalanced and likely shown significant gas mud cut, or even experienced a gas kick. Tuluvak pressures in the Stirrup- 1 area are most likely consistent with the water gradient observed in Horseshoe 1. Stirrup-1 Shallow Hazards - 25 September 2019 16 Tuluvak Pressures Pressure psi 5i :J 10010 1500 2000 500 ••�r,.�+ 10 ppg - Regional Aquifer Centroid Altan�u-a Top Tu€uvak 10 ppg Pioneer Top Tuluvak 10 ppg 1500 A talnura Base TulLivak 10 ppg Fiat Top 1 Top Tu;uvak 10 ppg Y a > Pioneer Base 'r�siuvak 10 to 2000 ' ppg 0 1..1.46 ppg �. c1 Q-9 Tuluvak 4-4 4-4 2500 10.49 ppg po Flat Top 1 Base Tu€uvak 1.0 pK)b t2s ' Q-9 Tu€uvak ?Ot�O Horse Oioer• 1 Tea€uvak 4000 f� l;airs Water (Nan 2y Figure 14: Tuluvak formation pressures combined with mud weights used in Stirrup-1 offset wells. 4.4. Pore Pressure Fracture Gradient Prediction Pore pressure and fracture gradient prediction for Stirrup-1 is based on several analogue wells. For the Tuluvak, aregional water gradient is extrapolated to match the Horseshoe 1 Tuluvak pressure. This pressure gradient is consistent with aquifer pressures recorded in Nanushuk Formation at Alpine 1 and the Torok Formation in Qugurk 8, Qugruk 1 and Qugruk 9. The Stirrup-1 Tuluvak pore pressure is further constrained by mud weights in the near offset wells Altamura 1, Pioneer 1 and Flat Top 1. Stirrup-1 Shallow Hazards - 25 September 2019 17 (1) 11il Search _w...w...._...w.w............... a _...................._._..... ......... .. ........... ....................... ... ............. .................................. Stirrup-1 .......... ._... _ .................................................._..............._............................... PPFG[SSTVD].. __ _ _ ,.. ' +:`"# ..$• t ......,......a..«M...,.»...Mu.«.....,..m..«,.,+..,..„,«.,a,,...ra.,,w,..,..m.,•.<.w.,,�-.vP,v.,,..�.wo,�•M.H�.�.a ,.,,....o..,,..w„uw,w4,.,o ,w .,..,N,.,.,.u,,,_.w..,.,,..., w.,,,.,,..�,..., ,,,,..��...,� ,,,,,,,,,,,,,,q�,, mom..,....., ..................<......,.....,..,,.,......,.,.,,.......,.,.,:...,...,........,...,...,,....,..,.............. ................... N....., f Overburden SM 4 Shale FG UPPER:: Sand FG Pore Pressure s 0 LOT M FIT ✓�f Formation. Pressure nwao ELL+ . MW Horseshoe I g gg y£ I py�g� �A inx I ' spork OD-.9 Rendezvous A 2S�M 25344 Horseshoe ;, 1 Rendezvous 1 Pioneer 1 5. Altornuro 1 Flattop I t. N.............. s. ww 3W 35344 NANUSIA)K ..u....�.,. . Ougruk's A'ANU S�),IUK 4`;�.�2 .., ��.` � - A$�t,�SN,,K (sF Horseshoe 1 � •. �. SOW 50344 x'"'' � fir• 5N 4 � Q O 0 } �^ yy yy,,,, VA 034 4 Nonuk2 p OROK A f 7000 � 70.; , t SW 80,344 Altomuro Nitomu 1 8.� 8!�U, W"8 92392 Figure 15: Stirrup-1 pore pressure and fracture gradient prediction expressed in pounds per square inch. Stirrup-1 Shallow Hazards - 25 September 2019 18 (1) Oil Se .Mw.mn�..�.�.�.�.�.,,�.,,www..,_.�.,.w.u........,..,...,...�..w......�,.,�.w,�.....,�.....,�,.. ..�,<.,�.,,��,.�.�.,.�w.. • Stirrup-1 ..�_.� _ ....�,�.�.�,�.�.,.�..�..m..w�M � .��....�....�.,�.w._�.,.�. PPG [SSTVD] � .. � . _ .._„�..,.m . .. ( ..'v°""�'� '�wx +ESHwrorc R�»xx HapzAW.