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Home My WebLink About225-028 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION Well clean up data for 19 wells Details are provided on following pages with well name and API table as reference. Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh 601 W 5th Ave., Anchorage, AK 99501 shannon.koh@santos.com DATE: 11/20/2025 From: Shannon Koh Santos 601 W 5th Ave. Anchorage, AK 99501 To: Gavin Glutas AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/Teams ܆Hardcopy ܈Other - FTP REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܈Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܆Other COMMENTS: Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.21 09:00:44 -09'00' LETTER OF TRANSMITTAL Well API NDB-010 50103209200000 NDB-011 50103209160000 NDBi-014 50103208690000 NDBi-016 50103208920000 NDBi-018 50103208880000 NDB-024 50103208620000 NDB-025 50103208770000 NDBi-030 50103208730000 NDB-031 50103209120000 NDB-032 50103208600000 NDBi-036 50103209080000 NDB-037 50103208950000 NDBi-043A 50103208590100 NDBi-044 50103208650000 NDBi-046L1 50103208830000 NDB-048 50103209020000 NDBi-049 50103208940000 NDBi-050 50103209040000 NDB-051 50103208800000 جؐؐؐNDB-010 ؒ Santos_Pikka_NDB-010_End of Well Data Report_1 min_FINAL (1).xlsx ؒ Santos_Pikka_NDB-010_End of Well Data Report_30 min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-010_Rev A (1).pdf ؒ جؐؐؐNDB-011 ؒ Santos_Pikka_NDB-011_End of Well Data Report_1 min_FINAL (1).xlsx ؒ Santos_Pikka_NDB-011_End of Well Data Report_30 Min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-011_Rev A (1).pdf ؒ جؐؐؐNDB-014 ؒ Santos_Pikka_NDBi-014_End of Well Clean-up Data Report_30 Minute_Final Data.xlsx ؒ Santos_Pikka_NDBi-014__End of Well Clean-up Data Report_1 Minute_Final Data.xlsx ؒ WT-XAK-0127.3_NDBi-014_Rev A_Signed.pdf ؒ جؐؐؐNDB-024 ؒ Santos_Pikka_NDB-024_End of Well Clean-Up Data Report_ 30-min_Final (2).xlsx ؒ Santos_Pikka_NDB-024_End of Well Clean-Up Data Report_1-min_Final (2).xlsx ؒ WT-XAK-0127.2_End of Well Clean-Up Data Report_NDB-024_Rev A_Signed.pdf 225-061 T41152 225-048 T41153 223-076 T39828 223-105 T39831 NDB-031 50103209120000 LETTER OF TRANSMITTAL ؒ جؐؐؐNDB-025 ؒ Santos_Pikka_NDB-025_End of Well Clean-up Data Report_1-min_Final Data.xlsx ؒ Santos_Pikka_NDB-025_End of Well Clean-up Data Report_30-min_Final Data.xlsx ؒ WT-XAK-0127.4_NDB-025_Rev A signed End of Well Clean-up Data Report.pdf ؒ جؐؐؐNDB-031 ؒ Santos_Pikka_NDB-031_End of Well Clean-up Data Report_1 min_FINAL.xlsx ؒ Santos_Pikka_NDB-031_End of Well Clean-up Data Report_30 min_FINAL.xlsx ؒ WT-XAK-0127.5_NDB-031_Rev A Signed (1).pdf ؒ جؐؐؐNDB-032 ؒ Santos_Pikka_NDB-032_End of Well Clean-up Data Report_ 30 min_Final Data (1).xlsx ؒ Santos_Pikka_NDB-032_End of Well Clean-up Data Report_1 min_Final Data (1).xlsx ؒ WT-XAK-0127.3_NDB-032_Rev A_Signed (2).pdf ؒ جؐؐؐNDB-037 ؒ Santos_Pikka_NDB-037_End of Well Clean-up Data Report_1-min_FINAL (1).xlsx ؒ Santos_Pikka_NDB-037_End of Well Clean-up Data Report_30-min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-037_Rev A_Signed (2).pdf ؒ جؐؐؐNDB-048 ؒ Santos_Pikka_NDB-048_End of Well Clean-up Data Report_1 min_FINAL.xlsx ؒ Santos_Pikka_NDB-048_End of Well Clean-up Data Report_30 min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-048_Rev A_Signed (2).pdf ؒ جؐؐؐNDB-051 ؒ Santos_Pikka_NDB-051_End of Well Clean-up Data Report_1 min_Final Data.xlsx ؒ Santos_Pikka_NDB-051_End of Well Clean-up Data Report_30 min_Final Data.xlsx ؒ WT-XAK-0127.4_NDB-051_Rev A_Signed.pdf ؒ جؐؐؐNDBi-016 ؒ Santos_Pikka_NDBi-016_End of Well Clean-Up_ Data Report_ 1 min_Final Data.xlsx ؒ Santos_Pikka_NDBi-016_End of Well Clean-Up_ Data Report_30 min_Final Data.xlsx ؒ WT-XAK-0127.4_NDBi-016_Rev A_Signed.pdf ؒ جؐؐؐNDBi-018 ؒ Santos_Pikka_NDBi-018_End of Well Clean-up_Build-up Data Report_1 min_Final.xlsx ؒ Santos_Pikka_NDBi-018_End of Well Clean-up_Build-up Data Report_30 min_Final.xlsx ؒ WT-XAK-0127.4_NDBi-018_Rev A_Signed.pdf ؒ جؐؐؐNDBi-030 224-006 T41154 225-028 T41155 224-124 T41156 224-143 T41157 224-105 T41158 224-085 T41159 224-013 T39830 223-006 T39829 223-120 T39832 NDB-031 ؐ LETTER OF TRANSMITTAL ؒ Santos_Pikka_NDBi-030_End of Well Clean-up Data Report_1-min_Final Data.xlsx ؒ Santos_Pikka_NDBi-030_End of Well Clean-up Data Report_30 minute_Final Data.xlsx ؒ WT-XAK-0127.3_NDBi-030_Rev A_Signed.pdf ؒ جؐؐؐNDBi-036 ؒ Santos_Pikka_NDBi-036_End of Well Clean-up Data Report_1 min_FINAL.xlsx ؒ Santos_Pikka_NDBi-036_End of Well Clean-up Data Report_30 min_FINAL.xlsx ؒ WT-XAK-0127.5_NDBi-036_Rev A Signed (1).pdf ؒ جؐؐؐNDBi-043A ؒ Santos_Pikka_NDBi-043_Daily Well Test Data Report_09152023_0830 - 09202023_2200_Final (1).xlsx ؒ WT-XAK-0127.1_NDBI-043_End of Well Report_Rev A (1).pdf ؒ جؐؐؐNDBi-044 ؒ Santos_Pikka_NDBi-044_End of Well Clean-Up Data Report_1-min_Final .xlsx ؒ Santos_Pikka_NDBi-044_End of Well Clean-Up Data Report_30-min_Final.xlsx ؒ WT-XAK-0127.3_End of Well Report_NDBi-044_Rev A_Signed.pdf ؒ جؐؐؐNDBi-046L1 ؒ Santos_Pikka_NDBi-046_End of Well Clean-up Data Report_1 min_Final Data.xlsx ؒ Santos_Pikka_NDBi-046_End of Well Clean-up Data Report_30 min_Final Data.xlsx ؒ WT-XAK-0127.4_NDBi-046_Rev A_Signed.pdf ؒ جؐؐؐNDBi-049 ؒ Santos_Pikka_NDBi-049_End of Well Clean-up Data Report_1-min_Final.xlsx ؒ Santos_Pikka_NDBi-049_End of Well Clean-up Data Report_30-min_Final.xlsx ؒ WT-XAK-0127.5_NDBi-049_Rev A Signed.pdf ؒ ؤؐؐؐNDBi-050 Santos_Pikka_NDBi-050_End of Well Clean-up Data Report_1-min_FINAL.xlsx Santos_Pikka_NDBi-050_End of Well Clean-up_Data Report_30-min_FINAL.xlsx WT-XAK-0127.5_NDBi-050_Rev A_Signed (1).pdf 225-012 T41160 224-119 T41161 224-154 T41162 223-052 T39834 223-087 T39835 224-029 T39837 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION Baker Hughes has provided us with LithTrak Azimuthal Caliper data for all 22 previous wells. Details are provided on following pages with well name and API table as reference. Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh 601 W 5th Ave., Anchorage, AK 99501 shannon.koh@santos.com DATE: 11/18/2025 From: Shannon Koh Santos 601 W 5th Ave. Anchorage, AK 99501 To: Gavin Glutas AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/Teams ܆Hardcopy ܈Other - FTP REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܈Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܆Other COMMENTS: Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.19 08:30:05 -09'00' LETTER OF TRANSMITTAL Well API NDB-010 50103209200000 NDB-011 50103209160000 NDBi-014 50103208690000 NDBi-016 50103208920000 NDBi-018 50103208880000 NDB-024 50103208620000 NDB-025 50103208770000 NDB-027 50103209220000 NDBi-030 50103208730000 NDB-031 50103209120000 NDB-032 50103208600000 NDBi-036 50103209080000 NDB-037 50103208950000 NDBi-043 50103208590000 NDBi-044 50103208650000 NDBi-046 50103208830000 NDB-048 50103209020000 NDBi-049 50103208940000 NDBi-050 50103209040000 NDB-051 50103208800000 DW-02 50103208550000 PWD-02 50103208790000 جؐؐؐDW-02 Lithotrak Caliper data ؒ SANTOS_DW-02_BHP_8_5_2384_7459ft_RUN5.dlis ؒ SANTOS_DW-02_BHP_8_5_2384_7459ft_RUN5.las ؒ جؐؐؐNDB-010 Lithotrak Caliper data ؒ SANTOS_NDB-010_BHP_8_5_9620_19462ft_Run3.dlis ؒ SANTOS_NDB-010_BHP_8_5_9620_19462ft_Run3.las ؒ جؐؐؐNDB-011 Lithotrak Caliper data ؒ جؐؐؐ12.25 in ؒ ؒ SANTOS_NDB-011_BHP_12_25in_2755_12365ft_RUN2.dlis ؒ ؒ SANTOS_NDB-011_BHP_12_25in_2755_12365ft_RUN2.las ؒ ؒ ؒ ؤؐؐؐ8.5 in ؒ SANTOS_NDB-011_BHP_8_5in_2755_12365ft_RUN3.dlis 223-039 T41107 225-061 T41108 225-048 T41109 NDB-031 50103209120000 LETTER OF TRANSMITTAL ؒ SANTOS_NDB-011_BHP_8_5in_2755_12365ft_RUN3.las ؒ جؐؐؐNDB-024 Lithotrak Caliper data ؒ جؐؐؐRun 6 ؒ ؒ Santos_NDB-024_BHP_12_25_2443_6175ft_Run6.dlis ؒ ؒ Santos_NDB-024_BHP_12_25_2443_6175ft_Run6.las ؒ ؒ ؒ ؤؐؐؐRun 7 ؒ SANTOS_NDB-024_BHP_8_5_11466_17969ft_RUN7.dlis ؒ SANTOS_NDB-024_BHP_8_5_11466_17969ft_RUN7.las ؒ جؐؐؐNDB-025 Lithotrak Caliper data ؒ SANTOS_NDB-025_BHP_8_5_8437_13838ft_Run3.dlis ؒ SANTOS_NDB-025_BHP_8_5_8437_13838ft_Run3.las ؒ جؐؐؐNDB-027 Lithotrak Caliper data ؒ SANTOS_NDB-027_BHP_6_125in_17280_12862ft_RUN6.dlis ؒ SANTOS_NDB-027_BHP_6_125in_17280_12862ft_RUN6.las ؒ جؐؐؐNDB-031 Lithotrak Caliper data ؒ SANTOS_NDB-031_BHP_6_125_18706_24362ft_Run4.dlis ؒ SANTOS_NDB-031_BHP_6_125_18706_24362ft_Run4.las ؒ جؐؐؐNDB-032 Lithotrak Caliper data ؒ جؐؐؐRun 3 ؒ ؒ SANTOS_NDB-032_BHP_12_25_2598_6224ft_Run3.las ؒ ؒ SANTOS_NDB_032_BHP_12_25_2598_6224ft_Run3.dlis ؒ ؒ ؒ ؤؐؐؐRun 4 ؒ SANTOS_NDB-032_BHP_8_5_6285_12280ft_Run4.dlis ؒ SANTOS_NDB-032_BHP_8_5_6285_12280ft_Run4.las ؒ جؐؐؐNDB-037 Lithotrak Caliper data ؒ SANTOS_NDB-037_BHP_8_25_10871_17793_RUN3.dlis ؒ SANTOS_NDB-037_BHP_8_25_10871_17793_RUN3.las ؒ جؐؐؐNDB-048 Lithotrak Caliper data ؒ جؐؐؐRun 2 ؒ ؒ SANTOS_NDB-048_BHP_12_25_2252_12112ft_Run2.dlis ؒ ؒ SANTOS_NDB-048_BHP_12_25_2252_12112ft_Run2.las ؒ ؒ ؒ ؤؐؐؐRun 3 223-076 T41110 224-006 T41111 225-066 T41112 225-028 T41113 223-060 T41114 224-124 T41115 224-143 T41116 NDB-031 Lithotrak Caliper data LETTER OF TRANSMITTAL ؒ SANTOS_NDB-048_BHP_8_5in_12168_21225ft_Run3.dlis ؒ SANTOS_NDB-048_BHP_8_5in_12168_21225ft_Run3.las ؒ جؐؐؐNDB-051 Lithotrak Caliper data ؒ جؐؐؐRun 2 ؒ ؒ SANTOS_NDB-051_BHP_12_25_3258_11502_RUN2.dlis ؒ ؒ SANTOS_NDB-051_BHP_12_25_3258_11502_RUN2.las ؒ ؒ ؒ ؤؐؐؐRun 3 ؒ SANTOS_NDB-051_BHP_8_5_11565_17429.dlis ؒ SANTOS_NDB-051_BHP_8_5_11565_17429.las ؒ جؐؐؐNDBi-014 Lithotrak Caliper data ؒ SANTOS_NDBi-014_BHP_8_5_10448_15362_RUN3.dlis ؒ SANTOS_NDBi-014_BHP_8_5_10448_15362_RUN3.las ؒ جؐؐؐNDBi-016 Lithotrak Caliper data ؒ SANTOS_NDBi-016_BHP_8_5in_12860_18610ft_RUN4.las ؒ SANTOS_NDBi-016_BHP_8_5in_12860_18610ft_RUN4_1.dlis ؒ جؐؐؐNDBi-018 Lithotrak Caliper data ؒ جؐؐؐRun 2 ؒ ؒ SANTOS_NDBi-018_BHP_12_25_2580_8193_RUN2.dlis ؒ ؒ SANTOS_NDBi-018_BHP_12_25_2580_8193_RUN2.las ؒ ؒ ؒ ؤؐؐؐRun 3 ؒ SANTOS_NDBi-018_BHP_8_5_8225_13060_RUN3.dlis ؒ SANTOS_NDBi-018_BHP_8_5_8225_13060_RUN3.las ؒ جؐؐؐNDBi-030 Lithotrak Caliper data ؒ SANTOS_NDBi-030_BHP_8_5in_11200_1743.6ft_Run6.dlis ؒ SANTOS_NDBi-030_BHP_8_5in_11200_1743.6ft_Run6.las ؒ جؐؐؐNDBi-036 Lithotrak Caliper data ؒ جؐؐؐRun 4 ؒ ؒ SANTOS_NDBi-036_BHP_8_5in_10990_16780ft_Run4.dlis ؒ ؒ SANTOS_NDBi-036_BHP_8_5in_10990_16780ft_Run4.las ؒ ؒ ؒ ؤؐؐؐRun 6 ؒ SANTOS_NDBi-036_BHP_6.125in_16813_22680ft_Run6.dlis ؒ SANTOS_NDBi-036_BHP_6.125in_16813_22680ft_Run6.las ؒ 224-013 T41117 223-105 T41118 224-105 T41119 224-085 T41120 223-120 T41121 225-012 T41122 LETTER OF TRANSMITTAL جؐؐؐNDBi-043 Lithotrak Caliper data ؒ جؐؐؐRun 2 ؒ ؒ Santos_NDBi-043_BHP_12_25_2443_6175ft_Run2.dlis ؒ ؒ Santos_NDBi-043_BHP_12_25_2443_6175ft_Run2.las ؒ ؒ ؒ ؤؐؐؐRun 4 ؒ Santos_NDBi-043_BHP_8_5_6240_13105ft_Run4.dlis ؒ Santos_NDBi-043_BHP_8_5_6240_13105ft_Run4.las ؒ جؐؐؐNDBi-044 Lithotrak Caliper data ؒ SANTOS_NDBi-044_BHP_8_5in_11114_17783ft_RUN5.dlis ؒ SANTOS_NDBi-044_BHP_8_5in_11114_17783ft_RUN5.las ؒ جؐؐؐNDBi-046 Lithotrak Caliper data ؒ SANTOS_NDBi-046_BHP_12_25_3758_12514_RUN2.dlis ؒ SANTOS_NDBi-046_BHP_12_25_3758_12514_RUN2.las ؒ جؐؐؐNDBi-049 Lithotrak Caliper data ؒ جؐؐؐRun 2 ؒ ؒ SANTOS_NDBi-049_BHP_12_25_2645_115572ft_Run2.dlis ؒ ؒ SANTOS_NDBi-049_BHP_12_25_2645_115572ft_Run2.las ؒ ؒ ؒ ؤؐؐؐRun 3 ؒ SANTOS_NDBi-049_BHP_8_5_11642_19250_RUN3.dlis ؒ SANTOS_NDBi-049_BHP_8_5_11642_19250_RUN3.las ؒ جؐؐؐNDBi-050 Lithotrak Caliper data ؒ SANTOS_NDBi-050_BHP_6_125_15145_22525ft_Run9.dlis ؒ SANTOS_NDBi-050_BHP_6_125_15145_22525ft_Run9.las ؒ ؤؐؐؐPWD-02 Lithotrak Caliper data SANTOS_PWD-02_BHP_8_5_6818_9461_Run_4_5_6.dlis SANTOS_PWD-02_BHP_8_5_6818_9461_Run_4_5_6.las 223-051 T41123 223-087 T41124 224-028 T41125 224-119 T41126 224-154 T41127 224-009 T41128 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDB-031 (50-103-20912-0000) Final Well data Submittal - Details on following pages. Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh 601 W 5th Ave., Anchorage, AK 99501 shannon.koh@santos.com DATE: 8/28/2025 From: Shannon Koh Santos 601 W 5th Ave. Anchorage, AK 99501 To: Gavin GluǇas AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/Teams ܆Hardcopy ܈Other - FTP REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܈Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܆Other COMMENTS: 225-028 T40839 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.28 13:54:16 -08'00' From:Wallace, Chris D (OGC) To:Leahy, Scott (Scott) Cc:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC); Senden, Robert (Ty); Michaela.Atherton@santos.com; Vern.Johnson@santos.com; travis.smith@santos.com Subject:FW: NDB-031 (PTD 2250280) Frac Sundry 325-411 Date:Wednesday, July 30, 2025 8:33:56 AM Attachments:NDB-031 MIT-IA 6-12-25.pdf NDB-031 MITIA Data.xlsx MIT-T 07132025 Standard MIT Form.xls SANTOS_07-13-25_00-11-28_DETAILED.pdf NDB-31 Revised Pressure Limits.pdf Scott, The proposed revisions to the pressure limits (as attached) are approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Leahy, Scott (Scott) <Scott.Leahy@santos.com> Sent: Tuesday, July 29, 2025 2:12 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Senden, Robert (Ty) <Ty.Senden@santos.com>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com>; Johnson, Vernon (Vern) <Vern.Johnson@santos.com>; Smith, Travis (Travis) <Travis.Smith@santos.com> Subject: RE: NDB-031 Frac Sundry 325-411 Bryan/ Chris, Due to a separate inquiry from Chris this morning, I’m requesting a modification of the fracture pressure limits on NDB-031. Please see the attached file highlighting the reduction in the MAWP based on MIT-T testing pressures. I have attached the pressure test data for your reference as well. The expected pressures during the fracture treatment remain below these adjustments. We are scheduled to frac this well on Friday so your prompt review would be appreciated. Regards, Scott Leahy – Completions SpecialistOil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, July 28, 2025 3:54 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Leahy, Scott (Scott) <Scott.Leahy@santos.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Senden, Robert (Ty) <Ty.Senden@santos.com>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com> Subject: ![EXT]: RE: NDB-031 Frac Sundry 325-411 Scott, The changes proposed propose in your email and its attachments to sundry 325-411 are approved. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, July 28, 2025 2:20 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: FW: NDB-031 Frac Sundry 325-411 Bryan, Please reply back to Santos and let them know if you need anything from them to formalize these changes/approvals. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Leahy, Scott (Scott) <Scott.Leahy@santos.com> Sent: Monday, July 28, 2025 1:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Senden, Robert (Ty) <Ty.Senden@santos.com>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com> Subject: RE: NDB-031 Frac Sundry 325-411 Chris/ Andrew, We are currently filling tanks and rigging up to fracture NDBi-031. Have you had a chance to review my request from last week? Thank you, Scott Leahy – Completions SpecialistOil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ From: Leahy, Scott (Scott) Sent: Tuesday, July 22, 2025 4:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Senden, Robert (Ty) <Ty.Senden@santos.com>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com> Subject: NDB-031 Frac Sundry 325-411 Chris/Andrew, Thank you for turning the NDB-031 Sundry around quickly. Over the past week, our groups have decided to change the pump designs, and I’ve included them for your review. The changes aren’t large but different enough that I wanted to highlight it. The total proppant is now planned at 2.46MM lbs (increased by ~200K lbs) with 22,136 total slurry volume, however, we plan to go to 10 PPA on most stages now as opposed to just the last stage. Going to 10 PPA increases the expected WHP, but it is expected that we will still be below the first trips. I’ve updated the expected pressure and frac geometry table for your reference. Lastly, I noticed that Tracerco didn’t plan to add a solid tracer and therefore left it out of the disclosure. The updated disclosure from Tracerco with the additional tracer is attached for your review. We’ve pumped these solid tracers before on other wells so there shouldn’t be a surprise. Thanks for your help. Let me know if we are still good to proceed. We plan to start hauling water and rigging up this weekend. Scott Leahy – Completions SpecialistOil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ Santos Ltd A.B.N. 80 007 550 923Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential orcontain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure isstrictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy.Please consider the environment before printing this email MECHANICAL INTEGRITY TEST (MIT) FORM WELL NO.: DATE: WELL TYPE: i,e,: Prod, Prod A/L, MI, SWI, PWI MIT TEST TYPE: i.e., Tbg, IA / 9-5/8", OA / 13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE:psi. Note: Please consult the Well Integrity Supervisor on results. FLUID TYPE(S) USED TO PRESSURE TEST: Record all Wellhead Pressures before and during Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME:PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI)(PSI)(PSI)*(PSI)**FAIL S TUBING 120 5820 5757 5729 PASS T IA / 9-5/8"82 424 420 413 OA / 13-3/8"0 0 0 0 1 COMMENTS: 5.45 bbls to fill Tubing. End test at 01:31hrs. Bled pressure down to 200psi and received 5.45bbls back to tank PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME:PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI)(PSI)(PSI)*(PSI)**FAIL S TUBING T IA / 9-5/8" OA / 13-3/8" 2 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME:PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI)(PSI)(PSI)(PSI)FAIL S TUBING T IA / 9-5/8" OA / 13-3/8" 3 COMMENTS: MISC COMMENTS: * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min Witness: NDB -031 07/13/2025 Tubing 5500 Diesel 00:59 Producer cc: PWS 6/3/00 CASING AND LEAK-OFF FRACTURE TESTS Well Name:NDB-031 Date:6/12/2025 Csg Size/Wt/Grade:Supervisor:J. Whitlatch Csg Setting Depth:18,526 TMD TVD Mud Weight:9.2 ppg Leakoff pressure =psi FIT/LOT=Hole Depth =md Fluid Pumped=12.2 Volume Back =12.2 bbls Estimated Pump Output:0.0925 Barrels/Stroke LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here -> ->0 0 -> ->12 315 -> ->24 698 -> ->36 1079 -> ->48 1480 -> ->60 1882 -> ->72 2280 -> ->84 2700 -> ->96 3127 -> ->108 3541 -> ->120 3966 -> ->132 4408 -> -> -> -> Enter Holding Enter Holding Enter Holding Time Here Time Here Pressure Here ->0 ->0 4408 ->1 ->1 4403 ->2 ->2 4399 ->3 ->3 4398 ->4 ->4 4396 ->5 ->5 4394 ->6 ->10 4385 ->7 ->15 4378 ->8 ->20 4374 ->9 ->25 4367 ->10 ->30 4365 -> -> -> -> -> -> 4.5" 12.6# P-110S TSH-563 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140Pressure (psi)Strokes (# of) LEAK-OFF DATA CASING TEST DATA 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 0 5 10 15 20 25 30 35Pressure (psi)Time (Minutes) LEAK-OFF DATA CASING TEST DATA a prograde from west to east. The Nanushuk Fm is often highly laminated and comprised of fine-grained sand, silt, and shale. It can contain lithic-clasts from various sedimentary and metamorphic sources. Distributary channel mouth bar deposits and shoreface sands comprise major sand packages in the Nanushuk Fm. Lower Confining Zone Name: Torok Formation Depth/Thickness: 4,692 to 5,591 ft TVDSS/899 ft thick Lithological Description: The Lower Torok sands are overlain by the Upper Torok Fm, which is up to 1,200 feet thick in the Pikka Unit. The Upper Torok is composed primarily of shale (Hue Shale) with some thin interbedded siltstones. Within the Upper Torok Fm, several condensed, impermeable shale layers called maximum flooding surfaces (MFS) are present. These are regionally extensive and provide excellent confining intervals. 10. Estimated fracture pressure for each zone listed below: (Revised 7/29) Held IA Pressure (psi) IA PRV (psi) GORV (psi) Pump Trip Pressure (psi) Surface Line Pressure Test (psi) MAWP (psi) Stages 1-10 3,800 4,100 8,200 7,700 9,000 8,600 Attachment H Step 17 notes that MIT-T will be done to 5500. MIT-T performed on 7/13 passed at 5,300 psi. (8600 psi MAWP – 3,800 psi IA hold) * 1.1 = 5,280 psi 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, July 28, 2025 3:54 PM To:Wallace, Chris D (OGC); Leahy, Scott (Scott) Cc:Dewhurst, Andrew D (OGC); Senden, Robert (Ty); Michaela.Atherton@santos.com Subject:RE: NDB-031 Frac Sundry 325-411 Scott, The changes proposed propose in your email and its attachments to sundry 325-411 are approved. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, July 28, 2025 2:20 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: FW: NDB-031 Frac Sundry 325-411 Bryan, Please reply back to Santos and let them know if you need anything from them to formalize these changes/approvals. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276- 7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Leahy, Scott (Scott) <Scott.Leahy@santos.com> Sent: Monday, July 28, 2025 1:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> 2 Cc: Senden, Robert (Ty) <Ty.Senden@santos.com>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com> Subject: RE: NDB-031 Frac Sundry 325-411 Chris/ Andrew, We are currently filling tanks and rigging up to fracture NDBi-031. Have you had a chance to review my request from last week? Thank you, Scott Leahy – Completions Specialist Oil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ From: Leahy, Scott (Scott) Sent: Tuesday, July 22, 2025 4:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Senden, Robert (Ty) <Ty.Senden@santos.com>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com> Subject: NDB-031 Frac Sundry 325-411 Chris/Andrew, Thank you for turning the NDB-031 Sundry around quickly. Over the past week, our groups have decided to change the pump designs, and I’ve included them for your review. The changes aren’t large but diƯerent enough that I wanted to highlight it. The total proppant is now planned at 2.46MM lbs (increased by ~200K lbs) with 22,136 total slurry volume, however, we plan to go to 10 PPA on most stages now as opposed to just the last stage. Going to 10 PPA increases the expected WHP, but it is expected that we will still be below the first trips. I’ve updated the expected pressure and frac geometry table for your reference. Lastly, I noticed that Tracerco didn’t plan to add a solid tracer and therefore left it out of the disclosure. The updated disclosure from Tracerco with the additional tracer is attached for your review. We’ve pumped these solid tracers before on other wells so there shouldn’t be a surprise. Thanks for your help. Let me know if we are still good to proceed. We plan to start hauling water and rigging up this weekend. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Scott Leahy – Completions Specialist Oil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email Well Name NDB-031 07/22/25 Schedule STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)(BBL)(BBL) a FP b FP c WF 26 3.5 40 40 1680 1680 40 40 d Pump Check WF 26 40 375 415 15750 17430 375 415 0 415 e DFIT XL 26 40 250 665 10500 27930 250 665 f WF 26 40 365 1030 15330 43260 365 1030 0 1030 PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME STAGE AVERAGE FLUID RATE STAGE CUM TOT JOB STAGE CUM STAGE CUM Size or Stage Cum #PPA TYPE (BPM)(BBL)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)Type (BBL)(BBL) 1 0 Line out XL XL 26 18 40 40 1070 1680 44940 0 0 40 1070 2 0 Drop Stage 1 Ball/Collet FP 0 18 3 43 1073 126 45066 0 0 CSG-IV 3 1073 3 0 Stage 1 PAD XL 26 40 336 379 1409 14112 59178 0 0 336 1409 4 0 Slow for Seat XL 26 18 50 429 1459 2100 61278 0 0 50 1459 5 0 Resume Pad XL 26 40 1 430 1460 42 61320 0 0 1 1460 6 1 Scour XL 26 40 30 460 1490 1260 62580 1207 1207 40/70-CL 29 1489 7 3 Scour XL 26 40 60 520 1550 2520 65100 6674 7881 40/70-CL 53 1542 8 0 Resume PAD XL 26 40 50 570 1600 2100 67200 0 7881 50 1592 9 1 Flat XL 26 40 125 695 1725 5250 72450 5027 12907 CSG-IV 120 1711 10 2 Flat XL 26 40 140 835 1865 5880 78330 10801 23708 CSG-IV 129 1840 11 3 Flat XL 26 40 170 1005 2035 7140 85470 18902 42610 CSG-IV 150 1990 12 4 Flat XL 26 40 170 1175 2205 7140 92610 24252 66863 CSG-IV 144 2134 13 5 Flat XL 26 40 170 1345 2375 7140 99750 29214 96076 CSG-IV 139 2273 14 6 Flat XL 26 40 170 1515 2545 7140 106890 33827 129904 CSG-IV 134 2408 15 7 Flat XL 26 40 140 1655 2685 5880 112770 31400 161304 CSG-IV 107 2514 16 8 Flat XL 26 40 100 1755 2785 4200 116970 24793 186096 CSG-IV 74 2588 17 0 Clear Surface Lines XL 26 40 15 1770 2800 630 117600 0 186096 15 2603 18 0 Spacer XL 26 40 15 1785 2815 630 118230 0 186096 15 2618 19 0 Drop Stage 2 Ball/Collet FP 0 40 3 1788 2818 126 118356 0 186096 3 2621 20 0 Stage 2 PAD XL 26 40 328 2116 3146 13776 132132 0 186096 328 2949 21 0 Slow for Seat XL 26 18 50 2166 3196 2100 134232 0 186096 50 2999 22 0 Resume Pad XL 26 40 1 2167 3197 42 134274 0 186096 1 3000 23 1 Scour XL 26 40 60 2227 3257 2520 136794 2413 188509 40/70-CL 57 3058 24 3 Scour XL 26 40 120 2347 3377 5040 141834 13348 201858 40/70-CL 106 3164 25 0 Flat XL 26 40 50 2397 3427 2100 143934 0 201858 50 3214 26 1 Flat XL 26 40 200 2597 3627 8400 152334 8043 209900 CSG-IV 191 3405 27 2 Flat XL 26 40 225 2822 3852 9450 161784 17358 227259 CSG-IV 207 3612 28 4 Flat XL 26 40 275 3097 4127 11550 173334 39232 266490 CSG-IV 234 3845 29 6 Flat XL 26 40 260 3357 4387 10920 184254 51736 318226 CSG-IV 205 4051 30 8 Flat XL 26 40 240 3597 4627 10080 194334 59502 377729 CSG-IV 177 4228 31 10 Flat XL 26 40 200 3797 4827 8400 202734 58170 435899 CSG-IV 138 4366 FLUID Neat Water COMMENTS SD monitor 20 min Load Stage 1 ball/collet, Prime and Pressure Test Open well Displace PT - Shut down 5 min Shut down- ISIP DFIT Dispacement to P-Sleeve (add line volume) Well Name NDB-031 07/22/25 Schedule STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)(BBL)(BBL) FLUID Neat Water Prime and Pressure Test320Clear Surface Lines XL 26 40 15 3812 4842 630 203364 0 435899 15 4381 33 0 Spacer XL 26 40 15 3827 4857 630 203994 0 435899 15 4396 34 0 Drop Stage 3 Ball/Collet FP 0 40 3 3830 4860 126 204120 0 435899 3 4399 35 0 Stage 3 PAD XL 26 40 320 4150 5180 13440 217560 0 435899 320 4719 36 0 Slow for Seat XL 26 18 50 4200 5230 2100 219660 0 435899 50 4769 37 0 Resume Pad XL 26 40 1 4201 5231 42 219702 0 435899 1 4770 38 1 Scour XL 26 40 60 4261 5291 2520 222222 2413 438312 40/70-CL 57 4828 39 3 Scour XL 26 40 120 4381 5411 5040 227262 13348 451660 40/70-CL 106 4934 40 0 Resume Pad XL 26 40 50 4431 5461 2100 229362 0 451660 50 4984 41 1 Flat XL 26 40 200 4631 5661 8400 237762 8043 459703 CSG-IV 191 5175 42 2 Flat XL 26 40 225 4856 5886 9450 247212 17358 477061 CSG-IV 207 5382 43 4 Flat XL 26 40 275 5131 6161 11550 258762 39232 516293 CSG-IV 234 5615 44 6 Flat XL 26 40 260 5391 6421 10920 269682 51736 568029 CSG-IV 205 5821 45 8 Flat XL 26 40 240 5631 6661 10080 279762 59502 627531 CSG-IV 177 5998 46 10 Flat XL 26 40 200 5831 6861 8400 288162 58170 685701 CSG-IV 138 6136 47 0 Clear Surface Lines XL 26 40 15 5846 6876 630 288792 0 685701 15 6151 48 0 Spacer XL 26 40 15 5861 6891 630 289422 0 685701 15 6166 49 0 Drop Stage 4 Ball/Collet FP 0 40 3 5864 6894 126 289548 0 685701 3 6169 50 0 Stage 4 PAD XL 26 40 311 6175 7205 13062 302610 0 685701 311 6480 51 0 Slow for Seat XL 26 18 50 6225 7255 2100 304710 0 685701 50 6530 52 0 Resume Pad XL 26 40 1 6226 7256 42 304752 0 685701 1 6531 53 1 Scour XL 26 40 60 6286 7316 2520 307272 2413 688114 40/70-CL 57 6589 54 3 Scour XL 26 40 120 6406 7436 5040 312312 13348 701462 40/70-CL 106 6695 55 0 Resume Pad XL 26 40 50 6456 7486 2100 314412 0 701462 50 6745 56 1 Flat XL 26 40 200 6656 7686 8400 322812 8043 709505 CSG-IV 191 6936 57 2 Flat XL 26 40 225 6881 7911 9450 332262 17358 726864 CSG-IV 207 7143 58 4 Flat XL 26 40 275 7156 8186 11550 343812 39232 766095 CSG-IV 234 7376 59 6 Flat XL 26 40 260 7416 8446 10920 354732 51736 817831 CSG-IV 205 7582 60 8 Flat XL 26 40 240 7656 8686 10080 364812 59502 877334 CSG-IV 177 7759 61 10 Flat XL 26 40 200 7856 8886 8400 373212 58170 935503 CSG-IV 138 7897 62 0 Clear Surface Lines XL 26 40 15 7871 8901 630 373842 0 935503 15 7912 63 0 Spacer XL 26 40 15 7886 8916 630 374472 0 935503 15 7927 64 0 Drop Stage 5 Ball/Collet FP 0 40 3 7889 8919 126 374598 0 935503 3 7930 65 0 Stage 5 PAD XL 26 40 303 8192 9222 12726 387324 0 935503 303 8233 66 0 Slow for Seat XL 26 18 50 8242 9272 2100 389424 0 935503 50 8283 67 0 Resume Pad XL 26 40 1 8243 9273 42 389466 0 935503 1 8284 68 1 Scour XL 26 40 60 8303 9333 2520 391986 2413 937917 40/70-CL 57 8342 69 3 Scour XL 26 40 120 8423 9453 5040 397026 13348 951265 40/70-CL 106 8448 70 0 Flat XL 26 40 50 8473 9503 2100 399126 0 951265 50 8498 71 1 Flat XL 26 40 200 8673 9703 8400 407526 8043 959308 CSG-IV 191 8689 72 2 Flat XL 26 40 225 8898 9928 9450 416976 17358 976666 CSG-IV 207 8896 73 4 Flat XL 26 40 275 9173 10203 11550 428526 39232 1015898 CSG-IV 234 9129 74 6 Flat XL 26 40 260 9433 10463 10920 439446 51736 1067634 CSG-IV 205 9334 Well Name NDB-031 07/22/25 Schedule STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)(BBL)(BBL) FLUID Neat Water Prime and Pressure Test758Flat XL 26 40 240 9673 10703 10080 449526 59502 1127136 CSG-IV 177 9512 76 10 Flat XL 26 40 200 9873 10903 8400 457926 58170 1185306 CSG-IV 138 9650 77 0 Clear Surface Lines XL 26 40 15 9888 10918 630 458556 0 1185306 15 9665 78 0 Spacer XL 26 40 15 9903 10933 630 459186 0 1185306 15 9680 79 0 Drop Stage 6 Ball/Collet FP 0 40 3 9906 10936 126 459312 0 1185306 3 9683 80 0 XL Flush (DFIT)XL 26 40 295 10201 11231 12390 471702 0 1185306 295 9978 81 0 Slow for seat (DFIT)XL 26 18 50 10251 11281 2100 473802 0 1185306 50 10028 82 DFIT Flush WF 26 40 265 10516 11546 11130 484932 265 10293 83 3000 feet MD + Surface Eqmt FP 20 58 10574 11604 2423 487355 TOTALS 11604 487355 1185306 Well Name NDB-031 07/22/25 Schedule STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)(BBL)(BBL) a FP b FP c WF 26 3.5 40 40 1680 1680 40 40 d Pump Ball to Seat WF 26 4 326 366 13692 15372 326 366 e Pump Check WF 26 40 120 486 5040 20412 120 486 0 486 PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME STAGE AVERAGE FLUID RATE STAGE CUM TOT JOB STAGE CUM STAGE CUM Size or Stage Cum #PPA TYPE (BPM)(BBL)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)Type (BBL)(BBL) 1 0 Line out XL XL 26 40 40 40 526 1680 22092 0 0 40 526 2 0 Stage 6 PAD XL 26 40 250 290 776 10500 32592 0 0 CSG-IV 250 776 3 1 Scour XL 26 40 60 350 836 2520 35112 2413 2413 40/70- CL 57 833 4 3 Scour XL 26 40 120 470 956 5040 40152 13348 15761 40/70- CL 106 939 5 0 Resume Pad XL 26 40 50 520 1006 2100 42252 0 15761 50 989 6 1 Flat XL 26 40 200 720 1206 8400 50652 8044 23805 16/20- CL 192 1181 7 2 Flat XL 26 40 225 945 1431 9450 60102 17363 41169 16/20- CL 207 1388 8 4 Flat XL 26 40 275 1220 1706 11550 71652 39232 80401 CSG-IV 234 1621 9 6 Flat XL 26 40 260 1480 1966 10920 82572 51736 132136 CSG-IV 205 1826 10 8 Flat XL 26 40 240 1720 2206 10080 92652 59502 191639 CSG-IV 177 2004 11 10 Flat XL 26 40 200 1920 2406 8400 101052 58170 249809 CSG-IV 138 2142 12 0 Clear Surface Lines XL 26 40 15 1935 2421 630 101682 0 249809 15 2157 13 0 Spacer XL 26 40 15 1950 2436 630 102312 0 249809 15 2172 14 0 Drop Stage 7 Ball/Collet FP 0 40 3 1953 2439 126 102438 0 249809 3 2175 15 0 Stage 7 PAD XL 26 40 287 2240 2726 12054 114492 0 249809 287 2462 16 0 Slow for Seat XL 26 18 50 2290 2776 2100 116592 0 249809 50 2512 17 0 Resume Pad XL 26 40 1 2291 2777 42 116634 0 249809 1 2513 18 1 Scour XL 26 40 60 2351 2837 2520 119154 2413 252222 40/70- CL 57 2570 19 3 Scour XL 26 40 120 2471 2957 5040 124194 13348 265570 40/70- CL 106 2676 20 0 Resume Pad XL 26 40 50 2521 3007 2100 126294 0 265570 50 2726 21 1 Flat XL 26 40 200 2721 3207 8400 134694 8044 273614 16/20- CL 192 2918 22 2 Flat XL 26 40 225 2946 3432 9450 144144 17363 290977 16/20- CL 207 3125 23 4 Flat XL 26 40 275 3221 3707 11550 155694 39232 330209 CSG-IV 234 3358 24 6 Flat XL 26 40 260 3481 3967 10920 166614 51736 381945 CSG-IV 205 3563 25 8 Flat XL 26 40 240 3721 4207 10080 176694 59502 441447 CSG-IV 177 3741 26 10 Flat XL 26 40 200 3921 4407 8400 185094 58170 499617 CSG-IV 138 3879 27 0 Clear Surface Lines XL 26 40 15 3936 4422 630 185724 0 499617 15 3894 28 0 Spacer XL 26 40 15 3951 4437 630 186354 0 499617 15 3909 29 0 Drop Stage 8 Ball/Collet FP 0 40 3 3954 4440 126 186480 0 499617 3 3912 30 0 Stage 8 PAD XL 26 40 278 4232 4718 11676 198156 0 499617 278 4190 31 0 Slow for Seat XL 26 18 50 4282 4768 2100 200256 0 499617 50 4240 32 0 Resume Pad XL 26 40 1 4283 4769 42 200298 0 499617 1 4241 33 1 Scour XL 26 40 60 4343 4829 2520 202818 2413 502030 40/70- CL 57 4299 FLUID Neat Water COMMENTS Ensure Stage 7 ball/collet is loaded Prime and Pressure Test Open well Displace PT and Drop Ball - Shut down 5 min Stage to "Line out XL" Well Name NDB-031 07/22/25 Schedule STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)(BBL)(BBL) FLUID Neat Water Prime and Pressure Test343Scour XL 26 40 120 4463 4949 5040 207858 13348 515379 40/70- CL 106 4404 35 0 Resume Pad XL 26 40 50 4513 4999 2100 209958 0 515379 50 4454 36 1 Flat XL 26 40 200 4713 5199 8400 218358 8044 523423 16/20- CL 192 4646 37 2 Flat XL 26 40 225 4938 5424 9450 227808 17363 540786 16/20- CL 207 4853 38 4 Flat XL 26 40 275 5213 5699 11550 239358 39232 580018 CSG-IV 234 5086 39 6 Flat XL 26 40 260 5473 5959 10920 250278 51736 631754 CSG-IV 205 5292 40 8 Flat XL 26 40 240 5713 6199 10080 260358 59502 691256 CSG-IV 177 5469 41 10 Flat XL 26 40 200 5913 6399 8400 268758 58170 749426 CSG-IV 138 5607 42 0 Clear Surface Lines XL 26 40 15 5928 6414 630 269388 0 749426 15 5622 43 0 Spacer XL 26 40 15 5943 6429 630 270018 0 749426 15 5637 44 0 Drop Stage 9 Ball/Collet FP 0 40 3 5946 6432 126 270144 0 749426 3 5640 45 0 Stage 9 PAD XL 26 40 270 6216 6702 11340 281484 0 749426 270 5910 46 0 Slow for Seat XL 26 18 50 6266 6752 2100 283584 0 749426 50 5960 47 0 Resume Pad XL 26 40 1 6267 6753 42 283626 0 749426 1 5961 48 1 Scour XL 26 40 60 6327 6813 2520 286146 2413 751839 40/70- CL 57 6019 49 3 Scour XL 26 40 120 6447 6933 5040 291186 13348 765187 40/70- CL 106 6125 50 0 Resume Pad XL 26 40 50 6497 6983 2100 293286 0 765187 50 6175 51 1 Flat XL 26 40 200 6697 7183 8400 301686 8044 773231 16/20- CL 192 6366 52 2 Flat XL 26 40 225 6922 7408 9450 311136 17363 790595 16/20- CL 207 6573 53 4 Flat XL 26 40 275 7197 7683 11550 322686 39232 829826 CSG-IV 234 6806 54 6 Flat XL 26 40 260 7457 7943 10920 333606 51736 881562 CSG-IV 205 7012 55 8 Flat XL 26 40 240 7697 8183 10080 343686 59502 941065 CSG-IV 177 7189 56 10 Flat XL 26 40 200 7897 8383 8400 352086 58170 999234 CSG-IV 138 7327 57 0 Clear Surface Lines XL 26 40 15 7912 8398 630 352716 0 999234 15 7342 58 0 Spacer XL 26 40 15 7927 8413 630 353346 0 999234 15 7357 59 0 Drop Stage 10 Ball/Collet FP 0 40 3 7930 8416 126 353472 0 999234 3 7360 60 0 Stage 10 PAD XL 26 40 263 8193 8679 11046 364518 0 999234 263 7623 61 0 Slow for Seat XL 26 18 50 8243 8729 2100 366618 0 999234 50 7673 62 0 Resume Pad XL 26 40 87 8330 8816 3654 370272 0 999234 87 7760 63 1 Flat XL 26 40 205 8535 9021 8610 378882 8245 1007480 16/20- CL 196 7956 64 3 Flat XL 26 40 205 8740 9226 8610 387492 22803 1030283 16/20- CL 181 8137 65 5 Flat XL 26 40 280 9020 9506 11760 399252 48117 1078400 CSG-IV 229 8367 66 7 Flat XL 26 40 255 9275 9761 10710 409962 57193 1135592 CSG-IV 195 8561 67 9 Flat XL 26 40 255 9530 10016 10710 420672 68867 1204460 CSG-IV 182 8743 68 10 Flat XL 26 40 225 9755 10241 9450 430122 65441 1269901 CSG-IV 156 8899 69 XL Flush XL 26 40 20 9775 10261 840 430962 20 8919 70 Linear Flush WF 26 40 213 9988 10474 8946 439908 213 9132 71 3000 feet MD + Surface Eqmt FP 20 58 10046 10532 2423 442331 TOTALS 10532 442331 1269901 Fracture gradient values for each stage are listed in detail within Attachment K. In general, the fracture gradient values for the confining zones and pay zone are listed below: Upper confining: Shale gradient – 0.71 psi/ft Fracturing: Sand gradient- 0.61 psi/ft Lower confining: Shale gradient- 0.69 psi/ft Mechanical condition of wells transecting the confining zones –NDBi-036 and NDBi- 050 are within 1/2-mile radius of NDB-031. Please see Attachment B as reference. 11. Suspected fault or fracture that may transect the confining zones: There are no known faults within the ½ mile radius of NDB-031. Please See Attachment B. Note: Fractures are estimated to propagate along wellbore longitudinally at ~330o. Stage MD Perf Depth (ft) TVD Perf Depth (ft) Max Frac Height (ft) Frac ½ Length (ft) Max Rate (bpm) Est. Max Pressure (psi) Max Prop Conc. (PPA) 1 24,094 4,110 255 450 40 6,691 8 2 23,550 4,118 257 471 40 7,289 10 3 23,006 4,124 254 460 40 7,170 10 4 22,463 4,130 251 401 40 6,990 10 5 21,920 4,136 253 379 40 6,817 10 6 21,378 4,142 249 439 40 6,686 10 7 20,833 4,148 248 436 40 6,554 10 8 20,289 4,154 253 375 40 6,391 10 9 19,745 4,161 247 400 40 6,227 10 10 19,202 4,166 249 405 40 6,104 10 Updated 07/21/2025 7/21/2025 TBD AK TSCA Status North Slope TBD Pre TBD TBD TBD Trade Name Supplier Purpose Ingredients Name CAS # Percentage by Mass of Ingredient Percent of Ingredient in Total Mass Pumped Mass of Ingredient (lbs) SME Tracerco Carrier Fluid Soy Methyl Ester 67784-80-9 100 #VALUE! 125.2224160000 T-160D Tracerco Chemical Tracer 2,4,5-Tribromotoluene 3278-88-4 100 #VALUE! 0.6613860000 T-165G Tracerco Chemical Tracer 2-Bromofluorene 1133-80-8 100 #VALUE! 0.8818480000 T-721 Tracerco Chemical Tracer 4,4'-Dichlorobenzophenone 90-98-2 100 #VALUE! 0.4409240000 T-720 Tracerco Chemical Tracer 1,2,4,5-Tetrabromobenzene 636-28-2 100 #VALUE! 0.4409240000 T-772 Tracerco Chemical Tracer 2-(Trifluoromethyl)Benzophenone 727-99-1 100 #VALUE! 0.4409240000 T-731 Tracerco Chemical Tracer 1-Bromo-3,5-dichlorobenzene 19752-55-7 100 #VALUE! 0.4409240000 T-165C Tracerco Chemical Tracer 9-Bromophenanthrene 573-17-1 100 #VALUE! 0.6613860000 T-161B Tracerco Chemical Tracer 4-Iodotoluene 624-31-7 100 #VALUE! 0.4409240000 T-166A Tracerco Chemical Tracer 5-Iodo-m-xylene 22445-41-6 100 #VALUE! 1.1023100000 T-719 Tracerco Chemical Tracer 3,4-Dichlorobenzophenone 6284-79-3 100 #VALUE! 0.4409240000 T-716 Tracerco Solid 1,3,5-Tribromobenzene 626-39-1 100 #VALUE! 0.4409240000 T-750 Tracerco Solid 1,4-Dibromo-2-fluorobenzene 1435-52-5 100 #VALUE! 0.4409240000 T-751 Tracerco Solid Bis(4-bromophenyl)ether 2050-47-7 100 #VALUE! 1.5432340000 Water Tracerco Carrier Fluid Water 7732-18-5 100 #VALUE! 73.9197766400 T-257a Tracerco Chemical Tracer Sodium-3,5-di(Trifluoromethyl)benzoate87441-96-1 100 #VALUE! 0.7716170000 T-805 Tracerco Chemical Tracer Sodium-2,4-Dichlorobenzoate 38402-11-8 100 #VALUE! 0.7716170000 T-806 Tracerco Chemical Tracer Sodium-2,5-dichlorobenzoate 63891-98-5 100 #VALUE! 0.7716170000 T-158d Tracerco Chemical Tracer Sodium-3,4-Difluorobenzoate 522651-44-1 100 #VALUE! 0.7716170000 T-176a Tracerco Chemical Tracer Sodium-2,3,4-trifluorobenzoate 402955-41-3 100 #VALUE! 0.7716170000 T-804 Tracerco Chemical Tracer Sodium-2,3-dichlorobenzoate 118537-84-1 100 #VALUE! 0.7716170000 T-190b Tracerco Chemical Tracer Sodium-3-(Trifluoromethyl) benzoate 69226-41-1 100 #VALUE! 0.7716170000 T-803 Tracerco Chemical Tracer Sodium-4-chlorobenzoate 3686-66-6 100 #VALUE! 0.7716170000 T-190c Tracerco Chemical Tracer Sodium-4-(Trifluoromethyl) benzoate 25832-58-0 100 #VALUE! 0.7738216200 T-801 Tracerco Chemical Tracer Sodium-2-chlorobenzoate 17264-74-3 100 #VALUE! 0.7760262400 Hydraulic Fracturing Fluid Product Component Information Disclosure Manufacturer Contact Tracerco 4106 New West Dr. Pasadena Texas 77507 Tel: 281-291-7769 Fracture Date State: Approved For Tracerco County: API Number: Operator Name: Oil Search Alaska, LLC Well Name and Number: NDB-031 Report Type (Pre or Post Job) Total Water Volume (gal): Water Mass Fraction Total Mass Pumped (lbs) 07/22/25 RBDMS JSB 072225 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDB-031 (50-103-20912-0000) Final Well data Submittal - Details on following pages. Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh 601 W 5th Ave., Anchorage, AK 99501 shannon.koh@santos.com DATE: 7/9/2025 From: Shannon Koh Santos 601 W 5th Ave. Anchorage, AK 99501 To: Gavin Glutas AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/Teams ܆Hardcopy ܈Other - FTP REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܈Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܆Other COMMENTS: 225-028 T40655 7/9/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.09 13:07:33 -08'00' LETTER OF TRANSMITTAL جؐؐؐDirectional Survey ؒ NDB-031 Definitive Compass Survey Report - NAD27.pdf ؒ NDB-031 Definitive Compass Survey Report - NAD83.pdf ؒ NDB-031 Definitive Survey - NAD27.txt ؒ NDB-031 Definitive Survey - NAD83.txt ؒ NDB-031 Final Definitive Survey.xlsx ؒ NDB-031 Plan View.pdf ؒ NDB-031 Vertical Section View.pdf ؒ ؤؐؐؐLog Digital Data and Plots جؐؐؐBaker Hughes ؒ جؐؐؐDigital Data ؒ ؒ جؐؐؐFE ؒ ؒ ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐBack ream data ؒ ؒ ؒ جؐؐؐRun 2 ؒ ؒ ؒ ؒ NDB-031_LWD_GR_Res_R02_RM_BROOH.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐRun 3 ؒ ؒ ؒ ؒ NDB-031_LWD_GR_Res_RM_12541 - 12460ft_BROOH.las ؒ ؒ ؒ ؒ NDB-031_LWD_GR_Res_RM_13022 - 12940ft_BROOH.las ؒ ؒ ؒ ؒ NDB-031_LWD_GR_Res_RM_18699 -15019ft_BROOH.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐRun 4 ؒ ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24398 -18737ft_BROOH.las ؒ ؒ ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ ؒ NDB-031_AP_R01_RM.las ؒ ؒ ؒ NDB-031_AP_R02_RM.las ؒ ؒ ؒ NDB-031_AP_R03_RM.las ؒ ؒ ؒ NDB-031_AP_R04_RM.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ NDB-031_DMD_RM_24415ft.las ؒ ؒ NDB-031_DMT_R01_RM.las ؒ ؒ NDB-031_DMT_R02_RM.las ؒ ؒ NDB-031_DMT_R03_RM.las ؒ ؒ NDB-031_DMT_R04_RM.las ؒ ؒ ؒ ؤؐؐؐGraphic Images ؒ جؐؐؐCGM LETTER OF TRANSMITTAL ؒ ؒ جؐؐؐFE ؒ ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_2MD.cgm ؒ ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_2TVD.cgm ؒ ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_5MD.cgm ؒ ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_5TVD.cgm ؒ ؒ ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ ؒ NDB-031_AP_RM.cgm ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ NDB-031_DMD_RM_24415ft.cgm ؒ ؒ NDB-031_DMT_RM.cgm ؒ ؒ ؒ ؤؐؐؐPDF ؒ جؐؐؐFE ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_2MD.pdf ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_2TVD.pdf ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_5MD.pdf ؒ ؒ NDB-031_LWD_GR_Res_Den_Neu_Cal_RM_24415ft_5TVD.pdf ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ NDB-031_AP_RM.pdf ؒ ؒ ؒ ؤؐؐؐVSS ؒ NDB-031_DMD_RM_24415ft.pdf ؒ NDB-031_DMT_RM.pdf ؒ ؤؐؐؐSLB NDBi-031_SonicScope_TOC_1000_MD_Memory_Data_LWD004.Pdf NDBi-031_SonicScope_TOC_2000_MD_Memory_Data_LWD004.Pdf NDBi-031_SonicScope_TOC_200_MD_Memory_Data_LWD004.Pdf NDBi-031_SonicScope_TOC_4000_MD_Memory_Data_LWD004.Pdf NDBi-031_SonicScope_TOC_500_MD_Memory_Data_LWD004.Pdf NDBi-031_SonicScope_TOC_6000_MD_Memory_Data_LWD004.Pdf NDBi-031_SonicScope_TOC_MD_Memory_Data_LWD004.dlis NDBi-031_SonicScope_TOC_MD_Memory_Data_LWD004.html NDBi-031_SonicScope_TOC_MD_Memory_Data_LWD004.las CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Staudinger, Mark (Mark) Cc:Tirpack, Robert (Robert) Subject:RE: NDB-031 (PTD 225-028) 9-5/8" Liner Cement Job and FIT results Date:Tuesday, May 27, 2025 9:39:00 AM Mark, A cement log will not be required for the Intermediate 1 casing first stage cement. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Wednesday, May 21, 2025 9:50 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: NDB-031 (PTD 225-028) 9-5/8" Liner Cement Job and FIT results Bryan, I wanted to give you an update on the 9-5/8” 1st and 2nd stage cement jobs, as well as the FIT result at the 9-5/8” shoe, which we just performed last night. 1st Stage Cement Job While drilling this well, we encountered losses near TD with a 12.8 ppg ECD. This is the first well this has happened while drilling the INT section. After that we saw dynamic losses with a relatively low ECD of ~12.2-12.5 ppg ECD. Attempted to spot a LCM pill on bottom, but it didn’t seem to heal up the loss zone. Ran 9-5/8” liner, and started encountering partial losses at ~4500’ MD, which had increased to full losses by ~6600’ MD. Continued to push away our pipe displacement from ~6600’ MD to TD at ~12,000’ MD. Pumped our first stage cement job (increased our volume by pumped volume by 30 bbls and added some LCM into cement due to losses) with ~80% to 95% losses during the job. However, we did see good lift pressure after cement turned the corner. 