Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
224-119
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 NDBi-049 50103208940000 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 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 NDBi-049ؐ 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 NDBi-049 50103208940000 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 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 ؐNDBi-049 Lithotrak Caliper data 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: ______________________ Oil Search Alaska, LLC Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 601 W 5th Avenue, Suite 600, Anchorage, AK 99501 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 19,302' feet N/A feet true vertical 4,095' feet N/A feet Effective Depth measured 19,177' feet See attached rpt feet true vertical 4,095' 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" P-110S 11,479' 3,791' 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:Contact Phone: 325-027 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 907-330-4595 Gas-Mcf MD 0 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 Water-BblOil-Bbl 0 00 320 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 3,512 986 8261,314 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-119 50-103-20894-00-00 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 392984, 391445, 393023, 393022, 393021, 392958 Pikka / Nanushuk Oil Pool Pikka NDBi-049 Junk measured Length 128' 2,608' 128'Conductor Surface Intermediate 20"x34" 13-3/8" Size 128' 9-5/8" measured TVD Production Liner 9,163' 11,479 7,739' Casing 3,830' 3,791' 4-1/2" 11,639' 11,479' 19,177'4,095' Plugs 4750 9210 5020 6870 11590 2,608'2,269' Burst Collapse 2260 Tieback 6870 4750 9210 2,476'Tieback 2,476'2,195 11590 4-1/2" p k ft t Fra O s O 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 06/03/2025 Completions Specialist By Grace Christianson at 3:16 pm, Jun 03, 2025 DSR-6/3/25 RBDMS JSB 061225 CDW 06/03/2025 BJM 9/19/25 Page 1 of 1 Packer Set Depths - NDBi-049 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Original Hole SLZXP Liner Top Hanger Packer w/centralizer 11,459.5 3,789.2 Original Hole HES Zoneguard OH Packer #12 13,274.9 4,153.3 Original Hole HES Zoneguard OH Packer #11 13,383.2 4,161.2 Original Hole HES Zoneguard OH Packer #10 14,007.9 4,171.3 Original Hole HES Zoneguard OH Packer #9 14,548.2 4,167.5 Original Hole HES Zoneguard OH Packer #8 15,128.3 4,162.3 Original Hole HES Zoneguard OH Packer #7 15,708.6 4,157.4 Original Hole HES Zoneguard OH Packer #6 16,332.5 4,152.9 Original Hole HES Zoneguard OH Packer #5 16,871.8 4,149.4 Original Hole HES Zoneguard OH Packer #4 17,454.6 4,145.1 Original Hole HES Zoneguard OH Packer #3 18,027.2 4,140.2 Original Hole HES Zoneguard OH Packer #2 18,648.7 4,135.2 Original Hole HES Zoneguard OH Packer #1 18,984.6 4,121.4 Frac Ops Summary Report - AOGCC Well Name NDBi-049 Primary Job Type OST Start Date End Date Summary 4/15/2025 4/16/2025 MIRU Frac Equipment. Pressure Up Well to Open Toe Sleeve 4/16/2025 4/17/2025 MIRU Frac Equipment 4/17/2025 4/18/2025 Wait on Weather 4/18/2025 4/19/2025 Wait on Weather 4/19/2025 4/20/2025 Waiting on Weather in the morning. Continue R/U Frac Equipment 4/20/2025 4/21/2025 Finish RU equipment, prime up and pressure test. Pump 40 bbls of WF126ST to Displace FP Fluid. Pump 300 bbls WF126ST for Pump Check. DataFrac: 200 bbls (YF126ST Fluid) and 288 bbls (WF126ST) at 40 bpm; as per design TLTR (DataFrac) - 828 bbls 4/21/2025 4/22/2025 Pump Frac Stages 1-4 Finish RU equipment, prime up and pressure test. Pump 100 bbl (WF126ST Fluid) Pump Check Frac stage 1: 1,956 bbls slurry (YF126ST Fluid), 207,108 lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,743 bbls clean fluid at 40 bpm; as per design Frac stage 2: 1,756 bbls slurry (YF126ST Fluid), 206,855 lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,543 bbls clean fluid at 40 bpm; as per design Frac stage 3: 1,981 bbls slurry (YF126ST Fluid), 235,490 lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,739 bbls clean fluid at 40 bpm; as per design Frac stage 4: 2,275 bbls slurry (YF126ST Fluid), 230,967 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 2,039 bbls clean fluid at 40 bpm; as per design Freeze Protect Well with 55 bbls of Diesel. TLTR (Stages 1-4): 7,064 bbls TLTR (Total): 7,892 bbls 4/22/2025 4/23/2025 Fill and heat frac tanks. 4/23/2025 4/24/2025 Fill and heat frac tanks. 4/24/2025 4/25/2025 Pump frac stages 5-8: Fire units and prep for frac. PT iron to 9,450psi. Hold safety meeting to discuss frac operation. Frac stage 5: Displace freeze protect fluid. Pump WF126 to pump ball down at 4bpm and perform pump check, 2,157bbls slurry (WF/YF126ST fluid), 215,445lbs 16/20 carbolite (1, 2, 4, 6, 8, 10ppa), 1,927bbs clean fluid at 40bpm as per design. Frac stage 6: 1,666bbls slurry (YF126ST fluid), 156,981lbs 16/20 carbolite (1, 3, 5, 7, 9ppa), 1,498bbs clean fluid at 40bpm; gel and sand issues, 65% of designed prop pumped. Shut down to fix Sahara sand problem. Frac stage 7: 1,897bbls slurry (YF126ST fluid), 237,937lbs 16/20 carbolite (1, 3, 5, 7, 9, 10ppa), 1,644bbs clean fluid at 40bpm as per design. Frac stage 8: 2,108bbls slurry (YF126ST fluid), 237,737lbs 16/20 carbolite (1, 3, 5, 7, 9, 10ppa), 1,855bbs clean fluid at 40bpm as per design. Tracerco tracers pumped as per design (details in the job time log for each stage). Well freeze protected with 50bbls (36bbls downhole and 14bbls surface lines). Total Load to Recover (TLTR) stage 5-8 – 6,924bbls Total Load to Recover (TLTR) – 14,816bbls Page 1 of 2 Frac Ops Summary Report - AOGCC Start Date End Date Summary 4/25/2025 4/26/2025 Pump frac stages 9-10: Continue hauling extra prop to account for Sahara bins that would not flow sand. Fire units and prep for frac. PT iron to 9,144psi. Hold safety meeting to discuss frac operation. Frac stage 9: Displace freeze protect fluid. Pump WF126 to pump ball down at 4bpm and perform pump check, 2,120bbls slurry (WF/YF126ST fluid), 241,178lbs 16/20 carbolite (1, 3, 5, 7, 9, 11ppa), 1,865bbs clean fluid at 40bpm as per design. Frac stage 10: 2,135bbls slurry (YF126ST fluid), 22,761lbs 40/70 carbolite (1, 3ppa), 238,863lbs 16/20 carbolite (1, 2, 4, 6, 8, 10ppa), 1,867bbs clean fluid at 40bpm as per design. Tracerco tracers pumped as per design (details in the job time log for each stage). Well freeze protected with 70bbls (56bbls downhole and 14bbls surface lines). T/I/O - 1,040/200/0psi Total Load to Recover (TLTR) stage 9-10 – 3,732bbls Total Load to Recover (TLTR) – 18,548bbls 4/26/2025 4/27/2025 RDMO frac. RD Cameron launch tree. Last report for Frac operations. Page 2 of 2 Flowback Ops Summary Report - AOGCC Well Name NDBi-049 Primary Job Type WSV Start Date End Date Summary 4/28/2025 4/29/2025 Rig up Well-test equipment to Production tree and rig up irons to the choke manifold. PT upstream equipment to 4500psi. Good test but unable to get a good test on equipment downstream of choke at midnight. 4/29/2025 4/30/2025 Completed pressure testing Well test equipment downstream of the choke to 1000psi. Good test. Completed testing process safety systems and ESD stations. Complete Pre-flow checklist, open well and start Well Cleanout/ Flowback as per procedure. FLOW WELL AS PER CLEAN UP PROCEDURE ON CHOKE 128/64". 4/30/2025 5/1/2025 FLOW WELL AS PER CLEAN UP PROCEDURE ON CHOKE 128/64". 5/1/2025 5/2/2025 FLOW WELL AS PER CLEAN UP PROCEDURE ON CHOKE 128/64". 5/2/2025 5/3/2025 FLOW WELL AS PER CLEAN UP PROCEDURE ON CHOKE 128/64". 5/3/2025 5/4/2025 FLOW WELL AS PER CLEAN UP PROCEDURE ON CHOKE 128/64". 5/4/2025 5/5/2025 FLOW WELL AS PER CLEAN UP PROCEDURE ON CHOKE 128/64". Perform a stepdown rate test at Choke 52/64" for 6hrs and Choke 44/64" until midnight. Page 1 of 1 Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 1.0 gal F103 Surfactant 1.0 Gal/mGal 748.0 gal J450 Stabilizing Agent 0.5 Gal/mGal 372.0 gal J475 Breaker J475 5.7 lb/mGal 4,445.0 lbm J511 Stabilizing Agent 1.7 lb/mGal 1,316.0 lbm J532 Crosslinker 2.2 Gal/mGal 1,691.0 gal J580 Gel J580 28.2 lb/mGal 21,809.0 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 75.5 gal M117 Clay Control Agent 333.3 lb/mGal 257,847.5 lbm M275 Bactericide 0.4 lb/mGal 276.0 lbm S522-1620 Propping Agent varied concentrations 2,210,763.0 lbm S522-4070 Propping Agent varied concentrations 22,761.0 lbm 71.28084 % 25.32136 % 2.83551 % 0.24663 % 0.08770 % 0.04069 % 0.04031 % 0.03886 % 0.03173 % 0.01492 % 0.01326 % 0.01326 % 0.01218 % 0.00957 % 0.00661 % 0.00200 % 0.00156 % 0.00106 % 0.00062 % 0.00031 % 0.00025 % 0.00025 % 0.00023 % 0.00019 % 0.00016 % 0.00004 % 0.00003 % 0.00003 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % 100 % 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. 9004-32-4 Sodium carboxymethylcellulose 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione 7632-00-0 Sodium nitrite 9000-90-2 Amylase, alpha 9005-65-6 Sorbitan monooleate, ethoxylated 11138-66-2 Xanthan Gum 36089-45-9 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2-hydroxyethyl 2-propenoate 68937-55-3 Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 68308-89-4 Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 64-19-7 Acetic acid (impurity) 1338-41-6 Sorbitan stearate 63148-62-9 Dimethyl siloxanes and silicones 532-32-1 Sodium benzoate 67762-90-7 Siloxanes and silicones, dimethyl, reaction products with silica 127-08-2 Acetic acid, potassium salt (impurity) 14808-60-7 Quartz, Crystalline silica 14464-46-1 Cristobalite 111-42-2 2,2'-Iminodiethanol 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 7786-30-3 Magnesium chloride 10377-60-3 Magnesium nitrate 9002-84-0 poly(tetrafluoroethylene) 14807-96-6 Magnesium silicate hydrate (talc) 91053-39-3 Diatomaceous earth, calcined 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 25038-72-6 Vinylidene chloride/methylacrylate copolymer 68131-39-5 Ethoxylated Alcohol 37288-54-3 Beta-Mannanase 67-63-0 Propan-2-ol 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 56-81-5 1, 2, 3 - Propanetriol 1303-96-4 Sodium tetraborate decahydrate 50-70-4 Sorbitol 7647-14-5 Sodium chloride 102-71-6 2,2`,2"-nitrilotriethanol 7727-54-0 Diammonium peroxodisulphate 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)* YF126ST:WF126 773,543 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-2025 Fluid Name & Volume Concentration Volume Disclosure Type:Post-Job Well Completed: Date Prepared:4/30/2025 State:Alaska County/Parish:North Slope Borough Case: Client:Oil Search Alaska Well:PIKKA NDBi-049 Basin/Field:Pikka # SLB-Private Page: 1 / 1 Updated 05-16-2025INPUT4/20/2025AK TSCA StatusNorthSlope AKTBDPOST753,40673.00000%8,820,711Trade Name Supplier Purpose Ingredients Name CAS #Percentage by Mass of IngredientPercent of Ingredient in Total Mass PumpedMass of Ingredient (lbs)SMETracercoCarrier FluidSoy Methyl Ester67784-80-91000.000789800269.6659920000T-168ATracercoChemical Tracer1-Chloro-4-iodobenzene637-87-61000.00000499870.4409240000T-168BTracercoChemical Tracer1,2-Dichloro-4-iodobenzene20555-91-31000.00000499870.4409240000T-716TracercoChemical Tracer1,3,5-Tribromobenzene626-39-11000.00000499870.4409240000T-784TracercoChemical Tracer2,4,6-Tribromoanisole607-99-81000.00000499870.4409240000T-769TracercoChemical Tracer4-Fluorobenzophenone345-83-51000.00001249681.1023100000T-712TracercoChemical Tracer1,2,3-Trichlorobenzene87-61-61000.00002499372.2046200000T-163BTracercoChemical Tracer1,2-Diiodobenzene615-42-91000.00000499870.4409240000T-718TracercoChemical Tracer4-Chlorobenzophenone134-85-01000.00000749810.6613860000T-169CTracercoChemical Tracer2,4-Dibromomesitylene6942-99-01000.00000999750.8818480000T-163BTracercoChemical Tracer1,2-Diiodobenzene615-42-91000.00000499870.4409240000WaterTracercoCarrier FluidWater7732-18-51000.000787300869.4455300000T-930TracercoChemical TracerSodium-3-fluoro-4-methylbenzoate1805805-74-61000.00000874780.7716170000T-950TracercoChemical TracerSodium-2-fluoro-3-(Trifluoromethyl)-benzoate1701446-41-41000.00000874780.7716170000T-912TracercoChemical TracerSodium-2-chloro-5-fluorobenzoate1382106-79-71000.00000874780.7716170000T-140CTracercoChemical TracerSodium-4-Fluorobenzoate499-90-11000.00000874780.7716170000T-176ATracercoChemical TracerSodium-2,3,4-trifluorobenzoate402955-41-31000.00000874780.7716170000T-804TracercoChemical TracerSodium-2,3-dichlorobenzoate118537-84-11000.00000874780.7716170000T-158FTracercoChemical TracerSodium-2,3-Difluorobenzoate1604819-08-01000.00000874780.7716170000T-803TracercoChemical TracerSodium-4-chlorobenzoate3686-66-61000.00000874780.7716170000T-158ATracercoChemical TracerSodium-2,4-Difluorobenzoate1765-08-81000.00000874780.7716170000T-801TracercoChemical TracerSodium-2-chlorobenzoate17264-74-31000.00000874780.7716170000Report Type (Pre or Post Job)Total Water Volume (gal):Water Mass FractionTotal Mass Pumped (lbs)Hydraulic 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-049 11:07:14 12:30:34 13:53:54 15:17:14 16:40:34 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 Stage 1 Stage 2 Stage 3 Stage 4 Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stages 1-4 4-21-2025 13:24:28 13:57:48 14:31:08 15:04:28 15:37:48 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 22 24 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con DataFrac © Schlumberger 1994-2017 Santos NDBi-049, DataFrac 4-20-2025 11:37:30 11:58:20 12:19:10 12:40:00 13:00:50 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 Slow for Seat Slow for Seat Collet Seated Collet Seated Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 1 4-21-2025 12:45:36 12:58:06 13:10:36 13:23:06 13:35:36 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 Tr. Press - psi15 20 25 30 35 40 45 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 Slow for Seat Collet Seated Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 2 4-21-2025 13:31:00 13:47:40 14:04:20 14:21:00 14:37:40 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 Tr. Press - psi15 20 25 30 35 40 45 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 Slow for Seat Collet Seated Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 3 4-21-2025 14:23:46 14:40:26 14:57:06 15:13:46 15:30:26 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 Close Well Slow for Seat DFIT Collet Seated Freeze Protect Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 4 4-21-2025 09:03:53 11:50:33 14:37:13 17:23:53 20:10:33 Time - hh:mm:ss -1000 0 1000 2000 3000 4000 5000 6000 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 Stage 6Stage 5 Stage 7 Stage 8 Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stages 5-8 4-24-2025 12:11:22 12:28:02 12:44:42 13:01:22 13:18:02 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 Slow for Seat Collet Seat Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 5 4-24-2025 13:10:06 13:22:36 13:35:06 13:47:36 14:00:06 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 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 Slow for Seat Collet Seat Sahara Delivery Issues Cut Prop Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 6 4-24-2025 15:59:30 16:16:10 16:32:50 16:49:30 17:06:10 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 Slow for Seat Collet Seat Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 7 4-24-2025 16:51:27 17:08:07 17:24:47 17:41:27 17:58:07 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 Slow for Seat Collet Seat DFIT Shutdown Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 8 4-24-2025 15:18:34 16:16:54 17:15:14 18:13:34 19:11:54 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 Ball to Seat Stage 9 Stage 10 Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stages 9-10 04-25-2025 16:58:49 17:15:29 17:32:09 17:48:49 18:05:29 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 seated Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 9 04-25-2025 17:58:38 18:15:18 18:31:58 18:48:38 19:05:18 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 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 Shutdown Main Treatment © Schlumberger 1994-2017 Santos NDBi-049, Stage 10 04-25-2025 WELL TEST,1*6800$5< Doc No::7;$.B1'%L Rev No:$ Issued:-0D\- 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$1726B3LNND'HYHORSPHQW 1'%L :7;$.B1'%L B5HY$ Completed by Name Checked by Name Approved by Name Index Santos – Pikka Development - Well Clean-Up and Shut-in/Build-up – NDBi-049 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 - 18 5. Test Data Report_ Well Clean-up Flow Period ....................................................................... 19 - 23 6. Test Data Plots_ Well Clean-up Flow Period ................................................................................. 24 Bottom Hole Plot ............................................................................................................................... 25 Well Head / Choke Plot ..................................................................................................................... 26 Well Head vs Bottom Hole Conditions Plot ........................................................................................ 27 Production Rate (Test Separator Flow Meter) Plot ........................................................................... 28 Production Rate (Tank Farm Strap) Plot ........................................................................................... 29 Cumulative (Test Separator Flow Meter) Plot ................................................................................... 30 Cumulative (Tank Farm Strap) Plot ................................................................................................... 31 Production Ratio Plot ........................................................................................................................ 32 Test Separator Plot ............................................................................................................................ 33 7. Tank Farm Rates & Volumes ................................................................................................. 34 - 40 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 2 Index Santos – Pikka Development - Well Clean-Up and Shut-in/Build-up – NDBi-049 8. Injection Well NDBi-014 Data ................................................................................................ 41 – 46 Well Head – Bottom Hole Plot_Flowback ......................................................................................... 47 Injection Rate - Cumulative Plot_Flowback ....................................................................................... 48 Well Head – Bottom Hole Plot_ Wireline Injectivity Test .................................................................. 49 Injection Rate - Cumulative Plot_Wireline Injectivity Test ................................................................ 50 9. Test Summary_Bottom Hole Shut-in / Build-up Period ............................................................ 51-52 10. Test Data Report_ Bottom Hole Shut-in / Build-up Period ...................................................... 53-58 Bottom Hole_Shut-in / Build-up Plot ................................................................................................. 59 11. Sequence of Events ............................................................................................................ 60 - 86 12. Combined Meter Shrinkage Factor (CMSF) .......................................................................... 87 - 89 13. Diagrams ................................................................................................................................... 90 Process and Instrumentation Diagram (P&ID) ............................................................................ 91 -97 Safety Analysis Function Evaluation (SAFE) Chart ................................................................... 98 - 100 General Arrangement Diagram (GAD) ................................................................................... 101 - 104 Process Flow Diagram (PFD) .................................................................................................. 105 - 109 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-0127.5_NDBi-049_Rev A www.expro.com Page 3 Santos – Pikka Development – NDBi-049 SECTION 1 INTRODUCTION WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 4 Introduction May 12th, 2025 Santos Pikka Development – NDBi-049 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 referenced well NDBi-049. 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: April 29th, 2025 10:00:00 End of Flow Period: May 5th, 2025 02:00:00 Well Shut-In & Build-Up Period: Start of Build-Up Period: May 5th, 2025 02:00:00 End of Build-Up Period: May 12th, 2025 02:00:00 Note: NDBi-049 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 DPI CyFi Desander. The DPI Unit 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 sand to the 400 bbl Atmospheric Horizontal Sand Tank. The disposal feature on the Expro DPI CyFi Desander was utilized multiple times during the clean-up period which equated to an approximate total of 30.16 bbls of sand accumulated in the 400 bbl Atmospheric horizontal Sand Tanks. 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 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 5 Introduction 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, Expro’s 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. Well effluent existing the choke manifold next entered the Santos test header and travelled to 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 Santos’ 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 a tank volume spreadsheet calculator along with BS&W values to deduce oil and water rates and cumulative values. Once the tanks reached the maximum level of 294 bbls, 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 injector well NDBi-014. Note that approximately 1835.64 bbls of fluid returned from well NDBi-049 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 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 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 6 Introduction 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 0.987 was applied on April 29th, 2025 at 17:00 hrs. See Section 12 of this report for a complete list of CMSF’s calculated and applied into our DAQ software calculations during flowback operations. x During the night shift starting May 1st, 2025, the well was slugging heavily. These adverse flowing conditions caused erroneous separator fluid rates over multiple reporting time intervals. To rectify the inaccurate data, additional meter factors were implemented specifically during these instances to ensure separator data corresponded to tank strap data. These meter factors along with their timeframe of usage can also be found in Section 12 of this report. 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, along with additional water samples every 3 hours for the 72 hours of flowback for Tracerco dye analysis. BS&W samples taken downstream of the choke manifold during preliminary stages of the flowback showed the presence of emulsion. Utilizing BS&W samples, assessments were carried out with two variations of emulsion breaker chemicals, the previously used Tretolite DMO146 and a new Tretolite DMO46x. Analysis confirmed that the Tretolite DMO46x was more efficient, so on April 29th, 2025, at 22:00, we began injecting the Tretolite DMO46x upstream of the choke manifold. 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. On May 12th at 02:00, Expro completed the Build-Up data for the purposes of this report, 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. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 7 Introduction 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 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-0127.5_NDBi-049_Rev A www.expro.com Page 8 Santos – Pikka Development – NDBi-049 SECTION 2 POINTS OF CONTACT WT-XAK-0127.5_NDBi-049_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 Victor Chavez Well Test Supervisor Victor Chavez@expro.com Office: (907) 707-7749 Yehia Elzeny Well Test DAQ Specialist Yehia.Elzeny@expro.com Office: (907) 229-3996 Roger Ihde Well Test Supervisor Roger.Ihde@expro.com Office: (907) 715-1827 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 Jose Reynoso Well Test Supervisor Jose.Reynoso@expro.com Office: (907) 382-7058 Travis Stacey Well Test Sr. DAQ Specialist Travis.Stacey@expro.com Office: (709) 743-0294 Sharon Oyao Well Test Field Engineer Sharon.Oyao@expro.com Office: (907) 382-8773 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 10 Santos – Pikka Development – NDBi-049 SECTION 3 NOMENCLATURE WT-XAK-0127.5_NDBi-049_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-0127.5_NDBi-049_Rev A www.expro.com Page 12 Nomenclature: Abbreviation Meaning Abbreviation Meaning P-Tank Pressurized Tank TRAC Toolbox Risk Assessment Card 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 WHPi Well Head Pressure Injection SSV Surface Safety Valve WHT Well Head Temperature STE Surface Well Test Equipment WST Well Stimulation Tool TBT Toolbox Talk WT Well Test WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 13 Santos – Pikka Development – NDBi-049 SECTION 4 TEST SUMMARY WELL CLEAN-UP FLOW WT-XAK-0127.5_NDBi-049_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 NDBi-049 – Clean-up Flow Period Well Clean-up Flow Test Start of 12 Hour Averaged Stable Flow Period: May 4th, 2025 01:00:00 End of 12 Hour Averaged Stable Flow Period: May 4th, 2025 13:00:00 On April 29th, 2025 @ 09:30 the NDBi-049 well was opened at the Flow Wing Valve (FWV) on the Wellhead to a ‘closed’ Expro choke manifold. At 10:00 the choke was opened to flow through the Expro Surface Test Equipment (STE) on a 20/64ths adjustable choke. Well NDBi-049 was opened on a 128/64ths adjustable choke on April 29th, 2025 @ 23:00 and flowed until May 5th, 2025 @ 02:00 when well production was ceased with a hard Shut-In at the Expro Choke Manifold. Prior to a hard shut-in at the choke manifold, the well was beaned down and flowed for a 6-hour period on each a 52/64ths adjustable choke on May 4th, 2025 @ 14:00 to May 4th, 2025 @ 20:00 and a 44/64ths adjustable choke on May 4th, 2025 @ 20:00 to May 5th, 2025 @ 02:00. The contents of this summary was deducted from 12 hours of stabilized flow at the end of the flow period on the highest choke size of 128/64ths. Provided below is a summary of the 12-hour flow period 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. 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. WT-XAK-0127.5_NDBi-049_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. Santos – Pikka Development NDBi-049 – 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) 05/04/2025 01:00 128 10.0 0 27,000 8 0.688 0.1 0.0 0.873 30.6 8.0 8.0 05/04/2025 01:30 128 6.0 0 27,000 8 0.688 0.1 0.0 0.873 30.6 8.0 8.0 05/04/2025 02:00 128 8.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 02:30 128 8.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 03:00 128 8.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 03:30 128 8.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 04:00 128 8.0 0 25,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 04:30 128 10.0 0 25,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 05:00 128 8.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 05:30 128 6.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 06:00 128 8.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 06:30 128 7.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 07:00 128 7.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 WT-XAK-0127.5_NDBi-049_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. 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) 05/04/2025 07:30 128 7.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 08:00 128 7.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 08:30 128 6.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 09:00 128 6.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 09:30 128 6.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 10:00 128 6.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 10:30 128 6.0 0 26,000 8 0.679 0.1 0.0 0.869 31.4 8.0 8.0 05/04/2025 11:00 128 5.5 0 26,000 8 0.679 0.1 0.0 0.873 30.6 8.0 8.0 05/04/2025 11:30 128 6.0 0 26,000 8 0.679 0.1 0.0 0.873 30.6 8.0 8.0 05/04/2025 12:00 128 6.0 0 26,000 8 0.684 0.1 0.0 0.873 30.6 8.0 8.0 05/04/2025 12:30 128 7.0 0 26,000 8 0.684 0.1 0.0 0.873 30.6 8.0 8.0 05/04/2025 13:00 128 7.0 0 24,000 8 0.684 0.1 0.0 0.873 30.6 8.0 8.0 WT-XAK-0127.5_NDBi-049_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 NDBi-049 – Clean-up Flow Test. Average Total Gas Rate (Formation + N2)1.8520 MMscf/day Cumulative Total Gas (Formation + N2)7.2533 MMscf Average N2 Rate 0.00 MMscf/day Cumulative N2 0.0 MMscf Average Oil Rate - Meter 5,247.47 Stb/day Cumulative Oil - Meter 19,606.49 Stb Average Oil Rate - Tanks 5,196.18 Stb/day Cumulative Oil -Tanks 19,655.82 Stb Average Water Rate - Meter 401.36 Stb/day Cumulative Water -Meter 5,448.76 Stb Average Water Rate - Tanks 386.48 Stb/day Cumulative Water -Tanks 5,378.56 Stb Average Sol/Mud/Car Rate 0.0 Stb/day Cumulative Sol/Mud/Carbo 1.97 Stb @ Flowmeter @ Flowmeter Average Sol/Mud/Car Rate 0.0 Stb/day Cumulative Sol/Mud/Carbo 1.93 Stb @ Strap Tanks @ Strap Tanks Average Total Fluid Rate 5,648.83 Stb/day Cumulative Total Fluid 25,055.24 Stb @ Flowmeter @ Flowmeter Average Total Fluid Rate @ Strap Tanks 5,582.64 Stb/day Cumulative Total Fluid @ Strap tanks 25,036.31 Stb Average GOR (Total) (Formation + N2)353.00 scf/stb % Frac Water Recovered 29.14 % Note: Well Clean-up: Flow rates and GOR are average values during the most stable flow period taken between May 4 th, 2025 at 01:00hrs through May 4 th, 2025 at 13:00hrs. Average Formation GOR can be assumed to be the same as Total GOR because Nitrogen was not being Injected during this stabilized period. Average Formation Gas Rate assumed to be the same as Total Gas Rate because Nitrogen was not being Injected during this stabilized period. All Cumulative Values including % Frac Water Recovered are totals at the end of the well clean-up flowback. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 18 Santos – Pikka Development – NDBi-049 SECTION 5TEST DATA REPORTWELL CLEAN-UP FLOWWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 19 START DATE:END DATE:TimeDPIGORFrac 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)Separator Inlet 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)(F)(psig) (psig) (psig)(F)(psig)(F)(psig)(F)(64ths) (%) (psig) (psig)(F) (F)(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)04-29-2025 09:30Pre-Flow Safety Meeting for NDBi-049 with Santos WSS, Expro, Magtec and LRS.09:49 Opened WH NDBi-049 Master Valve (23.5 turns).09:50 Opened WH NDBi-049 Production Wing Valve to closed Expro Choke Manifold. (24 Turns).09:50 Verified Valve Alignment to Flow Path through Ball catcher and DPI Unit, Bypassing Separator into Tank 1.09:52 Initial SIBHP 1747.21 psig; Initial SIBHT 87.91 °F; Initial WHP 296.4 psig & Initial WHT 32.84°F. 1747.61 87.90 0.00 11.63 2.06 21.54 16.63 48.13 5.60 19.34 0 0.00 0.99 53.01 52.710.0 0.0 0.0 0.004-29-2025 10:00Opened Well NDBi-049 on a 20/64ths adjustable Choke as per Santos WSS.10:15 Confirmed Fluid Returns at Tank Farm Manifold.1747.21 87.91 0.00 11.88 296.40 32.84 295.01 50.22 6.30 21.00 20 0.31 0.96 58.38 55.410.0 0.0 0.0 0.004-29-2025 10:30Increased Expro adjustable Choke to 24/64ths as per Santos WSS.10:31BS&W showed 100% Diesel.1646.59 89.34 0.00 11.72 169.09 29.80 164.52 32.37 5.78 47.08 24 0.51 0.00 61.15 56.040.00 0.00 1013.18 21.11 0.00 0.00 1013.18 21.11 0.00 0.0 0.0 0.0 0.004-29-2025 11:00Increased Expro adjustable Choke to 28/64ths as per Santos WSS.1709.26 90.86 0.00 12.54 133.57 26.80 126.54 30.93 6.73 43.60 28 1.67 0.00 59.98 56.090.00 0.00 1375.03 49.75 0.00 0.00 1375.03 49.75 0.00 0.0 0.0 0.0 0.004-29-2025 11:30Increased Expro adjustable Choke to 32/64ths as per Santos WSS.1729.39 91.20 0.36 13.48 75.33 28.56 72.94 30.70 4.45 42.80 32 1.09 0.00 57.50 55.830.00 0.00 868.44 67.85 0.00 0.00 868.44 67.85 0.00 0.0 0.0 0.0 0.004-29-2025 12:001695.67 92.61 0.56 13.56 42.06 32.27 37.69 33.34 7.25 45.27 32 1.20 0.00 55.24 55.470.00 0.00 868.44 85.94 0.00 0.00 868.44 85.94 0.00 0.0 0.0 0.0 0.004-29-2025 12:30Increased Expro adjustable Choke to 36/64ths as per Santos WSS.1686.43 93.36 1.81 13.84 59.25 34.86 53.73 35.72 8.67 47.50 36 2.62 0.00 53.48 54.910.00 0.00 1013.18 107.05 0.00 0.00 1013.18 107.05 0.00 0.0 0.0 0.0 0.004-29-2025 13:00Increased Expro adjustable Choke to 40/64ths as per Santos WSS.13:29 Gas at Surface.1676.25 94.32 3.12 15.61 310.49 38.26 294.34 38.85 58.76 49.55 40 21.40 0.00 52.20 54.560.00 0.00 2532.96 159.82 0.00 0.00 2532.96 159.82 0.00 0.0 0.0 0.0 0.004-29-2025 13:30Increased Expro adjustable Choke to 44/64ths as per Santos WSS.Oil at Surface.Diverted Well Flow through Separator.13:35 Gas Metered through 0.5" Coriolis Meter.13:38 Adjusted DAQ Fluid Cumulative Volumes to account for Volumes not Metered while the Separator was being Bypassed. Oil Cum 214.79 bbls. Water Cum 4.24 bbls. Total Fluid Cum 219.02 bbls.13:38 Commenced Chemical Injection of Defoamer & Demulsifier @ 8 gal/d.13:38Liquid Metered through 1.5" Turbine Meter.1628.56 95.34 7.19 16.64 191.87 42.64 159.21 43.25 42.66 54.30 44 3.00 0.47 51.16 54.010.00 0.00 0.00 0.00 0.0000 0.0000 0.0000 0.0000 0.00 0.00 0.00 214.79 0.00 4.24 0.00 219.02 0.00 0.00 2243.48 206.56 0.00 0.00 2243.48 206.56 0.00 0.0 0.00.00.004-29-2025 14:00Increased Expro adjustable Choke to 48/64ths as per Santos WSS.14:11 Adjusted Separator Liquid Level.1605.20 95.78 16.42 16.37 167.38 42.26 131.04 43.39 98.76 54.27 48 0.00 82.34 84.00 59.52 49.21 31.9 0.700 34.00 0.00 34.00 34.00 0.0000 0.2304 0.0000 0.0048 174.28 0.00 0.00 1322.01 242.33 681.03 18.43 2003.04 260.75 0.00 0.00 694.92 221.04 1403.65 29.24 2098.74 250.28 0.10 8.0 0.0 8.0 0.004-29-2025 14:30Increased Expro adjustable Choke to 52/64ths as per Santos WSS.1612.65 96.06 46.19 18.60 179.58 44.89 143.18 44.15 109.25 54.61 52 0.00 77.41 77.20 57.29 49.53 31.9 0.700 80.00 0.00 80.00 80.00 0.0000 0.2352 0.00000.0097 312.82 0.00 0.00 751.87 258.00 3007.49 81.08 3759.36 339.07 0.00 0.00 615.15 233.85 1845.44 67.69 2460.59 301.54 0.43 8.0 0.0 8.0 0.004-29-2025 15:00Increased Expro adjustable Choke to 56/64ths as per Santos WSS.Collected Tracerco Dye Water Sample.1593.55 96.23 99.96 19.09 205.82 47.38 152.62 46.24 113.05 56.53 56 0.00 78.61 79.19 56.46 50.57 31.9 36000 8 0.676 75.00 0.00 75.00 75.00 0.0000 0.24000.0000 0.0147 333.89 0.00 0.00 718.80 272.97 2156.40 126.01 2875.20 398.97 0.00 0.00 521.07 244.71 2084.26 111.11 2605.33 355.82 0.67 8.0 0.0 8.0 0.004-29-2025 15:30Increased Expro adjustable Choke to 60/64ths as per Santos WSS.1591.03 96.29 154.41 20.39 159.87 47.32 118.26 46.01 97.55 57.76 60 0.00 74.63 76.13 56.03 51.56 31.9 36000 8 0.676 0.10 0.0 80.00 0.00 80.00 80.00 0.0000 0.2688 0.0000 0.0203 486.20 0.00 0.00 552.86 284.49 2211.46 172.08 2764.32 456.56 0.00 0.00 669.42 258.65 2008.27 152.95 2677.70 411.61 0.92 8.0 0.08.0 0.004-29-2025 16:00Increased Expro adjustable Choke to 64/64ths as per Santos WSS.1563.57 96.42 205.82 20.09 207.54 48.57 146.35 47.60 118.81 58.46 64 0.00 87.80 88.93 55.13 52.14 30.9 33000 8 0.676 0.10 0.0 75.00 0.00 75.00 75.00 0.0000 0.2880 0.0000 0.0263 368.72 0.00 0.00 781.08 300.76 2343.24 220.90 3124.32 521.65 0.00 0.00 972.66 278.92 2066.89 196.01 3039.55 474.93 1.18 8.0 0.08.00.004-29-2025 16:301544.35 96.45 254.08 21.34 216.78 49.54 150.93 48.33 130.11 59.43 64 0.00 93.18 93.60 55.07 52.94 30.9 33000 8 0.680 0.10 0.0 68.00 0.00 68.00 68.00 0.0000 0.3504 0.0000 0.0336 342.79 0.00 0.00 1022.21 322.06 2172.19 266.15 3194.40 588.20 0.00 0.00 1058.05 300.96 2053.87 238.80 3111.92 539.76 1.42 8.00.0 8.0 0.004-29-2025 17:00Applied CMSF 0.987.1527.66 96.47 288.56 21.03 232.56 49.83 157.83 48.35 140.12 59.47 64 0.00 117.08 117.75 55.71 53.53 30.9 32000 8 0.680 0.10 0.0 66.00 0.00 66.00 66.00 0.0000 0.4368 0.0000 0.0427 390.38 0.00 0.00 1118.90 345.37 2171.98 311.40 3290.88 656.76 0.00 0.00 1302.66 328.10 1953.99 279.51 3256.66 607.61 1.67 8.0 0.0 8.0 0.004-29-2025 17:301514.83 96.46 316.93 22.80 249.27 50.35 187.13 48.83 169.85 59.46 64 0.00 119.08 118.56 55.87 53.56 30.9 32000 8 0.664 0.10 0.0 60.00 0.00 60.00 60.00 0.0000 0.4848 0.0000 0.0528 370.40 0.00 0.00 1308.86 372.64 1963.30 352.30 3272.16 724.93 0.00 0.00 781.60 344.38 2475.06 331.07 3256.66 675.45 1.88 8.00.08.00.004-29-2025 18:00Increased Expro adjustable Choke to 70/64ths as per Santos WSS.Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.1509.39 96.46 343.51 22.58 241.26 48.97 171.83 47.57 151.54 57.98 70 0.00 121.24 122.68 58.32 54.73 30.9 32000 8 0.664 0.10 0.0 76.00 0.00 76.00 76.00 0.0000 0.5136 0.0000 0.0635 658.54 0.00 0.00 779.90 388.88 2469.70 403.76 3249.60 792.63 0.00 0.00 1618.20 378.10 1493.72 362.19 3111.92 740.29 2.16 8.00.08.00.004-29-2025 18:30Increased Expro adjustable Choke to 76/64ths as per Santos WSS.18:45 Informed by Santos WSS that we can drawdown BHP below 1459 psi Bubble Point if necessary.1494.40 96.41 364.25 22.78 258.29 48.97 195.99 48.24 183.10 59.20 76 0.00 138.64 138.97 63.36 55.72 30.9 32000 8 0.664 0.10 0.0 48.00 0.00 48.00 48.00 0.0000 0.5616 0.0000 0.0752 316.14 0.00 0.00 1776.40 425.89 1639.76 437.92 3416.16 863.80 0.00 0.00 2396.90 428.03 932.13 381.61 3329.03 809.64 2.34 8.00.08.00.004-29-2025 19:00Increased Expro adjustable Choke to 82/64ths as per Santos WSS.Applied CMSF 0.959.1486.37 96.40 378.65 23.93 246.82 49.11 195.29 47.36 187.19 58.72 82 0.00 145.97 146.84 63.81 55.67 29.9 32000 8 0.667 0.10 0.0 28.00 0.00 28.00 28.00 0.0000 0.6096 0.0000 0.0879 249.45 0.00 0.00 2443.74 476.80 950.34 457.72 3394.08 934.51 0.00 0.00 1758.60 464.67 1498.06 412.82 3256.66 877.49 2.45 8.00.08.00.004-29-2025 19:30Increased Expro adjustable Choke to 88/64ths as per Santos WSS.1472.66 96.45 391.75 24.37 277.62 49.23 207.49 47.32 202.67 58.07 88 0.00 158.09 158.92 65.09 55.56 29.9 32000 8 0.660 0.10 0.0 46.00 0.00 46.00 46.00 0.0000 0.6672 0.0000 0.1018 374.19 0.00 0.00 1783.04 513.95 1518.88 489.36 3301.92 1003.30 0.00 0.00 2463.48 515.99 865.55 430.85 3329.03 946.84 2.62 8.0 0.0 8.0 0.004-29-2025 20:00Increased Expro adjustable Choke to 94/64ths as per Santos WSS.1471.73 96.41 408.93 25.45 261.57 49.46 197.62 47.45 194.15 58.59 94 0.00 158.27 158.03 65.94 55.29 31.0 31000 8 0.660 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 0.6672 0.0000 0.1157 273.98 0.00 0.00 2435.25 564.68 855.63 507.19 3290.88 1071.86 0.00 0.00 2396.90 565.93 932.13 450.27 3329.03 1016.20 2.71 8.0 0.0 8.0 0.004-29-2025 20:30Increased Expro adjustable Choke to 100/64ths as per Santos WSS.1466.43 96.39 422.80 24.81 287.26 49.50 214.62 47.14 212.46 59.43 100 0.00 167.84 168.19 65.46 54.96 31.0 31000 8 0.657 0.10 0.0 28.00 0.00 28.00 28.00 0.0000 0.6816 0.0000 0.1299 279.55 0.00 0.00 2438.21 615.48 948.19 526.94 3386.40 1142.41 0.00 0.00 2086.43 609.39 1278.78 476.91 3365.21 1086.31 2.82 8.0 0.0 8.0 0.004-29-2025 21:00Increased Expro adjustable Choke to 106/64ths as per Santos WSS.Collected Tracerco Dye Water Sample.1447.86 96.33 432.08 24.81 308.32 50.25 229.45 48.05 226.22 58.91 106 0.00 175.61 175.40 65.78 55.15 31.0 31000 8 0.657 0.10 0.0 38.00 0.00 38.00 38.00 0.0000 0.7104 0.0000 0.1447 335.60 0.00 0.00 2116.83 659.58 1297.41 553.97 3414.24 1213.54 0.00 0.00 2459.86 660.64 1267.20 503.31 3727.06 1163.95 2.96 8.0 0.0 8.0 0.004-29-2025 21:30Increased Expro adjustable Choke to 112/64ths as per Santos WSS.Diverted Gas Flow from 0.5" Coriolis Meter through 3" Coriolis Meter.1458.11 96.25 442.75 26.52 298.45 50.31 227.82 47.33 225.35 58.75 112 0.00 180.55 181.02 66.29 55.57 31.0 31000 8 0.657 0.10 0.0 34.00 0.00 34.00 34.00 0.0000 0.7488 0.0000 0.1603 331.79 0.00 0.00 2256.88 706.60 1162.64 578.19 3419.52 1284.78 0.00 0.00 2704.47 716.98 950.22 523.11 3654.69 1240.09 3.09 8.0 0.0 8.0 0.004-29-2025 22:00Increased Expro adjustable Choke to 118/64ths as per Santos WSS.Began Injecting Emulsion Breaker DM046X.1432.67 96.22 449.68 26.46 303.78 49.78 202.72 46.68 197.80 58.47 118 0.00 130.94 129.00 55.48 55.01 31.0 31000 8 0.657 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 0.8688 0.0000 0.1784 320.57 0.00 0.00 2710.18 763.06 952.22 598.03 3662.40 1361.08 0.00 0.00 2677.70 772.77 940.81 542.71 3618.51 1315.48 3.208.0 0.0 8.0 0.004-29-2025 22:30Increased Expro adjustable Choke to 124/64ths as per Santos WSS.1418.21 96.20 465.57 27.20 296.48 49.03 191.09 47.34 185.25 59.38 124 0.00 109.55 107.67 55.53 55.46 31.0 31000 8 0.657 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 1.1664 0.0000 0.2027 407.82 0.00 0.00 2860.07 822.65 1004.89 618.96 3864.96 1441.60 0.00 0.00 2761.65 830.30 1073.97 565.08 3835.62 1395.39 3.31 8.0 0.0 8.0 0.004-29-2025 23:00Increased Expro adjustable Choke to 128/64ths as per Santos WSS.1408.94 96.27 479.03 27.24 294.72 49.60 183.05 46.99 176.39 59.07 128 0.00 95.48 91.67 54.82 55.64 31.0 31000 8 0.657 0.10 0.0 28.00 0.00 28.00 28.00 0.0000 1.2528 0.0000 0.2288 435.17 0.00 0.00 2878.85 882.62 1119.55 642.29 3998.40 1524.90 0.00 0.00 3025.07 893.33 955.29 584.99 3980.36 1478.31 3.43 8.0 0.0 8.0 0.004-29-2025 23:301402.70 96.21 490.69 27.08 293.83 49.62 179.67 47.15 171.43 59.02 128 0.00 85.81 82.48 55.08 55.45 31.0 31000 8 0.657 0.10 0.0 24.00 0.00 24.00 24.00 0.0000 1.2960 0.0000 0.2558 426.69 0.00 0.00 3037.32 945.90 959.16 662.27 3996.48 1608.16 0.00 0.00 3204.55 960.09 703.44 599.64 3907.99 1559.73 3.54 8.00.08.00.004-30-2025 00:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.1394.99 96.19 499.37 26.96 293.55 49.71 177.50 48.08 170.46 59.17 128 0.00 82.75 79.28 54.82 55.73 31.0 30000 8 0.657 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.3248 0.0000 0.2834 398.14 0.00 0.00 3327.49 1015.22 730.43 677.49 4057.92 1692.70 0.00 0.00 3465.08 1032.28 660.02 613.39 4125.10 1645.67 3.628.0 0.0 8.0 0.004-30-2025 00:301391.52 96.20 506.96 27.64 296.08 49.38 180.96 47.36 174.30 59.00 128 0.00 90.66 86.36 55.19 55.65 31.0 30000 8 0.658 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.3440 0.0000 0.3114 393.08 0.00 0.00 3419.14 1086.45 651.26 691.06 4070.40 1777.50 0.00 0.00 3454.23 1104.24 562.32 625.11 4016.54 1729.35 3.708.0 0.0 8.0 0.004-30-2025 01:001:15 Began Injection into Well NDBi-014.1387.10 96.19 514.62 28.35 299.80 49.68 179.53 47.85 172.36 59.07 128 0.00 84.42 81.43 54.90 55.75 31.0 30000 8 0.658 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3488 0.0000 0.3395 384.45 0.00 0.00 3508.39 1159.55 571.13 702.95 4079.52 1862.49 0.00 0.00 3578.71 1178.80 582.58 637.24 4161.29 1816.04 3.768.0 0.0 8.0 0.004-30-2025 01:301383.90 96.19 519.68 28.55 300.52 49.59 182.59 47.51 175.68 59.08 128 0.00 91.88 86.80 54.92 55.49 31.0 30000 8 0.658 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4016 0.0000 0.3687 395.41 0.00 0.00 3544.71 1233.39 577.05 714.98 4121.76 1948.36 0.00 0.00 3647.46 1254.79 405.27 645.69 4052.73 1900.47 3.828.0 0.0 8.0 0.004-30-2025 02:001376.37 96.19 526.47 28.43 304.14 50.44 180.98 47.01 173.45 59.27 128 0.00 86.42 83.43 55.01 55.78 30.1 30000 8 0.658 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.3872 0.0000 0.3976 374.74 0.00 0.00 3701.81 1310.52 411.31 723.54 4113.12 2034.05 0.00 0.00 3728.51 1332.46 324.22 652.44 4052.73 1984.90 3.878.0 0.0 8.0 0.004-30-2025 02:301376.59 96.24 530.61 28.85 305.20 50.86 184.54 47.54 177.72 59.51 128 0.00 89.20 85.56 54.76 55.62 30.1 30000 8 0.658 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.4160 0.0000 0.4271 373.81 0.00 0.00 3788.04 1389.43 329.40 730.41 4117.44 2119.83 0.00 0.00 3485.35 1405.07 567.38 664.26 4052.73 2069.33 3.91 8.00.0 8.0 0.004-30-2025 03:00Collected Tracerco Dye Water Sample.1371.08 96.17 536.64 28.81 307.69 51.13 184.80 47.74 177.16 59.14 128 0.00 88.41 83.56 54.79 55.30 30.1 30000 8 0.658 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4304 0.0000 0.4569 404.80 0.00 0.00 3533.57 1463.05 575.23 742.39 4108.80 2205.43 0.00 0.00 3534.56 1478.71 481.99 674.30 4016.54 2153.01 3.978.0 0.0 8.0 0.004-30-2025 03:301369.69 96.17 539.79 29.63 312.78 51.30 187.89 47.80 180.88 59.23 128 0.00 89.61 85.16 54.47 54.55 30.1 30000 8 0.658 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.4496 0.0000 0.4871 396.79 0.00 0.00 3653.34 1539.16 498.18 752.77 4151.52 2291.92 0.00 0.00 3795.09 1557.77 330.01 681.18 4125.10 2238.95 4.038.0 0.0 8.0 0.004-30-2025 04:001363.76 96.17 544.59 28.97 314.16 49.50 187.27 48.37 179.82 59.26 128 0.00 88.94 84.62 54.71 54.98 30.1 31000 8 0.658 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.4976 0.0000 0.5183 385.73 0.00 0.00 3882.55 1620.05 337.61 759.80 4220.16 2379.84 0.00 0.00 3894.96 1638.92 338.69 688.23 4233.66 2327.15 4.06 8.00.0 8.0 0.004-30-2025 04:301363.14 96.17 548.93 29.49 317.54 48.80 188.47 47.96 181.01 58.73 128 0.00 89.33 84.49 54.66 55.49 30.1 31000 8 0.658 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.5120 0.0000 0.5498 392.47 0.00 0.00 3852.52 1700.31 335.00 766.78 4187.52 2467.08 0.00 0.00 3828.38 1718.68 332.90 695.17 4161.29 2413.85 4.10 8.00.0 8.0 0.004-30-2025 05:001358.53 96.16 552.87 29.69 320.15 48.91 190.81 47.62 183.30 58.73 128 0.00 87.98 84.76 54.42 55.49 30.1 32000 8 0.658 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.5456 0.0000 0.5820 396.87 0.00 0.00 3894.47 1781.44 338.65 773.84 4233.12 2555.27 0.00 0.00 3828.38 1798.44 332.90 702.10 4161.29 2500.54 4.14 8.00.0 8.0 0.004-30-2025 05:301355.65 96.16 557.33 29.85 324.17 49.13 194.70 48.19 187.03 59.17 128 0.00 91.85 86.75 54.82 55.81 30.1 32000 8 0.658 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.5600 0.0000 0.6145 400.25 0.00 0.00 3897.56 1862.64 338.92 780.90 4236.48 2643.53 0.00 0.00 3795.09 1877.50 330.01 708.98 4125.10 2586.48 4.18 8.00.0 8.0 0.004-30-2025 06:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.1351.61 96.16 560.79 30.70 325.45 49.25 189.00 48.43 180.73 59.77 128 0.00 90.81 84.49 54.61 55.78 30.1 32000 8 0.658 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.5888 0.0000 0.6476 405.02 0.00 0.00 3922.73 1944.36 341.11 788.01 4263.84 2732.36 0.00 0.00 3877.59 1958.28 247.51 714.14 4125.10 2672.42 4.21 8.00.0 8.0 0.004-30-2025 06:30Applied CMSF 0.935.1348.54 96.15 564.36 30.74 330.12 49.46 198.20 48.72 190.51 59.94 128 0.00 91.72 87.82 54.74 54.48 30.1 32000 8 0.658 0.10 0.0 6.00 0.00 6.00 6.00 0.00001.6080 0.0000 0.6811 399.22 0.00 0.00 4027.86 2028.28 257.10 793.36 4284.96 2821.63 0.00 0.00 3877.59 2039.07 247.51 719.29 4125.10 2758.36 4.24 8.00.0 8.0 0.004-30-2025 07:001344.37 96.14 566.70 30.49 332.33 49.61 198.60 48.82 190.85 59.56 128 0.00 92.33 88.07 54.52 54.02 30.1 32000 8 0.658 0.10 0.0 6.00 0.00 6.00 6.00 0.00001.6224 0.0000 0.7149 410.52 0.00 0.00 3952.06 2110.61 252.26 798.62 4204.32 2909.22 0.00 0.00 3870.00 2119.69 291.29 725.36 4161.29 2845.05 4.27 8.00.0 8.0 0.004-30-2025 07:3007:32Diverted Fluid Flow from 1.5'' Turbine Meter through 2'' Turbine Meter.1340.41 96.14 570.29 30.31 336.08 51.61 200.59 48.71 192.14 59.78 128 0.00 92.83 88.45 54.41 53.63 30.1 32000 8 0.658 0.10 0.0 7.00 0.00 7.00 7.00 0.00001.6512 0.0000 0.7493 422.16 0.00 0.00 3911.36 2192.10 294.40 804.75 4205.76 2996.84 0.00 0.00 3918.85 2201.33 206.26 729.66 4125.10 2930.99 4.30 8.00.0 8.0 0.004-30-2025 08:001336.70 96.13 572.88 31.26 336.95 51.50 201.74 49.58 193.15 58.87 128 0.00 93.63 87.26 54.20 53.45 30.1 32000 8 0.658 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.6656 0.0000 0.7840 381.24 0.00 0.00 4368.94 2283.12 229.94 809.54 4598.88 3092.65 0.00 0.00 4056.35 2285.84 213.49 734.11 4269.84 3019.95 4.33 8.00.0 8.0 0.004-30-2025 08:30Applied CMSF 0.939.08:35 Lowered Separator Pressure.1334.01 96.13 576.38 31.34 339.84 51.36 201.86 49.21 192.19 59.60 128 0.00 87.93 82.72 53.72 53.18 30.1 32000 8 0.656 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.7232 0.0000 0.8199 400.91 0.00 0.00 4298.26 2372.67 226.22 814.25 4524.48 3186.91 0.00 0.00 4013.65 2369.46 256.19 739.44 4269.84 3108.90 4.35 8.00.0 8.0 0.004-30-2025 09:00Collected Tracerco Dye Water Sample.1329.43 96.13 579.29 31.40 333.47 51.44 192.59 49.63 188.91 58.85 128 0.00 78.47 71.10 53.38 52.74 30.1 32000 8 0.656 0.10 0.0 6.00 0.00 6.00 6.00 0.00001.7712 0.0000 0.8568 439.05 0.00 0.00 4034.18 2456.71 257.50 819.62 4291.68 3276.32 0.00 0.00 3987.60 2452.53 209.87 743.82 4197.47 3196.35 4.38 8.00.0 8.0 0.004-30-2025 09:301325.87 96.13 582.57 31.22 343.21 52.01 198.12 48.56 189.10 59.60 128 0.00 80.72 71.75 53.40 52.74 30.1 32000 8 0.656 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.8096 0.0000 0.8945 437.73 0.00 0.00 4134.10 2542.84 217.58 824.15 4351.68 3366.98 0.00 0.00 4168.52 2539.38 173.69 747.43 4342.21 3286.81 4.41 8.00.0 8.0 0.004-30-2025 10:001321.63 96.13 585.26 31.54 344.18 52.12 200.37 48.15 190.11 59.42 128 0.00 80.58 72.42 53.37 52.66 30.1 32000 8 0.656 0.10 0.0 4.00 0.00 4.00 4.00 0.00001.8240 0.0000 0.9325 433.03 0.00 0.00 4212.17 2630.59 175.51 827.81 4387.68 3458.39 0.00 0.00 4029.57 2623.33 167.90 750.93 4197.47 3374.26 4.43 8.00.0 8.0 0.004-30-2025 10:3010:46 Bypassed Expro Ball Catcher.10:55 Inspected Ball Catcher. No Debris Observed.1318.90 96.13 587.51 31.34 347.27 52.67 202.46 48.58 192.17 59.82 128 0.00 80.30 71.89 53.29 52.61 30.1 32000 8 0.656 0.10 0.0 4.00 0.00 4.00 4.00 0.00001.8528 0.0000 0.9711 442.09 0.00 0.00 4190.98 2717.90 174.62 831.45 4365.60 3549.34 0.00 0.00 4125.10 2709.27 217.11 755.45 4342.21 3464.72 4.45 8.00.0 8.0 0.004-30-2025 11:0011:04 Diverted Flow back through Ball catcher. Ball Catcher In Service.11:07 Observed Well Slugging.1394.54 96.90 607.28 31.06 343.98 53.17 202.54 50.08 192.63 61.72 128 0.00 80.67 71.60 53.90 53.04 30.1 31000 8 0.656 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.9296 0.0000 1.0113 441.57 0.00 0.00 4369.85 2808.94 229.99 836.24 4599.84 3645.17 0.00 0.00 4307.47 2799.01 179.48 759.19 4486.95 3558.20 4.47 8.00.0 8.0 0.004-30-2025 11:3011:33 Observed Well Slugging.11:55 Observed Well Slugging.1467.51 96.89 644.19 32.40 172.73 52.00 117.73 49.24 116.51 61.25 128 0.00 62.43 60.66 53.64 53.42 30.1 31000 8 0.656 0.10 0.0 4.00 0.00 4.00 4.00 0.00001.3920 0.0000 1.0403 412.74 0.00 0.00 3372.60 2879.21 140.52 839.16 3513.12 3718.36 0.00 0.00 3265.34 2867.03 136.06 762.03 3401.40 3629.06 4.49 8.00.0 8.0 0.004-30-2025 12:00Collected Tracerco Dye Water Sample. Kit #1 Complete.Collected Tracerco Standard Sample.1479.89 96.76 674.95 32.20 166.26 56.55 103.18 54.53 100.32 66.29 128 0.00 57.66 55.86 55.82 55.98 30.1 31000 8 0.656 0.10 0.0 4.00 0.00 4.00 4.00 0.00000.1824 0.0000 1.0441 73.63 0.00 0.00 2477.26 2930.81 103.22 841.32 2580.48 3772.12 0.00 0.00 1823.73 2905.03 781.60 778.31 2605.33 3683.34 4.50 8.0 0.0 8.0 0.004-30-2025 12:30Observed Well Slugging.1475.80 96.91 693.27 33.65 165.25 54.64 98.44 52.50 93.17 64.95 128 0.00 51.04 51.06 57.61 57.31 30.1 31000 8 0.656 0.10 0.0 30.00 0.00 30.00 28.00 0.0000 0.3552 0.0000 1.0515 175.87 0.00 0.00 2019.70 2972.89 865.58 859.35 2885.28 3832.23 59.34 1.24 1483.59 2935.94 1424.25 807.98 2967.18 3745.16 4.608.00.08.00.004-30-2025 13:0013:19 Increased Separator Pressure.13:25 Sparged Separator. Trace Solids Observed.1478.47 96.87 716.32 34.27 173.03 57.82 107.51 55.91 102.97 67.84 128 0.00 49.23 47.78 58.46 58.51 30.1 31000 8 0.656 0.10 0.0 50.00 2.00 48.00 47.50 0.0000 0.0528 0.0000 1.0526 33.38 59.66 1.24 1581.72 3005.84 1460.04 889.77 3041.76 3895.60 15.20 1.55 1519.77 2967.60 1504.58 839.33 3039.55 3808.48 4.76 8.0 0.0 8.0 0.004-30-2025 13:30Collected Core Lab Sample.Observed Well Slugging.13:32 Tracerco Representative collected Dye Water Sample Kit #1.13:57 Observed Well Slugging.1483.21 96.76 729.94 35.76 234.42 58.99 150.25 57.68 146.02 67.85 128 0.00 92.49 92.54 60.19 59.95 30.1 35000 8 0.656 0.10 0.0 50.00 0.50 49.50 49.00 0.0000 0.2160 0.0000 1.0571 131.14 16.23 1.58 1647.11 3040.16 1614.49 923.40 3261.60 3963.55 16.28 1.89 1302.66 2994.74 1937.71 879.70 3256.66 3876.334.94 8.0 0.0 8.0 0.004-30-2025 14:001478.84 96.75 728.34 35.84 184.20 57.45 121.17 56.14 118.69 66.00 128 0.00 80.23 81.47 60.32 59.77 30.3 35000 8 0.656 0.10 0.0 60.00 0.50 59.50 59.50 0.0000 0.6576 0.0000 1.0708 497.68 16.23 1.92 1321.34 3067.69 1941.22 963.84 3262.56 4031.52 0.00 1.89 998.71 3015.54 2330.32 928.25 3329.03 3945.68 5.15 8.0 0.0 8.0 0.004-30-2025 14:301464.50 96.77 734.16 36.40 251.14 56.91 152.78 54.06 147.77 64.97 128 0.00 81.16 79.73 60.27 60.36 30.3 35000 8 0.656 0.10 0.0 70.00 0.00 70.00 70.00 0.0000 0.6432 0.0000 1.0842 610.78 0.00 1.92 1053.07 3089.63 2457.17 1015.03 3510.24 4104.65 0.00 1.89 1773.07 3052.48 1773.07 965.19 3546.14 4019.56 5.43 8.0 0.0 8.0 0.004-30-2025 15:00Collected Tracerco Dye Water Sample.1469.54 96.63 738.84 37.66 239.19 57.51 141.79 53.54 137.29 65.13 128 0.00 80.69 80.67 60.56 59.80 30.3 35000 8 0.656 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 0.9408 0.0000 1.1038 523.85 0.00 1.92 1795.92 3127.04 1795.92 1052.45 3591.84 4179.48 0.00 1.89 2952.70 3114.00 738.18 980.56 3690.88 4096.45 5.63 8.0 0.0 8.0 0.004-30-2025 15:301462.30 96.64 741.56 38.13 275.67 57.37 153.02 53.97 146.52 65.99 128 0.00 84.34 82.77 61.17 61.19 30.3 35000 8 0.694 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 0.9312 0.0000 1.1232 302.11 0.00 1.92 3082.37 3191.26 770.59 1068.50 3852.96 4259.75 0.00 1.89 1841.10 3152.35 1994.52 1022.12 3835.62 4176.36 5.71 8.0 0.0 8.0 0.004-30-2025 16:001459.45 96.59 738.32 38.03 217.41 56.30 127.10 52.75 119.85 64.78 128 0.00 82.17 82.52 60.19 60.60 30.3 35000 8 0.694 0.10 0.0 52.00 0.00 52.00 52.00 0.0000 1.1328 0.0000 1.1468 619.31 0.00 1.92 1829.15 3229.36 1981.57 1109.79 3810.72 4339.14 0.00 1.89 1990.18 3193.82 1990.18 1063.58 3980.36 4259.295.94 8.0 0.0 8.0 0.004-30-2025 16:301460.85 96.55 748.13 38.17 291.12 58.05 171.75 54.24 164.42 65.89 128 0.00 84.28 83.05 61.36 61.67 30.3 35000 8 0.694 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 0.9984 0.0000 1.1676 519.22 0.00 1.92 1922.88 3269.42 1922.88 1149.85 3845.76 4419.26 0.00 1.89 3439.03 3265.46 468.96 1073.35 3907.99 4340.70 6.15 8.0 0.0 8.0 0.004-30-2025 17:001444.42 96.63 738.38 38.25 286.76 56.78 177.98 53.24 170.97 64.95 128 0.00 92.58 89.18 60.43 61.03 30.3 35000 8 0.694 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.2480 0.0000 1.1936 339.88 0.00 1.92 3671.92 3345.92 500.72 1160.28 4172.64 4506.19 0.00 1.89 3357.98 3335.42 839.49 1090.84 4197.47 4428.15 6.21 8.0 0.0 8.0 0.004-30-2025 17:301455.79 96.50 747.82 38.01 291.90 57.95 197.32 54.89 192.19 66.13 128 0.00 90.78 89.17 61.52 61.51 30.3 35000 8 0.694 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.1088 0.0000 1.2167 368.54 0.00 1.92 3008.64 3408.60 752.16 1175.95 3760.80 4584.54 0.00 1.89 3452.06 3407.34 383.56 1098.83 3835.62 4508.06 6.29 8.0 0.0 8.0 0.004-30-2025 18:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.1444.62 96.49 744.77 38.33 317.18 57.65 192.49 56.89 183.48 66.13 128 0.00 100.75 97.71 61.78 62.00 30.3 35000 8 0.694 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.1664 0.0000 1.2410 315.46 0.00 1.92 3697.49 3485.63 410.83 1184.51 4108.32 4670.13 0.00 1.89 2686.38 3463.30 1511.09 1130.31 4197.47 4595.516.33 8.0 0.0 8.0 0.004-30-2025 18:301444.81 96.46 743.83 38.15 307.35 57.27 190.30 57.80 182.91 65.93 128 0.00 98.51 95.19 61.25 60.88 30.3 35000 8 0.694 0.10 0.0 36.00 0.00 36.00 36.00 0.0000 1.2576 0.0000 1.2672 484.24 0.00 1.92 2597.07 3539.74 1460.85 1214.94 4057.92 4754.67 0.00 1.89 2996.13 3525.72 1165.16 1154.58 4161.29 4682.206.50 8.0 0.0 8.0 0.0BS&W Properties Gas Rates & CumulativesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Chemical Injection Rates5-May-2025 @ 02:00Well Head ChokeSeparator Fluid Properties Gas PropertiesSANTOS WELL TEST LEAD:Jack Landry / Pere KeniyeLOCATION / FIELD:PIKKA - NDB SANTOS REP/SUPERVISORS:Jose Gonzalez / Dan BonnarWELL NUMBER:NDBi-049EXPRO SUPERVISORS :CLIENT:Santos PROJECT DESIGN NUMBER:WT-XAK-0127.5NDBi-049 WELL CLEAN-UP DATA SHEETVictor Chavez | Jose Reynoso29-April-2025 @ 10:00EXPRO DAQ ENGINEERS:Travis Stacey | Yehia ElzenyWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 20 START DATE:END DATE:TimeDPIGORFrac 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)Separator Inlet 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)(F)(psig) (psig) (psig)(F)(psig)(F)(psig)(F)(64ths) (%) (psig) (psig)(F) (F)(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)BS&W Properties Gas Rates & CumulativesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Chemical Injection Rates5-May-2025 @ 02:00Well Head ChokeSeparator Fluid Properties Gas PropertiesSANTOS WELL TEST LEAD:Jack Landry / Pere KeniyeLOCATION / FIELD:PIKKA - NDB SANTOS REP/SUPERVISORS:Jose Gonzalez / Dan BonnarWELL NUMBER:NDBi-049EXPRO SUPERVISORS :CLIENT:Santos PROJECT DESIGN NUMBER:WT-XAK-0127.5NDBi-049 WELL CLEAN-UP DATA SHEETVictor Chavez | Jose Reynoso29-April-2025 @ 10:00EXPRO DAQ ENGINEERS:Travis Stacey | Yehia Elzeny04-30-2025 19:001442.44 96.43 744.31 37.79 312.30 57.35 190.62 57.83 184.41 66.04 128 0.00 97.18 94.65 60.69 59.94 30.3 35000 8 0.694 0.10 0.0 28.00 0.00 28.00 28.00 0.0000 1.2384 0.0000 1.2930 422.02 0.00 1.92 2934.49 3600.87 1141.19 1238.72 4075.68 4839.58 0.00 1.89 3079.35 3589.88 1081.93 1177.12 4161.29 4768.896.62 8.0 0.0 8.0 0.004-30-2025 19:301442.63 96.41 744.51 38.03 310.65 58.71 191.71 57.86 185.04 65.54 128 0.00 101.06 98.13 60.83 60.29 30.3 35000 8 0.694 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 1.2576 0.0000 1.3192 416.04 0.00 1.92 3022.75 3663.85 1062.05 1260.84 4084.80 4924.68 0.00 1.89 3245.80 3657.50 915.48 1196.20 4161.29 4855.596.74 8.0 0.0 8.0 0.004-30-2025 20:001439.90 96.40 744.27 37.87 312.26 57.04 192.43 56.76 186.18 65.15 128 0.00 99.49 97.47 60.94 60.77 30.3 31000 8 0.694 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.2624 0.0000 1.3455 397.29 0.00 1.92 3177.53 3730.05 896.23 1279.51 4073.76 5009.55 0.00 1.89 3245.80 3725.12 915.48 1215.27 4161.29 4942.28 6.84 8.0 0.0 8.0 0.004-30-2025 20:301439.00 96.40 744.69 38.89 315.17 56.73 192.53 55.94 187.70 64.86 128 0.00 101.23 99.34 60.69 60.58 30.3 31000 8 0.694 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.2768 0.0000 1.3721 397.42 0.00 1.92 3212.73 3796.98 906.15 1298.39 4118.88 5095.36 0.00 1.89 3357.98 3795.08 839.49 1232.76 4197.47 5029.73 6.94 8.0 0.0 8.0 0.004-30-2025 21:00Collected Tracerco Dye Water Sample.1438.03 96.40 742.60 38.61 316.61 55.39 194.82 53.96 187.96 64.35 128 0.00 103.62 99.88 60.88 60.58 30.3 30000 8 0.694 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.2864 0.0000 1.3989 389.63 0.00 1.92 3301.63 3865.76 825.41 1315.59 4127.04 5181.34 0.00 1.89 3441.93 3866.78 755.54 1248.50 4197.47 5117.17 7.04 8.0 0.0 8.0 0.004-30-2025 21:301436.75 96.39 743.06 39.07 318.81 54.60 196.89 53.13 189.58 63.88 128 0.00 102.70 99.87 60.43 60.20 30.3 30000 8 0.694 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.2912 0.0000 1.4258 379.82 0.00 1.92 3399.52 3936.59 746.24 1331.13 4145.76 5267.71 0.00 1.89 3609.82 3941.99 587.65 1260.74 4197.47 5204.62 7.12 8.0 0.0 8.0 0.004-30-2025 22:001434.84 96.37 741.88 39.65 318.66 56.62 196.67 53.42 189.28 63.69 128 0.00 104.43 100.53 60.69 60.15 30.3 30000 8 0.694 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3056 0.0000 1.4530 367.04 0.00 1.92 3557.10 4010.69 579.06 1343.20 4136.16 5353.88 0.00 1.89 3578.71 4016.54 582.58 1272.88 4161.29 5291.327.18 8.0 0.0 8.0 0.004-30-2025 22:301434.05 96.36 741.74 38.79 318.30 56.06 196.41 51.76 190.46 62.87 128 0.00 104.59 101.61 60.16 59.96 30.3 30000 8 0.694 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3248 0.0000 1.4806 369.61 0.00 1.92 3584.34 4085.37 583.50 1355.35 4167.84 5440.71 0.00 1.89 3471.60 4088.87 762.06 1288.76 4233.66 5379.527.25 8.0 0.0 8.0 0.004-30-2025 23:001431.88 96.36 740.75 37.52 318.06 56.98 195.95 51.19 188.10 62.68 128 0.00 102.61 100.14 60.11 59.66 30.3 30000 8 0.694 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.3296 0.0000 1.5083 390.62 0.00 1.92 3403.85 4156.28 747.19 1370.92 4151.04 5527.19 0.00 1.89 3495.48 4161.69 665.81 1302.63 4161.29 5466.217.33 8.0 0.0 8.0 0.004-30-2025 23:301431.19 96.36 740.17 39.51 318.44 58.28 197.98 51.30 190.44 62.11 128 0.00 104.63 100.97 59.82 59.45 30.3 30000 8 0.694 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.3296 0.0000 1.5360 379.95 0.00 1.92 3499.37 4229.18 666.55 1384.81 4165.92 5613.98 0.00 1.89 3640.94 4237.54 592.71 1314.97 4233.66 5554.417.41 8.0 0.0 8.0 0.005-01-2025 00:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.1430.19 96.34 740.07 38.57 321.03 59.05 197.72 51.14 190.95 62.16 128 0.00 104.92 102.83 59.87 59.07 30.3 31000 8 0.694 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3248 0.0000 1.5636 370.29 0.00 1.92 3577.74 4303.72 582.42 1396.94 4160.16 5700.65 0.00 1.89 3609.82 4312.75 587.65 1327.22 4197.47 5641.867.47 8.0 0.0 8.0 0.005-01-2025 00:301429.77 96.34 739.27 39.29 321.88 58.86 197.72 51.88 192.11 62.57 128 0.00 104.55 101.77 59.81 59.22 30.3 31000 8 0.682 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3536 0.0000 1.5918 377.25 0.00 1.92 3588.06 4378.47 584.10 1409.11 4172.16 5787.57 0.00 1.89 3725.62 4390.37 508.04 1337.80 4233.66 5730.067.54 8.0 0.0 8.0 0.005-01-2025 01:001428.17 96.34 738.82 38.21 317.10 57.47 195.91 52.22 188.82 62.96 128 0.00 103.78 100.71 59.36 58.82 30.3 31000 8 0.682 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.3728 0.0000 1.6204 374.94 0.00 1.92 3661.36 4454.75 499.28 1419.51 4160.64 5874.25 0.00 1.89 3693.77 4467.32 503.70 1348.29 4197.47 5817.517.59 8.0 0.0 8.0 0.005-01-2025 01:301427.43 96.33 738.20 39.51 318.40 57.35 198.62 52.28 190.80 63.20 128 0.00 105.00 101.78 59.79 59.06 30.3 31000 8 0.682 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.3536 0.0000 1.6486 368.51 0.00 1.92 3673.19 4531.27 500.89 1429.95 4174.08 5961.21 0.00 1.89 3578.71 4541.88 582.58 1360.43 4161.29 5904.207.65 8.0 0.0 8.0 0.005-01-2025 02:001425.68 96.34 737.26 39.17 318.26 57.25 197.56 52.64 189.83 62.56 128 0.00 105.19 100.72 59.28 58.92 30.3 31000 8 0.682 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3680 0.0000 1.6771 381.09 0.00 1.92 3589.71 4606.06 584.37 1442.12 4174.08 6048.17 0.00 1.89 3609.82 4617.08 587.65 1372.67 4197.47 5991.657.71 8.0 0.0 8.0 0.005-01-2025 02:301425.17 96.32 737.24 39.19 321.06 57.29 197.70 51.71 190.72 62.43 128 0.00 105.64 102.60 59.58 58.84 30.3 31000 8 0.682 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.3632 0.0000 1.7055 380.15 0.00 1.92 3585.99 4680.77 583.77 1454.28 4169.76 6135.04 0.00 1.89 3777.72 4695.78 419.75 1381.42 4197.47 6079.097.78 8.0 0.0 8.0 0.005-01-2025 03:00Collected Tracerco Dye Water Sample.1423.99 96.32 737.22 39.09 321.80 56.66 201.05 52.56 193.39 62.79 128 0.00 106.84 103.81 59.69 58.87 30.3 31000 8 0.682 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.3680 0.0000 1.7340 364.49 0.00 1.92 3753.22 4758.96 417.02 1462.97 4170.24 6221.92 0.00 1.89 3725.62 4773.40 508.04 1392.00 4233.66 6167.307.82 8.0 0.0 8.0 0.005-01-2025 03:301422.99 96.32 737.80 39.47 321.22 57.32 192.67 52.73 184.76 62.46 128 0.00 91.75 88.06 58.81 58.60 30.3 31000 8 0.682 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.3968 0.0000 1.7631 375.60 0.00 1.92 3718.81 4836.43 507.11 1473.54 4225.92 6309.96 0.00 1.89 3861.67 4853.85 335.80 1399.00 4197.47 6254.74 7.88 8.0 0.0 8.0 0.005-01-2025 04:001420.93 96.33 737.12 38.87 318.00 59.04 191.91 52.29 183.45 62.59 128 0.00 90.99 87.13 58.94 58.41 30.3 31000 8 0.682 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.4208 0.0000 1.7927 366.15 0.00 1.92 3880.34 4917.28 337.42 1480.56 4217.76 6397.83 0.00 1.89 3894.96 4935.00 338.69 1406.06 4233.66 6342.94 7.92 8.0 0.0 8.0 0.005-01-2025 04:301418.89 96.33 737.52 39.43 318.56 57.44 188.01 52.08 179.77 62.37 128 0.00 84.04 78.20 58.65 58.64 30.3 32000 8 0.682 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.4544 0.0000 1.8230 372.82 0.00 1.92 3901.09 4998.55 339.23 1487.63 4240.32 6486.17 0.00 1.89 3842.86 5015.06 426.98 1414.95 4269.84 6431.90 7.96 8.0 0.0 8.0 0.005-01-2025 05:001418.53 96.33 738.10 39.09 318.06 58.52 185.02 52.03 177.69 62.22 128 0.00 81.26 75.93 58.12 57.47 30.3 32000 8 0.682 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.4640 0.0000 1.8535 378.77 0.00 1.92 3865.10 5079.07 429.46 1496.58 4294.56 6575.64 0.00 1.89 3928.25 5096.90 341.59 1422.07 4269.84 6520.85 8.00 8.0 0.0 8.0 0.005-01-2025 05:301597.58 96.98 771.35 39.43 385.95 59.96 228.93 53.69 217.83 65.07 128 0.00 101.96 95.55 59.98 58.53 30.3 32000 8 0.682 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.5408 0.0000 1.8856 342.98 0.00 1.92 4492.40 5172.66 390.64 1504.72 4883.04 6677.37 0.00 1.89 4494.19 5190.52 390.80 1430.21 4884.99 6622.62 8.058.00.08.00.005-01-2025 06:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.06:15 Observed Well Slugging.1613.39 96.74 814.29 40.36 201.54 60.17 123.40 54.22 118.96 66.29 128 0.00 90.66 90.35 60.44 59.41 30.3 32000 8 0.682 0.10 0.0 8.00 0.00 8.00 8.00 0.00001.4448 0.0000 1.9157 345.92 0.00 1.92 4176.65 5259.68 363.19 1512.28 4539.84 6771.95 0.00 1.89 4038.26 5274.65 448.70 1439.56 4486.95 6716.10 8.09 8.0 0.0 8.0 0.005-01-2025 06:301615.21 96.68 844.91 41.76 238.10 62.09 140.22 57.39 131.69 68.51 128 0.00 83.99 83.82 63.10 63.06 30.3 32000 8 0.682 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 0.8112 0.0000 1.9326 210.70 0.00 1.92 3849.98 5339.88 427.78 1521.20 4277.76 6861.07 0.00 1.89 2370.85 5324.05 1862.81 1478.37 4233.66 6804.30 8.14 8.0 0.0 8.0 0.005-01-2025 07:0007:20 Observed Well Slugging.1623.96 96.61 874.38 43.63 220.72 64.72 131.94 58.75 121.97 69.26 128 0.00 79.69 80.34 63.66 63.20 30.3 32000 8 0.682 0.10 0.0 44.00 0.00 44.00 44.00 0.0000 0.4032 0.0000 1.9410 202.98 0.00 1.92 1986.43 5381.27 1560.77 1553.71 3547.20 6934.97 0.00 1.89 2485.19 5375.82 1169.50 1502.73 3654.69 6880.448.31 8.0 0.0 8.0 0.005-01-2025 07:3007:34 Diverted Gas Flow from 3'' Coriolis Meter through 0.5'' Coriolis Meter.07:49 Lowered Separator Pressure.1626.60 96.57 893.55 44.55 200.95 65.44 114.14 59.25 108.69 69.40 128 0.00 72.18 71.86 64.51 63.98 30.3 32000 8 0.682 0.10 0.0 32.00 0.00 32.00 32.00 0.0000 0.0720 0.0000 1.9425 32.09 0.00 1.92 2243.67 5428.01 1055.85 1575.71 3299.52 7003.71 0.00 1.89 2304.99 5423.84 987.85 1523.31 3292.84 6949.04 8.43 8.0 0.0 8.0 0.005-01-2025 08:001625.72 96.54 908.34 45.74 180.20 66.00 108.57 60.00 103.20 70.44 128 0.00 72.66 73.13 62.70 64.36 30.3 32000 8 0.682 0.10 0.0 30.00 0.00 30.00 30.00 0.0000 0.2928 0.0000 1.9486 128.40 0.00 1.92 2280.43 5475.52 977.33 1596.07 3257.76 7071.58 0.00 1.89 865.55 5441.87 2463.48 1574.63 3329.03 7018.40 8.54 8.0 0.0 8.0 0.005-01-2025 08:301629.40 96.51 920.41 46.40 169.09 66.11 106.42 60.01 101.66 70.65 128 0.00 71.41 70.94 60.27 64.61 30.3 32000 8 0.682 0.10 0.0 74.00 0.00 74.00 74.00 0.0000 0.2976 0.0000 1.9548 377.49 0.00 1.92 788.36 5491.94 2243.80 1642.82 3032.16 7134.75 0.00 1.89 746.86 5457.43 2365.06 1623.90 3111.92 7083.23 8.79 8.0 0.0 8.0 0.005-01-2025 09:00Collected Tracerco Dye Water Sample.1627.81 96.50 930.26 47.16 182.27 66.56 109.23 61.08 102.50 72.26 128 0.00 68.85 68.93 58.35 65.12 30.3 32000 8 0.682 0.10 0.0 76.00 0.00 76.00 76.00 0.0000 0.2736 0.0000 1.9605 372.14 0.00 1.92 735.21 5507.26 2328.15 1691.32 3063.36 7198.57 0.00 1.89 955.29 5477.34 2229.00 1670.34 3184.29 7149.57 9.04 8.0 0.0 8.0 0.005-01-2025 09:301625.87 96.49 938.08 48.03 180.56 65.43 112.71 61.32 109.58 72.56 128 0.00 74.05 74.27 57.47 65.39 30.3 32000 8 0.682 0.10 0.0 70.00 0.00 70.00 70.00 0.0000 0.3024 0.0000 1.9668 317.89 0.00 1.92 951.26 5527.08 2219.62 1737.56 3170.88 7264.63 0.00 1.89 665.81 5491.21 2663.22 1725.83 3329.03 7218.93 9.29 8.0 0.0 8.0 0.005-01-2025 10:001626.75 96.48 945.09 48.81 183.23 65.75 106.82 60.77 98.99 73.13 128 0.00 69.06 70.26 57.34 65.77 30.1 32000 8 0.682 0.10 0.0 80.00 0.00 80.00 80.00 0.0000 0.2880 0.0000 1.9728 469.19 0.00 1.92 613.82 5539.87 2455.30 1788.71 3069.12 7328.57 0.00 1.89 651.33 5504.78 2605.33 1780.10 3256.66 7286.77 9.578.0 0.0 8.0 0.005-01-2025 10:301625.55 96.48 950.53 49.55 185.91 66.18 111.87 61.28 105.67 73.59 128 0.00 69.30 69.85 57.87 66.15 30.1 32000 8 0.682 0.10 0.0 80.00 0.00 80.00 80.00 0.0000 0.3072 0.0000 1.9792 487.66 0.00 1.92 629.95 5552.99 2519.81 1841.21 3149.76 7394.19 0.00 1.89 683.90 5519.02 2572.76 1833.70 3256.66 7354.62 9.85 8.0 0.0 8.0 0.005-01-2025 11:001622.51 96.48 955.80 49.84 191.29 66.63 115.60 61.51 110.57 73.55 128 0.00 71.66 71.19 58.62 66.66 30.1 31000 8 0.682 0.10 0.0 79.00 0.00 79.00 79.00 0.0000 0.3072 0.0000 1.9856 453.58 0.00 1.92 677.28 5567.10 2547.84 1894.29 3225.12 7461.38 0.00 1.89 665.81 5532.90 2663.22 1889.19 3329.03 7423.97 10.13 8.0 0.0 8.0 0.005-01-2025 11:301625.73 96.47 961.24 50.86 187.01 66.74 109.64 61.20 103.51 73.79 128 0.00 69.26 69.29 59.12 66.58 30.1 31000 8 0.682 0.10 0.0 80.00 0.00 80.00 80.00 0.0000 0.3216 0.0000 1.9923 524.83 0.00 1.92 612.77 5579.87 2451.07 1945.35 3063.84 7525.21 0.00 1.89 692.58 5547.32 2455.52 1940.34 3148.10 7489.56 10.40 8.0 0.0 8.0 0.005-01-2025 12:00Collected Tracerco Dye Water Sample. Kit #2 Complete.Collected Tracerco Standard Sample.1623.55 96.48 962.73 51.54 203.53 66.31 122.62 61.38 115.86 74.80 128 0.00 77.48 77.04 59.12 66.40 30.1 31000 8 0.682 0.10 0.0 78.00 0.00 78.00 78.00 0.0000 0.3168 0.0000 1.9989 435.73 0.00 1.92 727.06 5595.01 2577.74 1999.06 3304.80 7594.06 0.00 1.89 825.02 5564.51 2612.56 1994.77 3437.58 7561.18 10.69 8.0 0.0 8.0 0.005-01-2025 12:3012:31 Bypassed Expro Ball Catcher.1621.79 96.47 969.80 51.94 200.67 66.24 130.86 61.55 122.25 76.10 128 0.00 82.65 81.61 59.25 66.64 30.1 31000 8 0.685 0.10 0.0 76.00 0.00 76.00 76.00 0.0000 0.3552 0.0000 2.0063 449.66 0.00 1.92 789.93 5611.47 2501.43 2051.17 3291.36 7662.63 0.00 1.89 1020.42 5585.77 2380.98 2044.38 3401.40 7632.04 10.97 8.0 0.0 8.0 0.005-01-2025 13:001620.20 96.49 975.57 52.41 225.85 67.38 147.38 62.21 140.31 76.86 128 0.00 92.34 93.04 59.79 67.01 30.1 31000 8 0.685 0.10 0.0 70.00 0.00 70.00 70.00 0.0000 0.3744 0.0000 2.0141 350.55 0.00 1.92 1068.05 5633.72 2492.11 2103.09 3560.16 7736.80 0.00 1.89 1096.41 5608.61 2558.29 2097.67 3654.69 7708.1811.25 8.0 0.0 8.0 0.005-01-2025 13:3013:40 Configured DPI Unit into Parallel Flow.13:47 Diverted Gas Flow from 0.5'' Coriolis Meter through 3 '' Coriolis Meter.13:49 Lowered Separator Pressure.1616.46 96.49 978.04 53.55 236.75 67.41 156.44 63.36 148.77 76.41 128 0.00 101.66 102.11 60.32 67.18 30.1 31000 8 0.685 0.10 0.0 70.00 0.00 70.00 70.00 0.0000 0.4176 0.0000 2.0228 386.31 0.00 1.92 1081.01 5656.24 2522.35 2155.64 3603.36 7811.87 0.00 1.89 1328.72 5636.29 2362.16 2146.88 3690.88 7785.07 11.53 8.0 0.0 8.0 0.005-01-2025 14:0014:02 Observed Well Slugging.1609.64 96.53 988.06 53.61 224.36 67.83 169.93 65.12 164.37 76.36 128 0.00 84.46 82.08 68.12 67.50 30.1 31000 8 0.685 0.10 0.0 64.00 0.00 64.00 64.00 0.0000 0.4704 0.0000 2.0326 316.39 0.00 1.92 1486.77 5687.22 2643.15 2210.70 4129.92 7897.91 0.00 1.89 1650.04 5670.67 2475.06 2198.45 4125.10 7871.0111.82 8.0 0.0 8.0 0.005-01-2025 14:3014:41 Observed Well Slugging.1605.22 96.52 1006.45 54.31 238.28 67.59 170.71 63.88 154.92 76.35 128 0.00 76.06 73.55 69.69 68.25 30.1 31000 8 0.685 0.10 0.0 60.00 0.00 60.00 60.00 0.0000 0.6720 0.0000 2.0466 396.15 0.00 1.92 1696.32 5722.56 2544.48 2263.71 4240.80 7986.26 0.00 1.89 1280.95 5697.36 2988.89 2260.72 4269.84 7959.97 12.11 8.0 0.0 8.0 0.005-01-2025 15:00Collected Tracerco Dye Water Sample. 