�p xac�"nxa-0bralR'A,wAC.M$d34aWxa rA�>H�Haf65,j'6�6:r�<. .. ; 0 t ---■» € v r urden -,».,.. Shale Fri Sand FG «.".." Pore Prt-wire 0 LOT UPPER S{aH.ADUR St. �� t � FIT • D e . Formation Pressure .g„ ttTL„ ....,., .. s , �a t. ,.. Horseshoe 1 winx I M $ RendezvousA 25344 x Horseshoe 1 '�'`• a w Rendezvous Pioneer 1 9 , X Altaniura l SEA 4 s w 1'larto 1 s ,p ¢. Y134 $ " f Tofkat 1 5 35344 NANUSt4UK y,. a. ♦ 4 a Horseshoe s , " Cr t 50 50344s n 60344 gg ))yy++qq [[�'4q,y 4Jii i,4Yt 650 65'344 �e ♦ v 9 �..x ♦b k H4 < 4 FI * P k + �yy��.pyy{qy�� { » S P M 4 Altamura 1 V ' ♦ A � 3 9204,0 OZ39 A 1pne_ "PS.B Figure 16: Stirrup-1 pore pressure and fracture gradient prediction expressed in pounds per gallon. 4.5. Seismic Analysis Observations from seismic are based on the 2015 PSDM processed Horseshoe 3D volume. In this area sandstones and shale have low impedance contrast. Therefore, hard streaks tend to dominate; expressed as strong peaks. Constructive interference Stirrup-1 Shallow Hazards - 25 September 2019 19 (1) Oil Search of cemented zones can complicate the acoustic response. At the average depth of the Tuluvak (-2000 ft TVDSS) the Horseshoe 3D is low fold. Near stacks are especially pore owing to surface features such as lakes, rivers, bear dens, etc. For this reason, the Horseshoe 3D is not suitable for QI. Al HS3D► is Wavelet iSai®..... ,8# x�y tiat✓Y, F.'c�Nrntv,2„Cep. 'a ta: a��.i. xa' �r +nay 4 r £ 41 a }It ° 3 Stab."ti m r 4M y z } Constructive interference of multiple thin cemented zones Figure 17: Synthetic seismogram for Pioneer 1 at various frequencies. Within the Horseshoe 3D the Tuluvak is mapped along a gently east -dipping homocline with no fault closures and no obvious stratigraphic traps. Well correlations, amplitude extractions and spectral decomposition all indicated strong lateral continuity of sandstone intervals. Amplitude extraction and spectral decomposition images from three horizons within the Tuluvak Formation illustrate the low probability of gas near Stirrup-1. Stratigraphic features such as channels, beach ridges and small faults are detected in the horizon extraction. These features show a variety of amplitude responses between the full and far stack volumes. However, there is no regular pattern, conformant to structure or depth, that would suggest these amplitudes relate to gas presence. Altamura 1 and Pioneer 1 locally intersect bright amplitudes, yet these wells showed very low residual gas saturation while Stirrup-1 Shallow Hazards - 25 September 2019 20 W) Oil Search drilling. This inconsistency supports the interpretation that amplitude is primarily driven by hard -streaks such as cementation versus reservoir fluids. Figure 18: Far stack amplitude extractions from three horizons within the Tuluvak Formation. Redacted M. Guhl 5/6/2022 5tlrrup-1 Shallow Hazards - 26 September 2019 21 (P Oil Search :' Far Stack , Figure 19: Full stack and far stack seismic cross sections between Pioneer 1 and Stirrup-1. Figure 20: Far stack amplitude extractions From three horizons within the iuluvak Formation. Redacted M. Guhl 5/6/2022 Stirrup-1 Shallow Hazards - 25 September 2019 22 (P Oil Search XEIm:FR3aAkm aI-Hwwsfw 1Fw Figure 21: Full stack and far stack seismic crass sections between Altamura 1 and Stirrup-1. Redacted M. Guhl 5/6/2022 Stlrrup-1 Shallow Hazards - 25 September 2019 23 4) Oil Search Figure 22: Far stack amplitude extraction and spectral decomposition image from lower Tuluvak Formation, Redacted M. Guhl 5/6/2022 Stirrup-1 Shallow Hazards - 25 September 2019 24 (0 Oil Search Envelope of Far Angle Stack Figure 23: Far stack amplitude