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224-006
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-025 50103208770000 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-025 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-025 50103208770000 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-025 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 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Well Cleanup Oil Search Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,886 feet N/A feet true vertical 4,183 feet N/A feet Effective Depth measured 13,880 feet See attached rpt feet true vertical 4,183 feet See attached rpt feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6ppf P-110S 8,318' Packers and SSSV (type, measured and true vertical depth) See attached packer report 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Scott Leahy Contact Email:scott.leahy@santos.com Authorized Title: Completions Specialist Contact Phone: 907-330-4595 4,343' Burst Collapse 2260 4750 measured TVD Production Liner 2,572' 8,318' 5,595' Casing Conductor 2,302' 4,340' 4-1/2" 2,572' 8,318' 13,880' 4,183' Plugs Junk measured See attached report Length 128' 2,727' 5,863' 2,727'Surface Intermediate Tie-Back 20"x34" 13-3/8" 9-5/8" N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 392984, 393023, 391455, 393021 Pikka / Nanushuk Oil Pool Pikka NDB-025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-006 50-103-20877-00-00 601 W 5th Avenue Anchorage, AK 99501 3. Address: 375 Tieback 11590 4-1/2" 4750 9210 6870 11590 441 9171,667 0 00 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 128' See attached report Size 128' 2,388' 5020 68708,435' 324-598 Sr Pet Eng: 9210 Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 4,585 0 p k ft t Fra O s 224 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 03/03/2025 By Gavin Gluyas at 8:13 am, Mar 04, 2025 DSR-3/10/25BJM 5/1/25 CDW 03/04/2025RBDMS JSB 031325 Page 1 of 1 Packer Set Depths - NDB-025 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Original Hole SLZXP Liner Top Hanger Packer w/centralizer 8,306.4 4,339.8 Original Hole HES Zoneguard OH Packer #12 8,862.5 4,339.3 Original Hole HES Zoneguard OH Packer #11 8,969.7 4,336.0 Original Hole HES Zoneguard OH Packer #10 9,306.7 4,325.6 Original Hole HES Zoneguard OH Packer #9 9,800.6 4,310.2 Original Hole HES Zoneguard OH Packer #8 10,301.0 4,294.8 Original Hole HES Zoneguard OH Packer #7 10,803.5 4,279.1 Original Hole HES Zoneguard OH Packer #6 11,262.8 4,265.1 Original Hole HES Zoneguard OH Packer #5 11,722.9 4,250.9 Original Hole HES Zoneguard OH Packer #4 12,182.4 4,236.6 Original Hole HES Zoneguard OH Packer #3 12,643.2 4,222.5 Original Hole HES Zoneguard OH Packer #2 13,103.8 4,207.7 Original Hole HES Zoneguard OH Packer #1 13,481.9 4,195.4 Frac Ops Summary Report - AOGCC Well Name NDB-025 Primary Job Type Fracture Treatment Start Date End Date Summary 11/11/2024 11/12/2024 Continue heating water tanks. Finish SLB RU. 11/12/2024 11/13/2024 Continue to circulate water tanks and prep for frac (mix chemicals and test). 11/13/2024 11/14/2024 Review Frac Tank Loading work instruction and fluid transfer checklist with Worley. Finish filling last water tank and heat. Finalize RU and spot of last equipment in prep for frac in morning. 11/14/2024 11/15/2024 Frac stages 1-5 Finish spotting/RU equipment. Hold pre-job safety meeting. PT equipment (700psi low and 9500psi high for 5 min). Mix gel and test. Open well at 12:04 at 705psi. Start pumping at 1.5bpm and open stage 1 toe sleeve at 7867psi. Displace prime up fluid. Perform pump check and shut down. Stage 1 Datafrac: Pump 251bbls WF125 fluid and shut down to analyze – ISIP 850psi Stage 1 frac: 2,379bbls slurry (WF/YF125ST fluid), 274,593lbs 40/70 and 16/20 carbolite SG (1, 3 40/70 scour, 1, 3, 5, 7, 9, 10ppa 16/20 SG), 2,110bbs clean fluid at 40bpm as per design Stage 2 frac: 1,759bbls slurry (YF125ST fluid), 286,443lbs 16/20 carbolite SG (1, 2, 4, 6, 8, 10, 12ppa), 1,479bbls clean fluid at 40bpm as per design Stage 3 frac: 1,835bbls slurry (YF125ST fluid), 288,323lbs 16/20 carbolite SG (1, 2, 4, 6, 8, 10, 12ppa), 1,554bbls clean fluid at 40bpm as per design Stage 4 frac: 1,955bbls slurry (YF125ST fluid), 315,218lbs 16/20 carbolite SG (1, 2, 4, 6, 8, 10, 12ppa), 1,647bbls clean fluid at 40bpm as per design Stage 5 frac: 1,840bbls slurry (YF125ST fluid), 318,290lbs 16/20 carbolite and carbolite SG (1, 2, 4, 6, 8, 10, 12, 14ppa), 1,485bbls clean fluid at 40bpm, screened out with 61bbls flush pumped (52,755lbs left in pipe) Tracerco oil/water/solid tracers pumped as per design. Shut down and clean out frac equipment in preparation for coiled tubing cleanout. No freeze protect able to be pumped into well. Total Load to Recover (TLTR) stage 1-5 – 8,275bbls 11/15/2024 11/16/2024 RD SLB frac iron and LRS pumping iron from wellhead. RD Cameron launch tree and install flow cross in prep for coiled tubing work. 11/16/2024 11/17/2024 MIRU LRS Coil Tubing Unit #3. MIRU return tanks, supply tanks, recirculation filter skid, choke skid. 11/17/2024 11/18/2024 Test Coiled Tubing BOPE. 11/18/2024 11/19/2024 Make up BHA, pull test to 35k and pressure test. Hold PJSM with crew to discuss procedure and lift plan. Circulate 60/40 methanol spear and then slick/safe seawater fluid. Open well and RIH while circulating at 2.5bpm. Cleaned out to 4584' with no indication of proppant in returns. Tagged up and circulated bottoms up. RIH to tag at 4735' and then continued to work coil down to 4886' - weights indicating pushing the ball/collet. Called out 10bbls of acid. Circulated bottoms up and then swapped to diesel while POOH. Freeze protect wellhead and surface lines with diesel and close in swab valve to wait for acid to arrive. 11/19/2024 11/20/2024 Acid transport on location. Attempted to circulate and pressured up on pump - possible ice plug in surface lines. Spot in heaters and thaw out ice from surface lines. Blow air through lines to flowback tank and ensure surface lines are clear. Pump 60/40 methanol through surface lines and out to coil return tanks. Pump 40 bbls 60/40 methanol through coil to verify circulation. RIH to 4932' while circulating 10 bbls acid down coil. Tag up and work down to 5300' while acid coming out of tubing. Continue to clean out down to 5500' with indications that ball is dissolved and circulating some sand. Chase returns to surface at 2.5 bpm and 80 fpm. 1-5% sand in returns. RIH to 5500', circulate taking 100' bites down to 6000', chase returns to surface. At 3400' at midnight. 15-20% sand in returns. 11/20/2024 11/21/2024 Cleanout proppant from 6,000' to 7,500' ctmd pumping slick/safe seawater with gel pills at 2.5 bpm and chase proppant to surface. While chasing proppant to surface from 7,500', coil unit deck engine required a Re-gen. Once coil was at surface, secure well by closing lower master valve and performing a Re-gen on the deck engine. Keep coil at surface while waiting on wind to subside. Cleanout proppant from 7,500' to 8,000' ctmd pumping slick/safe seawater with gel pills at 2.5 bpm to chase proppant to surface (6'000' at midnight). Page 1 of Frac Ops Summary Report - AOGCC Start Date End Date Summary 11/21/2024 11/22/2024 Finish chasing returns from 8,000' ctmd to surface. Cleanout proppant from 8,000' to 8,500' ctmd pumping slick/safe seawater with gel pill at 2.5 bpm. Had a gas influx while RIH for next cleanout bite when coil was at 8,200'. Circulate gas to surface and fluid pack wellbore. Cleanout proppant from 8,500' to 9,000' ctmd pumping slick/safe seawater with gel pill at 2.5 bpm. Proppant bridged off at 7,900' ctmd, picked up rate to 3 bpm and work pipe down, continued to POOH at 50 fpm to surface. Cleanout proppant from 9,000' to 9,500' pumping slick/safe seawater with gel pill and chase returns to surface. Cleanout proppant from 9,500' to 10,000' ctmd pumping slick/safe seawater with gel pill at 3.0 bpm and chase proppant to surface. At 7,000' ctmd at midnight 11/22/2024 11/23/2024 Finish chasing returns to surface after cleaning out to 10,000' ctmd. Cleanout proppant from 10,000' to 10,500' pumping slick/safe seawater with gel pill and chase returns to surface. Force regen on CTU engine, freeze protect reel/surface lines with 60/40 methanol, come off well, check tools, small rock partially plugging off nozzle port, MU tools, change out stripper rubbers, stab onto well, PT QT sub and perform maintenance checks. Cleanout proppant from 10,500' to 11,000' pumping slick/safe seawater at 3.0 bpm with gel pill and chase returns to surface at 50 fpm. (at 6,000' at midnight). 11/23/2024 11/24/2024 Finish chasing returns to surface after cleaning out to 11,000' ctmd. Cleanout proppant from 11,000' to 11,500' ctmd, started to set down weight (-4k to -6K) at end of bite. Pump slick/safe seawater with gel pill and chase returns to surface. Change out tools to include XRV to assist in reaching desired cleanout depth. Cleanout proppant from 11,500' to 11,979' ctmd, tagged up on frac ball at stage 5 sleeve. Pump gel sweep off bottom and chase returns uphole at 3.0 bpm with slick/safe seawaer, pump additonal gel pill at 7,200' and chase to surface at 50 fpm. Assemble 3.5" knockout ball sub on BHA. RIH to 11,516' ctmd (stage 6), set weight and pressure up to 2,400 psi to shift open sleeve. Inject at 1 bpm at 927 psi. POOH to surface at 80 fpm. 11/24/2024 11/25/2024 PT Halliburton N2 lines. Blow down reel with Nitrogen. RD CTU. Start filling water tanks with KCL concentrate and fresh water. Start heating tanks. RD flow cross and RU Cameron launch tree on wellhead. 11/25/2024 11/26/2024 Continue to haul water and heat tanks. 11/26/2024 11/27/2024 Shut down tank filling and heating operations while investigating a possible faulty valve on Tank #5. 11/27/2024 11/28/2024 Shut down tank filling and heating operations while investigating a possible faulty valve on Tank #5. 11/28/2024 11/29/2024 Fill and Heat Frac Tanks. Perform Lab Testing on Frac Fluids. Pressure Test Frac Equipment - 500 psi Low Test for 5 mins, 9000 psi High Test for 5 mins. 11/29/2024 11/30/2024 Frac Stages 6-7 Finish RU of Frac equipment, prime up, pressure test. Pump Freeze Protect fluid past wellhead with 40 bbls WF125ST. Drop Ball and Pump Down with 175 bbls of WF125ST. Pump Check with 100 bbls WF125ST. Frac Stage 6: 2,035 bbls slurry (YF125ST fluid), 15,781 lbs 40/70 CarboLite (1, 3ppa), 270,982 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10, 12ppa), 1,731 bbls clean fluid at 40bpm, Comments: As per design. Frac Stage 7: 2,065 bbls slurry (YF125ST fluid), 16,743 lbs 40/70 CarboLite (1, 3ppa), 272,195 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10, 12ppa), 1,760 bbls clean fluid at 40bpm, Comments: Added 40/70 Scour Stage. Well screened out just after 12ppa hit formation. Pump 5 bbls Freeze Protect past wellhead. TLTR (Stages 6-8) – 3,687 bbls TLTR (Total for Well) – 11,962 bbls 11/30/2024 12/1/2024 MIRU LRS CTU #3. Fill reel with 60/40 MeOH. BOP Test. 12/1/2024 12/2/2024 Complete BOPE Test. M/U BHA. Stab onto well and pressure test. Troubleshoot throttle valve. RIH and cleanout. 12/2/2024 12/3/2024 Cleaned out from 3,500' to 6,600' while circulating 2% slk KCL at 2.5 BPM at 3,000 psi. Page 2 of Frac Ops Summary Report - AOGCC Start Date End Date Summary 12/3/2024 12/4/2024 Cleaned out from 6,600' to 8,100' while circulating 2% slk KCL with SafeLube at 2.5 BPM at 3,000 psi. 12/4/2024 12/5/2024 Cleaned out from 8,100' to 10,475' while circulating 2% slk KCL with SafeLube at 2.5 BPM at 3,000 psi. 12/5/2024 12/6/2024 Cleaned out to 11,060' ctmd. Shifted Sleeve 7 open at 10,527'. Freeze protected well. Blew reeel down with N2. RDMO. 12/6/2024 12/7/2024 RDMO Coil Unit. MIRU Frac Equipment. 12/7/2024 12/8/2024 MIRU Frac Equipment 12/8/2024 12/9/2024 Frac Stage 8 Finish RU of Frac equipment, prime up, pressure test. Pump Freeze Protect fluid past wellhead with 40 bbls WF126ST. Drop Ball and Pump Down with 175 bbls of WF126ST. DataFrac: 225 bbls YF126ST and 170 bbls WF126ST Fluid at 40bpm. Frac Stage 8: 1,691 bbls slurry (YF126ST fluid), 14,868 lbs 40/70 CarboLite (1, 3ppa), 203,715 lbs 16/20 Carbolite (1, 3, 5, 7, 9, 10ppa), 1,459 bbls clean fluid at 40bpm, Comments: Changed the 16/20 steps from 1 ,2, 4, 6, 8, 10, 12ppa. Screened out with 34 bbls of clean fluid past the wellhead. 86% of Proppant placed in formation. Pump 5 bbls Freeze Protect past wellhead. TLTR (Stage 8) – 2,069 bbls TLTR (Total for Well) – 14,031 bbls 12/9/2024 12/10/2024 RDMO Frac Equipment. 12/10/2024 12/11/2024 Waiting on LRS Coil Unit. 12/15/2024 12/16/2024 Waiting on LRS Coil Unit. 12/16/2024 12/17/2024 MIRU coiled tubing equipment. Spot Deadman blocks, crane and choke trailer. RU hard line from P-sub to choke trailer, RU hard line from choke trailer to tank manifold. RU hardline from twin pump to reel manifold. NU BOP's on P-sub. Pick-up Injector, MU lubricator, MU Coil connector and pull test to 35K lbs. 12/17/2024 12/18/2024 Replace computer in coil ops cab to enable monitors to work properly. Load coil with Diesel. Complete BOPE test to 250 psi low / 4,000 psi high. MU cleanout BHA with Down Jet Nozzle and RIH. Cleanout proppant to 5,000' ctmd. Appear to be pushing frac ball downhole while cleaning out. 12/18/2024 12/19/2024 Cleanout proppant to 6,000' ctmd, appear to be pushing frac ball/collet. Shut down pump, RIH for dry tag at 6018' ctmd. Pump 10 bbls of 15% HCl acid an circulate to end of coil. Set weight down on ball/collet when acid comes out of nozzle and coil starts to move downhole with acid at nozzle. RIH without pumping to 6047' ctmd. Circulate remaining acid to surface and POOH. MU fishing BHA with slick catch spear and RIH. RIH and tag fish at 6088'. Set down 3 times to engage fish. P/U and POOH to surface. Coil at surface, but unable to shut tree valves. 12/19/2024 12/20/2024 Pull fishing BHA to surface through tree while pumping 60/40 methanol down coil at 1.3 bpm and CTP = 4300 psi. No Collet on fishing BHA. Laydown BHA. Callout Baker Hughes for Slick catch 4" GS. RIH and tag collet at 6,088' ctmd. Set down 2 times and POOH. No Collet on fishing spear. 12/20/2024 12/21/2024 Make fishing run #2 with Baker fishing BHA, tag at 6,106' ctmd, come online with pump and tag at 6,236' ctmd. Pull heavy to 25K and kick on pump. POOH and have freezing issues at surface with fluid returns. Coil unable to move at 3,390' ctmd. Pump methanol out to return tanks and through BOP's, Pump hot water around coil out to return tanks. POOH and laydown fishing BHA. No Collet with spear. MU cleanout BHA. RIH and clean-out proppant down to 6,250' at midnight 12/21/2024 12/22/2024 Clean proppant down to 7,000' ctmd with PowerVis Gel pill and chase back to surface with 2% KCl slick/safe fluid. Clean proppant down to 7,500'ctmd with PowerVis Gel pill and chase back to surface with 2% KCl slick/safe fluid. Clean proppant down to 8,000' ctmd with PowerVis Gel pill and chase back to surface with 2% KCl slick/safe fluid. Page 3 of Frac Ops Summary Report - AOGCC Start Date End Date Summary 12/22/2024 12/23/2024 Change out BHA's. Install Quadco XRV BHA with 9 hole JSN. Clean proppant from 8000' to 8500' ctm. Pump Gel sweep and chase it out to surface. Made three more runs to cleanout proppant from 8,500' to 10,100' ctmd using 2% KCl water with 0.03% DR204 and 1.2% Safelube. Did not use Gel sweeps. P/U weight at 10,600' was 21,000lbs. Chase proppant out of well at 80 fpm, 2.5 bpm, CTP = 2500 psi while holding ~ 100 psi on choke. Heavy proppant to surface starting ~ 2500' ctmd on each run. 12/23/2024 12/24/2024 Cleanout from 10,600' to 11,100' ctmd. Chase returns to surface. RIH to 2,000' and pump diesel to freeze protect coil and tubing. Lay down cleanout BHA and MU Fishing BHA. RIH with choke closed and tag collet #8 at 10,055' ctmd. Jar down twice and POOH. Retrieved collet #8. M/U BHA with Knockout Sub, RIH and tagged collet #7 at 10557. Ctmd. POOH. Obtained verbal approval from Jim Regg with AOGCC to extend CTU BOP test past 0:00 on 12/24/24 for final CTU run at 7:30pm 12/23/24. 12/24/2024 12/25/2024 Obtained verbal approval from Jim Regg with AOGCC to extend CTU BOP test past 0:00 on 12/24/24 for final CTU run at 7:30pm 12/23/24. Continue to POOH to surface on Knockout sub run. Line up valves to inject into well and perform injection test with diesel (Freeze protect fluid) at 6bpm for 7mins with max WHP at 870psi. Rig up N2 and blow dry Coil tubing with N2. RD CTU #3 12/25/2024 12/26/2024 Continue to haul heated 4% KCL water for frac. RD flow cross off wellhead. RU Cameron launch tree and frac iron at wellhead. Fire up frac equipment and continue to prep for frac. 12/26/2024 12/27/2024 Continue to haul heated 4% KCL water for frac. Mix frac chemicals. RU LRS unit and manifold trailer. 12/27/2024 12/28/2024 Finish hauling water for frac. Function test Cameron launch tree valves. Test frac fluids. Fire frac units and do final RU/equipment checks. Pressure test frac iron. 12/28/2024 12/29/2024 Finish final RU and spot remaining equipment. Prime up pumps. PT to 9,400 psi. Hold pre-job safety meeting. Mix gel and test. Troubleshoot air system on blender. Pumped ball down to land on stage 8. Perform pump test at 18 bpm. Freeze protect well and surface equipment. RD blender to take back to shop to troubleshoot air system. 12/29/2024 12/30/2024 Wait on blender repairs. Prep for frac. 12/30/2024 12/31/2024 Spot blender and RU. Electronic communication and webasto issues while getting pumps running. Blender communication issues after pumps were running. Pressure test failed on high pressure test when pump fluid ends got cold (-15 to -25F) causing cap seals to start leaking. Decision made to not pump. Rewarmed fluid ends and performed pressure test. Blow down lines to shut down for the night. Night watch personnel to leave pumps running overnight in preparation for morning pump. 12/31/2024 1/1/2025 Frac stages 9-11: Fire up remaining units, prime up, pressure test, safety meeting, mix gel. Displace freeze protect fluid. Drop ball and pump down at 4bpm. Shut down to fix valve on J450 tote. Shut down to clean out sand belt that plugged off. Frac stage 9: Pump YF126ST to pump collet/ball down at 18bpm to start frac, 3,325bbls slurry (WF/YF126ST fluid), 19,332lbs 40/70 carbolite (1, 3ppa), 19,488lbs 16/20 carbolite (1, 2ppa), 214,409lbs 16/20 carbolite scaleguard (3, 4, 5, 6, 7, 8ppa), 3,075bbs clean fluid at 40bpm as per design. Shut down to repair pumps. Frac stage 10: 1,907bbls slurry (YF126ST fluid), 16,970lbs 40/70 carbolite (1, 3ppa), 16,973lbs 16/20 carbolite (1, 2ppa), 193,009lbs 16/20 carbolite scaleguard (3, 4, 5, 6, 7, 8ppa), 1,685bbs clean fluid at 40bpm as per design. Frac stage 11: 1,535bbls slurry (YF126ST fluid), 10,991lbs 40/70 carbolite (1, 3ppa), 13,539lbs 16/20 carbolite (1, 2ppa), 152,453lbs 16/20 carbolite scaleguard (3, 4, 5, 6, 7, 8ppa), 1,296bbs clean fluid at 40bpm as per design (65bbls freeze protect pumped). Tracerco tracers pumped as per design (details in the job time log for each stage). Shut down, blow down and winterize equipment for night. Total Load to Recover (TLTR) stage 9-11 – 6,056bbls Total Load to Recover (TLTR) – 20,087bbls 1/1/2025 1/2/2025 RD frac. Page 4 of Flowback Ops Summary Report - AOGCC Well Name NDB-025 Primary Job Type Flowback/Testing Start Date End Date Summary 11/30/2024 12/1/2024 Wait on Frac operations to be completed 12/15/2024 12/16/2024 Shovel snow and get equipment ready for FB operations and wait on Frac operations to be completed. 2/8/2025 2/9/2025 Rig up Well Test Equipment Rig up injection lines to NDBi-014 and NDBi-030. Pressure Test injection lines to Low 300psi and High 4000psi. Good test. 2/9/2025 2/10/2025 Pressure test Well test Equipment. Spot and RU N2 equipment to IA and PT lines. Spot and RU Twin Pumper to injection line and PT same to the plug valve. 2/10/2025 2/11/2025 Continue to RU Well test Equipment and complete safety systems test. Test ESD stations Wrap injection lines from NDBi-014 to NDBi-030 with Vis-queen and applied heat. Complete Pre-flow checklist, open well and start Well Cleanout/ Flowback as per procedure. 2/11/2025 2/12/2025 Continue Well Cleanup/ Flowback operations as per procedure. 2/12/2025 2/13/2025 Continue Well Cleanup/ Flowback operations as per procedure. 2/13/2025 2/14/2025 Continue Well Cleanup/ Flowback operations as per procedure. Shut in well. Secure well and equipment. Freeze protect surface lines. Stand by wait on Weather. 2/14/2025 2/15/2025 Stand by wait on weather. 2/15/2025 2/16/2025 Stand by wait on weather. Prepare equipment to flow the well' Flow Well as per clean up procedure. 2/16/2025 2/17/2025 Continue Well Cleanup/ Flowback operations as per procedure. 2/17/2025 2/18/2025 Flow well as per clean up procedure. Shut in well and monitor BHP and BHT. Freeze protect surface lines and RD Expro equipment. 2/18/2025 2/19/2025 RD Expro Equipment. Monitor BHP and BHT Page 1 of 1 Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 9.8 gal F103 Surfactant 1.0 Gal/mGal 814.2 gal J450 Stabilizing Agent 0.5 Gal/mGal 412.4 gal J475 Breaker J475 5.6 lb/mGal 4,723.2 lbm J511 Stabilizing Agent 1.7 lb/mGal 1,409.9 lbm J532 Crosslinker 2.3 Gal/mGal 1,910.1 gal J580 Gel J580 26.5 lb/mGal 22,466.8 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 59.9 gal M002 Additive 0.0 lb/mGal 1.7 lbm M117 Clay Control Agent 214.8 lb/mGal 181,935.4 lbm M275 Bactericide 0.5 lb/mGal 394.4 lbm S522-1620 Propping Agent varied concentrations 2,621,672.7 lbm S522-4070 Propping Agent varied concentrations 110,003.0 lbm S901 Proppant with Scale Inhibitor S901 varied concentrations 150,051.3 lbm 69.05182 % 28.51235 % 1.75708 % 0.22313 % 0.14940 % 0.05434 % 0.03961 % 0.03925 % 0.03762 % 0.03205 % 0.02988 % 0.01404 % 0.01268 % 0.01268 % 0.01164 % 0.00893 % 0.00632 % 0.00196 % 0.00189 % 0.00101 % 0.00056 % 0.00039 % 0.00024 % 0.00024 % 0.00024 % 0.00023 % 0.00020 % 0.00013 % 0.00008 % 0.00005 % 0.00004 % 0.00004 % 0.00004 % 0.00002 % 0.00002 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 %2634-33-5 1,2-benzisothiazolin-3-one Total * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. 100 9004-32-4 Sodium carboxymethylcellulose 7632-00-0 Sodium nitrite 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 9005-65-6 Sorbitan monooleate, ethoxylated 11138-66-2 Xanthan Gum 68937-55-3 Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 68308-89-4 Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 64-19-7 Acetic acid (impurity) 1338-41-6 Sorbitan stearate 532-32-1 Sodium benzoate 36089-45-9 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2-hydroxyethyl 2-propenoate 14808-60-7 Quartz, Crystalline silica 127-08-2 Acetic acid, potassium salt (impurity) 1310-73-2 Sodium hydroxide 67762-90-7 Siloxanes and silicones, dimethyl, reaction products with silica 9000-90-2 Amylase, alpha 14464-46-1 Cristobalite 111-42-2 2,2'-Iminodiethanol 7786-30-3 Magnesium chloride 63148-62-9 Dimethyl siloxanes and silicones 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 14807-96-6 Magnesium silicate hydrate (talc) 9002-84-0 poly(tetrafluoroethylene) 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 10377-60-3 Magnesium nitrate 68131-39-5 Ethoxylated Alcohol 91053-39-3 Diatomaceous earth, calcined 9025-56-3 Hemicellulase 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 25038-72-6 Vinylidene chloride/methylacrylate copolymer 9003-35-4 Phenolic resin 50-70-4 Sorbitol 67-63-0 Propan-2-ol 56-81-5 1, 2, 3 - Propanetriol 7727-54-0 Diammonium peroxodisulphate 1303-96-4 Sodium tetraborate decahydrate 68715-83-3 2-Butenedioic acid (2Z)-, polymer with sodium 2-propene-1-sulfonate 7647-14-5 Sodium chloride 102-71-6 2,2`,2"-nitrilotriethanol 66402-68-4 Ceramic materials and wares, chemicals 7447-40-7 Potassium chloride 9000-30-0 Guar gum CAS Number Chemical Name Mass Fraction -Water (Including Mix Water Supplied by Client)* YF125ST:WF125:YF126ST: WF126 846,850 gal † Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. Report ID:RPT-1982 Fluid Name & Volume Concentration Volume Disclosure Type:Post-Job Well Completed: Date Prepared:1/15/2025 State:Alaska County/Parish:North Slope Borough Case: Client:Oil Search Alaska Well:PIKKA NDB-025 Basin/Field:Pikka # SLB-Private Page: 1 / 1 Updated 01/17/2025INPUTEst 9th NovAK TSCA StatusNorthSlope AKTBDPOST821,04773.00000%100,437,901Trade Name Supplier Purpose Ingredients Name CAS #Percentage by Mass of IngredientPercent of Ingredient in Total Mass PumpedMass of Ingredient (lbs)SMETracercoCarrier FluidSoy Methyl Ester67784-80-91000.000074630374.9570800000T-751TracercoChemical TracerBis(4-bromophenyl)ether2050-47-71000.00000153651.5432340000T-758TracercoChemical Tracer3,4-Difluorobenzophenone85118-07-61000.00000043900.4409240000T-756TracercoChemical Tracer3,5-Difluorobenzophenone179113-89-41000.00000065850.6613860000T-162ATracercoChemical Tracer1,4-Dibromobenzene106-37-61000.00000109751.1023100000T-706TracercoChemical Tracer1-Bromo-4-chlorobenzen106-39-81000.00000219502.2046200000T-164BTracercoChemical Tracer2-Bromonaphthalene580-13-21000.00000109751.1023100000T-160CTracercoChemical Tracer2,4,6-Tribromotoluene6320-40-71000.00000043900.4409240000T-161BTracercoChemical Tracer4-Iodotoluene624-31-71000.00000043900.4409240000T-166ATracercoChemical Tracer5-Iodo-m-xylene22445-41-61000.00000109751.1023100000T-750TracercoChemical Tracer1,4-Dibromo-2-fluorobenzene1435-52-51000.00000043900.4409240000T-772TracercoChemical Tracer2-(Trifluoromethyl)Benzophenone727-99-11000.00000043900.4409240000T-160BTracercoChemical Tracer3,5-Dibromotoluene1611-92-31000.000021950122.0462000000T-166CTracercoChemical Tracer1-Iodo-3,4-dimethylbenzene31599-61-81000.000021950122.0462000000T-734TracercoChemical Tracer1-Bromo-2-(trifluoromethyl)benzene392-83-61000.000021950122.0462000000WaterTracercoCarrier FluidWater7732-18-51000.000079898380.2481680000T-801TracercoChemical TracerSodium-2-chlorobenzoate17264-74-31000.00000076830.7716170000T-940TracercoChemical TracerSodium-2-chloro-3-methylbenzoate1708942-16-81000.00000076830.7716170000T-804TracercoChemical TracerSodium-2,3-dichlorobenzoate118537-84-11000.00000076830.7716170000T-920TracercoChemical TracerSodium-5-chloro-2-fluorobenzoate1382106-78-61000.00000076830.7716170000T-176cTracercoChemical TracerSodium-2,4,5-trifluorobenzoate522651-48-51000.00000076830.7716170000T-158eTracercoChemical TracerSodium-3,5-Difluorobenzoate530141-39-01000.00000076830.7716170000T-194aTracercoChemical TracerSodium-2,3,4,5-Tetrafluorobenzoate67852-79-31000.00000076830.7716170000T-158aTracercoChemical TracerSodium-2,4-Difluorobenzoate1765-08-81000.00000076830.7716170000T-943TracercoChemical TracerSodium-3-chloro-2-methylbenzoate1708942-17-91000.00000076830.7716170000T-921TracercoChemical TracerSodium-3-chloro-2-fluorobenzoate1421029-89-11000.00000076830.7716170000T-808TracercoChemical TracerSodium-3,4-dichlorobenzoate17274-10-11000.00000076830.7716170000Hydraulic Fracturing Fluid Product Component Information DisclosureManufacturer Contact Tracerco 4106 New West Dr. Pasadena Texas 77507 Tel: 281-291-7769Fracture DateState:Approved For TracercoCounty:API Number:Operator Name: Santos AKWell Name and Number: NDBi-025Report Type (Pre or Post Job)Total Water Volume (gal):Water Mass FractionTotal Mass Pumped (lbs) 12:21:03 14:05:13 15:49:23 17:33:33 19:17:43 Time - hh:mm:ss 0 2000 4000 6000 8000 10000 12000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Pump Check / DFIT Stage 1 Stage 2 Stage 3 Stage 4 Stage 5 Main Treatment © Schlumberger 1994-2017 Santos NDB-025 11-14-2024 14:19:34 14:40:24 15:01:14 15:22:04 15:42:54 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Drop Rate to Seat Ball Collet Seat Main Treatment © Schlumberger 1994-2017 Santos NDB-025, Stage 1 11-14-2024 15:22:07 15:38:47 15:55:27 16:12:07 16:28:47 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi15 20 25 30 35 40 45 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Drop Rate to Seat Ball Collet Seat Main Treatment © Schlumberger 1994-2017 Santos NDB-025, Stage 2 11-14-2024 16:13:09 16:29:49 16:46:29 17:03:09 17:19:49 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Drop Rate to Seat Ball Collet Seat Main Treatment © Schlumberger 1994-2017 Santos NDB-025, Stage 3 11-14-2024 17:00:53 17:17:33 17:34:13 17:50:53 18:07:33 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Drop Rate to Seat Ball Collet Seat Main Treatment © Schlumberger 1994-2017 Santos NDB-025, Stage 4 11-14-2024 17:50:16 18:11:06 18:31:56 18:52:46 19:13:36 Time - hh:mm:ss 0 2000 4000 6000 8000 10000 12000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Screenout as 14ppa is Entering Formation Closed Well Main Treatment © Schlumberger 1994-2017 Santos NDB-025, Stage 5 11-14-2024 FracCAT Treatment Report Well : NDB-025 Stages 6-7 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : November 29, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi)200 Initial BHP at Gauge (psi)2,015 Final Surface ISIP (psi)NA/ Screenout Final ISIP at Gauge (psi)NA/ Screenout Surface Shut in Pressure (psi)NA/ Screenout BH Shut in Pressure (psi)NA/ Screenout Maximum Treating Pressure (psi)8,618 BH Gauge at 8,191 ft MD, 4,334 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)4,298.5 Total Proppant Pumped (lb) (per Load Tickets)583,295 Total YF125ST Past Wellhead (bbl)3,491.0 Total Proppant in Formation (lb)540,711 Total WF125 Past Wellhead (bbl)184.3 Total S522 - 16/20 CarboLite per Load Tickets (lb)526,043 Total Freeze Protect Past Wellhead (bbl) pumped by SLB 15.0 Total 6% S901 ScaleGUARD IV per Load Tickets (lb)33,577 Total Freeze Protect Past Wellhead (bbl) pumped by LRS 5.0 Total S522 - 40/70 CarboLite per Load Tickets (lb) 23,675 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal)140 139.37 M275 (lb)66.0 62.2 J450 (gal)93 92.685 J753 (gal)20.4 11.64 J580 (lb)4,198 3,877.8 J475 (lb)908 904 J532 (gal)366 364.4 J134 (lb)24 0 J511 (lb)475 279.74 D206 (gal)2 2 M002 (lbs)0.5 0.4 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is a ware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Summary On November 29, 2024, SLB performed a hydraulic fracturing treatment on Stages 6-7 of NDB-025. The initial design called for the completion of stages 6-8 with total of 791,299 lbs of proppant in 5,996 bbl of slurry. While pumping Stage 6, chunks of frozen sand and ice obstructions were found on the gates. In order to avoid concentration spikes when blockage was passing the gates, crew was opening the gates slowly and adjusting accordingly when staging over to higher PPA step. The same happened during stage 7. When 12PPA started entering the formation, crew staged over to Flush and pumped about 40bbl from the Blender, then Screen out occurred. By physical load cell count on SES, a total of 583,295 pounds of proppant was pumped and 540,711 was placed into formation in 4,298.5 bbl of slurry. Stages 6 and 7 consisted of a PAD, two Scour Steps 1-3PPA with proppant 40/70 CBL and 6 proppant steps 1-2-4-6-8-10-12 PPA, Pump trips were staggered from 7,400 to 7,900 psi. The GORV was set to 8,200 psi. Summary of Stages 6-7 Material Actual Design Slurry Volume (bbl)4,298.5 5,996 Clean Fluid Volume(bbl)3,675.3 5,101 Proppant (lb)583,295 791,299 11:44:09 12:00:49 12:17:29 12:34:09 12:50:49 13:07:29 13:24:09 13:40:49 13:57:29 14:14:09 14:30:49 14:47:29 15:04:09 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, Stage 6-7 11-29-2024 0 Stage #7Stage #6 Pump Check Displ PT Ball to Seat Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat, Pump Check. PT displacement followed by 10 min SD, then pumped Ball to Seat and Pump Check which followed by PAD stage 6. A summary of the stage and pressures as follows: Summary of Stage Displacement PT, Ball to Seat and Pump Check Total Proppant Pumped (lb)0 Max pumping Rate (bpm)10.9 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)6.2 Total Slurry Pumped (bbl)199.3 Maximum Treating Pressure (psi)2,058 YF125ST Pumped (bbl)0 Average Treating Pressure (psi)1,060 WF125 Pumped (bbl)184.3 Average Water Temperature (F)77.5 Freeze Protect (bbl) displaced downhole 15.0 Average Viscosity (cP)19.0 11:44:09 12:00:49 12:17:29 12:34:09 12:50:49 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, Displacement PT, Ball to Seat, Pump Check 11-29-2024 0 Pump CheckDisplacement PT Ball to Seat Ball seated Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displacement PT 15 3.9 4.1 FP 630 0 0 0 2 Displacement PT 25.2 3.9 6.5 WF125 1058 0 0 0 3 Ball To Seat 156 4.1 38.3 WF125 6549 0 0 0 4 Pump Check 3.1 6.2 0.5 WF125 132 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1,2 Displacement 3.9 4.3 789 865 429 3 Ball To Seat 4.1 4.1 767 1571 227 4 Pump Check 6.2 10.9 1625 2058 1335 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 6:52:27 Started Prime up 74 -0 0.0 5.5 0.0 2 8:19:31 Low Pressure Test 800 -0 0.0 0.0 0.0 3 8:23:59 HP Leak Pump 1 Bull Plug 3 -1 0.0 0.0 0.0 4 8:37:27 High Pressure Test 9283 1 0.0 0.0 0.0 5 8:49:28 Bucket Checks 1186 -1 0.0 0.0 0.0 6 9:21:37 Mixing 25# Gel 231 0 0.0 0.0 0.0 7 10:14:19 Finished Safety Meeting 3 0 0.0 0.0 0.0 8 10:14:24 Radio check 3 1 0.0 0.0 0.0 9 10:22:00 Priming LAS Pumps 5 -9 0.0 0.0 0.0 10 10:32:39 LRS Putting Pressure On IA 4 2438 0.0 0.0 0.0 11 10:36:03 Bring Up Line Pressure Verify No Leaks 1 2991 0.0 0.0 0.0 12 10:51:06 Greasing Bleed Line 2x1 Valves -2 2929 0.0 0.0 0.0 13 11:19:06 Swapping Out Leaking 2x2 -3 2899 0.0 0.0 0.0 14 11:47:13 Open Well 189 2881 0.0 0.0 0.0 15 11:48:26 Start Displacement PT Automatically 197 2884 0.0 0.0 0.0 16 11:48:26 Start Propped Frac Automatically 197 2884 0.0 0.0 0.0 17 11:48:26 Start Ball to Seat Automatically 197 2884 0.0 0.0 0.0 18 11:48:46 Started Pumping 465 2889 0.0 0.0 0.0 19 11:59:26 Stopped Pumping 601 2835 40.2 3.2 0.0 20 11:59:50 SD for 10 min 283 2825 40.2 0.0 0.0 21 12:14:26 Ball Loaded And Free Falling 225 2879 40.2 0.0 0.0 22 12:22:32 Radio check 226 2887 40.2 0.0 0.0 23 12:23:13 Started Pumping 227 2888 40.2 0.0 0.0 24 12:23:16 Start Ball To Seat Manually 227 2887 40.2 0.0 0.0 25 12:59:07 Ball Seated 801 3127 185.4 4.1 0.0 26 13:00:15 Stage at Perfs: Displacement PT 861 3133 190.0 4.1 0.0 27 13:01:46 Start Pump Check Manually 1340 3161 196.2 4.1 0.0 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Stage 6 The average treating pressure on PAD was around 2,900 psi, after 1-3 PPA Scour and 1 PPA 16/20 CSG-IV 6% were going through the formation, the pressure fell to 2,362 psi. Then during the proppant steps treating pressure was gradually increasing from 2,362 to 5,161 psi. While pumping Stage 6, chunks of frozen sand and ice obstructions were found on the gates. In order to avoid concentration spikes when blockage was passing the gates, crew was opening the gates slowly and adjusting accordingly when staging over to higher PPA step. A summary of the Stage and it’s measured pump schedule is below: Summary of Pressures When Collet Seats Collet #5 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure Sleeve was shifted by CTBottomhole Pressure Summary of Stage 6 Total Proppant Pumped (lb)290,672 Max pumping Rate (bpm)40.9 Total Proppant in Formation (lb)290,672 Average Pumping Rate (bpm)38.2 CarboLite 40/70 (lb) per Load Tickets 11,487 Maximum Treating Pressure (psi)5,116 CarboLite 16/20 (lb) per Load Tickets 262,434 Average Treating Pressure (psi)3,230 6% S901 ScaleGUARD IV (lb) per Load Tickets 16,751 Average Water Temperature (F)81.2 Total Slurry Pumped (bbl)2,034.5 Average Viscosity (cP)18.0 YF125ST Pumped (bbl)1,731.0 WF125 Pumped (bbl)0 12:59:00 13:07:20 13:15:40 13:24:00 13:32:20 13:40:40 13:49:00 13:57:20 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, Stage 6 11-29-2024 0 Collet/Ball#6 hit the sleeve Drop Rate for Ball/Collet#6 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Line out XL 63.7 20.6 3.1 YF125ST 2663 0 0 0 2 PAD st6 237.6 39.1 6.1 YF125ST 9978 0 0 0 3 1.0 PPA Scour 60 39.4 1.5 YF125ST 2455 CarboLite 40/70 0.9 0.6 1048 4 3.0 PPA Scour 146 39.5 3.7 YF125ST 5499 CarboLite 40/70 3.7 2.6 10439 5 Resume PAD 50 40 1.2 YF125ST 2098 0 0 0 6 1.0 PPA 180 39.7 4.5 YF125ST 7244 16/20 CSG-IV 6%1.3 1 7306 7 2.0 PPA 200 39.6 5.1 YF125ST 7736 16/20 CSG-IV 6%2.1 1.9 15383 8 4.0 PPA 220 39.7 5.5 YF125ST 7877 16/20 CSG-IV 6%4.2 3.9 31602 9 6.0 PPA 220 39.7 5.5 YF125ST 7319 16/20 CSG-IV 6%6.1 5.9 44553 10 8.0 PPA 220 39.6 5.6 YF125ST 6861 16/20 CSG-IV 6%8.1 7.8 55206 11 10.0 PPA 200 39.6 5.1 YF125ST 5846 16/20 CSG-IV 6%10.3 9.8 59254 12 12.0 PPA 197.8 39.6 5 YF125ST 5479 16/20 CSG-IV 6%12.2 11.7 65881 13 Clear Lines & Spacer 36.4 39.7 0.9 YF125ST 1523 0 0 0 14 Drop Collet#6 3 39.5 0.1 YF125ST 126 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Line out XL 20.6 29.8 2127 2757 2008 2 PAD st6 39.1 40.0 2894 3098 2654 3 1.0 PPA Scour 39.4 40.0 2761 2838 2702 4 3.0 PPA Scour 39.5 39.9 2616 2735 2484 5 Resume PAD 40.0 40.2 2473 2526 2448 6 1.0 PPA 39.7 40.0 2530 2608 2438 7 2.0 PPA 39.6 39.8 2377 2437 2338 8 4.0 PPA 39.7 39.9 2432 2519 2366 9 6.0 PPA 39.7 40.0 2886 3313 2522 10 8.0 PPA 39.6 39.8 3671 4067 3310 11 10.0 PPA 39.6 40.0 4292 4555 4064 12 12.0 PPA 39.6 40.2 4827 5061 4556 13 Clear Lines & Spacer 39.7 40.9 4721 5116 4567 14 Drop Collet#6 39.5 39.6 4617 4623 4611 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:02:16 Start Line out XL Manually 2506 3218 199.5 12.5 0.0 2 13:02:16 Start Propped Frac Manually 2506 3218 199.5 12.5 0.0 3 13:02:16 Start Stage 6 Automatically 2506 3218 199.5 12.5 0.0 4 13:03:53 Stage at Perfs: Ball To Seat 2034 3195 31.3 20.7 0.0 5 13:04:40 XL sample is good 2010 3201 47.6 20.7 0.0 6 13:05:21 Start PAD st6 Manually 2861 3232 63.7 32.0 0.0 7 13:08:35 Stage at Perfs: Pump Check 2896 3329 187.6 40.0 0.0 8 13:08:40 Stage at Perfs: Line out XL 2883 3332 190.9 39.9 0.0 9 13:10:15 Stage at Perfs: PAD st6 2842 3385 254.1 40.0 0.0 10 13:11:26 Start 1.0 PPA Scour Manually 2827 3347 301.5 40.0 0.0 11 13:11:26 Started Pumping Prop 2827 3347 301.5 40.0 0.0 12 13:12:58 Start 3.0 PPA Scour Automatically 2731 3336 361.8 39.4 0.9 13 13:16:15 Stage at Perfs: 1PPA Scour 2517 3354 491.6 39.5 3.2 14 13:16:39 Start Resume PAD Manually 2479 3312 507.5 39.9 0.8 15 13:16:45 Stopped Pumping Prop 2475 3306 511.4 40.0 0.1 16 13:17:46 Stage at Perfs: 3PPA Scour 2519 3332 552.2 40.0 0.0 17 13:17:54 Start 1.0 PPA Automatically 2545 3336 557.5 40.0 0.0 18 13:17:55 Started Pumping Prop 2543 3339 558.1 40.0 0.0 19 13:21:26 Stage at Perfs: Resume PAD 2454 3321 697.6 39.9 1.0 20 13:22:27 Start 2.0 PPA Automatically 2434 3343 738.0 39.6 1.1 21 13:22:42 Stage at Perfs: 1.0 PPA 2433 3350 747.9 39.9 1.6 22 13:23:17 Ball/Collet#6 is loaded to Ball Launcher 2415 3363 771.1 39.5 2.0 23 13:27:15 Stage at Perfs: 2.0 PPA 2365 3329 927.9 39.7 2.0 24 13:27:30 Start 4.0 PPA Automatically 2371 3332 937.8 39.8 1.9 25 13:32:18 Stage at Perfs: 4.0 PPA 2500 3384 1128.3 39.6 4.0 26 13:33:03 Start 6.0 PPA Automatically 2522 3390 1158.1 39.7 4.0 27 13:37:51 Stage at Perfs: 6.0 PPA 3234 3339 1348.5 39.5 6.1 28 13:38:35 Start 8.0 PPA Automatically 3313 3347 1377.5 39.7 6.0 29 13:43:23 Stage at Perfs: 8.0 PPA 4020 3372 1567.6 39.6 7.9 30 13:44:09 Start 10.0 PPA Automatically 4057 3373 1597.9 39.6 7.8 31 13:48:57 Stage at Perfs: 10.0 PPA 4543 3375 1787.7 39.0 9.9 32 13:49:12 Start 12.0 PPA Automatically 4556 3376 1797.6 39.7 9.9 33 13:54:00 Stage at Perfs: 12.0 PPA 5046 3369 1987.9 39.7 12.3 34 13:54:11 Start Clear Lines & Spacer Manually 5084 3366 1995.2 40.3 2.7 35 13:54:13 Stopped Pumping Prop 5091 3372 1996.6 40.4 1.0 36 13:55:06 Start Drop Collet#6 Manually 4620 3361 2031.6 39.6 0.0 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Stage 7 Once the Collet/Ball#6 shifted the sleeve the pressure transition from Stage 6 to 7 was atypical. The decision was made to pump Scour 1-3 PPA 40/70 CarboLite. The average treating pressure on PAD was around 3,300 psi. The pressure then slowly decreased to 2,304 psi while 1-3 PPA Scour and 1 PPA 16/20 CSG-IV 6% were going through the formation. After that, the pressure was gradually increasing from 2,304 to 4,909 psi and then screen out occurred. Collet/Ball#7 was dropped few seconds before screen out occurred. While pumping Stage 7, chunks of frozen sand and ice obstructions were found on the gates. In order to avoid concentration spikes when blockage was passing the gates, crew was opening the gates slowly and adjusting accordingly when staging over to higher PPA step. A summary of the Stage and it’s measured pump schedule is below: Summary of Pressures When Collet Seats Collet #6 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,617 4,170 4,478 Bottomhole Pressure 3,073 5,628 6,019 Summary of Stage 7 Total Proppant Pumped (lb)292,623 Max pumping Rate (bpm)40.7 Total Proppant in Formation (lb)250,039 Average Pumping Rate (bpm)37.8 CarboLite 40/70 (lb) per Load Tickets 12,188 Maximum Treating Pressure (psi)8,618 CarboLite 16/20 (lb) per Load Tickets 263,609 Average Treating Pressure (psi)3,267 6% S901 ScaleGUARD IV (lb) per Load Tickets 16,826 Average Water Temperature (F)89.0 Total Slurry Pumped (bbl)2,064.7 Average Viscosity (cP)17.3 YF125ST Pumped (bbl)1,760.0 WF125 Pumped (bbl)0 13:57:02 14:05:22 14:13:42 14:22:02 14:30:22 14:38:42 14:47:02 14:55:22 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, Stage 6 11-29-2024 Drop Rate for Ball/Collet#6 Collet/Ball#6 hit the sleeve 7 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st7 138 39.9 3.5 YF125ST 5796 0.0 0.0 0 2 Slow For Seat 52.4 21.8 2.7 YF125ST 2201 0.0 0.0 0 3 Resume PAD 109.4 36.3 3.1 YF125ST 4597 0.0 0.0 0 4 1.0 PPA Scour 60.4 39.4 1.5 YF125ST 2448 CarboLite 40/70 1.1 0.8 1409 5 3.0 PPA Scour 162.5 39.6 4.1 YF125ST 6168 CarboLite 40/70 3.0 2.4 10779 6 Resume PAD 50.2 40.2 1.3 YF125ST 2107 2.0 0.0 0 7 1.0 PPA 180 39.7 4.5 YF125ST 7254 16/20 CSG-IV 6%1.1 0.9 7079 8 2.0 PPA 200 39.6 5.1 YF125ST 7721 16/20 CSG-IV 6%2.1 2.0 15736 9 4.0 PPA 220 39.6 5.6 YF125ST 7866 16/20 CSG-IV 6%4.1 3.9 31840 10 6.0 PPA 220 39.7 5.5 YF125ST 7327 16/20 CSG-IV 6%6.1 5.9 44366 11 8.0 PPA 220 39.7 5.5 YF125ST 6854 16/20 CSG-IV 6%8.1 7.8 55336 12 10.0 PPA 200 39.6 5.1 YF125ST 5859 16/20 CSG-IV 6%10.1 9.8 58972 13 12.0 PPA 201.1 39.6 5.1 YF125ST 5568 16/20 CSG-IV 6%12.2 11.7 67106 14 Clear Lines & Spacer 50.7 35 2.5 YF125ST 2153 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st7 39.9 40.1 3872 4760 2939 2 Slow For Seat 21.8 40.1 2607 4513 1505 3 Resume PAD 36.3 40.1 3282 3782 2659 4 1.0 PPA Scour 39.4 39.9 2843 2983 2725 5 3.0 PPA Scour 39.6 39.8 2607 2764 2459 6 Resume PAD 40.2 40.6 2496 2539 2459 7 1.0 PPA 39.7 40.0 2508 2597 2401 8 2.0 PPA 39.6 39.7 2340 2412 2300 9 4.0 PPA 39.6 39.8 2455 2602 2333 10 6.0 PPA 39.7 39.9 2972 3374 2593 11 8.0 PPA 39.7 40.1 3720 4075 3370 12 10.0 PPA 39.6 40.0 4202 4454 4043 13 12.0 PPA 39.6 40.4 4642 4899 4445 14 Clear Lines & Spacer 35.0 40.7 5197 8618 3005 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:55:11 Start PAD st7 Automatically 4723 3368 0.0 40.0 0.0 2 13:55:11 Start Propped Frac Automatically 4723 3368 0.0 40.0 0.0 3 13:55:11 Start Stage7 Automatically 4723 3368 0.0 40.0 0.0 4 13:58:38 Start Slow For Seat Automatically 2801 3343 137.8 40.0 0.0 5 13:59:05 Stage at Perfs: Clear Lines & Spacer 1584 3316 150.1 18.5 0.0 6 14:00:09 Ball/Collet#6 Hit the Sleeve 3466 3363 169.2 17.9 0.0 7 14:01:07 Stage at Perfs: Drop Collet#6 3591 3333 186.5 17.7 0.0 8 14:01:18 Stage at Perfs: PAD st7 2952 3306 189.7 17.9 0.0 9 14:01:18 Start Resume PAD Manually 2952 3306 189.7 17.9 0.0 10 14:04:26 Start 1.0 PPA Scour Manually 2949 3282 299.5 40.0 0.0 11 14:04:26 Started Pumping Prop 2949 3282 299.5 40.0 0.0 12 14:04:45 1ppa scour 40-70 2895 3284 312.2 39.7 0.5 13 14:04:58 Stage at Perfs: Slow For Seat 2869 3286 320.7 39.1 0.9 14 14:05:58 Start 3.0 PPA Scour Manually 2741 3284 359.9 39.6 1.0 15 14:06:15 3 ppa scour 40-70 2730 3284 371.1 39.6 1.1 16 14:06:18 Stage at Perfs: Resume PAD 2727 3287 373.1 39.5 1.1 17 14:09:04 Stage at Perfs: 1.0 PPA 2543 3285 482.7 39.7 3.0 18 14:10:04 Start Resume PAD Manually 2458 3283 522.4 40.0 0.8 19 14:10:06 Stopped Pumping Prop 2465 3285 523.7 39.9 0.7 20 14:10:35 Stage at Perfs: 1.0 PPA 2503 3286 543.1 40.6 0.0 21 14:11:19 Start 1.0 PPA Manually 2547 3288 572.6 40.0 0.0 22 14:11:43 Started Pumping Prop 2535 3289 588.6 39.5 0.0 23 14:13:24 Ball/Collet#7 is loaded to Ball Launcher 2565 3305 655.1 39.7 1.1 24 14:14:40 Stage at Perfs: Resume PAD 2423 3310 705.5 39.7 1.0 25 14:15:52 Start 2.0 PPA Automatically 2414 3322 753.1 39.5 1.0 26 14:15:56 Stage at Perfs: 1.0 PPA 2400 3319 755.7 39.8 1.1 27 14:20:30 Stage at Perfs: 1.0 PPA 2332 3342 936.5 39.6 2.0 28 14:20:55 Start 4.0 PPA Automatically 2332 3346 953.0 39.5 2.0 29 14:25:33 Stage at Perfs: Resume PAD 2561 3351 1136.3 39.8 4.0 30 14:26:28 Start 6.0 PPA Automatically 2598 3355 1172.6 39.6 4.1 31 14:31:05 Stage at Perfs: 1.0 PPA 3299 3365 1355.8 39.7 6.0 32 14:32:01 Start 8.0 PPA Automatically 3377 3364 1392.9 39.5 5.9 33 14:36:38 Stage at Perfs: 2.0 PPA 4018 3359 1575.8 39.7 8.0 34 14:37:34 Start 10.0 PPA Automatically 4074 3358 1613.0 40.0 8.0 35 14:42:12 Stage at Perfs: 4.0 PPA 4415 3332 1796.3 40.0 10.0 36 14:42:37 Start 12.0 PPA Automatically 4459 3329 1812.9 39.7 10.0 37 14:47:14 Stage at Perfs: 6.0 PPA 4865 3306 1995.8 39.9 11.3 38 14:47:41 Start Clear Lines & Spacer Manually 4893 3301 2013.7 40.1 3.8 39 14:47:43 Stopped Pumping Prop 4899 3300 2015.0 39.7 2.5 40 14:48:38 Dropped Ball/Collet#7 4794 3300 2017.7 40.7 0.0 41 14:49:30 Stopped Pumping 5418 3405 2061.9 0.0 0.0 42 14:49:46 SD 4872 3379 2061.9 0.0 0.0 43 14:49:56 GORV popped off 4563 3364 2061.9 0.0 0.0 44 14:54:36 Started Pumping 2372 3091 2061.9 3.0 0.0 45 15:08:05 LRS pumping freeze protect 4388 2782 2064.4 0.0 0.0 46 15:23:31 Fanning out pumps -3 2229 2064.4 0.0 0.0 47 16:22:10 Freeze Protected Pumps 4 -3681 2064.4 35.2 0.0 FracCAT Treatment Report Well : NDB-025 Stages 8 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : December 08, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi)364 Initial BHP at Gauge (psi)2,028 Final Surface ISIP (psi)NA/ Screenout Final ISIP at Gauge (psi)NA/ Screenout Surface Shut in Pressure (psi)NA/ Screenout BH Shut in Pressure (psi)NA/ Screenout Maximum Treating Pressure (psi)8,453 BH Gauge at 8,191 ft MD, 4,334 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)2,357.1 Total Proppant Pumped (lb) (per Load Tickets)239,460 Total YF126ST Past Wellhead (bbl)1,709.2 Total Proppant in Formation (lb)208,589 Total WF126 Past Wellhead (bbl)401.8 Total S522 - 16/20 CarboLite per Load Tickets (lb)204,676 Total Freeze Protect Past Wellhead (bbl) by SLB 15.0 Total 6% S901 ScaleGUARD IV per Load Tickets (lb)13,064 Total Freeze Protect Past Wellhead (bbl) pumped by LRS 5.0 Total S522 - 40/70 CarboLite per Load Tickets (lb) 21,720 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal)108 107.8 M275 (lb)156 92.2 J450 (gal)50 49.7 J753 (gal)26.0 7.1 J580 (lb)2,727 2.394 J475 (lb)495 491.2 J532 (gal)244 242.7 J134 (lb)34 0 J511 (lb)600 157.2 D206 (gal)2.0 1.8 M002 (lbs)0.5 0.25 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unkn own data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger 's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is a ware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Summary On December 8, 2024, SLB performed a hydraulic fracturing treatment on Stage 8 of NDB-025. The initial design called for the completion of stages 8-11 with total of 978,654 lbs of proppant in 7,595 bbl of slurry. While pumping Stage 8, chunks of frozen sand and ice obstructions were found on the gates. In order to avoid concentration spikes when blockage was passing the gates, crew was opening the gates slowly and adjusting accordingly when staging over to higher PPA step. When 9 PPA was passing to the formation, the slope of the BH Pressure changed and the decision was made by Santos to cut prop and stage over to flush. Flush was pumped at about 58bbl from the Blender, then Screen out occurred, Ball/Collet#8 for the frac sleeve#9 was launched. By physical load cell count on SES, a total of 239,460 pounds of proppant was pumped and 280,589 was placed into formation in 2,357.1 bbl of slurry. Stages 8 consisted of a PAD, two Scour Steps 1-3PPA with proppant 40/70 CBL and 6 proppant steps 1-3-5-7-9-10 PPA, Pump trips were staggered from 7,400 to 7,900 psi. The GORV was set to 8,200 psi. Summary of Stages 8 Material Actual Stage 8 Design for Stg 8-11 Slurry Volume (bbl)2,357.1 5,996 Clean Fluid Volume(bbl)2,111.0 5,101 Proppant (lb)239,460 791,299 13:51:28 14:09:48 14:28:08 14:46:28 15:04:48 15:23:08 15:41:28 15:59:48 16:18:08 16:36:28 16:54:48 17:13:08 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, DF, Stage 8 12-08-2024 0 Stage #8DFITDispl PT Ball to Seat Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat, DFIT. PT displacement followed by 10 min SD, then pumped Ball to Seat and XL DFIT which followed by LG Flush and SD with pressure decline recording for 60 min. A summary of the stage and pressures as follows: Summary of Stage Displacement PT, Ball to Seat and DFIT Total Proppant Pumped (lb)0 Max pumping Rate (bpm)40.2 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)23.8 Total Slurry Pumped (bbl)641.8 Maximum Treating Pressure (psi)3,906 YF126ST Pumped (bbl)225.0 Average Treating Pressure (psi)2,718 WF126 Pumped (bbl)401.8 Average Water Temperature (F)81.5 Freeze Protect (bbl) displaced downhole 15.0 Average Viscosity (cP)19.0 13:51:28 14:01:28 14:11:28 14:21:28 14:31:28 14:41:28 14:51:28 15:01:28 15:11:28 15:21:28 15:31:28 15:41:28 15:51:28 16:01:28 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, DF 12-08-2024 0 DFITDisplacement PT Ball to Seat Ball seated Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displacement PT 15 3.8 3.9 FP 630 0 0 0 2 Displacement PT 25.3 3.8 7.3 WF126 1063 0 0 0 3 Ball To Seat 206.2 11.9 36.7 WF126 8662 0 0 0 4 XL DFIT 225 39.7 5.7 YF126ST 9449 0 0 0 5 Flush 170.3 39.8 4.3 WF126 7151 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1,2 Displacement PT 3.8 4.2 1810 2244 360 3 Ball To Seat 11.9 37.9 2327 3906 1091 4 XL DFIT 39.7 40.2 3512 3793 3296 5 Flush 39.8 40 3224 3291 764 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 9:28:17 Flood Lines With Diesel -5 -3 0.0 0.0 0.0 2 9:29:51 LRS Pressure Testing -5 -3 0.0 5.4 0.0 3 9:30:16 Start Priming pumps With Diesel -3 -3 0.0 5.4 0.0 4 10:10:47 Low Pressure Test 635 -7 0.0 0.0 0.0 5 10:18:09 Mid Pressure Test 4970 -9 0.0 0.0 0.0 6 10:22:17 Bleed Off Pressure, Fix HP Leak 11 -9 0.0 0.0 0.0 7 10:28:03 Mid Pressure Test 4940 -10 0.0 0.0 0.0 8 10:33:13 GORV HP Leak 4 -11 0.0 0.0 0.0 9 11:13:19 Low Pressure Test 391 -16 0.0 0.0 0.0 10 11:25:31 High Pressure Test 9594 -16 0.0 0.0 0.0 11 11:31:31 Good Test 9071 -17 0.0 0.0 0.0 12 11:32:28 Tanks 8 - 9 No Suction, investigating 9025 -16 0.0 0.0 0.0 13 12:04:56 PCM Eductor Pressure Issue 648 2955 0.0 0.0 0.0 14 13:15:13 Mixing Gel 26#92 2891 0.0 0.0 0.0 15 13:42:56 Finished Safety meeting 48 2874 0.0 0.0 0.0 16 13:55:45 Linear sample 11cP 80degF 85 2963 0.0 0.0 0.0 17 13:56:42 Ball Loaded In Launcher Tree 87 2963 0.0 0.0 0.0 18 13:58:15 Bump Up Line Pressure To 1,000 1015 2962 0.0 0.0 0.0 19 14:00:53 Open Well 363 2960 0.0 0.0 0.0 20 14:01:15 Start Displacement PT Automatically 362 2959 0.0 0.0 0.0 21 14:01:15 Start Propped Frac Automatically 362 2959 0.0 0.0 0.0 22 14:01:15 Start step Automatically 362 2959 0.0 0.0 0.0 23 14:01:25 Started Pumping 362 2958 0.0 0.0 0.0 24 14:12:32 Ball launched 1946 2927 38.4 3.8 0.0 25 14:12:58 Stopped Pumping 1630 2918 40.1 3.8 0.0 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 26 14:13:47 SD for 10 min 1267 2899 40.1 0.0 0.0 27 14:15:20 Ball in free fall 1147 2897 40.1 0.0 0.0 28 14:27:17 Started Pumping 873 2894 40.1 0.0 0.0 29 14:27:20 Start Ball To Seat Manually 983 2896 40.1 0.0 0.0 30 14:47:49 WF 80F 18cP 1695 3110 122.2 4.0 0.0 31 14:57:59 Ball seated 1793 3135 163.1 4.0 0.0 32 15:01:03 Stage at Perfs: Displacement PT 1833 3147 175.5 4.0 0.0 33 15:02:40 XL sample is good 2979 3200 201.9 22.5 0.0 34 15:03:10 Stage at Perfs: Ball To Seat 3650 3238 216.5 31.8 0.0 35 15:04:01 Start XL DFIT Manually 3779 3256 247.0 38.2 0.0 36 15:08:27 Stage at Perfs: XL DFIT 3375 3309 423.2 40.0 0.0 37 15:09:05 82degF 20cP 3333 3339 448.5 39.8 0.0 38 15:09:41 Start LG Flush Automatically 3278 3365 472.3 39.8 0.0 39 15:13:59 Stopped Pumping 1136 3199 641.8 8.6 0.0 40 15:14:48 SD monitor pressure decline 1069 3207 641.8 0.0 0.0 41 15:33:30 Reel Back Chemical Hoses To Prevent Freezing 793 2916 641.8 0.0 0.0 42 16:20:55 Radio check 494 2406 641.8 0.0 0.0 43 16:25:36 LRS Pressure Up IA 476 2364 641.8 0.0 0.0 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Stage 8 After DFIT analysis, Santos decided to make some changes in Design - decrease max prop conc from 12 PPA to 11 PPA. Then while pumping PAD of Stage 8, there were some changes of the schedule on the fly: Max proppant Conc = 10PPA, Concentration steps changed from 1-2-4-6-8-10-11 PPA to 1-2-5-7-9-10 PPA and Slurry Volume changed on proppant steps from 150-175-190-190-190- 190 bbl to 180-200-230-230-215-180 bbl. The average treating pressure on PAD was around 3,250 psi, after 1-3 PPA Scour 40/70 CarboLite and 1 PPA 16/20 CSG-IV 6% were going through the formation, the pressure fell to 2,492 psi. Then during the proppant steps treating pressure was gradually increasing from 2,492 to 5,065 psi. When 9 PPA was passing to the formation, the slope of the BH Pressure changed and the decision was made by Santos to cut prop and stage over to flush. Flush was pumped at about 58bbl from the Blender, then Screen out occurred, Ball/Collet#8 for the Frac Sleeve#9 was launched. While pumping Stage 8, chunks of frozen sand and ice obstructions were found on the gates. In order to avoid concentration spikes when blockage was passing the gates, crew was opening the gates slowly and adjusting accordingly when staging over to higher PPA step. A summary of the Stage and it’s measured pump schedule is below: Summary of Pressures When Collet Seats Collet #7 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure Sleeve was shifted by CTBottomhole Pressure Summary of Stage 8 Total Proppant Pumped (lb)239,460 Max pumping Rate (bpm)40.4 Total Proppant in Formation (lb)208,589 Average Pumping Rate (bpm)38.0 CarboLite 40/70 (lb) per Load Tickets 21,720 Maximum Treating Pressure (psi)8,453 CarboLite 16/20 (lb) per Load Tickets 204,676 Average Treating Pressure (psi)3,534 6% S901 ScaleGUARD IV (lb) per Load Tickets 13,064 Average Water Temperature (F)84.7 Total Slurry Pumped (bbl)1,715.3 Average Viscosity (cP)18.5 YF126ST Pumped (bbl)1,484.2 WF126 Pumped (bbl)0 16:21:28 16:28:08 16:34:48 16:41:28 16:48:08 16:54:48 17:01:28 17:08:08 17:14:48 17:21:28 17:28:08 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 2 4 6 8 10 12 14 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con PRC Plot Santos NDB-025, Stage 8 12-08-2024 0 Frozen sand in the hopper Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Line out XL 18.7 21.5 1.4 YF126ST 783 0 0 0 2 PAD st8 241.8 39.6 6.1 YF126ST 10150 0 0 0 3 1.0 PPA Scour 60 39.5 1.5 YF126ST 2459 CarboLite 40/70 1 0.5 1985 4 3.0 PPA Scour 127 39.7 3.2 YF126ST 4737 CarboLite 40/70 3.4 2.9 19735 5 Resume PAD 50 40 1.2 YF126ST 2097 0 0 0 6 1.0 PPA 180.2 39.7 4.5 YF126ST 7225 16/20 CSG-IV 6%1.2 1.1 8241 7 3.0 PPA 200.3 39.8 5 YF126ST 7437 16/20 CSG-IV 6%3.4 2.9 23414 8 5.0 PPA 230.4 39.7 5.8 YF126ST 7949 16/20 CSG-IV 6%5.9 4.9 41627 9 7.0 PPA 230.5 39.6 5.8 YF126ST 7450 16/20 CSG-IV 6%7.2 6.7 53723 10 9.0 PPA 215 39.7 5.4 YF126ST 6481 16/20 CSG-IV 6%9.2 8.9 61388 11 10.0 PPA 95.3 39.7 2.4 YF126ST 2795 16/20 CSG-IV 6%10 9.8 29347 12 Clean Lines & Spacer 37.9 39.9 1 YF126ST 1584 0 0 0 13 Drop Collet#8 3 39.9 0.1 YF126ST 126 0 0 0 14 XL Flush 25.2 34.3 1.3 YF126ST 1064 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Line out XL 21.5 32.4 2606 3279 489 2 PAD st8 39.6 40.3 3243 3569 3134 3 1.0 PPA Scour 39.5 39.9 3120 3161 3061 4 3.0 PPA Scour 39.7 40.3 2972 3058 2785 5 Resume PAD 40.0 40.4 2777 2811 2743 6 1.0 PPA 39.7 40.0 2760 2851 2664 7 3.0 PPA 39.8 39.9 2561 2665 2487 8 5.0 PPA 39.7 40.1 2626 2778 2537 9 7.0 PPA 39.6 39.9 3082 3446 2747 10 9.0 PPA 39.7 40.2 3952 4433 3446 11 10.0 PPA 39.7 40.0 4634 4984 4436 12 Clean Lines & Spacer 39.9 40.4 4699 5029 4439 13 Drop Collet#8 39.9 39.9 4734 4752 4722 14 XL Flush 34.3 39.9 5716 8453 4784 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 16:27:51 Started Pumping 488 2915 641.8 0.0 0.0 2 16:27:54 Start Line out XL Manually 489 2933 641.8 0.0 0.0 3 16:27:54 Start Propped Frac Manually 489 2933 641.8 0.0 0.0 4 16:27:54 Start Stage 8 Automatically 489 2933 641.8 0.0 0.0 5 16:28:54 Stage at Perfs: LG Flush 2901 3058 6.2 19.8 0.0 6 16:29:08 XL sample is good 3165 3066 12.0 28.2 0.0 7 16:29:22 Start PAD st8 Manually 3366 3069 19.2 33.6 0.0 8 16:33:21 Stage at Perfs: Line out XL 3178 3155 176.5 39.9 0.0 9 16:33:49 Stage at Perfs: PAD st8 3186 3173 195.1 40.0 0.0 10 16:35:28 Start 1.0 PPA Scour Manually 3153 3230 261.0 39.8 0.0 11 16:35:28 Started Pumping Prop 3153 3230 261.0 39.8 0.0 12 16:35:56 81degF 18cP 3129 3246 279.6 39.7 0.6 13 16:37:00 Start 3.0 PPA Scour Automatically 3039 3274 321.6 39.3 1.1 14 16:39:54 Stage at Perfs: 1 PPA Scour 2822 3229 436.8 39.5 3.1 15 16:40:11 Deactivated Extend Stage 2811 3231 448.0 39.4 1.3 16 16:40:11 Start Resume PAD Manually 2811 3231 448.0 39.4 1.3 17 16:40:13 Stopped Pumping Prop 2815 3232 449.3 39.5 0.7 18 16:41:24 Started Pumping Prop 2802 3248 496.7 39.8 0.0 19 16:41:25 Stage at Perfs: 3 PPA Scour 2803 3248 497.4 39.7 -0.0 20 16:41:26 Start 1.0 PPA Automatically 2804 3248 498.0 39.7 -0.0 21 16:42:04 Step 1.0 PPA extended from 150bbl to 180bbl 2828 3258 523.1 39.3 1.2 22 16:44:36 Stage at Perfs: Resume PAD 2686 3303 623.8 40.0 1.2 23 16:45:51 Stage at Perfs: 1.0 PPA 2672 3324 673.6 39.8 1.1 24 16:45:58 Start 3.0 PPA Manually 2657 3325 678.2 39.9 1.2 25 16:46:06 3PPA 2651 3327 683.5 39.9 1.2 26 16:50:15 Step 3.0 PPA slurry volume changed to 200bbl 2514 3292 848.7 39.8 3.0 27 16:50:23 Stage at Perfs: 3.0 PPA 2523 3293 854.0 39.8 3.0 28 16:51:00 Start 5.0 PPA Manually 2540 3302 878.5 39.8 3.0 29 16:51:52 Step 5.0 PPA slurry volume changed to 230bbl 2589 3312 912.8 39.8 3.8 30 16:52:07 5ppa 2572 3316 922.8 40.0 4.0 31 16:53:34 85degF 17cP 2605 3329 980.3 39.7 5.1 32 16:55:25 Stage at Perfs: 5.0 PPA 2675 3347 1053.9 39.8 5.1 33 16:56:48 Start 7.0 PPA Manually 2783 3356 1108.9 39.5 5.2 34 16:56:56 Step 7.0 PPA slurry volume changed to 230bbl 2771 3354 1114.2 39.4 5.1 35 16:57:00 7ppa 2780 3356 1116.8 39.6 5.1 36 16:59:18 86degF 18cP 3019 3255 1207.9 39.6 6.8 37 17:01:14 Stage at Perfs: 7.0 PPA 3321 3270 1284.6 39.5 7.0 38 17:02:37 Start 9.0 PPA Manually 3461 3280 1339.5 39.4 7.3 39 17:02:39 Step 9.0 PPA slurry volume changed to 215bbl 3456 3279 1340.8 39.4 7.2 40 17:02:48 9ppa 3457 3278 1346.7 39.3 7.2 41 17:06:34 19cP 85degF 4227 3243 1496.0 39.5 9.1 42 17:07:03 Stage at Perfs: 9.0 PPA 4332 3209 1515.3 40.1 9.1 43 17:08:02 Start 10.0 PPA Manually 4436 3209 1554.5 39.8 9.2 44 17:08:08 Activated Extend Stage 4445 3212 1558.5 39.9 9.0 45 17:10:26 Cut prop due to BH pressure slope change 5026 3237 1649.8 40.1 5.4 46 17:10:26 Start Clean Lines & Spacer Manually 5026 3237 1649.8 40.1 5.4 47 17:10:28 Stopped Pumping Prop 5046 3231 1651.1 40.3 3.0 Client: Santos Well: NDB-025 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 48 17:11:23 Start Drop Collet#8 Manually 4759 3239 1687.7 39.9 0.0 49 17:11:28 Start PAD st9 Automatically 4910 3244 0.0 39.8 0.0 50 17:11:28 Start Propped Frac Automatically 4910 3244 0.0 39.8 0.0 51 17:11:28 Start Stage 9 Automatically 4910 3244 0.0 39.8 0.0 52 17:11:43 Activated Extend Stage 5097 3257 10.0 39.9 0.0 53 17:23:43 Stopped Pumping 5423 3223 24.4 0.2 0.0 54 17:12:51 SD 5121 3212 24.4 0.0 0.0 55 17:15:41 89degF 18cP 2040 3026 24.4 0.0 0.0 56 17:19:43 SO occurred 4989 3147 24.4 0.0 0.0 57 17:27:54 LRS Pump FP Down Wellhead 3114 3004 24.4 0.0 0.0 58 17:38:19 Linear Sample PCM 20cP 82 Deg F 4028 2977 24.4 0.0 0.0 59 17:52:51 Fanning Out Pumps 76 2743 24.4 19.9 0.0 11:09:00 13:55:40 16:42:20 19:29:00 22:15:40Time - hh:mm:ss01000200030004000500060007000Tr. Press - psi01020304050Slurry Rate - bbl/min 0123456789Prop Con - PPA Treating PressureAnnulus PressureBHPSlurry RateProp ConBH Prop ConDisplaceStage 9Stage 9Stage 10Stage 11Shutdown Due to SaharaShutdown Due to PumpsShutdown Due to J450Treatment Plot© Schlumberger 1994-2017SantosNDB-025, Stages 9-1112-31-202411:09:00 13:55:40 16:42:20 19:29:00 22:15:40Time - hh:mm:ss01000200030004000500060007000Tr. Press - psi01020304050Slurry Rate - bbl/min 0123456789Prop Con - PPA Treating PressureAnnulus PressureBHPSlurry RateProp ConBH Prop ConDisplaceStage 9Stage 9Stage 10Stage 11Shutdown Due to SaharaShutdown Due to PumpsShutdown Due to J450Treatment Plot© Schlumberger 1994-2017SantosNDB-025, Stages 9-1112-31-2024 16:26:29 16:47:19 17:08:09 17:28:59 17:49:49 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Lost Pump Lost Pump Drop Rate to Launch Collet Collet Seated Treatment Plot © Schlumberger 1994-2017 Santos NDB-025, Stage 9 12-31-2024 17:27:20 17:56:30 18:25:40 18:54:50 19:24:00 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Shutdown for Pumps Collet Seated Drop Rate to Launch Collet Treatment Plot © Schlumberger 1994-2017 Santos NDB-025, Stage 10 12-31-2024 19:02:34 19:15:04 19:27:34 19:40:04 19:52:34 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 10 20 30 40 50 Slurry Rate - bbl/min0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Shutdown Treatment Plot © Schlumberger 1994-2017 Santos NDB-025, Stage 11 12-31-2024 WELL TEST,1*6800$5< Doc No::7;$.B1'% Rev No:$B'5 Issued:-)HEUXDU\- GREEN Key BLUE Level 1 Group YELLOW Level 2 Global Product line or Function GREEN Level 3 Local – Regional/Area/Country :HOO&OHDQXS(QGRI:HOO5HSRUW 1RUWK$PHULFD2IIVKRUH 6$1726B3LNND'HYHORSPHQW 1'% :7;$.B1'%B5HY$ Completed by Name Checked by Name Approved by Name Index Santos – Pikka Development - Well Clean-Up and Shut-in/Build-up – NDB-025 Cover ................................................................................................................................................. 1 Index ............................................................................................................................................ 2 - 3 1. Introduction ............................................................................................................................. 4 - 8 2. Points of Contact .................................................................................................................... 9 - 10 3. Nomenclature ....................................................................................................................... 11- 13 4. Test Summary_ Well Clean-up Flow Period ...........................................................................͘͘ 14 - ϮϮ 5. Test Data Report_ Well Clean-up Flow Period .......................................................................͘͘ Ϯϯ - 2ϳ 6. Test Data Plots_ Well Clean-up Flow Period ................................................................................. Ϯϴ Bottom Hole Plot ............................................................................................................................... Ϯϵ Well Head / Choke Plot ..................................................................................................................... ϯϭ Well Head vs Bottom Hole Conditions Plot ........................................................................................ ϯϯ Production Rate (Test Separator Flow Meter) Plot ........................................................................... ϯϱ Production Rate (Tank Farm Strap) Plot ........................................................................................... ϯϳ Cumulative (Test Separator Flow Meter) Plot ................................................................................... ϯϵ Cumulative (Tank Farm Strap) Plot ................................................................................................... ϰϭ Production Ratio Plot ........................................................................................................................ ϰϯ Test Separator Plot ............................................................................................................................ ϰϱ WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 2 Index Santos – Pikka Development - Well Clean-Up and Shut-in/Build-up – NDB-025 7. Tank Farm Rates & Volumes ................................................................................................. ϰϳ - ϱϭ 8. Injection Well NDBi-014 Data ................................................................................................ ϱϮ – ϱϴ Well Head – Bottom Hole Plot ........................................................................................................ ϱϳ Injection Rate - Cumulative Plot ...................................................................................................... ϱϴ 9. Test Summary_Bottom Hole Shut-in / Build-up Period ............................................................ϱϵ-ϲϬ 10. Test Data Report_ Bottom Hole Shut-in / Build-up Period ...................................................... ϲϭ-ϲϲ Bottom Hole_Shut-in / Build-up Plot ...............................................................................................