2nd Stage Cement Job Opened the CFLEX stage tool at ~5676’ MD and established circulation up to 6 bpm. We were able to pump the cement job (~336 bbls) with full returns throughout the job and good lift pressure throughout. Closed the CFLEX and set the LTP, then circulated ~140 bbls cement back to surface. Everything went well on this cement job, and the fact that we had no losses indicated the 1st stage cement job was able to plug up the lost circulation zone. 9-5/8” FIT Results Had both a good casing test to 2600 psi and a good FIT at the 9-5/8” shoe to 14.0 ppg EMW. Results are attached. This result shows that the 1st stage cement job was successful in achieving good integrity at the 9-5/8” shoe. We are currently drilling ahead. Request I’m seeking approval to not log the 1st stage 9-5/8” cement job with the following justification: Despite losses, the 1st stage job showed good lift pressure. Additionally, the FIT results show good 9-5/8” shoe integrity and the full returns on the 2nd stage job indicate that the cement was lifted and sealed the loss zone. Please let me know if you have any questions. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Staudinger, Mark (Mark) Cc:Tirpack, Robert (Robert) Subject:RE: NDB-031 (PTD 225-028) 7" Liner Cementing Proposal Date:Monday, May 19, 2025 10:32:00 AM Mark, This plan is approved. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Thursday, May 15, 2025 2:26 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: NDB-031 (PTD 225-028) 7" Liner Cementing Proposal Bryan, As per our discussion yesterday and the PTD Conditions of Approval, Oil Search Alaska (OSA) proposes the following plan for the upcoming 7” liner cement job on NDB-031: Options Evaluated Mud weight and rheology – MW driven by wellbore stability and already thinned prior to cementing. Spacer Design – Spacer design has already been optimized for displacement efficiency Lightweight Spacer – Modelling shows reduced cementing ECD’s with a 7.5 ppg spacer, pumped ahead of the cementing spacer Tail Cement Design – Adjustments to the slurry may compromise compressive strength, displacement efficiency, and log quality Lead Cement Slurry – Minimal ECD benefit and likely to compromise the compressive strength and log quality Proposed Plan: In addition to the increased TOC target height (150’ TVD above the Top Nanushuk) as already outlined in the PTD, OSA will plan on pumping a 160 bbl spacer of 7.5 ppg pre- mix OBM ahead of the normal 80 bbls of 12.5 ppg Clean Spacer. The objective of this spacer is to further reduce our cementing ECD’s, and ideally stay below fracture gradient in the wellbore to prevent losses during the job. The volume and weight of this spacer shows a modelled ECD reduction of ~0.5 ppg. This spacer will still keep the hydrostatic weight well above the Pore Pressure of any exposed formations. Please review and let me know if AOGCC agrees with the proposed plan for the 7” liner cement job on NDB-031. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may beconfidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use,distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email 1 Gluyas, Gavin R (OGC) From:Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent:Tuesday, April 29, 2025 9:50 AM To:McLellan, Bryan J (OGC) Cc:Davies, Stephen F (OGC) Subject:RE: NDB-031 (PTD 225-028) Clarifications Received. Thanks Bryan. Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and TwiƩer From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, April 29, 2025 9:49 AM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: ![EXT]: RE: NDB-031 (PTD 225-028) Clarifications Mark, My responses in red below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Monday, April 28, 2025 11:33 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: NDB-031 (PTD 225-028) Clarifications CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Sorry, 1 more thing I noticed. Regarding the 7” Cement Job log evaluation – when you state the “cement quality and height must be verified with a log,” would the TOC log still be acceptable for this? Yes -bjm Thanks, Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and TwiƩer From: Staudinger, Mark (Mark) Sent: Monday, April 28, 2025 11:29 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: NDB-031 (PTD 225-028) Clarifications Hey Bryan, I just had a few clarification questions on the PTD Conditions for NDB-031. 1) Section 15 states the 1000’ MD of this cement job is actually equivalent to ~79’ TVD (due to a higher sail angle on this well). Is it still acceptable to plan with 1000’ MD? Yes -bjm 2) As per our email correspondence, I’m still planning on 150’ TVD above top Nanushuk for TOC (not 100’ TVD as stated above). Just wanted to confirm that 150’ TVD should still be my planning number? Yes, plan for 150’ TVD as per the calculations you submitted by email and attached to the PTD. However we want to hear what other changes you’ll be making to the 7” cement program since pumping more volume may not help if you go on complete losses during the cement job. The expectation is that Oil Search will be trying something different because the previous two 7” cement attempts did not achieve the desired results. - bjm 3) Do you know specifically what information the AOGCC is looking for from NDB-031 in reference to the NDBi-050 Area of Review? With our current schedule, the NDBi-050 frac will happen prior to any data becoming available. This is a carryover from the NDBi-036 PTD. We already have the NDBi-050 information so you can ignore this CoA. -bjm Thanks, Mark Mark Staudinger Senior Drilling Engineer 3 m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and TwiƩer From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Monday, April 28, 2025 7:59 AM To: Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com>; Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>; Leahy, Scott (Scott) <Scott.Leahy@santos.com> Subject: ![EXT]: PERMIT Number 225-028 Hello, Attached is the Permit for Pikka NDB-031. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email 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 Mark Staudinger Senior Drilling Engineer Oil Search Alaska, LLC 601 W 5th Avenue Anchorage, AK, 99501 Re: Pikka Field, Nanushuk Oil Pool, NDBi-031 Oil Search Alaska, LLC Permit to Drill Number: 225-028 Surface Location: 2371’ FSL, 2170’ FWL, Sec 4, T11N, R6E, UM Bottomhole Location: 4758’ FSL, 4424’ FEL, Sec 12, T11N, R5E, UM Dear Mr. Staudinger: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. Proposed dry ditch sample interval from Attachment 9 accepted with modification of Ivishak (not to exceed 30'). This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this 25th day of April 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.25 16:52:53 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 24,427'TVD:4,104' 4a. Location of Well (Governmental Section): 7. Property Designation: ADL 392984, 391445, Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 05/01/25 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 541' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 69.79 15. Distance to Nearest Well Open Surface: x- 422,134.69 y- 5,972,756.54 Zone- 4 22.79 to Same Pool:2,146' 16. Deviated wells: Kickoff depth: 347 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.45 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42” 20”x34” 215# X-52 Welded 80’ Surface Surface 128' 128' 16” 13-3/8” 68# L-80 TXP BTC 2,70’ Surface Surface 2,780' 2,396' 12-1/4” 9-5/8” 47# L-80 HYD 563 ,’ 2,630' 2,319' 12,000' 3,325' Tie Back 9-5/8” 47# L-80 HYD 563 2,’ Surface Surface 2,630' 2,319' 8-1/2” x 9-7/8”7”26L-80 HYD 563 ,’ 11,850' 3,313' 18,710' 4,115' 6-1/8” 4-1/2” 12.6# P-110S HYD 563 ,’ 18,560' 4,085' 24,427' 4,104' Tubing 4-1/2” 12.6# P-110S HYD 563 18,’SurfaceSurface 18,560' 4,085' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Mark Staudinger Authorized Name: Mark Staudinger Contact Email:mark.staudinger@santos.com Authorized Title: Senior Drilling Engineer Contact Phone:1-520-273-6643 Date: Permit to Drill API Number: Permit Approval Number:Date: 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: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Pikka / NDB-031 Pikka / Nanushuk Oil Pool See attachment 6 See attachment 6 Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. Total Depth MD (ft): Total Depth TVD (ft): IS000361277U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 See attachment 6 1,482 129’ FSL, 1675’ FEL, Sec 12, T11N, R5E, UM 4758’ FSL, 4424’ FEL, Sec 12, T11N, R5E, UM LONS 19-003 601 W 5th Avenue, Anchorage, AK 99501-6301 Oil Search Alaska, LLC 2371’ FSL, 2170’ FWL, Sec 4, T11N, R6E, UM 393023, 393022, 393024, 392959, 392977 4395 18. Casing Program: Top - Setting Depth - BottomSpecifications 1,897 Cement Volume MDSize Plugs (measured): (including stage data) Grouted to surface See attachment 6 Conductor/Structural LengthCasing Authorized Signature: Production Liner Intermediate 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): Uncemented N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): s N ype of W L l R L 1b S Class: os N s No s N o D s s ssD 612 o well is p G S S 20 SS S s No s No S G E S s No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) March 27, 2025 Drilling Engineer By Grace Christianson at 4:06 pm, Mar 27, 2025 50-103-20912-00-00225-028 DSR-4/2/25 Surface casing must be set no deeper than 117' TVD above the top of Tuluvak Sand. BJM 4/24/25 See attached conditions of approval. Yess SFD 4/22/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.25 16:53:07 -08'00'04/25/25 04/25/25 T RBDMS JSB 042925 NDB-031 (PTD 225-028) WĞƌŵŝƚƚŽƌŝůůŽŶĚŝƟŽŶƐŽĨApproval 1. ŝǀĞƌƚĞƌǁĂŝǀĞƌƌĞƋƵĞƐƚ ŝƐĂƉƉƌŽǀĞĚŽŶƚŚĞĐŽŶĚŝƟŽŶƚŚĂƚƚŚĞƐƵƌĨĂĐĞŚŽůĞŵĂǇďĞĚƌŝůůĞĚŶŽ ĚĞĞƉĞƌƚŚĂŶϭϭϳŌĂďŽǀĞƚŚĞƚŽƉŽĨƚŚĞdƵůƵǀĂŬƐĂŶĚ͘ 2. /ŶŝƟĂůKWƚĞƐƚƚŽϱϬϬϬƉƐŝ͘^ƵďƐĞƋƵĞŶƚKWƚĞƐƚƚŽϯ6ϬϬƉƐŝ. All aŶŶƵůĂƌƚĞƐƚƐ ƚŽϯϬϬϬƉƐŝ͘ 3. sĂƌŝĂŶĐĞƚŽϮϬϮϱ͘Ϭϯϱ;ĞͿ;ϭϬͿ;ͿŝƐĐŽŶĚŝƟŽŶĂůůǇĂƉƉƌŽǀĞĚƚŽĂůůŽǁϮϭ-ĚĂǇKWƚĞƐƚŝŶƚĞƌǀĂů͘ ^ĞĞĐŽŶĚŝƟŽŶƐŽĨĂƉƉƌŽǀĂůŝŶŽĐŬĞƚKd,-25-ϬϭϬůĞƩĞƌŝŶƩĂĐŚŵĞŶƚϭϮŽĨƚŚŝƐWdĂƉƉůŝĐĂƟŽŶ͘ 4. >Kdͬ&/dƌĞƐƵůƚƐƚŽďĞƐƵďŵŝƩĞĚƚŽK'ǁŝƚŚŝŶϰϴŚŽƵƌƐŽĨŽďƚĂŝŶŝŶŐƚŚĞĚĂƚĂ͘ 5. /ĨDWǁŝůůďĞƵƐĞĚ͕Kŝů^ĞĂƌĐŚŵƵƐƚŵĂŝŶƚĂŝŶŵƵĚĚĞŶƐŝƚǇŝŶĞǆĐĞƐƐŽĨƚŚĞŚŝŐŚĞƐƚĂŶƟĐŝƉĂƚĞĚ ƌĞƐĞƌǀŽŝƌDt. 6. EŽƟĨǇK'ŝĨĐĞŵĞŶƚũŽďƐĚŽŶŽƚŐŽĂĐĐŽƌĚŝŶŐƚŽƉůĂŶŽƌŝĨũŽďƉĂƌĂŵĞƚĞƌƐĂƌĞŶŽƚĂƐ ĞǆƉĞĐƚĞĚ;ůŽƐƐĞƐŽĐĐƵƌ͕ƵŶĞǆƉĞĐƚĞĚůŝŌƉƌĞƐƐƵƌĞƐŽĐĐƵƌ͕ĐĞŵĞŶƚŝƐŶŽƚĐŝƌĐƵůĂƚĞĚŽīƚŚĞƚŽƉŽĨ ƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞůŝŶĞƌ͕ĞƚĐ͘Ϳ. Cement ƚŽďĞůŽŐŐĞĚŝĨũŽďĚŽĞƐŶŽƚŐŽĂĐĐŽƌĚŝŶŐƚŽƉůĂŶ͕ǁŝƚŚ ƉŽƐƐŝďůĞĞǆĐĞƉƟŽŶƐĨŽƌϵ-ϱͬϴ͟/ŶƚĞƌŵĞĚŝĂƚĞηϭĐĂƐŝŶŐĐĞŵĞŶƚ. ϳ͘ sĂƌŝĂŶĐĞĨƌŽŵƉŽŽůƌƵůĞƐŐƌĂŶƚĞĚƚŽŝƐŽůĂƚĞƐŝŐŶŝĮĐĂŶƚŚǇĚƌŽĐĂƌďŽŶǌŽŶĞŽĨ Upper dƵůƵǀĂŬĂďŽǀĞ d^ϳϵϬŚŽƌŝǌŽŶĂƐƉƌŽƉŽƐĞĚ ŝŶƐĞĐƟŽŶϭϱ. 8. sĂƌŝĂŶĐĞƚŽϮϬϮϱ͘ϬϯϬ;ĚͿ;ϱͿĨŽƌϮ-ƐƚĂŐĞŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐĐĞŵĞŶƚŽƉĞƌĂƟŽŶĂŶĚŐĂƉŝŶ ĐĞŵĞŶƚĐŽǀĞƌĂŐĞŝƐĂƉƉƌŽǀĞĚ͕ǁŝƚŚƐƚĂŐĞĐŽůůĂƌƉůĂĐĞŵĞŶƚĂƐĨŽůůŽǁƐ ;ƌĞĨĞƌĞŶĐĞƐĞĐƟŽŶϭϱŝŶ WdĂƉƉůŝĐĂƟŽŶͿ: a. ^ƚĂŐĞĐŽůůĂƌŵƵƐƚďĞƉůĂĐĞĚŶŽƐŚĂůůŽǁĞƌƚŚĂŶϱϬΖDďĞůŽǁƚŚĞďĂƐĞŽĨƚŚĞhƉƉĞƌ dƵůƵǀĂŬĂƐĚĞĮŶĞĚďǇƚŚĞd^ϳϵϬŚŽƌŝǌŽŶ͘ ď͘ ^ƵďŵŝƚϭϮ-ϭͬϰΗK,ůŽŐƐƚŽK'ĂƐƐŽŽŶĂƐƉƌĂĐƟĐĂůĂŌĞƌdŽĨŚŽůĞƐĞĐƟŽŶ͘ dŚĞ d^ϳϵϬŵĂƌŬĞƌŝƐǁĞůů-ĞƐƚĂďůŝƐŚĞĚŝŶƚŚĞĂƌĞĂŽĨEƉĂĚĂŶĚƚŚĞƌĞĨŽƌĞKŝů^ĞĂƌĐŚĚŽĞƐ ŶŽƚŶĞĞĚƚŽƐĞĞŬK'ĂƉƉƌŽǀĂůŽĨƚŚĞŝƌƉŝĐŬŽĨƚŚĞd^ϳϵϬďĞĨŽƌĞƌƵŶŶŝŶŐϵ-ϱͬϴ͟ ĐĂƐŝŶŐ͘ ϵ͘ dŚĞ>t-^ŽŶŝĐůŽŐǁŝůůŽŶůǇďĞĂĐĐĞƉƚĞĚĨŽƌĐĞŵĞŶƚĞǀĂůƵĂƟŽŶǁŚĞŶƚŚĞĨŽůůŽǁŝŶŐĐŽŶĚŝƟŽŶƐ are met: a. KŝůƐĞĂƌĐŚƚŽƉƌŽǀŝĚĞĂǁƌŝƩĞŶůŽŐĞǀĂůƵĂƟŽŶͬŝŶƚĞƌƉƌĞƚĂƟŽŶƚŽƚŚĞK'ĂůŽŶŐǁŝƚŚƚŚĞ ůŽŐĂƐƐŽŽŶĂƐƚŚĞǇďĞĐŽŵĞĂǀĂŝůĂďůĞ͘dŚĞĞǀĂůƵĂƟŽŶŝƐƚŽŝŶĚŝĐĂƚĞƚŚĞŝŶƚĞƌǀĂůƐŽĨ ĐŽŵƉĞƚĞŶƚĐĞŵĞŶƚƚŚĂƚKŝůƐĞĂƌĐŚŝƐƵƐŝŶŐƚŽŵĞĞƚƚŚĞŽďũĞĐƟǀĞƌĞƋƵŝƌĞŵĞŶƚƐĨŽƌ aŶŶƵůĂƌŝƐŽůĂƟŽŶĂŶĚƌĞƐĞƌǀŽŝƌŝƐŽůĂƟŽŶ͕ĂŶĚƚŽŝŶĚŝĐĂƚĞƚŚĞůŽĐĂƟŽŶŽĨĐŽŶĮŶŝŶŐǌŽŶĞƐ͕ ŚǇĚƌŽĐĂƌďŽŶ-ďĞĂƌŝŶŐǌŽŶĞƐ͕ŽǀĞƌƉƌĞƐƐƵƌĞĚǌŽŶĞƐĂŶĚĨƌĞƐŚǁĂƚĞƌ͕ŝĨƉƌĞƐĞŶƚ͘WƌŽǀŝĚŝŶŐ ƚŚĞůŽŐǁŝƚŚŽƵƚĂŶĞǀĂůƵĂƟŽŶͬŝŶƚĞƌƉƌĞƚĂƟŽŶŝƐŶŽƚĂĐĐĞƉƚĂďůĞ͘ ď͘ >tƐŽŶŝĐůŽŐƐŵƵƐƚƐŚŽǁĨƌĞĞƉŝƉĞĂŶĚdŽƉŽĨĞŵĞŶƚ͘ dŚĞůŽŐŵƵƐƚďĞƌƵŶĂĐƌŽƐƐƚŚĞ ƚĂƌŐĞƚǌŽŶĞƐĂŶĚĂƚĂĚĞƉƚŚƚŽĞŶƐƵƌĞƚŚĞĨƌĞĞƉŝƉĞĂďŽǀĞƚŚĞdKŝƐĐĂƉƚƵƌĞĚĂƐǁĞůůĂƐ ƚŚĞdK͘/ĨƚŚĞůŽŐŐĞĚŝŶƚĞƌǀĂůĚŽĞƐŶŽƚĐĂƉƚƵƌĞƚŚĞdKĂŶĚĨƌĞĞƉŝƉĞĂďŽǀĞŝƚ͕ it will ŶĞĞĚƚŽďĞƌĞ-ƌƵŶ͕ƵŶůĞƐƐƚŚĞĐĞŵĞŶƚǁĂƐƉůĂŶŶĞĚƚŽĐŽǀĞƌƚŚĞĞŶƟƌĞůĞŶŐƚŚŽĨůŝŶĞƌŽƌ ĐĂƐŝŶŐ͘ Đ͘ KŝůƐĞĂƌĐŚǁŝůůƉƌŽǀŝĚĞĂĐĞŵĞŶƚũŽďƐƵŵŵĂƌǇƌĞƉŽƌƚĂŶĚĞǀĂůƵĂƟŽŶĂůŽŶŐǁŝƚŚƚŚĞ ĐĞŵĞŶƚůŽŐĂŶĚĞǀĂůƵĂƟŽŶƚŽƚŚĞK'ǁŚĞŶƚŚĞǇďĞĐŽŵĞĂǀĂŝůĂďůĞ͘ d. ĞƉĞŶĚŝŶŐŽŶƚŚĞĐĞŵĞŶƚũŽďƌĞƐƵůƚƐŝŶĚŝĐĂƚĞĚďǇƚŚĞĐĞŵĞŶƚũŽďƌĞƉŽƌƚ͕ƚŚĞůŽŐƐĂŶĚ ƚŚĞ&/d͕ƌĞŵĞĚŝĂůŵĞĂƐƵƌĞƐŽƌĂĚĚŝƟŽŶĂůůŽŐŐŝŶŐŵĂǇďĞƌĞƋƵŝƌĞĚ͘ 10. sĂƌŝĂŶĐĞĨŽƌϵ-ϱͬϴ͟/ŶƚĞƌŵĞĚŝĂƚĞƉƌŝŵĂƌǇĐĞŵĞŶƚŽĨŽŶůǇϭϬϬ͛ds;ϭϬϬϬ͛DͿĂďŽǀĞƐŚŽĞ ŝƐ ĂƉƉƌŽǀĞĚĂƐĚĞƐĐƌŝďĞĚŝŶƐĞĐƟŽŶϭϱŽĨƚŚĞWd͘ 11. sĂƌŝĂŶĐĞŽĨϳ͟/ŶƚĞƌŵĞĚŝĂƚĞϮĐĞŵĞŶƚŽĨŽŶůǇϭ0ϬΖdsĂďŽǀĞƚŽƉŽĨEĂŶƵƐŚƵŬƉŽŽů ŝƐĂƉƉƌŽǀĞĚ͕ ŚŽǁĞǀĞƌKŝů^ĞĂƌĐŚŵƵƐƚƐĞĞŬĂŶĚŽďƚĂŝŶK'ĂƉƉƌŽǀĂůĨŽƌĂŶŝŵƉƌŽǀĞĚƉůĂŶĨŽƌĂĐŚŝĞǀŝŶŐ ĂĚĞƋƵĂƚĞĐĞŵĞŶƚƉůĂĐĞŵĞŶƚďĂƐĞĚŽŶƉŽŽƌƌĞƐƵůƚƐŝŶƚŚĞƉƌĞǀŝŽƵƐƚǁŽƐŝŵŝůĂƌǁĞůůƐEŝ-050 and NDBi-036͘dŚĞϳ͟ůŝŶĞƌĐĞŵĞŶƚƋƵĂůŝƚǇĂŶĚŚĞŝŐŚƚŵƵƐƚďĞǀĞƌŝĮĞĚǁŝƚŚĂůŽŐ͘ 12. WƌŽǀŝĚĞŝŶĨŽƌŵĂƟŽŶŽŶWŝŬŬĂEŝ-ϬϱϬĨŽƌƌĞĂŽĨZĞǀŝĞǁĂƐƐŽŽŶĂƐŝƚŝƐĂǀĂŝůĂďůĞ Page 1 of 1 27 March 2025 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, a subsidiary of Santos Limited NDB-031 Dear Sir/Madam, Oil Search (Alaska), LLC hereby applies for a Permit to Drill an onshore development well from the NDB drilling pad on the North Slope of Alaska. NDB-031 is planned to be a horizontal producer targeting the Nanushuk 3. The approximate spud date is anticipated to be May 1st, 2025. Parker Rig 272 will be used to drill this well. The 16” Surface Hole will TD above the Tuluvak sand and then 13-3/8” casing will be set and cemented. The 12-1/4” Intermediate Hole #1 will be drilled into the Seabee formation at an inclination of ~85 degrees. A 9-5/8” liner will be set and cemented from TD to secure the shoe and cover the Tuluvak sand. A 9-5/8” tieback will be run to the top of the 9-5/8” liner. The 8-1/2” x 9-7/8” Intermediate Hole #2 will be drilled through the Seabee and Nanushuk formations with the casing set in the Nanushuk 3 formation at ~79 degrees. A 7” liner will be set and cemented from TD to cover the Nanushuk formation. The 6-1/8” Production Hole will be geo-steered and landed in the Nanushuk 3 sand and the lateral will be drilled to TD. The well will be completed as a stimulated 4-1/2” liner with frac sleeves and isolation packers. The production liner will be tied back to surface with a 4-1/2” tubing upper completion string. Managed Pressure Drilling (MPD) will be implemented in the Intermediate #2 and Production Hole intervals. At no point will the static wellbore fluid be underbalanced. 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. If there are any questions and/or additional information desired, please contact me at (520) 273-6643 or mark.staudinger@santos.com. Respectfully, Mark Staudinger Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Respectfully, Mark Staudingerr Application for Permit to Drill NDB-031 Well Table of Contents 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. Discussion of Mud and Cuttings Disposal and Annular Disposal................................................12 15. Proposed Variance Requests......................................................................................................12 Attachments..................................................................................................................................................16 Attachment 1: Location Maps..........................................................................................................17 Attachment 2: Directional Plan........................................................................................................18 Attachment 3: BOPE Equipment ......................................................................................................19 Attachment 4: Drilling Hazards.........................................................................................................20 Attachment 5A: Leak Off Test Procedure (Conventional)................................................................22 Attachment 5B: Leak Off Test Procedure (With MPD).....................................................................23 Attachment 6: Cement Summary.....................................................................................................24 Attachment 7: Prognosed Formation Tops......................................................................................27 Attachment 8: Well Schematic.........................................................................................................28 Attachment 9: Formation Evaluation Program................................................................................29 Attachment 10: Wellhead & Tree Diagram......................................................................................30 Attachment 11: Diverter Variance Request NDB Surface Hole Map View.......................................31 Attachment 12: Oil Search Alaska 21-day BOPE Test Schedule Waiver Approval Letter.................32 Attachment 13: Managed Pressure Drilling .....................................................................................35 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. 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 NDB-031. This will be a development production well. 2. Location Summary 20 AAC 25.005 (c) (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 Location at Surface Reference to Government Section Lines 2371’ FSL, 2170’ FWL, Sec 4, T11N, R6E, UM NAD 27 Coordinate System N 5,972,757 E 422,135 Rig KB Elevation 47’ above GL Ground Level 22.79’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 129’ FSL, 1675’ FEL, Sec 12, T11N, R5E, UM NAD 27 Coordinate System N 5,965,393’ E 408,026’ Measured Depth, Rig KB (MD) 19,043’ Total Vertical Depth, Rig KB (TVD) 4,146’ Total vertical Depth, Subsea (TVDSS) 4,076’ Location at Bottom of Productive Interval Reference to Government Section Lines 4758’ FSL, 4424’ FEL, Sec 12, T11N, R5E, UM NAD 27 Coordinate System N 5,975,482’ E 406,362’ Measured Depth, Rig KB (MD) 24,427’ Total Vertical Depth, Rig KB (TVD) 4,104’ Total vertical Depth, Subsea (TVDSS) 4,034’ (D) other information required by 20 AAC 25.050(b); 20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must: (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 2: Directional Plan for further details. (2) for all wells within 200 feet of the proposed wellbore: (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The applicant is the only affected owner. 3. Blowout Prevention Equipment Information 20 AAC 25.005 (c) (3) A diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; A BOP test frequency for NDB-031 be 21-days is requested. Please refer to Section 15 for further details. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 21-day BOP test period should not be requested. Parker 272 BOP Equipment: BOP Equipment x NOV Shaffer Spherical annular BOP, 13-5/8” x 5000 psi x NOV T3 6012 double gate, 13-5/8” x 5000 psi x Mud cross, 13-5/8” x 5000 psi with 2 ea. 3-1/8" x 5000 psi side outlets x Choke Line, 3-1/8” x 5000 psi with 3-1/8” manual and HCR valve x Kill Line, 2-1/16” x 5000 psi with 3-1/8” manual and HCR valve x NOV T3 6012 single gate, 13-5/8” x 5000 psi Choke Manifold x 3-1/8” x 5000 psi working pressure with Axon Type S remote controlled chokes and NRG mud/gas separator BOP Closing Unit x NOV SARA Koomey Control System, 316 gallon, 299 gallon reservoir. Twenty-Four 15 gallon bottles. Equipped with 1 electric and 3 air pumps with emergency power. Please refer to Attachment 3: BOPE Equipment for further details. A BOP test frequency for NDB-031 be 21-days is requested. Please refer to Section 15 for further details. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 21-day BOP test period should not be requested. 4. Drilling Hazards Information 20 AAC 25.005 (c) (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; 12-1/4” Intermediate #1 Hole Pressure Data Maximum anticipated BHP 1,573 psi at TD in Seabee at 3,325’ TVD (9.1ppg EMW in the Seabee formation to section TD) Maximum surface pressure 1,241 psi from TD in the Seabee (0.10 psi/ft gas gradient to surface, 3,325’ TVD) Planned BOP test pressure Rams test to 5,000 psi / 250 psi (Initial) Rams test to 3,600 psi / 250 psi (Subsequent) Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test – 12-1/4” hole FIT after drilling 20’-50’ of new hole to 15.0 ppg. (12.9 ppg LOT required for Kick Tolerance with 11.5ppg MW) 13-3/8” Casing Test 2,600 psi surface pressure (Test pressure driven by 50% of Casing Burst) 8-1/2” Intermediate #2 Hole Pressure Data Maximum anticipated BHP 1,883 psi in the Nanushuk 3 at 4,115’ TVD (8.8ppg EMW Nanushuk 3 formation to section TD) Maximum surface pressure 1,472 psi from the Nanushuk 3 (0.10 psi/ft gas gradient to surface, 4,115’ TVD) Planned BOP test pressure Rams test to 3,600 psi / 250 psi Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test – 8-1/2” hole FIT after drilling 20’-50’ of new hole to 14.0 ppg. (11.8 ppg LOT required for Kick Tolerance with 11.0ppg MW) 9-5/8” Liner Test 4,000 psi surface pressure (MIT-IA after upper completion run, test pressure driven by annular pressure during frac job) 6-1/8” Production Hole Pressure Data Maximum anticipated BHP 1,897 psi in the Nanushuk 3.2 at 4,146’ TVD (8.8ppg EMW top NT3.2 formation to heel target) Maximum surface pressure 1,482 psi from the NT3.2 (0.10 psi/ft gas gradient to surface, 4,146’ TVD) Planned BOP test pressure Rams test to 3,600 psi / 250 psi Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test – 6-1/8” hole FIT after drilling 20’-50’ of new hole to 14.0 ppg. (10.4ppg required for infinite kick tolerance with 9.8ppg MW) 7” Liner Test 4,000 psi surface pressure (MIT-IA after upper completion run, test pressure driven by annular pressure during frac job) 14.0 ppg per M. Staudinger email 4/15/23 attached. -bjm (B) data on potential gas zones; and The Tuluvak formation is expected in this area and has a high potential for gas as based on offset Exploration and Appraisal well data. The Tuluvak is expected to be over-pressured at 10.2ppg pore pressure. The well plan is designed to safely manage pressures consistent with offset wells in the same manner that hydrocarbons are handled in the reservoir zone. BOPE will be installed before entering any hydrocarbon zones and appropriate mud weights will be utilized to provide sufficient overbalance. (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: Drilling Hazards 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (c) (5) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment 5: Leak Off Test Procedure 6. Casing and Cementing Program 20 AAC 25.005 (c) (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; Casing/Tubing Program Hole Size Liner / Tbg O.D.Wt/Ft Grade Conn Length Top MD Bottom MD / TVD 42” 20”x34” 215# X-52 Welded 80’ Surface 128’ / 128’ 16” 13-3/8” 68# L-80 TXP BTC 2,780’ Surface 2,780’ / 2,396’ 12-1/4” 9-5/8” 47# L-80 HYD 563 9,370’ 2,630’ 12,000’ /3,325’ Tie Back 9-5/8” 47# L-80 HYD 563 2,630’ Surface 2,630’ / 2,319’ 8-1/2” x 9-7/8”7” 26 L-80 HYD 563 6,860’ 11,850’ 18,710’ / 4,115’ 6-1/8” 4-1/2” 12.6# P-110S HYD 563 5,867’ 18,560’ 24,427’ / 4,104’ Tubing 4-1/2” 12.6# P-110S HYD 563 18,560’ Surface 18,560’ / 4,085’ Please refer to Attachment 6: Cement Summary for further details. high potential for ga Surface casing must be set no deeper than 117' TVD above the top of Tuluvak Sand. SFD` Tuluvak over-pressured at 10.2ppg 7. Diverter System Information 20 AAC 25.005 (c) (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); Parker 272 Diverter Equipment: x Hydril MSP annular BOP, 21 1/4” x 2000 psi, flanged x Diverter Spool 21 1/4” x 2000 psi with 16-3/4” flanged sidearm connection. Interlocked knife/gate valves. x 16” Diverter Line Please refer to Attachment 3: BOPE Equipment for further details. A diverter variance is requested for NDB-031. Please refer to Section 15 for further details. 