15:20 Increased Defoamer Injection rate to 11 gal/day.1601.75 96.53 1015.11 55.10 257.83 67.24 185.72 63.91 164.13 76.26 128 0.00 73.83 71.68 70.23 68.57 30.1 31000 8 0.685 0.10 0.0 70.00 0.00 70.00 70.00 0.0000 0.5904 0.0000 2.0589 429.90 0.00 1.92 1373.33 5751.17 3204.43 2330.47 4577.76 8081.63 0.00 1.89 2223.21 5743.67 2408.48 2310.89 4631.69 8056.46 12.46 8.0 0.0 8.0 0.005-01-2025 15:301602.39 96.52 1023.99 55.10 250.80 67.33 180.58 64.27 166.48 76.54 128 0.00 94.75 92.57 70.74 68.83 30.1 31000 8 0.685 0.10 0.0 52.00 0.00 52.00 52.00 0.0000 0.6624 0.0000 2.0727 294.45 0.00 1.92 2249.63 5798.04 2437.09 2381.24 4686.72 8179.27 0.00 1.89 1680.44 5778.68 2987.44 2373.13 4667.88 8153.71 12.73 11.0 0.0 8.0 0.005-01-2025 16:0016:09 Lowered Separator Level.1602.15 96.52 1031.10 56.20 247.20 67.43 167.49 64.57 161.71 76.50 128 0.00 89.16 86.65 70.71 68.86 30.1 32000 8 0.685 0.10 0.0 64.00 0.00 64.00 64.00 0.0000 0.8304 0.0000 2.0900 502.99 0.00 1.92 1650.93 5832.43 2934.99 2442.39 4585.92 8274.81 0.00 1.89 1958.34 5819.48 2492.43 2425.06 4450.77 8246.43 13.06 11.0 0.0 8.0 0.005-01-2025 16:301601.07 96.53 1037.89 57.37 247.52 67.20 175.73 64.68 163.15 76.92 128 0.00 89.56 87.72 70.98 68.94 30.1 32000 8 0.685 0.10 0.0 56.00 0.00 56.00 56.00 0.0000 0.8640 0.0000 2.1080 395.26 0.00 1.92 2185.92 5877.97 2782.08 2500.35 4968.00 8378.31 0.00 1.89 2388.22 5869.24 2388.22 2474.81 4776.43 8345.94 13.37 11.0 0.0 8.0 0.005-01-2025 17:00Applied CMSF 0.858.1599.73 96.52 1042.31 58.53 257.37 68.29 180.44 65.52 171.73 77.11 128 0.00 91.70 89.32 71.14 69.26 30.1 32000 8 0.688 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 0.8736 0.0000 2.1262 344.73 0.00 1.92 2534.16 5930.77 2534.16 2553.15 5068.32 8483.90 0.00 1.89 2388.22 5918.99 2388.22 2524.57 4776.43 8445.45 13.65 11.0 0.0 8.0 0.005-01-2025 17:301599.39 96.51 1044.02 58.67 270.39 67.94 189.02 64.74 181.42 76.76 128 0.00 93.64 90.50 71.24 69.02 30.1 32000 8 0.688 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 0.9120 0.0000 2.1452 358.36 0.00 1.92 2544.96 5983.79 2544.96 2606.17 5089.92 8589.94 0.00 1.89 2496.77 5971.01 2496.77 2576.58 4993.54 8549.48 13.94 11.0 0.0 8.0 0.005-01-2025 18:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.Applied CMSF 0.736 to compensate for erroneous Liquid Rates.18:06 Observed higher than expected Liquid Rates due to possible Gas Carry out the Liquid Line. Increased Separator Liquid Level.1599.82 96.51 1046.65 58.37 267.11 67.32 188.07 66.24 179.62 76.77 128 0.00 92.34 89.30 71.16 69.10 30.1 32000 8 0.688 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 0.9072 0.0000 2.1641 370.19 0.00 1.92 2450.64 6034.84 2450.64 2657.22 4901.28 8692.05 0.00 1.89 2540.19 6023.93 2163.87 2621.66 4704.06 8647.48 14.21 11.0 0.0 8.0 0.005-01-2025 18:30Re-Applied CMSF 0.858.1599.17 96.51 1046.39 58.99 264.98 66.18 186.28 68.20 178.61 76.87 128 0.00 93.55 91.57 71.21 68.75 30.1 32000 8 0.688 0.10 0.0 46.00 0.00 46.00 46.00 0.0000 0.9648 0.0000 2.1842 381.65 0.00 1.92 2527.98 6087.51 2153.46 2702.08 4681.44 8789.58 0.00 1.89 2370.85 6073.32 2188.47 2667.26 4559.32 8742.47 14.45 11.0 0.0 8.0 0.005-01-2025 19:0019:10 Increased Separator Pressure.1597.20 96.52 1046.49 58.97 272.38 67.84 187.23 68.38 179.14 76.76 128 0.00 91.58 88.78 71.13 70.27 30.1 24000 8 0.688 0.10 0.0 48.00 0.00 48.00 48.00 0.0000 0.9024 0.0000 2.2030 357.78 0.00 1.92 2522.21 6140.05 2328.19 2750.59 4850.40 8890.63 0.00 1.89 2388.22 6123.07 2388.22 2717.01 4776.43 8841.98 14.71 11.0 0.0 8.0 0.005-01-2025 19:301598.58 96.50 1046.85 59.38 270.77 68.81 187.67 68.11 180.23 76.03 128 0.00 96.38 93.72 71.56 70.80 30.1 24000 8 0.688 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 1.2000 0.0000 2.2280 487.14 0.00 1.92 2463.36 6191.37 2463.36 2801.91 4926.72 8993.27 0.00 1.89 2406.31 6173.21 2406.31 2767.14 4812.62 8942.24 14.98 11.0 0.0 8.0 0.005-01-2025 20:0020:10 Sparged Separator. Light Solids Observed.20:20 Increased Separator Pressure.1597.52 96.50 1046.37 58.73 275.59 68.65 192.21 67.47 185.21 76.23 128 0.00 98.95 96.12 71.43 71.04 30.1 22000 8 0.688 0.10 0.0 50.00 0.00 50.00 50.00 0.0000 1.0080 0.0000 2.2490 413.30 0.00 1.92 2438.88 6242.18 2438.88 2852.72 4877.76 9094.89 0.00 1.89 2579.27 6226.94 2197.16 2812.92 4776.43 9041.75 15.26 11.0 0.0 8.0 0.005-01-2025 20:30Increased Defoamer Injection rate to 15 gal/day.Observed Well Slugging.1599.23 96.49 1044.46 58.71 286.90 66.82 203.61 67.37 197.54 75.97 128 0.00 111.65 109.75 71.37 69.22 30.1 22000 8 0.688 0.10 0.0 46.00 0.00 46.00 46.000.0000 1.0080 0.0000 2.2700 386.15 0.00 1.92 2610.40 6296.57 2223.68 2899.04 4834.08 9195.60 0.00 1.89 2559.73 6280.27 2180.51 2858.34 4740.25 9140.50 15.50 15.0 0.0 8.0 0.005-01-2025 21:00Collected Tracerco Dye Water Sample.Applied CMSF 0.657 from 21:00 to 21:30 to correct erroneous Liquid Rates caused by the Well Slugging.1597.40 96.49 1038.60 59.96 290.16 66.04 207.51 65.23 200.62 75.37 128 0.00 113.01 110.30 70.83 68.68 30.1 22000 8 0.688 0.10 0.0 46.00 0.00 46.00 46.000.0000 2.1984 0.0000 2.3158 877.36 0.00 1.92 2505.69 6348.77 2134.47 2943.51 4640.16 9292.27 0.00 1.89 2431.64 6330.93 1910.57 2898.15 4342.21 9230.97 15.74 15.0 0.0 8.0 0.005-01-2025 21:30Applied CMSF 0.826.1599.95 96.48 1034.26 59.32 296.54 67.44 209.60 64.15 202.02 74.61 128 0.00 112.78 109.77 70.42 68.11 30.1 22000 8 0.688 0.10 0.0 44.00 0.00 44.00 44.000.0000 1.0560 0.0000 2.3378 404.34 0.00 1.92 2611.66 6403.18 2052.02 2986.26 4663.68 9389.43 0.00 1.89 2800.73 6389.28 1867.15 2937.05 4667.88 9328.21 15.97 15.0 0.0 8.0 0.005-01-2025 22:001598.03 96.45 1028.45 58.71 289.79 64.97 213.41 62.66 206.44 73.77 128 0.00 117.49 114.19 70.29 68.88 30.1 23000 8 0.688 0.10 0.0 40.00 0.00 40.00 40.000.0000 1.2912 0.0000 2.3647 487.85 0.00 1.92 2646.72 6458.32 1764.48 3023.02 4411.20 9481.33 0.00 1.89 2431.64 6439.93 1910.57 2976.85 4342.21 9418.68 16.17 15.0 0.0 8.0 0.005-01-2025 22:301598.43 96.45 1029.67 58.93 275.83 64.15 189.60 62.82 182.09 73.66 128 0.00 111.42 109.81 70.60 69.35 30.1 23000 8 0.688 0.10 0.0 44.00 0.00 44.00 44.000.0000 1.2096 0.0000 2.3899 467.48 0.00 1.92 2587.47 6512.22 2033.01 3065.38 4620.48 9577.59 0.00 1.89 2800.73 6498.28 1867.15 3015.75 4667.88 9515.92 16.39 15.0 0.0 8.0 0.005-01-2025 23:001600.62 96.43 1024.93 58.81 308.70 64.84 223.08 64.10 214.92 74.61 128 0.00 120.47 117.40 70.29 69.46 30.1 23000 8 0.688 0.10 0.0 40.00 0.00 40.00 40.000.0000 0.9072 0.0000 2.4088 336.36 0.00 1.92 2697.12 6568.41 1798.08 3102.84 4495.20 9671.24 0.00 1.89 3618.51 6573.67 904.63 3034.60 4523.14 9610.16 16.59 15.0 0.0 8.0 0.005-01-2025 23:3023:45 Increased Separator Pressure.1601.30 96.43 1019.19 58.97 265.42 66.93 190.97 62.34 185.25 73.53 128 0.00 114.07 113.00 70.05 69.49 30.1 23000 8 0.688 0.10 0.0 20.00 0.00 20.00 20.000.0000 1.1184 0.0000 2.4321 307.62 0.00 1.92 3635.71 6644.16 908.93 3121.77 4544.64 9765.92 0.00 1.89 2800.73 6632.02 1867.15 3073.49 4667.88 9707.40 16.69 15.0 0.0 8.0 0.005-02-2025 00:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.1595.57 96.46 1017.68 58.35 301.77 63.81 215.10 63.25 208.39 73.77 128 0.00 128.97 126.90 70.02 69.81 30.1 23000 8 0.688 0.10 0.0 40.00 0.00 40.00 39.950.0000 1.9008 0.0000 2.4717 818.45 0.00 1.92 2322.43 6692.54 1548.29 3154.03 3870.72 9846.56 1.97 1.93 2285.65 6679.64 1656.55 3108.01 3944.17 9789.57 16.87 15.0 0.0 8.0 0.005-02-2025 00:30Applied CMSF 0.657 from 00:30 to 01:00 to correct erroneous Liquid Rates caused by Slugging Well. 1598.66 96.38 1015.51 58.03 268.66 62.14 190.74 62.57 188.45 73.51 128 0.00 120.78 119.27 69.65 68.98 30.1 23000 8 0.688 0.10 0.0 42.05 0.05 42.00 42.000.0000 1.6512 0.0000 2.5061 627.56 2.27 1.97 2631.16 6747.36 1905.32 3193.72 4536.48 9941.07 0.00 1.93 2644.41 6734.77 1914.91 3147.90 4559.32 9884.56 17.08 15.0 0.0 8.0 0.005-02-2025 01:00Re-Applied CMSF 0.826.1589.05 96.46 1015.51 58.55 314.83 62.53 221.05 62.83 213.45 73.49 128 0.00 125.22 121.95 69.94 68.09 30.1 23000 8 0.688 0.10 0.0 42.00 0.00 42.00 42.000.0000 1.0272 0.0000 2.5275 354.06 0.00 1.97 2901.21 6807.80 2100.87 3237.49 5002.08 10045.28 0.00 1.93 2887.57 6794.93 1925.05 3188.00 4812.62 9984.82 17.31 15.0 0.0 8.0 0.005-02-2025 01:301596.29 96.47 1015.21 58.77 300.94 63.32 214.24 62.31 209.64 72.96 128 0.00 127.95 124.00 70.02 68.33 30.1 23000 8 0.688 0.10 0.0 40.00 0.00 40.00 40.000.0000 1.1712 0.0000 2.5519 434.75 0.00 1.97 2693.95 6863.92 1795.97 3274.91 4489.92 10138.82 0.00 1.93 2938.95 6856.15 1801.29 3225.53 4740.25 10083.58 17.51 15.0 0.0 8.0 0.005-02-2025 02:00Applied CMSF 0.685 from 02:00 to 03:30 to correct erroneous Liquid Rates caused by the Well Slugging.1594.74 96.49 1009.04 57.39 302.77 60.33 218.56 60.17 210.60 71.44 128 0.00 124.41 122.01 69.25 66.98 32.0 22000 8 0.672 0.10 0.0 38.00 0.00 38.00 38.000.0000 1.2288 0.0000 2.5775 415.15 0.00 1.97 2959.93 6925.59 1814.15 3312.70 4774.08 10238.28 0.00 1.93 2644.41 6911.20 1914.91 3265.43 4559.32 10178.56 17.72 15.0 0.0 8.0 0.005-02-2025 02:301589.24 96.47 1006.51 58.63 295.78 61.87 209.84 60.56 204.45 71.71 128 0.00 121.09 118.66 69.23 67.99 32.0 22000 8 0.672 0.10 0.0 42.00 0.00 42.00 42.000.0000 0.9984 0.0000 2.5983 383.80 0.00 1.97 2601.37 6979.78 1883.75 3351.95 4485.12 10331.72 0.00 1.93 3584.49 6985.88 1011.01 3286.49 4595.51 10274.30 17.93 15.0 0.0 8.0 0.005-02-2025 03:00Collected Tracerco Dye Water Sample.1595.24 96.47 1003.98 57.71 287.02 61.46 203.04 60.29 196.94 71.39 128 0.00 119.19 117.61 68.27 67.88 32.0 22000 8 0.672 0.10 0.0 22.00 0.00 22.00 22.000.0000 1.2336 0.0000 2.6240 357.90 0.00 1.97 3446.73 7051.59 972.15 3372.20 4418.88 10423.78 0.00 1.93 3149.55 7051.50 1482.14 3317.37 4631.69 10370.80 18.03 15.0 0.0 8.0 0.005-02-2025 03:30Re-Applied CMSF 0.826.1585.41 96.44 1003.80 55.72 324.13 62.20 225.57 60.92 219.83 72.23 128 0.00 132.46 129.49 69.36 68.31 32.0 22000 8 0.672 0.10 0.0 32.00 0.00 32.00 32.000.0000 1.6752 0.0000 2.6589 547.98 0.00 1.97 3057.06 7115.28 1438.62 3402.17 4495.68 10517.44 0.00 1.93 3256.66 7119.34 1266.48 3343.75 4523.14 10465.03 18.19 15.0 0.0 8.0 0.005-02-2025 04:001596.40 96.42 1004.92 56.76 297.61 62.01 223.16 60.87 205.28 71.61 128 0.00 126.48 124.16 68.48 67.93 32.0 23000 8 0.672 0.10 0.0 28.00 0.00 28.00 28.000.0000 1.2576 0.0000 2.6851 367.68 0.00 1.97 3420.40 7186.54 1330.16 3429.88 4750.56 10616.41 0.00 1.93 3176.33 7185.52 1636.29 3377.84 4812.62 10565.29 18.34 15.0 0.0 8.0 0.005-02-2025 04:301586.36 96.46 996.36 56.85 338.43 61.89 238.84 60.59 231.88 71.42 128 0.00 130.37 126.47 69.42 68.38 32.0 23000 8 0.672 0.10 0.0 34.00 0.00 34.00 34.00 0.0000 1.2672 0.0000 2.7115 401.73 0.00 1.97 3154.38 7252.25 1624.98 3463.74 4779.36 10715.98 0.00 1.93 3534.56 7259.15 1241.87 3403.71 4776.43 10664.80 18.52 15.0 0.0 8.0 0.005-02-2025 05:001593.71 96.45 995.72 55.52 293.87 60.60 213.96 59.02 206.37 70.58 128 0.00 131.98 129.76 68.77 68.06 32.0 22000 8 0.672 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 1.2816 0.0000 2.7382 406.68 0.00 1.97 3151.33 7317.91 1107.23 3486.80 4258.56 10804.70 0.00 1.93 3242.18 7326.70 1389.51 3432.66 4631.69 10761.29 18.65 15.0 0.0 8.0 0.005-02-2025 05:301588.73 96.44 995.78 56.50 329.53 61.94 227.40 60.41 218.93 71.41 128 0.00 129.08 126.57 69.05 67.98 32.0 22000 8 0.672 0.10 0.0 30.00 0.00 30.00 30.00 0.0000 1.2336 0.0000 2.7639 361.33 0.00 1.97 3414.10 7389.03 1463.18 3517.29 4877.28 10906.31 0.00 1.93 2964.28 7388.46 1667.41 3467.40 4631.69 10857.79 18.81 15.0 0.0 8.0 0.005-02-2025 06:00Collected Tracerco Dye Water Sample.Collected Tracerco Standard Sample.6:03 Observed Well Slugging.1587.87 96.46 999.92 56.10 318.52 62.35 238.70 61.72 232.57 72.87 128 0.00 130.14 126.72 68.19 67.28 32.0 23000 8 0.672 0.10 0.0 36.00 0.00 36.00 36.00 0.0000 1.2912 0.0000 2.7908 447.66 0.00 1.97 2884.30 7449.12 1622.42 3551.09 4506.72 11000.20 0.00 1.93 3051.13 7452.02 1870.05 3506.36 4921.17 10960.31 18.99 15.0 0.0 8.0 0.005-02-2025 06:3006:31 Applied CMSF = 0.936.06:33 Configured DPI into Series Flow.06:45 Sparged Separator. Heavy Solids Observed.1583.23 96.47 994.77 55.62 347.17 61.72 254.09 61.36 245.99 72.69 128 0.00 135.95 133.21 68.75 66.21 32.0 23000 8 0.672 0.10 0.0 38.00 0.00 38.00 38.00 0.0000 1.2720 0.0000 2.8173 431.87 0.00 1.97 2945.35 7510.48 1805.21 3588.70 4750.56 11099.17 0.00 1.93 2854.28 7511.48 2066.89 3549.42 4921.17 11062.84 19.19 15.0 0.0 8.0 0.005-02-2025 07:001589.76 96.40 989.45 55.48 347.11 63.16 219.30 60.73 212.21 71.98 128 0.00 130.87 127.74 67.49 65.33 32.0 32000 8 0.672 0.10 0.0 42.00 0.00 42.00 42.00 0.0000 1.2240 0.0000 2.8428 505.70 0.00 1.97 2420.41 7560.91 1752.71 3625.21 4173.12 11186.11 0.00 1.93 3132.90 7576.75 1100.75 3572.35 4233.66 11151.04 19.39 15.0 0.0 8.0 0.005-02-2025 07:301584.41 96.50 981.88 55.86 357.38 64.75 228.08 59.03 219.94 70.74 128 0.00 131.93 129.72 67.38 65.12 32.0 32000 8 0.672 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 1.2960 0.0000 2.8698 380.70 0.00 1.97 3404.24 7631.83 1196.08 3650.13 4600.32 11281.95 0.00 1.93 3242.18 7644.30 1389.51 3601.30 4631.69 11247.53 19.52 15.0 0.0 8.0 0.0WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 21 START DATE:END DATE:TimeDPIGORFrac WaterTime & Date COMMENTS BHP BHT I/A Pressure O/A PressureWell HeadPressureWell HeadTemperatureU/S ChokePressureU/S ChokeTemperatureD/S ChokePressureD/S ChokeTemperatureChoke SizeU/S DPI Solids,Mud & CarboliteSpin-out(Observed)Separator InletPressureSeparatorPressureGasTemperatureOil TemperatureCorrected APIWaterSalinity pH Gas S.G CO2 H2S Total ChokeBS&W(Solids, Mud, Carbolite & Water)Solids, Mud & Carbolite @ChokeWater Cut @ChokeSeparator OilLeg BS&W (2-Phase)NitrogenInjection RateTotal Gas Rate(N2+Formation)NitrogenInjectionCumulativeTotal GasCumulative(N2+Formation)Total GOR Solids, Mud & Carbolite RateSolids, Mud, & CarboliteCumulativeOil Rate Oil Cumulative Water RateWaterCumulativeTotal Fluid RateTotal FluidCumulativeTank Farm StrapSolids, Mud & Carbolite RateTank Farm StrapSolids, Mud, & CarboliteCumulativeTank Farm StrapOil RateTank Farm StrapOil CumulativeTank Farm StrapWater RateTank Farm StrapWater CumulativeTank Farm StrapTotal Rate(Tank 1 - Tank 10)Tank Farm StrapTotal Cumulative(Tank 1 - Tank 10)Percentage ofFrac WaterRecoveredDefoamer(D/S of ChokeManifold DataHeader)Methanol(MeOH)(Separator GasLine)Demulsifier(D/S of Choke Manifold DataHeader)H2S Scavenger(D/S of Choke Manifold DataHeader)(mm-dd-yyyy hh:mm)(psig)(F)(psig) (psig) (psig)(F)(psig)(F)(psig)(F)(64ths) (%) (psig) (psig)(F) (F)(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)BS&W Properties Gas Rates & CumulativesRates and Cumulatives(Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Chemical Injection Rates5-May-2025 @ 02:00Well Head ChokeSeparator Fluid Properties Gas PropertiesSANTOS WELL TEST LEAD:Jack Landry / Pere KeniyeLOCATION / FIELD:PIKKA - NDB SANTOS REP/SUPERVISORS:Jose Gonzalez / Dan BonnarWELL NUMBER:NDBi-049EXPRO SUPERVISORS :CLIENT:Santos PROJECT DESIGN NUMBER:WT-XAK-0127.5NDBi-049 WELL CLEAN-UP DATA SHEETVictor Chavez | Jose Reynoso29-April-2025 @ 10:00EXPRO DAQ ENGINEERS:Travis Stacey | Yehia Elzeny05-02-2025 08:001595.38 96.45 984.79 55.56 339.76 64.16 214.04 59.90 207.31 71.00 128 0.00 127.85 125.58 67.12 65.21 32.0 32000 8 0.672 0.10 0.0 30.00 0.00 30.00 30.00 0.0000 1.1952 0.0000 2.8947 380.16 0.00 1.97 3143.95 7697.33 1347.41 3678.20 4491.36 11375.52 0.00 1.93 3560.61 7718.48 781.60 3617.58 4342.21 11337.99 19.67 15.0 0.0 8.0 0.005-02-2025 08:301585.85 96.39 977.19 55.00 343.62 64.07 221.63 59.39 213.72 71.28 128 0.00 131.01 127.71 66.56 64.92 32.0 32000 8 0.672 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.2912 0.0000 2.9216 343.36 0.00 1.97 3760.45 7775.67 825.47 3695.40 4585.92 11471.06 0.00 1.93 2728.36 7775.32 1975.71 3658.74 4704.06 11436.00 19.76 15.0 0.0 8.0 0.005-02-2025 09:00Collected Tracerco Dye Water Sample.09:05 Sparged Separator. Trace Solids Observed.1586.85 96.41 980.05 55.04 342.37 65.36 218.34 60.54 211.41 72.27 128 0.00 130.58 128.09 66.45 64.71 32.0 32000 8 0.672 0.10 0.0 42.00 0.00 42.00 42.00 0.0000 1.2528 0.0000 2.9477 457.78 0.00 1.97 2736.67 7832.69 1981.73 3736.68 4718.40 11569.36 0.00 1.93 3216.85 7842.34 1378.65 3687.46 4595.51 11531.74 19.98 15.0 0.0 8.0 0.005-02-2025 09:301586.96 96.45 975.23 55.72 334.09 64.96 216.73 60.43 209.78 73.00 128 0.00 130.01 127.70 66.98 64.96 32.0 32000 8 0.672 0.10 0.0 30.00 0.00 30.00 30.00 0.0000 1.2528 0.0000 2.9738 401.66 0.00 1.97 3119.09 7897.67 1336.75 3764.53 4455.84 11662.19 0.00 1.93 3649.63 7918.37 801.14 3704.16 4450.77 11624.46 20.13 15.0 0.0 8.0 0.005-02-2025 10:001588.80 96.44 972.69 55.12 346.79 64.33 225.61 59.68 218.74 72.42 128 0.00 131.97 128.88 66.72 64.77 32.0 32000 8 0.672 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.2864 0.0000 3.0006 344.72 0.00 1.97 3731.72 7975.41 819.16 3781.60 4550.88 11757.00 0.00 1.93 2670.46 7974.01 1780.31 3741.24 4450.77 11717.18 20.22 15.0 0.0 8.0 0.005-02-2025 10:3010:39 Decreased Defoamer Chemical Injection to 12 gal/day.1587.01 96.36 972.49 54.80 338.63 65.07 234.37 60.92 228.48 73.63 128 0.00 134.33 129.94 66.80 65.07 32.0 32000 8 0.672 0.10 0.0 40.00 0.00 40.00 40.00 0.0000 1.2240 0.0000 3.0261 456.60 0.00 1.97 2680.70 8031.26 1787.14 3818.83 4467.84 11850.08 0.00 1.93 2735.59 8031.00 1823.73 3779.24 4559.32 11812.17 20.42 15.0 0.0 8.0 0.005-02-2025 11:001584.44 96.37 970.22 54.62 385.39 64.25 231.74 60.69 223.85 74.02 128 0.00 126.05 124.98 66.82 65.79 32.0 31000 8 0.672 0.10 0.0 40.00 0.00 40.00 40.00 0.0000 1.2864 0.0000 3.0529 478.08 0.00 1.97 2690.78 8087.32 1793.86 3856.20 4484.64 11943.51 0.00 1.93 3584.49 8105.67 1011.01 3800.30 4595.51 11907.91 20.62 12.0 0.0 8.0 0.005-02-2025 11:301582.83 96.43 968.17 55.66 332.39 61.49 211.36 60.84 206.38 74.60 128 0.00 133.75 130.46 67.35 66.81 32.0 31000 8 0.662 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.3152 0.0000 3.0803 368.53 0.00 1.97 3568.78 8161.67 1006.58 3877.17 4575.36 12038.83 0.00 1.93 3890.62 8186.73 741.07 3815.74 4631.69 12004.40 20.73 12.0 0.0 8.0 0.005-02-2025 12:00Collected Tracerco Dye Water Sample. Kit #3 Complete.Collected Tracerco Standard Sample.1587.37 96.42 964.62 55.28 338.84 60.09 215.00 60.10 207.21 73.99 128 0.00 132.12 131.38 67.80 67.38 32.0 31000 8 0.662 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.3248 0.0000 3.1079 350.33 0.00 1.97 3781.61 8240.45 720.31 3892.18 4501.92 12132.62 0.00 1.93 3556.27 8260.82 1003.05 3836.64 4559.32 12099.39 20.81 12.0 0.0 8.0 0.005-02-2025 12:3012:42 Decreased Defoamer Chemical Injection to 10 gal/day. 12:51 Sparged Separator. Trace Solids Observed. 1577.74 96.38 963.43 55.62 353.56 61.11 221.89 60.68 212.97 75.07 128 0.00 127.80 126.43 67.80 67.78 32.0 31000 8 0.662 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.3104 0.0000 3.1352 376.55 0.00 1.97 3480.05 8312.95 981.55 3912.63 4461.60 12225.57 0.00 1.93 3216.85 8327.84 1378.65 3865.36 4595.51 12195.13 20.92 12.0 0.0 8.0 0.005-02-2025 13:001584.61 96.33 960.74 54.74 348.98 59.92 221.93 59.81 215.56 75.58 128 0.00 130.82 129.23 67.65 66.46 32.0 31000 8 0.662 0.10 0.0 30.00 0.00 30.00 30.00 0.0000 1.3296 0.0000 3.1629 426.28 0.00 1.97 3119.09 8377.93 1336.75 3940.48 4455.84 12318.40 0.00 1.93 3676.40 8404.43 919.10 3884.51 4595.51 12290.87 21.07 10.0 0.0 8.0 0.005-02-2025 13:301582.58 96.33 957.67 55.32 370.06 60.61 237.59 61.20 230.95 76.16 128 0.00 133.87 131.89 67.30 66.11 30.3 31000 8 0.662 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.3152 0.0000 3.1903 371.88 0.00 1.97 3536.64 8451.61 884.16 3958.90 4420.80 12410.50 0.00 1.93 3499.82 8477.34 987.13 3905.07 4486.95 12384.35 21.17 10.0 0.0 8.0 0.005-02-2025 14:001577.42 96.33 957.54 54.07 364.65 59.70 232.97 61.81 225.11 73.38 128 0.00 134.52 131.79 67.33 66.28 30.3 31000 8 0.662 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.4016 0.0000 3.2195 381.10 0.00 1.97 3677.73 8528.23 1037.31 3980.51 4715.04 12508.73 0.00 1.93 3318.17 8546.47 1422.07 3934.70 4740.25 12483.10 21.29 10.0 0.0 8.0 0.005-02-2025 14:301580.08 96.34 958.87 54.60 362.98 60.62 238.59 60.83 233.20 74.06 128 0.00 137.85 133.10 67.22 66.01 30.3 31000 8 0.662 0.10 0.0 30.00 0.00 30.00 30.00 0.0000 1.3296 0.0000 3.2472 411.26 0.00 1.97 3232.99 8595.59 1385.57 4009.37 4618.56 12604.95 0.00 1.93 3080.80 8610.65 1587.08 3967.76 4667.88 12580.35 21.44 10.0 0.0 8.0 0.005-02-2025 15:0015:07 Decreased Defoamer Chemical Injection to 8 gal/day.1578.57 96.34 957.77 54.70 356.82 59.64 229.01 59.80 222.15 73.02 128 0.00 133.99 131.22 66.87 65.61 30.3 31000 8 0.662 0.10 0.0 34.00 0.00 34.00 34.00 0.0000 1.3584 0.0000 3.2755 445.91 0.00 1.97 3046.35 8659.05 1569.33 4042.07 4615.68 12701.11 0.00 1.93 3874.34 8691.37 793.54 3984.30 4667.88 12677.60 21.62 10.0 0.0 8.0 0.005-02-2025 15:301576.62 96.31 956.18 54.80 366.00 59.71 217.94 59.78 208.94 73.14 128 0.00 132.17 129.36 67.35 65.32 30.3 31000 8 0.662 0.10 0.0 17.00 0.00 17.00 17.00 0.0000 1.3344 0.0000 3.3033 350.54 0.00 1.97 3806.71 8738.36 779.69 4058.31 4586.40 12796.66 0.00 1.93 3763.25 8769.77 940.81 4003.90 4704.06 12775.60 21.70 8.0 0.0 8.0 0.005-02-2025 16:0016:06 Sparged Separator. Trace Solids Observed.1574.39 96.34 955.68 53.93 366.78 59.48 231.54 59.87 222.35 73.02 128 0.00 133.84 132.42 67.03 65.24 30.3 31000 8 0.662 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.3920 0.0000 3.3323 370.77 0.00 1.97 3754.37 8816.57 938.59 4077.87 4692.96 12894.43 0.00 1.93 3946.35 8851.98 866.27 4021.94 4812.62 12875.86 21.81 8.0 0.0 8.0 0.005-02-2025 16:301574.03 96.31 957.08 54.25 371.32 59.50 236.40 60.10 229.50 73.05 128 0.00 135.69 131.88 67.03 65.35 30.3 31000 8 0.662 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.3920 0.0000 3.3613 376.35 0.00 1.97 3698.66 8893.63 811.90 4094.78 4510.56 12988.40 0.00 1.93 3679.30 8928.64 807.65 4038.77 4486.95 12969.34 21.90 8.0 0.0 8.0 0.005-02-2025 17:001574.29 96.31 958.45 54.25 371.76 59.44 235.04 60.21 227.49 73.20 128 0.00 135.50 132.80 66.47 64.71 30.3 31000 8 0.662 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.4112 0.0000 3.3907 361.54 0.00 1.97 3903.33 8974.95 856.83 4112.63 4760.16 13087.57 0.00 1.93 4035.36 9012.71 885.81 4057.22 4921.17 13071.86 21.99 8.0 0.0 8.0 0.005-02-2025 17:301573.62 96.30 957.69 54.54 368.35 59.77 231.82 59.76 224.05 72.94 128 0.00 136.85 134.28 66.66 65.01 30.3 31000 8 0.670 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.3968 0.0000 3.4198 357.52 0.00 1.97 3906.87 9056.34 857.61 4130.50 4764.48 13186.83 0.00 1.93 3588.11 9087.46 1260.69 4083.49 4848.80 13172.88 22.09 8.0 0.0 8.0 0.005-02-2025 18:00Collected Tracerco Standard Sample.1569.84 96.32 955.94 55.60 370.10 59.50 231.12 61.68 220.53 72.71 128 0.00 139.91 138.61 66.71 64.98 30.3 31000 8 0.670 0.10 0.0 26.00 0.00 26.00 26.00 0.0000 1.4160 0.0000 3.4493 400.01 0.00 1.97 3539.92 9130.09 1243.76 4156.41 4783.68 13286.49 0.00 1.93 3879.04 9168.27 969.76 4103.69 4848.80 13273.90 22.23 8.0 0.0 8.0 0.005-02-2025 18:301572.57 96.30 956.48 55.78 363.57 59.70 226.84 62.41 221.54 72.42 128 0.00 136.05 136.95 66.98 65.91 30.3 31000 8 0.670 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4064 0.0000 3.4786 372.55 0.00 1.97 3775.10 9208.74 943.78 4176.07 4718.88 13384.80 0.00 1.93 3753.84 9246.48 1058.78 4125.75 4812.62 13374.16 22.33 8.0 0.0 8.0 0.005-02-2025 19:001571.36 96.31 955.94 54.76 376.44 60.02 238.88 62.64 231.78 72.04 128 0.00 139.13 135.36 66.93 66.45 30.3 24000 8 0.670 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.4112 0.0000 3.5080 384.54 0.00 1.97 3669.87 9285.19 1035.09 4197.64 4704.96 13482.82 0.00 1.93 3602.59 9321.53 1137.66 4149.45 4740.25 13472.91 22.45 8.0 0.0 8.0 0.005-02-2025 19:301569.85 96.30 956.04 54.86 372.13 60.77 238.33 62.61 228.21 71.94 128 0.00 138.38 134.03 67.17 66.63 30.3 24000 8 0.670 0.10 0.0 24.00 0.00 24.00 24.00 0.0000 1.4256 0.0000 3.5377 394.66 0.00 1.97 3612.25 9360.45 1140.71 4221.40 4752.96 13581.84 0.00 1.93 3907.99 9402.95 977.00 4169.80 4884.99 13574.68 22.58 8.0 0.0 8.0 0.005-02-2025 20:001569.71 96.31 955.09 54.76 376.49 60.41 240.85 61.99 232.98 71.79 128 0.00 138.27 136.04 67.17 66.97 30.3 26000 8 0.670 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4160 0.0000 3.5672 372.85 0.00 1.97 3797.76 9439.57 949.44 4241.18 4747.20 13680.74 0.00 1.93 3782.07 9481.74 1066.74 4192.03 4848.80 13675.70 22.68 8.0 0.0 8.0 0.005-02-2025 20:301569.90 96.30 953.87 55.34 375.98 59.99 243.08 61.40 233.69 71.27 128 0.00 138.71 135.91 67.35 66.93 30.3 26000 8 0.670 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.4160 0.0000 3.5967 380.95 0.00 1.97 3717.04 9517.01 1048.40 4263.02 4765.44 13780.02 0.00 1.93 3879.04 9562.55 969.76 4212.23 4848.80 13776.72 22.80 8.0 0.0 8.0 0.005-02-2025 21:001570.47 96.30 952.50 55.54 374.30 59.42 238.94 59.67 231.65 70.98 128 0.00 140.10 136.47 66.85 66.77 30.3 26000 8 0.670 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4256 0.0000 3.6264 376.87 0.00 1.97 3782.78 9595.82 945.70 4282.72 4728.48 13878.53 0.00 1.93 3657.59 9638.75 1155.03 4236.29 4812.62 13876.98 22.90 8.0 0.0 8.0 0.005-02-2025 21:301568.74 96.29 951.28 55.28 377.05 59.32 241.89 59.07 232.84 70.91 128 0.00 142.01 138.21 67.12 66.82 30.3 26000 8 0.670 0.10 0.0 24.00 0.00 24.00 24.00 0.0000 1.4208 0.0000 3.6560 391.19 0.00 1.97 3631.95 9671.48 1146.93 4306.62 4778.88 13978.09 0.00 1.93 3907.99 9720.17 977.00 4256.65 4884.99 13978.75 23.03 8.0 0.0 8.0 0.005-02-2025 22:0022:15 Sparged Separator. Trace Solids Observed.1568.10 96.28 951.11 54.23 377.65 59.21 242.61 59.17 234.01 70.76 128 0.00 142.16 138.48 66.88 66.63 30.3 26000 8 0.670 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4352 0.0000 3.6859 365.45 0.00 1.97 3927.17 9753.30 981.79 4327.07 4908.96 14080.36 0.00 1.93 3936.94 9802.19 984.23 4277.15 4921.17 14081.28 23.14 8.0 0.0 8.0 0.005-02-2025 22:301567.32 96.28 951.46 55.54 377.23 59.22 242.88 59.26 233.19 70.84 128 0.00 144.13 140.89 66.88 65.64 30.3 26000 8 0.670 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4352 0.0000 3.7158 377.98 0.00 1.97 3796.99 9832.40 949.25 4346.85 4746.24 14179.24 0.00 1.93 3602.59 9877.24 1137.66 4300.85 4740.25 14180.03 23.25 8.0 0.0 8.0 0.005-02-2025 23:001567.69 96.27 951.09 55.10 377.27 59.17 243.40 58.52 235.24 69.86 128 0.00 141.64 138.36 66.48 66.04 30.3 26000 8 0.670 0.10 0.0 24.00 0.00 24.00 24.00 0.0000 1.4304 0.0000 3.7456 383.48 0.00 1.97 3730.08 9910.11 1177.92 4371.39 4908.00 14281.49 0.00 1.93 3907.99 9958.66 977.00 4321.21 4884.99 14281.80 23.38 8.0 0.0 8.0 0.005-02-2025 23:301567.39 96.25 950.47 54.44 382.11 59.05 244.54 57.97 235.83 69.91 128 0.00 142.17 139.43 66.53 66.12 30.3 26000 8 0.670 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4400 0.0000 3.7756 364.61 0.00 1.97 3949.44 9992.39 987.36 4391.96 4936.80 14384.34 0.00 1.93 3782.07 10037.45 1066.74 4343.43 4848.80 14382.82 23.49 8.0 0.0 8.0 0.005-03-2025 00:00Collected Tracerco Standard Sample.1563.30 96.25 945.17 54.60 377.69 57.73 241.05 57.62 231.58 69.32 128 0.00 143.36 139.69 66.61 66.12 30.3 26000 8 0.670 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.5024 0.0000 3.8069 385.48 0.00 1.97 3897.50 10073.59 1099.30 4414.86 4996.80 14488.44 0.00 1.93 3725.62 10115.07 1050.81 4365.32 4776.43 14482.33 23.61 8.0 0.0 8.0 0.005-03-2025 00:301563.90 96.25 948.89 54.58 377.03 58.78 239.74 58.50 230.84 70.38 128 0.00 140.31 137.81 66.77 66.31 30.9 26000 8 0.669 0.10 0.0 22.00 0.00 22.00 22.00 0.0000 1.4496 0.0000 3.8371 379.40 0.00 1.97 3820.75 10153.19 1077.65 4437.31 4898.40 14590.49 0.00 1.93 3879.04 10195.88 969.76 4385.53 4848.80 14583.34 23.73 8.0 0.0 8.0 0.005-03-2025 01:0001:08 Sparged Separator. Trace Solids Observed.1564.94 96.24 948.64 54.29 381.49 58.70 247.22 58.63 237.71 70.14 128 0.00 143.22 139.96 66.77 66.28 30.9 26000 8 0.669 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4592 0.0000 3.8675 369.33 0.00 1.97 3950.98 10235.50 987.74 4457.89 4938.72 14693.38 0.00 1.93 3976.02 10278.72 872.78 4403.71 4848.80 14684.36 23.84 8.0 0.0 8.0 0.005-03-2025 01:301565.03 96.24 948.72 54.46 382.13 58.53 245.09 58.68 237.09 70.29 128 0.00 144.03 140.36 66.66 66.36 30.9 26000 8 0.669 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.4640 0.0000 3.8980 365.30 0.00 1.97 4007.64 10318.99 879.72 4476.22 4887.36 14795.20 0.00 1.93 4201.09 10366.24 683.90 4417.96 4884.99 14786.13 23.94 8.0 0.0 8.0 0.005-03-2025 02:001563.29 96.23 948.28 54.86 382.65 58.18 246.09 58.12 237.09 70.33 128 0.00 142.04 139.56 66.67 66.49 30.9 25000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4688 0.0000 3.9286 346.32 0.00 1.97 4241.11 10407.35 690.41 4490.60 4931.52 14897.94 0.00 1.93 4042.60 10450.46 770.02 4434.00 4812.62 14886.39 24.02 8.0 0.0 8.0 0.005-03-2025 02:301562.03 96.23 946.96 54.46 380.56 58.16 243.20 57.93 234.84 70.09 128 0.00 144.31 141.86 66.35 66.41 30.9 25000 8 0.669 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.4880 0.0000 3.9596 357.19 0.00 1.97 4165.86 10494.14 793.50 4507.13 4959.36 15001.26 0.00 1.93 4005.69 10533.91 879.30 4452.32 4884.99 14988.16 24.10 8.0 0.0 8.0 0.005-03-2025 03:001560.45 96.24 946.09 54.19 380.34 58.26 243.06 57.93 235.21 69.94 128 0.00 143.94 139.69 66.50 66.44 30.9 25000 8 0.669 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.4640 0.0000 3.9901 362.60 0.00 1.97 4037.55 10578.25 886.29 4525.60 4923.84 15103.84 0.00 1.93 4139.57 10620.15 1034.89 4473.88 5174.47 15095.97 24.20 8.0 0.0 8.0 0.005-03-2025 03:301561.31 96.23 945.27 54.50 382.13 58.28 246.57 58.06 235.98 70.05 128 0.00 143.95 140.10 66.45 66.22 30.9 25000 8 0.669 0.10 0.0 20.00 0.00 20.00 20.00 0.0000 1.4688 0.0000 4.0207 373.86 0.00 1.97 3928.70 10660.10 982.18 4546.06 4910.88 15206.15 0.00 1.93 4169.97 10707.03 678.83 4488.02 4848.80 15196.98 24.31 8.0 0.0 8.0 0.005-03-2025 04:0004:05 Sparged Separator. Trace Solids Observed.1561.23 96.23 945.09 54.07 392.74 58.31 250.93 58.21 242.32 70.23 128 0.00 146.92 142.91 66.48 66.21 30.9 26000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4688 0.0000 4.0513 347.54 0.00 1.97 4226.25 10748.15 687.99 4560.39 4914.24 15308.53 0.00 1.93 4005.69 10790.48 879.30 4506.34 4884.99 15298.75 24.39 8.0 0.0 8.0 0.005-03-2025 04:301560.28 96.22 943.44 54.56 380.46 57.72 243.78 57.69 234.81 70.08 128 0.00 146.13 141.07 66.45 65.12 30.9 26000 8 0.669 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.4976 0.0000 4.0825 384.41 0.00 1.97 3895.85 10829.31 855.19 4578.21 4751.04 15407.51 0.00 1.93 3857.33 10870.84 846.73 4523.98 4704.06 15396.75 24.48 8.0 0.0 8.0 0.005-03-2025 05:001559.88 96.21 943.18 54.29 383.82 57.32 246.85 57.23 236.25 69.84 128 0.00 148.35 145.31 66.16 65.79 30.9 26000 8 0.669 0.10 0.0 18.00 0.00 18.00 18.00 0.0000 1.4880 0.0000 4.1135 366.08 0.00 1.97 4064.71 10913.99 892.25 4596.80 4956.96 15510.78 0.00 1.93 4201.09 10958.36 683.90 4538.23 4884.99 15498.53 24.58 8.0 0.0 8.0 0.005-03-2025 05:301560.10 96.20 941.67 54.27 385.49 57.27 246.67 57.29 238.69 70.04 128 0.00 146.44 142.88 66.56 65.77 30.9 26000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4976 0.0000 4.1447 352.05 0.00 1.97 4253.90 11002.62 692.50 4611.22 4946.40 15613.83 0.00 1.93 4201.09 11045.89 683.90 4552.48 4884.99 15600.30 24.66 8.0 0.0 8.0 0.005-03-2025 06:00Collected Tracerco Standard Sample.1559.09 96.20 940.81 54.17 388.36 57.22 247.70 56.89 238.82 70.04 128 0.00 145.73 141.81 65.60 64.66 30.9 26000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.4928 0.0000 4.1758 349.57 0.00 1.97 4270.42 11091.58 695.18 4625.71 4965.60 15717.28 0.00 1.93 4155.50 11132.46 620.94 4565.41 4776.43 15699.81 24.74 8.0 0.0 8.0 0.005-03-2025 06:3006:49Lowered Separator Pressure.1557.92 96.20 940.06 54.44 381.19 56.74 242.53 56.89 233.46 70.04 128 0.00 145.13 143.13 65.59 63.67 30.9 27000 8 0.669 0.10 0.0 13.00 0.00 13.00 13.00 0.0000 1.4736 0.0000 4.2065 341.57 0.00 1.97 4314.23 11181.46 644.65 4639.14 4958.88 15820.59 0.00 1.93 4103.39 11217.95 781.60 4581.70 4884.99 15801.58 24.81 8.0 0.0 8.0 0.005-03-2025 07:001556.57 96.20 939.46 53.83 382.59 57.00 237.51 57.20 227.96 70.37 128 0.00 123.81 118.84 64.87 63.17 30.9 27000 8 0.669 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.5216 0.0000 4.2382 359.34 0.00 1.97 4234.41 11269.68 806.55 4655.94 5040.96 15925.61 0.00 1.93 4263.33 11306.77 694.03 4596.16 4957.36 15904.85 24.90 8.0 0.0 8.0 0.005-03-2025 07:301556.88 96.20 939.68 54.09 383.74 57.34 240.18 57.53 230.82 70.78 128 0.00 124.95 120.42 65.01 63.10 30.9 27000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.5600 0.0000 4.2707 356.11 0.00 1.97 4380.63 11360.94 713.13 4670.80 5093.76 16031.73 0.00 1.93 4494.19 11400.39 499.35 4606.56 4993.54 16008.89 24.98 8.0 0.0 8.0 0.005-03-2025 08:00Configured DPI Unit to Parallel Flow.1555.01 96.19 940.85 53.33 375.00 57.32 267.94 57.39 254.71 70.73 128 0.00 129.88 124.55 64.95 63.32 30.9 27000 8 0.669 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.5648 0.0000 4.3033 342.37 0.00 1.97 4570.56 11456.16 507.84 4681.38 5078.40 16137.53 0.00 1.93 4470.31 11493.53 667.98 4620.47 5138.28 16115.93 25.04 8.0 0.0 8.0 0.005-03-2025 08:3008:31 Applied CMSF 0.932.1548.98 96.21 946.84 54.33 350.03 57.73 246.65 58.06 237.95 71.03 128 0.00 126.45 121.32 65.32 64.77 30.9 27000 8 0.669 0.10 0.0 13.00 0.00 13.00 13.00 0.0000 1.6752 0.0000 4.3382 343.21 0.00 1.97 4880.91 11557.85 729.33 4696.57 5610.24 16254.41 0.00 1.93 4730.11 11592.07 770.02 4636.52 5500.13 16230.52 25.12 8.0 0.0 8.0 0.005-03-2025 09:00Collected 1st 5 gallons Bulk Sample at U/S Choke Manifold sample point.09:14 Lowered Separator Pressure.1547.38 96.21 951.14 53.93 379.40 58.66 272.40 58.73 260.92 71.65 128 0.00 134.04 126.11 65.61 64.13 30.9 27000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.6848 0.0000 4.3733 357.64 0.00 1.97 4710.87 11655.99 766.89 4712.55 5477.76 16368.53 0.00 1.93 4761.23 11691.26 775.08 4652.66 5536.32 16345.86 25.20 8.0 0.0 8.0 0.005-03-2025 09:3009:56 Sparged Separator. Light Solids Observed.1544.93 96.22 951.50 54.54 351.27 58.50 246.21 58.14 235.72 71.01 128 0.00 121.82 116.23 65.33 63.96 30.9 27000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7424 0.0000 4.4096 368.80 0.00 1.97 4724.50 11754.42 769.10 4728.57 5493.60 16482.98 0.00 1.93 4589.72 11786.88 874.23 4670.88 5463.95 16459.69 25.29 8.0 0.0 8.0 0.005-03-2025 10:00Collected 2nd 5 gallons Bulk Sample at U/S Choke Manifold sample point.1543.05 96.21 955.96 54.42 346.93 58.38 244.32 58.21 232.73 70.88 128 0.00 119.66 116.23 65.46 65.17 30.9 27000 8 0.669 0.10 0.0 16.00 0.00 16.00 16.00 0.0000 1.7520 0.0000 4.4461 390.76 0.00 1.97 4483.58 11847.83 854.02 4746.36 5337.60 16594.18 0.00 1.93 4636.76 11883.48 754.82 4686.60 5391.58 16572.02 25.38 8.0 0.0 8.0 0.005-03-2025 10:301542.50 96.21 957.75 54.52 362.90 58.81 264.26 58.91 253.19 71.57 128 0.00 126.87 121.02 66.04 66.00 30.7 27000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7568 0.0000 4.4827 376.59 0.00 1.97 4665.05 11945.02 759.43 4762.18 5424.48 16707.19 0.00 1.93 4761.23 11982.67 775.08 4702.75 5536.32 16687.36 25.47 8.0 0.0 8.0 0.005-03-2025 11:00Collected 3rd 5 gallons Bulk Sample at U/S Choke Manifold sample point.1539.90 96.20 958.17 54.86 364.25 59.07 255.05 58.81 244.86 71.77 128 0.00 126.13 119.29 66.20 66.51 30.7 27000 8 0.669 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7568 0.0000 4.5193 373.68 0.00 1.97 4701.38 12042.96 765.34 4778.13 5466.72 16821.08 0.00 1.93 4699.00 12080.57 764.95 4718.69 5463.95 16801.19 25.55 8.0 0.0 8.0 0.005-03-2025 11:301538.82 96.21 960.38 55.18 369.88 59.93 260.50 60.05 247.77 72.66 128 0.00 125.19 119.82 66.15 65.12 30.7 27000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7376 0.0000 4.5555 368.30 0.00 1.97 4717.89 12141.25 768.03 4794.13 5485.92 16935.37 0.00 1.93 4761.23 12179.76 775.08 4734.83 5536.32 16916.53 25.64 8.0 0.0 8.0 0.005-03-2025 12:00Collected 4th 5 gallons Bulk Sample at U/S Choke Manifold sample point.Collected Tracerco Standard Sample.1537.65 96.22 959.79 54.80 365.68 60.09 259.09 60.09 247.00 73.02 128 0.00 124.62 119.67 66.10 65.47 30.7 27000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7328 0.0000 4.5916 369.03 0.00 1.97 4695.60 12239.08 764.40 4810.05 5460.00 17049.12 0.00 1.93 4730.11 12278.30 770.02 4750.88 5500.13 17031.11 25.72 8.0 0.0 8.0 0.005-03-2025 12:3012:45 Collected Arctic Fox Flash Point Sample at U/S Choke Manifold samplepoint.1537.23 96.19 961.94 55.10 372.33 60.41 263.11 60.55 247.73 75.55 128 0.00 125.57 119.67 66.45 66.33 30.7 26000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7184 0.0000 4.6274 366.67 0.00 1.97 4686.52 12336.71 762.92 4825.95 5449.44 17162.65 0.00 1.93 4761.23 12377.50 775.08 4767.02 5536.32 17146.45 25.81 8.0 0.0 8.0 0.005-03-2025 13:001536.36 96.19 961.12 55.12 367.93 60.51 254.83 59.97 243.71 75.47 128 0.00 126.68 119.97 66.15 65.45 30.7 26000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7280 0.0000 4.6634 365.79 0.00 1.97 4724.08 12435.13 769.04 4841.97 5493.12 17277.09 0.00 1.93 4730.11 12476.04 770.02 4783.07 5500.13 17261.04 25.89 8.0 0.0 8.0 0.005-03-2025 13:3013:31 Applied CMSF 0.932.1534.44 96.18 962.13 55.44 381.05 60.25 274.63 61.54 262.38 75.71 128 0.00 130.46 124.24 66.50 65.04 30.7 26000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7280 0.0000 4.6994 364.70 0.00 1.97 4738.12 12533.84 771.32 4858.04 5509.44 17391.87 0.00 1.93 4854.59 12577.18 790.28 4799.53 5644.87 17378.64 25.98 8.0 0.0 8.0 0.005-03-2025 14:001534.93 96.18 962.87 56.10 372.53 59.99 261.34 61.95 247.65 72.56 128 0.00 123.69 119.05 66.58 66.10 30.7 26000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7328 0.0000 4.7355 367.09 0.00 1.97 4720.37 12632.18 768.43 4874.05 5488.80 17506.22 0.00 1.93 4776.43 12676.69 651.33 4813.10 5427.76 17491.72 26.07 8.0 0.0 8.0 0.005-03-2025 14:3014:38 Lowered Separator Pressure.1532.63 96.18 961.94 55.26 364.53 60.07 257.71 60.24 245.55 72.36 128 0.00 127.31 123.46 66.79 66.82 30.7 26000 8 0.674 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7472 0.0000 4.7719 358.10 0.00 1.97 4879.14 12733.83 665.34 4887.91 5544.48 17621.73 0.00 1.93 4776.43 12776.20 651.33 4826.67 5427.76 17604.80 26.14 8.0 0.0 8.0 0.005-03-2025 15:0015:28 Sparged Separator. Trace Solids Observed.1531.87 96.18 963.27 55.66 361.48 59.72 250.39 60.05 239.22 72.95 128 0.00 117.23 110.78 66.39 65.31 30.6 26000 8 0.674 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7616 0.0000 4.8086 359.55 0.00 1.97 4899.42 12835.90 668.10 4901.83 5567.52 17737.72 0.00 1.93 4823.47 12876.69 785.22 4843.03 5608.69 17721.65 26.21 8.0 0.0 8.0 0.005-03-2025 15:301531.35 96.18 964.32 55.78 388.12 60.49 274.57 61.27 259.64 73.98 128 0.00 120.69 110.92 66.74 65.10 30.6 26000 8 0.674 0.10 0.0 14.00 0.00 14.00 14.00 0.0000 1.7712 0.0000 4.8455 394.26 0.00 1.97 4492.50 12929.50 731.34 4917.07 5223.84 17846.55 0.00 1.93 4903.80 12978.85 668.70 4856.96 5572.50 17837.74 26.30 8.0 0.0 8.0 0.005-03-2025 16:0016:01 Lowered Separator Pressure.1528.71 96.17 962.23 55.54 371.08 59.97 258.55 60.59 247.19 73.60 128 0.00 120.31 112.92 66.82 66.35 30.6 26000 8 0.674 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7856 0.0000 4.8827 362.64 0.00 1.97 4923.92 13032.08 671.44 4931.05 5595.36 17963.12 0.00 1.93 4935.65 13081.67 673.04 4870.98 5608.69 17954.59 26.37 8.0 0.0 8.0 0.005-03-2025 16:301528.04 96.17 963.07 56.58 378.27 60.11 260.34 60.80 245.95 73.64 128 0.00 107.67 99.19 66.48 66.83 30.6 26000 8 0.674 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8624 0.0000 4.9215 375.02 0.00 1.97 4966.16 13135.54 677.20 4945.16 5643.36 18080.69 0.00 1.93 4776.43 13181.18 651.33 4884.55 5427.76 18067.67 26.45 8.0 0.0 8.0 0.005-03-2025 17:001525.65 96.18 963.05 56.89 367.81 60.22 252.62 60.86 240.31 73.69 128 0.00 107.33 100.26 66.82 67.04 30.6 26000 8 0.674 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8480 0.0000 4.9600 368.36 0.00 1.97 5016.84 13240.06 684.12 4959.41 5700.96 18199.46 0.00 1.93 5145.52 13288.38 571.72 4896.46 5717.24 18186.78 26.52 8.0 0.0 8.0 0.005-03-2025 17:301527.24 96.16 962.97 56.20 351.09 59.97 243.94 60.56 232.46 73.38 128 0.00 108.29 101.06 66.56 65.87 30.6 26000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8000 0.0000 4.9975 356.58 0.00 1.97 5047.92 13345.22 560.88 4971.10 5608.80 18316.31 0.00 1.93 5038.05 13393.34 498.27 4906.84 5536.32 18302.12 26.58 8.0 0.0 8.0 0.005-03-2025 18:00Collected Tracerco Standard Sample.1525.67 96.17 963.95 57.15 359.87 59.51 248.22 60.42 236.47 73.42 128 0.00 110.07 102.39 66.50 65.41 30.6 26000 8 0.688 0.10 0.0 9.00 0.00 9.00 9.00 0.0000 1.7904 0.0000 5.0348 347.13 0.00 1.97 5157.73 13452.67 510.11 4981.73 5667.84 18434.39 0.00 1.93 5178.09 13501.22 575.34 4918.83 5753.43 18421.98 26.64 8.0 0.0 8.0 0.005-03-2025 18:301525.42 96.16 964.70 57.13 365.31 60.07 251.90 60.79 239.69 73.44 128 0.00 109.21 101.45 66.26 66.16 30.6 26000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8096 0.0000 5.0725 353.02 0.00 1.97 5126.11 13559.47 569.57 4993.59 5695.68 18553.05 0.00 1.93 5063.02 13606.70 690.41 4933.21 5753.43 18541.84 26.71 8.0 0.0 8.0 0.005-03-2025 19:001522.47 96.16 963.89 57.41 363.63 59.20 250.17 60.82 238.69 72.68 128 0.00 110.55 101.21 66.16 66.48 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8000 0.0000 5.1100 352.99 0.00 1.97 5099.33 13665.70 566.59 5005.40 5665.92 18671.09 0.00 1.93 4935.65 13709.52 673.04 4947.23 5608.69 18658.69 26.77 8.0 0.0 8.0 0.005-03-2025 19:301523.01 96.16 964.09 57.01 366.08 59.11 251.70 60.04 239.89 72.64 128 0.00 112.43 101.75 66.10 66.61 30.6 27000 8 0.688 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8048 0.0000 5.1476 360.84 0.00 1.97 5001.64 13769.90 682.04 5019.61 5683.68 18789.50 0.00 1.93 4935.65 13812.35 673.04 4961.26 5608.69 18775.54 26.84 8.0 0.0 8.0 0.005-03-2025 20:001522.62 96.16 963.63 56.87 362.44 59.23 249.59 60.26 237.63 72.73 128 0.00 109.93 100.56 66.40 66.52 30.6 27000 8 0.688 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8000 0.0000 5.1851 359.61 0.00 1.97 5005.44 13874.18 682.56 5033.83 5688.00 18908.00 0.00 1.93 5112.95 13918.87 568.11 4973.09 5681.06 18893.89 26.92 8.0 0.0 8.0 0.005-03-2025 20:301522.27 96.15 964.05 57.21 361.42 58.87 249.69 59.74 238.20 72.40 128 0.00 110.62 100.83 65.89 66.62 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8000 0.0000 5.2226 354.13 0.00 1.97 5082.91 13980.08 564.77 5045.59 5647.68 19025.66 0.00 1.93 5047.82 14024.03 560.87 4984.78 5608.69 19010.74 26.98 8.0 0.0 8.0 0.005-03-2025 21:001522.27 96.14 963.77 56.00 375.64 59.28 264.26 59.64 253.11 72.86 128 0.00 113.45 104.19 66.61 66.64 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8048 0.0000 5.2602 351.43 0.00 1.97 5135.62 14087.07 570.62 5057.48 5706.24 19144.54 0.00 1.93 4935.65 14126.86 673.04 4998.80 5608.69 19127.59 27.05 8.0 0.0 8.0 0.005-03-2025 21:301520.73 96.14 963.21 56.64 370.34 59.15 254.51 59.62 241.98 72.62 128 0.00 108.34 100.98 65.89 65.57 30.6 27000 8 0.688 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.7952 0.0000 5.2976 359.47 0.00 1.97 4994.04 14191.11 681.00 5071.67 5675.04 19262.77 0.00 1.93 5080.39 14232.70 564.49 5010.56 5644.87 19245.19 27.12 8.0 0.0 8.0 0.005-03-2025 22:0022:10 Sparged Separator. Trace Solids Observed.1522.42 96.14 962.89 55.32 373.35 58.94 262.01 59.45 245.17 72.06 128 0.00 110.09 101.25 65.95 66.03 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8144 0.0000 5.3354 354.85 0.00 1.97 5113.15 14297.64 568.13 5083.50 5681.28 19381.13 0.00 1.93 5159.99 14340.20 448.70 5019.91 5608.69 19362.04 27.19 8.0 0.0 8.0 0.005-03-2025 22:301518.92 96.14 962.95 56.22 351.31 58.38 238.65 59.15 226.99 71.96 128 0.00 105.40 98.47 65.92 66.08 30.6 27000 8 0.688 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8432 0.0000 5.3738 360.16 0.00 1.97 5117.70 14404.26 445.02 5092.77 5562.72 19497.02 0.00 1.93 4840.12 14441.03 660.02 5033.66 5500.13 19476.6227.24 8.0 0.0 8.0 0.005-03-2025 23:001518.39 96.13 962.97 55.32 370.06 58.51 253.63 58.83 242.30 71.58 128 0.00 111.11 101.39 66.05 66.23 30.6 27000 8 0.688 0.10 0.0 12.00 0.00 12.00 12.00 0.0000 1.8192 0.0000 5.4117 363.94 0.00 1.97 4998.68 14508.39 681.64 5106.98 5680.32 19615.36 0.00 1.93 5047.82 14546.20 560.87 5045.34 5608.69 19593.47 27.31 8.0 0.0 8.0 0.005-03-2025 23:301517.86 96.13 962.87 54.94 360.63 58.21 248.70 58.73 238.13 71.88 128 0.00 109.14 99.79 66.11 66.20 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8192 0.0000 5.4496 355.43 0.00 1.97 5118.34 14615.03 568.70 5118.82 5687.04 19733.84 0.00 1.93 5193.28 14654.39 451.59 5054.75 5644.87 19711.07 27.37 8.0 0.0 8.0 0.005-04-2025 00:00Collected Tracerco Standard Sample.1518.13 96.13 963.71 55.54 364.73 58.21 250.55 58.97 238.84 71.64 128 0.00 108.75 100.59 66.05 66.26 30.6 27000 8 0.688 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8192 0.0000 5.4875 349.44 0.00 1.97 5206.02 14723.49 452.70 5128.25 5658.72 19851.73 0.00 1.93 5080.39 14760.23 564.49 5066.51 5644.87 19828.67 27.43 8.0 0.0 8.0 0.005-04-2025 00:301517.40 96.13 963.01 55.00 365.31 58.27 250.61 58.90 238.95 71.94 128 0.00 105.84 99.13 66.00 66.31 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8384 0.0000 5.5258 361.87 0.00 1.97 5080.32 14829.33 564.48 5140.01 5644.80 19969.33 0.00 1.93 5015.25 14864.72 557.25 5078.12 5572.50 19944.77 27.49 8.0 0.0 8.0 0.005-04-2025 01:0001:10 Sparged Separator. Trace Solids Observed.1517.78 96.13 962.31 55.94 366.34 58.22 252.48 59.05 241.71 72.10 128 0.00 111.44 101.13 65.95 65.37 30.6 27000 8 0.688 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8576 0.0000 5.5645 362.07 0.00 1.97 5130.43 14936.21 570.05 5151.89 5700.48 20088.09 0.00 1.93 5306.18 14975.26 338.69 5085.17 5644.87 20062.37 27.55 8.0 0.0 8.0 0.005-04-2025 01:301515.18 96.12 961.66 55.34 368.35 58.13 253.49 59.06 242.63 71.62 128 0.00 109.86 101.70 65.74 64.28 30.6 27000 8 0.688 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8384 0.0000 5.6028 346.82 0.00 1.97 5300.70 15046.64 338.34 5158.94 5639.04 20205.57 0.00 1.93 5060.12 15080.68 440.01 5094.34 5500.13 20176.96 27.59 8.0 0.0 8.0 0.0WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 22 START DATE:END DATE:TimeDPIGORFrac 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)Separator Inlet 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)(F)(psig) (psig) (psig)(F)(psig)(F)(psig)(F)(64ths) (%) (psig) (psig)(F) (F)(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)BS&W Properties Gas Rates & CumulativesRates and Cumulatives (Test Separator Flow Meters @ Stock Conditions)Rates and Cumulatives (Based on the BS&W Values)(Tank Farm Strap)Chemical Injection Rates5-May-2025 @ 02:00Well Head ChokeSeparator Fluid Properties Gas PropertiesSANTOS WELL TEST LEAD:Jack Landry / Pere KeniyeLOCATION / FIELD:PIKKA - NDB SANTOS REP/SUPERVISORS:Jose Gonzalez / Dan BonnarWELL NUMBER:NDBi-049EXPRO SUPERVISORS :CLIENT:Santos PROJECT DESIGN NUMBER:WT-XAK-0127.5NDBi-049 WELL CLEAN-UP DATA SHEETVictor Chavez | Jose Reynoso29-April-2025 @ 10:00EXPRO DAQ ENGINEERS:Travis Stacey | Yehia Elzeny05-04-2025 02:001515.13 96.13 961.26 55.46 364.05 57.80 250.39 58.72 239.22 71.28 128 0.00 109.97 100.86 65.49 65.05 31.4 26000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8528 0.0000 5.6414 351.69 0.00 1.97 5268.29 15156.40 458.11 5168.48 5726.40 20324.87 0.00 1.93 5193.28 15188.88 451.59 5103.75 5644.87 20294.56 27.64 8.0 0.0 8.0 0.005-04-2025 02:301515.13 96.12 962.09 55.48 364.23 58.15 250.45 59.26 237.94 70.38 128 0.00 109.84 99.79 65.79 65.40 31.4 26000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8528 0.0000 5.6800 354.39 0.00 1.97 5228.10 15265.32 454.62 5177.95 5682.72 20443.26 0.00 1.93 5193.28 15297.07 451.59 5113.16 5644.87 20412.1627.69 8.0 0.0 8.0 0.005-04-2025 03:001514.34 96.12 961.22 55.14 347.09 57.77 237.73 58.98 226.38 70.02 128 0.00 105.19 98.06 65.28 65.61 31.4 26000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8672 0.0000 5.7189 356.06 0.00 1.97 5244.00 15374.57 456.00 5187.45 5700.00 20562.01 0.00 1.93 5159.99 15404.57 448.70 5122.50 5608.69 20529.0127.74 8.0 0.0 8.0 0.005-04-2025 03:301514.52 96.13 960.28 54.64 346.23 57.97 237.87 58.48 227.30 69.57 128 0.00 104.93 98.08 65.60 65.80 31.4 26000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8624 0.0000 5.7577 355.93 0.00 1.97 5232.52 15483.58 455.00 5196.93 5687.52 20680.50 0.00 1.93 5193.28 15512.76 451.59 5131.91 5644.87 20646.6127.79 8.0 0.0 8.0 0.005-04-2025 04:0004:10 Sparged Separator. Light Solids Observed.1513.23 96.12 960.48 55.72 349.12 57.40 241.49 58.28 230.43 69.14 128 0.00 106.82 98.75 65.39 65.69 31.4 25000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8528 0.0000 5.7963 352.37 0.00 1.97 5258.13 15593.12 457.23 5206.46 5715.36 20799.57 0.00 1.93 5080.39 15618.60 564.49 5143.67 5644.87 20764.2127.84 8.0 0.0 8.0 0.005-04-2025 04:301512.71 96.12 959.43 55.48 349.97 57.83 242.33 59.07 231.25 69.94 128 0.00 106.16 99.04 65.71 65.87 31.4 25000 8 0.679 0.10 0.0 10.00 0.00 10.00 10.00 0.0000 1.8720 0.0000 5.8353 372.12 0.00 1.97 5030.64 15697.93 558.96 5218.10 5589.60 20916.02 0.00 1.93 5093.41 15724.72 442.91 5152.90 5536.32 20879.55 27.91 8.0 0.0 8.0 0.005-04-2025 05:001510.69 96.13 960.12 54.23 364.83 58.12 250.33 59.46 239.25 69.71 128 0.00 109.50 99.95 65.84 65.82 31.4 26000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8624 0.0000 5.8741 354.19 0.00 1.97 5258.13 15807.47 457.23 5227.63 5715.36 21035.09 0.00 1.93 5068.08 15830.30 323.49 5159.64 5391.58 20991.8727.96 8.0 0.0 8.0 0.005-04-2025 05:301510.16 96.12 958.19 55.08 351.41 58.28 239.36 59.51 227.18 69.93 128 0.00 105.51 98.08 65.19 64.54 31.4 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8624 0.0000 5.9129 347.45 0.00 1.97 5360.26 15919.14 342.14 5234.76 5702.40 21153.89 0.00 1.93 5093.41 15936.41 442.91 5168.87 5536.32 21107.2127.99 8.0 0.0 8.0 0.005-04-2025 06:00Collected Tracerco Standard Sample.1509.68 96.11 958.27 54.48 371.10 59.33 251.78 59.73 239.67 70.28 128 0.00 110.03 99.68 65.55 63.71 31.4 26000 8 0.679 0.10 0.0 8.00 0.00 8.00 8.00 0.0000 1.8480 0.0000 5.9514 352.58 0.00 1.97 5241.35 16028.34 455.77 5244.25 5697.12 21272.58 0.00 1.93 5317.04 16047.19 400.21 5177.20 5717.24 21226.3228.05 8.0 0.0 8.0 0.005-04-2025 06:301508.84 96.11 956.96 53.93 366.02 58.95 250.35 59.93 240.10 70.98 128 0.00 107.99 99.53 65.01 63.32 31.4 26000 8 0.679 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8528 0.0000 5.9900 350.49 0.00 1.97 5286.27 16138.47 397.89 5252.54 5684.16 21391.00 0.00 1.93 5182.43 16155.15 390.08 5185.33 5572.50 21342.4228.09 8.0 0.0 8.0 0.005-04-2025 07:001508.61 96.11 957.16 54.01 364.33 59.52 249.71 59.40 238.43 70.59 128 0.00 108.18 101.42 64.88 63.06 31.4 26000 8 0.679 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8336 0.0000 6.0282 349.58 0.00 1.97 5245.20 16247.74 394.80 5260.77 5640.00 21508.50 0.00 1.93 5115.12 16261.72 385.01 5193.35 5500.13 21457.00 28.13 8.0 0.0 8.0 0.005-04-2025 07:301507.75 96.11 957.42 54.56 358.81 59.92 247.84 59.15 236.50 70.75 128 0.00 110.79 103.10 64.83 62.85 31.4 26000 8 0.679 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8624 0.0000 6.0670 352.52 0.00 1.97 5283.14 16357.81 397.66 5269.05 5680.80 21626.85 0.00 1.93 5148.78 16368.98 387.54 5201.43 5536.32 21572.34 28.18 8.0 0.0 8.0 0.005-04-2025 08:001507.10 96.10 955.94 54.76 361.74 59.96 246.35 58.65 234.87 70.72 128 0.00 105.83 99.90 64.45 62.81 31.4 26000 8 0.679 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8528 0.0000 6.1056 348.73 0.00 1.97 5313.05 16468.50 399.91 5277.38 5712.96 21745.87 0.00 1.93 5238.15 16478.11 334.35 5208.39 5572.50 21688.4428.22 8.0 0.0 8.0 0.005-04-2025 08:301507.22 96.10 956.78 54.52 366.72 59.94 254.29 58.60 242.49 70.70 128 0.00 112.16 102.54 64.56 62.81 31.4 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8288 0.0000 6.1437 342.47 0.00 1.97 5339.95 16579.75 340.85 5284.48 5680.80 21864.22 0.00 1.93 5306.18 16588.66 338.69 5215.45 5644.87 21806.04 28.26 8.0 0.0 8.0 0.005-04-2025 09:001506.53 96.09 955.62 54.44 369.53 59.94 255.56 58.10 244.65 70.55 128 0.00 111.60 103.07 64.72 63.24 31.4 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8528 0.0000 6.1823 345.60 0.00 1.97 5361.16 16691.44 342.20 5291.61 5703.36 21983.04 0.00 1.93 5272.17 16698.49 336.52 5222.46 5608.69 21922.89 28.30 8.0 0.0 8.0 0.005-04-2025 09:301507.12 96.10 953.45 54.44 361.98 59.31 250.77 57.62 238.89 70.99 128 0.00 110.21 102.11 64.79 64.32 31.4 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8528 0.0000 6.2209 354.98 0.00 1.97 5219.48 16800.18 333.16 5298.55 5552.64 22098.72 0.00 1.93 5238.15 16807.62 334.35 5229.42 5572.50 22038.98 28.34 8.0 0.0 8.0 0.005-04-2025 10:001504.98 96.10 954.41 54.27 355.99 59.02 243.66 58.05 233.64 71.40 128 0.00 109.52 102.11 65.03 64.94 31.4 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8672 0.0000 6.2598 354.49 0.00 1.97 5267.31 16909.91 336.21 5305.56 5603.52 22215.46 0.00 1.93 5306.18 16918.17 338.69 5236.48 5644.87 22156.58 28.37 8.0 0.0 8.0 0.005-04-2025 10:301505.86 96.10 953.51 54.29 360.35 57.98 249.02 58.32 237.15 71.68 128 0.00 108.28 100.50 65.09 65.26 31.4 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8480 0.0000 6.2983 354.79 0.00 1.97 5208.65 17018.42 332.47 5312.49 5541.12 22330.90 0.00 1.93 5266.02 17027.88 306.49 5242.87 5572.50 22272.68 28.41 8.0 0.0 8.0 0.005-04-2025 11:001507.42 96.09 953.75 54.82 365.13 58.28 249.35 58.94 236.93 72.02 128 0.00 106.93 101.02 65.14 65.61 30.6 26000 8 0.679 0.10 0.0 5.50 0.00 5.50 5.50 0.0000 1.8384 0.0000 6.3366 350.05 0.00 1.97 5251.78 17127.84 305.66 5318.85 5557.44 22446.68 0.00 1.93 5170.13 17135.59 330.01 5249.74 5500.13 22387.26 28.44 8.0 0.0 8.0 0.005-04-2025 11:301505.68 96.09 952.06 55.86 354.28 58.28 247.78 58.95 236.49 72.25 128 0.00 110.91 103.96 65.38 65.43 30.6 26000 8 0.679 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8768 0.0000 6.3757 357.32 0.00 1.97 5252.42 17237.26 335.26 5325.84 5587.68 22563.09 0.00 1.93 5238.15 17244.72 334.35 5256.71 5572.50 22503.36 28.48 8.0 0.0 8.0 0.005-04-2025 12:00Collected Tracerco Standard Sample.1503.24 96.09 951.68 56.36 352.38 58.33 241.29 58.91 230.21 72.28 128 0.00 107.56 100.76 64.96 64.34 30.6 26000 8 0.684 0.10 0.0 6.00 0.00 6.00 6.00 0.0000 1.8432 0.0000 6.4141 350.77 0.00 1.97 5254.68 17346.73 335.40 5332.83 5590.08 22679.55 0.00 1.93 5148.78 17351.98 387.54 5264.78 5536.32 22618.70 28.52 8.0 0.0 8.0 0.005-04-2025 12:301503.30 96.09 953.20 55.00 371.46 58.58 256.88 59.26 244.35 73.56 128 0.00 112.48 104.90 65.06 63.83 30.6 26000 8 0.684 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8240 0.0000 6.4521 353.28 0.00 1.97 5163.06 17454.30 388.62 5340.92 5551.68 22795.21 0.00 1.93 5249.73 17461.35 395.14 5273.01 5644.87 22736.30 28.56 8.0 0.0 8.0 0.005-04-2025 13:001504.44 96.08 951.38 54.98 364.41 58.79 251.60 59.41 239.28 74.15 128 0.00 110.23 102.10 64.73 63.54 30.6 24000 8 0.684 0.10 0.0 7.00 0.00 7.00 7.00 0.0000 1.8384 0.0000 6.4904 354.35 0.00 1.97 5188.06 17562.38 390.50 5349.06 5578.56 22911.43 0.00 1.93 5266.02 17571.06 306.49 5279.40 5572.50 22852.39 28.61 8.0 0.0 8.0 0.005-04-2025 13:3013:38 Collected Core Lab sample U/S Choke Manifold sample point.1504.51 96.09 950.81 54.58 357.74 58.45 246.69 59.83 233.37 74.48 128 0.00 110.20 103.30 64.82 63.35 30.6 24000 8 0.684 0.10 0.0 5.50 0.00 5.50 5.50 0.0000 1.8288 0.0000 6.5285 351.04 0.00 1.97 5209.60 17670.92 303.20 5355.37 5512.80 23026.28 0.00 1.93 5293.88 17681.35 278.63 5285.20 5572.50 22968.48 28.64 8.0 0.0 8.0 0.005-04-2025 14:00Decreased Expro adjustable Choke to 52/64ths as per Santos WSS.1503.52 96.09 950.83 54.88 360.53 58.13 246.83 59.80 235.49 71.19 52 0.00 111.21 103.30 64.82 63.24 30.6 24000 8 0.684 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.8384 0.0000 6.5668 346.89 0.00 1.97 5299.63 17781.33 278.93 5361.18 5578.56 23142.50 0.00 1.93 5225.13 17790.21 275.01 5290.93 5500.13 23083.0728.67 8.0 0.0 8.0 0.005-04-2025 14:301523.39 96.02 938.74 55.00 433.16 57.92 370.37 58.07 215.43 69.82 52 0.00 112.05 104.92 64.27 62.52 30.6 24000 8 0.684 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.5120 0.0000 6.5983 368.95 0.00 1.97 4098.07 17866.70 215.69 5365.68 4313.76 23232.37 0.00 1.93 4193.85 17877.58 220.73 5295.53 4414.58 23175.0428.70 8.0 0.0 8.0 0.005-04-2025 15:001525.11 96.02 926.42 54.25 403.81 57.21 343.14 58.32 197.64 70.27 52 0.00 106.20 103.05 63.62 62.03 30.6 24000 8 0.684 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4976 0.0000 6.6295 376.89 0.00 1.97 3973.58 17949.48 209.14 5370.04 4182.72 23319.51 0.00 1.93 4056.35 17962.09 213.49 5299.98 4269.84 23264.0028.72 8.0 0.0 8.0 0.005-04-2025 15:3015:35 Sparged Separator. Trace Solids Observed.1525.95 96.00 919.49 54.56 399.37 56.85 341.43 57.66 197.71 69.45 52 0.00 105.40 102.40 63.20 61.87 30.6 24000 8 0.684 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4880 0.0000 6.6605 371.28 0.00 1.97 4007.78 18032.98 210.94 5374.43 4218.72 23407.40 0.00 1.93 4056.35 18046.59 213.49 5304.43 4269.84 23352.9528.74 8.0 0.0 8.0 0.005-04-2025 16:001526.91 95.99 913.44 53.73 400.35 57.33 342.45 58.33 195.51 70.30 52 0.00 105.56 101.60 63.09 61.95 30.7 24000 8 0.684 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4688 0.0000 6.6911 373.59 0.00 1.97 3931.63 18114.89 206.93 5378.74 4138.56 23493.62 0.00 1.93 4125.10 18132.53 217.11 5308.95 4342.21 23443.4128.76 8.0 0.0 8.0 0.005-04-2025 16:301527.42 96.00 907.56 53.07 402.38 57.52 342.84 58.43 197.55 70.18 52 0.00 106.24 101.20 63.23 63.01 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4880 0.0000 6.7221 371.87 0.00 1.97 4001.40 18198.25 210.60 5383.13 4212.00 23581.37 0.00 1.93 4056.35 18217.04 213.49 5313.40 4269.84 23532.3728.79 8.0 0.0 8.0 0.005-04-2025 17:001527.81 95.99 902.91 53.11 400.37 57.05 342.59 58.07 197.87 69.33 52 0.00 106.69 101.74 63.23 63.52 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4880 0.0000 6.7531 369.93 0.00 1.97 4022.38 18282.05 211.70 5387.54 4234.08 23669.58 0.00 1.93 4090.72 18302.26 215.30 5317.88 4306.03 23622.0828.81 8.0 0.0 8.0 0.005-04-2025 17:301528.04 95.99 898.41 52.03 405.19 57.10 344.36 57.36 198.27 68.45 52 0.00 106.12 101.07 63.24 63.52 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.5024 0.0000 6.7844 373.93 0.00 1.97 4017.82 18365.76 211.46 5391.94 4229.28 23757.69 0.00 1.93 4056.35 18386.77 213.49 5322.33 4269.84 23711.0328.84 8.0 0.0 8.0 0.005-04-2025 18:00Collected Tracerco Standard Sample.1528.29 95.99 895.22 52.37 402.48 56.47 343.26 58.19 198.40 68.53 52 0.00 105.98 101.33 63.15 63.57 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4976 0.0000 6.8156 371.48 0.00 1.97 4031.50 18449.75 212.18 5396.36 4243.68 23846.10 0.00 1.93 4159.48 18473.43 218.92 5326.89 4378.40 23802.2528.86 8.0 0.0 8.0 0.005-04-2025 18:301528.26 95.99 891.54 52.27 404.27 56.30 343.72 57.41 197.49 68.07 52 0.00 105.03 99.60 63.22 63.62 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.4976 0.0000 6.8468 372.11 0.00 1.97 4024.66 18533.59 211.82 5400.78 4236.48 23934.36 0.00 1.93 4090.72 18558.65 215.30 5331.38 4306.03 23891.96 28.88 8.0 0.0 8.0 0.005-04-2025 19:001528.67 95.99 888.41 52.79 403.87 56.20 343.08 57.12 198.17 68.29 52 0.00 103.91 100.28 63.09 63.64 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.4928 0.0000 6.8779 368.82 0.00 1.97 4047.46 18617.91 213.02 5405.22 4260.48 24023.12 0.00 1.93 4159.48 18645.30 218.92 5335.94 4378.40 23983.1728.91 8.0 0.0 8.0 0.005-04-2025 19:301528.59 95.99 887.06 52.29 403.53 55.80 342.82 56.90 197.52 67.80 52 0.00 103.29 99.77 63.28 63.51 30.7 24000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.4880 0.0000 6.9089 368.93 0.00 1.97 4033.32 18701.94 212.28 5409.64 4245.60 24111.57 0.00 1.93 4090.72 18730.53 215.30 5340.42 4306.03 24072.88 28.93 8.0 0.0 8.0 0.005-04-2025 20:00Decreased Expro adjustable Choke to 44/64ths as per Santos WSS.1531.16 95.99 883.81 51.36 410.48 56.19 361.59 57.20 182.97 67.72 44 0.00 101.98 99.24 62.70 63.50 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.4880 0.0000 6.9399 369.14 0.00 1.97 4031.04 18785.92 212.16 5414.06 4243.20 24199.97 0.00 1.93 4056.35 18815.04 213.49 5344.87 4269.84 24161.84 28.95 8.0 0.0 8.0 0.005-04-2025 20:301541.42 95.93 871.65 51.78 420.50 54.69 383.03 55.70 167.07 65.42 44 0.00 99.86 98.30 62.67 63.10 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.2528 0.0000 6.9660 389.20 0.00 1.97 3218.90 18852.98 169.42 5417.59 3388.32 24270.56 0.00 1.93 3300.08 18883.79 173.69 5348.49 3473.77 24234.21 28.97 8.0 0.0 8.0 0.005-04-2025 21:001542.26 95.92 859.66 50.52 422.01 54.86 384.33 55.37 169.11 65.19 44 0.00 100.29 98.72 61.95 62.48 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.2576 0.0000 6.9922 387.62 0.00 1.97 3244.44 18920.57 170.76 5421.15 3415.20 24341.71 0.00 1.93 3403.21 18954.69 179.12 5352.22 3582.32 24308.84 28.99 8.0 0.0 8.0 0.005-04-2025 21:301543.27 95.92 848.99 49.74 424.80 54.98 388.15 55.00 168.29 65.08 44 0.00 100.90 98.31 61.71 62.16 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.2768 0.0000 7.0188 393.59 0.00 1.97 3243.98 18988.16 170.74 5424.70 3414.72 24412.85 0.00 1.93 3059.45 19018.43 161.02 5355.57 3220.47 24375.93 29.01 8.0 0.0 8.0 0.005-04-2025 22:001544.38 95.92 842.92 50.10 424.04 54.66 386.51 55.01 170.50 64.79 44 0.00 99.12 96.72 61.64 61.97 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.2624 0.0000 7.0451 389.48 0.00 1.97 3241.25 19055.68 170.59 5428.26 3411.84 24483.93 0.00 1.93 3300.08 19087.18 173.69 5359.19 3473.77 24448.30 29.03 8.0 0.0 8.0 0.005-04-2025 22:30LRS Injection Pump Offline. Stopped Injecting into Well NDBi-014. Remaining produced fluids will be stored for Wireline Injectivity Test.1544.97 95.91 838.06 49.41 422.55 54.14 383.07 53.90 169.34 64.36 44 0.00 98.08 96.04 61.29 61.88 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.0000 1.2576 0.0000 7.0713 387.40 0.00 1.97 3246.26 19123.31 170.86 5431.82 3417.12 24555.12 0.00 1.93 3386.56 19157.73 159.58 5362.52 3546.14 24522.18 29.05 8.0 0.0 8.0 0.005-04-2025 23:001545.28 95.91 833.76 50.46 421.91 53.96 383.99 53.69 167.53 63.92 44 0.00 99.96 97.79 61.66 61.65 30.7 25000 8 0.678 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.2528 0.0000 7.0974 382.93 0.00 1.97 3271.60 19191.47 154.16 5435.03 3425.76 24626.49 0.00 1.93 3540.71 19231.50 186.35 5366.40 3727.06 24599.83 29.07 8.0 0.0 8.0 0.005-04-2025 23:301545.72 95.91 829.70 48.17 423.92 53.60 384.48 53.03 169.10 63.54 44 0.00 99.39 97.78 60.91 61.38 30.7 25000 8 0.678 0.10 0.0 4.50 0.00 4.50 4.50 0.0000 1.2576 0.0000 7.1236 383.86 0.00 1.97 3276.18 19259.73 154.38 5438.24 3430.56 24697.96 0.00 1.93 3300.08 19300.25 173.69 5370.02 3473.77 24672.20 29.08 8.0 0.0 8.0 0.005-05-2025 00:001546.39 95.91 824.98 47.91 423.82 53.43 385.02 52.72 170.82 63.27 44 0.00 101.36 98.31 60.88 61.01 30.7 25000 8 0.678 0.10 0.0 5.00 0.00 5.00 5.00 0.00001.2576 0.0000 7.1498 385.29 0.00 1.97 3264.05 19327.73 171.79 5441.82 3435.84 24769.54 0.00 1.93 3422.02 19371.54 124.11 5372.60 3546.14 24746.08 29.10 8.0 0.0 8.0 0.005-05-2025 00:301546.63 95.90 822.16 46.62 421.69 53.57 384.01 52.74 168.91 63.33 44 0.00 100.15 98.03 60.56 60.88 30.7 25000 8 0.678 0.10 0.0 3.50 0.00 3.50 3.50 0.00001.2528 0.0000 7.1759 377.22 0.00 1.97 3321.14 19396.92 120.46 5444.33 3441.60 24841.24 0.00 1.93 3432.73 19443.05 77.22 5374.21 3509.95 24819.20 29.12 8.0 0.0 8.0 0.005-05-2025 01:001:10 Sparged Separator. Trace Solids Observed.1546.76 95.91 819.09 47.97 424.04 53.29 385.98 52.59 168.60 63.12 44 0.00 99.08 98.57 60.32 59.71 30.7 25000 8 0.678 0.10 0.0 2.20 0.00 2.20 2.20 0.0000 1.2480 0.0000 7.2019 370.42 0.00 1.97 3369.17 19467.11 75.79 5445.91 3444.96 24913.01 0.00 1.93 3439.75 19514.72 70.20 5375.68 3509.95 24892.33 29.12 8.0 0.0 8.0 0.005-05-2025 01:3001:59 Discontinued Defoamer and Demulsifier injections.1547.10 95.92 816.26 47.51 424.38 52.97 385.64 52.43 170.21 62.92 44 0.00 101.05 98.70 59.98 59.87 30.7 25000 8 0.678 0.10 0.0 2.00 0.00 2.00 2.00 0.00001.2528 0.0000 7.2280 380.25 0.00 1.97 3294.68 19535.75 67.24 5447.31 3361.92 24983.05 0.00 1.93 3333.37 19584.16 68.03 5377.09 3401.40 24963.19 29.13 8.0 0.0 8.0 0.005-05-2025 02:00Hard Shut In @ Expro Choke Manifold. Began Well Build-Up.1547.54 95.91 811.84 46.74 441.10 52.09 434.31 51.94 133.23 62.49 0 0.00 99.59 96.03 59.74 59.95 30.7 25000 8 0.678 0.10 0.0 2.00 0.00 2.00 2.00 0.0000 1.2144 0.0000 7.2533 357.62 0.00 1.97 3395.82 19606.49 69.30 5448.76 3465.12 25055.24 0.00 1.93 3439.75 19655.82 70.20 5378.56 3509.95 25036.31 29.140.0 0.0 0.0 0.0WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 23 Santos – Pikka Development – NDBi-049 SECTION 6TEST DATA PLOTSWELL CLEAN-UP WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 24 Ϭ͘ϬϬϭϰ͘ϬϬϮϴ͘ϬϬϰϮ͘ϬϬϱϲ͘ϬϬϳϬ͘ϬϬϴϰ͘ϬϬϵϴ͘ϬϬϭϭϮ͘ϬϬϭϮϲ͘ϬϬϭϰϬ͘ϬϬϬϮϬϬϰϬϬϲϬϬϴϬϬϭϬϬϬϭϮϬϬϭϰϬϬϭϲϬϬϭϴϬϬϮϬϬϬPressure (psig)Santos - Pikka Development - NDBi-049_Well Clean-Up FlowBottom Hole Plot I/A Pressure BHP BHT O/A PressureChoke SizeTemperature (°F) / Size (64ths)WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 25 ϬϭϰϮϴϰϮϱϲϳϬϴϰϵϴϭϭϮϭϮϲϭϰϬϬϱϬϭϬϬϭϱϬϮϬϬϮϱϬϯϬϬϯϱϬϰϬϬϰϱϬϱϬϬTemperature (°F) / Size (64ths)Pressure (psig)Santos - Pikka Development - NDBi-049_Well Clean-Up FlowWell Head / Choke PlotWell Head PressureU/S Choke PressureD/S Choke PressureWell Head TemperatureU/S Choke TemperatureD/S Choke TemperatureChoke SizeWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 26 ϬϭϰϮϴϰϮϱϲϳϬϴϰϵϴϭϭϮϭϮϲϭϰϬϬϮϬϬϰϬϬϲϬϬϴϬϬϭϬϬϬϭϮϬϬϭϰϬϬϭϲϬϬϭϴϬϬϮϬϬϬTemperature (°F) / Size (64ths)Pressure (psig)Santos - Pikka Development - NDBi-049_Well Clean-Up FlowWell Head vs Bottom Hole Conditions Plot I/A PressureWell Head Pressure BHP BHTWell Head TemperatureChoke SizeWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 27 Ϭ͘ϬϭϮ͘ϬϮϰ͘Ϭϯϲ͘Ϭϰϴ͘ϬϲϬ͘ϬϳϮ͘ϬϬϭϬϬϬϮϬϬϬϯϬϬϬϰϬϬϬϱϬϬϬϲϬϬϬGas Rate (MMscf/day) / Solids Rate (stb/day) Fluid Rate (bbl/day)Santos - Pikka Development - NDBi-049_Well Clean-Up Flow Production Rate Plot - Flow MeterOil RateTotal Fluid RateWater RateTotal Gas Rate (N2+Formation)Solids, Mud & Carbolite RateNitrogen Injection RateWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 28 Ϭ͘ϬϮϬ͘ϬϰϬ͘ϬϲϬ͘ϬϴϬ͘ϬϭϬϬ͘ϬϭϮϬ͘ϬϬϭϬϬϬϮϬϬϬϯϬϬϬϰϬϬϬϱϬϬϬϲϬϬϬSolids Rate (stb/day) Fluid Rate (bbl/day)Santos - Pikka Development - NDBi-049_Well Clean-Up Flow Production Rate Plot - Tank StrapOil RateTotal Fluid RateWater RateSolids, Mud & Carbolite RateWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 29 Ϭ͘Ϭϭ͘ϱϯ͘Ϭϰ͘ϱϲ͘Ϭϳ͘ϱϵ͘ϬϬϱϬϬϬϭϬϬϬϬϭϱϬϬϬϮϬϬϬϬϮϱϬϬϬϯϬϬϬϬGas Cumulative (MMscf) / Solids Cumulative (stb) Fluid Cumulative (bbls)Santos - Pikka Development - NDBi-049_Well Clean-Up Flow Cumulative Plot - Flow MeterOil CumulativeWater CumulativeTotal Fluid CumulativeTotal Gas Cumulative (N2+Formation)Nitrogen Injection…Solids, Mud, & Carbolite CumulativeWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 30 Ϭ͘Ϭϭ͘ϱϯ͘Ϭϰ͘ϱϲ͘Ϭϳ͘ϱϵ͘ϬϬϱϬϬϬϭϬϬϬϬϭϱϬϬϬϮϬϬϬϬϮϱϬϬϬϯϬϬϬϬGas Cumulative (MMscf) / Solids Cumulative (stb) Fluid Cumulative (bbls)Santos - Pikka Development - NDBi-049_Well Clean-Up Flow Cumulative Plot - Tank StrapOil CumulativeWater CumulativeTotal Fluid CumulativeSolids, Mud, & Carbolite CumulativeWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 31 Ϭ͘ϬϬϭϬ͘ϬϬϮϬ͘ϬϬϯϬ͘ϬϬϰϬ͘ϬϬϱϬ͘ϬϬϲϬ͘ϬϬϳϬ͘ϬϬϴϬ͘ϬϬϵϬ͘ϬϬϬϭϬϬϮϬϬϯϬϬϰϬϬϱϬϬϲϬϬϳϬϬϴϬϬϵϬϬBS&W (%) / FRAC WATER RECOVERY (%)GOR (scf/stb)Santos - Pikka Development - NDBi-049_Well Clean-Up Flow Production Ratio PlotTotal GORTotal Choke BS&W(Solids, Mud, Carbolite & Water)Solids, Mud & Carbolite @ ChokeWater Cut @ ChokePercentage of Frac Water RecoveredWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 32 ϱϬϱϱϲϬϲϱϳϬϳϱϬϭϬϬϮϬϬϯϬϬϰϬϬϱϬϬTemperature (°F)Pressure (psig)Santos - Pikka Development - NDBi-049_Well Clean-Up FlowTest Separator PlotSeparator Inlet PressureSeparator PressureOil TemperatureGas TemperatureWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 33 Santos – Pikka Development – NDBi-049 SECTION 7TANK FARMRATES AND VOLUMESWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 34 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)4/29/2025 10:00 0.4 1.5 292.6 0.4 1.5 292.6 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 0.00 0.00 0.0 0.04/29/2025 10:30 6.2 22.6 271.5 0.4 1.5 292.6 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 1013.18 21.11 0.0 0.04/29/2025 11:00 6.2 22.6 271.5 8.2 30.2 263.9 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 1375.03 49.75 0.0 0.04/29/2025 11:30 11.1 40.7 253.4 8.2 30.2 263.9 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0291.1 868.44 67.85 0.0 0.04/29/2025 12:00 11.1 40.7 253.4 13.1 48.3 245.8 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 868.44 85.94 0.0 0.04/29/2025 12:30 16.8 61.8 232.3 13.1 48.3 245.8 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 1013.18 107.05 0.0 0.04/29/2025 13:00 16.8 61.8 232.3 27.5 101.0 193.1 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 2532.96 159.82 0.0 0.04/29/2025 13:30 29.5 108.6 185.5 27.5 101.0 193.1 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 2243.48 206.56 0.0 0.04/29/2025 14:00 29.5 108.6 185.5 39.4 144.7 149.3 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 2098.74 250.28 0.0 0.04/29/2025 14:30 43.5 159.8 134.3 39.4 144.7 149.3 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 2460.59 301.54 0.0 0.04/29/2025 15:00 43.5 159.8 134.3 39.4 144.7 149.3 0.4 1.5 292.6 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 2605.33 355.82 0.0 0.04/29/2025 15:30 58.7 215.6 78.5 54.1 199.0 95.1 1.2 4.5 289.5 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 2677.70 411.61 0.0 0.04/29/2025 16:00 58.7 215.6 78.5 71.4 262.3 31.7 1.2 4.5 289.5 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3039.55 474.93 0.0 0.04/29/2025 16:30 76.3 280.4 13.6 71.4 262.3 31.7 1.2 4.5 289.5 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3111.92 539.76 0.0 0.04/29/2025 17:00 76.3 280.4 13.6 71.4 262.3 31.7 19.3 70.9 223.2 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 3256.66 607.12 0.0 0.04/29/2025 17:30 76.3 280.4 13.6 71.4 262.3 31.7 19.3 70.9 223.2 19.7 72.4 221.7 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3256.66 675.45 0.0 0.04/29/2025 18:00 0.4 1.5 292.6 71.4 262.3 31.7 36.9 135.7 158.4 19.7 72.4 221.7 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3111.92 740.29 0.0 0.04/29/2025 18:30 0.4 1.5 292.6 71.4 262.3 31.7 36.9 135.7 158.4 38.6 141.7 152.3 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3329.03 809.64 0.0 0.04/29/2025 19:00 0.4 1.5 292.6 71.4 262.3 31.7 55.4 203.5 90.5 38.6 141.7 152.3 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3256.66 877.49 0.0 0.04/29/2025 19:30 0.4 1.5 292.6 0.4 1.5 292.6 55.4 203.5 90.5 57.4 211.1 83.0 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3329.03 946.84 0.0 0.04/29/2025 20:00 0.4 1.5 292.6 0.4 1.5 292.6 74.2 272.9 21.2 57.4 211.1 83.0 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3329.03 1016.20 0.0 0.04/29/2025 20:30 0.4 1.5 292.6 0.4 1.5 292.6 74.2 272.9 21.2 76.5 281.2 12.9 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3365.21 1086.31 0.0 0.04/29/2025 21:00 21.5 79.2 214.9 0.4 1.5 292.6 74.2 272.9 21.2 76.5 281.2 12.9 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 3727.06 1163.95 0.0 0.04/29/2025 21:30 21.5 79.2 214.9 0.4 1.5 292.6 74.2 272.9 21.2 76.5 281.2 12.9 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.83.0 291.1 3727.06 1163.95 0.0 0.04/29/2025 22:00 42.0 154.5 139.5 21.1 77.7 216.4 74.2 272.9 21.2 76.5 281.2 12.9 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.10.8 3.0 291.1 3618.51 1315.48 0.0 0.04/29/2025 22:30 42.0 154.5 139.5 42.9 157.6 136.5 74.2 272.9 21.2 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3835.62 1395.39 0.0 0.04/29/2025 23:00 64.6 237.5 56.6 42.9 157.6 136.5 74.2 272.9 21.2 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3980.36 1478.31 0.0 0.04/29/2025 23:30 64.6 237.5 56.6 42.9 157.6 136.5 74.2 272.9 21.2 1.2 4.5 289.5 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 3980.36 1478.31 0.0 0.04/30/2025 0:00 64.6 237.5 56.6 65.0 239.0 55.1 74.2 272.9 21.2 24.6 90.5 203.6 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 4125.10 1645.67 0.0 0.04/30/2025 0:30 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 24.6 90.5 203.6 0.8 3.0 291.1 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 4016.64 1729.35 0.0 0.04/30/2025 1:00 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 24.6 90.5 203.6 24.4 89.7 204.4 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.10.8 3.0 291.1 4161.29 1816.04 0.0 0.04/30/2025 1:30 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 24.6 90.5 203.6 24.4 89.7 204.4 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.10.8 3.0 291.1 4052.73 1900.47 2.8 43.14/30/2025 2:00 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 47.6 174.9 119.2 47.4 174.1 119.9 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 4052.73 1984.90 2.9 132.84/30/2025 2:30 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 47.6 174.9 119.2 47.4 174.1 119.9 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 4052.73 2069.33 2.9 237.74/30/2025 3:00 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 47.6 174.9 119.2 47.4 174.1 119.9 1.4 5.3 288.8 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 4016.54 2153.01 2.8 300.24/30/2025 3:30 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 47.6 174.9 119.2 47.4 174.1 119.9 24.8 91.2 202.9 8.6 31.7 262.4 0.8 3.0 291.1 0.8 3.0 291.1 0.8 3.0 291.1 4125.10 2238.95 2.9 386.54/30/2025 4:00 75.9 278.9 15.1 76.5 281.2 12.9 74.2 272.9 21.2 47.6 174.9 119.2 47.4 174.1 119.9 24.8 91.2 202.9 25.6 94.2 199.8 0.8 3.0 291.1 0.8 3.0291.1 0.8 3.0 291.1 4233.66 2327.15 2.9 471.84/30/2025 4:30 9.0 33.17 260.9 8.4 30.91 263.2 0.8 3.02 291.1 47.6 174.89 119.2 47.4 174.14 119.9 48.4 177.91 116.2 25.6 94.23 199.8 0.8 3.02 291.1 0.8 3.02 291.1 0.8 3.02 291.1 4161.29 2413.85 2.9 558.54/30/2025 5:00 9.0 33.17 260.9 8.4 30.91 263.2 0.8 3.02 291.1 47.6 174.89 119.2 47.4 174.14 119.9 48.4 177.91 116.2 49.2 180.93 113.1 0.8 3.02 291.10.8 3.02 291.1 0.8 3.02 291.1 4161.29 2500.54 2.9 646.14/30/2025 5:30 9.0 33.17 260.9 8.4 30.91 263.2 0.8 3.02 291.1 47.6 174.89 119.2 47.4 174.14 119.9 71.8 263.85 30.2 49.2 180.93 113.1 0.8 3.02 291.1 0.8 3.02 291.1 0.8 3.02 291.1 4125.10 2586.48 2.9 728.34/30/2025 6:00 9.0 33.17 260.9 8.4 30.91 263.2 0.8 3.02 291.1 34.0 125.14 168.9 27.5 101.02 193.1 71.8 263.85 30.2 72.6 266.87 27.2 0.8 3.02 291.1 0.8 3.02 291.1 0.8 3.02 291.1 4125.10 2672.42 2.9 812.04/30/2025 6:30 32.4 119.11 175.0 8.4 30.91 263.2 0.8 3.02 291.1 34.0 125.14 168.9 27.5 101.02 193.1 71.8 263.85 30.2 72.6 266.87 27.2 0.8 3.02 291.10.8 3.02 291.1 0.8 3.02 291.1 4125.10 2758.36 2.83 901.294/30/2025 7:00 32.4 119.11 175.0 32.0 117.60 176.5 0.8 3.02 291.1 11.5 42.22 251.9 5.7 21.11 273.0 71.8 263.85 30.2 72.6 266.87 27.2 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4161.29 2845.05 2.84 983.184/30/2025 7:30 55.8 205.05 89.0 32.0 117.60 176.5 0.8 3.02 291.1 11.5 42.22 251.9 5.7 21.11 273.0 71.8 263.85 30.2 72.6 266.87 27.2 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4125.10 2930.99 2.82 1060.324/30/2025 8:00 55.8 205.05 89.0 56.2 206.56 87.5 0.8 3.02 291.1 11.5 42.22 251.9 5.7 21.11 273.0 71.8 263.85 30.2 72.6 266.87 27.2 1.6 6.03 288.0 3.713.57 280.5 1.2 4.52 289.5 4269.84 3019.95 2.81 1142.734/30/2025 8:30 80.0 294.00 0.1 56.2 206.56 87.5 0.8 3.02 291.1 11.5 42.22 251.9 5.7 21.11 273.0 38.6 141.72 152.3 40.6 149.26 144.8 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4269.84 3108.90 2.83 1225.774/30/2025 9:00 80.0 294.00 0.1 80.0 294.00 0.1 0.8 3.02 291.1 11.5 42.22 251.9 5.7 21.11 273.0 26.7 98.00 196.1 29.5 108.56 185.5 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4197.47 3196.35 2.82 1309.244/30/2025 9:30 80.0 294.00 0.1 80.0 294.00 0.1 25.4 93.48 200.6 11.5 42.22 251.9 5.7 21.11 273.0 15.6 57.29 236.8 19.7 72.37 221.7 1.6 6.03 288.0 3.713.57 280.5 1.2 4.52 289.5 4342.21 3286.81 2.82 1397.424/30/2025 10:00 80.0 294.00 0.1 80.0 294.00 0.1 25.4 93.48 200.6 35.3 129.66 164.4 5.7 21.11 273.0 12.3 45.23 248.8 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4197.47 3374.26 2.82 1479.834/30/2025 10:30 80.0 294.00 0.1 80.0 294.00 0.1 25.4 93.48 200.6 35.3 129.66 164.4 5.7 21.11 273.0 12.3 45.23 248.8 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4342.21 3464.72 2.49 1567.484/30/2025 11:00 80.0 294.00 0.1 80.0 294.00 0.1 50.0 183.94 110.1 60.7 223.14 70.9 5.7 21.11 273.0 12.3 45.23 248.8 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 4486.95 3558.20 2.51 1642.934/30/2025 11:30 39.8 146.25 147.8 42.3 155.29 138.8 69.3 254.80 39.3 60.7 223.14 70.9 5.7 21.11 273.0 12.3 45.23 248.8 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 3401.40 3629.06 2.50 1712.014/30/2025 12:00 39.8 146.25 147.8 42.3 155.29 138.8 69.3 254.80 39.3 60.7 223.14 70.9 20.5 75.39 218.7 12.3 45.23 248.8 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 2605.33 3683.34 2.48 1786.754/30/2025 12:30 23.0 84.43 209.6 22.6 82.92 211.1 69.3 254.80 39.3 60.7 223.14 70.9 20.5 75.39 218.7 29.1 107.05 187.0 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 2967.18 3745.16 2.50 1861.674/30/2025 13:00 23.0 84.43 209.6 22.6 82.92 211.1 69.3 254.80 39.3 60.7 223.14 70.9 37.7 138.71 155.4 29.1 107.05 187.0 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 3039.55 3808.48 2.49 1936.484/30/2025 13:30 23.0 84.43 209.6 22.6 82.92 211.1 69.3 254.80 39.3 60.7 223.14 70.9 37.7 138.71 155.4 47.6 174.89 119.2 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 3256.66 3876.33 2.48 2011.63TANK 5 NDBi-049 WELL CLEAN-UP_TANK FARM TO INJECTION WELL NDBi-014Well:NDBi-049Start Date:29-April-2025 @ 10:00End Date:11-May-2025 @ 12:30Tank Strap Fluid CumulativeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-014TANK 6 TANK 7 TANK 8 TANK 9 TANK 10Tank Strap Fluid RateDate & TimeTANK 1 TANK 2 TANK 3 TANK 4WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 35 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)TANK 5 NDBi-049 WELL CLEAN-UP_TANK FARM TO INJECTION WELL NDBi-014Well:NDBi-049Start Date:29-April-2025 @ 10:00End Date:11-May-2025 @ 12:30Tank Strap Fluid CumulativeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-014TANK 6 TANK 7 TANK 8 TANK 9 TANK 10Tank Strap Fluid RateDate & TimeTANK 1 TANK 2 TANK 3 TANK 44/30/2025 14:00 23.0 84.43 209.6 22.6 82.92 211.1 42.3 155.29 138.8 43.5 159.82 134.3 56.6 208.06 86.0 47.6 174.89 119.2 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 3329.03 3945.68 2.49 2086.074/30/2025 14:30 16.4 60.31 233.8 15.6 57.29 236.8 42.3 155.29 138.8 43.5 159.82 134.3 56.6 208.06 86.0 67.7 248.77 45.3 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 3546.14 4019.56 2.49 2161.834/30/2025 15:00 16.4 60.31 233.8 15.6 57.29 236.8 42.3 155.29 138.8 43.5 159.82 134.3 77.5 284.96 9.1 67.7 248.77 45.3 15.2 55.79 238.3 1.6 6.03 288.0 3.7 13.57 280.5 1.2 4.52 289.5 3690.88 4096.45 2.49 2236.134/30/2025 15:30 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 77.5 284.96 9.1 67.7 248.77 45.3 15.2 55.79 238.3 1.6 6.03 288.025.4 93.48 200.6 1.2 4.52 289.5 3835.62 4176.36 2.21 2302.264/30/2025 16:00 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 62.8 230.68 63.4 60.3 221.63 72.4 15.2 55.79 238.3 1.6 6.03 288.0 25.4 93.48 200.6 23.8 87.45 206.6 3980.36 4259.29 2.18 2370.434/30/2025 16:30 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 49.2 180.93 113.1 51.3 188.46 105.6 15.2 55.79 238.3 1.6 6.03 288.0 47.6 174.89 119.2 23.8 87.45 206.6 3907.99 4340.70 2.20 2435.324/30/2025 17:00 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 44.3 162.83 131.2 42.3 155.29 138.8 15.2 55.79 238.3 1.6 6.03 288.0 47.6 174.89 119.2 47.6 174.89 119.2 4197.47 4428.15 2.20 2500.224/30/2025 17:30 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 34.5 126.65 167.4 34.0 125.14 168.9 15.2 55.79 238.3 1.6 6.03 288.0 69.3 254.80 39.3 47.6 174.89 119.2 3835.62 4508.06 2.39 2578.074/30/2025 18:00 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 34.5 126.65 167.4 34.0 125.14 168.9 15.2 55.79 238.3 1.6 6.03 288.0 69.3 254.80 39.3 71.4 262.34 31.7 4197.47 4595.51 2.34 2640.994/30/2025 18:30 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 15.2 55.79 238.3 25.2 92.72 201.3 69.3 254.80 39.3 71.4 262.34 31.7 4161.29 4682.20 2.35 2710.534/30/2025 19:00 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 38.8 142.48 151.6 25.2 92.72 201.3 69.3 254.80 39.3 71.4 262.34 31.7 4161.29 4768.89 2.59 2786.584/30/2025 19:30 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 38.8 142.48 151.6 48.8 179.42114.7 69.3 254.80 39.3 71.4 262.34 31.7 4161.29 4855.59 2.64 2866.724/30/2025 20:00 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42 114.7 69.3 254.80 39.3 71.4 262.34 31.7 4161.29 4942.28 2.61 2954.574/30/2025 20:30 16.4 60.31 233.8 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42 114.7 69.3 254.80 39.3 71.4 262.34 31.7 4197.47 5029.73 2.60 3050.694/30/2025 21:00 40.2 147.76 146.3 15.6 57.29 236.8 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42114.7 69.3 254.80 39.3 71.4 262.34 31.7 4197.47 5117.17 2.62 3100.994/30/2025 21:30 40.2 147.76 146.3 39.4 144.74 149.3 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42 114.7 13.1 48.25 245.8 15.0 55.03 239.0 4197.47 5204.62 2.64 3186.194/30/2025 22:00 63.8 234.45 59.6 39.4 144.74 149.3 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42114.7 13.1 48.25 245.8 15.0 55.03 239.0 4161.29 5291.32 2.65 3249.094/30/2025 22:30 63.8 234.45 59.6 39.4 144.74 149.3 15.6 57.29 236.8 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42114.7 13.1 48.25 245.8 15.0 55.03 239.0 4233.66 5379.52 2.62 3360.154/30/2025 23:00 63.8 234.45 59.6 39.4 144.74 149.3 39.2 143.99 150.1 18.1 66.34 227.7 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42 114.7 13.1 48.25 245.8 15.0 55.03 239.0 4161.29 5466.21 2.62 3360.154/30/2025 23:30 63.8 234.45 59.6 63.4 232.94 61.1 39.2 143.99 150.1 42.0 154.54 139.5 14.2 52.02 242.1 14.0 51.26 242.8 62.4 229.17 64.9 48.8 179.42 114.7 13.1 48.25 245.8 15.0 55.03 239.0 4233.66 5554.41 2.61 3498.265/1/2025 0:00 63.8 234.45 59.6 63.4 232.94 61.1 63.0 231.43 62.6 42.0 154.54 139.5 14.2 52.02 242.1 14.0 51.26 242.8 11.5 42.22 251.9 10.7 39.20 254.9 13.1 48.25 245.8 15.0 55.03 239.0 4197.47 5641.86 0.00 3581.865/1/2025 0:30 63.8 234.45 59.6 63.4 232.94 61.1 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 11.5 42.22 251.9 10.7 39.20 254.9 13.1 48.25 245.8 15.0 55.03 239.0 4233.66 5730.06 0.00 3581.865/1/2025 1:00 63.8 234.45 59.6 63.4 232.94 61.1 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 35.3 129.66 164.4 10.7 39.20 254.9 13.1 48.25 245.8 15.0 55.03 239.0 4197.47 5817.51 2.85 3644.295/1/2025 1:30 63.8 234.45 59.6 63.4 232.94 61.1 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 35.3 129.66 164.4 34.3 125.89 168.2 13.1 48.25 245.8 15.0 55.03 239.0 4161.29 5904.20 2.87 3730.575/1/2025 2:00 63.8 234.45 59.6 63.4 232.94 61.1 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 35.3 129.66 164.4 34.3 125.89 168.2 36.9 135.69 158.4 15.0 55.03 239.0 4197.47 5991.65 2.83 3815.835/1/2025 2:30 63.8 234.45 59.6 63.4 232.94 61.1 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 34.3 125.89 168.2 36.9 135.69 158.4 15.0 55.03 239.0 4197.47 6079.09 2.84 3903.785/1/2025 3:00 13.5 49.75 244.3 13.1 48.25 245.8 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 36.9 135.69 158.4 15.0 55.03 239.0 4233.66 6167.30 2.86 3990.735/1/2025 3:30 13.5 49.75 244.3 13.1 48.25 245.8 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 36.9 135.69 158.4 38.8 142.48 151.6 4197.47 6254.74 2.85 4072.455/1/2025 4:00 13.5 49.75 244.3 13.1 48.25 245.8 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 60.9 223.90 70.2 38.8 142.48 151.6 4233.66 6342.94 3.00 4159.885/1/2025 4:30 13.5 49.75 244.3 13.1 48.25 245.8 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 60.9 223.90 70.2 63.0 231.43 62.6 4269.84 6431.90 3.03 4251.695/1/2025 5:00 37.7 138.71 155.4 13.1 48.25 245.8 63.0 231.43 62.6 66.0 242.74 51.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 60.9 223.90 70.2 63.0 231.43 62.6 4228.80 6520.00 3.01 4357.315/1/2025 5:30 37.7 138.71 155.4 40.8 150.02 144.1 9.6 35.43 258.6 13.5 49.75 244.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 60.9 223.90 70.2 63.0 231.43 62.6 4884.99 6622.62 3.43 4449.485/1/2025 6:00 63.2 232.19 61.9 40.8 150.02 144.1 9.6 35.43 258.6 13.5 49.75 244.