ϲϳ 11. Sequence of Events ............................................................................................................ ϲϴ - ϴϰ 12. Combined Meter Shrinkage Factor (CMSF) .......................................................................... ϴϱ - ϴϳ 13. Diagrams ................................................................................................................................... ϴϴ Process and Instrumentation Diagram (P&ID) ..........................................................................ϴϵ -ϵϳ Safety Analysis Function Evaluation (SAFE) Chart ..................................................................ϵϴ - ϭϬϬ General Arrangement Diagram (GAD) ..................................................................................ϭϬϭ - ϭϬϰ Process Flow Diagram (PFD) .................................................................................................ϭϬϱ - ϭϭϬ This report is based on sound engineering practices, but because of variable well conditions and other information which must be relied upon, Expro Americas, Inc. makes no warranty, expressed or implied, as to the accuracy of the data or any calculations or opinions expressed herein. You agree that Expro Americas, Inc. shall not be liable for any loss of damage whether due to negligence or otherwise arising out of or in connection with such data, calculations, or opinions. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 3 Santos – Pikka Development – NDB-025 SECTION 1 INTRODUCTION WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 4 Introduction February 10th, 2025 Santos Pikka Development – NDB-025 Nanushuk 3 Reservoir Well Type: Injector To Whom It May Concern: Please find enclosed the well-clean-up and shut-in/build-up report, plots, and associated data for the well referenced NDB-025. The well clean-up flow period(s) and well shut-in / build up period(s) are defined as following: Well Clean-Up Flow Period: Start of Flow Period: February 10th, 2025 7:30:00 End of Flow Period: February 13th, 2025 10:00:00 NDB-025 was shut-in for weather conditions and then the clean-up operations were once again resumed on the following days. Start of Flow Period: February 15 th, 2025 15:30:00 End of Flow Period: February 17th, 2025 6:00:00 Well Shut-In & Build-Up Period: Start of Build-Up Period: February 17th, 2025 00:00:00 End of Build-Up Period: February 18th, 2025 15:00:00 Note: NDB-025 was continuously monitored, and downhole data reports were sent out daily as per requested time frequency. For the End of Well Report, the above dates are captured in the test summary and plotted. Expro conducted well testing / well clean-up operations within the facility start-up at Nanushuk Drill site – B (ND-B) on the North Slope Basin of Alaska. ND-B, as part of the Pikka Unit, is located 52 miles west of Deadhorse and approximately 6 miles from Nuiqsut. The flowback operations comprised of a well clean-up period and one main Shut-in/Build-up period. During the well clean-up period, well effluent was routed through Expro’s Surface Test Equipment to measure and record the flowing parameters of the well. Effluent from the well was first routed through Expro’s Ball Catcher which was designed to retrieve metallic spheres deployed during frac operations without interrupting the flow of the well. Once effluent exited the Ball Catcher, well fluids entered the Expro DPI CyFi Desander, which was composed of two vessels that could operate in series or parallel, for the purpose of separating solids from the produced fluids. This vessel was equipped with an isolated drain line routed to a horizontal Atmospheric 400 bbl Sand Tank to facilitate disposal of accumulated solids. Pressure differential across the Expro DPI CyFi Desander was monitored in real-time utilizing Expro’s Data Acquisition system (DAQ) and gave indication of an accumulation of sand in the vessel. Fluid samples taken upstream of the Expro DPI CyFi Desander alerted to the presence of sediment in the flow stream throughout the well clean-up period. Monitoring the Expro DPI CyFi Desander System differential pressure along with fluid samples alerted personnel to the presence of solids and to act accordingly by dumping sands to the 400 bbl Atmospheric Horizontal Sand Tank. The disposal feature on the Expro DPI CyFi Desander was utilized multiple WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 5 Introduction times during the clean-up period which equated to an approximate total of 55.12 bbls of sand accumulated in the 400 bbls Atmospheric horizontal Sand Tank. Effluent exiting the Expro DPI CyFi Desander unit was next routed through Expro’s Choke Manifold. The choke served as the primary flow control device and regulated pressures and fluid rates into the downstream equipment. Occasionally well debris would accumulate in the flow cavity of the adjustable choke and cause a disruption. To free the adjustable choke of debris and re-establish the desirable flow parameters, the adjustable choke was slightly turned in and out called “Rocking the Choke.” Prior to flow operations, a baseline thickness reading was identified on surface test flowline piping for critical erosion points and those selected areas were marked. During flowing operations, the Expro Well Test team performed thickness checks on these selected points for critical erosion when sand/solids were observed during sparging of the Expro DPI CyFi Desander. After effluent passed through the Expro Choke Manifold, it wasĚŝƌĞĐƚĞĚƚŽďLJƉĂƐƐ džƉƌŽ>ŝŶĞ,ĞĂƚĞƌ which ŝƐ equipped with an in-line adjustable choke. Well effluent next entered the Expro Test Separator. Effluent entering the test separator underwent two-phase separation: liquid (water + oil) and gas. The separator’s liquid was metered (oil and water) utilizing a turbine meter with Expro’s flow totalizer transmitter for determining a total liquid flow rate. The total liquid flow rates acquired were then modified utilizing basic sediment and water (BS&W) values, creating individualized oil and water rates. These oil and water rates subsequently created oil and water cumulative values. Gas exiting the separator was metered via a Coriolis Flow Meter before being routed to Expro’s Gas Scrubber. The gas scrubber was used for further separation and aided in removing any remaining liquid/condensate from the gas. Dry gas exited the gas scrubber via a 4” temporary test header to a 100’ flare stack for disposal through flaring. Liquid exiting the test separator flowed through a turbine flow meter and was then routed to Expro’s tank farm. The tank farm consisted of ten 367 bbl tanks and was used to determine liquid flow rates (oil + water). The well fluids were diverted between two tanks with flow into one of the 367 bbl tanks for 30 minutes, then, flow was diverted into another 367 bbl tank for 30 minutes. This cycle continued until the tank levels were at 80% volume capacity. Manual tank strap volumes were recorded every 30 minutes and reported to the DAQ operator for inclusion into liquid flow rate calculations. The liquid flow rates calculated from tank straps were entered into an tank volume spreadsheet calculator along with BS&W values to deduce oil and water rates and cumulative. Once the tanks reached the maximum level of 294 bbl., and an acceptable fluid Reid Vapor Test (RVP) was confirmed, Magtec pumped the fluid from each tank through a filter skid to a Little Red Services (LRS) triplex pump. LRS injected the fluid into disposal well NDBi-014, with the option to switch injection into well NDBi-030. Note that approximately 1200 bbl of initial fluid returned from well NDB-025 was transferred from the tanks directly to Worley Vac Truck and transported to an offsite disposal well. A Meter Factor is a ratio acquired by dividing the actual measured volume of a liquid by the amount of volume measured by a meter. Utilizing the production tank farm, multiple Combined Meter Shrinkage Factors (CMSF) were calculated for the separator total liquid flow turbine meter during the flow clean-up periods. Immediately prior to diverting into a production tank, an initial manual tank strap volume and fluid temperature was recorded. When the effluent was routed into the gauging tank, the initial cumulative value from the turbine meter fluid totalizer was recorded. After a designated time allotment (30 min), effluent was routed into another production tank and the WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 6 Introduction turbine meter fluid totalizer final volume is recorded. After another designated time allotment, the final manual strap volume and temperature is recorded. The time between diverting from the gauging production tank and the manual strap is performed allows extra gas to break out of the oil and accounts for the shrinkage in the calculation. Initial and Final Tank volumes are adjusted to standard conditions using recorded temperatures and then compared to the meter volumes to create the Combined Meter Shrinkage Factor (CMSF). Provided below are actions taken by the Expro Well Test Crew during the Clean-up flow period of the well test to achieve accurate separator total liquid flow meter rates compared to tank strap rates. Dates and times of each combined meter shrinkage factor are included such that the associated time interval can be referenced in the well test data and sequence of events. x Combined Meter and Shrinkage Factors (CMSF) were calculated and applied as necessary to ensure the accuracy of the Separator Liquid Turbine Meter compared to the Tank Strap Calculations. The first Combined Meter Shrinkage Factor of 0.944 was applied on February 10, 2025. See section 12 of this report for a complete list of CMSF’s calculated and applied into our DAQ software calculations during flowback operations. Throughout the well test, Basic Sediment and Water (BS&W) readings were taken downstream of the Expro Choke Manifold to determine the percentage of water and its properties including the pH, salinity, and weight. Oil API sampling was performed using a densitometer. BS&W samples were also taken upstream of the Expro DPI and at the Expro Test Separator oil leg to monitor for solids and to determine separation efficiency. Gas samples were taken from the Expro Test Separator gas line to determine Gas Specific Gravity and the concentration of CO2 and H2S. Daily oil and water samples were collected at twice per shift frequency downstream of the Expro Choke Manifold for Tracerco analysis. On February 11th, 2025 at 05:05 a leak was discovered on N2 supply system line that caused loss of the N2 supply source to our ESD panel. Subsequently, pressure to the ESD panel was lost causing a Fail-Safe Closure of the ESD devices and the well Shut-in at the Wellhead SDV and Expro’s SSV. On February 11th, 2025 at 23:30 another leak was discovered on the N2 supply system line that caused loss of the N2 supply source to our ESD panel. Subsequently, pressure to the ESD panel was lost causing a Fail-Safe Closure of the ESD devices and the well Shut-in at the Wellhead SDV and Expro’s SSV. To mitigate re-occurrence in the future, Expro implemented the following listed below: x Installed a data acquisition pressure transducer on the N2 supply going to the ESD panel. This transducer can then be continuously monitored from the data acquisition computer and alarms set to alert the operator of any drop in pressure. x On the N2 supply bottles, installed a diverter valve between N2 supply and Air supply, this will allow a chance to divert the ESD supply system from N2 to Air coming from compressor thus keeping the loop charged and the ESD system active while the issue is resolved. Once the clean-up flow period was complete, the well was immediately shut-in to commence the build-up period. During this time, the Schlumberger (SLB) down-hole gauge remained connected to Expro’s data logging system to collect downhole pressure and temperature data while personnel began rigging down the surface test equipment from the wellhead. On February 18th at 15:00, Expro completed the Build-Up data for the purposes of this report, WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 7 Introduction but Schlumberger’s downhole gauge communication interface remained connected to Expro’s data acquisition system for additional continuous monitoring and reporting. For the purposes of this report, Expro’s primary reference for determining liquid rates and cumulative values is tank strap readings taken at the tank farm. Expro’s separator turbine flow meters are used as reference for confirming liquid flow rates and liquid cumulative values throughout the well test. Expro’s primary reference for gas rates and gas cumulative values was the Coriolis Flow Meter (located in the gas line of the Expro Test Separator) and gas calculations from Expro’s data acquisition (DAQ) software. Data from the flow period described above is provided in this report. This includes a well test summary report with general comments. For a more detailed log outside of the flowing periods, please see the Sequence of Events section. Information from the well test summary report is also displayed in a graphical format. We appreciate your business and look forward to providing our services for your future testing needs. For all inquiries, please refer to the Points of Contact in Section 2 of this report. Disclaimer: Expro Well Testing will do its best efforts to furnish customers with accurate information and interpretations as a part of, and incident to, the services provided. However, Expro cannot and does not warrant the accuracy or correctness of such information or interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any decision regarding drilling, completion, production, financing, or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. These calculations are based on certain data, assumptions and applied mathematical methods. Inaccurate well data, changing well conditions, tolerance variations of mechanical components, mechanical malfunctions and other factors may affect these calculations. In no event will Expro be liable for failure to obtain any results or for any damages, including, but not limited to, indirect, special, or consequential damages, whether due to negligence or otherwise arising out of or in connection with such use of data, calculations, recommendations, or opinions provided by Expro. Sincerely, WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 8 Santos – Pikka Development – NDB-025 SECTION 2 POINTS OF CONTACT WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 9 Points of Contact Terry Park AK Operations Sales & Supervisor Terry. Park@expro.com Office: (907) 351-7952 Matt Purcell AK Operations Supervisor Matt.Purcell@expro.com Office: (907) 335-6618 Andres Arana Lead Engineer – North & Latin America Andres.Arana@expro.com Office: (337) 572-2473 Sharon Oyao Well Test Field Engineer Sharon.Oyao@expro.com Office: (907) 382-8773 Roger Ihde Well Test Supervisor Roger.Ihde@expro.com Office: (907) 715-1827 Travis Stacey Well Test Sr. DAQ Specialist Travis.Stacey@expro.com Office: (709) 743-0294 Jacques Guillot GOM & AK Operations Manager Jacques.Guillot@expro.com Office: (337) 839-6409 Ryan McMaster AK Operations Supervisor Ryan.McMaster@expro.com Office: (907) 398-1585 Stan Becnel NAM Product Line Manager Stan.Becnel@expro.com Office: (337) 839-6535 sŝĐƚŽƌŚĂǀĞnj Well Test Supervisor ǀŝĐƚŽƌ͘ĐŚĂǀĞnjΛĞdžƉƌŽ͘ĐŽŵ Office: (907) ϮϬϯ-ϮϮϮϵ Frank Tower Well Test Supervisor Frank.Tower@expro.com Office: (206) 743-2861 Yehia Elzeny Well Test Sr. DAQ Specialist Yehia.Elzeny@expro.com Office: (907) 229-3996 WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 10 Santos – Pikka Development – NDB-025 SECTION 3 NOMENCLATURE WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 11 Nomenclature: Abbreviation Meaning Abbreviation Meaning ADJ Adjustable HP High Pressure API American Petroleum Institute I/A Inner Annulus BHP Bottom Hole Pressure JRA Job Risk Assessment BHT Bottom Hole Temperature JSA Job Safety Assessment BPCV Back Pressure Control Valve KCl Potassium Chloride BS&W Basic Sediment & Water KWV Kill Wing Valve Chl Chloride LDHI Low Dosage Hydrate Inhibitor CIM Chemical Injection Mandrel LOTO Lock-out Tag-out CIV Chemical Injection Valve LP Low Pressure CO2 Carbon Dioxide LRS Little Red Services C/T Coil Tubing LSH Level Safety High CRU Colville River Unit LSL Level Safety Low DAQ Data Acquisition MeOH Methanol DCP Downstream Choke Pressure MF Meter Factor DCT Downstream Choke Temperature MV Master Valve DHSIT Downhole Shut-In Tool N2 Nitrogen Diff Differential N/R Not Recorded DW Disposal Well NDB Nanashuk Drilling – B Production EB Emulsion Breaker | Demulsifier NDBi Nanashuk Drilling – B Injection EDGE Expro’s Data Acquisition Software O/A Outer Annulus E-Line Wireline PLT Production Logging Tool ESD Emergency Shut Down Pos Positive FWD Forward POOH Pull out of Hole FWV Flow Wing Valve Pres Pressure GOR Gas Oil Ratio PSD Process Shut Down HES Halliburton Energy Services PSH Pressure Safety High H2O Water PSL Pressure Safety Low H2S Hydrogen Sulfide PSV Pressure Safety Valve WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 12 Nomenclature: Abbreviation Meaning Abbreviation Meaning P-Tank Pressurized Tank TBT Toolbox Talk PVT Pressure – Volume - Temperature Temp Temperature RIH Run in Hole UCP Upstream Choke Pressure Sal Water Salinity UCT Upstream Choke Temperature SDV Shutdown Valve US / DS Upstream / Downstream Sep Separator Vac Vacuum Truck SG Specific Gravity WGR Water Gas Ratio S/L Slick Line WHP Well Head Pressure SLB Schlumberger WHT Well Head Temperature SSV Surface Safety Valve WST Well Stimulation Tool STE Surface Well Test Equipment WT Well Test WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 13 Santos – Pikka Development – NDB-025 SECTION 4 TEST SUMMARY WELL CLEAN-UP FLOW WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 14 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Santos – Pikka Development NDB-025 – Clean-up Flow Period 1st flow black Well Clean-up Flow Test Start of 12 Hour Averaged Stable Flow Period: February 12th, 2025 11:00:00 End of 12 Hour Averaged Stable Flow Period: February 12th, 2025 23:00:00 On February 10th, 2024 @ 7:32 the NDB-025 well was opened at the Flow Wing Valve (FWV) on the Wellhead to a ‘closed’ Expro choke manifold. At 8:30 the choke was opened to flow through the Expro Surface Test Equipment (STE) on a 20/64ths adjustable choke bean. Well NDB-025 was opened on a 128/64ths adjustable choke on February 10th, 2025 @ 22:30 and flowed to February 13th, 2025 @ 10:00 At which NDB-025 was shut-in for bad weather conditions then on February 15th, 2025 @ 15:30 NDB-025 well was opened at the Flow Wing Valve (FWV) on the Wellhead to a ‘closed’ Expro choke manifold. At 16:00 the choke was opened to flow through the Expro Surface Test Equipment (STE) on a 24/64ths adjustable choke bean, then it was opened on a 128/64ths adjustable choke on February 15th, 2025 @ 23:00 The contents of this summary were deducted from 12 hours of stabilized flow at the end of the flow period. Prior to a hard shut-in at the choke manifold, the well was beaned down to and flowed for a 5-hour period on each a 52/64ths adjustable choke on February 16th, 2025 @ 18:00 to February 16th, 2025 @ 23:59 and a 44/64ths adjustable choke on November 17th, 2025 @ 00:00 to February 17th, 2025 @ 6:01. Provided below is a summary of the 12-hour flow period with the highest choke size flowing at stable conditions. Data was collected every 30 minutes, and the following table represents manual sample readings recorded at specific times during the 12-hour period. WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 15 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. At the end of this summary the average flow rates and GOR’s are presented for the 12-hour period while the volume cumulative values are totals at the end of the well clean-up flowback. Santos – Pikka Development NDB-025 – Clean-up Flow Period Date & Time Choke Size (1/64ths) Water Cut @ Choke (%) Solids, Mud & Carbolite BS&W (%) Salinity (ppm) Acid Base (pH) Gas Gravity (SG) CO2 (%) H2S (ppm) Oil Gravity SG (Water=1) Oil API (API) Demulsifier (EB) (gal/day) Defoamer (gal/day) 12-Feb-25 11:00128 10 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 11:30128 9 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 12:00128 10 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 12:30128 10 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 13:00128 12 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 13:30128 9 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 14:00128 8 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 14:30128 9 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 15:00128 10 0 28,000 7 0.707 0.1 0 0.880 29.3 8 8 12-Feb-25 15:30128 9 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 16:00128 12 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 16:30128 13 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 16 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. 12-Feb-25 17:00128 9 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 Date & Time Choke Size (1/64th) Water Cut @ Choke (%) Solids, Mud & Carbolite BS&W (%) Salinity (ppm) Acid Base (pH) Gas Gravity (SG) CO2 (%) H2S (ppm) Oil Gravity SG (Water=1) Oil API (API) Demulsifier (EB) (gal/day) Defoamer (gal/day) 12-Feb-25 17:30128 10 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 18:00128 9 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 18:30128 10 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 19:00128 11 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 19:30128 10 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 20:00128 8 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 20:30128 8 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 21:00128 7 0 28,000 7 0.708 0.1 0 0.879 29.5 8 8 12-Feb-25 21:30128 7 0 28,000 7 0.706 0.1 0 0.877 29.8 8 8 12-Feb-25 22:00128 7 0 28,000 7 0.706 0.1 0 0.877 29.8 8 8 12-Feb-25 22:30128 7 0 28,000 7 0.706 0.1 0 0.877 29.8 8 8 12-Feb-25 23:00128 7 0 28,000 7 0.706 0.1 0 0.877 29.8 8 8 WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 17 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Santos – Pikka Development NDB-025 – Clean-up Flow Test. Average Total Gas Rate (Formation + N2) 1.8264 MMscf/day Cumulative Total Gas (Formation + N2) 7.894 MMscf Average N2 Rate 0.00 MMscf/day Cumulative N2 0 MMscf Average Oil Rate - Meter 4895.19 Cumulative Oil - Meter 21459.25 Stb Average Oil Rate – Tanks 4940.71 Stb/day Cumulative Oil - Tanks ϮϭϱϲϮ͘ϳϮ Stb Average Water Rate - Meter 498.60 Stb/day Cumulative Water - Meter 2211.20 Stb Average Water Rate - Tanks 495.74 Stb/day Cumulative Water - Tanks 2108.14 Stb Average Sol/Mud/Car Rate 4.08 Stb/day Cumulative Sol/Mud/Carbo 4.50 Stb @ Flowmeter @ Flowmeter Average Sol/Mud/Car Rate 3.76 Stb/day Cumulative Sol/Mud/Carbo ϯ͘98 Stb @ Strap Tanks @ Strap Tanks Average Total Fluid Rate 5393.79 Stb/day Cumulative Total Fluid 23674.96 Stb @ Flowmeter @ Flowmeter Average Total Fluid Rate @ Strap Tanks 5436.45 Stb/day Cumulative Total Fluid @ Strap tanks 23674.84 Stb Average GOR (Total) (Formation + N2) 373.17 scf/stb % Frac Water Recovered 11.01 % Note: Well Clean-up: Flow rates and GOR are average values during the most stable flow period taken between February 12th, 2025 at 11:00hrs through February 12th, 2025 at 23:00hrs. Average Formation GOR can be assumed to be the same as Total GOR because Nitrogen was not Injected. Average Formation Gas Rate assumed to be the same as Total Gas Rate because Nitrogen was not Injected. All Cumulative Values including % Frac Water Recovered are totals at the end of the well clean-up flowback. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 18 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Santos – Pikka Development NDB-025 – Clean-up Flow Period Well Clean-up Flow Test Start of 7 Hour Averaged Stable Flow Period: February 16th, 2025 11:00:00 End of 7 Hour Averaged Stable Flow Period: February 16th, 2025 18:00:00 On February 16th, 2024 @ 10:50 the NDB-025 well fluids were Diverted to Parallel flow through DPI pods as per WSS. NDB-025 was opened on a 128/64ths adjustable choke on February 15th, 2025 @ 15:30 NDB-025 well was opened at the Flow Wing Valve (FWV) on the Wellhead to a ‘closed’ Expro choke manifold. At 16:00 the choke was opened to flow through the Expro Surface Test Equipment (STE) on a 24/64ths adjustable choke bean, then it was opened on a 128/64ths adjustable choke on February 15th, 2025 @ 23:00 The contents of this summary were deducted from 7 hours of stabilized flow at the end of the flow period. Prior to a hard shut-in at the choke manifold, the well was beaned down to and flowed for a 5-hour period on each a 52/64ths adjustable choke on February 16th, 2025 @ 18:00 to February 16th, 2025 @ 23:59 and a 44/64ths adjustable choke on November 17th, 2025 @ 00:00 to February 17th, 2025 @ 6:01. Provided below is a summary of the 7-hour flow period with the highest choke size flowing at stable conditions. Data was collected every 30 minutes, and the following table represents manual sample readings recorded at specific times during the 7-hour period. At the end of this summary the average flow rates and GOR’s are presented for the 7-hour period while the volume cumulative values are totals at the end of the well clean-up flowback. WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 19 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Santos – Pikka Development NDB-025 – Clean-up Flow Period Date & Time Choke Size (1/64ths) Water Cut @ Choke (%) Solids, Mud & Carbolite BS&W (%) Salinity (ppm) Acid Base (pH) Gas Gravity (SG) CO2 (%) H2S (ppm) Oil Gravity SG (Water=1) Oil API (API) Demulsifier (EB) (gal/day) Defoamer (gal/day) 16-Feb-25 11:00128 6 0 28,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 11:30128 5 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 12:00128 5 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 12:30128 5 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 13:00128 4 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 13:30128 5 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 14:00128 5 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 14:30128 5 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 15:00128 4 0 30,000 7 0.709 0.1 0 0.875 30.3 8 8 16-Feb-25 15:30128 5 0 30,000 7 0.711 0.1 0 0.877 29.8 8 8 16-Feb-25 16:00128 5 0 30,000 7 0.711 0.1 0 0.877 29.8 8 8 16-Feb-25 16:30128 4 0 29,000 7 0.711 0.1 0 0.877 29.8 8 8 16-Feb-25 17:00128 3 0 29,000 7 0.711 0.1 0 0.877 29.8 8 8 WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 20 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Date & Time Choke Size (1/64th) Water Cut @ Choke (%) Solids, Mud & Carbolite BS&W (%) Salinity (ppm) Acid Base (pH) Gas Gravity (SG) CO2 (%) H2S (ppm) Oil Gravity SG (Water=1) Oil API (API) Demulsifier (EB) (gal/day) Defoamer (gal/day) 16-Feb-25 17:30128 4 0 29,000 7 0.711 0.1 0 0.877 29.8 8 8 16-Feb-25 18:0052 4 0 29,000 7 0.711 0.1 0 0.877 29.8 8 8 WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 21 Test Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Santos – Pikka Development NDB-025 – Clean-up Flow Test. Average Total Gas Rate (Formation + N2) 2.2754 MMscf/day Cumulative Total Gas (Formation + N2) 7.894 MMscf Average N2 Rate 0.00 MMscf/day Cumulative N2 0 MMscf Average Oil Rate -Meter 6346.68 Cumulative Oil -Meter 21459.25 Stb Average Oil Rate –Tanks 6298.45 Stb/day Cumulative Oil -Tanks ϮϭϱϲϮ͘ϳϮ Stb Average Water Rate - Meter 305.44 Stb/day Cumulative Water - Meter 2211.20 Stb Average Water Rate -Tanks 294.47 Stb/day Cumulative Water -Tanks 2108.14 Stb Average Sol/Mud/Car Rate 0 Stb/day Cumulative Sol/Mud/Carbo 4.50 Stb @ Flowmeter @ Flowmeter Average Sol/Mud/Car Rate 0 Stb/day Cumulative Sol/Mud/Carbo ϯ.98 Stb @ Strap Tanks @ Strap Tanks Average Total Fluid Rate 6652.12 Stb/day Cumulative Total Fluid 23674.96 Stb @ Flowmeter @ Flowmeter Average Total Fluid Rate @ Strap Tanks 6592.92 Stb/day Cumulative Total Fluid @ Strap tanks 23674.84 Stb Average GOR (Total) (Formation + N2) 358.66 scf/stb % Frac Water Recovered 11.01 % Note: Well Clean-up: Flow rates and GOR are average values during the most stable flow period between February 16 th, 2025 at 11:00hrs through February 16th, 2025 at 18:00hrs. Average Formation GOR can be assumed to be the same as Total GOR because Nitrogen was not Injected. Average Formation Gas Rate assumed to be the same as Total Gas Rate because Nitrogen was not Injected. All Cumulative Values including % Frac Water Recovered are totals at the end of the well clean-up flowback. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 22 Santos – Pikka Development – NDB-025 SECTION 5 TEST DATA REPORT WELL CLEAN-UP FLOW WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 23 START DATE:END DATE:TimeDPI HeaterGORFrac WaterTime & Date COMMENTS BHP BHT I/A Pressure O/A Pressure Well Head PressureWell Head TemperatureU/S Choke PressureU/S Choke TemperatureD/S Choke PressureD/S Choke TemperatureChoke Size U/S DPI Solids, Mud & Carbolite Spin-out (Observed)D/S Heater PressureSeparator PressureGas Temperature Oil Temperature Corrected API WaterSalinity pH Gas S.G CO2 H2S Total Choke BS&W(Solids, Mud, Carbolite & Water)Solids, Mud & Carbolite @ ChokeWater Cut @ Choke Separator Oil Leg BS&W (2-Phase)Nitrogen Injection RateTotal Gas Rate (N2+Formation)Nitrogen InjectionCumulative Total Gas Cumulative (N2+Formation)Total GOR Solids, Mud & Carbolite RateSolids, Mud, & Carbolite CumulativeOil Rate Oil Cumulative Water RateWater CumulativeTotal Fluid RateTotal Fluid CumulativeTank Farm StrapSolids, Mud & Carbolite RateTank Farm StrapSolids, Mud, & Carbolite CumulativeTank Farm StrapOil RateTank Farm StrapOil CumulativeTank Farm StrapWater RateTank Farm StrapWater CumulativeTank Farm Strap Total Rate (Tank 1 - Tank 10)Tank Farm Strap Total Cumulative(Tank 1 - Tank 10)Percentage of Frac Water RecoveredDefoamer(D/S of Choke Manifold Data Header)Methanol (MeOH)(Separator Gas Line)Demulsifier(D/S of Choke Manifold Data Header)H2S Scavenger(D/S of Choke Manifold Data Header)(mm-dd-yyyy hh:mm)(psig) ) (psig) (psig) (psig) ) (psig) ) (psig) ) (64ths) (%) (psig) (psig) ) ) (API@60°)(ppm) (pH) (Air = 1) (%) (ppm) (%) (%) (%) (%) (MMscf/day) (MMscf/day) (MMscf) (MMscf) (scf/stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (%) (gal/day) (gal/day) (gal/day) (gal/day)02/10/2025 07:001991.27 105.59 0.00 0.00 15.83 67.40 2.44 93.37 0.00 75.07 0 0.00 0.00 0.00 69.99 63.79 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 0.00 0.00 0.00 0.0002/10/2025 07:3007:32 Opened Wellhead NDB-025 Production Wing Valve (PWV) to closed Expro Choke Manifold.1991.27 105.59 0.00 0.00 14.20 71.09 2.58 95.71 0.25 75.71 0 0.00 0.00 0.00 70.76 64.46 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 0.00 0.00 0.00 0.0002/10/2025 08:001990.85 105.60 0.00 0.00 294.66 61.97 290.64 95.16 0.00 75.80 0 0.00 0.00 0.00 70.14 64.47 45.00 0.00 0.00 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 0.00 0.00 0.00 0.0002/10/2025 08:30Opened Well on a 20/64ths adjustable Choke as per Santos WSS.08:35 Commenced Liquid sampling .1990.86 105.60 0.00 0.00 295.42 71.58 290.68 95.50 0.40 75.35 20 0.00 0.00 0.00 68.87 63.97 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 0.00 0.00 0.00 0.0002/10/2025 09:00Increased Expro adjustable Choke to 24/64ths as per Santos WSS.1969.60 105.44 0.00 0.00 179.21 58.57 176.05 52.02 3.60 49.37 24 0.00 0.00 0.00 67.82 65.96 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1194.11 24.88 0.00 1194.11 24.88 0.00 0.00 0.00 0.00 0.0002/10/2025 09:301969.72 105.11 3.14 0.00 53.27 57.68 43.96 49.87 2.82 45.62 24 0.00 1.08 0.00 66.79 66.46 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1375.03 53.53 0.00 0.00 1375.03 53.52 0.00 0.00 0.00 0.00 0.0002/10/2025 10:00Increased Expro adjustable Choke to 28/64ths as per Santos WSS.10:06 Reallocating WHT sensor.1980.71 105.32 5.11 0.00 53.59 44.17 48.74 64.99 3.93 50.97 28 0.00 0.88 0.00 65.48 65.39 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 361.85 61.07 0.00 0.00 361.85 61.06 0.00 0.00 0.00 0.00 0.0002/10/2025 10:30Increased Expro adjustable Choke to 32/64ths as per Santos WSS.1980.09 105.38 3.50 0.00 40.17 67.01 33.75 79.73 5.62 58.92 32 0.00 2.91 0.00 64.16 63.94 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 434.22 70.11 0.00 0.00 434.22 70.11 0.00 0.00 0.00 0.00 0.0002/10/2025 11:00Increased Expro adjustable Choke to 36/64ths as per Santos WSS.1961.16 105.13 11.22 0.00 34.48 51.62 23.64 45.06 6.43 42.28 36 0.00 2.52 0.00 62.82 62.74 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.00000.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 832.26 87.45 0.00 0.00 832.26 87.45 0.00 0.00 0.00 0.00 0.0002/10/2025 11:30Increased Expro adjustable Choke to 40/64ths as per Santos WSS.11:59'LYHUWHG)ORZWKURXJKWHVWLQJVHSDUDWRU11:59)ODUHOLW1947.16 105.13 42.32 0.00 55.10 61.66 39.80 49.03 10.05 45.26 40 0.00 4.68 0.00 61.57 61.72 45.0 0 0 0.000 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.35 0.07 682.81 101.68 652.69 13.60 1338.85 115.34 0.07 0.00 0.00 0.00 0.0002/10/2025 12:00Increased Expro adjustable Choke to 44/64ths as per Santos WSS.'XPSLQJJDVIURP6HSDUDWRUWR)ODUH0HWHULQJ*DVWKURXJK&RULROLVCumulative Volumes 128 bbls Diesel, 60.29 bbls Water and 0.18 bbls 6ROLGVZDVHQWHUHGLQWRWKH'$4VRIWZDUHWRDFFRXQWIRUUDWHVQRWEHLQJcalculated due to separator bieng bypassed.%HJDQGXPSLQJ)OXLGIURP 6HSDUDWRU 0HWHULQJWKURXJK/LQH Turbine Meter).12:25'LYHUWHG*DVIORZUDWHIURP &RULROLVPHWHUWR &RULROLVPHWHU1923.49 104.89 148.50 0.00 395.07 70.07 345.67 55.51 69.77 52.99 44 0.00 47.57 0.00 60.44 60.82 45.0 0 0 0.700 0.00 0.0 49.00 0.25 48.75 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.18 0.00 128.00 0.00 60.29 0.00 188.47 5.26 0.18 1263.58 128.00 2241.11 60.29 3509.95 188.46 0.30 0.00 0.00 0.00 0.0002/10/2025 12:30Increased Expro adjustable Choke to 48/64ths as per Santos WSS.$SSOLHG&0) 12:33 Adjusted separator liquid level to mid point.12:39(GJH[3&GRZQ12:45 Oil to surface.12:55(GJH[3&GRZQ1893.93 104.60 225.76 0.00 491.18 71.22 408.73 55.44 220.65 51.29 48 0.00 183.49 179.87 55.14 53.05 45.0 40000 7 0.700 0.00 0.0 64.00 0.15 63.85 63.85 0.0000 0.6735 0.0000 0.0140 551.72 5.13 0.29 1220.65 153.43 2199.41 106.11 3425.19 259.83 5.21 0.29 868.44 146.09 2600.12 114.46 3473.77 260.83 0.53 0.00 0.00 0.00 0.0002/10/2025 13:00Due to system outage tank strap reading is more representative Increased Expro adjustable Choke to 52/64ths as per Santos WSS.Commenced chemical injection of methanol,demulsifier and defoamer. @ 8 gal/day13:05'LYHUWHGOLTXLGIORZIURP WXUELQHPHWHUWR WXUELQHPHWHU1875.93 104.39 303.27 0.00 467.50 73.09 365.81 57.05 173.02 51.38 52 0.00 122.34 117.96 51.46 50.06 45.0 40000 7 0.654 0.00 0.0 75.00 0.15 74.85 74.85 0.0000 1.9480 0.0000 0.0546 1203.47 9.66 0.49 1618.62 187.15 4819.22 206.51 6447.50 394.15 4.23 0.38 3979.64 229.00 249.79 119.66 4233.66 349.04 1.03 8.00 8.00 8.00 0.0002/10/2025 13:30Increased Expro adjustable Choke to 56/64ths as per Santos WSS.13:45(GJH[3&GRZQ1865.59 104.24 394.47 0.00 451.99 65.88 335.06 58.16 162.02 53.52 56 0.00 101.36 95.86 51.60 50.38 45.0 38000 7 0.654 0.10 0.0 6.00 0.10 5.90 5.90 0.00001.5738 0.0000 0.0874 350.14 4.78 0.59 4494.94 280.80 282.07 212.39 4781.78 493.77 4.67 0.47 4644.54 325.76 18.67 120.05 4667.88 446.28 1.06 8.00 8.008.00 0.0002/10/2025 14:00Increased Expro adjustable Choke to 60/64ths as per Santos WSS.1853.96 104.11 489.75 0.00 438.89 65.18 308.77 61.13 168.51 55.99 60 0.00 104.05 96.24 53.17 51.96 29.6 38000 7 0.654 0.10 0.0 0.50 0.10 0.40 0.40 0.00001.5384 0.0000 0.1195 301.64 5.17 0.70 5100.28 387.05 54.91 213.53 5160.35 601.28 5.03 0.58 4979.43 429.50 45.27 120.99 5029.73 551.07 1.06 8.00 8.00 8.00 0.0002/10/2025 14:30Increased Expro adjustable Choke to 64/64ths as per Santos WSS.1845.40 104.06 579.62 0.00 441.74 68.34 274.13 62.14 157.74 58.51 64 0.00 84.06 74.59 54.37 53.75 29.6 38000 7 0.654 0.10 0.0 1.00 0.10 0.90 0.90 0.0000 1.6639 0.0000 0.1541 325.22 5.16 0.80 5116.16 493.64 46.46 214.50 5167.79 708.94 5.10 0.68 4898.01 531.54 198.98 125.14 5102.10 657.36 1.07 8.00 8.00 8.00 0.0002/10/2025 15:001831.75 104.01 659.64 0.00 416.99 72.76 254.93 64.18 160.19 61.03 64 0.00 83.79 74.21 56.44 55.48 29.6 38000 7 0.654 0.10 0.0 4.00 0.10 3.90 3.90 0.0000 1.7033 0.0000 0.1896 336.45 5.27 0.91 5062.43 599.11 205.45 218.78 5273.14 818.80 7.71 0.85 4881.37 633.24 249.21 130.33 5138.28 764.41 1.09 8.00 8.008.00 0.0002/10/2025 15:301826.38 103.98 725.93 0.00 411.30 71.68 246.37 65.00 155.35 62.11 64 0.00 80.84 73.93 57.94 57.08 29.6 38000 7 0.654 0.10 0.0 5.00 0.15 4.85 4.85 0.0000 1.6566 0.0000 0.2241 334.38 7.78 1.07 4952.88 702.29 252.54 224.04 5213.20 927.41 12.57 1.11 4727.94 731.74 289.21 136.35 5029.73 869.20 1.12 8.00 8.008.000.0002/10/2025 16:001819.14 103.94 779.45 0.00 401.76 74.57 238.94 66.46 151.31 62.48 64 0.00 82.42 74.06 59.05 58.41 29.8 38000 7 0.662 0.10 0.0 6.00 0.25 5.75 5.75 0.0000 1.6032 0.0000 0.2575 334.38 12.87 1.34 4834.27 803.00 294.91 230.19 5142.06 1034.53 5.14 1.21 4881.37 833.43 251.78 141.60 5138.28 976.24 1.15 8.00 8.00 8.00 0.0002/10/2025 16:301826.88 103.91 829.50 0.00 408.09 79.76 236.42 66.93 157.57 63.61 64 0.15 84.02 76.46 59.77 59.18 29.8 38000 7 0.662 0.10 0.0 5.00 0.10 4.90 5.75 0.0000 1.5379 0.0000 0.2896 312.70 4.88 1.45 4729.98 901.55 288.58 236.20 5023.55 1139.19 9.63 1.41 4235.10 921.66 567.89 153.43 4812.62 1076.51 1.18 8.00 8.00 8.00 0.0002/10/2025 17:001829.78 103.84 867.39 0.00 373.23 87.60 217.61 68.22 148.57 64.43 64 0.00 78.82 72.46 60.12 59.45 29.8 38000 7 0.662 0.10 0.0 12.00 0.20 11.80 11.80 0.0000 1.4450 0.0000 0.3197 331.07 8.95 1.65 4298.10 991.09 575.19 248.18 4883.04 1240.92 7.27 1.57 4557.87 1016.62 283.65 159.34 4848.80 1177.52 1.24 8.00 8.00 8.00 0.0002/10/2025 17:301824.89 103.86896.25 0.00 397.68 83.93 241.11 69.74 158.18 65.86 64 0.00 85.48 75.94 61.72 60.44 29.8 38000 7 0.662 0.10 0.0 6.00 0.15 5.85 5.85 0.0000 1.4946 0.0000 0.3508 328.26 7.73 1.80 4624.70 1087.44 287.40 254.17 4919.47 1343.41 4.88 1.67 4347.64 1107.19 532.46 170.43 4884.99 1279.29 1.27 8.00 8.00 8.00 0.0002/10/2025 18:00Collected Tracerco sample.18:13VKXWGRZQFRPSXWHUWRVZDSRXWZLWKEDFNXS1816.94 103.84 920.78 0.00 397.30 84.26 233.13 69.77 150.92 65.61 64 0.00 80.46 73.93 62.09 61.11 29.8 38000 7 0.662 0.10 0.0 11.00 0.10 10.90 10.90 0.0000 1.5506 0.0000 0.3831 379.05 4.74 1.91 4171.28 1174.34 730.67 269.39 4906.85 1445.64 4.81 1.77 4090.72 1192.42 717.08 185.37 4812.62 1379.56 1.34 8.00 8.00 8.00 0.0002/10/2025 18:30Increased Expro adjustable Choke to 68/64ths as per Santos WSS.1819.86 103.75 956.99 0.00 368.50 72.76 204.86 70.84 142.65 64.90 68 0.00 93.55 74.56 63.64 62.62 29.8 38000 7 0.687 0.10 0.0 15.00 0.10 14.90 14.90 0.0000 1.5100 0.0000 0.4146 331.00 5.37 2.02 4561.85 1269.38 799.67 286.05 5366.88 1557.45 24.79 2.28 3718.02 1269.88 1214.55 210.68 4957.36 1482.83 1.428.008.008.000.0002/10/2025 19:00Increased Expro adjustable Choke to 74/64ths as per Santos WSS.19:17'$4RQOLQH$OOUDWHVIRU*DV IOXLGVZHUHFDOFXODWHGPDQXDO\ LQVHUWHGLQWR'$4V\VWHPEDVHGRQ)ORZPHWHUUHDGLQJV 1818.54 103.71 951.65 0.00 376.47 83.71 197.65 72.02 139.65 64.52 74 0.00 88.99 74.58 64.68 63.63 29.8 38000 7 0.687 0.10 0.0 25.00 0.50 24.50 24.50 0.0000 1.5060 0.0000 0.4459 371.91 27.00 2.58 4049.28 1353.74 1322.76 313.61 5399.04 1669.93 4.96 2.39 4610.34 1365.93 342.06 217.80 4957.36 1586.11 1.568.008.008.000.0002/10/2025 19:30Increased Expro adjustable Choke to 80/64ths as per Santos WSS.1817.23 103.67 953.32 0.00 368.45 84.88 192.47 70.99 151.85 64.99 80 0.00 81.88 74.60 65.72 64.63 29.8 38000 7 0.694 0.10 0.0 7.00 0.10 6.90 6.90 0.0000 1.5086 0.0000 0.4774 314.40 5.16 2.69 4798.35 1453.70 356.01 321.02 5159.52 1777.42 17.35 2.75 4164.18 1452.68 775.83 233.97 4957.36 1689.39 1.60 8.00 8.00 8.00 0.0002/10/2025 20:00Increased Expro adjustable Choke to 88/64ths as per Santos WSS.1815.92 103.63 953.32 0.00 372.41 86.06 189.47 70.96 158.32 64.43 88 0.00 84.22 74.63 66.77 65.63 29.8 38000 7 0.694 0.10 0.0 16.00 0.35 15.65 15.65 0.0000 1.5551 0.0000 0.5098 356.78 18.16 3.07 4358.59 1544.51 812.05 337.94 5188.80 1885.52 2.64 2.80 4120.76 1538.53 1159.62 258.12 5283.02 1799.45 1.688.008.008.000.0002/10/2025 20:30Increased Expro adjustable Choke to 96/64ths as per Santos WSS.1814.60 103.59 997.65 0.00 382.65 87.24 184.37 71.93 154.95 65.61 96 0.00 89.32 74.65 65.81 64.64 29.8 38000 7 0.705 0.10 0.0 22.00 0.05 21.95 21.95 0.0000 1.5680 0.0000 0.5424 398.47 2.52 3.12 3934.94 1626.49 1107.33 361.01 5044.80 1990.62 5.10 2.91 4081.68 1623.56 1015.32 279.28 5102.10 1905.75 1.80 8.00 8.00 8.00 0.0002/10/2025 21:00Increased Expro adjustable Choke to 102/64ths as per Santos WSS.1811.17 103.79 1039.04 0.00 380.63 90.27 172.71 71.39 151.19 67.92 102 0.00 81.37 75.31 64.74 63.36 30.3 36000 8 0.705 0.10 0.0 20.00 0.10 19.90 19.90 0.0000 1.6498 0.0000 0.5768 384.97 5.36 3.23 4285.44 1715.77 1066.00 383.22 5356.80 2102.22 2.42 2.96 3976.02 1706.40 870.36 297.41 4848.80 2006.76 1.91 8.00 8.00 8.00 0.0002/10/2025 21:30Increased Expro adjustable Choke to 110/64ths as per Santos WSS.1808.68 103.77 1044.61 0.00 327.10 90.57 165.29 71.08 146.64 68.01 110 0.00 79.77 73.57 64.54 63.20 30.3 36000 8 0.705 0.10 0.0 18.00 0.05 17.95 17.95 0.0000 1.8260 0.0000 0.6148 462.25 2.41 3.28 3950.17 1798.06 864.70 401.23 4817.28 2202.58 2.33 3.01 3547.59 1780.31 1117.96 320.70 4667.88 2104.01 2.00 8.00 8.00 8.00 0.0002/10/2025 22:00Increased Expro adjustable Choke to 120/64ths as per Santos WSS.1811.56 103.74 1053.22 0.00 317.92 83.90 161.37 70.78 145.91 68.14 120 0.00 81.11 73.67 64.79 63.33 30.3 36000 8 0.705 0.10 0.0 24.00 0.05 23.95 23.95 0.0000 1.4110 0.0000 0.6442 380.18 2.44 3.33 3711.48 1875.38 1169.60 425.60 4883.52 2304.32 2.44 3.06 4298.79 1869.86 583.76 332.86 4884.99 2205.78 2.12 8.00 8.00 8.00 0.0002/10/2025 22:30Increased Expro adjustable Choke to 128/64ths as per Santos WSS.1806.39 103.72 1062.65 0.00 318.38 85.41 160.91 71.03 147.04 68.34 128 0.00 79.68 75.80 65.24 63.38 30.3 36000 8 0.705 0.10 0.0 12.00 0.05 11.95 11.95 0.0000 1.4105 0.0000 0.6736 330.14 2.43 3.38 4272.58 1964.40 580.20 437.69 4855.20 2405.47 2.32 3.11 3890.62 1950.92 738.75 348.25 4631.69 2302.28 2.188.008.008.000.0002/10/2025 23:0023:04(GJH[VHUYHUGRZQUHFDOFXODWHGYROFXPVDQG8SGDWHGV\VWHP1804.90 103.70 1071.25 0.00 318.22 81.82 161.80 72.07 148.37 68.44 128 0.00 79.53 73.30 65.10 63.32 30.3 31000 8 0.705 0.10 0.0 16.00 0.03 15.98 15.98 0.0000 1.6185 0.0000 0.7073 258.74 1.34 3.41 4488.83 2057.91 853.68 455.47 5343.84 2516.80 2.32 3.16 3890.62 2031.97 738.75 363.64 4631.69 2398.77 2.27 8.00 8.00 8.00 0.0002/10/2025 23:301802.35 103.70 1078.24 0.00 315.41 85.91 160.51 72.73 147.35 68.46 128 0.00 79.65 74.36 65.24 63.54 30.3 31000 8 0.706 0.10 0.0 10.00 0.05 9.95 9.95 0.0000 1.9070 0.0000 0.7471 361.81 2.45 3.46 3800.70 2137.09 711.02 470.29 4514.16 2610.84 2.35 3.21 4233.66 2120.17 468.05 373.39 4704.06 2496.77 2.34 8.00 8.00 8.00 0.0002/11/2025 00:00Collected Tracerco sample.Sparged Expro separator , Observed light trace of sand.1798.26 103.69 1087.52 0.00 315.17 85.76 163.00 71.73 149.33 68.87 128 0.00 81.66 74.37 65.58 63.64 31.0 29500 8 0.706 0.10 0.0 10.00 0.05 9.95 9.95 0.0000 1.4295 0.0000 0.7768 375.39 2.11 3.50 3808.01 2216.43 420.95 479.06 4231.07 2698.99 2.33 3.25 4201.09 2207.70 464.45 383.07 4667.88 2594.02 2.38 8.00 8.00 8.00 0.0002/11/2025 00:301798.83 103.66 1098.89 0.00 321.84 94.70 160.79 72.79 147.37 69.00 128 0.00 84.30 77.17 66.12 63.83 31.0 29500 8 0.704 0.10 0.0 10.00 0.05 9.95 9.95 0.0000 1.4349 0.0000 0.8067 372.56 2.14 3.55 3851.57 2296.67 425.76 487.93 4279.48 2788.14 2.39 3.30 3916.67 2289.29 857.37 400.93 4776.43 2693.53 2.43 8.00 8.00 8.00 0.0002/11/2025 01:001801.29 103.65 1106.49 0.00 331.28 88.35 155.20 71.49 142.40 68.96 128 0.00 75.89 71.96 65.88 64.10 30.7 30000 8 0.704 0.10 0.0 18.00 0.05 17.95 17.95 0.0000 1.45240.0000 0.8370 413.50 2.14 3.59 3512.40 2369.84 769.03 503.95 4283.57 2877.38 2.42 3.36 4072.99 2374.15 773.38 417.04 4848.80 2794.54 2.51 8.00 8.00 8.00 0.0002/11/2025 01:301794.06 103.65 1115.91 0.00 318.40 90.09 171.50 71.73 155.55 69.34 128 0.00 82.53 76.22 66.49 64.34 30.7 30000 8 0.706 0.10 0.0 15.95 0.00 15.95 15.95 0.0000 1.5023 0.0000 0.8683 408.67 2.12 3.64 3676.00 2446.43 698.11 518.49 4376.21 2968.56 0.00 3.36 4169.97 2461.02 678.83 431.19 4848.80 2895.56 2.588.008.008.000.0002/11/2025 02:001796.33 103.62 1124.45 0.00 322.56 90.69 162.52 73.52 147.61 69.60 128 0.00 82.67 77.29 66.30 64.61 31.6 30000 8 0.706 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.5005 0.0000 0.8996 392.79 0.00 3.64 3820.13 2526.01 622.30 531.46 4442.43 3061.11 0.00 3.36 4169.97 2547.90 678.83 445.33 4848.80 2996.58 2.65 8.00 8.00 8.00 0.0002/11/2025 02:301795.78 103.62 1130.700.00 310.09 85.10 164.03 73.74 149.87 69.65 128 0.00 82.15 74.36 66.44 64.61 31.6 30000 8 0.704 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4558 0.0000 0.9299 388.92 0.00 3.64 3743.19 2603.99 609.77 544.16 4352.96 3151.79 1.19 3.38 3917.87 2629.52 857.37 463.19 4776.43 3096.09 2.71 8.00 8.00 8.00 0.0002/11/2025 03:001791.71 103.61 1138.84 0.00 335.44 86.78 175.92 74.25 159.89 69.98 128 0.00 82.97 75.57 67.05 64.85 30.9 29000 8 0.704 0.10 0.0 18.00 0.05 17.95 17.95 0.0000 1.4898 0.0000 0.9609 412.18 2.20 3.68 3614.52 2679.30 791.44 560.65 4408.15 3243.63 2.44 3.43 4103.39 2715.01 779.16 479.42 4884.99 3197.86 2.798.008.008.000.0002/11/2025 03:301786.31 103.59 1149.28 0.00 329.37 88.01 171.94 74.45 155.29 70.37 128 0.00 83.89 77.85 67.10 65.30 30.9 29000 8 0.706 0.10 0.0 15.95 0.00 15.95 15.95 0.0000 1.5583 0.0000 0.9934 401.052.22 3.73 3885.68 2760.25 737.97 576.02 4625.87 3340.00 0.00 3.43 4376.95 2806.19 833.70 496.79 5210.65 3306.41 2.87 8.00 8.00 8.00 0.0002/11/2025 04:001786.29 103.61 1157.28 0.00 326.28 89.18 167.12 74.23 154.10 70.09 128 0.00 82.71 76.52 66.79 65.41 30.9 29000 8 0.706 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.4948 0.0000 1.0245 367.93 0.00 3.73 4062.79 2844.89 774.49 592.16 4837.28 3440.78 0.00 3.43 4232.21 2894.36 688.96 511.15 4921.17 3408.94 2.95 8.00 8.00 8.00 0.0002/11/2025 04:301794.39 103.56 1161.06 0.00 326.60 91.00 168.37 73.73 152.54 70.40 128 0.00 78.97 74.36 67.05 65.12 30.9 30000 8 0.704 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.5400 0.0000 1.0566 370.60 0.00 3.73 4155.57 2931.46 676.97 606.26 4832.54 3541.46 2.42 3.48 3976.02 2977.20 870.36 529.28 4848.80 3509.95 3.02 8.00 8.00 8.00 0.0002/11/2025 05:0005:05 Well Shut in at SSV05:11 2SHQHGZHOORQDWKV05:15 Increased Expro adjustable Choke to 64/64ths as per Santos WSS.05:27 Increased Expro adjustable Choke to 68/64ths as per Santos WSS.1799.99 103.56 1161.74 0.00 323.10 93.15 162.62 74.18 147.25 70.12 128 0.00 80.02 74.09 67.18 65.12 30.9 30000 8 0.704 0.10 0.0 18.00 0.05 17.95 17.95 0.0000 1.4878 0.0000 1.0876 382.61 2.37 3.78 3888.42 3012.47 851.44 624.00 4742.22 3640.25 0.00 3.48 4235.10 3065.43 577.51 541.31 4812.62 3610.22 3.118.008.008.000.0002/11/2025 05:30Applied CMSF = 0.9005:55 Increased Expro adjustable Choke to 78/64ths as per Santos WSS.1805.50 103.62 1119.13 0.00 340.22 92.36 200.32 72.34 137.49 67.87 68 0.00 76.86 72.24 65.29 63.15 30.3 30000 8 0.704 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 0.9468 0.0000 1.1073 348.43 0.00 3.78 2717.24 3069.08 370.74 631.72 3087.98 3704.59 1.59 3.51 2674.80 3121.15 507.89 551.89 3184.29 3676.56 3.148.00 8.00 8.00 0.0002/11/2025 06:00Collected Tracerco sample.06:02Increased Expro adjustable Choke to 84/64ths as per Santos WSS.06:09Increased Expro adjustable Choke to 90/64ths as per Santos WSS.06:15Increased Expro adjustable Choke to 102/64ths as per Santos WSS.06:21 Increased Expro adjustable Choke to 108/64ths as per Santos WSS.1793.83 103.57 1147.15 0.00 355.65 82.85 204.26 73.82 158.62 69.74 78 0.00 84.07 75.96 66.94 65.12 30.3 30000 8 0.704 0.10 0.0 16.00 0.05 15.95 15.95 0.0000 1.4247 0.0000 1.1370 353.77 2.40 3.83 4027.14 3152.98 764.76 647.66 4794.29 3804.47 4.23 3.60 3852.63 3201.42 376.80 559.74 4233.66 3764.76 3.228.00 8.00 8.00 0.0002/11/2025 06:3006:26 Increased Expro adjustable Choke to 114/64ths as per Santos WSS.06:45 Increased Expro adjustable Choke to 120/64ths as per Santos WSS.1800.28 103.56 1154.77 0.00 317.66 84.09 168.11 73.55 152.34 69.56 114 0.00 84.65 79.15 66.59 64.72 30.3 30000 8 0.704 0.10 0.0 9.00 0.10 8.90 8.90 0.0000 1.6169 0.0000 1.1707 401.30 4.36 3.92 3969.27 3235.67 387.96 655.74 4361.59 3895.33 4.63 3.70 4168.52 3288.26 458.54 569.29 4631.69 3861.25 3.26 8.00 8.00 8.00 0.0002/11/2025 07:001785.44 103.54 1164.53 0.00 337.15 84.88 171.52 74.32 153.61 69.84 128 0.00 81.37 78.37 66.84 64.53 30.3 30000 8 0.704 0.10 0.0 10.00 0.10 9.90 9.90 0.0000 1.4628 0.0000 1.2012 346.29 4.69 4.02 4224.13 3323.68 464.38 665.41 4693.20 3993.11 0.00 3.70 4362.47 3379.15 594.88 581.69 4957.36 3964.53 3.31 8.00 8.00 8.00 0.0002/11/2025 07:301773.87 103.52 1186.88 0.00 380.02 86.56 192.74 75.59 175.83 71.57 128 0.00 90.50 82.13 68.01 65.40 30.3 30000 8 0.704 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.70240.0000 1.2366 356.55 0.00 4.02 4774.70 3423.15 651.53 678.99 5426.23 4106.15 0.00 3.70 4103.39 3464.63 781.60 597.97 4884.99 4066.30 3.38 8.00 8.00 8.00 0.0002/11/2025 08:001772.88 103.51 1198.87 0.00 379.56 87.50 192.93 75.42 175.56 72.10 128 0.00 91.86 82.56 68.57 66.03 30.3 34000 8 0.704 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.7514 0.0000 1.2731 384.17 0.00 4.02 4566.28 3518.28 870.49 697.12 5436.82 4219.42 0.00 3.70 4263.33 3553.45 694.03 612.43 4957.36 4169.58 3.478.008.008.000.0002/11/2025 08:301770.89 103.50 1208.64 0.00 379.36 87.81 191.08 75.89 174.61 71.55 128 0.00 92.27 83.08 69.21 66.49 30.3 34000 8 0.704 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7172 0.0000 1.3089 371.74 0.00 4.02 4619.25 3614.52 752.62 712.80 5371.87 4331.34 0.00 3.70 4437.74 3645.91 845.28 630.04 5283.02 4279.64 3.55 8.00 8.00 8.00 0.0002/11/2025 09:001768.81 103.50 1216.830.00 380.44 88.24 193.09 75.76 175.01 71.94 128 0.00 93.33 82.95 69.71 66.81 30.3 34000 8 0.704 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.7008 0.0000 1.3443 381.92 0.00 4.02 4453.34 3707.29 849.11 730.49 5302.45 4441.80 0.00 3.70 4361.75 3736.77 957.46 649.99 5319.21 4390.46 3.64 8.00 8.00 8.00 0.0002/11/2025 09:301767.06 103.50 1223.10 0.00 379.52 88.90 192.76 75.88 176.34 71.81 128 0.25 91.73 82.69 69.82 66.54 29.6 34000 8 0.707 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.7092 0.0000 1.3799 385.56 0.00 4.02 4432.95 3799.65 974.15 750.79 5407.10 4554.45 0.00 3.70 4625.18 3833.13 947.33 669.72 5572.50 4506.55 3.74 8.00 8.00 8.00 0.0002/11/2025 10:001765.27 103.50 1224.47 0.00 376.38 89.90 191.68 76.43 174.41 71.39 128 0.00 91.33 83.07 70.01 66.81 29.6 34000 8 0.707 0.10 0.0 17.00 0.00 17.00 17.00 0.0000 1.7158 0.0000 1.4157 385.180.00 4.02 4454.63 3892.45 913.34 769.81 5367.97 4666.28 0.00 3.70 4510.11 3927.09 990.02 690.35 5500.13 4621.14 3.83 8.00 8.00 8.00 0.0002/11/2025 10:301763.94 103.49 1229.91 0.00 379.22 90.03 191.94 74.80 175.59 70.85 128 0.00 92.89 84.01 69.98 66.57 29.6 34000 8 0.707 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.7194 0.0000 1.4515 388.81 0.00 4.02 4422.07 3984.58 971.77 790.06 5393.83 4778.66 0.00 3.70 4854.59 4028.23 790.28 706.81 5644.87 4738.74 3.938.008.008.000.0002/11/2025 11:0011:02 Sparged Expro separator , Observed light trace of sand.1762.31 103.49 1234.27 0.00 380.72 90.53 192.24 75.58 175.98 71.16 128 0.00 94.37 84.94 70.07 66.36 29.6 34000 8 0.707 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7209 0.0000 1.4874 371.31 0.00 4.02 4634.62 4081.13 755.11 805.78 5389.72 4890.93 0.00 3.70 4832.88 4128.92 920.55 725.99 5753.43 4858.60 4.018.008.008.000.0002/11/2025 11:301760.58 103.49 1237.79 0.00 379.38 91.13 189.81 75.52 173.84 71.33 128 0.00 93.44 83.61 70.14 66.60 29.6 32000 8 0.707 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.7223 0.0000 1.5233 388.51 0.00 4.02 4433.07 4173.49 845.21 823.39 5278.28 5000.90 0.00 3.70 4421.09 4221.02 970.48 746.21 5391.58 4970.93 4.10 8.00 8.00 8.00 0.0002/11/2025 12:00Collected Tracerco sample.1757.50 103.49 1239.04 0.00 375.76 90.90 187.76 75.59 170.22 71.25 128 0.00 89.98 83.73 70.38 66.62 29.6 32000 8 0.707 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.7337 0.0000 1.5593 392.68 0.00 4.02 4415.13 4265.47 970.24 843.61 5385.37 5113.09 0.00 3.70 4625.18 4317.38 947.33 765.94 5572.50 5087.02 4.208.008.008.000.0002/11/2025 12:301759.50 103.49 1241.31 0.00 378.92 89.84 191.84 76.75 174.72 70.92 128 0.00 91.83 82.40 69.98 66.84 29.6 32000 8 0.707 0.10 0.0 17.00 0.00 17.00 17.00 0.0000 1.7291 0.0000 1.5954 386.59 0.00 4.02 4472.72 4358.65 917.04 862.71 5389.76 5225.38 0.00 3.70 4736.63 4416.06 835.88 783.36 5572.50 5203.11 4.29 8.00 8.00 8.00 0.0002/11/2025 13:00Collected corelab sample.1756.28 103.49 1242.71 0.00 380.34 88.97 188.06 75.94 172.88 70.77 128 0.00 92.77 83.51 70.19 67.43 29.6 32000 8 0.707 0.10 0.0 15.00 0.00 15.00 15.00 0.0000 1.7015 0.0000 1.6308 375.73 0.00 4.02 4528.42 4452.99 799.88 879.37 5328.31 5336.38 0.00 3.70 4595.14 4511.79 941.17 802.97 5536.32 5318.45 4.388.008.008.000.0002/11/2025 13:301754.85 103.50 1244.18 0.00 379.30 88.91 189.81 76.66 173.26 71.89 128 0.00 92.24 83.35 70.65 68.11 29.6 32000 8 0.707 0.10 0.0 17.00 0.00 17.00 17.00 0.0000 1.7317 0.0000 1.6669 388.29 0.00 4.02 4459.91 4545.90 914.49 898.42 5374.40 5448.34 0.00 3.70 4711.30 4609.94 897.39 821.66 5608.69 5435.30 4.478.008.008.000.0002/11/2025 14:0014:18 Sparged Expro separator , Observed light trace of sand.1752.72 103.50 1246.85 0.00 381.13 89.10 191.60 76.58 174.63 71.40 128 0.00 93.60 83.88 70.99 68.81 29.6 32000 8 0.707 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.7319 0.0000 1.7030 385.98 0.00 4.02 4486.91 4639.38 855.59 916.25 5342.50 5559.65 0.00 3.70 4816.60 4710.29 719.72 836.66 5536.32 5550.64 4.568.008.008.000.0002/11/2025 14:301750.06 103.50 1248.80 0.00 376.93 88.97 191.58 75.79 175.69 71.20 128 0.00 93.18 84.14 71.21 69.13 29.6 32000 8 0.707 0.10 0.0 13.00 0.00 13.00 13.00 0.0000 1.7316 0.0000 1.7391 382.86 0.00 4.02 4522.76 4733.60 676.44 930.34 5199.20 5667.96 0.00 3.70 4398.30 4801.92 776.17 852.83 5174.47 5658.44 4.63 8.00 8.00 8.00 0.0002/11/2025 15:001749.34 103.51 1250.09 0.00 376.20 89.02 189.05 76.37 172.71 70.29 128 0.00 93.72 83.20 71.15 69.29 29.6 32000 8 0.707 0.10 0.0 15.00 0.00 15.00 15.00 0.0000 1.7387 0.0000 1.7753 383.38 0.00 4.02 4535.06 4828.08 801.17 947.03 5336.24 5779.14 0.00 3.70 4823.47 4902.41 785.22 869.18 5608.69 5775.29 4.71 8.00 8.00 8.00 0.00CLIENT:SANTOS WELL TEST LEAD:SANTOS REP/SUPERVISORS:EXPRO SUPERVISORS :EXPRO DAQ ENGINEERS:Santos Adam Phillips / Craig Stevens-RVH*RQ]DOH]'DQ%RQQDU5RJHU,KGH_)UDQN7RZHU6KDURQ2\DR_<HKLD(O]HQ\WT-XAK-0127.4PIKKA - NDB NDB-025)HE# PresentFluid PropertiesBS&W PropertiesSeparatorPROJECT DESIGN NUMBER:LOCATION / FIELD:WELL NUMBER:Chemical Injection RatesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Well Head ChokeGas PropertiesGas Rates & CumulativesNDB-025 WELL CLEAN-UP DATA SHEETWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 24 START DATE:END DATE:TimeDPI HeaterGORFrac WaterTime & Date COMMENTS BHP BHT I/A Pressure O/A Pressure Well Head PressureWell Head TemperatureU/S Choke PressureU/S Choke TemperatureD/S Choke PressureD/S Choke TemperatureChoke Size U/S DPI Solids, Mud & Carbolite Spin-out (Observed)D/S Heater PressureSeparator PressureGas Temperature Oil Temperature Corrected API WaterSalinity pH Gas S.G CO2 H2S Total Choke BS&W(Solids, Mud, Carbolite & Water)Solids, Mud & Carbolite @ ChokeWater Cut @ Choke Separator Oil Leg BS&W (2-Phase)Nitrogen Injection RateTotal Gas Rate (N2+Formation)Nitrogen InjectionCumulative Total Gas Cumulative (N2+Formation)Total GOR Solids, Mud & Carbolite RateSolids, Mud, & Carbolite CumulativeOil Rate Oil Cumulative Water RateWater CumulativeTotal Fluid RateTotal Fluid CumulativeTank Farm StrapSolids, Mud & Carbolite RateTank Farm StrapSolids, Mud, & Carbolite CumulativeTank Farm StrapOil RateTank Farm StrapOil CumulativeTank Farm StrapWater RateTank Farm StrapWater CumulativeTank Farm Strap Total Rate (Tank 1 - Tank 10)Tank Farm Strap Total Cumulative(Tank 1 - Tank 10)Percentage of Frac Water RecoveredDefoamer(D/S of Choke Manifold Data Header)Methanol (MeOH)(Separator Gas Line)Demulsifier(D/S of Choke Manifold Data Header)H2S Scavenger(D/S of Choke Manifold Data Header)(mm-dd-yyyy hh:mm)(psig) ) (psig) (psig) (psig) ) (psig) ) (psig) ) (64ths) (%) (psig) (psig) ) ) (API@60°)(ppm) (pH) (Air = 1) (%) (ppm) (%) (%) (%) (%) (MMscf/day) (MMscf/day) (MMscf) (MMscf) (scf/stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (%) (gal/day) (gal/day) (gal/day) (gal/day)CLIENT:SANTOS WELL TEST LEAD:SANTOS REP/SUPERVISORS:EXPRO SUPERVISORS :EXPRO DAQ ENGINEERS:Santos Adam Phillips / Craig Stevens-RVH*RQ]DOH]'DQ%RQQDU5RJHU,KGH_)UDQN7RZHU6KDURQ2\DR_<HKLD(O]HQ\WT-XAK-0127.4PIKKA - NDB NDB-025)HE# PresentFluid PropertiesBS&W PropertiesSeparatorPROJECT DESIGN NUMBER:LOCATION / FIELD:WELL NUMBER:Chemical Injection RatesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Well Head ChokeGas PropertiesGas Rates & CumulativesNDB-025 WELL CLEAN-UP DATA SHEET02/11/2025 15:30$SSOLHG&06) 1746.64 103.51 1251.93 0.00 381.03 89.49 192.50 75.82 175.08 71.96 128 0.00 92.29 84.40 71.36 69.46 29.3 32000 8 0.707 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7374 0.0000 1.8115 380.95 0.00 4.02 4560.72 4923.10 743.18 962.51 5303.91 5889.63 0.00 3.70 4982.69 5006.22 553.63 880.72 5536.32 5890.63 4.79 8.00 8.00 8.00 0.0002/11/2025 16:001745.91 103.52 1254.31 0.00 377.85 89.58 190.45 75.50 173.22 71.34 128 0.00 93.47 83.20 71.34 69.66 29.3 32000 8 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7418 0.0000 1.8478 351.02 0.00 4.02 4962.09 5026.47 551.74 974.00 5513.83 6004.49 0.00 3.70 4840.12 5107.05 660.02 894.47 5500.13 6005.22 4.85 8.00 8.00 8.00 0.0002/11/2025 16:301742.69 103.52 1254.37 0.00 376.18 89.57 191.52 75.31 174.05 70.23 128 0.15 93.95 84.78 71.47 69.72 29.3 32000 8 0.707 0.10 0.0 12.00 0.00 12.00 12.000.0000 1.7384 0.0000 1.8840 361.53 0.00 4.02 4808.42 5126.65 656.27 987.67 5464.69 6118.34 0.00 3.70 4950.12 5210.18 550.01 905.93 5500.13 6119.80 4.92 8.00 8.00 8.00 0.0002/11/2025 17:001742.25 103.52 1256.33 0.00 375.62 89.75 190.75 75.48 173.41 70.38 128 0.00 91.58 83.88 71.44 69.72 29.3 32000 8 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7373 0.0000 1.9202 351.56 0.00 4.02 4941.71 5229.60 549.48 999.10 5491.18 6232.72 0.00 3.70 4871.96 5311.68 664.36 919.77 5536.32 6235.14 4.978.008.008.000.0002/11/2025 17:301739.94 103.53 1257.24 0.00 378.33 90.30 192.78 75.40 175.24 70.45 128 0.00 91.86 85.47 71.79 69.93 29.3 32000 8 0.707 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7396 0.0000 1.9564 361.81 0.00 4.02 4808.19 5329.77 656.24 1012.77 5464.43 6346.56 0.00 3.70 4862.91 5412.99 601.03 932.29 5463.95 6348.98 5.04 8.00 8.00 8.00 0.0002/11/2025 18:001737.07103.53 1258.91 0.00 374.50 90.52 190.71 75.00 174.21 69.85 128 0.00 94.13 85.34 71.92 69.90 29.3 32000 8 0.707 0.10 0.0 11.00 0.00 11.00 11.00 0.0000 1.7344 0.0000 1.9926 367.69 0.00 4.02 4716.96 5428.04 583.46 1024.93 5300.43 6456.99 0.00 3.70 4574.52 5508.29 744.69 947.80 5319.21 6459.79 5.10 8.00 8.00 8.00 0.0002/11/2025 18:301734.72 103.54 1260.63 0.00 377.19 90.86 192.76 75.11 178.04 70.40 128 0.00 92.54 84.41 71.79 70.01 29.3 32000 8 0.707 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7245 0.0000 2.0285 370.94 0.00 4.02 4649.01 5524.90 757.60 1040.71 5406.61 6569.62 2.73 3.76 4589.72 5603.91 871.50 965.96 5463.95 6573.62 5.16 8.00 8.00 8.00 0.0002/11/2025 19:001733.12 103.55 1259.99 0.00 371.98 90.84 191.16 74.88 173.55 69.85 128 0.00 91.46 82.93 71.63 70.06 29.3 32000 8 0.707 0.10 0.0 16.00 0.05 15.95 15.95 0.0000 1.7375 0.0000 2.0647 379.30 2.73 4.08 4580.85 5620.33 870.32 1058.84 5453.90 6683.25 0.00 3.76 4699.00 5701.81 764.95 981.90 5463.95 6687.46 5.24 8.00 8.00 8.00 0.0002/11/2025 19:301731.92 103.55 1261.48 0.00 371.08 90.99 188.18 74.74 170.21 69.73 128 0.00 91.97 82.94 71.76 70.17 29.3 32000 8 0.707 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7357 0.0000 2.1009 372.42 0.00 4.08 4660.48 5717.42 759.47 1074.66 5419.95 6796.16 0.00 3.76 4543.40 5796.46 739.62 997.31 5283.02 6797.52 5.34 8.00 8.00 8.00 0.0002/11/2025 20:001730.41 103.56 1262.18 0.00 370.02 91.44 188.12 75.17 171.13 70.05 128 0.00 92.89 84.93 71.90 70.31 29.3 32000 8 0.707 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7402 0.0000 2.1371 371.91 0.00 4.08 4679.10 5814.90 762.51 1090.55 5441.62 6909.53 0.00 3.76 4785.12 5896.15 715.02 1012.20 5500.13 6912.11 5.43 8.00 8.00 8.00 0.0002/11/2025 20:301725.32 103.56 1262.78 0.00372.53 91.98 191.52 75.93 173.23 71.29 128 0.00 95.28 85.73 72.14 70.34 29.3 32000 8 0.707 0.10 0.0 13.00 0.00 13.00 13.00 0.0000 1.7355 0.0000 2.1733 369.05 0.00 4.08 4702.61 5912.88 703.37 1105.20 5405.99 7022.15 0.00 3.76 4636.76 5992.75 754.82 1027.93 5391.58 7024.43 5.51 8.00 8.00 8.00 0.0002/11/2025 21:0021:02 Sparged Expro separator , Observed light trace of sand.1725.43 103.57 1263.33 0.00 367.77 92.15 187.92 75.92 170.46 71.21 128 0.00 92.86 84.52 71.95 70.66 29.3 32000 8 0.707 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7309 0.0000 2.2093 372.09 0.00 4.08 4651.73 6009.79 758.07 1121.00 5409.80 7134.86 0.00 3.76 5316.10 6103.50 75.48 1029.50 5391.58 7136.75 5.58 8.00 8.00 8.00 0.0002/11/2025 21:301720.96 103.59 1263.41 0.00 365.88 92.21 186.11 75.40 169.28 70.18 128 0.00 93.10 84.13 72.05 70.60 28.0 31000 8 0.708 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7328 0.0000 2.2454 392.95 0.00 4.08 4409.80 6101.66 718.60 1135.97 5128.40 7241.70 0.00 3.76 4450.04 6196.21 724.43 1044.59 5174.47 7244.56 5.66 8.00 8.00 8.00 0.0002/11/2025 22:001726.76 103.57 1264.35 0.00 366.18 92.37 184.44 74.80 168.00 70.00 128 0.00 92.68 84.88 71.92 70.52 28.0 31000 8 0.708 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7319 0.0000 2.2815 373.35 0.00 4.08 4638.72 6198.30 755.90 1151.71 5394.61 7354.09 0.00 3.76 4776.43 6295.72 651.33 1058.16 5427.76 7357.63 5.68 8.00 8.00 8.00 0.0002/11/2025 22:30$SSOLHG&06) 1740.18 103.56 1263.29 0.00 365.31 92.28 187.16 74.10 170.14 69.53 128 0.00 92.15 82.77 71.63 70.42 28.0 32000 7 0.708 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7363 0.0000 2.3175 369.50 0.00 4.08 4699.21 6296.21 642.79 1165.11 5340.55 7465.39 0.00 3.76 4787.29 6395.45 531.92 1069.24 5319.21 7468.45 5.80 8.00 8.00 8.00 0.0002/11/2025 23:001747.36 103.52 1262.70 0.00 356.51 92.35 181.97 74.14 166.25 69.26 128 0.00 90.07 83.95 71.76 70.34 28.0 32000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7209 0.0000 2.3534 352.43 0.00 4.08 4883.02 6397.94 542.94 1176.42 5425.96 7578.43 0.00 3.76 4712.75 6493.64 642.65 1082.63 5355.39 7580.02 5.87 8.00 8.00 8.00 0.0002/11/2025 23:3023:29 Well shut in at SSV23:302SHQHGZHOORQDWKV23:336ORZO\LQFUHDVHGWRDWKV23:35 Increased Expro adjust Choke to 64/64ths as per Santos WSS.1832.13 103.56 1263.95 0.00 72.65 91.81 70.80 74.31 68.95 68.86 32 0.00 69.73 71.95 70.75 70.24 28.0 32000 7 0.708 0.10 0.0 12.00 0.00 12.00 12.00 0.00001.5224 0.0000 2.3851 367.80 0.00 4.08 4139.30 6484.18 564.92 1188.19 4704.21 7676.44 0.00 3.76 4012.20 6577.22 547.12 1094.03 4559.32 7675.01 5.92 8.00 8.00 8.00 0.0002/12/2025 00:0023: Increased Expro adjust Choke to 68/64ths as per Santos WSS. 23:40 Increased Expro adjust Choke to 72/64ths as per Santos WSS.23:45 Increased Expro adjust Choke to 76/64ths as per Santos WSS.23:50 Increased Expro adjust Choke to 80/64ths as per Santos WSS.00:00 Increased Expro adjust Choke to 84/64ths as per Santos WSS.00:00 Collected Tracerco sample.1755.15 103.55 1239.40 0.00 359.85 90.72 200.22 72.93 159.60 67.95 84 0.00 87.32 80.23 70.08 68.83 28.0 32000 7 0.708 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.4172 0.0000 2.4146 365.39 0.00 4.08 3878.67 6564.98 529.32 1199.21 4407.99 7768.27 0.00 3.76 4127.99 6663.22 358.96 1101.51 4486.95 7768.49 5.98 8.00 8.00 8.00 0.0002/12/2025 00:3000:05 Increased Expro adjust Choke to 88/64ths as per Santos WSS.00:10 Increased Expro adjust Choke to 92/64ths as per Santos WSS.00:15 Increased Expro adjust Choke to 96/64ths as per Santos WSS.00:20 Increased Expro adjust Choke to 100/64ths as per Santos WSS.00:25 Increased Expro adjust Choke to 104/64ths as per Santos WSS.00:30 Increased Expro adjust Choke to 108/64ths as per Santos WSS.1743.28 103.52 1249.46 0.00 365.50 92.32 168.81 73.57 156.11 68.91 108 0.00 87.90 80.76 71.04 69.57 30.6 32000 7 0.708 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.6681 0.0000 2.4494 350.14 0.00 4.08 4764.11 6664.23 414.52 1207.85 5178.63 7876.16 0.00 3.76 4624.45 6759.57 513.83 1112.21 5138.28 7875.53 6.038.00 8.00 8.00 0.0002/12/2025 01:0000:35 Increased Expro adjust Choke to 112/64ths as per Santos WSS.00:40 Increased Expro adjust Choke to 116/64ths as per Santos WSS.00:45 Increased Expro adjust Choke to 120/64ths as per Santos WSS.00:50 Increased Expro adjust Choke to 124/64ths as per Santos WSS.00:55 Increased Expro adjust Choke to 128/64ths as per Santos WSS.1744.23 103.51 1254.97 0.00 374.54 92.32 189.23 73.45 173.99 68.97 128 0.00 90.40 81.98 70.88 69.78 30.6 32000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7655 0.0000 2.4862 366.73 0.00 4.08 4814.15 6764.53 535.32 1219.00 5349.47 7987.61 0.00 3.76 4574.52 6854.87 744.69 1127.73 5319.21 7986.35 6.10 8.00 8.00 8.00 0.0002/12/2025 01:301741.65 103.50 1258.83 0.00 372.97 92.58 187.90 73.64 170.53 69.24 128 0.00 91.46 84.70 71.23 69.87 30.6 32000 7 0.708 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7386 0.0000 2.5224 373.56 0.00 4.08 4654.20 6861.49 758.50 1234.80 5412.70 8100.37 0.00 3.76 4852.42 6955.96 539.16 1138.96 5391.58 8098.68 6.14 8.00 8.00 8.00 0.0002/12/2025 02:001740.63 103.50 1262.60 0.00 373.33 92.98 188.78 74.31 172.42 69.84 128 0.00 91.71 84.20 71.26 69.92 30.6 32000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.74280.0000 2.5587 354.91 0.00 4.08 4910.65 6963.80 546.06 1246.18 5456.71 8214.05 0.00 3.76 4712.75 7054.14 642.65 1152.35 5355.39 8210.25 6.22 8.00 8.008.000.0002/12/2025 02:301739.10 103.50 1263.41 0.00 372.91 93.23 189.49 74.25 170.52 69.89 128 0.00 92.10 83.42 71.33 70.11 30.6 31000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7457 0.0000 2.5951 364.51 0.00 4.08 4789.17 7063.57 649.59 1259.71 5438.76 8327.36 0.00 3.76 4744.59 7152.99 646.99 1165.83 5391.58 8322.57 6.26 8.00 8.00 8.00 0.0002/12/2025 03:001738.27 103.49 1266.32 0.00 372.17 93.31 186.98 73.75 170.67 69.25 128 0.00 91.84 83.83 71.31 70.03 29.8 29000 7 0.708 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7535 0.0000 2.6316 356.95 0.00 4.08 4912.48 7165.91 550.17 1271.18 5462.65 8441.17 0.00 3.76 4852.42 7254.08 539.16 1177.06 5391.58 8434.89 6.34 8.00 8.00 8.00 0.0002/12/2025 03:301736.90 103.49 1268.810.00 374.05 93.43 189.21 74.08 172.15 69.58 128 0.00 91.70 85.30 71.39 70.11 29.8 29000 7 0.706 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7551 0.0000 2.6682 364.53 0.00 4.08 4814.73 7266.22 535.38 1282.33 5350.11 8552.63 0.00 3.76 4701.89 7352.04 581.13 1189.17 5283.02 8544.96 6.38 8.00 8.00 8.00 0.0002/12/2025 04:001735.05 103.49 1269.82 0.00 375.70 93.49 190.92 74.24 173.41 69.55 128 0.00 93.73 85.31 71.44 70.16 29.8 29000 7 0.706 0.10 0.0 11.00 0.00 11.00 11.00 0.0000 1.7583 0.0000 2.7048 361.10 0.00 4.08 4869.33 7367.67 602.34 1294.88 5471.67 8666.62 0.00 3.76 4819.85 7452.45 535.54 1200.32 5355.39 8656.53 6.44 8.00 8.00 8.00 0.0002/12/2025 04:301733.43 103.49 1271.64 0.00 374.07 93.47 189.01 73.73 171.61 69.47 128 0.00 92.11 83.83 71.25 70.11 29.8 29000 7 0.706 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7572 0.0000 2.7414 359.210.00 4.08 4891.77 7469.58 543.95 1306.21 5435.72 8779.86 0.00 3.76 4917.55 7554.90 546.39 1211.71 5463.95 8770.36 6.51 8.00 8.00 8.00 0.0002/12/2025 05:001731.42 103.49 1272.07 0.00 371.04 93.60 189.11 73.67 170.96 69.27 128 0.00 93.31 83.71 71.25 69.92 29.8 29000 7 0.706 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7620 0.0000 2.7781 358.71 0.00 4.08 4912.21 7571.92 546.22 1317.59 5458.43 8893.58 0.00 3.76 4819.85 7655.31 535.54 1222.86 5355.39 8881.93 6.56 8.00 8.00 8.00 0.0002/12/2025 05:301729.85 103.50 1267.24 0.00 369.23 93.50 187.50 72.91 169.51 68.97 128 0.00 93.29 84.10 71.15 69.87 29.8 29000 7 0.706 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.6871 0.0000 2.8133 357.88 0.00 4.08 4713.98 7670.12 524.17 1328.51 5238.15 9002.71 0.00 3.76 4605.28 7751.26 569.19 1234.72 5174.47 8989.73 6.61 8.00 8.00 8.00 0.0002/12/2025 06:00Collected Tracerco sample.1728.13 103.50 1272.41 0.00 371.50 93.93 186.72 73.49 171.53 69.33 128 0.00 93.96 84.24 71.33 69.73 29.8 29000 7 0.706 0.10 0.0 11.00 0.00 11.00 11.00 0.0000 1.7526 0.0000 2.8498 368.32 0.00 4.08 4758.27 7769.25 588.58 1340.78 5346.85 9114.11 0.00 3.76 4722.15 7849.64 524.68 1245.65 5246.84 9099.04 6.67 8.00 8.00 8.00 0.0002/12/2025 06:301728.31 103.50 1273.59 0.00 372.33 93.84 187.46 73.30 170.82 69.19 128 0.00 91.72 84.76 71.20 69.71 29.8 28000 7 0.706 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7548 0.0000 2.8863 358.37 0.00 4.08 4896.74 7871.27 544.49 1352.12 5441.23 9227.47 0.00 3.76 4980.52 7953.40 374.88 1253.46 5355.39 9210.61 6.73 8.00 8.00 8.00 0.0002/12/2025 07:001726.57 103.50 1273.33 0.00 368.85 93.75 187.16 73.16 169.72 68.89 128 0.00 92.98 83.29 71.04 69.60 29.8 28000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.7278 0.0000 2.9220 345.15 0.00 4.08 5005.79 7975.55 376.98 1359.98 5382.77 9339.61 0.00 3.76 4893.67 8055.35 425.54 1262.33 5319.21 9321.43 6.778.00 8.00 8.00 0.0002/12/2025 07:301725.55 103.51 1274.32 0.00 367.02 93.77 186.01 73.00 170.29 68.64 128 0.00 93.98 83.83 70.94 69.57 29.8 28000 7 0.706 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.7614 0.0000 2.9587 351.57 0.00 4.08 5010.24 8079.93 435.93 1369.08 5446.17 9453.09 0.00 3.76 4926.96 8157.99 428.43 1271.25 5355.39 9433.00 6.82 8.00 8.00 8.00 0.0002/12/2025 08:001724.37 103.51 1276.89 0.00 370.40 93.90 188.78 72.79 170.72 68.59 128 0.20 92.38 84.64 71.15 69.39 29.8 28000 7 0.706 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.7603 0.0000 2.9954 352.21 0.00 4.08 4998.04 8184.06 434.87 1378.15 5432.91 9566.28 0.00 3.76 4873.41 8259.52 481.99 1281.30 5355.39 9544.57 6.868.00 8.00 8.00 0.0002/12/2025 08:30Sparged Expro separator , Observed light trace of sand.1720.38 103.51 1277.63 0.00 367.04 93.70 191.54 72.09 174.16 67.84 128 0.00 95.85 86.23 71.07 69.39 29.8 28000 7 0.706 0.1 0.0 9.00 0.00 9.00 9.00 0.00001.7771 0.0000 3.0324 352.46 0.00 4.08 5041.98 8289.10 498.99 1388.53 5540.97 9681.70 0.00 3.76 4862.91 8360.83 601.03 1293.82 5463.95 9658.40 6.91 8.00 8.00 8.00 0.0002/12/2025 09:001721.48 103.51 1280.30 0.00 372.21 93.89 189.35 72.06 172.30 67.78 128 0.10 94.80 84.91 71.04 69.20 29.8 28000 7 0.706 0.10 0.0 11.00 0.00 11.00 11.00 0.0000 1.7840 0.0000 3.0696 367.44 0.00 4.08 4855.12 8390.25 600.56 1401.05 5455.68 9795.37 0.00 3.76 4993.54 8464.86 434.22 1302.86 5427.76 9771.48 6.97 8.00 8.00 8.00 0.0002/12/2025 09:301719.66 103.52 1279.70 0.00 371.12 94.14 189.79 71.93 171.56 67.47 128 0.10 91.48 85.45 70.86 69.09 29.3 28000 7 0.707 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.7665 0.0000 3.1064 360.53 0.00 4.08 4899.72 8492.32 426.30 1409.93 5326.03 9906.33 0.00 3.76 4754.72 8563.92 528.30 1313.87 5283.02 9881.54 7.028.00 8.00 8.00 0.0002/12/2025 10:001727.75 103.50 1280.57 0.00 373.55 94.37 188.89 71.85 170.64 67.66 128 0.10 92.94 83.85 70.91 69.09 29.3 28000 7 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.00001.7805 0.0000 3.1435 365.55 0.00 4.08 4870.68 8593.79 541.57 1421.21 5412.25 10019.08 0.00 3.76 4860.38 8665.18 422.64 1322.67 5283.02 9991.61 7.088.00 8.00 8.00 0.0002/12/2025 10:301751.79 103.49 1276.79 0.00 318.18 93.10 169.71 70.78 155.90 66.45 128 0.00 91.23 83.35 69.92 68.69 29.3 28000 7 0.707 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.6519 0.0000 3.1779 358.34 0.00 4.08 4610.00 8689.84 401.09 1429.57 5011.09 10123.48 0.00 3.76 4461.62 8758.13 495.74 1333.00 4957.36 10094.89 7.12 8.00 8.00 8.00 0.0002/12/2025 11:00Sparged Expro separator , Observed light trace of sand.1734.93 103.49 1278.25 0.00 355.93 94.01 174.84 71.40 157.40 66.89 128 0.10 88.18 81.31 70.38 68.85 29.3 28000 7 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.6653 0.0000 3.2126 359.82 0.00 4.08 4627.99 8786.25 514.57 1440.29 5142.57 10230.62 0.00 3.76 4708.77 8856.23 465.70 1342.70 5174.47 10202.69 7.17 8.00 8.00 8.00 0.0002/12/2025 11:301733.75 103.49 1280.34 0.00 373.25 94.39 188.30 71.95 170.55 67.57 128 0.00 91.67 83.86 70.64 68.71 29.3 28000 7 0.707 0.10 0.0 9.00 0.00 9.00 9.00 0.0000 1.7241 0.0000 3.2486 360.22 0.00 4.08 4786.15 8885.96 473.65 1450.14 5259.79 10340.18 0.00 3.76 4689.59 8953.93 521.07 1353.56 5210.65 10311.24 7.22 8.00 8.00 8.00 0.0002/12/2025 12:00Collected Tracerco sample.