8. Drilling Fluid Program 20 AAC 25.005 (c) (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 16” Surface Hole 12-1/4” Int #1 Hole 8-1/2” Int #2 Hole 6-1/8” Prod Hole Mud Type Spud Mud (WBM)MOBM MOBM MOBM Mud Properties: Mud Weight Funnel Vis PV YP API Fluid Loss HPHT Fluid Loss pH MBT 9.0 - 10 ppg 100 - 300 sec ALAP 30 - 80 < 10 ml/30min n/a 8.6-10.5 <35 11.0 - 12.0 ppg 50 - 80 sec ALAP 15 - 30 n/a < 5 ml/30min n/a n/a 9.5 – 11.5 ppg 50 - 80 sec ALAP 15 - 30 n/a < 5 ml/30min n/a n/a 9.0 - 10.0 ppg 50 - 80 sec ALAP 10 - 20 n/a < 5 ml/30min n/a n/a A diagram of drilling fluid system on Parker 272 is on file with AOGCC. Recommend approving requested diverter variance based on additional information provided in emails dated April 21 and April 22, 2025 (attached). SFD 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) (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); N/A – Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis 20 AAC 25.005 (c) (10) For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A – Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis 20 AAC 25.005 (c) (11) For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); The NDB-031 Well is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) (12) Evidence showing that the requirements of 20 AAC 25.025 have been met; Evidence of bonding for Oil Search Alaska is on file with the Commission. 13. Proposed Drilling Program 20 AAC 25.005 (c) (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 NDB-031 is listed below. Please refer to Attachments 8-10 for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed NDB-031 Drilling Program 1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing ring on conductor. 2. Move in / rig up Parker 272. 3. Nipple up spacer spools over the 20” conductor. 4. Pick up 5-7/8” drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up 16” motor BHA with MWD and LWD tools. 5. Spud well and drill surface hole section to TD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH and lay down BHA. 6. Run 13-3/8” 68# surface casing as per casing tally and land on pre-installed landing ring. Circulate and condition mud prior to commencing cement job. 7. Cement 13-3/8” casing as per cement program. Verify cement returns to surface. 8. NU casing head and spacer spool. NU BOPE (configured from top to bottom: annular preventor, 4-1/2” x 7” VBR, blind/shear, mud cross, 9-5/8” Fixed Rams). NU Rotating Control Device (RCD). Test rams to 5000 psi high (initial test only – 3600 psi for subsequent tests) and annular to 3000 psi high as per AOGCC regulations. Provide AOGCC 48 hrs notice for witnessing BOP test. 9. Close blind shear rams and pressure test casing to 2600 psi for 30 min. 10. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to MOBM. 11. Drill out shoe track and 20 - 50’ of new formation. Perform FIT / LOT. 12. Directionally drill 12-1/4” intermediate hole section #1 to TD. Perform wiper trips as required. Circulate and condition hole to run liner. POOH. 13. RU and run 9-5/8” intermediate liner #1 as per casing tally then RIH on 5-7/8” DP / HWDP to TD. Circulate and condition mud prior to commencing cement job. 14. Set liner hanger and release running tool. Cement 9-5/8” liner with 1st stage cement job as per cement program. Monitor returns during displacement until plug bump. 15. Un-sting from liner hanger and POOH and LD liner running tools. 16. RIH with mechanical shifting tool and open 2 nd stage cement job tools. Pump secondary cement job, set liner top packer, and circulate cement to surface. POOH and lay down 5- Provide AOGCC 48 hrs notice for witnessing BOP test. Test rams to 5000 psi high 7/8” drillpipe and liner running tool. 17. Pressure test casing 13-3/8” casing and 9-5/8” liner to 2600 psi for 30 min. 18. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH on 5” drillpipe, clean out to top of float equipment and drill out the shoe track. 19. Drill out the 9-5/8” shoe and 20 - 50’ of new formation. Perform FIT / LOT. 20. Install the MPD bearing assembly and adjust mud weight as required for ECD management with MPD. 21. Directionally drill 8-1/2” x 9-7/8” intermediate hole section #2 to TD utilizing MPD. Perform wiper trips as required. 22. Circulate and condition hole to run liner. Displace weighted trip fluid as required and POOH. 23. Run cleanout/string mill assembly to dress the 9-5/8” CFLEX tool. 24. RU and run 7” intermediate liner #2 as per casing tally then RIH on 5” DP / HWDP to TD. Circulate and condition mud prior to commencing cement job. 25. Set liner hanger and release running tool. Cement 7” liner as per cement program. Monitor returns during displacement until plug bump. 26. Set liner top packer, un-sting from liner hanger, POOH and LD liner running tools. 27. RIH with polish mill assembly for cleanout of the 9-5/8” liner top PBR. Run 9-5/8” tieback string. Freeze protect the 13-3/8” x 9-5/8” annulus with diesel and land tieback. 28. Pressure test the 13-3/8” x 9-5/8” annulus to 2600 psi for 30 min. 29. Change upper BOP rams from 4-1/2” x 7” VBR’s to 3-1/2” x 5-1/2” VBR’s. Test rams to 3600 psi high and annular to 3000 psi high as per AOGCC regulations. Provide AOGCC 48 hrs notice for witnessing BOP test. 30. Pressure test the 9-5/8” liner / tieback and 7” liner to 3500 psi for 30 min. 31. Make up 6-1/8” RSS BHA with MWD and LWD tools. RIH on tapered string with 4” x 5” drillpipe. 32. RIH to top of the float equipment logging 7” liner cement with Sonic LWD tool on the trip in. 33. Displace well to MOBM at the required mud weight for MPD while drilling out the shoe track. 34. Circulate casing clean, install the MPD bearing assembly and test MPD surface equipment as required. 35. Drill 20 - 50’ of new formation. Perform FIT / LOT. 36. Directionally drill 6-1/8” production hole section to TD using MPD. Perform wiper trips as required. 37. Circulate and condition hole to run liner. Displace weighted trip fluid as required and POOH. 38. Circulate MOBM out of open hole with NaCl brine with biocide. Spot tail end of the spacer near the liner hanger/packer. Drop 1.125” ball during circulation to close WIV. 39. Close WIV collar and set open hole hydraulic set packers and liner hanger/top packer. 40. Set and pressure test the 9-5/8” x 7” x 4-1/2” IA to liner top packer to 3,500 psi for 10 min. Release the running tool. 41. Circulate corrosion inhibited brine. 42. POOH and LD liner running tool. 43. RU and run 4-1/2” upper completion and downhole jewelry with TEC wire. Space out seals. 44. Land tubing hanger. 45. Pressure test tubing to 3,500 psi for 30 mins. Pressure up on the annulus to 4,000 psi for 30 mins. Bleed pressure on tubing and shear upper gas lift valve. 46. Reverse circulate freeze protect and U-Tube. 47. Install TWC, pressure test to 2,500 psi for 10 mins. ND BOPE, NU frac tree. 48. Secure well and prepare for rig move. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) (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. The Oil Search Alaska NGI (Nanushuk Grind & Inject) facility is now operational, and cuttings will be hauled via truck as generated, processed at NGI, and disposed of into the DW-02 Class 1 disposal well. The NGI facility is located on NDB. In the event that NGI is not operational, 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. 15. Proposed Variance Requests 20 AAC 25.035. Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements. (h)(2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter is not necessary A diverter variance is requested for the NDB-031 surface hole section. Oil Search Alaska, LLC (OSA) has conducted internal risk assessments and determined that the risk of needing to use a diverter is negligible and operationally could pose an increase in HSE risks. NDB-031 surface hole is surrounded by more than 15 other existing surface holes at the NDB pad location. Additionally, there are 2 previously drilled wells (NDB-025 and NDBi-043) within 600’ of the proposed NDB-031 surface hole TD location (see attachment 11). More than 32 wells have been drilled in the NDB pad and Pikka area over the last 54 years with no signs or indications of shallow free gas above the Tuluvak. There are 16 Exploration and Appraisal wells and more than 16 NDB Pad wells totaling more than 70,000’ of drilled interval. In addition, OSA has acquired eight openhole logs across the surface hole intervals in the area consisting of four E-line Density Neutron logs and four LWD Sonic logs. All logs definitively show no free gas accumulations. During this time period, there have been zero well control events above the Tuluvak. OSA has built highly detailed geological models which predict the Top of the Tuluvak with very high accuracy. There is very low structural uncertainty and a high confidence marker with the MCU given the number of wells already drilled in the area. NDB-031 surface casing will have a maximum setting depth of 250’ TVD below the MCU marker. This setting depth is ~54’ TVD above the Tuluvak Shale Recommend approving requested diverter variance based on additional information provided in emails dated April 21 and April 22, 2025 (attached). 32 wells no signs or indications of shallow free gas above the Tuluvak setting depth is ~54’ TVD above the Tuluvak Shale diverter variance is requested for the NDB-031 surface hole section logs definitively show no free gas formation marker, and ~117’ TVD above the gas-bearing Tuluvak sand formation. Parker Rig 272's current elevated diverter rig-up introduces health, safety, and environmental (HSE) risks due to the complexities of installation at height. With the ongoing facility commissioning at NDB pad, the diverter line will need to be moved to ground level in the near future to be routed beneath the flowlines and pipe racks, passing through support pilings. This change will increase operational challenges and HSE risks, as the 75-foot diverter line will require multiple bends to navigate around existing equipment and infrastructure. With the multiple well penetrations at the NDB Pad and Pikka area, no free gas above the Tuluvak, the strong geologic understanding, and low structural uncertainty, combined with the increased HSE risks and challenges of running a diverter line, it is requested that a diverter variance for NDB-031 be granted. 20 AAC 25.035. Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements. (e)(10)(A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance It is requested that the blowout prevention equipment test frequency be granted for a 21-day BOPE test schedule per the waiver acceptance letter and conditional requirements outlined in Docket Number OTH-25-010 from the AOGCC to Oil Search Alaska for Parker 272 operating at NDB (see attachment 12). 20 AAC 25.030. Casing and cementing (d)(5) intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above all significant hydrocarbon zones and abnormally geo- pressured strata or, if zonal coverage is not required under (a) of this section, from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above the casing shoe A variance is requested to the above regulation 20 AAC 25.030 (d)(5) for the following: 1. 9-5/8” Primary Cement Job: The primary cement job will target a top of cement 1000 feet MD (~79 feet TVD at ~85° inclination) above the 9-5/8” shoe. Due to ERD nature of this section, additional TVD height of the cement top will significantly increase cement volumes and the subsequent risk of losses due to ECD’s exceeding the formation fracture gradient. Surface casing must be set no deeper than 117' TVD above the top of Tuluvak Sand. SFD formation marker, and ~117’ TVD above the gas-bearing Tuluvak sand formation. Note, with this well design the 9-5/8” is considered as an intermediate drilling liner and the shoe is not designed to isolate any significant hydrocarbon zones or abnormally geo-pressured strata. Isolation over the top of the Nanushuk formation will be provided by cement integrity at the subsequent 7” liner shoe. 2. 9-5/8” Secondary Cement Job: To not place cement across the entire annular space from the 9-5/8” shoe to above shallowest significant hydrocarbon zone. A two-stage cement job will be performed to isolate the shoe in the Seabee, and the second stage cement job will isolate the significant hydrocarbon zone in the Tuluvak formation. Due to the ERD nature and high angle of the Pikka NDB development wells, a single stage cement job on the 9-5/8” intermediate liner is not achievable without exceeding the fracture gradient and compromising cement placement and zonal isolation. The two-stage cement job will achieve all casing and cementing objectives outlined in AOGCC regulation 20 AAC 25.030.(a), stating that a well casing and cementing program must be designed to: 1) provide suitable and safe operating conditions for the total measured depth proposed; 2) confine fluids to the wellbore; 3) prevent migration of fluids from one stratum to another; 4) ensure control of well pressures encountered; 5) protect against thaw subsidence and freezeback effects within permafrost; 6) prevent contamination of freshwater; 7) protect significant hydrocarbon zones; and 8) provide well control until the next casing is set, considering all factors relevant to well control including formation fracture gradients, formation pressures, casing setting depths, and proposed total depth. The formation interval between the top of stage one and the bottom of stage two includes the Seabee and lower Tuluvak formation. These formations are interbedded silts and shales with very low permeability and contain no significant hydrocarbons. Based on offset well logs, cuttings, mudlogging analysis, and the latest petrophysical interpretation, the base of the significant hydrocarbon zone in the Tuluvak formation is contained only within the upper portion of TS 880 clinoform of the Upper Tuluvak in the NDB area. Within the TS 880 clinoform, the base of significant hydrocarbon is at or above 2,640’ TVD. The Tuluvak formation below 2,640’ TVD is not a significant hydrocarbon zone. A stage collar placement is proposed 50’ MD below the TS 790 formation marker (Upper Tuluvak). This stage collar depth will isolate any potential gas based on offset well data. The TS 875 and TS 870 clinoform is between the TS 880 clinoform and TS 790 top. The TS 875 and TS 870 clinoforms are shale dominated, very low net to gross, has no vertical permeability, and represents a seal to the hydrocarbon bearing TS 880. Moving the cementing stage tool to be placed at 50’ MD below the TS 790 formation marker allows placement of higher quality cement that provides better isolation across the significant stage collar placement is proposed 50’ MD below the TS 790 formation marker second stage cement job will isolate the significant hydrocarbon zone in the Tuluvak formation. hydrocarbon zone in the Tuluvak. Attempting to place cement across the entire Tuluvak will add risk to the primary objective of cement isolation across the significant hydrocarbon zone which is only located in the upper portion of the Tuluvak (TS 880). The increased risk is due to: a) Cementing the entire Tuluvak would require large cement jobs that jeopardize cement isolation across the upper Tuluvak. b) Large cement jobs likely require the use of lighter weight cement across the significant hydrocarbon zone. 3. 7” Liner Cement Job: The primary cement job will target a top of cement 100 feet TVD (~543 feet MD at ~79° inclination) above the top of the Nanushuk formation. Due to ERD nature of this section, additional TVD height of the cement top will significantly increase cement volumes and the subsequent risk of losses due to ECD’s exceeding the formation fracture gradient. Additionally, the 100 feet TVD above the top of the Nanushuk is targeted to: a) Allow the use of a single heavier tail slurry to provide the improved cement integrity and isolation across the top of the Nanushuk. Note, improved cement bond log quality has generally been observed with heavier weight tail slurries. b) Minimize the operational risk of cement returns up into the 9-5/8” shoe and above the top of the 7” liner hanger. will target a top of cement 100 feet TVD The targeted 7" cement height should be increased based on achieving <100' of good cement above top of the Nanushuk pool on NDBi-050 and NDBi-036. -bjm Attachments Attachment 1: Location Maps ADL 392977 ADL 392959ADL 392978 ADL 392965 ADL 392985 ADL 392984 ADL 392958 ADL 392992 ADL 392970 ADL 393024 ADL 393022 ADL 393021 ADL 393023 ADL 393019 ADL 393020 ADL 393015 ADL 393016 ADL 391320 ADL 391445 ADL 391455 U012N006E29 U012N005E35U012N005E26 U011N006E04 U012N006E32 U011N006E05 U012N006E33 U012N005E25 U012N006E28 U012N005E36 U011N005E01 U011N005E11U011N005E12 U011N006E09U011N006E08 U011N006E16U011N005E02U011N006E17 U011N005E13 U012N006E31 U011N006E06 U011N006E18 U011N006E07 COLVILLE RIVER 1 FIORD 3A QUGRUK 3 QUGRUK 301 QUGRUK 3A COLVILLE RIV UNIT CD1-15 QUGRUK 8 Colville River 1PB1 CD1-15PB1 Colville River Unit CD1-15PB2 DW-02 NDB-025 NDB-032 NDB-037 NDB-040 NDB-048 NDB-051 NDBi-014 NDBi-018 NDBi-030 NDBi-036 NDBi-043A NDBi-044 NDBi-046 NDBi-049 NDBi-050 OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD 0.25-MILE BUFFER 0.5-MILE BUFFER NDB-031 BOTTOM HOLE NDB DRILLED WELLS BOTTOM HOLES DEVELOPMENT WELLS EXPLORATION WELLS BOTTOM HOLES OTHER WELL TRAJECTORIES BY OTHERS NDB-031 SURFACE LOCATION PRODUCTION INTERVAL NDB-031 TRAJECTORY OTHER DRILLED NDB WELLS SANTOS LEASES SECTIONS DATE: 3/20/2025. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDB31_buffers GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDB-031 WELL Attachment 2: Directional Plan 24 March, 2025 Plan: Plan: NDB-031 Rev E.1 Pikka NDB B-31 NDB-031 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Pikka, North Slope Alaska, United States Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: NDB Map Slot Radius:0.9 usft usft usft " 5,972,909.13 423,383.61 36 70° 20' 10.132 N 150° 37' 17.794 W Well Well Position Longitude: Latitude: Easting: Northing: +E/-W +N/-S Position Uncertainty Ground Level: B-31 Wellhead Elevation:0.5 0.0 0.0 5,972,756.54 422,134.69 0.0 70° 20' 8.505 N 150° 37' 54.223 W 22.8 usft usft usft usft usft usft usft °-0.59Grid Convergence: Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) NDB-031 Model NameMagnetics BGGM2024 30/06/2025 13.69 80.53 57,120.44926926 Phase:Version: Audit Notes: Design Plan: NDB-031 Rev E.1 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:47.0 290.000.00.047.0 Plan Survey Tool Program RemarksTool NameSurvey (Wellbore) Date 24/03/2025 Depth To (usft) Depth From (usft) SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISC Plan: NDB-031 Rev E.1 (NDB-03147.0 800.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDB-031 Rev E.1 (NDB-032800.0 2,780.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDB-031 Rev E.1 (NDB-0332,780.0 12,000.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDB-031 Rev E.1 (NDB-03412,000.0 18,710.