extraction and spectral decomposition image from middle Tuluvak Formation. Redacted M. Guhl 5/6/2022 Stirrup-1 Shallow Hazards - 25 September 2019 25 NW Oil Search Envelope of Far Angle Stack Figure 24: Far stack amplitude extraction and spectral decomposition image From upper Tuluvak Formation. Redacted M. Guhl 5/6/2022 Stirrup-1 Shallow Hazards - 25 September 2019 26 5. Conclusions The Stirrup-1 overburden comprises two distinct permeable zones; the Middle Schrader Bluff Formation and the Tuluvak Formation. There is a moderate risk of low pressure gas or gas hydrates below permafrost in the Middle Schrader Bluff. The w.�.vn.ewr1.,M+rww+w.nwwww..'rww".+'++.u�'Ew�pe¢aN+nswu.w9tawty'awxwe+w+•vnw.ti+•Ve4wr+m.•:.... •..N. 'hwC:e. e,kn..f:.r.+!.u1!tl.^.L.'m'sTMY.'.A%Yr}'.»=" ' '".-`.:.¢aaANAaty:naOl.Rlm'.'.m+ra'v1irs SULet'.w:iJYhR\ risk of gas in the Tuluvak is very low. All seismic and offset well data strongly suggest that the Tuluvak at Stirrup-1 will be water bearing and normally pressured. If gas is encountered, then it is likely to be at residual saturation and very low pressure. This interpretation is based on the following data and interpretation. 1. Casing Design — Three near offset wells have surface casing set below the Tuluvak Formation; Altamura 1, Pioneer 1 and Flat Top 1. 2. Mud Logs — Gas mud cut from near offset wells showed a maximum of 5% gas cut at Altamura 1, up -dip of Stirrup-1 and a minimum of 0% gas cut down -dip at Horseshoe 1. At the same TVDSS depth as Stirrup-1, Flat Top 1 showed 1 % gas cut. 3. Mud Weight — The Tuluvak Formation was drilled with 10 ppg mud weight in three offset wells; Altamura 1, Pioneer 1 and Flat Top 1. None of these wells experienced a gas kick or significant gas mud cut. The Tuluvak Formation at Horseshoe 1 was drilled with 10.4 ppg mud weight, no gas was detected. 4. Pressure — The Tuluvak Formation pressure was measured at Horseshoe 1. This pressure is consistent with the regional aquifer trend. More importantly, this pressure is incongruent with overpressured gas observed in the Pikka Tuluvak, 30 miles north of Stirrup-1. 5. Trapping Mechanism — There is no structural or stratigraphic trapping mechanism mapped in the area surrounding Stirrup-1. Interpretation of the Horseshoe 3D seismic shows good reservoir continuity in the Tuluvak Formation which is oriented along an east -dipping homocline. 6. Seismic Amplitudes — Seismic amplitude extractions and spectral decomposition images from the Tuluvak Formation show a variety of sedimentological features. There are no pattern of amplitude anomalies to suggest the presence of a gas accumulation. Stirrup-1 Shallow Hazards - 25 September 2019 27 0 Oil Search Attachment 5: Drilling Hazards 12-1/4" Surface Hole Section Hazard Mitigations Conductor Broach Monitor conductor for any indications of broaching. Monitor pit volumes for any losses. Gas Hydrates Keep mud cool, optimize pump rates, minimize any excess circulation. Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Keep mud cool, optimize pump rates, minimize any excess circulation. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Shallow Gas Shallow hazards assessment, sufficient mud weight, on site surveillance (mud loggers, trained drilling personnel). 