$SSOLHG&06) 1730.84 103.48 1283.66 0.00 375.64 94.47 190.73 71.69 174.30 66.99 128 0.10 93.94 84.79 70.57 68.63 29.3 28000 7 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7743 0.0000 3.2855 364.28 0.00 4.08 4870.76 8987.44 541.57 1461.42 5412.32 10452.93 0.00 3.76 4754.72 9052.99 528.30 1364.57 5283.02 10421.31 7.28 8.00 8.00 8.00 0.0002/12/2025 12:301728.55 103.48 1286.03 0.00 376.24 94.61 191.10 71.90 174.66 67.06 128 0.00 93.91 85.71 70.67 68.69 29.3 28000 7 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.7867 0.0000 3.3228 374.82 0.00 4.08 4766.90 9086.75 530.02 1472.46 5296.91 10563.28 0.00 3.76 4808.27 9153.16 655.67 1378.23 5463.95 10535.14 7.33 8.00 8.00 8.00 0.0002/12/2025 13:0013:02 Sparged Expro separator , Observed trace of solids.1727.54 103.48 1287.00 0.00 378.13 94.55 191.98 71.90 175.63 66.90 128 0.00 93.78 85.58 70.67 68.58 29.3 28000 7 0.707 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8037 0.0000 3.3603 386.34 0.00 4.08 4668.57 9184.01 637.15 1485.74 5305.72 10673.83 0.00 3.76 4774.62 9252.63 472.22 1388.06 5246.84 10644.45 7.40 8.00 8.00 8.00 0.0002/12/2025 13:301726.54 103.48 1287.74 0.00 378.43 94.44 191.08 72.37 173.49 67.20 128 0.00 94.45 85.20 70.67 68.45 29.3 28000 7 0.707 0.10 0.0 9.00 0.00 9.00 9.00 0.0000 1.8151 0.0000 3.3981 376.59 0.00 4.08 4819.96 9284.42 476.99 1495.66 5296.95 10784.16 0.00 3.76 4926.96 9355.27 428.43 1396.99 5355.39 10756.02 7.45 8.00 8.00 8.00 0.0002/12/2025 14:001725.10 103.48 1288.14 0.00 376.34 94.72 189.91 72.65 174.29 67.11 128 0.00 92.86 85.46 70.65 68.31 29.3 28000 7 0.707 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8099 0.0000 3.4359 368.95 0.00 4.08 4905.56 9386.62 426.80 1504.56 5332.36 10895.26 0.00 3.76 4873.41 9456.80 481.99 1407.03 5355.39 10867.59 7.49 8.00 8.00 8.00 0.0002/12/2025 14:301724.38 103.48 1289.33 0.00 375.84 94.87 190.81 72.82 173.62 67.30 128 0.00 93.66 84.80 70.67 68.31 29.3 28000 7 0.707 0.10 0.0 9.00 0.00 9.00 9.00 0.00001.7993 0.0000 3.4733 372.31 0.00 4.08 4832.71 9487.30 478.25 1514.51 5310.95 11005.89 0.00 3.76 4819.85 9557.22 535.54 1418.19 5355.39 10979.16 7.54 8.00 8.00 8.00 0.0002/12/2025 15:001722.73 103.48 1290.35 0.00 377.47 94.93 191.24 72.69 174.53 67.61 128 0.00 93.89 85.04 70.56 68.39 29.3 28000 7 0.707 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8029 0.0000 3.5109 375.69 0.00 4.08 4798.94 9587.28 533.58 1525.64 5332.51 11116.99 0.00 3.76 4939.26 9660.12 488.50 1428.37 5427.76 11092.24 7.60 8.00 8.00 8.00 0.0002/12/2025 15:301723.85 103.47 1290.43 0.00 381.17 94.82 193.03 71.66 174.58 66.63 128 0.00 94.15 85.71 70.59 68.42 29.5 28000 7 0.708 0.10 0.0 9.00 0.00 9.00 9.00 0.0000 1.8149 0.0000 3.5487 369.83 0.00 4.08 4907.43 9689.52 485.65 1535.76 5393.08 11229.35 0.00 3.76 4840.12 9760.95 660.02 1442.12 5500.13 11206.82 7.65 8.00 8.00 8.00 0.0002/12/2025 16:001737.64 103.471292.28 0.00 382.89 94.87 194.65 71.15 177.81 66.27 128 0.00 94.02 85.45 70.43 68.21 29.5 28000 7 0.708 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8244 0.0000 3.5867 385.37 0.00 4.08 4734.20 9788.15 646.10 1549.22 5380.30 11341.44 0.00 3.76 4722.15 9859.33 705.61 1456.82 5427.76 11319.90 7.71 8.00 8.008.00 0.0002/12/2025 16:301736.66 103.44 1289.79 0.00 381.01 95.12 191.08 71.07 174.51 67.17 128 0.00 92.96 83.98 70.11 68.21 29.5 28000 7 0.708 0.10 0.0 13.00 0.00 13.00 13.00 0.0000 1.8726 0.0000 3.6258 392.39 0.00 4.08 4772.24 9887.57 713.72 1564.08 5485.97 11455.72 0.00 3.76 5038.05 9964.29 498.27 1467.20 5536.32 11435.24 7.79 8.00 8.00 8.00 0.0002/12/2025 17:001735.71 103.43 1291.88 0.00 374.70 95.27 196.62 71.16 179.93 67.53 128 0.10 94.99 84.79 70.14 68.07 29.5 28000 7 0.708 0.10 0.0 9.00 0.00 9.00 9.00 0.0000 1.8475 0.0000 3.6643375.47 0.00 4.08 4920.39 9990.08 486.93 1574.22 5407.32 11568.37 0.00 3.76 4950.12 10067.42 550.01 1478.65 5500.13 11549.83 7.84 8.00 8.00 8.00 0.0002/12/2025 17:301733.67 103.42 1292.92 0.00 386.39 95.55 194.93 71.03 177.70 66.80 128 0.00 97.11 86.92 70.43 68.02 29.5 28000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8384 0.0000 3.7025 372.08 0.00 4.08 4940.95 10093.01 549.37 1585.68 5490.32 11682.77 0.00 3.76 5070.98 10173.06 501.53 1489.10 5572.50 11665.92 7.89 8.00 8.00 8.00 0.0002/12/2025 18:001733.47 103.42 1294.29 0.00 384.42 95.38 194.41 71.36 177.97 66.85 128 0.00 94.61 85.86 70.33 67.88 29.5 28000 7 0.708 0.10 0.0 9.00 0.00 9.00 9.00 0.0000 1.8529 0.0000 3.7411 373.25 0.00 4.08 4964.12 10196.43 491.25 1595.90 5455.37 11796.40 0.00 3.76 4950.12 10276.19 550.01 1500.56 5500.13 11780.517.94 8.00 8.00 8.00 0.0002/12/2025 18:301732.45 103.41 1294.35 0.00 387.1395.68 194.71 71.57 178.44 67.08 128 0.00 96.66 86.96 70.49 67.88 29.5 28000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8564 0.0000 3.7798 374.21 0.00 4.08 4960.98 10299.78 551.59 1607.39 5512.57 11911.25 0.00 3.76 5023.94 10380.86 620.94 1513.50 5644.87 11898.11 8.00 8.00 8.00 8.00 0.0002/12/2025 19:001731.80 103.40 1296.34 0.00 385.51 95.78 197.59 71.10 179.01 66.76 128 0.00 96.16 85.74 70.35 67.79 29.5 28000 7 0.708 0.10 0.0 11.00 0.00 11.00 11.00 0.0000 1.8602 0.0000 3.8186 381.55 0.00 4.08 4875.27 10401.35 603.00 1619.95 5478.27 12025.38 0.00 3.76 4950.12 10483.99 550.01 1524.96 5500.13 12012.70 8.05 8.00 8.00 8.00 0.0002/12/2025 19:30Sparged Expro separator , Observed light trace of sand.1731.03 103.40 1297.60 0.00 385.81 95.95 196.52 71.20 179.16 66.90 128 0.00 95.60 85.34 70.40 67.90 29.5 28000 7 0.708 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8592 0.0000 3.8573 374.13 0.00 4.08 4969.40 10504.88 552.52 1631.46 5521.92 12140.42 0.00 3.76 5193.28 10592.18 451.59 1534.36 5644.87 12130.30 8.10 8.00 8.00 8.00 0.0002/12/2025 20:001730.08 103.40 1298.11 0.00 386.43 96.23 197.59 71.21 179.97 67.03 128 0.00 95.26 86.86 70.59 68.31 29.5 28000 7 0.708 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8711 0.0000 3.8963 379.22 0.00 4.08 4934.02 10607.67 429.28 1640.40 5363.29 12252.15 0.00 3.76 4893.67 10694.13 425.54 1543.23 5319.21 12241.118.18 8.00 8.00 8.00 0.0002/12/2025 20:301727.93 103.40 1298.03 0.00 385.22 96.56 196.30 71.65 179.27 67.31 128 0.00 97.99 86.51 70.88 69.03 29.5 28000 7 0.708 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8600 0.0000 3.9350 366.91 0.00 4.08 5069.41 10713.28 441.07 1649.59 5510.47 12366.95 0.00 3.76 5115.12 10800.70 385.01 1551.25 5500.13 12355.708.21 8.00 8.00 8.00 0.0002/12/2025 21:001725.90 103.40 1298.27 0.00 384.70 96.67 195.66 71.48 177.60 66.84 128 0.00 93.98 85.44 70.94 69.63 29.5 28000 7 0.708 0.10 0.0 7.00 0.00 7.00 7.00 0.00001.8626 0.0000 3.9738 366.77 0.00 4.08 5078.32 10819.08 382.43 1657.56 5460.75 12480.72 0.00 3.76 5115.12 10907.26 385.01 1559.27 5500.13 12470.29 8.26 8.00 8.00 8.00 0.0002/12/2025 21:301724.97 103.41 1298.07 0.00 382.93 96.96 194.85 71.21 177.28 66.77 128 0.00 96.24 85.30 71.10 69.89 29.8 28000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8658 0.0000 4.0127 367.78 0.00 4.08 5072.98 10924.77 382.04 1665.52 5455.02 12594.37 0.00 3.76 5182.43 11015.23 390.08 1567.40 5572.50 12586.388.30 8.00 8.00 8.00 0.0002/12/2025 22:001723.46 103.41 1296.10 0.00 384.62 97.01 197.06 70.97 178.49 66.49 128 0.00 91.49 83.98 70.91 69.97 29.8 28000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8712 0.0000 4.0517 365.99 0.00 4.08 5112.82 11031.29 385.04 1673.54 5497.86 12708.90 0.00 3.76 4980.52 11118.99 374.88 1575.21 5355.39 12697.958.35 8.00 8.00 8.00 0.0002/12/2025 22:30Sparged Expro separator , Observed light trace of sand.1723.40 103.41 1296.86 0.00 378.55 97.17 192.97 70.46 174.57 66.25 128 0.00 93.75 84.11 70.96 70.10 29.8 28000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8633 0.0000 4.0905 366.41 0.00 4.08 5085.19 11137.23 382.96 1681.52 5468.15 12822.82 0.00 3.76 5182.43 11226.96 390.08 1583.34 5572.50 12814.048.37 8.00 8.00 8.00 0.0002/12/2025 23:001720.78 103.41 1297.98 0.00 384.74 97.59 197.51 70.81 179.93 66.72 128 0.00 97.49 86.51 71.39 70.29 29.8 28000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8581 0.0000 4.1292 378.85 0.00 4.08 4904.63 11239.41 369.37 1689.21 5274.00 12932.70 0.00 3.76 5014.17 11331.42 377.41 1591.20 5391.58 12926.378.41 8.00 8.00 8.00 0.0002/12/2025 23:301718.95 103.41 1298.23 0.00 378.68 98.00 193.25 70.74 175.52 66.32 128 0.00 92.45 84.38 71.20 70.37 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8699 0.0000 4.1682 374.87 0.00 4.08 4988.13 11343.33 375.66 1697.04 5363.79 13044.44 0.00 3.76 5060.12 11436.84 440.01 1600.37 5500.13 13040.958.45 8.00 8.00 8.00 0.0002/13/2025 00:00$SSOLHG&06) Collected Tracerco sample.1716.81 103.41 1298.11 0.00 381.09 98.67 193.45 71.03 177.28 67.35 128 0.00 96.20 86.13 71.39 70.58 29.8 29000 7 0.706 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8659 0.0000 4.2070 376.67 0.00 4.08 4953.69 11446.53 431.03 1706.02 5384.72 13156.63 0.00 3.76 5216.08 11545.50 392.61 1608.54 5608.69 13157.808.49 8.00 8.00 8.00 0.0002/13/2025 00:301716.57 103.41 1297.06 0.00 380.12 98.85 194.01 70.82 177.42 67.30 128 0.00 95.61 86.15 71.47 70.65 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8696 0.0000 4.2460 374.86 0.00 4.08 4987.43 11550.43 375.61 1713.85 5363.04 13268.36 0.00 3.76 5047.82 11650.67 379.94 1616.46 5427.76 13270.888.53 8.00 8.00 8.00 0.0002/13/2025 01:001714.77 103.41 1297.28 0.00 379.58 98.76 191.66 70.14 174.62 66.32 128 0.00 94.14 85.38 71.37 70.75 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.00001.86340.0000 4.2848 376.33 0.00 4.08 4951.41 11653.59 372.90 1721.61 5324.31 13379.28 0.00 3.76 5081.47 11756.53 382.48 1624.43 5463.95 13384.71 8.57 8.00 8.00 8.00 0.0002/13/2025 01:301713.29 103.42 1298.25 0.00 381.31 99.55 193.55 70.40 175.55 66.13 128 0.00 93.48 84.27 71.45 70.54 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8574 0.0000 4.3235 375.40 0.00 4.08 4947.73 11756.67 372.62 1729.38 5320.35 13490.12 0.00 3.76 5047.82 11861.69 379.94 1632.34 5427.76 13497.798.61 8.00 8.00 8.00 0.0002/13/2025 02:001713.03 103.42 1298.15 0.00 381.17 100.03 191.68 70.14 174.71 66.16 128 0.00 93.52 83.89 71.34 70.64 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8597 0.0000 4.3622 379.26 0.00 4.08 4903.52 11858.82 369.29 1737.07 5272.81 13599.97 0.00 3.76 5047.82 11966.86 379.94 1640.26 5427.76 13610.87 8.65 8.00 8.00 8.00 0.0002/13/2025 02:301708.34 103.42 1297.480.00 377.21 100.73 191.10 69.82 173.04 66.20 128 0.00 94.86 85.76 71.10 70.59 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8684 0.0000 4.4012379.77 0.00 4.08 4919.74 11961.32 370.51 1744.79 5290.25 13710.18 0.00 3.76 5115.12 12073.42 385.01 1648.28 5500.13 13725.46 8.69 8.00 8.00 8.00 0.0002/13/2025 03:001709.91 103.42 1297.98 0.00 378.39 105.84 191.24 70.20 174.35 66.24 128 0.00 91.65 85.36 71.31 70.61 29.8 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8555 0.0000 4.4398 375.94 0.00 4.08 4935.64 12064.14 371.71 1752.53 5307.34 13820.75 0.00 3.76 5047.82 12178.59 379.94 1656.20 5427.76 13838.53 8.73 8.00 8.00 8.00 0.0002/13/2025 03:301708.63 103.43 1298.07 0.00 380.60 90.82 195.14 70.05 176.80 65.78 128 0.00 95.19 85.75 71.53 70.70 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8561 0.0000 4.4785 376.940.00 4.08 4924.09 12166.73 370.84 1760.26 5294.93 13931.06 0.00 3.76 5081.47 12284.45 382.48 1664.16 5463.95 13952.37 8.76 8.00 8.00 8.00 0.0002/13/2025 04:001705.11 103.43 1298.03 0.00 379.56 88.59 193.33 70.21 176.36 66.01 128 0.00 94.47 85.46 71.44 70.68 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8642 0.0000 4.5173 384.18 0.00 4.08 4852.48 12267.82 365.44 1767.87 5217.92 14039.77 0.00 3.76 4946.86 12387.51 372.34 1671.92 5319.21 14063.188.80 8.00 8.00 8.00 0.0002/13/2025 04:301710.94 103.42 1297.18 0.00 381.17 88.74 194.89 69.78 176.82 65.10 128 0.00 95.09 86.38 71.39 70.53 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8616 0.0000 4.5561 380.53 0.00 4.08 4892.01 12369.74 368.42 1775.55 5260.43 14149.36 0.00 3.76 5047.82 12492.67 379.94 1679.84 5427.76 14176.268.84 8.00 8.00 8.00 0.0002/13/2025 05:001717.15 103.40 1298.09 0.00 380.18 96.89194.87 69.51 178.08 64.61 128 0.00 94.63 85.44 70.98 70.03 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8590 0.0000 4.5948 379.32 0.00 4.08 4900.73 12471.84 369.07 1783.24 5269.80 14259.15 0.00 3.76 5081.47 12598.54 382.48 1687.80 5463.95 14290.09 8.88 8.00 8.00 8.00 0.0002/13/2025 05:301720.69 103.38 1297.94 0.00 380.16 99.24 193.89 69.43 177.66 64.74 128 0.00 96.34 86.89 71.04 69.93 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8582 0.0000 4.6335 376.66 0.00 4.08 4933.30 12574.61 371.52 1790.98 5304.82 14369.67 0.00 3.76 5081.47 12704.40 382.48 1695.77 5463.95 14403.938.92 8.00 8.00 8.00 0.0002/13/2025 06:00Collected Tracerco sample.1720.81 103.38 1298.75 0.00 380.32 63.68 193.13 69.64 175.90 64.74 128 0.00 92.83 85.41 71.07 69.96 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8589 0.0000 4.6723 378.63 0.00 4.08 4909.51 12676.89 369.73 1798.68 5279.24 14479.65 0.00 3.76 5047.82 12809.56 379.94 1703.69 5427.76 14517.008.95 8.00 8.00 8.00 0.0002/13/2025 06:301719.78 103.37 1298.09 0.00 378.66 71.28 194.25 69.28 177.38 64.94 128 0.00 93.89 85.14 71.00 69.88 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8582 0.0000 4.7110 378.18 0.00 4.08 4913.58 12779.26 370.04 1806.39 5283.62 14589.72 0.00 3.76 5047.82 12914.73 379.94 1711.60 5427.76 14630.088.99 8.00 8.00 8.00 0.00WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 25 START DATE:END DATE:TimeDPI HeaterGORFrac WaterTime & Date COMMENTS BHP BHT I/A Pressure O/A Pressure Well Head PressureWell Head TemperatureU/S Choke PressureU/S Choke TemperatureD/S Choke PressureD/S Choke TemperatureChoke Size U/S DPI Solids, Mud & Carbolite Spin-out (Observed)D/S Heater PressureSeparator PressureGas Temperature Oil Temperature Corrected API WaterSalinity pH Gas S.G CO2 H2S Total Choke BS&W(Solids, Mud, Carbolite & Water)Solids, Mud & Carbolite @ ChokeWater Cut @ Choke Separator Oil Leg BS&W (2-Phase)Nitrogen Injection RateTotal Gas Rate (N2+Formation)Nitrogen InjectionCumulative Total Gas Cumulative (N2+Formation)Total GOR Solids, Mud & Carbolite RateSolids, Mud, & Carbolite CumulativeOil Rate Oil Cumulative Water RateWater CumulativeTotal Fluid RateTotal Fluid CumulativeTank Farm StrapSolids, Mud & Carbolite RateTank Farm StrapSolids, Mud, & Carbolite CumulativeTank Farm StrapOil RateTank Farm StrapOil CumulativeTank Farm StrapWater RateTank Farm StrapWater CumulativeTank Farm Strap Total Rate (Tank 1 - Tank 10)Tank Farm Strap Total Cumulative(Tank 1 - Tank 10)Percentage of Frac Water RecoveredDefoamer(D/S of Choke Manifold Data Header)Methanol (MeOH)(Separator Gas Line)Demulsifier(D/S of Choke Manifold Data Header)H2S Scavenger(D/S of Choke Manifold Data Header)(mm-dd-yyyy hh:mm)(psig) ) (psig) (psig) (psig) ) (psig) ) (psig) ) (64ths) (%) (psig) (psig) ) ) (API@60°)(ppm) (pH) (Air = 1) (%) (ppm) (%) (%) (%) (%) (MMscf/day) (MMscf/day) (MMscf) (MMscf) (scf/stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (%) (gal/day) (gal/day) (gal/day) (gal/day)CLIENT:SANTOS WELL TEST LEAD:SANTOS REP/SUPERVISORS:EXPRO SUPERVISORS :EXPRO DAQ ENGINEERS:Santos Adam Phillips / Craig Stevens-RVH*RQ]DOH]'DQ%RQQDU5RJHU,KGH_)UDQN7RZHU6KDURQ2\DR_<HKLD(O]HQ\WT-XAK-0127.4PIKKA - NDB NDB-025)HE# PresentFluid PropertiesBS&W PropertiesSeparatorPROJECT DESIGN NUMBER:LOCATION / FIELD:WELL NUMBER:Chemical Injection RatesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Well Head ChokeGas PropertiesGas Rates & CumulativesNDB-025 WELL CLEAN-UP DATA SHEET02/13/2025 07:00$SSOLHG&06) 1719.22 103.37 1299.49 0.00 377.33 71.42 192.82 69.42 174.20 65.37 128 0.00 92.69 84.26 71.01 69.96 29.6 29000 7 0.706 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8660 0.0000 4.7499 381.60 0.00 4.08 4889.87 12881.13 368.25 1814.06 5258.12 14699.27 0.00 3.76 5225.13 13023.58 275.01 1717.33 5500.13 14744.679.03 8.00 8.00 8.00 0.0002/13/2025 07:301717.95 103.36 1300.76 0.00 380.24 71.13 193.05 69.13 175.98 65.09 128 0.00 95.07 85.27 70.93 70.04 29.6 29000 7 0.706 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.8649 0.0000 4.7887 360.86 0.00 4.08 5168.00 12988.80 272.10 1819.73 5440.11 14812.60 0.00 3.76 5068.08 13129.17 323.49 1724.07 5391.58 14856.999.06 8.00 8.00 8.00 0.0002/13/2025 08:001716.84 103.36 1300.68 0.00 380.24 70.89 194.97 68.89 176.76 65.16 128 0.00 93.60 85.67 70.99 69.70 29.6 29000 7 0.706 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8644 0.0000 4.8276 366.92 0.00 4.08 5081.18 13094.66 324.48 1826.49 5405.66 14925.22 0.00 3.76 5225.13 13238.02 275.01 1729.80 5500.13 14971.589.09 8.00 8.00 8.00 0.0002/13/2025 08:3008:40/56LQMHFWHGEEOVRIGLHVHOWRIUHH]HSURWHFWLQMHFWLRQZHOO1'%0141715.34 103.36 1301.04 0.00 381.49 69.06 195.26 67.06 177.73 63.18 128 0.00 93.56 85.65 70.56 69.48 29.6 29000 7 0.706 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.8645 0.0000 4.8664 360.14 0.00 4.08 5177.14 13202.51 272.58 1832.17 5449.72 15038.76 0.00 3.76 5225.13 13346.88 275.01 1735.53 5500.13 15086.179.12 8.00 8.00 8.00 0.0002/13/2025 09:001714.36 103.36 1300.74 0.00 380.26 69.26 192.95 67.26 176.33 63.20 128 0.00 95.38 85.91 70.48 69.25 29.6 29000 7 0.706 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.8662 0.0000 4.9053 363.37 0.00 4.08 5135.86 13309.51 270.41 1837.80 5406.27 15151.39 0.00 3.76 5122.00 13453.59 269.58 1741.15 5391.58 15198.499.15 8.00 8.00 8.00 0.0002/13/2025 09:3009:44&RPPHQFHGEOHHGLQJGRZQ,$SUHVVXUH09:53%OHGGRZQ,$SUHVVXUHWRSVL09:551'%VKXWLQDWFKRNHPDQLIROGGXHWRSKDVHZHDWKHUconditions09:56&ORVHG):9 WXUQV&ORVHG0DVWHUYDOYH WXUQV1713.46 103.36 1293.81 0.00 378.47 69.26 194.49 68.72 176.68 62.90 128 0.00 94.04 86.74 70.37 69.12 29.4 29000 7 0.703 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.8790 0.0000 4.9444 362.57 0.00 4.08 5182.53 13417.48 272.86 1843.49 5455.40 15265.04 0.00 3.76 4950.12 13556.72 260.53 1746.58 5210.65 15307.059.18 8.00 8.00 8.00 0.0002/13/2025 10:007DQNVWUDSUDWHLVEDVHGRQPLQXWHVRIIORZEDFN1792.95 103.36 835.31 0.00 472.76 68.89 61.39 63.41 60.93 61.47 0 0.00 59.14 61.63 70.03 68.99 29.4 29000 7 0.703 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4894 0.0000 4.9755 351.46 0.00 4.08 4237.72 13505.77 223.12 1848.13 4460.83 15357.98 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 8.00 8.00 8.00 0.0002/15/2025 11:0006:04([SURFUHZEDFNRQORFDWLRQCommenced NDBi-014 Injection.1916.07 105.06 0.00 0.00 400.05 18.79 0.00 74.29 2.54 63.86 0 0.00 0.00 1.34 70.00 66.14 45.0 0 0 0.703 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.2002/15/2025 11:301916.37 105.07 0.00 0.00 402.56 20.12 0.00 71.29 1.60 64.02 0 0.00 0.00 1.34 69.52 65.82 45.0 0 0 0.703 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.2002/15/2025 12:001916.67 105.07 0.00 0.00 421.91 23.16 0.00 71.36 2.54 65.14 0 0.00 0.00 1.20 69.20 65.72 45.0 0 0 0.703 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 12:301916.96 105.07 0.00 0.00 427.54 23.79 0.00 72.12 1.57 65.06 0 0.00 0.00 1.34 68.99 65.53 45.0 0 0 0.703 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 13:001917.25 105.08 0.00 0.00 430.55 23.94 0.00 72.36 0.83 65.80 0 0.00 0.00 1.34 68.67 65.00 45.0 0 0 0.703 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 13:301917.54 105.08 0.00 0.00 432.04 24.11 0.00 71.23 2.01 65.29 0 0.00 0.00 1.33 68.43 64.8745.0 0 0 0.703 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 14:001917.82 105.09 0.00 0.00 428.66 23.23 0.00 72.38 2.62 63.96 0 0.00 0.00 1.22 68.01 64.63 45.0 0 0 0.700 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 14:301918.10 105.09 0.00 0.00 429.14 23.45 0.00 73.65 2.03 64.31 0 0.00 0.00 1.22 67.92 64.60 45.0 0 0 0.700 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.439.20 0.00 0.00 0.00 0.0002/15/2025 15:001918.38 105.09 0.00 0.00 429.46 25.69 0.00 76.07 1.59 67.68 0 0.00 0.00 1.22 67.69 64.30 45.0 0 0 0.700 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 15:30Opened Master Valve = 24 turns. Opened Wellhead NDB-025 Production Wing Valve (PWV) 23.5 turns to closed Expro Choke Manifold.15:43)ODUHSLORWLVOLW15:55 Commenced chemical injection of demulsifier and defoamer. @ 8 gal/day1918.66 105.09 0.00 0.00 432.18 27.16 0.00 75.85 1.40 66.94 0 0.00 0.00 1.10 67.45 64.21 45.0 0 0 0.700 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 0.00 0.00 0.00 0.0002/15/2025 16:00Opened Well on a 24/64ths adjustable Choke as per Santos WSS.16:05'XPSLQJJDVIURP6HSDUDWRUWR)ODUH0HWHULQJ*DVWKURXJKCoriolis.16:17%HJDQGXPSLQJ)OXLGIURP6HSDUDWRU0HWHULQJWKURXJK/LQH 7XUELQH0HWHU 1918.77 105.10 0.00 0.00 664.48 36.78 665.33 75.31 1.39 67.37 24 0.00 0.00 1.12 67.13 63.59 45.0 0 0 0.700 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 4.9755 0.00 4.08 0.00 13505.70 0.00 1848.13 0.00 15357.91 0.00 3.76 3437.58 13628.33 180.93 1750.34 3618.51 15382.43 9.20 8.00 0.00 8.00 0.0002/15/2025 16:30Increased Expro adjustable Choke to 32/64ths as per Santos WSS.Commenced Liquid sampling.1902.07 105.00 0.00 0.00 390.45 37.34 383.64 41.66 80.02 43.25 32 0.00 69.73 71.68 69.00 66.18 45.0 0 0 0.700 0.00 0.0 0.00 0.00 0.00 0.00 0.0000 0.2063 0.0000 4.9797 339.96 0.00 4.08 606.84 13518.34 0.00 1848.13 606.84 15370.55 1.68 3.79 605.74 13640.95 65.62 1751.71 673.04 15396.45 9.20 8.00 8.00 8.000.0002/15/2025 17:00Increased Expro adjustable Choke to 40/64ths as per Santos WSS.1884.27 104.78 0.00 0.00 395.67 39.05 367.04 39.45 94.37 40.14 40 0.00 72.68 74.14 54.25 49.98 30.0 0 0 0.700 0.00 0.0 10.00 0.25 9.75 9.75 0.0000 0.5263 0.0000 4.9907 266.36 5.47 4.19 1975.87 13559.51 213.50 1852.58 2194.84 15416.28 4.13 3.88 1918.17 13680.92 140.25 1754.63 2062.55 15439.42 9.22 8.008.00 8.00 0.0002/15/2025 17:30Increased Expro adjustable Choke to 48/64ths as per Santos WSS.17:50'LYHUWHGOLTXLGIORZIURP WXUELQHPHWHUWR WXUELQHPHWHU1870.13 104.62 0.95 0.00 307.23 50.19 267.62 48.67 84.84 45.43 48 0.00 66.13 66.79 55.76 46.89 30.0 55000 9 0.700 0.00 0.0 7.00 0.20 6.80 6.80 0.0000 0.4918 0.0000 5.0010 194.39 5.43 4.31 2529.70 13612.21 184.54 1856.42 2719.66 15472.94 5.17 3.98 2454.43 13732.05 124.01 1757.22 2583.62 15493.25 9.24 8.00 8.00 8.00 0.0002/15/2025 18:00Increased Expro adjustable Choke to 56/64ths as per Santos WSS.Collected Tracerco sample1840.51 104.31 22.12 0.00 456.63 55.71 372.11 48.81 144.31 48.79 56 0.00 84.21 77.57 53.60 53.45 30.0 30000 9 0.700 0.00 0.0 5.00 0.20 4.80 4.80 0.0000 1.1014 0.0000 5.0239 242.89 9.53 4.51 4534.41 13706.67 228.63 1861.19 4772.56 15572.37 0.00 3.98 4549.55 13826.83 45.96 1758.17 4595.51 15588.99 9.278.00 8.00 8.00 0.0002/15/2025 18:30Increased Expro adjustable Choke to 64/64ths as per Santos WSS.1821.28 104.10 77.68 0.00 440.33 53.90 324.78 50.45 160.23 49.15 64 0.00 83.97 78.66 52.92 52.30 30.1 30000 7 0.700 0.00 0.0 1.00 0.00 1.00 1.00 0.0000 1.7042 0.0000 5.0594 335.71 0.00 4.51 5076.32 13812.43 51.28 1862.25 5127.60 15679.19 0.00 3.98 3838.51 13906.80 1082.66 1780.73 4921.17 15691.51 9.29 8.00 8.00 8.00 0.0002/15/2025 19:00$SSOLHG&06) 1806.74 103.97 167.27 0.00 426.59 57.92 277.91 52.57 169.83 52.11 64 0.00 89.36 80.68 54.56 54.35 30.1 30000 7 0.700 0.00 0.0 22.00 0.00 22.00 22.00 0.0000 1.8168 0.0000 5.0973 415.37 0.00 4.51 4373.99 13903.56 1233.76 1887.96 5607.75 15796.02 0.00 3.98 5183.51 14014.79 244.25 1785.82 5427.76 15804.59 9.32 8.00 8.00 8.00 0.0002/15/2025 19:30Increased Expro adjustable Choke to 72/64ths as per Santos WSS.1802.37 103.89 249.93 0.00 425.75 59.57 279.12 54.41 169.65 53.87 72 0.00 89.83 80.18 56.11 55.78 30.1 30000 7 0.700 0.00 0.0 4.50 0.00 4.50 4.50 0.0000 1.8349 0.0000 5.1355 358.17 0.00 4.51 5123.05 14010.29 241.41 1892.99 5364.46 15907.78 0.00 3.98 5251.40 14124.19 140.18 1788.74 5391.58 15916.92 9.35 8.00 8.00 8.00 0.0002/15/2025 20:00Increased Expro adjustable Choke to 80/64ths as per Santos WSS.1792.96 103.81 326.26 0.00 418.64 63.17 251.25 55.64 174.71 55.50 80 0.00 90.83 80.47 57.60 57.29 30.1 30000 7 0.700 0.00 0.0 2.60 0.00 2.60 2.60 0.0000 1.9074 0.0000 5.1752 347.23 0.00 4.51 5493.11 14124.73 146.64 1896.04 5639.75 16025.27 0.00 3.98 5438.76 14237.50 133.74 1791.53 5572.50 16033.01 9.44 8.00 8.00 8.00 0.0002/15/2025 20:30 Increased Expro adjustable Choke to 88/64ths as per Santos WSS. 1785.45 103.75 390.87 0.00 413.11 62.99 233.02 56.75 180.29 55.43 88 0.00 91.60 80.70 58.90 58.73 30.1 30000 7 0.700 0.00 0.0 2.40 0.00 2.40 2.40 0.0000 1.9602 0.0000 5.2161 350.22 0.00 4.51 5596.86 14241.33 137.64 1898.91 5734.50 16144.74 0.00 3.98 5544.71 14353.02 136.35 1794.37 5681.06 16151.36 9.46 8.00 8.00 8.00 0.0002/15/2025 21:00Increased Expro adjustable Choke to 96/64ths as per Santos WSS.Sparged Expro separator , Observed trace of solids.1783.48 103.72 444.14 0.00 387.43 63.93 209.24 57.58 177.75 56.88 96 0.00 90.53 78.84 59.97 60.03 30.1 30000 7 0.700 0.00 0.0 2.40 0.00 2.40 2.40 0.0000 1.9677 0.0000 5.2571 351.24 0.00 4.51 5602.22 14358.04 137.77 1901.78 5739.99 16264.33 0.00 3.98 5592.33 14469.52 161.10 1797.72 5753.43 16271.23 9.47 8.00 8.00 8.00 0.0002/15/2025 21:30 Increased Expro adjustable Choke to 104/64ths as per Santos WSS. 1772.03 103.68 493.00 0.00 401.64 74.54 213.91 59.26 180.40 59.13 104 0.00 89.84 76.29 61.29 61.02 30.0 30000 7 0.706 0.10 0.0 2.80 0.00 2.80 2.80 0.0000 2.0177 0.0000 5.2991 369.50 0.00 4.51 5460.72 14471.81157.32 1905.06 5618.04 16381.37 0.00 3.98 5462.86 14583.33 145.83 1800.76 5608.69 16388.08 9.48 8.00 8.00 8.00 0.0002/15/2025 22:00Increased Expro adjustable Choke to 112/64ths as per Santos WSS.1764.52 103.65 536.86 0.00 400.83 67.71 216.52 60.06 187.57 59.24 112 0.00 90.10 77.09 62.26 62.09 30.0 30000 7 0.706 0.10 0.0 2.60 0.00 2.60 2.60 0.00002.0684 0.0000 5.3422 353.10 0.00 4.51 5857.91 14593.85 156.39 1908.31 6014.29 16506.67 0.00 3.98 5838.54 14704.97 168.19 1804.26 6006.72 16513.22 9.50 8.00 8.00 8.00 0.0002/15/2025 22:30Increased Expro adjustable Choke to 120/64ths as per Santos WSS.1759.20 103.63 573.07 0.00 402.52 67.52 210.25 61.48 185.36 60.98 120 0.00 86.09 73.76 63.24 62.84 30.0 30000 7 0.706 0.10 0.0 2.80 0.00 2.80 2.80 0.00002.1027 0.0000 5.3860 354.27 0.00 4.51 5935.31 14717.50 170.99 1911.88 6106.30 16633.88 0.00 3.98 5921.04 14828.32 158.06 1807.56 6079.09 16639.86 9.52 8.00 8.00 8.00 0.0002/15/2025 23:00 Increased Expro adjustable Choke to 128/64ths as per Santos WSS. 1756.30 103.61 605.09 0.00 400.23 69.71 209.69 62.28 188.61 62.78 128 0.00 87.85 74.17 64.10 63.83 30.0 30000 7 0.706 0.10 0.0 2.60 0.00 2.60 2.60 0.0000 2.1405 0.0000 5.4306 355.50 0.00 4.51 6021.14 14842.94160.75 1915.23 6181.88 16762.67 0.00 3.98 5966.92 14952.64 184.54 1811.40 6151.46 16768.02 9.53 8.00 8.00 8.00 0.0002/15/2025 23:301754.11 103.58 631.45 0.00 401.40 76.13 209.32 63.10 187.53 62.97 128 0.00 88.89 75.09 65.00 64.31 30.0 30000 7 0.706 0.10 0.0 3.00 0.00 3.00 3.00 0.00002.1193 0.0000 5.4747 359.02 0.00 4.51 5903.03 14965.92 182.59 1919.03 6085.63 16889.45 0.00 3.98 5831.41 15074.12 211.50 1815.81 6042.91 16893.91 9.55 8.00 8.00 8.00 0.0002/16/2025 00:00$SSOLHG&06) Collected Tracerco sample.1753.17 103.57 653.96 0.00 402.78 59.93 209.61 63.56 187.63 63.08 128 0.00 89.90 75.12 65.53 65.05 30.0 30000 7 0.706 0.10 0.0 3.50 0.00 3.50 3.50 0.00002.1326 0.0000 5.5192 357.27 0.00 4.51 5969.34 15090.28 216.54 1923.54 6185.88 17018.33 0.00 3.98 5936.16 15197.79 215.30 1820.29 6151.46 17022.07 9.58 8.00 8.00 8.00 0.0002/16/2025 00:30 Sparged Expro separator , Observed trace of solids. 1752.47 103.55 671.68 0.00 402.58 60.57 208.54 63.96 188.02 61.61 128 0.00 88.63 74.73 65.80 65.15 30.0 29000 7 0.706 0.10 0.0 3.50 0.00 3.50 3.50 0.0000 2.1069 0.0000 5.5631 354.10 0.00 4.51 5949.97 15214.24 215.84 1928.046165.81 17146.78 0.00 3.98 5796.49 15318.55 210.24 1824.67 6006.72 17147.21 9.60 8.00 8.00 8.00 0.0002/16/2025 01:001748.55 103.53 689.08 0.00 391.77 63.05 177.59 64.25 161.83 63.97 128 0.00 86.89 76.73 66.49 65.68 30.0 29000 7 0.706 0.10 0.0 3.50 0.00 3.50 3.50 0.00002.1489 0.0000 5.6078 394.05 0.00 4.51 5453.42 15327.85 197.83 1932.16 5651.24 17264.51 0.00 3.98 5370.23 15430.43 166.09 1828.13 5536.32 17262.55 9.62 8.00 8.00 8.00 0.0002/16/2025 01:301753.03 103.52 700.55 0.00 409.55 64.78 201.33 64.60 182.28 63.41 128 0.00 87.68 75.26 66.63 65.76 30.0 29000 7 0.706 0.10 0.0 3.00 0.00 3.00 3.00 0.00002.0874 0.0000 5.6513 368.10 0.00 4.51 5670.69 15445.99 175.41 1935.81 5846.10 17386.31 0.00 3.98 5627.50 15547.67 234.48 1833.02 5861.98 17384.67 9.64 8.00 8.00 8.00 0.0002/16/2025 02:00 Sparged Expro separator , Observed trace of solids. 1750.85 103.51 712.24 0.00 408.87 65.26 201.85 64.84 182.83 64.76 128 0.00 87.68 75.13 67.05 66.32 30.0 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 2.0826 0.0000 5.6947 366.22 0.00 4.51 5686.87 15564.47 237.00 1940.755923.87 17509.72 0.00 3.98 5766.46 15667.81 240.27 1838.02 6006.72 17509.81 9.66 8.00 8.00 8.00 0.0002/16/2025 02:301748.91103.50 722.69 0.00 409.27 63.11 201.16 65.25 182.59 64.91 128 0.00 86.33 73.78 67.34 66.64 30.0 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 2.0754 0.0000 5.7379 383.60 0.00 4.51 5410.34 15677.18 225.48 1945.45 5635.82 17627.13 0.00 3.98 5419.08 15780.70 225.79 1842.73 5644.87 17627.41 9.69 8.008.00 8.00 0.0002/16/2025 03:001747.14 103.49 729.97 0.00 409.51 64.15 202.33 65.82 183.11 65.48 128 0.00 88.33 74.41 67.69 66.94 30.0 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0843 0.0000 5.7814 367.16 0.00 4.51 5676.87 15795.45 236.59 1950.38 5913.46 17750.33 0.00 3.98 5621.90 15897.83 203.90 1846.98 5825.80 17748.79 9.71 8.00 8.00 8.00 0.0002/16/2025 03:301745.67 103.49 738.97 0.00 406.22 65.04 201.49 65.77 182.38 65.37 128 0.00 86.59 74.18 67.89 67.20 29.7 29000 7 0.706 0.10 0.0 3.50 0.00 3.50 3.50 0.00002.0760 0.00005.8246 362.98 0.00 4.51 5719.21 15914.60 207.47 1954.70 5926.68 17873.80 0.00 3.98 5662.24 16015.79 235.93 1851.89 5898.17 17871.66 9.73 8.00 8.00 8.00 0.0002/16/2025 04:001743.99 103.48 746.18 0.00 406.20 55.55 201.67 65.97 181.01 66.11 128 0.00 85.53 74.44 68.14 67.41 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0827 0.0000 5.8680 378.32 0.00 4.51 5505.29 16029.29 229.44 1959.48 5734.73 17993.28 0.00 3.98 5488.55 16130.14 228.69 1856.66 5717.24 17990.77 9.76 8.00 8.00 8.00 0.0002/16/2025 04:301742.44 103.47 755.64 0.00 405.86 56.53 200.76 66.22 182.26 66.47 128 0.00 85.29 74.45 68.33 67.63 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0726 0.0000 5.9112 365.68 0.00 4.51 5667.74 16147.37 236.21 1964.40 5903.95 18116.28 0.00 3.98 5598.19 16246.77 263.79 1862.15 5861.98 18112.90 9.78 8.00 8.00 8.00 0.0002/16/2025 05:001740.50 103.46 761.31 0.00406.20 57.76 200.50 66.46 181.83 66.82 128 0.00 88.21 74.72 68.63 67.98 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 2.0748 0.0000 5.9544 370.79 0.00 4.51 5595.57 16263.94 263.74 1969.90 5859.31 18238.35 0.00 3.98 5632.75 16364.11 265.42 1867.68 5898.17 18235.78 9.80 8.00 8.00 8.00 0.0002/16/2025 05:301739.07 103.46 765.97 0.00 406.36 58.43 200.70 66.62 182.33 65.99 128 0.00 88.05 74.98 68.68 67.95 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.00002.0661 0.0000 5.9974 368.45 0.00 4.51 5607.60 16380.77 264.30 1975.40 5871.90 18360.68 0.00 3.98 5696.98 16482.80 237.37 1872.63 5934.35 18359.41 9.83 8.00 8.00 8.00 0.0002/16/2025 06:00 Collected Tracerco sample. 1737.73 103.45 772.38 0.00 403.77 59.31 199.88 66.52 179.43 66.29 128 0.00 87.54 75.11 68.86 68.03 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 2.0683 0.0000 6.0405 370.200.00 4.51 5586.87 16497.16 232.84 1980.25 5819.71 18481.92 0.00 3.98 5523.29 16597.87 230.14 1877.42 5753.43 18479.27 9.86 8.00 8.00 8.00 0.0002/16/2025 06:3006: 41(GJH[VHUYHUGRZQIRUPLQXWHVUHFDOFXODWHGYROFXPVDQG8SGDWHGV\VWHP1736.19 103.45 777.14 0.00 402.46 59.31 199.50 66.53 180.83 66.67 128 0.00 86.71 74.45 68.84 68.08 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0605 0.0000 6.0834 370.48 0.00 4.51 5561.76 16613.03 231.80 1985.09 5793.56 18602.62 0.00 3.98 5686.12 16716.33 175.86 1881.08 5861.98 18601.40 9.88 8.00 8.00 8.00 0.0002/16/2025 07:007:04 Sparged Expro separator , Observed trace of solids.1734.59 103.44 782.83 0.00 401.84 59.86 199.64 66.35 180.60 65.98 128 0.00 86.68 74.43 69.12 68.35 29.7 29000 7 0.706 0.10 0.0 3.00 0.00 3.00 3.00 0.00002.0542 0.0000 6.1264 365.06 0.00 4.51 5627.06 16730.26 198.14 1989.21 5825.16 18723.98 0.00 3.98 5523.29 16831.40 230.14 1885.88 5753.43 18721.26 9.90 8.00 8.00 8.00 0.0002/16/2025 07:301733.26 103.44 786.46 0.00 402.78 59.96 199.78 66.49 181.09 66.02 128 0.00 87.29 75.76 69.26 68.49 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0493 0.0000 6.1691 385.02 0.00 4.51 5322.66 16841.15 221.83 1993.84 5544.49 18839.49 0.00 3.98 5362.63 16943.12 282.24 1891.76 5644.87 18838.86 9.93 8.00 8.00 8.00 0.0002/16/2025 08:001732.16 103.43 791.59 0.00 402.64 60.87 199.76 66.46 180.12 66.36 128 0.20 85.35 74.39 69.28 67.59 29.7 29000 7 0.706 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.0480 0.0000 6.2117 376.04 0.00 4.51 5446.23 16954.61 286.73 1999.81 5732.97 18958.93 0.00 3.98 5558.03 17058.91 231.58 1896.58 5789.61 18959.48 9.96 8.00 8.00 8.00 0.0002/16/2025 08:3008:38 Opened bypass on Expro Ball catcher as per WSS.1730.95 103.43 796.27 0.00 402.06 61.66 199.86 66.68 180.21 66.01 128 0.00 84.86 73.98 69.15 66.98 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0547 0.0000 6.2545 371.81 0.00 4.51 5526.30 17069.74 230.32 2004.61 5756.61 19078.86 0.00 3.98 5627.50 17176.15 234.48 1901.47 5861.98 19081.60 9.98 8.00 8.00 8.00 0.0002/16/2025 09:001728.53 103.42 800.89 0.00 400.41 61.32 200.86 66.81 182.52 66.42 128 0.15 85.95 75.05 69.15 66.59 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0579 0.0000 6.2974 371.74 0.00 4.51 5535.89 17185.07 230.71 2009.41 5766.60 19198.99 0.00 3.98 5534.51 17291.45 291.29 1907.54 5825.80 19202.97 10.00 8.00 8.00 8.00 0.0002/16/2025 09:301727.79 103.42 805.31 0.00 399.57 62.71 201.79 67.27 182.50 67.38 128 0.00 87.43 74.37 69.04 66.65 30.3 29000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.0473 0.0000 6.3401 372.15 0.00 4.51 5501.39 17299.69 289.63 2015.45 5791.03 19319.64 0.00 3.98 5534.51 17406.76 291.29 1913.61 5825.80 19324.34 10.03 8.00 8.00 8.00 0.0002/16/2025 10:00$SSOLHG&06) 10:04 Sparged Expro separator , Observed trace of solids.1726.68 103.42 809.49 0.00 397.52 61.71 200.90 67.44 181.49 66.69 128 0.10 88.34 75.18 69.31 66.70 30.3 29000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.0364 0.0000 6.3825 372.91 0.00 4.51 5460.92 17413.46 287.50 2021.44 5748.42 19439.40 0.00 3.98 5592.77 17523.27 233.03 1918.46 5825.80 19445.72 10.06 8.00 8.00 8.00 0.0002/16/2025 10:3010:50'LYHUWHGIOXLGIORZWRSDUDOOHOWKURXJK'3,SRGVDVSHU:661725.43 103.41 812.42 0.00 398.52 61.81 199.86 67.75 182.50 66.77 128 0.00 86.35 74.38 69.31 66.91 30.3 28000 7 0.709 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.0460 0.0000 6.4251 376.85 0.00 4.51 5429.34 17526.57 226.27 2026.16 5655.62 19557.23 0.00 3.98 5340.20 17634.53 340.86 1925.56 5681.06 19564.07 10.09 8.00 8.00 8.00 0.0002/16/2025 11:001708.98 103.40 816.58 0.00 372.45 61.75 224.36 68.30 203.65 67.51 128 0.15 92.21 74.40 69.31 66.99 30.3 28000 7 0.709 0.10 0.0 6.00 0.00 6.00 6.00 0.00002.0800 0.0000 6.4683 372.90 0.00 4.51 5577.93 17642.77 356.16 2033.59 5934.09 19680.87 0.00 3.98 6050.15 17760.57 318.43 1932.20 6368.58 19696.75 10.12 8.00 8.00 8.00 0.0002/16/2025 11:301704.31 103.40 830.14 0.00 371.90 62.63 226.37 69.23 204.05 68.89 128 0.00 91.16 76.39 70.40 68.30 30.3 30000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.2734 0.0000 6.5157 354.94 0.00 4.51 6404.87 17776.21 337.20 2040.62 6742.08 19821.33 0.00 3.98 6290.78 17891.63 331.09 1939.09 6621.87 19834.71 10.16 8.00 8.00 8.00 0.0002/16/2025 12:00 Collected Tracerco sample. 1701.47 103.39 839.19 0.00 372.99 62.46 225.86 69.16 203.92 67.81 128 0.00 91.15 75.99 70.70 68.94 30.3 30000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.000.0000 2.3027 0.0000 6.5637 360.85 0.00 4.51 6381.36 17909.15 335.97 2047.62 6717.33 19961.27 0.00 3.98 6256.40 18021.97 329.28 1945.95 6585.69 19971.91 10.19 8.00 8.00 8.00 0.0002/16/2025 12:301699.69 103.39 845.90 0.00 373.11 62.66 224.66 69.47 202.83 68.91 128 0.00 91.28 75.72 70.99 69.60 30.3 30000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.2920 0.0000 6.6114 357.19 0.00 4.51 6416.71 18042.83 337.84 2054.66 6754.55 20101.99 0.00 3.98 6322.26 18153.69 263.43 1951.44 6585.69 20109.11 10.23 8.00 8.00 8.00 0.0002/16/2025 13:0013:04 Sparged Expro separator , Observed light trace of solids.1697.59 103.38 851.86 0.00 371.36 62.80 225.84 70.02 203.49 69.97 128 0.00 92.59 75.31 71.20 69.95 30.3 30000 7 0.709 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.2988 0.0000 6.6593 355.51 0.00 4.51 6466.32 18177.55 269.51 2060.27 6735.82 20242.33 0.00 3.98 6325.15 18285.46 332.90 1958.38 6658.06 20247.82 10.26 8.00 8.00 8.00 0.0002/16/2025 13:301696.79 103.38 854.48 0.00 372.25 62.94 225.12 69.65 201.70 69.17 128 0.00 93.14 76.25 71.15 69.55 30.3 30000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.2979 0.0000 6.7072 359.13 0.00 4.51 6398.40 18310.85 336.88 2067.29 6735.28 20382.64 0.00 3.98 6153.27 18413.65 323.86 1965.12 6477.13 20382.76 10.29 8.00 8.00 8.00 0.0002/16/2025 14:001694.69 103.38 860.12 0.00 371.38 63.20 226.51 70.16 202.77 69.45 128 0.00 92.23 75.33 71.25 68.88 30.3 30000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.3014 0.0000 6.7551 359.74 0.00 4.51 6397.43 18444.13 336.82 2074.31 6734.25 20522.94 0.00 3.98 6222.03 18543.28 327.48 1971.95 6549.50 20519.21 10.33 8.00 8.00 8.00 0.0002/16/2025 14:301693.13 103.38 862.85 0.00 374.40 63.19 225.66 70.30 203.27 68.46 128 0.00 90.56 75.82 71.47 69.57 30.3 30000 7 0.709 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.3055 0.0000 6.8031 358.12 0.00 4.51 6437.73 18578.25 338.94 2081.37 6776.67 20664.12 0.00 3.98 6357.00 18675.72 264.87 1977.46 6621.87 20657.16 10.36 8.00 8.00 8.00 0.0002/16/2025 15:001691.86 103.38 865.63 0.00 374.36 63.33 225.58 70.00 203.21 68.65 128 0.00 92.94 75.31 71.47 70.05 30.3 30000 7 0.709 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.3036 0.0000 6.8511 357.64 0.00 4.51 6441.30 18712.44 268.46 2086.96 6709.77 20803.91 0.00 3.98 6325.15 18807.49 332.90 1984.40 6658.06 20795.87 10.39 8.00 8.00 8.00 0.0002/16/2025 15:301690.53 103.38 869.12 0.00 372.39 63.05 225.58 69.90 202.33 68.78 128 0.00 89.75 74.81 71.63 70.29 29.8 30000 7 0.711 0.10 0.0 5.00 0.00 5.00 5.00 0.00002.2924 0.0000 6.8989 357.78 0.00 4.51 6407.18 18845.92 337.34 2093.99 6744.52 20944.42 0.00 3.98 6393.91 18940.70 336.52 1991.41 6730.43 20936.09 10.42 8.00 8.00 8.00 0.0002/16/2025 16:001688.68 103.38870.85 0.00 371.50 63.06 224.74 69.38 202.49 68.78 128 0.00 90.00 75.20 71.76 70.58 29.8 30000 7 0.711 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 2.2867 0.0000 6.9465 363.27 0.00 4.51 6294.69 18977.06 331.42 2100.89 6626.11 21082.46 0.00 3.98 6530.68 19076.75 272.11 1997.08 6802.80 21077.81 10.46 8.00 8.00 8.00 0.0002/16/2025 16:301687.71 103.38 872.24 0.00 368.67 62.99 222.83 69.12 200.01 68.61 128 0.00 90.64 75.32 71.81 70.45 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.28 0.0000 6.9941 359.73 0.00 4.51 6343.97 19109.23 264.41 2106.40 6608.38 21220.14 0.00 3.98 6317.92 19208.38 195.40 2001.15 6513.32 21213.51 10.49 8.00 8.00 8.00 0.0002/16/2025 17:001686.36 103.38 874.93 0.49 368.55 62.66 222.59 69.09 201.32 68.18 128 0.00 91.92 75.72 71.73 70.56 29.8 29000 7 0.711 0.10 0.0 3.00 0.00 3.00 3.00 0.00002.2757 0.0000 7.0414352.90 0.00 4.51 6448.47 19243.57 197.84 2110.52 6646.22 21358.60 0.00 3.98 6322.26 19340.09 263.43 2006.64 6585.69 21350.71 10.51 8.00 8.00 8.00 0.0002/16/2025 17:301685.78 103.38 876.36 0.59 368.77 62.82 222.53 68.77 201.78 68.24 128 0.00 92.24 75.85 71.92 70.51 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.2720 0.0000 7.0888 354.16 0.00 4.51 6415.00 19377.22 267.37 2116.11 6682.37 21497.83 0.00 3.98 6287.52 19471.08 261.98 2012.10 6549.50 21487.16 10.53 8.00 8.00 8.00 0.0002/16/2025 18:00Decreased Expro adjustable Choke to 52/64ths as per Santos WSS.Collected Tracerco sample.1684.54 103.38 877.66 1.73 366.88 62.53 223.51 68.98 200.41 68.05 128 0.00 90.17 75.32 71.76 70.65 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.00002.2673 0.0000 7.1360 356.00 0.00 4.51 6368.89 19509.90 265.45 2121.64 6634.34 21636.05 0.00 3.98 6322.26 19602.79 263.43 2017.58 6585.69 21624.36 10.56 8.00 8.00 8.00 0.0002/16/2025 18:301727.38 103.44 855.14 0.99 417.97 59.78 365.03 68.45 150.88 66.18 52 0.00 80.92 73.27 70.67 69.66 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 1.7081 0.0000 7.1716 384.31 0.00 4.51 4444.71 19602.50 185.25 2125.50 4629.95 21732.51 0.00 3.98 4515.90 19696.87 188.16 2021.50 4704.06 21722.36 10.58 8.00 8.00 8.00 0.0002/16/2025 19:001729.37 103.44 839.51 0.99 417.49 59.24 361.94 67.89 146.76 65.16 52 0.00 79.10 72.40 69.82 68.93 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 1.66280.0000 7.2062 392.34 0.00 4.51 4238.30 19690.80 176.64 2129.18 4414.94 21824.48 0.00 3.98 4296.98 19786.39 226.16 2026.22 4523.14 21816.59 10.60 8.00 8.00 8.00 0.0002/16/2025 19:301730.46 103.45 829.38 1.27 419.22 58.59 363.54 66.45 149.76 63.91 52 0.00 81.24 74.13 69.74 68.61 29.8 29000 7 0.711 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.6531 0.0000 7.2407 396.82 0.00 4.51 4165.90 19777.59 219.33 2133.75 4385.23 21915.84 0.00 3.98 4307.47 19876.13 179.48 2029.96 4486.95 21910.07 10.62 8.00 8.00 8.00 0.0002/16/2025 20:001730.80 103.45 822.95 1.03 417.85 58.45 361.49 66.06 150.06 63.85 52 0.00 82.36 73.35 69.23 68.15 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 1.6558 0.0000 7.2752 386.37 0.00 4.51 4285.50 19866.87 178.61 2137.47 4464.10 22008.84 0.00 3.98 4365.73 19967.09 229.78 2034.74 4595.51 22005.81 10.64 8.00 8.00 8.00 0.0002/16/2025 20:301731.15 103.45 818.610.11 419.10 58.36 361.86 65.38 148.73 63.22 52 0.00 80.92 73.49 69.18 67.85 29.8 29000 7 0.711 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.6488 0.0000 7.3095 386.84 0.00 4.51 4262.29 19955.67 224.40 2142.14 4486.69 22102.32 0.00 3.98 4446.42 20059.72 185.27 2038.60 4631.69 22102.30 10.66 8.00 8.00 8.00 0.0002/16/2025 21:001731.25 103.45 814.01 1.01 419.92 58.02 362.88 64.82 148.76 62.42 52 0.00 81.01 73.88 68.70 67.64 29.8 29000 7 0.711 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 1.6498 0.0000 7.3439 382.62 0.00 4.51 4311.71 20045.49 179.70 2145.89 4491.40 22195.89 0.00 3.98 4388.71 20151.15 206.80 2042.91 4595.51 22198.04 10.68 8.00 8.00 8.00 0.0002/16/2025 21:301729.41 103.45 811.18 0.11 417.69 57.81 360.37 64.79 148.65 62.25 52 0.00 80.23 73.70 68.72 67.41 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.6654 0.0000 7.3786 388.570.00 4.51 4285.83 20134.78 202.00 2150.10 4487.83 22289.38 0.00 3.98 4376.95 20242.34 182.37 2046.71 4559.32 22293.03 10.70 8.00 8.00 8.00 0.0002/16/2025 22:00Sparged Expro separator , Observed light trace of solids.1731.32 103.45 808.75 0.09 419.80 58.03 360.87 64.84 147.84 62.26 52 0.00 79.22 72.76 68.30 67.40 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.0000 1.6715 0.0000 7.4134 386.79 0.00 4.51 4321.42 20224.81 180.10 2153.85 4501.52 22383.17 0.00 3.98 4365.73 20333.29 229.78 2051.50 4595.51 22388.77 10.72 8.00 8.00 8.00 0.0002/16/2025 22:301731.13 103.45 806.94 0.21 417.19 58.75 362.44 64.76 149.66 62.58 52 0.00 81.02 72.75 68.48 67.33 29.7 29000 7 0.706 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.6719 0.0000 7.4482 394.78 0.00 4.51 4235.04 20313.04 222.96 2158.49 4458.00 22476.04 0.00 3.98 4388.71 20424.72 206.80 2055.81 4595.51 22484.51 10.75 8.00 8.00 8.00 0.0002/16/2025 23:001730.90 103.45 805.49 0.57 418.47 58.90 361.88 64.43 147.58 62.35 52 0.00 81.11 72.72 68.21 67.28 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.6734 0.0000 7.4831 389.25 0.00 4.51 4298.88 20402.60 202.62 2162.72 4501.49 22569.82 0.00 3.98 4307.47 20514.46 179.48 2059.54 4486.95 22577.99 10.77 8.00 8.00 8.00 0.0002/16/2025 23:301730.83 103.45 804.87 0.05 421.31 58.77 363.40 64.39 148.74 62.53 52 0.00 79.24 72.72 68.27 67.02 29.7 29000 7 0.706 0.10 0.0 4.00 0.00 4.00 4.00 0.00001.6702 0.0000 7.5179 386.47 0.00 4.51 4321.71 20492.64 180.11 2166.47 4501.82 22663.61 0.00 3.98 4423.27 20606.61 208.43 2063.89 4631.69 22674.48 10.79 8.00 8.00 8.00 0.0002/17/2025 00:00$SSOLHG&06) Decreased Expro adjustable Choke to 44/64ths as per Santos WSS.Collected Tracerco sample1730.41 103.45 804.43 0.35 419.02 58.64 363.54 64.65 149.21 62.79 44 0.00 80.54 72.72 68.00 67.03 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.6700 0.0000 7.5527 389.00 0.00 4.51 4293.07 20582.08 202.34 2170.68 4495.41 22757.27 0.00 3.98 4423.27 20698.76 208.43 2068.23 4631.69 22770.97 10.81 8.00 8.00 8.00 0.0002/17/2025 00:301749.78 103.49 784.33 0.15 439.91 57.80 406.49 63.18 125.04 60.81 44 0.00 74.97 71.39 67.18 66.06 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3790 0.0000 7.5814 392.61 0.00 4.51 3512.33 20655.25 165.54 2174.13 3677.87 22833.88 0.00 3.98 3490.23 20771.48 164.46 2071.66 3654.69 22847.11 10.82 8.00 8.00 8.00 0.0002/17/2025 01:00Sparged Expro separator , Observed light trace of solids.1750.90 103.51 771.82 0.00 439.93 57.10 405.75 63.23 125.01 60.55 44 0.00 75.15 71.94 66.75 65.44 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3720 0.0000 7.6100 391.90 0.00 4.51 3500.89 20728.18 165.00 2177.57 3665.89 22910.26 0.00 3.98 3455.68 20843.47 162.83 2075.05 3618.51 22922.50 10.84 8.00 8.00 8.00 0.001'%:HOO&OHDQ8SB)ORZWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 26 START DATE:END DATE:TimeDPI HeaterGORFrac WaterTime & Date COMMENTS BHP BHT I/A Pressure O/A Pressure Well Head PressureWell Head TemperatureU/S Choke PressureU/S Choke TemperatureD/S Choke PressureD/S Choke TemperatureChoke Size U/S DPI Solids, Mud & Carbolite Spin-out (Observed)D/S Heater PressureSeparator PressureGas Temperature Oil Temperature Corrected API WaterSalinity pH Gas S.G CO2 H2S Total Choke BS&W(Solids, Mud, Carbolite & Water)Solids, Mud & Carbolite @ ChokeWater Cut @ Choke Separator Oil Leg BS&W (2-Phase)Nitrogen Injection RateTotal Gas Rate (N2+Formation)Nitrogen InjectionCumulative Total Gas Cumulative (N2+Formation)Total GOR Solids, Mud & Carbolite RateSolids, Mud, & Carbolite CumulativeOil Rate Oil Cumulative Water RateWater CumulativeTotal Fluid RateTotal Fluid CumulativeTank Farm StrapSolids, Mud & Carbolite RateTank Farm StrapSolids, Mud, & Carbolite CumulativeTank Farm StrapOil RateTank Farm StrapOil CumulativeTank Farm StrapWater RateTank Farm StrapWater CumulativeTank Farm Strap Total Rate (Tank 1 - Tank 10)Tank Farm Strap Total Cumulative(Tank 1 - Tank 10)Percentage of Frac Water RecoveredDefoamer(D/S of Choke Manifold Data Header)Methanol (MeOH)(Separator Gas Line)Demulsifier(D/S of Choke Manifold Data Header)H2S Scavenger(D/S of Choke Manifold Data Header)(mm-dd-yyyy hh:mm)(psig) ) (psig) (psig) (psig) ) (psig) ) (psig) ) (64ths) (%) (psig) (psig) ) ) (API@60°)(ppm) (pH) (Air = 1) (%) (ppm) (%) (%) (%) (%) (MMscf/day) (MMscf/day) (MMscf) (MMscf) (scf/stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (stb/day) (stb) (%) (gal/day) (gal/day) (gal/day) (gal/day)CLIENT:SANTOS WELL TEST LEAD:SANTOS REP/SUPERVISORS:EXPRO SUPERVISORS :EXPRO DAQ ENGINEERS:Santos Adam Phillips / Craig Stevens-RVH*RQ]DOH]'DQ%RQQDU5RJHU,KGH_)UDQN7RZHU6KDURQ2\DR_<HKLD(O]HQ\WT-XAK-0127.4PIKKA - NDB NDB-025)HE# PresentFluid PropertiesBS&W PropertiesSeparatorPROJECT DESIGN NUMBER:LOCATION / FIELD:WELL NUMBER:Chemical Injection RatesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Well Head ChokeGas PropertiesGas Rates & CumulativesNDB-025 WELL CLEAN-UP DATA SHEET02/17/2025 01:301751.78 103.51 764.06 0.00 437.44 57.23 402.93 63.44 124.19 60.87 44 0.00 75.13 71.01 66.51 64.98 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3678 0.0000 7.6385 397.02 0.00 4.51 3445.30 20799.96 162.38 2180.95 3607.67 22985.42 0.00 3.98 3526.78 20916.94 127.91 2077.71 3654.69 22998.64 10.86 8.00 8.00 8.00 0.0002/17/2025 02:001752.27 103.52 759.52 0.00 438.22 57.69 402.63 63.39 124.96 61.00 44 0.00 76.32 72.75 66.54 65.30 29.7 29000 7 0.706 0.10 0.0 3.50 0.00 3.50 3.50 0.0000 1.3633 0.0000 7.6669 384.83 0.00 4.51 3542.64 20873.77 128.51 2183.63 3671.15 23061.90 0.00 3.98 3386.56 20987.50 159.58 2081.04 3546.14 23072.52 10.87 8.00 8.00 8.00 0.0002/17/2025 02:301752.67 103.52 754.92 0.29 440.41 57.50 405.27 63.29 124.07 60.45 44 0.00 76.71 72.72 66.43 65.31 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3648 0.0000 7.6953 387.88 0.00 4.51 3518.63 20947.07 165.83 2187.08 3684.46 23138.66 0.00 3.98 3455.68 21059.49 162.83 2084.43 3618.51 23147.90 10.89 8.00 8.00 8.00 0.0002/17/2025 03:001752.97 103.52 750.02 0.01 441.10 57.41 405.79 62.89 126.94 60.07 44 0.00 76.05 72.82 66.29 65.27 29.7 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.00001.3648 0.0000 7.7238 388.34 0.00 4.51 3514.37 21020.29 165.63 2190.53 3680.01 23215.33 0.00 3.98 3524.79 21132.92 166.09 2087.89 3690.88 23224.80 10.91 8.00 8.00 8.00 0.0002/17/2025 03:301753.30 103.52 746.98 0.03 438.38 57.70 404.84 62.94 125.98 60.87 44 0.00 74.34 72.52 66.16 65.21 29.8 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3669 0.0000 7.7522 388.03 0.00 4.51 3522.81 21093.68 166.03 2193.99 3688.84 23292.18 0.00 3.98 3524.79 21206.36 166.09 2091.35 3690.88 23301.69 10.92 8.00 8.00 8.00 0.0002/17/2025 04:00Sparged Expro separator , Observed trace of solids.1753.78 103.52 743.53 0.00 440.92 57.73 404.72 62.94 124.16 60.63 44 0.00 74.08 71.42 66.16 65.23 29.8 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3697 0.0000 7.7808 390.23 0.00 4.51 3510.04 21166.80 165.43 2197.44 3675.47 23368.75 0.00 3.98 3455.68 21278.35 162.83 2094.74 3618.51 23377.07 10.94 8.00 8.00 8.00 0.0002/17/2025 04:301753.89 103.52 742.92 0.39 440.31 58.09 405.08 62.74 125.20 60.51 44 0.00 75.85 72.35 65.95 65.07 29.8 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3671 0.0000 7.8093 393.86 0.00 4.51 3471.14 21239.12 163.60 2200.85 3634.74 23444.47 0.00 3.98 3455.68 21350.34 162.83 2098.13 3618.51 23452.46 10.96 8.00 8.00 8.00 0.0002/17/2025 05:001754.05 103.52 740.43 0.31 440.31 58.47 405.12 62.31 126.97 60.13 44 0.00 74.05 71.67 65.99 64.95 29.8 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3698 0.0000 7.8378 388.29 0.00 4.51 3527.65 21312.61 166.26 2204.31 3693.91 23521.43 0.00 3.98 3421.12 21421.62 161.20 2101.49 3582.32 23527.09 10.97 8.00 8.00 8.00 0.0002/17/2025 05:301754.10 103.52 740.39 0.15 440.43 58.51 405.02 62.17 124.75 60.23 44 0.00 74.47 71.66 65.81 64.75 29.8 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.00001.3673 0.0000 7.8663 388.05 0.00 4.51 3523.57 21386.02 166.07 2207.77 3689.63 23598.29 0.00 3.98 3386.56 21492.17 159.58 2104.82 3546.14 23600.97 10.99 8.00 8.00 8.00 0.0002/17/2025 06:00Stopped chemical injection of methanol, demulsifier and defoamer.6:01 NDB-025 shut in at choke manifold.6:03&ORVHG):9 WXUQV&ORVHG0DVWHUYDOYH WXUQV1754.06 103.52 739.41 0.17 441.14 58.36 404.94 62.31 125.97 60.64 44 0.00 75.19 72.36 65.76 64.58 29.8 29000 7 0.706 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.3671 0.0000 7.8947 388.90 0.00 4.51 3515.25 21459.25 165.67 2211.20 3680.92 23674.96 0.00 3.98 3386.56 21562.72 159.58 2108.14 3546.14 23674.85 11.01 0.00 0.00 0.00 0.00WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 27 Santos – Pikka Development – NDB-025 SECTION 6 TEST DATA PLOTS WELL CLEAN-UP WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 28 Ϭ͘ϬϬϯϬ͘ϬϬϲϬ͘ϬϬϵϬ͘ϬϬϭϮϬ͘ϬϬϭϱϬ͘ϬϬϬϱϬϬϭϬϬϬϭϱϬϬϮϬϬϬϮϱϬϬ3UHVVXUH SVLJ 6DQWRV 3LNND'HYHORSPHQW 1'%B:HOO&OHDQ8SVW)ORZ%RWWRP+ROH3ORW,$3UHVVXUH%+3%+7&KRNH6L]H7HPSHUDWXUH ) 6L]H WKV ϮŶĚƐŚƵƚŝŶϲϰͬϲϰƚŚƐϮϰͬϲϰƚŚƐϭϮϴͬϲϰƚŚƐϭƐƚƐŚƵƚŝŶtdͲy<ͲϬϭϮϳ͘ϰͺEͲϬϮϱͺZĞǀZZZH[SURFRPWĂŐĞϮϵ 0.0028.0056.0084.00112.00140.0005001000150020002500Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd FlowBottom Hole Plot I/A Pressure BHP BHTChoke SizeTemperature (°F) / Size (64ths)52/64ths64/64thsWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 30 ϬϮϱϱϬϳϱϭϬϬϭϮϱϭϱϬϬϭϬϬϮϬϬϯϬϬϰϬϬϱϬϬϲϬϬTemperature (°F) / Size (64ths)Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 1st FlowWell Head / Choke PlotWell Head PressureU/S Choke PressureD/S Choke PressureWell Head TemperatureU/S Choke TemperatureD/S Choke TemperatureChoke Size2nd shut in1st shut in128/64ths:7;$.B1'%B5HY$ZZZH[SURFRP3DJH 0204060801001201400100200300400500600700Temperature (°F) / Size (64ths)Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd FlowWell Head / Choke PlotWell Head PressureU/S Choke PressureD/S Choke PressureWell Head TemperatureU/S Choke TemperatureD/S Choke TemperatureChoke Size52/64ths128/64ths64/64thsWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 32 030609012015005001000150020002500Temperature (°F) / Size (64ths)Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 1st FlowWell Head vs Bottom Hole Conditions Plot I/A PressureWell Head Pressure BHP BHTWell Head TemperatureChoke Size128/64ths24/64ths64/64ths:7;$.B1'%B5HY$ZZZH[SURFRP3DJH2nd shut in1st shut in 028568411214005001000150020002500Temperature (°F) / Size (64ths)Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd FlowWell Head vs Bottom Hole Conditions Plot I/A PressureWell Head Pressure BHP BHTWell Head TemperatureChoke Size52/64ths64/64ths128/64ths:7;$.B1'%B5HY$www.expro.comPage 34 Ϭ͘Ϭϰ͘Ϭϴ͘ϬϭϮ͘Ϭϭϲ͘ϬϮϬ͘ϬϮϰ͘ϬϮϴ͘ϬϬϭϬϬϬϮϬϬϬϯϬϬϬϰϬϬϬϱϬϬϬϲϬϬϬϳϬϬϬ*DV5DWH 00VFIGD\ 6ROLGV5DWH VWEGD\ )OXLG5DWH EEOGD\ 6DQWRV 3LNND'HYHORSPHQW 1'%B:HOO&OHDQ8SVW)ORZ3URGXFWLRQ5DWH3ORW )ORZ0HWHU2LO5DWH7RWDO)OXLG5DWH:DWHU5DWH7RWDO*DV5DWH 1)RUPDWLRQ 6ROLGV0XG &DUEROLWH5DWH1LWURJHQ,QMHFWLRQ5DWH:7;$.B1'%B5HY$www.expro.com3DJH 0.01.32.53.85.06.37.58.810.0010002000300040005000600070008000Gas Rate (MMscf/day) / Solids Rate (stb/day) Fluid Rate (bbl/day)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd Flow Production Rate Plot - Flow MeterOil RateTotal Fluid RateWater RateTotal Gas Rate (N2+Formation)Solids, Mud & Carbolite RateNitrogen Injection Rate6776.76 bbls/d'LYHUWHGWR3DUDOOHOIORZWKURXJK'3,SRGVPage 36www.expro.comWT-XAK-0127.4_NDB-025_Rev$ Ϭ͘Ϭϰ͘Ϭϴ͘ϬϭϮ͘Ϭϭϲ͘ϬϮϬ͘ϬϮϰ͘ϬϮϴ͘ϬϬϭϬϬϬϮϬϬϬϯϬϬϬϰϬϬϬϱϬϬϬϲϬϬϬϳϬϬϬ*DV5DWH 00VFIGD\ 6ROLGV5DWH VWEGD\ )OXLG5DWH EEOGD\ 6DQWRV 3LNND'HYHORSPHQW 1'%B:HOO&OHDQ8SVW)ORZ3URGXFWLRQ5DWH3ORW 7DQN6WUDS2LO5DWH7RWDO)OXLG5DWH:DWHU5DWH7RWDO*DV5DWH 1)RUPDWLRQ 6ROLGV0XG &DUEROLWH5DWH1LWURJHQ,QMHFWLRQ5DWHwww.expro.comWT-XAK-0127.4_NDB-025_Rev $Page 37 0.00.81.52.33.03.84.55.36.0010002000300040005000600070008000Gas Rate (MMscf/day) / Solids Rate (stb/day) Fluid Rate (bbl/day)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd Flow Production Rate Plot - Tank StrapOil RateTotal Fluid RateWater RateTotal Gas Rate (N2+Formation)Solids, Mud & Carbolite RateNitrogen Injection Rate6802.80 bbls/d6530.68 bbls/dwww.expro.comPage 38WT-XAK-0127.4_NDB-025_Rev$ Ϭ͘ϬϮ͘Ϭϰ͘Ϭϲ͘ϬϬϮϬϬϬϰϬϬϬϲϬϬϬϴϬϬϬϭϬϬϬϬϭϮϬϬϬϭϰϬϬϬϭϲϬϬϬϭϴϬϬϬ*DV&XPXODWLYH 00VFI 6ROLGV&XPXODWLYH VWE )OXLG&XPXODWLYH EEOV 6DQWRV 3LNND'HYHORSPHQW 1'%B:HOO&OHDQ8SVW)ORZ&XPXODWLYH3ORW )ORZ0HWHU2LO&XPXODWLYH:DWHU&XPXODWLYH7RWDO)OXLG&XPXODWLYH7RWDO*DV&XPXODWLYH 1)RUPDWLRQ 1LWURJHQ,QMHFWLRQ«6ROLGV0XG &DUEROLWH&XPXODWLYHWT-XAK-0127.4_NDB-025_Rev$ www.expro.comPage 39 0.02.04.06.08.010.00500010000150002000025000Gas Cumulative (MMscf) / Solids Cumulative (stb) Fluid Cumulative (bbls)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd Flow Cumulative Plot - Flow MeterOil CumulativeWater CumulativeTotal Fluid CumulativeTotal Gas Cumulative (N2+Formation)Nitrogen Injection…Solids, Mud, & Carbolite Cumulativewww.expro.comWT-XAK-0127.4_NDB-025_Rev APage 40 0.01.02.03.04.05.06.00300060009000120001500018000Gas Cumulative (MMscf) / Solids Cumulative (stb)Fluid Cumulative (bbls)Santos - Pikka Development - NDB-025_Well Clean-Up 1st FlowCumulative Plot - Tank StrapOil CumulativeWater CumulativeTotal Fluid CumulativeTotal Gas Cumulative (N2+Formation)Nitrogen Injection…Solids, Mud, & Carbolite Cumulative 0.01.02.03.04.05.06.07.08.09.00300060009000120001500018000210002400027000Gas Cumulative (MMscf) / Solids Cumulative(stb)Fluid Cumulative (bbls)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd FlowCumulative Plot - Tank StrapOil CumulativeWater CumulativeTotal Gas Cumulative (N2+Formation)Total Fluid CumulativeNitrogen Injection…Solids, Mud, & Carbolite Cumulative 0.012.024.036.048.060.072.084.00200400600800100012001400BSW (%) / Frac Water Recovery (%)GOR (scf/stb)Santos -Pikka Development -NDB-025_Well Clean-Up 1st Flow Production Ratio PlotTotal GORSolids, Mud & Carbolite @ ChokeWater Cut @ ChokePercentage of Frac Water RecoveredTotal Choke BS&W(Solids, Mud, Carbolite & Water)WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 43 0.03.06.09.012.015.018.021.024.027.0050100150200250300350400450BSW (%) / Frac Water Recovery (%)GOR (scf/stb)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd Flow Production Ratio PlotTotal GORSolids, Mud & Carbolite @ ChokeWater Cut @ ChokePercentage of Frac Water RecoveredTotal Choke BS&W(Solids, Mud, Carbolite & Water)www.expro.comWT-XAK-0127.4_NDB-025_Rev APage 44 08162432404856647280020406080100120140160180200Temperature (°F)Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 1st FlowTest Separator PlotD/S Heater PressureSeparator PressureOil TemperatureGas TemperatureWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 45 010203040506070800102030405060708090100Temperature (°F)Pressure (psig)Santos - Pikka Development - NDB-025_Well Clean-Up 2nd FlowTest Separator PlotD/S Heater PressureSeparator PressureOil TemperatureGas TemperatureWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 46 Santos – Pikka Development – NDB-025 SECTION 7 TANK FARM RATES AND VOLUMES WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 47 Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining (mm/dd/yyyy hh:mm:ss) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (bbls/d) (bbls) (bbls/min) (bbls) (bbls/min) (bbls)2/10/2025 9:00 10.337.69 256.40.41.51 292.60.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 1194.11 24.88 0.00 0.00 0.00 0.002/10/2025 9:30 10.337.69 256.48.230.15 263.90.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 1375.03 53.52 0.00 0.00 0.00 0.002/10/2025 10:00 12.345.23 248.88.230.15 263.90.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 361.85 61.06 0.00 0.00 0.00 0.002/10/2025 10:30 12.345.23 248.810.739.20 254.90.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 434.22 70.11 0.00 0.00 0.00 0.002/10/2025 11:00 17.062.57 231.510.739.20 254.90.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 832.26 87.45 0.00 0.00 0.00 0.002/10/2025 11:30 17.062.57 231.518.367.09 227.00.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 1338.85 115.34 0.00 0.00 0.00 0.002/10/2025 12:00 36.9135.69 158.418.367.09 227.00.