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.0 60.9 223.90 70.2 63.0 231.43 62.6 4486.95 6716.10 3.43 4531.465/1/2025 6:30 63.2 232.19 61.9 64.8 238.22 55.9 9.6 35.43 258.6 13.5 49.75 244.3 14.2 52.02 242.1 14.0 51.26 242.8 59.1 217.11 77.0 58.2 214.10 80.060.9 223.90 70.2 63.0 231.43 62.6 4233.66 6804.30 3.42 4645.835/1/2025 7:00 74.0 272.14 21.9 74.9 275.16 18.9 9.6 35.43 258.6 13.5 49.75 244.3 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.550.0 183.94 110.1 52.1 191.48 102.6 3654.70 6880.44 3.43 4747.715/1/2025 7:30 74.0 272.14 21.9 74.9 275.16 18.9 28.3 104.03 190.0 13.5 49.75 244.3 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.5 36.1 132.68 161.4 38.2 140.22 153.9 3292.84 6949.04 3.43 4747.715/1/2025 8:00 74.0 272.14 21.9 74.9 275.16 18.9 28.3 104.03 190.0 32.4 119.11 175.0 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.5 23.0 84.43 209.6 26.3 96.49 197.6 3329.03 7018.40 3.43 4952.875/1/2025 8:30 74.0 272.14 21.9 74.9 275.16 18.9 45.9 168.86 125.2 32.4 119.11 175.0 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3111.92 7083.23 2.40 5029.635/1/2025 9:00 74.0 272.14 21.9 74.9 275.16 18.9 45.9 168.86 125.2 50.5 185.45 108.6 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3184.29 7149.57 2.00 5093.965/1/2025 9:30 55.8 205.05 89.0 54.6 200.53 93.5 64.8 238.22 55.9 50.5 185.45 108.6 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3329.03 7218.93 2.04 5158.335/1/2025 10:00 48.0 176.40 117.7 47.2 173.39 120.7 64.8 238.22 55.9 68.9 253.30 40.8 14.2 52.02 242.1 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3256.66 7286.77 2.05 5219.815/1/2025 10:30 39.6 145.49 148.6 38.4 140.97 153.1 64.8 238.22 55.9 68.9 253.30 40.8 32.6 119.86 174.2 14.0 51.26 242.8 18.9 69.35 224.7 17.0 62.57231.5 15.4 56.54 237.5 17.4 64.08 230.0 3256.66 7354.62 2.05 5303.885/1/2025 11:00 31.6 116.09 178.0 30.8 113.08 181.0 64.8 238.22 55.9 68.9 253.30 40.8 32.6 119.86 174.2 32.8 120.62 173.5 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3329.03 7423.97 2.05 5340.055/1/2025 11:30 24.0 88.20 205.9 22.8 83.68 210.4 64.8 238.22 55.9 68.9 253.30 40.8 50.5 185.45 108.6 32.8 120.62 173.5 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3148.10 7489.56 2.06 5400.235/1/2025 12:00 16.4 60.31 233.8 15.6 57.29 236.8 64.8 238.22 55.9 68.9 253.30 40.8 50.5 185.45 108.6 52.3 192.23 101.8 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3437.58 7561.18 2.04 5463.315/1/2025 12:30 16.4 60.31 233.8 15.6 57.29 236.8 57.0 209.57 84.5 58.7 215.60 78.5 69.7 256.31 37.8 52.3 192.23 101.8 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3401.40 7632.04 1.80 5520.835/1/2025 13:00 16.4 60.31 233.8 15.6 57.29 236.8 50.0 183.94 110.1 51.3 188.46 105.6 69.7 256.31 37.8 73.0 268.37 25.7 18.9 69.35 224.7 17.0 62.57 231.5 15.4 56.54 237.5 17.4 64.08 230.0 3654.69 7708.18 1.84 5575.405/1/2025 13:30 16.4 60.31 233.8 15.6 57.29 236.8 42.3 155.29 138.8 43.5 159.82 134.3 69.7 256.31 37.8 73.0 268.37 25.7 39.8 146.25 147.8 17.0 62.57231.5 15.4 56.54 237.5 17.4 64.08 230.0 3690.88 7785.07 1.83 5643.905/1/2025 14:00 16.4 60.31 233.8 15.6 57.29 236.8 34.5 126.65 167.4 36.5 134.19 159.9 69.7 256.31 37.8 73.0 268.37 25.7 39.8 146.25 147.8 40.4 148.51 145.6 15.4 56.54 237.5 17.4 64.08 230.0 4125.10 7871.01 2.51 5684.695/1/2025 14:30 16.4 60.31 233.8 15.6 57.29 236.8 24.4 89.71 204.4 26.1 95.74 198.3 69.7 256.31 37.8 73.0 268.37 25.7 64.0 235.20 58.9 40.4 148.51 145.6 15.4 56.54 237.5 17.4 64.08 230.0 4269.84 7959.97 2.51 5763.055/1/2025 15:00 16.4 60.31 233.8 15.6 57.29 236.8 16.4 60.31 233.8 18.9 69.35 224.7 69.7 256.31 37.8 73.0 268.37 25.7 64.0 235.20 58.9 66.7 245.00 49.1 15.4 56.54 237.5 17.4 64.08 230.0 4631.69 8056.46 2.50 5837.755/1/2025 15:30 16.4 60.31 233.8 15.6 57.29 236.8 16.4 60.31 233.8 18.9 69.35 224.7 59.1 217.11 77.0 58.2 214.10 80.0 64.0 235.20 58.9 66.7 245.00 49.1 41.8 153.79 140.3 17.4 64.08 230.0 4667.88 8153.71 2.49 5912.895/1/2025 16:00 16.4 60.31 233.8 15.6 57.29 236.8 16.4 60.31 233.8 18.9 69.35 224.7 47.0 172.63 121.4 45.9 168.86 125.2 64.0 235.20 58.9 66.7 245.0049.1 41.8 153.79 140.3 42.7 156.80 137.3 4450.77 8246.43 2.79 5993.775/1/2025 16:30 16.4 60.31 233.8 15.6 57.29 236.8 16.4 60.31 233.8 18.9 69.35 224.7 34.9 128.16 165.9 33.2 122.12 171.9 64.0 235.20 58.9 66.7 245.0049.1 68.9 253.30 40.8 42.7 156.80 137.3 4776.43 8345.94 3.21 6087.565/1/2025 17:00 16.4 60.31 233.8 15.6 57.29 236.8 16.4 60.31 233.8 18.9 69.35 224.7 34.9 128.16 165.9 33.2 122.12 171.9 64.0 235.20 58.9 66.7 245.0049.1 68.9 253.30 40.8 69.7 256.31 37.8 4776.43 8445.45 3.42 6189.745/1/2025 17:30 44.7 164.34 129.7 15.6 57.29 236.8 16.4 60.31 233.8 18.9 69.35 224.7 19.9 73.12 220.9 18.9 69.35 224.7 53.3 196.00 98.1 52.9 194.49 99.6 68.9 253.30 40.8 69.7 256.31 37.8 4993.54 8549.48 3.38 6291.03WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 36 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)TANK 5 NDBi-049 WELL CLEAN-UP_TANK FARM TO INJECTION WELL NDBi-014Well:NDBi-049Start Date:29-April-2025 @ 10:00End Date:11-May-2025 @ 12:30Tank Strap Fluid CumulativeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-014TANK 6 TANK 7 TANK 8 TANK 9 TANK 10Tank Strap Fluid RateDate & TimeTANK 1 TANK 2 TANK 3 TANK 45/1/2025 18:00 44.7 164.34 129.7 42.3 155.29 138.8 16.4 60.31 233.8 18.9 69.35 224.7 19.9 73.12 220.9 18.9 69.35 224.7 53.3 196.00 98.1 52.9 194.4999.6 68.9 253.30 40.8 69.7 256.31 37.8 4704.06 8647.48 3.40 6388.395/1/2025 18:30 70.6 259.33 34.7 42.3 155.29 138.8 16.4 60.31 233.8 18.9 69.35 224.7 19.9 73.12 220.9 18.9 69.35 224.7 53.3 196.00 98.1 52.9 194.49 99.6 68.9 253.30 40.8 69.7 256.31 37.8 4559.32 8742.47 3.46 6496.045/1/2025 19:00 70.6 259.33 34.7 69.3 254.80 39.3 16.4 60.31 233.8 18.9 69.35 224.7 19.9 73.12 220.9 18.9 69.35 224.7 14.0 51.26 242.8 12.3 45.23 248.8 68.9 253.30 40.8 69.7 256.31 37.8 4776.43 8841.98 3.55 6605.525/1/2025 19:30 70.6 259.33 34.7 69.3 254.80 39.3 43.7 160.57 133.5 18.9 69.35 224.7 19.9 73.12 220.9 18.9 69.35 224.7 14.0 51.26 242.8 12.3 45.23 248.8 68.9 253.30 40.8 69.7 256.31 37.8 4812.62 8942.24 3.40 6700.115/1/2025 20:00 70.6 259.33 34.7 69.3 254.80 39.3 43.7 160.57 133.5 45.9 168.86 125.2 19.9 73.12 220.9 18.9 69.35 224.7 14.0 51.26 242.8 12.3 45.23 248.8 68.9 253.30 40.8 69.7 256.31 37.8 4776.43 9041.75 3.37 6807.195/1/2025 20:30 70.6 259.33 34.7 69.3 254.80 39.3 70.6 259.33 34.7 45.9 168.86 125.2 19.9 73.12 220.9 18.9 69.35 224.7 14.0 51.26 242.8 12.3 45.23 248.8 68.9 253.30 40.8 69.7 256.31 37.8 4776.43 9041.75 3.45 6909.225/1/2025 21:00 70.6 259.33 34.7 69.3 254.80 39.3 70.6 259.33 34.7 70.6 259.33 34.7 19.9 73.12 220.9 18.9 69.35 224.7 14.0 51.26 242.8 12.3 45.23 248.8 10.7 39.20 254.9 13.3 49.00 245.1 4342.21 9230.97 3.44 7015.965/1/2025 21:30 70.6 259.33 34.7 69.3 254.80 39.3 70.6 259.33 34.7 70.6 259.33 34.7 46.4 170.37 123.7 18.9 69.35 224.7 14.0 51.26 242.8 12.3 45.23 248.8 10.7 39.20 254.9 13.3 49.00 245.1 4667.88 9328.21 3.38 7118.145/1/2025 22:00 70.6 259.33 34.7 69.3 254.80 39.3 70.6 259.33 34.7 70.6 259.33 34.7 46.4 170.37 123.7 43.5 159.82 134.3 14.0 51.26 242.8 12.3 45.23 248.8 10.7 39.20 254.9 13.3 49.00 245.1 4342.21 9418.68 3.38 7213.625/1/2025 22:30 70.6 259.33 34.7 69.3 254.80 39.3 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 43.5 159.82 134.3 14.0 51.26 242.8 12.3 45.23 248.8 10.7 39.20 254.9 13.3 49.00 245.1 4667.88 9515.92 3.46 7324.545/1/2025 23:00 12.7 46.74 247.3 12.3 45.23 248.8 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 69.1 254.05 40.0 14.0 51.26 242.8 12.3 45.23 248.8 10.7 39.20 254.9 13.3 49.00 245.1 4523.14 9610.16 3.45 7412.435/1/2025 23:30 12.7 46.74 247.3 12.3 45.23 248.8 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 69.1 254.05 40.0 40.4 148.51 145.6 12.3 45.23 248.8 10.7 39.20 254.9 13.3 49.00 245.1 4667.88 9707.40 3.37 7553.995/2/2025 0:00 12.7 46.74 247.3 12.3 45.23 248.8 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 69.1 254.05 40.0 40.4 148.51 145.6 34.7 127.40 166.7 10.7 39.20 254.9 13.3 49.00 245.1 3944.17 9789.57 0.00 7621.255/2/2025 0:30 12.7 46.74 247.3 12.3 45.23 248.8 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 34.7 127.40 166.7 10.7 39.20 254.9 13.3 49.00 245.1 4559.32 9884.56 0.00 7621.255/2/2025 1:00 12.7 46.74 247.3 12.3 45.23 248.8 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 61.9 227.66 66.4 10.7 39.20 254.9 13.3 49.00 245.1 4812.62 9984.82 3.35 7662.115/2/2025 1:30 12.7 46.74 247.3 12.3 45.23 248.8 70.6 259.33 34.7 70.6 259.33 34.7 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 61.9 227.66 66.4 37.5 137.96 156.1 13.3 49.00 245.1 4740.25 10083.58 3.37 7766.165/2/2025 2:00 12.7 46.74 247.3 12.3 45.23 248.8 10.9 39.95 254.1 14.2 52.02 242.1 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 61.9 227.66 66.4 37.5 137.96 156.1 39.2 143.99 150.1 4559.32 10178.56 3.37 7868.465/2/2025 2:30 12.7 46.74 247.3 12.3 45.23 248.8 10.9 39.95 254.1 14.2 52.02 242.1 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 39.2 143.99 150.1 4595.51 10274.30 3.64 7957.395/2/2025 3:00 12.7 46.74 247.3 12.3 45.23 248.8 10.9 39.95 254.1 14.2 52.02 242.1 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 65.4 240.48 53.6 4631.69 10370.80 3.71 8082.745/2/2025 3:30 38.4 140.97 153.1 12.3 45.23 248.8 10.9 39.95 254.1 14.2 52.02 242.1 72.8 267.62 26.5 69.1 254.05 40.0 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 65.4 240.48 53.6 4523.14 10465.03 3.73 8193.385/2/2025 4:00 38.4 140.97 153.1 39.6 145.49 148.6 10.9 39.95 254.1 14.2 52.02 242.1 13.1 48.25 245.8 11.7 42.97 251.1 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 65.4 240.48 53.6 4812.62 10565.29 3.73 8303.015/2/2025 4:30 65.4 240.48 53.6 39.6 145.49 148.6 10.9 39.95 254.1 14.2 52.02 242.1 13.1 48.25 245.8 11.7 42.97 251.1 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 65.4 240.48 53.6 4776.43 10664.80 3.64 8416.125/2/2025 5:00 65.4 240.48 53.6 39.6 145.49 148.6 10.9 39.95 254.1 14.2 52.02 242.1 13.1 48.25 245.8 11.7 42.97 251.1 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 65.4 240.48 53.6 4631.73 10761.29 3.74 8527.115/2/2025 5:30 65.4 240.48 53.6 65.8 241.99 52.1 37.1 136.45 157.6 14.2 52.02 242.1 13.1 48.25 245.8 11.7 42.97 251.1 66.2 243.50 50.6 61.9 227.66 66.4 63.6 233.70 60.4 65.4 240.48 53.6 4631.69 10857.79 3.74 8640.715/2/2025 6:00 65.4 240.48 53.6 65.8 241.99 52.1 37.1 136.45 157.6 42.0 154.54 139.5 13.1 48.25 245.8 11.7 42.97 251.1 12.5 45.99 248.1 10.5 38.45 255.6 63.6 233.70 60.4 65.4 240.48 53.6 4921.17 10960.31 3.63 8782.915/2/2025 6:30 65.4 240.48 53.6 65.8 241.99 52.1 65.0 238.97 55.1 42.0 154.54 139.5 13.1 48.25 245.8 11.7 42.97 251.1 12.5 45.99 248.1 10.5 38.45 255.6 40.6 149.26 144.8 43.1 158.31 135.8 4921.17 11062.84 3.71 8900.465/2/2025 7:00 65.4 240.48 53.6 65.8 241.99 52.1 65.0 238.97 55.1 66.0 242.74 51.3 13.1 48.25 245.8 11.7 42.97 251.1 12.5 45.99 248.1 10.5 38.45 255.6 26.5 97.25 196.8 29.5 108.56 185.5 4233.66 11151.04 3.71 8900.465/2/2025 7:30 65.4 240.48 53.6 65.8 241.99 52.1 65.0 238.97 55.1 66.0 242.74 51.3 39.4 144.74 149.3 11.7 42.97 251.1 12.5 45.99 248.1 10.5 38.45 255.6 15.8 58.05 236.0 18.5 67.85 226.2 4631.69 11247.53 3.60 9081.565/2/2025 8:00 47.0 172.63 121.4 47.2 173.39 120.7 65.0 238.97 55.1 66.0 242.74 51.3 39.4 144.74 149.3 36.3 133.43 160.6 12.5 45.99 248.1 10.5 38.45255.6 15.8 58.05 236.0 18.5 67.85 226.2 4342.21 11337.99 3.61 9193.285/2/2025 8:30 32.0 117.60 176.5 32.0 117.60 176.5 65.0 238.97 55.1 66.0 242.74 51.3 39.4 144.74 149.3 66.0 242.74 51.3 12.5 45.99 248.1 10.5 38.45 255.6 15.8 58.05 236.0 18.5 67.85 226.2 4704.06 11436.00 3.71 9301.915/2/2025 9:00 16.4 60.31 233.8 16.6 61.06 233.0 65.0 238.97 55.1 66.0 242.74 51.3 62.4 229.17 64.9 66.0 242.74 51.3 12.5 45.99 248.1 10.5 38.45 255.6 15.8 58.05 236.0 18.5 67.85 226.2 4595.51 11531.74 3.70 9410.405/2/2025 9:30 16.4 60.31 233.8 16.6 61.06 233.0 50.3 184.69 109.4 52.9 194.49 99.6 66.0 242.74 51.3 62.4 229.17 64.9 37.7 138.71 155.4 10.5 38.45 255.6 15.8 58.05 236.0 18.5 67.85 226.2 4450.77 11624.46 3.72 9522.215/2/2025 10:00 16.4 60.31 233.8 16.6 61.06 233.0 34.7 127.40 166.7 38.4 140.97 153.1 66.0 242.74 51.3 62.4 229.17 64.9 37.7 138.71 155.4 35.7 131.17 162.9 15.8 58.05 236.0 18.5 67.85 226.2 4450.77 11717.18 3.72 9634.255/2/2025 10:30 16.4 60.31 233.8 16.6 61.06 233.0 19.5 71.62 222.5 24.8 91.22 202.9 66.0 242.74 51.3 62.4 229.17 64.9 63.6 233.70 60.4 35.7 131.17 162.9 15.8 58.05 236.0 18.5 67.85 226.2 4559.32 11812.17 3.72 9743.005/2/2025 11:00 16.4 60.31 233.8 16.6 61.06 233.0 16.4 60.31 233.8 21.1 77.65 216.4 55.0 202.03 92.0 49.0 180.17 113.9 63.6 233.70 60.4 61.7 226.91 67.2 15.8 58.05 236.0 18.5 67.85 226.2 4595.51 11907.91 3.78 9855.795/2/2025 11:30 16.4 60.31 233.8 16.6 61.06 233.0 16.4 60.31 233.8 21.1 77.65 216.4 38.2 140.22 153.9 36.1 132.68 161.4 63.6 233.70 60.4 61.7 226.9167.2 42.0 154.54 139.5 18.5 67.85 226.2 4631.69 12004.40 3.71 9967.075/2/2025 12:00 16.4 60.31 233.8 16.6 61.06 233.0 16.4 60.31 233.8 21.1 77.65 216.4 24.8 91.22 202.9 22.4 82.17 211.9 63.6 233.70 60.4 61.7 226.91 67.2 42.0 154.54 139.5 44.3 162.83 131.2 4559.32 12099.39 3.69 10078.115/2/2025 12:30 16.4 60.31 233.8 16.6 61.06 233.0 16.4 60.31 233.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 63.6 233.70 60.4 61.7 226.91 67.2 68.1 250.28 43.8 44.3 162.83 131.2 4595.51 12195.13 3.02 10173.185/2/2025 13:00 16.4 60.31 233.8 16.6 61.06 233.0 16.4 60.31 233.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 52.5 192.99 101.1 47.6 174.89 119.2 68.1 250.28 43.8 70.3 258.57 35.5 4595.51 12290.87 3.03 10262.185/2/2025 13:30 41.8 153.79 140.3 16.6 61.06 233.0 16.4 60.31 233.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 39.4 144.74 149.3 36.1 132.68161.4 68.1 250.28 43.8 70.3 258.57 35.5 4486.95 12384.35 3.01 10355.855/2/2025 14:00 41.8 153.79 140.3 43.5 159.82 134.3 16.4 60.31 233.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 27.5 101.02 193.1 25.4 93.48200.6 68.1 250.28 43.8 70.3 258.57 35.5 4740.25 12483.10 2.99 10446.795/2/2025 14:30 68.3 251.03 43.0 43.5 159.82 134.3 16.4 60.31 233.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26 242.8 68.1 250.28 43.8 70.3 258.57 35.5 4667.88 12580.35 2.99 10534.835/2/2025 15:00 68.3 251.03 43.0 69.9 257.06 37.0 16.4 60.31 233.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26 242.8 68.1 250.28 0.0 58.7 215.60 78.5 4667.88 12677.60 2.99 10620.055/2/2025 15:30 68.3 251.03 43.0 69.9 257.06 37.0 43.1 158.31 135.8 21.1 77.65 216.4 11.7 42.97 251.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26 242.8 43.9 161.33 132.7 46.1 169.62 124.5 4704.06 12775.60 2.98 10711.085/2/2025 16:00 68.3 251.03 43.0 69.9 257.06 37.0 43.1 158.31 135.8 48.4 177.91 116.2 11.7 42.97 251.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26 242.8 32.8 120.62 173.5 35.9 131.92 162.1 4812.62 12875.86 2.99 1080.045/2/2025 16:30 68.3 251.03 43.0 69.9 257.06 37.0 68.5 251.79 42.3 48.4 177.91 116.2 11.7 42.97 251.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26 242.8 20.9 76.89 217.2 23.0 84.43 209.6 4486.95 12969.34 2.97 10891.635/2/2025 17:00 68.3 251.03 43.0 69.9 257.06 37.0 68.5 251.79 42.3 76.3 280.43 13.6 11.7 42.97 251.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26 242.8 15.4 56.54 237.5 17.4 64.08 230.0 4921.17 13071.86 2.88 10980.375/2/2025 17:30 51.7 189.97 104.1 51.3 188.46 105.6 68.5 251.79 42.3 76.3 280.43 13.6 39.2 143.99 150.1 11.1 40.71 253.4 15.2 55.79 238.3 14.0 51.26242.8 15.4 56.54 237.5 17.4 64.08 230.0 4848.80 13172.88 3.01 11070.105/2/2025 18:00 51.7 189.97 104.1 51.3 188.46 105.6 68.5 251.79 42.3 76.3 280.43 13.6 39.2 143.99 150.1 38.6 141.72 152.3 15.2 55.79 238.3 14.0 51.26 242.8 15.4 56.54 237.5 17.4 64.08 230.0 4848.80 13273.90 3.01 11158.195/2/2025 18:30 51.7 189.97 104.1 51.3 188.46 105.6 68.5 251.79 42.3 76.3 280.43 13.6 66.5 244.25 49.8 38.6 141.72 152.3 15.2 55.79 238.3 14.0 51.26242.8 15.4 56.54 237.5 17.4 64.08 230.0 4848.80 13374.16 3.01 11286.785/2/2025 19:00 17.2 63.32 230.7 17.6 64.83 229.2 68.5 251.79 42.3 76.3 280.43 13.6 66.5 244.25 49.8 65.4 240.48 53.6 15.2 55.79 238.3 14.0 51.26 242.8 15.4 56.54 237.5 17.4 64.08 230.0 4740.25 13472.91 3.02 11377.205/2/2025 19:30 17.2 63.32 230.7 17.6 64.83 229.2 68.5 251.79 42.3 76.3 280.43 13.6 66.5 244.25 49.8 65.4 240.48 53.6 42.9 157.56 136.5 14.0 51.26 242.8 15.4 56.54 237.5 17.4 64.08 230.0 4884.99 13574.68 3.01 11446.225/2/2025 20:00 17.2 63.32 230.7 17.6 64.83 229.2 68.5 251.79 42.3 76.3 280.43 13.6 66.5 244.25 49.8 65.4 240.48 53.6 42.9 157.56 136.5 41.4 152.28 141.8 15.4 56.54 237.5 17.4 64.08 230.0 4848.80 13675.70 3.02 11532.615/2/2025 20:30 17.2 63.32 230.7 17.6 64.83 229.2 68.5 251.79 42.3 76.3 280.43 13.6 66.5 244.25 49.8 65.4 240.48 53.6 70.3 258.57 35.5 41.4 152.28 141.8 15.4 56.54 237.5 17.4 64.08 230.0 4848.80 13776.72 3.01 11616.535/2/2025 21:00 17.2 63.32 230.7 17.6 64.83 229.2 68.5 251.79 42.3 76.3 280.43 13.6 66.5 244.25 49.8 65.4 240.48 53.6 70.3 258.57 35.5 68.7 252.54 41.5 15.4 56.54 237.5 17.4 64.08 230.0 4812.62 13876.98 3.02 11702.925/2/2025 21:30 17.2 63.32 230.7 17.6 64.83 229.2 12.5 45.99 248.1 15.6 57.29 236.8 66.5 244.25 49.8 65.4 240.48 53.6 70.3 258.57 35.5 68.7 252.54 41.5 43.1 158.31 135.8 17.4 64.08 230.0 4884.99 13978.75 3.13 11794.50WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 37 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)TANK 5 NDBi-049 WELL CLEAN-UP_TANK FARM TO INJECTION WELL NDBi-014Well:NDBi-049Start Date:29-April-2025 @ 10:00End Date:11-May-2025 @ 12:30Tank Strap Fluid CumulativeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-014TANK 6 TANK 7 TANK 8 TANK 9 TANK 10Tank Strap Fluid RateDate & TimeTANK 1 TANK 2 TANK 3 TANK 45/2/2025 22:00 17.2 63.32 230.7 17.6 64.83 229.2 12.5 45.99 248.1 15.6 57.29 236.8 66.5 244.25 49.8 65.4 240.48 53.6 70.3 258.57 35.5 68.7 252.54 41.5 43.1 158.31 135.8 45.3 166.60 127.5 4921.17 14081.28 3.01 11899.305/2/2025 22:30 17.2 63.32 230.7 17.6 64.83 229.2 12.5 45.99 248.1 15.6 57.29 236.8 66.5 244.25 49.8 65.4 240.48 53.6 70.3 258.57 35.5 68.7 252.54 41.5 69.9 257.06 37.0 45.3 166.60 127.5 4740.25 14180.03 3.03 11981.205/2/2025 23:00 17.2 63.32 230.7 17.6 64.83 229.2 12.5 45.99 248.1 15.6 57.29 236.8 66.5 244.25 49.8 65.4 240.48 53.6 70.3 258.57 35.5 68.7 252.54 41.5 69.9 257.06 37.0 73.0 268.37 25.7 4884.99 14281.80 3.41 12074.785/2/2025 23:30 44.7 164.34 129.7 17.6 64.83 229.2 12.5 45.99 248.1 15.6 57.29 236.8 23.0 84.43 209.6 21.9 80.66 213.4 70.3 258.57 35.5 68.7 252.54 41.5 69.9 257.06 37.0 73.0 268.37 25.7 4848.80 14382.82 3.42 12176.025/3/2025 0:00 44.7 164.34 129.7 44.7 164.34 129.7 12.5 45.99 248.1 15.6 57.29 236.8 23.0 84.43 209.6 21.9 80.66 213.4 70.3 258.57 35.5 68.7 252.54 41.5 69.9 257.06 37.0 73.0 268.37 25.7 4776.43 14482.33 0.00 12273.285/3/2025 0:30 72.2 265.36 28.7 44.7 164.34 129.7 12.5 45.99 248.1 15.6 57.29 236.8 23.0 84.43 209.6 21.9 80.66 213.4 70.3 258.57 35.5 68.7 252.54 41.5 69.9 257.06 37.0 73.0 268.37 25.7 4848.80 14583.30 0.00 12273.285/3/2025 1:00 72.2 265.36 28.7 72.2 265.36 28.7 12.5 45.99 248.1 15.6 57.29 236.8 23.0 84.43 209.6 21.9 80.66 213.4 70.3 258.57 35.5 68.7 252.54 41.5 69.9 257.06 37.0 73.0 268.37 25.7 4848.80 14684.36 3.80 12384.635/3/2025 1:30 72.2 265.36 28.7 72.2 265.36 28.7 40.2 147.76 146.3 15.6 57.29 236.8 23.0 84.43 209.6 21.9 80.66 213.4 23.8 87.45 206.6 21.7 79.91 214.2 69.9 257.06 37.0 73.0 268.37 25.7 4884.99 14786.13 3.68 12488.885/3/2025 2:00 72.2 265.36 28.7 72.2 265.36 28.7 40.2 147.76 146.3 42.9 157.56 136.5 23.0 84.43 209.6 21.9 80.66 213.4 23.8 87.45 206.6 21.7 79.91 214.2 69.9 257.06 37.0 73.0 268.37 25.7 4812.62 14886.39 3.74 12604.225/3/2025 2:30 72.2 265.36 28.7 72.2 265.36 28.7 67.9 249.53 44.5 42.9 157.56 136.5 23.0 84.43 209.6 21.9 80.66 213.4 23.8 87.45 206.6 21.7 79.91 214.2 69.9 257.06 37.0 73.0 268.37 25.7 4884.99 14988.16 3.76 12711.905/3/2025 3:00 72.2 265.36 28.7 72.2 265.36 28.7 67.9 249.53 44.5 72.2 265.36 28.7 23.0 84.43 209.6 21.9 80.66 213.4 23.8 87.45 206.6 21.7 79.91 214.2 69.9 257.06 37.0 73.0 268.37 25.7 5174.47 15095.97 3.76 12826.275/3/2025 3:30 72.2 265.36 28.7 72.2 265.36 28.7 67.9 249.53 44.5 72.2 265.36 28.7 50.5 185.45 108.6 21.9 80.66 213.4 23.8 87.45 206.6 21.7 79.91 214.2 13.1 48.25 245.8 15.2 55.79 238.3 4848.80 15196.98 3.77 12947.395/3/2025 4:00 72.2 265.36 28.7 72.2 265.36 28.7 67.9 249.53 44.5 72.2 265.36 28.7 50.5 185.45 108.6 49.6 182.43 111.6 23.8 87.45 206.6 21.7 79.91 214.2 13.1 48.25 245.8 15.2 55.79 238.3 4884.99 15298.75 3.76 13048.295/3/2025 4:30 72.2 265.36 28.7 72.2 265.36 28.7 67.9 249.53 44.5 72.2 265.36 28.7 77.1 283.45 10.6 49.6 182.43 111.6 23.8 87.45 206.6 21.7 79.91 214.2 13.1 48.25 245.8 15.2 55.79 238.3 4704.06 15396.75 3.76 13166.185/3/2025 5:00 72.2 265.36 28.7 72.2 265.36 28.7 67.9 249.53 44.5 72.2 265.36 28.7 77.1 283.45 10.6 49.6 182.43 111.6 23.8 87.45 206.6 21.7 79.91 214.2 13.1 48.25 245.8 15.2 55.79 238.3 4884.99 15498.53 3.76 13275.125/3/2025 5:30 13.1 48.25 245.8 12.3 45.23 248.8 67.9 249.53 44.5 72.2 265.36 28.7 77.1 283.45 10.6 49.6 182.43 111.6 5.1 18.85 275.2 21.7 79.91 214.2 13.1 48.25 245.8 15.2 55.79 238.3 4884.99 15600.30 3.77 13390.985/3/2025 6:00 13.1 48.25 245.8 12.3 45.23 248.8 46.4 170.37 123.7 50.5 185.45 108.6 77.1 283.45 10.6 49.6 182.43 111.6 51.5 189.22 104.9 48.8 179.42 114.7 13.1 48.25 245.8 15.2 55.79 238.3 4776.43 15699.81 3.77 13503.675/3/2025 6:30 13.1 48.25 245.8 12.3 45.23 248.8 31.2 114.59 179.5 36.5 134.19 159.9 77.1 283.45 10.6 49.6 182.43 111.6 79.2 290.99 3.1 48.8 179.42 114.7 13.1 48.25 245.8 15.2 55.79 238.3 4884.99 15801.58 3.77 13615.975/3/2025 7:00 13.1 48.25 245.8 12.3 45.23 248.8 15.6 57.29 236.8 20.5 75.39 218.7 77.1 283.45 10.6 49.6 182.43 111.6 79.2 290.99 3.1 76.9 282.70 11.4 13.1 48.25 245.8 15.2 55.79 238.3 4957.36 15904.85 3.77 13743.835/3/2025 7:30 13.1 48.25 245.8 12.3 45.23 248.8 15.6 57.29 236.8 20.5 75.39 218.7 64.4 236.71 57.4 62.8 230.68 63.4 79.2 290.99 3.1 76.9 282.70 11.441.4 152.28 141.8 15.2 55.79 238.3 4993.54 16008.89 3.76 13841.125/3/2025 8:00 13.1 48.25 245.8 12.3 45.23 248.8 15.6 57.29 236.8 20.5 75.39 218.7 46.4 170.37 123.7 47.0 172.63 121.4 79.2 290.99 3.1 76.9 282.70 11.4 41.4 152.28 141.8 44.3 162.83 131.2 5138.28 16115.93 3.77 13954.385/3/2025 8:30 13.1 48.25 245.8 12.3 45.23 248.8 15.6 57.29 236.8 20.5 75.39 218.7 35.5 130.42 163.7 33.4 122.88 171.2 79.2 290.99 3.1 76.9 282.70 11.4 72.6 266.87 27.2 44.3 162.83 131.2 5500.13 16230.52 3.76 14068.875/3/2025 9:00 13.1 48.25 245.8 12.3 45.23 248.8 15.6 57.29 236.8 20.5 75.39 218.7 17.2 63.32 230.7 16.0 58.80 235.3 79.2 290.99 3.1 76.9 282.70 11.472.6 266.87 27.2 75.7 278.17 15.9 5536.32 16345.86 3.76 14180.825/3/2025 9:30 44.1 162.08 132.0 12.3 45.23 248.8 15.6 57.29 236.8 20.5 75.39 218.7 17.2 63.32 230.7 16.0 58.80 235.3 66.7 245.00 49.1 63.6 233.70 60.4 72.6 266.87 27.2 75.7 278.17 15.9 5463.95 16459.69 3.76 14311.245/3/2025 10:00 44.1 162.08 132.0 42.9 157.56 136.5 15.6 57.29 236.8 20.5 75.39 218.7 17.2 63.32 230.7 16.0 58.80 235.3 51.3 188.46 105.6 49.2 180.93 113.1 72.6 266.87 27.2 75.7 278.17 15.9 5391.58 16572.02 3.75 14403.875/3/2025 10:30 75.5 277.42 16.7 42.9 157.56 136.5 15.6 57.29 236.8 20.5 75.39 218.7 17.2 63.32 230.7 16.0 58.80 235.3 36.9 135.69 158.4 33.4 122.88171.2 72.6 266.87 27.2 75.7 278.17 15.9 5536.32 16687.36 3.75 14518.655/3/2025 11:00 75.5 277.42 16.7 73.8 271.39 22.7 15.6 57.29 236.8 20.5 75.39 218.7 17.2 63.32 230.7 16.0 58.80 235.3 19.7 72.37 221.7 17.6 64.83 229.2 72.6 266.87 27.2 75.7 278.17 15.9 5463.95 16801.19 3.76 14632.265/3/2025 11:30 75.5 277.42 16.7 73.8 271.39 22.7 47.0 172.63 121.4 20.5 75.39 218.7 17.2 63.32 230.7 16.0 58.80 235.3 19.7 72.37 221.7 17.6 64.83 229.2 59.1 217.11 77.0 61.5 226.16 67.9 5536.32 16916.53 3.76 14744.645/3/2025 12:00 75.5 277.42 16.7 73.8 271.39 22.7 47.0 172.63 121.4 51.7 189.97 104.1 17.2 63.32 230.7 16.0 58.80 235.3 19.7 72.37 221.7 17.6 64.83 229.2 43.9 161.33 132.7 46.8 171.88 122.2 5500.13 17031.11 3.77 14857.965/3/2025 12:30 75.5 277.42 16.7 73.8 271.39 22.7 78.3 287.97 6.1 51.7 189.97 104.1 17.2 63.32 230.7 16.0 58.80 235.3 19.7 72.37 221.7 17.6 64.83 229.2 29.9 110.06 184.0 32.4 119.11 175.0 5536.32 17146.45 3.77 14969.865/3/2025 13:00 75.5 277.42 16.7 73.8 271.39 22.7 78.3 287.97 6.1 82.9 304.56 0.0 17.2 63.32 230.7 16.0 58.80 235.3 19.7 72.37 221.7 17.6 64.83 229.212.7 46.74 247.3 16.0 58.80 235.3 5500.13 17261.04 3.76 15080.505/3/2025 13:30 61.1 224.65 69.4 59.1 217.11 77.0 78.3 287.97 6.1 82.9 304.56 0.0 49.2 180.93 113.1 16.0 58.80 235.3 19.7 72.37 221.7 17.6 64.83 229.2 12.7 46.74 247.3 16.0 58.80 235.3 5644.87 17378.64 3.75 15193.875/3/2025 14:00 48.4 177.91 116.2 46.8 171.88 122.2 78.3 287.97 6.1 82.9 304.56 0.0 49.2 180.93 113.1 46.8 171.88 122.2 19.7 72.37 221.7 17.6 64.83 229.2 12.7 46.74 247.3 16.0 58.80 235.3 5427.76 17491.72 3.76 15304.195/3/2025 14:30 32.8 120.62 173.5 31.8 116.85 177.2 78.3 287.97 6.1 82.9 304.56 0.0 80.0 294.00 0.1 46.8 171.88 122.2 19.7 72.37 221.7 17.6 64.83 229.2 12.7 46.74 247.3 16.0 58.80 235.3 5427.76 17604.80 3.75 15428.285/3/2025 15:00 16.8 61.82 232.3 16.2 59.55 234.5 78.3 287.97 6.1 82.9 304.56 0.0 80.0 294.00 0.1 78.6 288.73 5.3 19.7 72.37 221.7 17.6 64.83 229.2 12.7 46.74 247.3 16.0 58.80 235.3 5608.69 17721.65 3.75 15534.085/3/2025 15:30 16.8 61.82 232.3 16.2 59.55 234.5 64.2 235.96 58.1 68.1 250.28 43.8 80.0 294.00 0.1 78.6 288.73 5.3 51.3 188.46 105.6 17.6 64.83 229.2 12.7 46.74 247.3 16.0 58.80 235.3 5572.50 17837.74 3.75 15642.035/3/2025 16:00 16.8 61.82 232.3 16.2 59.55 234.5 51.5 189.22 104.9 54.1 199.02 95.1 80.0 294.00 0.1 78.6 288.73 5.3 51.3 188.46 105.6 49.4 181.68 112.4 12.7 46.74 247.3 16.0 58.80 235.3 5608.69 17954.59 3.75 15642.035/3/2025 16:30 16.8 61.82 232.3 16.2 59.55 234.5 32.4 119.11 175.0 36.9 135.69 158.4 80.0 294.00 0.1 78.6 288.73 5.3 82.0 301.54 0.0 49.4 181.68 112.4 12.7 46.74 247.3 16.0 58.80 235.3 5427.76 18067.67 3.76 15870.195/3/2025 17:00 16.8 61.82 232.3 16.2 59.55 234.5 19.9 73.12 220.9 25.2 92.72 201.3 80.0 294.00 0.1 78.6 288.73 5.3 82.0 301.54 0.0 81.8 300.79 0.0 12.7 46.74 247.3 16.0 58.80 235.3 5717.24 18186.78 3.74 15981.505/3/2025 17:30 16.8 61.82 232.3 16.2 59.55 234.5 19.9 73.12 220.9 25.2 92.72 201.3 64.8 238.22 55.9 62.4 229.17 64.9 82.0 301.54 0.0 81.8 300.79 0.044.1 162.08 132.0 16.0 58.80 235.3 5536.32 18302.12 3.76 16105.415/3/2025 18:00 16.8 61.82 232.3 16.2 59.55 234.5 19.9 73.12 220.9 25.2 92.72 201.3 64.8 238.22 55.9 62.4 229.17 64.9 82.0 301.54 0.0 81.8 300.79 0.044.1 162.08 132.0 48.6 178.66 115.4 5753.32 18421.98 3.76 16208.215/3/2025 18:30 16.8 61.82 232.3 16.2 59.55 234.5 19.9 73.12 220.9 25.2 92.72 201.3 64.8 238.22 55.9 62.4 229.17 64.9 82.0 301.54 0.0 81.8 300.79 0.076.7 281.94 12.1 48.6 178.66 115.4 5753.32 18541.84 3.76 16321.315/3/2025 19:00 16.8 61.82 232.3 16.2 59.55 234.5 19.9 73.12 220.9 25.2 92.72 201.3 64.8 238.22 55.9 62.4 229.17 64.9 82.0 301.54 0.0 81.8 300.79 0.076.7 281.94 12.1 80.4 295.51 0.0 5608.69 18658.69 3.77 16434.415/3/2025 19:30 48.6 178.66 115.4 16.2 59.55 234.5 19.9 73.12 220.9 25.2 92.72 201.3 14.2 52.02 242.1 12.7 46.74 247.3 82.0 301.54 0.0 81.8 300.79 0.0 76.7 281.94 12.1 80.4 295.51 0.0 5608.69 18775.54 3.77 16547.525/3/2025 20:00 48.6 178.66 115.4 48.4 177.91 116.2 19.9 73.12 220.9 25.2 92.72 201.3 14.2 52.02 242.1 12.7 46.74 247.3 82.0 301.54 0.0 81.8 300.79 0.0 76.7 281.94 12.1 80.4 295.51 0.0 5681.06 18893.89 3.75 16667.895/3/2025 20:30 80.4 295.51 0.0 48.4 177.91 116.2 19.9 73.12 220.9 25.2 92.72 201.3 14.2 52.02 242.1 12.7 46.74 247.3 82.0 301.54 0.0 81.8 300.79 0.076.7 281.94 12.1 80.4 295.51 0.0 5608.69 19010.74 3.77 16771.955/3/2025 21:00 80.4 295.51 0.0 80.2 294.76 0.0 19.9 73.12 220.9 25.2 92.72 201.3 14.2 52.02 242.1 12.7 46.74 247.3 82.0 301.54 0.0 81.8 300.79 0.0 76.7 281.94 12.1 80.4 295.51 0.0 5608.69 19127.59 3.75 16885.315/3/2025 21:30 80.4 295.51 0.0 80.2 294.76 0.0 51.9 190.73 103.3 25.2 92.72 201.3 14.2 52.02 242.1 12.7 46.74 247.3 14.8 54.28 239.8 12.3 45.23 248.8 76.7 281.94 12.1 80.4 295.51 0.0 5644.87 19245.19 3.75 17000.655/3/2025 22:00 80.4 295.51 0.0 80.2 294.76 0.0 51.9 190.73 103.3 57.0 209.57 84.5 14.2 52.02 242.1 12.7 46.74 247.3 14.8 54.28 239.8 12.3 45.23 248.8 76.7 281.94 12.1 80.4 295.51 0.0 5608.69 19362.04 3.75 17109.195/3/2025 22:30 80.4 295.51 0.0 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 14.2 52.02 242.1 12.7 46.74 247.3 14.8 54.28 239.8 12.3 45.23 248.876.7 281.94 12.1 80.4 295.51 0.0 5500.32 19476.62 3.75 17224.795/3/2025 23:00 80.4 295.51 0.0 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 45.9 168.86 125.2 12.7 46.74 247.3 14.8 54.28 239.8 12.3 45.23 248.8 76.7 281.94 12.1 80.4 295.51 0.0 5608.69 19593.47 3.75 17338.355/3/2025 23:30 80.4 295.51 0.0 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 45.9 168.86 125.2 44.7 164.34 129.7 14.8 54.28 239.8 12.3 45.23 248.8 76.7 281.94 12.1 80.4 295.51 0.0 5644.87 19711.07 3.78 17453.385/4/2025 0:00 80.4 295.51 0.0 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 77.9 286.47 7.6 44.7 164.34 129.7 13.1 48.25 245.8 12.3 45.23 248.8 14.8 54.28 239.8 11.9 43.72 250.3 5644.87 19828.67 0.00 17559.245/4/2025 0:30 80.4 295.51 0.0 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 77.9 286.47 7.6 76.3 280.43 13.6 13.1 48.25 245.8 12.3 45.23 248.8 14.8 54.28 239.8 11.9 43.72 250.3 5572.50 19944.77 0.00 17559.245/4/2025 1:00 80.4 295.51 0.0 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 77.9 286.47 7.6 76.3 280.43 13.6 46.8 171.88 122.2 12.3 45.23 248.8 14.8 54.28 239.8 11.9 43.72 250.3 5644.87 20062.37 0.00 17559.245/4/2025 1:30 7.0 25.63 268.4 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 77.9 286.47 7.6 76.3 280.43 13.6 46.8 171.88 122.2 43.5 159.82 134.314.8 54.28 239.8 11.9 43.72 250.3 5500.13 20176.96 3.82 17639.90WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 38 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)TANK 5 NDBi-049 WELL CLEAN-UP_TANK FARM TO INJECTION WELL NDBi-014Well:NDBi-049Start Date:29-April-2025 @ 10:00End Date:11-May-2025 @ 12:30Tank Strap Fluid CumulativeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-014TANK 6 TANK 7 TANK 8 TANK 9 TANK 10Tank Strap Fluid RateDate & TimeTANK 1 TANK 2 TANK 3 TANK 45/4/2025 2:00 7.0 25.63 268.4 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 77.9 286.47 7.6 76.3 280.43 13.6 78.8 289.48 4.6 43.5 159.82 134.3 14.8 54.28 239.8 11.9 43.72 250.3 5500.13 20176.96 3.82 17747.525/4/2025 2:30 7.0 25.63 268.4 80.2 294.76 0.0 67.3 247.26 46.8 72.8 267.62 26.5 77.9 286.47 7.6 76.3 280.43 13.6 78.8 289.48 4.6 75.5 277.42 16.7 14.8 54.28 239.8 11.9 43.72 250.3 5644.87 20412.16 3.83 17858.415/4/2025 3:00 7.0 25.63 268.4 80.2 294.76 0.0 15.6 57.29 236.8 18.3 67.09 227.0 77.9 286.47 7.6 76.3 280.43 13.6 78.8 289.48 4.6 75.5 277.42 16.7 43.7 160.57 133.5 11.9 43.72 250.3 5391.58 20524.48 3.85 17973.195/4/2025 3:30 7.0 25.63 268.4 80.2 294.76 0.0 15.6 57.29 236.8 18.3 67.09 227.0 77.9 286.47 7.6 76.3 280.43 13.6 78.8 289.48 4.6 75.5 277.42 16.7 43.7 160.57 133.5 46.8 171.88 122.2 5862.24 20646.61 3.84 18088.415/4/2025 4:00 7.0 25.63 268.4 80.2 294.76 0.0 15.6 57.29 236.8 18.3 67.09 227.0 77.9 286.47 7.6 76.3 280.43 13.6 78.8 289.48 4.6 75.5 277.42 16.7 75.7 278.17 15.9 46.8 171.88 122.2 5644.87 20764.21 3.85 18199.595/4/2025 4:30 7.0 25.63 268.4 6.6 24.12 269.9 15.6 57.29 236.8 18.3 67.09 227.0 77.9 286.47 7.6 76.3 280.43 13.6 78.8 289.48 4.6 75.5 277.42 16.7 75.7 278.17 15.9 78.1 287.22 6.9 5536.32 20879.55 3.88 18320.275/4/2025 5:00 37.5 137.96 156.1 6.6 24.12 269.9 15.6 57.29 236.8 18.3 67.09 227.0 21.1 77.65 216.4 76.3 280.43 13.6 14.0 51.26 242.8 11.5 42.22 251.9 75.7 278.17 15.9 78.1 287.22 6.9 5391.58 20991.87 3.85 18431.225/4/2025 5:30 37.5 137.96 156.1 37.9 139.46 154.6 15.6 57.29 236.8 18.3 67.09 227.0 21.1 77.65 216.4 76.3 280.43 13.6 14.0 51.26 242.8 11.5 42.22 251.9 75.7 278.17 15.9 78.1 287.22 6.9 5536.32 21107.21 3.84 18556.735/4/2025 6:00 69.9 257.06 37.0 37.9 139.46 154.6 15.6 57.29 236.8 18.3 67.09 227.0 21.1 77.65 216.4 46.6 171.13 122.9 14.0 51.26 242.8 11.5 42.22 251.9 48.6 178.66 115.4 50.0 183.94 110.1 5717.24 21226.32 3.82 18670.375/4/2025 6:30 69.9 257.06 37.0 69.5 255.56 38.5 15.6 57.29 236.8 18.3 67.09 227.0 21.1 77.65 216.4 37.7 138.71 155.4 14.0 51.26 242.8 11.5 42.22 251.9 40.4 148.51 145.6 41.8 153.79 140.3 5572.50 21342.42 3.81 18780.255/4/2025 7:00 69.9 257.06 37.0 69.5 255.56 38.5 46.8 171.88 122.2 18.3 67.09 227.0 21.1 77.65 216.4 27.5 101.02 193.1 14.0 51.26 242.8 11.5 42.22 251.9 30.4 111.57 182.5 31.8 116.85 177.2 5500.13 21457.00 3.83 18894.095/4/2025 7:30 69.9 257.06 37.0 69.5 255.56 38.5 46.8 171.88 122.2 49.6 182.43 111.6 21.1 77.65 216.4 20.9 76.89 217.2 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5536.32 21572.34 3.80 19009.345/4/2025 8:00 50.9 186.96 107.1 50.0 183.94 110.1 78.3 287.97 6.1 49.6 182.43 111.6 21.1 77.65 216.4 20.9 76.89 217.2 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5572.50 21688.44 3.81 19121.515/4/2025 8:30 34.3 125.89 168.2 32.8 120.62 173.5 78.3 287.97 6.1 81.6 300.03 0.0 21.1 77.65 216.4 20.9 76.89 217.2 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5644.87 21806.04 3.82 19237.495/4/2025 9:00 20.5 75.39 218.7 20.1 73.88 220.2 78.3 287.97 6.1 81.6 300.03 0.0 52.9 194.49 99.6 20.9 76.89 217.2 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5608.69 21922.89 3.80 19352.105/4/2025 9:30 20.5 75.39 218.7 20.1 73.88 220.2 62.8 230.68 63.4 66.0 242.74 51.3 52.9 194.49 99.6 52.5 192.99 101.1 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5572.50 22038.98 3.80 19470.095/4/2025 10:00 20.5 75.39 218.7 20.1 73.88 220.2 47.0 172.63 121.4 66.0 242.74 51.3 84.9 312.10 0.0 52.5 192.99 101.1 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5644.87 22156.58 3.81 19582.125/4/2025 10:30 20.5 75.39 218.7 20.1 73.88 220.2 36.5 134.19 159.9 39.4 144.74 149.3 76.7 281.94 12.1 84.1 309.08 0.0 14.0 51.26 242.8 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5572.50 22272.68 3.80 19696.955/4/2025 11:00 20.5 75.39 218.7 20.1 73.88 220.2 24.2 88.96 205.1 26.9 98.76 195.3 76.7 281.94 12.1 76.3 280.43 13.6 45.1 165.85 128.2 11.5 42.22 251.9 22.2 81.42 212.7 24.2 88.96 205.1 5500.13 22387.26 3.81 19811.475/4/2025 11:30 20.5 75.39 218.7 20.1 73.88 220.2 17.8 65.59 228.5 23.0 84.43 209.6 68.1 250.28 43.8 66.5 244.25 49.8 45.1 165.85 128.2 43.1 158.31 135.8 22.2 81.42 212.7 24.2 88.96 205.1 5572.50 22503.36 3.81 19925.525/4/2025 12:00 20.5 75.39 218.7 20.1 73.88 220.2 17.8 65.59 228.5 23.0 84.43 209.6 53.3 196.00 98.1 51.3 188.46 105.6 76.5 281.19 12.9 43.1 158.31 135.8 22.2 81.42 212.7 24.2 88.96 205.1 5536.32 22618.70 3.79 20039.745/4/2025 12:30 20.5 75.39 218.7 20.1 73.88 220.2 17.8 65.59 228.5 23.0 84.43 209.6 37.3 137.20 156.9 36.5 134.19 159.9 76.5 281.19 12.9 75.1 275.9118.2 22.2 81.42 212.7 24.2 88.96 205.1 5644.87 22736.30 3.82 20154.655/4/2025 13:00 20.5 75.39 218.7 20.1 73.88 220.2 17.8 65.59 228.5 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 76.5 281.19 12.9 75.1 275.91 18.2 53.7 197.51 96.6 24.2 88.96 205.1 5572.50 22852.39 3.82 20268.785/4/2025 13:30 20.5 75.39 218.7 20.1 73.88 220.2 17.8 65.59 228.5 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 66.2 243.50 50.6 63.4 232.94 61.1 53.7 197.51 96.6 55.8 205.05 89.0 5572.50 22968.48 3.81 20383.015/4/2025 14:00 51.7 189.97 104.1 20.1 73.88 220.2 17.8 65.59 228.5 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 53.3 196.00 98.1 49.6 182.43 111.6 53.7 197.51 96.6 55.8 205.05 89.0 5500.13 23083.07 3.81 20496.215/4/2025 14:30 51.7 189.97 104.1 45.1 165.85 128.2 17.8 65.59 228.5 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 53.3 196.00 98.1 49.6 182.43111.6 37.1 136.45 157.6 34.9 128.16 165.9 4414.58 23175.04 3.82 20610.055/4/2025 15:00 75.9 278.93 15.1 45.1 165.85 128.2 17.8 65.59 228.5 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 23.8 87.45 206.6 21.7 79.91 214.2 37.1 136.45 157.6 34.9 128.16 165.9 4269.84 23264.00 3.82 20709.185/4/2025 15:30 75.9 278.93 15.1 69.3 254.80 39.3 17.8 65.59 228.5 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 17.0 62.57 231.5 15.0 55.03 239.0 37.1 136.45 157.6 34.9 128.16 165.9 4269.84 23352.95 3.01 20799.485/4/2025 16:00 75.9 278.93 15.1 69.3 254.80 39.3 42.5 156.05 138.0 23.0 84.43 209.6 16.2 59.55 234.5 14.8 54.28 239.8 17.0 62.57 231.5 15.0 55.03 239.0 40.6 149.26 144.8 37.7 138.71 155.4 4342.21 23443.41 3.01 20887.615/4/2025 16:30 75.9 278.93 15.1 69.3 254.80 39.3 42.5 156.05 138.0 47.2 173.39 120.7 16.2 59.55 234.5 14.8 54.28 239.8 17.0 62.57 231.5 15.0 55.03 239.0 25.8 94.99 199.1 26.3 96.49 197.6 4269.84 23532.37 2.80 20970.715/4/2025 17:00 75.9 278.93 15.1 69.3 254.80 39.3 66.9 245.76 48.3 47.2 173.39 120.7 16.2 59.55 234.5 14.8 54.28 239.8 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4306.03 23622.08 2.80 21048.465/4/2025 17:30 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 16.2 59.55 234.5 14.8 54.28 239.8 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4269.84 23711.03 1.80 21109.465/4/2025 18:00 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 41.0 150.77 143.3 14.8 54.28 239.8 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4378.40 23802.25 1.52 21157.925/4/2025 18:30 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 41.0 150.77 143.3 39.2 143.99 150.1 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4306.03 23891.96 1.54 21202.855/4/2025 19:00 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 65.8 241.99 52.1 39.2 143.99 150.1 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4378.40 23983.17 1.51 21247.445/4/2025 19:30 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 65.8 241.99 52.1 63.6 233.70 60.4 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4306.03 24072.88 1.50 21292.905/4/2025 20:00 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 17.0 62.57 231.5 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 4296.60 24161.84 1.50 21333.125/4/2025 20:30 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 36.7 134.94 159.1 15.0 55.03 239.0 17.2 63.32 230.7 19.3 70.86 223.2 3473.77 24234.21 1.20 21379.895/4/2025 21:00 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 36.7 134.94 159.1 35.3 129.66 164.4 17.2 63.32 230.7 19.3 70.86 223.2 3582.35 24308.84 1.23 21413.675/4/2025 21:30 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 55.0 202.03 92.0 35.3 129.66 164.4 17.2 63.32 230.7 19.3 70.86 223.2 3220.47 24375.93 1.23 21452.125/4/2025 22:00 64.8 238.22 55.9 62.8 230.68 63.4 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 55.0 202.03 92.0 55.0 202.03 92.0 17.2 63.32 230.7 19.3 70.86 223.2 3473.77 24448.30 1.23 21481.495/4/2025 22:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 55.0 202.03 92.0 55.0 202.03 92.0 37.3 137.20 156.9 19.3 70.86 223.2 3546.14 24522.18 0.00 21525.775/4/2025 23:00 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 55.0 202.03 92.0 37.3 137.20 156.9 19.3 70.86 223.2 3727.06 24599.83 1.20 21525.775/4/2025 23:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 37.3 137.20 156.9 19.3 70.86 223.2 3473.77 24672.20 0.00 21565.775/5/2025 0:00 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 37.3 137.20 156.9 39.4 144.74 149.3 3546.14 24746.08 0.00 21571.035/5/2025 0:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 57.2 210.33 83.7 39.4 144.74 149.3 3509.95 24819.20 0.00 21571.035/5/2025 1:00 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 57.2 210.33 83.7 59.3 217.86 76.2 3509.95 24892.33 0.00 21571.035/5/2025 1:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 76.5 281.19 12.9 59.3 217.86 76.2 3401.40 24963.19 0.00 21571.035/5/2025 2:00 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 76.5 281.19 12.9 79.2 290.99 3.1 3509.95 25036.31 0.00 21571.035/5/2025 2:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 76.5 281.19 12.9 79.2 290.99 3.1 3509.95 25036.31 0.00 21571.035/5/2025 3:00 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 76.5 281.19 12.9 79.2 290.99 3.1 3509.95 25036.31 0.00 21571.035/5/2025 3:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 76.5 281.19 12.9 79.2 290.99 3.1 3509.95 25036.31 0.00 21571.035/5/2025 4:00 29.0 43.72 250.4 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.7 76.5 281.19 12.9 79.2 290.99 3.1 3509.95 25036.31 0.00 21571.03WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 39 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)TANK 5 NDBi-049 WELL CLEAN-UP_TANK FARM TO INJECTION WELL NDBi-014Well:NDBi-049Start Date:29-April-2025 @ 10:00End Date:11-May-2025 @ 12:30Tank Strap Fluid CumulativeFluid Injection Rate into NDBi-014Fluid Injection Cumulative into NDBi-014TANK 6 TANK 7 TANK 8 TANK 9 TANK 10Tank Strap Fluid RateDate & TimeTANK 1 TANK 2 TANK 3 TANK 45/10/2025 10:00 7.8 28.65 265.4 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.776.5 281.19 12.9 79.2 290.99 3.1 0.00 25036.31 0.00 21571.035/10/2025 10:30 7.8 28.65 265.4 6.6 24.12 269.9 66.9 245.76 48.3 71.4 262.34 31.7 78.8 289.48 4.6 74.9 275.16 18.9 76.1 279.68 14.4 74.7 274.40 19.776.5 281.19 12.9 79.2 290.99 3.1 0.00 25036.31 0.00 21571.035/10/2025 11:00 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.8 263.85 30.2 70.6 259.33 34.7 71.6 263.10 31.0 71.0 260.83 33.2 69.7 256.31 37.8 68.9 253.30 40.8 70.1 257.82 36.3 0.00 25036.31 0.00 21571.035/10/2025 11:30 7.6 27.89 266.2 6.6 24.12 269.9 66.9 245.76 48.3 71.8 263.85 30.2 70.6 259.33 34.7 71.6 263.10 31.0 71.0 260.83 33.2 69.7 256.31 37.8 68.9 253.30 40.8 70.1 257.82 36.3 0.00 25036.31 3.70 21797.435/10/2025 12:00 7.6 27.89 266.2 6.6 24.12 269.9 66.0 242.74 51.3 64.0 235.20 58.9 62.4 229.17 64.9 62.4 229.17 64.9 62.4 229.17 64.9 62.4 229.17 64.9 62.1 228.42 65.7 62.8 230.68 63.4 0.00 25036.31 2.10 21907.735/10/2025 12:30 7.6 27.89 266.2 6.6 24.12 269.9 66.0 242.74 51.3 64.0 235.20 58.9 62.4 229.17 64.9 62.4 229.17 64.9 62.4 229.17 64.9 62.4 229.17 64.9 62.1 228.42 65.7 62.8 230.68 63.4 0.00 25036.31 2.00 21969.435/10/2025 13:00 7.6 27.89 266.2 6.6 24.12 269.9 63.8 234.45 59.6 59.1 217.11 77.0 56.8 208.82 85.3 57.8 212.59 81.5 57.8 212.59 81.5 58.2 214.10 80.0 57.6 211.83 82.2 58.2 214.10 80.0 0.00 25036.31 2.00 22031.145/10/2025 13:30 7.6 27.89 266.2 6.6 24.12 269.9 63.8 234.45 59.6 59.1 217.11 77.0 56.8 208.82 85.3 57.8 212.59 81.5 57.8 212.59 81.5 58.2 214.10 80.0 57.6 211.83 82.2 58.2 214.10 80.0 0.00 25036.31 3.50 22135.035/10/2025 14:00 7.6 27.89 266.2 6.6 24.12 269.9 54.1 199.02 95.1 52.9 194.49 99.6 51.3 188.46 105.6 51.3 188.46 105.6 50.9 186.96 107.1 51.3 188.46105.6 50.9 186.96 107.1 52.5 192.99 101.1 0.00 25036.31 3.50 22238.835/10/2025 14:30 7.6 27.89 266.2 6.6 24.12 269.9 54.1 199.02 95.1 52.9 194.49 99.6 51.3 188.46 105.6 51.3 188.46 105.6 50.9 186.96 107.1 51.3 188.46105.6 50.9 186.96 107.1 52.5 192.99 101.1 0.00 25036.31 3.50 22238.835/10/2025 15:00 7.6 27.89 266.2 6.6 24.12 269.9 45.7 168.11 126.0 46.1 169.62 124.5 45.1 165.85 128.2 45.3 166.60 127.5 45.5 167.36 126.7 46.1 169.62 124.5 45.9 168.86 125.2 45.9 168.86 125.2 0.00 25036.31 2.00 22436.435/10/2025 15:30 7.6 27.89 266.2 6.6 24.12 269.9 45.7 168.11 126.0 46.1 169.62 124.5 45.1 165.85 128.2 45.3 166.60 127.5 45.5 167.36 126.7 46.1 169.62 124.5 45.9 168.86 125.2 45.9 168.86 125.2 0.00 25036.31 2.10 22498.435/10/2025 16:00 7.6 27.89 266.2 6.6 24.12 269.9 45.7 168.11 126.0 46.1 169.62 124.5 45.1 165.85 128.2 45.3 166.60 127.5 45.5 167.36 126.7 46.1 169.62 124.5 45.9 168.86 125.2 45.9 168.86 125.2 0.00 25036.31 2.10 22498.435/10/2025 16:30 7.6 27.89 266.2 6.6 24.12 269.9 40.2 147.76 146.3 41.4 152.28 141.8 40.8 150.02 144.1 41.0 150.77 143.3 41.6 153.03 141.0 41.8 153.79 140.3 41.4 152.28 141.8 41.4 152.28 141.8 0.00 25036.31 0.00 22615.125/10/2025 17:00 7.6 27.89 266.2 6.6 24.12 269.9 40.2 147.76 146.3 41.4 152.28 141.8 40.8 150.02 144.1 41.0 150.77 143.3 41.6 153.03 141.0 41.8 153.79 140.3 41.4 152.28 141.8 41.4 152.28 141.8 0.00 25036.31 0.00 22615.125/10/2025 17:30 7.6 27.89 266.2 6.6 24.12 269.9 38.6 141.72 152.3 39.4 144.74 149.3 39.0 143.23 150.8 39.4 144.74 149.3 39.8 146.25 147.8 40.8 150.02 144.1 40.0 147.00 147.1 40.6 149.26 144.8 0.00 25036.31 0.00 22615.125/10/2025 18:00 7.6 27.89 266.2 6.6 24.12 269.9 38.6 141.72 152.3 39.4 144.74 149.3 39.0 143.23 150.8 39.4 144.74 149.3 39.8 146.25 147.8 40.8 150.02 144.1 40.0 147.00 147.1 40.6 149.26 144.8 0.00 25036.31 0.00 22615.125/10/2025 18:30 7.6 27.89 266.2 6.6 24.12 269.9 39.0 143.23 150.8 39.4 144.74 149.3 39.4 144.74 149.3 39.8 146.25 147.8 39.8 146.25 147.8 40.2 147.76 146.3 40.0 147.00 147.1 40.6 149.26 144.8 0.00 25036.31 0.00 22615.125/10/2025 19:00 7.6 27.89 266.2 6.6 24.12 269.9 39.0 143.23 150.8 39.4 144.74 149.3 39.4 144.74 149.3 39.8 146.25 147.8 39.8 146.25 147.8 40.2 147.76 146.3 40.0 147.00 147.1 40.6 149.26 144.8 0.00 25036.31 0.00 22615.125/10/2025 19:30 7.6 27.89 266.2 6.6 24.12 269.9 39.0 143.23 150.8 39.4 144.74 149.3 39.4 144.74 149.3 39.8 146.25 147.8 39.8 146.25 147.8 40.2 147.76 146.3 40.0 147.00 147.1 40.6 149.26 144.8 0.00 25036.31 3.30 22630.025/10/2025 20:00 7.6 27.89 266.2 6.6 24.12 269.9 39.0 143.23 150.8 39.4 144.74 149.3 39.4 144.74 149.3 39.8 146.25 147.8 39.8 146.25 147.8 40.2 147.76 146.3 40.0 147.00 147.1 40.6 149.26 144.8 0.00 25036.31 3.30 22729.615/10/2025 20:30 7.6 27.89 266.2 6.6 24.12 269.9 31.2 114.59 179.5 32.6 119.86 174.2 31.6 116.09 178.0 31.6 116.09 178.0 30.8 113.08 181.0 31.0 113.83 180.2 30.8 113.08 181.0 32.0 117.60 176.5 0.00 25036.31 3.40 22829.605/10/2025 21:00 7.6 27.89 266.2 6.6 24.12 269.9 31.2 114.59 179.5 32.6 119.86 174.2 31.6 116.09 178.0 31.6 116.09 178.0 30.8 113.08 181.0 31.0 113.83 180.2 30.8 113.08 181.0 32.0 117.60 176.5 0.00 25036.31 3.30 22930.605/10/2025 21:30 7.6 27.89 266.2 6.6 24.12 269.9 25.4 93.48 200.6 26.3 96.49 197.6 25.4 93.48 200.6 25.6 94.23 199.8 25.0 91.97 202.1 25.4 93.48 200.6 25.0 91.97 202.1 25.4 93.48 200.6 0.00 25036.31 3.40 23031.685/10/2025 22:00 7.6 27.89 266.2 6.6 24.12 269.9 25.4 93.48 200.6 26.3 96.49 197.6 25.4 93.48 200.6 25.6 94.23 199.8 25.0 91.97 202.1 25.4 93.48 200.6 25.0 91.97 202.1 25.4 93.48 200.6 0.00 25036.31 3.40 23136.685/10/2025 22:30 7.6 27.89 266.2 6.6 24.12 269.9 18.5 67.85 226.2 19.3 70.86 223.2 18.9 69.35 224.7 18.9 69.35 224.7 18.1 66.34 227.7 18.5 67.85 226.2 18.5 67.85 226.2 19.3 70.86 223.2 0.00 25036.31 3.40 23233.675/10/2025 23:00 7.6 27.89 266.2 6.6 24.12 269.9 18.5 67.85 226.2 19.3 70.86 223.2 18.9 69.35 224.7 18.9 69.35 224.7 18.1 66.34 227.7 18.5 67.85 226.2 18.5 67.85 226.2 19.3 70.86 223.2 0.00 25036.31 3.30 23334.665/10/2025 23:30 7.6 27.89 266.2 6.6 24.12 269.9 12.3 45.23 248.8 12.7 46.74 247.3 11.9 43.72 250.3 11.9 43.72 250.3 11.5 42.22 251.9 12.7 46.74 247.3 11.7 42.97 251.1 13.1 48.25 245.8 0.00 25036.31 3.40 23435.755/11/2025 0:00 7.6 27.89 266.2 6.6 24.12 269.9 12.3 45.23 248.8 12.7 46.74 247.3 11.9 43.72 250.3 11.9 43.72 250.3 11.5 42.22 251.9 12.7 46.74 247.311.7 42.97 251.1 13.1 48.25 245.8 0.00 25036.31 3.40 23536.745/11/2025 0:30 7.6 27.89 266.2 6.6 24.12 269.9 4.9 18.09 276.0 4.9 18.09 276.0 4.3 15.83 278.2 5.3 19.60 274.5 4.5 16.58 277.5 4.7 17.34 276.7 4.5 16.58 277.5 5.7 21.11 273.0 0.00 25036.31 3.40 23634.335/11/2025 1:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 1:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 2:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 2:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 3:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 3:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 4:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 4:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 5:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 5:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 6:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 6:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 7:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 7:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 8:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 8:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 9:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 9:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02 291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 10:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 10:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 11:00 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 11:30 7.4 27.14 266.9 4.9 18.09 276.0 4.5 16.58 277.5 4.1 15.08 279.0 4.7 17.34 276.7 4.9 18.09 276.0 1.4 5.28 288.8 2.5 9.05 285.0 0.8 3.02291.1 1.9 6.78 287.3 0.00 25036.31 0.00 23634.335/11/2025 12:00 1.4 5.28 288.8 4.1 15.08 279.0 0.6 2.26 291.8 0.8 3.02 291.1 1.2 4.52 289.5 1.9 6.78 287.3 0.8 3.02 291.1 0.6 2.26 291.8 1.2 4.52 289.50.8 3.02 291.1 0.00 25036.31 0.00 23634.335/11/2025 12:30 1.4 5.28 288.8 4.1 15.08 279.0 0.6 2.26 291.8 0.8 3.02 291.1 1.2 4.52 289.5 1.9 6.78 287.3 0.8 3.02 291.1 0.6 2.26 291.8 1.2 4.52 289.50.8 3.02 291.1 0.00 25036.31 0.00 23634.33WIRELINE INJECTIVITY TESTDISPOSED REMAINING PRODUCED FLUIDWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 40 Santos – Pikka Development – NDBi-049 SECTION 8 INJECTION WELL NDBi-014 DATA WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 41 BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) 04/30/2025 01:00:00 01:15 Began Injecting Tank 1 and Tank 2 down NDBi-014 @ 2.8 bbls/min.2001.69 103.66 251.21 8.11 6.11 0.00 0.00 04/30/2025 01:30:00 2367.98 100.52 637.84 8.13 5.66 2.80 43.05 04/30/2025 02:00:00 2355.27 94.59 693.84 8.19 5.69 2.87 132.79 04/30/2025 02:30:00 2364.64 93.00 700.90 8.09 5.66 2.86 237.65 04/30/2025 03:00:00 Began transferring fluid from Tank #3 to Worley Truck 86088. RVP 6. 2521.96 91.69 882.20 9.01 6.55 2.84 300.19 04/30/2025 03:30:00 2581.19 91.52 946.20 8.09 7.00 2.86 386.45 04/30/2025 04:00:00 04:15 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. 4:18 Finished transferring fluid from Tank #3 to Worley Truck 86088.2602.90 90.31 969.38 7.20 7.01 2.86 471.84 04/30/2025 04:30:00 2619.47 89.13 963.96 8.11 7.45 2.90 558.48 04/30/2025 05:00:00 2630.49 88.01 983.49 7.10 7.42 2.85 646.10 04/30/2025 05:30:00 2643.37 86.48 1018.06 7.12 6.95 2.85 728.32 04/30/2025 06:00:00 2658.81 86.20 1038.53 6.20 7.23 2.85 812.00 04/30/2025 06:30:00 2655.35 85.70 1034.90 6.20 6.09 2.83 901.29 04/30/2025 07:00:00 Added Tank 6 and Tank 7 to NDBi-014 Injection and Removed Tank 4 and Tank 5. 2654.07 85.09 1034.72 5.14 7.39 2.84 983.18 04/30/2025 07:30:00 2628.47 85.30 994.56 5.02 7.36 2.82 1060.32 04/30/2025 08:00:00 2639.12 84.46 1019.34 4.92 7.35 2.81 1142.73 04/30/2025 08:30:00 2647.66 83.90 1029.86 4.74 6.44 2.83 1225.77 04/30/2025 09:00:00 2653.22 83.42 1035.98 4.68 5.53 2.82 1309.24 04/30/2025 09:30:00 09:44 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 6 and Tank 7.2653.12 82.98 1035.70 2.67 9.05 2.82 1397.42 04/30/2025 10:00:00 2655.43 82.51 1024.89 2.63 8.15 2.82 1479.83 04/30/2025 10:30:00 2619.88 82.23 985.74 2.15 8.13 2.49 1567.48 04/30/2025 11:00:00 2610.51 81.80 982.97 2.37 7.20 2.51 1642.93 04/30/2025 11:30:00 2624.34 81.90 997.14 2.35 7.57 2.50 1712.01 04/30/2025 12:00:00 2619.59 81.78 992.67 2.35 5.89 2.48 1786.75 04/30/2025 12:30:00 12:56 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.2616.48 81.63 990.85 0.49 8.10 2.50 1861.67 04/30/2025 13:00:00 2614.58 81.46 987.30 0.55 8.53 2.49 1936.48 04/30/2025 13:30:00 2613.67 81.29 987.14 0.51 7.65 2.48 2011.63 04/30/2025 14:00:00 2614.01 81.13 989.00 0.00 10.32 2.49 2086.07 04/30/2025 14:30:00 2615.23 80.93 990.71 1.31 8.07 2.49 2161.83 04/30/2025 15:00:00 2621.73 80.84 998.77 2.23 7.19 2.49 2236.13 04/30/2025 15:30:00 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. 2575.71 80.99 937.36 0.47 8.99 2.21 2302.26 04/30/2025 16:00:00 2587.17 80.95 768.20 0.24 8.49 2.18 2370.43 04/30/2025 16:30:00 2585.83 80.21 695.30 1.91 8.05 2.20 2435.32 04/30/2025 17:00:00 2586.93 77.05 720.97 1.83 8.93 2.20 2500.22 04/30/2025 17:30:00 2533.44 75.47 792.88 2.67 11.06 2.39 2578.07 04/30/2025 18:00:00 2489.15 74.43 842.57 1.77 8.90 2.34 2640.99 04/30/2025 18:30:00 18:34 Increased Injection Rate to 2.6 bpm into well NDBi-014.2481.87 75.56 853.29 0.00 8.89 2.35 2710.53 04/30/2025 19:00:00 2620.35 76.34 836.47 3.57 8.02 2.59 2786.58 04/30/2025 19:30:00 2652.60 76.68 915.48 3.71 8.47 2.64 2866.72 04/30/2025 20:00:00 2660.71 73.38 998.57 3.87 5.85 2.61 2954.57 04/30/2025 20:30:00 2595.00 74.59 960.31 4.76 11.16 2.60 3050.69 04/30/2025 21:00:00 21:20 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 9 and Tank 10.2680.09 75.40 1048.37 1.27 12.06 2.62 3100.99 04/30/2025 21:30:00 2698.85 75.75 1046.59 3.89 9.38 2.64 3186.19 04/30/2025 22:00:00 2703.11 75.99 1051.78 4.62 9.38 2.65 3249.09 04/30/2025 22:30:00 2705.65 75.81 1056.51 4.03 8.07 2.62 3360.15 04/30/2025 23:00:00 2716.43 75.83 1074.37 4.96 8.99 2.62 3360.15 04/30/2025 23:30:00 2727.80 75.96 1092.20 5.08 8.55 2.61 3498.26 05/01/2025 00:00:00 LRS Injection pump offline for Preventative Maintenance / Data Download. 00:10 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 7 and Tank 8.2746.93 76.00 1119.12 5.20 9.01 0.00 3581.86 05/01/2025 00:30:00 00:37 LRS Injection pump back Online @ 2.8 bpm.2304.07 78.30 624.99 4.46 8.60 0.00 3581.86 05/01/2025 01:00:00 2666.20 78.09 1034.06 4.60 9.07 2.85 3644.29 05/01/2025 01:30:00 2713.54 77.44 1082.05 4.62 8.62 2.87 3730.57 05/01/2025 02:00:00 2728.68 76.95 1100.82 4.74 8.62 2.83 3815.83 05/01/2025 02:30:00 02:54 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.2742.28 76.80 1114.33 4.88 8.23 2.84 3903.78 05/01/2025 03:00:00 2748.28 76.64 1106.55 4.96 7.35 2.86 3990.73 05/01/2025 03:30:00 2751.64 76.50 1122.47 4.98 7.78 2.85 4072.45 05/01/2025 04:00:00 Increased Injection Rate to 3.0 bpm into well NDBi-014. 2768.65 75.81 1153.67 5.04 7.81 3.00 4159.88 05/01/2025 04:30:00 2777.17 76.00 1162.69 5.12 8.71 3.03 4251.69 05/01/2025 05:00:00 05:10 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 3 and Tank 4.2780.96 75.89 1166.36 5.28 8.73 3.01 4357.31 05/01/2025 05:30:00 Increased Injection Rate to 3.4 bpm into well NDBi-014. 2811.83 75.56 1213.52 5.28 8.27 3.43 4449.48 INJECTION WELL_NDBi-014 NDBi-014 INJECTION DATA_NDBi-049 WELL CLEAN-UP Location: Injection Start Date: Injection End Date: Pikka Development ND-B April 30th, 2025 @ 01:15 May 11th, 2025 @ 00:53 COMMENTS Date & Time WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 42 BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) INJECTION WELL_NDBi-014 NDBi-014 INJECTION DATA_NDBi-049 WELL CLEAN-UP Location: Injection Start Date: Injection End Date: Pikka Development ND-B April 30th, 2025 @ 01:15 May 11th, 2025 @ 00:53 COMMENTS Date & Time 05/01/2025 06:00:00 2819.52 75.18 1222.48 6.26 7.86 3.43 4531.46 05/01/2025 06:30:00 06:42 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.2828.02 74.85 1231.34 6.24 8.29 3.42 4645.83 05/01/2025 07:00:00 2831.48 74.67 1233.85 6.12 7.41 3.43 4747.71 05/01/2025 07:30:00 2834.94 74.50 1239.88 6.80 6.97 3.43 4747.71 05/01/2025 08:00:00 08:28 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10.2838.69 74.36 1243.91 7.12 5.97 3.43 4952.87 05/01/2025 08:30:00 Reduced Injection Rate to 2.4 bpm into well NDBi-014. 2701.52 75.11 1061.44 5.34 7.26 2.40 5029.63 05/01/2025 09:00:00 Reduced Injection Rate to 2.0 bpm into well NDBi-014. 2661.06 75.68 862.03 4.30 9.00 2.00 5093.96 05/01/2025 09:30:00 2635.85 76.15 892.25 4.14 8.98 2.04 5158.33 05/01/2025 10:00:00 2627.89 74.04 944.58 2.35 8.99 2.05 5219.81 05/01/2025 10:30:00 2581.49 74.22 935.23 3.01 8.96 2.05 5303.88 05/01/2025 11:00:00 2563.30 75.30 917.67 2.91 7.61 2.05 5340.05 05/01/2025 11:30:00 2628.95 76.00 984.15 2.79 8.47 2.06 5400.23 05/01/2025 12:00:00 12:01 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.2639.09 76.45 994.74 3.59 8.93 2.04 5463.31 05/01/2025 12:30:00 Reduced Injection Rate to 1.8 bpm into well NDBi-014. 2622.51 76.85 812.35 2.61 9.73 1.80 5520.83 05/01/2025 13:00:00 2622.38 77.20 756.27 6.16 7.99 1.84 5575.40 05/01/2025 13:30:00 2623.64 75.50 720.59 4.28 11.08 1.83 5643.90 05/01/2025 14:00:00 Increased Injection Rate to 2.5 bpm into well NDBi-014. 2666.38 74.57 764.07 5.14 12.39 2.51 5684.69 05/01/2025 14:30:00 14:56 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.2616.25 72.44 714.43 5.98 10.17 2.51 5763.05 05/01/2025 15:00:00 2592.91 71.42 869.99 6.08 11.06 2.50 5837.75 05/01/2025 15:30:00 15:38 Increased Injection Rate to 2.5 bpm into well NDBi-014.2588.20 70.60 761.65 6.24 9.78 2.49 5912.89 05/01/2025 16:00:00 2637.64 70.96 750.16 5.32 14.25 2.79 5993.77 05/01/2025 16:30:00 Increased Injection Rate to 3.4 bpm into well NDBi-014. 2748.96 69.48 863.96 9.83 10.68 3.21 6087.56 05/01/2025 17:00:00 17:06 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.2725.18 68.70 1020.50 9.83 11.56 3.42 6189.74 05/01/2025 17:30:00 2721.12 68.50 940.35 9.79 13.31 3.38 6291.03 05/01/2025 18:00:00 2802.72 69.81 923.50 13.30 11.52 3.40 6388.39 05/01/2025 18:30:00 2773.64 68.92 1072.77 12.42 10.62 3.46 6496.04 05/01/2025 19:00:00 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. 2731.28 68.90 1151.06 14.28 10.65 3.55 6605.52 05/01/2025 19:30:00 2824.19 71.30 1016.17 17.07 10.23 3.40 6700.11 05/01/2025 20:00:00 2857.77 70.33 978.20 20.76 8.95 3.37 6807.19 05/01/2025 20:30:00 2786.06 69.75 1122.25 22.72 12.08 3.45 6909.22 05/01/2025 21:00:00 21:05 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10.2752.95 70.65 1175.80 19.37 15.67 3.44 7015.96 05/01/2025 21:30:00 2856.43 72.23 1071.11 19.46 12.55 3.38 7118.14 05/01/2025 22:00:00 2868.97 71.60 990.53 21.50 12.17 3.38 7213.62 05/01/2025 22:30:00 2812.88 70.48 1148.94 22.62 11.35 3.46 7324.54 05/01/2025 23:00:00 23:10 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.2762.12 71.13 1186.33 23.51 11.78 3.45 7412.43 05/01/2025 23:30:00 2859.41 72.71 1100.88 24.35 11.30 3.37 7553.99 05/02/2025 00:00:00 LRS Injection Pump offline for Preventative Maintenance / Data Download. 2875.09 73.08 999.55 27.01 11.29 0.00 7621.25 05/02/2025 00:30:00 00:45 LRS Injection pump back Online @ 3.4 bpm.2402.23 74.67 473.38 20.80 10.86 0.00 7621.25 05/02/2025 01:00:00 2760.32 74.16 1014.97 20.00 11.32 3.35 7662.11 05/02/2025 01:30:00 2748.76 72.04 1151.88 21.16 10.94 3.37 7766.16 05/02/2025 02:00:00 02:06 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.2760.48 73.53 1185.25 23.19 10.52 3.37 7868.46 05/02/2025 02:30:00 2875.67 74.16 1108.94 26.03 10.56 3.64 7957.39 05/02/2025 03:00:00 2882.90 72.58 1164.21 27.03 11.50 3.71 8082.74 05/02/2025 03:30:00 2823.77 71.16 1255.94 26.27 11.48 3.73 8193.38 05/02/2025 04:00:00 04:05 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.2866.73 73.22 1304.54 27.28 11.53 3.73 8303.01 05/02/2025 04:30:00 2902.38 73.78 1123.71 29.96 11.53 3.64 8416.12 05/02/2025 05:00:00 2901.95 72.25 1227.73 28.22 11.98 3.74 8527.11 05/02/2025 05:30:00 05:50 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.2843.63 71.88 1274.85 29.14 11.52 3.74 8640.71 05/02/2025 06:00:00 2915.74 73.42 1241.20 30.99 11.12 3.63 8782.91 05/02/2025 06:30:00 2927.58 73.88 1211.05 33.67 6.25 3.71 8900.46 05/02/2025 07:00:00 07:25 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10.2913.39 71.61 1328.00 30.99 10.64 3.71 8900.46 05/02/2025 07:30:00 2891.20 73.30 1282.61 29.78 9.27 3.60 9081.56 05/02/2025 08:00:00 2935.68 73.81 1187.25 26.95 10.54 3.61 9193.28 05/02/2025 08:30:00 2930.61 71.80 1326.71 25.09 11.01 3.71 9301.91 05/02/2025 09:00:00 09:05 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.2893.30 73.15 1317.67 26.71 10.96 3.70 9410.40 05/02/2025 09:30:00 2945.38 73.76 1289.06 25.69 12.29 3.72 9522.21 05/02/2025 10:00:00 2945.15 72.47 1341.27 25.51 11.80 3.72 9634.25 05/02/2025 10:30:00 10:40 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.2947.00 73.46 1350.89 26.23 11.78 3.72 9743.00 05/02/2025 11:00:00 2970.87 73.74 1296.50 26.11 12.18 3.78 9855.79 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 43 BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) INJECTION WELL_NDBi-014 NDBi-014 INJECTION DATA_NDBi-049 WELL CLEAN-UP Location: Injection Start Date: Injection End Date: Pikka Development ND-B April 30th, 2025 @ 01:15 May 11th, 2025 @ 00:53 COMMENTS Date & Time 05/02/2025 11:30:00 2972.68 72.69 1343.54 25.99 11.72 3.71 9967.07 05/02/2025 12:00:00 12:05 Decreased Injection Rate to 3 bpm into well NDBi-014.2965.28 73.39 1375.29 25.83 12.58 3.69 10078.11 05/02/2025 12:30:00 12:35 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.2941.05 74.15 1329.64 25.55 10.32 3.02 10173.18 05/02/2025 13:00:00 2934.39 74.64 1246.82 22.72 12.50 3.03 10262.18 05/02/2025 13:30:00 2918.85 74.55 1254.72 22.60 11.62 3.01 10355.85 05/02/2025 14:00:00 2912.69 74.10 1286.76 22.60 11.62 2.99 10446.79 05/02/2025 14:30:00 14:35 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.2935.43 74.70 1317.83 23.51 11.16 2.99 10534.83 05/02/2025 15:00:00 2937.90 75.13 1252.89 22.64 12.52 2.99 10620.05 05/02/2025 15:30:00 2932.18 75.36 1276.05 23.47 10.76 2.98 10711.08 05/02/2025 16:00:00 2920.87 74.68 1295.46 21.60 13.39 2.99 10801.04 05/02/2025 16:30:00 16:51 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10.2929.76 75.11 1306.12 24.23 10.70 2.97 10891.63 05/02/2025 17:00:00 2936.71 75.28 1240.14 22.38 11.57 2.88 10980.37 05/02/2025 17:30:00 2937.66 75.39 1275.69 22.32 13.31 3.01 11070.10 05/02/2025 18:00:00 2932.76 73.85 1308.51 21.40 11.56 3.01 11158.19 05/02/2025 18:30:00 2922.82 75.06 1301.49 18.73 11.08 3.01 11286.78 05/02/2025 19:00:00 19:05 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.2935.93 75.24 1315.81 21.50 10.65 3.02 11377.20 05/02/2025 19:30:00 2937.84 75.34 1260.93 21.76 10.74 3.01 11446.22 05/02/2025 20:00:00 2936.96 74.69 1289.48 20.04 9.41 3.02 11532.61 05/02/2025 20:30:00 2922.12 74.67 1297.66 21.12 13.43 3.01 11616.53 05/02/2025 21:00:00 21:29 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.2940.99 75.03 1318.43 17.81 13.49 3.02 11702.92 05/02/2025 21:30:00 2942.55 75.14 1320.38 20.64 11.28 3.13 11794.50 05/02/2025 22:00:00 2943.53 75.22 1280.56 19.88 10.86 3.01 11899.30 05/02/2025 22:30:00 2942.33 73.73 1304.64 19.96 10.86 3.03 11981.20 05/02/2025 23:00:00 23:15 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.2946.57 74.56 1343.76 19.94 11.31 3.41 12074.78 05/02/2025 23:30:00 2973.87 74.66 1317.01 20.82 10.89 3.42 12176.02 05/03/2025 00:00:00 LRS Injection Pump offline for Preventative Maintenance / Data Download. 2961.10 74.70 1262.80 20.80 10.44 0.00 12273.28 05/03/2025 00:30:00 00:34 LRS Injection pump back Online @ 3.4 bpm.2521.54 76.14 825.42 15.46 10.42 0.00 12273.28 05/03/2025 01:00:00 01:27 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.2945.05 75.39 1358.83 17.25 10.42 3.80 12384.63 05/03/2025 01:30:00 2979.99 74.81 1385.18 19.92 10.44 3.68 12488.88 05/03/2025 02:00:00 2987.28 74.63 1386.42 21.72 9.98 3.74 12604.22 05/03/2025 02:30:00 2994.95 74.15 1400.60 21.72 10.44 3.76 12711.90 05/03/2025 03:00:00 3003.81 74.18 1409.62 21.80 10.44 3.76 12826.27 05/03/2025 03:30:00 03:15 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10.3007.03 74.13 1396.38 21.92 10.46 3.77 12947.39 05/03/2025 04:00:00 3008.35 74.09 1411.70 20.28 10.50 3.76 13048.29 05/03/2025 04:30:00 3010.95 73.93 1418.02 20.40 10.08 3.76 13166.18 05/03/2025 05:00:00 05:10 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.3013.31 73.93 1420.94 20.28 10.50 3.76 13275.12 05/03/2025 05:30:00 3015.21 73.90 1412.22 19.96 10.42 3.77 13390.98 05/03/2025 06:00:00 3016.00 73.88 1420.94 18.05 9.94 3.77 13503.67 05/03/2025 06:30:00 3018.32 73.77 1424.25 17.81 10.36 3.77 13615.97 05/03/2025 07:00:00 07:06 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.3020.60 73.75 1425.76 19.37 9.90 3.77 13743.83 05/03/2025 07:30:00 3018.50 73.73 1424.69 17.41 10.30 3.76 13841.12 05/03/2025 08:00:00 3020.78 73.59 1427.92 17.17 9.84 3.77 13954.38 05/03/2025 08:30:00 08:56 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.3022.39 73.69 1428.48 16.89 10.20 3.76 14068.87 05/03/2025 09:00:00 3023.21 73.69 1429.97 16.67 9.73 3.76 14180.82 05/03/2025 09:30:00 3024.09 73.69 1428.90 15.55 11.01 3.76 14311.24 05/03/2025 10:00:00 3024.52 73.52 1432.35 16.29 9.68 3.75 14403.87 05/03/2025 10:30:00 3025.97 73.66 1433.92 16.15 10.97 3.75 14518.65 05/03/2025 11:00:00 11:07 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.3028.19 73.68 1436.54 16.17 11.02 3.76 14632.26 05/03/2025 11:30:00 3028.62 73.70 1433.82 17.89 11.00 3.76 14744.64 05/03/2025 12:00:00 3029.62 73.57 1436.26 17.73 11.38 3.77 14857.96 05/03/2025 12:30:00 3029.98 73.68 1436.42 18.73 10.08 3.77 14969.86 05/03/2025 13:00:00 13:07 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10.3031.14 73.71 1438.41 18.05 11.90 3.76 15080.50 05/03/2025 13:30:00 3032.71 73.73 1440.31 16.39 11.89 3.75 15193.87 05/03/2025 14:00:00 3033.56 73.64 1442.28 16.53 12.42 3.76 15304.19 05/03/2025 14:30:00 3034.04 73.73 1443.34 15.77 12.40 3.75 15428.28 05/03/2025 15:00:00 15:05 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.3035.79 73.73 1445.26 16.81 13.33 3.75 15534.08 05/03/2025 15:30:00 3036.30 73.72 1444.54 18.65 11.10 3.75 15642.03 05/03/2025 16:00:00 3034.18 73.63 1444.60 16.03 15.56 3.75 15642.03 05/03/2025 16:30:00 3037.67 73.73 1448.17 19.64 11.12 3.76 15870.19 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 44 BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) INJECTION WELL_NDBi-014 NDBi-014 INJECTION DATA_NDBi-049 WELL CLEAN-UP Location: Injection Start Date: Injection End Date: Pikka Development ND-B April 30th, 2025 @ 01:15 May 11th, 2025 @ 00:53 COMMENTS Date & Time 05/03/2025 17:00:00 17:02 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.3039.40 73.75 1449.96 20.60 10.70 3.74 15981.50 05/03/2025 17:30:00 3039.10 73.75 1448.69 18.77 13.81 3.76 16105.41 05/03/2025 18:00:00 3040.25 73.71 1450.78 18.75 12.90 3.76 16208.21 05/03/2025 18:30:00 3041.23 73.78 1452.64 20.56 11.56 3.76 16321.31 05/03/2025 19:00:00 19:15 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.3042.75 73.80 1454.63 21.64 12.04 3.77 16434.41 05/03/2025 19:30:00 3043.07 73.79 1452.16 21.80 12.50 3.77 16547.52 05/03/2025 20:00:00 3040.45 73.81 1452.28 21.92 11.66 3.75 16667.89 05/03/2025 20:30:00 3040.73 73.81 1452.50 22.94 11.23 3.77 16771.95 05/03/2025 21:00:00 3045.16 73.85 1457.98 23.16 11.28 3.75 16885.31 05/03/2025 21:30:00 21:34 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.3045.86 73.85 1460.76 23.18 11.29 3.75 17000.65 05/03/2025 22:00:00 3044.90 73.88 1459.16 24.21 11.31 3.75 17109.19 05/03/2025 22:30:00 3042.40 73.87 1456.47 23.39 11.78 3.75 17224.79 05/03/2025 23:00:00 3046.16 73.94 1461.65 24.27 10.84 3.75 17338.35 05/03/2025 23:30:00 23:43 Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 9 and Tank 10.3046.73 73.96 1461.89 24.27 11.30 3.78 17453.38 05/04/2025 00:00:00 LRS Injection Pump offline for Preventative Maintenance / Data Download. Began transferring fluid from Tank #1 to Worley Truck 86088. RVP 6.3047.58 73.98 1460.16 23.45 10.87 0.00 17559.24 05/04/2025 00:30:00 2633.22 75.90 954.48 18.25 10.90 0.00 17559.24 05/04/2025 01:00:00 01:07 Finished transferring fluid from Tank #1 to Worley Truck 86088. 01:10 LRS Injection pump back Online @ 3.75 bpm.2520.25 77.17 844.31 15.54 10.46 0.00 17559.24 05/04/2025 01:30:00 2961.43 76.86 1415.95 17.37 10.46 3.82 17639.90 05/04/2025 02:00:00 3001.07 75.64 1423.75 19.98 10.45 3.82 17747.52 05/04/2025 02:30:00 02:41 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 3 and Tank 4. 02:53 Began transferring fluid from Tank #2 to Worley Truck 86060. RVP 6.3020.41 75.19 1445.16 20.86 10.45 3.83 17858.41 05/04/2025 03:00:00 3027.54 74.88 1451.36 20.88 10.88 3.85 17973.19 05/04/2025 03:30:00 3031.83 74.55 1456.91 21.96 10.92 3.84 18088.41 05/04/2025 04:00:00 04:12 Finished transferring fluid from Tank #2 to Worley truck 86060/86058. 04:13 Began transferring fluid from Tank #5 to Worley Truck 86058. RVP 6.3037.57 74.48 1462.21 22.84 10.90 3.85 18199.59 05/04/2025 04:30:00 04:47 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.3040.10 74.36 1465.78 21.94 10.89 3.88 18320.27 05/04/2025 05:00:00 Finished transferring fluid from Tank #5 to Worley Truck 86058. 05:10 Added Tank 6 to NDBi-014 Injection with Tank 9 and Tank 10.3041.56 74.25 1466.72 22.00 11.36 3.85 18431.22 05/04/2025 05:30:00 3043.26 74.15 1467.64 22.00 11.34 3.84 18556.73 05/04/2025 06:00:00 3041.50 74.08 1465.80 22.00 11.36 3.82 18670.37 05/04/2025 06:30:00 3045.98 74.07 1470.09 22.68 10.02 3.81 18780.25 05/04/2025 07:00:00 07:26 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9, Tank 6 and Tank 10.3046.84 74.04 1469.74 22.48 10.42 3.83 18894.09 05/04/2025 07:30:00 3048.09 74.01 1469.42 21.32 10.36 3.80 19009.34 05/04/2025 08:00:00 3048.98 73.98 1472.85 19.37 9.90 3.81 19121.51 05/04/2025 08:30:00 3049.48 73.98 1473.43 19.11 10.69 3.82 19237.49 05/04/2025 09:00:00 09:03Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2.3048.02 73.95 1471.49 18.97 11.16 3.80 19352.10 05/04/2025 09:30:00 3048.52 73.92 1470.39 16.99 12.47 3.80 19470.09 05/04/2025 10:00:00 10:08 Added Tank 5 to NDBi-014 Injection with Tank 3 and Tank 4. 10:15 Removed Tank 5 from NDBi-014 Injection.3049.76 73.86 1472.93 16.77 11.10 3.81 19582.12 05/04/2025 10:30:00 10:32 Added Tank 6 to NDBi-014 Injection with Tank 3 and Tank 4.3052.22 73.88 1474.56 18.53 11.52 3.80 19696.95 05/04/2025 11:00:00 11:16 Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4.3053.02 73.82 1475.76 18.33 10.60 3.81 19811.47 05/04/2025 11:30:00 3053.68 73.81 1476.06 18.23 11.47 3.81 19925.52 05/04/2025 12:00:00 3053.77 73.81 1476.86 18.19 11.45 3.79 20039.74 05/04/2025 12:30:00 3055.67 73.83 1478.67 18.21 11.48 3.82 20154.65 05/04/2025 13:00:00 13:16 Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6.3057.08 73.84 1481.39 19.13 11.04 3.82 20268.78 05/04/2025 13:30:00 3056.79 73.82 1478.77 18.31 13.72 3.81 20383.01 05/04/2025 14:00:00 3055.95 73.82 1481.53 19.31 11.95 3.81 20496.21 05/04/2025 14:30:00 14:43 Decreased Injection Rate to 3 bpm into well NDBi-014.3058.72 73.85 1482.62 19.44 12.42 3.82 20610.05 05/04/2025 15:00:00 15:20 Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8.2984.09 74.17 1374.23 18.59 14.20 3.82 20709.18 05/04/2025 15:30:00 15:46 Decreased Injection Rate to 2.8 bpm into well NDBi-014.2972.64 74.44 1358.35 19.52 12.00 3.01 20799.48 05/04/2025 16:00:00 2947.43 74.68 1326.39 20.50 10.71 3.01 20887.61 05/04/2025 16:30:00 16:40 Decreased Injection Rate to 2.5 bpm into well NDBi-014.2939.79 74.81 1321.18 18.73 12.04 2.80 20970.71 05/04/2025 17:00:00 17:01 Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. 17:02 Decreased Injection Rate to 2 bpm into well NDBi-014. 17:25 Decreased Injection Rate to 1.8 bpm into well NDBi-014. 2905.06 75.14 1276.67 18.75 11.57 2.80 21048.46 05/04/2025 17:30:00 2823.45 75.68 1170.87 14.42 12.48 1.80 21109.46 05/04/2025 18:00:00 Decreased Injection Rate to 1.5 bpm into well NDBi-014. 2766.07 76.27 1104.27 14.38 11.58 1.52 21157.92 05/04/2025 18:30:00 2742.93 76.68 1083.90 13.58 11.58 1.54 21202.85 05/04/2025 19:00:00 2729.34 76.92 1070.79 12.84 12.05 1.51 21247.44 05/04/2025 19:30:00 2719.94 77.20 1064.79 13.92 11.23 1.50 21292.90 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 45 BHP BHT WHPi IAPi OAPi Injection Rate Injection Cumulative (mm-dd-yyyy hh:mm:ss)(psig) (°F) (psig) (psig) (psig) (bbls/min) (bbls) INJECTION WELL_NDBi-014 NDBi-014 INJECTION DATA_NDBi-049 WELL CLEAN-UP Location: Injection Start Date: Injection End Date: Pikka Development ND-B April 30th, 2025 @ 01:15 May 11th, 2025 @ 00:53 COMMENTS Date & Time 05/04/2025 20:00:00 2713.67 77.48 1057.73 13.16 10.83 1.50 21333.12 05/04/2025 20:30:00 Decreased Injection Rate to 1.2 bpm into well NDBi-014. 2667.89 77.87 1008.11 13.22 11.26 1.20 21379.89 05/04/2025 21:00:00 2653.43 78.17 991.27 13.34 10.82 1.23 21413.67 05/04/2025 21:30:00 2644.05 78.41 985.22 11.59 10.84 1.23 21452.12 05/04/2025 22:00:00 2637.05 78.67 981.04 12.62 10.42 1.23 21481.49 05/04/2025 22:30:00 LRS Injection Pump Offline. Finished Injection into well NDBi-014. Save remaining Flowback Fluid in Tank Farm for Wireline Injectivity Test.2632.28 78.89 975.59 12.64 10.43 0.00 21525.77 05/10/2025 10:30:00 10:16 Opened Suction from Tanks 4 - Tank 10 to LRS Injection Pump. 10:18 Commenced Injection into NDBi-014 and Started WL Injectivity Test.2386.19 98.80 769.18 8.21 6.73 0.00 21571.03 05/10/2025 11:00:00 11:02 Added Tank 3 to NDBi-014 Injection. 2707.06 95.59 1113.19 9.93 6.30 3.50 21687.03 05/10/2025 11:30:00 2747.22 91.58 1182.38 8.07 7.17 3.70 21797.43 05/10/2025 12:00:00 Reduced Injection Pump Rate to 2 bpm. 2709.16 89.51 1051.76 7.20 7.13 2.10 21907.73 05/10/2025 12:30:00 2624.91 89.95 975.71 6.38 8.08 2.00 21969.43 05/10/2025 13:00:00 2638.32 89.03 1055.41 5.38 8.04 2.00 22031.14 05/10/2025 13:30:00 Increased Injection Pump Rate to 3.5 bpm. 2827.93 86.79 1250.73 6.24 8.05 3.50 22135.03 05/10/2025 14:00:00 2844.21 85.32 1269.43 5.36 7.17 3.50 22238.83 05/10/2025 14:30:00 2849.48 84.09 1267.59 4.40 8.91 3.50 22238.83 05/10/2025 15:00:00 Reduced Injection Pump Rate to 2 bpm. 2698.50 83.42 1064.03 4.38 8.90 2.00 22436.43 05/10/2025 15:30:00 2650.20 84.09 1013.24 5.18 7.98 2.10 22498.43 05/10/2025 16:00:00 HES WL began to POOH 16:28 LRS Injection Pump Offline.2638.55 84.02 1000.03 3.45 8.92 2.10 22498.43 05/10/2025 16:30:00 16:35 HES WL tool at surface.2446.05 84.08 771.51 4.36 8.91 0.00 22615.12 05/10/2025 17:00:00 2285.30 85.89 0.74 3.45 8.92 0.00 22615.12 05/10/2025 17:30:00 2232.92 87.24 559.87 3.39 7.55 0.00 22615.12 05/10/2025 18:00:00 2204.99 88.25 530.48 2.47 8.91 0.00 22615.12 05/10/2025 18:30:00 2187.25 89.06 513.60 3.35 8.03 0.00 22615.12 05/10/2025 19:00:00 19:25 LRS Injection Pump Online. Began Injecting into NDBi-014 at 3.3 bpm.2175.10 89.75 500.26 2.47 8.91 0.00 22615.12 05/10/2025 19:30:00 2570.96 90.18 964.40 4.28 8.45 3.30 22630.02 05/10/2025 20:00:00 2764.56 86.55 1170.67 5.24 8.47 3.30 22729.61 05/10/2025 20:30:00 2806.39 84.64 1216.96 6.20 7.57 3.40 22829.60 05/10/2025 21:00:00 2833.74 83.25 1243.79 5.40 8.05 3.30 22930.60 05/10/2025 21:30:00 2850.24 82.09 1260.73 5.48 8.51 3.40 23031.68 05/10/2025 22:00:00 2860.48 81.10 1272.32 4.60 8.03 3.40 23136.68 05/10/2025 22:30:00 2869.35 80.29 1280.44 5.68 8.53 3.40 23233.67 05/10/2025 23:00:00 2874.54 79.55 1286.80 5.68 8.55 3.30 23334.66 05/10/2025 23:30:00 2879.00 78.95 1291.19 4.80 8.53 3.40 23435.75 05/11/2025 00:00:00 2883.82 78.42 1295.80 4.94 8.94 3.40 23536.74 05/11/2025 00:30:00 Added Tank 1 and Tank 2 to Injection. 00:40 Reduced Injection rate to 1.8 bpm due to low tank volumes. 00:53 LRS Injection Pump lost prime. Pump offline. Injection Complete. 