8-1/2" Production Hole Section Hazard Mitigations Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Drill with oil based mud, maintain mud in specifications, use sufficient mud 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 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. Stirrup 1 Permit to Drill - 54 - 01-Nov-19 Oil Search Attachment 6: 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. Stirrup 1 Permit to Drill M ;55 - 01-Nov-19 /-- (-TAetz - Ir.?e-t� tJ -I - Oil Search Attachment 7: Cement Summary Surface Casing Cement Casing Size 9-5/8" 40# L80 BTC Surface Casing Lead Open hole volume + 500% excess in permafrost / 300% excess below . permafrost Basis Lead TOC Surface Tail Open hole volume + 50% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Spacer 60 bbls of 10.5 ppg Clean Spacer Total Cement Lead 692 bbls, 3885 cuft, 1605 sks of 11.0 ppg ArcticCem, Yield: 2.42 cuft/sk Volume Tail 49 bbls, 277 cuft, 234 sks 15.8 ppg Class G — 1.18 cuft/sk Temp BHST 820 F Verification Method Cement returns to surface Notes Job will be mixed on the fly Swap to tail cement when lead cement is seen at surface Conventional cement job with top and bottom cement plugs 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 —2750' (100' outside 9-5/8" shoe) Tail Open hole volume + 30% excess + 120 ft shoe track Tail TOC —3807' MD/TVD. 600' MD/TVD above top of Nanushuk Oa formation Spacer 30 bbls of 11.3 ppg Clean Spacer Total Cement Lead 31 bbls, 174 cuft, 82 sks of 12.0 ppg ExtendaCem, Yield: 2.13 cuft/sk Volume Tail 70 bbls, 391 cuft, 315 sks 15.3 ppg ExpandaCem Class G —1.24 cuft/sk Temp BHST 149° 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 + 10% excess Basis Lead TOC Surface Tail Open hole volume + 30% excess + Cased hole volume + 10% excess Tail TOC 500' TVD/MD above 9-5/8" casing shoe (stage tool 100' outside shoe) Spacer 30 bbls of 11.3 ppg Clean Spacer Total Cement Lead 66 bbls, 371 cuft, 154 sks of 12.0 ppg VariCem, Yield: 2.40 cuft/sk Volume Tail 19 bbls, 108 cuft, 87 sks 15.3 ppg ExpandaCem Class G —1.24 cuft/sk Temp BHST 81° 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 Stirrup 1 Permit to Drill - 56 - 01-Nov-19 Oil Search Attachment 8: Rig Fluid System Stirrup 1 Permit to Drill - 57 - 01-Nov-19 arnL rAMN rnPnGln = rcrr aar�, uET uvERs WILL LOW PRESSURE SYS. RE'I:RNS SUCTION raooG"� sWIVEL w_IR ao. e• S _. ( i t0^,ONE J• n J Y I iOV'cR-ROW � WELL -�- � - Mi%HOPPER e. J i 8 6" e 8' ;KHP fia8x11 �� OVM w/ 80 HP .5 HP �HP ax5x11 T 6' w180 HP B" HOPPER IV9 i � H DRILLING LTD. esazno�sna Nwx;,.nroeaz ' ruE /ra rnl�n5r 6. 6' Bx5e1 Mec a MacM1a— M J,. Orve Onve 3• The information eontainedin 7.5 HP Yb HP thla drawing is the foie property of Doyon AKITA JV. Any reproduction In whole or part without the express J' written consent of Doyon .5 HP AKITA JV. Is prohibited. GN1 ER GAUGHEft PUMP PUMP r B/1/08 I NTS � DDI kF Mud Schemed 3' 3' 3" Aned— Project Mud Tank Schematic i 4 Oil Search Attachment 9: Prognosed Formation Tops Stirrup 1 Prognosed Tops ft MD ft TVD(KB) ft TVDSS Pore Pressure Uncertainty Range PRINCE CREEK Fm. 0 0 54 7.0 0 PERMAFROST BASE 686 686 -632 7.8 +/-200 ft TVD MIDDLE SCHRADER BLUFF 842 842 -788 8.0 +/-100 ft TVD LOWER SCHRADER BLUFF 1318 1318 -1264 9.3 +/-100 ft TVD TULUVAK 1875 1875 -1821 9.1 +/-100 ft TVD SEABEE 2539 2539 -2485 8.8 +/-100 ft TVD TOP NANUSHUK 3376 3376 -3322 9.4 V +/-100 ft TVD NANUSHUK 3 3795 3795 -3741 9.0 +/-11S ft TVD