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 3509.95 188.46 0.00 0.00 0.00 0.002/10/2025 12:30 36.9135.69 158.437.9139.46 154.60.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 3473.77 260.83 0.00 0.00 0.00 0.002/10/2025 13:00 60.9223.90 70.237.9139.46 154.60.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 4233.66 349.04 0.00 0.00 0.00 0.002/10/2025 13:30 60.9223.90 70.264.4236.71 57.40.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 4667.88 446.28 0.00 0.00 0.00 0.002/10/2025 14:00 60.9223.90 70.264.4236.71 57.40.41.51 292.60.41.51 292.60.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 5029.73 551.07 0.00 0.00 0.00 0.002/10/2025 14:30 60.9223.90 70.264.4236.71 57.428.9106.29 187.829.3107.80 186.30.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 5102.10 657.36 0.00 0.00 0.00 0.002/10/2025 15:00 60.9223.90 70.264.4236.71 57.458.0213.34 80.729.3107.80 186.30.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 5138.28 764.41 0.00 0.00 0.00 0.002/10/2025 15:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 5029.73 869.20 0.00 0.00 0.00 0.002/10/2025 16:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.5 5138.28 976.24 0.00 0.00 0.00 0.002/10/2025 16:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54812.62 1076.510.00 0.00 0.00 0.002/10/2025 17:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54848.80 1177.520.00 0.00 0.00 0.002/10/2025 17:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54884.99 1279.290.00 0.00 0.00 0.002/10/2025 18:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54812.62 1379.560.00 0.00 0.00 0.002/10/2025 18:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54957.36 1482.830.00 0.00 0.00 0.002/10/2025 19:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54957.36 1586.110.00 0.00 0.00 0.002/10/2025 19:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54957.36 1689.39 3.0 27.90.00 0.002/10/2025 20:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.55283.02 1799.45 3.0 124.10.00 0.002/10/2025 20:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.55102.10 1905.75 3.0 124.10.00 0.002/10/2025 21:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54848.80 2006.76 3.0 124.10.00 0.002/10/2025 21:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54667.88 2104.01 3.5 268.50.00 0.002/10/2025 22:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54884.99 2205.78 3.5 372.70.00 0.002/10/2025 22:30 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54631.69 2302.28 3.5 478.90.00 0.002/10/2025 23:00 49.4181.68 112.43.914.32 279.758.0213.34 80.757.8212.59 81.50.83.02 291.01.66.03 288.00.41.51 292.60.83.02 291.01.24.52 289.52.17.54 286.54631.69 2398.77 3.5 584.50.00 0.002/10/2025 23:30 13.7 50.5 243.6 17.2 63.3 230.7 23.6 86.7 207.4 21.3 78.4 215.7 35.9 131.9 162.1 34.5 126.6 167.4 57.8 212.6 81.5 56.2 206.6 87.5 55.2 202.8 91.3 55.0 202.0 92.0 4704.06 2496.77 3.5 749.0 0.0 0.02/11/2025 0:00 40.2 147.8 146.3 17.2 63.3 230.7 23.6 86.7 207.4 21.3 78.4 215.7 35.9 131.9 162.1 34.5 126.6 167.4 57.8 212.6 81.5 56.2 206.6 87.5 55.2 202.8 91.3 55.0 202.0 92.0 4667.88 2496.77 0.0 786.0 0.0 0.02/11/2025 0:30 40.2 147.8 146.3 44.3 162.8 131.2 23.6 86.7 207.4 21.3 78.4 215.7 35.9 131.9 162.1 34.5 126.6 167.4 57.8 212.6 81.5 56.2 206.6 87.5 55.2 202.8 91.3 55.0 202.0 92.0 4776.43 2693.53 3.5 885.2 0.0 0.02/11/2025 1:00 67.7 248.8 45.3 44.3 162.8 131.2 23.6 86.7 207.4 21.3 78.4 215.7 35.9 131.9 162.1 34.5 126.6 167.4 7.6 27.9 266.2 4.5 16.6 277.5 55.2 202.8 91.3 55.0 202.0 92.0 4848.80 2794.54 3.5 986.1 0.0 0.02/11/2025 1:30 67.7 248.8 45.3 71.8 263.8 30.2 23.6 86.7 207.4 21.3 78.4 215.7 35.9 131.9 162.1 34.5 126.6 167.4 7.6 27.9 266.2 4.5 16.6 277.5 55.2 202.8 91.3 55.0 202.0 92.0 4848.80 2895.56 3.4 1088.4 0.0 0.02/11/2025 2:00 67.7 248.8 45.3 71.8 263.8 30.2 51.1 187.7 106.4 21.3 78.4 215.7 35.9 131.9 162.1 34.5 126.6 167.4 7.6 27.9 266.2 4.5 16.6 277.5 55.2 202.8 91.3 55.0 202.0 92.0 4848.80 2996.58 3.1 1193.5 0.0 0.02/11/2025 2:30 67.7 248.8 45.3 71.8 263.8 30.2 51.1 187.7 106.4 48.4 177.9 116.2 35.9 131.9 162.1 34.5 126.6 167.4 7.6 27.9 266.2 4.5 16.6 277.5 55.2202.8 91.3 55.0 202.0 92.0 4776.43 3096.09 3.4 1278.4 0.0 0.02/11/2025 3:00 67.7 248.8 45.3 71.8 263.8 30.2 78.8 289.5 4.6 48.4 177.9 116.2 35.9 131.9 162.1 34.5 126.6 167.4 7.6 27.9 266.2 4.5 16.6 277.5 26.7 98.0 196.1 28.3 104.0 190.0 4884.99 3197.86 3.3 1386.6 0.0 0.02/11/2025 3:30 67.7248.77 45.371.8263.85 30.278.8289.48 4.677.9286.47 7.635.9131.92 162.134.5126.65 167.47.627.89 266.24.516.58 277.526.798.00 196.128.3104.03 190.0 5210.65 3306.41 3.5 1482.8 0.0 0.02/11/2025 4:00 67.7248.77 45.371.8263.85 30.278.8289.48 4.677.9286.47 7.635.9131.92 162.134.5126.65 167.435.5130.42 163.64.516.58 277.526.798.00 196.128.3104.03 190.0 4921.17 3408.94 3.7 1599.5 0.0 0.02/11/2025 4:30 22.883.68 210.425.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.435.5130.42 163.632.0117.60 176.526.798.00 196.128.3104.03 190.0 4848.80 3509.95 3.7 1709.1 0.0 0.02/11/2025 5:00 22.883.68 210.425.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.462.8230.68 63.432.0117.60 176.526.798.00 196.128.3104.03 190.0 4812.62 3610.22 3.7 1817.6 0.0 0.02/11/2025 5:30 22.883.68 210.425.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.462.8230.68 63.450.0183.94 110.126.798.00 196.128.3104.03 190.0 3184.29 3676.56 3.71 1928.91 0.00 0.002/11/2025 6:00 22.883.68 210.425.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.462.8230.68 63.450.0183.94 110.150.7186.20 107.928.3104.03 190.0 4233.66 3764.76 3.69 2040.38 0.00 0.002/11/2025 6:30 24.690.46 203.625.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.650.7186.20 107.928.3104.03 190.0 4631.69 3861.25 3.69 2149.73 0.00 0.002/11/2025 7:00 24.690.46 203.625.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.678.8289.48 4.628.3104.03 190.0 4957.36 3964.53 3.69 2149.73 0.00 0.002/11/2025 7:30 24.690.46 203.625.091.97 202.178.8289.48 4.677.9286.47 7.623.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.678.8289.48 4.656.0205.80 88.3 4884.99 4066.30 3.66 2372.36 0.00 0.002/11/2025 8:00 55.0202.03 92.025.091.97 202.112.746.74 247.318.567.85 226.223.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.678.8289.48 4.656.0205.80 88.3 4957.36 4169.58 3.66 2481.98 0.00 0.002/11/2025 8:30 55.0202.03 92.055.0202.03 92.012.746.74 247.318.567.85 226.223.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.678.8289.48 4.656.0205.80 88.3 5283.02 4279.64 3.66 2592.05 0.00 0.002/11/2025 9:00 55.0202.03 92.055.0202.03 92.042.9157.56 136.518.567.85 226.223.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.678.8289.48 4.656.0205.80 88.3 5283.02 4279.64 3.66 2701.05 0.00 0.002/11/2025 9:30 55.0202.03 92.055.0202.03 92.042.9157.56 136.550.0183.94 110.123.686.69 207.421.980.66 213.462.8230.68 63.476.3280.43 13.678.8289.48 4.656.0205.80 88.3 5572.50 4506.55 3.63 2810.47 0.00 0.002/11/2025 10:00 55.0202.03 92.055.0202.03 92.074.0272.14 21.950.0183.94 110.123.686.69 207.421.980.66 213.416.460.31 233.813.549.75 244.378.8289.48 4.656.0205.80 88.3 5500.13 4621.14 3.62 2919.60 0.00 0.002/11/2025 10:30 55.0202.03 92.055.0202.03 92.074.0272.14 21.982.0301.54 0.023.686.69 207.421.980.66 213.416.460.31 233.813.549.75 244.378.8289.48 4.656.0205.80 88.3 5644.87 4738.74 3.64 3025.57 0.00 0.002/11/2025 11:00 55.0202.03 92.055.0202.03 92.074.0272.14 21.982.0301.54 0.056.2206.56 87.521.980.66 213.416.460.31 233.813.549.75 244.313.750.51 243.616.058.80 235.3 5753.43 4858.60 3.64 3025.57 0.00 0.002/11/2025 11:30 55.0202.03 92.055.0202.03 92.074.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.116.460.31 233.813.549.75 244.313.750.51 243.616.058.80 235.3 5391.58 4970.93 3.60 3245.72 0.00 0.002/11/2025 12:00 55.0202.03 92.055.0202.03 92.074.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.116.460.31 233.813.549.75 244.313.750.51 243.616.058.80 235.3 5572.50 5087.02 3.60 3245.72 0.00 0.002/11/2025 12:30 55.0202.03 92.055.0202.03 92.074.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.148.0176.40 117.745.1165.85 128.213.750.51 243.616.058.80 235.3 5572.50 5203.11 3.60 3470.91 0.00 0.002/11/2025 13:00 11.943.72 250.313.951.26 242.874.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.179.4291.74 2.345.1165.85 128.213.750.51 243.616.058.80 235.3 5536.32 5318.45 3.60 3470.91 0.00 0.002/11/2025 13:30 11.943.72 250.313.951.26 242.874.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.179.4291.74 2.376.9282.70 11.413.750.51 243.616.058.80 235.3 5608.69 5435.30 3.61 3712.94 0.00 0.002/11/2025 14:00 11.943.72 250.313.951.26 242.874.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.179.4291.74 2.376.9282.70 11.445.1165.85 128.216.058.80 235.3 5536.32 5550.64 3.60 3784.51 0.00 0.002/11/2025 14:30 11.943.72 250.313.951.26 242.874.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.179.4291.74 2.376.9282.70 11.445.1165.85 128.245.3166.60 127.5 5174.47 5658.44 3.59 3895.96 0.00 0.002/11/2025 15:00 11.943.72 250.313.951.26 242.874.0272.14 21.982.0301.54 0.056.2206.56 87.552.5192.99 101.179.4291.74 2.376.9282.70 11.476.9282.70 11.445.3166.60 127.5 5608.69 5775.29 3.59 4003.82 0.00 0.002/11/2025 15:30 11.943.72 250.313.951.26 242.810.739.20 254.916.661.06 233.056.2206.56 87.552.5192.99 101.179.4291.74 2.376.9282.70 11.476.9282.70 11.476.7281.94 12.1 5536.32 5890.63 3.62 4109.56 0.00 0.002/11/2025 16:00 43.1158.31 135.813.951.26 242.810.739.20 254.916.661.06 233.056.2206.56 87.552.5192.99 101.17.828.65 265.476.9282.70 11.476.9282.70 11.476.7281.94 12.1 5500.13 6005.22 3.59 4215.92 0.00 0.002/11/2025 16:30 43.1158.31 135.845.1165.85 128.210.739.20 254.916.661.06 233.056.2206.56 87.552.5192.99 101.17.828.65 265.476.9282.70 11.476.9282.70 11.476.7281.94 12.1 5500.13 6119.80 3.60 4326.78 0.00 0.002/11/2025 17:00 74.4273.65 20.445.1165.85 128.210.739.20 254.916.661.06 233.016.861.82 232.214.452.77 241.37.828.65 265.476.9282.70 11.476.9282.70 11.476.7281.94 12.1 5536.32 6235.14 3.20 4434.47 0.00 0.002/11/2025 17:30 74.4273.65 20.445.1165.85 128.210.739.20 254.916.661.06 233.016.861.82 232.214.452.77 241.37.828.65 265.476.9282.70 11.476.9282.70 11.476.7281.94 12.1 5463.95 6348.98 3.59 4542.17 0.00 0.002/11/2025 18:00 74.4273.65 20.476.1279.68 14.440.8150.02 144.016.661.06 233.016.861.82 232.214.452.77 241.37.828.65 265.476.9282.70 11.476.9282.70 11.476.7281.94 12.1 5319.21 6459.79 3.20 4653.30 0.00 0.002/11/2025 18:30 74.4273.65 20.476.1279.68 14.440.8150.02 144.047.6174.89 119.216.861.82 232.214.452.77 241.37.828.65 265.476.9282.70 11.476.9282.70 11.476.7281.94 12.1 5463.95 6573.62 3.20 4756.52 0.00 0.002/11/2025 19:00 74.4273.65 20.476.1279.68 14.471.8263.85 30.247.6174.89 119.216.861.82 232.214.452.77 241.37.828.65 265.476.9282.70 11.415.456.54 237.516.861.82 232.2 5463.95 6687.46 3.20 4890.60 0.00 0.002/11/2025 19:30 74.4273.65 20.476.1279.68 14.471.8263.85 30.277.5284.96 9.116.861.82 232.214.452.77 241.37.828.65 265.476.9282.70 11.415.456.54 237.516.861.82 232.2 5283.02 6797.52 3.20 4975.17 0.00 0.002/11/2025 20:00 74.4273.65 20.476.1279.68 14.471.8263.85 30.277.5284.96 9.148.0176.40 117.714.452.77 241.37.828.65 265.476.9282.70 11.415.456.54 237.516.861.82 232.2 5500.13 6912.11 3.20 5081.85 0.00 0.002/11/2025 20:30 74.4273.65 20.476.1279.68 14.471.8263.85 30.277.5284.96 9.148.0176.40 117.744.9165.09 129.07.828.65 265.44.918.09 276.015.456.54 237.516.861.82 232.2 5391.58 7024.43 3.20 5188.68 0.00 0.002/11/2025 21:00 74.4273.65 20.476.1279.68 14.471.8263.85 30.277.5284.96 9.178.3287.97 6.144.9165.09 129.07.828.65 265.44.918.09 276.015.456.54 237.516.861.82 232.2 5391.58 7136.75 3.20 5291.44 0.00 0.002/11/2025 21:30 12.345.23 248.814.252.02 242.071.8263.85 30.277.5284.96 9.178.3287.97 6.174.2272.90 21.27.828.65 265.44.918.09 276.015.456.54 237.516.861.82 232.2 5174.47 7244.56 3.20 5408.20 0.00 0.002/11/2025 22:00 12.345.23 248.814.252.02 242.071.8263.85 30.277.5284.96 9.178.3287.97 6.174.2272.90 21.238.6141.72 152.34.918.09 276.015.456.54 237.516.861.82 232.2 5427.76 7357.63 3.40 5514.08 0.00 0.002/11/2025 22:30 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.238.6141.72 152.335.1128.91 165.215.456.54 237.516.861.82 232.2 5319.21 7468.45 3.60 5639.66 0.00 0.00TANK 10Fluid Injection Cumulative into NDBi-014Fluid Injection Rate into NDBi-030TANK 6PresentTANK 2 TANK 3 TANK 4 TANK 5 NDB-025NDB-025 WELL CLEAN-UP_INJECTION TANK FARM TO INJECTION WELL NDBi-014 & NDBi-030Well:Tank Strap Fluid RateTank Strap Fluid CumulativeStart Data:End Date:Date & TimeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-030TANK 110-Feb-2025 @ 07:30TANK 7 TANK 8 TANK 9WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 48 Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining (mm/dd/yyyy hh:mm:ss) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (bbls/d) (bbls) (bbls/min) (bbls) (bbls/min) (bbls)TANK 10Fluid Injection Cumulative into NDBi-014Fluid Injection Rate into NDBi-030TANK 6PresentTANK 2 TANK 3 TANK 4 TANK 5 NDB-025NDB-025 WELL CLEAN-UP_INJECTION TANK FARM TO INJECTION WELL NDBi-014 & NDBi-030Well:Tank Strap Fluid RateTank Strap Fluid CumulativeStart Data:End Date:Date & TimeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-030TANK 110-Feb-2025 @ 07:30TANK 7 TANK 8 TANK 92/11/2025 23:00 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.835.1128.91 165.215.456.54 237.516.861.82 232.2 5355.39 7580.02 3.70 5749.99 0.00 0.002/11/2025 23:30 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.215.456.54 237.516.861.82 232.2 4559.32 7675.01 3.70 5876.88 0.00 0.002/12/2025 0:00 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.240.8150.02 144.016.861.82 232.2 4486.95 7768.49 0.00 5988.94 0.00 0.002/12/2025 0:30 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.240.8150.02 144.045.9168.86 125.2 5138.28 7875.53 0.00 5988.94 0.00 0.002/12/2025 1:00 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.271.0260.83 33.245.9168.86 125.2 5319.21 7986.35 3.70 6205.09 0.00 0.002/12/2025 1:30 12.345.23 248.814.252.02 242.015.657.29 236.822.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.271.0260.83 33.276.5281.19 12.9 5391.58 8098.68 3.70 6298.72 0.00 0.002/12/2025 2:00 42.7156.80 137.314.252.02 242.042.7156.80 137.322.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.271.0260.83 33.276.5281.19 12.9 5355.39 8210.25 3.70 6421.39 0.00 0.002/12/2025 2:30 42.7156.80 137.344.7164.34 129.742.7156.80 137.322.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.271.0260.83 33.276.5281.19 12.9 5391.58 8322.57 3.70 6421.39 0.00 0.002/12/2025 3:00 73.2269.13 24.944.7164.34 129.742.7156.80 137.322.181.42 212.678.3287.97 6.174.2272.90 21.268.9253.30 40.860.9223.90 70.271.0260.83 33.276.5281.19 12.9 5391.58 8434.89 3.70 6421.39 0.00 0.002/12/2025 3:30 73.2269.13 24.974.7274.40 19.715.657.29 236.822.181.42 212.619.772.37 221.716.460.31 233.821.579.15 214.917.865.59 228.571.0260.83 33.276.5281.19 12.9 5283.02 8544.96 3.60 6764.19 0.00 0.002/12/2025 4:00 73.2269.13 24.974.7274.40 19.745.9168.86 125.222.181.42 212.619.772.37 221.716.460.31 233.821.579.15 214.917.865.59 228.571.0260.83 33.276.5281.19 12.9 5355.39 8656.53 3.60 6882.19 0.00 0.002/12/2025 4:30 73.2269.13 24.974.7274.40 19.745.9168.86 125.253.1195.25 98.819.772.37 221.716.460.31 233.821.579.15 214.917.865.59 228.571.0260.83 33.276.5281.19 12.9 5463.95 8770.36 3.60 7002.44 0.00 0.002/12/2025 5:00 73.2269.13 24.974.7274.40 19.776.3280.43 13.653.1195.25 98.819.772.37 221.716.460.31 233.821.579.15 214.917.865.59 228.571.0260.83 33.276.5281.19 12.9 5355.39 8881.93 3.60 7114.60 0.00 0.002/12/2025 5:30 73.2269.13 24.974.7274.40 19.776.3280.43 13.653.1195.25 98.849.0180.17 113.916.460.31 233.821.579.15 214.917.865.59 228.571.0260.83 33.276.5281.19 12.9 5174.47 8989.73 3.60 7219.07 0.00 0.002/12/2025 6:00 73.2269.13 24.974.7274.40 19.776.3280.43 13.653.1195.25 98.849.0180.17 113.946.1169.62 124.421.579.15 214.917.865.59 228.571.0260.83 33.276.5281.19 12.9 5246.84 9099.04 3.60 7219.07 0.00 0.002/12/2025 6:30 73.2269.13 24.974.7274.40 19.776.3280.43 13.653.1195.25 98.879.4291.74 2.346.1169.62 124.421.579.15 214.917.865.59 228.517.263.32 230.718.969.35 224.7 5355.39 9210.61 3.60 7219.07 0.00 0.002/12/2025 7:00 73.2269.13 24.974.7274.40 19.776.3280.43 13.653.1195.25 98.879.4291.74 2.376.3280.43 13.621.579.15 214.917.865.59 228.517.263.32 230.718.969.35 224.7 5319.21 9321.43 3.80 7563.11 0.00 0.002/12/2025 7:30 16.460.31 233.817.865.59 228.576.3280.43 13.653.1195.25 98.879.4291.74 2.376.3280.43 13.651.9190.73 103.317.865.59 228.517.263.32 230.718.969.35 224.7 5355.39 9433.00 3.80 7563.11 0.00 0.002/12/2025 8:00 16.460.31 233.817.865.59 228.576.3280.43 13.653.1195.25 98.879.4291.74 2.376.3280.43 13.651.9190.73 103.348.2177.16 116.917.263.32 230.718.969.35 224.7 5355.39 9544.57 3.79 7791.11 0.00 0.002/12/2025 8:30 16.460.31 233.817.865.59 228.576.3280.43 13.653.1195.25 98.879.4291.74 2.376.3280.43 13.682.9304.56 0.048.2177.16 116.917.263.32 230.718.969.35 224.7 5463.95 9658.40 3.82 7905.14 0.00 0.002/12/2025 9:00 16.460.31 233.817.865.59 228.576.3280.43 13.648.0176.40 117.779.4291.74 2.376.3280.43 13.682.9304.56 0.079.0290.23 3.817.263.32 230.718.969.35 224.7 5427.76 9771.48 3.81 8019.22 0.00 0.002/12/2025 9:30 16.460.31 233.817.865.59 228.576.3280.43 13.648.0176.40 117.779.4291.74 2.376.3280.43 13.682.9304.56 0.079.0290.23 3.847.2173.39 120.718.969.35 224.7 5283.02 9881.54 3.81 8133.82 0.00 0.002/12/2025 10:00 16.460.31 233.817.865.59 228.576.3280.43 13.648.0176.40 117.716.058.80 235.312.947.49 246.682.9304.56 0.079.0290.23 3.847.2173.39 120.748.8179.42 114.6 5283.02 9991.61 3.80 8247.47 0.00 0.002/12/2025 10:30 16.460.31 233.817.865.59 228.576.3280.43 13.648.0176.40 117.716.058.80 235.312.947.49 246.682.9304.56 0.079.0290.23 3.875.3276.67 17.448.8179.42 114.6 4957.36 10094.13 3.80 8247.47 0.00 0.002/12/2025 11:00 16.460.31 233.817.865.59 228.576.3280.43 13.648.0176.40 117.716.058.80 235.312.947.49 246.682.9304.56 0.079.0290.23 3.875.3276.67 17.478.1287.22 6.8 5174.47 10202.69 3.82 8476.37 0.00 0.002/12/2025 11:30 16.460.31 233.817.865.59 228.576.3280.43 13.677.5284.96 9.116.058.80 235.312.947.49 246.682.9304.56 0.079.0290.23 3.875.3276.67 17.478.1287.22 6.8 5210.65 10311.24 3.82 8590.69 0.00 0.002/12/2025 12:00 46.3170.37 123.717.865.59 228.576.3280.43 13.677.5284.96 9.116.058.80 235.312.947.49 246.682.9304.56 0.079.0290.23 3.875.3276.67 17.478.1287.22 6.8 5283.02 10421.31 3.82 8590.69 0.00 0.002/12/2025 12:30 46.3170.37 123.748.8179.42 114.676.3280.43 13.677.5284.96 9.116.058.80 235.312.947.49 246.615.657.29 236.812.144.48 249.675.3276.67 17.478.1287.22 6.8 5463.95 10535.14 3.82 8590.69 0.00 0.002/12/2025 13:00 76.1279.68 14.448.8179.42 114.676.3280.43 13.677.5284.96 9.116.058.80 235.312.947.49 246.615.657.29 236.812.144.48 249.675.3276.67 17.478.1287.22 6.8 5246.84 10644.45 3.79 8932.34 0.00 0.002/12/2025 13:30 76.1279.68 14.479.2290.99 3.176.3280.43 13.677.5284.96 9.116.058.80 235.312.947.49 246.615.657.29 236.812.144.48 249.675.3276.67 17.478.1287.22 6.8 5355.39 10756.02 3.78 9045.98 0.00 0.002/12/2025 14:00 76.1279.68 14.479.2290.99 3.176.3280.43 13.677.5284.96 9.146.3170.37 123.712.947.49 246.615.657.29 236.812.144.48 249.675.3276.67 17.478.1287.22 6.8 5355.39 10867.59 3.78 9045.98 0.00 0.002/12/2025 14:30 76.1279.68 14.479.2290.99 3.176.3280.43 13.677.5284.96 9.146.3170.37 123.743.3159.06 135.015.657.29 236.812.144.48 249.617.263.32 230.718.066.34 227.7 5355.39 10979.16 3.78 9045.98 0.00 0.002/12/2025 15:00 76.1279.68 14.479.2290.99 3.176.3280.43 13.677.5284.96 9.146.3170.37 123.743.3159.06 135.015.657.29 236.812.144.48 249.617.263.32 230.718.066.34 227.7 5427.76 11092.24 3.81 9388.32 0.00 0.002/12/2025 15:30 76.1279.68 14.479.2290.99 3.176.3280.43 13.677.5284.96 9.177.1283.45 10.674.4273.65 20.415.657.29 236.812.144.48 249.617.263.32 230.718.066.34 227.7 5500.13 11206.82 3.81 9388.32 0.00 0.002/12/2025 16:00 76.1279.68 14.479.2290.99 3.176.3280.43 13.677.5284.96 9.177.1283.45 10.674.4273.65 20.446.3170.37 123.712.144.48 249.617.263.32 230.718.066.34 227.7 5427.76 11319.90 3.81 9616.74 0.00 0.002/12/2025 16:30 76.1279.68 14.479.2290.99 3.110.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.446.3170.37 123.743.5159.82 134.217.263.32 230.718.066.34 227.7 5536.32 11435.24 3.81 9616.74 0.00 0.002/12/2025 17:00 76.1279.68 14.479.2290.99 3.110.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.143.5159.82 134.217.263.32 230.718.066.34 227.7 5500.13 11549.83 3.82 9845.07 0.00 0.002/12/2025 17:30 76.1279.68 14.479.2290.99 3.110.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.217.263.32 230.718.066.34 227.7 5572.50 11665.92 3.80 9961.75 0.00 0.002/12/2025 18:00 76.1279.68 14.479.2290.99 3.110.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.248.4177.91 116.218.066.34 227.7 5500.13 11780.51 3.80 10073.96 0.00 0.002/12/2025 18:30 13.951.26 242.816.058.80 235.310.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.248.4177.91 116.250.0183.94 110.1 5644.87 11898.11 3.80 10187.86 0.00 0.002/12/2025 19:00 13.951.26 242.816.058.80 235.310.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5500.13 12012.70 3.80 10300.77 0.00 0.002/12/2025 19:30 45.9168.86 125.216.058.80 235.310.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5644.87 12130.30 3.80 10415.29 0.00 0.002/12/2025 20:00 45.9168.86 125.246.1169.62 124.410.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5319.21 12241.11 3.80 10529.16 0.00 0.002/12/2025 20:30 77.1283.45 10.646.1169.62 124.410.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5500.13 12355.70 3.80 10652.40 0.00 0.002/12/2025 21:00 77.1283.45 10.677.3284.20 9.910.337.69 256.416.661.06 233.077.1283.45 10.674.4273.65 20.477.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5500.13 12470.29 3.80 10780.93 0.00 0.002/12/2025 21:30 77.1283.45 10.677.3284.20 9.941.8153.79 140.316.661.06 233.018.567.85 226.217.263.32 230.777.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5572.50 12586.38 3.80 10904.66 0.00 0.002/12/2025 22:00 77.1283.45 10.677.3284.20 9.941.8153.79 140.347.0172.63 121.418.567.85 226.217.263.32 230.777.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5355.39 12697.95 3.80 11025.41 0.00 0.002/12/2025 22:30 77.1283.45 10.677.3284.20 9.973.4269.88 24.247.0172.63 121.418.567.85 226.217.263.32 230.777.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5572.50 12814.04 3.80 11145.06 0.00 0.002/12/2025 23:00 16.460.31 233.815.657.29 236.873.4269.88 24.277.5284.96 9.118.567.85 226.217.263.32 230.777.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5391.58 12926.37 3.80 11268.77 0.00 0.002/12/2025 23:30 16.460.31 233.815.657.29 236.873.4269.88 24.277.5284.96 9.149.6182.43 111.617.263.32 230.777.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5500.13 13040.95 3.80 11394.72 0.00 0.002/13/2025 0:00 16.460.31 233.815.657.29 236.873.4269.88 24.277.5284.96 9.149.6182.43 111.649.0180.17 113.977.5284.96 9.175.1275.91 18.279.6292.50 1.650.0183.94 110.1 5608.69 13157.80 3.80 11512.06 0.00 0.002/13/2025 0:30 16.460.31 233.815.657.29 236.873.4269.88 24.277.5284.96 9.149.6182.43 111.649.0180.17 113.977.5284.96 9.175.1275.91 18.211.943.72 250.313.148.25 245.8 5427.76 13270.88 3.80 11576.73 0.00 0.002/13/2025 1:00 16.460.31 233.815.657.29 236.873.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.177.5284.96 9.175.1275.91 18.211.943.72 250.313.148.25 245.8 5463.95 13384.71 4.00 11699.33 0.00 0.002/13/2025 1:30 47.2173.39 120.715.657.29 236.873.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.177.5284.96 9.175.1275.91 18.211.943.72 250.313.148.25 245.8 5427.76 13497.79 4.00 11833.59 0.00 0.002/13/2025 2:00 47.2173.39 120.746.3170.37 123.773.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.177.5284.96 9.175.1275.91 18.211.943.72 250.313.148.25 245.8 5427.76 13610.87 4.00 11964.92 0.00 0.002/13/2025 2:30 78.3287.97 6.146.3170.37 123.773.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.177.5284.96 9.115.255.79 238.311.943.72 250.313.148.25 245.8 5500.13 13725.46 4.00 12088.79 0.00 0.002/13/2025 3:00 78.3287.97 6.177.1283.45 10.673.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.177.5284.96 9.115.255.79 238.311.943.72 250.313.148.25 245.8 5427.76 13838.53 4.00 12221.16 0.00 0.002/13/2025 3:30 78.3287.97 6.177.1283.45 10.673.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.115.456.54 237.515.255.79 238.342.9157.56 136.513.148.25 245.8 5463.95 13952.37 4.00 12350.65 0.00 0.002/13/2025 4:00 78.3287.97 6.177.1283.45 10.673.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.115.456.54 237.515.255.79 238.342.9157.56 136.543.3159.06 135.0 5319.21 14063.18 4.00 12489.25 0.00 0.002/13/2025 4:30 78.3287.97 6.177.1283.45 10.673.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.115.456.54 237.515.255.79 238.373.6270.63 23.443.3159.06 135.0 5427.76 14176.26 4.00 12608.27 0.00 0.002/13/2025 5:00 78.3287.97 6.177.1283.45 10.673.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.115.456.54 237.515.255.79 238.373.6270.63 23.474.2272.90 21.2 5463.95 14290.09 4.00 12738.46 0.00 0.002/13/2025 5:30 78.3287.97 6.177.1283.45 10.673.4269.88 24.277.5284.96 9.149.6182.43 111.680.0294.00 0.146.3170.37 123.715.255.79 238.373.6270.63 23.474.2272.90 21.2 5463.95 14403.93 4.38 12869.72 0.00 0.002/13/2025 6:00 78.3287.97 6.177.1283.45 10.613.549.75 244.333.2122.12 171.931.6116.09 178.027.7101.77 192.346.3170.37 123.745.9168.86 125.273.6270.63 23.474.2272.90 21.2 5427.76 14517.00 4.40 13031.00 0.00 0.002/13/2025 6:30 78.3287.97 6.177.1283.45 10.613.549.75 244.333.2122.12 171.931.6116.09 178.027.7101.77 192.377.1283.45 10.645.9168.86 125.273.6270.63 23.474.2272.90 21.2 5427.76 14630.08 4.40 13031.00 0.00 0.002/13/2025 7:00 78.3287.97 6.177.1283.45 10.613.549.75 244.31.66.03 288.014.452.77 241.312.345.23 248.877.1283.45 10.677.1283.45 10.673.6270.63 23.474.2272.90 21.2 5500.13 14744.67 4.38 13264.71 0.00 0.002/13/2025 7:30 78.3287.97 6.177.1283.45 10.644.1162.08 132.01.66.03 288.014.452.77 241.312.345.23 248.877.1283.45 10.677.1283.45 10.673.6270.63 23.474.2272.90 21.2 5391.58 14856.99 4.38 13264.71 0.00 0.002/13/2025 8:00 78.3287.97 6.177.1283.45 10.644.1162.08 132.032.8120.62 173.414.452.77 241.312.345.23 248.877.1283.45 10.677.1283.45 10.613.549.75 244.315.456.54 237.5 5500.13 14971.58 4.38 13264.71 0.00 0.002/13/2025 8:30 78.3287.97 6.177.1283.45 10.675.3276.67 17.432.8120.62 173.414.452.77 241.312.345.23 248.857.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 5500.13 15086.17 0.00 13264.71 0.00 0.002/13/2025 9:00 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.114.452.77 241.312.345.23 248.857.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 5391.58 15198.49 0.00 13264.71 0.00 0.002/13/2025 9:30 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.712.345.23 248.857.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 5391.58 15198.49 0.00 13264.71 0.00 0.002/13/2025 10:00 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.712.345.23 248.857.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 5391.58 15198.49 0.00 13264.71 0.00 0.002/15/2025 11:00 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 0.00 13264.71 0.00 0.002/15/2025 11:30 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.08 13308.36 0.00 0.002/15/2025 12:00 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.06 13431.16 0.00 0.00NDB-025 - Well Clean-Up Flow #2WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 49 Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining (mm/dd/yyyy hh:mm:ss) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (bbls/d) (bbls) (bbls/min) (bbls) (bbls/min) (bbls)TANK 10Fluid Injection Cumulative into NDBi-014Fluid Injection Rate into NDBi-030TANK 6PresentTANK 2 TANK 3 TANK 4 TANK 5 NDB-025NDB-025 WELL CLEAN-UP_INJECTION TANK FARM TO INJECTION WELL NDBi-014 & NDBi-030Well:Tank Strap Fluid RateTank Strap Fluid CumulativeStart Data:End Date:Date & TimeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-030TANK 110-Feb-2025 @ 07:30TANK 7 TANK 8 TANK 92/15/2025 12:30 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.07 13552.76 0.00 0.002/15/2025 13:00 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.00 13552.76 0.00 0.002/15/2025 13:30 78.3287.97 6.177.1283.45 10.675.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.00 13717.80 0.00 0.002/15/2025 14:00 27.199.51 194.627.3100.26 193.875.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.04 13838.00 0.00 0.002/15/2025 14:30 27.199.51 194.627.3100.26 193.875.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.06 13981.55 0.00 0.002/15/2025 15:00 27.199.51 194.627.3100.26 193.875.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.06 13981.55 0.00 0.002/15/2025 15:30 27.199.51 194.627.3100.26 193.875.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 4.00 14163.19 0.00 0.002/15/2025 16:00 27.199.51 194.627.3100.26 193.875.3276.67 17.463.4232.94 61.143.9161.33 132.732.8120.62 173.457.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 4719.79 15382.43 3.99 14283.21 0.00 0.002/15/2025 16:30 31.0113.83 180.227.3100.26 193.817.865.59 228.523.084.43 209.615.255.79 238.316.460.31 233.857.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 1553.18 15396.45 3.99 14402.73 0.00 0.002/15/2025 17:00 31.0113.83 180.239.0143.23 150.817.865.59 228.523.084.43 209.615.255.79 238.316.460.31 233.857.0209.57 84.557.6211.83 82.213.549.75 244.315.456.54 237.5 2062.55 15439.42 0.00 14402.73 0.00 0.002/15/2025 17:30 45.5167.36 126.739.0143.23 150.817.865.59 228.523.084.43 209.615.255.79 238.316.460.31 233.857.0209.57 84.557.4211.08 83.013.750.51 243.616.058.80 235.3 2583.62 15493.25 0.00 14402.73 0.00 0.002/15/2025 18:00 45.5167.36 126.765.0238.97 55.117.865.59 228.523.084.43 209.615.255.79 238.316.460.31 233.857.0209.57 84.557.4211.08 83.013.750.51 243.616.058.80 235.3 4595.51 15588.99 4.00 14535.35 0.00 0.002/15/2025 18:30 73.4269.88 24.265.0238.97 55.117.865.59 228.523.084.43 209.615.255.79 238.316.460.31 233.857.0209.57 84.557.4211.08 83.013.750.51 243.616.058.80 235.3 4921.17 15691.51 4.00 14658.30 0.00 0.002/15/2025 19:00 73.4269.88 24.265.0238.97 55.148.6178.66 115.423.084.43 209.615.255.79 238.316.460.31 233.817.263.32 230.713.549.75 244.313.750.51 243.616.058.80 235.3 5427.76 15804.59 4.00 14777.97 0.00 0.002/15/2025 19:30 73.4269.88 24.265.0238.97 55.148.6178.66 115.453.5196.76 97.315.255.79 238.316.460.31 233.817.263.32 230.713.549.75 244.313.750.51 243.616.058.80 235.3 5391.58 15916.92 4.00 14902.71 0.00 0.002/15/2025 20:00 73.4269.88 24.265.0238.97 55.180.2294.76 0.053.5196.76 97.315.255.79 238.316.460.31 233.817.263.32 230.713.549.75 244.313.750.51 243.616.058.80 235.3 5572.50 16033.01 4.00 15014.54 0.00 0.002/15/2025 20:30 11.943.72 250.315.055.03 239.080.2294.76 0.053.5196.76 97.315.255.79 238.316.460.31 233.849.4181.68 112.413.549.75 244.313.750.51 243.616.058.80 235.3 5681.06 16151.36 4.00 15133.78 0.00 0.002/15/2025 21:00 11.943.72 250.315.055.03 239.080.2294.76 0.053.5196.76 97.315.255.79 238.316.460.31 233.849.4181.68 112.446.1169.62 124.413.750.51 243.616.058.80 235.3 5753.43 16271.23 4.00 15254.53 0.00 0.002/15/2025 21:30 11.943.72 250.315.055.03 239.080.2294.76 0.053.5196.76 97.315.255.79 238.316.460.31 233.849.4181.68 112.446.1169.62 124.445.5167.36 126.716.058.80 235.3 5608.69 16388.08 4.00 15374.04 0.00 0.002/15/2025 22:00 11.943.72 250.315.055.03 239.080.2294.76 0.053.5196.76 97.315.255.79 238.316.460.31 233.838.1140.22 153.846.1169.62 124.445.5167.36 126.750.0183.94 110.1 6006.72 16513.22 4.00 15491.51 0.00 0.002/15/2025 22:30 11.943.72 250.315.055.03 239.015.255.79 238.318.367.09 227.015.255.79 238.316.460.31 233.838.1140.22 153.880.6296.27 0.045.5167.36 126.750.0183.94 110.1 6079.09 16639.86 4.17 15607.18 0.00 0.002/15/2025 23:00 11.943.72 250.315.055.03 239.015.255.79 238.318.367.09 227.015.255.79 238.316.460.31 233.873.0268.37 25.780.6296.27 0.045.5167.36 126.750.0183.94 110.1 6042.91 16893.91 4.17 15743.57 0.00 0.002/15/2025 23:30 46.1169.62 124.415.055.03 239.015.255.79 238.318.367.09 227.015.255.79 238.316.460.31 233.873.0268.37 25.780.6296.27 0.015.657.29 236.813.951.26 242.8 6042.91 16893.91 4.17 15869.14 0.00 0.002/16/2025 0:00 46.1169.62 124.449.8183.19 110.915.255.79 238.318.367.09 227.015.255.79 238.316.460.31 233.873.0268.37 25.780.6296.27 0.015.657.29 236.813.951.26 242.8 6151.46 17022.07 0.00 15991.13 0.00 0.002/16/2025 0:30 46.1169.62 124.449.8183.19 110.949.2180.93 113.118.367.09 227.015.255.79 238.316.460.31 233.873.0268.37 25.780.6296.27 0.015.657.29 236.813.951.26 242.8 6006.72 17147.21 4.80 16103.72 0.00 0.002/16/2025 1:00 42.2155.29 138.844.9165.09 129.043.9161.33 132.749.6182.43 111.61.66.03 288.02.17.54 286.573.0268.37 25.780.6296.27 0.015.657.29 236.813.951.26 242.8 5536.32 17262.55 4.80 16103.72 0.00 0.002/16/2025 1:30 42.2155.29 138.844.9165.09 129.043.9161.33 132.749.6182.43 111.634.9128.16 165.92.17.54 286.514.854.28 239.812.746.74 247.315.657.29 236.813.951.26 242.8 5861.98 17384.67 5.05 16356.64 0.00 0.002/16/2025 2:00 42.2155.29 138.844.9165.09 129.043.9161.33 132.749.6182.43 111.634.9128.16 165.936.1132.68 161.43.914.32 279.75.319.60 274.57.226.38 267.78.230.15 263.9 6006.72 17509.81 4.47 16509.06 0.00 0.002/16/2025 2:30 5.319.60 274.510.939.95 254.112.345.23 248.849.6182.43 111.666.9245.76 48.336.1132.68 161.43.914.32 279.75.319.60 274.57.226.38 267.78.230.15 263.9 5644.87 17627.41 4.40 16644.74 0.00 0.002/16/2025 3:00 5.319.60 274.510.939.95 254.112.345.23 248.849.6182.43 111.666.9245.76 48.336.1132.68 161.436.9135.69 158.45.319.60 274.57.226.38 267.78.230.15 263.9 5825.80 17748.79 5.03 16799.04 0.00 0.002/16/2025 3:30 5.319.60 274.510.939.95 254.112.345.23 248.849.6182.43 111.666.9245.76 48.336.1132.68 161.436.9135.69 158.438.8142.48 151.67.226.38 267.78.230.15 263.9 5898.17 17871.66 4.85 16945.44 0.00 0.002/16/2025 4:00 5.319.60 274.510.939.95 254.112.345.23 248.849.6182.43 111.666.9245.76 48.336.1132.68 161.436.9135.69 158.438.8142.48 151.639.6145.49 148.68.230.15 263.9 5717.24 17990.77 4.30 17087.22 0.00 0.002/16/2025 4:30 38.6141.72 152.310.939.95 254.112.345.23 248.849.6182.43 111.666.9245.76 48.336.1132.68 161.421.378.40 215.718.768.60 225.515.255.79 238.38.230.15 263.9 5861.98 18112.90 4.73 17273.64 0.00 0.002/16/2025 5:00 38.6141.72 152.344.3162.83 131.212.345.23 248.849.6182.43 111.666.9245.76 48.336.1132.68 161.421.378.40 215.718.768.60 225.515.255.79 238.38.230.15 263.9 5898.17 18235.78 3.84 17374.05 0.00 0.002/16/2025 5:30 38.6141.72 152.344.3162.83 131.245.9168.86 125.249.6182.43 111.666.9245.76 48.336.1132.68 161.421.378.40 215.718.768.60 225.515.255.79 238.38.230.15 263.9 5934.35 18359.41 2.99 17456.69 0.00 0.002/16/2025 6:00 38.6141.72 152.344.3162.83 131.245.9168.86 125.251.9190.73 103.312.746.74 247.310.538.45 255.621.378.40 215.718.768.60 225.515.255.79 238.38.230.15 263.9 5753.43 18479.27 4.52 17579.16 0.00 0.002/16/2025 6:30 38.6141.72 152.344.3162.83 131.245.9168.86 125.251.9190.73 103.345.9168.86 125.210.538.45 255.621.378.40 215.718.768.60 225.515.255.79 238.38.230.15 263.9 5861.98 18601.40 4.52 17579.16 0.00 0.002/16/2025 7:00 8.631.66 262.413.951.26 242.815.657.29 236.851.9190.73 103.345.9168.86 125.243.1158.31 135.87.025.63 268.45.721.11 273.015.255.79 238.38.230.15 263.9 5753.43 18721.26 3.78 17846.35 0.00 0.002/16/2025 7:30 8.631.66 262.413.951.26 242.815.657.29 236.851.9190.73 103.345.9168.86 125.243.1158.31 135.839.0143.23 150.85.721.11 273.015.255.79 238.38.230.15 263.9 5644.87 18838.86 3.76 17957.72 0.00 0.002/16/2025 8:00 8.631.66 262.413.951.26 242.815.657.29 236.851.9190.73 103.345.9168.86 125.243.1158.31 135.839.0143.23 150.838.6141.72 152.33.713.57 280.58.230.15 263.9 5789.61 18959.48 3.76 18071.67 0.00 0.002/16/2025 8:30 8.631.66 262.413.951.26 242.815.657.29 236.851.9190.73 103.345.9168.86 125.243.1158.31 135.839.0143.23 150.838.6141.72 152.336.9135.69 158.48.230.15 263.9 5861.98 19081.60 3.76 18184.58 0.00 0.002/16/2025 9:00 41.6153.03 141.013.951.26 242.815.657.29 236.815.657.29 236.810.337.69 256.47.025.63 268.439.0143.23 150.838.6141.72 152.336.9135.69 158.48.230.15 263.9 5825.80 19202.97 3.77 18297.61 0.00 0.002/16/2025 9:30 41.6153.03 141.047.0172.63 121.415.657.29 236.815.657.29 236.810.337.69 256.47.025.63 268.439.0143.23 150.838.6141.72 152.336.9135.69 158.48.230.15 263.9 5825.80 19324.34 3.77 18297.61 0.00 0.002/16/2025 10:00 41.6153.03 141.047.0172.63 121.448.6178.66 115.415.657.29 236.810.337.69 256.47.025.63 268.410.337.69 256.49.033.17 260.96.423.37 270.78.230.15 263.9 5825.80 19445.72 3.76 18523.20 0.00 0.002/16/2025 10:30 41.6153.03 141.047.0172.63 121.448.6178.66 115.447.8175.65 118.410.337.69 256.47.025.63 268.410.337.69 256.49.033.17 260.96.423.37 270.78.230.15 263.9 5681.06 19564.07 3.77 18636.22 0.00 0.002/16/2025 11:00 41.6153.03 141.047.0172.63 121.448.6178.66 115.447.8175.65 118.446.3170.37 123.77.025.63 268.410.337.69 256.49.033.17 260.96.423.37 270.78.230.15 263.9 6368.58 19696.75 3.78 18749.52 0.00 0.002/16/2025 11:30 41.6153.03 141.047.0172.63 121.448.6178.66 115.447.8175.65 118.446.3170.37 123.744.5163.59 130.510.337.69 256.49.033.17 260.96.423.37 270.78.230.15 263.9 6621.87 19834.71 3.76 18863.09 0.00 0.002/16/2025 12:00 11.341.46 252.615.055.03 239.016.460.31 233.847.8175.65 118.446.3170.37 123.744.5163.59 130.547.6174.89 119.29.033.17 260.96.423.37 270.78.230.15 263.9 6585.69 19971.91 4.47 18993.09 0.00 0.002/16/2025 12:30 11.341.46 252.615.055.03 239.016.460.31 233.847.8175.65 118.446.3170.37 123.744.5163.59 130.547.6174.89 119.246.3170.37 123.76.423.37 270.78.230.15 263.9 6585.69 20109.11 4.47 19127.14 0.00 0.002/16/2025 13:00 11.341.46 252.615.055.03 239.016.460.31 233.847.8175.65 118.446.3170.37 123.744.5163.59 130.547.6174.89 119.246.3170.37 123.744.1162.08 132.08.230.15 263.9 6658.06 20247.82 4.48 19266.36 0.00 0.002/16/2025 13:30 48.0176.40 117.715.055.03 239.016.460.31 233.815.255.79 238.314.452.77 241.37.226.38 267.747.6174.89 119.246.3170.37 123.744.1162.08 132.08.230.15 263.9 6477.13 20382.76 4.48 19266.36 0.00 0.002/16/2025 14:00 48.0176.40 117.752.1191.48 102.616.460.31 233.815.255.79 238.314.452.77 241.37.226.38 267.747.6174.89 119.246.3170.37 123.744.1162.08 132.08.230.15 263.9 6549.50 20519.21 4.47 19528.99 0.00 0.002/16/2025 14:30 48.0176.40 117.752.1191.48 102.653.9198.26 95.810.337.69 256.414.452.77 241.37.226.38 267.717.062.57 231.516.460.31 233.815.456.54 237.58.230.15 263.9 6621.87 20657.16 3.75 19653.13 0.00 0.002/16/2025 15:00 48.0176.40 117.752.1191.48 102.653.9198.26 95.848.0176.40 117.714.452.77 241.37.226.38 267.717.062.57 231.516.460.31 233.815.456.54 237.58.230.15 263.9 6658.06 20795.87 3.76 19755.40 0.00 0.002/16/2025 15:30 48.0176.40 117.752.1191.48 102.653.9198.26 95.848.0176.40 117.747.6174.89 119.29.033.17 260.917.062.57 231.516.460.31 233.815.456.54 237.58.230.15 263.9 6730.43 20936.09 3.76 19878.71 0.00 0.002/16/2025 16:00 48.0176.40 117.752.1191.48 102.653.9198.26 95.848.0176.40 117.747.6174.89 119.247.6174.89 119.217.062.57 231.516.460.31 233.815.456.54 237.58.230.15 263.9 6802.80 21077.81 3.75 19991.29 0.00 0.002/16/2025 16:30 12.746.74 247.316.460.31 233.818.066.34 227.748.0176.40 117.747.6174.89 119.247.6174.89 119.253.9198.26 95.816.460.31 233.815.456.54 237.58.230.15 263.9 6513.32 21213.51 3.76 20113.74 0.00 0.002/16/2025 17:00 12.746.74 247.316.460.31 233.818.066.34 227.748.0176.40 117.747.6174.89 119.247.6174.89 119.253.9198.26 95.853.7197.51 96.615.456.54 237.58.230.15 263.9 6585.69 21350.71 3.77 20217.03 0.00 0.002/16/2025 17:30 12.746.74 247.316.460.31 233.818.066.34 227.720.575.39 218.715.456.54 237.511.742.97 251.153.9198.26 95.853.7197.51 96.652.5192.99 101.18.230.15 263.9 6549.50 21487.16 3.75 20329.87 0.00 0.002/16/2025 18:00 50.0183.94 110.116.460.31 233.818.066.34 227.720.575.39 218.715.456.54 237.511.742.97 251.153.9198.26 95.853.7197.51 96.652.5192.99 101.18.230.15 263.9 6585.69 21624.36 3.76 20457.79 0.00 0.002/16/2025 18:30 50.0183.94 110.143.1158.31 135.818.066.34 227.720.575.39 218.715.456.54 237.511.742.97 251.153.9198.26 95.853.7197.51 96.652.5192.99 101.18.230.15 263.9 4704.06 21722.36 3.76 20567.53 0.00 0.002/16/2025 19:00 75.7278.17 15.943.1158.31 135.818.066.34 227.720.575.39 218.715.456.54 237.511.742.97 251.153.9198.26 95.853.7197.51 96.652.5192.99 101.18.230.15 263.9 4523.14 21816.59 3.76 20669.00 0.00 0.002/16/2025 19:30 75.7278.17 15.968.5251.79 42.318.066.34 227.720.575.39 218.715.456.54 237.511.742.97 251.116.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4486.95 21910.07 3.43 20779.39 0.00 0.002/16/2025 20:00 75.7278.17 15.968.5251.79 42.344.1162.08 132.020.575.39 218.715.456.54 237.511.742.97 251.116.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4595.51 22005.81 3.43 20886.52 0.00 0.002/16/2025 20:30 75.7278.17 15.968.5251.79 42.344.1162.08 132.046.8171.88 122.215.456.54 237.511.742.97 251.116.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4631.69 22102.30 3.44 20981.35 0.00 0.002/16/2025 21:00 75.7278.17 15.968.5251.79 42.370.1257.82 36.246.8171.88 122.215.456.54 237.511.742.97 251.116.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4595.51 22198.04 3.43 21083.49 0.00 0.002/16/2025 21:30 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.215.456.54 237.511.742.97 251.116.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4559.32 22293.03 3.43 21188.48 0.00 0.002/16/2025 22:00 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.241.4152.28 141.811.742.97 251.116.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4595.51 22388.77 3.43 21289.51 0.00 0.002/16/2025 22:30 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.241.4152.28 141.837.7138.71 155.416.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4595.51 22484.51 3.44 21394.21 0.00 0.002/16/2025 23:00 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.337.7138.71 155.416.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4486.95 22577.99 3.43 21496.02 0.00 0.002/16/2025 23:30 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.916.058.80 235.314.854.28 239.813.148.25 245.88.230.15 263.9 4631.69 22674.48 3.43 21599.15 0.00 0.002/17/2025 0:00 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.942.2155.29 138.814.854.28 239.813.148.25 245.88.230.15 263.9 4631.69 22770.97 0.00 21697.18 0.00 0.002/17/2025 0:30 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.942.2155.29 138.835.5130.42 163.613.148.25 245.88.230.15 263.9 3654.69 22847.11 3.53 21773.94 0.00 0.002/17/2025 1:00 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.962.8230.68 63.435.5130.42 163.613.148.25 245.88.230.15 263.9 3618.51 22922.50 3.51 21885.93 0.00 0.002/17/2025 1:30 13.549.75 244.315.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.962.8230.68 63.456.2206.56 87.513.148.25 245.88.230.15 263.9 3654.69 22998.64 3.46 21985.95 0.00 0.002/17/2025 2:00 33.6123.63 170.415.255.79 238.370.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.962.8230.68 63.456.2206.56 87.513.148.25 245.88.230.15 263.9 3546.14 23072.52 3.49 22089.93 0.00 0.00WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 50 Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining Level Volume Space Remaining (mm/dd/yyyy hh:mm:ss) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (%) (bbls) (bbls) (bbls/d) (bbls) (bbls/min) (bbls) (bbls/min) (bbls)TANK 10Fluid Injection Cumulative into NDBi-014Fluid Injection Rate into NDBi-030TANK 6PresentTANK 2 TANK 3 TANK 4 TANK 5 NDB-025NDB-025 WELL CLEAN-UP_INJECTION TANK FARM TO INJECTION WELL NDBi-014 & NDBi-030Well:Tank Strap Fluid RateTank Strap Fluid CumulativeStart Data:End Date:Date & TimeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-030TANK 110-Feb-2025 @ 07:30TANK 7 TANK 8 TANK 92/17/2025 2:30 33.6123.63 170.435.7131.17 162.970.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.962.8230.68 63.456.2206.56 87.513.148.25 245.88.230.15 263.9 3618.51 23147.90 3.40 22197.04 0.00 0.002/17/2025 3:00 54.6200.53 93.535.7131.17 162.970.1257.82 36.272.6266.87 27.266.9245.76 48.364.0235.20 58.962.8230.68 63.456.2206.56 87.513.148.25 245.88.230.15 263.9 3690.88 23224.80 3.41 22296.16 0.00 0.002/17/2025 3:30 54.6200.53 93.556.6208.06 86.015.255.79 238.316.861.82 232.212.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3690.88 23301.69 3.41 22296.16 0.00 0.002/17/2025 4:00 75.1275.91 18.256.6208.06 86.015.255.79 238.316.861.82 232.212.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3618.51 23377.07 3.41 22296.16 0.00 0.002/17/2025 4:30 75.1275.91 18.256.6208.06 86.035.7131.17 162.916.861.82 232.212.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3618.51 23452.46 3.46 22343.09 0.00 0.002/17/2025 5:00 75.1275.91 18.276.9282.70 11.435.7131.17 162.916.861.82 232.212.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3582.32 23527.09 3.45 22435.39 0.00 0.002/17/2025 5:30 75.1275.91 18.276.9282.70 11.435.7131.17 162.936.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23600.97 3.47 22542.31 0.00 0.002/17/2025 6:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.50 22648.70 0.00 0.002/17/2025 6:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.09 22742.90 0.00 0.002/17/2025 7:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.08 22836.25 0.00 0.002/17/2025 7:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.07 22927.72 0.00 0.002/17/2025 8:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.08 23020.17 0.00 0.002/17/2025 8:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.08 23112.72 0.00 0.002/17/2025 9:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 3.08 23204.90 0.00 0.002/17/2025 9:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.70 23262.32 0.00 0.002/17/2025 10:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.67 23283.61 0.00 0.002/17/2025 10:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.76 23304.98 0.00 0.002/17/2025 11:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.72 23327.16 0.00 0.002/17/2025 11:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.66 23349.35 0.00 0.002/17/2025 12:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.75 23371.12 0.00 0.002/17/2025 12:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.76 23393.19 0.00 0.002/17/2025 13:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 0.78 23415.35 0.00 0.002/17/2025 13:30 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 1.20 23451.56 0.00 0.002/17/2025 14:00 75.1275.91 18.276.9282.70 11.455.8205.05 89.036.9135.69 158.412.947.49 246.610.036.94 257.162.8230.68 63.456.2206.56 87.513.148.25 245.879.2290.99 3.1 3546.14 23674.85 1.26 23488.02 0.00 0.002/17/2025 14:30 7.627.89 266.27.025.63 268.46.624.12 269.97.427.14 266.97.025.63 268.47.226.38 267.76.423.37 270.75.319.60 274.56.624.12 269.97.627.89 266.2 3546.14 23674.85 1.21 23524.37 0.00 0.002/17/2025 15:00 7.627.89 266.27.025.63 268.46.624.12 269.97.427.14 266.97.025.63 268.47.226.38 267.76.423.37 270.75.319.60 274.56.624.12 269.97.627.89 266.2 3546.14 23674.85 1.31 23562.23 0.00 0.002/17/2025 15:30 7.627.89 266.27.025.63 268.46.624.12 269.97.427.14 266.97.025.63 268.47.226.38 267.76.423.37 270.75.319.60 274.56.624.12 269.97.627.89 266.2 3546.14 23674.85 1.31 23652.94 0.00 0.002/17/2025 16:00 7.627.89 266.27.025.63 268.46.624.12 269.97.427.14 266.97.025.63 268.47.226.38 267.76.423.37 270.75.319.60 274.56.624.12 269.97.627.89 266.2 3546.14 23674.85 1.30 23729.79 0.00 0.002/17/2025 16:30 7.627.89 266.27.025.63 268.46.624.12 269.97.427.14 266.97.025.63 268.47.226.38 267.76.423.37 270.75.319.60 274.56.624.12 269.97.627.89 266.2 3546.14 23674.85 1.30 23769.54 0.00 0.002/17/2025 17:00 7.627.89 266.27.025.63 268.46.624.12 269.97.427.14 266.97.025.63 268.47.226.38 267.76.423.37 270.75.319.60 274.56.624.12 269.97.627.89 266.2 3546.14 23674.85 1.29 23808.40 0.00 0.00WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 51 Santos – Pikka Development – NDB-025 SECTION 8 INJECTION WELL NDB-025 DATA WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 52 Date & Time BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) 02/10/2025 19:00:00 1997.58 104.03 35.75 1.54 0.00 0.00 0.00 02/10/2025 19:30:00 2215.97 95.48 483.63 0.50 0.00 3.01 27.91 02/10/2025 20:00:00 2426.24 95.48 751.86 0.00 0.00 2.98 124.09 02/10/2025 20:30:00 2410.60 94.16 713.81 0.50 0.00 2.98 124.09 02/10/2025 21:00:00 2215.97 91.60 483.63 1.42 0.00 2.98 124.09 02/10/2025 21:30:00 2639.52 90.79 1001.12 1.54 0.00 3.49 268.51 02/10/2025 22:00:00 2700.95 89.42 1070.47 1.58 0.00 3.50 372.74 02/10/2025 22:30:00 2729.47 87.80 1100.74 0.78 0.00 3.48 478.89 02/10/2025 23:00:00 2752.65 86.18 1133.62 0.00 0.00 3.49 584.54 02/10/2025 23:30:00 2753.36 85.29 1092.70 0.08 0.00 3.48 749.00 02/11/2025 00:00:00 2499.58 83.82 758.46 0.70 0.00 0.00 786.00 02/11/2025 00:30:00 2782.88 81.83 1154.01 2.49 0.00 3.46 885.23 02/11/2025 01:00:00 2810.19 82.68 1193.07 2.37 0.00 3.48 986.11 02/11/2025 01:30:00 2793.91 83.01 1146.67 3.13 0.00 3.37 1088.39 02/11/2025 02:00:00 2790.11 80.68 1114.63 3.99 0.00 3.11 1193.48 02/11/2025 02:30:00 2780.58 81.28 1110.30 3.21 0.00 3.42 1278.40 02/11/2025 03:00:00 2776.42 81.29 1113.29 3.33 0.00 3.35 1386.64 02/11/2025 03:30:00 2809.29 81.25 1155.80 3.49 0.00 3.45 1482.75 02/11/2025 04:00:00 2817.82 80.95 1174.54 3.37 0.00 3.70 1599.53 02/11/2025 04:30:00 2827.39 80.18 1191.26 2.39 0.00 3.73 1709.07 02/11/2025 05:00:00 2830.10 80.15 1184.15 2.33 0.00 3.70 1817.55 02/11/2025 05:30:00 2829.31 78.89 1185.17 2.25 0.00 3.71 1928.91 02/11/2025 06:00:00 2842.58 79.33 1199.20 1.30 0.00 3.69 2040.38 02/11/2025 06:30:00 2842.57 79.31 1201.77 1.26 0.00 3.69 2149.73 02/11/2025 07:00:00 2846.60 79.04 1216.99 2.21 0.00 3.69 2149.73 02/11/2025 07:30:00 2846.91 78.95 1203.01 2.57 0.00 3.66 2372.36 02/11/2025 08:00:00 2839.28 79.04 1196.34 5.49 0.00 3.66 2481.98 02/11/2025 08:30:00 2842.29 78.58 1205.24 6.44 0.00 3.66 2592.05 02/11/2025 09:00:00 2849.77 78.50 1213.28 6.48 0.00 3.66 2701.05 02/11/2025 09:30:00 2852.41 78.39 1207.90 7.34 0.00 3.63 2810.47 02/11/2025 10:00:00 2853.21 78.25 1217.59 7.28 0.00 3.62 2919.60 02/11/2025 10:30:00 2858.46 78.04 1226.45 6.44 0.00 3.64 3025.57 02/11/2025 11:00:00 2859.87 78.13 1228.29 8.16 0.00 3.64 3025.57 02/11/2025 11:30:00 2858.30 78.10 1216.71 7.24 0.00 3.60 3245.72 02/11/2025 12:00:00 2857.15 78.07 1221.10 7.24 0.00 3.60 3245.72 02/11/2025 12:30:00 2861.97 77.82 1228.21 8.08 0.00 3.60 3470.91 02/11/2025 13:00:00 2867.22 77.87 1232.64 8.12 0.00 3.60 3470.91 02/11/2025 13:30:00 2866.12 77.83 1226.53 9.93 0.00 3.61 3712.94 02/11/2025 14:00:00 2869.10 77.29 1232.78 10.83 0.00 3.60 3784.51 02/11/2025 14:30:00 2876.09 77.63 1242.63 10.89 0.00 3.59 3895.96 02/11/2025 15:00:00 2875.81 77.68 1242.51 11.77 0.00 3.59 4003.82 02/11/2025 15:30:00 2876.37 77.69 1245.26 13.49 0.00 3.62 4109.56 02/11/2025 16:00:00 2877.46 77.69 1240.00 10.05 0.00 3.59 4215.92 02/11/2025 16:30:00 2879.20 77.33 1247.92 10.03 0.00 3.60 4326.78 02/11/2025 17:00:00 2883.11 77.60 1251.39 10.83 0.00 3.20 4434.47 02/11/2025 17:30:00 2881.19 77.59 1247.80 10.83 0.00 3.59 4542.17 02/11/2025 18:00:00 2880.00 77.52 1247.98 11.85 0.00 3.20 4653.30 02/11/2025 18:30:00 2883.46 77.53 1251.45 15.36 0.00 3.20 4756.52 02/11/2025 19:00:00 2885.22 77.52 1253.32 16.28 0.00 3.20 4890.60 02/11/2025 19:30:00 2886.72 77.51 1251.33 16.16 0.00 3.20 4975.17 02/11/2025 20:00:00 2887.29 77.52 1254.84 15.24 0.00 3.20 5081.85 02/11/2025 20:30:00 2889.83 77.47 1258.31 16.88 0.00 3.20 5188.68 02/11/2025 21:00:00 2891.94 77.51 1259.15 18.67 0.00 3.20 5291.44 02/11/2025 21:30:00 2892.74 77.53 1259.95 21.19 0.00 3.20 5408.20 02/11/2025 22:00:00 2901.57 77.47 1273.18 20.35 0.00 3.40 5514.08 02/11/2025 22:30:00 2916.99 77.31 1301.53 19.35 0.00 3.60 5639.66 02/11/2025 23:00:00 2930.64 77.17 1320.14 21.03 0.00 3.70 5749.99 02/11/2025 23:30:00 2935.56 77.07 1324.37 22.66 0.00 3.70 5876.88 02/12/2025 00:00:00 2936.87 77.01 1325.37 22.70 0.00 0.00 5988.94 02/12/2025 00:30:00 2732.37 78.26 1055.75 15.60 0.00 0.00 5988.94 NDBi-014 NDBi-014 INJECTION DATA_NDB-025 WELL CLEAN-UP COMMENTS Pikka Development ND-B February 10th, 2025 @ 19:00 February 17th, 2025 @ 17:00 Location: Injection Start Date: Injection End Date: Date & Time BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) NDBi-014 NDBi-014 INJECTION DATA_NDB-025 WELL CLEAN-UP COMMENTS Pikka Development ND-B February 10th, 2025 @ 19:00 February 17th, 2025 @ 17:00 Location: Injection Start Date: Injection End Date: 02/12/2025 01:00:00 2905.41 77.46 1296.18 20.95 0.00 3.70 6205.09 02/12/2025 01:30:00 2926.34 77.36 1317.31 23.56 0.00 3.70 6298.72 02/12/2025 02:00:00 2933.13 77.24 1321.02 26.33 0.00 3.70 6421.39 02/12/2025 02:30:00 2925.81 77.17 1305.86 25.39 0.00 3.70 6421.39 02/12/2025 03:00:00 2923.31 77.24 1305.76 26.25 0.00 3.70 6421.39 02/12/2025 03:30:00 2928.46 77.29 1310.23 28.89 0.00 3.60 6764.19 02/12/2025 04:00:00 2929.17 77.30 1307.51 28.01 0.00 3.60 6882.19 02/12/2025 04:30:00 2931.46 77.26 1313.82 28.89 0.00 3.60 7002.44 02/12/2025 05:00:00 2934.63 77.28 1319.18 28.05 0.00 3.60 7114.60 02/12/2025 05:30:00 2932.76 77.35 1317.27 28.83 0.00 3.60 7219.07 02/12/2025 06:00:00 2930.85 77.38 1311.94 25.29 0.00 3.60 7219.07 02/12/2025 06:30:00 2932.88 77.32 1317.37 26.21 0.00 3.60 7219.07 02/12/2025 07:00:00 2936.65 77.34 1320.94 27.17 0.00 3.80 7563.11 02/12/2025 07:30:00 2935.67 77.36 1320.02 28.01 0.00 3.80 7563.11 02/12/2025 08:00:00 2936.00 77.36 1318.25 28.89 0.00 3.79 7791.11 02/12/2025 08:30:00 2935.79 77.31 1320.06 27.13 0.00 3.82 7905.14 02/12/2025 09:00:00 2940.92 77.33 1326.29 28.92 0.00 3.81 8019.22 02/12/2025 09:30:00 2942.93 77.35 1329.08 29.01 0.00 3.81 8133.82 02/12/2025 10:00:00 2942.95 77.37 1325.61 30.00 0.00 3.80 8247.47 02/12/2025 10:30:00 2942.21 77.38 1325.55 29.94 0.00 3.80 8247.47 02/12/2025 11:00:00 2943.67 77.33 1330.04 29.08 0.00 3.82 8476.37 02/12/2025 11:30:00 2946.72 77.36 1333.69 30.94 0.00 3.82 8590.69 02/12/2025 12:00:00 2947.00 77.38 1333.69 30.94 0.00 3.82 8590.69 02/12/2025 12:30:00 2947.49 77.39 1332.79 30.96 0.00 3.82 8590.69 02/12/2025 13:00:00 2946.93 77.39 1332.79 30.04 0.00 3.79 8932.34 02/12/2025 13:30:00 2946.86 77.39 1333.67 31.00 0.00 3.78 9045.98 02/12/2025 14:00:00 2949.48 77.39 1337.34 31.88 0.00 3.78 9045.98 02/12/2025 14:30:00 2950.77 77.39 1332.87 31.92 0.00 3.78 9045.98 02/12/2025 15:00:00 2951.35 77.39 1333.65 27.39 0.00 3.81 9388.32 02/12/2025 15:30:00 2954.00 77.30 1337.96 27.51 0.00 3.81 9388.32 02/12/2025 16:00:00 2956.01 77.30 1341.61 28.21 0.00 3.81 9616.74 02/12/2025 16:30:00 2955.44 77.30 1340.73 28.25 0.00 3.81 9616.74 02/12/2025 17:00:00 2956.21 77.28 1341.65 23.78 0.00 3.82 9845.07 02/12/2025 17:30:00 2956.74 77.24 1342.53 23.02 0.00 3.80 9961.75 02/12/2025 18:00:00 2957.59 77.23 1344.44 24.82 0.00 3.80 10073.96 02/12/2025 18:30:00 2958.51 77.22 1345.52 25.04 0.00 3.80 10187.86 02/12/2025 19:00:00 2958.67 77.20 1345.82 26.05 0.00 3.80 10300.77 02/12/2025 19:30:00 2958.95 77.19 1345.90 25.29 0.00 3.80 10415.29 02/12/2025 20:00:00 2959.87 77.16 1346.46 25.06 0.00 3.80 10529.16 02/12/2025 20:30:00 2972.19 77.06 1371.83 26.49 0.00 3.80 10652.40 02/12/2025 21:00:00 2978.48 76.93 1380.71 27.13 0.00 3.80 10780.93 02/12/2025 21:30:00 2972.32 76.88 1374.33 28.05 0.00 3.80 10904.66 02/12/2025 22:00:00 2977.15 76.86 1379.71 27.21 0.00 3.80 11025.41 02/12/2025 22:30:00 2979.83 76.83 1383.35 27.25 0.00 3.80 11145.06 02/12/2025 23:00:00 2980.57 76.82 1385.14 28.17 0.00 3.80 11268.77 02/12/2025 23:30:00 2981.81 76.82 1385.30 29.16 0.00 3.80 11394.72 02/13/2025 00:00:00 2982.71 76.81 1387.14 31.08 0.00 3.80 11512.06 02/13/2025 00:30:00 2734.98 77.92 1058.42 23.22 0.00 3.80 11576.73 02/13/2025 01:00:00 2950.38 77.62 1353.68 27.73 0.00 4.00 11699.33 02/13/2025 01:30:00 2976.69 77.29 1389.41 28.73 0.00 4.00 11833.59 02/13/2025 02:00:00 2992.65 76.99 1406.39 29.76 0.00 4.00 11964.92 02/13/2025 02:30:00 3000.80 76.86 1417.10 30.68 0.00 4.00 12088.79 02/13/2025 03:00:00 2997.05 76.77 1410.94 28.05 0.00 4.00 12221.16 02/13/2025 03:30:00 3001.63 76.69 1417.00 26.09 0.00 4.00 12350.65 02/13/2025 04:00:00 3007.01 76.61 1423.85 27.71 0.00 4.00 12489.25 02/13/2025 04:30:00 3006.72 76.58 1423.59 29.24 0.00 4.00 12608.27 02/13/2025 05:00:00 3002.93 76.89 1416.08 28.09 0.00 4.00 12738.46 02/13/2025 05:30:00 3005.14 76.74 1419.48 28.73 0.00 4.38 12869.72 02/13/2025 06:00:00 3005.90 76.66 1420.21 29.50 0.00 4.40 13031.00 02/13/2025 06:30:00 3006.65 76.62 1420.12 29.44 0.00 4.40 13031.00 Date & Time BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) NDBi-014 NDBi-014 INJECTION DATA_NDB-025 WELL CLEAN-UP COMMENTS Pikka Development ND-B February 10th, 2025 @ 19:00 February 17th, 2025 @ 17:00 Location: Injection Start Date: Injection End Date: 02/13/2025 07:00:00 3009.23 76.58 1424.46 30.24 0.00 4.38 13264.71 02/13/2025 07:30:00 3011.58 76.57 1427.50 31.22 0.00 4.38 13264.71 02/13/2025 08:00:00 3011.43 76.56 1426.14 32.85 0.00 4.38 13264.71 02/13/2025 08:30:00 3011.98 76.55 1426.92 30.96 0.00 0.00 13264.71 02/13/2025 09:00:00 2700.79 78.04 1048.91 11.33 0.00 0.00 13264.71 02/13/2025 09:30:00 2537.80 79.40 385.50 6.68 0.00 0.00 13264.71 02/13/2025 10:00:00 2459.43 80.40 54.65 4.81 0.00 0.00 13264.71 02/15/2025 11:00:00 2224.94 97.44 623.00 0.00 0.00 0.00 13264.71 02/15/2025 11:30:00 2752.62 94.23 597.00 10.31 5.00 4.08 13308.36 02/15/2025 12:00:00 2766.76 91.09 875.00 13.76 5.43 4.06 13431.16 02/15/2025 12:30:00 2840.04 88.50 1311.00 12.02 7.22 4.07 13552.76 02/15/2025 13:00:00 2612.61 89.61 1436.00 10.25 7.21 4.00 13552.76 02/15/2025 13:30:00 2825.56 86.19 1529.00 11.17 5.91 4.00 13717.80 02/15/2025 14:00:00 2859.87 84.72 1500.00 12.10 5.04 4.04 13838.00 02/15/2025 14:30:00 2873.49 83.45 1265.00 12.34 6.45 4.06 13981.55 02/15/2025 15:00:00 2822.85 83.40 1581.00 7.04 5.94 4.06 13981.55 02/15/2025 15:30:00 2879.73 81.46 1666.00 8.15 8.24 4.00 14163.19 02/15/2025 16:00:00 2897.63 80.54 1130.00 8.39 7.38 3.99 14283.21 02/15/2025 16:30:00 2603.01 80.61 1630 8.53 7.37 3.99 14402.73 02/15/2025 17:00:00 2385.80 83.09 1620 4.92 9.58 0.00 14402.73 02/15/2025 17:30:00 2785.94 83.33 1820 8.35 7.36 0.00 14402.73 02/15/2025 18:00:00 2858.39 80.87 1812 9.23 8.24 4.00 14535.35 02/15/2025 18:30:00 2888.63 79.74 1867 11.27 6.94 4.00 14658.30 02/15/2025 19:00:00 2895.43 79.49 1658 11.58 7.92 4.00 14777.97 02/15/2025 19:30:00 2911.62 74.89 1920 11.90 4.88 4.00 14902.71 02/15/2025 20:00:00 2940.88 77.45 1615 6.62 8.87 4.00 15014.54 02/15/2025 20:30:00 2944.26 76.97 1710 7.52 8.38 4.00 15133.78 02/15/2025 21:00:00 2945.94 76.61 1577 8.31 7.54 4.00 15254.53 02/15/2025 21:30:00 2948.53 76.24 1570 7.36 8.38 4.00 15374.04 02/15/2025 22:00:00 2878.90 76.05 1757 8.27 5.28 4.00 15491.51 02/15/2025 22:30:00 2970.52 75.85 1589 9.03 6.59 4.17 15607.18 02/15/2025 23:00:00 2979.06 75.30 1592 9.13 7.51 4.17 15743.57 02/15/2025 23:30:00 2982.61 75.01 1630 10.15 7.06 4.17 15869.14 02/16/2025 00:00:00 2964.96 75.30 1620 10.43 7.58 0.00 15991.13 02/16/2025 00:30:00 2974.66 74.55 1820 14.18 7.64 4.80 16103.72 02/16/2025 01:00:00 2934.69 74.47 1812 14.00 5.73 4.80 16103.72 02/16/2025 01:30:00 3021.57 74.40 1867 13.90 8.42 5.05 16356.64 02/16/2025 02:00:00 3002.31 74.13 1630 13.08 8.49 4.47 16509.06 02/16/2025 02:30:00 3021.81 74.22 1620 15.65 8.46 4.40 16644.74 02/16/2025 03:00:00 3032.94 73.81 1820 19.16 6.63 5.03 16799.04 02/16/2025 03:30:00 3004.59 73.71 1812 20.16 7.56 4.85 16945.44 02/16/2025 04:00:00 3037.96 73.81 1867 21.04 8.46 4.30 17087.22 02/16/2025 04:30:00 3023.89 73.75 1658 20.96 8.42 4.73 17273.64 02/16/2025 05:00:00 2913.64 74.23 1920 20.98 8.47 3.84 17374.05 02/16/2025 05:30:00 2987.09 74.76 1615 20.96 8.40 2.99 17456.69 02/16/2025 06:00:00 3009.06 74.37 1710 21.86 8.43 4.52 17579.16 02/16/2025 06:30:00 3016.77 74.33 1577 26.25 9.32 4.52 17579.16 02/16/2025 07:00:00 2962.50 74.65 1570 23.43 9.72 3.78 17846.35 02/16/2025 07:30:00 2959.77 74.90 1757 24.87 7.47 3.76 17957.72 02/16/2025 08:00:00 2959.12 75.04 1589 28.28 6.51 3.76 18071.67 02/16/2025 08:30:00 2959.98 75.17 1592 28.94 7.35 3.76 18184.58 02/16/2025 09:00:00 2961.37 75.26 1630 30.63 8.24 3.77 18297.61 02/16/2025 09:30:00 2965.50 75.35 1620 27.92 8.68 3.77 18297.61 02/16/2025 10:00:00 2966.12 75.43 1820 29.72 10.47 3.76 18523.20 02/16/2025 10:30:00 2967.42 75.51 1812 28.88 3.78 3.77 18636.22 02/16/2025 11:00:00 2970.89 75.57 1710 32.47 10.01 3.78 18749.52 02/16/2025 11:30:00 3013.09 75.51 1577 30.71 11.37 3.76 18863.09 02/16/2025 12:00:00 3022.17 75.27 1570 34.33 7.85 4.47 18993.09 02/16/2025 12:30:00 3026.39 75.22 1757 37.74 8.66 4.47 19127.14 NDB-025 - Well Clean-Up_Flow #2 Date & Time BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) NDBi-014 NDBi-014 INJECTION DATA_NDB-025 WELL CLEAN-UP COMMENTS Pikka Development ND-B February 10th, 2025 @ 19:00 February 17th, 2025 @ 17:00 Location: Injection Start Date: Injection End Date: 02/16/2025 13:00:00 3028.27 75.21 1589 40.41 9.12 4.48 19266.36 02/16/2025 13:30:00 3031.28 75.23 1592 42.24 9.14 4.48 19266.36 02/16/2025 14:00:00 3004.53 75.26 1630 45.18 11.90 4.47 19528.99 02/16/2025 14:30:00 2982.52 75.58 1620 40.93 12.37 3.75 19653.13 02/16/2025 15:00:00 2982.22 75.77 1820 40.81 7.86 3.76 19755.40 02/16/2025 15:30:00 2983.69 75.89 1812 42.48 8.32 3.76 19878.71 02/16/2025 16:00:00 2983.86 75.99 1867 44.10 9.17 3.75 19991.29 02/16/2025 16:30:00 2985.36 76.07 1630 42.30 9.21 3.76 20113.74 02/16/2025 17:00:00 2987.90 76.15 1620 44.94 9.17 3.77 20217.03 02/16/2025 17:30:00 2988.06 76.21 1820 46.67 9.59 3.75 20329.87 02/16/2025 18:00:00 2989.00 76.26 1812 46.71 9.59 3.76 20457.79 02/16/2025 18:30:00 2991.82 76.32 1867 47.71 10.93 3.76 20567.53 02/16/2025 19:00:00 2993.16 76.36 1658 48.69 11.86 3.76 20669.00 02/16/2025 19:30:00 2964.17 76.58 1920 46.15 12.78 3.43 20779.39 02/16/2025 20:00:00 2962.26 76.69 1615 45.50 11.48 3.43 20886.52 02/16/2025 20:30:00 2963.61 76.76 1710 45.54 11.96 3.44 20981.35 02/16/2025 21:00:00 2964.12 76.83 1577 45.14 10.50 3.43 21083.49 02/16/2025 21:30:00 2963.39 76.87 1570 42.08 12.65 3.43 21188.48 02/16/2025 22:00:00 2963.24 76.91 1757 39.05 12.15 3.43 21289.51 02/16/2025 22:30:00 2962.98 76.93 1589 38.89 11.69 3.44 21394.21 02/16/2025 23:00:00 2964.92 76.94 1589 38.71 11.24 3.43 21496.02 02/16/2025 23:30:00 2965.95 76.94 1615 37.66 10.29 3.43 21599.15 02/17/2025 00:00:00 2919.80 77.84 1710 33.23 11.21 0.00 21697.18 02/17/2025 00:30:00 2954.76 77.42 1577 35.22 10.37 3.53 21773.94 02/17/2025 01:00:00 2960.95 77.23 1570 33.59 10.35 3.51 21885.93 02/17/2025 01:30:00 2959.95 77.15 1757 33.79 10.41 3.46 21985.95 02/17/2025 02:00:00 2960.49 77.07 1589 24.65 10.35 3.49 22089.93 02/17/2025 02:30:00 2962.99 76.78 1592 22.46 8.05 3.40 22197.04 02/17/2025 03:00:00 2746.78 77.69 1630 19.30 10.18 3.41 22296.16 02/17/2025 03:30:00 2581.57 79.19 1620 15.16 10.52 3.41 22296.16 02/17/2025 04:00:00 2501.58 80.23 1820 12.16 10.06 3.41 22296.16 02/17/2025 04:30:00 2889.42 79.64 1812 14.70 9.59 3.46 22343.09 02/17/2025 05:00:00 2929.50 78.65 1710 14.64 9.60 3.45 22435.39 02/17/2025 05:30:00 2946.43 78.12 1577 14.76 10.48 3.47 22542.31 02/17/2025 06:00:00 2919.31 77.82 1570 15.18 8.80 3.50 22648.70 02/17/2025 06:30:00 2911.92 77.75 1757 17.15 9.29 3.09 22742.90 02/17/2025 07:00:00 2914.50 77.59 1589 17.59 9.35 3.08 22836.25 02/17/2025 07:30:00 2917.28 77.45 623 17.27 10.36 3.07 22927.72 02/17/2025 08:00:00 2918.93 77.33 597 18.87 9.13 3.08 23020.17 02/17/2025 08:30:00 2920.15 77.22 875 17.47 9.64 3.08 23112.72 02/17/2025 09:00:00 2878.78 77.11 1482 17.71 10.12 3.08 23204.90 02/17/2025 09:30:00 2651.71 78.43 1388 16.11 8.37 0.70 23262.32 02/17/2025 10:00:00 2588.14 79.35 1450 16.15 7.07 0.67 23283.61 02/17/2025 10:30:00 2573.77 80.03 1420 15.19 7.47 0.76 23304.98 02/17/2025 11:00:00 2563.13 80.10 1466 14.32 7.05 0.72 23327.16 02/17/2025 11:30:00 2548.67 80.65 1158 13.36 8.33 0.66 23349.35 02/17/2025 12:00:00 2528.34 81.10 871 13.24 7.89 0.75 23371.12 02/17/2025 12:30:00 2517.81 81.52 916 13.24 6.54 0.76 23393.19 02/17/2025 13:00:00 2509.61 81.92 920 13.08 7.41 0.78 23415.35 02/17/2025 13:30:00 2564.88 82.14 780 12.12 7.39 1.20 23451.56 02/17/2025 14:00:00 2579.14 82.11 850 13.00 7.83 1.26 23488.02 02/17/2025 14:30:00 2574.84 82.18 975 12.04 9.17 1.21 23524.37 02/17/2025 15:00:00 2585.61 82.27 1030 12.92 7.87 1.31 23562.23 02/17/2025 15:30:00 2588.56 82.27 920 13.00 8.29 1.31 23652.94 02/17/2025 16:00:00 2588.14 82.34 780 12.08 8.73 1.30 23729.79 02/17/2025 16:30:00 2587.40 82.39 850 12.80 7.37 1.30 23769.54 02/17/2025 17:00:00 2586.32 82.43 975 12.66 7.68 1.29 23808.40 0.006000.0012000.0018000.0024000.0030000.0036000.000.01.02.03.04.05.06.0Rate (bbls/min)Santos - Pikka Development - NDB-025Injection Well NDBi-014Injection Rate - Cumulative Plot Injection Rate Injection CumulativeCumulative (bbls)Page 57www.expro.comWT-XAK-0127.4_NDB-025_Rev A Ϭ͘ϬϬϭϱ͘ϬϬϯϬ͘ϬϬϰϱ͘ϬϬϲϬ͘ϬϬϳϱ͘ϬϬϵϬ͘ϬϬϭϬϱ͘ϬϬϬϱϬϬϭϬϬϬϭϱϬϬϮϬϬϬϮϱϬϬϯϬϬϬϯϱϬϬ3UHVVXUH SVLJ 6DQWRV 3LNND'HYHORSPHQW 1'%,QMHFWLRQ:HOO1'%L:HOO+HDG %RWWRP+ROH&RQGLWLRQV3ORW%+3:+3L%+7,$3L2$3L3UHVVXUH SVLJ 7HPSHUDWXUH ;Σ&Ϳ WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 58 Santos – Pikka Development – NDB-025 SECTION 9 TEST SUMMARY SHUT-IN / BUILD-UP PERIOD WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 59 Build-Up Summary Notes: Unless otherwise stated, the above readings were taken just before shut-in. Flow rates and GORs are average values during the last hour (or most stable period) on each choke size. Throughout the report reference is made to Separator and Standard/Stock Tank (Stb) oil rates. The separator rate refers to the oil metered at separator conditions. The standard/stock tank rate is the metered rate corrected for shrinkage at standard conditions of 14.73 psi, 60°F. Santos – Pikka Development – NDB-025 – Shut-in / Build-up Period Duration of Monitored Build-up = 186 hrs. Shut-in / Build-up Period Start of Build-up Period: February 17th, 2025 06:00:00 End of Build-up Period: February 25th, 2025 00:00:00 During the Main Shut-In/Build-up period, data was collected in one second and 30-minute intervals through 3rd Party Downhole Gauge Schlumberger (SLB). Provided below are the initial and final data point values that were recorded during the Shut-in / Build- up Period. These values include Bottom-Hole Pressure and Bottom-Hole Temperature. Initial Data Values (Shut-in / Build-up Period): February 17th, 2025 @ 6:00:00 BH Pressure BH Temperature (psig) (°F) 1754.06 103.51 End Data Values (Shut-in / Build-up Period): February 25th, 2025 @ ϬϬ:00:00 BH Pressure BH Temperature (psig) (°F) 1937.41 105.39 Note: NDB-025 is continuously logged & monitored, with data reports distributed daily. For the End of Well Report, the above dates equivalent to 186 hrs (7 days, 18 hours) is captured in the build-up summary and plotted. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 60 Santos – Pikka Development – NDB-025 SECTION 10 TEST DATA REPORT SHUT-IN / BUILD-UP WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 61 Location / Field:Pikka Development / NDB Start Data:17-Feb-2025 @ 06:01 End Date:Present (mm-dd-yyyy hh:mm:ss)(psig) (°F) 2/17/2025 6:00:00 1754.06 103.52 2/17/2025 6:30:00 1811.74 103.70 2/17/2025 7:00:00 1818.28 103.76 2/17/2025 7:30:00 1822.78 103.82 2/17/2025 8:00:00 1826.40 103.88 2/17/2025 8:30:00 1829.55 103.93 2/17/2025 9:00:00 1832.29 103.97 2/17/2025 9:30:00 1834.80 104.01 2/17/2025 10:00:00 1837.09 104.06 2/17/2025 10:30:00 1839.19 104.09 2/17/2025 11:00:00 1841.15 104.13 2/17/2025 11:30:00 1842.95 104.16 2/17/2025 12:00:00 1844.68 104.19 2/17/2025 12:30:00 1846.35 104.22 2/17/2025 13:00:00 1847.89 104.25 2/17/2025 13:30:00 1849.35 104.28 2/17/2025 14:00:00 1850.76 104.31 2/17/2025 14:30:00 1852.08 104.34 2/17/2025 15:00:00 1853.35 104.37 2/17/2025 15:30:00 1854.53 104.39 2/17/2025 16:00:00 1855.72 104.41 2/17/2025 16:30:00 1856.86 104.44 2/17/2025 17:00:00 1857.96 104.46 2/17/2025 17:30:00 1859.03 104.48 2/17/2025 18:00:00 1860.05 104.50 2/17/2025 18:30:00 1861.05 104.51 2/17/2025 19:00:00 1862.02 104.53 2/17/2025 19:30:00 1862.97 104.55 2/17/2025 20:00:00 1863.88 104.56 2/17/2025 20:30:00 1864.77 104.58 2/17/2025 21:00:00 1865.64 104.59 2/17/2025 21:30:00 1866.48 104.60 2/17/2025 22:00:00 1867.31 104.62 2/17/2025 22:30:00 1868.11 104.63 2/17/2025 23:00:00 1868.89 104.65 2/17/2025 23:30:00 1869.66 104.66 2/18/2025 0:00:00 1870.41 104.67 2/18/2025 0:30:00 1871.14 104.68 2/18/2025 1:00:00 1871.81 104.69 2/18/2025 1:30:00 1872.55 104.70 2/18/2025 2:00:00 1873.23 104.71 2/18/2025 2:30:00 1873.91 104.73 2/18/2025 3:00:00 1874.56 104.73 2/18/2025 3:30:00 1875.220 104.738 2/18/2025 4:00:00 1875.840 104.738 2/18/2025 4:30:00 1876.460 104.756 2/18/2025 5:00:00 1877.080 104.756 2/18/2025 5:30:00 1877.680 104.774 2/18/2025 6:00:00 1878.270 104.774 2/18/2025 6:30:00 1878.860 104.774 2/18/2025 7:00:00 1879.430 104.792 2/18/2025 7:30:00 1880.000 104.792 2/18/2025 8:00:00 1880.550 104.810 2/18/2025 8:30:00 1881.090 104.810 2/18/2025 9:00:00 1881.640 104.828 2/18/2025 9:30:00 1882.180 104.828 2/18/2025 10:00:00 1882.700 104.828 2/18/2025 10:30:00 1883.210 104.846 2/18/2025 11:00:00 1883.710 104.846 2/18/2025 11:30:00 1884.200 104.864 2/18/2025 12:00:00 1884.690 104.864 2/18/2025 12:30:00 1885.170 104.864 2/18/2025 13:00:00 1885.650 104.882 2/18/2025 13:30:00 1886.110 104.882 2/18/2025 14:00:00 1886.580 104.882 2/18/2025 14:30:00 1887.040 104.900 2/18/2025 15:00:00 1887.480 104.900 2/18/2025 15:30:00 1887.920 104.918 2/18/2025 16:00:00 1888.360 104.918 2/18/2025 16:30:00 1888.800 104.918 2/18/2025 17:00:00 1889.220 104.918 2/18/2025 17:30:00 1889.650 104.936 2/18/2025 18:00:00 1890.060 104.936 2/18/2025 18:30:00 1890.470 104.936 2/18/2025 19:00:00 1890.870 104.954 2/18/2025 19:30:00 1891.270 104.954 2/18/2025 20:00:00 1891.670 104.954 2/18/2025 20:30:00 1892.060 104.954 2/18/2025 21:00:00 1892.450 104.972 2/18/2025 21:30:00 1892.830 104.972 2/18/2025 22:00:00 1893.210 104.972 NDB-025 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS NDB-025 Shut-in at choke manifold. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 62 Location / Field:Pikka Development / NDB Start Data:17-Feb-2025 @ 06:01 End Date:Present (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDB-025 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 2/18/2025 22:30:00 1893.580 104.972 2/18/2025 23:00:00 1893.950 104.990 2/18/2025 23:30:00 1894.320 104.990 2/19/2025 0:00:00 1894.680 104.990 2/19/2025 0:30:00 1895.050 104.995 2/19/2025 1:00:00 1895.400 104.999 2/19/2025 1:30:00 1895.750 105.003 2/19/2025 2:00:00 1896.100 105.006 2/19/2025 2:30:00 1896.440 105.012 2/19/2025 3:00:00 1896.780 105.015 2/19/2025 3:30:00 1897.110 105.019 2/19/2025 4:00:00 1897.440 105.022 2/19/2025 4:30:00 1897.760 105.026 2/19/2025 5:00:00 1898.090 105.030 2/19/2025 5:30:00 1898.410 105.033 2/19/2025 6:00:00 1898.710 105.039 2/19/2025 6:30:00 1899.030 105.040 2/19/2025 7:00:00 1899.340 105.044 2/19/2025 7:30:00 1899.640 105.048 2/19/2025 8:00:00 1899.950 105.051 2/19/2025 8:30:00 1900.250 105.055 2/19/2025 9:00:00 1900.540 105.058 2/19/2025 9:30:00 1900.840 105.060 2/19/2025 10:00:00 1901.130 105.064 2/19/2025 10:30:00 1901.420 105.067 2/19/2025 11:00:00 1901.710 105.071 2/19/2025 11:30:00 1901.990 105.075 2/19/2025 12:00:00 1902.270 105.076 2/19/2025 12:30:00 1902.550 105.080 2/19/2025 13:00:00 1902.820 105.084 2/19/2025 13:30:00 1903.090 105.085 2/19/2025 14:00:00 1903.360 105.089 2/19/2025 14:30:00 1903.620 105.091 2/19/2025 15:00:00 1903.880 105.094 2/19/2025 15:30:00 1904.150 105.098 2/19/2025 16:00:00 1904.410 105.100 2/19/2025 16:30:00 1904.660 105.103 2/19/2025 17:00:00 1904.910 105.105 2/19/2025 17:30:00 1905.160 105.107 2/19/2025 18:00:00 1905.420 105.111 2/19/2025 18:30:00 1905.660 105.112 2/19/2025 19:00:00 1905.910 105.116 2/19/2025 19:30:00 1906.160 105.118 2/19/2025 20:00:00 1906.400 105.120 2/19/2025 20:30:00 1906.640 105.123 2/19/2025 21:00:00 1906.890 105.125 2/19/2025 21:30:00 1907.120 105.127 2/19/2025 22:00:00 1907.370 105.130 2/19/2025 22:30:00 1907.600 105.132 2/19/2025 23:00:00 1907.840 105.134 2/19/2025 23:30:00 1908.070 105.138 2/20/2025 0:00:00 1908.300 105.139 2/20/2025 0:30:00 1908.530 105.141 2/20/2025 1:00:00 1908.760 105.143 2/20/2025 1:30:00 1908.980 105.147 2/20/2025 2:00:00 1909.210 105.148 2/20/2025 2:30:00 1909.430 105.150 2/20/2025 3:00:00 1909.650 105.152 2/20/2025 3:30:00 1909.860 105.154 2/20/2025 4:00:00 1910.080 105.157 2/20/2025 4:30:00 1910.510 105.161 2/20/2025 5:00:00 1910.510 105.161 2/20/2025 5:30:00 1910.720 105.163 2/20/2025 6:00:00 1910.930 105.165 2/20/2025 6:30:00 1911.130 105.166 2/20/2025 7:00:00 1911.340 105.168 2/20/2025 7:30:00 1911.540 105.170 2/20/2025 8:00:00 1911.750 105.172 2/20/2025 8:30:00 1911.950 105.174 2/20/2025 9:00:00 1912.150 105.175 2/20/2025 9:30:00 1912.350 105.177 2/20/2025 10:00:00 1912.540 105.179 2/20/2025 10:30:00 1912.740 105.181 2/20/2025 11:00:00 1912.935 105.183 20/02/2025 11:30:00 1913.140 105.170 20/02/2025 12:00:00 1913.330 105.180 20/02/2025 12:30:00 1913.520 105.190 20/02/2025 13:00:00 1913.710 105.190 20/02/2025 13:30:00 1913.890 105.190 20/02/2025 14:00:00 1914.080 105.190 20/02/2025 14:30:00 1914.270 105.200 WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 63 Location / Field:Pikka Development / NDB Start Data:17-Feb-2025 @ 06:01 End Date:Present (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDB-025 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 20/02/2025 15:00:00 1914.450 105.200 20/02/2025 15:30:00 1914.630 105.200 20/02/2025 16:00:00 1914.810 105.200 20/02/2025 16:30:00 1914.990 105.200 20/02/2025 17:00:00 1915.170 105.200 20/02/2025 17:30:00 1915.340 105.210 20/02/2025 18:00:00 1915.520 105.210 20/02/2025 18:30:00 1915.700 105.210 20/02/2025 19:00:00 1915.870 105.210 20/02/2025 19:30:00 1916.040 105.210 20/02/2025 20:00:00 1916.210 105.210 20/02/2025 20:30:00 1916.380 105.210 20/02/2025 21:00:00 1916.550 105.220 20/02/2025 21:30:00 1916.720 105.220 20/02/2025 22:00:00 1916.890 105.220 20/02/2025 22:30:00 1917.050 105.220 20/02/2025 23:00:00 1917.220 105.220 20/02/2025 23:30:00 1917.380 105.220 21/02/2025 00:00:00 1917.550 105.230 21/02/2025 00:30:00 1917.710 105.230 21/02/2025 01:00:00 1917.870 105.230 21/02/2025 01:30:00 1918.030 105.230 21/02/2025 02:00:00 1918.190 105.230 21/02/2025 02:30:00 1918.350 105.230 21/02/2025 03:00:00 1918.500 105.230 21/02/2025 03:30:00 1918.660 105.230 21/02/2025 04:00:00 1918.820 105.240 21/02/2025 04:30:00 1918.970 105.240 21/02/2025 05:00:00 1919.120 105.240 21/02/2025 05:30:00 1919.270 105.240 21/02/2025 06:00:00 1919.430 105.240 21/02/2025 06:30:00 1919.580 105.240 21/02/2025 07:00:00 1919.720 105.240 21/02/2025 07:30:00 1919.870 105.250 21/02/2025 08:00:00 1920.020 105.250 21/02/2025 08:30:00 1920.160 105.250 21/02/2025 09:00:00 1920.310 105.250 21/02/2025 09:30:00 1920.450 105.250 21/02/2025 10:00:00 1920.600 105.250 21/02/2025 10:30:00 1920.740 105.250 21/02/2025 11:00:00 1920.880 105.250 21/02/2025 11:30:00 1921.020 105.260 21/02/2025 12:00:00 1921.160 105.260 21/02/2025 12:30:00 1921.300 105.260 21/02/2025 13:00:00 1921.440 105.260 21/02/2025 13:30:00 1921.580 105.260 21/02/2025 14:00:00 1921.720 105.260 21/02/2025 14:30:00 1921.860 105.260 21/02/2025 15:00:00 1921.990 105.260 21/02/2025 15:30:00 1922.120 105.270 21/02/2025 16:00:00 1922.260 105.270 21/02/2025 16:30:00 1922.390 105.270 21/02/2025 17:00:00 1922.530 105.270 21/02/2025 17:30:00 1922.660 105.270 21/02/2025 18:00:00 1922.790 105.270 21/02/2025 18:30:00 1922.920 105.270 21/02/2025 19:00:00 1923.050 105.270 21/02/2025 19:30:00 1923.180 105.270 21/02/2025 20:00:00 1923.310 105.270 21/02/2025 20:30:00 1923.440 105.280 21/02/2025 21:00:00 1923.570 105.280 21/02/2025 21:30:00 1923.700 105.280 21/02/2025 22:00:00 1923.830 105.280 21/02/2025 22:30:00 1923.950 105.280 21/02/2025 23:00:00 1924.080 105.280 21/02/2025 23:30:00 1924.200 105.280 22/02/2025 00:00:00 1924.330 105.280 22/02/2025 00:30:00 1924.450 105.290 22/02/2025 01:30:00 1924.700 105.290 22/02/2025 02:30:00 1924.950 105.290 22/02/2025 03:30:00 1925.190 105.290 22/02/2025 04:30:00 1925.430 105.290 22/02/2025 05:30:00 1925.660 105.290 22/02/2025 06:30:00 1925.900 105.300 22/02/2025 07:30:00 1926.130 105.300 22/02/2025 08:30:00 1926.360 105.300 22/02/2025 09:30:00 1926.590 105.300 22/02/2025 10:30:00 1926.810 105.310 22/02/2025 12:30:00 1927.250 105.310 22/02/2025 13:30:00 1927.470 105.310 22/02/2025 14:30:00 1927.680 105.310 WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 64 Location / Field:Pikka Development / NDB Start Data:17-Feb-2025 @ 06:01 End Date:Present (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDB-025 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 22/02/2025 15:30:00 1927.890 105.310 22/02/2025 16:30:00 1928.100 105.320 22/02/2025 17:30:00 1928.310 105.320 22/02/2025 18:30:00 1928.520 105.320 22/02/2025 19:30:00 1928.720 105.320 22/02/2025 20:30:00 1928.920 105.320 22/02/2025 21:30:00 1929.130 105.320 22/02/2025 22:30:00 1929.330 105.320 22/02/2025 23:30:00 1929.530 105.330 23/02/2025 00:00:00 1929.630 105.330 23/02/2025 00:30:00 1929.730 105.330 23/02/2025 01:00:00 1929.820 105.330 23/02/2025 01:30:00 1929.920 105.330 23/02/2025 02:00:00 1930.020 105.330 23/02/2025 02:30:00 1930.120 105.330 23/02/2025 03:00:00 1930.210 105.330 23/02/2025 03:30:00 1930.310 105.330 23/02/2025 04:00:00 1930.410 105.330 23/02/2025 04:30:00 1930.510 105.340 23/02/2025 05:00:00 1930.600 105.340 23/02/2025 05:30:00 1930.700 105.340 23/02/2025 06:00:00 1930.790 105.340 23/02/2025 06:30:00 1930.890 105.340 23/02/2025 07:00:00 1930.980 105.340 23/02/2025 07:30:00 1931.070 105.340 23/02/2025 08:00:00 1931.160 105.340 23/02/2025 08:30:00 1931.260 105.340 23/02/2025 09:00:00 1931.350 105.340 23/02/2025 09:30:00 1931.440 105.340 23/02/2025 10:00:00 1931.530 105.340 23/02/2025 10:30:00 1931.620 105.340 23/02/2025 11:00:00 1931.710 105.340 23/02/2025 11:30:00 1931.800 105.340 23/02/2025 12:00:00 1931.890 105.350 23/02/2025 12:30:00 1931.980 105.350 23/02/2025 13:00:00 1932.070 105.350 23/02/2025 13:30:00 1932.150 105.350 23/02/2025 14:00:00 1932.240 105.350 23/02/2025 14:30:00 1932.330 105.350 23/02/2025 15:00:00 1932.410 105.350 23/02/2025 15:30:00 1932.500 105.350 23/02/2025 16:00:00 1932.580 105.350 23/02/2025 16:30:00 1932.660 105.350 23/02/2025 17:00:00 1932.750 105.350 23/02/2025 17:30:00 1932.830 105.350 23/02/2025 18:00:00 1932.920 105.350 23/02/2025 18:30:00 1933.000 105.350 23/02/2025 19:00:00 1933.080 105.350 23/02/2025 19:30:00 1933.170 105.360 23/02/2025 20:00:00 1933.250 105.360 23/02/2025 20:30:00 1933.330 105.360 23/02/2025 21:00:00 1933.410 105.360 23/02/2025 21:30:00 1933.490 105.360 23/02/2025 22:00:00 1933.580 105.360 23/02/2025 22:30:00 1933.660 105.360 23/02/2025 23:00:00 1933.740 105.360 23/02/2025 23:30:00 1933.820 105.360 24/02/2025 00:00:00 1933.900 105.360 24/02/2025 00:30:00 1933.980 105.360 24/02/2025 01:00:00 1934.060 105.360 24/02/2025 01:30:00 1934.140 105.360 24/02/2025 02:00:00 1934.220 105.360 24/02/2025 02:30:00 1934.300 105.360 24/02/2025 03:00:00 1934.380 105.360 24/02/2025 03:30:00 1934.460 105.360 24/02/2025 04:00:00 1934.540 105.370 24/02/2025 04:30:00 1934.620 105.370 24/02/2025 05:00:00 1934.700 105.370 24/02/2025 05:30:00 1934.780 105.370 24/02/2025 06:00:00 1934.850 105.370 24/02/2025 06:30:00 1934.930 105.370 24/02/2025 07:00:00 1935.010 105.370 24/02/2025 07:30:00 1935.090 105.370 24/02/2025 08:00:00 1935.160 105.370 24/02/2025 08:30:00 1935.240 105.370 24/02/2025 09:00:00 1935.310 105.370 24/02/2025 09:30:00 1935.390 105.370 24/02/2025 10:00:00 1935.460 105.370 24/02/2025 10:30:00 1935.540 105.370 24/02/2025 11:00:00 1935.610 105.370 24/02/2025 11:30:00 1935.680 105.380 WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 65 Location / Field:Pikka Development / NDB Start Data:17-Feb-2025 @ 06:01 End Date:Present (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDB-025 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 24/02/2025 12:00:00 1935.750 105.380 24/02/2025 12:30:00 1935.830 105.380 24/02/2025 13:00:00 1935.900 105.380 24/02/2025 13:30:00 1935.97 105.38 24/02/2025 14:00:00 1936.04 105.38 24/02/2025 14:30:00 1936.11 105.38 24/02/2025 15:00:00 1936.19 105.38 24/02/2025 15:30:00 1936.26 105.38 24/02/2025 16:00:00 1936.33 105.38 24/02/2025 16:30:00 1936.39 105.38 24/02/2025 17:00:00 1936.46 105.38 24/02/2025 17:30:00 1936.53 105.38 24/02/2025 18:00:00 1936.60 105.38 24/02/2025 18:30:00 1936.67 105.38 24/02/2025 19:00:00 1936.74 105.38 24/02/2025 19:30:00 1936.81 105.38 24/02/2025 20:00:00 1936.87 105.38 24/02/2025 20:30:00 1936.94 105.38 24/02/2025 21:00:00 1937.01 105.38 24/02/2025 21:30:00 1937.07 105.39 24/02/2025 22:00:00 1937.14 105.39 24/02/2025 22:30:00 1937.21 105.39 24/02/2025 23:00:00 1937.27 105.39 24/02/2025 23:30:00 1937.34 105.39 25/02/2025 00:00:00 1937.41 105.39 WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 66 102.5103.0103.5104.0104.5105.0105.5106.016501700175018001850190019502000Pressure (psig)Bottom Hole Data_Build-up Period_NDB-025BHPBHTTemperature (°F) Santos – Pikka Development – NDB-025 SECTION 11 SEQUENCE OF OPERATIONS WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 68 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss 10/Feb/2025 07:20:00 10/Feb/2025 07:25:00 10/Feb/2025 07:28:00 10/Feb/2025 07:32:00 10/Feb/2025 07:32:00 10/Feb/2025 08:30:00 10/Feb/2025 08:35:00 10/Feb/2025 08:36:00 10/Feb/2025 08:40:00 10/Feb/2025 09:00:00 10/Feb/2025 09:00:00 10/Feb/2025 09:01:00 10/Feb/2025 09:30:00 10/Feb/2025 09:31:00 10/Feb/2025 10:00:00 10/Feb/2025 10:00:00 10/Feb/2025 10:06:00 10/Feb/2025 10:30:00 10/Feb/2025 10:30:00 10/Feb/2025 10:31:00 10/Feb/2025 11:00:00 10/Feb/2025 11:00:00 10/Feb/2025 11:01:00 10/Feb/2025 11:30:00 10/Feb/2025 11:30:00 10/Feb/2025 11:31:00 10/Feb/2025 11:59:00 10/Feb/2025 11:59:00 10/Feb/2025 12:00:00 10/Feb/2025 12:00:00 10/Feb/2025 12:00:00 10/Feb/2025 12:00:00 10/Feb/2025 12:00:00 10/Feb/2025 12:01:00 10/Feb/2025 12:01:00 10/Feb/2025 12:25:00 10/Feb/2025 12:30:00 10/Feb/2025 12:30:00 10/Feb/2025 12:30:00 10/Feb/2025 12:30:00 10/Feb/2025 12:31:00 10/Feb/2025 12:37:00 10/Feb/2025 12:39:00 10/Feb/2025 12:45:00 10/Feb/2025 12:55:00 10/Feb/2025 13:00:00 10/Feb/2025 13:00:00 10/Feb/2025 13:00:00 10/Feb/2025 13:01:00 10/Feb/2025 13:01:00 10/Feb/2025 13:01:00 10/Feb/2025 13:05:00 10/Feb/2025 13:30:00 10/Feb/2025 13:30:00 10/Feb/2025 13:31:00 10/Feb/2025 13:31:00 10/Feb/2025 13:45:00 10/Feb/2025 14:00:00 10/Feb/2025 14:00:00 10/Feb/2025 14:00:00 Walked the Line and Verified Valve Alignment as per Pre-Flow Checklist. SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 BS&W at Choke Manifold Showed 100% Diesel. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 100% dirty Diesel. Increased Expro adjustable Choke to 28/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. Reallocating WHT sensor. Initial Bottomhole Pressure 1991.2 PSI; Initial Bottomhole Temperature 105.06 degF; Initial SITHP 293.2 PSI. Opened Well on a 20/64ths adjustable Choke as per Santos WSS. Fluid received at Tank Farm manifold lined up to Tank 1. BS&W at Choke Manifold Showed 100% Diesel. Increased Expro adjustable Choke to 24/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. OPERATIONS NDB-025 - Well Clean-Up Flow Verified valve alignment. Line up to DPI, Choke to Tank Farm Tank #1. Bypassed Line Heater and Test Separator. Opened Master Valve = 24 turns. Opened Wellhead NDB-025 Production Wing Valve (PWV) 23.5 turns to closed Expro Choke Manifold. Commenced Liquid sampling . Diverted Flow from Tank 2 to Tank 1. Increased Expro adjustable Choke to 32/64ths as per Santos WSS. BS&W at Choke Manifold Showed 100% dirty Diesel. Oil to surface. Edgex PC down. Increased Expro adjustable Choke to 52/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. Diverted Gas flow rate from 0.5'' Coriolis meter to 3'' Coriolis meter Increased Expro adjustable Choke to 48/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. Gas S.G = 0.654 Applied CMF= 0.944 BS&W at Choke Manifold Showed 74.85% Water and 0.15% Solids. Dirty Diesel 25%. Increased Expro adjustable Choke to 44/64ths as per Santos WSS. Dumping gas from Separator to Flare. Metering Gas through 0.5" Coriolis. Cumulative Volumes 128 bbls Diesel, 60.29 bbls Water and 0.18 bbls Solids was entered into the DAQ software to account for rates. Began dumping Fluid from Separator. Metering through 2" Line (1.5" Turbine Meter). BS&W at Choke Manifold Showed 63.85% Water and 0.15% Solids. Dirty Diesel 36%. Water Salinity 40000 ppm; Water pH 7, Water Weight 8.49 ppg. Increased Expro adjustable Choke to 36/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 100% dirty Diesel. Upstream DPI BS&W Sample Showed trace of Sediments. Edgex PC down. Diverted Flow from Tank 2 to Tank 1. Increased Expro adjustable Choke to 40/64ths as per Santos WSS. BS&W at Choke Manifold Showed 48.75% Water and 0.25% Solids. Dirty Diesel 51%. Flare lit. Diverted Flow through testing separator. Diverted Flow from Tank 1 to Tank 2. Diverted Flow from Tank 3 to Tank 4. Dumped DPI unit side A &. Observed trace of Solids. Increased Expro adjustable Choke to 56/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 0.4% Water and 0.1% Solids. Oil 99.5%. Oil API 29.6 @ 60F (Oil SG 0.878) Edgex PC down. Increased Expro adjustable Choke to 60/64ths as per Santos WSS. Commenced chemical injection of methanol,demulsifier and defoamer. @ 8 gal/day BS&W at Choke Manifold Showed 5.90% Water and 0.1% Solids. Oil 94%. Water Salinity 38000 ppm; Water pH 7, Water Weight 8.48 ppg. H2S 0 ppm. CO2 0.1%. Diverted liquid flow from 1.5'' turbine meter to 2'' turbine meter . WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 69 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 10/Feb/2025 14:01:00 10/Feb/2025 14:07:00 10/Feb/2025 14:30:00 10/Feb/2025 14:30:00 10/Feb/2025 14:31:00 10/Feb/2025 14:31:00 10/Feb/2025 14:43:00 10/Feb/2025 15:00:00 10/Feb/2025 15:00:00 10/Feb/2025 15:01:00 10/Feb/2025 15:01:00 10/Feb/2025 15:18:00 10/Feb/2025 15:28:00 10/Feb/2025 15:30:00 10/Feb/2025 15:31:00 10/Feb/2025 15:31:00 10/Feb/2025 15:31:00 10/Feb/2025 15:55:00 10/Feb/2025 16:00:00 10/Feb/2025 16:01:00 10/Feb/2025 16:01:00 10/Feb/2025 16:02:00 10/Feb/2025 16:12:00 10/Feb/2025 16:30:00 10/Feb/2025 16:31:00 10/Feb/2025 17:00:00 10/Feb/2025 17:01:00 10/Feb/2025 17:05:00 10/Feb/2025 17:30:00 10/Feb/2025 17:31:00 10/Feb/2025 18:00:00 10/Feb/2025 18:01:00 10/Feb/2025 19:07:00 10/Feb/2025 19:30:00 10/Feb/2025 19:30:00 10/Feb/2025 19:31:00 10/Feb/2025 19:31:00 10/Feb/2025 20:00:00 10/Feb/2025 20:00:00 10/Feb/2025 20:00:00 10/Feb/2025 20:00:00 10/Feb/2025 20:01:00 10/Feb/2025 20:03:00 10/Feb/2025 20:30:00 10/Feb/2025 20:30:00 10/Feb/2025 20:31:00 10/Feb/2025 20:49:00 10/Feb/2025 21:00:00 10/Feb/2025 21:00:00 10/Feb/2025 21:00:00 10/Feb/2025 21:01:00 10/Feb/2025 21:30:00 10/Feb/2025 21:30:00 10/Feb/2025 21:31:00 10/Feb/2025 22:00:00 10/Feb/2025 22:00:00 10/Feb/2025 22:00:00 10/Feb/2025 22:00:00 10/Feb/2025 22:01:00 10/Feb/2025 22:30:00 10/Feb/2025 22:30:00 BS&W at Choke Manifold Showed 0.9% Water and 0.1% Solids. Oil 99%. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 4 to Tank 3. Increased Expro adjustable Choke to 64/64ths as per Santos WSS. Gas S.G = 0.662 Dumped DPI unit side A &. Observed trace of Solids. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 4.90% Water and 0.1% Solids. Oil 95%. Water Salinity 38000 ppm; Water pH 7, Water Weight 8.48 ppg. Upstream DPI BS&W Sample Showed trace of Sediments. H2S 0 ppm. CO2 0.1%. Vac truck disconnected from tank 2 and lined up to tank 1. Vac truck disconnected from tank 1. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 5.75% Water and 0.25% Solids. Oil 94%. Oil API 29.8 @ 60F (Oil SG 0.877) BS&W at Choke Manifold Showed 3.9% Water and 0.1% Solids. Oil 96%. Upstream DPI BS&W Sample Showed trace of Sediments. Vac truck # 82310 lined up to tank 2, RVP=6 Diverted Flow from Tank 3 to Tank 4. Water Salinity 38000 ppm; Water pH 7, Water Weight 8.48 ppg. BS&W at Choke Manifold Showed 4.85% Water and 0.15% Solids. Oil 95%. BS&W at Choke Manifold Showed 15.65% Water and 0.35% Solids. Oil 84%. NDBi-014 Injection Rate 3.01 bpm; Injection Cumulative 27.91 bbls. Increased Expro adjustable Choke to 88/64ths as per Santos WSS. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 7 to Tank 8. Diverted Flow from Tank 6 to Tank 2. BS&W at Choke Manifold Showed 10.90% Water and 0.10% Solids. Oil 89%. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 14.90% Water and 0.1% Solids. Oil 85%. Increased Expro adjustable Choke to 80/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 7. Vac truck # 82322 lined up to tank 1,3 RVP=6 Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 11.8% Water and 0.2% Solids. Oil 88%. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 5.85% Water and 0.15% Solids. Oil 94%. Vac truck disconnected from tank 1,3. Commenced NDBi-014 Injection. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 23.95% Water and 0.05% Solids. Oil 76%. Increased Expro adjustable Choke to 120/64ths as per Santos WSS. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 9 to Tank 10. Dumped DPI unit side A & B. Observed light trace of frac sand. Side B observed trace of frac sand. Shut down injection to switch out the turbine meter Increased Expro adjustable Choke to 102/64ths as per Santos WSS. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 17.95% Water and 0.05% Solids. Oil 82%. Increased Expro adjustable Choke to 110/64ths as per Santos WSS. BS&W at Choke Manifold Showed 11.95% Water and 0.05% Solids. Oil 88%. Dumped DPI unit side A & B. Observed light trace of frac sand. Side B observed trace of frac sand. BS&W at Choke Manifold Showed 21.95% Water and 0.05% Solids. Oil 78%. NDBi-014 Injection Rate 2.98 bpm; Injection Cumulative 124.09 bbls. Increased Expro adjustable Choke to 96/64ths as per Santos WSS. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 19.90% Water and 0.1% Solids. Oil 80%. Diverted Flow from Tank 10 to Tank 9. NDBi-014 Injection Rate 3.48 bpm; Injection Cumulative 478.89 bbls. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 70 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 10/Feb/2025 22:31:00 10/Feb/2025 23:00:00 10/Feb/2025 23:00:00 10/Feb/2025 23:01:00 10/Feb/2025 23:04:00 10/Feb/2025 23:30:00 10/Feb/2025 23:30:00 10/Feb/2025 23:31:00 11/Feb/2025 00:00:00 11/Feb/2025 00:00:00 11/Feb/2025 00:00:00 11/Feb/2025 00:00:00 11/Feb/2025 00:01:00 11/Feb/2025 00:30:00 11/Feb/2025 00:31:00 11/Feb/2025 01:00:00 11/Feb/2025 01:00:00 11/Feb/2025 01:00:00 11/Feb/2025 01:01:00 11/Feb/2025 01:04:00 11/Feb/2025 01:30:00 11/Feb/2025 01:31:00 11/Feb/2025 02:00:00 11/Feb/2025 02:00:00 11/Feb/2025 02:01:00 11/Feb/2025 02:30:00 11/Feb/2025 02:30:00 11/Feb/2025 02:31:00 11/Feb/2025 02:57:00 11/Feb/2025 03:00:00 11/Feb/2025 03:01:00 11/Feb/2025 03:30:00 11/Feb/2025 03:30:00 11/Feb/2025 04:00:00 11/Feb/2025 04:00:00 11/Feb/2025 04:00:00 11/Feb/2025 04:30:00 11/Feb/2025 04:30:00 11/Feb/2025 04:31:00 11/Feb/2025 05:00:00 11/Feb/2025 05:00:00 11/Feb/2025 05:05:00 11/Feb/2025 05:11:00 11/Feb/2025 05:17:00 11/Feb/2025 05:21:00 11/Feb/2025 05:27:00 11/Feb/2025 05:30:00 11/Feb/2025 05:30:00 11/Feb/2025 05:55:00 11/Feb/2025 06:00:00 11/Feb/2025 06:00:00 11/Feb/2025 06:00:00 11/Feb/2025 06:20:00 11/Feb/2025 06:21:00 11/Feb/2025 06:26:00 11/Feb/2025 06:30:00 11/Feb/2025 06:31:00 11/Feb/2025 06:45:00 11/Feb/2025 06:51:00 11/Feb/2025 07:00:00 11/Feb/2025 07:01:00 BS&W at Choke Manifold Showed 17.95% Water and 0.05% Solids. Oil 82%. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 15.975% Water and 0.025% Solids. Oil 84%. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 4 to Tank 7. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 14% Water and 0% Solids. Oil 86%. Diverted Flow from Tank 4 to Tank 3. NDBi-014 Injection Rate 3.42 bpm; Injection Cumulative 492.50 bbls. BS&W at Choke Manifold Showed 17.975% Water and 0.025% Solids. Oil 82%. Upstream DPI BS&W Sample Showed trace of Sediments. Dumped DPI unit side A & B. Observed light trace of frac sand. Side B observed trace of frac sand. BS&W at Choke Manifold Showed 15.95% Water and 0.05% Solids. Oil 84%. NDBi-014 Injection Rate 3.48 bpm; Injection Cumulative 200.11 bbls. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 14% Water and 0% Solids. Oil 86%. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 8 to Tank 9. Increased Expro adjustable Choke to 78/64ths as per Santos WSS. Diverted Flow from Tank 9 to Tank 8. Sparged Expro separator , Observed light trace of sand. Collected Tracerco sample. NDBi-014 Injection Rate 3.70 bpm; Injection Cumulative 1031.55 bbls. Shut in well at SSV Opened well on adjustable Choke to 30/64ths as per Santos WSS. NDBi-014 Injection Rate 3.69 bpm; Injection Cumulative 1363.73 bbls. Increased Expro adjustable Choke to 120/64ths as per Santos WSS. LRS down on pump. total volume injected 786 bbls. Collected Tracerco sample. BS&W at Choke Manifold Showed 9.95% Water and 0.05% Solids. Oil 90%. Diverted Flow from Tank 2 to Tank 1. Diverted Flow from Tank 1 to Tank 2. Diverted Flow from Tank 10 to Tank 1. NDBi-014 Injection Rate 3.48 bpm; Injection Cumulative 686.64 bbls. BS&W at Choke Manifold Showed 9.95% Water and 0.05% Solids. Oil 90%. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 1 to Tank 2. Upstream DPI BS&W Sample Showed trace of Sediments. BS&W at Choke Manifold Showed 15.95% Water and 0.05% Solids. Oil 84%. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 15.95% Water and 0.05% Solids. Oil 84%. Applied CMSF = 0.90 Edgex server down recalculated vol cums and Updated system.. Increased Expro adjustable Choke to 64/64ths as per Santos WSS. Upstream DPI BS&W Sample Showed trace of Sediments. Increased Expro adjustable Choke to 68/64ths as per Santos WSS. Diverted Flow from Tank 7 to Tank 8. NDBi-014 Injection Rate 3.7 bpm; Injection Cumulative 813.53 bbls. Upstream DPI BS&W Sample Showed trace of Sediments. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 15.95% Water and 0.05% Solids. Oil 82%. Diverted Flow from Tank 7 to Tank 8. Dumped DPI unit side A & B. Observed trace of frac sand. Side B observed trace of frac sand. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Increased Expro adjustable Choke to 108/64ths as per Santos WSS. Dumped DPI unit side A &. Observed trace of Solids. Side B observed light solids Increased Expro adjustable Choke to 114/64ths as per Santos WSS. Diverted Flow from Tank 8 to Tank 9. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 71 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 11/Feb/2025 07:05:00 11/Feb/2025 07:18:00 11/Feb/2025 07:29:00 11/Feb/2025 07:30:00 11/Feb/2025 07:31:00 11/Feb/2025 07:35:00 11/Feb/2025 07:49:00 11/Feb/2025 08:00:00 11/Feb/2025 08:00:00 11/Feb/2025 08:01:00 11/Feb/2025 08:21:00 11/Feb/2025 08:30:00 11/Feb/2025 08:30:00 11/Feb/2025 08:31:00 11/Feb/2025 08:32:00 11/Feb/2025 08:45:00 11/Feb/2025 09:00:00 11/Feb/2025 09:01:00 11/Feb/2025 09:01:00 11/Feb/2025 09:01:00 11/Feb/2025 09:01:00 11/Feb/2025 09:01:00 11/Feb/2025 09:01:00 11/Feb/2025 09:08:00 11/Feb/2025 09:30:00 11/Feb/2025 09:30:00 11/Feb/2025 09:31:00 11/Feb/2025 09:34:00 11/Feb/2025 09:53:00 11/Feb/2025 10:00:00 11/Feb/2025 10:01:00 11/Feb/2025 10:23:00 11/Feb/2025 10:30:00 11/Feb/2025 10:31:00 11/Feb/2025 10:55:00 11/Feb/2025 11:00:00 11/Feb/2025 11:01:00 11/Feb/2025 11:01:00 11/Feb/2025 11:01:00 11/Feb/2025 11:02:00 11/Feb/2025 11:03:00 11/Feb/2025 11:11:00 11/Feb/2025 11:30:00 11/Feb/2025 11:30:00 11/Feb/2025 11:31:00 11/Feb/2025 11:31:00 11/Feb/2025 11:33:00 11/Feb/2025 12:00:00 11/Feb/2025 12:00:00 11/Feb/2025 12:01:00 11/Feb/2025 12:01:00 11/Feb/2025 12:03:00 11/Feb/2025 12:05:00 11/Feb/2025 12:30:00 11/Feb/2025 12:31:00 11/Feb/2025 12:46:00 11/Feb/2025 12:47:00 11/Feb/2025 12:48:00 11/Feb/2025 13:00:00 11/Feb/2025 13:00:00 11/Feb/2025 13:01:00 Diverted Flow from Tank 2 to Tank 3. Sparged Expro separator , Observed light trace of sand. BS&W at Choke Manifold Showed 16% Water and. Oil 84%. Dumped DPI unit side A &. Observed light sand on both sides. Dumped DPI unit side A & B. Observed trace of frac sand. Side B observed trace of frac sand. Sparged Expro separator , Observed light trace of sand. Dumped DPI unit side A & B. Observed trace of frac sand. Side B observed moderate frac sand. Diverted Flow from Tank 1 to Tank 2. NDBi-014 Injection Rate 3.66 bpm; Injection Cumulative 1695.98 bbls. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Dumped DPI unit side A & B. Observed light trace of frac sand. Side B observed trace of frac sand. Dumped DPI unit side A &. Observed moderate sand on both sides. Diverted Flow from Tank 10 to Tank 1. BS&W at Choke Manifold Showed 16% Water and. Oil 84%. Added tank7 and tank 8 to injection into injection well NDBi-014 Dumped DPI unit side A &. Observed moderate sand on both sides. BS&W at Choke Manifold Showed 18% Water and. Oil 82%. Dumped DPI unit side A & B. Observed light sand on both sides. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Acccuired Flare heat index Diverted Flow from Tank 5 to Tank 6. Added Tank 9 and Tank 10 into NDB-014 Injection and Removed Tank 7 and Tank 8. Diverted Flow from Tank 4 to Tank 3. NDBi-014 Injection Rate 3.63 bpm; Injection Cumulative 2024.47 bbls. BS&W at Choke Manifold Showed 17% Water and. Oil 83%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 3 to Tank 4. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 18% Water and. Oil 82%. Oil API 29.6 @ 60F (Oil SG 0.878) Upstream DPI BS&W Sample Showed 0.25% carbolites. H2S 0 ppm. CO2 0.1%. Water Salinity 34000 ppm; Water pH 7, Water Weight 8.45 ppg. Gas S.G = 0.707 Dumped DPI unit side A & B. Observed light sand on both sides. Gas scrubber is dry. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 15% Water and. Oil 85%. Observed well slugging Upstream DPI BS&W Sample Showed traces of solids. Dumped DPI unit side A & B. Observed trace of solids both sides. Diverted Flow from Tank 7 to Tank 8. Collected Tracerco sample. BS&W at Choke Manifold Showed 17% Water and. Oil 83%. Water Salinity 32000 ppm; Water pH 7, Water Weight 8.44 ppg. Diverted Flow from Tank 6 to Tank 7. NDBi-014 Injection Rate 3.60 bpm; Injection Cumulative 2459.72 bbls. BS&W at Choke Manifold Showed 18% Water and. Oil 82%. BS&W at Choke Manifold Showed 16% Water and. Oil 84%. Water Salinity 32000 ppm; Water pH 7, Water Weight 8.45 ppg. Upstream DPI BS&W Sample Showed 0.2% solids. Sparged Expro separator , Observed light trace of sand. Dumped DPI unit side A & B. Observed trace of solids both sides. Added Tank 1 and Tank 2 into NDB-014 Injection and Removed Tank 9 and Tank 10. Added Tank 3 and Tank 4 into NDB-014 Injection and Removed Tank 1 and Tank 2. Dumped DPI unit side A & B. Observed trace of solids both sides. Diverted Flow from Tank 7 to Tank 8. Collected corelab sample. BS&W at Choke Manifold Showed 17% Water and. Oil 83%. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 72 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 11/Feb/2025 13:18:00 11/Feb/2025 13:21:00 11/Feb/2025 13:30:00 11/Feb/2025 13:30:00 11/Feb/2025 13:31:00 11/Feb/2025 13:47:00 11/Feb/2025 14:00:00 11/Feb/2025 14:01:00 11/Feb/2025 14:18:00 11/Feb/2025 14:21:00 11/Feb/2025 14:30:00 11/Feb/2025 14:30:00 11/Feb/2025 14:31:00 11/Feb/2025 15:00:00 11/Feb/2025 15:00:00 11/Feb/2025 15:01:00 11/Feb/2025 15:01:00 11/Feb/2025 15:01:00 11/Feb/2025 15:01:00 11/Feb/2025 15:01:00 11/Feb/2025 15:17:00 11/Feb/2025 15:18:00 11/Feb/2025 15:21:00 11/Feb/2025 15:30:00 11/Feb/2025 15:30:00 11/Feb/2025 15:31:00 11/Feb/2025 15:31:00 11/Feb/2025 16:00:00 11/Feb/2025 16:01:00 11/Feb/2025 16:01:00 11/Feb/2025 16:07:00 11/Feb/2025 16:16:00 11/Feb/2025 16:30:00 11/Feb/2025 16:31:00 11/Feb/2025 17:00:00 11/Feb/2025 17:01:00 11/Feb/2025 17:16:00 11/Feb/2025 17:30:00 11/Feb/2025 17:30:00 11/Feb/2025 17:31:00 11/Feb/2025 17:50:00 11/Feb/2025 18:00:00 11/Feb/2025 18:05:00 11/Feb/2025 18:30:00 11/Feb/2025 18:31:00 11/Feb/2025 19:00:00 11/Feb/2025 19:00:00 11/Feb/2025 19:01:00 11/Feb/2025 19:11:00 11/Feb/2025 19:26:00 11/Feb/2025 19:30:00 11/Feb/2025 19:31:00 11/Feb/2025 20:00:00 11/Feb/2025 20:01:00 11/Feb/2025 20:05:00 11/Feb/2025 20:25:00 11/Feb/2025 20:30:00 11/Feb/2025 20:31:00 11/Feb/2025 21:00:00 11/Feb/2025 21:01:00 11/Feb/2025 21:01:00 BS&W at Choke Manifold Showed 13% Water and. Oil 87%. Sparged Expro separator , Observed light trace of sand. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 10 to Tank 9. NDBi-014 Injection Rate 3.59 bpm; Injection Cumulative 3109.96 bbls. Vac truck # 86073 lined up to tank 7, RVP=5. Diverted Flow from Tank 8 to Tank 9. NDBi-014 Injection Rate 3.61 bpm; Injection Cumulative 2926.94 bbls. BS&W at Choke Manifold Showed 16% Water and. Oil 84%. Dumped DPI unit side A & B. Observed lmoderate solids. Side B observed light solids. Diverted Flow from Tank 9 to Tank 10. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Applied CMSF= 0.93 BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Upstream DPI BS&W Sample Showed traces of solids. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Upstream DPI BS&W Sample Showed 0.15% solids. Water Salinity 32000 ppm; Water pH 7, Water Weight 8.45 ppg. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Added Tank 5 and Tank 6 into NDB-014 Injection and Removed Tank 3 and Tank 4. Dumped DPI unit side A & B. Observed lmoderate solids. Side B observed light solids. Vac truck # 86073 lined up to tank 7, RVP=5. Diverted Flow from Tank 10 to Tank 1. BS&W at Choke Manifold Showed 15% Water and. Oil 85%. Diverted Flow from Tank 9 to Tank 10. Diverted Flow from Tank 9 to Tank 10. Gas S.G = 0.707 H2S 0 ppm. CO2 0.1%. Oil API 29.3 @ 60F (Oil SG 0.880) BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Added Tank 1 and Tank 2 into NDB-014 Injection Dumped DPI unit side A & B. Observed lmoderate solids. Side B observed light solids. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 15.95% Water and 0.05% Solids. Oil 84%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 3 to Tank 4. Dumped DPI unit side A & B. Observed lmoderate solids. Side B observed trace solids. Diverted Flow from Tank 2 to Tank 3. NDBi-014 Injection Rate 3.59 bpm; Injection Cumulative 3756.17 bbls. BS&W at Choke Manifold Showed 11% Water and. Oil 89%. Sparged Expro separator , Observed light trace of sand. Diverted Flow from Tank 3 to Tank 4. Vac truck # 86073 disconnected from tank 7 Dumped DPI unit side A & B. Observed lmoderate solids. Side B observed light solids. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Vac truck # 82310 disconnected from tank 8 Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Oil API 28 @ 60F (Oil SG 0.887) Vac truck # 82310 lined up to tank 8, RVP=5. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 13% Water and. Oil 87%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 73 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 11/Feb/2025 21:01:00 11/Feb/2025 21:01:00 11/Feb/2025 21:01:00 11/Feb/2025 21:02:00 11/Feb/2025 21:05:00 11/Feb/2025 21:30:00 11/Feb/2025 21:30:00 11/Feb/2025 21:30:00 11/Feb/2025 21:31:00 11/Feb/2025 22:00:00 11/Feb/2025 22:00:00 11/Feb/2025 22:01:00 11/Feb/2025 22:02:00 Dumped DPI unit side A & B Dumped DPI unit Dumped DPI unit side A & B. Observed light solids Side B 11/Feb/2025 22:30:00 11/Feb/2025 22:30:00 11/Feb/2025 22:31:00 11/Feb/2025 23:00:00 11/Feb/2025 23:01:00 11/Feb/2025 23:02:00 11/Feb/2025 23:03:00 11/Feb/2025 23:27:00 11/Feb/2025 23:27:00 11/Feb/2025 23:28:00 11/Feb/2025 23:28:00 11/Feb/2025 23:28:00 11/Feb/2025 23:30:00 11/Feb/2025 23:30:00 11/Feb/2025 23:31:00 11/Feb/2025 23:35:00 11/Feb/2025 23:40:00 11/Feb/2025 23:45:00 11/Feb/2025 23:50:00 12/Feb/2025 00:00:00 12/Feb/2025 00:00:00 12/Feb/2025 00:00:00 12/Feb/2025 00:00:00 12/Feb/2025 00:01:00 12/Feb/2025 00:03:00 12/Feb/2025 00:05:00 12/Feb/2025 00:10:00 12/Feb/2025 00:15:00 12/Feb/2025 00:15:00 12/Feb/2025 00:15:00 12/Feb/2025 00:20:00 12/Feb/2025 00:25:00 12/Feb/2025 00:25:00 12/Feb/2025 00:29:00 12/Feb/2025 00:30:00 12/Feb/2025 00:30:00 12/Feb/2025 00:31:00 12/Feb/2025 00:35:00 12/Feb/2025 00:40:00 12/Feb/2025 00:45:00 12/Feb/2025 00:50:00 12/Feb/2025 00:55:00 12/Feb/2025 01:00:00 12/Feb/2025 01:00:00 12/Feb/2025 01:01:00 12/Feb/2025 01:30:00 12/Feb/2025 01:31:00 12/Feb/2025 01:42:00 H2S 0 ppm. CO2 0.1%. Gas S.G = 0.708 Water Salinity 32000 ppm; Water pH 7, Water Weight 8.43 ppg. Sparged Expro separator , Observed light trace of sand. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 6 to Tank 7. Removed Tank 1 and Tank 2 from Injection Well shut in at SSV Opened well on a 32/64ths Removed Tank 3 and Tank 4 from Injection Added Tank 5 and Tank 6 into NDB-014 Injection Slowly increased to a 60/64ths Increased Expro adjustable Choke to 64/64ths as per Santos WSS. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Observed well slugging Added Tank 3 and Tank 4 into NDB-014 Injection BS&W at Choke Manifold Showed 14% Water and. Oil 86%. NDBi-014 Injection Rate 3.6 bpm; Injection Cumulative 4853.66 bbls. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Applied CMSF= 0.947 Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Increased Expro adjustable Choke to 88/64ths as per Santos WSS. Increased Expro adjustable Choke to 92/64ths as per Santos WSS. Increased Expro adjustable Choke to 96/64ths as per Santos WSS. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. LRS commenced injecting Increased Expro adjustable Choke to 80/64ths as per Santos WSS. Increased Expro adjustable Choke to 84/64ths as per Santos WSS. LRS stopped injection Collected Tracerco sample. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Increased Expro adjustable Choke to 68/64ths as per Santos WSS. Increased Expro adjustable Choke to 72/64ths as per Santos WSS. Increased Expro adjustable Choke to 76/64ths as per Santos WSS. Increased Expro adjustable Choke to 128/64ths as per Santos WSS. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 14% Water and. Oil 86%. Diverted Flow from Tank 10 to Tank 1. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Increased Expro adjustable Choke to 112/64ths as per Santos WSS. Increased Expro adjustable Choke to 116/64ths as per Santos WSS. Increased Expro adjustable Choke to 120/64ths as per Santos WSS. Increased Expro adjustable Choke to 124/64ths as per Santos WSS. Increased Expro adjustable Choke to 100/64ths as per Santos WSS. Increased Expro adjustable Choke to 104/64ths as per Santos WSS. Observed well slugging Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Increased Expro adjustable Choke to 108/64ths as per Santos WSS. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Added Tank 7 and Tank 8 into NDB-014 Injection WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 74 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 12/Feb/2025 01:43:00 12/Feb/2025 02:00:00 12/Feb/2025 02:01:00 12/Feb/2025 02:04:00 12/Feb/2025 02:30:00 12/Feb/2025 02:30:00 12/Feb/2025 02:31:00 12/Feb/2025 03:00:00 12/Feb/2025 03:00:00 12/Feb/2025 03:00:00 12/Feb/2025 03:00:00 12/Feb/2025 03:00:00 12/Feb/2025 03:01:00 12/Feb/2025 03:09:00 12/Feb/2025 03:16:00 12/Feb/2025 03:16:00 12/Feb/2025 03:30:00 12/Feb/2025 03:31:00 12/Feb/2025 04:00:00 12/Feb/2025 04:01:00 12/Feb/2025 04:05:00 12/Feb/2025 04:30:00 12/Feb/2025 04:31:00 12/Feb/2025 05:00:00 12/Feb/2025 05:01:00 12/Feb/2025 05:06:00 12/Feb/2025 05:16:00 12/Feb/2025 05:17:00 12/Feb/2025 05:30:00 12/Feb/2025 05:31:00 12/Feb/2025 05:47:00 12/Feb/2025 06:00:00 12/Feb/2025 06:00:00 12/Feb/2025 06:01:00 12/Feb/2025 06:01:00 12/Feb/2025 06:04:00 12/Feb/2025 06:30:00 12/Feb/2025 06:31:00 12/Feb/2025 06:49:00 12/Feb/2025 07:00:00 12/Feb/2025 07:00:00 12/Feb/2025 07:01:00 12/Feb/2025 07:01:00 12/Feb/2025 07:17:00 12/Feb/2025 07:25:00 12/Feb/2025 07:30:00 12/Feb/2025 07:31:00 12/Feb/2025 07:31:00 12/Feb/2025 07:49:00 12/Feb/2025 08:00:00 12/Feb/2025 08:01:00 12/Feb/2025 08:30:00 12/Feb/2025 08:31:00 12/Feb/2025 08:31:00 12/Feb/2025 08:36:00 12/Feb/2025 08:52:00 12/Feb/2025 09:00:00 12/Feb/2025 09:01:00 12/Feb/2025 09:01:00 12/Feb/2025 09:01:00 12/Feb/2025 09:01:00 H2S 0 ppm. CO2 0.1%. Gas S.G = 0.706 Water Salinity 29000 ppm; Water pH 7, Water Weight 8.43 ppg. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. NDBi-014 Injection Rate 3.6 bpm; Injection Cumulative 5743.78 bbls. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Oil API 29.8 @ 60F (Oil SG 0.887) Removed Tank 5 and Tank 6 from Injection Diverted Flow from Tank 1 to Tank 2. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Added Tank 1 and Tank 2 into NDB-014 Injection Removed Tank 9 and Tank 10 from Injection Diverted Flow from Tank 5 to Tank 6. Diverted Flow from Tank 3 to Tank 5. BS&W at Choke Manifold Showed 11% Water and. Oil 89%. Dumped DPI unit side A & B. Observed light solids. Side B observed light of solids. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Dumped DPI unit side A & B. Observed light solids. Side B observed trace of solids. Removed Tank 7 and Tank 8 from Injection Added Tank 9 and Tank 10 into NDB-014 Injection Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 11% Water and. Oil 89%. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.45 ppg. Added Tank 5 and Tank 6 into NDB-014 Injection and removed Tank 1 and Tank 2. Added Tank 4 to NDB-014 injection. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Upstream DPI BS&W Sample Showed 0.2% solids. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Dumped DPI unit side A & B. Observed lmoderate solids. Side B observed trace solids. Diverted Flow from Tank 6 to Tank 7. NDBi-014 Injection Rate 3.8 bpm; Injection Cumulative 6777.11 bbls. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Diverted Flow from Tank 6 to Tank 5. Collected Tracerco sample. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.45 ppg. Gas scrubber is dry. H2S 0 ppm. CO2 0.1%. Oil API 29.3 @ 60F (Oil SG 0.880) Upstream DPI BS&W Sample Showed 0.1% solids. Removed Tank 4 from NDB-014 injection. Dumped DPI unit side A & B. Observed heavy solids. Side B observed moderate solids. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Gas S.G = 0.707 Dumped DPI unit side A & B. Observed heavy solids. Side B observed light solids. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 9% Water and. Oil 91%. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 11% Water and. Oil 89%. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 75 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 12/Feb/2025 09:01:00 12/Feb/2025 09:05:00 12/Feb/2025 09:17:00 12/Feb/2025 09:30:00 12/Feb/2025 09:31:00 12/Feb/2025 09:34:00 12/Feb/2025 09:37:00 12/Feb/2025 09:48:00 12/Feb/2025 09:59:00 12/Feb/2025 10:00:00 12/Feb/2025 10:01:00 12/Feb/2025 10:07:00 12/Feb/2025 10:20:00 12/Feb/2025 10:22:00 12/Feb/2025 10:30:00 12/Feb/2025 10:31:00 12/Feb/2025 10:31:00 12/Feb/2025 10:38:00 12/Feb/2025 10:52:00 12/Feb/2025 11:00:00 12/Feb/2025 11:00:00 12/Feb/2025 11:00:00 12/Feb/2025 11:00:00 12/Feb/2025 11:01:00 12/Feb/2025 11:01:00 12/Feb/2025 11:08:00 12/Feb/2025 11:23:00 12/Feb/2025 11:30:00 12/Feb/2025 11:31:00 12/Feb/2025 11:31:00 12/Feb/2025 11:38:00 12/Feb/2025 11:48:00 12/Feb/2025 12:00:00 12/Feb/2025 12:00:00 12/Feb/2025 12:00:00 12/Feb/2025 12:01:00 12/Feb/2025 12:01:00 12/Feb/2025 12:02:00 12/Feb/2025 12:02:00 12/Feb/2025 12:08:00 12/Feb/2025 12:30:00 12/Feb/2025 12:30:00 12/Feb/2025 12:31:00 12/Feb/2025 12:37:00 12/Feb/2025 13:00:00 12/Feb/2025 13:01:00 12/Feb/2025 13:02:00 12/Feb/2025 13:03:00 12/Feb/2025 13:30:00 12/Feb/2025 13:31:00 12/Feb/2025 13:39:00 12/Feb/2025 14:00:00 12/Feb/2025 14:01:00 12/Feb/2025 14:01:00 12/Feb/2025 14:04:00 12/Feb/2025 14:06:00 12/Feb/2025 14:12:00 12/Feb/2025 14:30:00 12/Feb/2025 14:31:00 12/Feb/2025 14:36:00 12/Feb/2025 15:00:00 Water Salinity 28000 ppm; Water pH 7, Water Weight 8.44 ppg. Dumped DPI unit side A & B. Heavy solids. Side B observed light solids. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Upstream DPI BS&W Sample Showed 0.1% solids. Dumped DPI unit side A & B. moderate solids. Side B observed light solids. Dumped DPI unit side A & B. Observed heavy solids. Side B observed moderate solids. Switching to 15 minutes dumping. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Acquired Flare heat index Dumped DPI unit side A & B. moderate solids. Side B observed trace solids. Gas scrubber is dry. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Dumped DPI unit side A & B. moderate solids. Side B observed trace solids. Observed well slugging Sparged Expro separator , Observed light trace of sand. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Dumped DPI unit side A & B. Observed moderate solids. Side B observed moderate solids. Added Tank 7 and Tank 8 into NDB-014 Injection and removed Tank 5 and Tank 6. Dumped DPI unit side A & B. Observed moderate solids. Side B observed trace solids. Upstream DPI BS&W Sample Showed 0.1% solids. Dumped DPI unit side A & B. moderate carbolites. Side B observed light carbolites. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 1 to Tank 2. Collected Tracerco sample. Diverted Flow from Tank 10 to Tank 4. Sparged Expro separator , Observed light trace of sand. Obtained and applied CMF for Injection flow meter based on tank volumes = 0.925 NDBi-014 Injection Rate 3.82 bpm; Injection Cumulative 7690.37 bbls. BS&W at Choke Manifold Showed 9% Water and. Oil 91%. Applied CMSF= 0.919 Upstream DPI BS&W Sample Showed traces of solids. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Dumped DPI unit side A & B. moderate solids. Side B observed trace solids. Diverted Flow from Tank 4 to Tank 1. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Sparged Expro separator , Observed trace of solids. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 2 to Tank 5. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 5 to Tank 6. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 12% Water and. Oil 99%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 9% Water and. Oil 91%. Upstream DPI BS&W Sample Showed traces of solids. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Gas scrubber is dry. Added Tank 9 and Tank 10 into NDB-014 Injection and removed Tank 7 and Tank 8. Flare Drain was free of Fluid. Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Dumped DPI unit side A & B. moderate carbolites. Side B observed trace carbolites. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 9% Water and. Oil 91%. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.45 ppg. Added Tank 3 and Tank 4 into NDB-014 Injection and removed Tank 9 and Tank 10. Dumped DPI unit side A & B. tace carbolites. Side B observed trace carbolites. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 76 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 12/Feb/2025 15:30:00 12/Feb/2025 15:31:00 12/Feb/2025 15:36:00 12/Feb/2025 16:00:00 12/Feb/2025 16:01:00 12/Feb/2025 16:01:00 12/Feb/2025 16:05:00 12/Feb/2025 16:25:00 12/Feb/2025 16:30:00 12/Feb/2025 16:31:00 12/Feb/2025 16:31:00 12/Feb/2025 16:39:00 12/Feb/2025 17:00:00 12/Feb/2025 17:01:00 12/Feb/2025 17:01:00 12/Feb/2025 17:01:00 12/Feb/2025 17:30:00 12/Feb/2025 17:30:00 12/Feb/2025 17:31:00 12/Feb/2025 17:40:00 12/Feb/2025 18:00:00 12/Feb/2025 18:01:00 12/Feb/2025 18:30:00 12/Feb/2025 18:31:00 12/Feb/2025 18:40:00 12/Feb/2025 18:40:00 12/Feb/2025 19:00:00 12/Feb/2025 19:01:00 12/Feb/2025 19:30:00 12/Feb/2025 19:30:00 12/Feb/2025 19:31:00 12/Feb/2025 19:39:00 12/Feb/2025 20:00:00 12/Feb/2025 20:00:00 12/Feb/2025 20:30:00 12/Feb/2025 20:31:00 12/Feb/2025 20:40:00 12/Feb/2025 21:00:00 12/Feb/2025 21:01:00 12/Feb/2025 21:01:00 12/Feb/2025 21:01:00 12/Feb/2025 21:01:00 12/Feb/2025 21:01:00 12/Feb/2025 21:16:00 12/Feb/2025 21:30:00 12/Feb/2025 21:31:00 12/Feb/2025 22:00:00 12/Feb/2025 22:01:00 12/Feb/2025 22:30:00 12/Feb/2025 22:30:00 12/Feb/2025 22:31:00 12/Feb/2025 22:43:00 12/Feb/2025 23:00:00 12/Feb/2025 23:01:00 12/Feb/2025 23:10:00 12/Feb/2025 23:29:00 12/Feb/2025 23:30:00 12/Feb/2025 23:31:00 13/Feb/2025 00:00:00 13/Feb/2025 00:00:00 13/Feb/2025 00:01:00 Dumped DPI unit side A & B. moderate carbolites. Side B observed trace carbolites. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 13% Water and. Oil 87%. NDBi-014 Injection Rate 3.82 bpm; Injection Cumulative 8830.74 bbls. Sparged Expro separator , Observed trace of solids. Added Tank 1 and Tank 2 into NDB-014 Injection and Removed Tank 3 and Tank 4. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 12% Water and. Oil 88%. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 11% Water and. Oil 89%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Added Tank 5 and Tank 6 into NDB-014 Injection and removed Tank 1 and Tank 2. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.45 ppg. Upstream DPI BS&W Sample Showed traces of solids. Diverted Flow from Tank 8 to Tank 9. NDBi-014 Injection Rate 3.80 bpm; Injection Cumulative 9175.75 bbls. BS&W at Choke Manifold Showed 9% Water and. Oil 91%. Dumped DPI unit side A & B. moderate carbolites. Side B observed light carbolites. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 9% Water and. Oil 91%. Upstream DPI BS&W Sample Showed 0.1% solids. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Gas S.G = 0.706 H2S 0 ppm. CO2 0.1%. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.44 ppg. Oil API 29.8 @ 60F (Oil SG 0.877) Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Dumped DPI unit side A & B. tace carbolites. Side B observed trace carbolites. Diverted Flow from Tank 9 to Tank 1. BS&W at Choke Manifold Showed 10% Water and. Oil 90%. Diverted Flow from Tank 1 to Tank 2. Sparged Expro separator , Observed trace of solids. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Added Tank 10 into NDB-014 Injection. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 8% Water and. Oil 92%. Diverted Flow from Tank 6 to Tank 5. Collected Tracerco sample. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Sparged Expro separator , Observed trace of solids. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Added Tank 9 and Tank 10 into NDB-014 Injection and removed Tank 1 and Tank 2. Added Tank 1 and Tank 2 into NDB-014 Injection and removed Tank 5, Tank 6 and Tank 10. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 3 to Tank 4. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 77 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 13/Feb/2025 00:28:00 13/Feb/2025 00:30:00 13/Feb/2025 00:31:00 13/Feb/2025 01:00:00 13/Feb/2025 01:01:00 13/Feb/2025 01:30:00 13/Feb/2025 01:31:00 13/Feb/2025 01:35:00 13/Feb/2025 02:00:00 13/Feb/2025 02:01:00 13/Feb/2025 02:31:00 13/Feb/2025 03:00:00 13/Feb/2025 03:01:00 13/Feb/2025 03:23:00 13/Feb/2025 03:30:00 13/Feb/2025 03:30:00 13/Feb/2025 03:31:00 13/Feb/2025 04:00:00 13/Feb/2025 04:01:00 13/Feb/2025 04:30:00 13/Feb/2025 04:30:00 13/Feb/2025 04:30:00 13/Feb/2025 04:31:00 13/Feb/2025 04:58:00 13/Feb/2025 05:00:00 13/Feb/2025 05:01:00 13/Feb/2025 05:30:00 13/Feb/2025 05:31:00 13/Feb/2025 05:54:00 13/Feb/2025 06:00:00 13/Feb/2025 06:00:00 13/Feb/2025 06:00:00 13/Feb/2025 06:01:00 13/Feb/2025 06:03:00 13/Feb/2025 06:30:00 13/Feb/2025 06:31:00 13/Feb/2025 06:34:00 13/Feb/2025 06:34:00 13/Feb/2025 06:39:00 13/Feb/2025 06:52:00 13/Feb/2025 07:00:00 13/Feb/2025 07:00:00 13/Feb/2025 07:01:00 13/Feb/2025 07:10:00 13/Feb/2025 07:30:00 13/Feb/2025 07:31:00 13/Feb/2025 07:31:00 13/Feb/2025 07:41:00 13/Feb/2025 07:42:00 13/Feb/2025 08:00:00 13/Feb/2025 08:01:00 13/Feb/2025 08:01:00 13/Feb/2025 08:19:00 13/Feb/2025 08:30:00 13/Feb/2025 08:31:00 13/Feb/2025 08:38:00 13/Feb/2025 08:40:00 13/Feb/2025 08:51:00 13/Feb/2025 09:00:00 13/Feb/2025 09:01:00 13/Feb/2025 09:01:00 BS&W at Choke Manifold Showed 6% Water and. Oil 94%. Upstream DPI BS&W Sample Showed traces of solids. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Removed Tank 7 from NDB-014 Injection Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 2 to Tank 9. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 6 to Tank 1. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 1 to Tank 2. NDBi-014 Injection Rate 4.40 bpm; Injection Cumulative 12245 bbls. Collected Tracerco sample. Vac truck # 86094 lined up to tank 4, RVP= 5. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Replaced WHT transeducer single core cable. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 10 to Tank 7. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Diverted Flow from Tank 7 to Tank 8. Added Tank 9 and Tank 10 into NDB-014 Injection and removed Tank 5, Tank 4 and Tank 6. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 9 to Tank 10. NDBi-014 Injection Rate 4.36 bpm; Injection Cumulative 11822.27 bbls. BS&W at Choke Manifold Showed 7% Water and. Oil 93%. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.45 ppg. LRS down on pump due to phase 2 weather conditions. Diverted Flow from Tank 3 to Tank 4. Upstream DPI BS&W Sample Showed traces of solids. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. LRS injected 30 bbls of diesel to freeze protect injection well NDB-014 Vac truck # 86094 disconnected from tank 6. Diverted Flow from Tank 3 to Tank 4. Added Tank 7 and Tank 8 into NDB-014 Injection and removed Tank 9 and Tank 10. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 5% Water and. Oil 95%. Vac truck # 86094 disconnected from Tank 4 and lined up to tank 5, RVP= 5. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Vac truck # 86094 disconnected from Tank 5 and lined up to tank 6, RVP= 5. Diverted Flow from Tank 8 to Tank 3. Applied CMSF= 0.924 BS&W at Choke Manifold Showed 5% Water and. Oil 95%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Gas scrubber is dry. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 5% Water and. Oil 95%. H2S 0 ppm. CO2 0.1%. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 78 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 13/Feb/2025 09:01:00 13/Feb/2025 09:01:00 13/Feb/2025 09:01:00 13/Feb/2025 09:30:00 13/Feb/2025 09:31:00 13/Feb/2025 09:31:00 13/Feb/2025 09:35:00 13/Feb/2025 09:44:00 13/Feb/2025 09:50:00 13/Feb/2025 09:53:00 13/Feb/2025 09:54:00 13/Feb/2025 10:00:00 15/Feb/2025 11:02:00 15/Feb/2025 14:00:00 15/Feb/2025 15:03:00 15/Feb/2025 15:30:00 15/Feb/2025 15:31:00 15/Feb/2025 15:42:00 15/Feb/2025 15:43:00 15/Feb/2025 15:55:00 15/Feb/2025 16:00:00 15/Feb/2025 16:05:00 15/Feb/2025 16:17:00 15/Feb/2025 16:30:00 15/Feb/2025 16:30:00 15/Feb/2025 16:30:00 15/Feb/2025 16:30:00 15/Feb/2025 16:30:00 15/Feb/2025 16:31:00 15/Feb/2025 16:31:00 15/Feb/2025 16:37:00 15/Feb/2025 16:45:00 15/Feb/2025 17:00:00 15/Feb/2025 17:00:00 15/Feb/2025 17:01:00 15/Feb/2025 17:01:00 15/Feb/2025 17:30:00 15/Feb/2025 17:30:00 15/Feb/2025 17:31:00 15/Feb/2025 17:31:00 15/Feb/2025 17:50:00 15/Feb/2025 18:00:00 15/Feb/2025 18:00:00 15/Feb/2025 18:01:00 15/Feb/2025 18:03:00 15/Feb/2025 18:04:00 15/Feb/2025 18:30:00 15/Feb/2025 18:30:00 15/Feb/2025 18:31:00 15/Feb/2025 18:50:00 15/Feb/2025 19:00:00 15/Feb/2025 19:00:00 15/Feb/2025 19:01:00 15/Feb/2025 19:02:00 15/Feb/2025 19:30:00 15/Feb/2025 19:30:00 15/Feb/2025 19:31:00 15/Feb/2025 20:00:00 15/Feb/2025 20:01:00 Upstream DPI BS&W Sample Showed traces of solids. NDBi-014 Injection Rate 4.04 bpm; Injection Cumulative 13052 bbls. Added Tank 5 and Tank 6 into NDB-014 Injection. Opened Master Valve = 24 turns. Opened Wellhead NDB-025 Production Wing Valve (PWV) 23.5 turns to closed Expro Choke Manifold. Verified valve alignment. Line up to DPI, Choke to separator and then to Tank Farm Tank #1. Bypassed Line Heater. Bled down IA pressure to 850 psi. NDB-025 shut-in at choke manifold. due to phase 2 weather conditions. Closed FWV= 24 turns, Closed Master valve= 24 turns. Stopped chemical injection of methanol, demulsifier and defoamer. Commenced NDBi-014 Injection. Oil API 29.4 @ 60F (Oil SG 0.879) Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 5% Water and. Oil 95%. Dumped DPI unit side A & B. light carbolites. Side B observed trace carbolites. Commenced bleeding down IA pressure. Gas S.G = 0.703 Water Salinity 28000 ppm; Water pH 7, Water Weight 8.45 ppg. NDB-025 - Well Clean-Up Flow #2 Added Tank 7 and Tank 8 into NDB-014 Injection and removed Tank 3,Tank 4, Tank 5 and Tank 6. LRS down on pump. Diverted Flow from Tank 2 to Tank 1. Increased Expro adjustable Choke to 40/64ths as per Santos WSS. BS&W at Choke Manifold Showed 6.80% Water and 0.20% Solids. Oil 93%. Diverted Flow from Tank 1 to Tank 2. Commenced Liquid sampling. Commenced chemical injection of methanol. @ 8 gal/day NDBi-014 Injection Rate 3.99 bpm; Injection Cumulative 13616.73 bbls. Oil API 31 @ 60F (Oil SG 0.871) BS&W at Choke Manifold Showed 9.75% Water and 0.25% Solids. Oil 90%. Flare pilot is lit. Commenced chemical injection of demulsifier and defoamer. @ 8 gal/day Opened Well on a 24/64ths adjustable Choke as per Santos WSS. Dumping gas from Separator to Flare. Metering Gas through 3" Coriolis. Began dumping Fluid from Separator. Metering through 2" Line (1.5" Turbine Meter). Increased Expro adjustable Choke to 32/64ths as per Santos WSS. Increased Expro adjustable Choke to 64/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 3. BS&W at Choke Manifold Showed 22% Water and trace of Solids. Oil 78%. Added Tank 1 and Tank 2 into NDB-014 Injection and removed Tank 7, Tank 8. Applied CMSF= 0.895 Diverted Flow from Tank 3 to Tank 4. Increased Expro adjustable Choke to 56/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 1% Water and trace of Solids. Oil 99%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Collected Tracerco sample. Water Salinity 55000 ppm; Water pH 9, Water Weight 8.01 ppg. Diverted Flow from Tank 1 to Tank 2. Increased Expro adjustable Choke to 48/64ths as per Santos WSS. BS&W at Choke Manifold Showed 4.80% Water and 0.20% Solids. Oil 95%. LRS Pump back online. Diverted liquid flow from 1.5'' turbine meter to 2'' turbine meter . Increased Expro adjustable Choke to 80/64ths as per Santos WSS. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B observed trace carbolites. Increased Expro adjustable Choke to 72/64ths as per Santos WSS. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 2.6% Water and trace of Solids. Oil 97.4%. Diverted Flow from Tank 3 to Tank 7. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 79 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 15/Feb/2025 20:01:00 15/Feb/2025 20:03:00 15/Feb/2025 20:30:00 15/Feb/2025 20:30:00 15/Feb/2025 20:31:00 15/Feb/2025 20:40:00 15/Feb/2025 20:48:00 15/Feb/2025 21:00:00 15/Feb/2025 21:00:00 15/Feb/2025 21:00:00 15/Feb/2025 21:00:00 15/Feb/2025 21:00:00 15/Feb/2025 21:00:00 15/Feb/2025 21:00:00 15/Feb/2025 21:01:00 15/Feb/2025 21:02:00 15/Feb/2025 21:30:00 15/Feb/2025 21:30:00 15/Feb/2025 21:31:00 15/Feb/2025 22:00:00 15/Feb/2025 22:00:00 15/Feb/2025 22:00:00 15/Feb/2025 22:19:00 15/Feb/2025 22:30:00 15/Feb/2025 22:30:00 15/Feb/2025 22:30:00 15/Feb/2025 22:31:00 15/Feb/2025 22:31:00 15/Feb/2025 23:00:00 15/Feb/2025 23:00:00 15/Feb/2025 23:01:00 15/Feb/2025 23:04:00 15/Feb/2025 23:20:00 15/Feb/2025 23:30:00 15/Feb/2025 23:31:00 16/Feb/2025 00:00:00 16/Feb/2025 00:00:00 16/Feb/2025 00:00:00 16/Feb/2025 00:01:00 16/Feb/2025 00:02:00 16/Feb/2025 00:15:00 16/Feb/2025 00:30:00 16/Feb/2025 00:30:00 16/Feb/2025 00:31:00 16/Feb/2025 00:40:00 16/Feb/2025 00:47:00 16/Feb/2025 00:55:00 16/Feb/2025 01:00:00 16/Feb/2025 01:00:00 16/Feb/2025 01:02:00 16/Feb/2025 01:17:00 16/Feb/2025 01:17:00 16/Feb/2025 01:30:00 16/Feb/2025 01:31:00 16/Feb/2025 01:40:00 16/Feb/2025 01:45:00 16/Feb/2025 02:00:00 16/Feb/2025 02:00:00 16/Feb/2025 02:01:00 16/Feb/2025 02:19:00 16/Feb/2025 02:30:00 Vac Truck removed 39.96 bbls Tank 7, 27.14 bbls from Tank 8, 30.91 bbls from Tank 9, 21.11 bbls Tank 10 Diverted Flow from Tank 8 to Tank 9. Oil API 30 @ 60F (Oil SG 0.876) Water Salinity 30000 ppm; Water pH 7, Water Weight 8.44 ppg. H2S 0 ppm. CO2 0.1%. Gas S.G = 0.706 BS&W at Choke Manifold Showed 2.8% Water and trace of Solids. Oil 97.2%. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 2.4% Water and trace of Solids. Oil 97.6%. Removed Tank 1 and Tank 2 into NDB-014 Injection Added Tank 3 and Tank 4 into NDB-014 Injection Increased Expro adjustable Choke to 96/64ths as per Santos WSS. Sparged Expro separator , Observed trace of solids. BS&W at Choke Manifold Showed 2.4% Water and trace of Solids. Oil 97.6%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Increased Expro adjustable Choke to 88/64ths as per Santos WSS. BS&W at Choke Manifold Showed 3% Water and trace of Solids. Oil 97%. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B observed trace carbolites. Removed Tank 9 and Tank 10 into NDB-014 Injection Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 3.5% Water and trace of Solids. Oil 96.5%. Collected Tracerco sample. Diverted Flow from Tank 8 to Tank 7. Removed Tank 3 and Tank 4 from NDB-014 Injection. BS&W at Choke Manifold Showed 2.6% Water and trace of Solids. Oil 97.4%. Increased Expro adjustable Choke to 128/64ths as per Santos WSS. Diverted Flow from Tank 7 to Tank 1. BS&W at Choke Manifold Showed 2.8% Water and 0% Solids. Oil 97.2%. Diverted Flow from Tank 10 to Tank 8. Added Tank 10 into NDB-014 Injection Increased Expro adjustable Choke to 120/64ths as per Santos WSS. Added Tank 9 into NDB-014 Injection Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Increased Expro adjustable Choke to 104/64ths as per Santos WSS. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 2.6% Water and trace of Solids. Oil 97.4%. Increased Expro adjustable Choke to 112/64ths as per Santos WSS. BS&W at Choke Manifold Showed 3% Water and trace of Solids. Oil 97%. Diverted Flow from Tank 4 to Tank 5. Dumped DPI unit side A & B. SIde A observed moderate solids. Side B observed light solids. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Added Tank 1. Tank 2 and Tank 3 into NDB-014 Injection and removed Tank 7, Tank 8. Diverted Flow from Tank 5 to Tank 6. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 3.5% Water and trace of Solids. Oil 96.5%. Vac Truck disconnected from Tank 5 and Tank 6 Vac Truck removed 15.08 bbls Tank 1 and 18.1 bbls from Tank 2 Vac Truck disconnected from Tank 1 and Tank 2 Diverted Flow from Tank 2 to Tank 3. Applied CMSF= 0.911 BS&W at Choke Manifold Showed 3.5% Water and trace of Solids. Oil 96.5%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Vac Truck removed 44.48 bbls Tank 5 and 45.23 bbls from Tank 6 Sparged Expro separator , Observed trace of solids. Diverted Flow from Tank 5 to Tank 7. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Dumped DPI unit side A & B. trace carbolites. Side B observed trace carbolites. Sparged Expro separator , Observed trace of solids. Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B observed trace carbolites. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 80 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 16/Feb/2025 02:31:00 16/Feb/2025 03:00:00 16/Feb/2025 03:00:00 16/Feb/2025 03:00:00 16/Feb/2025 03:00:00 16/Feb/2025 03:00:00 16/Feb/2025 03:01:00 16/Feb/2025 03:30:00 16/Feb/2025 03:31:00 16/Feb/2025 03:32:00 16/Feb/2025 04:00:00 16/Feb/2025 04:01:00 16/Feb/2025 04:05:00 16/Feb/2025 04:30:00 16/Feb/2025 04:31:00 16/Feb/2025 05:00:00 16/Feb/2025 05:01:00 16/Feb/2025 05:30:00 16/Feb/2025 05:30:00 16/Feb/2025 05:31:00 16/Feb/2025 05:32:00 16/Feb/2025 06:00:00 16/Feb/2025 06:00:00 16/Feb/2025 06:01:00 16/Feb/2025 06:01:00 16/Feb/2025 06:01:00 16/Feb/2025 06:30:00 16/Feb/2025 06:31:00 16/Feb/2025 06:31:00 16/Feb/2025 06:35:00 16/Feb/2025 06:41:00 16/Feb/2025 06:48:00 16/Feb/2025 07:00:00 16/Feb/2025 07:01:00 16/Feb/2025 07:01:00 16/Feb/2025 07:01:00 16/Feb/2025 07:02:00 16/Feb/2025 07:04:00 16/Feb/2025 07:30:00 16/Feb/2025 07:31:00 16/Feb/2025 07:31:00 16/Feb/2025 07:35:00 16/Feb/2025 08:00:00 16/Feb/2025 08:01:00 16/Feb/2025 08:01:00 16/Feb/2025 08:01:00 16/Feb/2025 08:30:00 16/Feb/2025 08:30:00 16/Feb/2025 08:31:00 16/Feb/2025 08:31:00 16/Feb/2025 08:33:00 16/Feb/2025 08:36:00 16/Feb/2025 08:38:00 16/Feb/2025 09:00:00 16/Feb/2025 09:01:00 16/Feb/2025 09:01:00 16/Feb/2025 09:01:00 16/Feb/2025 09:01:00 16/Feb/2025 09:01:00 16/Feb/2025 09:01:00 16/Feb/2025 09:30:00 Gas S.G = 0.706 Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 3.5% Water and trace of Solids. Oil 96.5%. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Oil API 29.7 @ 60F (Oil SG 0.878) H2S 0 ppm. CO2 0.1%. Water Salinity 29000 ppm; Water pH 7, Water Weight 8.45 ppg. Gas scrubber is dry. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Water Salinity 29000 ppm; Water pH 7, Water Weight 8.44 ppg. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 3% Water and trace of Solids. Oil 97%. Upstream DPI BS&W Sample Showed 0.1% solids. Collected Tracerco sample. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 3 to Tank 4. NDBi-014 Injection Rate 2.99 bpm; Injection Cumulative 16670.69 bbls. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Added Tank 1,2 and Tank 3 into NDB-014 Injection and removed Tank 7 and Tank 8 and Tank 9. Diverted Flow from Tank 4 to Tank 5. Diverted Flow from Tank 9 to Tank 1. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Added Tank 7, Tank 8 and Tank 9 into NDB-014 Injection and removed Tank 4, Tank 5 and Tank 6 Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 2 to Tank 3. Upstream DPI BS&W Sample Showed traces of solids. Diverted Flow from Tank 9 to Tank 1. NDBi-014 Injection Rate 3.76 bpm; Injection Cumulative 17398.58 bbls. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Upstream DPI BS&W Sample Showed 0.15% solids. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Upstream DPI BS&W Sample Showed 0.2% solids. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Water Salinity 29000 ppm; Water pH 7, Water Weight 8.44 ppg. Water Salinity 29000 ppm; Water pH 7, Water Weight 8.43 ppg. Upstream DPI BS&W Sample Showed traces of solids. Added Tank 6 into NDB-014 Injection. Sparged Expro separator , Observed trace of solids. Diverted Flow from Tank 7 to Tank 8. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Edgex server down for 5 minutes recalculated vol cums and Updated system Added Tank 4 and Tank 5 into NDB-014 Injection and removed Tank 1, Tank 2 and Tank 3. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. H2S 0 ppm. CO2 0.1%. Water Salinity 29000 ppm; Water pH 7, Water Weight 8.45 ppg. Gas S.G = 0.709. Upstream DPI BS&W Sample Showed traces of solids. Diverted Flow from Tank 2 to Tank 3. Added Tank 7, Tank 8 and Tank 9 into NDB-014 Injection and removed Tank 4, Tank 5 and Tank 6. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Opened bypass on Expro Ball catcher as per WSS. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Oil API 30.3 @ 60F (Oil SG 0.875) WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 81 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 16/Feb/2025 09:31:00 16/Feb/2025 09:31:00 16/Feb/2025 09:34:00 16/Feb/2025 10:00:00 16/Feb/2025 10:00:00 16/Feb/2025 10:01:00 16/Feb/2025 10:01:00 16/Feb/2025 10:01:00 16/Feb/2025 10:02:00 16/Feb/2025 10:04:00 16/Feb/2025 10:05:00 16/Feb/2025 10:30:00 16/Feb/2025 10:31:00 16/Feb/2025 10:31:00 16/Feb/2025 10:35:00 16/Feb/2025 10:37:00 16/Feb/2025 10:50:00 16/Feb/2025 11:00:00 16/Feb/2025 11:00:00 16/Feb/2025 11:01:00 16/Feb/2025 11:01:00 16/Feb/2025 11:01:00 16/Feb/2025 11:30:00 16/Feb/2025 11:31:00 16/Feb/2025 11:35:00 16/Feb/2025 11:39:00 16/Feb/2025 12:00:00 16/Feb/2025 12:00:00 16/Feb/2025 12:01:00 16/Feb/2025 12:01:00 16/Feb/2025 12:30:00 16/Feb/2025 12:31:00 16/Feb/2025 12:38:00 16/Feb/2025 13:00:00 16/Feb/2025 13:01:00 16/Feb/2025 13:03:00 16/Feb/2025 13:04:00 16/Feb/2025 13:07:00 16/Feb/2025 13:23:00 16/Feb/2025 13:30:00 16/Feb/2025 13:31:00 16/Feb/2025 13:34:00 16/Feb/2025 14:00:00 16/Feb/2025 14:00:00 16/Feb/2025 14:01:00 16/Feb/2025 14:25:00 16/Feb/2025 14:30:00 16/Feb/2025 14:31:00 16/Feb/2025 14:31:00 16/Feb/2025 14:33:00 16/Feb/2025 14:37:00 16/Feb/2025 15:00:00 16/Feb/2025 15:01:00 16/Feb/2025 15:01:00 16/Feb/2025 15:01:00 16/Feb/2025 15:01:00 16/Feb/2025 15:01:00 16/Feb/2025 15:03:00 16/Feb/2025 15:03:00 16/Feb/2025 15:30:00 16/Feb/2025 15:30:00 Upstream DPI BS&W Sample Showed 0.1% solids. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Diverted Flow from Tank 3 to Tank 4. Applied CMSF= 0.913 BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Upstream DPI BS&W Sample Showed traces of solids. Water Salinity 28000 ppm; Water pH 7, Water Weight 8.43 ppg. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Water Salinity 30000 ppm; Water pH 7, Water Weight 8.44 ppg. Upstream DPI BS&W Sample Showed traces of solids. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Added Tank 4, Tank 5 and Tank 6 into NDB-014 Injection and removed Tank 1, Tank 2 and Tank 3. Gas scrubber is dry. Dumped DPI unit side A & B. Side A observed light carbolites. Side B observed trace carbolites. Diverted fluid flow to parallel through DPI pods as per WSS. Diverted Flow from Tank 5 to Tank 6. NDBi-014 Injection Rate 3.78 bpm; Injection Cumulative 17963.52 bbls. Added Tank 1 and Tank 2 into NDB-014 Injection and removed Tank 7, Tank 8 and Tank 9. Sparged Expro separator , Observed trace of solids. Added Tank 3 into NDB-014 Injection. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 6% Water and trace of Solids. Oil 94%. Upstream DPI BS&W Sample Showed 0.15% solids. Added Tank 9 into NDB-014 Injection. Gas scrubber is dry. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B moderate carbolites. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Dumped DPI unit side A & B. Side A observed traces carbolites. Side B Moderate carbolites. Diverted Flow from Tank 9 to Tank 1. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Added Tank 7 and Tank 8 into NDB-014 Injection and remove,Tank 4, Tank 5 and Tank 6. Sparged Expro separator , Observed light trace of solids. Dumped DPI unit side A & B. Side A observed light carbolites. Side B light trace carbolites. Diverted Flow from Tank 7 to Tank 8. Collected Tracerco sample. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Acquired Flare heat index. Diverted Flow from Tank 8 to Tank 9. Oil API 29.8 @ 60F (Oil SG 0.877) Water Salinity 29000 ppm; Water pH 7, Water Weight 8.44 ppg. Gas scrubber is dry. Flare Drain was free of Fluid. Diverted Flow from Tank 5 to Tank 6. NDBi-014 Injection Rate 3.76 bpm; Injection Cumulative 19092.71 bbls. Added Tank 3 into NDB-014 Injection Dumped DPI unit side A & B. Side A observed light carbolites. Side B light carbolites. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Gas S.G = 0.711. H2S 0 ppm. CO2 0.1%. NDBi-014 Injection Rate 4.47 bpm; Injection Cumulative 18742.99 bbls. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Added Tank 1 and Tank 2 into NDB-014 Injection and removed Tank 7, Tank 8 and Tank 9. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Water Salinity 29000 ppm; Water pH 7, Water Weight 8.45 ppg. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 82 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 16/Feb/2025 15:31:00 16/Feb/2025 15:36:00 16/Feb/2025 16:00:00 16/Feb/2025 16:01:00 16/Feb/2025 16:02:00 16/Feb/2025 16:07:00 16/Feb/2025 16:30:00 16/Feb/2025 16:31:00 16/Feb/2025 16:35:00 16/Feb/2025 17:00:00 16/Feb/2025 17:01:00 16/Feb/2025 17:30:00 16/Feb/2025 17:31:00 16/Feb/2025 17:34:00 16/Feb/2025 17:37:00 16/Feb/2025 18:00:00 16/Feb/2025 18:00:00 16/Feb/2025 18:01:00 16/Feb/2025 18:01:00 16/Feb/2025 18:30:00 16/Feb/2025 18:31:00 16/Feb/2025 18:33:00 16/Feb/2025 19:00:00 16/Feb/2025 19:00:00 16/Feb/2025 19:00:00 16/Feb/2025 19:01:00 16/Feb/2025 19:30:00 16/Feb/2025 19:31:00 16/Feb/2025 19:33:00 16/Feb/2025 20:00:00 16/Feb/2025 20:01:00 16/Feb/2025 20:30:00 16/Feb/2025 20:31:00 16/Feb/2025 20:52:00 16/Feb/2025 21:00:00 16/Feb/2025 21:01:00 16/Feb/2025 21:28:00 16/Feb/2025 21:30:00 16/Feb/2025 21:31:00 16/Feb/2025 21:38:00 16/Feb/2025 21:52:00 16/Feb/2025 22:00:00 16/Feb/2025 22:00:00 16/Feb/2025 22:01:00 16/Feb/2025 22:30:00 16/Feb/2025 22:31:00 16/Feb/2025 23:00:00 16/Feb/2025 23:01:00 16/Feb/2025 23:30:00 16/Feb/2025 23:31:00 16/Feb/2025 23:31:00 16/Feb/2025 23:40:00 16/Feb/2025 23:40:00 17/Feb/2025 00:00:00 17/Feb/2025 00:00:00 17/Feb/2025 00:00:00 17/Feb/2025 00:01:00 17/Feb/2025 00:08:00 17/Feb/2025 00:30:00 17/Feb/2025 00:31:00 17/Feb/2025 01:00:00 Gas scrubber is dry. Diverted Flow from Tank 9 to Tank 1. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B light carbolites. Added Tank 7, Tank 8 and Tank 9 into NDB-014 Injection and removed Tank 4, Tank 5 and Tank 6. Collected Tracerco sample. Diverted Flow from Tank 1 to Tank 2. Sparged Expro separator , Observed light trace of solids. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 3% Water and trace of Solids. Oil 97%. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B trace carbolites. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B moderate carbolites. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Added Tank 4, Tank 5 and Tank 6 into NDB-014 Injection and removed Tank 1, Tank 2 and Tank 3 Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Vac truck commecned transferring fluid to Tank 10. Diverted Flow from Tank 3 to Tank 4. Flare Drain was free of Fluid. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Added Tank 1and Tank 2 into NDB-014 Injection and removed Tank 7, Tank 8 and Tank 9. Decreased Expro adjustable Choke to 52/64ths as per Santos WSS. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Dumped DPI unit side A & B. Side A observed light carbolites. Side B light trace carbolites. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Diverted Flow from Tank 6 to Tank 7. Dumped DPI unit side A & B. Side A observed light carbolites. Side B light trace carbolites. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Flare Drain was free of Fluid. Added Tank 5 and Tank 6 into NDB-014 Injection and removed Tank 3, Tank 4 Sparged Expro separator , Observed light trace of solids. Sparged Expro separator , Observed light trace of solids. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 5% Water and trace of Solids. Oil 95%. Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B trace carbolites. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 4% Water and trace of Solids. Oil 96%. Added Tank 3 and Tank 4 into NDB-014 Injection and removed Tank 1, Tank 2 Vac truck transferred 260.84 bbls to Tank 10. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Applied CMSF= 0.951 Decreased Expro adjustable Choke to 44/64ths as per Santos WSS. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Gas scrubber is dry. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 83 Customer: Field: Location: Well Name: Start Date: DATE / TIME dd/mmm/yyyy hh:mm:ss SEQUENCE OF EVENTS Pikka Development NDB NDB-025 10-Feb-25 OPERATIONS 17/Feb/2025 01:00:00 17/Feb/2025 01:01:00 17/Feb/2025 01:30:00 17/Feb/2025 01:30:00 17/Feb/2025 01:31:00 17/Feb/2025 01:45:00 17/Feb/2025 02:00:00 17/Feb/2025 02:01:00 17/Feb/2025 02:30:00 17/Feb/2025 02:31:00 17/Feb/2025 03:00:00 17/Feb/2025 03:00:00 17/Feb/2025 03:00:00 17/Feb/2025 03:01:00 17/Feb/2025 03:30:00 17/Feb/2025 03:31:00 17/Feb/2025 03:34:00 17/Feb/2025 04:00:00 17/Feb/2025 04:00:00 17/Feb/2025 04:01:00 17/Feb/2025 04:30:00 17/Feb/2025 04:31:00 17/Feb/2025 05:01:00 17/Feb/2025 05:30:00 17/Feb/2025 05:31:00 17/Feb/2025 05:46:00 17/Feb/2025 06:00:00 17/Feb/2025 06:01:00 17/Feb/2025 06:03:00 17/Feb/2025 07:00:00 17/Feb/2025 08:00:00 17/Feb/2025 09:00:00 17/Feb/2025 10:00:00 17/Feb/2025 11:00:00 17/Feb/2025 12:00:00 17/Feb/2025 13:00:00 17/Feb/2025 14:00:00 17/Feb/2025 15:00:00 17/Feb/2025 16:00:00 17/Feb/2025 17:00:00 17/Feb/2025 17:30:00 17/Feb/2025 18:00:00 17/Feb/2025 20:45:00 BS&W at Choke Manifold Showed 3.5% Water and trace of Solids. Oil 96.5%. Added Tank 7, Tank 8 and 10 into NDB-014 Injection and removed Tank 5, Tank 6 Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B trace carbolites. Diverted Flow from Tank 8 to Tank 1. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Added Tank 1and Tank 2 into NDB-014 Injection and removed Tank 7, Tank 8 and Tank 10. Stopped chemical injection of methanol, demulsifier and defoamer. Dumped DPI unit side A & B. Side A observed trace carbolites. Side B trace carbolites. Sparged Expro separator , Observed light trace of solids. Diverted Flow from Tank 1 to Tank 3. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 3 to Tank 2. Gas S.G = 0.706 H2S 0 ppm. CO2 0.1%. Oil API 29.8 @ 60F (Oil SG 0.877) BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 4.5% Water and trace of Solids. Oil 95.5%. LRS completed Injection to NDBi-014. NDBi-014 Injection Rate 1.30 bpm; Injection Cumulative 23729.79 bbls. NDBi-014 Injection Rate 1.29 bpm; Injection Cumulative 23808.4 bbls. LRS down on pump. Switching to Diesel flush. Total Diesel pumped 34.67 bbls NDBi-014 Injection Rate 0.67 bpm; Injection Cumulative 23283.61 bbls. NDBi-014 Injection Rate 0.72 bpm; Injection Cumulative 23327.16 bbls. NDBi-014 Injection Rate 0.75 bpm; Injection Cumulative 23371.12 bbls. NDBi-014 Injection Rate 0.78 bpm; Injection Cumulative 23415.35 bbls. NDBi-014 Injection Rate 1.26 bpm; Injection Cumulative 23488.02 bbls. NDBi-014 Injection Rate 1.31 bpm; Injection Cumulative 23562.23 bbls. NDB-025 shut in at choke manifold. Closed FWV= 24 turns, Closed Master valve= 24 turns NDBi-014 Injection Rate 3.08 bpm; Injection Cumulative 22836.25 bbls. NDBi-014 Injection Rate 3.08 bpm; Injection Cumulative 23020.17 bbls. NDBi-014 Injection Rate 3.08 bpm; Injection Cumulative 23204.90 bbls. WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 84 Santos – Pikka Development – NDB-025 SECTION 12 COMBINED METER & SHRINKAGE FACTOR (CMSF) WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 85 Combined Meter & Shrinkage FactorClient:Well No:Field:Test:MF #DateTimeChokeTankTankTTank vcfCorrecteddTankMeterMeter CountsdMeterCMSFCMSF Applied64thsbbls°F @ 60°FVolumebblsbblsbblsTimeStart15:00 106.29 75.0 0.993105.49426.12Applied 12:30Finish15:30 213.34 54.0 1.003213.98541.05Start22:30 104.03 71.0 0.995103.462050.10Applied 22:30Finish23:00 202.03 63.0 0.999201.732165.70Start3:00 177.91 58.0 1.001178.093004.23Applied 05:30Finish3:30 286.47 65.0 0.998285.753120.05Start15:00 166.60 69.5 0.995165.815827.13Applied 15:30Finish15:03 281.94 68.0 0.996280.815950.74Start22:00 141.72 70.5 0.995140.987538.97Applied 22:30Finish22:30 253.30 64.0 0.998252.797657.05Start11:30 60.31 68.7 0.99660.0510715.51Applied 12:00Finish12:00 170.37 66.5 0.997169.8210834.99Start10:00 172.63 70.0 0.995171.7713307.76Applied 22:30Finish10:30 284.96 65.0 0.998284.2513432.65Start6:30 49.75 67.0 0.99749.5815409.62Applied 07:00Finish7:00 162.08 66.0 0.997161.5915530.84Start19:00 178.664 69.0 0.996177.8616644.28Applied 19:00Finish19:30 294.758 67.0 0.997293.7316777.92Start12:00 55.1853 71.0 0.99554.8817891.11Applied 00:00Finish12:30 182.925 65.5 0.997182.4218031.09Note:133.640.8679 15-Feb-25 64115.872"0.9111. Tank corrected volume = tank reading x VCF2. CMSF = delta volume tank / delta meter10 16-Feb-25 128127.542"139.9811-Feb-25 128111.822''118.080.9470.9018 13-Feb-25 128112.022"121.220.9247 12-Feb-25 128112.482"124.896 12-Feb-25 128109.772''119.480.91950.9304 11-Feb-25 128115.002''123.610.9303 10-Feb-25 128107.672''115.820.9442 10-Feb-25 12898.272''115.600.850Tank Readings Test Separator1 10-Feb-25 48108.492''114.93SantosNDB-025PIKKA DevelopmentWell Clean-UpWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 86 Combined Meter & Shrinkage FactorClient:Well No:Field:Test:MF # Date Time Choke Tank TankT Tank vcf Corrected dTank Meter Meter Counts dMeter CMSFCMSF Applied64ths bbls °F @ 60°F Volume bbls bbls bblsTimeStart9:30 57.29 68.0 0.99657.0620427.96Applied 10:00Finish10:00 178.66 69.5 0.995177.8120560.20Start0:00 54.28 70.0 0.99554.0124218.64Applied 00:00Finish0:30 130.42 64.0 0.998130.1624298.74Note:SantosNDB-025PIKKA DevelopmentWell Clean-UpTank ReadingsTest Separator116-Feb-25128120.752''132.240.913217-Feb-254476.152"80.100.9511. Tank corrected volume = tank reading x VCF2. CMSF = delta volume tank / delta meterWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 87 Santos – Pikka Development – NDB-025 SECTION 13 DIAGRAMS WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 88 Santos – Pikka Development – NDB-025 P&ID Process & Instrumentation Diagram WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 89 ¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORUNCONTROLLED COPYxxxWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 90 UNCONTROLLED COPY¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 91 UNCONTROLLED COPY¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORxxxxxxxxxxxWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 92 ¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORUNCONTROLLED COPYxWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 93 ¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORUNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 94 ¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORUNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 95 ¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORUNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 96 ¤PIPEWORK IDENTIFICATIONREF MAWP REF DESCRIPTION115,000 PSIGFF FLUID FLOW210,000 PSIGOF OIL FLOW37,500 PSIGGF GAS FLOW45,000 PSIGWF WATER FLOW52,000 PSIGDF DIESEL FLOW61,440 PSIGSH STEAM FLOW71,000 PSIGVVENT LINE8 285 PSIG RF RELIEF LINE9250 PSIG CI CHEM. INJECTION10125 PSIG A PIPE11 150 PSIG B HOSEABBREVIATIONSSYM DESCRIPTION SYM DESCRIPTIONBP BLEED PORT N.C. NORMALLY CLOSEDBPV BACK PRESSURE VALVE N.O. NORMALLY OPENEDCI CHEMICAL INJECTION PI PRESSURE INDICATORDP DIFFERENTIAL PRESSURE PIC PRESSURE CONTROLLERDPT DIFF. PRESS. TRANSDUCER PIT PRESSURE TRANSDUCERCC CORROSION COUPON PR PRESSURE RECORDERF.C. FAIL SAFE CLOSED PSE RUPTURE DISCFM FLOW METER PSH HIGH PRESSURE PILOTF.O. FAIL SAFE OPEN PSL LOW PRESSURE PILOTFRT FLOW METER TRANSDUCER PSV PRESSURE SAFETY VALVEFSV FLOW CHECK VALVE SDT SAND DETECTIONLC LEVEL CONTROLLER SDVSHUTDOWN VALVE (ESD)LCV LEVEL CONTROL VALVE SP SAMPLE POINTLG LEVEL GAUGE TI TEMPERATURE INDICATORLSH LEVEL SAFETY HIGH TIT TEMP. TRANSDUCERLSL LEVEL SAFETY LOW TSE TEMPERATIRE SAFETY ELEMENTAUTHORDATEREVMAXIMUM FLOWING PARAMETERSAS PER CLIENT QUESTIONAIREPHASE RATE SGOILGASWATERCITHP (PSIG)EXPECTED FTHP (PSIG)FTHT (deg F)MAXIMUM TUBING TEST PRESSURE(PSIG)CO2 (%)H2S (PPM)OFPAGEREVISION HISTORYDATE REV # REASON FOR ISSUE BY CHK APRV9/17/2024 AADDITIONAL STORAGE TANKS & UTILIZE HP HEADERSO AS RM10/21/2024 BMOVE HP TEST HEADER TIE-IN TO VALVE HPPV-05 NEARWELL NDBi-019SO RI RM11/16/2024 C ADDED NDBi-030 INJECTION WELL SO AS RM12/17/2024 DREMOVE NDBi-030 & RIG-UP TO NDBi-018 INJ WELLSO RI RMDRAWING NUMBERTEMPORARY PIPEWORK TEMPERATURECONSTRAINTSCOFLEXIP HOSE -4F TO +266FHAMMER UNION PIPEWORK -20F TO +250FHUBBED PIPEWORK -20F TO +350FSYM DESCRIPTIONSYM DESCRIPTION SYM DESCRIPTIONPNEUMATIC LINEHYDRAULIC LINESTRAIGHTENINGREGULATORROXAR SAM ACOUSTICFLAME ARRESTORFLOW CHECKVANESVALVECONTROL VALVEOPEN CLOSEDCLAMP CONNECTIONAIR SUPPLYSAFETY VALVERUPTURE DISCCONNECTIONFLANGEVALVESAFETY VALVEFIXED CHOKEADJ. CHOKEHAMMER UNIONSWAGEVALVECHOKE INLINEDEVICE SYMBOLSSAND MONITORUNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 97 Santos – Pikka Development – NDB-025 SAFE CHART Safety Analysis Function Evaluation Chart WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 98 A A SO AS RM REV CREATE CHECK APPROVE 111 111 FSV 102A 111 111 FSV 102A 1 1 PSL 002 PSHH 003 111 111 PSV 003 111 111 111 111 1 1 111 111 111 111 111 PSE 102 1 1 111 1 1 1 1 PSE 103 111 1 LSH 102 FSV (GAS) DIESEL FIRED LINE HEATER BAP 101 PSV A.10c.6 PSH FLOWLINE CHOKE MANIFOLD TO HEATER FAQ 002 FSV A.1d.2 PSH A.1a.2 PSL 002 PSV A.1c.2 FLOWLINE WELL HEAD TO CHOKE MANIFOLD FAQ 001 DATE DESCRIPTION A.1c.2 FSV A.1d.2 A.1a.2 PSL 001 PSH PSV SDVSDVADDITIONAL STORAGE TANKS & TRANSFER PUMP CHANGE DESCRIPTION ALT. DEVICE IF APPLICABLESAC. REF. NO.IDENTIFICATION ALTERNATIVE PROTECTION SHUTDOWN ORCONTROL DEVICE I.D.WT-XAK-80127.4 SAFETY ANALYSIS FUNCTION EVALUATION (S.A.F.E.) CHART Santos - Pikka Development - Well Clean-Up Campaign RevisionDocument No. Project 9/17/2024 FUNCTIONPERFORMEDESDDEVICE I.D. PROCESS COMPONENT 12SHUT IN EXPRO / WELLSHUT IN EXPRO / WELLSHUTDOWN HEATERDAQ VISUAL ALARMLOCAL ALARMDAQ AUDIBLE ALARMPRESSURE RELIEFMINIMIZE BACKFLOWVACUUM / PRESS. RELIEFVENT101 LSH A.5c.2 VENT SHELL 101 A.10a.4 PSL 101 PSV A.10c.4 A.10a.2 PSL A.10b.3 102 PSV LSL (H2O)A.4e.2 LSL (OIL)A.4e.2 FSV (H2O)102D FSV (OIL)102B, 102C 102E FLOWLINE HEATER TO HP HORIZONTAL SEPARATOR FAQ 003 PSH 003 PSL 101 PSV 003 FSV 102A HP HORIZONTAL TEST SEPARATOR MBD GAS SCRUBBER MBF 103 PSH A.4a.5 PSL A.4b.4 PSV A.4c.6 LSHH 103 LSL A.4e.2 A.4f.2FSV (GAS) PSH 102 LSHH 102 PSHH 102 102 PSL 102 D/S 2,000 PSI COILS LSL A.5d.2 TSH PSH A.5e.3 U/S 5,000 PSI COILS VPSV WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 99 A A SO AS RM REV CREATE CHECK APPROVE Q DATE DESCRIPTION SDVSDVADDITIONAL STORAGE TANKS & TRANSFER PUMP CHANGE DESCRIPTION ALT. DEVICE IF APPLICABLESAC. REF. NO.IDENTIFICATION ALTERNATIVE PROTECTION SHUTDOWN ORCONTROL DEVICE I.D.WT-XAK-80127.4 SAFETY ANALYSIS FUNCTION EVALUATION (S.A.F.E.) CHART Santos - Pikka Development - Well Clean-Up Campaign RevisionDocument No. Project 9/17/2024 FUNCTIONPERFORMEDESDDEVICE I.D. PROCESS COMPONENT 12SHUT IN EXPRO / WELLSHUT IN EXPRO / WELLSHUTDOWN HEATERDAQ VISUAL ALARMLOCAL ALARMDAQ AUDIBLE ALARMPRESSURE RELIEFMINIMIZE BACKFLOWVACUUM / PRESS. RELIEFVENT1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 111 1 105A, 105B POSITIVE DISP. CHEMICAL PUMP PBA 105 106 PSH A.7b.4 PSL A.7d.4 PSV 105, 106 FSV 106A, 106B FSV 367 BBL ATMOSPHERIC TANK (INJECTION TANK FARM TANK 1 - TANK 10) *Note 1 BBJ 801 802 803 804 805 806 807 808 809 810 VENT 801, 802, 803, 804, 805, 806, 807, 808, 809, 810 VPSV 801, 802, 803, 804, 805, 806, 807, 808, 809, 810 LSH A.5c.2 LSL A.5d.3 367 BBL ATMOSPHERIC DIESEL TANK (WELL TEST BERM TANK D) *Note 1 BBJ 811 VENT 811 VPSV 811 LSH A.5c.2 LSL A.5d.3 400 BBL SAND / DRAIN TANK AND RELIEF TANK ABJ 401 402 VENT 401, 402 VPSV A.5b.2 LSH A.5c.2 LSL A.5d.4 MANUAL ESD PULL STATION EMERGENCY SHUT DOWN Notes: 1. Fill operations for Atmospheric Tanks (BBJ-801 through BBJ-816) is continously operated and manned. POSITIVE DISP. CHEMICAL PUMP PBA 109 110 111 PSH A.7b.4 PSL A.7d.4 PSV 109, 110, 111 FSV 109A, 110A, 111A FSV 109B, 110B, 111B 400/367 BBL ATMOSPHERIC TANK (STORAGE TANK FARM S1 - S5) *Note 1 BBJ 812 813 814 815 816 VENT 812, 813, 814, 815, 816 VPSV 812, 813, 814, 815, 816 LSH A.5c.2 LSL A.5d.3 TRANSFER PUMP (WELL TEST TANK FARM) PBA 112 PSH A.7b.5 PSL A.7d.5 PSV 112 FSV 112 WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 100 Santos – Pikka Development – NDB-025 GAD General Arrangement Drawing WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 101 ¤UNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 102 ¤UNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 103 ¤UNCONTROLLED COPYWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 104 Santos – Pikka Development – NDB-025 PFD Process Flow Diagram WT-XAK-0127.4_NDB-025_Rev A www.expro.com Page 105 10K PSI SSVESD PanelAir SupplyShut Down SignalESD Stations LoopESD Pilots LoopOil to Diverter Manifold ZZZ-110Indirect Fired Line Heater BAP-1015K/2K PSISP-101Arctic Mobile Well Test Trailer10K PSI Choke Manifold*Not in Service*3" 150210K PSI Data HeaderFrom Well Head Connection 4-1/16 5K To Expro4-1/16 10K400 BBL Atmospheric Tank Sand / Relief TankABJ-401Defoamer Chemical InjectionPBA-110DemulsifierChemical InjectionPBA-1091,440 PSI Gas ScrubberMBF-103Bleed Trailer100' Flare StackPropane TanksRemote Ignition Panel10K PSI Ball CatcherSP-001CI106CI1053" 1502 10K PSI Data Header1,440 PSI HP SeparatorMBD-102Sample Ports (SP): SP-105-H2S Sampling (Gastec)SP-106- CO2 Sampling (Gastec)- Gas SG (Ranarex)SP-103SP-105SP-106Sample Ports (SP): SP-001- Sample pull in 1000mLNalgene BottleSTEAM LINEWATER LINESTEAM LINEWATER LINEABCD1234ABCD1234ABCD1234ABCD1234LEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINEWELL TESTINGPROCESS & FLOW DIAGRAMPage 01 of 05Santos – Pikka Development2024 CampaignNameChristopher CarterRoger IhdeDate12/16/202412/16/2024DrawnReviewApprove WT-XAK-30127.4_Rev E12/17/2024DRAWING IDUNCONTROLLED COPYUNCONTROLLED COPY10K PSI Choke Manifold3" 150210K PSI Data HeaderSand to A-Tank ABJ-402Diaphragm PumpMethanol (MeOH) Chemical Injection PBA-105**Contingency**H2S Scavenger Chemical InjectionPBA-1114" FIG 1502Demulsifier Chemical Injection PBA-106*Contingency*Sample Ports (SP):SP-101- Water for Lab Analysis; 3x 1LNalgen for last 12 Hours ofFlowSP-103- Oil API (Anton Paar)- Oil Sampling (TracerCo)- Oil Sampling for Lab Analysis100mL After 1 Day of Crude toSurfaceRelief to A-Tank ABJ-40210K PSI CyFl Desander/ Filter DPIMAJ-1044" High Pressure Test Header4" Flare Low Pressure Test HeaderSharon OyaoWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 106 Cold VentSTEAM LINEWATER LINESTEAM LINEWATER LINEABCD1234ABCD1234ABCD1234ABCD1234LEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINEWELL TESTINGPROCESS & FLOW DIAGRAMPage 02 of 05Santos – Pikka Development2024 CampaignNameChristopher CarterRoger Ihde Sharon OyaoDate12/16/202412/16/2024DrawnReviewApprove WT-XAK-30127.4_Rev E12/17/2024DRAWING ID``From Diesel Vac Truck400 BBL Atmospheric TankSand/Drain and Relief TankABJ-402367 BBL Atmospheric Tank Tank DDiesel StorageBBJ-811Diesel Tee’d to Suction Manifold ZZZ-112 OutletUNCONTROLLED COPYUNCONTROLLED COPYSand from Scrubber & SeparatorRelief from Scrubber & SeparatorWT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 107 WELL TESTINGPROCESS & FLOW DIAGRAMPage 04 of 04Santos – Pikka Development NDB-024 WellNameSharon OyaoDateRev A_DR 02Prep.Rev.APP. WT-XAK-30127.2_Rev A_DR 02IDSTEAM LINEWATER LINESTEAM LINEWATER LINEABCD1234ABCD1234ABCD1234ABCD1234LEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINEWELL TESTINGPROCESS & FLOW DIAGRAMPage 03 of 05Santos – Pikka Development2024 CampaignNameChristopher CarterRoger Ihde Sharon OyaoDate12/16/202412/16/2024DrawnReviewApprove WT-XAK-30127.4_Rev E12/17/2024DRAWING IDT1- 367 BBL Atmospheric TankBBJ-801T2 - 367 BBL Atmospheric Tank BBJ-802T3 - 367 BBL Atmospheric TankBBJ-803T4- 367 BBL Atmospheric TankBBJ-804T5 - 367 BBL Atmospheric Tank BBJ-805Diverter Manifold 1 –InletZZZ-110Cold VentCold VentCold VentCold VentCold VentTo Diverter Manifold ZZZ-112To Diverter Manifold ZZZ-111From SeparatorUNCONTROLLED COPYUNCONTROLLED COPYT6- 367 BBL Atmospheric TankBBJ-806Cold VentFrom Diverter Manifold ZZZ-111To Suction Manifold ZZZ-112WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 108 STEAM LINEWATER LINESTEAM LINEWATER LINEABCD1234ABCD1234ABCD1234ABCD1234LEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINEWELL TESTINGPROCESS & FLOW DIAGRAMPage 04 of 05Santos – Pikka Development2024 CampaignNameChristopher CarterRoger Ihde Sharon OyaoDate12/16/202412/16/2024Drawn ReviewApprove WT-XAK-30127.4_Rev E12/17/2024DRAWING IDT7 - 367 BBL Atmospheric Tank BBJ-807T8 - 367 BBL Atmospheric TankBBJ-808T9- 367 BBL Atmospheric TankBBJ-809T10 - 367 BBL Atmospheric Tank BBJ-810Diverter Manifold 2 –InletZZZ-111Cold VentCold VentCold VentCold VentFromDiverter Manifold 1 – InletZZZ-110From A-TanksBBJ-801BBJ-802BBJ-803BBJ-804BBJ-805BBJ-806Diverter Manifold 1 -Suction ZZZ-112Diverter Manifold 2 -Suction ZZZ-113FromDiesel TankBBJ-811Disposal Injection Pump 1LRS Triplex Magtec Transfer Pump & Filtration UnitFilter PodsTo Storage Tank Farm BBJ-812– BBJ-816UNCONTROLLED COPYUNCONTROLLED COPYTo A-Tank BBJ-806To Disposal Well NDBi-014Transfer PumpPBA-112*Contingency*To DisposalWell NDBi-018WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 109 ABCD1234ABCD1234ABCD1234ABCD1234STEAM LINEWATER LINESTEAM LINEWATER LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINEWELL TESTINGPROCESS & FLOW DIAGRAMPage 05 of 05Santos – Pikka Development2024 CampaignNameChristopher Carter Roger Ihde Sharon Oyao Date12/16/202412/16/2024Drawn ReviewApprove WT-XAK-30127.4_Rev E12/17/2024DRAWING IDUNCONTROLLED COPYUNCONTROLLED COPYS1– 400 BBLAtmospheric Storage TankBBJ-812Cold VentS2– 400 BBLAtmospheric Storage TankBBJ-813Cold VentS3– 400 BBLAtmospheric Storage TankBBJ-814Cold VentS4– 367 BBLAtmospheric Storage TankBBJ-815Cold VentS5– 367 BBLAtmospheric Storage TankBBJ-816Cold VentFrom Magtec Transfer PumpMagtec Manifold ZZZ-114Magtec Manifold ZZZ-115TTLAVac Truck 1Vac Truck 2Vac Truck 3WT-XAK-0127.4_NDB-025_Rev Awww.expro.comPage 110 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDB-025 (50-103-20877-0000) Final Well data Submittal - Details on following pages. Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 shannon.koh@santos.com DATE: 11/7/2024 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Gavin Gluyas 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: 224-006 T39754 11/7/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.07 15:03:15 -09'00' LETTER OF TRANSMITTAL جؐؐؐDirectional Survey ؒ NDB-025 Definitive Compass Survey Report - NAD27.pdf ؒ NDB-025 Definitive Compass Survey Report - NAD83.pdf ؒ NDB-025 Definitive Survey - NAD27.txt ؒ NDB-025 Definitive Survey - NAD83.txt ؒ NDB-025 Definitive Survey Report.xlsx ؒ NDB-025 Plan View.pdf ؒ NDB-025 Vertical Section View.pdf ؒ جؐؐؐLog Digital Data and Plots (LWD) ؒ جؐؐؐDigital Data ؒ ؒ جؐؐؐAP ؒ ؒ ؒ NDB-025_AP_R01_RM.las ؒ ؒ ؒ NDBi-025_AP_R02_RM.las ؒ ؒ ؒ NDBi-025_AP_R03_RM.las ؒ ؒ ؒ ؒ ؒ جؐؐؐFE ؒ ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_5MD.las ؒ ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_BROOH_5MD.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ NDB-025_DMD_RM_13886ft.las ؒ ؒ NDB-025_DMT_R01_RM.las ؒ ؒ NDB-025_DMT_R02_RM.las ؒ ؒ NDB-025_DMT_R03_RM.las ؒ ؒ ؒ جؐؐؐGeoscience deliverables ؒ ؒ ؤؐؐؐSoundTrak- Acoustic Data ؒ ؒ جؐؐؐCBL ؒ ؒ ؒ NDB-025_9_625_Liner_Baker_Hughes_CBL_Final Report.pdf ؒ ؒ ؒ NDB-025_LWD_SDTK_CBL_4500_8450.cgm ؒ ؒ ؒ NDB-025_LWD_SDTK_CBL_4500_8450.dlis ؒ ؒ ؒ NDB-025_LWD_SDTK_CBL_4500_8450.las ؒ ؒ ؒ NDB-025_LWD_SDTK_CBL_4500_8450.PDF ؒ ؒ ؒ NDB-025_LWD_SDTK_CBL_4500_8450_dlis.txt ؒ ؒ ؒ ؒ ؒ ؤؐؐؐTOC ؒ ؒ NDB-025_LWD_SDTK_TOC_4500_8450.cgm ؒ ؒ NDB-025_LWD_SDTK_TOC_4500_8450.dlis ؒ ؒ NDB-025_LWD_SDTK_TOC_4500_8450.las ؒ ؒ NDB-025_LWD_SDTK_TOC_4500_8450.PDF ؒ ؒ NDB-025_LWD_SDTK_TOC_4500_8450_dlis.txt LETTER OF TRANSMITTAL ؒ ؒ ؒ ؤؐؐؐGraphic Images ؒ جؐؐؐCGM ؒ ؒ جؐؐؐFE ؒ ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_2MD.cgm ؒ ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_2TVD.cgm ؒ ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_5MD.cgm ؒ ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_5TVD.cgm ؒ ؒ ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ ؒ NDB-025_AP_RM.cgm ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ NDB-025_DMD_RM_13886ft.cgm ؒ ؒ NDB-025_DMT_RM.cgm ؒ ؒ ؒ ؤؐؐؐPDF ؒ جؐؐؐFE ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_2MD.pdf ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_2TVD.pdf ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_5MD.pdf ؒ ؒ NDB-025_LWD_GR_Res_Den_Neu_Cal_RM_13886ft_5TVD.pdf ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ NDB-025_AP_RM.pdf ؒ ؒ ؒ ؤؐؐؐVSS ؒ NDB-025_DMD_RM_13886ft.pdf ؒ NDB-025_DMT_RM.pdf ؒ ؤؐؐؐMudlog NoMudlogServices.txt 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Well Cleanup 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?Pikka NDB-025 Yes No 9. Property Designation (Lease Number): 10. Field: Pikka Nanushuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,886' 4,345' 13,880' 4,183' N/A N/A Casing Collapse Conductor Surface 2260 Intermediate 4750 Tie-Back 4750 Production 9210 Liner 9210 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Scott Leahy Contact Email:scott.leahy@santos.com Contact Phone: 907-330-4595 Authorized Title: Completions Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 11590 Tubing Grade: Tubing MD (ft): See attached packer report Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 392984, 393023, 391455, 393021 224-006 601 W 5th Avenue, Suite 600, Anchorage, AK 99501 50-103-20877-00-00 Oil Search Alaska, LLC Length Size Proposed Pools: 128' 128' P-110S TVD Burst 8,318' 11590 MD 6870 5020 6870 2,388' 4,343' 2,302' 4,340' 2,727' 8,435' 4-1/2" 128' 20"x34" 13-3/8" 9-5/8" 2,727' Tieback2,572' 5,863' 8,318' Perforation Depth MD (ft): 2,572' 8,318' 4-1/2" 10/31/24 13,880'5,595' 4-1/2" 12.6ppf 4,183' See attached packer report m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ons Specialist 10/14/2024 By Grace Christianson at 3:31 pm, Oct 14, 2024 324-598 10/31/24 4,183' SFD Fracture Stimulate BJM 10/24/24 10-404 CDW 10/21/2024 DSR-10/14/24SFD 10/23/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.25 10:55:59 -08'00'10/25/24 RBDMS JSB 102924 Page 1 of 1 Packer Set Depths - NDB-025 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Original Hole SLZXP Liner Top Hanger Packer w/centralizer 8,306.4 4,339.8 Original Hole HES Zoneguard OH Packer #12 8,862.5 4,339.3 Original Hole HES Zoneguard OH Packer #11 8,969.7 4,336.0 Original Hole HES Zoneguard OH Packer #10 9,306.7 4,325.6 Original Hole HES Zoneguard OH Packer #9 9,800.6 4,310.2 Original Hole HES Zoneguard OH Packer #8 10,301.0 4,294.8 Original Hole HES Zoneguard OH Packer #7 10,803.5 4,279.1 Original Hole HES Zoneguard OH Packer #6 11,262.8 4,265.1 Original Hole HES Zoneguard OH Packer #5 11,722.9 4,250.9 Original Hole HES Zoneguard OH Packer #4 12,182.4 4,236.6 Original Hole HES Zoneguard OH Packer #3 12,643.2 4,222.5 Original Hole HES Zoneguard OH Packer #2 13,103.8 4,207.7 Original Hole HES Zoneguard OH Packer #1 13,481.9 4,195.4 Page 1 of 20 NDB-025 Sundry Application Requirements 1. Affidavit of Notice – Attachment A 2. Plot showing well location, as well as ½ mile radius around well with all well penetrations, fractures, and faults within that radius – Attachment B 3. Identification of freshwater aquifers within ½ mile radius – There are no known underground sources of drinking water within a one-half mile radius of the current proposed well bore trajectory for NBD-025. At the NDB-025 location, the Permafrost interval extends down to approximately 1000-1400 ft and therefore, no shallow aquifer (typically found down to 400 ft depth) are located at the NDB-025 location. 4. Plan for freshwater sampling – There are no known freshwater wells proximal to the proposed operations, therefore no water sampling planned. 5. Detailed casing and cementing information – Attachment C 6. Assessment of casing and cementing operations – Attachment C 7. Casing and tubing pressure test information – Attachment D 8. Pressure ratings for wellbore, wellhead, BOPE and treating head – Attachments D and I 9. Lithological and geological descriptions of each zone – Attachment E and below Prince Creek Formation Depth/Thickness: Surface to 975 feet (ft) total vertical depth subsea (TVDSS)/ 975 ft thick Lithological Description: The Prince Creek Formation (Fm) in the Pikka Unit area consists predominantly of massive, unconsolidated sand and gravel sequence with minor clays that were deposited in a non-marine, fluvial setting. Schrader Bluff Formation (Upper, Middle, Lower) Depth/Thickness: 975 to 2,378 ft TVDSS/1,403 ft thick Lithological Description: The Schrader Bluff Fm in the Pikka Unit area was deposited in a shallow marine to shelf setting and dominantly consists of light grey claystone in the Upper Schrader Bluff (including shell fragments, lignite, and cherts), grading to a dark mudstone in the Middle Schrader and grading to a massive blocky shale in the Lower Schrader Bluff. Interbedded volcanic ash was observed and increasing from the Lower Schrader Bluff Fm. There are some thin (<15 ft), poor-quality (high clay content, low permeability) sands present in the Upper Schrader Bluff Fm within the Pikka Unit. Tuluvak Formation Depth/Thickness: 2,378 to 3,055 ft TVDSS/ 677 ft thick Hydrocarbon Zone: 2,436 to 3,055 ft TVDSS Lithological Description: The Tuluvak Fm in the Pikka Unit area consists predominantly of claystone, siltstone, and thinly interbedded sandstones deposited in a prograding, shallow marine setting, grading with depth to the deep marine shales of the Seabee Fm. Sandstones. Upper Confining Zone Name Seabee Formation Depth/Thickness: 3,055 to 3,766 ft TVDSS/ 711 ft thick Lithological Description: The Seabee Fm in the Pikka Unit area consists predominantly of claystone, shale, and volcanic tuff deposited in a deep marine setting. The base of the Seabee Fm grades into a condensed organic shale and provides an excellent seal and confining interval above the Nanushuk Fm reservoirs and also acts as a thick second overlying confining unit. Nanushuk Formation Depth/Thickness: 3,766 to 4,720 ft TVDSS/ 954 ft thick Lithological Description: The Nanushuk Fm is the primary oil production zone for the Pikka Development. This formation is a thick accumulation of fluvial, deltaic, and shallow marine deposits and is the up-dip, shelf topset equivalent of the deeper water, slope-to-basin floor Torok Fm. The Nanushuk-Torok clinoform sets sequentially 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: 4,720 to 5,619 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: Held IA Pressure (psi) IA PRV (psi) GORV (psi) Pump Trip Pressure (psi) Surface Line Pressure Test (psi) MAWP (psi) Stages 1-11 3,300 3,600 8,200 7,500 8,600 8,500 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 11.Mechanical condition of wells transecting the confining zones –NDBi-014, Qugruk 301, NDBi-044, NDBi-043, and NDBi-030 are within 1/2-mile radius of NDB-025. Additionally, NDB-037 is currently being drilled and is scheduled to be in reservoir when NDB-025 is fracture stimulated. Information regarding NDB-037 will be provided as it is available. Please see Attachment B as reference. 12.Suspected fault or fracture that may transect the confining zones. Please See Attachment B. 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 13,788 4,186 235 337 40 5,338 10 2 13,328 4,200 240 346 40 5,253 12 3 12,867 4,215 241 355 40 5,076 12 4 12,407 4,230 243 349 40 4,972 12 5 11,946 4,244 243 338 40 4,857 14 6 11,488 4,258 243 343 40 4,631 12 7 11,028 4,272 241 324 40 4,452 12 8 10,526 4,288 235 305 40 4,229 12 9 10,024 4,303 259 423 40 4,143 12 10 9,526 4,319 262 418 40 3,946 12 11 9,071 4,333 276 411 40 3,775 10 5,338 Note: Fractures are estimated to propagate along wellbore longitudinally at ~330 o. 13.Detailed proposed fracturing program –Attachments F & K 14.Well Clean Up procedure –Attachment G Section (b) Casing Pressure Test – We will not be treating through production or intermediate casing strings. Section (c) Fracture String Pressure Test –Attachment H Section (d) Pressure Relieve Valve –Attachment I Proposed Wellbore Schematic –Attachment J Attachment A Oil Search (Alaska), LLC a subsidiary of Santos Limited 900 E. Benson Blvd Anchorage, Alaska 99508 PO Box 240927 Anchorage, Alaska 99524 (T) +1 907 375 4642 —santos.com 1/2 October 7, 2024 Owners, Landowners, Surface Owners and Operators See Distribution List Colville River Area North Slope Basin, Alaska Re: Notice of Operations under 20 AAC 25.283 of Oil Search (Alaska), LLC’s Sundry Application for a Fracture Stimulation for the Proposed NDB-025 Well Dear Owner, Landowner, Surface Owner and/or Operator, Oil Search (Alaska), LLC (OSA) is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the proposed NDB-025 well. This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(1)(A) and 20 AAC 25.283(a)(1)(B). The complete application is available for review upon request. If you wish to review the application, please contact Tim Jones, Land Manager, at the following: Tim Jones Land Manager Oil Search (Alaska), LLC PO Box 240927 Anchorage, AK 99524 Direct: 907-375-4624 tim.jones3@santos.com OSA, through a search of the public record, has identified you as an Owner, Landowner, Surface Owner or Operator (as defined in AOGCC regulations) within ½ mile of the proposed NDB-025 well trajectory and fracture stimulation. Please contact me should you require additional information. Sincerely, Tim Jones Land Manager Distribution List: Alaska Division of Oil and Gas Arctic Slope Regional Corp. Kuukpik Corp. Oil Search (Alaska), LLC Repsol E&P USA LLC 2/2 Contact Information: State of Alaska CERTIFIED MAIL Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Arctic Slope Regional Corp. CERTIFIED MAIL Attn: David Knutson 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Kuukpik Corp CERTIFIED MAIL 582 E. 36th Avenue Anchorage, AK 99503 Oil Search (Alaska), LLC CERTIFIED MAIL PO Box 240927 Anchorage, AK 99524 Repsol E&P USA LLC CERTIFIED MAIL Attn: Jeremy McKee 2455 Technology Forest Blvd. The Woodlands, TX 77381 ADL 392985 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 49.84% DNR - 50.16% ADL 392984 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 50% DNR - 50% ADL 393022 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 39.48% DNR - 60.52% ADL 393021 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 19.22% DNR - 80.78% ADL 393023 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 44.08% DNR - 55.92% ADL 393019 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 33.1% DNR - 66.9% ADL 393020 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 26.59% DNR - 73.41% ADL 393016 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 33.17% DNR - 66.83% ADL 391445 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.98% DNR - 58.02% U011N006E04 U012N006E32 U011N006E05 U012N006E33 U011N006E09U011N006E08 U012N006E31 U011N006E06 U011N006E07 OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD .5-MILE BUFFER WELL TRAJECTORY TARGET BOTTOM HOLE SURFACE LOCATION SECTIONS DATE: 10/3/2024. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-PE-M_NDB25_ownership q GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDB25 WELL AREA NDBͲ025 Attachment B WELL NAME STATUS Casing SizeTop of Oil Pool Confining Layer (MD)Top of Oil Pool Confining Layer (TVDSS)Top of Cement (MD)Top of Cement (TVDSS)Top of Cement Determined ByReservoir Status Zonal IsolationCement Operations SummaryMechanical IntegrityQ-301 Abandoned9-5/8" 47# L-804042 (Nanushuk)3841 (Nanushuk) 3810'3683'logAbandoned with Cased hole cement plugsTOC 3,810' MDQ-301 was an exploration/appraisal well that was drilled in 2015. Itwas hydraulic fractured in the Nanushuk reservoir, flowed back, andplugged and abandoned in the same winter season.• The Nanushuk formation top was identified at 4042’ MD, withNanushuk target formation at 4631’ MD.• 9-5/8” Intermediate casing is set at 5241’ MD in the Nanushukreservoir. The primary cement job has the TOC at 3810’ MD (96.7 bbls13.9ppg Extended Class G), with a second stage cement job from3008’ MD to surface (187 bbls of 12.2ppg Extended Type I/II).• The 4-1/2” production liner in the Nanushuk reservoir is set at 7495’MD. The liner was P&A with a cement retainer set at 4503’ MD and 48bbls squeezed below the retainer (4-1/2” liner volume).• 3 cement abandonment plugs were set in the 9-5/8” casing:1. 1st Plug (300’ above cement retainer): 18 bbls of 15.8 ppg cementlaid above the cement retainer at 4503’.2. 2nd Plug (300’ across 13-3/8” casing shoe): A 9-5/8” bridge plug wasset at 2207’ MD (100’ below the surface casing shoe) with 19.1 bbls of15.6ppg Class G cement plug laid on top of it.Well is fully abandoned. NDBi-044 ACTIVE9-5/8" 47ppf9678 (Nanushuk)3,804 (Nanushuk) 7964 3,496 logopen hole liner for productionTOC 7,964' & packer @ 10,823' 1.9-5/8” x 13-3/8” Primary cement job a.Pump 80 bbls 12.5 ppg tuned spacer, 131 bbls 13.0 ppg 400 sxs 1.84 Ō^3/sx EconoCem Tpe I-II lead cement, and 80 bbls of 15.3 ppg 1.24 ft^3/sx Versacem Type I-II Tail. Planned TOC was ~8,350’ MD. b.No returns while displacing cement job. Wiper dart #2 was lodged in the liner running tool when it was recovered. The follow liner wiper plug was then found just below the 9-5/8” x 13-3/8” Liner top. A cleanout run was required to push the follow liner wiper plug to bottom and the shoe track was drilled out. Dynamic losses were encountered while drilling the float equipment indicating the lost circulation zone had not been isolated. c.A cement retainer was run in the hole and set at 11,010’ MD and a second cement job was pumped through the shoe d.15bbls 12.0 ppg tuned spacer and 95 bbls of 15.3 ppg 1.24 Ō^3/sx Versacem Type I-II Tail were circulated through the retainer, and 5 bblswere placed on top of the retainer. 2.9-5/8” Secondary Cement Job a.RIH and open up the Archer CŇex cement tool. Establish circulaƟon and pump 80 bbls 12.5 ppg Tuned spacer 214 bbls 15.3 ppg 1.24 Ō^3/sx Versacem Type I-II Tail. 129 bbls were lost while displacing. The LTP was set and 263 bbls of contaminated mud / cement/ spacer was circulated to surface while circulating with the Cflex running tool. An additional 5 bbls of cement was circulated out off the top of the liner when circulating with the liner running too at the top of the liner. 3.9-5/8” Cement EvaluaƟon Logs a.HES Cast tool was run in the hole on a welltec tractor. The 9-5/8” cement was logged. Showing the TOC of the primary job at 7,964' MD. 01/30/24, 9-5/8" casing pressure tested to 4284 psi for 30 minutesNDBi-043 ACTIVE9-5/8" 47ppf4,955 (Nanushuk)3,795 (Nanushuk) 2,792 2,730 logopen hole liner for injectionTOC 2,792 MD' & packer @ 6,071'Lead: 277bbls of 12ppg Tail: 44bbls of 15.3ppg8/21/23, 9-5/8" casing pressure tested to 4,200 psi for 30 minutes WELL NAME STATUS Casing SizeTop of Oil Pool Confining Layer (MD)Top of Oil Pool Confining Layer (TVDSS)Top of Cement (MD)Top of Cement (TVDSS)Top of Cement Determined ByReservoir Status Zonal IsolationCement Operations SummaryMechanical IntegrityNDBi-030 ACTIVE9-5/8" 47ppf9653 (Nanushuk)3,796 (Nanushuk) 9950 3,831 logopen hole liner for productionTOC 9,950' & packer @ 11,014' 1.9-5/8” x 13-3/8” Primary cement job a.Pump 80 bbls 12.5 ppg tuned spacer, 206bbls 15.3 ppg 1.24 Ō^3/sx Versacem Type I-II Tail. Planned TOC was ~8,450’ MD. b.Liner wiper plug system failure. When lower liner wiper plug landed on landing collar, plug bumped leaving all cement inside 9-5/8" liner. A cleanout run was required to drill out all cement and the landing collar was drilled out. c.A cement retainer was run in the hole and set at 11,160’ MD and a second cement job was pumped through the shoe. Diĸculty establishinggood circulation due to 80 bbls of water based 12.5ppg spacer left against formation from initial cement job. d.78bbls 12.5 ppg tuned spacer and 205 bbls of 15.3 ppg 1.24 Ō^3/sx Versacem Type I-II Tail was circulated through the retainer, and 3 bbls were placed on top of the retainer. Lost 110 bbls after cement entered annulus. 2.9-5/8” 2nd Stage Cement Job a.RIH and open up the Archer CŇex cement tool. Establish circulaƟon and pump 80 bbls 12.5 ppg MudŇush Spacer, 78 bbls 13.5 ppg Tuned spacer 252 bbls 15.3 ppg 1.24 ft^3/sx Versacem Type I-II Tail. No losses pumping cement and 26 bbls were lost while displacing. The LTP was setand 50 bbls of cement was circulated to surface while circulating with the Cflex running tool. 3.9-5/8” Cement EvaluaƟon Log a.Baker SoundTrak CBL tool was used to log cement aŌer drilling out cement retainer and Ňoat shoe. The 9-5/8”1st stage cement was loggedshowing the TOC of the primary job at 9,950' MD. Top of hydrocarbon bearing zone in the Nanushuk was in the NT7 at 10,240' MD.03/26/24, 9-5/8" casing pressure tested to 4150 psi for 30 minutesNDBi-014 ACTIVE9-5/8" 47ppf7677 (Nanushuk)3799 (Nanushuk) 7739 3,817 logopen hole liner for productionTOC 7,739' & packer @ 10,257' 1.9-5/8” x 13-3/8” Primary cement job a.Pump 80 bbls 13.5 ppg tuned spacer, 270 bbls of 15.3 ppg 1.24 Ō^3/sx Versacem Type I-II Tail. Planned TOC was ~6,820’ MD. b.Displace with rig pumps, adjusƟng rate to manage losses. Total losses from cement exit shoe to cement in place = 75 bbls. 2.9-5/8” Secondary Cement Job - stage collar located at base of Tuluvak formaƟon (5,140' MD) a.RIH and open up the Archer CŇex cement tool. Establish circulaƟon and pump 80 bbls 12.5 ppg Mud Flush spacer, 80 bbls of 13.5 ppg Tuned Spacer, 305 bbls 15.3 ppg 1.24 ft^3/sx Versacem Type I-II Tail. Slight losses reported but reduced with lower displacement rate. The LTP was set and 104 bbls of contaminated cement was circulated to surface while circulating with the Cflex running tool. 3.9-5/8” Cement EvaluaƟon Logs a.Baker SoundTrak CBL tool was used to log cement aŌer drilling the ProducƟon Hole. The 9-5/8” 1st stage cement was logged showing the TOC of the primary job at 7,739' MD. Top of hydrocarbon bearing zone in the Nanushuk was in the NT7 at 7,857' MD. CBL also showed adequate isolation throughout the Tuluvak with the 2nd stage cement job.2/14/24, 9-5/8" casing pressure tested to 4190 psi for 30 minutes Attachment C 9-5/8” 47# L80 HYDRIL 563 Liner Burst (Psi) Collapse (Psi) Tensil e (klbs) ID (in) Drift ID (in) Connecti on OD (in) Make-up Torque (ft-lbs) Make-Up Loss (in) 6870 4750 1086 8.681 8.525 10.625 15800 4.050 Intermediate Liner Cement Job Execution Cement job pumped following the Halliburton Cementing Program Well Design x 13-3/8” Casing Shoe: 2,727’ MD x 9-5/8” x 13-3/8” Liner top: 2,572’ MD x 9-5/8” Liner Shoe: 8,435 MD x 9-5/8” Archer Cflex Mechanical Stage tool: 3,854’ MD Geology x Top of Tuluvak TS 790 formation at 3,739’ MD. Significant hydrocarbons are contained only within the upper Tuluvak in the Tuluvak Sand (2,994’ MD). Top of the Nanushuk picked at 6,180 MD. Cement Job Planning/Execution See attached cementing reports starting on the next page for a summary of the work performed. Observations For the 1st stage of the cement job, we have adequate isolation in the upper Nanushuk formations across the hydrocarbon-bearing formations, and well above the planned TOC at 5,567’ MD (250’ TVD above top Nanushuk). This is supported by the CBL log, which indicates good cement throughout the first stage and an estimated TOC at 4,500’ MD. It should be noted that a clear TOC was not logged with the Sonic tool, as partial cement presence was still evident at the top of the logged interval (9-5/8” shoe to 4,500’ MD). The transition from good cement to partial cement was noted at 4,820’ to 4,500’ MD. o TOC was called at 4,500’ MD, as this is the top of the logged interval. o Approval to proceed without a clear TOC on the CBL was received from Mel Rixse with the AOGCC on 10/11/2024. For the 2nd stage of the cement job, based on job execution results, cement isolation was achieved across the significant hydrocarbon zone within the upper Tuluvak formation. Our assessment is that we have adequate isolation across hydrocarbon-bearing formations in the upper Nanushuk formations, as well as adequate isolation for frac operations. The 2 nd stage cement job yielded adequate isolation below, across and above the Tuluvak significant hydrocarbons. Page 1 of 1 Cement - NDB-025 Surface Casing Cement Surface Casing Cement, Casing, 9/24/2024 06:00 Type Casing Cementing Start Date 9/24/2024 Cementing End Date 9/24/2024 Wellbore Original Hole String Surface Casing, 2,727.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results Total displacement volume 391 bbls (measured by strokes at 96% pump efficiency). Observed 185 bbls of cement, 70 bbls of Spacer and 70 bbls of Interface returned to surface. Total losses from cement exit shoe to cement in place ~17 bbls (6 bbls with cement around shoe, 11 bbls during displacement). Comment Cement 13-3/8” Surface Casing as follows: - PJSM with cementers, rig crew and trucking lead. - Fill lines with 5 bbls water and conduct low followed by 4,500 psi high pressure test, no leaks or bleeds, good test. - Install 1st Bottom Non-Rotating Plug. - Pump 76 bbls of 10.5 ppg Tuned Spacer at 4.9 bpm, 240 psi, full returns, MW out 9.6 ppg. - Release 2nd Bottom Non-Rotating Plug. - Pump 405 bbls of 11.0 ppg ArcticCem lead cement at 5 bpm, Excess Volume 200% (897 sacks, yield 2.53 cu ft/sk); initial rate of 6 bpm but encountered slight losses during pumping so lowered rate to 5 bpm. - Pump 69 bbls of 15.3 ppg Type I/II tail at 5.3 bpm, Excess Volume 50% (312 sacks, yield 1.24 cu ft/sk). - Drop top plug and chase with 20 bbls water from cementers. - Perform displacement with rig pumps and 9.6 ppg water base mud. - 28 bbls displaced at 8 bpm: ICP 200 psi, FCP 300 psi, slight losses during displacement. - 67 bbls displaced at 6 bpm: ICP 300 psi, FCP 333 psi with losses. - Reduce rate to 5 bpm, losses stopped; displace 242 bbls at this rate, ICP 348 psi, FCP 705 psi. - Reduce rate to 4 bpm, 675 psi 20 bbls prior to bump, FCP 773 psi. - Reduce rate to 3 bpm, 745 psi 10 bbls prior to plug bump, final circulating pressure 760 psi prior to plug bump. - Bump plug, increase pressure to 1,290 psi, check floats – good. - CIP @ 1040 hrs. 1, 0.0-2,727.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 2,727.0 Full Return? Yes Vol Cement Ret (bbl) 185.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 6 Final Pump Rate (bbl/min) 5 Avg Pump Rate (bbl/min) 5 Final Pump Pressure (psi) 760.0 Plug Bump Pressure (psi) 1,290.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Tuned Spacer Amount (sacks) Class Tuned Volume Pumped (bbl) 80.0 Estimated Top (ftKB) 0.0 Percent Excess Pumped (%) Yield (ft³/sack) 1.72 Mix H20 Ratio (gal/sack) 11.51 Free Water (%) 0.00 Density (lb/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Lead Fluid Type Lead Fluid Description ArcticCem Amount (sacks) 897 Class ArcticCem Volume Pumped (bbl) 405.0 Estimated Top (ftKB) 0.0 Percent Excess Pumped (%) 200.0 Yield (ft³/sack) 2.54 Mix H20 Ratio (gal/sack) 12.21 Free Water (%) 0.00 Density (lb/gal) 11.00 Plastic Viscosity (cP) 14.3 Thickening Time (hr) 13.50 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 36.00 Tail Fluid Type Tail Fluid Description Tail Amount (sacks) 312 Class Type I/II Volume Pumped (bbl) 69.0 Estimated Top (ftKB) 0.0 Percent Excess Pumped (%) 50.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.66 Free Water (%) 0.30 Density (lb/gal) 15.30 Plastic Viscosity (cP) 24.8 Thickening Time (hr) 4.40 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 14.40 Page 1 of 1 Cement - NDB-025 Intermediate Casing Cement - 1st Stage Intermediate Casing Cement - 1st Stage, Casing, 10/1/2024 18:00 Type Casing Cementing Start Date 10/1/2024 Cementing End Date 10/1/2024 Wellbore Original Hole String Intermediate Liner, 8,435.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Baker Soundtrack LWD Cement Evaluation Results Comment PJSM with Third party and rig personnel for 1st stage cement job. - Pump 5 bbls water & Pressure test cement lines to 1,000 psi low 5000 psi High. - Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A - (65 gallons each) downhole at 4 bpm with 440 psi, - Release bottom pump down plug for bottom plug, chase with 15.3 ppg Versacem Tail Cement Type I/II at 4 bpm, initial circulating pressure 533 psi. - Continue to chase with 15.3 ppg Versacem Tail Cement Type I/II, pump total of 224 bbls at average of 4 bpm, 430 psi, excess volume 30% - Release top pump down plug, chase with 20 bbls of water from Halliburton. - No losses observed while pumping cement - Perform displacement with rig pumps, displace with 12 ppg OBM at 4 bpm, ICP 300 psi, FCP 700 psi. - Top pump down dart latch up confirmed at 34 bbls displaced. - Continue to displace with 12 ppg OBM, reduce rate to 3 bpm prior to plug bump: Final circulating pressure 700 psi. pressured up 500 psi over FCP 1,200 psi held 5 min, bled off checked floats. Floats held. - Total displacement volume 481 bbls (measured by strokes at 96% pump efficiency). CIP @ 22:00 hrs. - Total losses from cement exit shoe to cement in place: 0 bbls 1, 5,567.0-8,440.0ftKB Top Depth (ftKB) 5,567.0 Bottom Depth (ftKB) 8,440.0 Full Return? No Vol Cement Ret (bbl) Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 700.0 Plug Bump Pressure (psi) 700.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Tuned Spacer with Surfactant B and Musol A, 4# Red Dye Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.24 Mix H20 Ratio (gal/sack) 13.09 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Tail Fluid Type Tail Fluid Description Versacem Type I/II Amount (sacks) 1,019 Class I/II Volume Pumped (bbl) 224.0 Estimated Top (ftKB) 5,567.0 Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.56 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 129.0 Thickening Time (hr) 7.75 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 14.00 Page 1 of 1 Cement - NDB-025 Intermediate Casing Cement - 2nd Stage Intermediate Casing Cement - 2nd Stage, Casing, 10/2/2024 13:30 Type Casing Cementing Start Date 10/2/2024 Cementing End Date 10/2/2024 Wellbore Original Hole String Intermediate Liner, 8,435.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results Observed 65 bbls clean cement, 90 bbls spacer, 70 bbls interface returned to surface. Comment Cement 9-5/8” 47# Intermediate casing by open hole annulus through Archer cementing tool as follows: -Mix and pump 80 bbls of 12.5 ppg Mud Flush at 4 bpm, ICP 315 psi, FCP 210 psi, full returns (both spacers with Surfactant B and Musol A). -Mix and pump 80 bbls of 13.5 Tuned Spacer at 3.95 bpm, 215 psi, full returns. -Mix and pump 132 bbls of 15.3 ppg Versacem Type I-II Tail cement at 3.2 bpm, ICP 310 psi, FCP 305 psi, full returns throughout job. -Excess Volume 100% (599 sacks, yield 1.237 cu ft/sk). -Begin displacing with 20 bbls fresh water from cementing unit. -Continue to displace with 67.6 bbls 12.0 ppg OBM using rig pumps. -Displace to calculated volume of 87.6 bbls to Archer Stage Collar. -Displace at 5 bpm, 400 psi ICP, 484 FCP before slowing rate, 100% returns; FCP at 3 bpm, 468 psi. -Down on pumps, 290 psi held on drill pipe. -0 bbls lost during displacement. -CIP at 15:30 hrs. 2, 2,598.0-3,850.0ftKB Top Depth (ftKB) 2,598.0 Bottom Depth (ftKB) 3,850.0 Full Return? Yes Vol Cement Ret (bbl) 65.0 Top Plug? No Bottom Plug? No Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 468.0 Plug Bump Pressure (psi) Pipe Reciprocated? No Reciprocation Stroke Length (ft) 0.00 Reciprocation Rate (spm) 0 Pipe Rotated? No Pipe RPM (rpm) 0 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Mud Flush Spacer Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.22 Mix H20 Ratio (gal/sack) 12.89 Free Water (%) 0.00 Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Spacer Fluid Type Spacer Fluid Description Tuned Spacer Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 10.72 Free Water (%) 0.00 Density (lb/gal) 13.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Tail Fluid Type Tail Fluid Description Versacem Type I/II Amount (sacks) 599 Class Type I/II Volume Pumped (bbl) 132.0 Estimated Top (ftKB) Percent Excess Pumped (%) 100.