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDB-031 Rev E.1 (NDB-03518,710.0 24,427.2 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 2 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Inclination (°) Azimuth (°) +E/-W (usft) TFO (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections Target 0.000.000.000.000.00.047.00.000.0047.0 204.000.000.000.000.00.0347.0204.000.00347.0 204.000.002.232.23-33.3-74.7990.0204.0014.50996.9 0.000.000.000.00-49.1-110.21,140.1204.0014.501,151.9 37.021.972.893.04-729.3-717.12,370.0235.0860.002,728.5 0.000.000.000.00-800.3-766.72,420.0235.0860.002,828.5 0.200.013.003.00-1,460.3-1,226.72,669.9235.1785.483,677.9 0.000.000.000.00-11,581.8-8,270.13,643.8235.1785.4816,047.3 101.463.54-0.253.50-13,865.5-7,793.64,115.0329.3978.8618,711.8 0.000.003.503.50-14,033.0-7,510.44,145.8329.3990.4519,042.9 NDB-031 Heel Rev 91.190.000.000.00-16,774.4-2,876.14,103.8329.4090.4524,427.4 NDB-031 Toe Rev 0 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 3 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 47.0 0.00 47.0 0.0 0.00.00 422,134.695,972,756.54 70° 20' 8.505 N 150° 37' 54.223 W Start 300.0 hold at 47.0 MD 100.0 0.00 100.0 0.0 0.00.00 422,134.695,972,756.54 70° 20' 8.505 N 150° 37' 54.223 W 128.0 0.00 128.0 0.0 0.00.00 422,134.695,972,756.54 70° 20' 8.505 N 150° 37' 54.223 W 20" Conductor Casing 200.0 0.00 200.0 0.0 0.00.00 422,134.695,972,756.54 70° 20' 8.505 N 150° 37' 54.223 W 300.0 0.00 300.0 0.0 0.00.00 422,134.695,972,756.54 70° 20' 8.505 N 150° 37' 54.223 W 347.0 0.00 347.0 0.0 0.00.00 422,134.695,972,756.54 70° 20' 8.505 N 150° 37' 54.223 W Start Build 2.23 400.0 1.18 400.0 -0.5 -0.2204.00 422,134.465,972,756.05 70° 20' 8.500 N 150° 37' 54.230 W 500.0 3.41 499.9 -4.2 -1.9204.00 422,132.795,972,752.40 70° 20' 8.464 N 150° 37' 54.278 W 600.0 5.64 599.6 -11.4 -5.1204.00 422,129.515,972,745.22 70° 20' 8.393 N 150° 37' 54.371 W 700.0 7.88 698.9 -22.1 -9.9204.00 422,124.615,972,734.52 70° 20' 8.287 N 150° 37' 54.511 W 800.0 10.11 797.7 -36.4 -16.2204.00 422,118.115,972,720.31 70° 20' 8.147 N 150° 37' 54.697 W 900.0 12.34 895.7 -54.2 -24.1204.00 422,110.015,972,702.62 70° 20' 7.972 N 150° 37' 54.928 W 996.9 14.50 990.0 -74.7 -33.3204.00 422,100.655,972,682.17 70° 20' 7.770 N 150° 37' 55.195 W Start 155.0 hold at 996.9 MD 1,000.0 14.50 993.0 -75.4 -33.6204.00 422,100.335,972,681.47 70° 20' 7.763 N 150° 37' 55.204 W 1,052.5 14.50 1,043.8 -87.4 -38.9204.00 422,094.865,972,669.52 70° 20' 7.645 N 150° 37' 55.360 W Upper Schrader Bluff 1,100.0 14.50 1,089.8 -98.3 -43.8204.00 422,089.915,972,658.71 70° 20' 7.538 N 150° 37' 55.502 W 1,151.9 14.50 1,140.1 -110.2 -49.1204.00 422,084.505,972,646.89 70° 20' 7.421 N 150° 37' 55.656 W Start DLS 3.04 TFO 37.02 1,200.0 15.69 1,186.5 -121.5 -54.5207.26 422,078.955,972,635.66 70° 20' 7.310 N 150° 37' 55.815 W 1,300.0 18.29 1,282.1 -146.7 -69.1212.66 422,064.035,972,610.58 70° 20' 7.062 N 150° 37' 56.243 W 1,400.0 21.01 1,376.3 -174.3 -88.3216.74 422,044.545,972,583.20 70° 20' 6.791 N 150° 37' 56.803 W 1,417.7 21.50 1,392.8 -179.4 -92.2217.36 422,040.625,972,578.11 70° 20' 6.740 N 150° 37' 56.916 W Base Permafrost Transition 1,500.0 23.80 1,468.7 -204.1 -112.0219.91 422,020.565,972,553.60 70° 20' 6.497 N 150° 37' 57.495 W 1,600.0 26.65 1,559.2 -236.2 -140.1222.44 421,992.155,972,521.86 70° 20' 6.182 N 150° 37' 58.315 W 1,700.0 29.53 1,647.4 -270.3 -172.5224.51 421,959.385,972,488.07 70° 20' 5.846 N 150° 37' 59.262 W 1,800.0 32.44 1,733.1 -306.4 -209.2226.25 421,922.365,972,452.33 70° 20' 5.491 N 150° 38' 0.332 W 1,800.8 32.46 1,733.8 -306.7 -209.5226.26 421,922.055,972,452.04 70° 20' 5.488 N 150° 38' 0.341 W Middle Schrader Bluff 1,900.0 35.36 1,816.1 -344.5 -250.0227.72 421,881.185,972,414.73 70° 20' 5.117 N 150° 38' 1.523 W 2,000.0 38.31 1,896.2 -384.3 -294.8229.00 421,835.965,972,375.40 70° 20' 4.726 N 150° 38' 2.832 W 2,100.0 41.26 1,973.0 -425.8 -343.5230.12 421,786.825,972,334.42 70° 20' 4.318 N 150° 38' 4.254 W 2,200.0 44.23 2,046.4 -468.8 -396.0231.12 421,733.925,972,291.93 70° 20' 3.894 N 150° 38' 5.786 W 2,300.0 47.20 2,116.2 -513.3 -452.0232.01 421,677.385,972,248.03 70° 20' 3.457 N 150° 38' 7.424 W 2,344.1 48.51 2,145.8 -533.3 -477.9232.38 421,651.375,972,228.28 70° 20' 3.260 N 150° 38' 8.178 W MCU 2,400.0 50.18 2,182.2 -559.1 -511.6232.83 421,617.395,972,202.86 70° 20' 3.006 N 150° 38' 9.162 W 2,500.0 53.17 2,244.2 -606.1 -574.4233.57 421,554.095,972,156.54 70° 20' 2.544 N 150° 38' 10.996 W 2,600.0 56.16 2,302.1 -654.1 -640.3234.26 421,487.685,972,109.20 70° 20' 2.072 N 150° 38' 12.921 W 2,700.0 59.15 2,355.6 -703.0 -709.2234.90 421,418.345,972,060.98 70° 20' 1.590 N 150° 38' 14.931 W 2,728.5 60.00 2,370.0 -717.1 -729.3235.08 421,398.105,972,047.11 70° 20' 1.452 N 150° 38' 15.518 W Start 100.0 hold at 2728.5 MD 2,780.0 60.00 2,395.8 -742.7 -765.9235.08 421,361.245,972,021.95 70° 20' 1.201 N 150° 38' 16.587 W 13-3/8" Surface Casing 2,800.0 60.00 2,405.8 -752.6 -780.1235.08 421,346.945,972,012.18 70° 20' 1.103 N 150° 38' 17.002 W 2,828.5 60.00 2,420.0 -766.7 -800.3235.08 421,326.585,971,998.28 70° 20' 0.964 N 150° 38' 17.592 W Start DLS 3.00 TFO 0.00 2,889.8 61.84 2,449.8 -797.4 -844.2235.09 421,282.335,971,968.07 70° 20' 0.663 N 150° 38' 18.875 W Tuluvak Shale 2,900.0 62.15 2,454.6 -802.5 -851.6235.09 421,274.885,971,962.98 70° 20' 0.612 N 150° 38' 19.091 W 3,000.0 65.15 2,499.0 -853.8 -925.1235.10 421,200.885,971,912.48 70° 20' 0.107 N 150° 38' 21.236 W 3,033.5 66.15 2,512.8 -871.2 -950.1235.10 421,175.675,971,895.29 70° 19' 59.936 N 150° 38' 21.967 W Tuluvak Sand 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 4 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 3,100.0 68.15 2,538.6 -906.3 -1,000.4235.11 421,125.055,971,860.76 70° 19' 59.591 N 150° 38' 23.435 W 3,200.0 71.15 2,573.4 -959.9 -1,077.3235.12 421,047.615,971,807.95 70° 19' 59.063 N 150° 38' 25.680 W 3,300.0 74.15 2,603.2 -1,014.5 -1,155.6235.13 420,968.755,971,754.20 70° 19' 58.527 N 150° 38' 27.966 W 3,400.0 77.15 2,628.0 -1,069.9 -1,235.1235.14 420,888.715,971,699.66 70° 19' 57.982 N 150° 38' 30.287 W 3,500.0 80.15 2,647.7 -1,125.9 -1,315.5235.15 420,807.705,971,644.48 70° 19' 57.431 N 150° 38' 32.635 W 3,600.0 83.15 2,662.2 -1,182.4 -1,396.7235.16 420,725.935,971,588.81 70° 19' 56.875 N 150° 38' 35.006 W 3,677.9 85.48 2,669.9 -1,226.7 -1,460.3235.17 420,661.825,971,545.17 70° 19' 56.439 N 150° 38' 36.864 W 3,688.7 85.48 2,670.8 -1,232.9 -1,469.2235.17 420,652.935,971,539.12 70° 19' 56.378 N 150° 38' 37.122 W Start 12471.2 hold at 3688.7 MD 3,700.0 85.48 2,671.7 -1,239.3 -1,478.4235.17 420,643.655,971,532.80 70° 19' 56.315 N 150° 38' 37.391 W 3,800.0 85.48 2,679.6 -1,296.2 -1,560.2235.17 420,561.245,971,476.72 70° 19' 55.755 N 150° 38' 39.780 W 3,900.0 85.48 2,687.4 -1,353.2 -1,642.0235.17 420,478.845,971,420.64 70° 19' 55.195 N 150° 38' 42.169 W 4,000.0 85.48 2,695.3 -1,410.1 -1,723.9235.17 420,396.435,971,364.55 70° 19' 54.635 N 150° 38' 44.558 W 4,100.0 85.48 2,703.2 -1,467.0 -1,805.7235.17 420,314.035,971,308.47 70° 19' 54.075 N 150° 38' 46.946 W 4,200.0 85.48 2,711.0 -1,524.0 -1,887.5235.17 420,231.625,971,252.38 70° 19' 53.514 N 150° 38' 49.335 W 4,300.0 85.48 2,718.9 -1,580.9 -1,969.4235.17 420,149.215,971,196.30 70° 19' 52.954 N 150° 38' 51.724 W 4,400.0 85.48 2,726.8 -1,637.9 -2,051.2235.17 420,066.815,971,140.21 70° 19' 52.394 N 150° 38' 54.113 W 4,500.0 85.48 2,734.7 -1,694.8 -2,133.0235.17 419,984.405,971,084.13 70° 19' 51.834 N 150° 38' 56.501 W 4,600.0 85.48 2,742.5 -1,751.8 -2,214.8235.17 419,902.005,971,028.04 70° 19' 51.273 N 150° 38' 58.890 W 4,700.0 85.48 2,750.4 -1,808.7 -2,296.7235.17 419,819.595,970,971.96 70° 19' 50.713 N 150° 39' 1.278 W 4,800.0 85.48 2,758.3 -1,865.6 -2,378.5235.17 419,737.195,970,915.88 70° 19' 50.153 N 150° 39' 3.667 W 4,900.0 85.48 2,766.2 -1,922.6 -2,460.3235.17 419,654.785,970,859.79 70° 19' 49.593 N 150° 39' 6.055 W 5,000.0 85.48 2,774.0 -1,979.5 -2,542.1235.17 419,572.375,970,803.71 70° 19' 49.032 N 150° 39' 8.444 W 5,100.0 85.48 2,781.9 -2,036.5 -2,624.0235.17 419,489.975,970,747.62 70° 19' 48.472 N 150° 39' 10.832 W 5,200.0 85.48 2,789.8 -2,093.4 -2,705.8235.17 419,407.565,970,691.54 70° 19' 47.912 N 150° 39' 13.221 W 5,300.0 85.48 2,797.7 -2,150.3 -2,787.6235.17 419,325.165,970,635.45 70° 19' 47.351 N 150° 39' 15.609 W 5,400.0 85.48 2,805.5 -2,207.3 -2,869.4235.17 419,242.755,970,579.37 70° 19' 46.791 N 150° 39' 17.997 W 5,500.0 85.48 2,813.4 -2,264.2 -2,951.3235.17 419,160.355,970,523.29 70° 19' 46.231 N 150° 39' 20.386 W 5,600.0 85.48 2,821.3 -2,321.2 -3,033.1235.17 419,077.945,970,467.20 70° 19' 45.670 N 150° 39' 22.774 W 5,700.0 85.48 2,829.1 -2,378.1 -3,114.9235.17 418,995.535,970,411.12 70° 19' 45.110 N 150° 39' 25.162 W 5,800.0 85.48 2,837.0 -2,435.1 -3,196.8235.17 418,913.135,970,355.03 70° 19' 44.550 N 150° 39' 27.550 W 5,898.9 85.48 2,844.8 -2,491.4 -3,277.7235.17 418,831.655,970,299.58 70° 19' 43.996 N 150° 39' 29.912 W TS_790 5,900.0 85.48 2,844.9 -2,492.0 -3,278.6235.17 418,830.725,970,298.95 70° 19' 43.989 N 150° 39' 29.938 W 6,000.0 85.48 2,852.8 -2,548.9 -3,360.4235.17 418,748.325,970,242.86 70° 19' 43.429 N 150° 39' 32.327 W 6,100.0 85.48 2,860.6 -2,605.9 -3,442.2235.17 418,665.915,970,186.78 70° 19' 42.869 N 150° 39' 34.715 W 6,200.0 85.48 2,868.5 -2,662.8 -3,524.1235.17 418,583.515,970,130.69 70° 19' 42.308 N 150° 39' 37.103 W 6,300.0 85.48 2,876.4 -2,719.8 -3,605.9235.17 418,501.105,970,074.61 70° 19' 41.748 N 150° 39' 39.491 W 6,400.0 85.48 2,884.3 -2,776.7 -3,687.7235.17 418,418.695,970,018.53 70° 19' 41.187 N 150° 39' 41.879 W 6,500.0 85.48 2,892.1 -2,833.7 -3,769.5235.17 418,336.295,969,962.44 70° 19' 40.627 N 150° 39' 44.267 W 6,600.0 85.48 2,900.0 -2,890.6 -3,851.4235.17 418,253.885,969,906.36 70° 19' 40.067 N 150° 39' 46.654 W 6,700.0 85.48 2,907.9 -2,947.5 -3,933.2235.17 418,171.485,969,850.27 70° 19' 39.506 N 150° 39' 49.042 W 6,800.0 85.48 2,915.7 -3,004.5 -4,015.0235.17 418,089.075,969,794.19 70° 19' 38.946 N 150° 39' 51.430 W 6,900.0 85.48 2,923.6 -3,061.4 -4,096.8235.17 418,006.665,969,738.10 70° 19' 38.385 N 150° 39' 53.818 W 7,000.0 85.48 2,931.5 -3,118.4 -4,178.7235.17 417,924.265,969,682.02 70° 19' 37.825 N 150° 39' 56.206 W 7,100.0 85.48 2,939.4 -3,175.3 -4,260.5235.17 417,841.855,969,625.94 70° 19' 37.264 N 150° 39' 58.593 W 7,200.0 85.48 2,947.2 -3,232.2 -4,342.3235.17 417,759.455,969,569.85 70° 19' 36.704 N 150° 40' 0.981 W 7,300.0 85.48 2,955.1 -3,289.2 -4,424.2235.17 417,677.045,969,513.77 70° 19' 36.143 N 150° 40' 3.369 W 7,400.0 85.48 2,963.0 -3,346.1 -4,506.0235.17 417,594.645,969,457.68 70° 19' 35.583 N 150° 40' 5.756 W 7,500.0 85.48 2,970.9 -3,403.1 -4,587.8235.17 417,512.235,969,401.60 70° 19' 35.022 N 150° 40' 8.144 W 7,600.0 85.48 2,978.7 -3,460.0 -4,669.6235.17 417,429.825,969,345.51 70° 19' 34.462 N 150° 40' 10.531 W 7,700.0 85.48 2,986.6 -3,517.0 -4,751.5235.17 417,347.425,969,289.43 70° 19' 33.901 N 150° 40' 12.919 W 7,800.0 85.48 2,994.5 -3,573.9 -4,833.3235.17 417,265.015,969,233.34 70° 19' 33.341 N 150° 40' 15.306 W 7,900.0 85.48 3,002.3 -3,630.8 -4,915.1235.17 417,182.615,969,177.26 70° 19' 32.780 N 150° 40' 17.694 W 8,000.0 85.48 3,010.2 -3,687.8 -4,996.9235.17 417,100.205,969,121.18 70° 19' 32.220 N 150° 40' 20.081 W 8,100.0 85.48 3,018.1 -3,744.7 -5,078.8235.17 417,017.805,969,065.09 70° 19' 31.659 N 150° 40' 22.468 W 8,200.0 85.48 3,026.0 -3,801.7 -5,160.6235.17 416,935.395,969,009.01 70° 19' 31.098 N 150° 40' 24.856 W 8,300.0 85.48 3,033.8 -3,858.6 -5,242.4235.17 416,852.985,968,952.92 70° 19' 30.538 N 150° 40' 27.243 W 8,400.0 85.48 3,041.7 -3,915.6 -5,324.2235.17 416,770.585,968,896.84 70° 19' 29.977 N 150° 40' 29.630 W 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 5 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 8,500.0 85.48 3,049.6 -3,972.5 -5,406.1235.17 416,688.175,968,840.75 70° 19' 29.417 N 150° 40' 32.017 W 8,600.0 85.48 3,057.5 -4,029.4 -5,487.9235.17 416,605.775,968,784.67 70° 19' 28.856 N 150° 40' 34.405 W 8,700.0 85.48 3,065.3 -4,086.4 -5,569.7235.17 416,523.365,968,728.59 70° 19' 28.295 N 150° 40' 36.792 W 8,800.0 85.48 3,073.2 -4,143.3 -5,651.5235.17 416,440.965,968,672.50 70° 19' 27.735 N 150° 40' 39.179 W 8,900.0 85.48 3,081.1 -4,200.3 -5,733.4235.17 416,358.555,968,616.42 70° 19' 27.174 N 150° 40' 41.566 W 9,000.0 85.48 3,089.0 -4,257.2 -5,815.2235.17 416,276.145,968,560.33 70° 19' 26.614 N 150° 40' 43.953 W 9,100.0 85.48 3,096.8 -4,314.2 -5,897.0235.17 416,193.745,968,504.25 70° 19' 26.053 N 150° 40' 46.340 W 9,200.0 85.48 3,104.7 -4,371.1 -5,978.9235.17 416,111.335,968,448.16 70° 19' 25.492 N 150° 40' 48.727 W 9,300.0 85.48 3,112.6 -4,428.0 -6,060.7235.17 416,028.935,968,392.08 70° 19' 24.932 N 150° 40' 51.114 W 9,400.0 85.48 3,120.4 -4,485.0 -6,142.5235.17 415,946.525,968,336.00 70° 19' 24.371 N 150° 40' 53.501 W 9,500.0 85.48 3,128.3 -4,541.9 -6,224.3235.17 415,864.125,968,279.91 70° 19' 23.810 N 150° 40' 55.887 W 9,600.0 85.48 3,136.2 -4,598.9 -6,306.2235.17 415,781.715,968,223.83 70° 19' 23.250 N 150° 40' 58.274 W 9,700.0 85.48 3,144.1 -4,655.8 -6,388.0235.17 415,699.305,968,167.74 70° 19' 22.689 N 150° 41' 0.661 W 9,800.0 85.48 3,151.9 -4,712.7 -6,469.8235.17 415,616.905,968,111.66 70° 19' 22.128 N 150° 41' 3.048 W 9,900.0 85.48 3,159.8 -4,769.7 -6,551.6235.17 415,534.495,968,055.57 70° 19' 21.567 N 150° 41' 5.434 W 10,000.0 85.48 3,167.7 -4,826.6 -6,633.5235.17 415,452.095,967,999.49 70° 19' 21.007 N 150° 41' 7.821 W 10,100.0 85.48 3,175.6 -4,883.6 -6,715.3235.17 415,369.685,967,943.40 70° 19' 20.446 N 150° 41' 10.208 W 10,200.0 85.48 3,183.4 -4,940.5 -6,797.1235.17 415,287.275,967,887.32 70° 19' 19.885 N 150° 41' 12.594 W 10,300.0 85.48 3,191.3 -4,997.5 -6,878.9235.17 415,204.875,967,831.24 70° 19' 19.324 N 150° 41' 14.981 W 10,400.0 85.48 3,199.2 -5,054.4 -6,960.8235.17 415,122.465,967,775.15 70° 19' 18.764 N 150° 41' 17.367 W 10,500.0 85.48 3,207.0 -5,111.3 -7,042.6235.17 415,040.065,967,719.07 70° 19' 18.203 N 150° 41' 19.754 W 10,600.0 85.48 3,214.9 -5,168.3 -7,124.4235.17 414,957.655,967,662.98 70° 19' 17.642 N 150° 41' 22.140 W 10,700.0 85.48 3,222.8 -5,225.2 -7,206.3235.17 414,875.255,967,606.90 70° 19' 17.081 N 150° 41' 24.527 W 10,800.0 85.48 3,230.7 -5,282.2 -7,288.1235.17 414,792.845,967,550.81 70° 19' 16.521 N 150° 41' 26.913 W 10,900.0 85.48 3,238.5 -5,339.1 -7,369.9235.17 414,710.435,967,494.73 70° 19' 15.960 N 150° 41' 29.299 W 11,000.0 85.48 3,246.4 -5,396.1 -7,451.7235.17 414,628.035,967,438.65 70° 19' 15.399 N 150° 41' 31.686 W 11,100.0 85.48 3,254.3 -5,453.0 -7,533.6235.17 414,545.625,967,382.56 70° 19' 14.838 N 150° 41' 34.072 W 11,200.0 85.48 3,262.2 -5,509.9 -7,615.4235.17 414,463.225,967,326.48 70° 19' 14.277 N 150° 41' 36.458 W 11,220.8 85.48 3,263.8 -5,521.8 -7,632.4235.17 414,446.045,967,314.79 70° 19' 14.160 N 150° 41' 36.955 W Seabee 11,300.0 85.48 3,270.0 -5,566.9 -7,697.2235.17 414,380.815,967,270.39 70° 19' 13.716 N 150° 41' 38.844 W 11,400.0 85.48 3,277.9 -5,623.8 -7,779.0235.17 414,298.415,967,214.31 70° 19' 13.156 N 150° 41' 41.230 W 11,500.0 85.48 3,285.8 -5,680.8 -7,860.9235.17 414,216.005,967,158.22 70° 19' 12.595 N 150° 41' 43.617 W 11,600.0 85.48 3,293.7 -5,737.7 -7,942.7235.17 414,133.595,967,102.14 70° 19' 12.034 N 150° 41' 46.003 W 11,700.0 85.48 3,301.5 -5,794.6 -8,024.5235.17 414,051.195,967,046.05 70° 19' 11.473 N 150° 41' 48.389 W 11,800.0 85.48 3,309.4 -5,851.6 -8,106.3235.17 413,968.785,966,989.97 70° 19' 10.912 N 150° 41' 50.775 W 11,900.0 85.48 3,317.3 -5,908.5 -8,188.2235.17 413,886.385,966,933.89 70° 19' 10.351 N 150° 41' 53.161 W 12,000.0 85.48 3,325.1 -5,965.5 -8,270.0235.17 413,803.975,966,877.80 70° 19' 9.790 N 150° 41' 55.547 W 9-5/8" Intermediate Liner 12,100.0 85.48 3,333.0 -6,022.4 -8,351.8235.17 413,721.575,966,821.72 70° 19' 9.229 N 150° 41' 57.932 W 12,200.0 85.48 3,340.9 -6,079.4 -8,433.7235.17 413,639.165,966,765.63 70° 19' 8.668 N 150° 42' 0.318 W 12,300.0 85.48 3,348.8 -6,136.3 -8,515.5235.17 413,556.755,966,709.55 70° 19' 8.108 N 150° 42' 2.704 W 12,400.0 85.48 3,356.6 -6,193.2 -8,597.3235.17 413,474.355,966,653.46 70° 19' 7.547 N 150° 42' 5.090 W 12,500.0 85.48 3,364.5 -6,250.2 -8,679.1235.17 413,391.945,966,597.38 70° 19' 6.986 N 150° 42' 7.476 W 12,600.0 85.48 3,372.4 -6,307.1 -8,761.0235.17 413,309.545,966,541.30 70° 19' 6.425 N 150° 42' 9.861 W 12,700.0 85.48 3,380.3 -6,364.1 -8,842.8235.17 413,227.135,966,485.21 70° 19' 5.864 N 150° 42' 12.247 W 12,800.0 85.48 3,388.1 -6,421.0 -8,924.6235.17 413,144.735,966,429.13 70° 19' 5.303 N 150° 42' 14.633 W 12,900.0 85.48 3,396.0 -6,478.0 -9,006.4235.17 413,062.325,966,373.04 70° 19' 4.742 N 150° 42' 17.018 W 13,000.0 85.48 3,403.9 -6,534.9 -9,088.3235.17 412,979.915,966,316.96 70° 19' 4.181 N 150° 42' 19.404 W 13,100.0 85.48 3,411.7 -6,591.8 -9,170.1235.17 412,897.515,966,260.87 70° 19' 3.620 N 150° 42' 21.789 W 13,200.0 85.48 3,419.6 -6,648.8 -9,251.9235.17 412,815.105,966,204.79 70° 19' 3.059 N 150° 42' 24.175 W 13,300.0 85.48 3,427.5 -6,705.7 -9,333.7235.17 412,732.705,966,148.70 70° 19' 2.498 N 150° 42' 26.560 W 13,400.0 85.48 3,435.4 -6,762.7 -9,415.6235.17 412,650.295,966,092.62 70° 19' 1.937 N 150° 42' 28.946 W 13,500.0 85.48 3,443.2 -6,819.6 -9,497.4235.17 412,567.885,966,036.54 70° 19' 1.376 N 150° 42' 31.331 W 13,600.0 85.48 3,451.1 -6,876.6 -9,579.2235.17 412,485.485,965,980.45 70° 19' 0.815 N 150° 42' 33.717 W 13,700.0 85.48 3,459.0 -6,933.5 -9,661.1235.17 412,403.075,965,924.37 70° 19' 0.254 N 150° 42' 36.102 W 13,800.0 85.48 3,466.9 -6,990.4 -9,742.9235.17 412,320.675,965,868.28 70° 18' 59.693 N 150° 42' 38.487 W 13,900.0 85.48 3,474.7 -7,047.4 -9,824.7235.17 412,238.265,965,812.20 70° 18' 59.132 N 150° 42' 40.872 W 14,000.0 85.48 3,482.6 -7,104.3 -9,906.5235.17 412,155.865,965,756.11 70° 18' 58.570 N 150° 42' 43.258 W 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 6 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 14,100.0 85.48 3,490.5 -7,161.3 -9,988.4235.17 412,073.455,965,700.03 70° 18' 58.009 N 150° 42' 45.643 W 14,200.0 85.48 3,498.3 -7,218.2 -10,070.2235.17 411,991.045,965,643.95 70° 18' 57.448 N 150° 42' 48.028 W 14,300.0 85.48 3,506.2 -7,275.1 -10,152.0235.17 411,908.645,965,587.86 70° 18' 56.887 N 150° 42' 50.413 W 14,400.0 85.48 3,514.1 -7,332.1 -10,233.8235.17 411,826.235,965,531.78 70° 18' 56.326 N 150° 42' 52.798 W 14,500.0 85.48 3,522.0 -7,389.0 -10,315.7235.17 411,743.835,965,475.69 70° 18' 55.765 N 150° 42' 55.183 W 14,600.0 85.48 3,529.8 -7,446.0 -10,397.5235.17 411,661.425,965,419.61 70° 18' 55.204 N 150° 42' 57.568 W 14,700.0 85.48 3,537.7 -7,502.9 -10,479.3235.17 411,579.025,965,363.52 70° 18' 54.643 N 150° 42' 59.953 W 14,800.0 85.48 3,545.6 -7,559.9 -10,561.1235.17 411,496.615,965,307.44 70° 18' 54.081 N 150° 43' 2.338 W 14,900.0 85.48 3,553.5 -7,616.8 -10,643.0235.17 411,414.205,965,251.35 70° 18' 53.520 N 150° 43' 4.723 W 15,000.0 85.48 3,561.3 -7,673.7 -10,724.8235.17 411,331.805,965,195.27 70° 18' 52.959 N 150° 43' 7.108 W 15,100.0 85.48 3,569.2 -7,730.7 -10,806.6235.17 411,249.395,965,139.19 70° 18' 52.398 N 150° 43' 9.492 W 15,200.0 85.48 3,577.1 -7,787.6 -10,888.5235.17 411,166.995,965,083.10 70° 18' 51.837 N 150° 43' 11.877 W 15,300.0 85.48 3,585.0 -7,844.6 -10,970.3235.17 411,084.585,965,027.02 70° 18' 51.276 N 150° 43' 14.262 W 15,400.0 85.48 3,592.8 -7,901.5 -11,052.1235.17 411,002.185,964,970.93 70° 18' 50.714 N 150° 43' 16.647 W 15,500.0 85.48 3,600.7 -7,958.5 -11,133.9235.17 410,919.775,964,914.85 70° 18' 50.153 N 150° 43' 19.031 W 15,600.0 85.48 3,608.6 -8,015.4 -11,215.8235.17 410,837.365,964,858.76 70° 18' 49.592 N 150° 43' 21.416 W 15,700.0 85.48 3,616.4 -8,072.3 -11,297.6235.17 410,754.965,964,802.68 70° 18' 49.031 N 150° 43' 23.800 W 15,800.0 85.48 3,624.3 -8,129.3 -11,379.4235.17 410,672.555,964,746.60 70° 18' 48.470 N 150° 43' 26.185 W 15,900.0 85.48 3,632.2 -8,186.2 -11,461.2235.17 410,590.155,964,690.51 70° 18' 47.908 N 150° 43' 28.570 W 16,000.0 85.48 3,640.1 -8,243.2 -11,543.1235.17 410,507.745,964,634.43 70° 18' 47.347 N 150° 43' 30.954 W 16,047.3 85.48 3,643.8 -8,270.1 -11,581.8235.17 410,468.745,964,607.89 70° 18' 47.081 N 150° 43' 32.082 W 16,100.0 85.12 3,648.1 -8,299.4 -11,625.3236.98 410,424.895,964,579.04 70° 18' 46.793 N 150° 43' 33.352 W 16,160.0 84.71 3,653.4 -8,331.1 -11,676.0239.05 410,373.895,964,547.92 70° 18' 46.481 N 150° 43' 34.829 W Start DLS 3.75 TFO 103.89 16,200.0 84.44 3,657.2 -8,351.1 -11,710.4240.43 410,339.285,964,528.21 70° 18' 46.283 N 150° 43' 35.831 W 16,300.0 83.79 3,667.5 -8,397.6 -11,798.4243.88 410,250.875,964,482.67 70° 18' 45.824 N 150° 43' 38.395 W 16,400.0 83.15 3,678.8 -8,438.6 -11,888.8247.35 410,159.985,964,442.61 70° 18' 45.420 N 150° 43' 41.032 W 16,500.0 82.54 3,691.3 -8,474.0 -11,981.5250.82 410,066.965,964,408.16 70° 18' 45.070 N 150° 43' 43.733 W 16,600.0 81.96 3,704.8 -8,503.7 -12,076.0254.31 409,972.155,964,379.46 70° 18' 44.776 N 150° 43' 46.489 W 16,700.0 81.41 3,719.2 -8,527.6 -12,172.0257.80 409,875.905,964,356.61 70° 18' 44.540 N 150° 43' 49.289 W 16,800.0 80.89 3,734.6 -8,545.5 -12,269.2261.30 409,778.585,964,339.70 70° 18' 44.363 N 150° 43' 52.122 W 16,900.0 80.40 3,750.9 -8,557.4 -12,367.1264.81 409,680.545,964,328.79 70° 18' 44.244 N 150° 43' 54.978 W 17,000.0 79.94 3,768.0 -8,563.3 -12,465.5268.34 409,582.155,964,323.92 70° 18' 44.184 N 150° 43' 57.846 W 17,100.0 79.53 3,785.8 -8,563.1 -12,563.8271.87 409,483.795,964,325.11 70° 18' 44.184 N 150° 44' 0.716 W 17,200.0 79.15 3,804.3 -8,556.9 -12,661.9275.41 409,385.815,964,332.36 70° 18' 44.244 N 150° 44' 3.577 W 17,300.0 78.82 3,823.4 -8,544.6 -12,759.3278.96 409,288.585,964,345.64 70° 18' 44.363 N 150° 44' 6.418 W 17,400.0 78.52 3,843.1 -8,526.4 -12,855.6282.51 409,192.465,964,364.90 70° 18' 44.541 N 150° 44' 9.229 W 17,443.7 78.41 3,851.8 -8,516.5 -12,897.2284.07 409,150.945,964,375.17 70° 18' 44.637 N 150° 44' 10.443 W Nanushuk 17,500.0 78.27 3,863.2 -8,502.2 -12,950.5286.08 409,097.825,964,390.07 70° 18' 44.777 N 150° 44' 11.998 W 17,600.0 78.07 3,883.7 -8,472.2 -13,043.6289.65 409,005.005,964,421.05 70° 18' 45.071 N 150° 44' 14.717 W 17,700.0 77.91 3,904.5 -8,436.4 -13,134.7293.22 408,914.365,964,457.72 70° 18' 45.421 N 150° 44' 17.374 W 17,800.0 77.79 3,925.6 -8,395.1 -13,223.3296.80 408,826.225,964,499.96 70° 18' 45.826 N 150° 44' 19.960 W 17,881.2 77.73 3,942.8 -8,357.5 -13,293.2299.71 408,756.695,964,538.27 70° 18' 46.194 N 150° 44' 22.002 W NT7 MFS 17,900.0 77.72 3,946.8 -8,348.3 -13,309.0300.38 408,740.935,964,547.60 70° 18' 46.284 N 150° 44' 22.465 W 18,000.0 77.70 3,968.1 -8,296.3 -13,391.7303.96 408,658.795,964,600.47 70° 18' 46.794 N 150° 44' 24.880 W 18,073.8 77.71 3,983.8 -8,254.7 -13,450.6306.61 408,600.385,964,642.73 70° 18' 47.203 N 150° 44' 26.599 W NT6 MFS 18,100.0 77.72 3,989.4 -8,239.2 -13,471.0307.55 408,580.125,964,658.37 70° 18' 47.354 N 150° 44' 27.195 W 18,200.0 77.79 4,010.6 -8,177.3 -13,546.6311.13 408,505.205,964,721.08 70° 18' 47.962 N 150° 44' 29.403 W 18,267.4 77.86 4,024.8 -8,132.9 -13,595.3313.54 408,456.975,964,765.94 70° 18' 48.397 N 150° 44' 30.826 W NT5 MFS 18,300.0 77.91 4,031.6 -8,110.7 -13,618.2314.70 408,434.325,964,788.37 70° 18' 48.615 N 150° 44' 31.495 W 18,400.0 78.07 4,052.5 -8,039.8 -13,685.5318.28 408,367.745,964,859.99 70° 18' 49.312 N 150° 44' 33.463 W 18,425.9 78.12 4,057.8 -8,020.8 -13,702.2319.20 408,351.235,964,879.20 70° 18' 49.499 N 150° 44' 33.951 W NT4 MFS 18,500.0 78.28 4,073.0 -7,964.8 -13,748.3321.85 408,305.715,964,935.66 70° 18' 50.048 N 150° 44' 35.299 W 18,600.0 78.53 4,093.1 -7,885.9 -13,806.4325.41 408,248.465,965,015.12 70° 18' 50.823 N 150° 44' 36.998 W 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 7 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 18,608.7 78.55 4,094.8 -7,878.9 -13,811.2325.72 408,243.715,965,022.21 70° 18' 50.892 N 150° 44' 