2887.58 78.03 1302.09 5.00 8.17 3.40 23634.33 05/11/2025 01:00:00 2523.08 79.17 863.02 4.18 8.14 0.00 23634.33 WIRELINE INJECTIVITY TEST WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 46 Ϭ͘Ϭϭϱ͘ϬϯϬ͘Ϭϰϱ͘ϬϲϬ͘Ϭϳϱ͘ϬϵϬ͘ϬϭϬϱ͘ϬϬϱϬϬϭϬϬϬϭϱϬϬϮϬϬϬϮϱϬϬϯϬϬϬϯϱϬϬPressure (psig)Santos - Pikka Development - NDBi-049Injection Well NDBi-014Well Head - Bottom Hole Conditions PlotBHPWHPiBHTIAPiOAPiPressure (psig) / Temperature ;Σ&Ϳ WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 47 Ϭ͘ϬϲϬϬϬ͘ϬϭϮϬϬϬ͘ϬϭϴϬϬϬ͘ϬϮϰϬϬϬ͘ϬϬ͘Ϭϭ͘ϬϮ͘Ϭϯ͘Ϭϰ͘ϬRate (bbls/min)Santos - Pikka Development - NDBi-049Injection Well NDBi-014Injection Rate - Cumulative Plot Injection Rate Injection CumulativeCumulative (bbls)WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 48 Ϭ͘ϬϮϬ͘ϬϰϬ͘ϬϲϬ͘ϬϴϬ͘ϬϭϬϬ͘ϬϭϮϬ͘ϬϭϰϬ͘ϬϬϱϬϬϭϬϬϬϭϱϬϬϮϬϬϬϮϱϬϬϯϬϬϬϯϱϬϬPressure (psig)Santos - Pikka DevelopmentInjection Well NDBi-014Well Head - Bottom Hole Conditions PlotWireline Injectivity TestBHPWHPiBHTIAPiOAPiPressure (psig) / Temperature ;Σ&Ϳ WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 49 ϮϬϬϬϬ͘ϬϮϭϬϬϬ͘ϬϮϮϬϬϬ͘ϬϮϯϬϬϬ͘ϬϮϰϬϬϬ͘ϬϬ͘Ϭϭ͘ϬϮ͘Ϭϯ͘Ϭϰ͘ϬRate (bbls/min)Santos - Pikka DevelopmentInjection Well NDBi-014Injection Rate - Cumulative PlotWireline Injectivity Test Injection Rate Injection CumulativeCumulative (bbls)WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 50 Santos – Pikka Development – NDBi-049 SECTION 9 TEST SUMMARY SHUT-IN / BUILD-UP PERIOD WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 51 ƵŝůĚͲhƉ^ƵŵŵĂƌLJ ^ĂŶƚŽƐʹWŝŬŬĂĞǀĞůŽƉŵĞŶƚʹEŝͲϬϰϵʹ^ŚƵƚͲŝŶͬƵŝůĚͲƵƉWĞƌŝŽĚ ƵƌĂƚŝŽŶŽĨDŽŶŝƚŽƌĞĚƵŝůĚͲƵƉсϭϲϴŚƌƐ͘ ^ŚƵƚͲŝŶͬƵŝůĚͲƵƉWĞƌŝŽĚ ^ƚĂƌƚŽĨƵŝůĚͲƵƉWĞƌŝŽĚ͗ DĂLJϱ ƚŚ͕ϮϬϮϱ ϬϮ͗ϬϬ͗ϬϬ ŶĚŽĨƵŝůĚͲƵƉWĞƌŝŽĚ͗ DĂLJϭϮ ƚŚ͕ϮϬϮϱ ϬϮ͗ϬϬ͗ϬϬ ƵƌŝŶŐƚŚĞDĂŝŶ^ŚƵƚͲ/ŶͬƵŝůĚͲƵƉƉĞƌŝŽĚ͕ĚĂƚĂǁĂƐĐŽůůĞĐƚĞĚŝŶŽŶĞƐĞĐŽŶĚ͕ŽŶĞŵŝŶƵƚĞĂŶĚϯϬͲŵŝŶƵƚĞ ŝŶƚĞƌǀĂůƐƚŚƌŽƵŐŚϯƌĚWĂƌƚLJŽǁŶŚŽůĞ'ĂƵŐĞ^ĐŚůƵŵďĞƌŐĞƌ;^>Ϳ͘ WƌŽǀŝĚĞĚďĞůŽǁĂƌĞƚŚĞŝŶŝƚŝĂůĂŶĚĨŝŶĂůĚĂƚĂƉŽŝŶƚǀĂůƵĞƐƚŚĂƚǁĞƌĞƌĞĐŽƌĚĞĚĚƵƌŝŶŐƚŚĞ^ŚƵƚͲŝŶͬƵŝůĚͲ ƵƉWĞƌŝŽĚ͘dŚĞƐĞǀĂůƵĞƐŝŶĐůƵĚĞŽƚƚŽŵͲ,ŽůĞWƌĞƐƐƵƌĞĂŶĚŽƚƚŽŵͲ,ŽůĞdĞŵƉĞƌĂƚƵƌĞ͘ /ŶŝƚŝĂůĂƚĂsĂůƵĞƐ;^ŚƵƚͲŝŶͬƵŝůĚͲƵƉWĞƌŝŽĚͿ͗ DĂLJϱƚŚ͕ϮϬϮϱΛϬϮ͗ϬϬ͗ϬϬ ,WƌĞƐƐƵƌĞ,dĞŵƉĞƌĂƚƵƌĞ ;ƉƐŝŐͿ;Σ&Ϳ ϭϱϰϳ͘ϰϴ ϵϱ͘ϵϭ ŶĚĂƚĂsĂůƵĞƐ;^ŚƵƚͲŝŶͬƵŝůĚͲƵƉWĞƌŝŽĚͿ͗ DĂLJϭϮƚŚ͕ϮϬϮϱΛϬϮ͗ϬϬ͗ϬϬ ,WƌĞƐƐƵƌĞ,dĞŵƉĞƌĂƚƵƌĞ ;ƉƐŝŐͿ;Σ&Ϳ ϭϳϭϮ͘Ϯϴ ϴϴ͘ϴϲ EŽƚĞ͗EŝͲϬϰϵŝƐĐŽŶƚŝŶƵŽƵƐůLJůŽŐŐĞĚΘŵŽŶŝƚŽƌĞĚ͕ǁŝƚŚĚĂƚĂƌĞƉŽƌƚƐĚŝƐƚƌŝďƵƚĞĚĚĂŝůLJ͘&ŽƌƚŚĞ ŶĚŽĨtĞůů ZĞƉŽƌƚ͕ƚŚĞĂďŽǀĞĚĂƚĞƐĞƋƵŝǀĂůĞŶƚƚŽϭϲϴŚƌƐ͘;ϳĚĂLJƐͿĂƌĞĐĂƉƚƵƌĞĚŝŶƚŚĞďƵŝůĚͲƵƉƐƵŵŵĂƌLJĂŶĚƉůŽƚƚĞĚ͘ WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 52 Santos – Pikka Development – NDBi-049 SECTION 10 TEST DATA REPORT SHUT-IN / BUILD-UP WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 53 >ŽĐĂƚŝŽŶͬ&ŝĞůĚ͗WŝŬŬĂĞǀĞůŽƉŵĞŶƚͬEͲ ^ƚĂƌƚĂƚĂ͗5-May-2025 @ 02:00 ŶĚĂƚĞ͗12-May-2025 @ 02:00 (mm-dd-yyyy hh:mm:ss)(psig) (°F) 5/5/2025 2:00:00 1547.48 95.91 5/5/2025 2:30:00 1590.18 95.41 5/5/2025 3:00:00 1596.30 95.12 5/5/2025 3:30:00 1599.87 94.89 5/5/2025 4:00:00 1602.98 94.69 5/5/2025 4:30:00 1605.79 94.52 5/5/2025 5:00:00 1608.16 94.36 5/5/2025 5:30:00 1610.28 94.22 5/5/2025 6:00:00 1612.22 94.08 5/5/2025 6:30:00 1614.03 93.96 5/5/2025 7:00:00 1615.74 93.84 5/5/2025 7:30:00 1617.29 93.73 5/5/2025 8:00:00 1618.77 93.64 5/5/2025 8:30:00 1620.21 93.53 5/5/2025 9:00:00 1621.59 93.44 5/5/2025 9:30:00 1622.90 93.35 5/5/2025 10:00:00 1624.16 93.26 5/5/2025 10:30:00 1625.37 93.18 5/5/2025 11:00:00 1626.54 93.11 5/5/2025 11:30:00 1627.66 93.03 5/5/2025 12:00:00 1628.75 92.96 5/5/2025 12:30:00 1629.79 92.89 5/5/2025 13:00:00 1630.81 92.82 5/5/2025 13:30:00 1631.79 92.75 5/5/2025 14:00:00 1632.74 92.68 5/5/2025 14:30:00 1633.66 92.62 5/5/2025 15:00:00 1634.56 92.56 5/5/2025 15:30:00 1635.43 92.50 5/5/2025 16:00:00 1636.28 92.44 5/5/2025 16:30:00 1637.10 92.39 5/5/2025 17:00:00 1637.91 92.34 5/5/2025 17:30:00 1638.71 92.29 5/5/2025 18:00:00 1639.47 92.24 5/5/2025 18:30:00 1640.21 92.18 5/5/2025 19:00:00 1640.94 92.14 5/5/2025 19:30:00 1641.65 92.09 5/5/2025 20:00:00 1642.36 92.05 5/5/2025 20:30:00 1643.05 92.02 5/5/2025 21:00:00 1643.72 91.98 5/5/2025 21:30:00 1644.39 91.94 5/5/2025 22:00:00 1645.04 91.90 5/5/2025 22:30:00 1645.68 91.86 5/5/2025 23:00:00 1646.30 91.82 5/5/2025 23:30:00 1646.92 91.78 5/6/2025 0:00:00 1647.52 91.75 5/6/2025 0:30:00 1648.12 91.72 5/6/2025 1:00:00 1648.71 91.68 5/6/2025 1:30:00 1649.30 91.64 5/6/2025 2:00:00 1649.88 91.62 5/6/2025 2:30:00 1650.45 91.59 5/6/2025 3:00:00 1651.01 91.55 5/6/2025 3:30:00 1651.56 91.51 5/6/2025 4:00:00 1652.11 91.48 5/6/2025 4:30:00 1652.64 91.45 5/6/2025 5:00:00 1653.17 91.43 5/6/2025 5:30:00 1653.69 91.39 5/6/2025 6:00:00 1654.21 91.36 5/6/2025 6:30:00 1654.72 91.34 5/6/2025 7:00:00 1655.23 91.32 5/6/2025 7:30:00 1655.73 91.29 5/6/2025 8:00:00 1656.23 91.26 5/6/2025 8:30:00 1656.73 91.23 5/6/2025 9:00:00 1657.24 91.21 5/6/2025 9:30:00 1657.74 91.18 5/6/2025 10:00:00 1658.24 91.16 5/6/2025 10:30:00 1658.73 91.13 5/6/2025 11:00:00 1659.23 91.10 5/6/2025 11:30:00 1659.74 91.08 5/6/2025 12:00:00 1660.24 91.07 5/6/2025 12:30:00 1660.73 91.04 5/6/2025 13:00:00 1661.22 91.01 5/6/2025 13:30:00 1661.72 90.99 5/6/2025 14:00:00 1662.21 90.97 5/6/2025 14:30:00 1662.70 90.95 5/6/2025 15:00:00 1663.18 90.93 5/6/2025 15:30:00 1663.66 90.90 5/6/2025 16:00:00 1664.14 90.88 5/6/2025 16:30:00 1664.61 90.86 5/6/2025 17:00:00 1665.09 90.84 5/6/2025 17:30:00 1665.57 90.83 5/6/2025 18:00:00 1666.03 90.81 NDBi-049 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS ,ĂƌĚ^ŚƵƚͲ/ŶΛ džƉƌŽŚŽŬĞDĂŶŝĨŽůĚ͘ WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 54 >ŽĐĂƚŝŽŶͬ&ŝĞůĚ͗WŝŬŬĂĞǀĞůŽƉŵĞŶƚͬEͲ ^ƚĂƌƚĂƚĂ͗5-May-2025 @ 02:00 ŶĚĂƚĞ͗12-May-2025 @ 02:00 (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDBi-049 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 5/6/2025 18:30:00 1666.49 90.79 5/6/2025 19:00:00 1666.96 90.77 5/6/2025 19:30:00 1667.41 90.75 5/6/2025 20:00:00 1667.87 90.73 5/6/2025 20:30:00 1668.32 90.71 5/6/2025 21:00:00 1668.77 90.70 5/6/2025 21:30:00 1669.22 90.67 5/6/2025 22:00:00 1669.67 90.66 5/6/2025 22:30:00 1670.11 90.64 5/6/2025 23:00:00 1670.55 90.63 5/6/2025 23:30:00 1670.99 90.61 5/7/2025 0:00:00 1671.43 90.59 5/7/2025 0:30:00 1671.88 90.58 5/7/2025 1:00:00 1672.32 90.56 5/7/2025 1:30:00 1672.76 90.54 5/7/2025 2:00:00 1673.20 90.53 5/7/2025 2:30:00 1673.63 90.51 5/7/2025 3:00:00 1674.06 90.49 5/7/2025 3:30:00 1674.50 90.48 5/7/2025 4:00:00 1674.92 90.47 5/7/2025 4:30:00 1675.34 90.45 5/7/2025 5:00:00 1675.75 90.44 5/7/2025 5:30:00 1676.15 90.42 5/7/2025 6:00:00 1676.55 90.41 5/7/2025 6:30:00 1676.96 90.40 5/7/2025 7:00:00 1677.35 90.37 5/7/2025 7:30:00 1677.74 90.37 5/7/2025 8:00:00 1678.13 90.35 5/7/2025 8:30:00 1678.50 90.33 5/7/2025 9:00:00 1678.86 90.31 5/7/2025 9:30:00 1679.22 90.31 5/7/2025 10:00:00 1679.58 90.29 5/7/2025 10:30:00 1679.94 90.28 5/7/2025 11:00:00 1680.29 90.27 5/7/2025 11:30:00 1680.63 90.25 5/7/2025 12:00:00 1680.97 90.24 5/7/2025 12:30:00 1681.30 90.23 5/7/2025 13:00:00 1681.62 90.21 5/7/2025 13:30:00 1681.95 90.20 5/7/2025 14:00:00 1682.28 90.19 5/7/2025 14:30:00 1682.60 90.17 5/7/2025 15:00:00 1682.91 90.16 5/7/2025 15:30:00 1683.21 90.15 5/7/2025 16:00:00 1683.51 90.14 5/7/2025 16:30:00 1683.79 90.12 5/7/2025 17:00:00 1684.07 90.11 5/7/2025 17:30:00 1684.35 90.11 5/7/2025 18:00:00 1684.62 90.10 5/7/2025 18:30:00 1684.90 90.08 5/7/2025 19:00:00 1685.17 90.07 5/7/2025 19:30:00 1685.44 90.06 5/7/2025 20:00:00 1685.72 90.05 5/7/2025 20:30:00 1685.98 90.03 5/7/2025 21:00:00 1686.22 90.02 5/7/2025 21:30:00 1686.46 90.01 5/7/2025 22:00:00 1686.68 90.00 5/7/2025 22:30:00 1686.91 90.00 5/7/2025 23:00:00 1687.13 89.98 5/7/2025 23:30:00 1687.35 89.97 5/8/2025 0:00:00 1687.57 89.97 5/8/2025 0:30:00 1687.79 89.96 5/8/2025 1:00:00 1688.00 89.94 5/8/2025 1:30:00 1688.22 89.93 5/8/2025 2:00:00 1688.43 89.92 5/8/2025 2:30:00 1688.64 89.91 5/8/2025 3:00:00 1688.85 89.91 5/8/2025 3:30:00 1689.06 89.89 5/8/2025 4:00:00 1689.27 89.88 5/8/2025 4:30:00 1689.47 89.87 5/8/2025 5:00:00 1689.68 89.87 5/8/2025 5:30:00 1689.88 89.86 5/8/2025 6:00:00 1690.08 89.85 5/8/2025 6:30:00 1690.28 89.85 5/8/2025 7:00:00 1690.48 89.84 5/8/2025 7:30:00 1690.67 89.83 5/8/2025 8:00:00 1690.87 89.82 5/8/2025 8:30:00 1691.06 89.80 5/8/2025 9:00:00 1691.25 89.80 5/8/2025 9:30:00 1691.44 89.79 5/8/2025 10:00:00 1691.63 89.79 5/8/2025 10:30:00 1691.82 89.78 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 55 >ŽĐĂƚŝŽŶͬ&ŝĞůĚ͗WŝŬŬĂĞǀĞůŽƉŵĞŶƚͬEͲ ^ƚĂƌƚĂƚĂ͗5-May-2025 @ 02:00 ŶĚĂƚĞ͗12-May-2025 @ 02:00 (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDBi-049 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 5/8/2025 11:00:00 1692.00 89.76 5/8/2025 11:30:00 1692.19 89.75 5/8/2025 12:00:00 1692.36 89.74 5/8/2025 12:30:00 1692.55 89.73 5/8/2025 13:00:00 1692.73 89.73 5/8/2025 13:30:00 1692.91 89.72 5/8/2025 14:00:00 1693.09 89.72 5/8/2025 14:30:00 1693.26 89.71 5/8/2025 15:00:00 1693.44 89.70 5/8/2025 15:30:00 1693.62 89.70 5/8/2025 16:00:00 1693.79 89.68 5/8/2025 16:30:00 1693.96 89.67 5/8/2025 17:00:00 1694.14 89.66 5/8/2025 17:30:00 1694.31 89.65 5/8/2025 18:00:00 1694.48 89.64 5/8/2025 18:30:00 1694.65 89.64 5/8/2025 19:00:00 1694.81 89.63 5/8/2025 19:30:00 1694.98 89.63 5/8/2025 20:00:00 1695.14 89.61 5/8/2025 20:30:00 1695.31 89.61 5/8/2025 21:00:00 1695.47 89.60 5/8/2025 21:30:00 1695.63 89.60 5/8/2025 22:00:00 1695.80 89.59 5/8/2025 22:30:00 1695.96 89.57 5/8/2025 23:00:00 1696.12 89.57 5/8/2025 23:30:00 1696.27 89.56 5/9/2025 0:00:00 1696.43 89.56 5/9/2025 0:30:00 1696.59 89.55 5/9/2025 1:00:00 1696.74 89.55 5/9/2025 1:30:00 1696.89 89.54 5/9/2025 2:00:00 1697.05 89.53 5/9/2025 2:30:00 1697.19 89.52 5/9/2025 3:00:00 1697.35 89.52 5/9/2025 3:30:00 1697.49 89.51 5/9/2025 4:00:00 1697.64 89.50 5/9/2025 4:30:00 1697.79 89.50 5/9/2025 5:00:00 1697.94 89.48 5/9/2025 5:30:00 1698.08 89.47 5/9/2025 6:00:00 1698.23 89.47 5/9/2025 6:30:00 1698.37 89.47 5/9/2025 7:00:00 1698.52 89.45 5/9/2025 7:30:00 1698.66 89.45 5/9/2025 8:00:00 1698.80 89.45 5/9/2025 8:30:00 1698.94 89.44 5/9/2025 9:00:00 1699.08 89.44 5/9/2025 9:30:00 1699.22 89.43 5/9/2025 10:00:00 1699.35 89.42 5/9/2025 10:30:00 1699.49 89.42 5/9/2025 11:00:00 1699.62 89.42 5/9/2025 11:30:00 1699.76 89.40 5/9/2025 12:00:00 1699.89 89.39 5/9/2025 12:30:00 1700.03 89.39 5/9/2025 13:00:00 1700.16 89.39 5/9/2025 13:30:00 1700.29 89.38 5/9/2025 14:00:00 1700.43 89.38 5/9/2025 14:30:00 1700.56 89.37 5/9/2025 15:00:00 1700.69 89.36 5/9/2025 15:30:00 1700.82 89.36 5/9/2025 16:00:00 1700.94 89.34 5/9/2025 16:30:00 1701.07 89.34 5/9/2025 17:00:00 1701.20 89.33 5/9/2025 17:30:00 1701.33 89.33 5/9/2025 18:00:00 1701.45 89.33 5/9/2025 18:30:00 1701.58 89.32 5/9/2025 19:00:00 1701.70 89.32 5/9/2025 19:30:00 1701.83 89.32 5/9/2025 20:00:00 1701.95 89.31 5/9/2025 20:30:00 1702.07 89.30 5/9/2025 21:00:00 1702.19 89.29 5/9/2025 21:30:00 1702.32 89.29 5/9/2025 22:00:00 1702.45 89.28 5/9/2025 22:30:00 1702.57 89.27 5/9/2025 23:00:00 1702.69 89.27 5/9/2025 23:30:00 1702.81 89.26 5/10/2025 0:00:00 1702.93 89.26 5/10/2025 0:30:00 1703.04 89.25 5/10/2025 1:00:00 1703.16 89.25 5/10/2025 1:30:00 1703.27 89.23 5/10/2025 2:00:00 1703.38 89.23 5/10/2025 2:30:00 1703.50 89.23 5/10/2025 3:00:00 1703.61 89.22 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 56 >ŽĐĂƚŝŽŶͬ&ŝĞůĚ͗WŝŬŬĂĞǀĞůŽƉŵĞŶƚͬEͲ ^ƚĂƌƚĂƚĂ͗5-May-2025 @ 02:00 ŶĚĂƚĞ͗12-May-2025 @ 02:00 (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDBi-049 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 5/10/2025 3:30:00 1703.73 89.22 5/10/2025 4:00:00 1703.84 89.21 5/10/2025 4:30:00 1703.95 89.21 5/10/2025 5:00:00 1704.06 89.21 5/10/2025 5:30:00 1704.17 89.20 5/10/2025 6:00:00 1704.28 89.20 5/10/2025 6:30:00 1704.39 89.19 5/10/2025 7:00:00 1704.50 89.18 5/10/2025 7:30:00 1704.61 89.18 5/10/2025 8:00:00 1704.71 89.17 5/10/2025 8:30:00 1704.82 89.17 5/10/2025 9:00:00 1704.92 89.17 5/10/2025 9:30:00 1705.03 89.16 5/10/2025 10:00:00 1705.13 89.16 5/10/2025 10:30:00 1705.24 89.16 5/10/2025 11:00:00 1705.35 89.15 5/10/2025 11:30:00 1705.45 89.14 5/10/2025 12:00:00 1705.56 89.14 5/10/2025 12:30:00 1705.66 89.14 5/10/2025 13:00:00 1705.76 89.13 5/10/2025 13:30:00 1705.87 89.12 5/10/2025 14:00:00 1705.97 89.12 5/10/2025 14:30:00 1706.07 89.12 5/10/2025 15:00:00 1706.18 89.11 5/10/2025 15:30:00 1706.28 89.11 5/10/2025 16:00:00 1706.38 89.11 5/10/2025 16:30:00 1706.48 89.10 5/10/2025 17:00:00 1706.58 89.10 5/10/2025 17:30:00 1706.68 89.09 5/10/2025 18:00:00 1706.78 89.09 5/10/2025 18:30:00 1706.88 89.08 5/10/2025 19:00:00 1706.98 89.08 5/10/2025 19:30:00 1707.08 89.08 5/10/2025 20:00:00 1707.17 89.07 5/10/2025 20:30:00 1707.27 89.07 5/10/2025 21:00:00 1707.37 89.07 5/10/2025 21:30:00 1707.47 89.06 5/10/2025 22:00:00 1707.56 89.05 5/10/2025 22:30:00 1707.65 89.05 5/10/2025 23:00:00 1707.75 89.05 5/10/2025 23:30:00 1707.84 89.04 5/11/2025 0:00:00 1707.94 89.04 5/11/2025 0:30:00 1708.03 89.04 5/11/2025 1:00:00 1708.12 89.04 5/11/2025 1:30:00 1708.21 89.02 5/11/2025 2:00:00 1708.30 89.02 5/11/2025 2:30:00 1708.39 89.02 5/11/2025 3:00:00 1708.47 89.02 5/11/2025 3:30:00 1708.56 89.01 5/11/2025 4:00:00 1708.65 89.01 5/11/2025 4:30:00 1708.74 89.01 5/11/2025 5:00:00 1708.83 89.00 5/11/2025 5:30:00 1708.91 88.99 5/11/2025 6:00:00 1709.00 88.99 5/11/2025 6:30:00 1709.09 88.99 5/11/2025 7:00:00 1709.18 88.98 5/11/2025 7:30:00 1709.26 88.98 5/11/2025 8:00:00 1709.35 88.98 5/11/2025 8:30:00 1709.43 88.97 5/11/2025 9:00:00 1709.52 88.96 5/11/2025 9:30:00 1709.61 88.96 5/11/2025 10:00:00 1709.69 88.96 5/11/2025 10:30:00 1709.78 88.95 5/11/2025 11:00:00 1709.86 88.95 5/11/2025 11:30:00 1709.94 88.94 5/11/2025 12:00:00 1710.03 88.94 5/11/2025 12:30:00 1710.11 88.94 5/11/2025 13:00:00 1710.20 88.93 5/11/2025 13:30:00 1710.28 88.93 5/11/2025 14:00:00 1710.36 88.93 5/11/2025 14:30:00 1710.45 88.92 5/11/2025 15:00:00 1710.53 88.92 5/11/2025 15:30:00 1710.61 88.92 5/11/2025 16:00:00 1710.70 88.91 5/11/2025 16:30:00 1710.78 88.91 5/11/2025 17:00:00 1710.86 88.91 5/11/2025 17:30:00 1710.94 88.91 5/11/2025 18:00:00 1711.03 88.90 5/11/2025 18:30:00 1711.11 88.90 5/11/2025 19:00:00 1711.19 88.89 5/11/2025 19:30:00 1711.27 88.89 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 57 >ŽĐĂƚŝŽŶͬ&ŝĞůĚ͗WŝŬŬĂĞǀĞůŽƉŵĞŶƚͬEͲ ^ƚĂƌƚĂƚĂ͗5-May-2025 @ 02:00 ŶĚĂƚĞ͗12-May-2025 @ 02:00 (mm-dd-yyyy hh:mm:ss)(psig) (°F) NDBi-049 DOWNHOLE_SHUT-IN / BUILD-UP PERIOD Date & Time BHP BHT COMMENTS 5/11/2025 20:00:00 1711.35 88.89 5/11/2025 20:30:00 1711.43 88.89 5/11/2025 21:00:00 1711.51 88.88 5/11/2025 21:30:00 1711.59 88.87 5/11/2025 22:00:00 1711.66 88.88 5/11/2025 22:30:00 1711.74 88.87 5/11/2025 23:00:00 1711.82 88.87 5/11/2025 23:30:00 1711.90 88.86 5/12/2025 0:00:00 1711.98 88.86 5/12/2025 0:30:00 1712.05 88.85 5/12/2025 1:00:00 1712.13 88.86 5/12/2025 1:30:00 1712.20 88.86 5/12/2025 2:00:00 1712.28 88.86 ϳĂLJƵŝůĚͲhƉŽŵƉůĞƚĞ͘ WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 58 88.089.090.091.092.093.094.095.096.097.098.099.0152015401560158016001620164016601680170017201740Pressure (psig)Bottom Hole Data_Build-up Period_NDBi-049BHPBHTTemperature (°F)WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 59 Santos – Pikka Development – NDBi-049 SECTION 11 SEQUENCE OF OPERATIONS WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 60 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 29-Apr-2025 09:30:00 29-Apr-2025 09:49:00 29-Apr-2025 09:50:00 29-Apr-2025 09:50:00 29-Apr-2025 09:52:00 29-Apr-2025 10:00:00 29-Apr-2025 10:15:00 29-Apr-2025 10:30:00 29-Apr-2025 10:30:00 29-Apr-2025 11:00:00 29-Apr-2025 11:00:00 29-Apr-2025 11:01:00 29-Apr-2025 11:30:00 29-Apr-2025 11:30:00 29-Apr-2025 11:31:00 29-Apr-2025 12:00:00 29-Apr-2025 12:01:00 29-Apr-2025 12:30:00 29-Apr-2025 12:30:00 29-Apr-2025 12:31:00 29-Apr-2025 13:00:00 29-Apr-2025 13:00:00 29-Apr-2025 13:00:00 29-Apr-2025 13:01:00 29-Apr-2025 13:29:00 29-Apr-2025 13:30:00 29-Apr-2025 13:30:00 29-Apr-2025 13:30:00 29-Apr-2025 13:30:00 29-Apr-2025 13:31:00 29-Apr-2025 13:31:00 29-Apr-2025 13:35:00 29-Apr-2025 13:38:00 29-Apr-2025 13:38:00 29-Apr-2025 13:38:00 29-Apr-2025 14:00:00 29-Apr-2025 14:00:00 29-Apr-2025 14:01:00 29-Apr-2025 14:11:00 29-Apr-2025 14:30:00 29-Apr-2025 14:30:00 29-Apr-2025 14:31:00 29-Apr-2025 14:31:00 29-Apr-2025 14:31:00 29-Apr-2025 15:00:00 29-Apr-2025 15:00:00 29-Apr-2025 15:00:00 29-Apr-2025 15:01:00 29-Apr-2025 15:01:00 29-Apr-2025 15:01:00 29-Apr-2025 15:30:00 29-Apr-2025 15:30:00 29-Apr-2025 15:31:00 29-Apr-2025 15:31:00 29-Apr-2025 15:31:00 29-Apr-2025 16:00:00 29-Apr-2025 16:00:00 Diverted Flow from Tank 2 to Tank 1. Increased Expro adjustable Choke to 28/64ths as per Santos WSS. BS&W at Choke Manifold Showed 100% Diesel. Increased Expro adjustable Choke to 32/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 100% Diesel. Verified Valve Alignment to Flow Path through Ball catcher and DPI Unit, Bypassing Separator into Tank 1. Initial SIBHP 1747.21 psig; Initial SIBHT 87.91 °F; Initial WHP 296.4 psig & Initial WHT 32.84°F. Opened Well on a 20/64ths adjustable Choke as per Santos WSS. Confirmed fluid at Tank Farm Manifold. Diverted Flow from Tank 1 to Tank 2. Increased Expro adjustable Choke to 24/64ths as per Santos WSS. 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS Pre-Flow Safety Meeting for NDBi-049 with Santos WSS, Expro, Magtec and LRS. Opened WH NDBi-049 Master Valve (23.5 turns). Opened WH NDBi-049 Production Wing Valve to closed Expro Choke Manifold. (24 Turns). NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: Oil at Surface. Diverted Well Flow through Separator. BS&W at Choke Manifold Showed 34% Water and Trace Solids. Oil = 66%. Oil API 31.9 @ 60F (Oil SG 0.866). Gas Metering through 0.5" Coriolis Meter. Adjusted DAQ Fluid Cumulative Volumes to account for Volumes not Metered while the Separator was being Bypassed. Oil Cum 214.79 bbls. Water Cum 4.24 bbls. Total Fluid Cum 219.02 bbls. Diverted Flow from Tank 2 to Tank 1. Flare Ignited. BS&W at Choke Manifold Showed 100% Diesel. Gas at Surface. Diverted Flow from Tank 1 to Tank 2. Increased Expro adjustable Choke to 44/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 100% Diesel. 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% Diesel. Increased Expro adjustable Choke to 40/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 80% Water and Trace Solids. Oil = 20%. Gas SG = 0.676, CO2 = 0.1%, H2S = 0 ppm. Upstream DPI BS&W sample showed Trace Solids Increased Expro adjustable Choke to 60/64ths as per Santos WSS. Increased Expro adjustable Choke to 52/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 75% Water and Trace Solids. Oil = 25%. Water Salinity = 36,000 ppm. Water pH = 8. Water Weight = 8.52 ppg. Gas SG = 0.676. Increased Expro adjustable Choke to 56/64ths as per Santos WSS. Commenced Chemical Injection of Defoamer & Demulsifier @ 8 gal/d. Liquid Metering through 1.5" Turbine Meter. Increased Expro adjustable Choke to 48/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 80% Water and Trace Solids. Oil = 20%. Adjusted Separator Liquid Level. Diverted Flow from Tank 1 to Tank 2. Oil API 30.9 @ 60F (Oil SG 0.871). BS&W at Choke Manifold Showed 75% Water and Trace Solids. Oil = 25%. Water Salinity = 33,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. Increased Expro adjustable Choke to 64/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 61 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 29-Apr-2025 16:00:00 29-Apr-2025 16:01:00 29-Apr-2025 16:01:00 29-Apr-2025 16:15:00 29-Apr-2025 16:30:00 29-Apr-2025 16:31:00 29-Apr-2025 16:31:00 29-Apr-2025 16:44:00 29-Apr-2025 17:00:00 29-Apr-2025 17:00:00 29-Apr-2025 17:00:00 29-Apr-2025 17:01:00 29-Apr-2025 17:01:00 29-Apr-2025 17:25:00 29-Apr-2025 17:30:00 29-Apr-2025 17:30:00 29-Apr-2025 17:31:00 29-Apr-2025 17:31:00 29-Apr-2025 17:45:00 29-Apr-2025 18:00:00 29-Apr-2025 18:00:00 29-Apr-2025 18:00:00 29-Apr-2025 18:00:00 29-Apr-2025 18:01:00 29-Apr-2025 18:01:00 29-Apr-2025 18:15:00 29-Apr-2025 18:30:00 29-Apr-2025 18:30:00 29-Apr-2025 18:30:00 29-Apr-2025 18:31:00 29-Apr-2025 18:31:00 29-Apr-2025 18:31:00 29-Apr-2025 18:45:00 29-Apr-2025 18:50:00 29-Apr-2025 19:00:00 29-Apr-2025 19:00:00 29-Apr-2025 19:00:00 29-Apr-2025 19:00:00 29-Apr-2025 19:00:00 29-Apr-2025 19:01:00 29-Apr-2025 19:01:00 29-Apr-2025 19:15:00 29-Apr-2025 19:15:00 29-Apr-2025 19:30:00 29-Apr-2025 19:30:00 29-Apr-2025 19:30:00 29-Apr-2025 19:31:00 29-Apr-2025 19:31:00 29-Apr-2025 19:31:00 29-Apr-2025 20:00:00 29-Apr-2025 20:00:00 29-Apr-2025 20:00:00 29-Apr-2025 20:01:00 29-Apr-2025 20:01:00 29-Apr-2025 20:30:00 29-Apr-2025 20:30:00 29-Apr-2025 20:31:00 Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.36 ppg. Began transferring fluid from Tank #1 to Worley Truck 82325. RVP 6. Diverted Flow from Tank 3 to Tank 4. Applied CMSF = 0.987. Upstream DPI BS&W sample showed Trace Solids BS&W at Choke Manifold Showed 60% Water and Trace Solids. Oil = 40%. Upstream DPI BS&W sample showed Trace Solids BS&W at Choke Manifold Showed 68% Water and Trace Solids. Oil = 32%. Gas SG = 0.680, CO2 = 0.1%, H2S = 0 ppm. Collected Flare Heat Index. Diverted Flow from Tank 1 to Tank 3. BS&W at Choke Manifold Showed 66% Water and Trace Solids. Oil = 34%. BS&W at Choke Manifold Showed 48% Water, Trace Solids and Trace Emulsion. Oil = 52%. Began transferring fluid from Tank #2 to Worley Truck 86085. RVP 6. Diverted Flow from Tank 4 to Tank 3. Increased Expro adjustable Choke to 76/64ths as per Santos WSS. Upstream DPI BS&W sample showed No Solids. Oil API 29.9 @ 60F (Oil SG 0.877). Finished transferring fluid from Tank #1 to Worley Truck 82325. Diverted Flow from Tank 3 to Tank 4. Increased Expro adjustable Choke to 70/64ths as per Santos WSS. Upstream DPI BS&W sample showed Trace Solids. Collected Tracerco Dye Water Sample. Gas SG = 0.667, CO2 = 0.1%, H2S = 0 ppm. Gas SG = 0.664, CO2 = 0.1%, H2S = 0 ppm. Dumped DPI Unit Side A and Side B. No Solids Observed on both Sides. Diverted Flow from Tank 4 to Tank 3. Upstream DPI BS&W sample showed Trace Solids. BS&W at Choke Manifold Showed 76% Water and Trace Solids. Oil = 24%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Isolated Flare Ignitor Propane Supply. Increased Expro adjustable Choke to 88/64ths as per Santos WSS. Diverted Flow from Tank 4 to Tank 3. Dumped DPI Unit Side A and Side B. Trace Solids observed on Side A and No Solids observed on Side B. Oil API 31.0 @ 60F (Oil SG 0.871). BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. Increased Expro adjustable Choke to 82/64ths as per Santos WSS. Gas Scrubber Free of Fluid. Applied CMSF 0.959. Gas SG = 0.660, CO2 = 0.1%, H2S = 0 ppm. BS&W at Choke Manifold Showed 46% Water, Trace Solids and Trace Emulsion. Oil = 54%. Flare Base Free of Fluid. BS&W at Choke Manifold Showed 28% Water, Trace Solids and 18% Emulsion. Oil = 54%. Water Salinity = 33,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. Discussed Bubble Point Limit with Santos WSS - Instructed to carry on with Choke changes causing BHP to go below Bubble Point. Finished transferring fluid from Tank #2 to Worley truck 86085. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 3 to Tank 4. Increased Expro adjustable Choke to 100/64ths as per Santos WSS. Diverted Flow from Tank 4 to Tank 1. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.33 ppg. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.34 ppg. Upstream DPI BS&W sample showed No Solids. Increased Expro adjustable Choke to 94/64ths as per Santos WSS. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 28% Water and Trace Solids. Oil = 72%. Gas SG = 0.657, CO2 = 0.1%, H2S = 0 ppm. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 62 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 29-Apr-2025 20:31:00 29-Apr-2025 20:35:00 29-Apr-2025 20:57:00 29-Apr-2025 21:00:00 29-Apr-2025 21:00:00 29-Apr-2025 21:00:00 29-Apr-2025 21:00:00 29-Apr-2025 21:01:00 29-Apr-2025 21:23:00 29-Apr-2025 21:30:00 29-Apr-2025 21:30:00 29-Apr-2025 21:31:00 29-Apr-2025 21:31:00 29-Apr-2025 21:45:00 29-Apr-2025 21:48:00 29-Apr-2025 22:00:00 29-Apr-2025 22:00:00 29-Apr-2025 22:00:00 29-Apr-2025 22:01:00 29-Apr-2025 22:05:00 29-Apr-2025 22:08:00 29-Apr-2025 22:15:00 29-Apr-2025 22:24:00 29-Apr-2025 22:30:00 29-Apr-2025 22:30:00 29-Apr-2025 22:31:00 29-Apr-2025 22:31:00 29-Apr-2025 23:00:00 29-Apr-2025 23:00:00 29-Apr-2025 23:00:00 29-Apr-2025 23:01:00 29-Apr-2025 23:05:00 29-Apr-2025 23:30:00 29-Apr-2025 23:31:00 29-Apr-2025 23:31:00 30-Apr-2025 00:00:00 30-Apr-2025 00:00:00 30-Apr-2025 00:00:00 30-Apr-2025 00:00:00 30-Apr-2025 00:01:00 30-Apr-2025 00:01:00 30-Apr-2025 00:01:00 30-Apr-2025 00:15:00 30-Apr-2025 00:30:00 30-Apr-2025 00:31:00 30-Apr-2025 00:31:00 30-Apr-2025 01:00:00 30-Apr-2025 01:00:00 30-Apr-2025 01:00:00 30-Apr-2025 01:01:00 30-Apr-2025 01:13:00 30-Apr-2025 01:15:00 30-Apr-2025 01:25:00 30-Apr-2025 01:30:00 30-Apr-2025 01:31:00 30-Apr-2025 01:31:00 30-Apr-2025 02:00:00 Upstream DPI BS&W sample showed No Solids. Increased Expro adjustable Choke to 106/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 34% Water and Trace Solids. Oil = 66%. Gas Scrubber Free of Fluid. BS&W at Choke Manifold Showed 38% Water and Trace Solids. Oil = 62%. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Began transferring fluid from Tank #4 to Worley Truck 86058. RVP 6. Began Injecting Emulsion Breaker DMO46X. Finished transferring fluid from Tank #4 to Worley Truck 86058. Increased Expro adjustable Choke to 124/64ths as per Santos WSS. Diverted Flow from Tank 2 to Tank 1. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.40 ppg. BS&W at Choke Manifold Showed 28% Water and Trace Solids. Oil = 72%. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 1 to Tank 2. Increased Expro adjustable Choke to 118/64ths as per Santos WSS. BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. Dumped DPI Unit Side A and Side B. Trace Solids observed on Side A and No Solids Observed on Side B. Gas Scrubber Free of Fluid. Diverted Flow from Tank 2 to Tank 1. Increased Expro adjustable Choke to 112/64ths as per Santos WSS. BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.40 ppg. Flare Base Free of Fluid. Diverted Gas Flow from 0.5" Coriolis Meter through 3" Coriolis Meter. BS&W at Choke Manifold Showed 16% Water and Trace Solids. Oil = 84%. Gas SG = 0.658, CO2 = 0.1%, H2S = 0 ppm. Oil API 30.1 @ 60F (Oil SG 0.876). Diverted Flow from Tank 1 to Tank 2. (15 min Flow) Diverted Flow from Tank 2 to Tank 5. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Upstream DPI BS&W sample showed No Solids. Dumped DPI Unit Side A and Side B. No Solids observed. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. Increased Expro adjustable Choke to 128/64ths as per Santos WSS. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 24% Water and Trace Solids. Oil = 76%. Dumped DPI Unit Side A and Side B. Trace Solids Observed on Side A and No Solids Observed on Side B. Diverted Flow from Tank 2 to Tank 4. Began Injecting Tank 1 and Tank 2 down NDBi-014 @ 2.8 bbls/min. Flare Base Free of Fluid. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 10% Water. Oil = 90%. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Diverted Flow from Tank 5 to Tank 4. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.42 ppg. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 5 to Tank 4. Dumped DPI Unit Side A and Side B. Trace Solids observed on Side A and No Solids observed on Side B. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Gas Scrubber Free of Fluid. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 63 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 30-Apr-2025 02:00:00 30-Apr-2025 02:00:00 30-Apr-2025 02:01:00 30-Apr-2025 02:30:00 30-Apr-2025 02:30:00 30-Apr-2025 02:31:00 30-Apr-2025 02:31:00 30-Apr-2025 03:00:00 30-Apr-2025 03:00:00 30-Apr-2025 03:00:00 30-Apr-2025 03:00:00 30-Apr-2025 03:00:00 30-Apr-2025 03:01:00 30-Apr-2025 03:30:00 30-Apr-2025 03:30:00 30-Apr-2025 03:31:00 30-Apr-2025 03:31:00 30-Apr-2025 04:00:00 30-Apr-2025 04:00:00 30-Apr-2025 04:00:00 30-Apr-2025 04:00:00 30-Apr-2025 04:00:00 30-Apr-2025 04:01:00 30-Apr-2025 04:09:00 30-Apr-2025 04:15:00 30-Apr-2025 04:18:00 30-Apr-2025 04:30:00 30-Apr-2025 04:31:00 30-Apr-2025 04:31:00 30-Apr-2025 05:00:00 30-Apr-2025 05:00:00 30-Apr-2025 05:00:00 30-Apr-2025 05:01:00 30-Apr-2025 05:30:00 30-Apr-2025 05:31:00 30-Apr-2025 05:31:00 30-Apr-2025 05:58:00 30-Apr-2025 06:00:00 30-Apr-2025 06:00:00 30-Apr-2025 06:00:00 30-Apr-2025 06:01:00 30-Apr-2025 06:30:00 30-Apr-2025 06:30:00 30-Apr-2025 06:31:00 30-Apr-2025 06:31:00 30-Apr-2025 07:00:00 30-Apr-2025 07:00:00 30-Apr-2025 07:00:00 30-Apr-2025 07:01:00 30-Apr-2025 07:30:00 30-Apr-2025 07:31:00 30-Apr-2025 07:31:00 30-Apr-2025 07:32:00 30-Apr-2025 08:00:00 30-Apr-2025 08:01:00 30-Apr-2025 08:01:00 30-Apr-2025 08:01:00 Dumped DPI Unit Side A and Side B. Trace Solids observed on both Sides. Injection Rate into NDBi-014 @ 2.87 bpm with a Total of 132.79 bbls Injected. BS&W at Choke Manifold Showed 8% Water. Oil = 92%. Diverted Flow from Tank 4 to Tank 5. Injection Rate into NDBi-014 @ 2.86 bpm with a Total of 237.65 bbls Injected. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.43 ppg. Diverted Flow from Tank 7 to Tank 6. Completed Flare Heat Index. Dumped DPI Unit Side A and Side B. Trace Solids observed on Side A and No Solids Observed on Side B. Injection Rate into NDBi-014 @ 2.86 bpm with a Total of 471.84 bbls Injected. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Flare Base Free of Fluid. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Diverted Flow from Tank 6 to Tank 7. Injection Rate into NDBi-014 @ 2.86 bpm with a Total of 386.45 bbls Injected. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Upstream DPI BS&W sample showed No Solids. BS&W at Choke Manifold Showed 14% Water. Oil = 86%. Upstream DPI BS&W sample showed No Solids. Dumped DPI Unit Side A and Side B. Trace Solids observed on both Sides. Collected Tracerco Dye Water Sample. Injection Rate into NDBi-014 @ 2.84 bpm with a Total of 300.19 bbls Injected. Began transferring fluid from Tank #3 to Worley Truck 86088. RVP 6. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. Diverted Flow from Tank 7 to Tank 1. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Diverted Flow from Tank 1 to Tank 2. Dumped DPI Unit Side A and Side B. Trace Solids Observed on Side A and No Solids Observed on Side B. Diverted Flow from Tank 7 to Tank 6. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Diverted Flow from Tank 6 to Tank 7. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Finished transferring fluid from Tank #3 to Worley Truck 86088. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Upstream DPI BS&W sample showed No Solids. Dumped DPI Unit Side A and Side B. Trace Solids Observed on Side A and No Solids Observed on Side B. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Gas SG = 0.656, CO2 = 0.1%, H2S = 0 ppm. Dumped DPI Unit Side A and Side B. Trace Solids Observed on Side A and No Solids Observed on Side B. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Diverted Liquid Flow from 1.5'' Turbine Meter through 2'' Turbine Meter. Diverted Flow from Tank 2 to Tank 1. Applied CMSF 0.935. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Diverted Flow from Tank 2 to Tank 1. Injection Rate into NDBi-014 @ 2.84 bpm with a Total of 983.18 bbls Injected. Added Tank 6 and Tank 7 to NDBi-014 Injection and Removed Tank 4 and Tank 5. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 64 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 30-Apr-2025 08:01:00 30-Apr-2025 08:02:00 30-Apr-2025 08:28:00 30-Apr-2025 08:30:00 30-Apr-2025 08:30:00 30-Apr-2025 08:31:00 30-Apr-2025 08:31:00 30-Apr-2025 08:35:00 30-Apr-2025 09:00:00 30-Apr-2025 09:00:00 30-Apr-2025 09:01:00 30-Apr-2025 09:01:00 30-Apr-2025 09:21:00 30-Apr-2025 09:30:00 30-Apr-2025 09:31:00 30-Apr-2025 09:31:00 30-Apr-2025 09:44:00 30-Apr-2025 09:48:00 30-Apr-2025 10:00:00 30-Apr-2025 10:01:00 30-Apr-2025 10:01:00 30-Apr-2025 10:01:00 30-Apr-2025 10:30:00 30-Apr-2025 10:30:00 30-Apr-2025 10:31:00 30-Apr-2025 10:31:00 30-Apr-2025 10:44:00 30-Apr-2025 10:46:00 30-Apr-2025 10:55:00 30-Apr-2025 11:00:00 30-Apr-2025 11:01:00 30-Apr-2025 11:04:00 30-Apr-2025 11:17:00 30-Apr-2025 11:30:00 30-Apr-2025 11:31:00 30-Apr-2025 11:33:00 30-Apr-2025 11:41:00 30-Apr-2025 11:55:00 30-Apr-2025 12:00:00 30-Apr-2025 12:00:00 30-Apr-2025 12:00:00 30-Apr-2025 12:01:00 30-Apr-2025 12:02:00 30-Apr-2025 12:10:00 30-Apr-2025 12:18:00 30-Apr-2025 12:30:00 30-Apr-2025 12:30:00 30-Apr-2025 12:31:00 30-Apr-2025 12:32:00 30-Apr-2025 12:56:00 30-Apr-2025 13:00:00 30-Apr-2025 13:01:00 30-Apr-2025 13:01:00 30-Apr-2025 13:19:00 30-Apr-2025 13:25:00 30-Apr-2025 13:30:00 30-Apr-2025 13:30:00 Oil API 30.1 @ 60F (Oil SG 0.876). Upstream DPI BS&W sample showed Trace Solids Adjusted Separator Pressure. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 6 and Tank 7. Gas Scrubber Free of Fluid. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 4% Water and Trace Solids. Oil = 96%. Dumped DPI Unit Side A and Side B. No Solids Observed on both Sides. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Dumped DPI Unit Side A and Side B. No Solids Observed on both Sides. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 4% Water and Trace Solids. Oil = 96%. Diverted Flow from Tank 1 to Tank 2. Applied CMSF 0.939. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Lowered Separator Pressure. Diverted Flow from Tank 2 to Tank 3. Diverted Flow from Tank 3 to Tank 5. BS&W at Choke Manifold Showed 4% Water and Trace Solids. Oil = 96%. Observed Well Slugging. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Observed Well Slugging. Diverted Flow from Tank 5 to Tank 6. Bypassed Expro Ball Catcher. Opened and Inspected Ball Catcher. No Debris Present. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 4% Water and Trace Solids. Oil = 96%. Diverted Well Flow back through Ball Catcher. Ball Catcher In Service. Observed Well Slugging. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 3 to Tank 4. Injection Rate into NDBi-014 @ 2.49 bpm with a Total of 1567.48 bbls Injected. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. No Solids Observed on both Sides. BS&W at Choke Manifold Showed 49.5% Water and 0.5% Solids. Oil = 50%. Water Salinity = 35,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Increased separator pressure. Sparged Separator. Observed Traces solids Diverted Flow from Tank 6 to Tank 5. Collected Core lab sample. Diverted Flow from Tank 6 to Tank 5. Observed Well Slugging. BS&W at Choke Manifold Showed 48% Water and 2% Solids. Oil = 50%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Diverted Flow from Tank 5 to Tank 6. Completed Tracerco Dye Water Sample. Kit #1 Complete. Collected Tracerco Standard Sample. BS&W at Choke Manifold Showed 30% Water and Trace Solids. Oil = 70%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Flare Base Free of Fluid. Upstream DPI BS&W sample showed Trace Solids. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 65 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 30-Apr-2025 13:31:00 30-Apr-2025 13:31:00 30-Apr-2025 13:32:00 30-Apr-2025 13:57:00 30-Apr-2025 13:59:00 30-Apr-2025 14:00:00 30-Apr-2025 14:00:00 30-Apr-2025 14:01:00 30-Apr-2025 14:01:00 30-Apr-2025 14:02:00 30-Apr-2025 14:30:00 30-Apr-2025 14:31:00 30-Apr-2025 15:00:00 30-Apr-2025 15:00:00 30-Apr-2025 15:00:00 30-Apr-2025 15:01:00 30-Apr-2025 15:01:00 30-Apr-2025 15:12:00 30-Apr-2025 15:30:00 30-Apr-2025 15:30:00 30-Apr-2025 15:31:00 30-Apr-2025 15:31:00 30-Apr-2025 16:00:00 30-Apr-2025 16:01:00 30-Apr-2025 16:02:00 30-Apr-2025 16:13:00 30-Apr-2025 16:30:00 30-Apr-2025 16:31:00 30-Apr-2025 16:31:00 30-Apr-2025 17:00:00 30-Apr-2025 17:00:00 30-Apr-2025 17:01:00 30-Apr-2025 17:01:00 30-Apr-2025 17:01:00 30-Apr-2025 17:30:00 30-Apr-2025 17:31:00 30-Apr-2025 17:31:00 30-Apr-2025 18:00:00 30-Apr-2025 18:00:00 30-Apr-2025 18:00:00 30-Apr-2025 18:00:00 30-Apr-2025 18:00:00 30-Apr-2025 18:01:00 30-Apr-2025 18:30:00 30-Apr-2025 18:30:00 30-Apr-2025 18:30:00 30-Apr-2025 18:31:00 30-Apr-2025 18:31:00 30-Apr-2025 18:34:00 30-Apr-2025 18:37:00 30-Apr-2025 19:00:00 30-Apr-2025 19:00:00 30-Apr-2025 19:00:00 30-Apr-2025 19:01:00 30-Apr-2025 19:05:00 30-Apr-2025 19:14:00 30-Apr-2025 19:30:00 Diverted Flow from Tank 5 to Tank 9. Dumped DPI Unit Side A and Side B. No solids Observed on Side A and No solids on Side B. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Gas SG = 0.694. CO2 = 0.1%, H2S = 0 ppm. Collected Flare Heat Index. Injection Rate into NDBi-014 @ 2.49 bpm with a Total of 2086.07 bbls Injected. BS&W at Choke Manifold Showed 70% Water and Trace Solids. Oil = 30%. Water Salinity = 35,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 50% Water and Trace Solids. Oil = 50%. Oil API 30.3 @ 60F (Oil SG 0.875). BS&W at Choke Manifold Showed 59.5% Water and 0.5% Solids. Oil = 40%. Tracerco representative collected Dye sample kit #1. Observed Well Slugging. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Diverted Flow from Tank 5 to Tank 6. Injection Rate into NDBi-014 @ 2.2 bpm with a Total of 2500.22 bbls Injected. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Flare Base Free of Fluid. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 12% Water and 0.5% Solids. Oil = 88%. Water Salinity = 35,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Diverted Flow from Tank 10 to Tank 9. Diverted Flow from Tank 9 to Tank 10. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. BS&W at Choke Manifold Showed 52% Water and Trace Solids. Oil = 48%. Water Salinity = 35,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 50% Water and Trace Solids. Oil = 50%. Increased Injection Rate to 2.6 bpm into well NDBi-014. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 2.59 bpm with a Total of 2786.58 bbls Injected. BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. BS&W at Choke Manifold Showed 36% Water and Trace Solids. Oil = 64%. Diverted Flow from Tank 8 to Tank 7. Upstream DPI BS&W sample showed No Solids. Injection Rate into NDBi-014 @ 2.35 bpm with a Total of 2710.53 bbls Injected. BS&W at Choke Manifold Showed 28% Water and Trace Solids. Oil = 72%. Water Salinity = 35,000 ppm. Water pH = 8. Water Weight = 8.50 ppg. Water Salinity = 35,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Diverted Flow from Tank 10 to Tank 8. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. Injection Rate into NDBi-014 @ 2.34 bpm with a Total of 2640.99 bbls Injected. Gas Scrubber Free of Fluid. Flare Base Free of Fluid. Diverted Flow from Tank 8 to Tank 7. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 66 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 30-Apr-2025 19:30:00 30-Apr-2025 19:30:00 30-Apr-2025 19:31:00 30-Apr-2025 19:31:00 30-Apr-2025 20:00:00 30-Apr-2025 20:00:00 30-Apr-2025 20:00:00 30-Apr-2025 20:01:00 30-Apr-2025 20:30:00 30-Apr-2025 20:30:00 30-Apr-2025 20:30:00 30-Apr-2025 20:31:00 30-Apr-2025 20:31:00 30-Apr-2025 21:00:00 30-Apr-2025 21:00:00 30-Apr-2025 21:00:00 30-Apr-2025 21:00:00 30-Apr-2025 21:01:00 30-Apr-2025 21:20:00 30-Apr-2025 21:30:00 30-Apr-2025 21:30:00 30-Apr-2025 21:30:00 30-Apr-2025 21:31:00 30-Apr-2025 21:31:00 30-Apr-2025 22:00:00 30-Apr-2025 22:00:00 30-Apr-2025 22:00:00 30-Apr-2025 22:01:00 30-Apr-2025 22:30:00 30-Apr-2025 22:30:00 30-Apr-2025 22:30:00 30-Apr-2025 22:31:00 30-Apr-2025 22:31:00 30-Apr-2025 22:41:00 30-Apr-2025 23:00:00 30-Apr-2025 23:00:00 30-Apr-2025 23:01:00 30-Apr-2025 23:30:00 30-Apr-2025 23:30:00 30-Apr-2025 23:30:00 30-Apr-2025 23:31:00 30-Apr-2025 23:31:00 01-May-2025 00:00:00 01-May-2025 00:00:00 01-May-2025 00:00:00 01-May-2025 00:00:00 01-May-2025 00:00:00 01-May-2025 00:00:00 01-May-2025 00:01:00 01-May-2025 00:01:00 01-May-2025 00:01:00 01-May-2025 00:10:00 01-May-2025 00:30:00 01-May-2025 00:30:00 01-May-2025 00:31:00 01-May-2025 00:31:00 01-May-2025 00:37:00 Upstream DPI BS&W sample showed No Solids. Injection Rate into NDBi-014 @ 2.6 bpm with a Total of 3050.69 bbls Injected. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Injection Rate into NDBi-014 @ 2.62 bpm with a Total of 3100.99 bbls Injected. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 2.61 bpm with a Total of 2954.57 bbls Injected. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Diverted Flow from Tank 8 to Tank 1. Upstream DPI BS&W sample showed No Solids. Injection Rate into NDBi-014 @ 2.64 bpm with a Total of 2866.72 bbls Injected. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 2 to Tank 3. Injection Rate into NDBi-014 @ 2.62 bpm with a Total of 3360.15 bbls Injected. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.42 ppg. Injection Rate into NDBi-014 @ 2.64 bpm with a Total of 3186.19 bbls Injected. Water Salinity = 30,000 ppm. Water pH = 8. Water Weight = 8.42 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 1 to Tank 2. Injection Rate into NDBi-014 @ 2.65 bpm with a Total of 3249.09 bbls Injected. Diverted Flow from Tank 1 to Tank 2. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Diverted Flow from Tank 2 to Tank 1. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 3 to Tank 4. LRS Injection Pump offline for Preventative Maintenance / Data Download. Injection Rate into NDBi-014 @ 0 bpm with a Total of 3581.86 bbls Injected. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Oil API 30.3 @ 60F (Oil SG 0.875). Gas SG = 0.682, CO2 = 0.1%, H2S = 0 ppm. Injection Rate into NDBi-014 @ 2.61 bpm with a Total of 3498.26 bbls Injected. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Collected Tracerco Standard Sample. Collected Tracerco Dye Water Sample. Dumped DPI Unit Side A and Side B. No Solids Observed on both Sides. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 16% Water and Trace Solids. Oil = 84%. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 4 to Tank 3. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 4 to Tank 7. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.50 ppg. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. LRS Injection Pump back Online @ 2.8 bpm. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 67 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 01-May-2025 01:00:00 01-May-2025 01:00:00 01-May-2025 01:00:00 01-May-2025 01:01:00 01-May-2025 01:16:00 01-May-2025 01:30:00 01-May-2025 01:30:00 01-May-2025 01:30:00 01-May-2025 01:31:00 01-May-2025 01:31:00 01-May-2025 02:00:00 01-May-2025 02:00:00 01-May-2025 02:00:00 01-May-2025 02:01:00 01-May-2025 02:30:00 01-May-2025 02:30:00 01-May-2025 02:30:00 01-May-2025 02:31:00 01-May-2025 02:31:00 01-May-2025 02:54:00 01-May-2025 03:00:00 01-May-2025 03:00:00 01-May-2025 03:00:00 01-May-2025 03:00:00 01-May-2025 03:01:00 01-May-2025 03:05:00 01-May-2025 03:30:00 01-May-2025 03:30:00 01-May-2025 03:30:00 01-May-2025 03:31:00 01-May-2025 03:31:00 01-May-2025 03:41:00 01-May-2025 04:00:00 01-May-2025 04:00:00 01-May-2025 04:00:00 01-May-2025 04:01:00 01-May-2025 04:10:00 01-May-2025 04:15:00 01-May-2025 04:30:00 01-May-2025 04:30:00 01-May-2025 04:30:00 01-May-2025 04:31:00 01-May-2025 04:31:00 01-May-2025 05:00:00 01-May-2025 05:00:00 01-May-2025 05:00:00 01-May-2025 05:01:00 01-May-2025 05:10:00 01-May-2025 05:30:00 01-May-2025 05:30:00 01-May-2025 05:30:00 01-May-2025 05:30:00 01-May-2025 05:31:00 01-May-2025 05:31:00 01-May-2025 06:00:00 01-May-2025 06:00:00 01-May-2025 06:00:00 Upstream DPI BS&W sample showed No Solids. Injection Rate into NDBi-014 @ 2.87 bpm with a Total of 3730.57 bbls Injected. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 9 to Tank 7. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 2.85 bpm with a Total of 3644.29 bbls Injected. BS&W at Choke Manifold Showed 12% Water and 0.5% Solids. Oil = 88%. Gas Scrubber Free of Fluid. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Began reducing Separator Pressure to reduce Back Pressure against the well. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 10 to Tank 9. Injection Rate into NDBi-014 @ 2.85 bpm with a Total of 4072.45 bbls Injected. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Collected Tracerco Dye Water Sample. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 8 to Tank 10. Injection Rate into NDBi-014 @ 2.86 bpm with a Total of 3990.73 bbls Injected. Injection Rate into NDBi-014 @ 2.83 bpm with a Total of 3815.83 bbls Injected. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Diverted Flow from Tank 7 to Tank 8. Upstream DPI BS&W sample showed No Solids. Injection Rate into NDBi-014 @ 2.84 bpm with a Total of 3903.78 bbls Injected. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Diverted Flow from Tank 1 to Tank 2. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Injection Rate into NDBi-014 @ 3.01 bpm with a Total of 4357.31 bbls Injected. BS&W at Choke Manifold Showed 8% Water. Oil = 92%. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Flare Base Free of Fluid. Completed Flare Heat Index. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 10 to Tank 1. Injection Rate into NDBi-014 @ 3.03 bpm with a Total of 4251.69 bbls Injected. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. No Solids Observed on both Sides. Diverted Flow from Tank 9 to Tank 10. Injection Rate into NDBi-014 @ 3.0 bpm with a Total of 4159.88 bbls Injected. BS&W at Choke Manifold Showed 8% Water. Oil = 92%. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. Diverted Flow from Tank 2 to Tank 1. Diverted Flow from Tank 2 to Tank 1. Upstream DPI BS&W sample showed No Solids. BS&W at Choke Manifold Showed 8% Water. Oil = 92%. Injection Rate into NDBi-014 @ 3.43 bpm with a Total of 4449.48 bbls Injected. BS&W at Choke Manifold Showed 8% Water. Oil = 92%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 68 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 01-May-2025 06:01:00 01-May-2025 06:02:00 01-May-2025 06:03:00 01-May-2025 06:13:00 01-May-2025 06:15:00 01-May-2025 06:21:00 01-May-2025 06:30:00 01-May-2025 06:31:00 01-May-2025 06:42:00 01-May-2025 06:45:00 01-May-2025 07:00:00 01-May-2025 07:01:00 01-May-2025 07:01:00 01-May-2025 07:14:00 01-May-2025 07:20:00 01-May-2025 07:30:00 01-May-2025 07:31:00 01-May-2025 07:34:00 01-May-2025 07:43:00 01-May-2025 07:49:00 01-May-2025 08:00:00 01-May-2025 08:01:00 01-May-2025 08:01:00 01-May-2025 08:15:00 01-May-2025 08:28:00 01-May-2025 08:30:00 01-May-2025 08:30:00 01-May-2025 08:31:00 01-May-2025 08:48:00 01-May-2025 09:00:00 01-May-2025 09:00:00 01-May-2025 09:01:00 01-May-2025 09:01:00 01-May-2025 09:30:00 01-May-2025 09:31:00 01-May-2025 09:31:00 01-May-2025 10:00:00 01-May-2025 10:01:00 01-May-2025 10:15:00 01-May-2025 10:30:00 01-May-2025 10:31:00 01-May-2025 10:31:00 01-May-2025 10:46:00 01-May-2025 11:00:00 01-May-2025 11:01:00 01-May-2025 11:18:00 01-May-2025 11:30:00 01-May-2025 11:31:00 01-May-2025 11:31:00 01-May-2025 12:00:00 01-May-2025 12:00:00 01-May-2025 12:00:00 01-May-2025 12:01:00 01-May-2025 12:01:00 01-May-2025 12:01:00 01-May-2025 12:03:00 01-May-2025 12:16:00 Flare Base Free of Fluid. Observed Well Slugging. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Diverted Flow from Tank 2 to Tank 1.(15 min Flow). BS&W at Choke Manifold Showed 44% Water. Oil = 56%. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. BS&W at Choke Manifold Showed 10% Water. Oil = 90%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Gas Scrubber Free of Fluid. BS&W at Choke Manifold Showed 74% Water. Oil = 26%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Diverted Flow from Tank 3 to Tank 4. Injection Rate into NDBi-014 @ 2.40 bpm with a Total of 5029.63 bbls Injected. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 30% Water. Oil = 70%. Diverted Gas Flow from 3'' Coriolis Meter through 0.5'' Coriolis Meter. Upstream DPI BS&W sample showed No Solids. Lowered Separator Pressure. Diverted Flow from Tank 4 to Tank 3. Diverted Flow from Tank 1 to Tank 2.(15 min Flow). Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 32% Water. Oil = 68%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Observed Well Slugging. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 79% Water. Oil = 21%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Upstream DPI BS&W sample showed No Solids. Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 80% Water. Oil = 20%. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 80% Water. Oil = 20%. Oil API 30.1 @ 60F (Oil SG 0.876). Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 80% Water. Oil = 20%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. BS&W at Choke Manifold Showed 76% Water. Oil = 24%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Diverted Flow from Tank 4 to Tank 3. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 70% Water. Oil = 30%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Collected Tracerco Standard Sample. BS&W at Choke Manifold Showed 76% Water. Oil = 24%. Gas SG = 0.685, CO2 = 0.1%, H2S = 0 ppm. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 78% Water. Oil = 22%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Diverted Flow from Tank 6 to Tank 5. Collected Tracerco Dye Water Sample. Kit #2 Complete. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 69 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 01-May-2025 12:30:00 01-May-2025 12:31:00 01-May-2025 12:31:00 01-May-2025 12:31:00 01-May-2025 13:00:00 01-May-2025 13:00:00 01-May-2025 13:01:00 01-May-2025 13:14:00 01-May-2025 13:30:00 01-May-2025 13:31:00 01-May-2025 13:31:00 01-May-2025 13:40:00 01-May-2025 13:47:00 01-May-2025 13:49:00 01-May-2025 14:00:00 01-May-2025 14:01:00 01-May-2025 14:02:00 01-May-2025 14:14:00 01-May-2025 14:30:00 01-May-2025 14:31:00 01-May-2025 14:31:00 01-May-2025 14:41:00 01-May-2025 14:45:00 01-May-2025 14:56:00 01-May-2025 15:00:00 01-May-2025 15:00:00 01-May-2025 15:01:00 01-May-2025 15:09:00 01-May-2025 15:20:00 01-May-2025 15:30:00 01-May-2025 15:31:00 01-May-2025 15:31:00 01-May-2025 15:33:00 01-May-2025 15:38:00 01-May-2025 15:58:00 01-May-2025 16:00:00 01-May-2025 16:00:00 01-May-2025 16:01:00 01-May-2025 16:01:00 01-May-2025 16:02:00 01-May-2025 16:09:00 01-May-2025 16:17:00 01-May-2025 16:18:00 01-May-2025 16:30:00 01-May-2025 16:31:00 01-May-2025 16:31:00 01-May-2025 16:31:00 01-May-2025 16:34:00 01-May-2025 16:45:00 01-May-2025 16:52:00 01-May-2025 17:00:00 01-May-2025 17:00:00 01-May-2025 17:01:00 01-May-2025 17:06:00 01-May-2025 17:30:00 01-May-2025 17:31:00 01-May-2025 17:31:00 Diverted Flow from Tank 5 to Tank 6. Bypassed Expro Ball Catcher. BS&W at Choke Manifold Showed 70% Water. Oil = 30%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Diverted Flow from Tank 6 to Tank 7. Injection Rate into NDBi-014 @ 1.80 bpm with a Total of 5575.40 bbls Injected. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 70% Water. Oil = 30%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Observed Well Slugging. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Diverted Gas Flow from 0.5" Coriolis Meter through 3" Coriolis Meter. Lowered Separator Pressure. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 60% Water. Oil = 40%. Observed Well Slugging. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. BS&W at Choke Manifold Showed 70% Water. Oil = 30%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and No Solids on Side B. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 64% Water. Oil = 36%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Configured DPI Unit to Parallel Flow. Injection Rate into NDBi-014 @ 2.79 bpm with a Total of 5993.77 bbls Injected. BS&W at Choke Manifold Showed 56% Water. Oil = 44%. Oil API 30.1 @ 60F (Oil SG 0.876). Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Lowered Separator Liquid Level. Cusco began vac on DPI Sparge Tank. BS&W at Choke Manifold Showed 64% Water. Oil = 36%. Water Salinity = 33,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolites on Side B. Increased Injection Rate to 2.8 bpm into well NDBi-014. Collected Flare Heat Index. Diverted Flow from Tank 10 to Tank 9. Diverted Flow from Tank 8 to Tank 9. Collected Tracerco Dye Water Sample. BS&W at Choke Manifold Showed 52% Water. Oil = 48%. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite on Side B. Increased Chemical Injection of Defoamer to 11 gal/d. Diverted Flow from Tank 9 to Tank 10. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 50% Water. Oil = 50%. Water Salinity = 33,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Cusco Finished vaccing DPI Sparge Tank. 45 bbls of Fluid Removed. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite on Side B. Diverted Flow from Tank 10 to Tank 1. Applied CMSF 0.858. BS&W at Choke Manifold Showed 50% Water. Oil = 50%. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite on Side B. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 50% Water. Oil = 50%. Gas SG = 0.688, CO2 = 0.1%, H2S = 0 ppm. Water Salinity = 33,000 ppm. Water pH = 8. Water Weight = 8.51 ppg. Increased Injection Rate to 3.4 bpm into well NDBi-014. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 70 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 01-May-2025 17:32:00 01-May-2025 18:00:00 01-May-2025 18:00:00 01-May-2025 18:00:00 01-May-2025 18:00:00 01-May-2025 18:00:00 01-May-2025 18:00:00 01-May-2025 18:01:00 01-May-2025 18:06:00 01-May-2025 18:15:00 01-May-2025 18:30:00 01-May-2025 18:30:00 01-May-2025 18:30:00 01-May-2025 18:30:00 01-May-2025 18:31:00 01-May-2025 18:31:00 01-May-2025 18:45:00 01-May-2025 19:00:00 01-May-2025 19:00:00 01-May-2025 19:00:00 01-May-2025 19:00:00 01-May-2025 19:01:00 01-May-2025 19:10:00 01-May-2025 19:30:00 01-May-2025 19:30:00 01-May-2025 19:30:00 01-May-2025 19:30:00 01-May-2025 19:30:00 01-May-2025 19:31:00 01-May-2025 19:31:00 01-May-2025 20:00:00 01-May-2025 20:00:00 01-May-2025 20:00:00 01-May-2025 20:01:00 01-May-2025 20:10:00 01-May-2025 20:20:00 01-May-2025 20:30:00 01-May-2025 20:30:00 01-May-2025 20:30:00 01-May-2025 20:30:00 01-May-2025 20:30:00 01-May-2025 20:31:00 01-May-2025 20:31:00 01-May-2025 21:00:00 01-May-2025 21:00:00 01-May-2025 21:00:00 01-May-2025 21:00:00 01-May-2025 21:00:00 01-May-2025 21:01:00 01-May-2025 21:05:00 01-May-2025 21:22:00 01-May-2025 21:30:00 01-May-2025 21:30:00 01-May-2025 21:30:00 01-May-2025 21:30:00 01-May-2025 21:30:00 01-May-2025 21:31:00 Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Diverted Flow from Tank 2 to Tank 1. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Flare Base Free of Fluid. Diverted Flow from Tank 2 to Tank 3. Dumped DPI Unit Side A and Side B. Heavy Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Injection Rate into NDBi-014 @ 3.55 bpm with a Total of 6605.52 bbls Injected. Gas Scrubber Free of Fluid. Diverted Flow from Tank 1 to Tank 2. Upstream DPI BS&W sample showed Trace Solids. Injection Rate into NDBi-014 @ 3.46 bpm with a Total of 6496.04 bbls Injected. Re-Applied CMSF 0.858. BS&W at Choke Manifold Showed 48% Water and Trace Solids. Oil = 52%. Injection Rate into NDBi-014 @ 3.40 bpm with a Total of 6388.39 bbls Injected. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. Applied CMSF 0.736 to compensate for erroneous Liquid Rates. BS&W at Choke Manifold Showed 46% Water and Trace Solids. Oil = 54%. Observed higher than expected Liquid Rates due to possible gas carry out liquid line overspinning turbine. Increased Separator Liquid Level. BS&W at Choke Manifold Showed 46% Water and Trace Solids. Oil = 54%. Sparged Separator. Light Solids Observed. Increased Separator Pressure. Diverted Flow from Tank 3 to Tank 4. Increased Chemical Injection of Defoamer to 15 gal/day. Injection Rate into NDBi-014 @ 3.45 bpm with a Total of 6909.22 bbls Injected. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Water Salinity = 22,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. BS&W at Choke Manifold Showed 50% Water and Trace Solids. Oil = 50%. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Diverted Flow from Tank 4 to Tank 3. Injection Rate into NDBi-014 @ 3.37 bpm with a Total of 6807.19 bbls Injected. BS&W at Choke Manifold Showed 50% Water and Trace Solids. Oil = 50%. Increased Separator Pressure. Diverted Flow from Tank 3 to Tank 4. Dumped 1 bbl. fluid from Gas Scrubber. Upstream DPI BS&W sample showed Trace Solids. Injection Rate into NDBi-014 @ 3.40 bpm with a Total of 6700.11 bbls Injected. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 5 to Tank 6. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.38 bpm with a Total of 7118.14 bbls Injected. Applied CMSF 0.826. BS&W at Choke Manifold Showed 40% Water and Trace Solids. Oil = 60%. Injection Rate into NDBi-014 @ 3.44 bpm with a Total of 7015.96 bbls Injected. Collected Tracerco Dye Water Sample. Applied CMSF 0.657 from 21:00 to 21:30 to correct erroneous Liquid Rate caused by Slugging Well. BS&W at Choke Manifold Showed 44% Water. Oil = 56%. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Water Salinity = 22,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. BS&W at Choke Manifold Showed 46% Water and Trace Solids. Oil = 54%. Water Salinity = 22,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Diverted Flow from Tank 4 to Tank 5. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 71 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 01-May-2025 21:31:00 01-May-2025 22:00:00 01-May-2025 22:00:00 01-May-2025 22:00:00 01-May-2025 22:01:00 01-May-2025 22:30:00 01-May-2025 22:30:00 01-May-2025 22:30:00 01-May-2025 22:30:00 01-May-2025 22:31:00 01-May-2025 22:34:00 01-May-2025 22:46:00 01-May-2025 23:00:00 01-May-2025 23:00:00 01-May-2025 23:00:00 01-May-2025 23:01:00 01-May-2025 23:10:00 01-May-2025 23:30:00 01-May-2025 23:30:00 01-May-2025 23:30:00 01-May-2025 23:30:00 01-May-2025 23:31:00 01-May-2025 23:31:00 01-May-2025 23:45:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:00:00 02-May-2025 00:01:00 02-May-2025 00:30:00 02-May-2025 00:30:00 02-May-2025 00:30:00 02-May-2025 00:30:00 02-May-2025 00:31:00 02-May-2025 00:31:00 02-May-2025 00:45:00 02-May-2025 01:00:00 02-May-2025 01:00:00 02-May-2025 01:00:00 02-May-2025 01:00:00 02-May-2025 01:01:00 02-May-2025 01:02:00 02-May-2025 01:30:00 02-May-2025 01:30:00 02-May-2025 01:30:00 02-May-2025 01:30:00 02-May-2025 01:31:00 02-May-2025 01:31:00 02-May-2025 02:00:00 02-May-2025 02:00:00 02-May-2025 02:00:00 02-May-2025 02:00:00 02-May-2025 02:01:00 Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.45 bpm with a Total of 7412.43 bbls Injected. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Diverted Flow from Tank 7 to Tank 8. Diverted Flow from Tank 5 to Tank 6. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.46 bpm with a Total of 7324.54 bbls Injected. Water Salinity = 23,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. BS&W at Choke Manifold Showed 40% Water and Trace Solids. Oil = 60%. Flare Base Free of Fluid. Water Salinity = 23,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 6 to Tank 5. Injection Rate into NDBi-014 @ 3.38 bpm with a Total of 7213.62 bbls Injected. BS&W at Choke Manifold Showed 44% Water and Trace Solids. Oil = 56%. Upstream DPI BS&W sample showed Trace Solids. Oil API 32.0 @ 60F (Oil SG 0.865). Gas SG = 0.672, CO2 = 0.1%, H2S = 0 ppm. BS&W at Choke Manifold Showed 42% Water and 0.05% Solids. Oil = 58%. Diverted Flow from Tank 7 to Tank 8. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Diverted Flow from Tank 8 to Tank 7. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. LRS Injection Pump offline for Preventative Maintenance / Data Download. Injection Rate into NDBi-014 @ 0 bpm with a Total of 7621.26 bbls Injected. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.37 bpm with a Total of 7553.99 bbls Injected. BS&W at Choke Manifold Showed 40% Water and Trace Solids. Oil = 60%. Water Salinity = 23,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Increased Separator Pressure. Dumped DPI Unit Side A and Side B. Heavy Solids Observed on both Sides. Upstream DPI BS&W sample showed Trace Solids. BS&W at Choke Manifold Showed 38% Water and Trace Solids. Oil = 62%. Water Salinity = 22,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Diverted Flow from Tank 10 to Tank 9. Injection Rate into NDBi-014 @ 3.35 bpm with a Total of 7662.1 bbls Injected. Re-Applied CMSF 0.826. BS&W at Choke Manifold Showed 40% Water and Trace Solids. Oil = 60%. Flare Base Free of Fluid. Diverted Flow from Tank 9 to Tank 10. Injection Rate into NDBi-014 @ 3.37 bpm with a Total of 7766.16 bbls Injected. Applied CMSF 0.657 from 00:30 to 01:00 to correct erroneous Liquid Rate caused by Slugging Well. BS&W at Choke Manifold Showed 42% Water and Trace Solids. Oil = 58%. Water Salinity = 23,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. LRS Injection pump back Online @ 3.4 bpm. Dumped DPI Unit Side A and Side B. Heavy Solids Observed on both Sides. Diverted Flow from Tank 8 to Tank 9. Injection Rate into NDBi-014 @ 3.37 bpm with a Total of 7868.46 bbls Injected. Applied CMSF 0.685 from 02:00 to 03:00 to correct erroneous Liquid Rates caused by Slugging Well. BS&W at Choke Manifold Showed 42% Water and Trace Solids. Oil = 58%. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 72 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 02-May-2025 02:06:00 02-May-2025 02:30:00 02-May-2025 02:30:00 02-May-2025 02:30:00 02-May-2025 02:30:00 02-May-2025 02:31:00 02-May-2025 02:31:00 02-May-2025 03:00:00 02-May-2025 03:00:00 02-May-2025 03:00:00 02-May-2025 03:00:00 02-May-2025 03:00:00 02-May-2025 03:01:00 02-May-2025 03:30:00 02-May-2025 03:30:00 02-May-2025 03:30:00 02-May-2025 03:30:00 02-May-2025 03:30:00 02-May-2025 03:31:00 02-May-2025 03:31:00 02-May-2025 03:35:00 02-May-2025 04:00:00 02-May-2025 04:00:00 02-May-2025 04:00:00 02-May-2025 04:00:00 02-May-2025 04:00:00 02-May-2025 04:01:00 02-May-2025 04:05:00 02-May-2025 04:15:00 02-May-2025 04:30:00 02-May-2025 04:30:00 02-May-2025 04:30:00 02-May-2025 04:30:00 02-May-2025 04:31:00 02-May-2025 04:31:00 02-May-2025 04:35:00 02-May-2025 05:00:00 02-May-2025 05:00:00 02-May-2025 05:00:00 02-May-2025 05:01:00 02-May-2025 05:18:00 02-May-2025 05:30:00 02-May-2025 05:30:00 02-May-2025 05:30:00 02-May-2025 05:30:00 02-May-2025 05:31:00 02-May-2025 05:31:00 02-May-2025 05:50:00 02-May-2025 05:55:00 02-May-2025 06:00:00 02-May-2025 06:00:00 02-May-2025 06:00:00 02-May-2025 06:01:00 02-May-2025 06:03:00 02-May-2025 06:10:00 02-May-2025 06:27:00 02-May-2025 06:30:00 Re-Applied CMSF 0.826. Collected Tracerco Dye Water Sample. Injection Rate into NDBi-014 @ 3.71 bpm with a Total of 8082.74 bbls Injected. BS&W at Choke Manifold Showed 32% Water and Trace Solids. Oil = 68%. Dumped DPI Unit Side A and Side B. Heavy Solids Observed on both Sides. Diverted Flow from Tank 1 to Tank 2. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Upstream DPI BS&W sample showed Light Solids. Water Salinity = 22,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Dumped DPI Unit Side A and Side B. Heavy Solids Observed on both Sides. Diverted Flow from Tank 10 to Tank 1. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Injection Rate into NDBi-014 @ 3.64 bpm with a Total of 7957.39 bbls Injected. Diverted Flow from Tank 9 to Tank 10. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Upstream DPI BS&W sample showed Light Solids. Diverted Flow from Tank 1 to Tank 2. Injection Rate into NDBi-014 @ 3.64 bpm with a Total of 8416.12 bbls Injected. Completed Critical Points Check. Diverted Flow from Tank 2 to Tank 1. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.73 bpm with a Total of 8303.01 bbls Injected. Completed Flare Heat Index. BS&W at Choke Manifold Showed 34% Water and Trace Solids. Oil = 66%. Injection Rate into NDBi-014 @ 3.73 bpm with a Total of 8193.38 bbls Injected. Upstream DPI BS&W sample showed Light Solids. Re-Applied CMSF 0.826. BS&W at Choke Manifold Showed 28% Water and Trace Solids. Oil = 72%. Water Salinity = 23,000 ppm. Water pH = 8. Water Weight = 8.36 ppg. Flare Base Free of Fluid. BS&W at Choke Manifold Showed 36% Water and Trace Solids. Oil = 64%. Water Salinity = 23,000 ppm. Water pH = 8. Water Weight = 8.43 ppg. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Collected Tracerco Dye Water Sample. Collected Tracerco Standard Sample. BS&W at Choke Manifold Showed 30% Water and Trace Solids. Oil = 70%. Gas Scrubber Free of Fluid. Diverted Flow from Tank 3 to Tank 4. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Upstream DPI BS&W sample showed Trace Solids. Injection Rate into NDBi-014 @ 3.74 bpm with a Total of 8640.71 bbls Injected. BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. Water Salinity = 22,000 ppm. Water pH = 8. Water Weight = 8.41 ppg. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Diverted Flow from Tank 2 to Tank 3. Injection Rate into NDBi-014 @ 3.74 bpm with a Total of 8527.11 bbls Injected. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 38% Water and Trace Solids. Oil = 62%. Observed Well Slugging. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Heavy Carbolite Observed on Side B. Upstream DPI BS&W sample showed Trace Solids. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 73 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 02-May-2025 06:30:00 02-May-2025 06:31:00 02-May-2025 06:31:00 02-May-2025 06:31:00 02-May-2025 06:33:00 02-May-2025 06:45:00 02-May-2025 06:56:00 02-May-2025 07:00:00 02-May-2025 07:01:00 02-May-2025 07:25:00 02-May-2025 07:26:00 02-May-2025 07:30:00 02-May-2025 07:31:00 02-May-2025 07:31:00 02-May-2025 07:57:00 02-May-2025 08:00:00 02-May-2025 08:10:00 02-May-2025 08:26:00 02-May-2025 08:30:00 02-May-2025 08:31:00 02-May-2025 08:41:00 02-May-2025 08:57:00 02-May-2025 09:00:00 02-May-2025 09:01:00 02-May-2025 09:05:00 02-May-2025 09:05:00 02-May-2025 09:06:00 02-May-2025 09:24:00 02-May-2025 09:30:00 02-May-2025 09:31:00 02-May-2025 09:31:00 02-May-2025 09:56:00 02-May-2025 10:00:00 02-May-2025 10:01:00 02-May-2025 10:09:00 02-May-2025 10:28:00 02-May-2025 10:30:00 02-May-2025 10:30:00 02-May-2025 10:31:00 02-May-2025 10:31:00 02-May-2025 10:39:00 02-May-2025 10:40:00 02-May-2025 10:43:00 02-May-2025 11:00:00 02-May-2025 11:00:00 02-May-2025 11:01:00 02-May-2025 11:01:00 02-May-2025 11:30:00 02-May-2025 11:30:00 02-May-2025 11:31:00 02-May-2025 11:31:00 02-May-2025 11:47:00 02-May-2025 12:00:00 02-May-2025 12:00:00 02-May-2025 12:00:00 02-May-2025 12:00:00 02-May-2025 12:01:00 Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 5 to Tank 6. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 42% Water and Trace Solids. Oil = 56%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Applied CMSF = 0.936. Configured DPI Unit to Series Flow. Sparged Separator. Heavy Solids Observed, Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Sparged Separator. Trace Solids Observed. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Heavy Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 42% Water and Trace Solids. Oil = 58%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 30% Water and Trace Solids. Oil = 70%. BS&W at Choke Manifold Showed 30% Water and Trace Solids. Oil = 70%. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 6 to Tank 5. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Light Carbolite Observed on Side B. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 8 to Tank 9. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Gas SG = 0.662, CO2 = 0.1%, H2S = 0 ppm. Diverted Flow from Tank 9 to Tank 10. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 3.72 bpm with a Total of 9743.20 bbls Injected. BS&W at Choke Manifold Showed 40% Water and Trace Solids. Oil = 60%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Decreased Chemical Injection of Defoamer to 12 gal/d. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Water Salinity = 32,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Heavy Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 40% Water and Trace Solids. Oil = 60%. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Heavy Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Collected Tracerco Dye sample. Kit #3 Complete. Collected Core Lab Sample. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Dumped DPI Unit Side A and Side B. Heavy Carbolite Observed on Side A and Trace Carbolite Observed on Side B. BS&W at Choke Manifold Showed 16% Water and Trace Solids. Oil = 84%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 10 to Tank 9. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 74 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 02-May-2025 12:05:00 02-May-2025 12:30:00 02-May-2025 12:30:00 02-May-2025 12:31:00 02-May-2025 12:31:00 02-May-2025 12:35:00 02-May-2025 12:42:00 02-May-2025 12:51:00 02-May-2025 13:00:00 02-May-2025 13:01:00 02-May-2025 13:01:00 02-May-2025 13:28:00 02-May-2025 13:30:00 02-May-2025 13:31:00 02-May-2025 13:31:00 02-May-2025 13:57:00 02-May-2025 14:00:00 02-May-2025 14:01:00 02-May-2025 14:30:00 02-May-2025 14:30:00 02-May-2025 14:31:00 02-May-2025 14:35:00 02-May-2025 14:54:00 02-May-2025 14:58:00 02-May-2025 15:00:00 02-May-2025 15:07:00 02-May-2025 15:30:00 02-May-2025 15:30:00 02-May-2025 15:31:00 02-May-2025 15:31:00 02-May-2025 15:51:00 02-May-2025 16:00:00 02-May-2025 16:00:00 02-May-2025 16:01:00 02-May-2025 16:01:00 02-May-2025 16:01:00 02-May-2025 16:06:00 02-May-2025 16:28:00 02-May-2025 16:30:00 02-May-2025 16:30:00 02-May-2025 16:31:00 02-May-2025 16:31:00 02-May-2025 16:51:00 02-May-2025 16:56:00 02-May-2025 16:57:00 02-May-2025 17:00:00 02-May-2025 17:00:00 02-May-2025 17:01:00 02-May-2025 17:01:00 02-May-2025 17:29:00 02-May-2025 17:30:00 02-May-2025 17:30:00 02-May-2025 17:31:00 02-May-2025 17:31:00 02-May-2025 18:00:00 02-May-2025 18:00:00 02-May-2025 18:00:00 BS&W at Choke Manifold Showed 30% Water and Trace Solids. Oil = 70%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Decreased Chemical Injection of Defoamer to 10 gal/d. Sparged Separator. Trace Solids Observed. Diverted Flow from Tank 10 to Tank 1. Decreased Injection Rate to 3 bpm into well NDBi-014. Diverted Flow from Tank 9 to Tank 10. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 2 to Tank 3. Decreased Chemical Injection of Defoamer to 8 gal/d. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 30% Water and Trace Solids. Oil = 70%. Diverted Flow from Tank 1 to Tank 2. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Oil API 30.3 @ 60F (Oil SG 0.875). Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Injection Rate into NDBi-014 @ 2.97 bpm with a Total of 10891.63 bbls Injected. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Upstream DPI BS&W sample showed Trace Solids. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Sparged Separator. Trace Solids Observed. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 3 to Tank 4. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Collected Flare Heat Index. Diverted Flow from Tank 4 to Tank 3. Injection Rate into NDBi-014 @ 2.99 bpm with a Total of 10801.04 bbls Injected. Injection Rate into NDBi-014 @ 3.01 bpm with a Total of 11070.10 bbls Injected. BS&W at Choke Manifold Showed 26% Water and Trace Solids. Oil = 74%. Water Salinity = 31,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Diverted Flow from Tank 6 to Tank 5. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.01 bpm with a Total of 11158.19 bbls Injected. Diverted Flow from Tank 4 to Tank 5. Injection Rate into NDBi-014 @ 2.87 bpm with a Total of 10980.37 bbls Injected. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Gas SG = 0.670, CO2 = 0.1%, H2S = 0 ppm. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 5 to Tank 6. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 75 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 02-May-2025 18:00:00 02-May-2025 18:00:00 02-May-2025 18:01:00 02-May-2025 18:30:00 02-May-2025 18:30:00 02-May-2025 18:30:00 02-May-2025 18:30:00 02-May-2025 18:31:00 02-May-2025 18:31:00 02-May-2025 18:40:00 02-May-2025 19:00:00 02-May-2025 19:00:00 02-May-2025 19:00:00 02-May-2025 19:00:00 02-May-2025 19:01:00 02-May-2025 19:05:00 02-May-2025 19:30:00 02-May-2025 19:30:00 02-May-2025 19:30:00 02-May-2025 19:31:00 02-May-2025 19:31:00 02-May-2025 19:40:00 02-May-2025 20:00:00 02-May-2025 20:00:00 02-May-2025 20:00:00 02-May-2025 20:00:00 02-May-2025 20:01:00 02-May-2025 20:30:00 02-May-2025 20:30:00 02-May-2025 20:30:00 02-May-2025 20:30:00 02-May-2025 20:31:00 02-May-2025 20:31:00 02-May-2025 20:56:00 02-May-2025 21:00:00 02-May-2025 21:00:00 02-May-2025 21:00:00 02-May-2025 21:00:00 02-May-2025 21:01:00 02-May-2025 21:29:00 02-May-2025 21:30:00 02-May-2025 21:30:00 02-May-2025 21:30:00 02-May-2025 21:30:00 02-May-2025 21:31:00 02-May-2025 21:31:00 02-May-2025 21:44:00 02-May-2025 21:45:00 02-May-2025 22:00:00 02-May-2025 22:00:00 02-May-2025 22:00:00 02-May-2025 22:00:00 02-May-2025 22:01:00 02-May-2025 22:15:00 02-May-2025 22:30:00 02-May-2025 22:30:00 02-May-2025 22:30:00 Upstream DPI BS&W sample showed Trace Solids. Collected Tracerco Standard Sample. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Diverted Flow from Tank 5 to Tank 6. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Upstream DPI BS&W sample showed Trace Solids. Upstream DPI BS&W sample showed Trace Solids. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 6 to Tank 7. Injection Rate into NDBi-014 @ 3.02 bpm with a Total of 11377.2 bbls Injected. BS&W at Choke Manifold Showed 24% Water and Trace Solids. Oil = 76%. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Diverted Flow from Tank 7 to Tank 8. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.02 bpm with a Total of 11286.78 bbls Injected. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Flare Base Free of Fluid. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.02 bpm with a Total of 11702.92 bbls Injected. BS&W at Choke Manifold Showed 24% Water and Trace Solids. Oil = 76%. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Diverted Flow from Tank 9 to Tank 10. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Gas Scrubber Free of Fluid. Diverted Flow from Tank 8 to Tank 9. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 8 to Tank 7. Injection Rate into NDBi-014 @ 3.02 bpm with a Total of 11532.61 bbls Injected. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 3.01 bpm with a Total of 11616.53 bbls Injected. Upstream DPI BS&W sample showed Trace Solids. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 9 to Tank 10. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 10 to Tank 9. Injection Rate into NDBi-014 @ 3.01 bpm with a Total of 11899.30 bbls Injected. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Sparged Separator. Trace Solids Observed. Upstream DPI BS&W sample showed Trace Solids. Injection Rate into NDBi-014 @ 3.13 bpm with a Total of 11794.50 bbls Injected. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. Flare Base Free of Fluid. Gas Scrubber Free of Fluid. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 76 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 02-May-2025 22:30:00 02-May-2025 22:31:00 02-May-2025 22:31:00 02-May-2025 23:00:00 02-May-2025 23:00:00 02-May-2025 23:00:00 02-May-2025 23:00:00 02-May-2025 23:00:00 02-May-2025 23:01:00 02-May-2025 23:08:00 02-May-2025 23:15:00 02-May-2025 23:30:00 02-May-2025 23:30:00 02-May-2025 23:30:00 02-May-2025 23:30:00 02-May-2025 23:31:00 02-May-2025 23:31:00 02-May-2025 23:55:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:00:00 03-May-2025 00:30:00 03-May-2025 00:30:00 03-May-2025 00:30:00 03-May-2025 00:31:00 03-May-2025 00:31:00 03-May-2025 00:34:00 03-May-2025 00:44:00 03-May-2025 00:52:00 03-May-2025 01:00:00 03-May-2025 01:00:00 03-May-2025 01:00:00 03-May-2025 01:00:00 03-May-2025 01:01:00 03-May-2025 01:08:00 03-May-2025 01:27:00 03-May-2025 01:30:00 03-May-2025 01:30:00 03-May-2025 01:30:00 03-May-2025 01:30:00 03-May-2025 01:31:00 03-May-2025 01:31:00 03-May-2025 01:48:00 03-May-2025 01:54:00 03-May-2025 02:00:00 03-May-2025 02:00:00 03-May-2025 02:00:00 03-May-2025 02:00:00 03-May-2025 02:01:00 03-May-2025 02:30:00 03-May-2025 02:30:00 03-May-2025 02:30:00 Injection Rate into NDBi-014 @ 3.03 bpm with a Total of 11981.2 bbls Injected. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.40 ppg. BS&W at Choke Manifold Showed 24% Water and Trace Solids. Oil = 76%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.43 ppg. BS&W at Choke Manifold Showed 22% Water and Trace Solids. Oil = 78%. Gas Scrubber Free of Fluid. Gas SG = 0.669, CO2 = 0.1%, H2S = 0 ppm. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 2 to Tank 1. Gas Scrubber Free of Fluid. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Diverted Flow from Tank 1 to Tank 2. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.42 bpm with a Total of 12176.02 bbls Injected. Completed Critical Points Check. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Diverted Flow from Tank 10 to Tank 1. Injection Rate into NDBi-014 @ 3.41 bpm with a Total of 12074.78 bbls Injected. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Gas Scrubber Free of Fluid. Diverted Flow from Tank 2 to Tank 3. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.8 bpm with a Total of 12384.63 bbls Injected. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.39 ppg. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. LRS Injection pump back Online @ 3.4 bpm. Flare Base Free of Fluid. Upstream DPI BS&W sample showed Trace Solids. Oil API 30.9 @ 60F (Oil SG 0.871). Collected Tracerco Standard Sample. LRS Injection Pump offline for Preventative Maintenance / Data Download. Injection Rate into NDBi-014 @ 0 bpm with a Total of 12273.28 bbls Injected. Diverted Flow from Tank 1 to Tank 2. Diverted Flow from Tank 4 to Tank 3. Injection Rate into NDBi-014 @ 3.74 bpm with a Total of 12607.22 bbls Injected. BS&W at Choke Manifold Showed 16% Water and Trace Solids. Oil = 84%. Diverted Flow from Tank 3 to Tank 4. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.42 ppg. Flare Base Free of Fluid. Gas Scrubber Free of Fluid. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Sparged Separator. Trace Solids Observed. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Diverted Flow from Tank 3 to Tank 4. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Injection Rate into NDBi-014 @ 3.68 bpm with a Total of 12488.88 bbls Injected. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 77 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 03-May-2025 02:30:00 03-May-2025 02:31:00 03-May-2025 02:31:00 03-May-2025 02:59:00 03-May-2025 03:00:00 03-May-2025 03:00:00 03-May-2025 03:00:00 03-May-2025 03:00:00 03-May-2025 03:01:00 03-May-2025 03:30:00 03-May-2025 03:30:00 03-May-2025 03:30:00 03-May-2025 03:30:00 03-May-2025 03:31:00 03-May-2025 03:31:00 03-May-2025 03:51:00 03-May-2025 04:00:00 03-May-2025 04:00:00 03-May-2025 04:00:00 03-May-2025 04:00:00 03-May-2025 04:01:00 03-May-2025 04:05:00 03-May-2025 04:15:00 03-May-2025 04:24:00 03-May-2025 04:30:00 03-May-2025 04:30:00 03-May-2025 04:30:00 03-May-2025 04:30:00 03-May-2025 04:31:00 03-May-2025 04:31:00 03-May-2025 05:00:00 03-May-2025 05:00:00 03-May-2025 05:00:00 03-May-2025 05:00:00 03-May-2025 05:01:00 03-May-2025 05:05:00 03-May-2025 05:30:00 03-May-2025 05:30:00 03-May-2025 05:30:00 03-May-2025 05:30:00 03-May-2025 05:31:00 03-May-2025 05:31:00 03-May-2025 05:57:00 03-May-2025 06:00:00 03-May-2025 06:00:00 03-May-2025 06:01:00 03-May-2025 06:01:00 03-May-2025 06:13:00 03-May-2025 06:25:00 03-May-2025 06:30:00 03-May-2025 06:31:00 03-May-2025 06:45:00 03-May-2025 06:49:00 03-May-2025 07:00:00 03-May-2025 07:01:00 03-May-2025 07:01:00 03-May-2025 07:03:00 Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 12947.39 bbls Injected. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.45 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Gas Scrubber Free of Fluid. Diverted Flow from Tank 6 to Tank 5. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 12826.27 bbls Injected. BS&W at Choke Manifold Showed 20% Water and Trace Solids. Oil = 80%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 5 to Tank 6. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 12711.90 bbls Injected. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.41 ppg. Gas Scrubber Free of Fluid. Diverted Flow from Tank 4 to Tank 5. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 6 to Tank 7. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Trace Carbolite observed on both Sides. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 13275.12 bbls Injected. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Gas Scrubber Free of Fluid. Diverted Flow from Tank 5 to Tank 6. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 13166.18 bbls Injected. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Trace Carbolite Observed on Side B. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.43 ppg. Dumped DPI Unit Side A and Side B. Trace Solids Observed on both Sides. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 13048.29 bbls Injected. BS&W at Choke Manifold Showed 18% Water and Trace Solids. Oil = 82%. Sparged Separator. Trace Solids Observed. Completed Flare Heat Index. Flare Base Free of Fluid. Upstream DPI BS&W sample showed Trace Solids. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 16% Water and Trace Solids. Oil = 84%. Dumped DPI Unit Side A and Side B. Light Carbolite observed on Side A and Trace Carbolite observed on Side B. Lowered Separator Pressure. Diverted Flow from Tank 8 to Tank 9. Dumped DPI Unit Side A and Side B. Trace Carbolite observed on both Sides. Collected Tracerco Standard Sample. Diverted Flow from Tank 8 to Tank 7. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. BS&W at Choke Manifold Showed 13% Water and Trace Solids. Oil = 87%. Flare Base Free of Fluid. Diverted Flow from Tank 7 to Tank 8. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Light Carbolite observed on both Sides. Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 13390.98 bbls Injected. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.44 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Gas Scrubber Free of Fluid. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 78 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 03-May-2025 07:06:00 03-May-2025 07:30:00 03-May-2025 07:31:00 03-May-2025 07:43:00 03-May-2025 08:00:00 03-May-2025 08:00:00 03-May-2025 08:01:00 03-May-2025 08:01:00 03-May-2025 08:18:00 03-May-2025 08:30:00 03-May-2025 08:31:00 03-May-2025 08:31:00 03-May-2025 08:45:00 03-May-2025 09:00:00 03-May-2025 09:00:00 03-May-2025 09:01:00 03-May-2025 09:01:00 03-May-2025 09:14:00 03-May-2025 09:30:00 03-May-2025 09:31:00 03-May-2025 09:48:00 03-May-2025 09:56:00 03-May-2025 10:00:00 03-May-2025 10:00:00 03-May-2025 10:00:00 03-May-2025 10:01:00 03-May-2025 10:01:00 03-May-2025 10:01:00 03-May-2025 10:01:00 03-May-2025 10:05:00 03-May-2025 10:16:00 03-May-2025 10:30:00 03-May-2025 10:31:00 03-May-2025 10:45:00 03-May-2025 11:00:00 03-May-2025 11:00:00 03-May-2025 11:01:00 03-May-2025 11:01:00 03-May-2025 11:01:00 03-May-2025 11:07:00 03-May-2025 11:17:00 03-May-2025 11:30:00 03-May-2025 11:31:00 03-May-2025 11:45:00 03-May-2025 12:00:00 03-May-2025 12:00:00 03-May-2025 12:00:00 03-May-2025 12:01:00 03-May-2025 12:01:00 03-May-2025 12:15:00 03-May-2025 12:30:00 03-May-2025 12:31:00 03-May-2025 12:45:00 03-May-2025 12:46:00 03-May-2025 13:00:00 03-May-2025 13:01:00 03-May-2025 13:01:00 Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Applied CMSF = 0.932. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Diverted Flow from Tank 10 to Tank 1. Collected 1st 5 gallon bulk Chemical Free sample at the U/S Choke Manifold sample point. Dumped DPI Unit Side A and Side B. Light Carbolite observed on Side A and Trace Carbolite observed on Side B. Diverted flow to parallel on DPI unit. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 13% Water and Trace Solids. Oil = 87%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Upstream DPI BS&W sample showed Trace Solids. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 86%. Oil API 30.7 @ 60F (Oil SG 0.872). Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Sparged Separator. Light Solids Observed. Diverted Flow from Tank 2 to Tank 1. Injection Rate into NDBi-014 @ 3.75 bpm with a Total of 14403.87 bbls Injected. Collected 2nd 5 gallon bulk Chemical Free sample at the U/S Choke Manifold sample point. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Lowered Separator Pressure. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 16% Water and Trace Solids. Oil = 84%. Dumped DPI Unit Side A and Side B. Heavy Carbolite Observed on Side A and Trace Carbolite Observed on Side B. Collected Tracerco Standard Sample. Collected 4th 5 gallon bulk Chemical Free sample at the U/S Choke Manifold sample point. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 3 to Tank 4. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 3. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 2 to Tank 3. Collected 3rd 5 gallon bulk Chemical Free sample at the U/S Choke Manifold sample point. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Gas SG = 0.674, CO2 = 0.1%, H2S = 0 ppm. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Collected Arctic Fox Flash Point sample at the U/S Choke Manifold sample point. (Chemical Free) Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 79 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 03-May-2025 13:07:00 03-May-2025 13:17:00 03-May-2025 13:30:00 03-May-2025 13:31:00 03-May-2025 13:31:00 03-May-2025 13:45:00 03-May-2025 14:00:00 03-May-2025 14:01:00 03-May-2025 14:01:00 03-May-2025 14:15:00 03-May-2025 14:18:00 03-May-2025 14:30:00 03-May-2025 14:31:00 03-May-2025 14:31:00 03-May-2025 14:38:00 03-May-2025 14:46:00 03-May-2025 15:00:00 03-May-2025 15:01:00 03-May-2025 15:01:00 03-May-2025 15:05:00 03-May-2025 15:16:00 03-May-2025 15:25:00 03-May-2025 15:28:00 03-May-2025 15:30:00 03-May-2025 15:30:00 03-May-2025 15:31:00 03-May-2025 15:45:00 03-May-2025 16:00:00 03-May-2025 16:01:00 03-May-2025 16:01:00 03-May-2025 16:01:00 03-May-2025 16:16:00 03-May-2025 16:27:00 03-May-2025 16:30:00 03-May-2025 16:31:00 03-May-2025 16:44:00 03-May-2025 17:00:00 03-May-2025 17:01:00 03-May-2025 17:01:00 03-May-2025 17:01:00 03-May-2025 17:02:00 03-May-2025 17:15:00 03-May-2025 17:30:00 03-May-2025 17:30:00 03-May-2025 17:31:00 03-May-2025 17:47:00 03-May-2025 18:00:00 03-May-2025 18:00:00 03-May-2025 18:00:00 03-May-2025 18:01:00 03-May-2025 18:11:00 03-May-2025 18:15:00 03-May-2025 18:30:00 03-May-2025 18:30:00 03-May-2025 18:31:00 03-May-2025 18:31:00 03-May-2025 18:42:00 Diverted Flow from Tank 6 to Tank 5. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Flare Base Free of Fluid. Diverted Flow from Tank 5 to Tank 6. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Applied CMSF = 0.944. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Collected Flare Heat Index. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. EDGE Computer restarted (1 min). Sparged Separator. Trace Solids Observed. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Oil API 30.6 @ 60F (Oil SG 0.873). Lowered Separator Pressure. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 14% Water and Trace Solids. Oil = 86%. Diverted Flow from Tank 9 to Tank 10. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 16105.41 bbls Injected. BS&W at Choke Manifold Showed 9% Water and Trace Solids. Oil = 91%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Collected Tracerco Standard Sample. Diverted Flow from Tank 10 to Tank 9. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Gas SG = 0.688. CO2 = 0.1%, H2S = 0 ppm. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Lowered Separator Pressure. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Gas Scrubber Free of Fluid. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Flare Base Free of Fluid. Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 16208.21 bbls Injected. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Diverted Flow from Tank 10 to Tank 9. Injection Rate into NDBi-014 @ 3.76 bpm with a Total of 16321.31 bbls Injected. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 80 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 03-May-2025 18:45:00 03-May-2025 18:59:00 03-May-2025 19:00:00 03-May-2025 19:00:00 03-May-2025 19:01:00 03-May-2025 19:15:00 03-May-2025 19:15:00 03-May-2025 19:30:00 03-May-2025 19:30:00 03-May-2025 19:31:00 03-May-2025 19:31:00 03-May-2025 19:45:00 03-May-2025 19:57:00 03-May-2025 20:00:00 03-May-2025 20:00:00 03-May-2025 20:01:00 03-May-2025 20:15:00 03-May-2025 20:30:00 03-May-2025 20:30:00 03-May-2025 20:31:00 03-May-2025 20:31:00 03-May-2025 20:45:00 03-May-2025 20:58:00 03-May-2025 21:00:00 03-May-2025 21:00:00 03-May-2025 21:01:00 03-May-2025 21:15:00 03-May-2025 21:30:00 03-May-2025 21:30:00 03-May-2025 21:31:00 03-May-2025 21:31:00 03-May-2025 21:34:00 03-May-2025 21:45:00 03-May-2025 21:45:00 03-May-2025 22:00:00 03-May-2025 22:00:00 03-May-2025 22:01:00 03-May-2025 22:10:00 03-May-2025 22:15:00 03-May-2025 22:15:00 03-May-2025 22:30:00 03-May-2025 22:30:00 03-May-2025 22:31:00 03-May-2025 22:31:00 03-May-2025 22:45:00 03-May-2025 22:57:00 03-May-2025 23:00:00 03-May-2025 23:00:00 03-May-2025 23:00:00 03-May-2025 23:01:00 03-May-2025 23:15:00 03-May-2025 23:30:00 03-May-2025 23:30:00 03-May-2025 23:31:00 03-May-2025 23:31:00 03-May-2025 23:43:00 03-May-2025 23:45:00 Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 16434.41 bbls Injected. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Diverted Flow from Tank 1 to Tank 2. Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 16547.52 bbls Injected. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Gas Scrubber Free of Fluid. Diverted Flow from Tank 10 to Tank 1. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Gas Scrubber Free of Fluid. Diverted Flow from Tank 2 to Tank 3. Injection Rate into NDBi-014 @ 3.75 bpm with a Total of 16885.31 bbls Injected. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Diverted Flow from Tank 1 to Tank 2. Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 16771.95 bbls Injected. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Flare Base Free of Fluid. Diverted Flow from Tank 2 to Tank 1. Injection Rate into NDBi-014 @ 3.75 bpm with a Total of 16667.89 bbls Injected. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 5. Injection Rate into NDBi-014 @ 3.75 bpm with a Total of 17224.79 bbls Injected. BS&W at Choke Manifold Showed 12% Water and Trace Solids. Oil = 88%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 3. (15 min Flow) Injection Rate into NDBi-014 @ 3.75 bpm with a Total of 17109.19 bbls Injected. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Sparged Separator. Trace Solids Observed. Diverted Flow from Tank 3 to Tank 4. (15 min Flow) Diverted Flow from Tank 3 to Tank 4. Injection Rate into NDBi-014 @ 3.75 bpm with a Total of 17000.65 bbls Injected. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Flare Base Free of Fluid. Diverted Flow from Tank 6 to Tank 5. Injection Rate into NDBi-014 @ 3.8 bpm with a Total of 17453.38 bbls Injected. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Gas Scrubber Free of Fluid. Diverted Flow from Tank 5 to Tank 6. Injection Rate into NDBi-014 @ 3.77 bpm with a Total of 17338.35 bbls Injected. Flare Base Free of Fluid. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 81 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 04-May-2025 00:00:00 04-May-2025 00:00:00 04-May-2025 00:00:00 04-May-2025 00:00:00 04-May-2025 00:00:00 04-May-2025 00:00:00 04-May-2025 00:01:00 04-May-2025 00:05:00 04-May-2025 00:15:00 04-May-2025 00:30:00 04-May-2025 00:31:00 04-May-2025 00:31:00 04-May-2025 00:45:00 04-May-2025 00:47:00 04-May-2025 01:00:00 04-May-2025 01:01:00 04-May-2025 01:07:00 04-May-2025 01:10:00 04-May-2025 01:10:00 04-May-2025 01:14:00 04-May-2025 01:15:00 04-May-2025 01:30:00 04-May-2025 01:30:00 04-May-2025 01:31:00 04-May-2025 01:31:00 04-May-2025 01:45:00 04-May-2025 01:57:00 04-May-2025 02:00:00 04-May-2025 02:00:00 04-May-2025 02:01:00 04-May-2025 02:15:00 04-May-2025 02:30:00 04-May-2025 02:30:00 04-May-2025 02:31:00 04-May-2025 02:31:00 04-May-2025 02:41:00 04-May-2025 02:45:00 04-May-2025 02:50:00 04-May-2025 02:53:00 04-May-2025 03:00:00 04-May-2025 03:00:00 04-May-2025 03:10:00 04-May-2025 03:15:00 04-May-2025 03:30:00 04-May-2025 03:30:00 04-May-2025 03:30:00 04-May-2025 03:31:00 04-May-2025 03:31:00 04-May-2025 03:45:00 04-May-2025 03:56:00 04-May-2025 04:00:00 04-May-2025 04:00:00 04-May-2025 04:01:00 04-May-2025 04:10:00 04-May-2025 04:12:00 04-May-2025 04:13:00 04-May-2025 04:15:00 Injection Rate into NDBi-014 @ 0 bpm with a Total of 17559.24 bbls Injected. Began transferring fluid from Tank #1 to Worley Truck 86088. RVP 6. LRS Injection Pump offline for Preventative Maintenance / Data Download. Diverted Flow from Tank 5 to Tank 6. Oil API 31.4 @ 60F (Oil SG 0.869). Gas SG = 0.679, CO2 = 0.1%, H2S = 0 ppm. LRS Injection pump back Online @ 3.75 bpm. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Diverted Flow from Tank 8 to Tank 7. Injection Rate into NDBi-014 @ 3.82 bpm with a Total of 17639.9 bbls Injected. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Gas Scrubber Free of Fluid. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Finished transferring fluid from Tank #1 to Worley Truck 86088. Sparged Separator. Trace Solids Observed. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Gas Scrubber Free of Fluid. Began transferring fluid from Tank #2 to Worley Truck 86060. RVP 6. Diverted Flow from Tank 9 to Tank 10. Injection Rate into NDBi-014 @ 3.85 bpm with a Total of 17973.19 bbls Injected. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Moderate Carbolite Observed on both Sides. Diverted Flow from Tank 8 to Tank 9. Injection Rate into NDBi-014 @ 3.83 bpm with a Total of 17858.41 bbls Injected. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Water Salinity = 27,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Gas Scrubber Free of Fluid. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 3.82 bpm with a Total of 17747.52 bbls Injected. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Finished transferring fluid from Tank #2 to Worley truck 86060/86058. Began transferring fluid from Tank #5 to Worley Truck 86058. RVP 6. Completed Flare Heat Index. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Gas Scrubber Free of Fluid. Diverted Flow from Tank 9 to Tank 10. Injection Rate into NDBi-014 @ 3.85 bpm with a Total of 18199.59 bbls Injected. BS&W at Choke Manifold Showed 10% Water and Trace Solids. Oil = 90%. Sparged Separator. Light Solids Observed. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 10 to Tank 9. Injection Rate into NDBi-014 @ 3.84 bpm with a Total of 18088.41 bbls Injected. Completed Critical Points Check. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 82 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 04-May-2025 04:15:00 04-May-2025 04:30:00 04-May-2025 04:30:00 04-May-2025 04:31:00 04-May-2025 04:31:00 04-May-2025 04:45:00 04-May-2025 04:47:00 04-May-2025 05:00:00 04-May-2025 05:00:00 04-May-2025 05:01:00 04-May-2025 05:05:00 04-May-2025 05:10:00 04-May-2025 05:15:00 04-May-2025 05:18:00 04-May-2025 05:30:00 04-May-2025 05:31:00 04-May-2025 05:31:00 04-May-2025 05:51:00 04-May-2025 06:00:00 04-May-2025 06:00:00 04-May-2025 06:01:00 04-May-2025 06:15:00 04-May-2025 06:30:00 04-May-2025 06:31:00 04-May-2025 06:31:00 04-May-2025 06:31:00 04-May-2025 06:47:00 04-May-2025 07:00:00 04-May-2025 07:00:00 04-May-2025 07:01:00 04-May-2025 07:07:00 04-May-2025 07:17:00 04-May-2025 07:26:00 04-May-2025 07:30:00 04-May-2025 07:31:00 04-May-2025 07:31:00 04-May-2025 08:00:00 04-May-2025 08:01:00 04-May-2025 08:02:00 04-May-2025 08:16:00 04-May-2025 08:30:00 04-May-2025 08:31:00 04-May-2025 08:31:00 04-May-2025 09:00:00 04-May-2025 09:01:00 04-May-2025 09:01:00 04-May-2025 09:01:00 04-May-2025 09:03:00 04-May-2025 09:30:00 04-May-2025 09:31:00 04-May-2025 09:31:00 04-May-2025 10:00:00 04-May-2025 10:01:00 04-May-2025 10:01:00 04-May-2025 10:08:00 04-May-2025 10:15:00 04-May-2025 10:16:00 Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 10 to Tank 1. Injection Rate into NDBi-014 @ 3.88 bpm with a Total of 18320.27 bbls Injected. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Collected Tracerco Standard Sample. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 7% Water and Trace Solids. Oil = 93%. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Gas Scrubber Free of Fluid. Added Tank 6 to NDBi-014 Injection with Tank 9 and Tank 10. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on both Sides. Flare Base Free of Fluid. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 8% Water and Trace Solids. Oil = 92%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Injection Rate into NDBi-014 @ 3.85 bpm with a Total of 18431.22 bbls Injected. Diverted Flow from Tank 1 to Tank 2. Diverted Flow from Tank 4 to Tank 3. BS&W at Choke Manifold Showed 7% Water and Trace Solids. Oil = 93%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Gas Scrubber Free of Fluid. Diverted Flow from Tank 3 to Tank 4. Injection Rate into NDBi-014 @ 3.80 bpm with a Total of 19352.10 bbls Injected. BS&W at Choke Manifold Showed 7% Water and Trace Solids. Oil = 93%. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9, Tank 6 and Tank 10. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 7% Water and Trace Solids. Oil = 93%. BS&W Untreated Sample at Choke Manifold Showed 6.5% Water, 0.5% Emulsion and Trace Solids. Oil = 93%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Upstream DPI BS&W sample showed Trace Solids. Added Tank 5 to NDBi-014 Injection with Tank 3 and Tank 4. Removed Tank 5 from NDBi-014 Injection. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Applied CMSF = 0.926. Upstream DPI BS&W sample showed Trace Solids. Added Tank 3 and Tank 4 to NDBi-014 Injection and Removed Tank 1 and Tank 2. Diverted Flow from Tank 6 to Tank 5. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Dumped DPI Unit Side A and Side B. Light Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Diverted Flow from Tank 5 to Tank 6. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 83 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 04-May-2025 10:30:00 04-May-2025 10:31:00 04-May-2025 10:31:00 04-May-2025 10:31:00 04-May-2025 10:32:00 04-May-2025 10:44:00 04-May-2025 11:00:00 04-May-2025 11:01:00 04-May-2025 11:16:00 04-May-2025 11:16:00 04-May-2025 11:30:00 04-May-2025 11:31:00 04-May-2025 11:31:00 04-May-2025 11:31:00 04-May-2025 12:00:00 04-May-2025 12:00:00 04-May-2025 12:00:00 04-May-2025 12:01:00 04-May-2025 12:01:00 04-May-2025 12:15:00 04-May-2025 12:30:00 04-May-2025 12:31:00 04-May-2025 12:31:00 04-May-2025 13:00:00 04-May-2025 13:01:00 04-May-2025 13:15:00 04-May-2025 13:16:00 04-May-2025 13:30:00 04-May-2025 13:31:00 04-May-2025 13:31:00 04-May-2025 13:38:00 04-May-2025 14:00:00 04-May-2025 14:00:00 04-May-2025 14:00:00 04-May-2025 14:01:00 04-May-2025 14:15:00 04-May-2025 14:30:00 04-May-2025 14:31:00 04-May-2025 14:31:00 04-May-2025 14:43:00 04-May-2025 15:00:00 04-May-2025 15:01:00 04-May-2025 15:15:00 04-May-2025 15:20:00 04-May-2025 15:30:00 04-May-2025 15:31:00 04-May-2025 15:31:00 04-May-2025 15:31:00 04-May-2025 15:35:00 04-May-2025 15:41:00 04-May-2025 15:46:00 04-May-2025 16:00:00 04-May-2025 16:00:00 04-May-2025 16:01:00 04-May-2025 16:01:00 04-May-2025 16:14:00 04-May-2025 16:30:00 Gas SG = 0.684, CO2 = 0.1%, H2S = 0 ppm. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Diverted Flow from Tank 7 to Tank 8. Collected Tracerco Standard Sample. Injection Rate into NDBi-014 @ 3.79 bpm with a Total of 20039.74 bbls Injected. BS&W at Choke Manifold Showed 7% Water and Trace Solids. Oil = 93%. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Added Tank 5 and Tank 6 to NDBi-014 Injection and Removed Tank 3 and Tank 4. Diverted Flow from Tank 8 to Tank 7. BS&W at Choke Manifold Showed 6% Water and Trace Solids. Oil = 94%. Diverted Flow from Tank 6 to Tank 7. BS&W at Choke Manifold Showed 5.5% Water and Trace Solids. Oil = 94.5%. Water Salinity = 26,000 ppm. Water pH = 8. Water Weight = 8.49 ppg. Oil API 30.6 @ 60F (Oil SG 0.873). Added Tank 6 to NDBi-014 Injection with Tank 3 and Tank 4. Removed tank 6 from NDBi-014 Injection. Collected Core Lab sample at the U/S Choke Manifold sample point. (Chemical Free) Decreased Expro adjustable Choke to 52/64ths as per Santos WSS. Diverted Flow from Tank 1 to Tank 2. Injection Rate into NDBi-014 @ 3.81 bpm with a Total of 20496.21 bbls Injected. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. BS&W at Choke Manifold Showed 5.5% Water and Trace Solids. Oil = 94.5%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Added Tank 7 and Tank 8 to NDBi-014 Injection and Removed Tank 5 and Tank 6. Diverted Flow from Tank 10 to Tank 1. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Upstream DPI BS&W sample showed Trace Solids. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Moderate Carbolite Observed on Side B. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 7% Water and Trace Solids. Oil = 93%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Diverted Flow from Tank 9 to Tank 10. Sparged Separator. Trace Solids Observed. Gas Scrubber Free of Fluid. Decreased Injection Rate to 2.8 bpm into well NDBi-014. Collected Flare Heat Index. Diverted Flow from Tank 3 to Tank 4. Gas SG = 0.678, CO2 = 0.1%, H2S = 0 ppm. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Added Tank 9 and Tank 10 to NDBi-014 Injection and Removed Tank 7 and Tank 8. Diverted Flow from Tank 2 to Tank 3. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Oil API 30.7 @ 60F (Oil SG 0.872). Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Diverted Flow from Tank 2 to Tank 1. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Decreased Injection Rate to 3 bpm into well NDBi-014. Diverted Flow from Tank 1 to Tank 2. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on Side A and Light Carbolite Observed on Side B. Diverted Flow from Tank 4 to Tank 3. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 84 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 04-May-2025 16:31:00 04-May-2025 16:31:00 04-May-2025 16:40:00 04-May-2025 17:00:00 04-May-2025 17:01:00 04-May-2025 17:01:00 04-May-2025 17:01:00 04-May-2025 17:02:00 04-May-2025 17:15:00 04-May-2025 17:24:00 04-May-2025 17:30:00 04-May-2025 17:31:00 04-May-2025 17:31:00 04-May-2025 18:00:00 04-May-2025 18:00:00 04-May-2025 18:00:00 04-May-2025 18:01:00 04-May-2025 18:14:00 04-May-2025 18:15:00 04-May-2025 18:30:00 04-May-2025 18:30:00 04-May-2025 18:31:00 04-May-2025 18:31:00 04-May-2025 18:43:00 04-May-2025 19:00:00 04-May-2025 19:00:00 04-May-2025 19:15:00 04-May-2025 19:15:00 04-May-2025 19:30:00 04-May-2025 19:30:00 04-May-2025 19:31:00 04-May-2025 19:31:00 04-May-2025 19:45:00 04-May-2025 20:00:00 04-May-2025 20:00:00 04-May-2025 20:01:00 04-May-2025 20:13:00 04-May-2025 20:15:00 04-May-2025 20:21:00 04-May-2025 20:30:00 04-May-2025 20:30:00 04-May-2025 20:31:00 04-May-2025 20:31:00 04-May-2025 20:54:00 04-May-2025 21:00:00 04-May-2025 21:00:00 04-May-2025 21:01:00 04-May-2025 21:15:00 04-May-2025 21:30:00 04-May-2025 21:30:00 04-May-2025 21:31:00 04-May-2025 21:31:00 04-May-2025 22:00:00 04-May-2025 22:00:00 04-May-2025 22:01:00 04-May-2025 22:02:00 04-May-2025 22:15:00 Decreased Injection Rate to 1.8 bpm into well NDBi-014. Diverted Flow from Tank 4 to Tank 5. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Diverted Flow from Tank 5 to Tank 6. Collected Tracerco Standard Sample. Diverted Flow from Tank 3 to Tank 4. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Added Tank 1 and Tank 2 to NDBi-014 Injection and Removed Tank 9 and Tank 10. Decreased Injection Rate to 2 bpm into well NDBi-014. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Decreased Injection Rate to 2.5 bpm into well NDBi-014. Gas Scrubber Free of Fluid. Diverted Flow from Tank 6 to Tank 5. (15 min flow) Injection Rate into NDBi-014 @ 1.50 bpm with a Total of 21292.9 bbls Injected. BS&W at Choke Manifold Showed 5% Water. Oil = 95%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Diverted Flow from Tank 5 to Tank 6. (15 min Flow) BS&W at Choke Manifold Showed 5% Water. Oil = 95%. Water Salinity = 24,000 ppm. Water pH = 8. Water Weight = 8.48 ppg. Flare Base Free of Fluid. Diverted Flow from Tank 5 to Tank 6. Injection Rate into NDBi-014 @ 1.51 bpm with a Total of 21247.44 bbls Injected. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Injection Rate into NDBi-014 @ 1.52 bpm with a Total of 21157.92 bbls Injected. BS&W at Choke Manifold Showed 5% Water. Oil = 95%. Gas Scrubber Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Diverted Flow from Tank 6 to Tank 5. Injection Rate into NDBi-014 @ 1.54 bpm with a Total of 21202.85 bbls Injected. Injection Rate into NDBi-014 @ 1.23 bpm with a Total of 21413.67 bbls Injected. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 1.23 bpm with a Total of 21452.12 bbls Injected. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Diverted Flow from Tank 7 to Tank 8. Injection Rate into NDBi-014 @ 1.20 bpm with a Total of 21379.89 bbls Injected. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Gas Scrubber Free of Fluid. Diverted Flow from Tank 8 to Tank 7. Diverted Flow from Tank 6 to Tank 7. Injection Rate into NDBi-014 @ 1.50 bpm with a Total of 21333.12 bbls Injected. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Gas Scrubber Free of Fluid. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Injection Rate into NDBi-014 @ 1.23 bpm with a Total of 21481.49 bbls Injected. Diverted Flow from Tank 8 to Tank 9. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 85 Well: Field: Location: DATE / TIME dd/mmm/yyyy hh:mm:ss 5-May-2025 @ 02:00 NDBi-049 - Well Clean-Up Flow SEQUENCE of EVENTS NDBi-049 Project Design #:WT-XAK-0127.5 Pikka Start Date:29-April-2025 @ 10:00 ND-B End Date: 04-May-2025 22:30:00 04-May-2025 22:30:00 04-May-2025 22:30:00 04-May-2025 22:31:00 04-May-2025 22:31:00 04-May-2025 22:55:00 04-May-2025 22:57:00 04-May-2025 23:00:00 04-May-2025 23:01:00 04-May-2025 23:15:00 04-May-2025 23:28:00 04-May-2025 23:30:00 04-May-2025 23:31:00 04-May-2025 23:31:00 04-May-2025 23:56:00 05-May-2025 00:00:00 05-May-2025 00:00:00 05-May-2025 00:00:00 05-May-2025 00:07:00 05-May-2025 00:15:00 05-May-2025 00:30:00 05-May-2025 00:31:00 05-May-2025 00:31:00 05-May-2025 01:26:00 05-May-2025 01:30:00 05-May-2025 01:31:00 05-May-2025 01:31:00 05-May-2025 02:00:00 05-May-2025 02:00:00 05-May-2025 02:00:00 05-May-2025 02:00:00 06-May-2025 02:00:00 Closed NDBi-049 Master Valve (MV) - 24 Turns. LRS Injection Pump Online and began to freeze protect to well NDBi-014 with Diesel. Diverted Flow from Tank 7 to Tank 8. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. LRS Injection Pump Offline. 40 bbls diesel Pumped to well NDBi-014 for freeze protect. Diverted Flow from Tank 8 to Tank 10. Diverted Flow from Tank 9 to Tank 7. LRS Injection Pump Offline. Finished Injection into well NDBi-014. Save remaining Flowback Fluid in Tank Farm for Wireline Injectivity Test. Injection Rate into NDBi-014 @ 0 bpm with a Total of 21525.77 bbls Injected. BS&W at Choke Manifold Showed 4.5% Water and Trace Solids. Oil = 95.5%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.47 ppg. Gas Scrubber Free of Fluid. Closed NDBi-049 Production Wing Valve (PWV) - 24 Turns. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 2% Water and Trace Solids. Oil = 98%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. BS&W at Choke Manifold Showed 2% Water and Trace Solids. Oil = 98%. Hard Shut-In @ Expro Choke Manifold. Stopped all Chemical Injection. Flare Base Free of Fluid. Dumped DPI Unit Side A and Side B. Trace Carbolite Observed on both Sides. Diverted Flow from Tank 9 to Tank 10. BS&W at Choke Manifold Showed 2.2% Water and Trace Solids. Oil = 97.8%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Flare Base Free of Fluid. BS&W at Choke Manifold Showed 5% Water and Trace Solids. Oil = 95%. Water Salinity = 25,000 ppm. Water pH = 8. Water Weight = 8.46 ppg. Gas Scrubber Free of Fluid. Diverted Flow from Tank 10 to Tank 9. BS&W at Choke Manifold Showed 3.5% Water and Trace Solids. Oil = 96.5%. Collected Tracerco Standard Sample. WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 86 Santos – Pikka Development – NDBi-049 SECTION 12COMBINED METER & SHRINKAGE FACTOR (CMSF)WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 87 Combined Meter & Shrinkage FactorClient:Well No:Field:Test:MF #DateTimeChokeTankTankTTank vcfCorrecteddTankMeterMeter CountsdMeterCMSFCMSF Applied64thsbbls°F @ 60°FVolumebblsbblsbblsTimeStart16:30 3.02 50.5 1.0053.03343.80Applied 17:00Finish17:00 70.86 53.6 1.00371.09412.76Start18:30 135.69 52.3 1.004136.21863.80Applied 19:00Finish19:00 203.54 54.6 1.003204.09934.58Start6:30 30.19 51.8 1.00430.312668.68Applied 06:30Finish7:00 117.60 50.8 1.005118.142762.64Start8:00 205.05 50.2 1.005206.0593.62Applied 08:30Finish8:30 294.00 53.0 1.004295.03188.41Start17:3012860.31 71.6 0.99459.965969.90Applied 17:00 - 18:00Finish18:00 164.34 71.6 0.994163.396090.40Start18:0012857.29 71.6 0.99456.966090.40Applied 18:00 - 18:30Finish18:30 155.29 71.6 0.994154.396222.80Re-Applied 0.858 @ 18:30Start21:0012873.12 71.6 0.99472.706827.50Applied 21:00-21:30Finish21:30 170.37 71.6 0.994169.386974.60Start22:00128170.37 68.3 0.996169.667090.30Applied 21:30Finish22:30 267.62 69.5 0.995266.357207.40Start12:30 127.4 68.1 0.996126.887657.10Applied 12:30 - 1:00Finish1:00 227.66 68.1 0.996226.747787.20Re-Applied 0.826 @ 01:00Start2:00 137.96 68.1 0.996137.408024.00Applied 02:00 - 03:30Finish2:30 233.70 68.1 0.996232.758163.10Re-Applied 0.826 @ 03:30Note:SantosNDBi-049PIKKA DevelopmentWell Clean-UpTank Readings Test Separator1 29-Apr-25 6468.051.5''68.960.9872 29-Apr-25 8267.881.5"70.780.9590.9354 30-Apr-25 12888.972''94.790.9393 30-Apr-25 12887.831.5''93.960.858697.432''132.400.7365103.432''120.501-May-251-May-250.657896.692"117.100.826796.692''147.102-May-251-May-251. Tank corrected volume = tank reading x VCF2. CMSF = delta volume tank / delta meter0.76810 2-May-25 12895.352"139.100.6859 2-May-25 12899.852"130.10WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 88 Combined Meter & Shrinkage FactorClient:Well No:Field:Test:MF #DateTimeChokeTankTankTTank vcfCorrecteddTankMeterMeter CountsdMeterCMSFCMSF Applied64thsbbls°F @ 60°FVolumebblsbblsbblsTime2-May-25Start3:00 140.97 68.2 0.996140.398557.40Applied 0400 - 0430Finish4:00 240.48 68.2 0.996239.498700.10Re-Applied 0.826 @ 04:302-May-25Start6:30 154.54 61.0 1.000154.469171.42Finish7:00 242.74 63.7 0.998242.299265.26Applied 6:302-May-25Start21:30 64.08 64.8 0.99863.932276.10Finish22:00 166.60 66.1 0.997166.092382.50Applied 21:303-May-25Start8:00 152.28 62.0 0.999152.134548.71Finish8:30 266.87 64.1 0.998266.324671.18Applied 8:303-May-25Start13:00 63.32 66.0 0.99763.135778.14Finish13:30 180.93 66.2 0.997180.375902.34Applied 13:30Start8:30 77.65 61.0 1.00077.6110684.34Finish9:00 194.49 63.5 0.998194.1510810.15Applied 09:00Note:SantosNDBi-049PIKKA DevelopmentWell Clean-UpTank Readings Test Separator112899.102"142.700.694212887.832"93.840.9360.9604128114.202"122.470.9323128102.172"106.401. Tank corrected volume = tank reading x VCF2. CMSF = delta volume tank / delta meter0.9446 4-May-25 128116.542''125.810.9265128117.242''124.20WT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 89 Santos – Pikka Development – NDBi-049SECTION 13DIAGRAMSWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 90 Santos – Pikka Development – NDBi-049P&IDProcess & Instrumentation DiagramWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 91 ¤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 APRV4/28/2025 A INITIAL RELEASE. NEW LOCATION OF WELLHEAD BERM SO VC 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 COPYxxx xxxxxxxxxxxUNCONTROLLED 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 APRV4/28/2025 A INITIAL RELEASE. NEW LOCATION OF WELLHEAD BERM SO VC 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 MONITOR ¤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 APRV4/28/2025 A INITIAL RELEASE. NEW LOCATION OF WELLHEAD BERM SO VC 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 COPYx ¤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 APRV4/28/2025 A INITIAL RELEASE. NEW LOCATION OF WELLHEAD BERM SO VC 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 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 APRV4/28/2025 A INITIAL RELEASE. NEW LOCATION OF WELLHEAD BERM SO VC 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 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 APRV4/28/2025 A INITIAL RELEASE. NEW LOCATION OF WELLHEAD BERM SO VC 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 COPY Santos – Pikka Development – NDBi-049 SAFE CHART Safety Analysis Function Evaluation Chart WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 98 A A SO VC RM REV CREATE CHECK APPROVE 11 111 FSV 102A 11 111 11 111 1 1 111 11 111 11 111 PSE 102 1 1 11 1 1 1 1 PSE 103 11 1 1 1 1 PSHH 102 102 PSL 102 A.4f.2FSV (GAS) LSH A.5c.2 LSL A.5d.4 PSH 102 LSHH 102 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 FLOWLINE CHOKE TO HP HORIZONTAL SEPARATOR FAQ 002 PSH 002 PSL 101 PSV 002 FSV 102A 102 PSV LSL (H2O)A.4e.2 LSL (OIL) A.4e.2 FSV (H2O)102D FSV (OIL) 102B, 102C 102E DAQ AUDIBLE ALARMPRESSURE RELIEFMINIMIZE BACKFLOWVACUUM / PRESS. RELIEFVENTDAQ VISUAL ALARMLOCAL ALARMFUNCTIONPERFORMEDDEVICE I.D. PROCESS COMPONENT 12SHUT IN EXPRO / WELLSHUT IN EXPRO / WELLSDVSDVINITIAL RELEASE. CHANGE OF TANK FARM & REMOVAL OF HEATER CHANGE DESCRIPTION ALT. DEVICE IF APPLICABLESAC. REF. NO.IDENTIFICATION ALTERNATIVE PROTECTION SHUTDOWN ORCONTROL DEVICE I.D.WT-XAK-80127.5 SAFETY ANALYSIS FUNCTION EVALUATION (S.A.F.E.) CHART Santos - Pikka Development - Well Clean-Up Campaign RevisionDocument No. Project 4/28/2025 FLOWLINE WELL HEAD TO CHOKE MANIFOLD FAQ 001 DATE DESCRIPTION A.1c.2 FSV A.1d.2 A.1a.2 PSL 001 PSH PSV LSH 102 FSV (GAS) 400 BBL SAND / DRAIN TANK AND RELIEF TANK ABJ 401 402 VENT 401, 402 VPSV A.5b.2 367 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 WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 99 A A SO VC RM REV CREATE CHECK APPROVE DAQ AUDIBLE ALARMPRESSURE RELIEFMINIMIZE BACKFLOWVACUUM / PRESS. RELIEFVENTDAQ VISUAL ALARMLOCAL ALARMFUNCTIONPERFORMEDDEVICE I.D. PROCESS COMPONENT 12SHUT IN EXPRO / WELLSHUT IN EXPRO / WELLSDVSDVINITIAL RELEASE. CHANGE OF TANK FARM & REMOVAL OF HEATER CHANGE DESCRIPTION ALT. DEVICE IF APPLICABLESAC. REF. NO.IDENTIFICATION ALTERNATIVE PROTECTION SHUTDOWN ORCONTROL DEVICE I.D.WT-XAK-80127.5 SAFETY ANALYSIS FUNCTION EVALUATION (S.A.F.E.) CHART Santos - Pikka Development - Well Clean-Up Campaign RevisionDocument No. Project 4/28/2025 DATE DESCRIPTION 1 1 1 1 1 1 1 1 1 1 111 1 TRANSFER PUMP (WELL TEST TANK FARM) PBA 112 PSH A.7b.5 PSL A.7d.5 PSV 112 FSV 112 FSV 109B, 110B, 111B POSITIVE DISP. CHEMICAL PUMP PBA 109 110 111 PSH A.7b.4 PSL A.7d.4 PSV 109, 110, 111 FSV 109A, 110A, 111A Notes: 1. Fill operations for Atmospheric Tanks (BBJ-801 through BBJ-810) is continously operated and manned. MANUAL ESD PULL STATION EMERGENCY SHUT DOWN 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 FSV 105A, 105B POSITIVE DISP. CHEMICAL PUMP PBA 105 106 PSH A.7b.4 PSL A.7d.4 PSV 105, 106 FSV 106A, 106B WT-XAK-0127.5_NDBi-049_Rev A www.expro.com Page 100 Santos – Pikka Development – NDBi-049GADGeneral Arrangement DrawingWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 101 ¤UNCONTROLLED COPY ¤UNCONTROLLED COPY ¤UNCONTROLLED COPY Santos – Pikka Development – NDBi-049PFDProcess Flow DiagramWT-XAK-0127.5_NDBi-049_Rev Awww.expro.comPage 105 10K PSI SSVESD PanelAir SupplyShut Down SignalESD Stations LoopESD Pilots LoopOil to Diverter Manifold ZZZ-110SP-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 Frac Tank DPI Sand 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 04Santos – Pikka Development2025 CampaignNameChris CarterVictor ChavezDate04/25/202504/28/2025DrawnReviewApprove WT-XAK-30127.5_Rev A04/28/2025DRAWING IDUNCONTROLLED COPYUNCONTROLLED COPY10K PSI Choke Manifold3" 150210K PSI Data HeaderFluid/Sand 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 HeaderRyan McMaster 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 04Santos – Pikka Development2025 CampaignNameChris CarterVictor Chavez Ryan McMasterDate04/23/202504/28/2025DrawnReviewApprove WT-XAK-30127.5_Rev A04/28/2025DRAWING 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 COPYFluid from Scrubber & Sand from SeparatorRelief from Scrubber & Separator 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 04Santos – Pikka Development2025 CampaignNameChris CarterVictor Chavez Ryan McMasterDate04/25/202504/28/2025DrawnReviewApprove WT-XAK-30127.5_Rev A04/28/2025DRAWING 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-112 STEAM LINEWATER LINESTEAM LINEWATER LINEABCD1234ABCD1234ABCD1234ABCD1234LEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINELEGENDITEMDESCRIPTIONWELL EFFLUENTOIL LINEGAS LINERELIEF LINEAIR LINEHYDRAULIC LINECHEMICAL LINEWELL TESTINGPROCESS & FLOW DIAGRAMPage 04 of 04Santos – Pikka Development2025 CampaignNameChris CarterVictor Chavez Ryan McMasterDate04/25/202504/28/2025Drawn ReviewApprove WT-XAK-30127.5_Rev A04/28/2025DRAWING IDT7 - 367 BBLAtmospheric TankBBJ-807T8 - 367 BBLAtmospheric TankBBJ-808T9- 367 BBLAtmospheric TankBBJ-809T10 - 367 BBLAtmospheric TankBBJ-810DiverterManifold 2–InletZZZ-111Cold VentCold VentCold VentCold VentFromDiverterManifold1 – InletZZZ-110From A-TanksBBJ-801BBJ-802BBJ-803BBJ-804BBJ-805BBJ-806DiverterManifold 1 -SuctionZZZ-112Diverter Manifold 2 -Suction ZZZ-113FromDieselTankBBJ-811DisposalInjectionPump 1LRS TriplexMagtec TransferPump & Filtration UnitFilter PodsUNCONTROLLED COPYUNCONTROLLED COPYTo A-TankBBJ-806Transfer PumpPBA-112To PRIMARYInjection Wellfor DisposalTo SECONDARYInjection Well forDisposal From:Davies, Stephen F (OGC) To:Leahy, Scott (Scott) Cc:Wallace, Chris D (OGC); Dewhurst, Andrew D (OGC) Subject:RE: NDBi-049 Frac Sundry (PTD 224-119, Sundry 325-027) - Additional Questions Date:Friday, April 11, 2025 11:56:00 AM Attachments:image005.png image008.png Scott, Thank you all for the detailed explanation and illustrations. I took a closer look at this yesterday and this morning, spotted the fracture sleeves and packers for all wells in this area on my base map, and I agree that separation distance is sufficient to prevent interference during the fracturing operations (assuming that the wellbore paths, modeled frac lengths, and modeled frac heights are reasonably accurate, and the induced fractures propagate sub-parallel with the wellbore). Along with NDB-046, my concern also extends to NDB-048, which crosses NDB-049 above the Stage 10 frac. Please also monitor this well during frac operations. Thanks for Your Help and Be Well, Steve Davies AOGCC From: Leahy, Scott (Scott) <Scott.Leahy@santos.com> Sent: Thursday, April 10, 2025 10:33 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Atherton, Michaela (Michaela) <Michaela.Atherton@santos.com>; Senden, Robert (Ty) <Ty.Senden@santos.com> Subject: RE: NDBi-049 Frac Sundry (PTD 224-119, Sundry 325-027) - Additional Questions Steve, Agreed that NDBi-049 is in a congested area. We’ve had many discussions on the well placements and their close proximity and believe that we have come up with a good plan. Stage 10 of NDBi-049 has its half-length modelled at ~ 324 feet. As noted in one of the attached figures, Stage 10 of NDBi-049 and Stage 9 of NDBi-046 are approximately 1,000 feet apart. NDBi-046 does penetrate the Nan 3.2 top and approaches the Stage 10 port of NDBi-049 at a distance close to 350-400 feet however, the fracture azimuth is believed to be along the direction of the wellbore, ~330o. We believe the spacing of the ports between wells between NDBi-049 and NDBi-046 and the azimuth offset of the lateral between the two wells have sufficient distance between the two to not interfere during fracture operations. The penetration of the NT3.2 on wells NDB-048 and NDBi-050 are greater than 1000 feet from the closest frac port on NDBi-049 and lie perpendicular to the expected fracture plane. Santos does not anticipate that fractures will reach these wells. Also included in the attachment is a cross section of the NDBi-049 well showing the location of wells NDB-048, NDBi-050 and NDBi-050PB1 sailing above the NDBi-049 lateral. All three wells are above the Nan 3.2 top reservoir and the fracture model does not indicate that the fracture grows above this boundary. Furthermore, the modelled hydraulic fracture height on Stage 10 of NDBi-049 is 247 feet however this is total height which extends above and below the fracture initiation point. For a mitigation measure, Santos will monitor the BHP gauge from the NDBi-046 well in the Frac Van. If a pressure increase is observed in the NDBi-046 well while fracturing Stage 10 on NDBi-049, the frac supervisor will cut proppant and go to flush. Scott Leahy – Completions SpecialistOil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, April 8, 2025 4:58 PM To: Leahy, Scott (Scott) <Scott.Leahy@santos.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: ![EXT]: NDBi-049 Frac Sundry (PTD 224-119, Sundry 325-027) - Additional Questions Scott, Thank you for the additional information related to NDB-050 and NDB-050PB1. I notice that NDB-049 (the frac candidate) lies near existing wells NDB-046, NDB-048, NDB-50, and NDB-50PB1 in a very congested area. Given that the half-lengths of the induced fractures within NDB- 049 are expected to extend up to 490’ and the height of these induced fractures may reach 250’, does Santos anticipate that any of these induced fractures will reach these nearby wells (especially NDB-46 and NDB-048)? Please provide details. If not, how closely will the induced fractures approach these wells? What mitigation measures will Santos have in place should any of the induced fractures reach one of the offset wells or the fractures induced in those wells? How will these measures be communicated with the onsite workers? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Leahy, Scott (Scott) <Scott.Leahy@santos.com> Sent: Tuesday, March 25, 2025 6:19 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty) <Ty.Senden@santos.com> Subject: NDBi-049 Frac Sundry Steve/ Chris, In the NDBi-049 frac sundry, I did not include the mechanical condition of the NDBi-050 or NDBi-050PB wells. These two wells were not drilled when I submitted the Sundry, and I didn’t realize they would be in the ½ mile radius. Please see the attached files that show the location for NDBi-050 (NDBi-050PB is near the NDBi-050 trajectory path), along with the mechanical condition of both NDBi-050PB/ NDBi- 050. In addition, you should receive notification in the next few days of the tubing and IA being pressure tested as outlined in the Sundry. Additionally, Ty and I would like to come by your office this week (Wednesday or Thursday) to discuss the NDB-048 Sundry. There are points about this well that are unique which we feel would be easier to explain in person. I submitted the Sundry request for NDB-048 on 2/20/25. Scott Leahy – Completions SpecialistOil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Ave Anchorage, Alaska 99501 m: +1 (907) 330-4595 Scott.Leahy@santos.com https://www.santos.com/ Santos Ltd A.B.N. 80 007 550 923Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are notthe 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 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20894-00-00Well Name/No.PIKKA NDBi-049 Completion Status WAGINCompletion Date 12/10/2024 Permit to Drill 2241190 Operator Oil Search (Alaska), LLC MD 19302 TVD 4071 Current Status WAGIN 4/8/2025 UIC Yes Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:GR-RES-NEU-DEN-Sonic NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 1/9/2025################Electronic Data Set, Filename: NDBi- 049_AP_R01_RM.las 39945ED Digital Data DF 1/9/2025################Electronic Data Set, Filename: NDBi- 049_AP_R02_RM.las 39945ED Digital Data DF 1/9/2025################Electronic Data Set, Filename: NDBi- 049_AP_R03_RM.las 39945ED Digital Data DF 1/9/2025100 19302 Electronic Data Set, Filename: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft.l as 39945ED Digital Data DF 1/9/202512000 19300 Electronic Data Set, Filename: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_R03_BR OOH.las 39945ED Digital Data DF 1/9/2025100 19302 Electronic Data Set, Filename: NDBi- 049_DMD_RM_19302ft.las 39945ED Digital Data DF 1/9/2025################Electronic Data Set, Filename: NDBi- 049_DMT_R01_RM.las 39945ED Digital Data DF 1/9/2025################Electronic Data Set, Filename: NDBi- 049_DMT_R02_RM.las 39945ED Digital Data DF 1/9/2025################Electronic Data Set, Filename: NDBi- 049_DMT_R03_RM.las 39945ED Digital Data DF 1/9/20259074 11571 Electronic Data Set, Filename: NDBi- 049_LWD_SDTK_CBL_9074-11564.las 39945ED Digital Data DF 1/9/20259074 11571 Electronic Data Set, Filename: NDBi- 049_LWD_SDTK_TOC_9074-11564.las 39945ED Digital Data DF 1/9/202511496 19301 Electronic Data Set, Filename: NDBi- 049_LWD_MED_Resistivity_RM_19302.las 39945ED Digital Data Tuesday, April 8, 2025AOGCC Page 1 of 5 NDBi-, 049_DMD_RM_19302ft.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20894-00-00Well Name/No.PIKKA NDBi-049 Completion Status WAGINCompletion Date 12/10/2024 Permit to Drill 2241190 Operator Oil Search (Alaska), LLC MD 19302 TVD 4071 Current Status WAGIN 4/8/2025 UIC Yes DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_TOC_9074-11564.dlis 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_TOC_9074-11564.PDF 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_TOC_9074-11564_dlis.txt 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 2MD.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 2TVD.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 5MD.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 5TVD.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049_AP_RM.cgm39945EDDigital Data DF 1/9/2025 Electronic File: NDBi- 049_DMD_RM_19302ft.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049_DMT_RM.cgm39945EDDigital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 2MD.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 2TVD.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 5MD.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_ 5TVD.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 Definitive Compass Survey Report - NAD27.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 Definitive Compass Survey Report - NAD83.pdf 39945ED Digital Data Tuesday, April 8, 2025AOGCC Page 2 of 5 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20894-00-00Well Name/No.PIKKA NDBi-049 Completion Status WAGINCompletion Date 12/10/2024 Permit to Drill 2241190 Operator Oil Search (Alaska), LLC MD 19302 TVD 4071 Current Status WAGIN 4/8/2025 UIC Yes DF 1/9/2025 Electronic File: NDBi-049 Definitive Survey - NAD27.txt 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 Definitive Survey - NAD83.txt 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 Definitive Survey Report.xlsx 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 Plan View.pdf39945EDDigital Data DF 1/9/2025 Electronic File: NDBi-049 Vertical Section View.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_9_625_Liner_Baker_Hughes_CBL_Final Report.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_CBL_9074-11564.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_CBL_9074-11564.dlis 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_CBL_9074-11564.PDF 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_CBL_9074-11564_dlis.txt 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_SDTK_TOC_9074-11564.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049_AP_RM.pdf39945EDDigital Data DF 1/9/2025 Electronic File: NDBi-049_DMD_RM_19302ft.pdf39945EDDigital Data DF 1/9/2025 Electronic File: NDBi-049_DMT_RM.pdf39945EDDigital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_MED_Resisitivity_19302ft_2MD&5MD. cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_MED_Resisitivity_19302ft_2TVD&5TV D.cgm 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 MED Resistivity_19302ft_2MD&5MD.emf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049 MED Resistivity_19302ft_2TVD&5TVD.emf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi-049_STS_Image.dlis39945EDDigital Data Tuesday, April 8, 2025AOGCC Page 3 of 5 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20894-00-00Well Name/No.PIKKA NDBi-049 Completion Status WAGINCompletion Date 12/10/2024 Permit to Drill 2241190 Operator Oil Search (Alaska), LLC MD 19302 TVD 4071 Current Status WAGIN 4/8/2025 UIC Yes Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:12/10/2024 Release Date:10/25/2024 DF 1/9/2025 Electronic File: NDBi-049_STS_Image.ver39945EDDigital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_MED_Resisitivity_19302ft_2MD&5MD. pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_MED_Resisitivity_19302ft_2TVD&5TV D.pdf 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_MED_Resisitivity_19302ft_2MD&5MD. tif 39945ED Digital Data DF 1/9/2025 Electronic File: NDBi- 049_LWD_MED_Resisitivity_19302ft_2TVD&5TV D.tif 39945ED Digital Data DF 1/9/2025 Electronic File: NoMudlogServices.txt39945EDDigital Data Tuesday, April 8, 2025AOGCC Page 4 of 5 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20894-00-00Well Name/No.PIKKA NDBi-049 Completion Status WAGINCompletion Date 12/10/2024 Permit to Drill 2241190 Operator Oil Search (Alaska), LLC MD 19302 TVD 4071 Current Status WAGIN 4/8/2025 UIC Yes Compliance Reviewed By:Date: Tuesday, April 8, 2025AOGCC Page 5 of 5 M.Guhl 4/8/2025 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 NDBi-049 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): 19,302' 4,071' 19,177' 4,095' 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 03/01/25 19,177'7,739' 4-1/2" 12.6ppf 4,095' See attached packer report 2,476' 9,163' 11,479' Perforation Depth MD (ft): 2,476' 11,479' 4-1/2" 3,791' 2,608' 11,639' 4-1/2" 128' 20"x34" 13-3/8" 9-5/8" 2,608' Tieback MD 6870 5020 6870 2,269' 3,830' 2,195' Length Size Proposed Pools: 128' 128' P-110S TVD Burst 11,479' 11590 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 392984, 391445, 393023, 393022, 393021, 392958 224-119 601 W 5th Avenue, Suite 600, Anchorage, AK 99501 50-103-20894-00-00 Oil Search Alaska, LLC AOGCC USE ONLY 11590 Tubing Grade: Tubing MD (ft): See attached packer report Perforation Depth TVD (ft): 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 written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY 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 ions Specialist 01/23/2025 By Grace Christianson at 8:32 am, Jan 23, 2025 325-027 CDW 01/30/2025 DSR-1/31/25 10-404 03/01/25 SFD 2/12/2025BJM 2/20/25 Fracture Stimulate *&: 2/21/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.21 11:53:10 -09'00' RBDMS JSB 022525 Page 1 of 1 Packer Set Depths - NDBi-049 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Original Hole SLZXP Liner Top Hanger Packer w/centralizer 11,459.5 3,789.2 Original Hole HES Zoneguard OH Packer #12 13,274.9 4,153.3 Original Hole HES Zoneguard OH Packer #11 13,383.2 4,161.2 Original Hole HES Zoneguard OH Packer #10 14,007.9 4,171.3 Original Hole HES Zoneguard OH Packer #9 14,548.2 4,167.5 Original Hole HES Zoneguard OH Packer #8 15,128.3 4,162.3 Original Hole HES Zoneguard OH Packer #7 15,708.6 4,157.4 Original Hole HES Zoneguard OH Packer #6 16,332.5 4,152.9 Original Hole HES Zoneguard OH Packer #5 16,871.8 4,149.4 Original Hole HES Zoneguard OH Packer #4 17,454.6 4,145.1 Original Hole HES Zoneguard OH Packer #3 18,027.2 4,140.2 Original Hole HES Zoneguard OH Packer #2 18,648.7 4,135.2 Original Hole HES Zoneguard OH Packer #1 18,984.6 4,121.4 Page 1 of 19 NDBi-049 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 NBDi-049. At the NDBi-049 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 NDBi-049 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 962 feet (ft) total vertical depth subsea (TVDSS)/ 962 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: 962 to 2,379 ft TVDSS/1,417 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: 2,379 to 3,157 ft TVDSS/ 778 ft thick Hydrocarbon Zone: 2,442 to 3,157 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: 3,157 to 3,743 ft TVDSS/ 586 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: 3,743 to 4,697 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: 4,697 to 5,596 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 1-10 3,800 4,100 8,500 7,800 9,200 8,800 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 –Qugruk 3A, Qugruk 3, NDB-051, NDBi-046, and NDB-048 are within 1/2-mile radius of NDBi-049. Please see Attachment B as reference. 12.Suspected fault or fracture that may transect the confining zones: One known fault described as being a low confidence fault that has less than 20’ of throw and could also be a stratigraphic feature. The fault as mapped on seismic tips out within the Nanushuk formation- covered by the Seabee, the upper confining layer. 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 18,833 4,131 251 452 40 7,202 8 2 18,334 4,138 242 477 40 7,013 8 3 17,755 4,143 243 488 40 6,810 8 4 17,177 4,147 235 455 40 6,856 10 5 16,598 4,151 244 365 40 6,612 10 6 16,014 4,155 244 357 40 6,418 10 7 15,432 4,160 247 359 40 6,194 10 8 14,853 4,165 244 357 40 5,979 10 9 14,272 4,170 243 360 40 5,802 11 10 13,732 4,173 247 324 40 5,551 10 7,202 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 601 W 5th Avenue Anchorage, Alaska 99501 (T) +1 907 375 4642 —santos.com 1/2 January 16, 2025 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 NDBi-049 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 NDBi-049 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 601 W 5th Ave Anchorage, AK 99501 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 NDBi-049 well trajectory and fracture stimulation. Please contact Tim Jones should you require additional information. Sincerely, Jacob Owens Commercial Analyst Distribution List: Alaska Division of Oil and Gas Arctic Slope Regional Corp. Kuukpik Corp. Oil Search (Alaska), LLC Repsol E&P USA LLC ConocoPhillips Alaska, Inc. Sincerely, 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 601 W 5th Ave Anchorage, AK 99501 Repsol E&P USA LLC CERTIFIED MAIL 2455 Technology Forest Blvd. The Woodlands, TX 77381 ConocoPhillips Alaska, Inc. CERTIFIED MAIL Attn: Land Manager PO Box 100360 Anchorage AK 99510 ADL 392977 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 17.22% DNR - 82.78% ADL 392991 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.58% DNR - 58.42%ADL 392985Surface Owners: KuukpikOIL SEARCH - 51%, REPSOL - 49%SUBS.OWNERS:ASRC - 49.84% DNR - 50.16%ADL 392984Surface Owners: KuukpikOIL SEARCH - 51%, REPSOL - 49%SUBS.OWNERS:ASRC - 50% DNR - 50%ADL 392958 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 36.31% DNR - 63.69% ADL 392970 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 40.29% DNR - 59.71% 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 393018 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 29.67% DNR - 70.33% ADL 393020 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 26.59% DNR - 73.41% ADL Surface Ow OIL SEARCH - 5 SUBS.O ASRC - 31.69 ADL 393016Surface Owners: KuukpikOIL 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% ADL 391455 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 46.4% DNR - 53.6% U012N006E29 U011N006E04 U012N006E32 U011N006E05 U012N006E33 U012N005E25 U012N U012N005E36 U011N005E01 U011N005E12 U011N006E09 U011N006E08 U012N006E31 U011N006E06 U012N006E30 U011N006E07 OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD TARGET BOTTOM HOLE SURFACE LOCATION WELL TRAJECTORY .5-MILE BUFFER SANTOS LEASES SECTIONS DATE: 1/14/2025. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-PE-M_NDBi49_well_ownership GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDBi49 WELL AREA Attachment B WELL NAME STATUS Casing Size Top 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 By Reservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity Q3A Abandoned Open Hole 4678 (Nanushuk) 4192' (Nanushuk)4678' 4177' Tag TOC set down 15k with DP. Open Hole Abandonment Plug TOC 4,177' MD • The 8-1/2” open hole section was abandoned with two open hole plugs: 1st plug (open hole plug): An open hole balanced cement plug was attempted to be laid in the well from 10,420’ MD by pumping a 136 bbls of 15.8 ppg cement. Cement was pumped with full returns, but while laying in the balanced plug in the well the string including the drill pipe and 4-1/2” 2,000’ 12.6 ppf tubing stinger became stuck at 10,383’ MD. The pipe was severed at 6,243’ MD. TOC was estimated to be at 8,003’ MD in the annulus and 8,650’ MD inside the drill pipe. 2.) 2nd plug (open hole balanced plug): A second open hole balanced plug was placed in the well by circulating 73 bbls of 15.8 ppg class G cement into the hole at 4950’ MD. TOC was confirmed at 4,177’ MD by tagging and placing 15k WOB several times Well is fully abandoned. Q3 Abandoned Open Hole 3875 3502 3502 Tag TOC with DP.Open Hole Abandonment Plug TOC 3502' MD The 12-1/4" open hole section was abandoned with 4 open hole plugs. Kuparuk C 6750' - 6753' MD, Alpine 6970' - 7230' MD Cement Plug #1: Pump mud push, 120 bbls 15. 8 ppg Class G cement for open hole plug# 1. POOH to 6624' and circulate drill pipe clean. Pick up drill pipe while WOC. Tag plug at 6852', with 14,000 lbs. Tag witnessed by Bob Noble. Plug at 7,500' MD - 6,852' MD, Cement Plug #2A: Pump mud push, 115 bbls 15. 8 ppg Class G cement for open hole plug# 2.Tag plug at 4216', with 10,000 lbs. Tag witnessed by Bob Noble. plug #2 4,581' MD - 4,216' MD. Plug #2 didn't meet regulations. Mixed up a second one. Cement Plug #2B: Pump mud push, 100 bbls 17 ppg Class G. Tag plug at 3,502' MD. Tag witnessed by Louis Grimaldi. Plug #2A 4,216' MD - 3,502' MD. Cement Plug #3: Pump mud push, 108 bbls 17 ppg Class G cement for bottom kick off plug. POOH to 2275. Cement plug #3 Kick off plug 3,144' - 2,507' MD Cement Plug #4: Pump mud push, 88 bbls 15. 7 ppg AS1 cement for top kick off plug. Cement plug #4 top kick off plug 2,255 - 1,735' MD The Q3A sidetrack wellbore was then kicked off by washing through soft cement and kicking off of cement plug #3 at 2708' MD. The Q3A well was then drilled and abandoned per the AOGCC Regulations. Well is fully abandoned. NDB-051 ACTIVE 9-5/8" 47ppf 10,178 (Nanushuk) 3,740 (Nanushuk) 9,250 3,514 log open hole liner for production TOC 9,250' & packer @11,378' 9-5/8” x 13-3/8” Primary cement job Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A - (65 gallons each) downhole at 2.9-3 bpm, 93% returns. -Release bottom pump down plug for bottom plug, chase with 15.3 ppg Versacem Tail Cement Type I/II at 2.9-3 bpm, Excess Volume 30% (839 sacks, yield 1.237 cu.ft/sk), initial circulating pressure 440 psi. -Added 300 lbs of Halliburton Bridgemaker II LCM to cement: 10 bbls neat cement ahead, 60 bbls with LCM added, 115 bbls of neat cement. - Land dart at 69 bbls away at 2.9 bpm at latch (1.5 bbls behind as calculated), clear indication of latch and release at 1000 psi. -Continue to chase with 15.3 ppg Versacem Tail Cement Type I/II, pump total of 185 bbls at average of 2.9 bpm, 235-400 psi, excess volume 30% (839 sacks, yield 1.237 cu ft/sk). -Release top pump down plug, chase with 20 bbls of washup from Halliburton. -Perform displacement with rig pumps, displace with 11.8 ppg OBM at 2.5 bpm, ICP 272 psi 1% return flow, FCP 600 psi 7% return flow. -Top pump down dart latch up confirmed at 45 bbls displaced. -Continue to displace with 11.8 ppg OBM, reduce rate to 2.5 bpm prior to plug bump: Final circulating pressure 600 psi. -Total displacement volume 656 bbls (measured by strokes at 96% pump efficiency). -Total losses from cement exit shoe to cement in place: 52 bbls w/4 bbls bleed back. 06/11/24, 9-5/8" casing pressure tested to 3640 psi for 30 minutes NDBi-046 ACTIVE 9-5/8" 47ppf 11,166' (Nanushuk) 3,733' (Nanushuk) 10255 3,615 log open hole liner for production TOC 10,255' & packer @ 12,572' 9-5/8” x 13-3/8” Primary cement job - Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol at 3.7-4 bpm, release bottom pump down plug for bottom plug, chase with 15.3 ppg Versacem Tail Cement Type I/II, pump total of 197 bbls at 4 bpm, release top pump down plug, chase with 20 bbls of water from Halliburton. Perform displacement with rig pumps, displace with 11.8 ppg OBM at 4 bpm, ICP 395 psi 8% flow, FCP 596 psi, 2% return flow, reduce rate to 3 bpm prior to plug bump: Final circulating pressure 596 psi. pressured up 500 psi over FCP 1,080 psi. Held 5 min, bled off checked floats. Floats held. CIP @ 12:45 hrs. - Total losses from cement exit shoe to cement in place: 43 bbls. Cement Evaluation Results: TOC was found to be 911’ above the Top of the Nanushuk Pool (11,166’ MD) at 10,255’ MD. Cement isolation from the TOC down to the casing show was found to be in good quality ranging down to partial coverage in limited areas. 07/11/24, 9-5/8" casing pressure tested to 3,667 psi for 30 minutes NDB-048 ACTIVE 9-5/8" 47ppf 12,044' (Nanushuk) 3,733' (Nanushuk) 10,908'3,574'Log open hole liner for production TOC 12,044 MD' & Packer @ 11,989 MD' First stage of cement job: Pump 82 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A downhole at 3 bpm, ~0% returns. Release bottom pump down plug for bottom plug, pump 153 bbls 15.3 ppg Versacem Tail Cement Type I/II (681 sacks, yield 1.237 cu ft/sk – 1st 20 bbls Neat and last 40 bbls Neat without Bridgemaker II LCM), excess volume 30%, at 3.5 bpm, average circulating pressure 330 psi. ~5% returns throughout cement pumping. Release top pump down plug, chase plug with displacement by rig pumps, displace with 11.5 ppg OBM at 3.5 bpm, ICP 200 psi. Average ~0% returns during displacement. Bottom plug landed on calculated strokes at 3.5 bpm, 520 psi circ pressure, shear with drop in circulating pressure to 493 psi and maintain 3.5 bpm as cemenexits shoe. Circulating pressure with cement turning shoe 493 ICP at 3.5 bpm. Reduce rate to 3.0 bpm, 455 psi circ. pressure to reduce ECD. Maintain 3 bpm to plug bump, FCP 500 psi; ~0% returns with cement around shoe. Bump plug, hold for 5 minutes, to check floats, floats held, Observations for the 1st stage of the cement job: There is adequate isolation of the 9-5/8” shoe in the Top Nanushuk and good isolation in the lower Seabee formation based on the CBL log. While losses were encountered during the liner run and subsequent cement job, the CBL log indicates good cement isolation to the picked TOC at 10,908’ MD. The CBL indicates good quality cement from 12,066’ to 10,908’, with poor to no cement from 10,908’ to 9,825’ MD. 12/31/24, 9-5/8" casing pressure tested to 3,755 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: 2,608’ MD x 9-5/8” x 13-3/8” Liner top: 2,476’ MD x 9-5/8” Liner Shoe: 11,639 MD x 9-5/8” Archer Cflex Mechanical Stage tool: 5,337’ MD Geology x Top of Tuluvak TS 790 formation at 5,234 MD. Significant hydrocarbons are contained only within the upper Tuluvak in the Tuluvak Sand (3,245 MD). x Top of the Nanushuk picked at 11,560 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 above the top of the Nanushuk formation. This is supported by the CBL log, which indicates good cement throughout the first stage with a TOC at 10,400’ MD (1160’ MD / 223’ TVD above top Nanushuk). -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 the top of the Nanushuk formation 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 - NDBi-049 Surface Casing Cement Surface Casing Cement, Casing, 11/15/2024 08:00 Type Casing Cementing Start Date 11/15/2024 Cementing End Date 11/15/2024 Wellbore Original Hole String Surface Casing, 2,608.3ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results 47 bbls clean cement returned to surface. Comment Cement 13-3/8” Surface Casing as follows: -Fill lines with 5 water and pressure test to 3,500 psi for 5 minutes -Drop 1st Bottom Non-Rotating Plug -Pump 80 bbls of 10.5 ppg Tuned Spacer at 5.0 bpm, 200 psi. -Release 2nd Bottom Non-Rotating Plug -Pump 364 bbls of 11.0 ppg ArcticCem lead cement at 4 bpm, Excess Volume 150% (806 sacks, yield 2.535 cu.ft/sk) -Pump 65 bbls of 15.3 ppg Type I/II tail at 4 bpm, Excess Volume 50% (312 sacks, yield 1.24 cu.ft/sk) -Drop top plug and chase with 2 bbls Tail Cement -Perform displacement with rig pumps and 9.5 ppg mud -300 bbls displaced at 8 bpm: ICP 440 psi 17% return flow, FCP 750 psi -40 bbls displaced at 6 bpm: ICP 600 psi, FCP 662 psi. -Reduce rate to 3 bpm prior to plug bump: Final circulating pressure 510 psi prior to plug bump. -Bump plug and increase pressure to 1,050 psi, check floats – good. -Total displacement volume 353 bbls (measured by strokes at 96% pump efficiency). -Observed 113 bbls of interface (mud/mud push/cement contaminated) returns and 47 bbls clean cement to surface. A total of 175 bbls were dumped to the cuttings box. -Total losses from cement exit shoe to cement in place: 0 bbls 1, 0.0-2,618.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 2,618.0 Full Return? Yes Vol Cement Ret (bbl) 47.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 5 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 662.0 Plug Bump Pressure (psi) 510.0 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 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 (%) 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) 806 Class ArcticCem Volume Pumped (bbl) 364.0 Estimated Top (ftKB) 2,618.0 Percent Excess Pumped (%) 150.0 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) 65.0 Estimated Top (ftKB) 2,618.0 Percent Excess Pumped (%) 50.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.68 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 24.8 Thickening Time (hr) 4.50 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 11.50 Page 1 of 1 Cement - NDBi-049 Intermediate Casing Cement - 1st Stage Intermediate Casing Cement - 1st Stage, Casing, 11/27/2024 08:00 Type Casing Cementing Start Date 11/27/2024 Cementing End Date 11/27/2024 Wellbore Original Hole String Intermediate Liner, 11,639.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Baker Soundtrack LWD Cement Evaluation Results Comment Conduct 1st Stage Cement Job of 9-5/8” 47# L-80 Hyd 563 Intermediate Liner. - Fluid pack lines, pressure test to 5000 psi. - Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A downhole at 3 bpm, ~50% returns. - Release bottom pump down plug for bottom plug, pump 109 bbls 15.3 ppg Versacem Tail Cement Type I/II (493 sacks, yield 1.237 cu ft/sk – 1st 10 bbls Neat and last 39 bbls Neat without Bridgemaker II LCM), excess volume 30%, at 3 bpm, average circulating pressure 300 psi. ~40% returns throughout cement pumping. - Release top pump down plug, chase plug with displacement by rig pumps, displace with 11.5 ppg OBM at 3 bpm, ICP 80 psi. Aver age ~37% returns during displacement. - Bottom plug landed on calculated strokes at 3 bpm, 310 psi circ pressure, shear with drop in circulating pressure to 265 psi and maintain 3 bpm as cement exits shoe. - Circulating pressure with cement turning shoe 280 ICP. - Maintain 3 bpm to plug bump, FCP 407 psi; ~41% returns with cement around shoe. - Bump plug, hold for 5 minutes, to check floats, floats held, CIP 1500 hrs. - Total displacement volume 705 bbls (measured by strokes at 96% pump efficiency). - Total surface returns losses from cement exit shoe to cement in place: 88 bbls (rig team estimation is that final lift press ure and consistent return rate suggests full cement placement across interval with loss zone higher in formation). * Note: Report of release of coolant into containment from cementing unit coolant overfill reservoir. Notifications made, Spill Tech reports <1 cup into containment, possibly 1 teaspoon to ground observed. Spill Tech cleaned up. 1, 10,219.0-11,644.0ftKB Top Depth (ftKB) 10,219.0 Bottom Depth (ftKB) 11,644.0 Full Return? No Vol Cement Ret (bbl) Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 2 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 3 Final Pump Pressure (psi) 407.0 Plug Bump Pressure (psi) 1,225.0 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 w/4# Red Dye, 65 gal Surfactant B & Musol A 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) Time of 1st Compressive Strength Test (hr) Tail Fluid Type Tail Fluid Description Versacem Tail (Type 1/2) w/5lb/bbl Bridgemaker II LCM Amount (sacks) 493 Class Type I/II Volume Pumped (bbl) 109.0 Estimated Top (ftKB) 8,400.0 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) 7.10 1st Compressive Strength (psi) 500.0 Time of 1st Compressive Strength Test (hr) 12.51 Page 1 of 1 Cement - NDBi-049 Intermediate Casing Cement - 2nd stage Intermediate Casing Cement - 2nd stage, Casing, 11/28/2024 02:00 Type Casing Cementing Start Date 11/28/2024 Cementing End Date 11/28/2024 Wellbore Original Hole String Intermediate Liner, 11,639.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results 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 3 bpm, ICP 266 psi, FCP 134 psi, 0 bbls lost during this phase. -Mix and pump 80 bbls of 13.5 Tuned Spacer at 3 bpm, ICP 151 psi. FCP 160 psi. Full returns no losses. -Mix and pump 310 bbls of 15.3 ppg. Versacem Type I/II Tail cement at 4.0 bpm, ICP 212 psi, FCP 454 psi, 6 bbls lost lost durin g this phase. -Excess Volume 100% (1417 sacks, yield 1.236 cu ft/sk). -Begin displacing with 2 bbls fresh water from cementing unit. -Continue to displace with 117 bbls 11.5 ppg OBM using rig pumps. -Displace to calculated volume of 117 bbls to Archer Stage Collar. -Displace at 4 bpm, 109 psi ICP, 482 FCP before slowing rate, 100% returns; FCP at 3 bpm 389 psi. -42 bbls lost during displacement. -CIP at 05:00 hrs. 2, 2,475.0-5,333.0ftKB Top Depth (ftKB) 2,475.0 Bottom Depth (ftKB) 5,333.0 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) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 389.0 Plug Bump Pressure (psi) 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 Mix and pump 80 bbls of 12.5 ppg Mud Flush at 3 bpm, ICP 266 psi, FCP 134 psi 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 (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Time of 1st Compressive Strength Test (hr) Spacer Fluid Type Spacer Fluid Description Mix and pump 80 bbls of 13.5 Tuned Spacer at 3 bpm, ICP 151 psi. FCP 160 psi, 0 bbls lost during spacer pumping. 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 (%) Density (lb/gal) 13.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Time of 1st Compressive Strength Test (hr) Tail Fluid Type Tail Fluid Description Versacem (Type 1/2) Amount (sacks) 1,410 Class Type I/II Volume Pumped (bbl) 310.0 Estimated Top (ftKB) Percent Excess Pumped (%) 100.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) Density (lb/gal) 15.30 Plastic Viscosity (cP) 131.8 Thickening Time (hr) 6.65 1st Compressive Strength (psi) 500.0 Time of 1st Compressive Strength Test (hr) 18.43 Attachment D Attachment E Attachment F Well Name NDBi-049 01/20/25 Preliminary Design STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL) a FP b FP c WF 26 3.5 40 40 1680 1680 40 40 d Pump Check WF 26 40 300 340 12600 14280 300 340 0 340 eDFIT XL 26 40 200 540 8400 22680 200 540 f WF 26 40 290 830 12180 34860 290 830 0830 0830 PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUM STAGE AVERAGE FLUID RATE STAGE CUM TOT JOB STAGE CUM STAGE CUM Size or Stage Cum #PPA TYPE (BPM)(BBL)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)Type (BBL)(BBL) 1 0 Line out XL XL 26 21 40 40 580 1680 36540 00 40870 2 0 Drop Stage 1 Ball/Collet FP 0 21 3 43 583 126 36666 0016/20-CL 3873 3 0 Stage 1 PAD XL 26 40 256 299 839 10752 47418 00 2561129 4 0 Slow for Seat XL 26 18 50 349 889 2100 49518 0 0 50 1179 5 0 Resume Pad XL 26 40 44 393 933 1848 51366 0 0 44 1223 6 1 Flat XL 26 40 160 553 1093 6720 58086 6435 6435 16/20-CL 153 1376 7 2 Flat XL 26 40 160 713 1253 6720 64806 12347 18783 16/20-CL 147 1523 8 3 Flat XL 26 40 180 893 1433 7560 72366 20022 38805 16/20-CL 159 1682 9 4 Flat XL 26 40 180 1073 1613 7560 79926 25693 64497 16/20-CL 153 1835 10 5 Flat XL 26 40 180 1253 1793 7560 87486 30952 95450 16/20-CL 147 1982 11 6 Flat XL 26 40 180 1433 1973 7560 95046 35844 131293 16/20-CL 142 2125 12 7 Flat XL 26 40 160 1593 2133 6720 101766 35916 167209 16/20-CL 122 2247 13 8 Flat XL 26 40 140 1733 2273 5880 107646 34742 201951 16/20-CL 103 2350 14 0 Clear Surface Lines XL 26 40 15 1748 2288 630 108276 0201951 152365 15 0 Spacer XL 26 40 15 1763 2303 630 108906 0201951 152380 16 0 Drop Stage 2 Ball/Collet FP 0 40 3 1766 2306 126 109032 0 201951 3 2383 17 0 Stage 2 PAD XL 26 40 249 2015 2555 10458 119490 0 201951 249 2632 18 0 Slow for Seat XL 26 18 50 2065 2605 2100 121590 0201951 502682 19 0 Resume Pad XL 26 40 51 2116 2656 2142 123732 0201951 512733 20 1 Flat XL 26 40 160 2276 2816 6720 130452 6435 208386 16/20-CL 153 2886 21 2 Flat XL 26 40 160 2436 2976 6720 137172 12347 220734 16/20-CL 147 3033 22 3 Flat XL 26 40 180 2616 3156 7560 144732 20022 240756 16/20-CL 159 3192 23 4 Flat XL 26 40 180 2796 3336 7560 152292 25693 266449 16/20-CL 153 3345 24 5 Flat XL 26 40 180 2976 3516 7560 159852 30952 297401 16/20-CL 147 3493 25 6 Flat XL 26 40 180 3156 3696 7560 167412 35844 333245 16/20-CL 142 3635 26 7 Flat XL 26 40 160 3316 3856 6720 174132 35916 369160 16/20-CL 122 3757 27 8 Flat XL 26 40 140 3456 3996 5880 180012 34742 403902 16/20-CL 103 3860 28 0 Clear Surface Lines XL 26 40 15 3471 4011 630 180642 0403902 153875 29 0 Spacer XL 26 40 15 3486 4026 630 181272 0403902 153890 30 0 Drop Stage 3 Ball/Collet FP 0 40 3 3489 4029 126 181398 0 403902 3 3893 31 0 Stage 3 PAD XL 26 40 240 3729 4269 10080 191478 0 403902 240 4133 FLUID Neat Water COMMENTS SD monitor 20 min Prime and Pressure Test Open well and open initiator sleeve Displace PT - Shut down 5 min SD monitor 1H, line up for XL Load Stage 1 ball/collet, DFIT Dispacement to P-Sleeve Well Name NDBi-049 01/20/25 Preliminary Design STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL) FLUID Neat Water 32 0 Slow for Seat XL 26 18 50 3779 4319 2100 193578 0403902 504183 33 0 Resume Pad XL 26 40 60 3839 4379 2520 196098 0403902 604243 34 1 Flat XL 26 40 180 4019 4559 7560 203658 7240 411142 16/20-CL 172 4416 35 2 Flat XL 26 40 180 4199 4739 7560 211218 13891 425033 16/20-CL 165 4581 36 3 Flat XL 26 40 200 4399 4939 8400 219618 22247 447280 16/20-CL 177 4758 37 4 Flat XL 26 40 200 4599 5139 8400 228018 28547 475827 16/20-CL 170 4928 38 5 Flat XL 26 40 200 4799 5339 8400 236418 34391 510218 16/20-CL 164 5091 39 6 Flat XL 26 40 200 4999 5539 8400 244818 39827 550045 16/20-CL 158 5250 40 7 Flat XL 26 40 187 5186 5726 7854 252672 41976 592021 16/20-CL 143 5392 41 8 Flat XL 26 40 170 5356 5896 7140 259812 42187 634208 16/20-CL 126 5518 42 0 Clear Surface Lines XL 26 40 15 5371 5911 630 260442 0634208 155533 43 0 Spacer XL 26 40 15 5386 5926 630 261072 0634208 155548 44 0 Drop Stage 4 Ball/Collet FP 0 40 3 5389 5929 126 261198 0 634208 3 5551 45 0 Stage 4 PAD XL 26 40 231 5620 6160 9702 270900 0 634208 231 5782 46 0 Slow for Seat XL 26 18 50 5670 6210 2100 273000 0634208 505832 47 0 Resume Pad XL 26 40 19 5689 6229 798 273798 0634208 195851 48 1 Flat XL 26 40 195 5884 6424 8190 281988 7843 642051 16/20-CL 187 6038 49 2 Flat XL 26 40 215 6099 6639 9030 291018 16592 658643 16/20-CL 198 6235 50 4 Flat XL 26 40 250 6349 6889 10500 301518 35684 694327 16/20-CL 212 6448 51 6 Flat XL 26 40 250 6599 7139 10500 312018 49783 744110 16/20-CL 198 6645 52 8 Flat XL 26 40 235 6834 7374 9870 321888 58317 802427 16/20-CL 174 6819 53 10 Flat XL 26 40 210 7044 7584 8820 330708 61145 863572 16/20-CL 146 6964 54 0 Clear Surface Lines XL 26 40 15 7059 7599 630 331338 0863572 156979 55 0 Spacer XL 26 40 15 7074 7614 630 331968 0863572 156994 56 0 Drop Stage 5 Ball/Collet FP 0 40 3 7077 7617 126 332094 0 863572 3 6997 57 0 Stage 5 PAD XL 26 40 222 7299 7839 9324 341418 0 863572 222 7219 58 0 Slow for Seat XL 26 18 50 7349 7889 2100 343518 0863572 507269 59 0 Resume Pad XL 26 40 28 7377 7917 1176 344694 0863572 287297 60 1 Flat XL 26 40 190 7567 8107 7980 352674 7642 871213 16/20-CL 182 7479 61 2 Flat XL 26 40 220 7787 8327 9240 361914 16978 888191 16/20-CL 202 7681 62 4 Flat XL 26 40 240 8027 8567 10080 371994 34257 922448 16/20-CL 204 7885 63 6 Flat XL 26 40 240 8267 8807 10080 382074 47792 970240 16/20-CL 190 8075 64 8 Flat XL 26 40 240 8507 9047 10080 392154 59558 1029797 16/20-CL 177 8252 65 10 Flat XL 26 40 200 8707 9247 8400 400554 58233 1088031 16/20-CL 139 8391 66 0 Clear Surface Lines XL 26 40 15 8722 9262 630 401184 0 1088031 15 8406 67 0 Spacer XL 26 40 15 8737 9277 630 401814 0 1088031 15 8421 68 0 Drop Stage 6 Ball/Collet FP 0 40 3 8740 9280 126 401940 0 1088031 3 8424 69 0 Stage 6 PAD XL 26 40 213 8953 9493 8946 410886 0 1088031 213 8637 70 0 Slow for Seat XL 26 18 50 9003 9543 2100 412986 0 1088031 50 8687 71 0 Resume Pad XL 26 40 17 9020 9560 714 413700 0 1088031 17 8704 72 1 Flat XL 26 40 190 9210 9750 7980 421680 7642 1095672 16/20-CL 182 8886 73 3 Flat XL 26 40 215 9425 9965 9030 430710 23915 1119588 16/20-CL 190 9075 74 5 Flat XL 26 40 240 9665 10205 10080 440790 41270 1160857 16/20-CL 197 9272 Well Name NDBi-049 01/20/25 Preliminary Design STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL) FLUID Neat Water 75 7 Flat XL 26 40 240 9905 10445 10080 450870 53874 1214731 16/20-CL 183 9455 76 9 Flat XL 26 40 220 10125 10665 9240 460110 59475 1274206 16/20-CL 157 9613 77 10 Flat XL 26 40 190 10315 10855 7980 468090 55321 1329528 16/20-CL 132 9744 78 0 Clear Surface Lines XL 26 40 15 10330 10870 630 468720 0 1329528 15 9759 79 0 Spacer XL 26 40 15 10345 10885 630 469350 0 1329528 15 9774 80 0 Drop Stage 7 Ball/Collet FP 0 40 3 10348 10888 126 469476 0 1329528 3 9777 81 0 LG Flush WF 26 40 196 10544 11084 8232 477708 0 1329528 196 9973 82 0 Slow for seat WF 26 18 50 10594 11134 2100 479808 0 1329528 50 10023 83 0 Overflush/ MT PCM WF 26 40 200 10794 11334 8400 488208 0 1329528 200 10223 84 Linear Flush WF 26 20 1 10795 11335 42 488250 110224 85 Linear Flush WF 26 20 1 10796 11336 42 488292 110225 86 3000 feet MD + Surface Eqmt FP 20 58 10854 11394 2423 490715 TOTALS 11684 490715 1329528 Well Name NDBi-049 01/20/25 Preliminary Design STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL) a FP b WF 26 3.5 40 40 1680 1680 40 40 0 0 c Pump Ball to Seat WF 26 4 235 275 9870 11550 235 275 d Pump Check WF 26 40 100 375 4200 15750 100 375 0375 0375 PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUM STAGE AVERAGE FLUID RATE STAGE CUM TOT JOB STAGE CUM STAGE CUM Size or Stage Cum #PPA TYPE (BPM)(BBL)(BBL)(BBL)(GAL)(GAL)(LBS)(LBS)Type (BBL)(BBL) 1 0 Line out XL XL 26 40 40 40 415 1680 17430 00 40415 2 0 Stage 7 PAD XL 26 40 280 320 695 11760 29190 0016/20-CL 280 695 3 1 Flat XL 26 40 190 510 885 7980 37170 7642 7642 16/20-CL 182 877 4 3 Flat XL 26 40 215 725 1100 9030 46200 23915 31557 16/20-CL 190 1067 5 5 Flat XL 26 40 240 965 1340 10080 56280 41270 72827 16/20-CL 197 1263 6 7 Flat XL 26 40 240 1205 1580 10080 66360 53874 126700 16/20-CL 183 1447 7 9 Flat XL 26 40 220 1425 1800 9240 75600 59475 186176 16/20-CL 157 1604 8 10 Flat XL 26 40 190 1615 1990 7980 83580 55321 241497 16/20-CL 132 1736 9 0 Clear Surface Lines XL 26 40 15 1630 2005 630 84210 0241497 151751 10 0 Spacer XL 26 40 15 1645 2020 630 84840 0241497 151766 11 0 Drop Ball/Collet #8 FP 0 40 3 1648 2023 126 84966 0 241497 3 1769 12 0 Stage 8 PAD XL 26 40 195 1843 2218 8190 93156 0 241497 195 1964 13 0 Slow for Seat XL 26 18 50 1893 2268 2100 95256 0241497 502014 14 0 Resume Pad XL 26 40 35 1928 2303 1470 96726 0241497 352049 15 1 Flat XL 26 40 190 2118 2493 7980 104706 7642 249139 16/20-CL 182 2231 16 3 Flat XL 26 40 215 2333 2708 9030 113736 23915 273054 16/20-CL 190 2420 17 5 Flat XL 26 40 240 2573 2948 10080 123816 41270 314324 16/20-CL 197 2617 18 7 Flat XL 26 40 240 2813 3188 10080 133896 53874 368197 16/20-CL 183 2800 19 9 Flat XL 26 40 220 3033 3408 9240 143136 59475 427673 16/20-CL 157 2957 20 10 Flat XL 26 40 190 3223 3598 7980 151116 55321 482994 16/20-CL 132 3089 21 0 Clear Surface Lines XL 26 40 15 3238 3613 630 151746 0482994 153104 22 0 Spacer XL 26 40 15 3253 3628 630 152376 0482994 153119 23 0 Drop Ball/Collet #9 FP 0 40 3 3256 3631 126 152502 0 482994 3 3122 24 0 Stage 9 PAD XL 26 40 187 3443 3818 7854 160356 0 482994 187 3309 25 0 Slow for Seat XL 26 18 50 3493 3868 2100 162456 0482994 503359 26 0 Resume Pad XL 26 40 43 3536 3911 1806 164262 0482994 433402 27 1 Flat XL 26 40 190 3726 4101 7980 172242 7642 490636 16/20-CL 182 3584 28 3 Flat XL 26 40 215 3941 4316 9030 181272 23915 514551 16/20-CL 190 3774 29 5 Flat XL 26 40 240 4181 4556 10080 191352 41270 555821 16/20-CL 197 3970 30 7 Flat XL 26 40 240 4421 4796 10080 201432 53874 609694 16/20-CL 183 4154 31 9 Flat XL 26 40 220 4641 5016 9240 210672 59475 669170 16/20-CL 157 4311 32 11 Flat XL 26 40 195 4836 5211 8190 218862 60596 729766 16/20-CL 131 4442 33 0 Clear Surface Lines XL 26 40 15 4851 5226 630 219492 0729766 154457 FLUID Neat Water COMMENTS Prime and Pressure Test Displace PT - Shut down 10 min Drop Ball-SD 10 minutes Load ball/collet#6 (Stage 7), Stage to Line out XL Well Name NDBi-049 01/20/25 Preliminary Design STAGE COMMENTS PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT #TYPE PPT RATE STAGE CUM STAGE CUM STAGE CUM SIZE Stage Cum Pre Frac - Non Proppant stages (BPM) (BBL) (BBL)(GAL) (GAL)(LBS) (LBS) (BBL) (BBL) FLUID Neat Water 34 0 Spacer XL 26 40 15 4866 5241 630 220122 0729766 154472 35 0 Drop Ball/Collet #10 FP 0 40 3 4869 5244 126 220248 0 729766 3 4475 36 0 Stage 10 PAD XL 26 40 179 5048 5423 7518 227766 0 729766 179 4654 37 0 Slow for Seat XL 26 18 50 5098 5473 2100 229866 0729766 504704 38 0 Resume Pad XL 26 40 1 5099 5474 42 229908 0 729766 1 4705 39 1 Scour XL 26 40 60 5159 5534 2520 232428 2413 732179 16/20-CL 57 4763 40 3 Scour XL 26 40 120 5279 5654 5040 237468 13348 745527 16/20-CL 106 4869 41 0 Resume Pad XL 26 40 50 5329 5704 2100 239568 0745527 504919 42 1 Flat XL 26 40 215 5544 5919 9030 248598 8647 754174 16/20-CL 206 5124 43 2 Flat XL 26 40 235 5779 6154 9870 258468 18135 772310 16/20-CL 216 5340 44 4 Flat XL 26 40 260 6039 6414 10920 269388 37112 809421 16/20-CL 221 5561 45 6 Flat XL 26 40 260 6299 6674 10920 280308 51775 861196 16/20-CL 205 5767 46 8 Flat XL 26 40 240 6539 6914 10080 290388 59558 920753 16/20-CL 177 5944 47 10 Flat XL 26 40 210 6749 7124 8820 299208 61145 981898 16/20-CL 146 6090 48 XLFlush XL 26 40 20 6769 7144 840 300048 20 6110 49 LG Flush WF 26 40 129 6898 7273 5418 305466 129 6239 50 3000 feet MD + Surface Eqmt FP 20 58 6956 7331 2423 307889 TOTALS 7291 307889 981898 Additive Additive Description F103 Surfactant 1.0 Gal/mGal 689.1 gal J450 Stabilizing Agent 0.5 Gal/mGal 344.5 gal J475 Breaker J475 6.0 lb/mGal 4,134.3 lbm J511 Stabilizing Agent 2.0 lb/mGal 1,378.1 lbm J532 Crosslinker 2.2 Gal/mGal 1,548.3 gal J580 Gel J580 26.0 lb/mGal 17,915.4 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 34.5 gal M117 Clay Control Agent 339.0 lb/mGal 233,577.0 lbm M275 Bactericide 0.3 lb/mGal 206.7 lbm S522-1620 Propping Agent varied concentrations 2,295,538.0 lbm S522-4070 Propping Agent varied concentrations 15,762.0 lbm ~ 68 % ~ 28 % ~ 3 % < 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 % < 0.001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.00001 % 100 % 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 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. 