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.56 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 140.3 Thickening Time (hr) 7.53 1st Compressive Strength (psi) 100.0 CmprStr Time 1 (hr) 15.95 Attachment D Attachment E Attachment F Well NameNDB-2510/08/24 Preliminary DesignSTAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT#TYPEPPTRATESTAGECUMSTAGE CUMSTAGECUM SIZEStageCumPre Frac - Non Proppant stages(BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL)aFPbFPcWF 253.54040168016804040d Pump CheckWF25 4024028010080117602402800280eDFITWF25 40250530 10500 22260 250 53005300530 PUMP DIRTY VOLUME DIRTY VOLUME PROPPANTCLEAN VOLUM STAGEAVERAGEFLUIDRATESTAGECUMTOT JOBSTAGECUMSTAGECUM Size orStageCum#PPATYPE(BPM)(BBL)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)Type(BBL)(BBL)10Line out XL XL 25214040 5701680 168000 4057020Stage 1 PAD (PS)XL 2540 225265 7959450 1113000CSG-IV225 79531ScourXL 2540 60325 8552520 136502413 241340/70-CL57 85243ScourXL 2540 120445 9755040 1869013348 1576140/70-CL106 95850Resume PadXL 2540 50495 10252100 207900 15761 50 100861FlatXL 2540 190685 12157980 287707641 23402CSG-IV182 119073FlatXL 2540 210895 14258820 3759023349 46752CSG-IV185 137685FlatXL 2540 2351130 16609870 4746040384 87135CSG-IV192 156897FlatXL 2540 2351365 18959870 5733052707 139842CSG-IV179 1747109FlatXL 2540 2201585 21159240 6657059415 199257CSG-IV157 19041110FlatXL 2540 1901775 23057980 7455055261 254519CSG-IV132 2036120Clear Surface LinesXL 2540 151790 2320630 751800 254519 15 2051130Spacer XL 2540151805 2335630 758100 254519 15 2066140Drop Ball/Collet #1 FP 04031808 2338126 759360254519 32069150Stage 2 PAD (CS#1)XL 2540 1731981 25117266 832020 254519 173 2242160Slow for Seat XL 2518502031 25612100 853020254519 502292170Resume PadXL 2540 772108 26383234 885360254519 772369181FlatXL 2540 1802288 28187560 960967239 261757CSG-IV172 2541192FlatXL 2540 2002488 30188400 10449615430 277187CSG-IV184 2725204FlatXL 2540 2202708 32389240 11373631385 308572CSG-IV187 2912216FlatXL 2540 2202928 34589240 12297643777 352349CSG-IV174 3086228FlatXL 2540 2203148 36789240 13221654544 406893CSG-IV162 32482310FlatXL 2540 2003348 38788400 14061658170 465062CSG-IV138 33862412FlatXL 2540 1803528 40587560 14817659183 524246CSG-IV117 3504250Clear Surface LinesXL 2540 153543 4073630 1488060524246 153519260Spacer XL 2540153558 4088630 1494360524246 153534270Drop Ball/Collet #2 FP 04033561 4091126 1495620524246 33537280Stage 3 PAD (CS#2)XL 2540 1663727 42576972 1565340 524246 166 3703290Slow for Seat XL 2518503777 43072100 1586340524246 503753300Resume PadXL 2540 843861 43913528 1621620524246 843837311FlatXL 2540 1804041 45717560 1697227239 531484CSG-IV172 4009322FlatXL 2540 2004241 47718400 17812215430 546914CSG-IV184 4193FLUIDNeat WaterCOMMENTSSD monitor 30 minPrime and Pressure TestOpen well and open initiator sleeveDisplace PT - Shut down 5 minLoad Stage 1 ball/collet, SD monitor 1H, line up for XL Well NameNDB-2510/08/24 Preliminary DesignSTAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT#TYPEPPTRATESTAGECUMSTAGE CUMSTAGECUM SIZEStageCumPre Frac - Non Proppant stages(BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL)FLUIDNeat Water334FlatXL 2540 2204461 49919240 18736231385 578299CSG-IV187 4380346FlatXL 2540 2204681 52119240 19660243777 622076CSG-IV174 4553358FlatXL 2540 2204901 54319240 20584254544 676620CSG-IV162 47163610FlatXL 2540 2005101 56318400 21424258170 734790CSG-IV138 48543712FlatXL 2540 1805281 58117560 22180259183 793973CSG-IV117 4972380Clear Surface LinesXL 2540 155296 5826630 2224320793973 154987390Spacer XL 2540155311 5841630 2230620793973 155002400Drop Ball/Collet #3 FP 04035314 5844126 2231880793973 35005410Stage 4 PAD (CS#3)XL 2540 1595473 60036678 2298660 793973 159 5164420Slow for Seat XL 2518505523 60532100 2319660793973 505214430Resume PadXL 2540 915614 61443822 2357880793973 915305441FlatXL 2540 2005814 63448400 2441888043 802016CSG-IV191 5496452FlatXL 2540 2206034 65649240 25342816973 818989CSG-IV202 5698464FlatXL 2540 2406274 680410080 26350834239 853227CSG-IV204 5902476FlatXL 2540 2506524 705410500 27400849746 902973CSG-IV197 6099488FlatXL 2540 2506774 730410500 28450861982 964955CSG-IV184 62844910FlatXL 2540 2206994 75249240 29374863987 1028942CSG-IV152 64365012FlatXL 2540 2007194 77248400 30214865759 1094701CSG-IV130 6567510Clear Surface LinesXL 2540 157209 7739630 3027780 1094701 15 6582520Spacer XL 2540157224 7754630 3034080 1094701 15 6597530Drop Ball/Collet #4 FP 04037227 7757126 3035340 1094701 3 6600540Stage 5 PAD (CS#4)XL 2540 1527379 79096384 3099180 1094701 152 6752550Slow for Seat XL 2518507429 79592100 3120180 1094701 50 6802560Resume PadXL 2540 987527 80574116 3161340 1094701 98 6900571FlatXL 2540 1607687 82176720 3228546434 1101135CSG-IV153 7053582FlatXL 2540 1757862 83927350 33020413501 1114636CSG-IV161 7214594FlatXL 2540 1908052 85827980 33818427106 1141742CSG-IV161 7375606FlatXL 2540 1908242 87727980 34616437807 1179549CSG-IV150 7525618FlatXL 2540 1908432 89627980 35414447106 1226655CSG-IV140 76656210FlatXL 2540 1908622 91527980 36212455261 1281916CSG-IV132 77976312FlatXL 2540 1758797 93277350 36947457540 1339456CSG-IV114 79116414FlatXL 2540 1508947 94776300 37577454388 1393844CSG-IV92 8003650Clear Surface LinesXL 2540 158962 9492630 3764040 1393844 15 8018660Spacer XL 2540158977 9507630 3770340 1393844 15 8033670Drop Ball/Collet #5 FP 040158992 9522630 3776640 1393844 15 8048680LG FlushWF 2540 1459137 96676090 3837540 1393844 145 8193690Slow for seat WF 2518509187 97172100 3858540 1393844 50 8243700Overflush/ MT PCMWF 254020093879917840039425401393844200844371Linear FlushWF 25201 9388 966842 4165561 844472Linear FlushWF 25201 9389 966942 4165981 8445733000 feet MD + Surface EqmtFP20 589447 97272423 419021TOTALS9977 4190211393844 Well NameNDB-2510/08/24 Preliminary DesignSTAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT#TYPEPPTRATESTAGECUMSTAGE CUMSTAGECUM SIZEStageCumPre Frac - Non Proppant stages(BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL)FLUIDNeat WaterSD and obtain ISIP & 15 min SIP. Well NameNDB-2510/08/24 Preliminary DesignSTAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT#TYPEPPTRATESTAGECUMSTAGE CUMSTAGECUM SIZEStageCumPre Frac - Non Proppant stages(BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL)aFPbWF 253.54000000cPump Ball to SeatWF25 417517573507350175175dPump CheckWF25 4010010042001155010027502750275 PUMP DIRTY VOLUME DIRTY VOLUME PROPPANTCLEAN VOLUM STAGEAVERAGEFLUIDRATESTAGECUMTOT JOBSTAGECUMSTAGECUM Size orStageCum#PPATYPE(BPM)(BBL)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)Type(BBL)(BBL)10Line out XL XL 25404040 2151680 168000 4031520Stage 6 PAD (CS#5)XL 2540 300340 51512600 1428000CSG-IV300 61531FlatXL 2540 200540 7158400 226808043 8043CSG-IV191 80642FlatXL 2540 220760 9359240 3192016973 25016CSG-IV202 100954FlatXL 2540 2401000 117510080 4200034239 59254CSG-IV204 121266FlatXL 2540 2501250 142510500 5250049746 109000CSG-IV197 141078FlatXL 2540 2501500 167510500 6300061982 170982CSG-IV184 1594810FlatXL 2540 2201720 18959240 7224063987 234969CSG-IV152 1747912FlatXL 2540 2001920 20958400 8064065759 300728CSG-IV130 1877100Clear Surface LinesXL 2540 151935 2110630 812700300728 151892110Spacer XL 2540151950 2125630 819000300728 151907120Drop Ball/Collet #6 FP 04031953 2128126 820260 300728 3 1910130Stage 7 PAD (CS#6)XL 2540 1382091 22665796 878220 300728 138 2048140Slow for Seat XL 2518502141 23162100 899220300728 502098150Resume PadXL 2540 872228 24033654 935760300728 872185161FlatXL 2540 1802408 25837560 1011367239 307967CSG-IV172 2357172FlatXL 2540 2002608 27838400 10953615430 323396CSG-IV184 2541184FlatXL 2540 2202828 30039240 11877631385 354782CSG-IV187 2728196FlatXL 2540 2203048 32239240 12801643777 398558CSG-IV174 2902208FlatXL 2540 2203268 34439240 13725654544 453102CSG-IV162 30642110FlatXL 2540 2003468 36438400 14565658170 511272CSG-IV138 32022212FlatXL 2540 1803648 38237560 15321659183 570455CSG-IV117 3320230Clear Surface LinesXL 2540 153663 3838630 1538460570455 153335240Spacer XL 2540153678 3853630 1544760570455 153350250Drop Ball/Collet #7 FP 04033681 3856126 1546020 570455 3 3353260Stage 8 PAD (CS#7)XL 2540 1303811 39865460 1600620 570455 130 3483270Slow for Seat XL 2518503861 40362100 1621620570455 503533280Resume PadXL 2540 703931 41062940 1651020570455 703603291FlatXL 2540 1504081 42566300 1714026032 576487CSG-IV144 3747302FlatXL 2540 1754256 44317350 17875213501 589988CSG-IV161 3907314FlatXL 2540 1904446 46217980 18673227106 617094CSG-IV161 4069326FlatXL 2540 1904636 48117980 19471237807 654901CSG-IV150 4219338FlatXL 2540 1904826 50017980 20269247106 702007CSG-IV140 4359FLUIDNeat WaterCOMMENTSPrime and Pressure TestDisplace PT - Shut down 10 minDrop Ball-SD 10 minutesLoad ball/collet#6 (Stage 7), Stage to Line out XL Well NameNDB-2510/08/24 Preliminary DesignSTAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT#TYPEPPTRATESTAGECUMSTAGE CUMSTAGECUM SIZEStageCumPre Frac - Non Proppant stages(BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL)FLUIDNeat Water3410FlatXL 2540 1905016 51917980 21067255261 757268CSG-IV132 44903512FlatXL 2540 1605176 53516720 21739252608 809876CSG-IV104 4595360Clear Surface LinesXL 2540 155191 5366630 2180220809876 154610370Spacer XL 2540155206 5381630 2186520809876 154625380Drop Ball/Collet #8 FP 04035209 5384126 2187780 809876 3 4628390Stage 9 PAD (CS#8)XL 2540 1225331 55065124 2239020 809876 122 4750400Slow for Seat XL 2518505381 55562100 2260020809876 504800410Resume PadXL 2540 285409 55841176 2271780809876 284828421ScourXL 2540 605469 56442520 2296982413 81228940/70- CL57 4885433ScourXL 2540 1205589 57645040 23473813348 82563740/70- CL106 4991440FlatXL 2540 505639 58142100 2368380825637 505041451FlatXL 2540 1505789 59646300 2431386032 831669CSG-IV144 5185462FlatXL 2540 1755964 61397350 25048813501 845170CSG-IV161 5345474FlatXL 2540 1906154 63297980 25846827106 872276CSG-IV161 5507486FlatXL 2540 1906344 65197980 26644837807 910083CSG-IV150 5657498FlatXL 2540 1906534 67097980 27442847106 957189CSG-IV140 57975010FlatXL 2540 1906724 68997980 28240855261 1012450CSG-IV132 59295112FlatXL 2540 1606884 70596720 28912852608 1065058CSG-IV104 6033520Clear Surface LinesXL 2540 156899 7074630 2897580 1065058 15 6048530Spacer XL 2540156914 7089630 2903880 1065058 15 6063540Drop Ball/Collet #9 FP 04036917 7092126 2905140 1065058 3 6066550Stage 10 PAD (CS#9)XL 2540 1157032 72074830 2953440 1065058 115 6181560Slow for Seat XL 2518507082 72572100 2974440 1065058 50 6231570Resume PadXL 2540 357117 72921470 2989140 1065058 35 6266581ScourXL 2540 607177 73522520 3014342413 106747140/70- CL57 6323593ScourXL 2540 1207297 74725040 30647413348 108081940/70- CL106 6429600FlatXL 2540 507347 75222100 3085740 1080819 50 6479611FlatXL 2540 1407487 76625880 3144545630 1086449CSG-IV134 6613622FlatXL 2540 1607647 78226720 32117412344 1098793CSG-IV147 6760634FlatXL 2540 1807827 80027560 32873425679 1124472CSG-IV153 6913646FlatXL 2540 1808007 81827560 33629435817 1160289CSG-IV142 7055658FlatXL 2540 1808187 83627560 34385444627 1204916CSG-IV133 71886610FlatXL 2540 1708357 85327140 35099449444 1254360CSG-IV118 73066712FlatXL 2540 1508507 86826300 35729449320 1303680CSG-IV98 7404680Clear Surface LinesXL 2540 158522 8697630 3579240 1303680 15 7419690Spacer XL 2540158537 8712630 3585540 1303680 15 7434700Drop Ball/Collet #10 FP 04038540 8715126 3586800 1303680 3 7437710Stage 11 PAD (CS#10)XL 2540 1088648 88234536 3632160 1303680 108 7545720Slow for Seat XL 2518508698 88732100 3653160 1303680 50 7595730Resume PadXL 2540 428740 89151764 3670800 1303680 42 7637741ScourXL 2540 608800 89752520 3696002413 130609340/70- CL57 7694753ScourXL 2540 1208920 90955040 37464013348 131944140/70- CL106 7800760FlatXL 2540 508970 91452100 3767400 1319441 50 7850 Well NameNDB-2510/08/24 Preliminary DesignSTAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT#TYPEPPTRATESTAGECUMSTAGE CUMSTAGECUM SIZEStageCumPre Frac - Non Proppant stages(BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL)FLUIDNeat Water771FlatXL 2540 1809150 93257560 3843007239 1326680CSG-IV172 8023783FlatXL 2540 2009350 95258400 39270022238 1348917CSG-IV176 8199795FlatXL 2540 2209570 97459240 40194037806 1386723CSG-IV180 8379807FlatXL 2540 2209790 99659240 41118049343 1436066CSG-IV168 8547819FlatXL 2540 2009990 101658400 41958054014 1490080CSG-IV143 86908210FlatXL 254018010170103457560427140523531542432CSG-IV125881483XLFlushXL 254020 10190 8717840 43953020 883484LG FlushWF 254058 10248 87752436 44196658 8892853000 feet MD + Surface EqmtFP20 5810306 88332423 444389TOTALS10581 4443891542432SD and obtain ISIP & 15 min SIP. Additive Additive Description F103 Surfactant 1.0 Gal/mGal 726.1 gal J450 Stabilizing Agent 0.5 Gal/mGal 363.0 gal J475 Breaker J475 6.0 lb/mGal 4,356.3 lbm J511 Stabilizing Agent 2.0 lb/mGal 1,452.1 lbm J532 Crosslinker 2.3 Gal/mGal 1,682.8 gal J580 Gel J580 25.0 lb/mGal 18,151.4 lbm J753 Enzyme Breaker J753 0.0 Gal/mGal 36.3 gal M117 Clay Control Agent 339.0 lb/mGal 246,120.1 lbm M275 Bactericide 0.3 lb/mGal 217.8 lbm S522-1620 Propping Agent varied concentrations 2,700,844.0 lbm S522-4070 Propping Agent varied concentrations 63,044.0 lbm S901 Proppant with Scale Inhibitor S901 varied concentrations 172,394.0 lbm ~ 65 % ~ 32 % ~ 3 % < 1 % < 1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.01 % < 0.01 % < 0.01 % < 0.01 % < 0.01 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.00001 % Total 100 % * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. Total 64-19-7 Acetic acid (impurity) 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 14464-46-1 Cristobalite 14808-60-7 Quartz, Crystalline silica 532-32-1 Sodium benzoate 7786-30-3 Magnesium chloride 127-08-2 Acetic acid, potassium salt (impurity) 9000-90-2 Amylase, alpha 9002-84-0 poly(tetrafluoroethylene) 10377-60-3 Magnesium nitrate 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 14807-96-6 Magnesium silicate hydrate (talc) 68131-39-5 Ethoxylated Alcohol 9025-56-3 Hemicellulase 91053-39-3 Diatomaceous earth, calcined 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 25038-72-6 Vinylidene chloride/methylacrylate copolymer 1303-96-4 Sodium tetraborate decahydrate 50-70-4 Sorbitol 67-63-0 Propan-2-ol 7727-54-0 Diammonium peroxodisulphate 9003-35-4 Phenolic resin 56-81-5 1, 2, 3 - Propanetriol 68715-83-3 2-Butenedioic acid (2Z)-, polymer with sodium 2-propene-1-sulfonate 7647-14-5 Sodium chloride 102-71-6 2,2`,2"-nitrilotriethanol 66402-68-4 Ceramic materials and wares, chemicals 7447-40-7 Potassium chloride 9000-30-0 Guar gum CAS Number Chemical Name Mass Fraction - Water (Including Mix Water Supplied by Client)* YF125 ST:WF125 726,054 gal † Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. Report ID: RPT-1960 Fluid Name & Volume Concentration Volume Disclosure Type: Pre-Job Well Completed: Date Prepared: 10/10/2024 State: Alaska County/Parish: North Slope Borough Case: Client: Oil Search Alaska Well: NDB-025 Basin/Field: Pikka # SLB-Private Page: 1 / 1 Updated 10/10/2024INPUTEst 9th NovAK TSCA StatusNorthSlope AKTBDPre720,14773.00000% Trade Name Supplier Purpose Ingredients Name CAS #Percentage by Mass of IngredientPercent of Ingredient in Total Mass PumpedMass of Ingredient (lbs)SMETracercoCarrier FluidSoy Methyl Ester67784-80-9100#VALUE!105.3808360000T-751TracercoChemical TracerBis(4-bromophenyl)ether2050-47-7100#VALUE!1.5432340000T-758TracercoChemical Tracer3,4-Difluorobenzophenone85118-07-6100#VALUE!0.4409240000T-756TracercoChemical Tracer3,5-Difluorobenzophenone179113-89-4100#VALUE!0.6613860000T-162ATracercoChemical Tracer1,4-Dibromobenzene106-37-6100#VALUE!1.1023100000T-706TracercoChemical Tracer1-Bromo-4-chlorobenzen106-39-8100#VALUE!2.2046200000T-164BTracercoChemical Tracer2-Bromonaphthalene580-13-2100#VALUE!1.1023100000T-160CTracercoChemical Tracer2,4,6-Tribromotoluene6320-40-7100#VALUE!0.4409240000T-161BTracercoChemical Tracer4-Iodotoluene624-31-7100#VALUE!0.4409240000T-166ATracercoChemical Tracer5-Iodo-m-xylene22445-41-6100#VALUE!1.1023100000T-750TracercoChemical Tracer1,4-Dibromo-2-fluorobenzene1435-52-5100#VALUE!0.4409240000T-772TracercoChemical Tracer2-(Trifluoromethyl)Benzophenone727-99-1100#VALUE!0.4409240000T-721TracercoChemical Tracer4,4'-Dichlorobenzophenone90-98-2100#VALUE!0.4409240000T-160BTracercoChemical Tracer3,5-Dibromotoluene1611-92-3100#VALUE!22.0462000000T-166CTracercoChemical Tracer1-Iodo-3,4-dimethylbenzene31599-61-8100#VALUE!22.0462000000T-734TracercoChemical Tracer1-Bromo-2-(trifluoromethyl)benzene392-83-6100#VALUE!22.0462000000WaterTracercoCarrier FluidWater7732-18-5100#VALUE!87.1927210000T-801TracercoChemical TracerSodium-2-chlorobenzoate17264-74-3100#VALUE!0.7716170000T-940TracercoChemical TracerSodium-2-chloro-3-methylbenzoate1708942-16-8100#VALUE!0.7716170000T-804TracercoChemical TracerSodium-2,3-dichlorobenzoate118537-84-1100#VALUE!0.7716170000T-920TracercoChemical TracerSodium-5-chloro-2-fluorobenzoate1382106-78-6100#VALUE!0.7716170000T-176cTracercoChemical TracerSodium-2,4,5-trifluorobenzoate522651-48-5100#VALUE!0.7716170000T-158eTracercoChemical TracerSodium-3,5-Difluorobenzoate530141-39-0100#VALUE!0.7716170000T-194aTracercoChemical TracerSodium-2,3,4,5-Tetrafluorobenzoate67852-79-3100#VALUE!0.7716170000T-158aTracercoChemical TracerSodium-2,4-Difluorobenzoate1765-08-8100#VALUE!0.7716170000T-943TracercoChemical TracerSodium-3-chloro-2-methylbenzoate1708942-17-9100#VALUE!0.7716170000T-921TracercoChemical TracerSodium-3-chloro-2-fluorobenzoate1421029-89-1100#VALUE!0.7716170000T-808TracercoChemical TracerSodium-3,4-dichlorobenzoate17274-10-1100#VALUE!0.7716170000T-955TracercoChemical TracerSodium-4-fluoro-2-(Trifluoromethyl)-benzoate1708942-22-6100#VALUE!0.7716170000Hydraulic Fracturing Fluid Product Component Information DisclosureManufacturer Contact Tracerco 4106 New West Dr. Pasadena Texas 77507 Tel: 281-291-7769Fracture DateState:Approved For TracercoCounty:API Number:Operator Name: Santos AKWell Name and Number: NDBi-025Report Type (Pre or Post Job)Total Water Volume (gal):Water Mass FractionTotal Mass Pumped (lbs) Attachment G NDB-025 Well Clean Up Summary Flow Periods Flowback Period Duration (hours)Purpose/Remarks Ramp Up 72-96 Bring well on slowly (16/64th) via adjustable choke, change as necessary to achieve stable flow. Monitor returns for proppant and adjust choke as necessary to avoid damage to reservoir proppant pack and minimize surface equipment erosion. Santos Subsurface Team will advise choke changes/rates during ramp up period. Clean Up 48+ Continue clean up period until there is a meaningful decline in solids volume to surface in combination with 2-3% WC. See Chart 1. Step Down 48-72 Measure well productivity and inflow performance. Build Up 240-336 Goal to identify linear-flow period after 10 hours. Table 1 Chart 1 Per regulation 20 AAC 25.235 (d) 6, Santos is requesting AOGCC permission to flare the produced gas for the duration of the development well flowback work. Total volume of gas per the flowback program outlined in Table 1 is approximately 15 MMscf. Well Flowback - Operational Summary: x Total flowback volume (including ramp up, clean up and step down periods) not to exceed 2.0X TLTR (total load to recover) from the frac job. Santos to contact AOGCC when 1.5X TLTR is recovered and provide update on solids content and WC. If necessary, additional flowback volume exceeding 2.0X TLTR may be approved if both parties agree after reviewing actual flowback data. x Target Clean Up Flow Rate: 4500 BPD & 2.2 mmscf/d. x Choke Setting: Use adjustable choke to achieve a flow rate at approximately 100 psi per hour drawdown or until well is stable. Watch BS&W and adjust drawdown rate as needed. The Santos Subsurface Team or Santos Well Test Supervisor will advise choke changes based on well performance and solids production. x Proppant Production: Proppant production is expected and will be managed by bringing on the well slowly and beaning up choke based on well performance and bottoms up solids production. x Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure is 2,000 psi, bleed down as necessary. x Sampling: Per Surface Sampling Program below in Table 2. Metering Standard Fluid Rates & Volumes - Tank Straps will be used for all reported fluid rates & volumes, in addition there will be turbine meters on the oil and water legs of the separator for reference. Gas Rates & Volumes - A micromotion Coriolis flow meter will be used for gas rates & volumes. Table 2 g Per regulation 20 AAC 25.235 (d) 6, Santos is requesting AOGCC permission to flare the produced gasg(),qgppg for the duration of the development well flowback work. Total volume of gas per the flowback programp outlined in Table 1 is approximately 15 MMscf. Attachment H NDB-025 4-1/2” Production Liner Section Summary Procedure: 1. Run 4-1/2” 12.6 ppf P-110S TSH563 lower completions per tally. 2. Circulate out 10.0 ppg OBM with 10.0 ppg NaCl/KCl brine to surface. 3. Drop 1.125” phenolic ball and circulate up to 5 bpm to close WIV. 4. Pressure up to close the WIV at 1,980 psi. 5. Continue increasing pressure to start setting the openhole hydraulic packers at 2,688 psi. 6. Set the 9-5/8” x 4-1/2” SLZXP liner hanger/top packer and openhole packers to 4,000 psi. 7. Before releasing, pressure test the IA to top liner hanger/packer to 3,500 psi for 10 minutes. 8. Release running tool from liner hanger. 9. Circulate 9.4 ppg NaCl Corrosion Inhibited brine with biocide to surface at 10 bpm pump rate. 10.POOH with liner hanger running tool. 11.Prepare to run upper completion. NDB-025 4-1/2” Upper Completion Section Summary Procedure: 1. Run 4-1/2” 12.6 ppf P110S TSH563 tubing and downhole jewellery. 2. Land tubing hanger. 3. MIT-T to 3,500 psi. (Post drilling rig move, MIT-T to be tested to 5,800 psi) a. (8,500 psi MAWP – 3,300 psi IA hold) * 1.1 = 5,720 psi 4. MIT-IA to 3,800 psi. (Post drilling rig move, MIT-IA to be tested to 3,800 psi with AOGCC witness notification) 5. Shear circulation valve. 6. Reverse circulate freeze protect and U-Tube. 7. Install TWCV into the tubing hanger and pressure test from direction of flow. 8. Nipple down BOP stack and install 10k frac tree. 9. RDMO 3,800 psi 5,800 psi) NDB-025 Well Clean Up Procedure 1. Move in and rig up Well Clean Up Surface Equipment as per P&ID and Pad Layout/Flow Diagram 2. Perform Low pressure air test of 100 – 120 psi, hold 10 minutes. (N2 will be used if hydrocarbon is present) 3. Pressure test all surface equipment and hardline upstream of the choke manifold to 5000psi and hold 15 minutes. Pressure test all surface equipment and hardline downstream of the choke manifold (with exception of flare) to 1000 psi and hold 15 minutes. Cap the gas line to the flare and test with air to 120 psi, hold 15 minutes. (N2 will be used if hydrocarbon is present). 4. Perform clean-up operations as per procedures. 5. Perform sampling as per procedures. 6. Rig down and demobilize equipment. Attachment I Attachment J Attachment K FracCADE* STIMULATION PROPOSAL Operator :Oil Search Well :NDB-025 Field :Pikka Formation :Nanushuk Stages 1 to 11 County : North Slope State : Alaska Country : United States Prepared for : Scott Leahy Service Point : Prudhoe Bay, Alaska Business Phone : 1 907 659 2434 Date Prepared : 10-09-2024 FAX No. : 1 907 659 2538 Prepared by : Laura Acosta Phone : E-Mail Address :NTrevino2@slb.com * Mark of Schlumberger Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 1 SLB Private Attachment K Section 1: Zone Data (Stage 1; 13788 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4093.5 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4103.5 15.0 0.70 2857 1.76E+06 0.220 1000 Nanushuk 3 SS 4118.5 15.3 0.68 2798 1.90E+06 0.220 1000 Top Nan CS 4133.8 19.5 0.62 2581 9.00E+05 0.270 1000 Nan SS 4153.3 2.0 0.69 2880 2.67E+06 0.230 2500 Nan CS 4155.3 1.5 0.64 2652 1.29E+06 0.260 1000 Nan CS 4156.8 4.5 0.62 2562 6.44E+05 0.280 1000 Nan DS 4161.3 3.5 0.69 2886 1.77E+06 0.260 1500 Nan DS 4164.8 14.5 0.65 2712 1.39E+06 0.260 1500 Nan CS 4179.3 1.5 0.64 2692 1.15E+06 0.270 1000 Nan CS 4180.8 12.5 0.63 2638 8.82E+05 0.270 1000 Nan DS 4193.3 2.0 0.65 2722 1.40E+06 0.260 1500 Nan CS 4195.3 9.0 0.61 2558 8.54E+05 0.270 1000 Nan DS 4204.3 7.0 0.65 2752 1.40E+06 0.260 1500 Nan DS 4211.3 9.0 0.64 2705 1.13E+06 0.270 1500 Nan DS 4220.3 3.5 0.64 2720 1.69E+06 0.260 1500 Nan DS 4223.8 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4228.8 2.0 0.69 2910 1.80E+06 0.250 1500 Nan CS 4230.8 10.5 0.62 2607 7.36E+05 0.270 1000 Nan CS 4241.3 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4244.8 2.0 0.62 2611 6.70E+05 0.280 1000 Nan CS 4246.8 5.5 0.65 2754 1.30E+06 0.260 1000 Nan DS 4252.3 3.5 0.69 2935 1.53E+06 0.260 1500 Nan DS 4255.8 3.5 0.63 2687 1.19E+06 0.270 1500 Nan DS 4259.3 5.5 0.69 2928 1.42E+06 0.260 1500 Nan CS 4264.8 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4275.3 1.5 0.65 2797 1.38E+06 0.260 1500 Nan DS 4276.8 5.0 0.62 2657 1.14E+06 0.270 1500 Nan DS 4281.8 2.0 0.66 2805 1.56E+06 0.260 1500 Nan DS 4283.8 4.0 0.62 2674 8.96E+05 0.270 1500 Nan DS 4287.8 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4289.8 10.0 0.63 2693 9.81E+05 0.270 1500 Nan DS 4299.8 4.0 0.65 2813 1.63E+06 0.260 1500 Nan DS 4303.8 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4307.8 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4317.3 2.0 0.61 2649 7.82E+05 0.270 1000 Nan DS 4319.3 9.5 0.69 2975 1.69E+06 0.260 1500 Nan DS 4328.8 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4330.8 2.0 0.69 3002 2.67E+06 0.230 2500 Nan DS 4332.8 2.0 0.64 2765 1.09E+06 0.270 1500 Shale 4334.8 2.0 0.69 3005 2.67E+06 0.230 2500 Nan DS 4336.8 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4340.8 19.5 0.69 3015 2.67E+06 0.230 2500 Nan DS 4360.3 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4362.3 2.0 0.69 3024 2.67E+06 0.230 2500 Nan DS 4364.3 8.0 0.65 2855 1.37E+06 0.260 1500 Nan DS 4372.3 8.0 0.65 2827 1.56E+06 0.260 1500 Shale 4380.3 20.0 0.69 3038 2.67E+06 0.230 2500 Zone Name Poisson’s Ratio Formation Mechanical Properties 2 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4093.5 10.0 0.001 1.0 1890 4103.5 15.0 0.001 1.0 1898 4118.5 15.3 0.005 10.0 1905 4133.8 19.5 30.655 23.7 1915 4153.3 2.0 5.000 10.0 1924 4155.3 1.5 2.095 16.9 1925 4156.8 4.5 48.388 26.6 1926 4161.3 3.5 0.478 12.4 1928 4164.8 14.5 15.008 17.7 1930 4179.3 1.5 3.661 17.6 1937 4180.8 12.5 34.723 23.9 1937 4193.3 2.0 1.697 15.6 1943 4195.3 9.0 54.319 24.4 1944 4204.3 7.0 3.610 14.8 1948 4211.3 9.0 22.986 20.4 1952 4220.3 3.5 0.835 14.0 1956 4223.8 5.0 65.392 23.4 1957 4228.8 2.0 0.006 10.5 1960 4230.8 10.5 100.832 25.6 1961 4241.3 3.5 17.434 20.5 1966 4244.8 2.0 161.343 26.3 1967 4246.8 5.5 4.627 18.4 1968 4252.3 3.5 5.075 14.8 1971 4255.8 3.5 8.651 19.4 1972 4259.3 5.5 10.205 16.0 1974 4264.8 10.5 17.356 20.1 1977 4275.3 1.5 3.106 14.8 1982 4276.8 5.0 52.863 20.6 1982 4281.8 2.0 2.277 14.1 1985 4283.8 4.0 122.778 23.1 1986 4287.8 2.0 0.333 12.5 1987 4289.8 10.0 39.939 21.2 1988 4299.8 4.0 0.748 13.3 1993 4303.8 4.0 0.009 10.9 1995 4307.8 9.5 5.399 16.7 1997 4317.3 2.0 160.618 24.9 2001 4319.3 9.5 0.033 11.5 2002 4328.8 2.0 6.733 16.2 2007 4330.8 2.0 0.001 1.0 2008 4332.8 2.0 29.480 19.6 2009 4334.8 2.0 0.001 1.0 2009 4336.8 4.0 8.473 16.6 2010 4340.8 19.5 0.001 1.0 2012 4360.3 2.0 2.185 16.4 2021 4362.3 2.0 0.001 1.0 2022 4364.3 8.0 2.645 15.9 2023 4372.3 8.0 2.026 14.4 2027 4380.3 20.0 0.001 10.0 2031 Nan DS Shale Nan DS Nan DS Shale Shale Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Shale Nan DS Nan DS Nan CS Nan CS Nan CS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Zone Name Formation Transmissibility Properties Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS Nan DS Nan CS 3 SLB Private Attachment K Section 2: Propped Fracture Schedule (Stage 1; 13788 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 225.0 25 0 1.0 PPA 40 YF125ST 57.4 25 1 3.0 PPA 40 YF125ST 105.6 25 3 Resume PAD 40 YF125ST 50.0 25 0 1.0 PPA 40 YF125ST 182.0 25 1 3.0 PPA 40 YF125ST 185.6 25 3 5.0 PPA 40 YF125ST 192.8 25 5 7.0 PPA 40 YF125ST 179.9 25 7 9.0 PPA 40 YF125ST 157.8 25 9 10.0 PPA 40 YF125ST 132.2 25 10 Flush 40 YF125ST 210.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1678.4 bbl of YF125ST 0 bbl of WF125 239581 lb of 15712 lb of % PAD Clean 15.3 % PAD Dirty 13.0 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 225.0 225 225 225 0 0 3557 5.6 5.6 1.0 PPA 57.4 282 60 285 2410 2410 3557 1.5 7.1 3.0 PPA 105.6 388 120 405 13302 15712 3582 3.0 10.1 Resume PAD 50.0 438 50 455 0 15712 3705 1.3 11.4 1.0 PPA 182.0 620 190 645 7645 23357 3840 4.8 16.1 3.0 PPA 185.6 806 210 855 23389 46747 3679 5.3 21.4 5.0 PPA 192.8 998 235 1090 40490 87237 4188 5.9 27.3 7.0 PPA 179.9 1178 235 1325 52888 140124 4741 5.9 33.1 9.0 PPA 157.8 1336 220 1545 59661 199785 5120 5.5 38.6 10.0 PPA 132.2 1468 190 1735 55508 255293 5299 4.8 43.4 Flush 210.0 1678 210 1945 0 255293 4913 5.3 48.6 Carbolite 16/20 Carbolite 40/70 Proppant Totals Carbolite 16/20 Pad Percentages Job Execution Step Name Carbolite 40/70 Carbolite 40/70 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 336.9 ft with an average conductivity (Kfw) of 16984.9 md.ft. Job Description Fluid Name Prop. Type and Mesh 4 SLB Private Attachment K 5299 Section 3: Propped Fracture Simulation (Stage 1; 13788 ft MD) Initial Fracture Top TVD 4101.2 ft Initial Fracture Bottom TVD 4336.2 ft Propped Fracture Half-Length 336.9 ft EOJ Hyd Height at Well 235 ft Average Propped Width 0.196 in Net Pressure 278 psi Max Surface Pressure 5338 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 84.2 9.4 0.249 189.9 2.15 258.6 22307 84.2 168.5 8.1 0.246 208.3 2.19 271.5 21793 168.5 252.7 6.4 0.203 194 1.81 309.4 17757 252.7 336.9 1.9 0.099 163.3 0.9 473.5 7815 Simulation Results by Fracture Segment The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. 5 SLB Private Attachment K 5338 psi Section 4: Zone Data (Stage 2; 13328 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4106.7 10.0 0.71 2937 1.46E+06 0.220 1000 Shale 4116.7 15.0 0.70 2866 1.76E+06 0.220 1000 Nanushuk 3 SS 4131.7 15.3 0.68 2806 1.90E+06 0.220 1000 Top Nan CS 4147.0 19.5 0.62 2590 9.00E+05 0.270 1000 Nan SS 4166.5 2.0 0.69 2880 2.67E+06 0.230 2500 Nan CS 4168.5 1.5 0.64 2660 1.29E+06 0.260 1000 Nan CS 4170.0 4.5 0.62 2570 6.44E+05 0.280 1000 Nan DS 4174.5 3.5 0.69 2886 1.77E+06 0.260 1500 Nan DS 4178.0 14.5 0.65 2720 1.39E+06 0.260 1500 Nan CS 4192.5 1.5 0.64 2700 1.15E+06 0.270 1000 Nan CS 4194.0 12.5 0.63 2646 8.82E+05 0.270 1000 Nan DS 4206.5 2.0 0.65 2731 1.40E+06 0.260 1500 Nan CS 4208.5 9.0 0.61 2558 8.54E+05 0.270 1000 Nan DS 4217.5 7.0 0.65 2761 1.40E+06 0.260 1500 Nan DS 4224.5 9.0 0.64 2705 1.13E+06 0.270 1500 Nan DS 4233.5 3.5 0.64 2720 1.69E+06 0.260 1500 Nan DS 4237.0 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4242.0 2.0 0.69 2919 1.80E+06 0.250 1500 Nan CS 4244.0 10.5 0.61 2607 7.36E+05 0.270 1000 Nan CS 4254.5 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4258.0 2.0 0.62 2619 6.70E+05 0.280 1000 Nan CS 4260.0 5.5 0.65 2762 1.30E+06 0.260 1000 Nan DS 4265.5 3.5 0.69 2944 1.53E+06 0.260 1500 Nan DS 4269.0 3.5 0.63 2695 1.19E+06 0.270 1500 Nan DS 4272.5 5.5 0.68 2928 1.42E+06 0.260 1500 Nan CS 4278.0 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4288.5 1.5 0.65 2805 1.38E+06 0.260 1500 Nan DS 4290.0 5.0 0.62 2666 1.14E+06 0.270 1500 Nan DS 4295.0 2.0 0.66 2814 1.56E+06 0.260 1500 Nan DS 4297.0 4.0 0.62 2683 8.96E+05 0.270 1500 Nan DS 4301.0 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4303.0 10.0 0.63 2701 9.81E+05 0.270 1500 Nan DS 4313.0 4.0 0.65 2822 1.63E+06 0.260 1500 Nan DS 4317.0 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4321.0 9.5 0.64 2784 1.33E+06 0.260 1500 Nan DS 4330.5 2.0 0.61 2649 7.82E+05 0.270 1000 Nan DS 4332.5 9.5 0.69 2975 1.69E+06 0.260 1500 Nan DS 4342.0 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4344.0 2.0 0.69 3002 2.67E+06 0.230 2500 Nan DS 4346.0 2.0 0.64 2765 1.09E+06 0.270 1500 Shale 4348.0 2.0 0.69 3005 2.67E+06 0.230 2500 Nan DS 4350.0 4.0 0.65 2844 1.29E+06 0.260 1500 Shale 4354.0 19.5 0.69 3015 2.67E+06 0.230 2500 Nan DS 4373.5 2.0 0.64 2820 1.36E+06 0.260 1500 Shale 4375.5 2.0 0.69 3024 2.67E+06 0.230 2500 Nan DS 4377.5 8.0 0.65 2855 1.37E+06 0.260 1500 Nan DS 4385.5 8.0 0.65 2836 1.56E+06 0.260 1500 Shale 4393.5 20.0 0.69 3047 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 6 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4106.7 10.0 0.001 1.0 1890 4116.7 15.0 0.001 1.0 1898 4131.7 15.3 0.005 10.0 1905 4147.0 19.5 30.655 23.7 1915 4166.5 2.0 5.000 10.0 1924 4168.5 1.5 2.095 16.9 1925 4170.0 4.5 48.388 26.6 1926 4174.5 3.5 0.478 12.4 1928 4178.0 14.5 15.008 17.7 1930 4192.5 1.5 3.661 17.6 1937 4194.0 12.5 34.723 23.9 1937 4206.5 2.0 1.697 15.6 1943 4208.5 9.0 54.319 24.4 1944 4217.5 7.0 3.610 14.8 1948 4224.5 9.0 22.986 20.4 1952 4233.5 3.5 0.835 14.0 1956 4237.0 5.0 65.392 23.4 1957 4242.0 2.0 0.006 10.5 1960 4244.0 10.5 100.832 25.6 1961 4254.5 3.5 17.434 20.5 1966 4258.0 2.0 161.343 26.3 1967 4260.0 5.5 4.627 18.4 1968 4265.5 3.5 5.075 14.8 1971 4269.0 3.5 8.651 19.4 1972 4272.5 5.5 10.205 16.0 1974 4278.0 10.5 17.356 20.1 1977 4288.5 1.5 3.106 14.8 1982 4290.0 5.0 52.863 20.6 1982 4295.0 2.0 2.277 14.1 1985 4297.0 4.0 122.778 23.1 1986 4301.0 2.0 0.333 12.5 1987 4303.0 10.0 39.939 21.2 1988 4313.0 4.0 0.748 13.3 1993 4317.0 4.0 0.009 10.9 1995 4321.0 9.5 5.399 16.7 1997 4330.5 2.0 160.618 24.9 2001 4332.5 9.5 0.033 11.5 2002 4342.0 2.0 6.733 16.2 2007 4344.0 2.0 0.001 1.0 2008 4346.0 2.0 29.480 19.6 2009 4348.0 2.0 0.001 1.0 2009 4350.0 4.0 8.473 16.6 2010 4354.0 19.5 0.001 1.0 2012 4373.5 2.0 2.185 16.4 2021 4375.5 2.0 0.001 1.0 2022 4377.5 8.0 2.645 15.9 2023 4385.5 8.0 2.026 14.4 2027 4393.5 20.0 0.001 10.0 2031 Nan DS Nan DS Shale Shale Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan CS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan DS Formation Transmissibility Properties Zone Name Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS 7 SLB Private Attachment K Section 5: Propped Fracture Schedule (Stage 2; 13328 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 300.0 25 0 1.0 PPA 40 YF125ST 172.5 25 1 2.0 PPA 40 YF125ST 183.9 25 2 4.0 PPA 40 YF125ST 187.2 25 4 6.0 PPA 40 YF125ST 174.2 25 6 8.0 PPA 40 YF125ST 162.9 25 8 10.0 PPA 40 YF125ST 139.1 25 10 12.0 PPA 40 YF125ST 118.0 25 12 Flush 40 YF125ST 203.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1640.9 bbl of YF125ST 0 bbl of WF125 270716 lb of % PAD Clean 20.9 % PAD Dirty 17.4 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 300.0 300 300 300 0 0 3492 7.5 7.5 1.0 PPA 172.5 472 180 480 7243 7243 3480 4.5 12.0 2.0 PPA 183.9 656 200 680 15448 22691 3533 5.0 17.0 4.0 PPA 187.2 844 220 900 31454 54145 3842 5.5 22.5 6.0 PPA 174.2 1018 220 1120 43910 98055 4392 5.5 28.0 8.0 PPA 162.9 1181 220 1340 54751 152805 4851 5.5 33.5 10.0 PPA 139.1 1320 200 1540 58429 211234 5087 5.0 38.5 12.0 PPA 118.0 1438 180 1720 59482 270716 5175 4.5 43.0 Flush 203.0 1641 203 1923 0 270716 4838 5.1 48.1 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 345.8 ft with an average conductivity (Kfw) of 17534.6 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 8 SLB Private Attachment K Section 6: Propped Fracture Simulation (Stage 2; 13328 ft MD) Initial Fracture Top TVD 4114.5 ft Initial Fracture Bottom TVD 4354.5 ft Propped Fracture Half-Length 345.8 ft EOJ Hyd Height at Well 240 ft Average Propped Width 0.202 in Net Pressure 264 psi Max Surface Pressure 5253 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 86.5 11.1 0.241 192.9 2.08 245.2 21485 86.5 172.9 9 0.235 205.3 2.09 258.4 20822 172.9 259.4 7.6 0.208 191.6 1.87 282.2 18087 259.4 345.8 3.5 0.135 169.8 1.27 450.7 10976 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 9 SLB Private Attachment K Section 7: Zone Data (Stage 3; 12867 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4118.9 10.0 0.71 2937 1.46E+06 0.220 1000 Shale 4128.9 15.0 0.70 2875 1.76E+06 0.220 1000 Nanushuk 3 SS 4143.9 15.3 0.68 2815 1.90E+06 0.220 1000 Top Nan CS 4159.2 19.5 0.62 2597 9.00E+05 0.270 1000 Nan SS 4178.7 2.0 0.69 2880 2.67E+06 0.230 2500 Nan CS 4180.7 1.5 0.64 2668 1.29E+06 0.260 1000 Nan CS 4182.2 4.5 0.62 2578 6.44E+05 0.280 1000 Nan DS 4186.7 3.5 0.69 2886 1.77E+06 0.260 1500 Nan DS 4190.2 14.5 0.65 2728 1.39E+06 0.260 1500 Nan CS 4204.7 1.5 0.64 2708 1.15E+06 0.270 1000 Nan CS 4206.2 12.5 0.63 2654 8.82E+05 0.270 1000 Nan DS 4218.7 2.0 0.65 2739 1.40E+06 0.260 1500 Nan CS 4220.7 9.0 0.61 2558 8.54E+05 0.270 1000 Nan DS 4229.7 7.0 0.65 2769 1.40E+06 0.260 1500 Nan DS 4236.7 9.0 0.64 2705 1.13E+06 0.270 1500 Nan DS 4245.7 3.5 0.64 2720 1.69E+06 0.260 1500 Nan DS 4249.2 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4254.2 2.0 0.69 2928 1.80E+06 0.250 1500 Nan CS 4256.2 10.5 0.61 2607 7.36E+05 0.270 1000 Nan CS 4266.7 3.5 0.63 2705 1.10E+06 0.270 1000 Nan CS 4270.2 2.0 0.62 2627 6.70E+05 0.280 1000 Nan CS 4272.2 5.5 0.65 2770 1.30E+06 0.260 1000 Nan DS 4277.7 3.5 0.69 2953 1.53E+06 0.260 1500 Nan DS 4281.2 3.5 0.63 2703 1.19E+06 0.270 1500 Nan DS 4284.7 5.5 0.68 2928 1.42E+06 0.260 1500 Nan CS 4290.2 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4300.7 1.5 0.65 2813 1.38E+06 0.260 1500 Nan DS 4302.2 5.0 0.62 2673 1.14E+06 0.270 1500 Nan DS 4307.2 2.0 0.66 2822 1.56E+06 0.260 1500 Nan DS 4309.2 4.0 0.62 2690 8.96E+05 0.270 1500 Nan DS 4313.2 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4315.2 10.0 0.63 2709 9.81E+05 0.270 1500 Nan DS 4325.2 4.0 0.65 2830 1.63E+06 0.260 1500 Nan DS 4329.2 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4333.2 9.5 0.64 2784 1.33E+06 0.260 1500 Nan DS 4342.7 2.0 0.61 2649 7.82E+05 0.270 1000 Nan DS 4344.7 9.5 0.68 2975 1.69E+06 0.260 1500 Nan DS 4354.2 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4356.2 2.0 0.69 3002 2.67E+06 0.230 2500 Nan DS 4358.2 2.0 0.63 2765 1.09E+06 0.270 1500 Shale 4360.2 2.0 0.69 3005 2.67E+06 0.230 2500 Nan DS 4362.2 4.0 0.65 2844 1.29E+06 0.260 1500 Shale 4366.2 19.5 0.69 3015 2.67E+06 0.230 2500 Nan DS 4385.7 2.0 0.64 2820 1.36E+06 0.260 1500 Shale 4387.7 2.0 0.69 3024 2.67E+06 0.230 2500 Nan DS 4389.7 8.0 0.65 2855 1.37E+06 0.260 1500 Nan DS 4397.7 8.0 0.65 2843 1.56E+06 0.260 1500 Shale 4405.7 20.0 0.69 3056 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 10 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4118.9 10.0 0.001 1.0 1890 4128.9 15.0 0.001 1.0 1898 4143.9 15.3 0.005 10.0 1905 4159.2 19.5 30.655 23.7 1915 4178.7 2.0 5.000 10.0 1924 4180.7 1.5 2.095 16.9 1925 4182.2 4.5 48.388 26.6 1926 4186.7 3.5 0.478 12.4 1928 4190.2 14.5 15.008 17.7 1930 4204.7 1.5 3.661 17.6 1937 4206.2 12.5 34.723 23.9 1937 4218.7 2.0 1.697 15.6 1943 4220.7 9.0 54.319 24.4 1944 4229.7 7.0 3.610 14.8 1948 4236.7 9.0 22.986 20.4 1952 4245.7 3.5 0.835 14.0 1956 4249.2 5.0 65.392 23.4 1957 4254.2 2.0 0.006 10.5 1960 4256.2 10.5 100.832 25.6 1961 4266.7 3.5 17.434 20.5 1966 4270.2 2.0 161.343 26.3 1967 4272.2 5.5 4.627 18.4 1968 4277.7 3.5 5.075 14.8 1971 4281.2 3.5 8.651 19.4 1972 4284.7 5.5 10.205 16.0 1974 4290.2 10.5 17.356 20.1 1977 4300.7 1.5 3.106 14.8 1982 4302.2 5.0 52.863 20.6 1982 4307.2 2.0 2.277 14.1 1985 4309.2 4.0 122.778 23.1 1986 4313.2 2.0 0.333 12.5 1987 4315.2 10.0 39.939 21.2 1988 4325.2 4.0 0.748 13.3 1993 4329.2 4.0 0.009 10.9 1995 4333.2 9.5 5.399 16.7 1997 4342.7 2.0 160.618 24.9 2001 4344.7 9.5 0.033 11.5 2002 4354.2 2.0 6.733 16.2 2007 4356.2 2.0 0.001 1.0 2008 4358.2 2.0 29.480 19.6 2009 4360.2 2.0 0.001 1.0 2009 4362.2 4.0 8.473 16.6 2010 4366.2 19.5 0.001 1.0 2012 4385.7 2.0 2.185 16.4 2021 4387.7 2.0 0.001 1.0 2022 4389.7 8.0 2.645 15.9 2023 4397.7 8.0 2.026 14.4 2027 4405.7 20.0 0.001 10.0 2031Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Nan DS Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS Formation Transmissibility Properties Zone Name 11 SLB Private Attachment K Section 8: Propped Fracture Schedule (Stage 3; 12867 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 300.0 25 0 1.0 PPA 40 YF125ST 172.5 25 1 2.0 PPA 40 YF125ST 183.9 25 2 4.0 PPA 40 YF125ST 187.2 25 4 6.0 PPA 40 YF125ST 174.2 25 6 8.0 PPA 40 YF125ST 162.9 25 8 10.0 PPA 40 YF125ST 139.1 25 10 12.0 PPA 40 YF125ST 118.0 25 12 Flush 40 YF125ST 195.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1632.9 bbl of YF125ST 0 bbl of WF125 270716 lb of % PAD Clean 20.9 % PAD Dirty 17.4 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 300.0 300 300 300 0 0 3420 7.5 7.5 1.0 PPA 172.5 472 180 480 7243 7243 3401 4.5 12.0 2.0 PPA 183.9 656 200 680 15448 22691 3469 5.0 17.0 4.0 PPA 187.2 844 220 900 31454 54145 3829 5.5 22.5 6.0 PPA 174.2 1018 220 1120 43910 98055 4356 5.5 28.0 8.0 PPA 162.9 1181 220 1340 54751 152805 4763 5.5 33.5 10.0 PPA 139.1 1320 200 1540 58429 211234 4947 5.0 38.5 12.0 PPA 118.0 1438 180 1720 59482 270716 5019 4.5 43.0 Flush 195.0 1633 195 1915 0 270716 4705 4.9 47.9 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 354.8 ft with an average conductivity (Kfw) of 17021.7 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 12 SLB Private Attachment K Section 9: Propped Fracture Simulation (Stage 3; 12867 ft MD) Initial Fracture Top TVD 4126.7 ft Initial Fracture Bottom TVD 4368 ft Propped Fracture Half-Length 354.8 ft EOJ Hyd Height at Well 241.2 ft Average Propped Width 0.197 in Net Pressure 259 psi Max Surface Pressure 5076 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 88.7 11.3 0.237 194.1 2.05 245.2 21226 88.7 177.4 9 0.23 205.8 2.04 259.9 20290 177.4 266.1 7.5 0.203 192.4 1.82 282.3 17572 266.1 354.8 3.4 0.127 169.8 1.19 513.7 10306 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 13 SLB Private Attachment K Section 10: Zone Data (Stage 4; 12407 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4136.2 10.0 0.71 2937 1.46E+06 0.220 1000 Shale 4146.2 15.0 0.70 2887 1.76E+06 0.220 1000 Nanushuk 3 SS 4161.2 15.3 0.68 2826 1.90E+06 0.220 1000 Top Nan CS 4176.5 19.5 0.62 2608 9.00E+05 0.270 1000 Nan SS 4196.0 2.0 0.69 2880 2.67E+06 0.230 2500 Nan CS 4198.0 1.5 0.64 2679 1.29E+06 0.260 1000 Nan CS 4199.5 4.5 0.62 2588 6.44E+05 0.280 1000 Nan DS 4204.0 3.5 0.69 2886 1.77E+06 0.260 1500 Nan DS 4207.5 14.5 0.65 2740 1.39E+06 0.260 1500 Nan CS 4222.0 1.5 0.64 2719 1.15E+06 0.270 1000 Nan CS 4223.5 12.5 0.63 2665 8.82E+05 0.270 1000 Nan DS 4236.0 2.0 0.65 2750 1.40E+06 0.260 1500 Nan CS 4238.0 9.0 0.60 2558 8.54E+05 0.270 1000 Nan DS 4247.0 7.0 0.65 2780 1.40E+06 0.260 1500 Nan DS 4254.0 9.0 0.64 2705 1.13E+06 0.270 1500 Nan DS 4263.0 3.5 0.64 2720 1.69E+06 0.260 1500 Nan DS 4266.5 5.0 0.62 2665 7.57E+05 0.270 1000 Nan DS 4271.5 2.0 0.69 2939 1.80E+06 0.250 1500 Nan CS 4273.5 10.5 0.61 2607 7.36E+05 0.270 1000 Nan CS 4284.0 3.5 0.63 2705 1.10E+06 0.270 1000 Nan CS 4287.5 2.0 0.62 2637 6.70E+05 0.280 1000 Nan CS 4289.5 5.5 0.65 2781 1.30E+06 0.260 1000 Nan DS 4295.0 3.5 0.69 2965 1.53E+06 0.260 1500 Nan DS 4298.5 3.5 0.63 2713 1.19E+06 0.270 1500 Nan DS 4302.0 5.5 0.68 2928 1.42E+06 0.260 1500 Nan CS 4307.5 10.5 0.62 2693 1.17E+06 0.270 1000 Nan DS 4318.0 1.5 0.65 2824 1.38E+06 0.260 1500 Nan DS 4319.5 5.0 0.62 2684 1.14E+06 0.270 1500 Nan DS 4324.5 2.0 0.66 2833 1.56E+06 0.260 1500 Nan DS 4326.5 4.0 0.62 2701 8.96E+05 0.270 1500 Nan DS 4330.5 2.0 0.66 2876 1.66E+06 0.260 1500 Nan DS 4332.5 10.0 0.63 2720 9.81E+05 0.270 1500 Nan DS 4342.5 4.0 0.65 2841 1.63E+06 0.260 1500 Nan DS 4346.5 4.0 0.68 2974 1.75E+06 0.260 1500 Nan DS 4350.5 9.5 0.64 2784 1.33E+06 0.260 1500 Nan DS 4360.0 2.0 0.61 2649 7.82E+05 0.270 1000 Nan DS 4362.0 9.5 0.68 2975 1.69E+06 0.260 1500 Nan DS 4371.5 2.0 0.64 2812 1.37E+06 0.260 1500 Shale 4373.5 2.0 0.69 3002 2.67E+06 0.230 2500 Nan DS 4375.5 2.0 0.63 2765 1.09E+06 0.270 1500 Shale 4377.5 2.0 0.69 3005 2.67E+06 0.230 2500 Nan DS 4379.5 4.0 0.65 2844 1.29E+06 0.260 1500 Shale 4383.5 19.5 0.69 3015 2.67E+06 0.230 2500 Nan DS 4403.0 2.0 0.64 2820 1.36E+06 0.260 1500 Shale 4405.0 2.0 0.69 3024 2.67E+06 0.230 2500 Nan DS 4407.0 8.0 0.65 2855 1.37E+06 0.260 1500 Nan DS 4415.0 8.0 0.65 2855 1.56E+06 0.260 1500 Shale 4423.0 20.0 0.69 3068 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 14 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4136.2 10.0 0.001 1.0 1890 4146.2 15.0 0.001 1.0 1898 4161.2 15.3 0.005 10.0 1905 4176.5 19.5 30.655 23.7 1915 4196.0 2.0 5.000 10.0 1924 4198.0 1.5 2.095 16.9 1925 4199.5 4.5 48.388 26.6 1926 4204.0 3.5 0.478 12.4 1928 4207.5 14.5 15.008 17.7 1930 4222.0 1.5 3.661 17.6 1937 4223.5 12.5 34.723 23.9 1937 4236.0 2.0 1.697 15.6 1943 4238.0 9.0 54.319 24.4 1944 4247.0 7.0 3.610 14.8 1948 4254.0 9.0 22.986 20.4 1952 4263.0 3.5 0.835 14.0 1956 4266.5 5.0 65.392 23.4 1957 4271.5 2.0 0.006 10.5 1960 4273.5 10.5 100.832 25.6 1961 4284.0 3.5 17.434 20.5 1966 4287.5 2.0 161.343 26.3 1967 4289.5 5.5 4.627 18.4 1968 4295.0 3.5 5.075 14.8 1971 4298.5 3.5 8.651 19.4 1972 4302.0 5.5 10.205 16.0 1974 4307.5 10.5 17.356 20.1 1977 4318.0 1.5 3.106 14.8 1982 4319.5 5.0 52.863 20.6 1982 4324.5 2.0 2.277 14.1 1985 4326.5 4.0 122.778 23.1 1986 4330.5 2.0 0.333 12.5 1987 4332.5 10.0 39.939 21.2 1988 4342.5 4.0 0.748 13.3 1993 4346.5 4.0 0.009 10.9 1995 4350.5 9.5 5.399 16.7 1997 4360.0 2.0 160.618 24.9 2001 4362.0 9.5 0.033 11.5 2002 4371.5 2.0 6.733 16.2 2007 4373.5 2.0 0.001 1.0 2008 4375.5 2.0 29.480 19.6 2009 4377.5 2.0 0.001 1.0 2009 4379.5 4.0 8.473 16.6 2010 4383.5 19.5 0.001 1.0 2012 4403.0 2.0 2.185 16.4 2021 4405.0 2.0 0.001 1.0 2022 4407.0 8.0 2.645 15.9 2023 4415.0 8.0 2.026 14.4 2027 4423.0 20.0 0.001 10.0 2031Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Nan DS Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS Formation Transmissibility Properties Zone Name 15 SLB Private Attachment K Section 11: Propped Fracture Schedule (Stage 4; 12407 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 300.0 25 0 1.0 PPA 40 YF125ST 191.6 25 1 2.0 PPA 40 YF125ST 202.3 25 2 4.0 PPA 40 YF125ST 204.2 25 4 6.0 PPA 40 YF125ST 198.0 25 6 8.0 PPA 40 YF125ST 185.2 25 8 10.0 PPA 40 YF125ST 153.0 25 10 12.0 PPA 40 YF125ST 131.1 25 12 Flush 40 YF125ST 189.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1754.5 bbl of YF125ST 0 bbl of WF125 301831 lb of % PAD Clean 19.2 % PAD Dirty 16.0 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 300.0 300 300 300 0 0 3348 7.5 7.5 1.0 PPA 191.6 492 200 500 8048 8048 3334 5.0 12.5 2.0 PPA 202.3 694 220 720 16993 25040 3396 5.5 18.0 4.0 PPA 204.2 898 240 960 34313 59354 3716 6.0 24.0 6.0 PPA 198.0 1096 250 1210 49898 109251 4213 6.3 30.3 8.0 PPA 185.2 1281 250 1460 62217 171468 4606 6.3 36.5 10.0 PPA 153.0 1434 220 1680 64272 235740 4790 5.5 42.0 12.0 PPA 131.1 1565 200 1880 66091 301831 4866 5.0 47.0 Flush 189.0 1754 189 2069 0 301831 4590 4.7 51.7 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 348.7 ft with an average conductivity (Kfw) of 19429.3 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 16 SLB Private Attachment K Section 12: Propped Fracture Simulation (Stage 4; 12407 ft MD) Initial Fracture Top TVD 4144.1 ft Initial Fracture Bottom TVD 4387 ft Propped Fracture Half-Length 348.7 ft EOJ Hyd Height at Well 242.9 ft Average Propped Width 0.222 in Net Pressure 269 psi Max Surface Pressure 4972 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 87.2 10.9 0.256 139.9 2.17 248.1 22977 87.2 174.4 9 0.254 216.5 2.22 257.6 22583 174.4 261.5 7.8 0.244 199.9 2.19 267.5 21422 261.5 348.7 3.2 0.146 148.8 1.33 494.6 12195 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 17 SLB Private Attachment K Section 13: Zone Data (Stage 5; 11946 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4150.5 10.0 0.71 2937 1.46E+06 0.220 1000 Shale 4160.5 15.0 0.70 2897 1.76E+06 0.220 1000 Nanushuk 3 SS 4175.5 15.3 0.68 2836 1.90E+06 0.220 1000 Top Nan CS 4190.8 19.5 0.62 2617 9.00E+05 0.270 1000 Nan SS 4210.3 2.0 0.68 2880 2.67E+06 0.230 2500 Nan CS 4212.3 1.5 0.64 2688 1.29E+06 0.260 1000 Nan CS 4213.8 4.5 0.62 2597 6.44E+05 0.280 1000 Nan DS 4218.3 3.5 0.68 2886 1.77E+06 0.260 1500 Nan DS 4221.8 14.5 0.65 2749 1.39E+06 0.260 1500 Nan CS 4236.3 1.5 0.64 2729 1.15E+06 0.270 1000 Nan CS 4237.8 12.5 0.63 2674 8.82E+05 0.270 1000 Nan DS 4250.3 2.0 0.65 2759 1.40E+06 0.260 1500 Nan CS 4252.3 9.0 0.60 2558 8.54E+05 0.270 1000 Nan DS 4261.3 7.0 0.65 2789 1.40E+06 0.260 1500 Nan DS 4268.3 9.0 0.63 2705 1.13E+06 0.270 1500 Nan DS 4277.3 3.5 0.64 2720 1.69E+06 0.260 1500 Nan DS 4280.8 5.0 0.62 2665 7.57E+05 0.270 1000 Nan DS 4285.8 2.0 0.69 2949 1.80E+06 0.250 1500 Nan CS 4287.8 10.5 0.61 2607 7.36E+05 0.270 1000 Nan CS 4298.3 3.5 0.63 2705 1.10E+06 0.270 1000 Nan CS 4301.8 2.0 0.62 2646 6.70E+05 0.280 1000 Nan CS 4303.8 5.5 0.65 2791 1.30E+06 0.260 1000 Nan DS 4309.3 3.5 0.69 2975 1.53E+06 0.260 1500 Nan DS 4312.8 3.5 0.63 2722 1.19E+06 0.270 1500 Nan DS 4316.3 5.5 0.68 2928 1.42E+06 0.260 1500 Nan CS 4321.8 10.5 0.62 2693 1.17E+06 0.270 1000 Nan DS 4332.3 1.5 0.65 2834 1.38E+06 0.260 1500 Nan DS 4333.8 5.0 0.62 2693 1.14E+06 0.270 1500 Nan DS 4338.8 2.0 0.66 2843 1.56E+06 0.260 1500 Nan DS 4340.8 4.0 0.62 2710 8.96E+05 0.270 1500 Nan DS 4344.8 2.0 0.66 2876 1.66E+06 0.260 1500 Nan DS 4346.8 10.0 0.63 2729 9.81E+05 0.270 1500 Nan DS 4356.8 4.0 0.65 2851 1.63E+06 0.260 1500 Nan DS 4360.8 4.0 0.68 2974 1.75E+06 0.260 1500 Nan DS 4364.8 9.5 0.64 2784 1.33E+06 0.260 1500 Nan DS 4374.3 2.0 0.61 2649 7.82E+05 0.270 1000 Nan DS 4376.3 9.5 0.68 2975 1.69E+06 0.260 1500 Nan DS 4385.8 2.0 0.64 2812 1.37E+06 0.260 1500 Shale 4387.8 2.0 0.68 3002 2.67E+06 0.230 2500 Nan DS 4389.8 2.0 0.63 2765 1.09E+06 0.270 1500 Shale 4391.8 2.0 0.68 3005 2.67E+06 0.230 2500 Nan DS 4393.8 4.0 0.65 2844 1.29E+06 0.260 1500 Shale 4397.8 19.5 0.68 3015 2.67E+06 0.230 2500 Nan DS 4417.3 2.0 0.64 2820 1.36E+06 0.260 1500 Shale 4419.3 2.0 0.68 3024 2.67E+06 0.230 2500 Nan DS 4421.3 8.0 0.65 2855 1.37E+06 0.260 1500 Nan DS 4429.3 8.0 0.65 2864 1.56E+06 0.260 1500 Shale 4437.3 20.0 0.69 3078 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 18 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4150.5 10.0 0.001 1.0 1890 4160.5 15.0 0.001 1.0 1898 4175.5 15.3 0.005 10.0 1905 4190.8 19.5 30.655 23.7 1915 4210.3 2.0 5.000 10.0 1924 4212.3 1.5 2.095 16.9 1925 4213.8 4.5 48.388 26.6 1926 4218.3 3.5 0.478 12.4 1928 4221.8 14.5 15.008 17.7 1930 4236.3 1.5 3.661 17.6 1937 4237.8 12.5 34.723 23.9 1937 4250.3 2.0 1.697 15.6 1943 4252.3 9.0 54.319 24.4 1944 4261.3 7.0 3.610 14.8 1948 4268.3 9.0 22.986 20.4 1952 4277.3 3.5 0.835 14.0 1956 4280.8 5.0 65.392 23.4 1957 4285.8 2.0 0.006 10.5 1960 4287.8 10.5 100.832 25.6 1961 4298.3 3.5 17.434 20.5 1966 4301.8 2.0 161.343 26.3 1967 4303.8 5.5 4.627 18.4 1968 4309.3 3.5 5.075 14.8 1971 4312.8 3.5 8.651 19.4 1972 4316.3 5.5 10.205 16.0 1974 4321.8 10.5 17.356 20.1 1977 4332.3 1.5 3.106 14.8 1982 4333.8 5.0 52.863 20.6 1982 4338.8 2.0 2.277 14.1 1985 4340.8 4.0 122.778 23.1 1986 4344.8 2.0 0.333 12.5 1987 4346.8 10.0 39.939 21.2 1988 4356.8 4.0 0.748 13.3 1993 4360.8 4.0 0.009 10.9 1995 4364.8 9.5 5.399 16.7 1997 4374.3 2.0 160.618 24.9 2001 4376.3 9.5 0.033 11.5 2002 4385.8 2.0 6.733 16.2 2007 4387.8 2.0 0.001 1.0 2008 4389.8 2.0 29.480 19.6 2009 4391.8 2.0 0.001 1.0 2009 4393.8 4.0 8.473 16.6 2010 4397.8 19.5 0.001 1.0 2012 4417.3 2.0 2.185 16.4 2021 4419.3 2.0 0.001 1.0 2022 4421.3 8.0 2.645 15.9 2023 4429.3 8.0 2.026 14.4 2027 4437.3 20.0 0.001 10.0 2031Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Nan DS Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS Formation Transmissibility Properties Zone Name 19 SLB Private Attachment K Section 14: Propped Fracture Schedule (Stage 5; 11946 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 300.0 25 0 1.0 PPA 40 YF125ST 153.3 25 1 2.0 PPA 40 YF125ST 160.9 25 2 4.0 PPA 40 YF125ST 161.7 25 4 6.0 PPA 40 YF125ST 150.5 25 6 8.0 PPA 40 YF125ST 140.7 25 8 10.0 PPA 40 YF125ST 132.2 25 10 12.0 PPA 40 YF125ST 114.7 25 12 14.0 PPA 40 YF125ST 93.0 25 14 Flush 40 YF125ST 181.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1588 bbl of YF125ST 0 bbl of WF125 300355 lb of % PAD Clean 21.3 % PAD Dirty 17.4 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 300.0 300 300 300 0 0 3273 7.5 7.5 1.0 PPA 153.3 453 160 460 6438 6438 3265 4.0 11.5 2.0 PPA 160.9 614 175 635 13517 19955 3289 4.4 15.9 4.0 PPA 161.7 776 190 825 27165 47120 3561 4.8 20.6 6.0 PPA 150.5 926 190 1015 37922 85042 4028 4.8 25.4 8.0 PPA 140.7 1067 190 1205 47285 132327 4425 4.8 30.1 10.0 PPA 132.2 1199 190 1395 55508 187834 4629 4.8 34.9 12.0 PPA 114.7 1314 175 1570 57830 245664 4697 4.4 39.3 14.0 PPA 93.0 1407 150 1720 54691 300355 4778 3.8 43.0 Flush 181.0 1588 181 1901 0 300355 4498 4.5 47.5 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 337.5 ft with an average conductivity (Kfw) of 19944.4 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 20 SLB Private Attachment K Section 15: Propped Fracture Simulation (Stage 5; 11946 ft MD) Initial Fracture Top TVD 4159.2 ft Initial Fracture Bottom TVD 4402.3 ft Propped Fracture Half-Length 337.5 ft EOJ Hyd Height at Well 243.1 ft Average Propped Width 0.228 in Net Pressure 260 psi Max Surface Pressure 4857 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 84.4 12.7 0.263 186.7 2.22 228.3 23786 84.4 168.8 10.3 0.26 213.6 2.27 235.9 23158 168.8 253.2 8.9 0.242 194.9 2.18 249.2 21232 253.2 337.5 3.7 0.157 175 1.43 414.2 13168 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 21 SLB Private Attachment K Section 16: Zone Data (Stage 6; 11488 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4166.7 10.0 0.70 2937 1.46E+06 0.220 1000 Shale 4176.7 15.0 0.70 2908 1.76E+06 0.220 1000 Nanushuk 3 SS 4191.7 15.3 0.68 2847 1.90E+06 0.220 1000 Top Nan CS 4207.0 19.5 0.62 2627 9.00E+05 0.270 1000 Nan SS 4226.5 2.0 0.68 2880 2.67E+06 0.230 2500 Nan CS 4228.5 1.5 0.64 2698 1.29E+06 0.260 1000 Nan CS 4230.0 4.5 0.62 2607 6.44E+05 0.280 1000 Nan DS 4234.5 3.5 0.68 2886 1.77E+06 0.260 1500 Nan DS 4238.0 14.5 0.65 2759 1.39E+06 0.260 1500 Nan CS 4252.5 1.5 0.64 2739 1.15E+06 0.270 1000 Nan CS 4254.0 12.5 0.63 2684 8.82E+05 0.270 1000 Nan DS 4266.5 2.0 0.65 2770 1.40E+06 0.260 1500 Nan CS 4268.5 9.0 0.60 2558 8.54E+05 0.270 1000 Nan DS 4277.5 7.0 0.65 2800 1.40E+06 0.260 1500 Nan DS 4284.5 9.0 0.63 2705 1.13E+06 0.270 1500 Nan DS 4293.5 3.5 0.63 2720 1.69E+06 0.260 1500 Nan DS 4297.0 5.0 0.62 2665 7.57E+05 0.270 1000 Nan DS 4302.0 2.0 0.69 2960 1.80E+06 0.250 1500 Nan CS 4304.0 10.5 0.60 2607 7.36E+05 0.270 1000 Nan CS 4314.5 3.5 0.63 2705 1.10E+06 0.270 1000 Nan CS 4318.0 2.0 0.62 2656 6.70E+05 0.280 1000 Nan CS 4320.0 5.5 0.65 2801 1.30E+06 0.260 1000 Nan DS 4325.5 3.5 0.69 2986 1.53E+06 0.260 1500 Nan DS 4329.0 3.5 0.63 2733 1.19E+06 0.270 1500 Nan DS 4332.5 5.5 0.68 2928 1.42E+06 0.260 1500 Nan CS 4338.0 10.5 0.62 2693 1.17E+06 0.270 1000 Nan DS 4348.5 1.5 0.65 2844 1.38E+06 0.260 1500 Nan DS 4350.0 5.0 0.62 2703 1.14E+06 0.270 1500 Nan DS 4355.0 2.0 0.66 2853 1.56E+06 0.260 1500 Nan DS 4357.0 4.0 0.62 2720 8.96E+05 0.270 1500 Nan DS 4361.0 2.0 0.66 2876 1.66E+06 0.260 1500 Nan DS 4363.0 10.0 0.63 2739 9.81E+05 0.270 1500 Nan DS 4373.0 4.0 0.65 2861 1.63E+06 0.260 1500 Nan DS 4377.0 4.0 0.68 2974 1.75E+06 0.260 1500 Nan DS 4381.0 9.5 0.63 2784 1.33E+06 0.260 1500 Nan DS 4390.5 2.0 0.60 2649 7.82E+05 0.270 1000 Nan DS 4392.5 9.5 0.68 2975 1.69E+06 0.260 1500 Nan DS 4402.0 2.0 0.64 2812 1.37E+06 0.260 1500 Shale 4404.0 2.0 0.68 3002 2.67E+06 0.230 2500 Nan DS 4406.0 2.0 0.63 2765 1.09E+06 0.270 1500 Shale 4408.0 2.0 0.68 3005 2.67E+06 0.230 2500 Nan DS 4410.0 4.0 0.64 2844 1.29E+06 0.260 1500 Shale 4414.0 19.5 0.68 3015 2.67E+06 0.230 2500 Nan DS 4433.5 2.0 0.64 2820 1.36E+06 0.260 1500 Shale 4435.5 2.0 0.68 3024 2.67E+06 0.230 2500 Nan DS 4437.5 8.0 0.64 2855 1.37E+06 0.260 1500 Nan DS 4445.5 8.0 0.65 2874 1.56E+06 0.260 1500 Shale 4453.5 20.0 0.69 3089 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 22 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4166.7 10.0 0.001 1.0 1890 4176.7 15.0 0.001 1.0 1898 4191.7 15.3 0.005 10.0 1905 4207.0 19.5 30.655 23.7 1915 4226.5 2.0 5.000 10.0 1924 4228.5 1.5 2.095 16.9 1925 4230.0 4.5 48.388 26.6 1926 4234.5 3.5 0.478 12.4 1928 4238.0 14.5 15.008 17.7 1930 4252.5 1.5 3.661 17.6 1937 4254.0 12.5 34.723 23.9 1937 4266.5 2.0 1.697 15.6 1943 4268.5 9.0 54.319 24.4 1944 4277.5 7.0 3.610 14.8 1948 4284.5 9.0 22.986 20.4 1952 4293.5 3.5 0.835 14.0 1956 4297.0 5.0 65.392 23.4 1957 4302.0 2.0 0.006 10.5 1960 4304.0 10.5 100.832 25.6 1961 4314.5 3.5 17.434 20.5 1966 4318.0 2.0 161.343 26.3 1967 4320.0 5.5 4.627 18.4 1968 4325.5 3.5 5.075 14.8 1971 4329.0 3.5 8.651 19.4 1972 4332.5 5.5 10.205 16.0 1974 4338.0 10.5 17.356 20.1 1977 4348.5 1.5 3.106 14.8 1982 4350.0 5.0 52.863 20.6 1982 4355.0 2.0 2.277 14.1 1985 4357.0 4.0 122.778 23.1 1986 4361.0 2.0 0.333 12.5 1987 4363.0 10.0 39.939 21.2 1988 4373.0 4.0 0.748 13.3 1993 4377.0 4.0 0.009 10.9 1995 4381.0 9.5 5.399 16.7 1997 4390.5 2.0 160.618 24.9 2001 4392.5 9.5 0.033 11.5 2002 4402.0 2.0 6.733 16.2 2007 4404.0 2.0 0.001 1.0 2008 4406.0 2.0 29.480 19.6 2009 4408.0 2.0 0.001 1.0 2009 4410.0 4.0 8.473 16.6 2010 4414.0 19.5 0.001 1.0 2012 4433.5 2.0 2.185 16.4 2021 4435.5 2.0 0.001 1.0 2022 4437.5 8.0 2.645 15.9 2023 4445.5 8.0 2.026 14.4 2027 4453.5 20.0 0.001 10.0 2031Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Nan DS Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS Formation Transmissibility Properties Zone Name 23 SLB Private Attachment K Section 17: Propped Fracture Schedule (Stage 6; 11488 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 300.0 25 0 1.0 PPA 40 YF125ST 191.6 25 1 2.0 PPA 40 YF125ST 202.3 25 2 4.0 PPA 40 YF125ST 204.2 25 4 6.0 PPA 40 YF125ST 198.0 25 6 8.0 PPA 40 YF125ST 185.2 25 8 10.0 PPA 40 YF125ST 153.0 25 10 12.0 PPA 40 YF125ST 131.1 25 12 Flush 40 YF125ST 174.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1739.5 bbl of YF125ST 0 bbl of WF125 301831 lb of 0 lb of % PAD Clean 19.2 % PAD Dirty 16.0 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 300.0 300 300 300 0 0 3201 7.5 7.5 1.0 PPA 191.6 492 200 500 8048 8048 3191 5.0 12.5 2.0 PPA 202.3 694 220 720 16993 25040 3256 5.5 18.0 4.0 PPA 204.2 898 240 960 34313 59354 3546 6.0 24.0 6.0 PPA 198.0 1096 250 1210 49898 109251 3959 6.3 30.3 8.0 PPA 185.2 1281 250 1460 62217 171468 4313 6.3 36.5 10.0 PPA 153.0 1434 220 1680 64272 235740 4486 5.5 42.0 12.0 PPA 131.1 1565 200 1880 66091 301831 4547 5.0 47.0 Flush 174.0 1739 174 2054 0 301831 4324 4.4 51.4 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 12/18 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 343.1 ft with an average conductivity (Kfw) of 19637.1 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 24 SLB Private Attachment K Section 18: Propped Fracture Simulation (Stage 6; 11488 ft MD) Initial Fracture Top TVD 4176.2 ft Initial Fracture Bottom TVD 4419.5 ft Propped Fracture Half-Length 343.1 ft EOJ Hyd Height at Well 243.3 ft Average Propped Width 0.225 in Net Pressure 264 psi Max Surface Pressure 4631 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 85.8 10.9 0.264 196.1 2.28 245 23644 85.8 171.6 9 0.262 196.1 2.32 256 23298 171.6 257.4 7.8 0.25 196.1 2.25 269.5 21925 257.4 343.1 3 0.137 179.4 1.25 533.5 11295 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 25 SLB Private Attachment K Section 19: Zone Data (Stage 7; 11028 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4180.7 10.0 0.70 2937 1.46E+06 0.220 1000 Shale 4190.7 15.0 0.70 2918 1.76E+06 0.220 1000 Nanushuk 3 SS 4205.7 15.3 0.68 2857 1.90E+06 0.220 1000 Top Nan CS 4221.0 19.5 0.62 2636 9.00E+05 0.270 1000 Nan SS 4240.5 2.0 0.68 2880 2.67E+06 0.230 2500 Nan CS 4242.5 1.5 0.64 2707 1.29E+06 0.260 1000 Nan CS 4244.0 4.5 0.62 2616 6.44E+05 0.280 1000 Nan DS 4248.5 3.5 0.68 2886 1.77E+06 0.260 1500 Nan DS 4252.0 14.5 0.65 2769 1.39E+06 0.260 1500 Nan CS 4266.5 1.5 0.64 2748 1.15E+06 0.270 1000 Nan CS 4268.0 12.5 0.63 2693 8.82E+05 0.270 1000 Nan DS 4280.5 2.0 0.65 2779 1.40E+06 0.260 1500 Nan CS 4282.5 9.0 0.60 2558 8.54E+05 0.270 1000 Nan DS 4291.5 7.0 0.65 2809 1.40E+06 0.260 1500 Nan DS 4298.5 9.0 0.63 2705 1.13E+06 0.270 1500 Nan DS 4307.5 3.5 0.63 2720 1.69E+06 0.260 1500 Nan DS 4311.0 5.0 0.62 2665 7.57E+05 0.270 1000 Nan DS 4316.0 2.0 0.69 2970 1.80E+06 0.250 1500 Nan CS 4318.0 10.5 0.60 2607 7.36E+05 0.270 1000 Nan CS 4328.5 3.5 0.62 2705 1.10E+06 0.270 1000 Nan CS 4332.0 2.0 0.62 2665 6.70E+05 0.280 1000 Nan CS 4334.0 5.5 0.65 2810 1.30E+06 0.260 1000 Nan DS 4339.5 3.5 0.69 2995 1.53E+06 0.260 1500 Nan DS 4343.0 3.5 0.63 2742 1.19E+06 0.270 1500 Nan DS 4346.5 5.5 0.67 2928 1.42E+06 0.260 1500 Nan CS 4352.0 10.5 0.62 2693 1.17E+06 0.270 1000 Nan DS 4362.5 1.5 0.65 2854 1.38E+06 0.260 1500 Nan DS 4364.0 5.0 0.62 2712 1.14E+06 0.270 1500 Nan DS 4369.0 2.0 0.66 2862 1.56E+06 0.260 1500 Nan DS 4371.0 4.0 0.62 2729 8.96E+05 0.270 1500 Nan DS 4375.0 2.0 0.66 2876 1.66E+06 0.260 1500 Nan DS 4377.0 10.0 0.63 2748 9.81E+05 0.270 1500 Nan DS 4387.0 4.0 0.65 2870 1.63E+06 0.260 1500 Nan DS 4391.0 4.0 0.68 2974 1.75E+06 0.260 1500 Nan DS 4395.0 9.5 0.63 2784 1.33E+06 0.260 1500 Nan DS 4404.5 2.0 0.60 2649 7.82E+05 0.270 1000 Nan DS 4406.5 9.5 0.67 2975 1.69E+06 0.260 1500 Nan DS 4416.0 2.0 0.64 2812 1.37E+06 0.260 1500 Shale 4418.0 2.0 0.68 3002 2.67E+06 0.230 2500 Nan DS 4420.0 2.0 0.63 2765 1.09E+06 0.270 1500 Shale 4422.0 2.0 0.68 3005 2.67E+06 0.230 2500 Nan DS 4424.0 4.0 0.64 2844 1.29E+06 0.260 1500 Shale 4428.0 19.5 0.68 3015 2.67E+06 0.230 2500 Nan DS 4447.5 2.0 0.63 2820 1.36E+06 0.260 1500 Shale 4449.5 2.0 0.68 3024 2.67E+06 0.230 2500 Nan DS 4451.5 8.0 0.64 2855 1.37E+06 0.260 1500 Nan DS 4459.5 8.0 0.65 2883 1.56E+06 0.260 1500 Shale 4467.5 20.0 0.69 3098 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 26 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4180.7 10.0 0.001 1.0 1890 4190.7 15.0 0.001 1.0 1898 4205.7 15.3 0.005 10.0 1905 4221.0 19.5 30.655 23.7 1915 4240.5 2.0 5.000 10.0 1924 4242.5 1.5 2.095 16.9 1925 4244.0 4.5 48.388 26.6 1926 4248.5 3.5 0.478 12.4 1928 4252.0 14.5 15.008 17.7 1930 4266.5 1.5 3.661 17.6 1937 4268.0 12.5 34.723 23.9 1937 4280.5 2.0 1.697 15.6 1943 4282.5 9.0 54.319 24.4 1944 4291.5 7.0 3.610 14.8 1948 4298.5 9.0 22.986 20.4 1952 4307.5 3.5 0.835 14.0 1956 4311.0 5.0 65.392 23.4 1957 4316.0 2.0 0.006 10.5 1960 4318.0 10.5 100.832 25.6 1961 4328.5 3.5 17.434 20.5 1966 4332.0 2.0 161.343 26.3 1967 4334.0 5.5 4.627 18.4 1968 4339.5 3.5 5.075 14.8 1971 4343.0 3.5 8.651 19.4 1972 4346.5 5.5 10.205 16.0 1974 4352.0 10.5 17.356 20.1 1977 4362.5 1.5 3.106 14.8 1982 4364.0 5.0 52.863 20.6 1982 4369.0 2.0 2.277 14.1 1985 4371.0 4.0 122.778 23.1 1986 4375.0 2.0 0.333 12.5 1987 4377.0 10.0 39.939 21.2 1988 4387.0 4.0 0.748 13.3 1993 4391.0 4.0 0.009 10.9 1995 4395.0 9.5 5.399 16.7 1997 4404.5 2.0 160.618 24.9 2001 4406.5 9.5 0.033 11.5 2002 4416.0 2.0 6.733 16.2 2007 4418.0 2.0 0.001 1.0 2008 4420.0 2.0 29.480 19.6 2009 4422.0 2.0 0.001 1.0 2009 4424.0 4.0 8.473 16.6 2010 4428.0 19.5 0.001 1.0 2012 4447.5 2.0 2.185 16.4 2021 4449.5 2.0 0.001 1.0 2022 4451.5 8.0 2.645 15.9 2023 4459.5 8.0 2.026 14.4 2027 4467.5 20.0 0.001 10.0 2031Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Nan DS Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS Formation Transmissibility Properties Zone Name 27 SLB Private Attachment K Section 20: Propped Fracture Schedule (Stage 7; 11028 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 275.0 25 0 1.0 PPA 40 YF125ST 172.5 25 1 2.0 PPA 40 YF125ST 183.9 25 2 4.0 PPA 40 YF125ST 187.2 25 4 6.0 PPA 40 YF125ST 174.2 25 6 8.0 PPA 40 YF125ST 162.9 25 8 10.0 PPA 40 YF125ST 139.1 25 10 12.0 PPA 40 YF125ST 118.0 25 12 Flush 40 YF125ST 167.0 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1579.9 bbl of YF125ST 0 bbl of WF125 270716 lb of 0 lb of % PAD Clean 19.5 % PAD Dirty 16.2 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 275.0 275 275 275 0 0 3128 6.9 6.9 1.0 PPA 172.5 447 180 455 7243 7243 3113 4.5 11.4 2.0 PPA 183.9 631 200 655 15448 22691 3156 5.0 16.4 4.0 PPA 187.2 819 220 875 31454 54145 3423 5.5 21.9 6.0 PPA 174.2 993 220 1095 43910 98055 3844 5.5 27.4 8.0 PPA 162.9 1156 220 1315 54751 152805 4178 5.5 32.9 10.0 PPA 139.1 1295 200 1515 58429 211234 4325 5.0 37.9 12.0 PPA 118.0 1413 180 1695 59482 270716 4374 4.5 42.4 Flush 167.0 1580 167 1862 0 270716 4137 4.2 46.5 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 12/18 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 323.8 ft with an average conductivity (Kfw) of 18510.9 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 28 SLB Private Attachment K Section 21: Propped Fracture Simulation (Stage 7; 11028 ft MD) Initial Fracture Top TVD 4192.4 ft Initial Fracture Bottom TVD 4433.4 ft Propped Fracture Half-Length 323.8 ft EOJ Hyd Height at Well 241.1 ft Average Propped Width 0.214 in Net Pressure 253 psi Max Surface Pressure 4452 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 81 11.2 0.254 162.9 2.2 240.9 22685 81 161.9 9.1 0.248 211.8 2.21 253.6 21904 161.9 242.9 7.4 0.221 194.8 1.96 281 19183 242.9 323.8 3.3 0.143 174.2 1.31 445.5 11603 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 29 SLB Private Attachment K Section 22: Zone Data (Stage 8; 10526 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4199.9 10.0 0.70 2955 1.46E+06 0.220 1000 Shale 4209.9 15.0 0.70 2931 1.76E+06 0.220 1000 Siltstone 4224.9 15.3 0.68 2870 1.90E+06 0.220 1000 Top Nan CS 4240.2 17.5 0.62 2648 8.18E+05 0.270 1000 Nan DS 4257.7 2.0 0.60 2549 7.85E+05 0.270 1000 Nan DS 4259.7 5.5 0.63 2673 1.25E+06 0.260 1500 SHALE 4265.2 3.5 0.68 2909 2.67E+06 0.230 2500 Nan DS 4268.7 1.5 0.63 2676 1.10E+06 0.270 1500 Nan DS 4270.2 2.0 0.64 2712 9.14E+05 0.270 1500 Nan CS 4272.2 1.5 0.61 2605 6.70E+05 0.280 1000 Nan CS 4273.7 2.0 0.64 2740 1.25E+06 0.260 1000 Nan CS 4275.7 3.5 0.60 2560 7.72E+05 0.270 1000 Nan CS 4279.2 4.5 0.61 2605 8.74E+05 0.270 1000 Nan DS 4283.7 7.0 0.65 2768 1.42E+06 0.260 1500 Nan DS 4290.7 4.5 0.61 2611 7.58E+05 0.270 1000 Nan DS 4295.2 5.0 0.61 2627 9.98E+05 0.270 1500 Nan CS 4300.2 4.5 0.64 2758 1.12E+06 0.270 1000 Nan CS 4304.7 9.5 0.60 2593 7.78E+05 0.270 1000 Nan DS 4314.2 2.5 0.64 2767 1.69E+06 0.260 1500 Nan DS 4316.7 12.0 0.62 2685 9.65E+05 0.270 1500 Nan DS 4328.7 2.5 0.65 2801 1.47E+06 0.260 1500 Nan DS 4331.2 9.5 0.62 2706 1.30E+06 0.260 1500 Nan DS 4340.7 2.0 0.64 2765 1.44E+06 0.260 1500 Nan DS 4342.7 41.0 0.63 2729 1.02E+06 0.270 1500 Nan DS 4383.7 1.5 0.62 2732 8.62E+05 0.270 1000 Nan CS 4385.2 6.0 0.61 2695 7.65E+05 0.280 1000 Nan DS 4391.2 6.0 0.66 2899 1.24E+06 0.260 1500 Nan DS 4397.2 4.0 0.68 2991 1.69E+06 0.260 1500 Nan DS 4401.2 2.0 0.64 2817 1.01E+06 0.270 1500 Nan DS 4403.2 2.0 0.69 3026 1.69E+06 0.260 1500 Nan DS 4405.2 2.0 0.63 2786 1.13E+06 0.270 1500 Nan DS 4407.2 5.5 0.68 2994 1.69E+06 0.260 1500 Nan DS 4412.7 4.0 0.62 2720 9.50E+05 0.270 1000 Nan DS 4416.7 2.0 0.68 2995 1.69E+06 0.260 1500 Nan DS 4418.7 12.0 0.63 2783 9.20E+05 0.270 1000 Nan DS 4430.7 4.0 0.69 3036 1.43E+06 0.260 1500 Nan DS 4434.7 4.0 0.63 2810 1.47E+06 0.260 1500 SHALE 4438.7 2.0 0.68 3023 2.67E+06 0.230 2500 Nan DS 4440.7 1.5 0.64 2849 1.37E+06 0.260 1500 SHALE 4442.2 8.0 0.68 3028 2.67E+06 0.230 2500 Nan DS 4450.2 8.0 0.62 2772 1.13E+06 0.270 1500 Nan DS 4458.2 1.5 0.63 2792 1.42E+06 0.260 1500 SHALE 4459.7 2.0 0.68 3038 2.67E+06 0.230 2500 Nan DS 4461.7 4.0 0.64 2843 1.28E+06 0.260 1500 SHALE 4465.7 2.0 0.68 3042 2.67E+06 0.230 2500 Nan DS 4467.7 6.0 0.63 2801 1.07E+06 0.270 1500 SHALE 4473.7 20.0 0.68 3059 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 30 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4199.9 10.0 0.001 1.0 1913 4209.9 15.0 0.001 1.0 1918 4224.9 15.3 0.005 10.0 1925 4240.2 17.5 39.470 24.9 1932 4257.7 2.0 113.240 25.3 1940 4259.7 5.5 22.020 19.7 1941 4265.2 3.5 0.001 1.0 1944 4268.7 1.5 21.670 21.3 1945 4270.2 2.0 159.890 23.6 1946 4272.2 1.5 110.140 27.0 1947 4273.7 2.0 2.870 19.7 1948 4275.7 3.5 94.750 25.5 1949 4279.2 4.5 44.130 24.1 1950 4283.7 7.0 4.280 17.9 1952 4290.7 4.5 91.630 25.7 1956 4295.2 5.0 31.600 22.6 1958 4300.2 4.5 3.110 21.1 1960 4304.7 9.5 131.710 25.4 1962 4314.2 2.5 1.000 15.1 1967 4316.7 12.0 104.140 23.0 1968 4328.7 2.5 2.350 17.3 1974 4331.2 9.5 31.760 19.2 1975 4340.7 2.0 3.790 17.6 1979 4342.7 41.0 72.280 22.4 1980 4383.7 1.5 68.110 24.3 1999 4385.2 6.0 156.150 26.2 2000 4391.2 6.0 40.960 19.9 2003 4397.2 4.0 0.020 15.0 2006 4401.2 2.0 17.850 22.4 2008 4403.2 2.0 0.010 15.0 2009 4405.2 2.0 22.090 21.0 2010 4407.2 5.5 0.020 15.0 2011 4412.7 4.0 63.420 23.1 2013 4416.7 2.0 0.020 15.0 2015 4418.7 12.0 74.620 23.5 2016 4430.7 4.0 11.770 17.8 2022 4434.7 4.0 2.490 17.3 2023 4438.7 2.0 0.001 1.0 2025 4440.7 1.5 3.220 18.4 2026 4442.2 8.0 0.001 1.0 2027 4450.2 8.0 65.690 21.2 2031 4458.2 1.5 4.800 17.8 2035 4459.7 2.0 0.001 1.0 2035 4461.7 4.0 11.980 19.3 2036 4465.7 2.0 0.001 1.0 2038 4467.7 6.0 60.610 22.1 2039 4473.7 20.0 0.001 1.0 2042 Nan DS SHALE Nan DS SHALE Nan DS Nan DS SHALE Nan DS SHALE Nan DS SHALE Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Nan DS Nan DS Nan DS Nan CS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan CS Shale Shale Siltstone Top Nan CS Nan DS Nan DS SHALE Nan DS Nan DS Nan CS Nan CS Formation Transmissibility Properties Zone Name 31 SLB Private Attachment K Section 23: Propped Fracture Schedule (Stage 8; 10526 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 250.0 25 0 1.0 PPA 40 YF125ST 143.7 25 1 2.0 PPA 40 YF125ST 160.9 25 2 4.0 PPA 40 YF125ST 161.7 25 4 6.0 PPA 40 YF125ST 150.5 25 6 8.0 PPA 40 YF125ST 140.7 25 8 10.0 PPA 40 YF125ST 132.2 25 10 12.0 PPA 40 YF125ST 104.9 25 12 Flush 40 YF125ST 160.3 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1404.9 bbl of YF125ST 0 bbl of WF125 240305 lb of 0 lb of % PAD Clean 20.1 % PAD Dirty 16.7 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 250.0 250 250 250 0 0 3015 6.3 6.3 1.0 PPA 143.7 394 150 400 6036 6036 3005 3.8 10.0 2.0 PPA 160.9 555 175 575 13517 19553 3039 4.4 14.4 4.0 PPA 161.7 716 190 765 27165 46717 3265 4.8 19.1 6.0 PPA 150.5 867 190 955 37922 84640 3631 4.8 23.9 8.0 PPA 140.7 1008 190 1145 47285 131924 3967 4.8 28.6 10.0 PPA 132.2 1140 190 1335 55508 187432 4130 4.8 33.4 12.0 PPA 104.9 1245 160 1495 52873 240305 4174 4.0 37.4 Flush 160.3 1405 160 1655 0 240305 3955 4.0 41.4 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 12/18 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 305.3 ft with an average conductivity (Kfw) of 17790.9 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 32 SLB Private Attachment K Section 24: Propped Fracture Simulation (Stage 8; 10526 ft MD) Initial Fracture Top TVD 4211.8 ft Initial Fracture Bottom TVD 4446.4 ft Propped Fracture Half-Length 305.3 ft EOJ Hyd Height at Well 234.6 ft Average Propped Width 0.204 in Net Pressure 152 psi Max Surface Pressure 4229 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 76.3 11.8 0.247 189.1 2.15 228 22213 76.3 152.6 9.4 0.24 189.1 2.13 241.9 21156 152.6 229 6.7 0.217 186.8 1.93 267 18885 229 305.3 2.5 0.124 171.2 1.11 672.2 10216 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 33 SLB Private Attachment K Section 25: Zone Data (Stage 9; 10024 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4180.4 41.7 0.71 2965 1.46E+06 0.220 1000 SHALE 4222.1 15.0 0.70 2940 1.76E+06 0.220 1000 SILTSTONE 4237.1 24.1 0.68 2881 1.90E+06 0.220 1000 Top Nan CS 4261.2 7.0 0.62 2654 2.37E+06 0.240 1000 DIRTY-SANDSTONE 4268.2 1.5 0.67 2880 1.50E+06 0.240 1000 SHALE 4269.7 2.0 0.68 2917 2.67E+06 0.230 2500 CLEAN-SANDSTONE 4271.7 10.5 0.61 2622 6.84E+05 0.280 1000 DIRTY-SANDSTONE 4282.2 6.5 0.63 2711 1.02E+06 0.270 1500 DIRTY-SANDSTONE 4288.7 5.5 0.64 2739 1.54E+06 0.260 1500 DIRTY-SANDSTONE 4294.2 5.0 0.62 2662 1.23E+06 0.260 1000 DIRTY-SANDSTONE 4299.2 1.5 0.65 2773 1.41E+06 0.260 1500 DIRTY-SANDSTONE 4300.7 2.0 0.64 2767 1.70E+06 0.260 1500 DIRTY-SANDSTONE 4302.7 1.5 0.60 2573 5.77E+05 0.280 1500 DIRTY-SANDSTONE 4304.2 11.5 0.64 2767 1.31E+06 0.260 1500 DIRTY-SANDSTONE 4315.7 1.8 0.67 2875 1.24E+06 0.270 1500 DIRTY-SANDSTONE 4317.5 2.1 0.68 2929 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4319.6 8.2 0.62 2685 9.65E+05 0.270 1000 DIRTY-SANDSTONE 4327.8 4.9 0.64 2771 1.46E+06 0.260 1500 DIRTY-SANDSTONE 4332.7 1.5 0.67 2890 1.68E+06 0.260 1500 DIRTY-SANDSTONE 4334.2 2.0 0.63 2732 1.51E+06 0.260 1500 SHALE 4336.2 