NANUSHUK 0 4236 4236 -4182 8.9 +/-130 ft TVD NANUSHUK_Oa 4408 4408 -4354 8.8 +/-130 ft TVD TOROK 4740 4740 -4686 8.7 +/-140 ft TVD TD 6000 6000 -5946 8.6 - Stirrup 1 Permit to Drill - 59 - 01-Nov-19 /0. Attachment 10: Pore Pressure Fracture Gradient Plot • Stirrup-1_PPFG [SSTVD] 4W -34 3 f 01 500 534 4 UPPER SCHRADER BLUFF MIDDLE SCHRADER BLUFF 1000 10344 LOWER SCHRADER BLUFF 1500 15344 2000 20344 101 UVAK 2500 25344 3000 30344 3500 35344 NANUSHUK NANUSHUK_3 4000 40344 NANUSHUK 0 4500 T 5000 45344 50344 NANUSHUK. 0a - 5500 55344 6000 60344 TOROK 6500 65344 S t. L' Horsesh 1 Qugru Horsesh e 1 O O 3 ' � � 3 fm1 O Nanu c I[,or Oil Search — Overburden — Shale FG — Sand FG — Pore Pressure O LOT ® FIT • Formation Pressure - - - ECD MW orseshoe 1 nx i 3peI BB 9 --- Rendezvous A Rendezvous 1 Pioneer 1 I A/tamun: 1 Flattop 1 Tofkat 1 N Stirrup 1 Permit to Drill - 60 - 01-Nov-19 Oil Search Attachment 11: Independent V Party Pore Pressure Fracture Gradient Plot Stirrup 1 Permit to Drill - 61 - 01-Nov-19 Stirrup gradient ppg Equivalent Mudweight (ppg) calculated from KB N ikon Scienu W1 Oil Search Attachment 13: Formation Evaluation Program 12-1/4" Surface Hole LWD Gamma Ray Resistivity v Sonic Open Hole Wireline None Cased Hole Wireline None 8-1/2" Production Hole Gamma Ray LWD Resistivity Sonic Conventional Core Up to 540' of 4" conventional core Density Neutron Induction Resistivity Sonic Spectroscopy Open Hole Wireline* Spectral Gamma Ray Image Log 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. Stirrup 1 Permit to Drill - 64 - 01-Nov-19 Attachment 14: Wellhead Diagram 43.0" 43.0' 4-1/16" 10M l 4-1n6" 1GM CL u O 4.1116" 1 OM 3' MALE -n 1502 WECO 4-1116" 10R7 78.4" 4-1116" 10M C 189.1" f f Oil Search 43.0" _41/16"10M 4"1002 - -"' FEMALE WECO 9-1/2" (4-ACME)OTIS 0... 4-1/16'5M 4-1116" IOM 4-1116' 10M 1,01 4-1/16" 10M 3" FEMALE 1502 WECO 4 >� r l �'G A-9L- 2-1116' 5M 2-1l16- 5M 11' 5M MODIFIED 19LI5" f iE Gh91 i ffff CUT-01 F 1 i ti� 1I i i i IF CASING 9-WFCASING = T'CASING 412" v Ill? TUBING - '. -----CONTROL LINE Pressure Control ER 16' x g-5/8" x 7" x 4-1/2 x 3-1/2" 5/10M MB-230 MulGbowl Assembly BAKER , FWith MB-230 Upper Head and MB-230 Tubing Hanger and K Tubing Bonnet 4 a GE company DRAWN DRAWING O �'.:- mxaoe9e ''. r:cawvr rm"nae.w anuua a.�ewm:a,mwxw R:Naaw"mrmeeatnww. n..",na. enawe awree ' MEWED BYAIRROVE- 0.ev Sltt.' - '. wrao a�srp:�owe"co:n m"owms�mr".�x ae,trwy�n. 't Stirrup 1 Permit to Drill - 65 - 01-Nov-19 T C 0 3 0 0 5 0 1,000 2,000 3,000 0 $ 4,000 L a a 0 W Z 0 5,000 6,000 7,000 8,000 Stirrup-1 Days vs. Depth 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 O Schwartz. Guy L (CED) From: Williams, Rob <Rob.Williams@oilsearch.com> Sent: Friday, November 22, 2019 12:22 PM To: Schwartz, Guy L (CED) Cc: Davies, Stephen F (CED) Subject: RE: Stirrup 1 (PTD 219-153) Hi Guy, Thanks again for your feedback and discussion over the phone today. See my responses below. 1) Good catch on the Umiaq survey vs. the drilling pad layout. The well position is correct in both but the pad location is in relation to the well is slightly different between the two. I'll review with our permit team to determine if any updates are required for any of the other permits related to Stirrup 1. 2) 13.2ppg is the minimum LOT required for the surface casing shoe based on a swabbed kick from TD of the 8-1/2" section. 