14808-60-7 Quartz, Crystalline silica 532-32-1 Sodium benzoate 64-19-7 Acetic acid (impurity) 127-08-2 Acetic acid, potassium salt (impurity) 9000-90-2 Amylase, alpha 14464-46-1 Cristobalite 111-42-2 2,2'-Iminodiethanol 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 7786-30-3 Magnesium chloride 14807-96-6 Magnesium silicate hydrate (talc) 9002-84-0 poly(tetrafluoroethylene) 10377-60-3 Magnesium nitrate 91053-39-3 Diatomaceous earth, calcined 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 25038-72-6 Vinylidene chloride/methylacrylate copolymer 68131-39-5 Ethoxylated Alcohol 9025-56-3 Hemicellulase 67-63-0 Propan-2-ol 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 56-81-5 1, 2, 3 - Propanetriol 1303-96-4 Sodium tetraborate decahydrate 50-70-4 Sorbitol 7647-14-5 Sodium chloride 102-71-6 2,2`,2"-nitrilotriethanol 7727-54-0 Diammonium peroxodisulphate 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)* YF126 ST:WF126 689,052 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-1984 Fluid Name & Volume Concentration Volume Disclosure Type:Pre-Job Well Completed: Date Prepared:1/21/2025 State:Alaska County/Parish:North Slope Borough Case: Client:Oil Search Alaska Well:NDBi-049 Basin/Field:Pikka # SLB-Private Page: 1 / 1 Updated 01/30/2025 INPUT TBD AK TSCA Status North Slope AK TBD PRE - job TBD 73.00000% TBD - post job Trade Name Supplier Purpose Ingredients Name CAS # Percentage by Mass of Ingredient Percent of Ingredient in Total Mass Pumped Mass of Ingredient (lbs) SME Tracerco Carrier Fluid Soy Methyl Ester 67784-80-9 100 #VALUE!69.6659920000 T-168A Tracerco Chemical Tracer 1-Chloro-4-iodobenzene 637-87-6 100 #VALUE!0.4409240000 T-168B Tracerco Chemical Tracer 1,2-Dichloro-4-iodobenzene 20555-91-3 100 #VALUE!0.4409240000 T-165D Tracerco Chemical Tracer 4-Iodobiphenyl 1591-31-7 100 #VALUE!0.4409240000 T-784 Tracerco Chemical Tracer 2,4,6-Tribromoanisole 607-99-8 100 #VALUE!0.4409240000 T-769 Tracerco Chemical Tracer 4-Fluorobenzophenone 345-83-5 100 #VALUE!1.1023100000 T-712 Tracerco Chemical Tracer 1,2,3-Trichlorobenzene 87-61-6 100 #VALUE!2.2046200000 T-163B Tracerco Chemical Tracer 1,2-Diiodobenzene 615-42-9 100 #VALUE!0.4409240000 T-718 Tracerco Chemical Tracer 4-Chlorobenzophenone 134-85-0 100 #VALUE!0.6613860000 T-169C Tracerco Chemical Tracer 2,4-Dibromomesitylene 6942-99-0 100 #VALUE!0.8818480000 T-163A Tracerco Chemical Tracer 1,4-Diiodobenze 624-38-4 100 #VALUE!0.4409240000 Water Tracerco Carrier Fluid Water 7732-18-5 100 #VALUE!74.6900708680 T-257a Tracerco Chemical Tracer Sodium-3,5-di(Trifluoromethyl)benzoate 87441-96-1 100 #VALUE!0.8024816800 T-805 Tracerco Chemical Tracer Sodium-2,4-Dichlorobenzoate 38402-11-8 100 #VALUE!0.7848447200 T-806 Tracerco Chemical Tracer Sodium-2,5-dichlorobenzoate 63891-98-5 100 #VALUE!0.7923404280 T-158d Tracerco Chemical Tracer Sodium-3,4-Difluorobenzoate 522651-44-1 100 #VALUE!0.8062295340 T-176a Tracerco Chemical Tracer Sodium-2,3,4-trifluorobenzoate 402955-41-3 100 #VALUE!0.7738216200 T-804 Tracerco Chemical Tracer Sodium-2,3-dichlorobenzoate 118537-84-1 100 #VALUE!0.7738216200 T-190b Tracerco Chemical Tracer Sodium-3-(Trifluoromethyl) benzoate 69226-41-1 100 #VALUE!0.7738216200 T-803 Tracerco Chemical Tracer Sodium-4-chlorobenzoate 3686-66-6 100 #VALUE!0.7738216200 T-190c Tracerco Chemical Tracer Sodium-4-(Trifluoromethyl) benzoate 25832-58-0 100 #VALUE!0.7738216200 T-801 Tracerco Chemical Tracer Sodium-2-chlorobenzoate 17264-74-3 100 #VALUE!0.7738216200 Sodium Fluorescein Tracerco Chemical Tracer Sodium Fluorescein 518-47-8 100 #VALUE!1.5432340000 Rhodamine WT Tracerco Chemical Tracer Rhodamine WT 37299-86-8 100 #VALUE!0.7716170000 Report Type (Pre or Post Job) Total Water Volume (gal): Water Mass Fraction Total Mass Pumped (lbs) County: API Number: Operator Name: Santos AK Well Name and Number: NDBi-049 Hydraulic Fracturing Fluid Product Component Information Disclosure Manufacturer Contact Tracerco 4106 New West Dr. Pasadena Texas 77507 Tel: 281-291-7769 Fracture Date State:Approved For Tracerco Updated 01-17-2025 INPUT TBD AK TSCA Status NorthSlope AK TBD Pre 73.00000% Trade Name Supplier Purpose Ingredients Name CAS # Percentage by Mass of Ingredient Percent of Ingredient in Total Mass Pumped Mass of Ingredient (lbs) SME Tracerco Carrier Fluid Soy Methyl Ester 67784-80-9 100 #DIV/0!68.7841440000 T-168A Tracerco Chemical Tracer 1-Chloro-4-iodobenzene 637-87-6 100 #DIV/0!0.4409240000 T-168B Tracerco Chemical Tracer 1,2-Dichloro-4-iodobenzene 20555-91-3 100 #DIV/0!0.4409240000 T-716 Tracerco Chemical Tracer 1,3,5-Tribromobenzene 626-39-1 100 #DIV/0!0.4409240000 T-784 Tracerco Chemical Tracer 2,4,6-Tribromoanisole 607-99-8 100 #DIV/0!0.4409240000 T-769 Tracerco Chemical Tracer 4-Fluorobenzophenone 345-83-5 100 #DIV/0!1.1023100000 T-712 Tracerco Chemical Tracer 1,2,3-Trichlorobenzene 87-61-6 100 #DIV/0!2.2046200000 T-163B Tracerco Chemical Tracer 1,2-Diiodobenzene 615-42-9 100 #DIV/0!0.4409240000 T-718 Tracerco Chemical Tracer 4-Chlorobenzophenone 134-85-0 100 #DIV/0!0.6613860000 T-169C Tracerco Chemical Tracer 2,4-Dibromomesitylene 6942-99-0 100 #DIV/0!0.8818480000 T-163B Tracerco Chemical Tracer 1,2-Diiodobenzene 615-42-9 100 #DIV/0!0.4409240000 Water Tracerco Carrier Fluid Water 7732-18-5 100 #DIV/0!73.3036150000 T-930 Tracerco Chemical Tracer Sodium-3-fluoro-4-methylbenzoate 1805805-74-6 100 #DIV/0!0.7716170000 T-950 Tracerco Chemical Tracer Sodium-2-fluoro-3-(Trifluoromethyl)-benzoate 1701446-41-4 100 #DIV/0!0.7716170000 T-912 Tracerco Chemical Tracer Sodium-2-chloro-5-fluorobenzoate 1382106-79-7 100 #DIV/0!0.7716170000 T-140C Tracerco Chemical Tracer Sodium-4-Fluorobenzoate 499-90-1 100 #DIV/0!0.7716170000 T-176A Tracerco Chemical Tracer Sodium-2,3,4-trifluorobenzoate 402955-41-3 100 #DIV/0!0.7716170000 T-804 Tracerco Chemical Tracer Sodium-2,3-dichlorobenzoate 118537-84-1 100 #DIV/0!0.7716170000 T-158F Tracerco Chemical Tracer Sodium-2,3-Difluorobenzoate 1604819-08-0 100 #DIV/0!0.7716170000 T-803 Tracerco Chemical Tracer Sodium-4-chlorobenzoate 3686-66-6 100 #DIV/0!0.7716170000 T-158A Tracerco Chemical Tracer Sodium-2,4-Difluorobenzoate 1765-08-8 100 #DIV/0!0.7716170000 T-801 Tracerco Chemical Tracer Sodium-2-chlorobenzoate 17264-74-3 100 #DIV/0!0.7716170000 Sodium Fluorescein Tracerco Chemical Tracer Sodium Fluorescein 518-47-8 100 #DIV/0!1.5432340000 Rhodamine WT Tracerco Chemical Tracer Rhodamine WT 37299-86-8 100 #DIV/0!0.7716170000 Hydraulic Fracturing Fluid Product Component Information Disclosure Manufacturer Contact Tracerco 4106 New West Dr. Pasadena Texas 77507 Tel: 281-291-7769 Fracture Date State:Approved For Tracerco County: API Number: Operator Name: Santos AK Well Name and Number: NDBi-049 Report Type (Pre or Post Job) Total Water Volume (gal): Water Mass Fraction Total Mass Pumped (lbs) Superseded Attachment G NDBi-049 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 NDBi-049 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 9.2 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. NDBi-049 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 5,500 psi (Estimated time to Psi test, end of Feb 2025)) a. (8,800 psi MAWP – 3,800 psi IA hold) * 1.1 = 5,500 psi 4. MIT-IA to 4,000 psi. (Post drilling rig move, MIT-IA to be tested to 4,300 psi (Estimated time to Psi test, end of Feb 2025)) 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 NDBi-049 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 :NDBi-049 Field :Pikka Formation :Nanushuk Stages 1 to 10 County : North Slope State : Alaska Country : United States Prepared for : Scott Leahy Service Point : Prudhoe Bay, Alaska Business Phone : 1 907 659 2434 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 Date Prepared : 01-22-2025 Section 1: Zone Data (Stage 1; 18833 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 4051.5 10.0 0.72 2937 1.46E+06 0.220 2500 Shale 4061.5 15.0 0.70 2828 1.76E+06 0.220 2500 Nanushuk 3 SS 4076.5 15.3 0.68 2769 1.90E+06 0.220 2000 Top Nan 4091.8 6.0 0.64 2630 8.39E+05 0.270 1000 Shale 4097.8 2.0 0.70 2858 2.67E+06 0.230 2500 Nan DS 4099.8 1.5 0.63 2584 8.19E+05 0.270 1500 Nan DS 4101.3 2.0 0.64 2615 1.22E+06 0.260 1500 Nan CS 4103.3 13.0 0.62 2562 8.69E+05 0.270 1000 Nan CS 4116.3 1.5 0.61 2524 1.00E+06 0.270 1000 Nan CS 4117.8 4.0 0.64 2630 7.07E+05 0.280 1000 Nan CS 4121.8 9.0 0.61 2505 1.17E+06 0.270 1000 Nan CS 4130.8 7.0 0.64 2659 7.69E+05 0.270 1000 Nan CS 4137.8 5.5 0.61 2543 1.28E+06 0.260 1000 Nan CS 4143.3 13.0 0.64 2665 6.92E+05 0.280 1000 Nan DS 4156.3 2.5 0.68 2817 1.75E+06 0.260 1500 Nan DS 4158.8 12.5 0.64 2649 1.11E+06 0.270 1500 Nan DS 4171.3 4.0 0.69 2891 1.69E+06 0.260 1500 Nan DS 4175.3 2.5 0.64 2675 8.22E+05 0.270 1500 Shale 4177.8 2.0 0.70 2913 2.67E+06 0.230 2500 Nan DS 4179.8 4.0 0.65 2710 1.16E+06 0.270 1500 Nan DS 4183.8 4.0 0.63 2624 8.38E+05 0.270 1000 Shale 4187.8 4.0 0.70 2921 2.67E+06 0.230 2500 Nan DS 4191.8 6.0 0.64 2682 1.13E+06 0.270 1500 Shale 4197.8 2.0 0.70 2927 2.67E+06 0.230 2500 Nan DS 4199.8 2.0 0.62 2614 1.08E+06 0.270 1500 Nan DS 4201.8 6.5 0.66 2781 1.69E+06 0.260 1500 Nan DS 4208.3 4.0 0.61 2576 8.99E+05 0.270 1500 Nan DS 4212.3 3.5 0.64 2711 9.29E+05 0.270 1500 Shale 4215.8 2.0 0.70 2939 2.67E+06 0.230 2500 Nan DS 4217.8 12.5 0.64 2698 1.56E+06 0.260 1500 Nan DS 4230.3 2.0 0.65 2747 1.40E+06 0.260 1500 Shale 4232.3 2.0 0.70 2951 2.67E+06 0.230 2500 Nan DS 4234.3 2.0 0.65 2757 1.24E+06 0.260 1500 Shale 4236.3 8.0 0.69 2922 2.67E+06 0.230 2500 Nan DS 4244.3 2.0 0.63 2690 9.33E+05 0.270 1500 Shale 4246.3 4.0 0.70 2961 2.67E+06 0.230 2500 Nan DS 4250.3 6.0 0.65 2748 1.43E+06 0.260 1500 Shale 4256.3 8.0 0.70 2969 2.67E+06 0.230 2500 Nan DS 4264.3 6.5 0.65 2766 1.47E+06 0.260 1500 Shale 4270.8 6.0 0.69 2945 2.67E+06 0.230 2500 Nan DS 4276.8 2.0 0.64 2726 8.38E+05 0.270 1000 Shale 4278.8 2.0 0.70 2983 2.67E+06 0.230 2500 Nan DS 4280.8 4.0 0.65 2784 1.47E+06 0.260 1500 Shale 4284.8 2.0 0.70 2987 2.67E+06 0.230 2500 Nan DS 4286.8 6.0 0.66 2849 1.55E+06 0.260 1500 Shale 4292.8 12.0 0.70 2996 2.67E+06 0.230 2500 Nan DS 4304.8 2.5 0.64 2754 1.21E+06 0.270 1500 Shale 4307.3 20.0 0.69 2975 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) 4051.5 10.0 0.001 1.0 1881 4061.5 15.0 0.001 1.0 1886 4076.5 15.3 0.005 10.0 1890 4091.8 6.0 56.445 22.0 1882 4097.8 2.0 0.001 1.0 1884 4099.8 1.5 109.347 15.0 1885 4101.3 2.0 4.377 15.0 1886 4103.3 13.0 42.829 22.0 1887 4116.3 1.5 11.097 22.0 1893 4117.8 4.0 91.857 22.0 1894 4121.8 9.0 4.906 22.0 1896 4130.8 7.0 12.361 22.0 1900 4137.8 5.5 2.537 22.0 1903 4143.3 13.0 61.847 22.0 1906 4156.3 2.5 0.081 15.0 1912 4158.8 12.5 22.858 15.0 1913 4171.3 4.0 0.018 15.0 1919 4175.3 2.5 94.329 15.0 1920 4177.8 2.0 0.001 1.0 1922 4179.8 4.0 45.186 15.0 1922 4183.8 4.0 24.865 15.0 1924 4187.8 4.0 0.001 1.0 1926 4191.8 6.0 6.405 15.0 1928 4197.8 2.0 0.001 1.0 1931 4199.8 2.0 13.686 15.0 1932 4201.8 6.5 0.229 15.0 1933 4208.3 4.0 49.420 15.0 1936 4212.3 3.5 63.759 15.0 1938 4215.8 2.0 0.001 1.0 1939 4217.8 12.5 1.337 15.0 1940 4230.3 2.0 1.843 15.0 1946 4232.3 2.0 0.001 1.0 1947 4234.3 2.0 4.320 15.0 1948 4236.3 8.0 0.001 1.0 1949 4244.3 2.0 91.060 15.0 1952 4246.3 4.0 0.001 1.0 1953 4250.3 6.0 4.551 15.0 1955 4256.3 8.0 0.001 1.0 1958 4264.3 6.5 7.953 15.0 1962 4270.8 6.0 0.001 1.0 1965 4276.8 2.0 24.687 15.0 1967 4278.8 2.0 0.001 1.0 1968 4280.8 4.0 2.159 10.0 1969 4284.8 2.0 0.001 1.0 1971 4286.8 6.0 1.534 10.0 1972 4292.8 12.0 0.001 1.0 1975 4304.8 2.5 5.632 10.0 1980 4307.3 20.0 0.001 1.0 1982 Nan DS Nan DS Shale Nan CS Nan CS Nan CS Nan CS Nan CS Nan CS Zone Name Formation Transmissibility Properties Shale Shale Nanushuk 3 SS Top Nan Shale Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Shale Nan DS Shale Nan DS Shale 3 SLB Private Attachment K Section 2: Propped Fracture Schedule (Stage 1; 18833 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 14700.0 26 0 1.0 PPA 40 YF126ST 6435.4 26 1 2.0 PPA 40 YF126ST 6174.0 26 2 3.0 PPA 40 YF126ST 6674.6 26 3 4.0 PPA 40 YF126ST 6423.8 26 4 5.0 PPA 40 YF126ST 6191.2 26 5 6.0 PPA 40 YF126ST 5974.9 26 6 7.0 PPA 40 YF126ST 5131.7 26 7 8.0 PPA 40 YF126ST 4343.6 26 8 Flush 40 YF126ST 12049.5 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,764.3 bbl of YF126ST 0 bbl of WF126 201978 lb of % PAD Clean 23.7 % PAD Dirty 20.7 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 14700.0 14700 350 350 0 0 4643 8.8 8.8 1.0 PPA 6435.4 21135 160 510 6435 6435 4662 4.0 12.8 2.0 PPA 6174.0 27309 160 670 12348 18783 4725 4.0 16.8 3.0 PPA 6674.6 33984 180 850 20024 38807 5046 4.5 21.3 4.0 PPA 6423.8 40408 180 1030 25695 64503 5541 4.5 25.8 5.0 PPA 6191.2 46599 180 1210 30956 95459 5973 4.5 30.3 6.0 PPA 5974.9 52574 180 1390 35849 131308 6396 4.5 34.8 7.0 PPA 5131.7 57706 160 1550 35922 167230 6754 4.0 38.8 8.0 PPA 4343.6 62049 140 1690 34748 201978 7013 3.5 42.3 Flush 12049.5 74099 287 1977 0 201978 6347 7.2 49.4 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 451.9 ft with an average conductivity (Kfw) of 9808.6 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Pad Percentages Job Execution Step Name Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Proppant Totals Carbolite 16/20 4 SLB Private Attachment K 7013 Section 3: Propped Fracture Simulation (Stage 1; 18333 ft MD) Initial Fracture Top TVD 4048.9 ft Initial Fracture Bottom TVD 4299.6 ft Propped Fracture Half-Length 451.9 ft EOJ Hyd Height at Well 250.7 ft Average Propped Width 0.115 in Net Pressure 234 psi Max Surface Pressure 7202 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) 0 113 7.3 0.131 117.6 1.12 279.3 11734 113 226 5.2 0.126 176.2 1.11 301.6 10863 226 338.9 3.9 0.116 162.9 1.04 324.2 9873 338.9 451.9 1.6 0.092 130.5 0.85 322.1 7462 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 5 SLB Private Attachment K 7202 Section 4: Zone Data (Stage 2; 18334 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 4051.5 10.0 0.72 2937 1.46E+06 0.220 2500 Shale 4061.5 15.0 0.70 2828 1.76E+06 0.220 2500 Nanushuk 3 SS 4076.5 15.3 0.68 2769 1.90E+06 0.220 2000 Top Nan 4091.8 6.0 0.64 2630 8.39E+05 0.270 1000 Shale 4097.8 2.0 0.70 2858 2.67E+06 0.230 2500 Nan DS 4099.8 1.5 0.63 2584 8.19E+05 0.270 1500 Nan DS 4101.3 2.0 0.64 2615 1.22E+06 0.260 1500 Nan CS 4103.3 13.0 0.62 2562 8.69E+05 0.270 1000 Nan CS 4116.3 1.5 0.61 2524 1.00E+06 0.270 1000 Nan CS 4117.8 4.0 0.64 2630 7.07E+05 0.280 1000 Nan CS 4121.8 9.0 0.61 2505 1.17E+06 0.270 1000 Nan CS 4130.8 7.0 0.64 2659 7.69E+05 0.270 1000 Nan CS 4137.8 5.5 0.61 2543 1.28E+06 0.260 1000 Nan CS 4143.3 13.0 0.64 2665 6.92E+05 0.280 1000 Nan DS 4156.3 2.5 0.68 2817 1.75E+06 0.260 1500 Nan DS 4158.8 12.5 0.64 2649 1.11E+06 0.270 1500 Nan DS 4171.3 4.0 0.69 2891 1.69E+06 0.260 1500 Nan DS 4175.3 2.5 0.64 2675 8.22E+05 0.270 1500 Shale 4177.8 2.0 0.70 2913 2.67E+06 0.230 2500 Nan DS 4179.8 4.0 0.65 2710 1.16E+06 0.270 1500 Nan DS 4183.8 4.0 0.63 2624 8.38E+05 0.270 1000 Shale 4187.8 4.0 0.70 2921 2.67E+06 0.230 2500 Nan DS 4191.8 6.0 0.64 2682 1.13E+06 0.270 1500 Shale 4197.8 2.0 0.70 2927 2.67E+06 0.230 2500 Nan DS 4199.8 2.0 0.62 2614 1.08E+06 0.270 1500 Nan DS 4201.8 6.5 0.66 2781 1.69E+06 0.260 1500 Nan DS 4208.3 4.0 0.61 2576 8.99E+05 0.270 1500 Nan DS 4212.3 3.5 0.64 2711 9.29E+05 0.270 1500 Shale 4215.8 2.0 0.70 2939 2.67E+06 0.230 2500 Nan DS 4217.8 12.5 0.64 2698 1.56E+06 0.260 1500 Nan DS 4230.3 2.0 0.65 2747 1.40E+06 0.260 1500 Shale 4232.3 2.0 0.70 2951 2.67E+06 0.230 2500 Nan DS 4234.3 2.0 0.65 2757 1.24E+06 0.260 1500 Shale 4236.3 8.0 0.69 2922 2.67E+06 0.230 2500 Nan DS 4244.3 2.0 0.63 2690 9.33E+05 0.270 1500 Shale 4246.3 4.0 0.70 2961 2.67E+06 0.230 2500 Nan DS 4250.3 6.0 0.65 2748 1.43E+06 0.260 1500 Shale 4256.3 8.0 0.70 2969 2.67E+06 0.230 2500 Nan DS 4264.3 6.5 0.65 2766 1.47E+06 0.260 1500 Shale 4270.8 6.0 0.69 2945 2.67E+06 0.230 2500 Nan DS 4276.8 2.0 0.64 2726 8.38E+05 0.270 1000 Shale 4278.8 2.0 0.70 2983 2.67E+06 0.230 2500 Nan DS 4280.8 4.0 0.65 2784 1.47E+06 0.260 1500 Shale 4284.8 2.0 0.70 2987 2.67E+06 0.230 2500 Nan DS 4286.8 6.0 0.66 2849 1.55E+06 0.260 1500 Shale 4292.8 12.0 0.70 2996 2.67E+06 0.230 2500 Nan DS 4304.8 2.5 0.64 2754 1.21E+06 0.270 1500 Shale 4307.3 20.0 0.69 2975 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) 4051.5 10.0 0.001 1.0 1881 4061.5 15.0 0.001 1.0 1886 4076.5 15.3 0.005 10.0 1890 4091.8 6.0 56.445 22.0 1882 4097.8 2.0 0.001 1.0 1884 4099.8 1.5 109.347 15.0 1885 4101.3 2.0 4.377 15.0 1886 4103.3 13.0 42.829 22.0 1887 4116.3 1.5 11.097 22.0 1893 4117.8 4.0 91.857 22.0 1894 4121.8 9.0 4.906 22.0 1896 4130.8 7.0 12.361 22.0 1900 4137.8 5.5 2.537 22.0 1903 4143.3 13.0 61.847 22.0 1906 4156.3 2.5 0.081 15.0 1912 4158.8 12.5 22.858 15.0 1913 4171.3 4.0 0.018 15.0 1919 4175.3 2.5 94.329 15.0 1920 4177.8 2.0 0.001 1.0 1922 4179.8 4.0 45.186 15.0 1922 4183.8 4.0 24.865 15.0 1924 4187.8 4.0 0.001 1.0 1926 4191.8 6.0 6.405 15.0 1928 4197.8 2.0 0.001 1.0 1931 4199.8 2.0 13.686 15.0 1932 4201.8 6.5 0.229 15.0 1933 4208.3 4.0 49.420 15.0 1936 4212.3 3.5 63.759 15.0 1938 4215.8 2.0 0.001 1.0 1939 4217.8 12.5 1.337 15.0 1940 4230.3 2.0 1.843 15.0 1946 4232.3 2.0 0.001 1.0 1947 4234.3 2.0 4.320 15.0 1948 4236.3 8.0 0.001 1.0 1949 4244.3 2.0 91.060 15.0 1952 4246.3 4.0 0.001 1.0 1953 4250.3 6.0 4.551 15.0 1955 4256.3 8.0 0.001 1.0 1958 4264.3 6.5 7.953 15.0 1962 4270.8 6.0 0.001 1.0 1965 4276.8 2.0 24.687 15.0 1967 4278.8 2.0 0.001 1.0 1968 4280.8 4.0 2.159 10.0 1969 4284.8 2.0 0.001 1.0 1971 4286.8 6.0 1.534 10.0 1972 4292.8 12.0 0.001 1.0 1975 4304.8 2.5 5.632 10.0 1980 4307.3 20.0 0.001 1.0 1982 Nan CS Formation Transmissibility Properties Zone Name Shale Shale Nanushuk 3 SS Top Nan Shale Nan DS Nan DS Nan CS Nan DS Nan CS Nan CS Nan CS Nan CS Nan CS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Shale Nan DS Shale 7 SLB Private Attachment K Section 5: Propped Fracture Schedule (Stage 2; 18334 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 14700.0 26 0 1.0 PPA 40 YF126ST 6435.4 26 1 2.0 PPA 40 YF126ST 6174.0 26 2 3.0 PPA 40 YF126ST 6674.6 26 3 4.0 PPA 40 YF126ST 6423.8 26 4 5.0 PPA 40 YF126ST 6191.2 26 5 6.0 PPA 40 YF126ST 5974.9 26 6 7.0 PPA 40 YF126ST 5131.7 26 7 8.0 PPA 40 YF126ST 4343.6 26 8 Flush 40 YF126ST 11730.2 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,756.7 bbl of YF126ST 0 bbl of WF126 201978 lb of % PAD Clean 23.7 % PAD Dirty 20.7 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 14700.0 14700 350 350 0 0 4549 8.8 8.8 1.0 PPA 6435.4 21135 160 510 6435 6435 4565 4.0 12.8 2.0 PPA 6174.0 27309 160 670 12348 18783 4647 4.0 16.8 3.0 PPA 6674.6 33984 180 850 20024 38807 4967 4.5 21.3 4.0 PPA 6423.8 40408 180 1030 25695 64503 5404 4.5 25.8 5.0 PPA 6191.2 46599 180 1210 30956 95459 5823 4.5 30.3 6.0 PPA 5974.9 52574 180 1390 35849 131308 6230 4.5 34.8 7.0 PPA 5131.7 57706 160 1550 35922 167230 6578 4.0 38.8 8.0 PPA 4343.6 62049 140 1690 34748 201978 6828 3.5 42.3 Flush 11730.2 73779 279 1969 0 201978 6216 7.0 49.2 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 476.9 ft with an average conductivity (Kfw) of 10395.1 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 8 SLB Private Attachment K Section 6: Propped Fracture Simulation (Stage 2; 18334 ft MD) Initial Fracture Top TVD 4052.1 ft Initial Fracture Bottom TVD 4294.4 ft Propped Fracture Half-Length 476.9 ft EOJ Hyd Height at Well 242.3 ft Average Propped Width 0.122 in Net Pressure 353 psi Max Surface Pressure 7013 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) 0 119.2 7 0.145 114 1.24 255.3 13108 119.2 238.5 5 0.131 181.2 1.15 298.9 11374 238.5 357.7 3.9 0.118 163.8 1.03 333.8 9970 357.7 476.9 2 0.103 119.8 0.98 361.3 8486 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; 17755 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 4054.5 10.0 0.72 2937 1.46E+06 0.220 2500 Shale 4064.5 15.0 0.70 2830 1.76E+06 0.220 2500 Nanushuk 3 SS 4079.5 15.3 0.68 2771 1.90E+06 0.220 2000 Top Nan 4094.8 6.0 0.64 2630 8.39E+05 0.270 1000 Shale 4100.8 2.0 0.70 2858 2.67E+06 0.230 2500 Nan DS 4102.8 1.5 0.63 2584 8.19E+05 0.270 1500 Nan DS 4104.3 2.0 0.64 2615 1.22E+06 0.260 1500 Nan CS 4106.3 13.0 0.62 2562 8.69E+05 0.270 1000 Nan CS 4119.3 1.5 0.61 2526 1.00E+06 0.270 1000 Nan CS 4120.8 4.0 0.64 2630 7.07E+05 0.280 1000 Nan CS 4124.8 9.0 0.61 2506 1.17E+06 0.270 1000 Nan CS 4133.8 7.0 0.64 2659 7.69E+05 0.270 1000 Nan CS 4140.8 5.5 0.61 2543 1.28E+06 0.260 1000 Nan CS 4146.3 13.0 0.64 2665 6.92E+05 0.280 1000 Nan DS 4159.3 2.5 0.68 2817 1.75E+06 0.260 1500 Nan DS 4161.8 12.5 0.64 2651 1.11E+06 0.270 1500 Nan DS 4174.3 4.0 0.69 2891 1.69E+06 0.260 1500 Nan DS 4178.3 2.5 0.64 2675 8.22E+05 0.270 1500 Shale 4180.8 2.0 0.70 2915 2.67E+06 0.230 2500 Nan DS 4182.8 4.0 0.65 2712 1.16E+06 0.270 1500 Nan DS 4186.8 4.0 0.63 2626 8.38E+05 0.270 1000 Shale 4190.8 4.0 0.70 2921 2.67E+06 0.230 2500 Nan DS 4194.8 6.0 0.64 2682 1.13E+06 0.270 1500 Shale 4200.8 2.0 0.70 2929 2.67E+06 0.230 2500 Nan DS 4202.8 2.0 0.62 2614 1.08E+06 0.270 1500 Nan DS 4204.8 6.5 0.66 2781 1.69E+06 0.260 1500 Nan DS 4211.3 4.0 0.61 2576 8.99E+05 0.270 1500 Nan DS 4215.3 3.5 0.64 2711 9.29E+05 0.270 1500 Shale 4218.8 2.0 0.70 2941 2.67E+06 0.230 2500 Nan DS 4220.8 12.5 0.64 2698 1.56E+06 0.260 1500 Nan DS 4233.3 2.0 0.65 2747 1.40E+06 0.260 1500 Shale 4235.3 2.0 0.70 2953 2.67E+06 0.230 2500 Nan DS 4237.3 2.0 0.65 2759 1.24E+06 0.260 1500 Shale 4239.3 8.0 0.69 2924 2.67E+06 0.230 2500 Nan DS 4247.3 2.0 0.63 2690 9.33E+05 0.270 1500 Shale 4249.3 4.0 0.70 2963 2.67E+06 0.230 2500 Nan DS 4253.3 6.0 0.65 2750 1.43E+06 0.260 1500 Shale 4259.3 8.0 0.70 2972 2.67E+06 0.230 2500 Nan DS 4267.3 6.5 0.65 2766 1.47E+06 0.260 1500 Shale 4273.8 6.0 0.69 2947 2.67E+06 0.230 2500 Nan DS 4279.8 2.0 0.64 2726 8.38E+05 0.270 1000 Shale 4281.8 2.0 0.70 2985 2.67E+06 0.230 2500 Nan DS 4283.8 4.0 0.65 2786 1.47E+06 0.260 1500 Shale 4287.8 2.0 0.70 2989 2.67E+06 0.230 2500 Nan DS 4289.8 6.0 0.66 2849 1.55E+06 0.260 1500 Shale 4295.8 12.0 0.70 2998 2.67E+06 0.230 2500 Nan DS 4307.8 2.5 0.64 2754 1.21E+06 0.270 1500 Shale 4310.3 20.0 0.69 2977 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) 4054.5 10.0 0.001 1.0 1881 4064.5 15.0 0.001 1.0 1886 4079.5 15.3 0.005 10.0 1890 4094.8 6.0 56.445 22.0 1882 4100.8 2.0 0.001 1.0 1884 4102.8 1.5 109.347 15.0 1885 4104.3 2.0 4.377 15.0 1886 4106.3 13.0 42.829 22.0 1887 4119.3 1.5 11.097 22.0 1893 4120.8 4.0 91.857 22.0 1894 4124.8 9.0 4.906 22.0 1896 4133.8 7.0 12.361 22.0 1900 4140.8 5.5 2.537 22.0 1903 4146.3 13.0 61.847 22.0 1906 4159.3 2.5 0.081 15.0 1912 4161.8 12.5 22.858 15.0 1913 4174.3 4.0 0.018 15.0 1919 4178.3 2.5 94.329 15.0 1920 4180.8 2.0 0.001 1.0 1922 4182.8 4.0 45.186 15.0 1922 4186.8 4.0 24.865 15.0 1924 4190.8 4.0 0.001 1.0 1926 4194.8 6.0 6.405 15.0 1928 4200.8 2.0 0.001 1.0 1931 4202.8 2.0 13.686 15.0 1932 4204.8 6.5 0.229 15.0 1933 4211.3 4.0 49.420 15.0 1936 4215.3 3.5 63.759 15.0 1938 4218.8 2.0 0.001 1.0 1939 4220.8 12.5 1.337 15.0 1940 4233.3 2.0 1.843 15.0 1946 4235.3 2.0 0.001 1.0 1947 4237.3 2.0 4.320 15.0 1948 4239.3 8.0 0.001 1.0 1949 4247.3 2.0 91.060 15.0 1952 4249.3 4.0 0.001 1.0 1953 4253.3 6.0 4.551 15.0 1955 4259.3 8.0 0.001 1.0 1958 4267.3 6.5 7.953 15.0 1962 4273.8 6.0 0.001 1.0 1965 4279.8 2.0 24.687 15.0 1967 4281.8 2.0 0.001 1.0 1968 4283.8 4.0 2.159 10.0 1969 4287.8 2.0 0.001 1.0 1971 4289.8 6.0 1.534 10.0 1972 4295.8 12.0 0.001 1.0 1975 4307.8 2.5 5.632 10.0 1980 4310.3 20.0 0.001 1.0 1982 Formation Transmissibility Properties Zone Name Nan CS Shale Shale Nanushuk 3 SS Top Nan Shale Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Shale Nan CS Nan CS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS 11 SLB Private Attachment K Section 8: Propped Fracture Schedule (Stage 3; 17755 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 14700.0 26 0 1.0 PPA 40 YF126ST 7239.9 26 1 2.0 PPA 40 YF126ST 6945.8 26 2 3.0 PPA 40 YF126ST 7416.2 26 3 4.0 PPA 40 YF126ST 7137.6 26 4 5.0 PPA 40 YF126ST 6879.1 26 5 6.0 PPA 40 YF126ST 6638.7 26 6 7.0 PPA 40 YF126ST 5933.5 26 7 8.0 PPA 40 YF126ST 5274.3 26 8 Flush 40 YF126ST 11359.8 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,893.5 bbl of YF126ST 0 bbl of WF126 229888 lb of % PAD Clean 21.6 % PAD Dirty 18.8 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 14700.0 14700 350 350 0 0 4441 8.8 8.8 1.0 PPA 7239.9 21940 180 530 7240 7240 4458 4.5 13.3 2.0 PPA 6945.8 28886 180 710 13892 21131 4522 4.5 17.8 3.0 PPA 7416.2 36302 200 910 22249 43380 4847 5.0 22.8 4.0 PPA 7137.6 43439 200 1110 28550 71931 5301 5.0 27.8 5.0 PPA 6879.1 50319 200 1310 34396 106326 5697 5.0 32.8 6.0 PPA 6638.7 56957 200 1510 39832 146159 6087 5.0 37.8 7.0 PPA 5933.5 62891 185 1695 41534 187693 6419 4.6 42.4 8.0 PPA 5274.3 68165 170 1865 42194 229888 6644 4.3 46.6 Flush 11359.8 79525 270 2135 0 229888 6147 6.8 53.4 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 488.1 ft with an average conductivity (Kfw) of 11447.8 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 12 SLB Private Attachment K Section 9: Propped Fracture Simulation (Stage 3; 17755 ft MD) Initial Fracture Top TVD 4055.1 ft Initial Fracture Bottom TVD 4297.8 ft Propped Fracture Half-Length 488.1 ft EOJ Hyd Height at Well 242.8 ft Average Propped Width 0.133 in Net Pressure 362 psi Max Surface Pressure 6810 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) 0 122 7.1 0.147 123.4 1.26 271.1 13247 122 244.1 5.3 0.144 187.2 1.28 291.1 12559 244.1 366.1 4.2 0.134 163.8 1.18 322.1 11533 366.1 488.1 2.2 0.114 116.9 1.07 343.2 9414 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; 17177 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 4059.5 10.0 0.72 2937 1.46E+06 0.220 2500 Shale 4069.5 15.0 0.70 2834 1.76E+06 0.220 2500 Nanushuk 3 SS 4084.5 15.3 0.68 2774 1.90E+06 0.220 2000 Top Nan 4099.8 6.0 0.64 2630 8.39E+05 0.270 1000 Shale 4105.8 2.0 0.70 2858 2.67E+06 0.230 2500 Nan DS 4107.8 1.5 0.63 2584 8.19E+05 0.270 1500 Nan DS 4109.3 2.0 0.64 2615 1.22E+06 0.260 1500 Nan CS 4111.3 13.0 0.62 2562 8.69E+05 0.270 1000 Nan CS 4124.3 1.5 0.61 2529 1.00E+06 0.270 1000 Nan CS 4125.8 4.0 0.64 2630 7.07E+05 0.280 1000 Nan CS 4129.8 9.0 0.61 2510 1.17E+06 0.270 1000 Nan CS 4138.8 7.0 0.64 2659 7.69E+05 0.270 1000 Nan CS 4145.8 5.5 0.61 2543 1.28E+06 0.260 1000 Nan CS 4151.3 13.0 0.64 2665 6.92E+05 0.280 1000 Nan DS 4164.3 2.5 0.68 2817 1.75E+06 0.260 1500 Nan DS 4166.8 12.5 0.64 2654 1.11E+06 0.270 1500 Nan DS 4179.3 4.0 0.69 2891 1.69E+06 0.260 1500 Nan DS 4183.3 2.5 0.64 2675 8.22E+05 0.270 1500 Shale 4185.8 2.0 0.70 2918 2.67E+06 0.230 2500 Nan DS 4187.8 4.0 0.65 2715 1.16E+06 0.270 1500 Nan DS 4191.8 4.0 0.63 2630 8.38E+05 0.270 1000 Shale 4195.8 4.0 0.70 2921 2.67E+06 0.230 2500 Nan DS 4199.8 6.0 0.64 2682 1.13E+06 0.270 1500 Shale 4205.8 2.0 0.70 2932 2.67E+06 0.230 2500 Nan DS 4207.8 2.0 0.62 2614 1.08E+06 0.270 1500 Nan DS 4209.8 6.5 0.66 2781 1.69E+06 0.260 1500 Nan DS 4216.3 4.0 0.61 2576 8.99E+05 0.270 1500 Nan DS 4220.3 3.5 0.64 2711 9.29E+05 0.270 1500 Shale 4223.8 2.0 0.70 2945 2.67E+06 0.230 2500 Nan DS 4225.8 12.5 0.64 2698 1.56E+06 0.260 1500 Nan DS 4238.3 2.0 0.65 2747 1.40E+06 0.260 1500 Shale 4240.3 2.0 0.70 2956 2.67E+06 0.230 2500 Nan DS 4242.3 2.0 0.65 2762 1.24E+06 0.260 1500 Shale 4244.3 8.0 0.69 2927 2.67E+06 0.230 2500 Nan DS 4252.3 2.0 0.63 2690 9.33E+05 0.270 1500 Shale 4254.3 4.0 0.70 2967 2.67E+06 0.230 2500 Nan DS 4258.3 6.0 0.65 2753 1.43E+06 0.260 1500 Shale 4264.3 8.0 0.70 2975 2.67E+06 0.230 2500 Nan DS 4272.3 6.5 0.65 2766 1.47E+06 0.260 1500 Shale 4278.8 6.0 0.69 2950 2.67E+06 0.230 2500 Nan DS 4284.8 2.0 0.64 2726 8.38E+05 0.270 1000 Shale 4286.8 2.0 0.70 2989 2.67E+06 0.230 2500 Nan DS 4288.8 4.0 0.65 2789 1.47E+06 0.260 1500 Shale 4292.8 2.0 0.70 2993 2.67E+06 0.230 2500 Nan DS 4294.8 6.0 0.66 2849 1.55E+06 0.260 1500 Shale 4300.8 12.0 0.70 3002 2.67E+06 0.230 2500 Nan DS 4312.8 2.5 0.64 2754 1.21E+06 0.270 1500 Shale 4315.3 20.0 0.69 2980 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) 4059.5 10.0 0.001 1.0 1881 4069.5 15.0 0.001 1.0 1886 4084.5 15.3 0.005 10.0 1890 4099.8 6.0 56.445 22.0 1882 4105.8 2.0 0.001 1.0 1884 4107.8 1.5 109.347 15.0 1885 4109.3 2.0 4.377 15.0 1886 4111.3 13.0 42.829 22.0 1887 4124.3 1.5 11.097 22.0 1893 4125.8 4.0 91.857 22.0 1894 4129.8 9.0 4.906 22.0 1896 4138.8 7.0 12.361 22.0 1900 4145.8 5.5 2.537 22.0 1903 4151.3 13.0 61.847 22.0 1906 4164.3 2.5 0.081 15.0 1912 4166.8 12.5 22.858 15.0 1913 4179.3 4.0 0.018 15.0 1919 4183.3 2.5 94.329 15.0 1920 4185.8 2.0 0.001 1.0 1922 4187.8 4.0 45.186 15.0 1922 4191.8 4.0 24.865 15.0 1924 4195.8 4.0 0.001 1.0 1926 4199.8 6.0 6.405 15.0 1928 4205.8 2.0 0.001 1.0 1931 4207.8 2.0 13.686 15.0 1932 4209.8 6.5 0.229 15.0 1933 4216.3 4.0 49.420 15.0 1936 4220.3 3.5 63.759 15.0 1938 4223.8 2.0 0.001 1.0 1939 4225.8 12.5 1.337 15.0 1940 4238.3 2.0 1.843 15.0 1946 4240.3 2.0 0.001 1.0 1947 4242.3 2.0 4.320 15.0 1948 4244.3 8.0 0.001 1.0 1949 4252.3 2.0 91.060 15.0 1952 4254.3 4.0 0.001 1.0 1953 4258.3 6.0 4.551 15.0 1955 4264.3 8.0 0.001 1.0 1958 4272.3 6.5 7.953 15.0 1962 4278.8 6.0 0.001 1.0 1965 4284.8 2.0 24.687 15.0 1967 4286.8 2.0 0.001 1.0 1968 4288.8 4.0 2.159 10.0 1969 4292.8 2.0 0.001 1.0 1971 4294.8 6.0 1.534 10.0 1972 4300.8 12.0 0.001 1.0 1975 4312.8 2.5 5.632 10.0 1980 4315.3 20.0 0.001 1.0 1982 Formation Transmissibility Properties Zone Name Nan CS Shale Shale Nanushuk 3 SS Top Nan Shale Nan DS Nan DS Nan CS Nan CS Nan CS Nan CS Shale Nan CS Nan CS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS 15 SLB Private Attachment K Section 11: Propped Fracture Schedule (Stage 4; 17177 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 12600.0 26 0 1.0 PPA 40 YF126ST 7843.2 26 1 2.0 PPA 40 YF126ST 8296.3 26 2 4.0 PPA 40 YF126ST 8922.0 26 4 6.0 PPA 40 YF126ST 8298.4 26 6 8.0 PPA 40 YF126ST 7291.0 26 8 10.0 PPA 40 YF126ST 6115.8 26 10 Flush 40 YF126ST 10990.0 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,675.2 bbl of YF126ST 0 bbl of WF126 229400 lb of % PAD Clean 21.6 % PAD Dirty 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 12600.0 12600 300 300 0 0 4317 7.5 7.5 1.0 PPA 7843.2 20443 195 495 7843 7843 4344 4.9 12.4 2.0 PPA 8296.3 28740 215 710 16593 24436 4461 5.4 17.8 4.0 PPA 8922.0 37662 250 960 35688 60124 4925 6.3 24.0 6.0 PPA 8298.4 45960 250 1210 49791 109914 5688 6.3 30.3 8.0 PPA 7291.0 53251 235 1445 58328 168242 6367 5.9 36.1 10.0 PPA 6115.8 59367 210 1655 61158 229400 6754 5.3 41.4 Flush 10990.0 70357 262 1917 0 229400 6069 6.5 47.9 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 488.1 ft with an average conductivity (Kfw) of 11447.8 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 16 SLB Private Attachment K 18.1 Section 12: Propped Fracture Simulation (Stage 4; 17177 ft MD) Initial Fracture Top TVD Initial Fracture Bottom TVD Propped Fracture Half-Length EOJ Hyd Height at Well Average Propped Width Net Pressure Max Surface Pressure 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) 0 113.8 8.7 1.55 113.8 227.5 6.3 227.5 4.4 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 341.5 341.5 455.3 1.9 0.180 0.167 0.149 0.093 135.0 199.4 159.5 111.9 1.47 1.30 0.88 220.9 247.9 286.9 395.5 16254 14730 12833 7416 4166.8 ft 4179.3 ft 455.3 ft 235.4 ft 0.145 in 368 psi 6856 psi Section 13: Zone Data (Stage 5; 16598 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 4063.4 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4073.4 15.0 0.70 2836 1.76E+06 0.220 1000 Nanushuk 3 SS 4088.4 15.3 0.68 2777 1.90E+06 0.220 1000 Top Nan CS 4103.7 19.5 0.63 2591 9.00E+05 0.270 1000 Nan SS 4123.2 2.0 0.69 2850 2.67E+06 0.230 2500 Nan CS 4125.2 1.5 0.64 2655 1.29E+06 0.260 1000 Nan CS 4126.7 4.5 0.62 2543 6.44E+05 0.280 1000 Nan DS 4131.2 3.5 0.69 2856 1.77E+06 0.260 1500 Nan DS 4134.7 14.5 0.66 2726 1.39E+06 0.260 1500 Nan CS 4149.2 1.5 0.65 2706 1.15E+06 0.270 1000 Nan CS 4150.7 12.5 0.64 2641 8.82E+05 0.270 1000 Nan DS 4163.2 2.0 0.65 2703 1.40E+06 0.260 1500 Nan CS 4165.2 9.0 0.61 2531 8.54E+05 0.270 1000 Nan DS 4174.2 7.0 0.66 2755 1.40E+06 0.260 1500 Nan DS 4181.2 9.0 0.65 2705 1.13E+06 0.270 1500 Nan DS 4190.2 3.5 0.64 2691 1.69E+06 0.260 1500 Nan DS 4193.7 5.0 0.64 2665 7.57E+05 0.270 1000 Nan DS 4198.7 2.0 0.70 2925 1.80E+06 0.250 1500 Nan CS 4200.7 10.5 0.62 2603 7.36E+05 0.270 1000 Nan CS 4211.2 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4214.7 2.0 0.62 2614 6.70E+05 0.280 1000 Nan CS 4216.7 5.5 0.66 2768 1.30E+06 0.260 1000 Nan DS 4222.2 3.5 0.70 2936 1.53E+06 0.260 1500 Nan DS 4225.7 3.5 0.64 2701 1.19E+06 0.270 1500 Nan DS 4229.2 5.5 0.69 2924 1.42E+06 0.260 1500 Nan CS 4234.7 10.5 0.64 2693 1.17E+06 0.270 1000 Nan DS 4245.2 1.5 0.66 2811 1.38E+06 0.260 1500 Nan DS 4246.7 5.0 0.62 2643 1.14E+06 0.270 1500 Nan DS 4251.7 2.0 0.66 2809 1.56E+06 0.260 1500 Nan DS 4253.7 4.0 0.63 2688 8.96E+05 0.270 1500 Nan DS 4257.7 2.0 0.68 2876 1.66E+06 0.260 1500 Nan DS 4259.7 10.0 0.63 2674 9.81E+05 0.270 1500 Nan DS 4269.7 4.0 0.65 2794 1.63E+06 0.260 1500 Nan DS 4273.7 4.0 0.70 2974 1.75E+06 0.260 1500 Nan DS 4277.7 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4287.2 2.0 0.62 2646 7.82E+05 0.270 1000 Nan DS 4289.2 9.5 0.69 2971 1.69E+06 0.260 1500 Nan DS 4298.7 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4300.7 2.0 0.70 2998 2.67E+06 0.230 2500 Nan DS 4302.7 2.0 0.64 2737 1.09E+06 0.270 1500 Shale 4304.7 2.0 0.70 3001 2.67E+06 0.230 2500 Nan DS 4306.7 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4310.7 19.5 0.70 3011 2.67E+06 0.230 2500 Nan DS 4330.2 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4332.2 2.0 0.70 3020 2.67E+06 0.230 2500 Nan DS 4334.2 8.0 0.66 2855 1.37E+06 0.260 1500 Nan DS 4342.2 8.0 0.65 2812 1.56E+06 0.260 1500 Shale 4350.2 20.0 0.70 3042 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) 4063.4 10.0 0.001 1.0 1890 4073.4 15.0 0.001 1.0 1898 4088.4 15.3 0.005 10.0 1905 4103.7 19.5 30.655 23.7 1915 4123.2 2.0 5.000 10.0 1924 4125.2 1.5 2.095 16.9 1925 4126.7 4.5 48.388 26.6 1926 4131.2 3.5 0.478 12.4 1928 4134.7 14.5 15.008 17.7 1930 4149.2 1.5 3.661 17.6 1937 4150.7 12.5 34.723 23.9 1937 4163.2 2.0 1.697 15.6 1943 4165.2 9.0 54.319 24.4 1944 4174.2 7.0 3.610 14.8 1948 4181.2 9.0 22.986 20.4 1952 4190.2 3.5 0.835 14.0 1956 4193.7 5.0 65.392 23.4 1957 4198.7 2.0 0.006 10.5 1960 4200.7 10.5 100.832 25.6 1961 4211.2 3.5 17.434 20.5 1966 4214.7 2.0 161.343 26.3 1967 4216.7 5.5 4.627 18.4 1968 4222.2 3.5 5.075 14.8 1971 4225.7 3.5 8.651 19.4 1972 4229.2 5.5 10.205 16.0 1974 4234.7 10.5 17.356 20.1 1977 4245.2 1.5 3.106 14.8 1982 4246.7 5.0 52.863 20.6 1982 4251.7 2.0 2.277 14.1 1985 4253.7 4.0 122.778 23.1 1986 4257.7 2.0 0.333 12.5 1987 4259.7 10.0 39.939 21.2 1988 4269.7 4.0 0.748 13.3 1993 4273.7 4.0 0.009 10.9 1995 4277.7 9.5 5.399 16.7 1997 4287.2 2.0 160.618 24.9 2001 4289.2 9.5 0.033 11.5 2002 4298.7 2.0 6.733 16.2 2007 4300.7 2.0 0.001 1.0 2008 4302.7 2.0 29.480 19.6 2009 4304.7 2.0 0.001 1.0 2009 4306.7 4.0 8.473 16.6 2010 4310.7 19.5 0.001 1.0 2012 4330.2 2.0 2.185 16.4 2021 4332.2 2.0 0.001 1.0 2022 4334.2 8.0 2.645 15.9 2023 4342.2 8.0 2.026 14.4 2027 4350.2 20.0 0.001 10.0 2031 Formation Transmissibility Properties Zone Name Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS 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 Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS 19 SLB Private Attachment K Section 14: Propped Fracture Schedule (Stage 5; 16598 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 12600.0 26 0 1.0 PPA 40 YF126ST 7642.1 26 1 2.0 PPA 40 YF126ST 8489.3 26 2 4.0 PPA 40 YF126ST 8565.1 26 4 6.0 PPA 40 YF126ST 7966.5 26 6 8.0 PPA 40 YF126ST 7446.1 26 8 10.0 PPA 40 YF126ST 5824.6 26 10 Flush 40 YF126ST 10619.5 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,646.5 bbl of YF126ST 0 bbl of WF126 224495 lb of % PAD Clean 21.5 % PAD Dirty 18.4 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 12600.0 12600 300 300 0 0 4221 7.5 7.5 1.0 PPA 7642.1 20242 190 490 7642 7642 4240 4.8 12.3 2.0 PPA 8489.3 28731 220 710 16979 24621 4360 5.5 17.8 4.0 PPA 8565.1 37296 240 950 34260 58881 4804 6.0 23.8 6.0 PPA 7966.5 45263 240 1190 47799 106680 5504 6.0 29.8 8.0 PPA 7446.1 52709 240 1430 59569 166249 6153 6.0 35.8 10.0 PPA 5824.6 58534 200 1630 58246 224495 6518 5.0 40.8 Flush 10619.5 69153 253 1883 0 224495 5846 6.3 47.1 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 364.5 ft with an average conductivity (Kfw) of 13421.9 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 20 SLB Private Attachment K Section 15: Propped Fracture Simulation (Stage 5; 16598 ft MD) Initial Fracture Top TVD 4068.6 ft Initial Fracture Bottom TVD 4312.3 ft Propped Fracture Half-Length 364.5 ft EOJ Hyd Height at Well 243.7 ft Average Propped Width 0.158 in Net Pressure 250 psi Max Surface Pressure 6612 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 91.1 9.3 0.19 220 1.64 230.8 16862 91.1 182.3 7.3 0.185 212.9 1.65 244.3 15838 182.3 273.4 5.8 0.161 196.4 1.46 272.3 13582 273.4 364.5 2.7 0.106 175.9 1.01 394.2 8247 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; 16014 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 4065.4 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4075.4 15.0 0.70 2838 1.76E+06 0.220 1000 Nanushuk 3 SS 4090.4 15.3 0.68 2778 1.90E+06 0.220 1000 Top Nan CS 4105.7 19.5 0.63 2593 9.00E+05 0.270 1000 Nan SS 4125.2 2.0 0.69 2851 2.67E+06 0.230 2500 Nan CS 4127.2 1.5 0.64 2655 1.29E+06 0.260 1000 Nan CS 4128.7 4.5 0.62 2545 6.44E+05 0.280 1000 Nan DS 4133.2 3.5 0.69 2857 1.77E+06 0.260 1500 Nan DS 4136.7 14.5 0.66 2726 1.39E+06 0.260 1500 Nan CS 4151.2 1.5 0.65 2706 1.15E+06 0.270 1000 Nan CS 4152.7 12.5 0.64 2641 8.82E+05 0.270 1000 Nan DS 4165.2 2.0 0.65 2704 1.40E+06 0.260 1500 Nan CS 4167.2 9.0 0.61 2532 8.54E+05 0.270 1000 Nan DS 4176.2 7.0 0.66 2755 1.40E+06 0.260 1500 Nan DS 4183.2 9.0 0.65 2705 1.13E+06 0.270 1500 Nan DS 4192.2 3.5 0.64 2693 1.69E+06 0.260 1500 Nan DS 4195.7 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4200.7 2.0 0.70 2925 1.80E+06 0.250 1500 Nan CS 4202.7 10.5 0.62 2605 7.36E+05 0.270 1000 Nan CS 4213.2 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4216.7 2.0 0.62 2614 6.70E+05 0.280 1000 Nan CS 4218.7 5.5 0.66 2768 1.30E+06 0.260 1000 Nan DS 4224.2 3.5 0.70 2937 1.53E+06 0.260 1500 Nan DS 4227.7 3.5 0.64 2701 1.19E+06 0.270 1500 Nan DS 4231.2 5.5 0.69 2926 1.42E+06 0.260 1500 Nan CS 4236.7 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4247.2 1.5 0.66 2811 1.38E+06 0.260 1500 Nan DS 4248.7 5.0 0.62 2644 1.14E+06 0.270 1500 Nan DS 4253.7 2.0 0.66 2809 1.56E+06 0.260 1500 Nan DS 4255.7 4.0 0.63 2688 8.96E+05 0.270 1500 Nan DS 4259.7 2.0 0.68 2876 1.66E+06 0.260 1500 Nan DS 4261.7 10.0 0.63 2675 9.81E+05 0.270 1500 Nan DS 4271.7 4.0 0.65 2795 1.63E+06 0.260 1500 Nan DS 4275.7 4.0 0.70 2974 1.75E+06 0.260 1500 Nan DS 4279.7 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4289.2 2.0 0.62 2647 7.82E+05 0.270 1000 Nan DS 4291.2 9.5 0.69 2973 1.69E+06 0.260 1500 Nan DS 4300.7 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4302.7 2.0 0.70 3000 2.67E+06 0.230 2500 Nan DS 4304.7 2.0 0.64 2738 1.09E+06 0.270 1500 Shale 4306.7 2.0 0.70 3002 2.67E+06 0.230 2500 Nan DS 4308.7 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4312.7 19.5 0.70 3013 2.67E+06 0.230 2500 Nan DS 4332.2 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4334.2 2.0 0.70 3022 2.67E+06 0.230 2500 Nan DS 4336.2 8.0 0.66 2855 1.37E+06 0.260 1500 Nan DS 4344.2 8.0 0.65 2813 1.56E+06 0.260 1500 Shale 4352.2 20.0 0.70 3042 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) 4065.4 10.0 0.001 1.0 1890 4075.4 15.0 0.001 1.0 1898 4090.4 15.3 0.005 10.0 1905 4105.7 19.5 30.655 23.7 1915 4125.2 2.0 5.000 10.0 1924 4127.2 1.5 2.095 16.9 1925 4128.7 4.5 48.388 26.6 1926 4133.2 3.5 0.478 12.4 1928 4136.7 14.5 15.008 17.7 1930 4151.2 1.5 3.661 17.6 1937 4152.7 12.5 34.723 23.9 1937 4165.2 2.0 1.697 15.6 1943 4167.2 9.0 54.319 24.4 1944 4176.2 7.0 3.610 14.8 1948 4183.2 9.0 22.986 20.4 1952 4192.2 3.5 0.835 14.0 1956 4195.7 5.0 65.392 23.4 1957 4200.7 2.0 0.006 10.5 1960 4202.7 10.5 100.832 25.6 1961 4213.2 3.5 17.434 20.5 1966 4216.7 2.0 161.343 26.3 1967 4218.7 5.5 4.627 18.4 1968 4224.2 3.5 5.075 14.8 1971 4227.7 3.5 8.651 19.4 1972 4231.2 5.5 10.205 16.0 1974 4236.7 10.5 17.356 20.1 1977 4247.2 1.5 3.106 14.8 1982 4248.7 5.0 52.863 20.6 1982 4253.7 2.0 2.277 14.1 1985 4255.7 4.0 122.778 23.1 1986 4259.7 2.0 0.333 12.5 1987 4261.7 10.0 39.939 21.2 1988 4271.7 4.0 0.748 13.3 1993 4275.7 4.0 0.009 10.9 1995 4279.7 9.5 5.399 16.7 1997 4289.2 2.0 160.618 24.9 2001 4291.2 9.5 0.033 11.5 2002 4300.7 2.0 6.733 16.2 2007 4302.7 2.0 0.001 1.0 2008 4304.7 2.0 29.480 19.6 2009 4306.7 2.0 0.001 1.0 2009 4308.7 4.0 8.473 16.6 2010 4312.7 19.5 0.001 1.0 2012 4332.2 2.0 2.185 16.4 2021 4334.2 2.0 0.001 1.0 2022 4336.2 8.0 2.645 15.9 2023 4344.2 8.0 2.026 14.4 2027 4352.2 20.0 0.001 10.0 2031 Formation Transmissibility Properties Zone Name Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS 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 Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS 23 SLB Private Attachment K Section 17: Propped Fracture Schedule (Stage 6; 16014 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 11760.0 26 0 1.0 PPA 40 YF126ST 7642.1 26 1 3.0 PPA 40 YF126ST 7972.5 26 3 5.0 PPA 40 YF126ST 8255.0 26 5 7.0 PPA 40 YF126ST 7697.5 26 7 9.0 PPA 40 YF126ST 6609.7 26 9 10.0 PPA 40 YF126ST 5533.4 26 10 Flush 40 YF126ST 10245.9 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,564.7 bbl of YF126ST 0 bbl of WF126 241538 lb of % PAD Clean 21.2 % PAD Dirty 17.8 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 11760.0 11760 280 280 0 0 4123 7.0 7.0 1.0 PPA 7642.1 19402 190 470 7642 7642 4133 4.8 11.8 3.0 PPA 7972.5 27375 215 685 23917 31559 4347 5.4 17.1 5.0 PPA 8255.0 35630 240 925 41275 72834 4991 6.0 23.1 7.0 PPA 7697.5 43327 240 1165 53883 126717 5639 6.0 29.1 9.0 PPA 6609.7 49937 220 1385 59487 186204 6127 5.5 34.6 10.0 PPA 5533.4 55470 190 1575 55333 241538 6363 4.8 39.4 Flush 10245.9 65716 244 1819 0 241538 5651 6.1 45.5 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 356.5 ft with an average conductivity (Kfw) of 14814.9 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 24 SLB Private Attachment K Section 18: Propped Fracture Simulation (Stage 6; 16014 ft MD) Initial Fracture Top TVD 4070.2 ft Initial Fracture Bottom TVD 4314.4 ft Propped Fracture Half-Length 356.5 ft EOJ Hyd Height at Well 244.2 ft Average Propped Width 0.173 in Net Pressure 252 psi Max Surface Pressure 6418 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 89.1 9.6 0.196 138.6 1.69 221.5 17434 89.1 178.3 8.2 0.196 209.2 1.74 228 17015 178.3 267.4 7.1 0.178 198.1 1.59 236.7 15240 267.4 356.5 3.7 0.128 161.2 1.2 350.3 10416 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; 15432 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 4068.4 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4078.4 15.0 0.70 2840 1.76E+06 0.220 1000 Nanushuk 3 SS 4093.4 15.3 0.68 2781 1.90E+06 0.220 1000 Top Nan CS 4108.7 19.5 0.63 2595 9.00E+05 0.270 1000 Nan SS 4128.2 2.0 0.69 2853 2.67E+06 0.230 2500 Nan CS 4130.2 1.5 0.64 2655 1.29E+06 0.260 1000 Nan CS 4131.7 4.5 0.62 2547 6.44E+05 0.280 1000 Nan DS 4136.2 3.5 0.69 2859 1.77E+06 0.260 1500 Nan DS 4139.7 14.5 0.66 2726 1.39E+06 0.260 1500 Nan CS 4154.2 1.5 0.65 2706 1.15E+06 0.270 1000 Nan CS 4155.7 12.5 0.63 2641 8.82E+05 0.270 1000 Nan DS 4168.2 2.0 0.65 2706 1.40E+06 0.260 1500 Nan CS 4170.2 9.0 0.61 2534 8.54E+05 0.270 1000 Nan DS 4179.2 7.0 0.66 2755 1.40E+06 0.260 1500 Nan DS 4186.2 9.0 0.65 2705 1.13E+06 0.270 1500 Nan DS 4195.2 3.5 0.64 2694 1.69E+06 0.260 1500 Nan DS 4198.7 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4203.7 2.0 0.70 2925 1.80E+06 0.250 1500 Nan CS 4205.7 10.5 0.62 2607 7.36E+05 0.270 1000 Nan CS 4216.2 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4219.7 2.0 0.62 2614 6.70E+05 0.280 1000 Nan CS 4221.7 5.5 0.66 2768 1.30E+06 0.260 1000 Nan DS 4227.2 3.5 0.70 2939 1.53E+06 0.260 1500 Nan DS 4230.7 3.5 0.64 2701 1.19E+06 0.270 1500 Nan DS 4234.2 5.5 0.69 2928 1.42E+06 0.260 1500 Nan CS 4239.7 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4250.2 1.5 0.66 2811 1.38E+06 0.260 1500 Nan DS 4251.7 5.0 0.62 2646 1.14E+06 0.270 1500 Nan DS 4256.7 2.0 0.66 2809 1.56E+06 0.260 1500 Nan DS 4258.7 4.0 0.63 2688 8.96E+05 0.270 1500 Nan DS 4262.7 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4264.7 10.0 0.63 2677 9.81E+05 0.270 1500 Nan DS 4274.7 4.0 0.65 2797 1.63E+06 0.260 1500 Nan DS 4278.7 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4282.7 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4292.2 2.0 0.62 2649 7.82E+05 0.270 1000 Nan DS 4294.2 9.5 0.69 2975 1.69E+06 0.260 1500 Nan DS 4303.7 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4305.7 2.0 0.70 3002 2.67E+06 0.230 2500 Nan DS 4307.7 2.0 0.64 2740 1.09E+06 0.270 1500 Shale 4309.7 2.0 0.70 3005 2.67E+06 0.230 2500 Nan DS 4311.7 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4315.7 19.5 0.70 3015 2.67E+06 0.230 2500 Nan DS 4335.2 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4337.2 2.0 0.70 3024 2.67E+06 0.230 2500 Nan DS 4339.2 8.0 0.66 2855 1.37E+06 0.260 1500 Nan DS 4347.2 8.0 0.65 2815 1.56E+06 0.260 1500 Shale 4355.2 20.0 0.70 3042 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) 4068.4 10.0 0.001 1.0 1890 4078.4 15.0 0.001 1.0 1898 4093.4 15.3 0.005 10.0 1905 4108.7 19.5 30.655 23.7 1915 4128.2 2.0 5.000 10.0 1924 4130.2 1.5 2.095 16.9 1925 4131.7 4.5 48.388 26.6 1926 4136.2 3.5 0.478 12.4 1928 4139.7 14.5 15.008 17.7 1930 4154.2 1.5 3.661 17.6 1937 4155.7 12.5 34.723 23.9 1937 4168.2 2.0 1.697 15.6 1943 4170.2 9.0 54.319 24.4 1944 4179.2 7.0 3.610 14.8 1948 4186.2 9.0 22.986 20.4 1952 4195.2 3.5 0.835 14.0 1956 4198.7 5.0 65.392 23.4 1957 4203.7 2.0 0.006 10.5 1960 4205.7 10.5 100.832 25.6 1961 4216.2 3.5 17.434 20.5 1966 4219.7 2.0 161.343 26.3 1967 4221.7 5.5 4.627 18.4 1968 4227.2 3.5 5.075 14.8 1971 4230.7 3.5 8.651 19.4 1972 4234.2 5.5 10.205 16.0 1974 4239.7 10.5 17.356 20.1 1977 4250.2 1.5 3.106 14.8 1982 4251.7 5.0 52.863 20.6 1982 4256.7 2.0 2.277 14.1 1985 4258.7 4.0 122.778 23.1 1986 4262.7 2.0 0.333 12.5 1987 4264.7 10.0 39.939 21.2 1988 4274.7 4.0 0.748 13.3 1993 4278.7 4.0 0.009 10.9 1995 4282.7 9.5 5.399 16.7 1997 4292.2 2.0 160.618 24.9 2001 4294.2 9.5 0.033 11.5 2002 4303.7 2.0 6.733 16.2 2007 4305.7 2.0 0.001 1.0 2008 4307.7 2.0 29.480 19.6 2009 4309.7 2.0 0.001 1.0 2009 4311.7 4.0 8.473 16.6 2010 4315.7 19.5 0.001 1.0 2012 4335.2 2.0 2.185 16.4 2021 4337.2 2.0 0.001 1.0 2022 4339.2 8.0 2.645 15.9 2023 4347.2 8.0 2.026 14.4 2027 4355.2 20.0 0.001 10.0 2031 Formation Transmissibility Properties Zone Name Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS 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 Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS 27 SLB Private Attachment K Section 20: Propped Fracture Schedule (Stage 7; 15432 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 11760.0 26 0 1.0 PPA 40 YF126ST 7642.0 26 1 3.0 PPA 40 YF126ST 7972.0 26 3 5.0 PPA 40 YF126ST 8255.0 26 5 7.0 PPA 40 YF126ST 7698.0 26 7 9.0 PPA 40 YF126ST 6610.0 26 9 10.0 PPA 40 YF126ST 5533.0 26 10 Flush 40 YF126ST 9873.5 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,555.8 bbl of YF126ST 0 bbl of WF126 241539 lb of % PAD Clean 21.2 % PAD Dirty 17.8 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 11760.0 11760 280 280 0 0 4013 7.0 7.0 1.0 PPA 7642.0 19402 190 470 7642 7642 4023 4.8 11.8 3.0 PPA 7972.0 27374 215 685 23916 31558 4187 5.4 17.2 5.0 PPA 8255.0 35629 240 925 41275 72833 4866 6.0 23.2 7.0 PPA 7698.0 43327 240 1165 53886 126719 5532 6.0 29.2 9.0 PPA 6610.0 49937 220 1385 59490 186209 5948 5.5 34.7 10.0 PPA 5533.0 55470 190 1575 55330 241539 6141 4.7 39.4 Flush 9873.5 65344 235 1810 0 241539 5490 5.9 45.3 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 356.5 ft with an average conductivity (Kfw) of 14814.9 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 28 SLB Private Attachment K Section 21: Propped Fracture Simulation (Stage 7; 15432 ft MD) Initial Fracture Top TVD 4073 ft Initial Fracture Bottom TVD 4317.6 ft Propped Fracture Half-Length 358.8 ft EOJ Hyd Height at Well 244.6 ft Average Propped Width 0.173 in Net Pressure 254 psi Max Surface Pressure 6194 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 89.7 9.6 0.197 139.5 1.7 224.2 17588 89.7 179.4 8.2 0.198 209.2 1.75 227.4 17345 179.4 269.1 7 0.183 198.2 1.66 230 15610 269.1 358.8 3.4 0.122 155.1 1.14 369.6 10001 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; 14853 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 4068.4 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4078.4 15.0 0.70 2840 1.76E+06 0.220 1000 Nanushuk 3 SS 4093.4 15.3 0.68 2781 1.90E+06 0.220 1000 Top Nan CS 4108.7 19.5 0.63 2595 9.00E+05 0.270 1000 Nan SS 4128.2 2.0 0.69 2853 2.67E+06 0.230 2500 Nan CS 4130.2 1.5 0.64 2655 1.29E+06 0.260 1000 Nan CS 4131.7 4.5 0.62 2547 6.44E+05 0.280 1000 Nan DS 4136.2 3.5 0.69 2859 1.77E+06 0.260 1500 Nan DS 4139.7 14.5 0.66 2726 1.39E+06 0.260 1500 Nan CS 4154.2 1.5 0.65 2706 1.15E+06 0.270 1000 Nan CS 4155.7 12.5 0.63 2641 8.82E+05 0.270 1000 Nan DS 4168.2 2.0 0.65 2706 1.40E+06 0.260 1500 Nan CS 4170.2 9.0 0.61 2534 8.54E+05 0.270 1000 Nan DS 4179.2 7.0 0.66 2755 1.40E+06 0.260 1500 Nan DS 4186.2 9.0 0.65 2705 1.13E+06 0.270 1500 Nan DS 4195.2 3.5 0.64 2694 1.69E+06 0.260 1500 Nan DS 4198.7 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4203.7 2.0 0.70 2925 1.80E+06 0.250 1500 Nan CS 4205.7 10.5 0.62 2607 7.36E+05 0.270 1000 Nan CS 4216.2 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4219.7 2.0 0.62 2614 6.70E+05 0.280 1000 Nan CS 4221.7 5.5 0.66 2768 1.30E+06 0.260 1000 Nan DS 4227.2 3.5 0.70 2939 1.53E+06 0.260 1500 Nan DS 4230.7 3.5 0.64 2701 1.19E+06 0.270 1500 Nan DS 4234.2 5.5 0.69 2928 1.42E+06 0.260 1500 Nan CS 4239.7 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4250.2 1.5 0.66 2811 1.38E+06 0.260 1500 Nan DS 4251.7 5.0 0.62 2646 1.14E+06 0.270 1500 Nan DS 4256.7 2.0 0.66 2809 1.56E+06 0.260 1500 Nan DS 4258.7 4.0 0.63 2688 8.96E+05 0.270 1500 Nan DS 4262.7 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4264.7 10.0 0.63 2677 9.81E+05 0.270 1500 Nan DS 4274.7 4.0 0.65 2797 1.63E+06 0.260 1500 Nan DS 4278.7 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4282.7 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4292.2 2.0 0.62 2649 7.82E+05 0.270 1000 Nan DS 4294.2 9.5 0.69 2975 1.69E+06 0.260 1500 Nan DS 4303.7 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4305.7 2.0 0.70 3002 2.67E+06 0.230 2500 Nan DS 4307.7 2.0 0.64 2740 1.09E+06 0.270 1500 Shale 4309.7 2.0 0.70 3005 2.67E+06 0.230 2500 Nan DS 4311.7 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4315.7 19.5 0.70 3015 2.67E+06 0.230 2500 Nan DS 4335.2 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4337.2 2.0 0.70 3024 2.67E+06 0.230 2500 Nan DS 4339.2 8.0 0.66 2855 1.37E+06 0.260 1500 Nan DS 4347.2 8.0 0.65 2815 1.56E+06 0.260 1500 Shale 4355.2 20.0 0.70 3042 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) 4068.4 10.0 0.001 1.0 1890 4078.4 15.0 0.001 1.0 1898 4093.4 15.3 0.005 10.0 1905 4108.7 19.5 30.655 23.7 1915 4128.2 2.0 5.000 10.0 1924 4130.2 1.5 2.095 16.9 1925 4131.7 4.5 48.388 26.6 1926 4136.2 3.5 0.478 12.4 1928 4139.7 14.5 15.008 17.7 1930 4154.2 1.5 3.661 17.6 1937 4155.7 12.5 34.723 23.9 1937 4168.2 2.0 1.697 15.6 1943 4170.2 9.0 54.319 24.4 1944 4179.2 7.0 3.610 14.8 1948 4186.2 9.0 22.986 20.4 1952 4195.2 3.5 0.835 14.0 1956 4198.7 5.0 65.392 23.4 1957 4203.7 2.0 0.006 10.5 1960 4205.7 10.5 100.832 25.6 1961 4216.2 3.5 17.434 20.5 1966 4219.7 2.0 161.343 26.3 1967 4221.7 5.5 4.627 18.4 1968 4227.2 3.5 5.075 14.8 1971 4230.7 3.5 8.651 19.4 1972 4234.2 5.5 10.205 16.0 1974 4239.7 10.5 17.356 20.1 1977 4250.2 1.5 3.106 14.8 1982 4251.7 5.0 52.863 20.6 1982 4256.7 2.0 2.277 14.1 1985 4258.7 4.0 122.778 23.1 1986 4262.7 2.0 0.333 12.5 1987 4264.7 10.0 39.939 21.2 1988 4274.7 4.0 0.748 13.3 1993 4278.7 4.0 0.009 10.9 1995 4282.7 9.5 5.399 16.7 1997 4292.2 2.0 160.618 24.9 2001 4294.2 9.5 0.033 11.5 2002 4303.7 2.0 6.733 16.2 2007 4305.7 2.0 0.001 1.0 2008 4307.7 2.0 29.480 19.6 2009 4309.7 2.0 0.001 1.0 2009 4311.7 4.0 8.473 16.6 2010 4315.7 19.5 0.001 1.0 2012 4335.2 2.0 2.185 16.4 2021 4337.2 2.0 0.001 1.0 2022 4339.2 8.0 2.645 15.9 2023 4347.2 8.0 2.026 14.4 2027 4355.2 20.0 0.001 10.0 2031 Formation Transmissibility Properties Zone Name Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS 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 Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS 31 SLB Private Attachment K Section 23: Propped Fracture Schedule (Stage 8; 14853 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 11760.0 26 0 1.0 PPA 40 YF126ST 7642.0 26 1 3.0 PPA 40 YF126ST 7972.0 26 3 5.0 PPA 40 YF126ST 8255.0 26 5 7.0 PPA 40 YF126ST 7698.0 26 7 9.0 PPA 40 YF126ST 6610.0 26 9 10.0 PPA 40 YF126ST 5533.0 26 10 Flush 40 YF126ST 9503.1 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1547.0 bbl of YF126ST 0 bbl of WF126 241539 lb of % PAD Clean 21.2 % PAD Dirty 17.8 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 11760.0 11760 280 280 0 0 3905 7.0 7.0 1.0 PPA 7642.0 19402 190 470 7642 7642 3917 4.7 11.7 3.0 PPA 7972.0 27374 215 685 23916 31558 4092 5.4 17.1 5.0 PPA 8255.0 35629 240 925 41275 72833 4719 6.0 23.1 7.0 PPA 7698.0 43327 240 1165 53886 126719 5340 6.0 29.1 9.0 PPA 6610.0 49937 220 1385 59490 186209 5736 5.5 34.6 10.0 PPA 5533.0 55470 190 1575 55330 241539 5926 4.7 39.4 Flush 9503.1 64973 226 1801 0 241539 5248 5.7 45.0 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 356.5 ft with an average conductivity (Kfw) of 14814.9 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 32 SLB Private Attachment K Section 24: Propped Fracture Simulation (Stage 8; 14853 ft MD) Initial Fracture Top TVD 4073.3 ft Initial Fracture Bottom TVD 4317.3 ft Propped Fracture Half-Length 357 ft EOJ Hyd Height at Well 244 ft Average Propped Width 0.172 in Net Pressure 254 psi Max Surface Pressure 5979 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 89.3 9.6 0.197 139.2 1.7 224.1 17515 89.3 178.5 8.2 0.198 208.8 1.75 226.5 17308 178.5 267.8 7.1 0.18 197.8 1.61 231.8 15427 267.8 357 3.3 0.123 157.2 1.15 366.7 9918 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; 14272 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 4080.4 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4090.4 15.0 0.70 2848 1.76E+06 0.220 1000 Nanushuk 3 SS 4105.4 15.3 0.68 2789 1.90E+06 0.220 1000 Top Nan CS 4120.7 19.5 0.63 2602 9.00E+05 0.270 1000 Nan SS 4140.2 2.0 0.69 2862 2.67E+06 0.230 2500 Nan CS 4142.2 1.5 0.64 2655 1.29E+06 0.260 1000 Nan CS 4143.7 4.5 0.62 2554 6.44E+05 0.280 1000 Nan DS 4148.2 3.5 0.69 2868 1.77E+06 0.260 1500 Nan DS 4151.7 14.5 0.66 2726 1.39E+06 0.260 1500 Nan CS 4166.2 1.5 0.65 2706 1.15E+06 0.270 1000 Nan CS 4167.7 12.5 0.63 2641 8.82E+05 0.270 1000 Nan DS 4180.2 2.0 0.65 2714 1.40E+06 0.260 1500 Nan CS 4182.2 9.0 0.61 2541 8.54E+05 0.270 1000 Nan DS 4191.2 7.0 0.66 2755 1.40E+06 0.260 1500 Nan DS 4198.2 9.0 0.64 2705 1.13E+06 0.270 1500 Nan DS 4207.2 3.5 0.64 2702 1.69E+06 0.260 1500 Nan DS 4210.7 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4215.7 2.0 0.69 2925 1.80E+06 0.250 1500 Nan CS 4217.7 10.5 0.62 2614 7.36E+05 0.270 1000 Nan CS 4228.2 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4231.7 2.0 0.62 2614 6.70E+05 0.280 1000 Nan CS 4233.7 5.5 0.65 2768 1.30E+06 0.260 1000 Nan DS 4239.2 3.5 0.70 2947 1.53E+06 0.260 1500 Nan DS 4242.7 3.5 0.64 2701 1.19E+06 0.270 1500 Nan DS 4246.2 5.5 0.69 2936 1.42E+06 0.260 1500 Nan CS 4251.7 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4262.2 1.5 0.66 2811 1.38E+06 0.260 1500 Nan DS 4263.7 5.0 0.62 2654 1.14E+06 0.270 1500 Nan DS 4268.7 2.0 0.66 2809 1.56E+06 0.260 1500 Nan DS 4270.7 4.0 0.63 2688 8.96E+05 0.270 1500 Nan DS 4274.7 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4276.7 10.0 0.63 2685 9.81E+05 0.270 1500 Nan DS 4286.7 4.0 0.65 2805 1.63E+06 0.260 1500 Nan DS 4290.7 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4294.7 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4304.2 2.0 0.62 2656 7.82E+05 0.270 1000 Nan DS 4306.2 9.5 0.69 2983 1.69E+06 0.260 1500 Nan DS 4315.7 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4317.7 2.0 0.70 3010 2.67E+06 0.230 2500 Nan DS 4319.7 2.0 0.64 2748 1.09E+06 0.270 1500 Shale 4321.7 2.0 0.70 3013 2.67E+06 0.230 2500 Nan DS 4323.7 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4327.7 19.5 0.70 3023 2.67E+06 0.230 2500 Nan DS 4347.2 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4349.2 2.0 0.70 3032 2.67E+06 0.230 2500 Nan DS 4351.2 8.0 0.66 2855 1.37E+06 0.260 1500 Nan DS 4359.2 8.0 0.65 2823 1.56E+06 0.260 1500 Shale 4367.2 20.0 0.69 3042 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) 4080.4 10.0 0.001 1.0 1890 4090.4 15.0 0.001 1.0 1898 4105.4 15.3 0.005 10.0 1905 4120.7 19.5 30.655 23.7 1915 4140.2 2.0 5.000 10.0 1924 4142.2 1.5 2.095 16.9 1925 4143.7 4.5 48.388 26.6 1926 4148.2 3.5 0.478 12.4 1928 4151.7 14.5 15.008 17.7 1930 4166.2 1.5 3.661 17.6 1937 4167.7 12.5 34.723 23.9 1937 4180.2 2.0 1.697 15.6 1943 4182.2 9.0 54.319 24.4 1944 4191.2 7.0 3.610 14.8 1948 4198.2 9.0 22.986 20.4 1952 4207.2 3.5 0.835 14.0 1956 4210.7 5.0 65.392 23.4 1957 4215.7 2.0 0.006 10.5 1960 4217.7 10.5 100.832 25.6 1961 4228.2 3.5 17.434 20.5 1966 4231.7 2.0 161.343 26.3 1967 4233.7 5.5 4.627 18.4 1968 4239.2 3.5 5.075 14.8 1971 4242.7 3.5 8.651 19.4 1972 4246.2 5.5 10.205 16.0 1974 4251.7 10.5 17.356 20.1 1977 4262.2 1.5 3.106 14.8 1982 4263.7 5.0 52.863 20.6 1982 4268.7 2.0 2.277 14.1 1985 4270.7 4.0 122.778 23.1 1986 4274.7 2.0 0.333 12.5 1987 4276.7 10.0 39.939 21.2 1988 4286.7 4.0 0.748 13.3 1993 4290.7 4.0 0.009 10.9 1995 4294.7 9.5 5.399 16.7 1997 4304.2 2.0 160.618 24.9 2001 4306.2 9.5 0.033 11.5 2002 4315.7 2.0 6.733 16.2 2007 4317.7 2.0 0.001 1.0 2008 4319.7 2.0 29.480 19.6 2009 4321.7 2.0 0.001 1.0 2009 4323.7 4.0 8.473 16.6 2010 4327.7 19.5 0.001 1.0 2012 4347.2 2.0 2.185 16.4 2021 4349.2 2.0 0.001 1.0 2022 4351.2 8.0 2.645 15.9 2023 4359.2 8.0 2.026 14.4 2027 4367.2 20.0 0.001 10.0 2031 Formation Transmissibility Properties Zone Name Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS 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 Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS 35 SLB Private Attachment K Section 26: Propped Fracture Schedule (Stage 9; 14272 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 11760.0 26 0 1.0 PPA 40 YF126ST 7642.0 26 1 3.0 PPA 40 YF126ST 7972.0 26 3 5.0 PPA 40 YF126ST 8255.0 26 5 7.0 PPA 40 YF126ST 7698.0 26 7 9.0 PPA 40 YF126ST 6610.0 26 9 11.0 PPA 40 YF126ST 5510.0 26 11 Flush 40 YF126ST 9131.3 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1,37.6 bbl of YF126ST 0 bbl of WF126 246819 lb of % PAD Clean 21.2 % PAD Dirty 17.7 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 11760.0 11760 280 280 0 0 3804 7.0 7.0 1.0 PPA 7642.0 19402 190 470 7642 7642 3809 4.7 11.7 3.0 PPA 7972.0 27374 215 685 23916 31558 3986 5.4 17.1 5.0 PPA 8255.0 35629 240 925 41275 72833 4554 6.0 23.1 7.0 PPA 7698.0 43327 240 1165 53886 126719 5144 6.0 29.1 9.0 PPA 6610.0 49937 220 1385 59490 186209 5537 5.5 34.6 11.0 PPA 5510.0 55447 195 1580 60610 246819 5730 4.9 39.5 Flush 9131.3 64578 217 1797 0 246819 5141 5.4 44.9 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 360.4 ft with an average conductivity (Kfw) of 14982 md.ft. Job Description Fluid Name Prop. Type and Mesh Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Carbolite 16/20 Pad Percentages Carbolite 16/20 Fluid Totals Proppant Totals Carbolite 16/20 Job Execution Step Name 36 SLB Private Attachment K Section 27: Propped Fracture Simulation (Stage 9; 14272 ft MD) Initial Fracture Top TVD 4085.7 ft Initial Fracture Bottom TVD 4329 ft Propped Fracture Half-Length 360.4 ft EOJ Hyd Height at Well 243.3 ft Average Propped Width 0.175 in Net Pressure 259 psi Max Surface Pressure 5802 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 90.1 10.2 0.209 140 1.8 209.6 18718 90.1 180.2 8.3 0.197 209 1.74 224.5 17209 180.2 270.3 7.1 0.178 197.6 1.59 238.7 15343 270.3 360.4 3.6 0.124 160.2 1.16 351.4 10189 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; 13732 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 4092.7 10.0 0.72 2937 1.46E+06 0.220 1000 Shale 4102.7 15.0 0.70 2857 1.76E+06 0.220 1000 Nanushuk 3 SS 4117.7 15.3 0.68 2797 1.90E+06 0.220 1000 Top Nan CS 4133.0 19.5 0.63 2610 9.00E+05 0.270 1000 Nan SS 4152.5 2.0 0.69 2870 2.67E+06 0.230 2500 Nan CS 4154.5 1.5 0.64 2655 1.29E+06 0.260 1000 Nan CS 4156.0 4.5 0.62 2561 6.44E+05 0.280 1000 Nan DS 4160.5 3.5 0.69 2876 1.77E+06 0.260 1500 Nan DS 4164.0 14.5 0.65 2726 1.39E+06 0.260 1500 Nan CS 4178.5 1.5 0.65 2706 1.15E+06 0.270 1000 Nan CS 4180.0 12.5 0.63 2641 8.82E+05 0.270 1000 Nan DS 4192.5 2.0 0.65 2722 1.40E+06 0.260 1500 Nan CS 4194.5 9.0 0.61 2549 8.54E+05 0.270 1000 Nan DS 4203.5 7.0 0.65 2755 1.40E+06 0.260 1500 Nan DS 4210.5 9.0 0.64 2705 1.13E+06 0.270 1500 Nan DS 4219.5 3.5 0.64 2710 1.69E+06 0.260 1500 Nan DS 4223.0 5.0 0.63 2665 7.57E+05 0.270 1000 Nan DS 4228.0 2.0 0.69 2925 1.80E+06 0.250 1500 Nan CS 4230.0 10.5 0.62 2622 7.36E+05 0.270 1000 Nan CS 4240.5 3.5 0.64 2705 1.10E+06 0.270 1000 Nan CS 4244.0 2.0 0.62 2614 6.70E+05 0.280 1000 Nan CS 4246.0 5.5 0.65 2768 1.30E+06 0.260 1000 Nan DS 4251.5 3.5 0.70 2956 1.53E+06 0.260 1500 Nan DS 4255.0 3.5 0.63 2701 1.19E+06 0.270 1500 Nan DS 4258.5 5.5 0.69 2945 1.42E+06 0.260 1500 Nan CS 4264.0 10.5 0.63 2693 1.17E+06 0.270 1000 Nan DS 4274.5 1.5 0.66 2811 1.38E+06 0.260 1500 Nan DS 4276.0 5.0 0.62 2661 1.14E+06 0.270 1500 Nan DS 4281.0 2.0 0.66 2809 1.56E+06 0.260 1500 Nan DS 4283.0 4.0 0.63 2688 8.96E+05 0.270 1500 Nan DS 4287.0 2.0 0.67 2876 1.66E+06 0.260 1500 Nan DS 4289.0 10.0 0.63 2692 9.81E+05 0.270 1500 Nan DS 4299.0 4.0 0.65 2813 1.63E+06 0.260 1500 Nan DS 4303.0 4.0 0.69 2974 1.75E+06 0.260 1500 Nan DS 4307.0 9.5 0.65 2784 1.33E+06 0.260 1500 Nan DS 4316.5 2.0 0.62 2664 7.82E+05 0.270 1000 Nan DS 4318.5 9.5 0.69 2992 1.69E+06 0.260 1500 Nan DS 4328.0 2.0 0.65 2812 1.37E+06 0.260 1500 Shale 4330.0 2.0 0.70 3019 2.67E+06 0.230 2500 Nan DS 4332.0 2.0 0.64 2756 1.09E+06 0.270 1500 Shale 4334.0 2.0 0.70 3021 2.67E+06 0.230 2500 Nan DS 4336.0 4.0 0.66 2844 1.29E+06 0.260 1500 Shale 4340.0 19.5 0.70 3032 2.67E+06 0.230 2500 Nan DS 4359.5 2.0 0.65 2820 1.36E+06 0.260 1500 Shale 4361.5 2.0 0.70 3041 2.67E+06 0.230 2500 Nan DS 4363.5 8.0 0.65 2855 1.37E+06 0.260 1500 Nan DS 4371.5 8.0 0.65 2831 1.56E+06 0.260 1500 Shale 4379.5 20.0 0.69 3042 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) 4092.7 10.0 0.001 1.0 1890 4102.7 15.0 0.001 1.0 1898 4117.7 15.3 0.005 10.0 1905 4133.0 19.5 30.655 23.7 1915 4152.5 2.0 5.000 10.0 1924 4154.5 1.5 2.095 16.9 1925 4156.0 4.5 48.388 26.6 1926 4160.5 3.5 0.478 12.4 1928 4164.0 14.5 15.008 17.7 1930 4178.5 1.5 3.661 17.6 1937 4180.0 12.5 34.723 23.9 1937 4192.5 2.0 1.697 15.6 1943 4194.5 9.0 54.319 24.4 1944 4203.5 7.0 3.610 14.8 1948 4210.5 9.0 22.986 20.4 1952 4219.5 3.5 0.835 14.0 1956 4223.0 5.0 65.392 23.4 1957 4228.0 2.0 0.006 10.5 1960 4230.0 10.5 100.832 25.6 1961 4240.5 3.5 17.434 20.5 1966 4244.0 2.0 161.343 26.3 1967 4246.0 5.5 4.627 18.4 1968 4251.5 3.5 5.075 14.8 1971 4255.0 3.5 8.651 19.4 1972 4258.5 5.5 10.205 16.0 1974 4264.0 10.5 17.356 20.1 1977 4274.5 1.5 3.106 14.8 1982 4276.0 5.0 52.863 20.6 1982 4281.0 2.0 2.277 14.1 1985 4283.0 4.0 122.778 23.1 1986 4287.0 2.0 0.333 12.5 1987 4289.0 10.0 39.939 21.2 1988 4299.0 4.0 0.748 13.3 1993 4303.0 4.0 0.009 10.9 1995 4307.0 9.5 5.399 16.7 1997 4316.5 2.0 160.618 24.9 2001 4318.5 9.5 0.033 11.5 2002 4328.0 2.0 6.733 16.2 2007 4330.0 2.0 0.001 1.0 2008 4332.0 2.0 29.480 19.6 2009 4334.0 2.0 0.001 1.0 2009 4336.0 4.0 8.473 16.6 2010 4340.0 19.5 0.001 1.0 2012 4359.5 2.0 2.185 16.4 2021 4361.5 2.0 0.001 1.0 2022 4363.5 8.0 2.645 15.9 2023 4371.5 8.0 2.026 14.4 2027 4379.5 20.0 0.001 10.0 2031 Formation Transmissibility Properties Zone Name Nan DS Shale Shale Nanushuk 3 SS Top Nan CS Nan SS Nan CS Nan CS Nan DS Nan DS Nan CS Nan CS 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 Nan DS Nan CS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Nan DS Shale Nan DS Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Shale Nan DS Nan DS 39 SLB Private Attachment K Section 29: Propped Fracture Schedule (Stage 10; 13732 ft MD) Pumping Schedule Step Pump Step Fluid Gel Prop. Name Rate Volume Conc. Conc. (bbl/min) (bbl) (lb/mgal) (PPA) PAD 40 YF126ST 9450.0 26 0 1.0 PPA Scou 40 YF126ST 2413.3 26 1 3.0 PPA Scou 40 YF126ST 4449.7 26 3 Resume PAD 40 YF126ST 2100.0 26 0 1.0 PPA 40 YF126ST 8647.6 26 1 2.0 PPA 40 YF126ST 9068.1 26 2 4.0 PPA 40 YF126ST 9278.9 26 4 6.0 PPA 40 YF126ST 8630.4 26 6 8.0 PPA 40 YF126ST 7446.1 26 8 10.0 PPA 40 YF126ST 6115.8 26 10 FLUSH 40 WF126 8785.8 26 0 Please note that this pumping schedule is under-displaced by 0 bbl. 1609.5 bbl of YF126ST 209.2 bbl of WF126 236408 lb of 15763 lb of % PAD Clean 14.0 % PAD Dirty 12.0 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 9450.0 9450 225 225 0 0 3724 5.6 5.6 1.0 PPA Scou 2413.3 11863 60 285 2413 2413 3716 1.5 7.1 3.0 PPA Scou 4449.7 16313 120 405 13349 15763 3782 3.0 10.1 Resume PAD 2100.0 18413 50 455 0 15763 3943 1.3 11.4 1.0 PPA 8647.6 27061 215 670 8648 24410 3940 5.4 16.8 2.0 PPA 9068.1 36129 235 905 18136 42546 3804 5.9 22.6 4.0 PPA 9278.9 45408 260 1165 37116 79662 4200 6.5 29.1 6.0 PPA 8630.4 54038 260 1425 51782 131444 4782 6.5 35.6 8.0 PPA 7446.1 61484 240 1665 59569 191013 5226 6.0 41.6 10.0 PPA 6115.8 67600 210 1875 61158 252171 5487 5.3 46.9 FLUSH 8785.8 76386 209 2084 0 252171 5445 5.2 52.1 Carbolite 16/20 The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 323.6 ft with an average conductivity (Kfw) of 16278.1 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 40 SLB Private Attachment K Section 30: Propped Fracture Simulation (Stage 10; 13732 ft MD) Initial Fracture Top TVD 4096.4 ft Initial Fracture Bottom TVD 4343.3 ft Propped Fracture Half-Length 323.6 ft EOJ Hyd Height at Well 246.8 ft Average Propped Width 0.19 in Net Pressure 208 psi Max Surface Pressure 5551 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 80.9 8.8 0.252 206 2.19 229.1 22513 80.9 161.8 7 0.236 206 2.09 253.8 20603 161.8 242.7 5.1 0.199 206 1.74 300.5 17165 242.7 323.6 1.8 0.087 200.8 0.86 750.1 6609 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 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: NDBi-049, 9 5/8” Liner Field Name: Pikka Company: Santos Rig: Parker 272 Region: North Slope State: Alaska Country: United States Prepared by: GCEA Alaska Version: Preliminary Report Santos USA and Baker Hughes Confidential Page 2 Contents Baker Hughes Legal Disclaimer ................................................................................................................................................................ 3 Executive Summary ........................................................................................................................................................................................... 4 Appendix I: Methodology of LWD Cement Bond Log Evaluation......................................................................................6 Santos USA and Baker Hughes Confidential Page 3 Baker Hughes Legal Disclaimer IN MAKING INTERPRETATIONS OF LOGS OUR EMPLOYEES WILL GIVE CUSTOMERS 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 The 9 5/8” liner was logged for Top of Cement (TOC)/Cement Bond Log (CBL) with the 6 ¾” SoundTrak LWD Acoustic tool while pulling out of the hole after drilling the 8 ½” hole section. The cement log was performed with the bottom hole assembly inside casing above the 9 5/8” shoe. The up-log depths ranged from 11,564 to 9,074’ MD. The TOC log was performed at ~1,000 feet per hour. The drilling parameters used to log the cement were 400 GPM and 120 RPM. The LWD Acoustic parameter file was optimized for TOC/CBL acquisition only to reduce logging time. Interpretation Summary 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 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 a more detailed interval inspection. The main zones of interest are defined below: - 9,074 ft MD to 10,400 ft MD: Poor to no cement presence above 10,400 ft MD. - 10,400 ft MD to 11,564 ft MD: Good Cement with some partial bonding. Please see the following screen shot covering the entire zone of interest. Full TOC and CBL logs/digital data are available for further discussion. -10,400 ft MD to 11,564 ft MD: Good Cement with some partial bonding. Santos USA and Baker Hughes Confidential Page 5 Poor to no cement observed above 10,400 ft MD. Santos USA and Baker Hughes Confidential Page 6 Appendix I: 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 successfully utilizing traditional non-azimuthal CBL techniques. Wireline Acoustic 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 one from the 5 ft spaced receiver for VDL (Variable Density Log). Figure 1: Traditional Wireline CBL technique. LWD Acoustic tool uses 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. Santos USA and Baker Hughes Confidential Page 7 Figure 2: CBL concept in "free" pipe Figure 3: CBL concept in cemented pipe Santos USA and Baker Hughes Confidential Page 8 Figure 4: General TOC log example Figure 5: LWD Acoustic tool and LWD CBL concept Current traditional offerings of LWD Acoustic 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 run. However, it is not a replacement for quantitative cement evaluation tools. Santos USA and Baker Hughes Confidential Page 9 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 T x R spacing (10.7 ft) for the 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 control 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 the LWD SoundTrak tool is recommended in scenarios where the cement slurry density is 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. Furthermore, adding this service can increase operational efficiency since it can be done in the same drilling trip and logging speed for TOC detection and CBL evaluation can be as high as ~1000 - 1500 ft/hr still providing good data quality. With combination semblance (SV), Delta-T Compressional, and the correlation image; the TOC can be detected in real-time (for final analysis it is recommended to compare real-time data with the memory data for access to the full waveforms). Santos USA and Baker Hughes Confidential Page 10 Good alignment between real-time and memory TOC can be seen in the following figure. Figure 7: LWD capability of Real-Time Top of Cement acquisition displayed in WellLink RT (left) versus Memory TOC log (right) on NDBi-049. 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 February 18, 2025 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. SFD 2/11/2025 (a)(2) Plat Provided with application. SFD 2/11/2025 (a)(2)(A) Well location Provided with application. Well lies in Sections 4, 5, 8, 7, and 6 of T11N, R6E, UM, and Section 1 of T11N, R5E, UM. SFD 2/11/2025 (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 Feb. 11, 2025), there are no wells are used for drinking water purposes are known to lie within ½ mile of the surface location of NDBi- 049. There are no subsurface water rights or temporary subsurface water rights within 18 miles of the surface location of NDBi-049. SFD 2/11/2025 (a)(2)(C) Identify all well types within ½ mile Provided with application. SFD 2/11/2025 (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 (-1,305’ TVDSS)); and DW-02 (223-039) ~21,500 mg/l SFD 2/11/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 February 18, 2025 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 2/11/2025 (a)(5) Casing and cementing information Provided with application. Proposed schematic attached, as built not generated to date. CDW 01/29/2025 (a)(6) Casing and cementing operation assessment 13-3/8” surface casing went as planned with no losses after cement turned corner and 47 bbl clean/uncontaminated cement to surface. 9-5/8” intermediate liner tie back. Stage tool at 5337 so cement from there to liner top of 2476 ft (132 ft overlap with 13-3/8” casing) Two stage cement job in 9-5/8” casing had losses in lower stage and losses in top stage though stage tool. SoundTrak interpretation says 10400-11564 ft MD good cement with some partial bonding. Casing shoe not logged down to 11639 ft. Perf/frac interval starts at 13732 ft. No issues with cement for the upcoming stimulation. 