37.139 W NT3 MFS 18,645.1 78.66 4,102.0 -7,849.2 -13,831.0327.02 408,224.265,965,052.13 70° 18' 51.184 N 150° 44' 37.717 W Start 85.1 hold at 18645.1 MD 18,700.0 78.82 4,112.7 -7,803.5 -13,859.5328.97 408,196.215,965,098.06 70° 18' 51.632 N 150° 44' 38.552 W 18,710.0 78.85 4,114.6 -7,795.1 -13,864.5329.33 408,191.265,965,106.53 70° 18' 51.715 N 150° 44' 38.699 W 7" Intermediate Liner 18,711.8 78.86 4,115.0 -7,793.6 -13,865.5329.39 408,190.375,965,108.09 70° 18' 51.730 N 150° 44' 38.726 W 18,730.2 79.50 4,118.5 -7,778.0 -13,874.7329.39 408,181.335,965,123.73 70° 18' 51.883 N 150° 44' 38.995 W Start Build 3.50 18,767.3 80.80 4,124.8 -7,746.5 -13,893.3329.39 408,163.035,965,155.39 70° 18' 52.192 N 150° 44' 39.540 W NT3.2 Top Reservoir 18,800.0 81.95 4,129.7 -7,718.7 -13,909.7329.39 408,146.895,965,183.35 70° 18' 52.465 N 150° 44' 40.021 W 18,900.0 85.45 4,140.7 -7,633.2 -13,960.3329.39 408,097.185,965,269.39 70° 18' 53.306 N 150° 44' 41.502 W 19,000.0 88.95 4,145.6 -7,547.3 -14,011.2329.39 408,047.235,965,355.86 70° 18' 54.150 N 150° 44' 42.990 W 19,042.9 90.45 4,145.8 -7,510.4 -14,033.0329.39 408,025.795,965,392.97 70° 18' 54.512 N 150° 44' 43.629 W 19,100.0 90.45 4,145.3 -7,461.2 -14,062.1329.39 407,997.215,965,442.43 70° 18' 54.995 N 150° 44' 44.480 W 19,131.3 90.45 4,145.1 -7,434.2 -14,078.0329.39 407,981.555,965,469.55 70° 18' 55.260 N 150° 44' 44.947 W Start 5384.6 hold at 19131.3 MD 19,200.0 90.45 4,144.6 -7,375.1 -14,113.0329.39 407,947.205,965,529.01 70° 18' 55.841 N 150° 44' 45.971 W 19,300.0 90.45 4,143.8 -7,289.1 -14,163.9329.39 407,897.185,965,615.59 70° 18' 56.686 N 150° 44' 47.461 W 19,400.0 90.45 4,143.0 -7,203.0 -14,214.8329.39 407,847.165,965,702.17 70° 18' 57.532 N 150° 44' 48.951 W 19,500.0 90.45 4,142.2 -7,116.9 -14,265.8329.39 407,797.155,965,788.75 70° 18' 58.377 N 150° 44' 50.441 W 19,600.0 90.45 4,141.4 -7,030.9 -14,316.7329.39 407,747.135,965,875.33 70° 18' 59.223 N 150° 44' 51.932 W 19,700.0 90.45 4,140.7 -6,944.8 -14,367.6329.39 407,697.125,965,961.91 70° 19' 0.068 N 150° 44' 53.422 W 19,800.0 90.45 4,139.9 -6,858.8 -14,418.5329.39 407,647.105,966,048.49 70° 19' 0.914 N 150° 44' 54.912 W 19,900.0 90.45 4,139.1 -6,772.7 -14,469.4329.39 407,597.095,966,135.07 70° 19' 1.759 N 150° 44' 56.403 W 20,000.0 90.45 4,138.3 -6,686.6 -14,520.3329.39 407,547.075,966,221.65 70° 19' 2.605 N 150° 44' 57.893 W 20,100.0 90.45 4,137.5 -6,600.6 -14,571.2329.39 407,497.065,966,308.23 70° 19' 3.450 N 150° 44' 59.384 W 20,200.0 90.45 4,136.8 -6,514.5 -14,622.2329.39 407,447.045,966,394.81 70° 19' 4.296 N 150° 45' 0.874 W 20,300.0 90.45 4,136.0 -6,428.4 -14,673.1329.39 407,397.035,966,481.39 70° 19' 5.141 N 150° 45' 2.365 W 20,400.0 90.45 4,135.2 -6,342.4 -14,724.0329.39 407,347.025,966,567.97 70° 19' 5.986 N 150° 45' 3.855 W 20,500.0 90.45 4,134.4 -6,256.3 -14,774.9329.39 407,297.005,966,654.55 70° 19' 6.832 N 150° 45' 5.346 W 20,600.0 90.45 4,133.6 -6,170.2 -14,825.8329.39 407,246.995,966,741.13 70° 19' 7.677 N 150° 45' 6.836 W 20,700.0 90.45 4,132.9 -6,084.2 -14,876.7329.39 407,196.985,966,827.71 70° 19' 8.523 N 150° 45' 8.327 W 20,800.0 90.45 4,132.1 -5,998.1 -14,927.6329.39 407,146.965,966,914.29 70° 19' 9.368 N 150° 45' 9.818 W 20,900.0 90.45 4,131.3 -5,912.0 -14,978.6329.39 407,096.955,967,000.87 70° 19' 10.214 N 150° 45' 11.308 W 21,000.0 90.45 4,130.5 -5,826.0 -15,029.5329.39 407,046.945,967,087.45 70° 19' 11.059 N 150° 45' 12.799 W 21,100.0 90.45 4,129.7 -5,739.9 -15,080.4329.39 406,996.935,967,174.04 70° 19' 11.905 N 150° 45' 14.290 W 21,200.0 90.45 4,129.0 -5,653.8 -15,131.3329.39 406,946.925,967,260.62 70° 19' 12.750 N 150° 45' 15.780 W 21,300.0 90.45 4,128.2 -5,567.8 -15,182.2329.39 406,896.905,967,347.20 70° 19' 13.595 N 150° 45' 17.271 W 21,400.0 90.45 4,127.4 -5,481.7 -15,233.1329.39 406,846.895,967,433.78 70° 19' 14.441 N 150° 45' 18.762 W 21,500.0 90.45 4,126.6 -5,395.7 -15,284.0329.39 406,796.885,967,520.36 70° 19' 15.286 N 150° 45' 20.253 W 21,600.0 90.45 4,125.8 -5,309.6 -15,334.9329.39 406,746.875,967,606.94 70° 19' 16.132 N 150° 45' 21.744 W 21,700.0 90.45 4,125.1 -5,223.5 -15,385.9329.39 406,696.865,967,693.53 70° 19' 16.977 N 150° 45' 23.235 W 21,800.0 90.45 4,124.3 -5,137.5 -15,436.8329.39 406,646.855,967,780.11 70° 19' 17.823 N 150° 45' 24.726 W 21,900.0 90.45 4,123.5 -5,051.4 -15,487.7329.39 406,596.845,967,866.69 70° 19' 18.668 N 150° 45' 26.217 W 22,000.0 90.45 4,122.7 -4,965.3 -15,538.6329.39 406,546.835,967,953.27 70° 19' 19.513 N 150° 45' 27.708 W 22,100.0 90.45 4,121.9 -4,879.3 -15,589.5329.39 406,496.825,968,039.86 70° 19' 20.359 N 150° 45' 29.199 W 22,200.0 90.45 4,121.2 -4,793.2 -15,640.4329.39 406,446.815,968,126.44 70° 19' 21.204 N 150° 45' 30.690 W 22,300.0 90.45 4,120.4 -4,707.1 -15,691.3329.40 406,396.805,968,213.02 70° 19' 22.050 N 150° 45' 32.181 W 22,400.0 90.45 4,119.6 -4,621.0 -15,742.2329.40 406,346.795,968,299.61 70° 19' 22.895 N 150° 45' 33.672 W 22,500.0 90.45 4,118.8 -4,535.0 -15,793.1329.40 406,296.785,968,386.19 70° 19' 23.741 N 150° 45' 35.163 W 22,600.0 90.45 4,118.0 -4,448.9 -15,844.1329.40 406,246.785,968,472.77 70° 19' 24.586 N 150° 45' 36.654 W 22,700.0 90.45 4,117.3 -4,362.8 -15,895.0329.40 406,196.775,968,559.36 70° 19' 25.431 N 150° 45' 38.145 W 22,800.0 90.45 4,116.5 -4,276.8 -15,945.9329.40 406,146.765,968,645.94 70° 19' 26.277 N 150° 45' 39.636 W 22,900.0 90.45 4,115.7 -4,190.7 -15,996.8329.40 406,096.755,968,732.52 70° 19' 27.122 N 150° 45' 41.128 W 23,000.0 90.45 4,114.9 -4,104.6 -16,047.7329.40 406,046.745,968,819.11 70° 19' 27.968 N 150° 45' 42.619 W 23,100.0 90.45 4,114.1 -4,018.6 -16,098.6329.40 405,996.745,968,905.69 70° 19' 28.813 N 150° 45' 44.110 W 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 8 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 23,200.0 90.45 4,113.4 -3,932.5 -16,149.5329.40 405,946.735,968,992.28 70° 19' 29.658 N 150° 45' 45.601 W 23,300.0 90.45 4,112.6 -3,846.4 -16,200.4329.40 405,896.725,969,078.86 70° 19' 30.504 N 150° 45' 47.093 W 23,400.0 90.45 4,111.8 -3,760.4 -16,251.3329.40 405,846.725,969,165.44 70° 19' 31.349 N 150° 45' 48.584 W 23,500.0 90.45 4,111.0 -3,674.3 -16,302.2329.40 405,796.715,969,252.03 70° 19' 32.195 N 150° 45' 50.075 W 23,600.0 90.45 4,110.2 -3,588.2 -16,353.1329.40 405,746.705,969,338.61 70° 19' 33.040 N 150° 45' 51.567 W 23,700.0 90.45 4,109.5 -3,502.2 -16,404.0329.40 405,696.705,969,425.20 70° 19' 33.885 N 150° 45' 53.058 W 23,800.0 90.45 4,108.7 -3,416.1 -16,454.9329.40 405,646.695,969,511.78 70° 19' 34.731 N 150° 45' 54.550 W 23,900.0 90.45 4,107.9 -3,330.0 -16,505.9329.40 405,596.695,969,598.37 70° 19' 35.576 N 150° 45' 56.041 W 24,000.0 90.45 4,107.1 -3,244.0 -16,556.8329.40 405,546.685,969,684.95 70° 19' 36.421 N 150° 45' 57.533 W 24,100.0 90.45 4,106.3 -3,157.9 -16,607.7329.40 405,496.685,969,771.54 70° 19' 37.267 N 150° 45' 59.024 W 24,200.0 90.45 4,105.6 -3,071.8 -16,658.6329.40 405,446.675,969,858.12 70° 19' 38.112 N 150° 46' 0.516 W 24,300.0 90.45 4,104.8 -2,985.7 -16,709.5329.40 405,396.675,969,944.71 70° 19' 38.958 N 150° 46' 2.008 W 24,400.0 90.45 4,104.0 -2,899.7 -16,760.4329.40 405,346.665,970,031.30 70° 19' 39.803 N 150° 46' 3.499 W 24,427.0 90.45 4,103.8 -2,876.4 -16,774.1329.40 405,333.165,970,054.67 70° 19' 40.031 N 150° 46' 3.902 W 4-1/2" Production Liner 24,427.4 90.45 4,103.8 -2,876.1 -16,774.4329.40 405,332.945,970,055.06 70° 19' 40.035 N 150° 46' 3.909 W Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Design Targets LongitudeLatitude Dip Angle (°) Dip Dir. (°) NDB-031 Toe Rev 0.0 4,103.8 5,970,055.06 405,332.94-2,876.1 -16,774.40.00 0.00 70° 19' 40.035 N 150° 46' 3.909 W - plan hits target center - Point NDB-031 Heel Rev 0.4,145.8 5,965,392.97 408,025.79-7,510.4 -14,033.00.00 0.00 70° 18' 54.512 N 150° 44' 43.629 W - plan hits target center - Polygon -131.3Point 1 5,965,257.88 408,391.874,145.8 367.5 True 5,019.7Point 2 5,970,439.75 405,398.594,145.8 -2,679.7 True 4,765.2Point 3 5,970,189.76 404,965.614,145.8 -3,110.1 True -385.8Point 4 5,965,007.88 407,958.894,145.8 -62.9 True Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 20" Conductor Casing128.0128.0 20 20 13-3/8" Surface Casing2,395.82,780.0 13-3/8 16 9-5/8" Intermediate Liner3,325.112,000.0 9-5/8 12-1/4 7" Intermediate Liner4,114.618,710.0 78-1/2 4-1/2" Production Liner4,103.824,427.0 4-1/2 6-1/8 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 9 Santos Ltd Planning Report - Geographic Well B-31Local Co-ordinate Reference:Database:EDM Parker 272 @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-31Well: NDB-031Wellbore: Plan: NDB-031 Rev E.1Design: Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations 1,052.5 Upper Schrader Bluff1,043.8 1,417.7 Base Permafrost Transition 0.001,392.8 1,800.8 Middle Schrader Bluff1,733.8 2,344.1 MCU2,145.8 2,889.8 Tuluvak Shale 0.002,449.8 3,033.5 Tuluvak Sand 0.002,512.8 5,898.9 TS_790 0.002,844.8 11,220.8 Seabee 0.003,263.8 17,443.7 Nanushuk 0.003,851.8 17,881.2 NT7 MFS 0.003,942.8 18,073.8 NT6 MFS 0.003,983.8 18,267.4 NT5 MFS 0.004,024.8 18,425.9 NT4 MFS 0.004,057.8 18,608.7 NT3 MFS 0.004,094.8 18,767.3 NT3.2 Top Reservoir 0.004,124.8 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 47.0 47.0 0.0 0.0 Start 300.0 hold at 47.0 MD 347.0 347.0 0.0 0.0 Start Build 2.23 996.9 990.0 -74.7 -33.3 Start 155.0 hold at 996.9 MD 1,151.9 1,140.1 -110.2 -49.1 Start DLS 3.04 TFO 37.02 2,728.5 2,370.0 -717.1 -729.3 Start 100.0 hold at 2728.5 MD 2,828.5 2,420.0 -766.7 -800.3 Start DLS 3.00 TFO 0.00 3,688.7 2,670.8 -1,232.9 -1,469.2 Start 12471.2 hold at 3688.7 MD 16,160.0 3,653.4 -8,331.1 -11,676.0 Start DLS 3.75 TFO 103.89 18,645.1 4,102.0 -7,849.2 -13,831.0 Start 85.1 hold at 18645.1 MD 18,730.2 4,118.5 -7,778.0 -13,874.7 Start Build 3.50 19,131.3 4,145.1 -7,434.2 -14,078.0 Start 5384.6 hold at 19131.3 MD 24,515.9 TD at 24515.9 24/03/2025 10:05:36 COMPASS 5000.17 Build Page 10 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 47.0 0.00 0.00 47.0 0.0 0.0 0.00 0.00 0.0 Start 300.0 hold at 47.0 MD 2 347.0 0.00 204.00 347.0 0.0 0.0 0.00 204.00 0.0 Start Build 2.23 3 996.9 14.50 204.00 990.0 -74.7 -33.3 2.23 204.00 5.7 Start 155.0 hold at 996.9 MD 4 1151.9 14.50 204.00 1140.1 -110.2 -49.1 0.00 0.00 8.4 Start DLS 3.04 TFO 37.02 5 2728.5 60.00 235.08 2370.0 -717.1 -729.3 3.04 37.02 440.0 Start 100.0 hold at 2728.5 MD 6 2828.5 60.00 235.08 2420.0 -766.7 -800.3 0.00 0.00 489.8 Start DLS 3.00 TFO 0.00 7 3677.9 85.48 235.16 2669.9 -1226.7 -1460.3 3.00 0.19 952.7 8 16047.0 85.48 235.16 3643.8 -8270.7 -11581.0 0.00 0.00 8053.9 9 18711.6 78.86 329.39 4115.0 -7794.2 -13864.8 3.50 101.4610362.8 10 19042.7 90.45 329.39 4145.8 -7511.0 -14032.3 3.50 0.0010617.1 NDB-031 Heel Rev 0.0 11 24427.2 90.45 329.39 4103.8 -2876.9 -16774.0 0.00 0.00 14778.5 NDB-031 Toe Rev 0.0 47 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 5000 5000 8000 8000 12000 12000 13000 13000 14000 14000 15000 15000 16000 16000 20700 Plan: NDB-031 Rev E.1 Plan Summary 0 3 Dogleg Severity0 3500 7000 10500 14000 17500 21000 24500 Measured Depth 20" Conductor Casing 13-3/8" Surface Casing 9-5/8" Intermediate Liner 7" Intermediate Liner 4-1/2" Production Liner 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Highside Toolface Angle [°] vs Travelling Cylinder Separation [90 usft/in] 5075100125150175200225250275300325327 350375400425450475500525550Plan: NDBi-026 Rev A.0 475075100125150175200225250275300325327 350375400425450475500525550575600625650675700 Plan: NDB-027 Rev B.0 75100125150175200225250275300325327 350 37540042545047550052555057560062565067570072575077580082585087590092595097510001025105010751100112511501175120012251250127513001325135013641375140014251450147515001525155015751600162516501675170017251750177518001825185018751900192519501975Plan NDBi-028 Rev A.0 475075100125150175200225250275300325327 350375400425450475500525550575600625650675700725750775800825850875900925950NDB-29 Rev12 475075100125150175200225250275300325 350375400425450475500525550575600625650675700725750775800 825 850 NDBi-030 475075100125150175200225250275300325 350375400425450475500525550563575600625650675700725750775800825850 875 900 925 950 NDB-032 75100125150175200225250275300325 3503754004254504755005255505756006256506757007257507758008258488508759009259509751000 1025105010751100112511501175120012251250127513001325135013751400142514501475150015251550157516001625165016751700172517501775Plan: NDB-033 Rev A.0 5075100125150175200225250275300325 350375400425450475500525550551575600625650675700725750775800825 Plan: NDBi-034 Rev A.0 475075100125150175200225250275300325 3503754004254504755005255505756006256506757007257507758008258508658759009259509751000NDB-035 Rev12475075100125150175200225250275300325 34835037540042545047550052555057560062565067570072575077580082585087590092595097510001025105010751100Plan: NDBi-036 Rev E.0 0 2250 True Vertical Depth0 2250 4500 6750 9000 11250 13500 Vertical Section at 290.00° 20" Conductor Casing 13-3/8" Surface Casing 9-5/8" Intermediate Liner 7" Intermediate Liner 4-1/2" Production Liner 0 28 55 Centre to Centre Separation0 275 550 825 1100 1375 1650 1925 Measured Depth Equivalent Magnetic Distance DDI 7.472 SURVEY PROGRAM Date: 2021-02-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 47.0 800.0 Plan: NDB-031 Rev E.1 (NDB-031)SDI_URSA1_I4 800.0 2780.0 Plan: NDB-031 Rev E.1 (NDB-031)3_MWD+IFR2+MS+Sag 2780.0 12000.0 Plan: NDB-031 Rev E.1 (NDB-031)3_MWD+IFR2+MS+Sag 12000.0 18710.0 Plan: NDB-031 Rev E.1 (NDB-031)3_MWD+IFR2+MS+Sag 18710.0 24427.2 Plan: NDB-031 Rev E.1 (NDB-031)3_MWD+IFR2+MS+Sag Surface Location North / 5972504.54 East / 1562167.50 Elevation / 22.8 CASING DETAILS TVD MD Name 128.0 128.020" Conductor Casing 2395.8 2780.013-3/8" Surface Casing 3325.1 12000.09-5/8" Intermediate Liner 4114.7 18710.0 7" Intermediate Liner 4103.8 24427.04-1/2" Production Liner Mag Model & Date: BGGM2024 30-Jun-25 Magnetic North is 13.69° East of True North (Magnetic De Mag Dip & Field Strength: 80.53° 57120.44955 FORMATION TOP DETAILS TVDPath Formation 1043.8 Upper SB 1392.8 BP Transition 1733.8 Middle SB 2145.8 MCU 2449.8 Tuluvak Shale 2512.8 Tuluvak Sand 2844.8 TS_790 3263.8 Seabee 3851.8 Nanushuk 3942.8 NT7 MFS 3983.8 NT6 MFS 4009.8 NT8 MFS 4024.8 NT5 MFS 4057.8 NT4 MFS 4094.8 NT3 MFS 4124.8NT3.2 Top Reservoir By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by BHI DE Accepted by BHI PSD Approved by Santos DE Parker 272 @ 69.8usft -10000-8000-6000-4000-20000South(-)/North(+)-16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0West(-)/East(+)NDB-031 Toe Rev 0.0NDB-031 Heel Rev 0.095%20" Conductor Casing13-3/8" Surface Casing9-5/8" Intermediate Liner7" Intermediate Liner4-1/2" Production LinerPlan: NDB-031 Rev E.1Plan: NDB-031 Rev E.19:21, March 24 2025 -15000150030004500True Vertical Depth-2000 0 2000 4000 6000 8000 10000 12000 14000 16000Vertical Section at 290.00°20" Conductor Casing13-3/8" Surface Casing9-5/8" Intermediate Liner7" Intermediate Liner4-1/2" Production Liner1000200030004000500060007000800090001000011000120001300014000150001600017000180001900020000 21000 22000 23000 24000 24427 0°30°60°85°90°90 ° Plan: NDB-031 Rev E.1 Upper Schrader BluffBase Permafrost TransitionMiddle Schrader BluffMCUTuluvak ShaleTuluvak SandTS_790SeabeeNanushukNT7 MFSNT6 MFSNT5 MFSNT4 MFSNT3 MFSNT3.2 Top ReservoirPlan: NDB-031 Rev E.19:17, March 24 2025 24 March, 2025 Anticollision Summary Report Santos Pikka NDB B-31 NDB-031 Plan: NDB-031 Rev E.1 Santos Ltd Anticollision Summary Report Well B-31 - Slot B-31Local Co-ordinate Reference:SantosCompany: Parker 272 @ 69.8usftTVD Reference:PikkaProject: Parker 272 @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-31Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-031 Database:EDM Offset DatumReference Design:Plan: NDB-031 Rev E.1 Offset TVD Reference: Interpolation Method: Depth Range: Reference Error Model: Scan Method: Error Surface: Filter type: ISCWSA Closest Approach 3D Combined Pedal Curve NO GLOBAL FILTER: Using user defined selection & filtering criteria MD Interval 25.0usft Unlimited Maximum centre distance of 2,468.9usft Plan: NDB-031 Rev E.1 Results Limited by: SigmaWarning Levels Evaluated at:2.79 ISCWSA TESTCasing Method: From (usft) Survey Tool Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 24/03/2025 SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISCWSA Rev 4)47.0 800.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag800.0 2,780.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag2,780.0 12,000.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag12,000.0 18,710.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag18,710.0 24,427.2 Plan: NDB-031 Rev E.1 (NDB-031) Offset Well - Wellbore - Design Reference Measured Depth (usft) Offset Measured Depth (usft) Between Centres (usft) Between Ellipses (usft) Separation Factor Warning Summary Site Name Distance NDB CCB-11 - NDB-011 - Plan: NDB-011 Rev D.2 325.0 325.0 399.9 391.0 83.300 ESB-11 - NDB-011 - Plan: NDB-011 Rev D.2 350.0 350.1 399.9 391.0 82.849 SFB-11 - NDB-011 - Plan: NDB-011 Rev D.2 10,775.0 14,057.7 1,110.7 1,007.9 13.798 CCB-14 - NDBi-014 - NDBi-014 366.5 368.1 339.5 330.6 69.417 ESB-14 - NDBi-014 - NDBi-014 375.0 376.7 339.5 330.6 69.285 SFB-14 - NDBi-014 - NDBi-014 7,250.0 7,800.9 1,596.8 1,421.0 11.504 CCB-19 - NDBi-019 - Plan: NDBi-019 Rev A.0 1,729.4 1,827.4 167.6 146.2 11.203 ESB-19 - NDBi-019 - Plan: NDBi-019 Rev A.0 1,775.0 1,873.1 168.0 145.7 10.696 SFB-19 - NDBi-019 - Plan: NDBi-019 Rev A.0 11,900.0 11,747.9 2,118.6 1,755.4 7.336 CCB-20 - NDBi-020 - Plan: NDBi-020 Rev A.0 325.0 325.2 219.3 210.2 44.516 ESB-20 - NDBi-020 - Plan: NDBi-020 Rev A.0 350.0 350.2 219.3 210.2 44.093 SFB-20 - NDBi-020 - Plan: NDBi-020 Rev A.0 725.0 720.5 242.1 231.6 39.808 CCB-21 - NDB-021 - Plan:NDB-021 Rev A.0 1,655.8 1,732.0 150.4 132.2 12.182 ESB-21 - NDB-021 - Plan:NDB-021 Rev A.0 1,675.0 1,751.4 150.5 132.0 11.968 SFB-21 - NDB-021 - Plan:NDB-021 Rev A.0 11,900.0 11,787.6 1,641.4 1,256.6 5.360 CCB-22 - NDB-022 - Plan NDB-022 Rev A.0 325.0 325.2 179.2 170.1 36.056 ESB-22 - NDB-022 - Plan NDB-022 Rev A.0 350.0 350.2 179.2 170.0 35.697 SFB-22 - NDB-022 - Plan NDB-022 Rev A.0 700.0 697.5 199.1 188.6 32.790 CCB-23 - NDB-023 - NDB-023 Rev12 325.0 325.2 159.1 150.3 33.119 ESB-23 - NDB-023 - NDB-023 Rev12 350.0 350.2 159.1 150.3 32.945 SFB-23 - NDB-023 - NDB-023 Rev12 575.0 574.9 165.8 156.5 32.146 CCB-24 - NDB-024 - NDB-024 189.1 188.8 140.0 131.4 29.546 ESB-24 - NDB-024 - NDB-024 350.0 349.5 140.2 131.3 28.216 SFB-24 - NDB-024 - NDB-024 475.0 472.6 143.2 134.1 27.546 CCB-24 - NDB-024PB1 - NDB-024PB1 189.1 188.8 140.0 131.2 29.512 ESB-24 - NDB-024PB1 - NDB-024PB1 350.0 349.5 140.2 131.1 28.184 SFB-24 - NDB-024PB1 - NDB-024PB1 475.0 472.6 143.2 133.9 27.515 CCB-25 - NDB-025 - NDB-025 368.4 368.8 118.9 110.0 24.281 ESB-25 - NDB-025 - NDB-025 375.0 375.4 118.9 110.0 24.245 SFB-25 - NDB-025 - NDB-025 3,075.0 3,231.0 243.9 199.5 7.218 CCB-25 - NDB-025 - Plan: NDB-25 Rev E.2 325.0 324.7 119.7 110.9 24.605 ESB-25 - NDB-025 - Plan: NDB-25 Rev E.2 350.0 349.7 119.7 110.9 24.473 SFB-25 - NDB-025 - Plan: NDB-25 Rev E.2 3,900.0 4,007.7 417.1 320.6 5.515 CCB-26 - NDBi-026 - Plan: NDBi-026 Rev A.0 325.0 325.0 99.8 90.8 19.879 ESB-26 - NDBi-026 - Plan: NDBi-026 Rev A.0 350.0 350.0 99.8 90.7 19.681 SFB-26 - NDBi-026 - Plan: NDBi-026 Rev A.0 500.0 499.2 103.2 93.6 18.959 CCB-27 - NDB-027 - Plan: NDB-027 Rev B.0 325.0 325.2 79.1 70.3 16.102 ESB-27 - NDB-027 - Plan: NDB-027 Rev B.0 350.0 350.2 79.1 70.2 16.027 24/03/2025 09:06:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 2 Santos Ltd Anticollision Summary Report Well B-31 - Slot B-31Local Co-ordinate Reference:SantosCompany: Parker 272 @ 69.8usftTVD Reference:PikkaProject: Parker 272 @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-31Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-031 Database:EDM Offset DatumReference Design:Plan: NDB-031 Rev E.1 Offset TVD Reference: Offset Well - Wellbore - Design Reference Measured Depth (usft) Offset Measured Depth (usft) Between Centres (usft) Between Ellipses (usft) Separation Factor Warning Summary Site Name Distance NDB SFB-27 - NDB-027 - Plan: NDB-027 Rev B.0 425.0 425.1 79.9 70.9 15.921 CCB-28 - NDBi-028 - Plan NDBi-028 Rev A.0 1,364.3 1,379.5 39.5 24.2 3.762 ESB-28 - NDBi-028 - Plan NDBi-028 Rev A.0 1,375.0 1,390.0 39.5 24.1 3.740 SFB-28 - NDBi-028 - Plan NDBi-028 Rev A.0 13,150.0 13,007.7 1,152.9 751.3 3.603 CCB-29 - NDB-029 - NDB-29 Rev12 325.0 325.2 39.0 30.1 7.725 ESB-29 - NDB-029 - NDB-29 Rev12 350.0 350.2 39.0 30.1 7.683 SFB-29 - NDB-029 - NDB-29 Rev12 375.0 375.2 39.1 30.2 7.657 B-30 - NDBi-030 - NDBi-030 47.0 46.4 19.8 SFB-30 - NDBi-030 - NDBi-030 125.0 124.4 19.8 10.7 3.707 CC, ES, SFB-32 - NDB-032 - NDB-032 563.1 562.8 15.3 5.8 2.441 CCB-33 - NDB-033 - Plan: NDB-033 Rev A.0 847.8 844.0 26.3 16.2 4.235 ESB-33 - NDB-033 - Plan: NDB-033 Rev A.0 850.0 846.1 26.3 16.2 4.232 Take Immediate Action, SB-33 - NDB-033 - Plan: NDB-033 Rev A.0 17,375.0 17,059.5 373.8 -18.1 1.193 CCB-34 - NDBi-034 - Plan: NDBi-034 Rev A.0 550.0 548.4 57.6 48.0 10.316 ESB-34 - NDBi-034 - Plan: NDBi-034 Rev A.0 551.1 549.5 57.6 48.0 10.309 SFB-34 - NDBi-034 - Plan: NDBi-034 Rev A.0 625.0 619.9 60.1 50.1 10.120 CC, ESB-35 - NDB-035 - NDB-035 Rev12 865.2 861.9 62.2 52.2 10.572 SFB-35 - NDB-035 - NDB-035 Rev12 900.0 895.9 62.6 52.6 10.512 CCB-36 - NDBi-036 - Plan: NDBi-036 Rev E.0 348.0 348.0 100.2 91.3 20.403 ESB-36 - NDBi-036 - Plan: NDBi-036 Rev E.0 400.0 398.6 100.2 91.2 20.163 SFB-36 - NDBi-036 - Plan: NDBi-036 Rev E.0 11,025.0 10,913.8 701.1 327.1 2.352 CCB-37 - NDB-037 - NDB-037 225.0 224.6 120.2 111.4 25.199 ESB-37 - NDB-037 - NDB-037 275.0 274.5 120.2 111.4 25.024 SFB-37 - NDB-037 - NDB-037 675.0 663.3 124.9 115.4 23.148 CC, ESB-38 - NDBi-038 - Plan: NDBi-038 Rev A.0 755.6 741.8 131.6 121.9 23.914 Normal Operations, SFB-38 - NDBi-038 - Plan: NDBi-038 Rev A.0 18,600.0 17,440.2 558.8 135.8 1.655 CCB-39 - NDB-039 - Plan: NDB-039 Rev A.0 621.2 613.5 154.7 144.6 26.801 ESB-39 - NDB-039 - Plan: NDB-039 Rev A.0 625.0 617.0 154.7 144.6 26.743 SFB-39 - NDB-039 - Plan: NDB-039 Rev A.0 750.0 729.4 159.7 149.1 25.810 CC, ESB-40 - NDB-040 - Plan: NDB-040 Rev C.1 346.8 346.8 180.3 171.4 37.113 SFB-40 - NDB-040 - Plan: NDB-040 Rev C.1 10,325.0 9,899.4 1,284.5 930.9 4.566 CC, ESB-41 - NDBi-041 - Plan: NDBi-041 Rev A.0 637.1 626.4 193.9 184.3 36.263 SFB-41 - NDBi-041 - Plan: NDBi-041 Rev A.0 800.0 769.7 201.0 191.0 34.952 CC, ESB-42 - NDB-042 - NDB-042 Rev12 1,021.3 1,000.0 179.0 168.5 29.280 SFB-42 - NDB-042 - NDB-042 Rev12 1,025.0 1,000.0 179.0 168.6 29.248 CC, ESB-43 - NDBi-043 - NDBi-043 1,000.0 966.3 201.9 191.2 31.890 SFB-43 - NDBi-043 - NDBi-043 3,075.0 2,866.5 352.4 308.5 10.576 CC, ESB-43 - NDBi-043A - NDBi-043A 1,000.0 966.3 201.9 191.2 31.890 SFB-43 - NDBi-043A - NDBi-043A 3,075.0 2,866.5 352.4 308.5 10.576 CC, ESB-44 - NDBi-044 - NDBi-044 752.6 734.3 254.6 244.8 45.832 SFB-44 - NDBi-044 - NDBi-044 5,225.0 4,133.2 2,466.6 2,369.2 32.472 Caution - Monitor Closely,B-45 - NDB-045 - Plan: NDB-045 Rev A.0 18,550.0 18,255.6 118.7 5.2 1.312 Caution - Monitor Closely,B-45 - NDB-045 - Plan: NDB-045 Rev A.0 18,678.9 18,139.4 112.5 15.5 1.458 B-46 - NDBi-046 - NDBi-046 47.0 46.8 300.1 SFB-46 - NDBi-046 - NDBi-046 12,100.0 17,680.0 784.5 621.7 6.091 B-46 - NDBi-046 L1 - NDBi-046 L1 47.0 46.8 300.1 SFB-46 - NDBi-046 L1 - NDBi-046 L1 12,900.0 17,541.8 1,058.9 922.2 9.820 CC, ESB-47 - NDB-047 - NDB-047 Rev12 947.2 900.0 299.9 289.7 51.427 SFB-47 - NDB-047 - NDB-047 Rev12 1,175.0 1,082.2 311.9 300.9 47.973 CCB-48 - NDB-048 - NDB-048 486.1 474.1 340.0 330.9 67.992 ESB-48 - NDB-048 - NDB-048 500.0 486.1 340.1 330.9 67.721 SFB-48 - NDB-048 - NDB-048 14,550.0 18,657.2 843.5 699.5 7.416 CC, ESB-50 - NDBi-050 - NDBi-050 52.0 51.8 380.2 371.1 81.518 SFB-50 - NDBi-050 - NDBi-050 16,125.0 19,453.2 615.9 496.0 6.547 Wildcat Take Immediate Action, CQugruk-8 - Qugruk-8 - Qugruk-8 15,585.5 3,574.0 311.6 -35.3 1.124 24/03/2025 09:06:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 3 Santos Ltd Anticollision Summary Report Well B-31 - Slot B-31Local Co-ordinate Reference:SantosCompany: Parker 272 @ 69.8usftTVD Reference:PikkaProject: Parker 272 @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-31Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-031 Database:EDM Offset DatumReference Design:Plan: NDB-031 Rev E.1 Offset TVD Reference: 0 600 1200 1800 2400 Centre to Centre Separation0 4000 8000 12000 16000 20000 24000 Measured Depth Ladder Plot B-11, NDB-011, Plan: NDB-011 Rev D.2 V0 B-14, NDBi-014, NDBi-014 V0 B-19, NDBi-019, Plan: NDBi-019 Rev A.0 V0 B-20, NDBi-020, Plan: NDBi-020 Rev A.0 V0 B-21, NDB-021, Plan:NDB-021 Rev A.0 V0 B-22, NDB-022, Plan NDB-022 Rev A.0 V0 B-23, NDB-023, NDB-023 Rev12 V0 B-24, NDB-024, NDB-024 V0 B-24, NDB-024PB1, NDB-024PB1 V0 B-25, NDB-025, NDB-025 V0 B-25, NDB-025, Plan: NDB-25 Rev E.2 V0 B-26, NDBi-026, Plan: NDBi-026 Rev A.0 V0 B-27, NDB-027, Plan: NDB-027 Rev B.0 V0 B-28, NDBi-028, Plan NDBi-028 Rev A.0 V0 B-29, NDB-029, NDB-29 Rev12 V0 B-30, NDBi-030, NDBi-030 V0 B-32, NDB-032, NDB-032 V0 B-33, NDB-033, Plan: NDB-033 Rev A.0 V0 B-34, NDBi-034, Plan: NDBi-034 Rev A.0 V0 B-35, NDB-035, NDB-035 Rev12 V0 B-36, NDBi-036, Plan: NDBi-036 Rev E.0 V0 B-37, NDB-037, NDB-037 V0 B-38, NDBi-038, Plan: NDBi-038 Rev A.0 V0 B-39, NDB-039, Plan: NDB-039 Rev A.0 V0 B-40, NDB-040, Plan: NDB-040 Rev C.1 V0 B-41, NDBi-041, Plan: NDBi-041 Rev A.0 V0 B-42, NDB-042, NDB-042 Rev12 V0 B-43, NDBi-043, NDBi-043 V0 B-43, NDBi-043A, NDBi-043A V0 B-44, NDBi-044, NDBi-044 V0 B-45, NDB-045, Plan: NDB-045 Rev A.0 V0 B-46, NDBi-046, NDBi-046 V0 B-46, NDBi-046 L1, NDBi-046 L1 V0 B-47, NDB-047, NDB-047 Rev12 V0 B-48, NDB-048, NDB-048 V0 B-50, NDBi-050, NDBi-050 V0 Qugruk-8, Qugruk-8, Qugruk-8 V0 L E G E N D Coordinates are relative to: B-31 - Slot B-31 Coordinate System is US State Plane 1983, Alaska Zone 4 Grid Convergence at Surface is: -0.60°Central Meridian is 150° 0' 0.000 W Offset Depths are relative to Offset Datum Reference Depths are relative to Parker 272 @ 69.8usft 24/03/2025 09:06:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 4 Santos Ltd Anticollision Summary Report Well B-31 - Slot B-31Local Co-ordinate Reference:SantosCompany: Parker 272 @ 69.8usftTVD Reference:PikkaProject: Parker 272 @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-31Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-031 Database:EDM Offset DatumReference Design:Plan: NDB-031 Rev E.1 Offset TVD Reference: 0.00 3.00 6.00 9.00 Separation Factor0 4500 9000 13500 18000 22500 Measured Depth Stop Drilling Caution - Monitor Closely Normal Operations Separation Factor Plot B-11, NDB-011, Plan: NDB-011 Rev D.2 V0 B-14, NDBi-014, NDBi-014 V0 B-19, NDBi-019, Plan: NDBi-019 Rev A.0 V0 B-20, NDBi-020, Plan: NDBi-020 Rev A.0 V0 B-21, NDB-021, Plan:NDB-021 Rev A.0 V0 B-22, NDB-022, Plan NDB-022 Rev A.0 V0 B-23, NDB-023, NDB-023 Rev12 V0 B-24, NDB-024, NDB-024 V0 B-24, NDB-024PB1, NDB-024PB1 V0 B-25, NDB-025, NDB-025 V0 B-25, NDB-025, Plan: NDB-25 Rev E.2 V0 B-26, NDBi-026, Plan: NDBi-026 Rev A.0 V0 B-27, NDB-027, Plan: NDB-027 Rev B.0 V0 B-28, NDBi-028, Plan NDBi-028 Rev A.0 V0 B-29, NDB-029, NDB-29 Rev12 V0 B-30, NDBi-030, NDBi-030 V0 B-32, NDB-032, NDB-032 V0 B-33, NDB-033, Plan: NDB-033 Rev A.0 V0 B-34, NDBi-034, Plan: NDBi-034 Rev A.0 V0 B-35, NDB-035, NDB-035 Rev12 V0 B-36, NDBi-036, Plan: NDBi-036 Rev E.0 V0 B-37, NDB-037, NDB-037 V0 B-38, NDBi-038, Plan: NDBi-038 Rev A.0 V0 B-39, NDB-039, Plan: NDB-039 Rev A.0 V0 B-40, NDB-040, Plan: NDB-040 Rev C.1 V0 B-41, NDBi-041, Plan: NDBi-041 Rev A.0 V0 B-42, NDB-042, NDB-042 Rev12 V0 B-43, NDBi-043, NDBi-043 V0 B-43, NDBi-043A, NDBi-043A V0 B-44, NDBi-044, NDBi-044 V0 B-45, NDB-045, Plan: NDB-045 Rev A.0 V0 B-46, NDBi-046, NDBi-046 V0 B-46, NDBi-046 L1, NDBi-046 L1 V0 B-47, NDB-047, NDB-047 Rev12 V0 B-48, NDB-048, NDB-048 V0 B-50, NDBi-050, NDBi-050 V0 Qugruk-8, Qugruk-8, Qugruk-8 V0 L E G E N D Coordinates are relative to: B-31 - Slot B-31 Coordinate System is US State Plane 1983, Alaska Zone 4 Grid Convergence at Surface is: -0.60°Central Meridian is 150° 0' 0.000 W Offset Depths are relative to Offset Datum Reference Depths are relative to Parker 272 @ 69.8usft 24/03/2025 09:06:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 5 Northing (5000 usft/in)Easting (5000 usft/in)Northing (5000 usft/in)Easting (5000 usft/in)Plan: NDB-011 Rev D.2NDBi-014Plan: NDBi-019 Rev A.0Plan: NDBi-020 Rev A.0Plan:NDB-021 Rev A.0Plan NDB-022 Rev A.0NDB-023 Rev12NDB-024NDB-024PB1NDB-025Plan: NDBi-026 Rev A.0Plan: NDB-027 Rev B.0Plan NDBi-028 Rev A.0NDB-29 Rev12NDBi-030NDB-032Plan: NDB-033 Rev A.0Plan: NDBi-034 Rev A.0NDB-035 Rev12Plan: NDBi-036 Rev E.0NDB-037Plan: NDBi-038 Rev A.0Plan: NDB-039 Rev A.0Plan: NDB-040 Rev C.1Plan: NDBi-041 Rev A.0NDB-042 Rev12NDBi-043NDBi-043ANDBi-044Plan: NDB-045 Rev A.0NDBi-046NDBi-046 L1NDB-047 Rev12NDB-048NDBi-050Qugruk-8Plan: NDB-031 Rev E.1NDANDBNPF9:09, March 24 2025 Plan:NDBͲ031RevE.1ACFlipbookSURVEY PROGRAMDepth From Depth To Tool47.0 800.0 SDI_URSA1_I4800.0 2780.0 3_MWD+IFR2+MS+Sag2780.0 12000.0 3_MWD+IFR2+MS+Sag12000.0 18710.0 3_MWD+IFR2+MS+Sag18710.0 24427.2 3_MWD+IFR2+MS+SagCASING DETAILSTVD MD Name128.0 128.0 20" Conductor Casing2395.8 2780.013-3/8" Surface Casing3325.1 12000.09-5/8" Intermediate Liner4114.7 18710.0 7" Intermediate Liner4103.8 24427.04-1/2" Production Liner1515303045456060757590900901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [30 usft/in]475176101126151176201226251276301326351375400425450475499524548573597622646670694717741765788811833856NDBi-030475075100125150175200225250275300325350375400425450475500525550575600625649674698723747771795818842865888911934956NDB-032475075100125150175200225250275300325350374399423447472496520Plan: NDBi-026 Rev A.0475075100125150175200225250275300325350374399423448472496521545569593616640664687Plan: NDB-027 Rev B.07075100125150175200225250275300325350374399424448473498522547571596621645670694719744768793818843867892917941966991101610411065109011151140116411891213123712621286131113351360138514091434145914841508153315581583160816331658168317091734175917841810183518611886191219371963Plan NDBi-028 Rev A.0475075100125150175200225250275300325350375399424449473498523547572597621646670694719743767791815839863887910934957NDB-29 Rev12707510012515017520022525027530032535037540042645147650152755257760262765267870372875377880482985487990492995598010051030105510801105112911541180120512311256128213071333135813841410143614621487151315391565159116171643166916961722Plan: NDB-033 Rev A.0475075100125150175200225250275300325350375401426451477502527552576601626650674698722746770793816Plan: NDBi-034 Rev A.0475075100125150175200225250275300325350375401426452477503528554579604629655680705730755780804829854878902927951975999NDB-035 Rev12475075100125150175200225250275300325350376401427453478504530555581606632658683709735760786811837863888914940965Plan: NDBi-036 Rev E.047 500500 10001000 15001500 20002000 25002500 30003000 50005000 80008000 1200012000 1300013000 1400014000 1500015000 1600016000 20700From Colour To MD47.0To24427.2MD Azi TFace47.0 0.00 0.00347.0 204.00204.00996.9 204.00204.001151.9 204.00 0.002728.5 235.08 37.022828.5 235.08 0.003677.9 235.16 0.1916047.0 235.16 0.0018711.6 329.39101.4619042.7 329.39 0.0024427.2 329.39 0.00 0 30 60 Centre to Centre Separation0 450 900 1350 1800 2250 Partial Measured DepthNDBi-030NDB-032Equivalent Magnetic Distance Plan: NDB-031 Rev E.1 Ladder View 0 150 300 Centre to Centre Separation0 3500 7000 10500 14000 17500 21000 Measured DepthNDB-024NDB-024PB1NDB-025NDBi-030NDB-032NDB-037NDBi-043NDBi-043ANDBi-044NDBi-046NDBi-046 L1Qugruk-8Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 47.0 800.0 Plan: NDB-031 Rev E.1 (NDB-031) SDI_URSA1_I4 800.0 2780.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag 2780.0 12000.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag 12000.0 18710.0 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag 18710.0 24427.2 Plan: NDB-031 Rev E.1 (NDB-031) 3_MWD+IFR2+MS+Sag 9:27, March 24 2025 CASING DETAILS TVD MD Name 128.0 128.020" Conductor Casing 2395.8 2780.013-3/8" Surface Casing 3325.1 12000.09-5/8" Intermediate Liner 4114.7 18710.0 7" Intermediate Liner 4103.8 24427.04-1/2" Production Liner Attachment 3: BOPE Equipment 21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000# 21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#FORWARD 13-5/8" X 5,000#13-5/8" X 5,000#30"13-5/8" X 5,000#186"13-5/8" X 5,000#DUTCH LOCK DOWN ChokeLinefromBOPPressureGauge1502PressureSensorPressureTransducerBill ofMaterialItemDescriptionToPanicLineItemDescriptionA3Ͳ1/8”– 5,000psi W.P.RemoteHydraulicOperatedChokeB3Ͳ1/8”–5,000psiW.P.AdjustableManualChoke1–14 3Ͳ1/8”– 5,000psi W.P.ManualGateValve1521/16”5 000 i WP152Ͳ1/16”–5,000psiW.P.ManualGateValveToMudGasLegendBlindSpareToTigerTankSeparatorValveNormally OpenValveNormally Closed Attachment 4: Drilling Hazards 16” 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. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Anti-Collision Closely monitor real-time surveys and run GWD in BHA 12-1/4” and 8-1/2” Intermediate Hole Sections Hazard Mitigations Lost Returns Optimal drillpipe sizing. MPD to be used to manage ECD loads (8- 1/2” hole only). Monitor ECD with MWD tools. Pump LCM as required (consult prepared lost returns decisions tree). Slow pump rates, reduce ROP / trip speed when necessary. ECD modelling for cement jobs. Challenging liner runs The Intermediate liner runs requires relatively low OH friction factor to run to TD (hole cleaning and lubricants). Ability to rotate while RIH to overcome drag. Washouts/Hole Enlargement Drill with oil-based mud, maintain mud in specifications, use sufficient mud weight / back-pressure to hold back formations. Tight Hole/Stuck Pipe Hole cleaning and tripping practices, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Hole Cleaning in 85° Sail Conduct T&D and hydraulics modeling, control ROP limits based on cuttings returns and comparison to the models. Pack Off During Cementing Proper wellbore cleanup procedure prior to running in hole. Stage circulation rates up while running in hole with liner. Circulate bottoms up at multiple depths to condition mud the way in the hole. Circulate at TD to planned cementing rates and ensure hole is clean. Wireline Inaccessibility The sail angle on this section is too high for wireline to be run conventionally. If wireline logs are required for operations a tractor will be required. Operational complexity with Mechanical two stage cement equipment (9-5/8” Liner) The 2 nd stage of the cement job will be conducted through a mechanically shifted sleeve. This will require the LTP to not be set until the 2nd stage is pumped giving a higher complexity leading to complications with setting the LTP. 6-1/8” Production Hole Section Hazard Mitigations Lost Returns MPD to be used to control ECD loading. 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. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Wellbore Instability Maintain adequate mud weight / back-pressure for wellbore stability. Monitor cuttings returns, LWD logs, and drilling parameters for signs of washout. MPD to minimize pressure cycles on formation. * Note that no H2S has been encountered on nearby offset wells, and H2S is not anticipated in this well. Attachment 5A: Leak Off Test Procedure (Conventional) 1. Drill out shoe track, cement plus minimum of 20’ of new formation. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight-in is equal to mud weight-out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe. 4. Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above expected test pressure. a. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string. 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 0.50bbl/min (or as low as possible). Record pump pressures at 0.25bbl increments (~2 stokes). 8. Record and plot the volume pumped against pressure until leak-off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak-off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in-situ stress. c. If FIT skip step 9. 9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 11. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to establish the volume of mud lost to the formation. Top up and close the annulus valve between the casing and the previous casing string. 13. Open the BOP. Attachment 5B: Leak Off Test Procedure (With MPD) 1. Drill out shoe track and cement. Install MPD Bearing Assembly and drill a minimum of 20’ of new formation, holding required EMW using the MPD choke manifold. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight-in is equal to mud weight-out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe, continuing to hold required EMW using the MPD choke. 4. Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above expected test pressure. a. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string with the MPD chokes closed (i.e. well shut-in). 6. Starting at the MPD set-point pressure (back pressure needed for required baseline EMW), perform the LOT or FIT pumping at a constant rate of 0.50bbl/min (or as low as possible). Record pump pressures at 0.25bbl increments (~2 stokes). 7. Record and plot the volume pumped against pressure until leak-off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak-off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in-situ stress. c. If FIT skip step 9. 8. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 9. 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. 10. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 11. Bleed off pressure (through MPD choke) down to the starting MPD set-point pressure and record the volume returned to establish the volume of mud lost to the formation. Attachment 6: Cement Summary Surface Casing Cement Casing Size 13-3/8” 68# L-80 BTC/TXP-BTC Surface Casing Basis Lead Open hole volume + 150% excess in permafrost / 50% excess below permafrost Lead TOC Surface Tail Open hole volume + 50% excess + 65 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 10.5 ppg Tuned Spacer Lead 11.0ppg Lead: 354 bbls, 1986 cuft, 784 sks ArcticCem, Yield: 2.53 cuft/sk Tail 15.3ppg Tail: 66 bbls, 370 cuft, 299 sks HalCem Type I/II – 1.24 cuft/sk Temp BHST 61° F (2.25°/100’ TVD below PermaFrost) Verification Method Cement returns to surface Notes Job will be mixed on the fly NDB-031 13-3/8" SURFACE CEMENT JOB Description TOP BOTTOM LENGTH CAPACITY VOLUME SHOE TRACK LENGTH 2715 2780 65 0.14973 9.7 TAIL LENGTH 2280 2780 500 0.07491 37.5 TAIL EXCESS 50% 18.7 LEAD TOP TO BASE PERMAFROST 1418 2280 862 0.07491 64.6 EXCESS FACTOR FOR ABOVE 50% 32.3 PERMAFROST ANNULUS (Lead) 128 1418 1290 0.07491 96.6 EXCESS FACTOR FOR ABOVE 150% 144.9 CASED HOLE ANNULUS 46 128 82 0.18620 15.3 TOTAL LEAD VOLUME 353.7 TOTAL TAIL VOLUME 65.9 Verified cement volume -bjm Intermediate #1 Liner Cement Casing Size 9-5/8” 47# L-80 Hydril 563 Intermediate Liner #1 Basis Tail Open hole volume + excess + 85 ft shoe track Tail TOC Stage 1: 1000’ MD above the shoe Stage 2: Top of the 9-5/8” Liner Total Cement Volume Spacer ~80 bbls of 12.5 ppg Clean Spacer Tail Stage 1: 30% Open Hole Excess 15.3ppg Tail: 79 bbls, 442cuft, 357sks VersaCem Type I/II – 1.24 cuft/sk Stage 2: 100% Open Hole Excess 15.3ppg Tail: 363 bbls, 2037cuft, 1646sks VersaCem Type I/II – 1.24 cuft/sk Temp Stage 1 - BHST 80° F (2.25°/100’ TVD below PermaFrost) Stage 2 - BHST 71° F (2.25°/100’ TVD below PermaFrost) Notes Job will be mixed on the fly Verification Method -1stStage Cement Job will not be logged, assuming job parameters are as expected (no losses, good lift pressures, FIT / LOT results). -2nd Stage Cement Job will not be logged, assuming job parameters are as expected (no losses, good lift pressures, circulate cement off top of liner). Justification: -1ststage is only designed to provide adequate cement integrity around the shoe (i.e. Nanushuk will be isolated with 7” shoe) - Stage tool allows for precise placement of base cement column at base Tuluvak hydrocarbon. - Bond log not required for 2 nd Stage per Regulation 20 AAC 25.030(d)(5) -2nd Stage bond evaluation does not affect 1 st Stage bond evaluation and frac decision. -2nd Stage cement job will isolate Tuluvak with cement and a V0-rated LTP above it as a redundant means of isolation. - Well design allows for the OA annulus to be freeze protected by circulating in place (with Tieback) vs. bullheaded into place. With a sufficient initial LOT/FIT at the surface casing shoe, any potential Tuluvak pressures will be contained by the surface casing shoe and not cross flow into shallower formations. - Tuluvak isolation has been achieved on all historical Pikka development wells. - Seeking to simplify an already complicated operation, saving time/money. NDB-031 9.625" Intermediate Liner #1 – 1st Stage Description TOP BOTTOM LENGTH CAPACITY VOLUME SHOE TRACK LENGTH 11915 12000 85 0.07321 6.2 TAIL LENGTH 11000 12000 1000 0.05578 55.8 TAIL EXCESS 30% 16.7 TOTAL TAIL VOLUME 78.7 With a sufficient initial LOT/FIT at the surface casing shoe, any potential Tuluvak pressures will be contained by the surface casing shoe and not cross flow into shallower formations Verified cement volume. -bjm NDB-031 9.625" Intermediate Liner #1 - 2nd Stage Description TOP BOTTOM LENGTH CAPACITY VOLUME TAIL LENGTH 2780 5951 3171 0.05578 176.9 TAIL EXCESS 100% 176.9 LINER LAP 13-3/8" 68# x 9-5/8" 47# LNR 2630 2780 150 0.05974 9.0 TOTAL TAIL VOLUME 362.7 Intermediate #2 Liner Cement Casing Size 7” 26# L-80 Hydril 563 Intermediate Liner #2 Basis Lead Open hole volume + excess Lead TOC No Lead Planned Tail Open hole volume + 30% excess + 120 ft shoe track Tail TOC 100’ TVD above the top Nanushuk Total Cement Volume Spacer ~80 bbls of 12.5 ppg Clean Spacer Lead No Lead Planned Tail 15.3ppg Tail: 116 bbls, 649cuft, 524sks VersaCem Type I/II – 1.24 cuft/sk Temp BHST 99° F (2.25°/100’ TVD below PermaFrost) Notes Job will be mixed on the fly Verification Method - LWD Sonic will be used to log the cement job. Justification: - Future hydraulic fracture operations will only be done in the Nanushuk formation. Log verification of the cement job will verify proper isolation has been achieved for frac operations. NDB-031 7" Intermediate Liner #2 Description TOP BOTTOM LENGTH CAPACITY VOLUME SHOE TRACK LENGTH 18590 18710 120 0.03826 4.6 TAIL LENGTH 16900 18710 1810 0.04713 85.3 TAIL EXCESS 30% 25.6 TOTAL TAIL VOLUME 115.5 16600 2110 Plan for 150' TVD above top Nanushuk. -bjm See updated calculations based on additional cement in attached email. -bjm 99.4 Verified cement volume. -bjm 133.9 -bjm Attachment 7: Prognosed Formation Tops NDB-031 Prognosed Tops Formation MD (ft) TVD KB (ft) TVDss (ft) Pore Pressure (ppg) Upper Schrader Bluff 1052 1044 974 7.2 Permafrost Base Transition 1418 1393 1323 7.3 Middle Schrader Bluff 1801 1734 1664 7.6 MCU (Lower Schrader Bluff) 2344 2146 2076 7.8 Tuluvak Shale 2890 2450 2380 7.9 Tuluvak Sand 3034 2513 2443 10.2 TS 790 5901 2845 2775 9.4 Seabee 11222 3264 3194 9.1 Nanushuk 17443 3852 3782 9.0 NT8 MFS 17881 3943 3873 8.9 NT7 MFS 18073 3984 3914 8.9 NT6 MFS 18196 4010 3940 8.9 NT5 MFS 18267 4025 3955 8.9 NT4 MFS 18426 4058 3988 8.8 NT3 MFS 18608 4095 4025 8.8 Nanushuk 3.2 (NT3) 18767 4125 4055 8.8 Attachment 8: Well Schematic 16,600' MD - 7" TOC (150' TVD above Nanushuk) per Mark Staudinger email attached 4/16/25. -bjm Attachment 9: Formation Evaluation Program 16” Surface Hole LWD Gamma Ray Resistivity 12-1/4” Intermediate Hole #1 LWD Gamma Ray Resistivity 8-1/2” Intermediate Hole #2 LWD Gamma Ray Resistivity 6-1/8” Production Hole LWD Gamma Ray Resistivity Density Neutron Sonic (7” Liner Cement Evaluation Only) Mudlogging No mudlogging is planned for NDB-031 Attachment 10: Wellhead & Tree Diagram Attachment 11: Diverter Variance Request NDB Surface Hole Map View Attachment 12: Oil Search Alaska 21-day BOPE Test Schedule Waiver Approval Letter Attachment 13: Managed Pressure Drilling Managed Pressure Drilling (MPD) will be implemented on NDB-031 in both the Intermediate #2 and Production sections of the well. The MPD system will be provided by Beyond Energy Services and Technology with an integrated piping and choke manifold on the Parker 272 rig. The only MPD equipment located outside of the rig will be the nitrogen rack. The plan in the 8-1/2” x 9-7/8” Intermediate hole will be to drill with a reduced 9.5 – 10.5ppg mud weight and utilize MPD to trap back-pressure in order to manage ECD for losses as well as providing adequate pressures to maintain wellbore stability through the Seabee and Nanushuk formations. Weighted trip fluids will be utilized to maintain downhole pressures for the final trip out and running of the 7” liner without MPD. The plan in the 6-1/8” Production hole will be to drill with a reduced 9.0 – 10.0ppg mud weight with MPD utilized to trap back-pressure in order to manage ECD for losses as well as providing adequate pressures to maintain wellbore stability through the Nanushuk formations. Weighted trip fluids will be utilized to maintain downhole pressures for the final trip out and running of the 4-1/2” liner without MPD. At no point will the static wellbore fluid be underbalanced. See below for a schematic of the BOP/MPD stack with the choke flow diagram. At no point will the static wellbore fluid be underbalanced. 