3) As discussed the plan for the completion is to perforate the well prior to running the completion so that larger guns can be run. Once we get open hole logs and select a perforation interval we'll request approval as part of the frac. sundry. 4) Noted. We will make sure we plot the casing test and LOT data on the same plot and get this through to you as soon as it is completed. Unless you have concerns, as long as we get a minimum of 13.2ppg EMW for the LOT we will plan to proceed ahead with drilling operations. Any other concerns or issues please let me know. Regards, Rob. ROB WILLIAMS I SENIOR DRILLING ENGINEER 1 OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 ' Mob: +1 907 830 2209 Email: robmilliams2@oilsearch.com j Web: www.oilsearch.com From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Friday, November 22, 2019 11:25 AM To: Williams, Rob <Rob.Williams@oilsearch.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: [EXTERNAL] Stirrup 1 (PTD 219-153) Rob, Here are some additional follow up comments for you on the Stirrup 1 well: 1) As we discussed check the pad layout vs as staked survey. The as -staked shows the well centered on the north side of ice pad vs the equipment layout (shows well location shifted about 150 ft to east) 2) What is your min FIT value for drilling out of the surf casing shoe? 3) You may want to include running the 3 %" completion with this PTD so you are not waiting for frac sundry approval to run tubing. You can send mean outline of the tubing / packer completion by email. 4) Make sure you include the 9 5/8" casing test with the FIT data . We will want the FIT/LOT data forwarded as soon as it is completed. (see AOGCC guidance doc 17.001) 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.aov). ************************************************************************************************** ************* 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 ************************************************************************************************** ************* Kick Tolerance Calculations guy schwartz 11/25/2019 input in yellow areas only Stirrup 1 219-153 MW (ppg) 10.5 ppg LOT/FIT (ppg) 13.2 TVD Casing Shoe (ft) 2650 ft TVD If a formation deeper then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 6000 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 8.5 inches Drill Pipe OD (in) 5 inches BHA OD (in) 4.75 inches Lenth of BHA (ft) 250 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.0459 bbl/ft Annular Capacity between OH and DP 0.0483 bbl/ft Annular Capacity between OH and BHA 372.06 psi Maximum Allowable Surface Pressure 156 psi Underbalance due to Kick Intensity 216.06 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 484.4 feet Volume of Gas Kick 23.4 bbl CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 22.2 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 11.8 bbl CASE 2 depth Conversion KICK TOLERANCE: 11.8 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 INDEX MAP Stirrup 1 (PTD 219-153) AOGCC November 5, 2019 Kick Tolerance Calculations guy schwartz 12/12/2019 input in yellow areas only Stirrup 1 219-153 MW (ppg) 10.5 ppg LOT/FIT (ppg) 13.2 TVD Casing Shoe (ft) 2650 ft TVD If a formation deeper ' then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 6000 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 