9-5/8” liner/tie back was pressure tested to 4000 psi pre-frac. 4.5” liner top packer set at 11438 which is within the cement logging interval which is interpreted as “good cement with partial bonding”. 4.5” tubing/tie back liner uncemented with open hole packers and frac sleeves. CDW 01/29/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 February 18, 2025 (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 2/11/2025 (a)(6)( B) Each hydrocarbon zone is isolated Yes: Surface casing was set at 2,608’ MD (-2,200’ TVDSS) and cemented with 47 bbls of clean cement returns at surface. For NDBi-049, a two-stage cement job for intermediate 9- 5/8” casing was conducted. Stage 2 was pumped through an Archer Cementing tool at 5,333’ MD (-2,757’ TVDSS). Vendor’s cementing report indicates 310 bbls of 15.3 ppg Versacem Type I/II cement were pumped. The vendor’s cementing report states full returns of 65 bbls. Vendor’s estimated TOC is 2,475’ MD (-2,126’ TVDSS), so the upper portion of the Tuluvak sand is isolated. Stage 1 cement pumped through casing shoe at 11,639’ MD (-3,761’ TVDSS). AOGCC’s (SFD) interpretation of the CBL places the top of consistent, excellent-quality cement at 10,470’ MD (-3,530’ TVDSS), which isolates the fracturing interval (top of frac interval at 13,133’ MD (-4,069’ TVDSS). So, cement isolates the hydrocarbon and fracturing zones. SFD 2/12/2025 (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 4300 psi MITIA planned, 5500 psi MITT plan. CDW 01/29/2025 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 10K psi wellhead max. frac. Pressure 7202 psi. Pump knock out 7800 and GORV 8500 psi., lines test 9200 psi. CDW 01/29/2025 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone Upper Confining Zones: About 586’ true vertical thickness (TVT) of claystone, shale and volcanic tuff assigned to the 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 February 18, 2025 (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 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 954’ TVT in this area and has an estimated fracture gradient of 11.7 ppg EMW (0.61 psi/ft). Lower Confining Zones: Lower Torok siltstone and shale that is about 900’ thick in this area with an estimated fracture gradient of 13.3 ppg EMW (0.69 psi/ft). SFD 2/12/2025 (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. There are 5 wells identified within ½ mile of NDBi-049 that penetrate the confining intervals. Oil Search has provided a table showing 2 abandoned and 3 active wells with confinement and cement log information. Qugruk 3 (212-187; Pilot Hole for Qugruk 3A): This well is plugged and abandoned. Well drilled to Nuiqsut then plugged back with cement plugs set and then tagged across the Nuiqsut and Alpine, Nanushuk, and Tuluvak. Cement plug isolates Nanushuk reservoir (Additional plugging details are provided within Operator’s application for Pikka NDB-014 (PTD No. 223-105; Sundry No. 324-085.) Qugruk 3A (213-031): This well is plugged and abandoned. Cement isolates the Nanushuk fracturing zone. Kicked off from Qugruk 3 and drilled to Nuiqsut. Cement plugs set across Nuiqsut, Alpine, Kup C, and Nanushuk 3 reservoir sand. Plug 2 is set from 4,177’ to 4,950’ MD (-3,913’ to -4,282’ TVDSS) across the Nanushuk 3 reservoir sand (4,489’ to 4,684’ MD, or -4,050’ to -4,150’ TVDSS). (Plugging details are provided SFD 2/12/2025 CDW 01/30/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 February 18, 2025 within Operator’s application for Pikka NDB-014 (PTD No. 223-105; Sundry No. 324-085.) NDB-046 (224-028): Nanushuk isolation provided by first stage of intermediate liner cement job. TOC around 10,300' MD. Good quality from that point down with a few intervals of patchiness. Fully covers top of Nanushuk Oil Pool at 11,369' MD. Pikka NDB-048 (224-143): Nanushuk is isolated by good- quality cement bonding. Upper portion of Tuluvak is covered by poor- to fair-quality cement bonding. Pikka NDB-051 (224-013): Nanushuk isolated with intermediate stage 1 cement. TOC of 9,250' MD. Good quality throughout. (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 None. The operator has identified one small fault (< 20’ of vertical displacement) of low-confidence using seismic data within a ½-mile radius of NDBi-049. It is unlikely that this fault will interfere with containment of the 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 2/12/2025 (a)(12) Proposed program for fracturing operation Provided with application. CDW 01/29/2025 (a)(12)(A) Estimated volume Provided with application. 11394 bbl total dirty vol. 1.33M lb total proppant CDW 01/29/2025 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 01/29/2025 (a)(12)(C) Chemical name and CAS number of each Provided with application. Schlumberger and Tracerco disclosures provided. Updated tracerco disclosure received. CDW 01/29/2025 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 01/29/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 6 February 18, 2025 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max surface pressure 7202 psi. Max. 8800 psi allowable treating pressure. 9200 psi line pressure test, pump knock out 7800 and 8500 psi global kickout. IA With 3800 psi back pressure IA (IA popoff set 4100 psi), max tubing differential should be 5000 psi. CDW 01/29/2025 (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 325' to 490' according to the Operator’s computer simulation. Computer simulation indicates the anticipated height of the induced fractures will range from 235' to 250' TVD, with the shallowest modeled TVD of about 4,131’ and deepest modeled TVD of about 4,173’. Induced fractures will remain within the Nanushuk interval and below the overlying confining Seabee Shale that is about 660’ thick in this area. (The boundary between Nanushuk and overlying Seabee lies at 11,561’ MD, -3,743’ TVDSS in NDBi-049). SFD 2/12/2025 (a)(13) Proposed program for post- fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. Gas flaring during flowback requested. Class I disposal wells at Pikka. CDW 01/29/2025 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 3800 psi back pressure, plan to test to 4300 psi, popoff set as 4100 psi CDW 01/29/2025 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 4.5” liner tie back to 4.5” tubing anchored at 11438 ft with liner packer which is within the interval logged by Soundrack interpretation of TOC of 10400 ft as “good cement with partial bonding” so packer approx. 1000 ft below TOC. First frac sleeve is.13732 ft CDW 01/29/2025 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 5500 psi plan. Max pressure differential is estimated as 5000 psi (8800 psi with 3800 psi backpressure) so test of 5500 psi satisfies 110% CDW 01/29/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist Pikka NDBi-049 (PTD No. 224-119; Sundry No. 325-027) Paragraph Sub-Paragraph Section Complete? AOGCC Page 7 February 18, 2025 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 9200 psi line pressure test, pump knock out 7800 and 8500 psi global kickout. IA PRV set as 4100 psi. CDW 01/29/2025 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 01/29/2025 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 4100 psi. Surface annulus open. Frac pressures continuously monitored. CDW 01/29/2025 (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 01/29/2025 (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 2/12/2025 (k) Confidential information Clearly marked and specific facts supporting nondisclosure Not applicable: This well is not confidential. SFD 2/12/2025 (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. LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDBi-049 (50-103-20894-0000) Final Well data Submittal - Details on following pages. Please note NO Mudlog services and only Density and Caliper were run in the 12.25” hole rection. No neutron data was acquired. 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: 1/9/2025 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 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: 224-119 T39945 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.09 13:27:43 -09'00' LETTER OF TRANSMITTAL جؐؐؐDirectional Survey ؒ NDBi-049 Definitive Compass Survey Report - NAD27.pdf ؒ NDBi-049 Definitive Compass Survey Report - NAD83.pdf ؒ NDBi-049 Definitive Survey - NAD27.txt ؒ NDBi-049 Definitive Survey - NAD83.txt ؒ NDBi-049 Definitive Survey Report.xlsx ؒ NDBi-049 Plan View.pdf ؒ NDBi-049 Vertical Section View.pdf ؒ جؐؐؐLog Digital Data and Plots (LWD) ؒ جؐؐؐBaker Hughes ؒ ؒ جؐؐؐDigital Data ؒ ؒ ؒ جؐؐؐAP ؒ ؒ ؒ ؒ NDBi-049_AP_R01_RM.las ؒ ؒ ؒ ؒ NDBi-049_AP_R02_RM.las ؒ ؒ ؒ ؒ NDBi-049_AP_R03_RM.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐFE ؒ ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft.las ؒ ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_R03_BROOH.las ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ ؒ NDBi-049_DMD_RM_19302ft.las ؒ ؒ ؒ NDBi-049_DMT_R01_RM.las ؒ ؒ ؒ NDBi-049_DMT_R02_RM.las ؒ ؒ ؒ NDBi-049_DMT_R03_RM.las ؒ ؒ ؒ ؒ ؒ جؐؐؐGeoscience Deliverables ؒ ؒ ؒ ؤؐؐؐSoundTrak- Acoustic Data ؒ ؒ ؒ جؐؐؐCBL ؒ ؒ ؒ ؒ NDBi-049_9_625_Liner_Baker_Hughes_CBL_Final Report.pdf ؒ ؒ ؒ ؒ NDBi-049_LWD_SDTK_CBL_9074-11564.cgm ؒ ؒ ؒ ؒ NDBi-049_LWD_SDTK_CBL_9074-11564.dlis ؒ ؒ ؒ ؒ NDBi-049_LWD_SDTK_CBL_9074-11564.las ؒ ؒ ؒ ؒ NDBi-049_LWD_SDTK_CBL_9074-11564.PDF ؒ ؒ ؒ ؒ NDBi-049_LWD_SDTK_CBL_9074-11564_dlis.txt ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐTOC ؒ ؒ ؒ NDBi-049_LWD_SDTK_TOC_9074-11564.cgm ؒ ؒ ؒ NDBi-049_LWD_SDTK_TOC_9074-11564.dlis ؒ ؒ ؒ NDBi-049_LWD_SDTK_TOC_9074-11564.las ؒ ؒ ؒ NDBi-049_LWD_SDTK_TOC_9074-11564.PDF LETTER OF TRANSMITTAL ؒ ؒ ؒ NDBi-049_LWD_SDTK_TOC_9074-11564_dlis.txt ؒ ؒ ؒ ؒ ؒ ؤؐؐؐGraphic Images ؒ ؒ جؐؐؐCGM ؒ ؒ ؒ جؐؐؐFE ؒ ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_2MD.cgm ؒ ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_2TVD.cgm ؒ ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_5MD.cgm ؒ ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_5TVD.cgm ؒ ؒ ؒ ؒ ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ ؒ ؒ NDBi-049_AP_RM.cgm ؒ ؒ ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ ؒ NDBi-049_DMD_RM_19302ft.cgm ؒ ؒ ؒ NDBi-049_DMT_RM.cgm ؒ ؒ ؒ ؒ ؒ ؤؐؐؐPDF ؒ ؒ جؐؐؐFE ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_2MD.pdf ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_2TVD.pdf ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_5MD.pdf ؒ ؒ ؒ NDBi-049_LWD_GR_Res_Den_Neu_Cal_RM_19302ft_5TVD.pdf ؒ ؒ ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ ؒ NDBi-049_AP_RM.pdf ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ NDBi-049_DMD_RM_19302ft.pdf ؒ ؒ NDBi-049_DMT_RM.pdf ؒ ؒ ؒ ؤؐؐؐHalliburton ؒ جؐؐؐCGM ؒ ؒ NDBi-049_LWD_MED_Resisitivity_19302ft_2MD&5MD.cgm ؒ ؒ NDBi-049_LWD_MED_Resisitivity_19302ft_2TVD&5TVD.cgm ؒ ؒ ؒ جؐؐؐEMF ؒ ؒ NDBi-049 MED Resistivity_19302ft_2MD&5MD.emf ؒ ؒ NDBi-049 MED Resistivity_19302ft_2TVD&5TVD.emf ؒ ؒ ؒ جؐؐؐLWD Data ؒ ؒ NDBi-049_LWD_MED_Resistivity_RM_19302.las LETTER OF TRANSMITTAL ؒ ؒ NDBi-049_STS_Image.dlis ؒ ؒ NDBi-049_STS_Image.ver ؒ ؒ ؒ جؐؐؐPDF ؒ ؒ NDBi-049_LWD_MED_Resisitivity_19302ft_2MD&5MD.pdf ؒ ؒ NDBi-049_LWD_MED_Resisitivity_19302ft_2TVD&5TVD.pdf ؒ ؒ ؒ ؤؐؐؐTIFF ؒ NDBi-049_LWD_MED_Resisitivity_19302ft_2MD&5MD.tif ؒ NDBi-049_LWD_MED_Resisitivity_19302ft_2TVD&5TVD.tif ؒ ؤؐؐؐMudlog NoMudlogServices.txt 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 22.82 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: ADL 3929874, 391445, 393023, 393022, 393021, 392958 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: GR-RES-NEU-DEN- Sonic 23. BOTTOM 20"x34" X-52 128' 13-3/8" L-80 2,270' 9-5/8" L-80 3,831' 9-5/8" L-80 2,197' 4-1/2" P-110S 4,095' 4-1/2" P-110S 3,794' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, See attached cement rptTie Back TUBING RECORD Uncemented 11,479' 19,177' See attached cement rpt 3,784' Surface 12-1/4" 8-1/2" 19,177' MD4-1/2" N/A BOTTOM 16" Grouted to surface Surface See attached cement rpt 47# Surface Surface 2,608' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil Search Alaska, LLC WAG Gas 12/10/24 224-119 50-103-20894-00-00 Pikka NDBi-0492275 FSL, 3457 FEL, S04, T11N, R6E, UM 4927 FSL, 1520 FEL, S01, T11N, R5E, UM LONS 19-003 11/12/24 19,302' MD / 4,071' TVD N/A 69. 601 W 5th Avenue, Anchorage, AK 99501-6301 421,786.71 5,972,663.37 4961 FSL, 3205 FEL, S07, T11N, R6E, UM CASING WT. PER FT.GRADE 12/03/24 CEMENTING RECORD 5,970,183.10 1,357' MD / 1,333' TVD SETTING DEPTH TVD 5,975,467.05 TOP HOLE SIZE AMOUNT PULLED 411,460.28 408,301.69 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A Surface Surface Per 20 AAC 25.283 (i)(2) attach electronic information 47# 2,476' 2,197' Surface 215# 68# 128' 2,476' 11,639' SIZE DEPTH SET (MD) See attached report PACKER SET (MD/TVD) 12.6# 11,438' Surface 42" 12.6# Tubing Flow Tubing Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet GeoSr Pet Eng Pikka / Nanushuk Oil Pool N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST Date of Test: Oil-Bbl: G s d 1 0 p dB P L (att Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:08 pm, Jan 02, 2025 Complete 12/10/2024 JSB RBDMS JSB 011325 G DSR-4/7/25SFD 3/25/2025BJM 3/19/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1,404' 1,378' Top of Productive Interval 13,133' 4,139' 1,052' 1,043' 1,801' 1,729' 2,381' 2,143' 3,015' 2,450' Tuluvak Sand 3,238' 2,510' TS_790 5,235' 2,816' 7,921' 3,218' 11,561' 3,812' NT8 MFS 11,783' 3,865' NT7 MFS 11,984' 3,913' NT6 MFS 12,165' 3,957' NT5 MFS 12,320' 3,994' NT4 MFS 12,622' 4,040' NT3 MFS 12,941' 4,116' 13,133' 4,139' 31. List of Attachments: Summary of Daily Operations, Packer Report, Cement Report, Directional Survey, Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Russell Conwell Digital Signature with Date:Contact Email:russell.conwell@santos.com Contact Phone: 1-907-615-2234 Authorized Title: Senior Drilling Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Middle Schrader Bluff Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Nanushuk MCU NT3.2 Tuluvak Shale Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Seabee Upper Schrader Bluff TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS NT3.2 Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov egoing is true and correct to the best o ,p 01/02/25 NDBi-049 Well Schematic 20" Insulated Conductor128' MD 9-5/8" Liner Hanger and Liner Top Packer2476' MD 13-3/8" 68 ppf L-80 Surface Casing2608' MD 9-5/8", 47ppf L-80 Int Liner11639' MD 4-½”, 12.6ppf P-110S Production Liner 19177' MD 4-½” Liner Hanger/ Top Packer11438' MD GL 69.67' RKB – Bottom Flange 12/11/2024 1 2 3 4 5 6 7 8 9 9-5/8" 47ppf L-80 Tieback2476' MD 9-5/8" Cflex Stage Tool5337' MD TOC First Stage Cement10400' MD 8-½” Openhole 19302' MD # Completion Item Top Depth (MD') Depth (TVD') Inc ID" OD" 1 X Landing Nipple 1556 1517 27 3.813 4.790 2 Gaslift Mandrel 1.5" 2192 2026 48 3.865 7.650 3 X Landing Nipple 2263 2072 51 3.813 4.790 4 X Landing Nipple 11289 3751 78 3.813 4.776 5 D/H Psi-Temp Gauge 11352 3765 77 3.905 6.000 6 X Landing Nipple 11374 3770 77 3.813 4.776 7 Tieback Seal Assy 11479 3794 77 3.908 5.220 8 9.625" x 4.5" LH/Packer 11438 3784 77 6.090 8.480 9 #12 Openhole Packer 13268 4153 85 3.918 8.000 10 #11 Openhole Packer 13378 4161 87 3.918 8.000 11 Stage 10 - Frac Sleeve 13732 4173 89 3.735 5.632 12 #10 Openhole Packer 14001 4172 90 3.918 8.000 13 Stage 9 - Frac Sleeve 14272 4170 90 3.735 5.630 14 #9 Openhole Packer 14542 4168 90 3.918 8.000 15 Stage 8 - Frac Sleeve 14853 4165 91 3.735 5.635 16 #8 Openhole Packer 15122 4162 91 3.918 8.000 17 Stage 7 - Frac Sleeve 15432 4160 90 3.735 5.628 18 #7 Openhole Packer 15702 4157 90 3.918 8.000 19 Stage 6 - Frac Sleeve 16014 4155 90 3.735 5.623 20 #6 Openhole Packer 16326 4153 90 3.918 8.000 21 Stage 5 - Frac Sleeve 16598 4151 90 3.735 5.635 22 #5 Openhole Packer 16865 4149 90 3.918 8.000 23 Stage 4 - Frac Sleeve 17177 4147 90 3.735 5.630 24 #4 Openhole Packer 17448 4145 90 3.918 8.000 25 Stage 3 - Frac Sleeve 17755 4143 91 3.735 5.632 26 #3 Openhole Packer 18021 4140 90 3.918 8.000 27 Stage 2 - Frac Sleeve 18334 4138 91 3.735 5.632 28 #2 Openhole Packer 18642 4135 90 3.918 8.000 29 Stage 1 - Frac Sleeve 18833 4131 93 3.735 5.634 30 #1 Openhole Packer 18978 4122 95 3.918 8.000 31 #2 Toe Sleeve 19085 4110 98 3.500 5.750 32 #1 Toe Sleeve 19097 4108 99 3.500 5.750 33 WIV Collar 19160 4098 100 0.870 5.610 34 Float Collar #2 19173 4096 100 3.980 5.220 35 Float Collar #1 19174 4095 100 3.980 5.220 36 Eccentric shoe 19176 4095 100 3.290 5.190 Page 1 of 1 Packer Set Depths - NDBi-049 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Original Hole SLZXP Liner Top Hanger Packer w/centralizer 11,459.5 3,789.2 Original Hole HES Zoneguard OH Packer #12 13,274.9 4,153.3 Original Hole HES Zoneguard OH Packer #11 13,383.2 4,161.2 Original Hole HES Zoneguard OH Packer #10 14,007.9 4,171.3 Original Hole HES Zoneguard OH Packer #9 14,548.2 4,167.5 Original Hole HES Zoneguard OH Packer #8 15,128.3 4,162.3 Original Hole HES Zoneguard OH Packer #7 15,708.6 4,157.4 Original Hole HES Zoneguard OH Packer #6 16,332.5 4,152.9 Original Hole HES Zoneguard OH Packer #5 16,871.8 4,149.4 Original Hole HES Zoneguard OH Packer #4 17,454.6 4,145.1 Original Hole HES Zoneguard OH Packer #3 18,027.2 4,140.2 Original Hole HES Zoneguard OH Packer #2 18,648.7 4,135.2 Original Hole HES Zoneguard OH Packer #1 18,984.6 4,121.4 Page 1 of 1 Cement - NDBi-049 Surface Casing Cement Surface Casing Cement, Casing, 11/15/2024 08:00 Type Casing Cementing Start Date 11/15/2024 Cementing End Date 11/15/2024 Wellbore Original Hole String Surface Casing, 2,608.3ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results 47 bbls clean cement returned to surface. Comment Cement 13-3/8” Surface Casing as follows: -Fill lines with 5 water and pressure test to 3,500 psi for 5 minutes -Drop 1st Bottom Non-Rotating Plug -Pump 80 bbls of 10.5 ppg Tuned Spacer at 5.0 bpm, 200 psi. -Release 2nd Bottom Non-Rotating Plug -Pump 364 bbls of 11.0 ppg ArcticCem lead cement at 4 bpm, Excess Volume 150% (806 sacks, yield 2.535 cu.ft/sk) -Pump 65 bbls of 15.3 ppg Type I/II tail at 4 bpm, Excess Volume 50% (312 sacks, yield 1.24 cu.ft/sk) -Drop top plug and chase with 2 bbls Tail Cement -Perform displacement with rig pumps and 9.5 ppg mud -300 bbls displaced at 8 bpm: ICP 440 psi 17% return flow, FCP 750 psi -40 bbls displaced at 6 bpm: ICP 600 psi, FCP 662 psi. -Reduce rate to 3 bpm prior to plug bump: Final circulating pressure 510 psi prior to plug bump. -Bump plug and increase pressure to 1,050 psi, check floats – good. -Total displacement volume 353 bbls (measured by strokes at 96% pump efficiency). -Observed 113 bbls of interface (mud/mud push/cement contaminated) returns and 47 bbls clean cement to surface. A total of 175 bbls were dumped to the cuttings box. -Total losses from cement exit shoe to cement in place: 0 bbls 1, 0.0-2,618.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 2,618.0 Full Return? Yes Vol Cement Ret (bbl) 47.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 5 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 662.0 Plug Bump Pressure (psi) 510.0 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 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 (%) 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) 806 Class ArcticCem Volume Pumped (bbl) 364.0 Estimated Top (ftKB) 2,618.0 Percent Excess Pumped (%) 150.0 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) 65.0 Estimated Top (ftKB) 2,618.0 Percent Excess Pumped (%) 50.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.68 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 24.8 Thickening Time (hr) 4.50 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 11.50 Page 1 of 1 Cement - NDBi-049 Intermediate Casing Cement - 1st Stage Intermediate Casing Cement - 1st Stage, Casing, 11/27/2024 08:00 Type Casing Cementing Start Date 11/27/2024 Cementing End Date 11/27/2024 Wellbore Original Hole String Intermediate Liner, 11,639.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Baker Soundtrack LWD Cement Evaluation Results Comment Conduct 1st Stage Cement Job of 9-5/8” 47# L-80 Hyd 563 Intermediate Liner. - Fluid pack lines, pressure test to 5000 psi. - Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A downhole at 3 bpm, ~50% returns. - Release bottom pump down plug for bottom plug, pump 109 bbls 15.3 ppg Versacem Tail Cement Type I/II (493 sacks, yield 1.237 cu ft/sk – 1st 10 bbls Neat and last 39 bbls Neat without Bridgemaker II LCM), excess volume 30%, at 3 bpm, average circulating pressure 300 psi. ~40% returns throughout cement pumping. - Release top pump down plug, chase plug with displacement by rig pumps, displace with 11.5 ppg OBM at 3 bpm, ICP 80 psi. Average ~37% returns during displacement. - Bottom plug landed on calculated strokes at 3 bpm, 310 psi circ pressure, shear with drop in circulating pressure to 265 psi and maintain 3 bpm as cement exits shoe. - Circulating pressure with cement turning shoe 280 ICP. - Maintain 3 bpm to plug bump, FCP 407 psi; ~41% returns with cement around shoe. - Bump plug, hold for 5 minutes, to check floats, floats held, CIP 1500 hrs. - Total displacement volume 705 bbls (measured by strokes at 96% pump efficiency). - Total surface returns losses from cement exit shoe to cement in place: 88 bbls (rig team estimation is that final lift pressure and consistent return rate suggests full cement placement across interval with loss zone higher in formation). * Note: Report of release of coolant into containment from cementing unit coolant overfill reservoir. Notifications made, Spill Tech reports <1 cup into containment, possibly 1 teaspoon to ground observed. Spill Tech cleaned up. 1, 10,219.0-11,644.0ftKB Top Depth (ftKB) 10,219.0 Bottom Depth (ftKB) 11,644.0 Full Return? No Vol Cement Ret (bbl) Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 2 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 3 Final Pump Pressure (psi) 407.0 Plug Bump Pressure (psi) 1,225.0 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 w/4# Red Dye, 65 gal Surfactant B & Musol A 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 Tail (Type 1/2) w/5lb/bbl Bridgemaker II LCM Amount (sacks) 493 Class Type I/II Volume Pumped (bbl) 109.0 Estimated Top (ftKB) 8,400.0 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) 7.10 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 12.51 Page 1 of 1 Cement - NDBi-049 Intermediate Casing Cement - 2nd stage Intermediate Casing Cement - 2nd stage, Casing, 11/28/2024 02:00 Type Casing Cementing Start Date 11/28/2024 Cementing End Date 11/28/2024 Wellbore Original Hole String Intermediate Liner, 11,639.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results 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 3 bpm, ICP 266 psi, FCP 134 psi, 0 bbls lost during this phase. -Mix and pump 80 bbls of 13.5 Tuned Spacer at 3 bpm, ICP 151 psi. FCP 160 psi. Full returns no losses. -Mix and pump 310 bbls of 15.3 ppg. Versacem Type I/II Tail cement at 4.0 bpm, ICP 212 psi, FCP 454 psi, 6 bbls lost lost during this phase. -Excess Volume 100% (1417 sacks, yield 1.236 cu ft/sk). -Begin displacing with 2 bbls fresh water from cementing unit. -Continue to displace with 117 bbls 11.5 ppg OBM using rig pumps. -Displace to calculated volume of 117 bbls to Archer Stage Collar. -Displace at 4 bpm, 109 psi ICP, 482 FCP before slowing rate, 100% returns; FCP at 3 bpm 389 psi. -42 bbls lost during displacement. -CIP at 05:00 hrs. 2, 2,475.0-5,333.0ftKB Top Depth (ftKB) 2,475.0 Bottom Depth (ftKB) 5,333.0 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) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 389.0 Plug Bump Pressure (psi) 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 Mix and pump 80 bbls of 12.5 ppg Mud Flush at 3 bpm, ICP 266 psi, FCP 134 psi 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 (%) 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 Mix and pump 80 bbls of 13.5 Tuned Spacer at 3 bpm, ICP 151 psi. FCP 160 psi, 0 bbls lost during spacer pumping. 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 (%) 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 1/2) Amount (sacks) 1,410 Class Type I/II Volume Pumped (bbl) 310.0 Estimated Top (ftKB) Percent Excess Pumped (%) 100.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) Density (lb/gal) 15.30 Plastic Viscosity (cP) 131.8 Thickening Time (hr) 6.65 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 18.43 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/11/2024 11/12/2024 0 One Incident. No Accidents, No Spills. Complete rig move checklist for moving off of well NDB-037 (rig release 12:00 hrs on 11/11/2024). Move rig modules, stage in and rig up for operations on well NDBi-049. Work to complete rig acceptance checklist. Rig module contacted light plant. Security notified, directed to stop movement of module until Security takes pictures – did not stop progress of move. 11/12/2024 11/13/2024 128 121.00 9.00 No Accidents, No Incidents, No Spills. Electrician calibrated and tested Gas and Fire alarms. Take on fluids, calibrate and test PVT sensors, test Totco gas watch at flow line. Nipple up 21-1/4” Diverter System, Function test Diverter Knife Valve and Annular. AOGCC rep Guy Cook waived witness on 11/11/2024. Make up 16” Surface Drilling BHA #1. Run in hole and Spud well. Drill ahead in 16” Hole Section per DD plan to 249’ md. POOH and pick up directional tools, scribe motor. 11/13/2024 11/14/2024 249 1,876.00 9.35 No Accidents, No Incidents, No Spills. P/U 16” Surface BHA from 117’ to 249’ MD. Drill 16” Surface hole from 249’ to 764’ MD. Perform Rig Service. Drill 16” Surface hole from 764’ to 1,807’ MD. Circulate BU 3X. POOH from 1,611’ to 860’ MD. RIH from 860’ to 1,806’ MD. Drill 16” Surface hole from 1,807' to 2,125’ MD. 11/14/2024 11/15/2024 2,125 493.00 9.60 No Accidents, No Incidents, No Spills. Drill 16” Surface hole from 2,125’ to TD at 2,618’ MD. CBU 3X. BROOH from 2,373’ to 1,610’ MD. POOH on elevators from 1,610’ to 954’ MD. Backream from 954’ to 860’ MD. Wiper trip from 860’ to 1,807’ MD. Circulate and condition hole for 13-3/8” Surface casing run. POOH & LD BHA. Rig up 13-3/8” casing running equipment. Run 13-3/8” 68#, L-80, TXP-BTC Casing to 166’ MD. 11/15/2024 11/16/2024 2,618 0.00 9.55 No Accidents, No Incidents, No Spills. Run 13-3/8” 68#, L-80, TXP-BTC Casing from 166’ to to 1,337’ MD. Work through tight spot at 1,337’ MD. Run 13-3/8” 68#, L-80, TXP-BTC Casing from 1,361’ to 2,608’ MD. M/U casing hanger and landing joint, land casing hanger. Circulate and condition mud prior to Surface cement job. Cement 13-3/8” Surface Casing. Pump 80 bbls of 10.5 ppg Tuned Spacer. Pump 364 bbls of 11.0 ppg ArcticCem Lead Cement. Pump 65 bbls of 15.3 ppg Type I/II tail. Displace with 9.5 ppg mud. 47 bbls clean cement returns to surface, total 175 bbls dumped to cuttings box. Cement in place at 19:00 hrs, FCP 510 psi. Contacted AOGCC for witness of upcoming BOPE Test at 05:48 hrs. AOGCC Rep Brian Bixby replied at 05:56 that he will witness test. RD cement equip & casing tools. ND Surface Stack & Diverter line. 11/16/2024 11/17/2024 2,618 0.00 9.50 No Accidents, No Incidents, No Spills. ND Surface Stack & Diverter line. Install wellhead as per FMC rep. NU & Test 13-5/8" BOPE to 250 psi low, 3,600 psi high for 5 minutes each. Test with 5-7/8” and 9-5/8” test joints, test annular with 5-7/8” Joint. BOPE tests began at 12:00 and concluded at 15:30, all tests successful. Test witnessed by AOGCC Rep. Brian Bixby. BOP Configuration: 13-5/8” 5k Annular, 13-5/8” 5k Double Gate rams with 4-1/2” x 7” Upper Rams, 13-5/8” 5k Double Gate rams with Blind / Shear Lower Rams, 13-5/8” Mud Cross, 13-5/8” 5k Single Gate rams with 9-5/8” Fixed Rams. Pressure test MPD system. Pressure test 13-3/8 Surface casing to 2,600 psi for 30 min - good test (4.8 bbls pumped, 4.8 bbls bled back). Cut & slip drill line. MU 12-1/4” Intermediate BHA as per Baker DD/MWD. 11/17/2024 11/18/2024 2,618 1,027.00 11.50 No Accidents, No Incidents, No Spills. MU 12-1/4” Intermediate BHA & RIH from 427' to 2,410' MD. Wash down from 2,410’ and tag plugs at 2,516’ MD. Drill shoe track and cement from 2,515’ to 2,600’ MD. Install Beyond MPD bearing. Obtain parameters & Connection Practices with rig crew. Drill out remaining shoe track and 20’ new formation from 2,600’ to 2,638’ MD. Circulate & condition mud prior to FIT. Perform FIT test: Mud wt: 11.5 ppg OBM, 2,275’ TVD, 2,638’ MD. Pump 0.8 bbls to 361 psi, bleed back 0.8 bbls. FIT EMW = 14.55 ppg. Drill 12-1/4” Intermediate hole from 2,638’ to 3,645’ MD. 11/18/2024 11/19/2024 3,645 3,000.00 11.45 No Accidents, No Incidents, No Spills. Drill 12-1/4” Intermediate hole from 3,645’ to 6,645’ MD, maintaining static 13.0 EMW on connections with MPD. 11/19/2024 11/20/2024 6,645 3,100.00 11.50 No Accidents, No Incidents, No Spills. Drill 12-1/4” Intermediate hole from 6,645’ to 9,745' MD, maintaining static 13.0 EMW on connections with MPD. Well Name Wellbore Name PTD # Start Drill Date End Drill Date Page 1 of 4 Well Name NDBi-049 Wellbore Name Original Hole PTD # 224-119 Start Drill Date 2/10/2024 End Drill Date 12/11/2024 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/20/2024 11/21/2024 9,745 1,899.00 11.55 No Accidents, No Incidents, No Spills. Drill 12-1/4” Intermediate hole from 9,745’ to 11,314' MD, maintaining static 13.0 EMW on connections with MPD. Open Bypass line on MPD skid, remove & clean both chokes. Drill 12- 1/4” Intermediate hole from 11,314’ to TD at 11,644’ MD, maintaining static 13.0 EMW on connections with MPD. Circulate and condition 4X bottoms up from 11,644’ to 11,512’ MD. RIH from 11,512’ to 11,638’ MD. Drop 2.5” ball to open Well Commander. Low energy backream from 11,638’ to 11,417’ MD, while holding 150-200 psi backpressure with MPD. 11/21/2024 11/22/2024 11,644 0.00 11.65 No Accidents, No Incidents, No Spills. Low Energy Back Ream from 11,417’ to 2,602’ MD. Close Well Commander. Circulate BU 2X inside 13-3/8” casing shoe. RIH performing top-down cleanup cycles in 500' increments from 2,602’ to 4,411’ MD, RIH at 200 gpm, maintaining 200-220 psi back pressure with MPD. 11/22/2024 11/23/2024 11,644 0.00 11.60 No Accidents, No Incidents, No Spills. Continue clean up cycle at 4,411’ MD. RIH from 4,411’ to 4,977’ MD and perform clean up cycle. RIH from 4,977’ to 5,534’ MD and perform clean up cycle. RIH from 5,534’ to 6,110’ MD and perform clean up cycle. Packoff while staging up with 81 bbls mud losses. RIH from 6,110’ to 6,770’ MD and perform clean up cycle. RIH from 6,770’ to 7,812’ MD and perform clean up cycle. RIH from 7,812’ to 9,706’ MD and perform clean up cycle. RIH from 9,706’ to 11,644’ MD and perform clean up cycle. 11/23/2024 11/24/2024 11,644 0.00 11.60 No Accidents, No Incidents, No Spills. Perform clean up cycle at 11,644’ MD. Pull out of hole on elevators from 11,411’ to 11,275’ MD. RIH from 11,275’ to 11,405’ MD. BROOH from 11,405’ to 11,222’ MD for additional clean up. Drop 2.5” Ball to open well commander. LEBR out from 11,222’ to 9,987’ MD. Stripping out of the hole from 9,987’ to 4,595’ MD. Daily losses to formation: 65 bbls. 11/24/2024 11/25/2024 11,644 0.00 11.65 No Accidents, No Incidents, No Spills. Strip out of the hole from 4,595’ to inside casing shoe at 2,602’ MD. Drop ball and close Well Commander. Circulate bottoms up. Strip out of the hole to 427' MD. Lay down 12 ¼” Intermediate BHA. R/U casing equipment, test equipment and confirm proper operation. Run 9- 5/8”, 47#, L-80, Hyd 563 Liner to 2,600’ MD. Circulate bottoms up at 2,608' MD. Continue to run 9-5/8”, 47#, L-80, Hyd 563 Liner from 2,600’ – 4,070’ MD. 11/25/2024 11/26/2024 11,644 0.00 11.70 No Accidents, No Incidents, No Spills. Run 9-5/8”, 47#, L-80, Hyd 563 Liner from 4,070’ – 9,130' MD. Rig down TRS Casing Equipment. Make up liner hanger/packer assembly. Run 9-5/8”, 47#, L-80, Hyd 563 Liner on DP/HWDP from 9,171’ – 10,118’ MD. 345 bbls mud losses for the day. 11/26/2024 11/27/2024 11,644 0.00 11.55 No Accidents, One Incident, No Spills. Run and land 9-5/8”, 47#, L-80, Hyd 563 Liner on 5-7/8” DP/HWDP with shoe at 11,639’ MD. Circulate ball down, set Liner Hanger at 2,496’ MD. Conduct preventative rig maintenance and offload drill pipe / BHA while waiting on mud system blend and delivery from Prudhoe Bay mud plant. 214 bbls mud losses for the day while running liner and circulating. 11/27/2024 11/28/2024 11,644 0.00 11.60 No Accidents, No incidents. Minor release. Non-recordable release of <1 cup of coolant into containment from cement unit. Conduct preventative rig maintenance until mud arrives from mud plant. Stage up circulation, conduct Intermediate first stage cement job of 9-5/8” 47# L-80 Hyd 563 liner: Pump 80 bbls 12.5 ppg Tuned Spacer. Pump 109 bbls 15.3 ppg Versacem Tail Cement Type I/II, excess volume 30%. Displace with 11.5 ppg OBM. Circulating pressure with cement turning shoe 280 ICP, FCP 407 psi. CIP 15:00 hrs. No Spacer or cement returns to surface. Circulate above Liner Hanger, POOH with running tool and lay down. Make up and run in hole with Archer C-flex cement BHA. Page 2 of 4 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/28/2024 11/29/2024 11,644 0.00 11.55 No Accidents, No Incidents. 2 cu.ft dry cement to pad. Function open C-flex, conduct Intermediate Second Stage cement job of 9-5/8” 47# L-80 Hyd 563 liner as follows: Pump 80 bbl 12.5 ppg Tuned Spacer followed by 80 bbls 13.5 ppg Tuned Spacer. Pump 310 bbls 15.3 ppg Versacem Tail Cement Type I/II, excess volume 100%. Displace with 11.5 ppg OBM. Circulating pressure with cement exiting C-flex into OH Annulus 390 ICP, FCP 455 psi. CIP 05:00 hrs. Total returns to surface: 50 bbls contaminated OBM/Spacer, 140 bbls Spacer, 35 bbls contaminated cement, 65 bbls pure cement. Set Liner Top Packer. POOH with Archer C-flex cement BHA. Flush stack. Make up, run in hole with Polish Mill BHA. Polish off liner top per plan. POOH with assembly. Pull Wear Ring, flush across hanger profile. Rig up, run 9-5/8” 47# L-80 Hyd 563 Tie-Back assembly. Sent AOGCC BOP Test request at 09:10 hrs on 11/28/2024; received witness waive from AOGCC Rep Kam St. John at 09:30 hrs, 11/28/2024. 11/29/2024 11/30/2024 11,644 0.00 11.55 No Accidents, No Incidents, No Spills. Pressure test seal assembly to 2600 psi for 10 mins: Good test. Install pups for space out, land 9-5/8” tie back. Freeze protect annulus with 149 bbls 6.8 ppg diesel. Conduct 30-min No-flow test of annular: No inflow. Conduct 30-min annular test to 2600 psi on chart for 30 minutes, 3 bbls pumped in and bled back: Good test. Drain stack, back out running tool, rig down casing tools. Install/test casing packoff, 5K for 10 min. C/O saver sub to 544 fill, flush and fill BOP stack, build test joints, test plug, test alarms. Rig up, test BOPE to 250 psi low/3600 psi high with 5” and 4-1/2” test joints, test annular with 4-1/2” joint, tested 15 valves, all equipment passed, test witness waived by AOGCC Rep Kam St. John at 09:30 hrs on 11/28/2024, test start 12:30 hrs, test end 18:30 hrs. Conduct 9-5/8” casing pressure test to 3500 psi for 30 minutes: Good test, 19.6 bbls pumped in, 19.6 bbls bled back. Pick up Baker 8-1/2” AutoTrak directional BHA. 11/30/2024 12/1/2024 11,644 180.00 9.10 No Accidents, No Incidents, No Spills. Make up and run in hole with 8-1/2” Production Drilling BHA, drill out plugs and float collar, displace from 11.5 ppg OBM to 9.2 ppg OBM while drilling out. Drill out shoe,circulate bottoms up 2x, install MPD bearing and drill new formation to 11,664’. Pull into shoe, conduct LOT to 14.5 ppg EMW (1051 psi) with 9.2 ppg OBM. Volume pumped in 3.2 bbls, volume bled back 2.7 bbls. Drill ahead in 8-1/2” Production hole section from 11,664’ to 11,824’ md. 12/1/2024 12/2/2024 11,824 2,406.00 9.20 No Incidents, No Accidents, No Spills. Drill 8-1/2” Production Hole using MPD from 11,824’ to 14,230' md (4170' TVD). 12/2/2024 12/3/2024 14,230 3,005.00 9.20 No Incidents, No Accidents, No Spills. Drill 8-1/2” Production Hole using MPD from 14,230’ to 17,235' md (4147' TVD). 12/3/2024 12/4/2024 17,235 2,067.00 9.30 No Incidents, No Accidents, No Spills. Drill ahead in 8-1/2” Production Hole section from 17,235’ to TD of 19,302’ md using MPD. Circulate two bottoms up from 19,302’ to 19,110’ md. Backream from 19,110’ to 18,348’ md. 12/4/2024 12/5/2024 19,302 0.00 9.30 No Incidents, No Accidents, No Spills. Backream out of hole from 18,348' to 12,260' md. 12/5/2024 12/6/2024 19,302 0.00 11.50 No Incidents, No Accidents, No Spills. Backream from 12,260’ md, pull into 9-5/8” shoe at 11,644’ md, circulate bottoms up 2x, check trip to 12,170' md stripping in and back out to shoe, conduct Sonic log of cement from shoe to 9200’ md holding backpressure. Displace to 11.5 ppg OBM from 9200’ md. Strip out of hole from 9220’ to 6841’ md. 12/6/2024 12/7/2024 19,302 0.00 11.50 No Incidents, No Accidents, No Spills. Strip out of hole from 6841’ to 955’ md. Flow check, pull and stand back RCD Bearing Assembly. POOH while laying down BHA. BHA in good shape, bit grade 1-1-WT-A-X-I-NO-TD. Make up and run in hole with Reverse Circulating Junk Basket (RCJB)/String Mill cleanout BHA to C-flex depth of 5337’ md. Conduct cleanout operations, open circ sub and CBU from 5500’. POOH with BHA and lay down. Pull drilling wear ring, install wear ring with filter screen. Page 3 of 4 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/7/2024 12/8/2024 19,302 0.00 11.40 No Incidents, No Accidents, No Spills. Function test and Jet BOP, pull filter wear bushing and install regular wear bushing. Rig up and run 4-1/2” 12.6# P-110S Hyd 563 Lower Completion Assembly per running summary. Cross over to 5” drill pipe and install MPD Bearing, displace from 11.5 ppg OBM to 9.2 ppg OBM at 9274’. Continue to run in hole on 5” drill pipe per program. 12/8/2024 12/9/2024 19,302 0.00 9.80 No Incidents, No Accidents, No Spills. Strip in using MPD with 4-1/2” 12.6# P-110S Hyd 563 Lower Completion Assembly from 11,270’ to 19,177' md. Perform pit management for upcoming displacement. 12/9/2024 12/10/2024 19,302 0.00 9.26 No Incidents, No Accidents, No Spills. Displace to 9.2 ppg NaCl Brine from TD. Close WIV, set Liner Hanger/Packer, and release HRDE. Set openhole packers. Pressure test annulus to 3500 psi. Pressure up to 3620 psi and hold for 10 mins for Liner Top Packer verification test, 80 psi bleed off in 10 mins to 3540 psi; Good test. Displace upper hole section to 9.2 ppg NaCl Brine with corrosion inhibitor and Biocide. Flow check, pick up and remove RCD Bearing. POOH with running assembly, lay down tools. Pull wear bushing, rig up and run in the hole with 4-1/2” 12.6# P-110S Hyd 563 Upper Seal Bore Completion Assembly to 200’ md. Install and test temp/psi gauge. 12/10/2024 12/11/2024 19,302 0.00 9.26 No Incidents, No Accidents, No Spills. Run 4.5” 12.6# P-110S TSH563 Upper Completions Tie Back from 200’ to 11395’. Circulate to clean above Completion SBR. Spaceout, terminate control line, land hanger and upper completion.. Land hanger, L/O landing joint. Pressure test tubing to 3700 psi for 30 minutes. 3.9 bbls pumped and 3.9 bbls returned. Good MIT-T test. Pressure test IA to 4000 psi for 30 min. 8.9 bbls pumped and 8.9 bbls returned. Good MIT-IA test. Sheer circulation valve. 12/11/2024 12/11/2024 19,302 0.00 9.26 No Incidents, No Accidents, No Spills. Perform freeze protect to 1,500' TVD. Pump 105 bbls of 6.8 ppg diesel down IA at 2.5 bpm, initial pressure of 70 psi and final circulating pressure of 270 psi.. Install TWC and test both ways to 2500 psi for 10 mins - good test. N/D BOP’s and N/U frac tree and pressure test same. Rig Released 12/11/24 @ 1530 - See reports for NDB-048. Page 4 of 4 12 D e c e m b e r , 2 0 2 4 De s i g n : N D B i - 0 4 9 Pi k k a ND B B- 4 9 ND B i - 0 4 9 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e Ma p S y s t e m : Ge o D a t u m : Pr o j e c t Ma p Z o n e : Sy s t e m D a t u m : US S t a t e P l a n e 1 9 2 7 ( E x a c t s o l u t i o n ) NA D 1 9 2 7 ( N A D C O N C O N U S ) Pi k k a , N o r t h S l o p e A l a s k a , U n i t e d S t a t e s Al a s k a Z o n e 0 4 Me a n S e a L e v e l Us i n g W e l l R e f e r e n c e P o i n t Us i n g g e o d e t i c s c a l e f a c t o r Si t e P o s i t i o n : Fr o m : Si t e La t i t u d e : Lo n g i t u d e : Po s i t i o n U n c e r t a i n t y : No r t h i n g : Ea s t i n g : Gr i d C o n v e r g e n c e : ND B us f t Ma p us f t us f t ° -0 . 5 9 Sl o t R a d i u s : " 36 5, 9 7 2 , 9 0 9 . 1 3 42 3 , 3 8 3 . 6 2 0. 9 70 ° 2 0 ' 1 0 . 1 3 2 N 15 0 ° 3 7 ' 1 7 . 7 9 4 W We l l We l l P o s i t i o n Lo n g i t u d e : La t i t u d e : Ea s t i n g : No r t h i n g : us f t +E / - W +N / - S Po s i t i o n U n c e r t a i n t y us f t us f t us f t Gr o u n d L e v e l : B- 4 9 us f t us f t 0. 0 0. 0 5, 9 7 2 , 6 6 3 . 3 7 42 1 , 7 8 6 . 7 1 22 . 8 We l l h e a d E l e v a t i o n : us f t 0. 5 70 ° 2 0 ' 7 . 5 5 3 N 15 0 ° 3 8 ' 4 . 3 5 8 W We l l b o r e De c l i n a t i o n (° ) Fi e l d S t r e n g t h (n T ) Sa m p l e D a t e D i p A n g l e (° ) ND B i - 0 4 9 Mo d e l N a m e Ma g n e t i c s BG G M 2 0 2 4 4 / 1 2 / 2 0 2 4 1 3 . 9 5 8 0 . 5 5 5 7 , 1 4 0 . 5 4 9 2 5 8 0 1 Ph a s e : Ve r s i o n : Au d i t N o t e s : De s i g n ND B i - 0 4 9 1. 0 AC T U A L Ve r t i c a l S e c t i o n : D e p t h F r o m ( T V D ) (u s f t ) +N / - S (u s f t ) Di r e c t i o n (° ) +E / - W (u s f t ) Ti e O n D e p t h : 46 . 9 28 1 . 1 5 0. 0 0. 0 46 . 9 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 2 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e Fr o m (u s f t ) Su r v e y P r o g r a m De s c r i p t i o n To o l N a m e Su r v e y ( W e l l b o r e ) To (u s f t ) Da t e 12 / 1 2 / 2 0 2 4 SD I _ U R S A 1 _ I 4 S D I U R S A - 1 g y r o M W D ( I S C W S A R e v 4 ) 69 . 7 5 9 4 . 8 0 1 S D I U R S A G y r o M W D 1 6 i n H o l e < 4 6 - 59 3_ M W D + I F R 2 + M S + S a g A0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 69 1 . 7 2 , 5 4 6 . 6 0 2 B H O n t r a K 1 6 i n H o l e < 6 9 1 - 2 5 4 6 > ( ND B 3_ M W D + I F R 2 + M S + S a g A0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 2, 6 4 4 . 8 1 1 , 6 0 4 . 0 0 3 B H O n t r a K 1 2 . 2 5 i n H o l e < 2 6 4 4 - 1 1 6 0 3 > 3_ M W D + I F R 2 + M S + S a g A0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 11 , 6 7 0 . 8 1 9 , 3 0 2 . 0 0 4 B H O n t r a K 8 . 5 i n H o l e < 1 1 6 7 0 - 1 9 2 7 6 > MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 46 . 9 0 . 0 0 0 . 0 0 4 6 . 9 - 2 2 . 8 0 . 0 0 . 0 5 , 9 7 2 , 6 6 3 . 3 7 4 2 1 , 7 8 6 . 7 1 0 . 0 0 0 . 0 69 . 7 0 . 0 0 0 . 0 0 6 9 . 7 0 . 0 0 . 0 0 . 0 5 , 9 7 2 , 6 6 3 . 3 7 4 2 1 , 7 8 6 . 7 1 0 . 0 0 0 . 0 12 8 . 0 0 . 1 8 2 5 1 . 0 2 1 2 8 . 0 5 8 . 3 0 . 0 - 0 . 1 5 , 9 7 2 , 6 6 3 . 3 4 4 2 1 , 7 8 6 . 6 2 0 . 3 0 0 . 1 20 " C o n d u c t o r C a s i n g 12 9 . 3 0 . 1 8 2 5 1 . 0 2 1 2 9 . 3 5 9 . 6 0 . 0 - 0 . 1 5 , 9 7 2 , 6 6 3 . 3 4 4 2 1 , 7 8 6 . 6 2 0 . 3 0 0 . 1 18 4 . 6 0 . 2 6 2 3 8 . 3 6 1 8 4 . 6 1 1 4 . 9 - 0 . 1 - 0 . 3 5 , 9 7 2 , 6 6 3 . 2 5 4 2 1 , 7 8 6 . 4 3 0 . 1 7 0 . 2 27 9 . 0 0 . 1 8 2 4 4 . 6 9 2 7 9 . 0 2 0 9 . 3 - 0 . 3 - 0 . 6 5 , 9 7 2 , 6 6 3 . 0 8 4 2 1 , 7 8 6 . 1 1 0 . 0 9 0 . 5 37 1 . 2 0 . 4 4 2 7 7 . 0 3 3 7 1 . 2 3 0 1 . 5 - 0 . 3 - 1 . 1 5 , 9 7 2 , 6 6 3 . 0 6 4 2 1 , 7 8 5 . 6 3 0 . 3 3 1 . 0 46 8 . 3 1 . 4 1 2 7 7 . 0 3 4 6 8 . 3 3 9 8 . 6 - 0 . 1 - 2 . 6 5 , 9 7 2 , 6 6 3 . 2 7 4 2 1 , 7 8 4 . 0 8 1 . 0 0 2 . 6 56 1 . 6 3 . 5 9 2 7 0 . 3 5 5 6 1 . 5 4 9 1 . 8 0 . 0 - 6 . 7 5 , 9 7 2 , 6 6 3 . 4 7 4 2 1 , 7 8 0 . 0 2 2 . 3 5 6 . 6 59 4 . 8 4 . 6 5 2 6 6 . 1 3 5 9 4 . 6 5 2 4 . 9 - 0 . 1 - 9 . 1 5 , 9 7 2 , 6 6 3 . 4 1 4 2 1 , 7 7 7 . 6 4 3 . 3 2 8 . 9 69 1 . 7 7 . 7 2 2 5 8 . 6 8 6 9 0 . 9 6 2 1 . 2 - 1 . 6 - 1 9 . 4 5 , 9 7 2 , 6 6 1 . 9 8 4 2 1 , 7 6 7 . 3 2 3 . 2 7 1 8 . 7 78 5 . 9 1 0 . 4 7 2 5 4 . 2 5 7 8 4 . 0 7 1 4 . 3 - 5 . 2 - 3 3 . 8 5 , 9 7 2 , 6 5 8 . 5 6 4 2 1 , 7 5 2 . 8 3 3 . 0 1 3 2 . 2 88 0 . 1 1 3 . 1 5 2 5 1 . 9 3 8 7 6 . 2 8 0 6 . 5 - 1 0 . 8 - 5 2 . 3 5 , 9 7 2 , 6 5 3 . 1 0 4 2 1 , 7 3 4 . 3 5 2 . 8 9 4 9 . 2 97 5 . 8 1 4 . 3 0 2 4 4 . 9 8 9 6 9 . 1 8 9 9 . 4 - 1 9 . 2 - 7 3 . 3 5 , 9 7 2 , 6 4 4 . 9 5 4 2 1 , 7 1 3 . 2 1 2 . 1 0 6 8 . 2 1, 0 5 2 . 0 1 4 . 6 4 2 4 3 . 3 5 1 , 0 4 2 . 9 9 7 3 . 2 - 2 7 . 5 - 9 0 . 4 5 , 9 7 2 , 6 3 6 . 8 3 4 2 1 , 6 9 5 . 9 9 0 . 6 9 8 3 . 4 Up p e r S c h r a d e r B l u f f 1, 0 7 0 . 8 1 4 . 7 2 2 4 2 . 9 6 1 , 0 6 1 . 0 9 9 1 . 3 - 2 9 . 6 - 9 4 . 7 5 , 9 7 2 , 6 3 4 . 7 3 4 2 1 , 6 9 1 . 7 3 0 . 6 9 8 7 . 2 1, 1 6 5 . 1 1 5 . 2 8 2 4 3 . 5 3 1 , 1 5 2 . 2 1 , 0 8 2 . 5 - 4 0 . 6 - 1 1 6 . 5 5 , 9 7 2 , 6 2 3 . 9 7 4 2 1 , 6 6 9 . 8 1 0 . 6 1 1 0 6 . 4 1, 2 6 0 . 0 1 7 . 3 1 2 4 2 . 6 4 1 , 2 4 3 . 2 1 , 1 7 3 . 5 - 5 2 . 7 - 1 4 0 . 2 5 , 9 7 2 , 6 1 2 . 1 6 4 2 1 , 6 4 5 . 9 6 2 . 1 6 1 2 7 . 4 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 3 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 1, 3 5 4 . 6 2 0 . 6 0 2 3 9 . 9 8 1 , 3 3 2 . 7 1 , 2 6 3 . 0 - 6 7 . 5 - 1 6 7 . 1 5 , 9 7 2 , 5 9 7 . 6 4 4 2 1 , 6 1 8 . 8 8 3 . 5 9 1 5 0 . 9 1, 4 0 4 . 0 2 2 . 3 2 2 4 0 . 9 1 1 , 3 7 8 . 7 1 , 3 0 9 . 0 - 7 6 . 4 - 1 8 2 . 9 5 , 9 7 2 , 5 8 8 . 9 0 4 2 1 , 6 0 3 . 0 8 3 . 5 5 1 6 4 . 6 Ba s e P e r m a f r o s t T r a n s i t i o n 1, 4 4 9 . 6 2 3 . 9 1 2 4 1 . 6 5 1 , 4 2 0 . 7 1 , 3 5 1 . 0 - 8 5 . 0 - 1 9 8 . 6 5 , 9 7 2 , 5 8 0 . 4 6 4 2 1 , 5 8 7 . 2 8 3 . 5 5 1 7 8 . 4 1, 5 4 4 . 9 2 6 . 5 2 2 4 4 . 5 9 1 , 5 0 6 . 8 1 , 4 3 7 . 1 - 1 0 3 . 3 - 2 3 4 . 8 5 , 9 7 2 , 5 6 2 . 5 5 4 2 1 , 5 5 0 . 9 0 3 . 0 4 2 1 0 . 4 1, 6 3 9 . 4 2 9 . 1 5 2 4 6 . 7 6 1 , 5 9 0 . 4 1 , 5 2 0 . 7 - 1 2 1 . 4 - 2 7 5 . 0 5 , 9 7 2 , 5 4 4 . 8 3 4 2 1 , 5 1 0 . 4 9 2 . 9 8 2 4 6 . 3 1, 7 3 4 . 3 3 1 . 6 1 2 4 7 . 3 1 1 , 6 7 2 . 2 1 , 6 0 2 . 5 - 1 4 0 . 1 - 3 1 9 . 2 5 , 9 7 2 , 5 2 6 . 5 8 4 2 1 , 4 6 6 . 1 2 2 . 6 1 2 8 6 . 1 1, 8 0 1 . 0 3 3 . 5 6 2 4 8 . 0 3 1 , 7 2 8 . 5 1 , 6 5 8 . 8 - 1 5 3 . 8 - 3 5 2 . 4 5 , 9 7 2 , 5 1 3 . 2 8 4 2 1 , 4 3 2 . 7 4 2 . 9 8 3 1 6 . 0 Mi d d l e S c h r a d e r B l u f f 1, 8 2 8 . 9 3 4 . 3 8 2 4 8 . 3 1 1 , 7 5 1 . 6 1 , 6 8 1 . 9 - 1 5 9 . 6 - 3 6 6 . 9 5 , 9 7 2 , 5 0 7 . 6 4 4 2 1 , 4 1 8 . 2 3 2 . 9 8 3 2 9 . 1 1, 9 2 3 . 1 3 7 . 4 3 2 4 8 . 7 6 1 , 8 2 7 . 9 1 , 7 5 8 . 2 - 1 7 9 . 8 - 4 1 8 . 3 5 , 9 7 2 , 4 8 7 . 9 6 4 2 1 , 3 6 6 . 5 9 3 . 2 5 3 7 5 . 7 2, 0 1 7 . 9 4 0 . 8 1 2 4 8 . 1 3 1 , 9 0 1 . 4 1 , 8 3 1 . 7 - 2 0 1 . 8 - 4 7 3 . 9 5 , 9 7 2 , 4 6 6 . 5 7 4 2 1 , 3 1 0 . 7 7 3 . 5 9 4 2 6 . 0 2, 1 1 2 . 5 4 4 . 3 2 2 4 7 . 0 6 1 , 9 7 1 . 1 1 , 9 0 1 . 4 - 2 2 6 . 2 - 5 3 3 . 1 5 , 9 7 2 , 4 4 2 . 7 8 4 2 1 , 2 5 1 . 3 6 3 . 7 9 4 7 9 . 3 2, 1 4 4 . 4 4 5 . 9 2 2 4 6 . 4 0 1 , 9 9 3 . 6 1 , 9 2 3 . 9 - 2 3 5 . 1 - 5 5 3 . 8 5 , 9 7 2 , 4 3 4 . 0 8 4 2 1 , 2 3 0 . 5 5 5 . 2 4 4 9 7 . 9 2, 1 7 6 . 0 4 7 . 4 2 2 4 6 . 2 2 2 , 0 1 5 . 3 1 , 9 4 5 . 6 - 2 4 4 . 4 - 5 7 4 . 9 5 , 9 7 2 , 4 2 5 . 0 4 4 2 1 , 2 0 9 . 3 5 4 . 7 5 5 1 6 . 8 2, 2 0 6 . 7 4 9 . 0 4 2 4 5 . 6 6 2 , 0 3 5 . 7 1 , 9 6 6 . 0 - 2 5 3 . 7 - 5 9 5 . 8 5 , 9 7 2 , 4 1 5 . 9 3 4 2 1 , 1 8 8 . 3 6 5 . 4 5 5 3 5 . 5 2, 3 0 1 . 7 5 2 . 9 3 2 4 6 . 4 3 2 , 0 9 5 . 5 2 , 0 2 5 . 8 - 2 8 3 . 6 - 6 6 3 . 2 5 , 9 7 2 , 3 8 6 . 7 1 4 2 1 , 1 2 0 . 6 5 4 . 1 5 5 9 5 . 8 2, 3 8 1 . 0 5 4 . 3 2 2 4 7 . 3 3 2 , 1 4 2 . 6 2 , 0 7 2 . 9 - 3 0 8 . 7 - 7 2 1 . 9 5 , 9 7 2 , 3 6 2 . 2 5 4 2 1 , 0 6 1 . 6 6 1 . 9 7 6 4 8 . 6 MC U 2, 3 9 6 . 5 5 4 . 5 9 2 4 7 . 5 0 2 , 1 5 1 . 6 2 , 0 8 1 . 9 - 3 1 3 . 5 - 7 3 3 . 6 5 , 9 7 2 , 3 5 7 . 5 2 4 2 1 , 0 4 9 . 9 5 1 . 9 7 6 5 9 . 1 2, 4 9 1 . 3 5 5 . 8 4 2 4 8 . 3 0 2 , 2 0 5 . 7 2 , 1 3 6 . 0 - 3 4 2 . 8 - 8 0 5 . 8 5 , 9 7 2 , 3 2 8 . 9 8 4 2 0 , 9 7 7 . 5 0 1 . 4 9 7 2 4 . 3 2, 5 4 6 . 6 5 6 . 7 2 2 4 8 . 2 0 2 , 2 3 6 . 3 2 , 1 6 6 . 6 - 3 5 9 . 9 - 8 4 8 . 4 5 , 9 7 2 , 3 1 2 . 4 0 4 2 0 , 9 3 4 . 6 6 1 . 6 0 7 6 2 . 8 2, 6 0 8 . 0 5 7 . 6 6 2 4 8 . 3 3 2 , 2 6 9 . 6 2 , 1 9 9 . 9 - 3 7 9 . 0 - 8 9 6 . 4 5 , 9 7 2 , 2 9 3 . 7 9 4 2 0 , 8 8 6 . 5 1 1 . 5 5 8 0 6 . 2 13 - 3 / 8 " S u r f a c e C a s i n g 2, 6 4 4 . 8 5 8 . 2 3 2 4 8 . 4 1 2 , 2 8 9 . 2 2 , 2 1 9 . 5 - 3 9 0 . 5 - 9 2 5 . 4 5 , 9 7 2 , 2 8 2 . 6 0 4 2 0 , 8 5 7 . 3 9 1 . 5 5 8 3 2 . 4 2, 6 5 9 . 0 5 8 . 8 1 2 4 8 . 3 0 2 , 2 9 6 . 6 2 , 2 2 6 . 9 - 3 9 5 . 0 - 9 3 6 . 7 5 , 9 7 2 , 2 7 8 . 2 4 4 2 0 , 8 4 6 . 0 7 4 . 1 3 8 4 2 . 6 2, 7 5 3 . 6 6 2 . 0 1 2 4 7 . 6 7 2 , 3 4 3 . 3 2 , 2 7 3 . 6 - 4 2 5 . 8 - 1 , 0 1 2 . 9 5 , 9 7 2 , 2 4 8 . 2 1 4 2 0 , 7 6 9 . 5 3 3 . 4 3 9 1 1 . 5 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 4 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 2, 8 4 8 . 9 6 4 . 8 8 2 4 7 . 9 0 2 , 3 8 5 . 9 2 , 3 1 6 . 2 - 4 5 8 . 0 - 1 , 0 9 1 . 8 5 , 9 7 2 , 2 1 6 . 8 1 4 2 0 , 6 9 0 . 3 1 3 . 0 2 9 8 2 . 6 2, 9 4 2 . 8 6 8 . 3 5 2 4 8 . 0 2 2 , 4 2 3 . 1 2 , 3 5 3 . 4 - 4 9 0 . 4 - 1 , 1 7 1 . 7 5 , 9 7 2 , 1 8 5 . 3 1 4 2 0 , 6 1 0 . 0 9 3 . 7 0 1 , 0 5 4 . 8 3, 0 1 5 . 0 7 0 . 6 3 2 4 8 . 1 9 2 , 4 4 8 . 4 2 , 3 7 8 . 7 - 5 1 5 . 6 - 1 , 2 3 4 . 4 5 , 9 7 2 , 1 6 0 . 7 6 4 2 0 , 5 4 7 . 1 1 3 . 1 7 1 , 1 1 1 . 4 Tu l u v a k S h a l e 3, 0 3 7 . 6 7 1 . 3 5 2 4 8 . 2 4 2 , 4 5 5 . 8 2 , 3 8 6 . 1 - 5 2 3 . 5 - 1 , 2 5 4 . 2 5 , 9 7 2 , 1 5 3 . 0 4 4 2 0 , 5 2 7 . 1 9 3 . 1 7 1 , 1 2 9 . 4 3, 1 3 2 . 5 7 3 . 9 4 2 4 8 . 1 0 2 , 4 8 4 . 1 2 , 4 1 4 . 4 - 5 5 7 . 2 - 1 , 3 3 8 . 3 5 , 9 7 2 , 1 2 0 . 2 4 4 2 0 , 4 4 2 . 7 9 2 . 7 3 1 , 2 0 5 . 3 3, 2 2 7 . 0 7 6 . 9 5 2 4 8 . 1 7 2 , 5 0 7 . 8 2 , 4 3 8 . 1 - 5 9 1 . 2 - 1 , 4 2 3 . 2 5 , 9 7 2 , 0 8 7 . 0 8 4 2 0 , 3 5 7 . 5 9 3 . 1 9 1 , 2 8 2 . 0 3, 2 3 8 . 0 7 7 . 2 8 2 4 8 . 1 3 2 , 5 1 0 . 3 2 , 4 4 0 . 6 - 5 9 5 . 2 - 1 , 4 3 3 . 2 5 , 9 7 2 , 0 8 3 . 1 8 4 2 0 , 3 4 7 . 5 6 2 . 9 7 1 , 2 9 1 . 0 Tu l u v a k S a n d 3, 3 2 1 . 9 7 9 . 7 5 2 4 7 . 7 9 2 , 5 2 7 . 0 2 , 4 5 7 . 3 - 6 2 6 . 1 - 1 , 5 0 9 . 4 5 , 9 7 2 , 0 5 3 . 1 1 4 2 0 , 2 7 1 . 0 1 2 . 9 7 1 , 3 5 9 . 9 3, 4 1 6 . 6 8 1 . 1 8 2 4 7 . 5 0 2 , 5 4 2 . 7 2 , 4 7 3 . 0 - 6 6 1 . 6 - 1 , 5 9 5 . 7 5 , 9 7 2 , 0 1 8 . 5 2 4 2 0 , 1 8 4 . 3 3 1 . 5 4 1 , 4 3 7 . 7 3, 5 1 1 . 3 8 1 . 2 9 2 4 7 . 5 9 2 , 5 5 7 . 1 2 , 4 8 7 . 4 - 6 9 7 . 4 - 1 , 6 8 2 . 2 5 , 9 7 1 , 9 8 3 . 6 6 4 2 0 , 0 9 7 . 4 4 0 . 1 5 1 , 5 1 5 . 7 3, 6 0 6 . 4 8 1 . 2 0 2 4 7 . 3 5 2 , 5 7 1 . 6 2 , 5 0 1 . 9 - 7 3 3 . 4 - 1 , 7 6 9 . 0 5 , 9 7 1 , 9 4 8 . 5 7 4 2 0 , 0 1 0 . 2 8 0 . 2 7 1 , 5 9 3 . 9 3, 7 0 0 . 5 8 1 . 3 9 2 4 7 . 4 8 2 , 5 8 5 . 8 2 , 5 1 6 . 1 - 7 6 9 . 1 - 1 , 8 5 5 . 0 5 , 9 7 1 , 9 1 3 . 7 2 4 1 9 , 9 2 3 . 9 9 0 . 2 4 1 , 6 7 1 . 3 3, 7 9 5 . 1 8 1 . 3 6 2 4 7 . 6 3 2 , 6 0 0 . 0 2 , 5 3 0 . 3 - 8 0 4 . 8 - 1 , 9 4 1 . 4 5 , 9 7 1 , 8 7 8 . 9 3 4 1 9 , 8 3 7 . 1 9 0 . 1 6 1 , 7 4 9 . 2 3, 8 9 0 . 1 8 1 . 4 1 2 4 7 . 4 7 2 , 6 1 4 . 3 2 , 5 4 4 . 6 - 8 4 0 . 7 - 2 , 0 2 8 . 2 5 , 9 7 1 , 8 4 3 . 9 7 4 1 9 , 7 5 0 . 0 2 0 . 1 7 1 , 8 2 7 . 4 3, 9 8 4 . 9 8 1 . 3 2 2 4 7 . 4 0 2 , 6 2 8 . 5 2 , 5 5 8 . 8 - 8 7 6 . 6 - 2 , 1 1 4 . 8 5 , 9 7 1 , 8 0 8 . 9 1 4 1 9 , 6 6 3 . 1 2 0 . 1 2 1 , 9 0 5 . 4 4, 0 7 9 . 4 8 1 . 4 4 2 4 7 . 3 2 2 , 6 4 2 . 7 2 , 5 7 3 . 0 - 9 1 2 . 6 - 2 , 2 0 1 . 0 5 , 9 7 1 , 7 7 3 . 8 4 4 1 9 , 5 7 6 . 5 1 0 . 1 5 1 , 9 8 3 . 0 4, 1 7 4 . 4 8 1 . 4 2 2 4 6 . 8 4 2 , 6 5 6 . 8 2 , 5 8 7 . 1 - 9 4 9 . 2 - 2 , 2 8 7 . 5 5 , 9 7 1 , 7 3 8 . 2 0 4 1 9 , 4 8 9 . 6 9 0 . 5 0 2 , 0 6 0 . 8 4, 2 6 9 . 3 8 1 . 3 9 2 4 7 . 0 6 2 , 6 7 1 . 0 2 , 6 0 1 . 3 - 9 8 5 . 9 - 2 , 3 7 3 . 8 5 , 9 7 1 , 7 0 2 . 3 5 4 1 9 , 4 0 2 . 9 4 0 . 2 3 2 , 1 3 8 . 4 4, 3 6 3 . 6 8 1 . 3 8 2 4 7 . 5 3 2 , 6 8 5 . 1 2 , 6 1 5 . 4 - 1 , 0 2 1 . 9 - 2 , 4 5 9 . 8 5 , 9 7 1 , 6 6 7 . 2 8 4 1 9 , 3 1 6 . 6 0 0 . 4 9 2 , 2 1 5 . 8 4, 4 5 8 . 6 8 1 . 3 2 2 4 7 . 0 6 2 , 6 9 9 . 4 2 , 6 2 9 . 7 - 1 , 0 5 8 . 2 - 2 , 5 4 6 . 5 5 , 9 7 1 , 6 3 1 . 9 1 4 1 9 , 2 2 9 . 5 4 0 . 4 9 2 , 2 9 3 . 9 4, 5 5 3 . 4 8 1 . 3 6 2 4 7 . 0 9 2 , 7 1 3 . 7 2 , 6 4 4 . 0 - 1 , 0 9 4 . 7 - 2 , 6 3 2 . 8 5 , 9 7 1 , 5 9 6 . 3 2 4 1 9 , 1 4 2 . 8 7 0 . 0 5 2 , 3 7 1 . 5 4, 6 4 8 . 1 8 1 . 3 6 2 4 7 . 4 1 2 , 7 2 7 . 9 2 , 6 5 8 . 2 - 1 , 1 3 0 . 9 - 2 , 7 1 9 . 1 5 , 9 7 1 , 5 6 1 . 0 4 4 1 9 , 0 5 6 . 2 0 0 . 3 3 2 , 4 4 9 . 2 4, 7 4 2 . 8 8 1 . 3 5 2 4 7 . 5 5 2 , 7 4 2 . 1 2 , 6 7 2 . 4 - 1 , 1 6 6 . 7 - 2 , 8 0 5 . 6 5 , 9 7 1 , 5 2 6 . 0 7 4 1 8 , 9 6 9 . 3 1 0 . 1 5 2 , 5 2 7 . 1 4, 8 3 7 . 2 8 1 . 3 8 2 4 7 . 9 1 2 , 7 5 6 . 3 2 , 6 8 6 . 6 - 1 , 2 0 2 . 1 - 2 , 8 9 2 . 0 5 , 9 7 1 , 4 9 1 . 6 1 4 1 8 , 8 8 2 . 6 0 0 . 3 8 2 , 6 0 5 . 0 4, 9 3 2 . 6 8 1 . 4 1 2 4 7 . 7 8 2 , 7 7 0 . 6 2 , 7 0 0 . 9 - 1 , 2 3 7 . 7 - 2 , 9 7 9 . 4 5 , 9 7 1 , 4 5 6 . 9 4 4 1 8 , 7 9 4 . 8 6 0 . 1 4 2 , 6 8 3 . 9 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 5 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 5, 0 2 7 . 1 8 1 . 3 5 2 4 8 . 3 0 2 , 7 8 4 . 8 2 , 7 1 5 . 1 - 1 , 2 7 2 . 6 - 3 , 0 6 6 . 0 5 , 9 7 1 , 4 2 2 . 9 1 4 1 8 , 7 0 7 . 8 5 0 . 5 5 2 , 7 6 2 . 2 5, 1 2 2 . 2 8 1 . 3 5 2 4 8 . 2 4 2 , 7 9 9 . 1 2 , 7 2 9 . 4 - 1 , 3 0 7 . 4 - 3 , 1 5 3 . 4 5 , 9 7 1 , 3 8 9 . 0 2 4 1 8 , 6 2 0 . 1 8 0 . 0 6 2 , 8 4 1 . 1 5, 2 1 7 . 0 8 1 . 3 8 2 4 7 . 7 0 2 , 8 1 3 . 3 2 , 7 4 3 . 6 - 1 , 3 4 2 . 6 - 3 , 2 4 0 . 2 5 , 9 7 1 , 3 5 4 . 7 8 4 1 8 , 5 3 2 . 9 4 0 . 5 6 2 , 9 1 9 . 5 5, 2 3 5 . 0 8 1 . 3 7 2 4 7 . 6 2 2 , 8 1 6 . 0 2 , 7 4 6 . 3 - 1 , 3 4 9 . 3 - 3 , 2 5 6 . 7 5 , 9 7 1 , 3 4 8 . 1 9 4 1 8 , 5 1 6 . 4 3 0 . 4 2 2 , 9 3 4 . 4 TS _ 7 9 0 5, 3 1 1 . 3 8 1 . 3 2 2 4 7 . 3 0 2 , 8 2 7 . 5 2 , 7 5 7 . 8 - 1 , 3 7 8 . 3 - 3 , 3 2 6 . 4 5 , 9 7 1 , 3 2 0 . 0 0 4 1 8 , 4 4 6 . 4 3 0 . 4 2 2 , 9 9 7 . 2 5, 4 0 5 . 9 8 1 . 4 5 2 4 7 . 4 9 2 , 8 4 1 . 6 2 , 7 7 1 . 9 - 1 , 4 1 4 . 2 - 3 , 4 1 2 . 7 5 , 9 7 1 , 2 8 4 . 9 7 4 1 8 , 3 5 9 . 7 7 0 . 2 4 3 , 0 7 4 . 9 5, 5 0 0 . 8 8 1 . 4 5 2 4 7 . 4 3 2 , 8 5 5 . 7 2 , 7 8 6 . 0 - 1 , 4 5 0 . 2 - 3 , 4 9 9 . 4 5 , 9 7 1 , 2 4 9 . 9 1 4 1 8 , 2 7 2 . 7 5 0 . 0 6 3 , 1 5 3 . 0 5, 5 9 5 . 8 8 1 . 4 5 2 4 7 . 9 0 2 , 8 6 9 . 9 2 , 8 0 0 . 2 - 1 , 4 8 5 . 9 - 3 , 5 8 6 . 3 5 , 9 7 1 , 2 1 5 . 1 2 4 1 8 , 1 8 5 . 4 8 0 . 4 9 3 , 2 3 1 . 3 5, 6 9 0 . 4 8 1 . 4 4 2 4 8 . 1 6 2 , 8 8 3 . 9 2 , 8 1 4 . 2 - 1 , 5 2 0 . 9 - 3 , 6 7 3 . 1 5 , 9 7 1 , 1 8 1 . 0 2 4 1 8 , 0 9 8 . 3 4 0 . 2 7 3 , 3 0 9 . 7 5, 7 8 5 . 4 8 1 . 3 5 2 4 7 . 8 6 2 , 8 9 8 . 1 2 , 8 2 8 . 4 - 1 , 5 5 6 . 0 - 3 , 7 6 0 . 1 5 , 9 7 1 , 1 4 6 . 7 8 4 1 8 , 0 1 0 . 9 4 0 . 3 3 3 , 3 8 8 . 3 5, 8 7 9 . 9 8 1 . 3 6 2 4 7 . 6 9 2 , 9 1 2 . 4 2 , 8 4 2 . 7 - 1 , 5 9 1 . 4 - 3 , 8 4 6 . 7 5 , 9 7 1 , 1 1 2 . 3 2 4 1 7 , 9 2 4 . 0 2 0 . 1 8 3 , 4 6 6 . 4 5, 9 7 4 . 5 8 1 . 3 5 2 4 7 . 8 7 2 , 9 2 6 . 6 2 , 8 5 6 . 9 - 1 , 6 2 6 . 7 - 3 , 9 3 3 . 2 5 , 9 7 1 , 0 7 7 . 8 9 4 1 7 , 8 3 7 . 1 7 0 . 1 9 3 , 5 4 4 . 4 6, 0 6 9 . 2 8 1 . 4 4 2 4 7 . 6 5 2 , 9 4 0 . 8 2 , 8 7 1 . 1 - 1 , 6 6 2 . 2 - 4 , 0 1 9 . 9 5 , 9 7 1 , 0 4 3 . 3 3 4 1 7 , 7 5 0 . 0 6 0 . 2 5 3 , 6 2 2 . 7 6, 1 6 4 . 3 8 1 . 3 9 2 4 7 . 3 5 2 , 9 5 4 . 9 2 , 8 8 5 . 2 - 1 , 6 9 8 . 2 - 4 , 1 0 6 . 7 5 , 9 7 1 , 0 0 8 . 2 8 4 1 7 , 6 6 2 . 8 9 0 . 3 2 3 , 7 0 0 . 9 6, 2 5 8 . 9 8 1 . 4 1 2 4 7 . 1 9 2 , 9 6 9 . 1 2 , 8 9 9 . 4 - 1 , 7 3 4 . 3 - 4 , 1 9 3 . 0 5 , 9 7 0 , 9 7 3 . 0 5 4 1 7 , 5 7 6 . 2 6 0 . 1 7 3 , 7 7 8 . 6 6, 3 5 4 . 3 8 1 . 3 8 2 4 6 . 9 3 2 , 9 8 3 . 4 2 , 9 1 3 . 7 - 1 , 7 7 1 . 1 - 4 , 2 7 9 . 9 5 , 9 7 0 , 9 3 7 . 1 7 4 1 7 , 4 8 8 . 9 6 0 . 2 7 3 , 8 5 6 . 7 6, 4 4 8 . 5 8 1 . 4 1 2 4 6 . 6 9 2 , 9 9 7 . 5 2 , 9 2 7 . 8 - 1 , 8 0 7 . 7 - 4 , 3 6 5 . 5 5 , 9 7 0 , 9 0 1 . 4 2 4 1 7 , 4 0 3 . 0 5 0 . 2 5 3 , 9 3 3 . 6 6, 5 4 3 . 5 8 1 . 3 8 2 4 6 . 5 5 3 , 0 1 1 . 7 2 , 9 4 2 . 0 - 1 , 8 4 5 . 0 - 4 , 4 5 1 . 7 5 , 9 7 0 , 8 6 5 . 0 4 4 1 7 , 3 1 6 . 4 3 0 . 1 5 4 , 0 1 1 . 0 6, 6 3 8 . 3 8 1 . 3 5 2 4 6 . 8 8 3 , 0 2 5 . 9 2 , 9 5 6 . 2 - 1 , 8 8 2 . 1 - 4 , 5 3 7 . 8 5 , 9 7 0 , 8 2 8 . 8 8 4 1 7 , 2 2 9 . 9 4 0 . 3 5 4 , 0 8 8 . 3 6, 7 3 3 . 1 8 1 . 4 5 2 4 6 . 6 7 3 , 0 4 0 . 1 2 , 9 7 0 . 4 - 1 , 9 1 9 . 1 - 4 , 6 2 4 . 0 5 , 9 7 0 , 7 9 2 . 8 2 4 1 7 , 1 4 3 . 4 2 0 . 2 4 4 , 1 6 5 . 7 6, 8 2 7 . 8 8 1 . 3 6 2 4 6 . 6 2 3 , 0 5 4 . 2 2 , 9 8 4 . 5 - 1 , 9 5 6 . 1 - 4 , 7 0 9 . 9 5 , 9 7 0 , 7 5 6 . 6 2 4 1 7 , 0 5 7 . 1 4 0 . 1 1 4 , 2 4 2 . 8 6, 9 2 2 . 6 8 1 . 3 5 2 4 6 . 4 4 3 , 0 6 8 . 5 2 , 9 9 8 . 8 - 1 , 9 9 3 . 5 - 4 , 7 9 5 . 9 5 , 9 7 0 , 7 2 0 . 1 8 4 1 6 , 9 7 0 . 7 6 0 . 1 9 4 , 3 2 0 . 0 7, 0 1 7 . 4 8 1 . 3 5 2 4 6 . 9 5 3 , 0 8 2 . 7 3 , 0 1 3 . 0 - 2 , 0 3 0 . 6 - 4 , 8 8 1 . 9 5 , 9 7 0 , 6 8 4 . 0 2 4 1 6 , 8 8 4 . 3 4 0 . 5 3 4 , 3 9 7 . 2 7, 1 1 2 . 4 8 1 . 3 9 2 4 7 . 0 0 3 , 0 9 7 . 0 3 , 0 2 7 . 3 - 2 , 0 6 7 . 3 - 4 , 9 6 8 . 4 5 , 9 7 0 , 6 4 8 . 1 7 4 1 6 , 7 9 7 . 4 8 0 . 0 7 4 , 4 7 5 . 0 7, 2 0 6 . 5 8 1 . 4 1 2 4 7 . 6 8 3 , 1 1 1 . 1 3 , 0 4 1 . 4 - 2 , 1 0 3 . 2 - 5 , 0 5 4 . 3 5 , 9 7 0 , 6 1 3 . 2 1 4 1 6 , 7 1 1 . 2 3 0 . 7 1 4 , 5 5 2 . 3 7, 3 0 1 . 5 8 1 . 4 8 2 4 8 . 0 0 3 , 1 2 5 . 2 3 , 0 5 5 . 5 - 2 , 1 3 8 . 6 - 5 , 1 4 1 . 3 5 , 9 7 0 , 5 7 8 . 7 0 4 1 6 , 6 2 3 . 8 8 0 . 3 4 4 , 6 3 0 . 8 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 6 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 7, 3 9 6 . 4 8 1 . 3 9 2 4 7 . 9 2 3 , 1 3 9 . 3 3 , 0 6 9 . 6 - 2 , 1 7 3 . 8 - 5 , 2 2 8 . 3 5 , 9 7 0 , 5 4 4 . 4 0 4 1 6 , 5 3 6 . 5 5 0 . 1 3 4 , 7 0 9 . 3 7, 4 9 0 . 5 8 1 . 3 0 2 4 8 . 1 3 3 , 1 5 3 . 5 3 , 0 8 3 . 8 - 2 , 2 0 8 . 6 - 5 , 3 1 4 . 5 5 , 9 7 0 , 5 1 0 . 5 1 4 1 6 , 4 4 9 . 9 7 0 . 2 4 4 , 7 8 7 . 2 7, 5 8 6 . 3 8 1 . 4 2 2 4 7 . 8 5 3 , 1 6 7 . 9 3 , 0 9 8 . 2 - 2 , 2 4 4 . 1 - 5 , 4 0 2 . 3 5 , 9 7 0 , 4 7 5 . 9 2 4 1 6 , 3 6 1 . 7 6 0 . 3 1 4 , 8 6 6 . 5 7, 6 8 0 . 8 8 1 . 4 1 2 4 7 . 9 9 3 , 1 8 2 . 0 3 , 1 1 2 . 3 - 2 , 2 7 9 . 2 - 5 , 4 8 8 . 9 5 , 9 7 0 , 4 4 1 . 7 2 4 1 6 , 2 7 4 . 8 7 0 . 1 5 4 , 9 4 4 . 7 7, 7 7 5 . 6 8 1 . 4 2 2 4 7 . 8 4 3 , 1 9 6 . 2 3 , 1 2 6 . 5 - 2 , 3 1 4 . 5 - 5 , 5 7 5 . 8 5 , 9 7 0 , 4 0 7 . 3 6 4 1 6 , 1 8 7 . 6 0 0 . 1 6 5 , 0 2 3 . 1 7, 8 7 0 . 1 8 1 . 3 3 2 4 7 . 4 9 3 , 2 1 0 . 3 3 , 1 4 0 . 6 - 2 , 3 5 0 . 0 - 5 , 6 6 2 . 2 5 , 9 7 0 , 3 7 2 . 7 7 4 1 6 , 1 0 0 . 8 3 0 . 3 8 5 , 1 0 1 . 0 7, 9 2 1 . 0 8 1 . 3 4 2 4 7 . 3 3 3 , 2 1 8 . 0 3 , 1 4 8 . 3 - 2 , 3 6 9 . 3 - 5 , 7 0 8 . 6 5 , 9 7 0 , 3 5 3 . 9 4 4 1 6 , 0 5 4 . 2 0 0 . 3 0 5 , 1 4 2 . 9 Se a b e e 7, 9 6 5 . 1 8 1 . 3 5 2 4 7 . 2 0 3 , 2 2 4 . 6 3 , 1 5 4 . 9 - 2 , 3 8 6 . 2 - 5 , 7 4 8 . 8 5 , 9 7 0 , 3 3 7 . 5 2 4 1 6 , 0 1 3 . 8 3 0 . 3 0 5 , 1 7 9 . 1 8, 0 5 9 . 6 8 1 . 3 5 2 4 7 . 1 7 3 , 2 3 8 . 8 3 , 1 6 9 . 1 - 2 , 4 2 2 . 4 - 5 , 8 3 4 . 9 5 , 9 7 0 , 3 0 2 . 2 1 4 1 5 , 9 2 7 . 3 7 0 . 0 3 5 , 2 5 6 . 5 8, 1 5 4 . 4 8 1 . 4 5 2 4 7 . 3 6 3 , 2 5 3 . 0 3 , 1 8 3 . 3 - 2 , 4 5 8 . 6 - 5 , 9 2 1 . 4 5 , 9 7 0 , 2 6 6 . 8 8 4 1 5 , 8 4 0 . 5 5 0 . 2 2 5 , 3 3 4 . 3 8, 2 4 8 . 6 8 1 . 3 2 2 4 7 . 3 2 3 , 2 6 7 . 1 3 , 1 9 7 . 4 - 2 , 4 9 4 . 5 - 6 , 0 0 7 . 4 5 , 9 7 0 , 2 3 1 . 8 9 4 1 5 , 7 5 4 . 2 1 0 . 1 4 5 , 4 1 1 . 8 8, 3 4 3 . 5 8 1 . 4 4 2 4 7 . 8 5 3 , 2 8 1 . 3 3 , 2 1 1 . 6 - 2 , 5 3 0 . 3 - 6 , 0 9 4 . 1 5 , 9 7 0 , 1 9 7 . 0 2 4 1 5 , 6 6 7 . 1 0 0 . 5 7 5 , 4 8 9 . 9 8, 4 3 8 . 2 8 1 . 4 1 2 4 8 . 0 2 3 , 2 9 5 . 5 3 , 2 2 5 . 8 - 2 , 5 6 5 . 4 - 6 , 1 8 0 . 9 5 , 9 7 0 , 1 6 2 . 7 6 4 1 5 , 5 7 9 . 9 8 0 . 1 8 5 , 5 6 8 . 3 8, 5 3 3 . 2 8 1 . 4 1 2 4 8 . 3 0 3 , 3 0 9 . 7 3 , 2 4 0 . 0 - 2 , 6 0 0 . 4 - 6 , 2 6 8 . 1 5 , 9 7 0 , 1 2 8 . 7 2 4 1 5 , 4 9 2 . 4 2 0 . 2 9 5 , 6 4 7 . 1 8, 6 2 8 . 1 8 1 . 4 4 2 4 7 . 9 9 3 , 3 2 3 . 8 3 , 2 5 4 . 1 - 2 , 6 3 5 . 3 - 6 , 3 5 5 . 2 5 , 9 7 0 , 0 9 4 . 7 0 4 1 5 , 4 0 4 . 9 7 0 . 3 2 5 , 7 2 5 . 8 8, 7 2 3 . 3 8 1 . 3 9 2 4 7 . 9 2 3 , 3 3 8 . 0 3 , 2 6 8 . 3 - 2 , 6 7 0 . 6 - 6 , 4 4 2 . 4 5 , 9 7 0 , 0 6 0 . 3 1 4 1 5 , 3 1 7 . 4 2 0 . 0 9 5 , 8 0 4 . 5 8, 8 1 7 . 6 8 1 . 4 7 2 4 7 . 8 9 3 , 3 5 2 . 1 3 , 2 8 2 . 4 - 2 , 7 0 5 . 7 - 6 , 5 2 8 . 9 5 , 9 7 0 , 0 2 6 . 1 0 4 1 5 , 2 3 0 . 5 8 0 . 0 9 5 , 8 8 2 . 6 8, 9 1 2 . 5 8 1 . 2 9 2 4 7 . 3 9 3 , 3 6 6 . 3 3 , 2 9 6 . 6 - 2 , 7 4 1 . 4 - 6 , 6 1 5 . 6 5 , 9 6 9 , 9 9 1 . 3 5 4 1 5 , 1 4 3 . 5 3 0 . 5 5 5 , 9 6 0 . 7 9, 0 0 7 . 2 8 1 . 4 2 2 4 7 . 3 8 3 , 3 8 0 . 5 3 , 3 1 0 . 8 - 2 , 7 7 7 . 4 - 6 , 7 0 2 . 0 5 , 9 6 9 , 9 5 6 . 2 5 4 1 5 , 0 5 6 . 7 3 0 . 1 4 6 , 0 3 8 . 6 9, 1 0 1 . 3 8 1 . 3 9 2 4 7 . 3 1 3 , 3 9 4 . 6 3 , 3 2 4 . 9 - 2 , 8 1 3 . 3 - 6 , 7 8 7 . 9 5 , 9 6 9 , 9 2 1 . 3 1 4 1 4 , 9 7 0 . 4 9 0 . 0 8 6 , 1 1 5 . 9 9, 1 9 5 . 9 8 1 . 3 5 2 4 7 . 3 0 3 , 4 0 8 . 8 3 , 3 3 9 . 1 - 2 , 8 4 9 . 4 - 6 , 8 7 4 . 2 5 , 9 6 9 , 8 8 6 . 1 2 4 1 4 , 8 8 3 . 8 2 0 . 0 4 6 , 1 9 3 . 6 9, 2 9 0 . 6 8 1 . 3 5 2 4 7 . 4 2 3 , 4 2 3 . 0 3 , 3 5 3 . 3 - 2 , 8 8 5 . 4 - 6 , 9 6 0 . 6 5 , 9 6 9 , 8 5 0 . 9 9 4 1 4 , 7 9 7 . 0 6 0 . 1 3 6 , 2 7 1 . 4 9, 3 8 5 . 0 8 1 . 5 0 2 4 7 . 1 6 3 , 4 3 7 . 1 3 , 3 6 7 . 4 - 2 , 9 2 1 . 4 - 7 , 0 4 6 . 7 5 , 9 6 9 , 8 1 5 . 8 5 4 1 4 , 7 1 0 . 5 8 0 . 3 2 6 , 3 4 8 . 9 9, 4 8 1 . 1 8 1 . 4 4 2 4 7 . 4 9 3 , 4 5 1 . 4 3 , 3 8 1 . 7 - 2 , 9 5 8 . 1 - 7 , 1 3 4 . 4 5 , 9 6 9 , 7 8 0 . 1 5 4 1 4 , 6 2 2 . 5 6 0 . 3 5 6 , 4 2 7 . 9 9, 5 7 5 . 3 8 1 . 3 1 2 4 7 . 2 3 3 , 4 6 5 . 5 3 , 3 9 5 . 8 - 2 , 9 9 3 . 9 - 7 , 2 2 0 . 3 5 , 9 6 9 , 7 4 5 . 2 0 4 1 4 , 5 3 6 . 2 3 0 . 3 1 6 , 5 0 5 . 3 9, 6 6 9 . 6 8 1 . 3 8 2 4 7 . 0 2 3 , 4 7 9 . 7 3 , 4 1 0 . 0 - 3 , 0 3 0 . 2 - 7 , 3 0 6 . 3 5 , 9 6 9 , 7 0 9 . 8 5 4 1 4 , 4 4 9 . 9 3 0 . 2 3 6 , 5 8 2 . 6 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 7 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 9, 7 6 4 . 6 8 1 . 4 2 2 4 6 . 9 8 3 , 4 9 3 . 9 3 , 4 2 4 . 2 - 3 , 0 6 6 . 9 - 7 , 3 9 2 . 7 5 , 9 6 9 , 6 7 4 . 0 5 4 1 4 , 3 6 3 . 0 9 0 . 0 6 6 , 6 6 0 . 3 9, 8 5 9 . 2 8 1 . 4 2 2 4 6 . 9 9 3 , 5 0 8 . 0 3 , 4 3 8 . 3 - 3 , 1 0 3 . 4 - 7 , 4 7 8 . 8 5 , 9 6 9 , 6 3 8 . 3 9 4 1 4 , 2 7 6 . 6 6 0 . 0 1 6 , 7 3 7 . 7 9, 9 5 4 . 1 8 1 . 3 5 2 4 7 . 2 1 3 , 5 2 2 . 2 3 , 4 5 2 . 5 - 3 , 1 3 9 . 9 - 7 , 5 6 5 . 2 5 , 9 6 9 , 6 0 2 . 7 8 4 1 4 , 1 8 9 . 8 5 0 . 2 4 6 , 8 1 5 . 4 10 , 0 4 8 . 7 8 1 . 4 2 2 4 7 . 1 8 3 , 5 3 6 . 4 3 , 4 6 6 . 7 - 3 , 1 7 6 . 2 - 7 , 6 5 1 . 5 5 , 9 6 9 , 5 6 7 . 4 3 4 1 4 , 1 0 3 . 2 5 0 . 0 8 6 , 8 9 3 . 0 10 , 1 4 3 . 8 8 1 . 3 5 2 4 7 . 7 1 3 , 5 5 0 . 6 3 , 4 8 0 . 9 - 3 , 2 1 2 . 3 - 7 , 7 3 8 . 3 5 , 9 6 9 , 5 3 2 . 2 9 4 1 4 , 0 1 6 . 0 8 0 . 5 6 6 , 9 7 1 . 2 10 , 2 3 8 . 3 8 1 . 3 8 2 4 7 . 7 8 3 , 5 6 4 . 8 3 , 4 9 5 . 1 - 3 , 2 4 7 . 6 - 7 , 8 2 4 . 8 5 , 9 6 9 , 4 9 7 . 8 0 4 1 3 , 9 2 9 . 2 2 0 . 0 8 7 , 0 4 9 . 3 10 , 3 3 2 . 7 8 1 . 4 4 2 4 7 . 6 1 3 , 5 7 8 . 9 3 , 5 0 9 . 2 - 3 , 2 8 3 . 1 - 7 , 9 1 1 . 1 5 , 9 6 9 , 4 6 3 . 2 8 4 1 3 , 8 4 2 . 5 1 0 . 1 9 7 , 1 2 7 . 1 10 , 4 2 7 . 7 8 1 . 3 9 2 4 7 . 7 2 3 , 5 9 3 . 1 3 , 5 2 3 . 4 - 3 , 3 1 8 . 8 - 7 , 9 9 8 . 0 5 , 9 6 9 , 4 2 8 . 4 9 4 1 3 , 7 5 5 . 2 5 0 . 1 3 7 , 2 0 5 . 5 10 , 5 2 2 . 1 8 0 . 3 8 2 5 1 . 2 9 3 , 6 0 8 . 0 3 , 5 3 8 . 3 - 3 , 3 5 1 . 4 - 8 , 0 8 5 . 3 5 , 9 6 9 , 3 9 6 . 7 9 4 1 3 , 6 6 7 . 7 0 3 . 8 9 7 , 2 8 4 . 8 10 , 6 1 6 . 5 8 0 . 1 1 2 5 4 . 4 8 3 , 6 2 4 . 0 3 , 5 5 4 . 3 - 3 , 3 7 8 . 8 - 8 , 1 7 4 . 2 5 , 9 6 9 , 3 7 0 . 3 4 4 1 3 , 5 7 8 . 5 0 3 . 3 4 7 , 3 6 6 . 7 10 , 7 1 1 . 5 7 9 . 8 2 2 5 6 . 7 3 3 , 6 4 0 . 6 3 , 5 7 0 . 9 - 3 , 4 0 2 . 0 - 8 , 2 6 4 . 8 5 , 9 6 9 , 3 4 8 . 0 4 4 1 3 , 4 8 7 . 6 8 2 . 3 5 7 , 4 5 1 . 1 10 , 8 0 6 . 5 7 9 . 5 1 2 5 8 . 6 9 3 , 6 5 7 . 7 3 , 5 8 8 . 0 - 3 , 4 2 1 . 9 - 8 , 3 5 6 . 1 5 , 9 6 9 , 3 2 9 . 0 9 4 1 3 , 3 9 6 . 1 3 2 . 0 5 7 , 5 3 6 . 9 10 , 9 0 0 . 3 7 9 . 2 3 2 6 0 . 2 1 3 , 6 7 5 . 0 3 , 6 0 5 . 3 - 3 , 4 3 8 . 8 - 8 , 4 4 6 . 8 5 , 9 6 9 , 3 1 3 . 1 5 4 1 3 , 3 0 5 . 3 2 1 . 6 2 7 , 6 2 2 . 6 10 , 9 9 6 . 0 7 9 . 0 4 2 6 2 . 6 7 3 , 6 9 3 . 0 3 , 6 2 3 . 3 - 3 , 4 5 2 . 8 - 8 , 5 3 9 . 7 5 , 9 6 9 , 3 0 0 . 1 4 4 1 3 , 2 1 2 . 2 9 2 . 5 3 7 , 7 1 1 . 0 11 , 0 9 0 . 3 7 8 . 9 2 2 6 5 . 4 7 3 , 7 1 1 . 0 3 , 6 4 1 . 3 - 3 , 4 6 2 . 4 - 8 , 6 3 1 . 7 5 , 9 6 9 , 2 9 1 . 5 4 4 1 3 , 1 2 0 . 1 4 2 . 9 2 7 , 7 9 9 . 5 11 , 1 8 4 . 6 7 8 . 5 5 2 6 8 . 5 4 3 , 7 2 9 . 5 3 , 6 5 9 . 8 - 3 , 4 6 7 . 2 - 8 , 7 2 4 . 1 5 , 9 6 9 , 2 8 7 . 6 7 4 1 3 , 0 2 7 . 7 2 3 . 2 2 7 , 8 8 9 . 2 11 , 2 8 0 . 3 7 7 . 5 9 2 7 2 . 1 2 3 , 7 4 9 . 2 3 , 6 7 9 . 5 - 3 , 4 6 6 . 7 - 8 , 8 1 7 . 6 5 , 9 6 9 , 2 8 9 . 1 8 4 1 2 , 9 3 4 . 2 1 3 . 8 0 7 , 9 8 1 . 1 11 , 3 7 4 . 5 7 6 . 9 7 2 7 4 . 7 2 3 , 7 7 0 . 0 3 , 7 0 0 . 3 - 3 , 4 6 1 . 2 - 8 , 9 0 9 . 4 5 , 9 6 9 , 2 9 5 . 6 1 4 1 2 , 8 4 2 . 5 3 2 . 7 7 8 , 0 7 2 . 1 11 , 4 6 9 . 9 7 6 . 9 2 2 7 7 . 6 2 3 , 7 9 1 . 5 3 , 7 2 1 . 8 - 3 , 4 5 1 . 2 - 9 , 0 0 1 . 8 5 , 9 6 9 , 3 0 6 . 5 6 4 1 2 , 7 5 0 . 2 8 2 . 9 6 8 , 1 6 4 . 7 11 , 5 6 1 . 0 7 6 . 5 0 2 8 0 . 1 3 3 , 8 1 2 . 5 3 , 7 4 2 . 8 - 3 , 4 3 7 . 5 - 9 , 0 8 9 . 4 5 , 9 6 9 , 3 2 1 . 1 5 4 1 2 , 6 6 2 . 8 3 2 . 7 2 8 , 2 5 3 . 3 Na n u s h u k 11 , 5 6 3 . 8 7 6 . 4 9 2 8 0 . 2 1 3 , 8 1 3 . 1 3 , 7 4 3 . 4 - 3 , 4 3 7 . 0 - 9 , 0 9 2 . 1 5 , 9 6 9 , 3 2 1 . 6 7 4 1 2 , 6 6 0 . 1 1 2 . 7 2 8 , 2 5 6 . 1 11 , 6 0 4 . 0 7 6 . 5 4 2 8 1 . 1 7 3 , 8 2 2 . 5 3 , 7 5 2 . 8 - 3 , 4 2 9 . 8 - 9 , 1 3 0 . 4 5 , 9 6 9 , 3 2 9 . 3 0 4 1 2 , 6 2 1 . 8 6 2 . 3 3 8 , 2 9 5 . 1 11 , 6 3 9 . 0 7 6 . 4 6 2 8 0 . 9 6 3 , 8 3 0 . 7 3 , 7 6 1 . 0 - 3 , 4 2 3 . 2 - 9 , 1 6 3 . 9 5 , 9 6 9 , 3 3 6 . 1 9 4 1 2 , 5 8 8 . 4 9 0 . 6 2 8 , 3 2 9 . 1 9- 5 / 8 " I n t e r m e d i a t e L i n e r 11 , 6 7 0 . 8 7 6 . 3 9 2 8 0 . 7 7 3 , 8 3 8 . 1 3 , 7 6 8 . 4 - 3 , 4 1 7 . 4 - 9 , 1 9 4 . 2 5 , 9 6 9 , 3 4 2 . 3 4 4 1 2 , 5 5 8 . 1 8 0 . 6 2 8 , 3 6 0 . 1 11 , 7 6 5 . 6 7 6 . 4 2 2 8 4 . 6 0 3 , 8 6 0 . 4 3 , 7 9 0 . 7 - 3 , 3 9 7 . 2 - 9 , 2 8 4 . 1 5 , 9 6 9 , 3 6 3 . 4 9 4 1 2 , 4 6 8 . 5 7 3 . 9 3 8 , 4 5 2 . 1 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 8 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 11 , 7 8 3 . 0 7 6 . 3 7 2 8 5 . 3 0 3 , 8 6 4 . 5 3 , 7 9 4 . 8 - 3 , 3 9 2 . 8 - 9 , 3 0 0 . 4 5 , 9 6 9 , 3 6 8 . 0 3 4 1 2 , 4 5 2 . 2 6 3 . 9 2 8 , 4 6 9 . 0 NT 8 M F S 11 , 8 6 0 . 3 7 6 . 1 7 2 8 8 . 4 1 3 , 8 8 2 . 9 3 , 8 1 3 . 2 - 3 , 3 7 1 . 0 - 9 , 3 7 2 . 3 5 , 9 6 9 , 3 9 0 . 5 6 4 1 2 , 3 8 0 . 6 0 3 . 9 2 8 , 5 4 3 . 8 11 , 9 5 5 . 6 7 5 . 9 4 2 9 1 . 1 5 3 , 9 0 5 . 8 3 , 8 3 6 . 1 - 3 , 3 3 9 . 8 - 9 , 4 5 9 . 3 5 , 9 6 9 , 4 2 2 . 7 3 4 1 2 , 2 9 3 . 9 7 2 . 8 0 8 , 6 3 5 . 1 11 , 9 8 4 . 0 7 5 . 9 4 2 9 2 . 2 1 3 , 9 1 2 . 8 3 , 8 4 3 . 1 - 3 , 3 2 9 . 6 - 9 , 4 8 4 . 9 5 , 9 6 9 , 4 3 3 . 1 9 4 1 2 , 2 6 8 . 4 6 3 . 6 3 8 , 6 6 2 . 2 NT 7 M F S 12 , 0 5 0 . 6 7 5 . 9 5 2 9 4 . 7 1 3 , 9 2 8 . 9 3 , 8 5 9 . 2 - 3 , 3 0 3 . 9 - 9 , 5 4 4 . 2 5 , 9 6 9 , 4 5 9 . 5 2 4 1 2 , 2 0 9 . 4 9 3 . 6 3 8 , 7 2 5 . 3 12 , 1 4 5 . 5 7 6 . 1 1 2 9 7 . 3 8 3 , 9 5 1 . 8 3 , 8 8 2 . 1 - 3 , 2 6 3 . 4 - 9 , 6 2 6 . 9 5 , 9 6 9 , 5 0 0 . 8 2 4 1 2 , 1 2 7 . 1 6 2 . 7 3 8 , 8 1 4 . 4 12 , 1 6 5 . 0 7 6 . 1 1 2 9 7 . 9 1 3 , 9 5 6 . 5 3 , 8 8 6 . 8 - 3 , 2 5 4 . 6 - 9 , 6 4 3 . 7 5 , 9 6 9 , 5 0 9 . 7 7 4 1 2 , 1 1 0 . 5 1 2 . 6 3 8 , 8 3 2 . 5 NT 6 M F S 12 , 2 4 1 . 0 7 6 . 1 0 2 9 9 . 9 7 3 , 9 7 4 . 8 3 , 9 0 5 . 1 - 3 , 2 1 9 . 0 - 9 , 7 0 8 . 2 5 , 9 6 9 , 5 4 6 . 1 2 4 1 2 , 0 4 6 . 3 5 2 . 6 3 8 , 9 0 2 . 7 12 , 3 2 0 . 0 7 6 . 0 2 3 0 3 . 8 0 3 , 9 9 3 . 8 3 , 9 2 4 . 1 - 3 , 1 7 8 . 5 - 9 , 7 7 3 . 3 5 , 9 6 9 , 5 8 7 . 2 9 4 1 1 , 9 8 1 . 6 7 4 . 7 0 8 , 9 7 4 . 4 NT 5 M F S 12 , 3 3 5 . 7 7 6 . 0 1 3 0 4 . 5 6 3 , 9 9 7 . 6 3 , 9 2 7 . 9 - 3 , 1 6 9 . 9 - 9 , 7 8 5 . 9 5 , 9 6 9 , 5 9 5 . 9 9 4 1 1 , 9 6 9 . 1 5 4 . 7 0 8 , 9 8 8 . 5 12 , 4 3 1 . 2 7 6 . 7 7 3 0 7 . 5 2 4 , 0 2 0 . 1 3 , 9 5 0 . 4 - 3 , 1 1 5 . 3 - 9 , 8 6 1 . 0 5 , 9 6 9 , 6 5 1 . 3 9 4 1 1 , 8 9 4 . 6 7 3 . 1 1 9 , 0 7 2 . 7 12 , 5 2 6 . 4 7 7 . 7 1 3 1 1 . 8 2 4 , 0 4 1 . 1 3 , 9 7 1 . 4 - 3 , 0 5 6 . 1 - 9 , 9 3 2 . 4 5 , 9 6 9 , 7 1 1 . 3 4 4 1 1 , 8 2 3 . 9 0 4 . 5 2 9 , 1 5 4 . 2 12 , 6 2 1 . 3 7 8 . 1 6 3 1 4 . 7 3 4 , 0 6 1 . 0 3 , 9 9 1 . 3 - 2 , 9 9 2 . 4 - 1 0 , 0 0 0 . 0 5 , 9 6 9 , 7 7 5 . 6 7 4 1 1 , 7 5 6 . 9 9 3 . 0 3 9 , 2 3 2 . 8 12 , 6 2 2 . 0 7 8 . 1 7 3 1 4 . 7 6 4 , 0 6 1 . 1 3 , 9 9 1 . 4 - 2 , 9 9 1 . 9 - 1 0 , 0 0 0 . 5 5 , 9 6 9 , 7 7 6 . 1 5 4 1 1 , 7 5 6 . 5 1 3 . 9 0 9 , 2 3 3 . 3 NT 4 M F S 12 , 7 1 6 . 6 7 9 . 4 7 3 1 8 . 2 7 4 , 0 7 9 . 5 4 , 0 0 9 . 8 - 2 , 9 2 4 . 6 - 1 0 , 0 6 4 . 3 5 , 9 6 9 , 8 4 4 . 1 0 4 1 1 , 6 9 3 . 4 0 3 . 9 0 9 , 3 0 9 . 0 12 , 8 1 2 . 3 8 0 . 5 3 3 2 2 . 6 0 4 , 0 9 6 . 1 4 , 0 2 6 . 4 - 2 , 8 5 2 . 0 - 1 0 , 1 2 4 . 3 5 , 9 6 9 , 9 1 7 . 3 6 4 1 1 , 6 3 4 . 1 5 4 . 5 9 9 , 3 8 1 . 9 12 , 9 0 7 . 0 8 1 . 5 8 3 2 4 . 4 7 4 , 1 1 0 . 8 4 , 0 4 1 . 1 - 2 , 7 7 6 . 7 - 1 0 , 1 7 9 . 9 5 , 9 6 9 , 9 9 3 . 2 2 4 1 1 , 5 7 9 . 3 1 2 . 2 4 9 , 4 5 1 . 0 12 , 9 4 1 . 0 8 1 . 9 6 3 2 5 . 5 5 4 , 1 1 5 . 7 4 , 0 4 6 . 0 - 2 , 7 4 9 . 2 - 1 0 , 1 9 9 . 2 5 , 9 7 0 , 0 2 0 . 9 5 4 1 1 , 5 6 0 . 3 3 3 . 3 4 9 , 4 7 5 . 3 NT 3 M F S 13 , 0 0 2 . 3 8 2 . 6 4 3 2 7 . 5 0 4 , 1 2 3 . 9 4 , 0 5 4 . 2 - 2 , 6 9 8 . 5 - 1 0 , 2 3 2 . 7 5 , 9 7 0 , 0 7 2 . 0 0 4 1 1 , 5 2 7 . 3 3 3 . 3 4 9 , 5 1 8 . 0 13 , 0 9 7 . 7 8 3 . 8 2 3 2 8 . 7 5 4 , 1 3 5 . 1 4 , 0 6 5 . 4 - 2 , 6 1 8 . 0 - 1 0 , 2 8 2 . 8 5 , 9 7 0 , 1 5 2 . 9 4 4 1 1 , 4 7 8 . 1 7 1 . 8 0 9 , 5 8 2 . 6 13 , 1 3 3 . 0 8 3 . 7 9 3 2 8 . 6 9 4 , 1 3 8 . 9 4 , 0 6 9 . 2 - 2 , 5 8 8 . 1 - 1 0 , 3 0 1 . 0 5 , 9 7 0 , 1 8 3 . 1 0 4 1 1 , 4 6 0 . 2 8 0 . 1 8 9 , 6 0 6 . 2 NT 3 . 2 T o p R e s e r v o i r 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 9 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 13 , 1 9 1 . 8 8 3 . 7 5 3 2 8 . 6 0 4 , 1 4 5 . 3 4 , 0 7 5 . 6 - 2 , 5 3 8 . 1 - 1 0 , 3 3 1 . 4 5 , 9 7 0 , 2 3 3 . 3 5 4 1 1 , 4 3 0 . 3 7 0 . 1 8 9 , 6 4 5 . 8 13 , 2 8 7 . 6 8 5 . 2 3 3 2 8 . 7 5 4 , 1 5 4 . 5 4 , 0 8 4 . 8 - 2 , 4 5 6 . 7 - 1 0 , 3 8 1 . 0 5 , 9 7 0 , 3 1 5 . 3 0 4 1 1 , 3 8 1 . 6 6 1 . 5 5 9 , 7 1 0 . 1 13 , 3 8 2 . 6 8 6 . 6 2 3 2 9 . 5 5 4 , 1 6 1 . 3 4 , 0 9 1 . 6 - 2 , 3 7 5 . 3 - 1 0 , 4 2 9 . 6 5 , 9 7 0 , 3 9 7 . 1 6 4 1 1 , 3 3 3 . 9 1 1 . 6 9 9 , 7 7 3 . 6 13 , 4 7 7 . 8 8 7 . 2 3 3 2 9 . 2 8 4 , 1 6 6 . 4 4 , 0 9 6 . 7 - 2 , 2 9 3 . 5 - 1 0 , 4 7 7 . 9 5 , 9 7 0 , 4 7 9 . 4 9 4 1 1 , 2 8 6 . 4 1 0 . 7 0 9 , 8 3 6 . 8 13 , 5 7 2 . 7 8 8 . 6 2 3 2 9 . 5 0 4 , 1 6 9 . 8 4 , 1 0 0 . 1 - 2 , 2 1 1 . 9 - 1 0 , 5 2 6 . 2 5 , 9 7 0 , 5 6 1 . 5 9 4 1 1 , 2 3 8 . 9 8 1 . 4 8 9 , 9 0 0 . 0 13 , 6 6 8 . 0 8 8 . 7 4 3 2 9 . 8 7 4 , 1 7 2 . 0 4 , 1 0 2 . 3 - 2 , 1 2 9 . 7 - 1 0 , 5 7 4 . 3 5 , 9 7 0 , 6 4 4 . 2 9 4 1 1 , 1 9 1 . 7 8 0 . 4 1 9 , 9 6 3 . 0 13 , 7 6 2 . 9 8 9 . 8 5 3 2 9 . 7 2 4 , 1 7 3 . 2 4 , 1 0 3 . 5 - 2 , 0 4 7 . 6 - 1 0 , 6 2 2 . 0 5 , 9 7 0 , 7 2 6 . 8 3 4 1 1 , 1 4 4 . 8 8 1 . 1 8 1 0 , 0 2 5 . 8 13 , 8 5 7 . 6 9 0 . 7 1 3 2 8 . 9 7 4 , 1 7 2 . 7 4 , 1 0 3 . 0 - 1 , 9 6 6 . 2 - 1 0 , 6 7 0 . 3 5 , 9 7 0 , 8 0 8 . 7 4 4 1 1 , 0 9 7 . 4 8 1 . 2 1 1 0 , 0 8 8 . 8 13 , 9 5 2 . 0 9 0 . 4 0 3 2 8 . 5 3 4 , 1 7 1 . 8 4 , 1 0 2 . 1 - 1 , 8 8 5 . 5 - 1 0 , 7 1 9 . 3 5 , 9 7 0 , 8 8 9 . 9 3 4 1 1 , 0 4 9 . 3 6 0 . 5 7 1 0 , 1 5 2 . 5 14 , 0 4 8 . 4 9 0 . 4 6 3 2 8 . 6 7 4 , 1 7 1 . 1 4 , 1 0 1 . 4 - 1 , 8 0 3 . 2 - 1 0 , 7 6 9 . 5 5 , 9 7 0 , 9 7 2 . 7 4 4 1 0 , 9 9 9 . 9 9 0 . 1 6 1 0 , 2 1 7 . 7 14 , 1 4 3 . 4 9 0 . 2 4 3 2 8 . 3 9 4 , 1 7 0 . 5 4 , 1 0 0 . 8 - 1 , 7 2 2 . 2 - 1 0 , 8 1 9 . 1 5 , 9 7 1 , 0 5 4 . 2 5 4 1 0 , 9 5 1 . 2 6 0 . 3 7 1 0 , 2 8 2 . 0 14 , 2 3 8 . 3 9 0 . 4 3 3 2 8 . 0 8 4 , 1 7 0 . 0 4 , 1 0 0 . 3 - 1 , 6 4 1 . 5 - 1 0 , 8 6 9 . 1 5 , 9 7 1 , 1 3 5 . 4 6 4 1 0 , 9 0 2 . 1 4 0 . 3 8 1 0 , 3 4 6 . 6 14 , 3 3 3 . 2 9 0 . 4 3 3 2 8 . 1 4 4 , 1 6 9 . 2 4 , 0 9 9 . 5 - 1 , 5 6 0 . 9 - 1 0 , 9 1 9 . 2 5 , 9 7 1 , 2 1 6 . 5 9 4 1 0 , 8 5 2 . 8 3 0 . 0 6 1 0 , 4 1 1 . 4 14 , 4 2 8 . 6 9 0 . 4 9 3 2 8 . 2 3 4 , 1 6 8 . 5 4 , 0 9 8 . 8 - 1 , 4 7 9 . 8 - 1 0 , 9 6 9 . 5 5 , 9 7 1 , 2 9 8 . 1 4 4 1 0 , 8 0 3 . 4 1 0 . 1 1 1 0 , 4 7 6 . 4 14 , 5 2 3 . 7 9 0 . 4 9 3 2 8 . 9 6 4 , 1 6 7 . 7 4 , 0 9 8 . 0 - 1 , 3 9 8 . 7 - 1 1 , 0 1 9 . 0 5 , 9 7 1 , 3 7 9 . 8 0 4 1 0 , 7 5 4 . 7 1 0 . 7 7 1 0 , 5 4 0 . 7 14 , 6 1 8 . 2 9 0 . 4 3 3 2 9 . 5 2 4 , 1 6 6 . 9 4 , 0 9 7 . 2 - 1 , 3 1 7 . 5 - 1 1 , 0 6 7 . 4 5 , 9 7 1 , 4 6 1 . 5 0 4 1 0 , 7 0 7 . 2 3 0 . 6 0 1 0 , 6 0 3 . 8 14 , 7 1 3 . 9 9 0 . 4 6 3 2 9 . 4 8 4 , 1 6 6 . 2 4 , 0 9 6 . 5 - 1 , 2 3 5 . 0 - 1 1 , 1 1 6 . 0 5 , 9 7 1 , 5 4 4 . 4 8 4 1 0 , 6 5 9 . 5 1 0 . 0 5 1 0 , 6 6 7 . 5 14 , 8 0 8 . 9 9 0 . 5 5 3 2 9 . 8 3 4 , 1 6 5 . 3 4 , 0 9 5 . 6 - 1 , 1 5 3 . 1 - 1 1 , 1 6 3 . 9 5 , 9 7 1 , 6 2 6 . 8 9 4 1 0 , 6 1 2 . 4 1 0 . 3 8 1 0 , 7 3 0 . 4 14 , 9 0 3 . 6 9 0 . 5 8 3 2 9 . 6 7 4 , 1 6 4 . 4 4 , 0 9 4 . 7 - 1 , 0 7 1 . 3 - 1 1 , 2 1 1 . 6 5 , 9 7 1 , 7 0 9 . 1 9 4 1 0 , 5 6 5 . 5 6 0 . 1 7 1 0 , 7 9 3 . 0 14 , 9 9 8 . 6 9 0 . 4 9 3 3 0 . 1 1 4 , 1 6 3 . 5 4 , 0 9 3 . 8 - 9 8 9 . 1 - 1 1 , 2 5 9 . 3 5 , 9 7 1 , 7 9 1 . 8 6 4 1 0 , 5 1 8 . 7 7 0 . 4 7 1 0 , 8 5 5 . 6 15 , 0 9 3 . 1 9 0 . 5 8 3 3 0 . 1 5 4 , 1 6 2 . 6 4 , 0 9 2 . 9 - 9 0 7 . 1 - 1 1 , 3 0 6 . 3 5 , 9 7 1 , 8 7 4 . 2 7 4 1 0 , 4 7 2 . 5 7 0 . 1 0 1 0 , 9 1 7 . 6 15 , 1 8 8 . 5 9 0 . 5 2 3 2 9 . 7 1 4 , 1 6 1 . 7 4 , 0 9 2 . 0 - 8 2 4 . 6 - 1 1 , 3 5 4 . 1 5 , 9 7 1 , 9 5 7 . 3 1 4 1 0 , 4 2 5 . 6 4 0 . 4 7 1 0 , 9 8 0 . 5 15 , 2 8 3 . 6 9 0 . 5 2 3 2 9 . 3 6 4 , 1 6 0 . 8 4 , 0 9 1 . 1 - 7 4 2 . 6 - 1 1 , 4 0 2 . 4 5 , 9 7 2 , 0 3 9 . 7 6 4 1 0 , 3 7 8 . 3 0 0 . 3 7 1 1 , 0 4 3 . 6 15 , 3 7 8 . 8 9 0 . 4 9 3 2 8 . 8 6 4 , 1 6 0 . 0 4 , 0 9 0 . 3 - 6 6 0 . 9 - 1 1 , 4 5 1 . 3 5 , 9 7 2 , 1 2 2 . 0 2 4 1 0 , 3 3 0 . 2 4 0 . 5 3 1 1 , 1 0 7 . 4 15 , 4 7 3 . 8 9 0 . 4 3 3 2 8 . 5 5 4 , 1 5 9 . 2 4 , 0 8 9 . 5 - 5 7 9 . 7 - 1 1 , 5 0 0 . 6 5 , 9 7 2 , 2 0 3 . 6 7 4 1 0 , 2 8 1 . 7 7 0 . 3 3 1 1 , 1 7 1 . 5 15 , 5 6 9 . 0 9 0 . 4 6 3 2 8 . 6 7 4 , 1 5 8 . 5 4 , 0 8 8 . 8 - 4 9 8 . 4 - 1 1 , 5 5 0 . 2 5 , 9 7 2 , 2 8 5 . 4 5 4 1 0 , 2 3 3 . 0 3 0 . 1 3 1 1 , 2 3 5 . 9 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 10 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 15 , 6 6 4 . 1 9 0 . 4 6 3 2 8 . 7 4 4 , 1 5 7 . 7 4 , 0 8 8 . 0 - 4 1 7 . 2 - 1 1 , 5 9 9 . 6 5 , 9 7 2 , 3 6 7 . 1 8 4 1 0 , 1 8 4 . 5 0 0 . 0 7 1 1 , 3 0 0 . 1 15 , 7 5 9 . 2 9 0 . 4 9 3 2 8 . 6 3 4 , 1 5 6 . 9 4 , 0 8 7 . 2 - 3 3 6 . 0 - 1 1 , 6 4 9 . 0 5 , 9 7 2 , 4 4 8 . 9 1 4 1 0 , 1 3 5 . 9 5 0 . 1 2 1 1 , 3 6 4 . 2 15 , 8 5 4 . 5 9 0 . 4 6 3 2 9 . 0 0 4 , 1 5 6 . 2 4 , 0 8 6 . 5 - 2 5 4 . 4 - 1 1 , 6 9 8 . 4 5 , 9 7 2 , 5 3 0 . 9 9 4 1 0 , 0 8 7 . 4 3 0 . 3 9 1 1 , 4 2 8 . 4 15 , 9 4 9 . 6 9 0 . 5 2 3 2 9 . 4 9 4 , 1 5 5 . 3 4 , 0 8 5 . 6 - 1 7 2 . 7 - 1 1 , 7 4 7 . 0 5 , 9 7 2 , 6 1 3 . 1 9 4 1 0 , 0 3 9 . 6 6 0 . 5 2 1 1 , 4 9 2 . 0 16 , 0 4 4 . 3 9 0 . 4 3 3 3 0 . 2 0 4 , 1 5 4 . 6 4 , 0 8 4 . 9 - 9 0 . 8 - 1 1 , 7 9 4 . 6 5 , 9 7 2 , 6 9 5 . 5 8 4 0 9 , 9 9 2 . 9 5 0 . 7 6 1 1 , 5 5 4 . 5 16 , 1 3 9 . 4 9 0 . 3 4 3 3 0 . 2 2 4 , 1 5 3 . 9 4 , 0 8 4 . 2 - 8 . 3 - 1 1 , 8 4 1 . 8 5 , 9 7 2 , 7 7 8 . 5 8 4 0 9 , 9 4 6 . 5 7 0 . 1 0 1 1 , 6 1 6 . 8 16 , 2 3 4 . 4 9 0 . 3 4 3 2 9 . 7 3 4 , 1 5 3 . 4 4 , 0 8 3 . 7 7 4 . 0 - 1 1 , 8 8 9 . 3 5 , 9 7 2 , 8 6 1 . 3 1 4 0 9 , 8 9 9 . 9 0 0 . 5 2 1 1 , 6 7 9 . 3 16 , 3 2 9 . 5 9 0 . 3 1 3 2 9 . 3 6 4 , 1 5 2 . 8 4 , 0 8 3 . 1 1 5 5 . 9 - 1 1 , 9 3 7 . 5 5 , 9 7 2 , 9 4 3 . 7 4 4 0 9 , 8 5 2 . 5 9 0 . 3 9 1 1 , 7 4 2 . 4 16 , 4 2 4 . 5 9 0 . 3 7 3 2 8 . 9 7 4 , 1 5 2 . 2 4 , 0 8 2 . 5 2 3 7 . 5 - 1 1 , 9 8 6 . 2 5 , 9 7 3 , 0 2 5 . 8 6 4 0 9 , 8 0 4 . 7 2 0 . 4 2 1 1 , 8 0 6 . 0 16 , 5 1 9 . 5 9 0 . 4 0 3 2 9 . 0 7 4 , 1 5 1 . 6 4 , 0 8 1 . 9 3 1 8 . 9 - 1 2 , 0 3 5 . 1 5 , 9 7 3 , 1 0 7 . 7 6 4 0 9 , 7 5 6 . 7 0 0 . 1 1 1 1 , 8 6 9 . 7 16 , 6 1 4 . 5 9 0 . 3 1 3 2 9 . 2 2 4 , 1 5 1 . 0 4 , 0 8 1 . 3 4 0 0 . 5 - 1 2 , 0 8 3 . 8 5 , 9 7 3 , 1 8 9 . 8 0 4 0 9 , 7 0 8 . 8 5 0 . 1 8 1 1 , 9 3 3 . 3 16 , 7 1 0 . 1 9 0 . 4 0 3 2 9 . 2 0 4 , 1 5 0 . 4 4 , 0 8 0 . 7 4 8 2 . 6 - 1 2 , 1 3 2 . 8 5 , 9 7 3 , 2 7 2 . 4 1 4 0 9 , 6 6 0 . 7 8 0 . 1 0 1 1 , 9 9 7 . 1 16 , 8 0 5 . 0 9 0 . 3 4 3 2 8 . 8 5 4 , 1 4 9 . 8 4 , 0 8 0 . 1 5 6 4 . 0 - 1 2 , 1 8 1 . 6 5 , 9 7 3 , 3 5 4 . 3 3 4 0 9 , 6 1 2 . 7 6 0 . 3 7 1 2 , 0 6 0 . 8 16 , 9 0 0 . 1 9 0 . 4 6 3 2 9 . 3 5 4 , 1 4 9 . 2 4 , 0 7 9 . 5 6 4 5 . 6 - 1 2 , 2 3 0 . 5 5 , 9 7 3 , 4 3 6 . 4 2 4 0 9 , 5 6 4 . 7 8 0 . 5 4 1 2 , 1 2 4 . 5 16 , 9 9 5 . 2 9 0 . 3 7 3 2 9 . 5 9 4 , 1 4 8 . 5 4 , 0 7 8 . 8 7 2 7 . 5 - 1 2 , 2 7 8 . 8 5 , 9 7 3 , 5 1 8 . 8 0 4 0 9 , 5 1 7 . 3 5 0 . 2 7 1 2 , 1 8 7 . 7 17 , 0 9 0 . 3 9 0 . 4 0 3 2 9 . 2 8 4 , 1 4 7 . 8 4 , 0 7 8 . 1 8 0 9 . 4 - 1 2 , 3 2 7 . 1 5 , 9 7 3 , 6 0 1 . 1 9 4 0 9 , 4 6 9 . 8 4 0 . 3 3 1 2 , 2 5 1 . 0 17 , 1 8 5 . 4 9 0 . 3 7 3 2 9 . 8 7 4 , 1 4 7 . 2 4 , 0 7 7 . 5 8 9 1 . 4 - 1 2 , 3 7 5 . 3 5 , 9 7 3 , 6 8 3 . 6 7 4 0 9 , 4 2 2 . 5 6 0 . 6 2 1 2 , 3 1 4 . 1 17 , 2 8 0 . 3 9 0 . 3 7 3 2 9 . 8 5 4 , 1 4 6 . 6 4 , 0 7 6 . 9 9 7 3 . 4 - 1 2 , 4 2 2 . 9 5 , 9 7 3 , 7 6 6 . 1 9 4 0 9 , 3 7 5 . 7 9 0 . 0 2 1 2 , 3 7 6 . 7 17 , 3 7 4 . 9 9 0 . 5 2 3 2 9 . 9 5 4 , 1 4 5 . 8 4 , 0 7 6 . 1 1 , 0 5 5 . 3 - 1 2 , 4 7 0 . 4 5 , 9 7 3 , 8 4 8 . 5 3 4 0 9 , 3 2 9 . 2 0 0 . 1 9 1 2 , 4 3 9 . 1 17 , 4 7 0 . 1 9 0 . 4 6 3 2 9 . 6 4 4 , 1 4 5 . 0 4 , 0 7 5 . 3 1 , 1 3 7 . 6 - 1 2 , 5 1 8 . 3 5 , 9 7 3 , 9 3 1 . 3 1 4 0 9 , 2 8 2 . 1 6 0 . 3 3 1 2 , 5 0 2 . 0 17 , 5 6 5 . 2 9 0 . 5 2 3 2 9 . 5 1 4 , 1 4 4 . 2 4 , 0 7 4 . 5 1 , 2 1 9 . 5 - 1 2 , 5 6 6 . 4 5 , 9 7 4 , 0 1 3 . 7 8 4 0 9 , 2 3 4 . 8 8 0 . 1 5 1 2 , 5 6 5 . 1 17 , 6 6 0 . 0 9 0 . 4 6 3 2 8 . 7 8 4 , 1 4 3 . 4 4 , 0 7 3 . 7 1 , 3 0 1 . 0 - 1 2 , 6 1 5 . 1 5 , 9 7 4 , 0 9 5 . 7 0 4 0 9 , 1 8 7 . 0 8 0 . 7 7 1 2 , 6 2 8 . 6 17 , 7 5 5 . 6 9 0 . 5 5 3 2 8 . 5 8 4 , 1 4 2 . 6 4 , 0 7 2 . 9 1 , 3 8 2 . 6 - 1 2 , 6 6 4 . 7 5 , 9 7 4 , 1 7 7 . 8 1 4 0 9 , 1 3 8 . 2 9 0 . 2 3 1 2 , 6 9 3 . 1 17 , 8 5 0 . 0 9 0 . 4 9 3 2 8 . 3 1 4 , 1 4 1 . 7 4 , 0 7 2 . 0 1 , 4 6 3 . 0 - 1 2 , 7 1 4 . 1 5 , 9 7 4 , 2 5 8 . 7 6 4 0 9 , 0 8 9 . 7 3 0 . 2 9 1 2 , 7 5 7 . 1 17 , 9 4 5 . 6 9 0 . 4 6 3 2 8 . 2 2 4 , 1 4 0 . 9 4 , 0 7 1 . 2 1 , 5 4 4 . 4 - 1 2 , 7 6 4 . 