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 March 24, 2025 Mr. Stephen Lambe Senior Operations Manager – Drilling and Completions Santos P.O. Box 240927 Anchorage, Alaska 99524-0927 Re: Docket Number: OTH-25-010 Application for Waiver – Parker 272 BOPE Test Frequency Dear Mr. Lambe: By electronic mail dated February 7, 2025, Santos 1 requested a waiver from the Alaska Oil and Gas Conservation Commission’s (AOGCC) regulatory required blowout prevention equipment (BOPE) test frequency for Parker Rig 272, petitioning to test the BOPE on a 21-day test schedule. AOGCC grants approval for limited duration and scope. February 7, 2025, correspondence includes the following justification in support of approval of a 21-day BOPE test schedule: - Increasing complexity of the Pikka NDB well portfolio. - Drilling shallow formations at a high angle are problematic, particularly due to the time sensitive nature to the shales. - Parker Rig 272 BOPE is fully compliant with API STD 53, Fifth Edition, December 2018. - BOPE underwent a full recertification prior to spudding in June 2023 which is valid for up to 5 years. Santos also provided details about the scope and BOPE performance achievements under its Between Well Maintenance (BWM) Program for Parker Rig 272.2 Included in the BWM Program are training objectives directed at personnel who work on and maintain Parker Rig 272 well control equipment, personnel who are responsible for well control equipment serviceability, and personnel in supervisory roles. The BWM training material is in accordance with the Original Equipment Manufacturers (OEM) recommended maintenance practices, and focuses on establishing BWM 1 Oil Search Alaska LLC is a subsidiary of Santos and designated operator for the Pikka Unit. 2 Parker 272 BOPE performance test data for 2024 shows the BWM has resulted in improved first-time pass rate and reduced overall number of component failures during BOPE testing through implementation of the Santos BWM recommended practice. Docket Number: OTH-25-010 Oil Search – 21-day BOPE Test Interval March 24, 2025 frequencies, visual inspections and service of all components within the well control system prior to BOPE testing. AOGCC acknowledges the challenging drilling programs that have been initiated at Pikka to target resources while maintaining a small environmental footprint, and the commitment to use a robust drilling rig and rig crews to perform those projects in a safe and efficient manner. In support of proactive efforts that increase safety, reliability, and longevity of critically important well control equipment, Santos was given conditional approved of a 21-day BOPE test interval for drilling Pikka well NDB-050 (PTD 2241540)3. Taking into consideration the challenges noted by Santos, past BOPE test results, and the commitment by Santos to implement their BWM program recommended practice, the AOGCC approves a variance from the regulatory requirements of 20 AAC 25.035(e)(10)(A) with the following conditions: - This variance is approved for the duration of primary development drilling program on the Pikka Field NDB pad with Parker Rig 272. - Santos must continue to implement the BWM program as outlined in its March 2024 document “Recommended Practice: BOPE Between Wells Maintenance”. - Development drilling wells only are included in this approval. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - Santos is encouraged to take advantage of opportunities to test. Unless otherwise approved by AOGCC, BOPE must be tested before reentering the well if a trip to surface occurs within 7 days of the due date. - Parker Rig 272 must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. - 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to witness. 3 Email from Santos 2/19/2025 requested interim approval of 21-day BOPE test interval; approved by email response on 2/25/2025. Docket Number: OTH-25-010 Oil Search – 21-day BOPE Test Interval March 24, 2025 The AOGCC reserves the right to rescind this approval and return to the 14-day BOPE test standard in 20 AAC 25.035(e)(10)(A). Please contact Jim Regg at (907) 793-1236 if you have any questions regarding this approval. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Bryan McLellan (email) AOGCC Inspectors (email) Phoebe Brooks (email) Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.24 14:42:53 -08'00' Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.03.26 03:13:07 -08'00' NDB-CISUV-000025 1 McLellan, Bryan J (OGC) From:Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent:Tuesday, April 15, 2025 3:47 PM To:McLellan, Bryan J (OGC) Subject:RE: NDB-031 10-401 PTD Application Hi Bryan, Welcome back from vacation. Just following up on the PTD request for NDB-031, and specifically if any questions have come up on the diverter waiver request? Also, in an effort to standardize our LOT/FIT values, I would like to request to change the planned FIT value at the 13-3/8” shoe from 15 ppg to 14 ppg. This value still gives us plenty of room for kick tolerance and ECD management. Please reference Section 4. Drilling Hazards Information on the PTD application. Let me know if you have any questions or concerns with the above request. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twi Ʃer From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, April 7, 2025 10:31 AM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: ![EXT]: RE: NDB-031 10-401 PTD Application Mark, Thanks for the notice. We’ll evaluate this request shortly. Thanks Again and Be Well, Steve Davies AOGCC From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Monday, April 7, 2025 10:04 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: NDB-031 10-401 PTD Application 2 Steve / Andy, I just wanted to give you guys a heads up that this PTD application for NDB-031does have a Diverter Waiver request. I spoke with Bryan, and since he is out until next Monday, he mentioned that I should let you guys know so you could start looking at it this week. If you have any questions, please don’t hesitate to reach out, as we’d like to try and work out any questions/issues up front. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twi Ʃer From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Thursday, March 27, 2025 4:10 PM To: Davis, Rachel (Rachel) <Rachel.Davis@santos.com > Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Subject: ![EXT]: RE: NDB-031 10-401 PTD Application Hello, This application has been received for processing. Thank you, GGrace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 conƱdential 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 Ʊrst saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Sent: Thursday, March 27, 2025 12:55 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Subject: NDB-031 10-401 PTD Application 3 Hello, Please see attached the NDB-031 10-401 PTD Application for review/approval. Thank you, Rachel Davis Technical Assistant t:1 (907) 375-4678 | e: rachel.davis@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy.Please consider the environment before printing this email CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 1 McLellan, Bryan J (OGC) From:Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent:Wednesday, April 16, 2025 2:47 PM To:McLellan, Bryan J (OGC) Cc:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Wallace, Chris D (OGC) Subject:RE: NDB-031 PTD 7" liner cement Bryan, I’ve adjusted the cement calcs for NDB-031 7” Liner as per your request. See below for more detailed information (schematic update and cement calcs): CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Intermediate #2 Liner Cement Casing Size 7” 26# L-80 Hydril 563 Intermediate Liner #2 Basis Lead Open hole volume + excess Lead TOC No Lead Planned Tail Open hole volume + 30% excess + 120 ft shoe track Tail TOC 150’ TVD above the top Nanushuk Spacer ~80 bbls of 12.5 ppg Clean Spacer 3 Total Cement Volume Lead No Lead Planned Tail 15.3ppg Tail: 134 bbls, 752cuft, 608sks VersaCem Type I/II – 1.24 cuft/sk Temp BHST 99° F (2.25°/100’ TVD below PermaFrost) Notes Job will be mixed on the fly Verification Method - LWD Sonic will be used to log the cement job. Justification: - Future hydraulic fracture operations will only be done in the Nanushuk formation. Log verification of the cement job will verify proper isolation has been achieved for frac operations. NDB-031 7" Intermediate Liner #2 Description TOP BOTTOM LENGTH CAPACITY VOLUME SHOE TRACK LENGTH 18590 18710 120 0.03826 4.6 TAIL LENGTH 16600 18710 2110 0.04713 99.4 TAIL EXCESS 30% 29.8 TOTAL TAIL VOLUME 133.9 Please let me know if you have any questions. Thanks, Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twi Ʃer From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, April 16, 2025 10:23 AM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: ![EXT]: NDB-031 PTD 7" liner cement Mark, Based on the 7” cement job on NDBi-050 not achieving 100’ TVD of cement above the Nanushuk Oil Pool, the AOGCC is planning to require 150’ TVD above the Nanushuk pool on PTDs as a condition of approval of the variance request going forward. Need to tweak the program to achieve the desired outcome. Please submit cement calcs based on this change for NDB-031 and I’ll attach to the PTD. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov 4 +1 (907) 250-9193 Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email From:Staudinger, Mark (Mark) To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); McLellan, Bryan J (OGC); Tirpack, Robert (Robert); Harvey, Brett (Brett); Villarreal, Aimee (Aimee) Subject:RE: NDB-031 (PTD 225-028) - Data Request Date:Tuesday, April 22, 2025 12:44:41 PM Attachments:image002.png image003.png image004.png image005.png Steve, I passed on your questions to our Subsurface team, and they have reviewed and responded to your questions below, in blue. Please let me know if you need any further information or details. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, April 21, 2025 4:32 PM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; Harvey, Brett (Brett) <Brett.Harvey@santos.com> Subject: ![EXT]: RE: NDB-031 (PTD 225-028) - Data Request Mark, I have a few more requests related to Oil Search’s requested diverter waiver for proposed well NDB-031: Are there any faults in the vicinity of NDB-031? If so, please provide a map displaying the location and extent of these faults. Please also provide the expected depths of the shallowest and deepest extents of each fault, along with a description of which formations are affected. No faults in the vicinity of NDB-031 Please describe the seismic data used to map this area (2D, 3D, vintage, quality of data within the section above the Tuluvak sand in the above the path of NDB-031 and in the vicinity of the well, etc.). 3D seismic data acquired in 2010, reprocessed in 2023. Data quality in the vicinity of the well is adequate, without gaps, obvious noise trains or shallow velocity anomalies. What is the approximate vertical displacement of the smallest fault that can be resolved on the seismic data in the vicinity of NDB-031? Smallest detectable and mappable fault offset at Tuluvak interval is estimated to be 20-30’ Again, Thanks and Be Safe, Steve Davies AOGCC From: Davies, Stephen F (OGC) Sent: Monday, April 21, 2025 4:10 PM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; Harvey, Brett (Brett) <Brett.Harvey@santos.com> Subject: RE: NDB-031 (PTD 225-028) - Data Request Mark, Thank you for the detailed response. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thanks Again and Be Safe, Steve Davies AOGCC From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Monday, April 21, 2025 3:50 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; Harvey, Brett (Brett) <Brett.Harvey@santos.com> Subject: RE: NDB-031 (PTD 225-028) - Data Request Steve, Please see our responses below in blue. I’ve also added a few pictures from a slidepack – if you have a hard time seeing them I can send them as an attachment separately – just let me know. Let us know if you have any more questions or need more clarification. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, April 18, 2025 12:01 PM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: ![EXT]: RE: NDB-031 (PTD 225-028) - Data Request Mark, In addition to my data request, below, regarding Oil Search’s requested diverter waiver, I have few questions. With respect to existing nearby well NDB-043, located about 300’ away from NDB-031 at the surface casing shoes, I notice that the surface casing for NDB-031 is proposed to be set about 150’ TVD deeper, which places the shoe much closer to the Tuluvak Shale and the Tuluvak Sand intervals. Note that the Gas Peaks Report for NDB-043 (shown in part below), shows significant amounts of formation gas at 915’, 1030’, 1779’, and from 2995’ to 3285’ MD. The surface hole of NDB-031 will drill strata equivalent to those that yielded the elevated gas readings at 915’, 1030’, and 1779’ MD in nearby NDB-043. Why don’t those strata warrant drilling with a diverter? The gas readings in the above-mentioned intervals are from gas hydrates. Gas hydrates aren’t capable of any sustained flow, so a diverter would not be required if hydrates are encountered. Diverters are only designed to divert hydrocarbons from the rig if shallow, free gas is encountered that can yield extended flow. When hydrates are encountered while drilling, gas shows are generally very short in duration. If a diverter waiver were granted for NDB-031, what measures will Oil Search have in place to mitigate the effects of any gas encountered and prevent an incident? Oil Search has a recommended practice for handling gas hydrates while drilling. Current drilling practices are employed that mitigate hydrate breakout: keeping mud temperature cool, no extended circulation at any point in the well, optimized drilling and tripping strategies, utilization of GWD to minimize stationary time. When gas hydrates are encountered in the surface hole, the recommended practice outlines procedures to follow for identification of hydrates (i.e. bubbles in the flow both with no signs of pit gain or flow from the well), handling hydrates at surface (i.e. utilization of degasser and isolation of gas-cut mud in the pits), and drilling practices (i.e. controlling pump rates and maximizing ROP to get through a hydrate zone). All events are still treated with the utmost caution as though they are a potential gas kick, but all evidence to date supports that the elevated gas encountered in these strata have been caused from hydrates. The Gas Peaks Report for NDB-043 clearly shows that the Tuluvak interval is gas-bearing. Why is Oil search setting surface casing closer to this potential drilling hazard? NDB-043 was the first well drilled along the NDB well row. Initially, we took an overly conservative approach by setting the surface casing ~100-150’ TVD below the MCU. The MCU pick is a highly predictable, high quality seismic pick. Additionally, a consistent thickness between MCU and Tuluvak Shale has been shown as the drilling campaign progressed. These two points above have led to the team gradually deepening the surface casing point over time (200’ -250’ TVD) as offset data supports doing so. The slide below demonstrates how the level of confidence in our depth control has allowed this deepening of the casing shoe over time to the current maximum depth of 250’ TVD below the MCU. The team does not intend on deepening further than the maximum of 250’ TVD below the MCU. What measures will Oil Search have in place to ensure that NDB-031 does not inadvertently penetrate the gas-bearing Tuluvak while drilling the surface hole interval? A rigorous pre-drill technical evaluation is done for every well (following the Santos Surface Casing Recommended Practice) that evaluates seismic quality, nearest offset wells (LWD, gas data and formation tops) to ensure there is high confidence that the surface casing shoe is set well-above the gas-bearing Tuluvak. This generally guarantees a casing point that is a minimum of ~50’ TVD above the Tuluvak Shale and >100’ TVD above the gas-bearing Tuluvak. What mitigation measures will Oil Search have in place should that interval be penetrated? Diverters are not a piece of Blow out Prevention Equipment (not pressure or fluid containing). Oil Search has rigorous processes in place to ensure that the gas-bearing Tuluvak is not penetrated without BOPE. Oil Search’s primary mitigation for penetrating the Tuluvak is the high confidence of the surface casing pick from data density and quality, and extensive characterization and mapping of the NDB pad area. The risk of penetrating the gas-bearing Tuluvak without BOPE is assessed as negligible. A diverter variance increases personal safety by eliminating high-risk rig up & rig down activities of diverter lines. Rig evacuation plans and muster points are in place. These would apply with or without a diverter in place. Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (OGC) Sent: Friday, April 18, 2025 11:29 AM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: NDB-031 (PTD 225-018) - Data Request Mark, I’m reviewing Oil Search’s Permit to Drill application for NDB-031, and I’m evaluating the diverter waiver request by reviewing records from nearby wells. One of those wells, NDB-043 (PTD 223-051), was mud logged. The electronic file supplied by Oil Search for one of the associated mud logging records, the mud logger’s Show Report #1, displays a file size of 0KB and it triggers an error in Adobe Acrobat. Could Oil Search please provide a replacement file for this show report in .pdf format as soon as is practical? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email 1 McLellan, Bryan J (OGC) From:Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent:Thursday, April 24, 2025 1:38 PM To:McLellan, Bryan J (OGC) Subject:RE: NDB-031 (PTD 225-028) Directional Report Bryan, We’ve evaluated and risk assessed the close approach with Qugruk 8 (Q8), and the close approach is approved to proceed within our internal policy. Q8 is a vertical exploration well drilled and P&A’ed in 2015. The close approach interval is with the 7” casing on Q8, in a portion which has a cemented open hole annulus. The 7” casing itself has 3 P&A plugs. We’ve deemed this close approach as only a low financial risk (No HSE risk). Please let me know if you have any further questions. Thanks, Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twi Ʃer From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, April 24, 2025 12:31 PM To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Subject: ![EXT]: RE: NDB-031 (PTD 225-028) Directional Report Mark, Please address the close approach with Qugruk 8 at 15,585’ MD. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Thursday, April 24, 2025 10:35 AM 2 To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: NDB-031 (PTD 225-028) Directional Report Hi Bryan, I was looking through the submitted PTD application and noticed we didn’t send you the full directional report (including anti-collision info) for NDB-031. I have included it in the attachments. Please let me know if you have any questions. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twi Ʃer Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements 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 the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 225-028 NANUSHUK OIL Pikka NDB-031 PIKKA WELL PERMIT CHECKLISTCompanyOil Search (Alaska), LLCWell Name:PIKKA NDB-031Initial Class/TypeDEV / PENDGeoArea890Unit11580On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250280Field & Pool:PIKKA, NANUSHUK OIL - 600100NA1 Permit fee attachedYes Surface Location lies within ADL0392984; Portion of Well Passes Thru ADL0391445, ADL0393023,2 Lease number appropriateYes ADL0393022, ADL0393024; Top Productive Interval lies in ADL0392959; TD lies in ADL0392977.3 Unique well name and numberYes PIKKA, NANUSHUK OIL - 600100 - governed by CO 8074 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes 2-stage cement with gap in cement coverage between stages21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes Close approach to Qugruk 8, but this is a P&A'd well with multiple plugs and low HSE risk for collision26 Adequate wellbore separation proposedNo Diverter request approved, with maximum surface hole depth specified to avoid Tuluvak.27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP=1482 psi, BOP rated to 5000 psi (Initial BOP test to 5000 psi, subsequent tests to 3600 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S Measures not required: no risk based on nearby wells; see p. 38.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure range is 0.374 to 0.529 psi/ft (7.2 to 10.2 ppg EMW). Operator's planned mud program36 Data presented on potential overpressure zonesNA appears sufficient to control anticipated pressures and maintain wellbore stability.37 Seismic analysis of shallow gas zonesNA Managed pressure drilling will be used while drilling intermediate and production hole.38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate4/18/2025ApprBJMDate4/24/2025ApprSFDDate4/18/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 4/25/2025