372.06 psi Maximum Allowable Surface Pressure 156 psi Underbalance due to Kick Intensity 216.06 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 484.4 feet Volume of Gas Kick 1.2.6- bbl CASF 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 24.5 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 13.0 bbl CASE 2 depth Conversion KICK TOLERANCE: 12.6 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 Schwartz, Guy L (CED) From: Williams, Rob <Rob.WiIlia ms@oilsearch.com> Sent: Friday, November 22, 2019 12:22 PM To: Schwartz, Guy L (CED) Cc: Davies, Stephen F (CED) Subject: RE: Stirrup 1 (PTD 219-153) Hi Guy, Thanks again for your feedback and discussion over the phone today. See my responses below. 1) Good catch on the Umiaq survey vs. the drilling pad layout. The well position is correct in both but the pad location is in relation to the well is slightly different between the two. I'll review with our permit team to determine if any updates are required for any of the other permits related to Stirrup 1. 2) 13.2ppg is the minimum LOT required for the surface casing shoe based on a swabbed kick from TD of the 8-1/2" section. 3) As discussed the plan for the completion is to perforate the well prior to running the completion so that larger guns can be run. Once we get open hole logs and select a perforation interval we'll request approval as part of the frac. sundry. 4) Noted. We will make sure we plot the casing test and LOT data on the same plot and get this through to you as soon as it is completed. Unless you have concerns, as long as we get a minimum of 13.2ppg EMW for the LOT we will plan to proceed ahead with drilling operations. Any other concerns or issues please let me know. Regards, Rob ROB WILLIAMS I SENIOR DRILLING ENGINEER I OIL SEARCH ALASKA PO Box 240927, Anchorage, Alaska 99524-0927 Tel: +1 907 375 4690 1 Mob: +1 907 830 2209 Email: rob.williamsooilsearch.com i Web: www.oilsearch.com From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Friday, November 22, 2019 11:25 AM To: Williams, Rob <Rob.Williams@oilsearch.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: [EXTERNAL] Stirrup 1 (PTD 219-153) Rob, Here are some additional follow up comments for you on the Stirrup 1 well: 1) As we discussed check the pad layout vs as staked survey. The as -staked shows the well centered on the north side of ice pad vs the equipment layout (shows well location shifted about 150 ft to east) 2) What is your min FIT value for drilling out of the surf casing shoe? 3) You may want to include running the 3 %Z" completion with this PTD so you are not waiting for frac sundry approval to run tubing. You can send mean outline of the tubing / packer completion by email. 4) Make sure you include the 9 5/8" casing test with the FIT data . We will want the FIT/LOT data forwarded as soon as it is completed. (see AOGCC guidance doc 17.001) FIELD: TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development Service `/Exploratory _ Stratigraphic Test _ Non -Conventional POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation 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 implemented a water well testing program to provide baseline data on Well water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: / Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015