3.5 0.69 2989 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4339.7 1.5 0.65 2814 1.65E+06 0.260 1500 SHALE 4341.2 1.5 0.68 2966 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4342.7 3.5 0.63 2717 1.48E+06 0.260 1500 SHALE 4346.2 5.0 0.68 2971 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4351.2 2.0 0.62 2696 1.12E+06 0.270 1500 SHALE 4353.2 5.0 0.68 2976 2.67E+06 0.230 2500 SHALE 4358.2 3.5 0.68 2979 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4361.7 1.5 0.65 2819 1.31E+06 0.260 1500 SHALE 4363.2 11.0 0.68 2985 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4374.2 2.0 0.62 2717 8.37E+05 0.270 1000 SHALE 4376.2 1.5 0.68 2990 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4377.7 2.0 0.63 2741 9.57E+05 0.270 1000 DIRTY-SANDSTONE 4379.7 4.0 0.68 2984 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4383.7 5.5 0.63 2769 1.20E+06 0.270 1500 DIRTY-SANDSTONE 4389.2 2.0 0.62 2728 9.33E+05 0.270 1000 DIRTY-SANDSTONE 4391.2 6.0 0.68 2992 1.74E+06 0.260 1500 DIRTY-SANDSTONE 4397.2 21.5 0.63 2787 1.08E+06 0.270 1500 DIRTY-SANDSTONE 4418.7 2.0 0.69 3036 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4420.7 4.0 0.64 2842 1.16E+06 0.270 1500 DIRTY-SANDSTONE 4424.7 2.0 0.60 2660 8.76E+05 0.270 1500 SHALE 4426.7 2.0 0.68 3025 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4428.7 4.0 0.64 2828 1.52E+06 0.260 1500 DIRTY-SANDSTONE 4432.7 4.0 0.62 2768 1.12E+06 0.270 1500 DIRTY-SANDSTONE 4436.7 2.0 0.68 3018 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4438.7 7.5 0.64 2821 1.18E+06 0.270 1500 SHALE 4446.2 9.5 0.68 3041 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 34 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4180.4 41.7 0.010 1.0 1918 4222.1 15.0 0.010 1.0 1923 4237.1 24.1 0.050 10.0 1929 4261.2 7.0 6.009 4.1 1940 4268.2 1.5 0.192 12.0 1944 4269.7 2.0 0.010 1.0 1944 4271.7 10.5 100.314 26.7 1945 4282.2 6.5 21.598 22.3 1950 4288.7 5.5 1.009 16.6 1953 4294.2 5.0 3.544 19.9 1956 4299.2 1.5 5.023 17.9 1958 4300.7 2.0 0.319 14.9 1959 4302.7 1.5 236.504 28.4 1960 4304.2 11.5 21.887 19.1 1960 4315.7 1.8 50.818 20.1 1966 4317.5 2.1 0.026 15.0 1968 4319.6 8.2 62.684 23.0 1970 4327.8 4.9 4.489 17.4 1970 4332.7 1.5 0.488 15.1 1974 4334.2 2.0 1.982 16.9 1974 4336.2 3.5 0.010 1.0 1975 4339.7 1.5 0.552 15.4 1977 4341.2 1.5 0.010 1.0 1978 4342.7 3.5 3.859 17.2 1978 4346.2 5.0 0.010 1.0 1980 4351.2 2.0 41.288 21.2 1982 4353.2 5.0 0.010 1.0 1983 4358.2 3.5 0.010 1.0 1986 4361.7 1.5 5.111 19.0 1987 4363.2 11.0 0.010 1.0 1988 4374.2 2.0 111.829 24.6 1993 4376.2 1.5 0.010 1.0 1994 4377.7 2.0 102.765 23.1 1995 4379.7 4.0 0.016 15.0 1996 4383.7 5.5 24.191 20.3 1997 4389.2 2.0 33.759 23.4 2000 4391.2 6.0 0.015 14.5 2001 4397.2 21.5 82.778 21.8 2004 4418.7 2.0 0.014 15.0 2014 4420.7 4.0 26.711 20.7 2015 4424.7 2.0 162.436 24.1 2017 4426.7 2.0 0.010 1.0 2018 4428.7 4.0 1.983 16.8 2019 4432.7 4.0 30.725 21.1 2020 4436.7 2.0 0.009 15.0 2022 4438.7 7.5 8.533 20.5 2023 4446.2 9.5 0.010 1.0 2027 DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE Shale SHALE SILTSTONE Top Nan CS DIRTY-SANDSTONE SHALE CLEAN-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE Formation Transmissibility Properties Zone Name 35 SLB Private Attachment K Section 26: Propped Fracture Schedule (Stage 9; 10024 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 200.0 25 0 1.0 PPA Scou 40 YF125ST 57.4 25 1 3.0 PPA Scou 40 YF125ST 105.6 25 3 Resume PAD 40 YF125ST 50.0 25 0 1.0 PPA 40 YF125ST 143.7 25 1 2.0 PPA 40 YF125ST 160.9 25 2 4.0 PPA 40 YF125ST 161.7 25 4 6.0 PPA 40 YF125ST 150.5 25 6 8.0 PPA 40 YF125ST 140.7 25 8 10.0 PPA 40 YF125ST 132.2 25 10 12.0 PPA 40 YF125ST 104.9 25 12 Flush 40 YF125ST 151.7 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1559.2 bbl of YF125ST 0 bbl of WF125 240306 lb of 15712 lb of % PAD Clean 14.2 % PAD Dirty 11.9 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 200.0 200 200 200 0 0 3039 5.0 5.0 1.0 PPA Scou 57.4 257 60 260 2410 2410 3045 1.5 6.5 3.0 PPA Scou 105.6 363 120 380 13302 15712 3067 3.0 9.5 Resume PAD 50.0 413 50 430 0 15712 3164 1.3 10.7 1.0 PPA 143.7 557 150 580 6036 21748 3251 3.8 14.5 2.0 PPA 160.9 718 175 755 13516 35264 3070 4.4 18.9 4.0 PPA 161.7 879 190 945 27164 62428 3271 4.8 23.7 6.0 PPA 150.5 1030 190 1135 37920 100348 3599 4.8 28.5 8.0 PPA 140.7 1170 190 1325 47288 147636 3857 4.8 33.2 10.0 PPA 132.2 1303 190 1515 55510 203146 4033 4.8 38.0 12.0 PPA 104.9 1408 160 1675 52872 256018 4086 4.0 42.0 Flush 151.7 1559 152 1827 0 256018 3885 3.8 45.8 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 40/70 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 422.6 ft with an average conductivity (Kfw) of 12599.7 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 40/70 Carbolite 40/70 Carbolite 16/20 36 SLB Private Attachment K Section 27: Propped Fracture Simulation (Stage 9; 10024 ft MD) Initial Fracture Top TVD 4207.8 ft Initial Fracture Bottom TVD 4466.7 ft Propped Fracture Half-Length 422.6 ft EOJ Hyd Height at Well 258.9 ft Average Propped Width 0.147 in Net Pressure 445 psi Max Surface Pressure 4143 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 105.7 10 0.212 207.1 1.78 237.3 19338 105.7 211.3 6.9 0.183 207.1 1.59 271.8 16236 211.3 317 4.3 0.135 204.4 1.2 349.6 11397 317 422.6 1 0.075 146.2 0.72 490.1 5412 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 37 SLB Private Attachment K Section 28: Zone Data (Stage 10; 9526 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4200.4 41.7 0.70 2965 1.46E+06 0.220 1000 SHALE 4242.1 15.0 0.70 2953 1.76E+06 0.220 1000 SILTSTONE 4257.1 24.1 0.68 2894 1.90E+06 0.220 1000 Top Nan CS 4281.2 7.0 0.62 2654 2.37E+06 0.240 1000 DIRTY-SANDSTONE 4288.2 1.5 0.67 2880 1.50E+06 0.240 1000 SHALE 4289.7 2.0 0.68 2917 2.67E+06 0.230 2500 CLEAN-SANDSTONE 4291.7 10.5 0.61 2622 6.84E+05 0.280 1000 DIRTY-SANDSTONE 4302.2 6.5 0.63 2711 1.02E+06 0.270 1500 DIRTY-SANDSTONE 4308.7 5.5 0.64 2739 1.54E+06 0.260 1500 DIRTY-SANDSTONE 4314.2 5.0 0.62 2662 1.23E+06 0.260 1000 DIRTY-SANDSTONE 4319.2 1.5 0.65 2786 1.41E+06 0.260 1500 DIRTY-SANDSTONE 4320.7 2.0 0.64 2767 1.70E+06 0.260 1500 DIRTY-SANDSTONE 4322.7 1.5 0.60 2585 5.77E+05 0.280 1500 DIRTY-SANDSTONE 4324.2 11.5 0.64 2767 1.31E+06 0.260 1500 DIRTY-SANDSTONE 4335.7 1.8 0.67 2888 1.24E+06 0.270 1500 DIRTY-SANDSTONE 4337.5 2.1 0.68 2929 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4339.6 8.2 0.62 2697 9.65E+05 0.270 1000 DIRTY-SANDSTONE 4347.8 4.9 0.64 2784 1.46E+06 0.260 1500 DIRTY-SANDSTONE 4352.7 1.5 0.66 2890 1.68E+06 0.260 1500 DIRTY-SANDSTONE 4354.2 2.0 0.63 2732 1.51E+06 0.260 1500 SHALE 4356.2 3.5 0.69 3003 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4359.7 1.5 0.65 2814 1.65E+06 0.260 1500 SHALE 4361.2 1.5 0.68 2966 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4362.7 3.5 0.62 2717 1.48E+06 0.260 1500 SHALE 4366.2 5.0 0.68 2971 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4371.2 2.0 0.62 2696 1.12E+06 0.270 1500 SHALE 4373.2 5.0 0.68 2976 2.67E+06 0.230 2500 SHALE 4378.2 3.5 0.68 2979 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4381.7 1.5 0.64 2819 1.31E+06 0.260 1500 SHALE 4383.2 11.0 0.68 2985 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4394.2 2.0 0.62 2729 8.37E+05 0.270 1000 SHALE 4396.2 1.5 0.68 2990 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4397.7 2.0 0.63 2754 9.57E+05 0.270 1000 DIRTY-SANDSTONE 4399.7 4.0 0.68 2984 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4403.7 5.5 0.63 2769 1.20E+06 0.270 1500 DIRTY-SANDSTONE 4409.2 2.0 0.62 2728 9.33E+05 0.270 1000 DIRTY-SANDSTONE 4411.2 6.0 0.68 2992 1.74E+06 0.260 1500 DIRTY-SANDSTONE 4417.2 21.5 0.63 2787 1.08E+06 0.270 1500 DIRTY-SANDSTONE 4438.7 2.0 0.69 3050 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4440.7 4.0 0.64 2842 1.16E+06 0.270 1500 DIRTY-SANDSTONE 4444.7 2.0 0.60 2660 8.76E+05 0.270 1500 SHALE 4446.7 2.0 0.68 3025 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4448.7 4.0 0.64 2828 1.52E+06 0.260 1500 DIRTY-SANDSTONE 4452.7 4.0 0.62 2768 1.12E+06 0.270 1500 DIRTY-SANDSTONE 4456.7 2.0 0.68 3031 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4458.7 7.5 0.64 2834 1.18E+06 0.270 1500 SHALE 4466.2 9.5 0.68 3041 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4475.7 2.0 0.68 3058 1.69E+06 0.260 1500 SHALE 4477.7 50.0 0.69 3085 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 38 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4200.4 41.7 0.010 1.0 1918 4242.1 15.0 0.010 1.0 1923 4257.1 24.1 0.050 10.0 1929 4281.2 7.0 6.009 4.1 1940 4288.2 1.5 0.192 12.0 1944 4289.7 2.0 0.010 1.0 1944 4291.7 10.5 100.314 26.7 1945 4302.2 6.5 21.598 22.3 1950 4308.7 5.5 1.009 16.6 1953 4314.2 5.0 3.544 19.9 1956 4319.2 1.5 5.023 17.9 1958 4320.7 2.0 0.319 14.9 1959 4322.7 1.5 236.504 28.4 1960 4324.2 11.5 21.887 19.1 1960 4335.7 1.8 50.818 20.1 1966 4337.5 2.1 0.026 15.0 1968 4339.6 8.2 62.684 23.0 1970 4347.8 4.9 4.489 17.4 1970 4352.7 1.5 0.488 15.1 1974 4354.2 2.0 1.982 16.9 1974 4356.2 3.5 0.010 1.0 1975 4359.7 1.5 0.552 15.4 1977 4361.2 1.5 0.010 1.0 1978 4362.7 3.5 3.859 17.2 1978 4366.2 5.0 0.010 1.0 1980 4371.2 2.0 41.288 21.2 1982 4373.2 5.0 0.010 1.0 1983 4378.2 3.5 0.010 1.0 1986 4381.7 1.5 5.111 19.0 1987 4383.2 11.0 0.010 1.0 1988 4394.2 2.0 111.829 24.6 1993 4396.2 1.5 0.010 1.0 1994 4397.7 2.0 102.765 23.1 1995 4399.7 4.0 0.016 15.0 1996 4403.7 5.5 24.191 20.3 1997 4409.2 2.0 33.759 23.4 2000 4411.2 6.0 0.015 14.5 2001 4417.2 21.5 82.778 21.8 2004 4438.7 2.0 0.014 15.0 2014 4440.7 4.0 26.711 20.7 2015 4444.7 2.0 162.436 24.1 2017 4446.7 2.0 0.010 1.0 2018 4448.7 4.0 1.983 16.8 2019 4452.7 4.0 30.725 21.1 2020 4456.7 2.0 0.009 15.0 2022 4458.7 7.5 8.533 20.5 2023 4466.2 9.5 0.010 1.0 2027 4475.7 2.0 15.000 10.0 2096 4477.7 50.0 0.010 1.0 2107SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE Shale SHALE SILTSTONE Top Nan CS DIRTY-SANDSTONE SHALE CLEAN-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE Formation Transmissibility Properties Zone Name 39 SLB Private Attachment K Section 29: Propped Fracture Schedule (Stage 10; 9526 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 200.0 25 0 1.0 PPA Scou 40 YF125ST 57.4 25 1 3.0 PPA Scou 40 YF125ST 105.6 25 3 Resume PAD 40 YF125ST 50.0 25 0 1.0 PPA 40 YF125ST 134.1 25 1 2.0 PPA 40 YF125ST 147.1 25 2 4.0 PPA 40 YF125ST 153.2 25 4 6.0 PPA 40 YF125ST 142.6 25 6 8.0 PPA 40 YF125ST 133.3 25 8 10.0 PPA 40 YF125ST 118.2 25 10 12.0 PPA 40 YF125ST 98.3 25 12 Flush 40 YF125ST 145.1 25 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1485 bbl of YF125ST 0 bbl of WF125 223682 lb of 15712 lb of % PAD Clean 14.2 % PAD Dirty 11.9 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 200.0 200 200 200 0 0 2956 5.0 5.0 1.0 PPA Scou 57.4 257 60 260 2410 2410 2964 1.5 6.5 3.0 PPA Scou 105.6 363 120 380 13302 15712 2987 3.0 9.5 Resume PAD 50.0 413 50 430 0 15712 3068 1.3 10.7 1.0 PPA 134.1 547 140 570 5633 21345 3140 3.5 14.2 2.0 PPA 147.1 694 160 730 12358 33704 2981 4.0 18.2 4.0 PPA 153.2 847 180 910 25735 59439 3141 4.5 22.7 6.0 PPA 142.6 990 180 1090 35926 95365 3438 4.5 27.2 8.0 PPA 133.3 1123 180 1270 44796 140161 3730 4.5 31.7 10.0 PPA 118.2 1242 170 1440 49665 189826 3872 4.3 36.0 12.0 PPA 98.3 1340 150 1590 49568 239394 3905 3.8 39.7 Flush 145.1 1485 145 1735 0 239394 3699 3.6 43.4 Job Execution Step Name Pad Percentages Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 40/70 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 422.6 ft with an average conductivity (Kfw) of 12599.7 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 40/70 Carbolite 40/70 Carbolite 16/20 40 SLB Private Attachment K Section 30: Propped Fracture Simulation (Stage 10; 9526 ft MD) Initial Fracture Top TVD 4227.6 ft Initial Fracture Bottom TVD 4489.6 ft Propped Fracture Half-Length 417.8 ft EOJ Hyd Height at Well 262 ft Average Propped Width 0.135 in Net Pressure 350 psi Max Surface Pressure 3946 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 104.5 10.1 0.191 210.3 1.59 238.1 17143 104.5 208.9 7 0.168 210.3 1.44 272.9 14573 208.9 313.4 4.4 0.125 208.9 1.09 343.8 10430 313.4 417.8 1 0.069 170.1 0.62 479.5 4868 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 41 SLB Private Attachment K Section 31: Zone Data (Stage 11; 9071 ft MD) Top TVD Zone Height Frac Grad. Insitu Stress Young’s Modulus Toughness (ft) (ft) (psi/ft) (psi) (psi) (psi.in 0.5) Shale 4237.3 31.7 0.71 3001 1.46E+06 0.220 1000 SHALE 4269.0 15.0 0.70 2972 1.76E+06 0.220 1000 SILTSTONE 4284.0 24.1 0.68 2913 1.90E+06 0.220 1000 CLEAN-SANDSTONE 4308.1 3.5 0.61 2607 8.57E+05 0.270 1000 SHALE 4311.6 1.5 0.68 2952 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4313.1 1.5 0.63 2713 9.12E+05 0.270 1000 DIRTY-SANDSTONE 4314.6 3.5 0.66 2857 1.15E+06 0.270 1500 CLEAN-SANDSTONE 4318.1 2.0 0.62 2682 7.24E+05 0.280 1000 SHALE 4320.1 1.5 0.68 2958 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4321.6 14.0 0.64 2762 1.55E+06 0.260 1500 SHALE 4335.6 1.5 0.68 2969 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4337.1 3.5 0.62 2681 1.15E+06 0.270 1500 DIRTY-SANDSTONE 4340.6 1.5 0.68 2959 1.69E+06 0.260 1500 DIRTY-SANDSTONE 4342.1 2.0 0.61 2636 8.10E+05 0.270 1000 DIRTY-SANDSTONE 4344.1 5.0 0.66 2868 1.28E+06 0.260 1500 DIRTY-SANDSTONE 4349.1 10.0 0.62 2717 1.50E+06 0.260 1500 DIRTY-SANDSTONE 4359.1 10.0 0.65 2847 8.70E+05 0.270 1500 DIRTY-SANDSTONE 4369.1 5.0 0.62 2709 1.22E+06 0.270 1500 DIRTY-SANDSTONE 4374.1 8.5 0.68 2987 1.52E+06 0.260 1500 DIRTY-SANDSTONE 4382.6 3.5 0.62 2722 1.47E+06 0.260 1500 SHALE 4386.1 2.5 0.68 3004 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4388.6 1.0 0.64 2830 1.61E+06 0.260 1500 SHALE 4389.6 7.0 0.68 3008 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4396.6 3.5 0.64 2811 9.39E+05 0.270 1000 DIRTY-SANDSTONE 4400.1 4.5 0.68 3014 1.56E+06 0.260 1500 DIRTY-SANDSTONE 4404.6 2.0 0.63 2791 1.35E+06 0.260 1500 DIRTY-SANDSTONE 4406.6 2.0 0.68 3008 1.74E+06 0.260 1500 DIRTY-SANDSTONE 4408.6 5.5 0.62 2730 9.70E+05 0.270 1500 DIRTY-SANDSTONE 4414.1 6.0 0.68 3018 1.65E+06 0.260 1500 DIRTY-SANDSTONE 4420.1 10.0 0.65 2876 1.24E+06 0.260 1500 DIRTY-SANDSTONE 4430.1 2.0 0.65 2869 1.50E+06 0.260 1500 DIRTY-SANDSTONE 4432.1 7.5 0.63 2795 9.80E+05 0.270 1500 DIRTY-SANDSTONE 4439.6 1.5 0.68 3029 1.87E+06 0.250 1500 DIRTY-SANDSTONE 4441.1 3.0 0.61 2706 9.11E+05 0.270 1500 DIRTY-SANDSTONE 4444.1 5.0 0.64 2830 1.76E+06 0.260 1500 SHALE 4449.1 6.0 0.69 3067 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4455.1 2.0 0.65 2903 1.72E+06 0.260 1500 SHALE 4457.1 23.0 0.68 3060 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4480.1 2.0 0.63 2817 1.24E+06 0.260 1500 SHALE 4482.1 2.0 0.68 3070 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4484.1 2.0 0.66 2969 1.68E+06 0.260 1500 SHALE 4486.1 4.5 0.69 3092 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4490.6 10.0 0.63 2850 1.28E+06 0.260 1500 SHALE 4500.6 10.5 0.69 3105 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4511.1 2.0 0.65 2926 1.40E+06 0.260 1500 SHALE 4513.1 19.0 0.68 3097 2.67E+06 0.230 2500 DIRTY-SANDSTONE 4532.1 2.0 0.64 2897 1.44E+06 0.260 1500 SHALE 4534.1 25.0 0.69 3114 2.67E+06 0.230 2500 Formation Mechanical Properties Zone Name Poisson’s Ratio 42 SLB Private Attachment K Top TVD Net Perm Porosity Res. Pressure (ft)Height (md) (%) (psi) (ft) 4237.3 31.7 0.010 1.0 1919 4269.0 15.0 0.010 1.0 1929 4284.0 24.1 0.050 10.0 1936 4308.1 3.5 48.343 24.3 1947 4311.6 1.5 0.006 10.0 1949 4313.1 1.5 39.757 23.6 1949 4314.6 3.5 6.288 20.8 1950 4318.1 2.0 71.711 26.2 1952 4320.1 1.5 0.006 10.0 1952 4321.6 14.0 56.440 16.7 1953 4335.6 1.5 0.006 10.0 1960 4337.1 3.5 18.893 20.8 1960 4340.6 1.5 0.023 15.0 1962 4342.1 2.0 115.609 24.9 1963 4344.1 5.0 20.857 19.5 1964 4349.1 10.0 1.968 17.0 1966 4359.1 10.0 74.766 24.2 1971 4369.1 5.0 11.675 20.1 1975 4374.1 8.5 7.321 16.9 1978 4382.6 3.5 3.784 17.3 1982 4386.1 2.5 0.006 10.0 1983 4388.6 1.0 1.340 15.9 1984 4389.6 7.0 0.006 10.0 1985 4396.6 3.5 40.985 23.3 1988 4400.1 4.5 1.316 14.2 1990 4404.6 2.0 4.219 18.6 1992 4406.6 2.0 0.015 14.6 1993 4408.6 5.5 61.197 22.9 1994 4414.1 6.0 0.552 13.9 1996 4420.1 10.0 28.233 19.9 1999 4430.1 2.0 1.534 17.0 2004 4432.1 7.5 79.135 22.8 2005 4439.6 1.5 0.006 10.0 2008 4441.1 3.0 120.250 23.7 2009 4444.1 5.0 0.329 14.3 2010 4449.1 6.0 0.006 10.0 2013 4455.1 2.0 0.136 14.8 2015 4457.1 23.0 0.006 10.0 2016 4480.1 2.0 15.982 19.8 2027 4482.1 2.0 0.006 10.0 2028 4484.1 2.0 0.344 15.1 2029 4486.1 4.5 0.006 10.0 2030 4490.6 10.0 6.547 19.3 2032 4500.6 10.5 0.006 10.0 2036 4511.1 2.0 1.897 18.0 2041 4513.1 19.0 0.006 10.0 2042 4532.1 2.0 4.758 17.7 2051 4534.1 25.0 0.006 10.0 2052 Formation Transmissibility Properties Zone Name DIRTY-SANDSTONE Shale SHALE SILTSTONE CLEAN-SANDSTONE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE CLEAN-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE SHALE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE SHALE DIRTY-SANDSTONE 43 SLB Private Attachment K Section 32: Propped Fracture Schedule (Stage 11; 9071 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF125ST 200.0 25 0 1.0 PPA Scou 40 YF125ST 57.4 25 1 3.0 PPA Scou 40 YF125ST 105.6 25 3 Resume PAD 40 YF125ST 50.0 25 0 1.0 PPA 40 YF125ST 172.5 25 1 3.0 PPA 40 YF125ST 176.8 25 3 5.0 PPA 40 YF125ST 180.5 25 5 7.0 PPA 40 YF125ST 168.4 25 7 9.0 PPA 40 YF125ST 143.5 25 9 10.0 PPA 40 YF125ST 125.2 25 10 Flush 40 YF125ST 137.2 25 0 Please note that this pumping schedule is under-displaced by 1 bbl. 1517 bbl of YF125ST 0 bbl of WF125 223759 lb of 15712 lb of % PAD Clean 14.5 % PAD Dirty 12.3 Step Fluid Cum. Fluid Step Slurry Cum. Slurry Step Prop Cum. Avg. Surface Step Time Cum. Volume Volume Volume Volume (lb)Prop. Pressure (min)Time (bbl) (bbl) (bbl) (bbl) (lb) (psi) (min) PAD 200.0 200 200 200 0 0 2922 5.0 5.0 1.0 PPA Scou 57.4 257 60 260 2410 2410 2931 1.5 6.5 3.0 PPA Scou 105.6 363 120 380 13302 15712 2941 3.0 9.5 Resume PAD 50.0 413 50 430 0 15712 3006 1.3 10.7 1.0 PPA 172.5 585 180 610 7243 22955 3021 4.5 15.2 3.0 PPA 176.8 762 200 810 22275 45230 2996 5.0 20.2 5.0 PPA 180.5 943 220 1030 37905 83136 3292 5.5 25.7 7.0 PPA 168.4 1111 220 1250 49512 132648 3563 5.5 31.2 9.0 PPA 143.5 1255 200 1450 54237 186885 3710 5.0 36.2 10.0 PPA 125.2 1380 180 1630 52586 239471 3767 4.5 40.7 Flush 137.2 1517 137 1767 0 239471 3554 3.4 44.2 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 410.9 ft with an average conductivity (Kfw) of 11555.1 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 40/70 Carbolite 40/70 Carbolite 16/20 Pad Percentages Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Carbolite 40/70 Job Execution Step Name 44 SLB Private Attachment K Section 33: Propped Fracture Simulation (Stage 11; 9071 ft MD) Initial Fracture Top TVD 4244 ft Initial Fracture Bottom TVD 4520 ft Propped Fracture Half-Length 410.9 ft EOJ Hyd Height at Well 276 ft Average Propped Width 0.137 in Net Pressure 306 psi Max Surface Pressure 3775 psi From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Pumping Width Height Prop. Conc. Gel Conc. Conductivity (PPA) (in) (ft) (lb/ft2) (lb/mgal) (md.ft) 0 102.7 8.5 0.166 257.4 1.31 260.9 14583 102.7 205.4 6.3 0.157 235.8 1.28 285 13482 205.4 308.1 4.5 0.148 211.1 1.27 318.9 12672 308.1 410.9 1.3 0.083 177.2 0.75 635.3 6445 The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Simulation Results by Fracture Segment 45 SLB Private Attachment K Santos USA and Baker Hughes Confidential Page 1 © 2018 Baker Hughes, LLC - All rights reserved. LLWD Qualitative Cement Bond Log Evaluation Report Well Name, Section: NDB-025, 9 5/8” Liner Field Name: Pikka Company: Santos Rig: Parker 272 Region: North Slope State: Alaska Country: United States Prepared by: Reservoir Technical Services Alaska Version: Preliminary Report Santos USA and Baker Hughes Confidential Page 2 Contents Baker Hughes Legal Disclaimer ................................................................................................................................................................ 3 Executive Summary ........................................................................................................................................................................................... 4 Tool Diagram ..........................................................................................................................................................................................................6 Methodology of LWD Cement Bond Log Evaluation ................................................................................................................. 7 Log Screen Captures ...................................................................................................................................................................................... 12 Santos USA and Baker Hughes Confidential Page 3 Baker Hughes Legal Disclaimer IN MAKING INTERPRETATIONS OF LOGS OUR EMPLOYEES WILL GIVE CUSTOMER THE BENEFIT OF THEIR BEST JUDGMENT. BUT SINCE ALL INTERPRETATIONS ARE OPINIONS BASED ON ELECTRICAL OR OTHER MEASUREMENTS, WE CANNOT, AND WE DO NOT GUARANTEE THE ACCURACY OR CORRECTNESS OF ANY INTERPRETATION. WE SHALL NOT BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COST, DAMAGES, OR EXPENSES WHATSOEVER INCURRED OR SUSTAINED BY THE CUSTOMER RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR EMPLOYEES. Santos USA and Baker Hughes Confidential Page 4 Executive Summary Cement Bond Logging with LWD Acoustic (Sonic) tool SoundTrak was performed after drilling of 8 ½” section. Logs were acquired while pulling out of hole across 9 5/8” liner in upward direction. The objective and plan were to cover with CBL logs to evaluate the first stage cementing from the 9 5/8” Liner shoe to the planned TOC of 5430’ MD. Cement Bond Index (BI) curve was computed and presented in the log plot showing color gradation from good cement bond (brown) to poor cement (blue). The following values were used by interpreter to differentiate intervals of good bond (curve value above 0.8) to partial (0.2 to 0.8) and poor (lower than 0.2). Summaries of initial pre-job logging plan and Cement Bond Index interpretation are outlined below. Logging Plan Summary Down link to the SoundTrak tool after drilling of 8 ½” open hole and upon coming to the 9 5/8” liner shoe at 8,435ft MD to initiate top of cement mode and continue backreaming out of hole to log the cement in the 9 5/8” Liner at 400 gpm and 60-120 rpm (per Bakerhughes recommendation). x Log cement from 9-5/8” shoe (8,435’ MD) to 5,430’ MD planned top of cement. Log up at 1,200 fph. x Log free pipe from 5,430’ to 4,500’ MD (930’ of free pipe) at 1,200 fph. LWD logging was optimized to gain higher efficiency and reduce overall rig time by modifying acquisition parameters and logging at 1200 ft/hr entire well interval. Santos USA and Baker Hughes Confidential Page 5 Interpretation Summary The Intermediate section was drilled and 9 5/8” Casing shoe was set at 8,435’. After drilling 8 ½” to TD, a Logging up was performed to capture cement Bond on the 9 5/8” casing. Following observations are summarized below by interval. Please note that Bond Index curve (BI) and color coding in combination with other data on the log can be used for more detailed interval inspection to draw conclusions on zonal isolation of narrower intervals. Overall, 3 main zones were defined as listed below, with more detailed interpretation within each zone presented in the table that follows. - 4,500’-4,700’: Partial cement presence in that interval. - 4,700’-5,893’: Mostly Good, with some intervals of partial cement presence. - 5,893 to 8,369’ Very Good presence in this entire interval For more detailed description of each interval please refer to the table below summarizing Interpretation results. 4,700’ Santos USA and Baker Hughes Confidential Page 6 Tool Diagram Santos USA and Baker Hughes Confidential Page 7 Methodology of LWD Cement Bond Log Evaluation Before the arrival of more advanced Wireline technologies offering azimuthal coverage of the casing to cement and cement to formation bonding, oil and gas operators have been relying on traditional non-azimuthal CBL, Cement Bond Log, technique, that is being run successfully to date. Wireline Acoustic (Sonic) tool’s CBL measurement principle relies on detecting and measuring first “casing ringing” amplitude reflected from the casing wall. The idea is that free pipe (with cement absence) would “ring” freely creating high Casing Ringing Amplitude, whereas well cemented casing would result in dampened first arrival and thus indicate well cemented pipe. Traditional Wireline tool relies on the arrival of the sound detected at the receiver spaced at 3 ft for CBL Amplitude and for the one from the 5 ft spaced receiver for VDL (Variable Density Log). Figure 1: Traditional Wireline CBL technique Santos USA and Baker Hughes Confidential Page 8 LWD Acoustic (Sonic) tool is using the same principle for CBL measurement. It is also non- azimuthal. However, the one difference is that receiver spacing is longer and all measurements are based on the 10.7 ft receiver spacing for CBL Amplitude. See figures below for the main principle behind cemented vs free pipe detection in traditional CBL measurement. Figure 2: CBL concept in "free" pipe Figure 3: CBL concept in cemented pipe Santos USA and Baker Hughes Confidential Page 9 Figure 4: General CBL concept and corresponding log example Figure 5: LWD Acoustic (Sonic) tool and LWD CBL concept Current traditional offering of LWD Acoustic (Sonic) tool for cement quality evaluation is to detect Top of Cement in wells where running Wireline could be challenging for various reasons and Top of Cement or TOC detection can be done in the same drilling trip typically on the way out of casing after drilling is completed. Santos USA and Baker Hughes Confidential Page 10 Baker Hughes offers both traditional TOC service and a more advanced workflow of providing Cement Bond Index. This Cement Bond Index is a relative Cement Quality Indicator helping operators to still acquire positive zonal isolation information in wells where running Wireline could be challenging and / or would otherwise increase overall rig time. To convert casing amplitude to cement bond index (BI), two reference points are required: -Free casing - 100% bonded point Figure 6: Cement Bond Index computation concept Traditionally as part of the CBL logging deliverable, Bond Index (BI) is computed and displayed in the log. Values above 80% BI are typically seen as “good" cement, whereas values below 80% are typically seen as either "poor," contaminated or channeled cement. Note however, that the TR spacing (10.66 ft) for LWD SoundTrak tool is over 3.5 times longer than the spacing of traditional Wireline CBL tool (3 ft), so the casing amplitude has a much higher attenuation, especially across well bonded intervals. Careful quality check must be carried out to validate the data, because If the casing amplitude in these well bonded intervals is below noise level, the 100% bonded reference point might be incorrect and the “BI” could be over-estimated, reducing quantitative precision of the measurement. Additionally, Cement Evaluation with LWD SoundTrak tool would be ideal in standard cements with slurry density of equal or greater than 14 ppg. Slurries below 14 ppg would typically be classified as light-weight cements and sometimes can cause uncertainty in cement evaluation. However, more integrated interpretation would be required to reduce that uncertainty and confirm proper cement presence. For example, detection of behind casing open hole DT from waveforms could confirm that proper cement is present. Santos USA and Baker Hughes Confidential Page 11 Furthermore, adding this service can increase operational efficiency since it can be done in the same drilling trip on the way out and logging speed for top of cement detection and CBL evaluation can be as high as ~1500 ft/hr still providing good data quality. With combination of casing mode semblance (SV) and formation arrival in correlogram, TOC can be detected in Real-Time. Good agreement between RT and memory TOC can be seen in the figure below. Figure 7: LWD capability of Real-Time Top of Cement acquisition This method has limitations though as it has no azimuthal coverage and can not identify micro channeling. It is not a replacement for quantitative cement evaluation tools such as SBT, InTex, or CICM Santos USA and Baker Hughes Confidential Page 12 Log Screen Captures Following figures contain interpretation observations, however Bond Index curve and color coding can be used for more detailed interval inspection to draw conclusions on zonal isolation. Please refer to the tables on pages 6 for more detailed interpretation. Figure 8: Interval 1 of LWD CBL logging General Interpretation Comments: 4,500’ to 5,000’ partial to Good cement in that interval. Santos USA and Baker Hughes Confidential Page 13 Figure 9: Interval 2 of LWD CBL Logging General Interpretation Comments: 5,000’ to 5,700’ Good to partial cement presence in that interval Mostly Good Cement. Santos USA and Baker Hughes Confidential Page 14 Figure 10: Interval 3 of LWD CBL Logging General Interpretation Comments: 57,00’ to 6,400’ Very Good to Partial cement presence. Mostly very good, with some intervals of partial cement presence. Santos USA and Baker Hughes Confidential Page 15 Figure 11: Interval 4 of LWD CBL Logging General Interpretation Comments: 6,400’ to 7,100’ Very Good cement in that interval Santos USA and Baker Hughes Confidential Page 16 Figure 12: Interval 5 of LWD CBL Logging General Interpretation Comments: 7,100’ to 7,800’ Very Good presence cement presence in the entire interval. Santos USA and Baker Hughes Confidential Page 17 Figure 13: Interval 6 of LWD CBL Logging General Interpretation Comments: 7,800’ to 8,369’ Very Good presence cement presence in the entire interval. 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDB-025 (PTD No. 224-006; Sundry No. 324-598) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 October 25, 2024 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. SFD 10/21/2024 (a)(2) Plat Provided with application. SFD 10/21/2024 (a)(2)(A) Well location Provided with application. Well traverses Sections 4, 5, 8, 5 (again), and 6 of T11N, R6E, UM. SFD 10/21/2024 (a)(2)(B) Each water well within ½ mile None: According to the Water Estate map available through DNR’s Alaska Mapper application (accessed online October 21, 2024), there are no wells are used for drinking water purposes are known to lie within ½ mile of the surface location of NDB-025. There are no subsurface water rights or temporary subsurface water rights within 14-1/2 miles of the surface location of NDB-025. SFD 10/21/2024 (a)(2)(C) Identify all well types within ½ mile Nine wells lie within a ½-mile radius of NCB-025. They are depicted on Attachment B of the application. SFD 10/21/2024 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth None. No freshwater aquifers are present within the Pikka Unit per salinity calculations provided by the operator on Aug. 21, 2023 as part of their Sundry Application to hydraulically fracture nearby well NDB-024 (see AOGCC’s Well History File 223-076, p. 101-107 of Sundry Application 323-591). Pickett Plot well-log analyses were performed on three wells within the unit that have wireline log coverage from surface through the fracturing interval: Colville River 1, Till 1, and Pikka DW-02. Estimated salinity values for clean, porous 100% water-saturated sands beneath the base of the permafrost layer in these three wells are: Colville River 1 (192-153) ~20,000 mg/l between 1,400 and 2,000’ MD(-1,354’ to 1,954' TVDSS; base of permafrost 1,350’ MD (-1,313’ TVDSS)); Till 1 (193-004) 16,700 to ~23,000 mg/l between 1,400’ and 1,500’ MD (-1,463’ to -1,363’ TVDSS; base of permafrost 1,350’ MD SFD 10/21/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDB-025 (PTD No. 224-006; Sundry No. 324-598) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 October 25, 2024 (-1,305’ TVDSS)); and DW-02 (223-039) ~21,500 mg/l between 1,550’ and 1,650’ MD (-1,408’ to -1,486’ TVDSS; base of permafrost ~1,170’ MD (~-1,080’ TVDSS). (a)(4) Baseline water sampling plan None required: No freshwater aquifers are present. SFD 10/21/2024 (a)(5) Casing and cementing information Provided with application. Proposed schematic attached, as built not generated to date. CDW 10/21/2024 (a)(6) Casing and cementing operation assessment 4.5” uncemented liner and tubing will be anchored with a liner hanger/packer 8285 ft MD and packer set at approx. 8313 ft with shallowest frac sleeve at 9072 ft MD. 9-5/8” production liner cemented from shoe at 8435 to TOC of around 4500 ft (SoundTrak run shows good cement conservatively from 4700 ft.) Job pumped to plan, no losses. 2nd stage from 3854 ft back to liner top (2572 ft) with cement returns seen at surface. Zero losses. 13-3/8” surface casing cemented from shoe at 2727 ft back to surface with cement returned to surface. CDW 10/21/2024 (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 No freshwater aquifers are present. (See Section (a)(3), above.) SFD 10/21/2024 (a)(6)( B) Each hydrocarbon zone is isolated Yes. Tuluvak: AOGCC considers the upper Tuluvak between the top of the Tuluvak Sand at 2,994’ MD and the TS 790 Marker at 3,739’ MD to bear significant hydrocarbons. The second stage collar within the intermediate liner was set beneath the TS 790 marker at 3,854’ MD. Second-stage cement was pumped from 3,854’ MD to the liner top at 2,572’ MD with full cement returns and no losses. SFD 10/23/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDB-025 (PTD No. 224-006; Sundry No. 324-598) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 October 25, 2024 Nanushuk: Nanushuk interval top occurs at 6,180’ MD. Nanushuk is covered by mostly good to very cement with some interspersed intervals of partial cement below 4,728’ MD to the intermediate liner shoe at 8,435’ MD. So, cement isolates the Nanushuk and the fracturing hydrocarbon zone. (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well MITIA plan 3800 psi. (PRV set as 3600 psi) MITT plan 5800 psi. (110% satisfied for 8500 psi max with 3300 psi hold.) CDW 10/21/2024 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 10K psi frac tree max. frac. Pressure 8500 psi. Pump knock out 7500 and GORV 8200 psi, lines test 8600 psi. CDW 10/21/2024 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper Confining Zones: About 700’ true vertical thickness (TVT) of claystone, shale and volcanic tuff assigned to the Seabee having an estimated fracture gradient of 13.7 ppg EMW (0.71 psi/ft). Fracturing Zone: Perforated zone lies within a subdivision of the Nanushuk Formation comprising fine-grained sand, silt and shale that is about 950’ TVT in this area and has an estimated fracture gradient of 12.3 to 12.7 ppg EMW (0.64 to 0.66 psi/ft). Lower Confining Zones: Lower Torok siltstone and shale that is about 1,200’ thick in this area with an estimated fracture gradient of 13.3 ppg EMW (0.69 psi/ft). SFD 10/23/2024 (a)(10) Location, orientation, report on mechanical condition of each well that may transect the confining zones and sufficient information to determine wells will not interfere with containment of hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory It is highly unlikely that any of the wells or wellbores within a ½-mile radius will interfere with hydraulic fracturing fluids from this operation because of cement isolation and / or separation distance. Oil Search has identified five wells and provided cement/zonal isolation information for these. NDB-037 is within ½ mile and currently being drilled. CDW 10/21/2024 SFD 10/23/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDB-025 (PTD No. 224-006; Sundry No. 324-598) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 October 25, 2024 (a)(11) Faults and fractures, Sufficient information to determine no interference with containment of the hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory Yes. The operator has identified two faults within a ½-mile radius of NDBi-025 that do not intersect the wellbore. These faults have vertical displacements of about 20’, azimuths of about 5° and 25° (according to the map provided in that application), and extend upward within the Nanushuk and according to the operator’s seismic interpretation, both faults terminate below the upper-confining Seabee. It is unlikely that any faults will interfere with containment of injected fracturing fluids. However, if there are indications that a fracture has intersected a fault or natural-fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. SFD 10/23/2024 (a)(12) Proposed program for fracturing operation Provided with application. CDW 10/21/2024 (a)(12)(A) Estimated volumeProvided with application. Approx. 20K bbl total dirty vol. 2M lb total proppant CDW 10/21/2024 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 10/21/2024 (a)(12)(C) Chemical name and CAS number of each Provided with application. Schlumberger and Tracerco disclosures provided. CDW 10/21/2024 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 10/21/2024 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max surface pressure 5338 psi. Max. 8500 psi allowable treating pressure. Max pressure is 7500 psi to 8200 psi to Pump shutdown. With 3300 psi back pressure IA (IA popoff set 3600 psi), max tubing differential should be 5200 psi. CDW 10/21/2024 (a)(12)(F) Fractures – height, length, MD and TVD to top, description of fracturing model Provided with application. The anticipated half-lengths of the induced fractures range from 305’ to 425’ according to the Operator’s computer simulation. Computer simulation 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDB-025 (PTD No. 224-006; Sundry No. 324-598) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 October 25, 2024 indicates the anticipated height of the induced fractures will range from 235’ to 275’, with the shallowest modeled TVD of about 4,100’ and deepest modeled TVD of about 4,520’. Induced fractures will remain within the Nanushuk interval and below the overlying confining Seabee Shale that is about 700’ thick in this area. SFD 10/23/2024 (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. No disposal identified CDW 10/21/2024 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 3300 psi back pressure, plan to test to 3800 psi, popoff set as 3600 psi CDW 10/21/2024 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 4.5” liner and tubing will be anchored with a liner hanger/packer 8285 ft MD and packer set at approx. 8313 ft with shallowest frac sleeve at 9072 ft MD. 9-5/8” production liner cemented from shoe at 8435 to TOC of around 4500 ft (SoundTrak run shows good cement conservatively from 4700 ft.) 2nd stage from 3854 ft back to liner top (2572 ft) with cement circulated off liner and seen at surface. USIT/CBL conservatively shows good cement at area of interest so no cement concerns. CDW 10/21/2024 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 5800 psi planned. Max pressure differential is estimated as 5200 psi (8500 with 3300 psi backpressure) so test of 5800 psi satisfies 110% CDW 10/21/2024 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 8600 psi line pressure test, pump knock out 7500 and 8200 psi. IA PRV set as 3600 psi. CDW 10/21/2024 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 10/21/2024 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 3600 psi. Surface annulus open. Frac pressures continuously monitored. CDW 10/21/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDB-025 (PTD No. 224-006; Sundry No. 324-598) Paragraph Sub-Paragraph Section Complete? AOGCC Page 6 October 25, 2024 (g) Annulus pressure monitoring & notification 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: CDW 10/21/2024 (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac water sampling plan Not required. No freshwater aquifers present. (See Section (a)(3), above.) SFD 10/21/2024 (k) Confidential information Clearly marked and specific facts supporting nondisclosure Not applicable: This well is not confidential. SFD 10/21/2024 (l) Variances requested Modifications of deadlines, requests for variances or waivers No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. 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:Staudinger, Mark (Mark) To:McLellan, Bryan J (OGC) Cc:Conwell, Russell (Russell); Tirpack, Robert (Robert); Staudinger, Mark (Mark) Subject:RE: NDB-025 (PTD 224-006) Intermediate 9-5/8" Cement Bond Log Date:Monday, October 14, 2024 1:48:13 PM Attachments:NDB-025_9_625_Liner_Baker_Hughes_CBL_Final Report.pdf NDB-025 Schematic E.2 As Drilled 10.14.24.pdf Reporting - Cement - NDB-025 - 2024-10-14 15.26.46.pdf Hi Bryan, Attached is the final 9-5/8” intermediate Casing CBL report from Baker as well as the Wellview Cementing Reports, and schematic. Below is a high-level summary: Well Design 9-5/8” Liner Top at 2,572’ MD 13-3/8” Casing Shoe at 2,727’ MD CFLEX Stage Tool at 3,854’ MD 9-5/8” Shoe at 8,435’ MD Geology TS790 at 3,739’ MD. Top of the Nanushuk was picked at 6,180’ MD. Cement Job Planning / Execution 1st Stage of cement job planned with a full 15.3 ppg tail slurry at 30% excess, targeting TOC 250’ TVD above top of Nanushuk to 5,567’ MD. During execution of the 1st stage cement, no losses were reported and good lift pressure was observed. 2nd Stage of cement job planned with CFLEX ~115’ below the TS790. Also planned with a full 15.3 ppg tail slurry at 100% excess, targeting TOC at the 9-5/8” liner top. During execution of the 2nd stage cement, no losses were encountered and we saw good lift pressure. An estimated 65 bbls of clean cement, 90 bbls of spacer and 70 bbls of interface were observed at surface off the top of liner. Observations / Conclusions For the 1st stage of the cement job, we have adequate isolation in the upper Nanushuk formations across the hydrocarbon-bearing formations, and well above the planned TOC at 5,567’ MD (250’ TVD above top Nanushuk). This is supported by the CBL log, which indicates good cement throughout the first stage and an estimated TOC at 4,500’ MD. It should be noted that a clear TOC was not logged with the Sonic tool, as partial cement presence was still evident at the top of the logged interval (9-5/8” shoe to 4,500’ MD). The transition from good cement to partial cement was noted at 4,820’ to 4,500’ MD. TOC was called at 4,500’ MD, as this is the top of the logged interval. Approval to proceed without a clear TOC on the CBL was received from Mel Rixse with the AOGCC on 10/11/2024. For the 2nd stage of the cement job, based on job execution results, cement isolation was achieved across the significant hydrocarbon zone within the upper Tuluvak formation. Our assessment is that we have adequate isolation across hydrocarbon-bearing formations in the upper Nanushuk formations, as well as adequate isolation for frac operations. The 2nd stage cement job yielded adequate isolation below, across and above the Tuluvak significant hydrocarbons. 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. You don't often get email from russell.conwell@santos.com. Learn why this is important From:Rixse, Melvin G (OGC) To:Conwell, Russell (Russell) Cc:Staudinger, Mark (Mark); Tirpack, Robert (Robert); McLellan, Bryan J (OGC) Subject:RE: NDB-025 9-5/8" Intermediate Cement Bond Log Date:Friday, October 11, 2024 11:52:46 AM Russell, Approved to proceed with log showing cement across the interval logged. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Conwell, Russell (Russell) <Russell.Conwell@santos.com> Sent: Friday, October 11, 2024 11:24 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: NDB-025 9-5/8" Intermediate Cement Bond Log Hi Mel, Sorry – should have your correct email this time. Thanks. Regards Russell Russell Conwell Senior Drilling Engineer m: +1 907 615 2234| e: russell.conwell@santos.com From: Conwell, Russell (Russell) Sent: Friday, 11 October 2024 11:12 AM To: mel.rixse@alaska.gov Cc: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: NDB-025 9-5/8" Intermediate Cement Bond Log Hi Mel, Good to chat this morning. As discussed, we received the processed CBL log from the NDB- 025 9-5/8” intermediate liner last night (as attached). As discussed, we didn’t get a clear TOC from the log, but we do see where it transitions to a partial cement coverage on the upper few hundred feet of the logged Interval. We did log extra footage (1000' above planned TOC vs. 750') on this well because we had an excellent primary cement job with no losses reported. We just need to get permission that the AOGCC will accept the log even though a clear TOC is not evident on the log. If you can provide an email confirmation that would be appreciated. We will followup with the full cementing and log summary on Monday with Bryan. Thanks again for your time and let me know if you need anything further at this stage. Regards Russell Russell Conwell Senior Drilling Engineer m: +1 907 615 2234| e: russell.conwell@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 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PIKKA NDB-025 JBR 11/25/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 TJ's Used 5-7/8 and 9-5/8" Accumulator precharge avg 24 @ 1067 psi Test Results TEST DATA Rig Rep:Sonny ClarkOperator:Oil Search (Alaska), LLC Operator Rep:Rob O'Neal Rig Owner/Rig No.:Parker 272 PTD#:2240060 DATE:9/25/2024 Type Operation:DRILL Annular: 250/3600Type Test:INIT Valves: 250/3600 Rams: 250/3600 Test Pressures:Inspection No:bopKPS240925153623 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 1553 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 4-1/2" X 7" V P #2 Rams 1 Blinds P #3 Rams 1 7" Fixed P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 1 3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2000 200 PSI Attained P18 Full Pressure Attained P73 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P14@ 2253 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9999 9 9 9 %23(7HVW3DUNHU 3LNND1'% 37' $2*&&,QVSERS.36 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: Reviewed By: P.I. Suprv Comm ________PIKKA NDB-025 JBR 10/17/2024 MISC. INSPECTIONS: GAS DETECTORS: DIVERTER SYSTEM:MUD SYSTEM: P/F P/F P/F Alarm Visual Alarm Visual Time/Pressure Size Number of Failures:0 Remarks:Good Inspection. All signs and barriers are in place. TEST DATA Rig Rep:Sonny ClarkOperator:Oil Search (Alaska), LLC Operator Rep:Rob Oneal Contractor/Rig No.:Parker 272 PTD#:2240060 DATE:9/21/2024 Well Class:DEV Inspection No:divJDH240921131910 Inspector Josh Hunt Inspector Insp Source Related Insp No: Test Time:1 ACCUMULATOR SYSTEM: Location Gen.:P Housekeeping:P Warning Sign P 24 hr Notice:P Well Sign:P Drlg. Rig.P Misc:NA Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:NA NA Designed to Avoid Freeze-up?P Remote Operated Diverter?P No Threaded Connections?P Vent line Below Diverter?P Diverter Size:21.25 P Hole Size:16 P Vent Line(s) Size:16 P Vent Line(s) Length:40.25 P Closest Ignition Source:90 P Outlet from Rig Substructure:51 P Vent Line(s) Anchored:P Turns Targeted / Long Radius:P Divert Valve(s) Full Opening:P Valve(s) Auto & Simultaneous: Annular Closed Time:25 P Knife Valve Open Time:19 P Diverter Misc:0 NA Systems Pressure:P3000 Pressure After Closure:P2250 200 psi Recharge Time:P14 Full Recharge Time:P55 Nitrogen Bottles (Number of):P14 Avg. Pressure:P2330 Accumulator Misc:NA0 P PTrip Tank: P PMud Pits: P PFlow Monitor: NA NAMud System Misc: 9 9 9 9 From:McLellan, Bryan J (OGC) To:Staudinger, Mark (Mark) Cc:Tirpack, Robert (Robert); Conwell, Russell (Russell) Subject:RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Date:Thursday, September 19, 2024 11:54:00 AM Attachments:image004.png image005.png image006.png image007.png Mark, These changes are 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: Tuesday, September 17, 2024 10:12 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; Conwell, Russell (Russell) <Russell.Conwell@santos.com> Subject: RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Good morning Bryan, I’ll be taking the NDB-025 well operations over, and wanted to seek approval for a couple more small additional changes to the approved PTD to align with our current practices. 1. We request to reduce the FIT at the 9-5/8” INT shoe from 15.0ppg EMW to 14.0 ppg EMW (Section 4. Drilling Hazards Information). This is still well above the min LOT requirement of 10.5 ppg and well above our ECD requirement at the shoe. 2. I don’t know if this requires an approval, but more for awareness, in Attachment 6: Cement Summary, our base plan will be to cement the INT Liner Stage 1 with a single 15.3 ppg Tail slurry, instead of a separate lead and tail. The total cement volume will remain the same, targeting the TOC at ~250’ TVD above the Nanushuk formation. 3. Just as an FYI, in Section 4 (Drilling Hazards Information), we are planning on increasing the BOP Rams test to 3,600 psi (versus 3,500 psi). This is for compliance with our own internal Santos Standards. 4. Again for internal compliance, we have a slight change in our test pressures that are stated in the operational steps in Section 13 (Proposed Drilling Program). For step 33, we now test the tubing to 3,500 psi for 30 mins (versus 4,000 psi), and then decrease tubing pressure to 3,000 psi while we pressure up and test the inner annulus to 4,000 psi for 30 mins. We then continue on to bleed the tubing and shear the upper gas lift valve and follow the steps as stated in the PTD. Please let me know if you approve of these changes. Thanks, Mark Mark Staudinger Senior Drilling Engineer t: +1 (907) 375-4654 | m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, September 6, 2024 2:54 PM To: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: ![EXT]: RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Jake, The changes requested in your emails below are approved. These are all in line with the latest PTDs at NDB pad. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Sent: Friday, September 6, 2024 2:50 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> 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. Subject: RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Bryan, Upon reviewing the old PTD that we planned on pumping 300% excess cement in through the permafrost in with our surface casing. Our recent surface holes have experiences significantly less washout that this, so we have since revised our strategy to pumping 200% excess cement through the permafrost. This is an additional change we would like to request. Below are the revised cement numbers for our surface casing. Surface Casing Cement Casing Size 13-3/8” 68# L-80 BTC Surface Casing Basis Lead Open hole volume + 200% excess in permafrost / 50% excess below permafrost Lead TOC Surface Tail Open hole volume + 50% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 10.5 ppg Clean Spacer Lead 11.0ppg Lead: 397.7 bbls, 2233.3 cuft, 783.6 sks ArcticCem, Yield: 2.85 cuft/sk Tail 15.3ppg Tail: 68.9 bbls, 386.9 cuft, 309.5 sks HalCem Type I/II – 1.25 cuft/sk Temp BHST 53° F Verification Method Cement returns to surface Notes Job will be mixed on the fly NDB-025 13-3/8" SURFACE CEMENT JOB Description TOP BOTTOM LENGTH CAPACITY VOLUME (bbls) Shoe track length 2663 2748 85 0.14973 12.7 TAIL LENGTH 2248 2748 500 0.07491 37.5 TAIL EXCESS 50%18.7 LEAD TOP TO BASE OF PERMA 1412 2248 836 0.07491 62.6 EXCESS FACTOR FOR ABOVE 50%31.3 PERMAFROST ANNULUS(Lead)128 1412 1284 0.07491 96.2 EXCESS FACTOR FOR ABOVE 200%192.4 CASED HOLE ANNULUS 46 128 82 0.18620 15.3 Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@santos.com https://www.santos.com/ From: Thompson, Jacob (Jacob) Sent: Wednesday, September 4, 2024 4:02 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Bryan, I hope you had a good labor day weekend. I was hoping to get an update on the below requested changes to the sundry. Let me know what you think, or when you may be able to get back to us. My plan is to get my well program out for signatures by Friday so it would be good to get your feedback / approval. Thanks, Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@santos.com https://www.santos.com/ From: Thompson, Jacob (Jacob) Sent: Wednesday, August 28, 2024 3:28 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: NDB-025 (PTD 224-006) Change Request to Approved PTD. Bryan, We have had a change to our rig schedule and are planning to move to the NDB-025 for our next well. This will put the spud around the last week of September. After reviewing the approved PTD we would like to request approval for the following changes: Change to the Surface Casing Depth to 250’ TVD below the MCU at 2,748’ MD. This will allow us to cover more of the overburden with surface pipe but maintain TD above the Tuluvak. o We will still be setting in a competent formation, so the deeper casing point will maintain the same FIT requirements for kick tolerance. We are requesting a change to the planned mud weight ranges. The below chart covers the requested MW ranges for each section which have been used on the recently drilled wells. All planned MW will maintain a overbalance to permeable zones. Surface Hole Intermediate Hole Production Hole Mud Type Water based Spud Mud Mineral Oil Based Mud Mineral Oil Based Mud Mud Properties: Mud Weight Funnel Vis PV YP API Fluid Loss HPHT Fluid Loss pH MBT 9.0 – 10.0 ppg 100-300 seconds ALAP 30-80 < 10 ml/30min n/a 8.6-10.5 <35 11.0-12.5 ppg 50-80 seconds ALAP 15-30 n/a < 5 ml/30min n/a n/a 9.2-10.0 ppg 50-80 seconds ALAP 10-20 n/a < 5 ml/30min n/a n/a We are requesting approval to leave the 9-5/8” fixed bore rams in the lower ram cavity while drilling ahead in the production hole. (Remove step 21 of the approved PTD.) We request that the conditional submittal of open hole logs and approval of stage collar placement follow more recent PTD approvals. See the recommended language below from the NDBi-016 PTD The requested changes are all in line with current well planning practices and are in agreement with the most recently processed PTD. If you could please submit your approval or comments by next Wednesday 9/4/2024 it would be greatly appreciated. Thanks, Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@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 or contain 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 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:Thompson, Jacob (Jacob) Cc:Tirpack, Robert (Robert) Subject:RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Date:Friday, September 6, 2024 2:53:00 PM Attachments:image008.png image009.png image010.png image011.png Jake, The changes requested in your emails below are approved. These are all in line with the latest PTDs at NDB pad. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Sent: Friday, September 6, 2024 2:50 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Bryan, Upon reviewing the old PTD that we planned on pumping 300% excess cement in through the permafrost in with our surface casing. Our recent surface holes have experiences significantly less washout that this, so we have since revised our strategy to pumping 200% excess cement through the permafrost. This is an additional change we would like to request. Below are the revised cement numbers for our surface casing. Surface Casing Cement Casing Size 13-3/8” 68# L-80 BTC Surface Casing Lead Open hole volume + 200% excess in permafrost / 50% excess below permafrost Basis Lead TOC Surface Tail Open hole volume + 50% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 10.5 ppg Clean Spacer Lead 11.0ppg Lead: 397.7 bbls, 2233.3 cuft, 783.6 sks ArcticCem, Yield: 2.85 cuft/sk Tail 15.3ppg Tail: 68.9 bbls, 386.9 cuft, 309.5 sks HalCem Type I/II – 1.25 cuft/sk Temp BHST 53° F Verification Method Cement returns to surface Notes Job will be mixed on the fly NDB-025 13-3/8" SURFACE CEMENT JOB Description TOP BOTTOM LENGTH CAPACITY VOLUME (bbls) Shoe track length 2663 2748 85 0.14973 12.7 TAIL LENGTH 2248 2748 500 0.07491 37.5 TAIL EXCESS 50%18.7 LEAD TOP TO BASE OF PERMA 1412 2248 836 0.07491 62.6 EXCESS FACTOR FOR ABOVE 50%31.3 PERMAFROST ANNULUS(Lead)128 1412 1284 0.07491 96.2 EXCESS FACTOR FOR ABOVE 200%192.4 CASED HOLE ANNULUS 46 128 82 0.18620 15.3 Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@santos.com https://www.santos.com/ From: Thompson, Jacob (Jacob) Sent: Wednesday, September 4, 2024 4:02 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: RE: NDB-025 (PTD 224-006) Change Request to Approved PTD. Bryan, I hope you had a good labor day weekend. I was hoping to get an update on the below requested changes to the sundry. Let me know what you think, or when you may be able to get back to us. My plan is to get my well program out for signatures by Friday so it would be good to get your feedback / approval. Thanks, Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@santos.com https://www.santos.com/ From: Thompson, Jacob (Jacob) Sent: Wednesday, August 28, 2024 3:28 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: NDB-025 (PTD 224-006) Change Request to Approved PTD. Bryan, We have had a change to our rig schedule and are planning to move to the NDB-025 for our next well. This will put the spud around the last week of September. After reviewing the approved PTD we would like to request approval for the following changes: Change to the Surface Casing Depth to 250’ TVD below the MCU at 2,748’ MD. This will allow us to cover more of the overburden with surface pipe but maintain TD above the Tuluvak. o We will still be setting in a competent formation, so the deeper casing point will maintain the same FIT requirements for kick tolerance. We are requesting a change to the planned mud weight ranges. The below chart covers the requested MW ranges for each section which have been used on the recently drilled wells. All planned MW will maintain a overbalance to permeable zones. Surface Hole Intermediate Hole Production Hole Mud Type Water based Spud Mud Mineral Oil Based Mud Mineral Oil Based Mud Mud Properties: Mud Weight Funnel Vis PV YP API Fluid Loss HPHT Fluid Loss pH 9.0 – 10.0 ppg 100-300 seconds ALAP 30-80 < 10 ml/30min n/a 11.0-12.5 ppg 50-80 seconds ALAP 15-30 n/a < 5 ml/30min n/a 9.2-10.0 ppg 50-80 seconds ALAP 10-20 n/a < 5 ml/30min n/a MBT 8.6-10.5 <35 n/a n/a We are requesting approval to leave the 9-5/8” fixed bore rams in the lower ram cavity while drilling ahead in the production hole. (Remove step 21 of the approved PTD.) We request that the conditional submittal of open hole logs and approval of stage collar placement follow more recent PTD approvals. See the recommended language below from the NDBi-016 PTD The requested changes are all in line with current well planning practices and are in agreement with the most recently processed PTD. If you could please submit your approval or comments by next Wednesday 9/4/2024 it would be greatly appreciated. Thanks, Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@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 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 NDB-025 (PTD 224-006) WĞƌŵŝƚ ƚŽ ƌŝůů ŽŶĚŝƟŽŶƐ ŽĨ Approval 1.KW ƚĞƐƚ ƚŽ ϯϱϬϬ ƉƐŝ͕ ŶŶƵůĂƌ ƚĞƐƚ ƚŽ ϯϬϬϬ ƉƐŝ͘ 2.>Kdͬ&/d ƌĞƐƵůƚƐ ƚŽ ďĞ ƐƵďŵŝƩĞĚ ƚŽ K' ǁŝƚŚŝŶ ϰϴ ŚŽƵƌƐ ŽĨ ŽďƚĂŝŶŝŶŐ ƚŚĞ ĚĂƚĂ͘ ϯ͘ sĂƌŝĂŶĐĞ ƚŽ ϮϬ Ϯϱ͘ϬϯϬ;ĚͿ;ϱͿ ĨŽƌ Ϯ-ƐƚĂŐĞ ŝŶƚĞƌŵĞĚŝĂƚĞ ĐĂƐŝŶŐ cĞŵĞŶƚ ŽƉĞƌĂƟŽŶ ĂŶĚ ŐĂƉ ŝŶ ĐĞŵĞŶƚ ĐŽǀĞƌĂŐĞ ŝƐ ĂƉƉƌŽǀĞĚ͕ ďƵƚ ǁŝƚŚ ƐƚĂŐĞ ĐŽůůĂƌ ƉůĂĐĞŵĞŶƚ ĂƐ ĨŽůůŽǁƐ͗ a.^ƚĂŐĞ ĐŽůůĂƌ ŵƵƐƚ ďĞ ƉůĂĐĞĚ ŶŽ ƐŚĂůůŽǁĞƌ ƚŚĂŶ ϱϬΖ D ďĞůŽǁ ƚŚĞ ďĂƐĞ ŽĨ ƚŚĞ hƉƉĞƌ dƵůƵǀĂŬ ĂƐ ĚĞĮŶĞĚ ďLJ ƚŚĞ d^ϳϵϬ ŚŽƌŝnjŽŶ͘ ď͘ SƵďŵŝƚ ϭϮ-ϭͬϰΗ K, ůŽŐƐ ƚŽ K' ĂŶĚ ŽďƚĂŝŶ ĂƉƉƌŽǀĂů ĨŽƌ ƐƚĂŐĞ ĐŽůůĂƌ ƐĞƫŶŐ ĚĞƉƚŚ ďĞĨŽƌĞ ƌƵŶŶŝŶŐ ϵ-ϱͬϴΗ ůŝŶĞƌ 4.dŚĞ >t-^ŽŶŝĐ ůŽŐ ǁŝůů ŽŶůLJ ďĞ ĂĐĐĞƉƚĞĚ ĨŽƌ ĐĞŵĞŶƚ ĞǀĂůƵĂƟŽŶ ǁŚĞŶ ƚŚĞ ĨŽůůŽǁŝŶŐ ĐŽŶĚŝƟŽŶƐ ĂƌĞ ŵĞƚ͗ a.KŝůƐĞĂƌĐŚ ƚŽ ƉƌŽǀŝĚĞ Ă ǁƌŝƩĞŶ ůŽŐ ĞǀĂůƵĂƟŽŶͬŝŶƚĞƌƉƌĞƚĂƟŽŶ ƚŽ ƚŚĞ K' ĂůŽŶŐ ǁŝƚŚ ƚŚĞ ůŽŐ ĂƐ ƐŽŽŶ ĂƐ ƚŚĞLJ ďĞĐŽŵĞ ĂǀĂŝůĂďůĞ͘ dŚĞ ĞǀĂůƵĂƟŽŶ ŝƐ ƚŽ ŝŶĚŝĐĂƚĞ ƚŚĞ ŝŶƚĞƌǀĂůƐ ŽĨ ĐŽŵƉĞƚĞŶƚ ĐĞŵĞŶƚ ƚŚĂƚ KŝůƐĞĂƌĐŚ ŝƐ ƵƐŝŶŐ ƚŽ ŵĞĞƚ ƚŚĞ ŽďũĞĐƟǀĞ ƌĞƋƵŝƌĞŵĞŶƚƐĨŽƌ aŶŶƵůĂƌ ŝƐŽůĂƟŽŶ ĂŶĚ ƌĞƐĞƌǀŽŝƌ ŝƐŽůĂƟŽŶ͕ ĂŶĚ ƚŽ ŝŶĚŝĐĂƚĞ ƚŚĞ ůŽĐĂƟŽŶ ŽĨ ĐŽŶĮŶŝŶŐ njŽŶĞƐ͕ ŚLJĚƌŽĐĂƌďŽŶ-ďĞĂƌŝŶŐ njŽŶĞƐ͕ ŽǀĞƌƉƌĞƐƐƵƌĞĚ njŽŶĞƐ ĂŶĚ ĨƌĞƐŚ ǁĂƚĞƌ͕ ŝĨ ƉƌĞƐĞŶƚ͘ WƌŽǀŝĚŝŶŐ ƚŚĞ ůŽŐ ǁŝƚŚŽƵƚ ĂŶ ĞǀĂůƵĂƟŽŶͬŝŶƚĞƌƉƌĞƚĂƟŽŶ ŝƐ ŶŽƚ ĂĐĐĞƉƚĂďůĞ͘ ď͘ >t ƐŽŶŝĐ ůŽŐƐ ŵƵƐƚ ƐŚŽǁ ĨƌĞĞ ƉŝƉĞ ĂŶĚ dŽƉ ŽĨ ĞŵĞŶƚ͘ dŚĞ ůŽŐ ŵƵƐƚ ďĞ ƌƵŶ ĂĐƌŽƐƐ ƚŚĞ ƚĂƌŐĞƚ njŽŶĞƐ ĂŶĚ Ăƚ Ă ĚĞƉƚŚ ƚŽ ĞŶƐƵƌĞ ƚŚĞ ĨƌĞĞ ƉŝƉĞ ĂďŽǀĞ ƚŚĞ dK ŝƐ ĐĂƉƚƵƌĞĚ ĂƐǁĞůůĂƐ ƚŚĞ dK͘ /Ĩ ƚŚĞ ůŽŐŐĞĚ ŝŶƚĞƌǀĂů ĚŽĞƐ ŶŽƚ ĐĂƉƚƵƌĞ ƚŚĞ dK ĂŶĚ ĨƌĞĞ ƉŝƉĞ ĂďŽǀĞ ŝƚ͕ ŝƚ ǁŝůů ŶĞĞĚ ƚŽ ďĞ ƌĞ-ƌƵŶ͕ ƵŶůĞƐƐ ƚŚĞ ĐĞŵĞŶƚ ǁĂƐ ƉůĂŶŶĞĚ ƚŽ ĐŽǀĞƌ ƚŚĞ ĞŶƟƌĞ ůĞŶŐƚŚ ŽĨ ůŝŶĞƌ Žƌ ĐĂƐŝŶŐ͘ c.KŝůƐĞĂƌĐŚ ǁŝůů ƉƌŽǀŝĚĞ Ă ĐĞŵĞŶƚ ũŽď ƐƵŵŵĂƌLJ ƌĞƉŽƌƚ ĂŶĚ ĞǀĂůƵĂƟŽŶ ĂůŽŶŐ ǁŝƚŚƚŚĞ ĐĞŵĞŶƚ ůŽŐ ĂŶĚ ĞǀĂůƵĂƟŽŶ ƚŽ ƚŚĞ K' ǁŚĞŶ ƚŚĞLJ ďĞĐŽŵĞ ĂǀĂŝůĂďůĞ͘ d.ĞƉĞŶĚŝŶŐ ŽŶ ƚŚĞ ĐĞŵĞŶƚ ũŽď ƌĞƐƵůƚƐ ŝŶĚŝĐĂƚĞĚ ďLJ ƚŚĞ ĐĞŵĞŶƚ ũŽď ƌĞƉŽƌƚ͕ ƚŚĞ ůŽŐƐ ĂŶĚ ƚŚĞ &/d͕ ƌĞŵĞĚŝĂů ŵĞĂƐƵƌĞƐ Žƌ ĂĚĚŝƟŽŶĂů ůŽŐŐŝŶŐ ŵĂLJ ďĞ ƌĞƋƵŝƌĞĚ͘ Page 1 of 1 31 January 2024 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-025 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-025 is planned to be a horizontal producer targeting the Nanushuk 3. The approximate spud date is anticipated to be March 12 th, 2024. 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 will be drilled to above the top of the Nanushuk 3 formation at an inclination of ~88 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” production hole will be geo-steered in the Nanushuk 3 sand. The well will be completed as a stimulated producer with 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. 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 (907) 854- 4377 or Jacob.Thompson@santos.com. Respectfully, Jacob Thompson Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Application for Permit to Drill NDB-025 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..............................................11 15. Proposed Variance Request...................................................................................................11 Attachments............................................................................................................................................13 Attachment 1: Location Maps......................................................................................................14 Attachment 2: Directional Plan....................................................................................................15 Attachment 3: BOPE Equipment..................................................................................................1 6 Attachment 4: Drilling Hazards....................................................................................................17 Attachment 5: Leak Off Test Procedure.......................................................................................19 Attachment 6: Cement Summary.................................................................................................20 Attachment 7: Prognosed Formation Tops...................................................................................22 Attachment 8: Well Schematic.....................................................................................................23 Attachment 9: Formation Evaluation Program.............................................................................24 Attachment 10: Wellhead & Tree Diagram ..................................................................................25 (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; BOP test frequency for NDB-025 will be 14-days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14-day BOP test period should not be requested. 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. 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-025 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. Redacted 2/21/2024 Redacted 2/21/2024 Attachments Attachment 1: Location Maps Attachment 2: Directional Plan 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" 2 000#21 1/4" 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" 2 000# 21-1/4" X 2 000# 21-1/4" 2 000# FORWARD 3 5/8" 5 000# 3-5/8" X 5 000# 30" 3-5/8" X 5 000# 186" 3-5/8" X 000# DU CH OCK DOWN Attachment 5: Leak Off Test Procedure 1. Drill out shoe track, cement plus minimum of 20’ of new formation. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight-in is equal to mud weight-out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe. 4. Rig up high pressure lines as required to pump down the drill string. 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 0.25bbl/min. Record pump pressures at 0.25bbl increments. 8. Record and plot the volume pumped against pressure until leak-off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak-off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in-situ stress. c. If FIT skip step 9. 9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 11. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to establish the volume of mud lost to the formation. Top up and close the annulus valve between the casing and the previous casing string. 13. Open the BOP. Attachment 8: Well Schematic See condition of approval for stage tool depth. -bjm Attachment 10: Wellhead & Tree Diagram Redacted 2/21/2024 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 nogreater 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. Pikka NDB-025 NANUSHUK OIL POOLPIKKA X 224-006