4 5 , 9 7 4 , 3 4 0 . 6 2 4 0 9 , 0 4 0 . 2 8 0 . 1 0 1 2 , 8 2 2 . 2 18 , 0 4 0 . 7 9 0 . 4 3 3 2 8 . 6 3 4 , 1 4 0 . 2 4 , 0 7 0 . 5 1 , 6 2 5 . 3 - 1 2 , 8 1 4 . 2 5 , 9 7 4 , 4 2 2 . 0 9 4 0 8 , 9 9 1 . 3 7 0 . 4 3 1 2 , 8 8 6 . 6 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 11 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e MD (u s f t ) In c (° ) Az i ( a z i m u t h ) (° ) N/ S (u s f t ) E/ W (u s f t ) No r t h i n g (u s f t ) TV D S S (u s f t ) Ea s t i n g (u s f t ) Su r v e y TV D (u s f t ) DL e g (° / 1 0 0 u s f t ) V. S e c (u s f t ) 18 , 1 3 5 . 5 9 0 . 4 6 3 2 8 . 9 1 4 , 1 3 9 . 4 4 , 0 6 9 . 7 1 , 7 0 6 . 5 - 1 2 , 8 6 3 . 4 5 , 9 7 4 , 5 0 3 . 7 3 4 0 8 , 9 4 3 . 0 3 0 . 3 0 1 2 , 9 5 0 . 6 18 , 2 3 1 . 0 9 0 . 4 3 3 2 9 . 1 9 4 , 1 3 8 . 7 4 , 0 6 9 . 0 1 , 7 8 8 . 3 - 1 2 , 9 1 2 . 5 5 , 9 7 4 , 5 8 6 . 0 8 4 0 8 , 8 9 4 . 8 0 0 . 3 0 1 3 , 0 1 4 . 6 18 , 3 2 5 . 7 9 0 . 5 2 3 2 9 . 7 0 4 , 1 3 7 . 9 4 , 0 6 8 . 2 1 , 8 6 9 . 9 - 1 2 , 9 6 0 . 6 5 , 9 7 4 , 6 6 8 . 1 4 4 0 8 , 8 4 7 . 5 1 0 . 5 5 1 3 , 0 7 7 . 6 18 , 4 2 0 . 8 9 0 . 5 2 3 3 0 . 0 2 4 , 1 3 7 . 0 4 , 0 6 7 . 3 1 , 9 5 2 . 1 - 1 3 , 0 0 8 . 3 5 , 9 7 4 , 7 5 0 . 8 2 4 0 8 , 8 0 0 . 6 5 0 . 3 4 1 3 , 1 4 0 . 3 18 , 5 1 5 . 8 9 0 . 4 0 3 2 9 . 7 8 4 , 1 3 6 . 3 4 , 0 6 6 . 6 2 , 0 3 4 . 3 - 1 3 , 0 5 6 . 0 5 , 9 7 4 , 8 3 3 . 5 6 4 0 8 , 7 5 3 . 8 3 0 . 2 8 1 3 , 2 0 3 . 0 18 , 6 1 1 . 1 9 0 . 4 3 3 2 9 . 7 1 4 , 1 3 5 . 6 4 , 0 6 5 . 9 2 , 1 1 6 . 6 - 1 3 , 1 0 4 . 0 5 , 9 7 4 , 9 1 6 . 2 9 4 0 8 , 7 0 6 . 7 2 0 . 0 8 1 3 , 2 6 6 . 0 18 , 7 0 6 . 3 9 0 . 5 2 3 2 9 . 2 0 4 , 1 3 4 . 8 4 , 0 6 5 . 1 2 , 1 9 8 . 6 - 1 3 , 1 5 2 . 4 5 , 9 7 4 , 9 9 8 . 7 8 4 0 8 , 6 5 9 . 2 0 0 . 5 4 1 3 , 3 2 9 . 3 18 , 8 0 1 . 4 9 2 . 3 3 3 2 8 . 2 9 4 , 1 3 2 . 4 4 , 0 6 2 . 7 2 , 2 7 9 . 9 - 1 3 , 2 0 1 . 7 5 , 9 7 5 , 0 8 0 . 6 1 4 0 8 , 6 1 0 . 6 9 2 . 1 3 1 3 , 3 9 3 . 4 18 , 8 9 6 . 7 9 3 . 0 7 3 2 4 . 6 1 4 , 1 2 7 . 9 4 , 0 5 8 . 2 2 , 3 5 9 . 2 - 1 3 , 2 5 4 . 3 5 , 9 7 5 , 1 6 0 . 3 9 4 0 8 , 5 5 8 . 9 8 3 . 9 4 1 3 , 4 6 0 . 3 18 , 9 9 1 . 7 9 5 . 6 2 3 2 2 . 1 7 4 , 1 2 0 . 7 4 , 0 5 1 . 0 2 , 4 3 5 . 2 - 1 3 , 3 1 0 . 8 5 , 9 7 5 , 2 3 7 . 0 5 4 0 8 , 5 0 3 . 2 6 3 . 7 1 1 3 , 5 3 0 . 5 19 , 0 8 6 . 6 9 8 . 3 1 3 1 9 . 4 5 4 , 1 0 9 . 2 4 , 0 3 9 . 5 2 , 5 0 8 . 2 - 1 3 , 3 7 0 . 3 5 , 9 7 5 , 3 1 0 . 6 6 4 0 8 , 4 4 4 . 5 2 4 . 0 2 1 3 , 6 0 3 . 0 19 , 1 7 7 . 0 1 0 0 . 0 9 3 1 7 . 0 0 4 , 0 9 4 . 8 4 , 0 2 5 . 1 2 , 5 7 4 . 8 - 1 3 , 4 2 9 . 7 5 , 9 7 5 , 3 7 7 . 8 0 4 0 8 , 3 8 5 . 7 9 3 . 3 3 1 3 , 6 7 4 . 2 4- 1 / 2 " P r o d u c t i o n L i n e r 19 , 1 8 1 . 6 1 0 0 . 1 8 3 1 6 . 8 7 4 , 0 9 4 . 0 4 , 0 2 4 . 3 2 , 5 7 8 . 1 - 1 3 , 4 3 2 . 8 5 , 9 7 5 , 3 8 1 . 1 3 4 0 8 , 3 8 2 . 7 4 3 . 3 3 1 3 , 6 7 7 . 8 19 , 2 5 5 . 0 1 0 1 . 4 2 3 1 5 . 8 5 4 , 0 8 0 . 2 4 , 0 1 0 . 5 2 , 6 3 0 . 2 - 1 3 , 4 8 2 . 6 5 , 9 7 5 , 4 3 3 . 8 3 4 0 8 , 3 3 3 . 5 3 2 . 1 8 1 3 , 7 3 6 . 7 NT 3 . 2 T o p R e s e r v o i r ) 19 , 2 7 6 . 2 1 0 1 . 7 8 3 1 5 . 5 5 4 , 0 7 5 . 9 4 , 0 0 6 . 2 2 , 6 4 5 . 1 - 1 3 , 4 9 7 . 1 5 , 9 7 5 , 4 4 8 . 8 7 4 0 8 , 3 1 9 . 1 5 2 . 1 8 1 3 , 7 5 3 . 9 19 , 3 0 2 . 0 1 0 1 . 7 8 3 1 5 . 5 5 4 , 0 7 0 . 7 4 , 0 0 1 . 0 2 , 6 6 3 . 1 - 1 3 , 5 1 4 . 8 5 , 9 7 5 , 4 6 7 . 0 5 4 0 8 , 3 0 1 . 6 9 0 . 0 0 1 3 , 7 7 4 . 7 Pr o j T D 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 12 Pr o j e c t : Co m p a n y : Lo c a l C o - o r d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s L t d Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : B- 4 9 ND B i - 0 4 9 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 @ 6 9 . 7 u s f t De s i g n : ND B i - 0 4 9 Da t a b a s e : ED M MD R e f e r e n c e : Pa r k e r 2 7 2 @ 6 9 . 7 u s f t No r t h R e f e r e n c e : We l l B - 4 9 Tr u e Ve r t i c a l De p t h (u s f t ) Me a s u r e d De p t h (u s f t ) Ca s i n g Di a m e t e r (" ) Ho l e Di a m e t e r (" ) Na m e Ca s i n g P o i n t s 20 " C o n d u c t o r C a s i n g 12 8 . 0 12 8 . 0 20 2 0 13 - 3 / 8 " S u r f a c e C a s i n g 2, 2 6 9 . 6 2, 6 0 8 . 0 13 - 3 / 8 1 6 9- 5 / 8 " I n t e r m e d i a t e L i n e r 3, 8 3 0 . 7 11 , 6 3 9 . 0 9- 5 / 8 1 2 - 1 / 4 4- 1 / 2 " P r o d u c t i o n L i n e r 4, 0 9 4 . 8 19 , 1 7 7 . 0 4- 1 / 2 8 - 1 / 2 Me a s u r e d De p t h (u s f t ) Ve r t i c a l De p t h (u s f t ) Di p Di r e c t i o n (° ) Na m e L i t h o l o g y Di p (° ) Fo r m a t i o n s 5, 2 3 5 . 0 2 , 8 1 6 . 0 T S _ 7 9 0 7, 9 2 1 . 0 3 , 2 1 8 . 0 S e a b e e 11 , 9 8 4 . 0 3 , 9 1 2 . 8 N T 7 M F S 12 , 6 2 2 . 0 4 , 0 6 1 . 1 N T 4 M F S 2, 3 8 1 . 0 2 , 1 4 2 . 6 M C U 11 , 7 8 3 . 0 3 , 8 6 4 . 5 N T 8 M F S 13 , 1 3 3 . 0 4 , 1 3 8 . 9 N T 3 . 2 T o p R e s e r v o i r 12 , 9 4 1 . 0 4 , 1 1 5 . 7 N T 3 M F S 3, 0 1 5 . 0 2 , 4 4 8 . 4 T u l u v a k S h a l e 1, 0 5 2 . 0 1 , 0 4 2 . 9 U p p e r S c h r a d e r B l u f f 3, 2 3 8 . 0 2 , 5 1 0 . 3 T u l u v a k S a n d 12 , 1 6 5 . 0 3 , 9 5 6 . 5 N T 6 M F S 19 , 2 5 5 . 0 4 , 0 8 0 . 2 N T 3 . 2 T o p R e s e r v o i r ) 1, 8 0 1 . 0 1 , 7 2 8 . 5 M i d d l e S c h r a d e r B l u f f 11 , 5 6 1 . 0 3 , 8 1 2 . 5 N a n u s h u k 1, 4 0 4 . 0 1 , 3 7 8 . 7 B a s e P e r m a f r o s t T r a n s i t i o n 12 , 3 2 0 . 0 3 , 9 9 3 . 8 N T 5 M F S 12 / 1 2 / 2 0 2 4 1 1 : 4 1 : 3 0 CO M P A S S 5 0 0 0 . 1 7 B u i l d Pa g e 13 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:Conwell, Russell (Russell) Cc:Tirpack, Robert (Robert) Subject:RE: NDBi-049 Surface Casing Test and FIT (PTD 224-119) Date:Monday, November 18, 2024 4:34:00 PM Russell, No issues with the higher FIT values at either casing string. Oilsearch has approval to proceed with the changes to the NDBi-049 PTD as described in your email below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Conwell, Russell (Russell) <Russell.Conwell@santos.com> Sent: Monday, November 18, 2024 7:06 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com> Subject: NDBi-049 Surface Casing Test and FIT (PTD 224-119) Hi Bryan, Attached are the FIT results for the 13-3/8” shoe that was conducted on Sunday - good FIT test to 14.5ppg EWM. Note, we increased the FIT value in the PTD (13ppg) due to a higher than anticipated ECD seen after drilling out the shoe and displacing to the new mud (i.e. rheology and backpressure through the MPD system). The increased FIT was required to confirm adequate formation strength at the shoe for drilling ahead with the higher ECD. Also, looking ahead, we plan to increase the FIT at the 9-5/8” shoe to 15ppg rather than the 14ppg in the PTD. This is due to the fact that the 9-5/8” shoe is set in the top of the Nanushuk and we don’t have any LOT / FIT at this depth from other wells. The increased FIT at this depth will provide further data for the modified casing design on this well and future wells. Let me know if you have any questions or concerns with the 13-3/8” FIT data or proposed FIT at the 9-5/8” shoe. Thanks Russell Russell Conwell Senior Drilling Engineer m: +1 907 615 2234| e: russell.conwell@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 beconfidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use,distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PIKKA NDBi-049 JBR 01/28/2025 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 Great Test, jested with 5 7/8" and 9 5/8" test joints. Precharge Bottles = 21@1100psi and 3@1000psi. Test Results TEST DATA Rig Rep:Sonny ClarkOperator:Oil Search (Alaska), LLC Operator Rep:Brian Buzby Rig Owner/Rig No.:Parker 272 PTD#:2241190 DATE:11/16/2024 Type Operation:DRILL Annular: 250/3600Type Test:INIT Valves: 250/3600 Rams: 250/3600 Test Pressures:Inspection No:bopBDB241119031224 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 1493 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 P #2 Rams 1 Blind/shear P #3 Rams 1 9 5/8 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 2 1/16,3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2100 200 PSI Attained P19 Full Pressure Attained P64 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P14@2300 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 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 9 9 9999 9 9 9 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Russell Conwell Senior Drilling Engineer Oil Search Alaska, LLC 900 E Benson Boulevard Anchorage, AK, 99508 Re: Pikka Field, Nanushuk Oil Pool, Pikka NDBi-049 Oil Search Alaska, LLC Permit to Drill Number: 224-119 Surface Location: 2275’ FSL, 1823’ FWL, Sec 4, T11N, R6E, UM Bottomhole Location: 5046’ FSL, 1634’ FEL, Sec 1, T11N, R5E, UM Dear Mr. Conwell: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. Proposed dry ditch sample interval from Attachment 9 accepted with modification of Ivishak (not to exceed 30'). This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this 25 th day of October 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.25 09:30:04 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 19,470' TVD: 4,040' 4a. Location of Well (Governmental Section): 7. Property Designation: ADL 392984, Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 11/15/2024 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2,697' 10. KB Elevation above MSL (ft): 69.82' 15. Distance to Nearest Well Open4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 70.207553 y- -150.384358 Zone- 4 22.82' to Same Pool: 360' 16. Deviated wells: Kickoff depth: 397 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 102 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20"x34" 215# X-52 Welded 80' Surface Surface 128' 54' 16" 13-3/8" 68# L-80 BTC or TXP BTC 2,625' Surface Surface 2,625' 2,290' 12-1/4" 9-5/8" 47# L-80 HYD563 9,135' 2,475' 2,208' 11,610' 3,823' Tie Back 9-5/8" 47# L-80 HYD563 2,475' Surface Surface 2,475' 2,208' 8-1/2" 4-1/2" 12.6# P-110S HYD563 8,007' 11,460' 3,789' 19,467' 4,040' Tubing 4-1/2" 12.6# P-110S HYD563 11,460' Surface Surface 11,460' 3,789' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Russell Conwell Russell Conwell Contact Email:russell.conwell@santos.com Senior Drilling Engineer Contact Phone:1-907-615-2234 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft):Perforation Depth MD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Conductor/Structural LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) Grouted to surface See attachment 6 See attachment 6 N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): 3589 18. Casing Program: Top - Setting Depth - BottomSpecifications 1,909 GL / BF Elevation above MSL (ft): Total Depth MD (ft): Total Depth TVD (ft): IS000361277U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 See attachment 6 1,493 4540’ FSL, 1200’ FEL, Sec 1, T11N, R5E, UM 5046’ FSL, 1634’ FEL, Sec 1, T11N, R5E, UM LONS 19-003 601 W Fifth Avenue, Anchorage, AK 99501-6301 Oil Search Alaska, LLC 2445’ FSL, 2860’ FEL, Sec 4, T11N, R6E, UM 391445, 393023, 393022, 393021, 392958 NDBi-049 Pikka/Nanushuk Oil Pool Uncemented Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. s N ype of W L l R L 1b S Class: os N s No s N o D s s sD 277U o : well is p GS S S 20 S S S s No s No S G E S s No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) enior Drilling Engineer By Grace Christianson at 4:18 pm, Sep 26, 2024 7:53 am, Sep 27, 2024 224-119 BJM 10/24/24 A.Dewhurst 24OCT24 5,972,663' See attached emails. -A.Dewhurst 24OCT24 See attached conditions of approval Variance from pool rules granted to isolate Tuluvak significant hydrocarbons as proposed. -A.Dewhurst 23OCT24 Pikka DSR-9/27/24 421,786' 50-103-20894-00-00 2,275’ FSL, 1,823’ FWL *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.25 09:30:15 -08'00'10/25/24 10/25/24 RBDMS JSB 102924 NDBi-049 (PTD 224-119) WĞƌŵŝƚƚŽƌŝůůŽŶĚŝƟŽŶƐŽĨApproval 1. KWƚĞƐƚƚŽϯ6ϬϬƉƐŝ͕ŶŶƵůĂƌƚĞƐƚƚŽϯϬϬϬƉƐŝ͘ 2. >Kdͬ&/dƌĞƐƵůƚƐƚŽďĞƐƵďŵŝƩĞĚƚŽK'ǁŝƚŚŝŶϰϴŚŽƵƌƐŽĨŽďƚĂŝŶŝŶŐƚŚĞĚĂƚĂ͘ ϯ͘ /ĨDWǁŝůůďĞƵƐĞĚ͕Kŝů^ĞĂƌĐŚŵƵƐƚŵĂŝŶƚĂŝŶŵƵĚĚĞŶƐŝƚLJŝŶĞdžĐĞƐƐŽĨƚŚĞŚŝŐŚĞƐƚĂŶƟĐŝƉĂƚĞĚ ƌĞƐĞƌǀŽŝƌ Dt. 4. EŽƟĨLJK'ŝĨĐĞŵĞŶƚũŽďƐĚŽŶŽƚŐŽĂĐĐŽƌĚŝŶŐƚŽƉůĂŶŽƌŝĨũŽďƉĂƌĂŵĞƚĞƌƐĂƌĞŶŽƚĂƐ ĞdžƉĞĐƚĞĚ;ůŽƐƐĞƐŽĐĐƵƌ͕ƵŶĞdžƉĞĐƚĞĚůŝŌƉƌĞƐƐƵƌĞƐŽĐĐƵƌ͕ĐĞŵĞŶƚŝƐŶŽƚĐŝƌĐƵůĂƚĞĚŽīƚŚĞƚŽƉŽĨ ƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞůŝŶĞƌ͕ĞƚĐ͘Ϳ. Cement ƚŽďĞůŽŐŐĞĚŝĨũŽďĚŽĞƐŶŽƚŐŽĂĐĐŽƌĚŝŶŐƚŽƉůĂŶ͘ 5. sĂƌŝĂŶĐĞƚŽϮϬϮϱ͘ϬϯϬ;ĚͿ;ϱͿĨŽƌϮ-ƐƚĂŐĞŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐ ĐĞŵĞŶƚŽƉĞƌĂƟŽŶĂŶĚŐĂƉŝŶ ĐĞŵĞŶƚĐŽǀĞƌĂŐĞŝƐĂƉƉƌŽǀĞĚ͕ǁŝƚŚƐƚĂŐĞĐŽůůĂƌƉůĂĐĞŵĞŶƚĂƐĨŽůůŽǁƐ ;ƌĞĨĞƌĞŶĐĞƐĞĐƟŽŶϭϱŝŶ WdĂƉƉůŝĐĂƟŽŶͿ: a. ^ƚĂŐĞĐŽůůĂƌŵƵƐƚďĞƉůĂĐĞĚŶŽƐŚĂůůŽǁĞƌƚŚĂŶϱϬΖDďĞůŽǁƚŚĞďĂƐĞŽĨƚŚĞhƉƉĞƌ dƵůƵǀĂŬĂƐĚĞĮŶĞĚďLJƚŚĞd^ϳϵϬŚŽƌŝnjŽŶ͘ ď͘ ^ƵďŵŝƚϭϮ-ϭͬϰΗK,ůŽŐƐƚŽK'ĂƐƐŽŽŶĂƐƉƌĂĐƟĐĂůĂŌĞƌdŽĨŚŽůĞƐĞĐƟŽŶ͘ dŚĞ d^ϳϵϬŵĂƌŬĞƌŝƐǁĞůů-ĞƐƚĂďůŝƐŚĞĚŝŶƚŚĞĂƌĞĂŽĨEƉĂĚĂŶĚƚŚĞƌĞĨŽƌĞKŝů^ĞĂƌĐŚĚŽĞƐ ŶŽƚŶĞĞĚƚŽƐĞĞŬK'ĂƉƉƌŽǀĂůŽĨƚŚĞŝƌƉŝĐŬŽĨƚŚĞd^ϳϵϬďĞĨŽƌĞƌƵŶŶŝŶŐϵ-ϱͬϴ͟ ĐĂƐŝŶŐ͘ 6. dŚĞ>t-^ŽŶŝĐůŽŐǁŝůůŽŶůLJďĞĂĐĐĞƉƚĞĚĨŽƌĐĞŵĞŶƚĞǀĂůƵĂƟŽŶǁŚĞŶƚŚĞĨŽůůŽǁŝŶŐĐŽŶĚŝƟŽŶƐ are met: a. KŝůƐĞĂƌĐŚƚŽƉƌŽǀŝĚĞĂǁƌŝƩĞŶůŽŐĞǀĂůƵĂƟŽŶͬŝŶƚĞƌƉƌĞƚĂƟŽŶƚŽƚŚĞK'ĂůŽŶŐǁŝƚŚƚŚĞ ůŽŐĂƐƐŽŽŶĂƐƚŚĞLJďĞĐŽŵĞĂǀĂŝůĂďůĞ͘dŚĞĞǀĂůƵĂƟŽŶŝƐƚŽŝŶĚŝĐĂƚĞƚŚĞŝŶƚĞƌǀĂůƐŽĨ ĐŽŵƉĞƚĞŶƚĐĞŵĞŶƚƚŚĂƚKŝůƐĞĂƌĐŚŝƐƵƐŝŶŐƚŽŵĞĞƚƚŚĞŽďũĞĐƟǀĞƌĞƋƵŝƌĞŵĞŶƚƐĨŽƌ aŶŶƵůĂƌŝƐŽůĂƟŽŶĂŶĚƌĞƐĞƌǀŽŝƌŝƐŽůĂƟŽŶ͕ĂŶĚƚŽŝŶĚŝĐĂƚĞƚŚĞůŽĐĂƟŽŶŽĨĐŽŶĮŶŝŶŐnjŽŶĞƐ͕ ŚLJĚƌŽĐĂƌďŽŶ-ďĞĂƌŝŶŐnjŽŶĞƐ͕ŽǀĞƌƉƌĞƐƐƵƌĞĚnjŽŶĞƐĂŶĚĨƌĞƐŚǁĂƚĞƌ͕ŝĨƉƌĞƐĞŶƚ͘WƌŽǀŝĚŝŶŐ ƚŚĞůŽŐǁŝƚŚŽƵƚĂŶĞǀĂůƵĂƟŽŶͬŝŶƚĞƌƉƌĞƚĂƟŽŶŝƐŶŽƚĂĐĐĞƉƚĂďůĞ͘ ď͘ >tƐŽŶŝĐůŽŐƐŵƵƐƚƐŚŽǁĨƌĞĞƉŝƉĞĂŶĚdŽƉŽĨĞŵĞŶƚ͘ dŚĞůŽŐŵƵƐƚďĞƌƵŶĂĐƌŽƐƐƚŚĞ ƚĂƌŐĞƚnjŽŶĞƐĂŶĚĂƚĂĚĞƉƚŚƚŽĞŶƐƵƌĞƚŚĞĨƌĞĞƉŝƉĞĂďŽǀĞƚŚĞdKŝƐĐĂƉƚƵƌĞĚĂƐǁĞůůĂƐ ƚŚĞdK͘/ĨƚŚĞůŽŐŐĞĚŝŶƚĞƌǀĂůĚŽĞƐŶŽƚĐĂƉƚƵƌĞƚŚĞdKĂŶĚĨƌĞĞƉŝƉĞĂďŽǀĞŝƚ͕ ŝƚǁŝůů ŶĞĞĚƚŽďĞƌĞ-ƌƵŶ͕ƵŶůĞƐƐƚŚĞĐĞŵĞŶƚǁĂƐƉůĂŶŶĞĚƚŽĐŽǀĞƌƚŚĞĞŶƟƌĞůĞŶŐƚŚŽĨůŝŶĞƌŽƌ ĐĂƐŝŶŐ͘ Đ͘ KŝůƐĞĂƌĐŚǁŝůůƉƌŽǀŝĚĞĂĐĞŵĞŶƚũŽďƐƵŵŵĂƌLJƌĞƉŽƌƚĂŶĚĞǀĂůƵĂƟŽŶĂůŽŶŐǁŝƚŚƚŚĞ ĐĞŵĞŶƚůŽŐĂŶĚĞǀĂůƵĂƟŽŶƚŽƚŚĞK'ǁŚĞŶƚŚĞLJďĞĐŽŵĞĂǀĂŝůĂďůĞ͘ d. ĞƉĞŶĚŝŶŐŽŶƚŚĞĐĞŵĞŶƚũŽďƌĞƐƵůƚƐŝŶĚŝĐĂƚĞĚďLJƚŚĞĐĞŵĞŶƚũŽďƌĞƉŽƌƚ͕ƚŚĞůŽŐƐĂŶĚ ƚŚĞ&/d͕ƌĞŵĞĚŝĂůŵĞĂƐƵƌĞƐŽƌĂĚĚŝƟŽŶĂůůŽŐŐŝŶŐŵĂLJďĞƌĞƋƵŝƌĞĚ͘ Page 1 of 1 26 September 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 NDBi-049 Dear Sir/Madam, Oil Search (Alaska), LLC hereby applies for a Permit to Drill an onshore development well from the NDB drilling pad on the North Slope of Alaska. NDBi-049 is planned to be a horizontal injector targeting the Nanushuk 3. The approximate spud date is anticipated to be November 15th, 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 into the top of the Nanushuk formation at an inclination of ~82 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 and landed in the Nanushuk 3 sand and the lateral will be drilled to TD. The well will be completed as a stimulated 4-1/2” liner with frac sleeves and isolation packers. The production liner will be tied back to surface with a 4-1/2” tubing upper completion string. Managed Pressure Drilling (MPD) will be implemented in both the Intermediate and Production hole intervals. This will allow a change in the 9-5/8” casing depth which will be set approximately 10’ TVD below the top of the Nanushuk pool. The production section will be extended to accommodate the shallower casing point with MPD utilized to maintain the appropriate ECD / back-pressure for managing losses and wellbore stability. At no point will the static wellbore fluid be underbalanced. Please find enclosed for your review Form 10-401 Permit to Drill with a supporting Application for Permit to Drill containing information as required by 20 AAC 25.005. If there are any questions and/or additional information desired, please contact me at (907) 615-2234 or Russell.conwell@santos.com. Respectfully, Russell Conwell Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Respectfully, Russell Conwell Application for Permit to Drill NDBi-049 Well Table of Contents 1. Well Name......................................................................................................................................3 2. Location Summary..........................................................................................................................3 3. Blowout Prevention Equipment Information.................................................................................4 4. Drilling Hazards Information...........................................................................................................6 5. Procedure for Conducting Formation Integrity Tests.....................................................................7 6. Casing and Cementing Program.....................................................................................................7 7. Diverter System Information..........................................................................................................8 8. Drilling Fluid Program.....................................................................................................................8 9. Abnormally Pressured Formation Information..............................................................................9 10. Seismic Analysis............................................................................................................................9 11. Seabed Condition Analysis............................................................................................................9 12. Evidence of Bonding.....................................................................................................................9 13. Proposed Drilling Program .........................................................................................................10 14. Discussion of Mud and Cuttings Disposal and Annular Disposal................................................12 15. Proposed Variance Request........................................................................................................12 Attachments..................................................................................................................................................14 Attachment 1: Location Maps..........................................................................................................15 Attachment 2: Directional Plan........................................................................................................16 Attachment 3: BOPE Equipment ......................................................................................................17 Attachment 4: Drilling Hazards.........................................................................................................18 Attachment 5: Leak Off Test Procedure...........................................................................................20 Attachment 6: Cement Summary.....................................................................................................21 Attachment 7: Prognosed Formation Tops......................................................................................23 Attachment 8: Well Schematic.........................................................................................................24 Attachment 9: Formation Evaluation Program................................................................................25 Attachment 10: Wellhead & Tree Diagram......................................................................................26 Attachment 11: Injector Area of Review..........................................................................................27 Attachment 12: Managed Pressure Drilling.....................................................................................28 An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. 1. Well Name 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as NDBi-049. This will be a development injection well. 2. Location Summary 20 AAC 25.005 (c) (2) A plat identifying the property and the property's owners and showing: (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth Location at Surface Reference to Government Section Lines 2445’ FSL, 2860’ FEL, Sec 4, T11N, R6E, UM NAD 27 Coordinate System N 5,972,663 E 424,786 Rig KB Elevation 47’ above GL Ground Level 22.82’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 173’ FSL, 3501’ FEL, Sec 6, T11N, R6E, UM NAD 27 Coordinate System N 5,970,679’ E 411,167’ Measured Depth, Rig KB (MD) 13,710’ Total Vertical Depth, Rig KB (TVD) 4,174’ Total vertical Depth, Subsea (TVDSS) 4,104’ Location at Bottom of Productive Interval Reference to Government Section Lines 4540’ FSL, 1200’ FEL, Sec 1, T11N, R5E, UM NAD 27 Coordinate System N 5,975,076’ E 408,617’ Measured Depth, Rig KB (MD) 18,792’ Total Vertical Depth, Rig KB (TVD) 4,133’ Total vertical Depth, Subsea (TVDSS) 4,064’ See attached emails. -A.Dewhurst 24OCT24 2,275’ FSL, 1,823’ FWL E 421,786' Location at TD Reference to Government Section Lines 5046’ FSL, 1634’ FEL, Sec 1, T11N, R5E, UM NAD 27 Coordinate System N 5,975,587’ E 408,189’ Measured Depth, Rig KB (MD) 19,467’ Total Vertical Depth, Rig KB (TVD) 4,040’ Total vertical Depth, Subsea (TVDSS) 3,970’ (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 NDBi-049 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. 4. Drilling Hazards Information 20 AAC 25.005 (c) (4) Information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure; 12-1/4” Intermediate Hole Pressure Data Maximum anticipated BHP 1,769 psi in the top Nanushuk at 3,823’ TVD (8.9ppg EMW Nanushuk formation to section TD) Maximum surface pressure 1,398 psi from the Nanushuk (0.10 psi/ft gas gradient to surface, 3,853’ TVD) Planned BOP test pressure Rams test to 3,600 psi / 250 psi Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test – 12-1/4” hole LOT after drilling 20’-50’ of new hole. (13.0 ppg LOT required for Kick Tolerance) 13-3/8” Casing Test 2,600 psi surface pressure (Test pressure driven by 50% of Casing Burst) 8-1/2” Production Hole Pressure Data Maximum anticipated BHP 1,909 psi in the Nanushuk 3.2 at 4,173’ TVD (8.8ppg EMW top NT3.2 formation to heel target) Maximum surface pressure 1,493 psi from the NT3.2 (0.10 psi/ft gas gradient to surface, 4,173’ TVD) Planned BOP test pressure Rams test to 3,600 psi / 250 psi Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test – 8-1/2” hole FIT after drilling 20’-50’ of new hole to 14.0 ppg. (10.5 ppg EMW adequate for infinite kick tolerance) 9-5/8” Liner Test 4,000 psi surface pressure (Test pressure driven by annular pressure during frac job) (B) data on potential gas zones; and The Tuluvak formation is expected in this area and has a high potential for gas as based on offset Exploration and Appraisal well data. The Tuluvak is expected to be over-pressured at 10.2ppg pore pressure. The well plan is designed to safely manage pressures consistent with offset wells in the same manner that hydrocarbons are handled in the reservoir zone. BOPE will be installed before entering any hydrocarbon zones and appropriate mud weights will be utilized to provide sufficient overbalance. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please refer to Attachment 4: Drilling Hazards 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (c) (5) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment 5: Leak Off Test Procedure 6. Casing and Cementing Program 20 AAC 25.005 (c) (6) A complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perforated liner, or screen to be installed; Casing/Tubing Program Hole Size Liner / Tbg O.D.Wt/Ft Grade Conn Length Top MD Bottom MD / TVD 42” 20”x34” 215# X-52 Welded 80’ Surface 128’ / 54’ 16” 13-3/8” 68# L-80 BTC or TXP BTC 2,625’ Surface 2,625’ / 2,290’ 12-1/4” 9-5/8” 47# L-80 HYD 563 9,135’ 2,475’ 11,610’ /3,823’ Tie Back 9-5/8” 47# L-80 HYD 563 2,475’ Surface 2,475’ / 2,208’ 8-1/2” 4-1/2” 12.6# P-110S HYD 563 8,007 11,460’ 19,467’ / 4,040’ Tubing 4-1/2” 12.6# P-110S HYD 563 11,460’ Surface 11,460’ / 3,789’ Please refer to Attachment 6: Cement Summary for further details. 7. Diverter System Information 20 AAC 25.005 (c) (7) A diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Parker 272 Diverter Equipment: x Hydril MSP annular BOP, 21 1/4” x 2000 psi, flanged x Diverter Spool 21 1/4” x 2000 psi with 16-3/4” flanged sidearm connection. Interlocked knife/gate valves. x 16” Diverter Line Please refer to Attachment 3: BOPE Equipment for further details. 8. Drilling Fluid Program 20 AAC 25.005 (c) (8) A drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary 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 ppg 100-300 seconds ALAP 30-80 < 10 ml/30min n/a 8.6-10.5 <35 11.0-12.0 ppg 50-80 seconds ALAP 15-30 n/a < 5 ml/30min n/a n/a 9.0-10.0 ppg 50-80 seconds ALAP 10-20 n/a < 5 ml/30min n/a n/a A diagram of drilling fluid system on Parker 272 is on file with AOGCC. 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 NDBi-049 Well is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) (12) Evidence showing that the requirements of 20 AAC 25.025 have been met; Evidence of bonding for Oil Search Alaska is on file with the Commission. 13. Proposed Drilling Program 20 AAC 25.005 (c) (13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to NDBi-049 is listed below. Please refer to Attachments 8-10 for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed Drilling Program NDBi-049 1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing ring on conductor. 2. Move in / rig up Parker 272. 3. Nipple up spacer spools and diverter over the 20” conductor. Verify that the diverter line is at least 75’ away from a potential source of ignition and beyond the drill rig substructure. 4. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC 24hrs notice for witnessing diverter test. 5. Pick up 5-7/8” drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up 16” motor BHA with MWD and LWD tools. 6. Spud well and drill surface hole section to TD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH and lay down BHA. 7. Run 13-3/8” 68# surface casing as per casing tally and land on pre-installed landing ring. Circulate and condition mud prior to commencing cement job. 8. Cement 13-3/8” casing as per cement program. Verify cement returns to surface. 9. ND diverter and NU casing head and spacer spool. NU BOPE (configured from top to bottom: annular preventor, 4-1/2” x 7” VBR, blind/shear, mud cross, 9-5/8” Fixed Rams). NU Rotating Control Device (RCD) and other MPD surface equipment as required. Test rams to 3600 psi high and annular to 3000 psi high as per AOGCC regulations. Provide AOGCC 24hrs notice for witnessing BOP test. 10. Close blind shear rams and pressure test casing to 2600 psi for 30 min. 11. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to MOBM. 12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test. 13. Install MPD bearing assembly. 14. Directionally drill 12-1/4” intermediate hole section to TD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH. 15. Run 9-5/8” production liner as per casing tally then RIH on 5-7/8” DP. Circulate and condition mud prior to commencing cement job. 16. Set liner hanger and release running tool. Cement 9-5/8” liner with 1st stage cement job as per cement program. Monitor returns during displacement until plug bump. 17. Un-sting from liner hanger and POOH and LD liner running tools. 18. RIH with mechanical shifting tool and open 2 nd stage cement job tools. Sting into second stage tool pump secondary stage, SO and set liner top packer, circulate cement to surface. POOH and lay down running tool. 19. Run 9-5/8” tie-back string. Freeze protect the 13-3/8” x 9-5/8” annulus with diesel and land tie-back. 20. Pressure test 13-3/8” x 9-5/8” to 2600 psi for 30 min. 21. Pressure test the 9-5/8” liner and tieback to 3500 psi for 30 min. 22. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to production hole MOBM. 23. Install MPD bearing assembly. 24. Drill out shoe track and 20 - 50’ of new formation. Perform formation integrity test. 25. Directionally drill 8-1/2” hole section as per well plan to TD. Perform wiper trips as required. 26. Displace weighted trip fluid as required. 27. POOH. Log first stage cement with Sonic LWD. NOTE: See more details / justification in Attachment 6: Cement Summary 28. Run cleanout/string mill assembly to dress the 9-5/8” CFLEX tool. 29. RU and run 4-1/2” production liner with liner hanger / liner top packer and downhole jewelry to TD. 30. Set and pressure test the 9-5/8” x 4-1/2” IA to liner top packer to 3,500 psi for 10 min. Release the running tool. 31. Circulate corrosion inhibited brine. 32. POOH and LD liner running tool. 33. RU and run 4-1/2” upper completion and downhole jewelry with TEC wire. Space out seals. 34. Land tubing hanger. 35. Pressure test tubing to 3,500 psi for 30 mins. Pressure up on the annulus to 4,000 psi for 30 mins. Bleed pressure on tubing and shear upper gas lift valve. 36. Reverse circulate freeze protect and U-Tube. 37. Install TWC, pressure test to 2,500 psi for 10 mins. ND BOPE, NU frac tree. 38. Secure well and prepare for rig move. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) (14) A general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. Water-based and oil-based drilling muds and cuttings will typically be hauled directly offsite via truck as it is generated. Contractual arrangements have been made with other operators on the North Slope to utilize their waste injection/disposal facilities (Class 1 and Class 2) at Prudhoe Bay, Kuparuk and Milne Point. If waste cannot be hauled directly offsite, it may be stored temporarily in drilling waste cuttings bins or a bermed cuttings storage cell in accordance with a drilling waste temporary storage plan approved by Alaska Department of Conservation (ADEC) Solid Waste Program until it can be transported for proper disposal. In the event the Oil Search Alaska NGI (Nanushuk Grind & Inject) facility is operational, cuttings will be hauled via truck as generated, process at NGI, and disposed of into the DW-02 Class 1 disposal well. The NGI facility is located on NDB. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. 15. Proposed Variance Request 20 AAC 25.030. Casing and cementing (d)(5) intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above all significant hydrocarbon zones and abnormally geo- pressured strata A variance is requested to the above regulation 20 AAC 25.030 (d)(5) to not place cement across the entire annular space from the casing shoe to above shallowest significant hydrocarbon zone. A two-stage cement job will be performed to isolate the significant hydrocarbon zone in the Nanushuk formation (primary job), and the second stage cement job will isolate the significant hydrocarbon zone in the Tuluvak formation. The primary cement job will target a top of cement 500’ MD or 250’ TVD, whichever is greater, above the top of the Nanushuk. Due to the ERD nature and high angle of the Pikka NDB development wells, a single stage cement job on the intermediate liner is not achievable without exceeding the fracture gradient and compromising cement placement and zonal isolation. The two-stage cement job will achieve all casing and cementing objectives outlined in AOGCC regulation 20 AAC 25.030.(a), stating that a well casing and cementing program must be designed to: 1) provide suitable and safe operating conditions for the total measured depth proposed; 2) confine fluids to the wellbore; 3) prevent migration of fluids from one stratum to another; 4) ensure control of well pressures encountered; 5) protect against thaw subsidence and freezeback effects within permafrost; 6) prevent contamination of freshwater; 7) protect significant hydrocarbon zones; and 8) provide well control until the next casing is set, considering all factors relevant to well control including formation fracture gradients, formation pressures, casing setting depths, and proposed total depth. The formation interval between the top of stage one and the bottom of stage two includes the Seabee and lower Tuluvak formation. These formations are interbedded silts and shales with very low permeability and contain no significant hydrocarbons. Based on offset well logs, cuttings, mudlogging analysis, and the latest petrophysical interpretation, the base of the significant hydrocarbon zone in the Tuluvak formation is contained only within the upper portion of TS 880 clinoform of the Upper Tuluvak in the NDB area. Within the TS 880 clinoform, the base of significant hydrocarbon is at or above 2,640’ TVD. The Tuluvak formation below 2,640’ TVD is not a significant hydrocarbon zone. A stage collar placement is proposed 50’ MD below the TS 790 formation marker (Upper Tuluvak). This stage collar depth will isolate any potential gas based on offset well data. The TS 875 and TS 870 clinoform is between the TS 880 clinoform and TS 790 top. The TS 875 and TS 870 clinoforms are shale dominated, very low net to gross, has no vertical permeability, and represents a seal to the hydrocarbon bearing TS 880. Moving the cementing stage tool to be placed at 50’ MD below the TS 790 formation marker allows placement of higher quality cement that provides better isolation across the significant hydrocarbon zone in the Tuluvak. Attempting to place cement across the entire Tuluvak will add risk to the primary objective of cement isolation across the significant hydrocarbon zone which is only located in the upper portion of the Tuluvak (TS 880). The increased risk is due to: 1) Cementing the entire Tuluvak would require large cement jobs that jeopardize cement isolation across the upper Tuluvak. 2) Large cement jobs likely require the use of lighter weight cement across the significant hydrocarbon zone. Recommend granting requested variance to permit two-stage cementing operation. Recommend granting variance from pool rules to isolate significant hydrocarbons as proposed above (base of significant HC zone defined from TS790 maker). -A.Dewhurst 23OCT24 Attachments Attachment 1: Location Maps DW-02 NDB-032 NDB-051 NDBi-014 NDBi-018 NDBi-030 NDBi-043 NDBi-044 ADL 392977 ADL 392991 ADL 392985 ADL 392984ADL 392958 ADL 392970 ADL 393022 ADL 393021 ADL 393023 ADL 393019 ADL 393018 ADL 393020 ADL 393015 ADL 393016 ADL 391445 ADL 391455 U012N006E29 U011N006E04 U012N006E32 U011N006E05 U012N006E33 U012N005E25 U012N006E28 U012N005E36 U011N005E01 U011N005E12 U011N006E09 U011N006E08 U012N006E31 U011N006E06 U012N006E30 U011N006E07 FIORD 3A FIORD 3 QUGRUK 3 QUGRUK 301 QUGRUK 3A OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD NDBI-049 PLANNED TRAJECTORY OTHER DRILLED NDB WELLS NDBI-049 SURFACE LOCATION NDBI-049 BOTTOM HOLE 0.25-MILE BUFFER 0.5-MILE BUFFER PRODUCTION INTERVAL NDB DRILLED WELLS BOTTOM HOLES WELL TRAJECTORIES BY OTHERS BOTTOM HOLES OTHER EXPLORATION WELLS SECTIONS SANTOS LEASES DATE: 8/7/2024. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDBi49_buffers GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDBi49 WELL OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD OTHER NDB WELLS WELL HEAD DIVERTER (50-ft) RIG OUTLINES DATE: 8/7/2024. By: JB 0204010 Feet Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDBi49_well_diverter GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 010205 Meters PIKKA DEVELOPMENT NDBi-049 WELL DIVERTER Latitude (decimal degree) Long (decimal degree)Latitude Longitude Y (ft) x (ft) 70.335112 Ͳ150.637676 N 70° 20' 06.4015" W 150° 38' 15.6345" 5,972,411.35 1,561,819.52 Latitude (decimal degree) Long (decimal degree)Latitude Longitude y (ft) x (ft) 70.33543 Ͳ150.634543 N 70° 20' 07.5529" W 150° 38' 04.3578" 5,972,663.37 421,786.71 State Plane NAD83 Zone 4 (as-built) StatePlane NAD27 Zone 4 (as-built) Attachment 2: Directional Plan SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 47.0 0.00 0.00 47.0 0.0 0.0 0.00 0.00 0.0 Start 350.0 hold at 47.0 MD 2 397.0 0.00 247.45 397.0 0.0 0.0 0.00 247.45 0.0 Start Build 2.50 3 997.0 15.00 247.45 990.2 -29.9 -72.1 2.50 247.45 64.7 Start 157.0 hold at 997.0 MD 4 1154.0 15.00 247.45 1141.8 -45.5 -109.6 0.00 0.00 98.3 Start Build 3.00 5 3287.3 79.00 247.45 2522.3 -613.2 -1476.8 3.00 0.00 1324.3 Start DLS 3.00 TFO 0.14 6 3367.1 81.39 247.46 2535.9 -643.4 -1549.4 3.00 0.14 1389.4 Start 7093.5 hold at 3367.1 MD 7 10460.6 81.39 247.46 3597.6 -3332.3 -8027.0 0.00 0.00 7198.4 Start DLS 3.00 TFO 101.14 8 12345.9 76.00 305.00 4000.0 -3150.0 -9782.0 3.00 101.14 8954.4 NDBi-049 Flex Point Rev 2.0 Start DLS 3.28 TFO 74.32 9 13083.8 83.50 328.40 4133.0 -2624.6 -10274.6 3.28 74.32 9542.1 Start 100.0 hold at 13083.8 MD 10 13183.8 83.50 328.40 4144.3 -2540.0 -10326.7 0.00 0.00 9610.1 Start DLS 1.25 TFO 2.62 11 13707.0 90.03 328.70 4173.8 -2094.6 -10599.1 1.25 2.62 9966.1 NDBi-049 Heel Rev 3.0 Start DLS 3.00 TFO 54.46 12 13731.1 90.45 329.29 4173.7 -2074.0 -10611.5 3.00 54.46 9982.3 Start 5058.9 hold at 13731.1 MD 13 18790.0 90.45 329.29 4133.8 2275.1 -13195.3 0.00 0.00 13383.7 NDBi-049 Build up Rev 4.0 Start DLS 3.99 TFO -52.14 14 19268.5 102.02 313.98 4081.6 2646.8 -13488.6 3.99 -52.14 13745.5 Start DLS 0.01 TFO 125.40 15 19467.4 102.00 314.00 4040.2 2781.9 -13628.7 0.01 125.40 13909.7 NDBi-049 TD Rev 1.0 TD at 19467.4 47 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 5000 5000 8000 8000 12000 12000 16000 16000 20700 Plan: NDBi-049 Rev J.0 Plan Summary 0 3 Dogleg Severity0 3000 6000 9000 12000 15000 18000 Measured Depth 20" Conductor Casing 13-3/8" Surface Casing 9-5/8" Intermediate Liner 4-1/2" Production Liner 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in] 475075100125150175200225 250275300325350375400424448472496520543567591NDBi-044 7075100125150175200225250275300325350375400424448472496520544568592616640664688712736760784807831 Plan: NDB-045 Rev A.0 475075100125150 175200225 25027530032535037540042444947349852254657159561964466869271674176578981383786188590893295697910031028NDBi-046 475075100125150 175200225 25027530032535037540042444947349852254657159561964466869271674176578981383786188590893295697910031028NDBi-046 L1 475075100125150175200225250275300325350375400424449473498523547572596620645669693717741765789813837860884907931NDB-047 Rev12 4750751001251501752002252502753003253503754004254504744995245495735986236476726977217467717958208448698939189429679911016104010651090111511391164118812121236126012841308133213551379NDB-048 Rev E.1 475075100125150175200225250275300325350375400425450476 5015265515776026276526787037287537798048298548799059309559801005103010551080110511301155118112061231125612811307133213571382140714321458148315081533155815831608163416591684170917341759178418091834185918841909193419601985201020352060208521102135216021852209223422592284230923342359238424092434245924842509253325582583260826332658Plan: NDBi-050 Rev D.2 475075100125150175200225250275300325350375400426451477502528553579604 630656681707 732758784809835861887912938964990101510401065109011151140116511911217124412701296132213481374140014261452147815041530155615821608NDB-051 0 2250 True Vertical Depth0 2000 4000 6000 8000 10000 12000 14000 Vertical Section at 281.54° 20" Conductor Casing 13-3/8" Surface Casing 9-5/8" Intermediate Liner 4-1/2" Production Liner 0 28 55 Centre to Centre Separation0 275 550 825 1100 1375 1650 1925 Measured Depth Equivalent Magnetic Distance DDI 7.322 SURVEY PROGRAM Date: 2021-02-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 47.0 600.0 Plan: NDBi-049 Rev J.0 (NDBi-049) SDI_URSA1_I4 600.0 1800.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 600.0 2625.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 2625.0 3825.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 2625.0 4280.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 4280.0 5000.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD_Interp Azi+Sag 5000.0 6200.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 5000.0 11610.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 11610.0 12810.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 11610.0 19467.4 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag Surface Location North / 5972411.35 East / 1561819.52 Elevation / 22.8 CASING DETAILS TVD MD Name 127.0 127.0 20" Conductor Casing 2286.8 2625.0 13-3/8" Surface Casing 3823.6 11610.0 9-5/8" Intermediate Liner 4040.2 19467.4 4-1/2" Production Liner Mag Model & Date: BGGM2023 31-Dec-24 Magnetic North is 13.95° East of True North (Magnetic Declin Mag Dip & Field Strength: 80.54° 57140.12889196nT FORMATION TOP DETAILS TVDPath Formation 1040.8 Upper SB 1392.8Base Permafrost Transition 1731.8 MSB 2144.8 MCU 2446.8 Tuluvak 2508.8 Tuluvak S 2.8 TS_790 3065.8 Seabee 3811.8 Nanushuk 3865.8 NT8 MFS 3909.8 NT7 MFS 3948.8 NT6 MFS 3994.8 NT5 MFS 4038.8 NT4 MFS 4072.6 NT3.2 PB 4125.8 NT3 MFS 4149.8 NT3.2 By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by BHI DE Accepted by BHI PSD Approved by Santos DE P272 As Plan @ 69.8usft Standard Planning Report - Geographic 25 September, 2024 Plan: Plan: NDBi-049 Rev J.0 Santos Pikka NDB B-49 - Slot B-49 NDBi-049 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1983 North American Datum 1983 Pikka, North Slope Alaska, United States Alaska Zone 4 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: NDB Map Slot Radius:0.9 usft usft usft " 5,972,657.73 1,563,416.33 36 70° 20' 8.988 N 150° 37' 29.073 W Well Well Position Longitude: Latitude: Easting: Northing: +E/-W +N/-S Position Uncertainty Ground Level: B-49 - Slot B-49 Wellhead Elevation:0.5 0.0 0.0 5,972,411.35 1,561,819.52 70° 20' 6.402 N 150° 38' 15.635 W 22.8 usft usft usft usft usft usft usft °-0.60Grid Convergence: Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) NDBi-049 Model NameMagnetics BGGM2023 31/12/2024 13.95 80.54 57,140.12889196 Phase:Version: Audit Notes: Design Plan: NDBi-049 Rev J.0 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:47.0 281.540.00.047.0 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 2 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Plan Survey Tool Program RemarksTool NameSurvey (Wellbore) Date 25/09/2024 Depth To (usft) Depth From (usft) SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISC Plan: NDBi-049 Rev J.0 (NDBi-04147.0 600.0 3_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-049 Rev J.0 (NDBi-042600.0 1,800.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-049 Rev J.0 (NDBi-043600.0 2,625.0 3_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-049 Rev J.0 (NDBi-0442,625.0 3,825.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-049 Rev J.0 (NDBi-0452,625.0 4,280.0 3_MWD_Interp Azi+Sag H003Mb: Interpolated azimu Plan: NDBi-049 Rev J.0 (NDBi-0464,280.0 5,000.0 3_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-049 Rev J.0 (NDBi-0475,000.0 6,200.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-049 Rev J.0 (NDBi-0485,000.0 11,610.0 3_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-049 Rev J.0 (NDBi-04 0911,610.0 12,810.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-049 Rev J.0 (NDBi-04 01011,610.0 19,467.4 Inclination (°) Azimuth (°) +E/-W (usft) TFO (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections Target 0.000.000.000.000.00.047.00.000.0047.0 247.450.000.000.000.00.0397.0247.450.00397.0 247.450.002.502.50-72.1-29.9990.2247.4515.00997.0 0.000.000.000.00-109.6-45.51,141.8247.4515.001,154.0 0.000.003.003.00-1,476.8-613.22,522.3247.4579.003,287.3 0.140.013.003.00-1,549.4-643.42,535.9247.4681.393,367.1 0.000.000.000.00-8,027.0-3,332.33,597.6247.4681.3910,460.6 101.143.05-0.293.00-9,782.0-3,150.04,000.0305.0076.0012,345.9 NDBi-049 Flex Poin 74.323.171.023.28-10,274.6-2,624.64,133.0328.4083.5013,083.8 0.000.000.000.00-10,326.7-2,540.04,144.3328.4083.5013,183.8 2.620.061.251.25-10,599.1-2,094.64,173.8328.7090.0313,707.0 NDBi-049 Heel Rev 54.462.441.743.00-10,611.5-2,074.04,173.7329.2990.4513,731.1 0.000.000.000.00-13,195.32,275.14,133.8329.2990.4518,790.0 NDBi-049 Build up R -52.14-3.202.423.99-13,488.62,646.84,081.6313.98102.0219,268.5 125.400.01-0.010.01-13,628.72,781.94,040.2314.00102.0019,467.4 NDBi-049 TD Rev 1 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 3 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 47.0 0.00 47.0 0.0 0.00.00 1,561,819.525,972,411.35 70° 20' 6.402 N 150° 38' 15.635 W Start 350.0 hold at 47.0 MD 100.0 0.00 100.0 0.0 0.00.00 1,561,819.525,972,411.35 70° 20' 6.402 N 150° 38' 15.635 W 127.0 0.00 127.0 0.0 0.00.00 1,561,819.525,972,411.35 70° 20' 6.402 N 150° 38' 15.635 W 20" Conductor Casing 200.0 0.00 200.0 0.0 0.00.00 1,561,819.525,972,411.35 70° 20' 6.402 N 150° 38' 15.635 W 300.0 0.00 300.0 0.0 0.00.00 1,561,819.525,972,411.35 70° 20' 6.402 N 150° 38' 15.635 W 397.0 0.00 397.0 0.0 0.00.00 1,561,819.525,972,411.35 70° 20' 6.402 N 150° 38' 15.635 W Start Build 2.50 400.0 0.08 400.0 0.0 0.0247.45 1,561,819.525,972,411.35 70° 20' 6.401 N 150° 38' 15.635 W 500.0 2.58 500.0 -0.9 -2.1247.45 1,561,817.385,972,410.49 70° 20' 6.393 N 150° 38' 15.697 W 600.0 5.08 599.7 -3.4 -8.3247.45 1,561,811.195,972,408.00 70° 20' 6.368 N 150° 38' 15.877 W 700.0 7.58 699.1 -7.7 -18.5247.45 1,561,800.985,972,403.88 70° 20' 6.326 N 150° 38' 16.174 W 800.0 10.08 797.9 -13.6 -32.6247.45 1,561,786.755,972,398.14 70° 20' 6.268 N 150° 38' 16.588 W 900.0 12.58 896.0 -21.1 -50.8247.45 1,561,768.545,972,390.81 70° 20' 6.194 N 150° 38' 17.117 W 997.0 15.00 990.2 -29.9 -72.1247.45 1,561,747.105,972,382.17 70° 20' 6.107 N 150° 38' 17.741 W Start 157.0 hold at 997.0 MD 1,000.0 15.00 993.1 -30.2 -72.8247.45 1,561,746.385,972,381.88 70° 20' 6.104 N 150° 38' 17.762 W 1,049.4 15.00 1,040.8 -35.2 -84.7247.45 1,561,734.525,972,377.10 70° 20' 6.056 N 150° 38' 18.107 W Upper Schrader Bluff 1,100.0 15.00 1,089.7 -40.2 -96.7247.45 1,561,722.385,972,372.20 70° 20' 6.006 N 150° 38' 18.460 W 1,154.0 15.00 1,141.8 -45.5 -109.6247.45 1,561,709.415,972,366.98 70° 20' 5.954 N 150° 38' 18.837 W Start Build 3.00 1,200.0 16.38 1,186.1 -50.3 -121.1247.45 1,561,697.885,972,362.33 70° 20' 5.907 N 150° 38' 19.172 W 1,300.0 19.38 1,281.3 -62.1 -149.5247.45 1,561,669.415,972,350.86 70° 20' 5.791 N 150° 38' 20.000 W 1,400.0 22.38 1,374.7 -75.7 -182.4247.45 1,561,636.365,972,337.54 70° 20' 5.657 N 150° 38' 20.961 W 1,419.6 22.97 1,392.8 -78.6 -189.4247.45 1,561,629.345,972,334.71 70° 20' 5.628 N 150° 38' 21.166 W Base Permafrost Transition 1,500.0 25.38 1,466.1 -91.3 -219.8247.45 1,561,598.825,972,322.41 70° 20' 5.504 N 150° 38' 22.053 W 1,600.0 28.38 1,555.3 -108.6 -261.5247.45 1,561,556.895,972,305.51 70° 20' 5.333 N 150° 38' 23.272 W 1,700.0 31.38 1,642.0 -127.7 -307.5247.45 1,561,510.695,972,286.89 70° 20' 5.145 N 150° 38' 24.616 W 1,800.0 34.38 1,726.0 -148.5 -357.7247.45 1,561,460.355,972,266.61 70° 20' 4.941 N 150° 38' 26.080 W 1,807.1 34.59 1,731.8 -150.1 -361.4247.45 1,561,456.635,972,265.11 70° 20' 4.926 N 150° 38' 26.188 W Middle Schrader Bluff 1,900.0 37.38 1,807.0 -171.0 -411.8247.45 1,561,406.005,972,244.70 70° 20' 4.720 N 150° 38' 27.660 W 2,000.0 40.38 1,884.8 -195.1 -469.8247.45 1,561,347.795,972,221.24 70° 20' 4.483 N 150° 38' 29.353 W 2,100.0 43.38 1,959.3 -220.7 -531.4247.45 1,561,285.895,972,196.30 70° 20' 4.231 N 150° 38' 31.153 W 2,200.0 46.38 2,030.1 -247.7 -596.6247.45 1,561,220.455,972,169.93 70° 20' 3.965 N 150° 38' 33.056 W 2,300.0 49.38 2,097.2 -276.2 -665.1247.45 1,561,151.675,972,142.21 70° 20' 3.685 N 150° 38' 35.056 W 2,374.9 51.63 2,144.8 -298.3 -718.4247.45 1,561,098.095,972,120.61 70° 20' 3.467 N 150° 38' 36.615 W MCU 2,400.0 52.38 2,160.3 -305.9 -736.7247.45 1,561,079.735,972,113.21 70° 20' 3.392 N 150° 38' 37.149 W 2,500.0 55.38 2,219.2 -336.9 -811.3247.45 1,561,004.825,972,083.03 70° 20' 3.088 N 150° 38' 39.327 W 2,600.0 58.38 2,273.8 -369.0 -888.6247.45 1,560,927.155,972,051.73 70° 20' 2.772 N 150° 38' 41.585 W 2,625.0 59.13 2,286.8 -377.2 -908.4247.45 1,560,907.335,972,043.74 70° 20' 2.691 N 150° 38' 42.162 W 13-3/8" Surface Casing 2,700.0 61.38 2,324.0 -402.2 -968.5247.45 1,560,846.945,972,019.40 70° 20' 2.446 N 150° 38' 43.918 W 2,800.0 64.38 2,369.6 -436.3 -1,050.7247.45 1,560,764.405,971,986.14 70° 20' 2.110 N 150° 38' 46.318 W 2,900.0 67.38 2,410.5 -471.3 -1,135.0247.45 1,560,679.775,971,952.03 70° 20' 1.765 N 150° 38' 48.779 W 3,000.0 70.38 2,446.5 -507.1 -1,221.1247.45 1,560,593.275,971,917.17 70° 20' 1.414 N 150° 38' 51.294 W 3,000.9 70.41 2,446.8 -507.4 -1,221.9247.45 1,560,592.455,971,916.84 70° 20' 1.410 N 150° 38' 51.318 W Tuluvak Shale 3,100.0 73.38 2,477.6 -543.5 -1,308.9247.45 1,560,505.135,971,881.65 70° 20' 1.055 N 150° 38' 53.857 W 3,200.0 76.38 2,503.7 -580.5 -1,398.0247.45 1,560,415.615,971,845.57 70° 20' 0.691 N 150° 38' 56.460 W 3,222.4 77.05 2,508.8 -588.9 -1,418.1247.45 1,560,395.445,971,837.44 70° 20' 0.609 N 150° 38' 57.047 W Tuluvak Sand 3,287.3 79.00 2,522.3 -613.2 -1,476.8247.45 1,560,336.485,971,813.69 70° 20' 0.369 N 150° 38' 58.761 W Start DLS 3.00 TFO 0.14 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 4 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 3,300.0 79.38 2,524.7 -618.0 -1,488.3247.45 1,560,324.955,971,809.04 70° 20' 0.322 N 150° 38' 59.096 W 3,367.1 81.39 2,535.9 -643.4 -1,549.4247.46 1,560,263.645,971,784.33 70° 20' 0.072 N 150° 39' 0.879 W Start 7093.5 hold at 3367.1 MD 3,400.0 81.39 2,540.8 -655.8 -1,579.5247.46 1,560,233.425,971,772.16 70° 19' 59.949 N 150° 39' 1.758 W 3,500.0 81.39 2,555.8 -693.8 -1,670.8247.46 1,560,141.725,971,735.21 70° 19' 59.576 N 150° 39' 4.424 W 3,600.0 81.39 2,570.7 -731.7 -1,762.1247.46 1,560,050.025,971,698.27 70° 19' 59.203 N 150° 39' 7.090 W 3,700.0 81.39 2,585.7 -769.6 -1,853.4247.46 1,559,958.325,971,661.32 70° 19' 58.830 N 150° 39' 9.757 W 3,800.0 81.39 2,600.7 -807.5 -1,944.7247.46 1,559,866.615,971,624.38 70° 19' 58.457 N 150° 39' 12.423 W 3,900.0 81.39 2,615.6 -845.4 -2,036.1247.46 1,559,774.915,971,587.43 70° 19' 58.084 N 150° 39' 15.089 W 4,000.0 81.39 2,630.6 -883.3 -2,127.4247.46 1,559,683.215,971,550.49 70° 19' 57.711 N 150° 39' 17.755 W 4,100.0 81.39 2,645.6 -921.2 -2,218.7247.46 1,559,591.515,971,513.54 70° 19' 57.338 N 150° 39' 20.422 W 4,200.0 81.39 2,660.5 -959.1 -2,310.0247.46 1,559,499.815,971,476.60 70° 19' 56.965 N 150° 39' 23.088 W 4,300.0 81.39 2,675.5 -997.0 -2,401.3247.46 1,559,408.115,971,439.65 70° 19' 56.592 N 150° 39' 25.754 W 4,400.0 81.39 2,690.5 -1,034.9 -2,492.6247.46 1,559,316.405,971,402.71 70° 19' 56.219 N 150° 39' 28.420 W 4,500.0 81.39 2,705.4 -1,072.8 -2,584.0247.46 1,559,224.705,971,365.76 70° 19' 55.846 N 150° 39' 31.086 W 4,600.0 81.39 2,720.4 -1,110.7 -2,675.3247.46 1,559,133.005,971,328.82 70° 19' 55.472 N 150° 39' 33.752 W 4,700.0 81.39 2,735.4 -1,148.6 -2,766.6247.46 1,559,041.305,971,291.87 70° 19' 55.099 N 150° 39' 36.419 W 4,800.0 81.39 2,750.3 -1,186.6 -2,857.9247.46 1,558,949.605,971,254.93 70° 19' 54.726 N 150° 39' 39.085 W 4,900.0 81.39 2,765.3 -1,224.5 -2,949.2247.46 1,558,857.905,971,217.98 70° 19' 54.353 N 150° 39' 41.751 W 5,000.0 81.39 2,780.3 -1,262.4 -3,040.6247.46 1,558,766.195,971,181.04 70° 19' 53.980 N 150° 39' 44.417 W 5,100.0 81.39 2,795.2 -1,300.3 -3,131.9247.46 1,558,674.495,971,144.09 70° 19' 53.607 N 150° 39' 47.082 W 5,200.0 81.39 2,810.2 -1,338.2 -3,223.2247.46 1,558,582.795,971,107.15 70° 19' 53.233 N 150° 39' 49.748 W 5,257.4 81.39 2,818.8 -1,359.9 -3,275.6247.46 1,558,530.195,971,085.95 70° 19' 53.019 N 150° 39' 51.278 W TS_790 5,300.0 81.39 2,825.2 -1,376.1 -3,314.5247.46 1,558,491.095,971,070.20 70° 19' 52.860 N 150° 39' 52.414 W 5,400.0 81.39 2,840.2 -1,414.0 -3,405.8247.46 1,558,399.395,971,033.26 70° 19' 52.487 N 150° 39' 55.080 W 5,500.0 81.39 2,855.1 -1,451.9 -3,497.1247.46 1,558,307.695,970,996.31 70° 19' 52.114 N 150° 39' 57.746 W 5,600.0 81.39 2,870.1 -1,489.8 -3,588.5247.46 1,558,215.985,970,959.37 70° 19' 51.740 N 150° 40' 0.412 W 5,700.0 81.39 2,885.1 -1,527.7 -3,679.8247.46 1,558,124.285,970,922.42 70° 19' 51.367 N 150° 40' 3.078 W 5,800.0 81.39 2,900.0 -1,565.6 -3,771.1247.46 1,558,032.585,970,885.47 70° 19' 50.994 N 150° 40' 5.743 W 5,900.0 81.39 2,915.0 -1,603.5 -3,862.4247.46 1,557,940.885,970,848.53 70° 19' 50.621 N 150° 40' 8.409 W 6,000.0 81.39 2,930.0 -1,641.4 -3,953.7247.46 1,557,849.185,970,811.58 70° 19' 50.247 N 150° 40' 11.075 W 6,100.0 81.39 2,944.9 -1,679.4 -4,045.0247.46 1,557,757.485,970,774.64 70° 19' 49.874 N 150° 40' 13.741 W 6,200.0 81.39 2,959.9 -1,717.3 -4,136.4247.46 1,557,665.775,970,737.69 70° 19' 49.501 N 150° 40' 16.406 W 6,300.0 81.39 2,974.9 -1,755.2 -4,227.7247.46 1,557,574.075,970,700.75 70° 19' 49.127 N 150° 40' 19.072 W 6,400.0 81.39 2,989.8 -1,793.1 -4,319.0247.46 1,557,482.375,970,663.80 70° 19' 48.754 N 150° 40' 21.737 W 6,500.0 81.39 3,004.8 -1,831.0 -4,410.3247.46 1,557,390.675,970,626.86 70° 19' 48.381 N 150° 40' 24.403 W 6,600.0 81.39 3,019.8 -1,868.9 -4,501.6247.46 1,557,298.975,970,589.91 70° 19' 48.007 N 150° 40' 27.069 W 6,700.0 81.39 3,034.7 -1,906.8 -4,593.0247.46 1,557,207.275,970,552.97 70° 19' 47.634 N 150° 40' 29.734 W 6,800.0 81.39 3,049.7 -1,944.7 -4,684.3247.46 1,557,115.565,970,516.02 70° 19' 47.260 N 150° 40' 32.400 W 6,900.0 81.39 3,064.7 -1,982.6 -4,775.6247.46 1,557,023.865,970,479.08 70° 19' 46.887 N 150° 40' 35.065 W 6,907.5 81.39 3,065.8 -1,985.5 -4,782.5247.46 1,557,016.965,970,476.30 70° 19' 46.859 N 150° 40' 35.266 W Seabee 7,000.0 81.39 3,079.6 -2,020.5 -4,866.9247.46 1,556,932.165,970,442.13 70° 19' 46.514 N 150° 40' 37.731 W 7,100.0 81.39 3,094.6 -2,058.4 -4,958.2247.46 1,556,840.465,970,405.19 70° 19' 46.140 N 150° 40' 40.396 W 7,200.0 81.39 3,109.6 -2,096.3 -5,049.5247.46 1,556,748.765,970,368.24 70° 19' 45.767 N 150° 40' 43.061 W 7,300.0 81.39 3,124.5 -2,134.2 -5,140.9247.46 1,556,657.065,970,331.30 70° 19' 45.393 N 150° 40' 45.727 W 7,400.0 81.39 3,139.5 -2,172.2 -5,232.2247.46 1,556,565.365,970,294.35 70° 19' 45.020 N 150° 40' 48.392 W 7,500.0 81.39 3,154.5 -2,210.1 -5,323.5247.46 1,556,473.655,970,257.41 70° 19' 44.646 N 150° 40' 51.057 W 7,600.0 81.39 3,169.5 -2,248.0 -5,414.8247.46 1,556,381.955,970,220.46 70° 19' 44.273 N 150° 40' 53.723 W 7,700.0 81.39 3,184.4 -2,285.9 -5,506.1247.46 1,556,290.255,970,183.52 70° 19' 43.899 N 150° 40' 56.388 W 7,800.0 81.39 3,199.4 -2,323.8 -5,597.5247.46 1,556,198.555,970,146.57 70° 19' 43.526 N 150° 40' 59.053 W 7,900.0 81.39 3,214.4 -2,361.7 -5,688.8247.46 1,556,106.855,970,109.63 70° 19' 43.152 N 150° 41' 1.718 W 8,000.0 81.39 3,229.3 -2,399.6 -5,780.1247.46 1,556,015.155,970,072.68 70° 19' 42.779 N 150° 41' 4.383 W 8,100.0 81.39 3,244.3 -2,437.5 -5,871.4247.46 1,555,923.445,970,035.74 70° 19' 42.405 N 150° 41' 7.049 W 8,200.0 81.39 3,259.3 -2,475.4 -5,962.7247.46 1,555,831.745,969,998.79 70° 19' 42.032 N 150° 41' 9.714 W 8,300.0 81.39 3,274.2 -2,513.3 -6,054.0247.46 1,555,740.045,969,961.85 70° 19' 41.658 N 150° 41' 12.379 W 8,400.0 81.39 3,289.2 -2,551.2 -6,145.4247.46 1,555,648.345,969,924.90 70° 19' 41.285 N 150° 41' 15.044 W 8,500.0 81.39 3,304.2 -2,589.1 -6,236.7247.46 1,555,556.645,969,887.96 70° 19' 40.911 N 150° 41' 17.709 W 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 5 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 8,600.0 81.39 3,319.1 -2,627.0 -6,328.0247.46 1,555,464.945,969,851.01 70° 19' 40.538 N 150° 41' 20.374 W 8,700.0 81.39 3,334.1 -2,665.0 -6,419.3247.46 1,555,373.235,969,814.06 70° 19' 40.164 N 150° 41' 23.039 W 8,800.0 81.39 3,349.1 -2,702.9 -6,510.6247.46 1,555,281.535,969,777.12 70° 19' 39.790 N 150° 41' 25.704 W 8,900.0 81.39 3,364.0 -2,740.8 -6,601.9247.46 1,555,189.835,969,740.17 70° 19' 39.417 N 150° 41' 28.369 W 9,000.0 81.39 3,379.0 -2,778.7 -6,693.3247.46 1,555,098.135,969,703.23 70° 19' 39.043 N 150° 41' 31.034 W 9,100.0 81.39 3,394.0 -2,816.6 -6,784.6247.46 1,555,006.435,969,666.28 70° 19' 38.670 N 150° 41' 33.699 W 9,200.0 81.39 3,408.9 -2,854.5 -6,875.9247.46 1,554,914.735,969,629.34 70° 19' 38.296 N 150° 41' 36.363 W 9,300.0 81.39 3,423.9 -2,892.4 -6,967.2247.46 1,554,823.025,969,592.39 70° 19' 37.922 N 150° 41' 39.028 W 9,400.0 81.39 3,438.9 -2,930.3 -7,058.5247.46 1,554,731.325,969,555.45 70° 19' 37.549 N 150° 41' 41.693 W 9,500.0 81.39 3,453.8 -2,968.2 -7,149.9247.46 1,554,639.625,969,518.50 70° 19' 37.175 N 150° 41' 44.358 W 9,600.0 81.39 3,468.8 -3,006.1 -7,241.2247.46 1,554,547.925,969,481.56 70° 19' 36.801 N 150° 41' 47.023 W 9,700.0 81.39 3,483.8 -3,044.0 -7,332.5247.46 1,554,456.225,969,444.61 70° 19' 36.427 N 150° 41' 49.687 W 9,800.0 81.39 3,498.8 -3,081.9 -7,423.8247.46 1,554,364.525,969,407.67 70° 19' 36.054 N 150° 41' 52.352 W 9,900.0 81.39 3,513.7 -3,119.8 -7,515.1247.46 1,554,272.815,969,370.72 70° 19' 35.680 N 150° 41' 55.017 W 10,000.0 81.39 3,528.7 -3,157.8 -7,606.4247.46 1,554,181.115,969,333.78 70° 19' 35.306 N 150° 41' 57.681 W 10,100.0 81.39 3,543.7 -3,195.7 -7,697.8247.46 1,554,089.415,969,296.83 70° 19' 34.933 N 150° 42' 0.346 W 10,200.0 81.39 3,558.6 -3,233.6 -7,789.1247.46 1,553,997.715,969,259.89 70° 19' 34.559 N 150° 42' 3.010 W 10,300.0 81.39 3,573.6 -3,271.5 -7,880.4247.46 1,553,906.015,969,222.94 70° 19' 34.185 N 150° 42' 5.675 W 10,400.0 81.39 3,588.6 -3,309.4 -7,971.7247.46 1,553,814.315,969,186.00 70° 19' 33.811 N 150° 42' 8.339 W 10,460.6 81.39 3,597.6 -3,332.3 -8,027.0247.46 1,553,758.785,969,163.63 70° 19' 33.585 N 150° 42' 9.953 W Start DLS 3.00 TFO 101.14 10,500.0 81.16 3,603.6 -3,346.9 -8,063.2248.63 1,553,722.475,969,149.43 70° 19' 33.441 N 150° 42' 11.008 W 10,600.0 80.61 3,619.4 -3,380.5 -8,156.0251.62 1,553,629.295,969,116.84 70° 19' 33.110 N 150° 42' 13.717 W 10,700.0 80.07 3,636.2 -3,409.1 -8,250.3254.61 1,553,534.685,969,089.20 70° 19' 32.827 N 150° 42' 16.470 W 10,800.0 79.57 3,653.9 -3,432.7 -8,345.9257.62 1,553,438.915,969,066.58 70° 19' 32.594 N 150° 42' 19.258 W 10,900.0 79.09 3,672.4 -3,451.3 -8,442.4260.63 1,553,342.245,969,049.05 70° 19' 32.411 N 150° 42' 22.074 W 11,000.0 78.64 3,691.8 -3,464.7 -8,539.5263.65 1,553,244.935,969,036.65 70° 19' 32.278 N 150° 42' 24.910 W 11,100.0 78.22 3,711.8 -3,473.0 -8,637.2266.68 1,553,147.255,969,029.42 70° 19' 32.195 N 150° 42' 27.759 W 11,200.0 77.83 3,732.6 -3,476.0 -8,734.9269.73 1,553,049.475,969,027.38 70° 19' 32.164 N 150° 42' 30.613 W 11,300.0 77.48 3,754.0 -3,473.9 -8,832.6272.78 1,552,951.865,969,030.53 70° 19' 32.184 N 150° 42' 33.463 W 11,400.0 77.16 3,775.9 -3,466.6 -8,929.8275.83 1,552,854.675,969,038.87 70° 19' 32.255 N 150° 42' 36.303 W 11,500.0 76.88 3,798.4 -3,454.1 -9,026.5278.90 1,552,758.195,969,052.37 70° 19' 32.376 N 150° 42' 39.124 W 11,558.8 76.73 3,811.8 -3,444.3 -9,082.9280.70 1,552,701.845,969,062.71 70° 19' 32.472 N 150° 42' 40.772 W Nanushuk 11,600.0 76.63 3,821.3 -3,436.5 -9,122.2281.97 1,552,662.675,969,071.00 70° 19' 32.549 N 150° 42' 41.919 W 11,610.0 76.61 3,823.6 -3,434.4 -9,131.7282.28 1,552,653.185,969,073.14 70° 19' 32.569 N 150° 42' 42.196 W 9-5/8" Intermediate Liner 11,700.0 76.42 3,844.6 -3,413.8 -9,216.7285.05 1,552,568.375,969,094.69 70° 19' 32.771 N 150° 42' 44.679 W 11,789.9 76.27 3,865.8 -3,389.0 -9,300.5287.82 1,552,484.885,969,120.27 70° 19' 33.013 N 150° 42' 47.126 W NT8 MFS 11,800.0 76.25 3,868.2 -3,386.0 -9,309.9288.13 1,552,475.565,969,123.40 70° 19' 33.042 N 150° 42' 47.399 W 11,900.0 76.12 3,892.1 -3,353.3 -9,401.3291.22 1,552,384.495,969,157.04 70° 19' 33.363 N 150° 42' 50.069 W 11,973.6 76.05 3,909.8 -3,326.1 -9,467.4293.49 1,552,318.685,969,184.91 70° 19' 33.629 N 150° 42' 51.999 W NT7 MFS 12,000.0 76.03 3,916.2 -3,315.8 -9,490.8294.30 1,552,295.415,969,195.52 70° 19' 33.731 N 150° 42' 52.682 W 12,100.0 75.97 3,940.4 -3,273.5 -9,578.1297.40 1,552,208.565,969,238.73 70° 19' 34.146 N 150° 42' 55.233 W 12,134.8 75.96 3,948.8 -3,257.7 -9,607.9298.47 1,552,178.915,969,254.85 70° 19' 34.301 N 150° 42' 56.103 W NT6 MFS 12,200.0 75.95 3,964.6 -3,226.5 -9,663.0300.49 1,552,124.185,969,286.55 70° 19' 34.606 N 150° 42' 57.712 W 12,300.0 75.98 3,988.9 -3,175.1 -9,745.2303.58 1,552,042.505,969,338.86 70° 19' 35.111 N 150° 43' 0.115 W 12,324.4 75.99 3,994.8 -3,161.9 -9,764.9304.34 1,552,022.985,969,352.30 70° 19' 35.241 N 150° 43' 0.689 W NT5 MFS 12,345.9 76.00 4,000.0 -3,150.0 -9,782.0305.00 1,552,005.965,969,364.33 70° 19' 35.358 N 150° 43' 1.190 W Start DLS 3.28 TFO 74.32 12,400.0 76.49 4,012.9 -3,119.2 -9,824.6306.76 1,551,963.735,969,395.56 70° 19' 35.660 N 150° 43' 2.434 W 12,500.0 77.41 4,035.4 -3,058.7 -9,900.9309.98 1,551,888.015,969,456.82 70° 19' 36.254 N 150° 43' 4.665 W 12,515.5 77.56 4,038.8 -3,049.0 -9,912.5310.48 1,551,876.595,969,466.69 70° 19' 36.350 N 150° 43' 5.002 W NT4 MFS 12,600.0 78.38 4,056.4 -2,993.8 -9,974.0313.19 1,551,815.585,969,522.47 70° 19' 36.891 N 150° 43' 6.802 W 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 6 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 12,700.0 79.39 4,075.7 -2,924.7 -10,043.7316.37 1,551,746.685,969,592.30 70° 19' 37.570 N 150° 43' 8.838 W 12,800.0 80.42 4,093.2 -2,851.6 -10,109.6319.53 1,551,681.535,969,666.08 70° 19' 38.288 N 150° 43' 10.765 W 12,900.0 81.48 4,109.0 -2,774.8 -10,171.6322.67 1,551,620.345,969,743.57 70° 19' 39.043 N 150° 43' 12.578 W 13,000.0 82.57 4,122.8 -2,694.4 -10,229.5325.80 1,551,563.325,969,824.51 70° 19' 39.832 N 150° 43' 14.271 W 13,023.3 82.83 4,125.8 -2,675.3 -10,242.3326.52 1,551,550.665,969,843.83 70° 19' 40.021 N 150° 43' 14.647 W NT3 MFS 13,083.8 83.50 4,133.0 -2,624.6 -10,274.6328.40 1,551,518.895,969,894.79 70° 19' 40.518 N 150° 43' 15.592 W Start 100.0 hold at 13083.8 MD 13,100.0 83.50 4,134.8 -2,610.9 -10,283.1328.40 1,551,510.595,969,908.60 70° 19' 40.653 N 150° 43' 15.839 W 13,183.8 83.50 4,144.3 -2,540.0 -10,326.7328.40 1,551,467.725,969,979.94 70° 19' 41.350 N 150° 43' 17.116 W Start DLS 1.25 TFO 2.62 13,200.0 83.70 4,146.1 -2,526.3 -10,335.2328.41 1,551,459.425,969,993.76 70° 19' 41.485 N 150° 43' 17.363 W 13,234.7 84.14 4,149.8 -2,496.9 -10,353.2328.43 1,551,441.685,970,023.31 70° 19' 41.774 N 150° 43' 17.891 W NT3.2 Top Reservoir 13,300.0 84.95 4,156.0 -2,441.5 -10,387.2328.47 1,551,408.235,970,079.08 70° 19' 42.318 N 150° 43' 18.887 W 13,400.0 86.20 4,163.7 -2,356.5 -10,439.3328.52 1,551,357.035,970,164.62 70° 19' 43.154 N 150° 43' 20.411 W 13,500.0 87.45 4,169.3 -2,271.3 -10,491.4328.58 1,551,305.845,970,250.33 70° 19' 43.991 N 150° 43' 21.935 W 13,600.0 88.70 4,172.6 -2,186.0 -10,543.5328.64 1,551,254.695,970,336.18 70° 19' 44.829 N 150° 43' 23.459 W 13,700.0 89.94 4,173.8 -2,100.6 -10,595.5328.69 1,551,203.595,970,422.12 70° 19' 45.668 N 150° 43' 24.980 W 13,707.0 90.03 4,173.8 -2,094.6 -10,599.1328.70 1,551,200.005,970,428.16 70° 19' 45.727 N 150° 43' 25.087 W Start DLS 3.00 TFO 54.46 13,731.1 90.45 4,173.7 -2,074.0 -10,611.5329.29 1,551,187.845,970,448.89 70° 19' 45.930 N 150° 43' 25.450 W Start 5058.9 hold at 13731.1 MD 13,800.0 90.45 4,173.2 -2,014.7 -10,646.7329.29 1,551,153.265,970,508.51 70° 19' 46.512 N 150° 43' 26.480 W 13,900.0 90.45 4,172.4 -1,928.7 -10,697.8329.29 1,551,103.095,970,595.01 70° 19' 47.357 N 150° 43' 27.975 W 14,000.0 90.45 4,171.6 -1,842.8 -10,748.9329.29 1,551,052.935,970,681.50 70° 19' 48.202 N 150° 43' 29.470 W 14,100.0 90.45 4,170.8 -1,756.8 -10,800.0329.29 1,551,002.765,970,767.99 70° 19' 49.047 N 150° 43' 30.964 W 14,200.0 90.45 4,170.0 -1,670.8 -10,851.0329.29 1,550,952.595,970,854.48 70° 19' 49.891 N 150° 43' 32.459 W 14,300.0 90.45 4,169.2 -1,584.9 -10,902.1329.29 1,550,902.435,970,940.98 70° 19' 50.736 N 150° 43' 33.954 W 14,400.0 90.45 4,168.4 -1,498.9 -10,953.2329.29 1,550,852.265,971,027.47 70° 19' 51.581 N 150° 43' 35.449 W 14,500.0 90.45 4,167.7 -1,412.9 -11,004.2329.29 1,550,802.105,971,113.96 70° 19' 52.426 N 150° 43' 36.944 W 14,600.0 90.45 4,166.9 -1,327.0 -11,055.3329.29 1,550,751.935,971,200.45 70° 19' 53.271 N 150° 43' 38.439 W 14,700.0 90.45 4,166.1 -1,241.0 -11,106.4329.29 1,550,701.775,971,286.94 70° 19' 54.115 N 150° 43' 39.934 W 14,800.0 90.45 4,165.3 -1,155.0 -11,157.5329.29 1,550,651.605,971,373.44 70° 19' 54.960 N 150° 43' 41.429 W 14,900.0 90.45 4,164.5 -1,069.0 -11,208.5329.29 1,550,601.435,971,459.93 70° 19' 55.805 N 150° 43' 42.924 W 15,000.0 90.45 4,163.7 -983.1 -11,259.6329.29 1,550,551.275,971,546.42 70° 19' 56.650 N 150° 43' 44.419 W 15,100.0 90.45 4,162.9 -897.1 -11,310.7329.29 1,550,501.105,971,632.91 70° 19' 57.494 N 150° 43' 45.914 W 15,200.0 90.45 4,162.1 -811.1 -11,361.8329.29 1,550,450.945,971,719.41 70° 19' 58.339 N 150° 43' 47.410 W 15,300.0 90.45 4,161.3 -725.2 -11,412.8329.29 1,550,400.775,971,805.90 70° 19' 59.184 N 150° 43' 48.905 W 15,400.0 90.45 4,160.6 -639.2 -11,463.9329.29 1,550,350.605,971,892.39 70° 20' 0.029 N 150° 43' 50.400 W 15,500.0 90.45 4,159.8 -553.2 -11,515.0329.29 1,550,300.445,971,978.88 70° 20' 0.873 N 150° 43' 51.895 W 15,600.0 90.45 4,159.0 -467.3 -11,566.1329.29 1,550,250.275,972,065.37 70° 20' 1.718 N 150° 43' 53.391 W 15,700.0 90.45 4,158.2 -381.3 -11,617.1329.29 1,550,200.115,972,151.87 70° 20' 2.563 N 150° 43' 54.886 W 15,800.0 90.45 4,157.4 -295.3 -11,668.2329.29 1,550,149.945,972,238.36 70° 20' 3.408 N 150° 43' 56.382 W 15,900.0 90.45 4,156.6 -209.3 -11,719.3329.29 1,550,099.775,972,324.85 70° 20' 4.253 N 150° 43' 57.877 W 16,000.0 90.45 4,155.8 -123.4 -11,770.4329.29 1,550,049.615,972,411.34 70° 20' 5.097 N 150° 43' 59.373 W 16,100.0 90.45 4,155.0 -37.4 -11,821.4329.29 1,549,999.445,972,497.84 70° 20' 5.942 N 150° 44' 0.868 W 16,200.0 90.45 4,154.2 48.6 -11,872.5329.29 1,549,949.285,972,584.33 70° 20' 6.787 N 150° 44' 2.364 W 16,300.0 90.45 4,153.5 134.5 -11,923.6329.29 1,549,899.115,972,670.82 70° 20' 7.631 N 150° 44' 3.859 W 16,400.0 90.45 4,152.7 220.5 -11,974.7329.29 1,549,848.955,972,757.31 70° 20' 8.476 N 150° 44' 5.355 W 16,500.0 90.45 4,151.9 306.5 -12,025.7329.29 1,549,798.785,972,843.80 70° 20' 9.321 N 150° 44' 6.850 W 16,600.0 90.45 4,151.1 392.4 -12,076.8329.29 1,549,748.615,972,930.30 70° 20' 10.166 N 150° 44' 8.346 W 16,700.0 90.45 4,150.3 478.4 -12,127.9329.29 1,549,698.455,973,016.79 70° 20' 11.010 N 150° 44' 9.842 W 16,800.0 90.45 4,149.5 564.4 -12,179.0329.29 1,549,648.285,973,103.28 70° 20' 11.855 N 150° 44' 11.338 W 16,900.0 90.45 4,148.7 650.4 -12,230.0329.29 1,549,598.125,973,189.77 70° 20' 12.700 N 150° 44' 12.833 W 17,000.0 90.45 4,147.9 736.3 -12,281.1329.29 1,549,547.955,973,276.26 70° 20' 13.545 N 150° 44' 14.329 W 17,100.0 90.45 4,147.1 822.3 -12,332.2329.29 1,549,497.785,973,362.76 70° 20' 14.389 N 150° 44' 15.825 W 17,200.0 90.45 4,146.4 908.3 -12,383.3329.29 1,549,447.625,973,449.25 70° 20' 15.234 N 150° 44' 17.321 W 17,300.0 90.45 4,145.6 994.2 -12,434.3329.29 1,549,397.455,973,535.74 70° 20' 16.079 N 150° 44' 18.817 W 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 7 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 17,400.0 90.45 4,144.8 1,080.2 -12,485.4329.29 1,549,347.295,973,622.23 70° 20' 16.923 N 150° 44' 20.313 W 17,500.0 90.45 4,144.0 1,166.2 -12,536.5329.29 1,549,297.125,973,708.73 70° 20' 17.768 N 150° 44' 21.809 W 17,600.0 90.45 4,143.2 1,252.1 -12,587.6329.29 1,549,246.955,973,795.22 70° 20' 18.613 N 150° 44' 23.305 W 17,700.0 90.45 4,142.4 1,338.1 -12,638.6329.29 1,549,196.795,973,881.71 70° 20' 19.457 N 150° 44' 24.801 W 17,800.0 90.45 4,141.6 1,424.1 -12,689.7329.29 1,549,146.625,973,968.20 70° 20' 20.302 N 150° 44' 26.297 W 17,900.0 90.45 4,140.8 1,510.0 -12,740.8329.29 1,549,096.465,974,054.69 70° 20' 21.147 N 150° 44' 27.793 W 18,000.0 90.45 4,140.1 1,596.0 -12,791.9329.29 1,549,046.295,974,141.19 70° 20' 21.991 N 150° 44' 29.289 W 18,100.0 90.45 4,139.3 1,682.0 -12,842.9329.29 1,548,996.125,974,227.68 70° 20' 22.836 N 150° 44' 30.786 W 18,200.0 90.45 4,138.5 1,768.0 -12,894.0329.29 1,548,945.965,974,314.17 70° 20' 23.681 N 150° 44' 32.282 W 18,300.0 90.45 4,137.7 1,853.9 -12,945.1329.29 1,548,895.795,974,400.66 70° 20' 24.525 N 150° 44' 33.778 W 18,400.0 90.45 4,136.9 1,939.9 -12,996.1329.29 1,548,845.635,974,487.16 70° 20' 25.370 N 150° 44' 35.274 W 18,500.0 90.45 4,136.1 2,025.9 -13,047.2329.29 1,548,795.465,974,573.65 70° 20' 26.215 N 150° 44' 36.771 W 18,600.0 90.45 4,135.3 2,111.8 -13,098.3329.29 1,548,745.305,974,660.14 70° 20' 27.059 N 150° 44' 38.267 W 18,700.0 90.45 4,134.5 2,197.8 -13,149.4329.29 1,548,695.135,974,746.63 70° 20' 27.904 N 150° 44' 39.763 W 18,790.0 90.45 4,133.8 2,275.1 -13,195.3329.29 1,548,650.005,974,824.43 70° 20' 28.664 N 150° 44' 41.109 W Start DLS 3.99 TFO -52.14 18,800.0 90.70 4,133.7 2,283.8 -13,200.5328.97 1,548,644.945,974,833.11 70° 20' 28.749 N 150° 44' 41.261 W 18,900.0 93.14 4,130.4 2,367.9 -13,254.3325.81 1,548,591.985,974,917.84 70° 20' 29.575 N 150° 44' 42.838 W 19,000.0 95.58 4,122.8 2,448.8 -13,312.6322.65 1,548,534.575,974,999.32 70° 20' 30.370 N 150° 44' 44.544 W 19,100.0 98.00 4,110.9 2,526.0 -13,375.0319.45 1,548,472.985,975,077.18 70° 20' 31.128 N 150° 44' 46.371 W 19,200.0 100.40 4,094.9 2,599.2 -13,441.2316.22 1,548,407.525,975,151.02 70° 20' 31.847 N 150° 44' 48.311 W 19,268.5 102.02 4,081.6 2,646.8 -13,488.6313.98 1,548,360.615,975,199.08 70° 20' 32.314 N 150° 44' 49.698 W Start DLS 0.01 TFO 125.40 19,300.0 102.01 4,075.1 2,668.2 -13,510.8313.98 1,548,338.655,975,220.72 70° 20' 32.524 N 150° 44' 50.347 W 19,312.0 102.01 4,072.6 2,676.3 -13,519.3313.98 1,548,330.295,975,228.96 70° 20' 32.604 N 150° 44' 50.595 W NT3.2 Top Reservoir PB 19,400.0 102.01 4,054.3 2,736.1 -13,581.2313.99 1,548,269.005,975,289.38 70° 20' 33.191 N 150° 44' 52.407 W 19,467.4 102.00 4,040.2 2,781.9 -13,628.6314.00 1,548,222.065,975,335.66 70° 20' 33.640 N 150° 44' 53.795 W TD at 19467.4 - 4-1/2" Production Liner Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Design Targets LongitudeLatitude Dip Angle (°) Dip Dir. (°) NDBi-049 Flex Point R 4,000.0 5,969,364.33 1,552,005.96-3,150.0 -9,782.00.00 0.00 70° 19' 35.358 N 150° 43' 1.190 W - plan hits target center - Point NDBi-049 TD Rev 1.0 4,040.2 5,975,335.68 1,548,222.032,781.9 -13,628.70.00 0.00 70° 20' 33.640 N 150° 44' 53.796 W - plan hits target center - Point NDBi-049 Build up Re 4,133.8 5,974,824.43 1,548,650.002,275.1 -13,195.30.00 0.00 70° 20' 28.664 N 150° 44' 41.109 W - plan hits target center - Point NDBi-049 Heel Rev 3 4,173.8 5,970,428.16 1,551,200.00-2,094.6 -10,599.10.00 0.00 70° 19' 45.727 N 150° 43' 25.087 W - plan hits target center - Polygon -130.4Point 1 5,970,294.03 1,551,556.694,173.8 358.1 True 5,066.1Point 2 5,975,521.99 1,548,536.704,173.8 -2,716.8 True 4,810.6Point 3 5,975,271.03 1,548,103.684,173.8 -3,147.2 True -385.9Point 4 5,970,042.97 1,551,133.674,173.8 -62.3 True 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 8 Santos Ltd Planning Report - Geographic Well B-49 - Slot B-49Local Co-ordinate Reference:Database:EDM P272 As Plan @ 69.8usftTVD Reference:SantosCompany: P272 As Plan @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-49Well: NDBi-049Wellbore: Plan: NDBi-049 Rev J.0Design: Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 20" Conductor Casing127.0127.0 20 20 13-3/8" Surface Casing2,286.82,625.0 13-3/8 16 9-5/8" Intermediate Liner3,823.611,610.0 9-5/8 12-1/4 4-1/2" Production Liner4,040.219,467.4 4-1/2 8-1/2 Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations 1,049.4 Upper Schrader Bluff1,040.8 1,419.6 Base Permafrost Transition1,392.8 1,807.1 Middle Schrader Bluff1,731.8 2,374.9 MCU 0.002,144.8 3,000.9 Tuluvak Shale2,446.8 3,222.4 Tuluvak Sand2,508.8 5,257.4 TS_790 0.002,818.8 6,907.5 Seabee3,065.8 11,558.8 Nanushuk 0.003,811.8 11,789.9 NT8 MFS 0.003,865.8 11,973.6 NT7 MFS 0.003,909.8 12,134.8 NT6 MFS 0.003,948.8 12,324.4 NT5 MFS 0.003,994.8 12,515.5 NT4 MFS 0.004,038.8 19,312.0 NT3.2 Top Reservoir PB 0.004,072.6 13,023.3 NT3 MFS 0.004,125.8 13,234.7 NT3.2 Top Reservoir4,149.8 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 47.0 47.0 0.0 0.0 Start 350.0 hold at 47.0 MD 397.0 397.0 0.0 0.0 Start Build 2.50 997.0 990.2 -29.9 -72.1 Start 157.0 hold at 997.0 MD 1,154.0 1,141.8 -45.5 -109.6 Start Build 3.00 3,287.3 2,522.3 -613.2 -1,476.8 Start DLS 3.00 TFO 0.14 3,367.1 2,535.9 -643.4 -1,549.4 Start 7093.5 hold at 3367.1 MD 10,460.6 3,597.6 -3,332.3 -8,027.0 Start DLS 3.00 TFO 101.14 12,345.9 4,000.0 -3,150.0 -9,782.0 Start DLS 3.28 TFO 74.32 13,083.8 4,133.0 -2,624.6 -10,274.6 Start 100.0 hold at 13083.8 MD 13,183.8 4,144.3 -2,540.0 -10,326.7 Start DLS 1.25 TFO 2.62 13,707.0 4,173.8 -2,094.6 -10,599.1 Start DLS 3.00 TFO 54.46 13,731.1 4,173.7 -2,074.0 -10,611.5 Start 5058.9 hold at 13731.1 MD 18,790.0 4,133.8 2,275.1 -13,195.3 Start DLS 3.99 TFO -52.14 19,268.5 4,081.6 2,646.8 -13,488.6 Start DLS 0.01 TFO 125.40 19,467.4 4,040.2 2,781.9 -13,628.7 TD at 19467.4 25/09/2024 11:15:54 COMPASS 5000.17 Build Page 9 -4000-2000020004000South(-)/North(+)-14000 -12000 -10000 -8000 -6000 -4000 -2000 0West(-)/East(+)NDBi-049 TD Rev 1.0NDBi-049 Heel Rev 3.020" Conductor Casing13-3/8" Surface Casing9-5/8" Intermediate Liner4-1/2" Production LinerPlan: NDBi-049 Rev J.0Plan: NDBi-049 Rev J.09:31, September 25 2024 -95009501900285038004750True Vertical Depth-2000 0 2000 4000 6000 8000 10000 12000 14000Vertical Section at 281.54°20" Conductor Casing13-3/8" Surface Casing9-5/8" Intermediate Liner4-1/2" Production Liner100020003000400050006000700080009000100001100012000130001 4000 15000 16 000 1 7000 18 000 1 9 0 0 0 1 9 4 6 7 0°30°60°81°90°90° P la n : N D B i-0 4 9 R e v J .0 Upper Schrader BluffBase Permafrost TransitionMiddle Schrader BluffMCUTuluvak ShaleTuluvak SandTS_790SeabeeNanushukNT8 MFSNT7 MFSNT6 MFSNT5 MFSNT4 MFSNT3 MFSNT3.2 Top ReservoirNT3.2 Top Reservoir PBPlan: NDBi-049 Rev J.09:34, September 25 2024 25 September, 2024 Anticollision Summary Report Santos Pikka NDB B-49 NDBi-049 Plan: NDBi-049 Rev J.0 Anticollision Summary Report Well B-49 - Slot B-49Local Co-ordinate Reference:SantosCompany: P272 As Plan @ 69.8usftTVD Reference:PikkaProject: P272 As Plan @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-49Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDBi-049 Database:EDM STO Alaska Offset DatumReference Design:Plan: NDBi-049 Rev J.0 Offset TVD Reference: Interpolation Method: Depth Range: Reference Error Model: Scan Method: Error Surface: Filter type: ISCWSA Closest Approach 3D Combined Pedal Curve GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere MD Interval 25.0usft Unlimited Maximum centre distance of 2,142.0usft Plan: NDBi-049 Rev J.0 Results Limited by: SigmaWarning Levels Evaluated at:2.79 ISCWSA TESTCasing Method: From (usft) Survey Tool Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 25/09/2024 SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISCWSA Rev 4)47.0 600.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag600.0 1,800.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag600.0 2,625.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag2,625.0 3,825.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag2,625.0 4,280.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth + sag correction4,280.0 5,000.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag5,000.0 6,200.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag5,000.0 11,610.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag11,610.0 12,810.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag11,610.0 19,467.4 Plan: NDBi-049 Rev J.0 (NDBi-049) Offset Well - Wellbore - Design Reference Measured Depth (usft) Offset Measured Depth (usft) Between Centres (usft) Between Ellipses (usft) Separation Factor Warning Summary Site Name Distance NDB CCB-11 - NDB-011 - Plan: NDB-011 Rev A.0 10,316.7 16,052.8 727.0 629.2 9.485 ESB-11 - NDB-011 - Plan: NDB-011 Rev A.0 10,350.0 16,057.3 727.8 627.9 9.302 SFB-11 - NDB-011 - Plan: NDB-011 Rev A.0 10,750.0 16,131.9 837.7 706.8 8.126 CC, ESB-14 - NDBi-014 - NDBi-014 409.5 413.4 699.5 690.5 142.024 SFB-14 - NDBi-014 - NDBi-014 5,000.0 5,304.2 1,993.5 1,851.9 17.897 CCB-33 - NDB-033 - Plan: NDB-033 Rev A.0 375.0 375.2 319.2 310.0 63.754 ESB-33 - NDB-033 - Plan: NDB-033 Rev A.0 400.0 400.2 319.2 310.0 63.071 SFB-33 - NDB-033 - Plan: NDB-033 Rev A.0 5,000.0 5,203.8 830.5 668.2 6.483 CCB-36 - NDBi-036 - Plan: NDBi-036 Rev B.0 375.0 375.2 259.1 250.2 53.224 ESB-36 - NDBi-036 - Plan: NDBi-036 Rev B.0 400.0 400.2 259.1 250.1 52.907 SFB-36 - NDBi-036 - Plan: NDBi-036 Rev B.0 6,100.0 6,464.7 811.1 608.5 5.055 CC, ESB-37 - NDB-037 - Plan: NDB-037 Rev C.1 409.7 411.0 239.9 230.9 48.792 SFB-37 - NDB-037 - Plan: NDB-037 Rev C.1 3,800.0 3,461.6 1,780.2 1,699.1 28.292 CC, ESB-38 - NDBi-038 - NDBi-038 Rev A.0 400.0 400.2 219.0 209.7 43.153 SFB-38 - NDBi-038 - NDBi-038 Rev A.0 5,000.0 5,106.4 606.3 448.9 4.878 CCB-39 - NDB-039 - Plan: NDB-039 Rev A.0 327.9 328.1 199.0 190.0 40.321 ESB-39 - NDB-039 - Plan: NDB-039 Rev A.0 400.0 400.1 199.1 189.8 39.153 SFB-39 - NDB-039 - Plan: NDB-039 Rev A.0 3,800.0 3,326.7 1,645.2 1,548.7 21.908 CC, ESB-40 - NDB-040 - Plan: NDB-040 Rev A.0 400.0 400.2 179.0 169.8 35.187 SFB-40 - NDB-040 - Plan: NDB-040 Rev A.0 9,550.0 9,608.8 962.3 676.4 4.233 CCB-41 - NDBi-041 - Plan: NDBi-041 Rev A.0 327.9 328.1 159.0 149.9 32.107 Take Immediate Action, EB-41 - NDBi-041 - Plan: NDBi-041 Rev A.0 19,325.0 15,466.7 389.4 -38.9 1.137 CCB-42 - NDB-042 - NDB-042 Rev12 375.0 375.2 138.9 130.0 28.461 ESB-42 - NDB-042 - NDB-042 Rev12 400.0 400.2 138.9 130.0 28.284 SFB-42 - NDB-042 - NDB-042 Rev12 500.0 500.2 141.2 132.1 27.935 CCB-43 - NDBi-043 - NDBi-043 47.0 46.6 120.1 111.0 25.454 ESB-43 - NDBi-043 - NDBi-043 50.0 49.6 120.1 111.0 25.440 SFB-43 - NDBi-043 - NDBi-043 2,425.0 2,565.6 207.2 176.0 8.999 CCB-43 - NDBi-043A - NDBi-043A 47.0 46.6 120.1 111.0 25.454 ESB-43 - NDBi-043A - NDBi-043A 50.0 49.6 120.1 111.0 25.440 SFB-43 - NDBi-043A - NDBi-043A 2,425.0 2,565.6 207.2 176.0 8.999 CC, ESB-44 - NDBi-044 - NDBi-044 414.4 415.0 99.2 90.1 19.706 25/09/2024 9:27:18AM COMPASS 5000.17 Build 02 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 2 Anticollision Summary Report Well B-49 - Slot B-49Local Co-ordinate Reference:SantosCompany: P272 As Plan @ 69.8usftTVD Reference:PikkaProject: P272 As Plan @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-49Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDBi-049 Database:EDM STO Alaska Offset DatumReference Design:Plan: NDBi-049 Rev J.0 Offset TVD Reference: Offset Well - Wellbore - Design Reference Measured Depth (usft) Offset Measured Depth (usft) Between Centres (usft) Between Ellipses (usft) Separation Factor Warning Summary Site Name Distance NDB SFB-44 - NDBi-044 - NDBi-044 5,000.0 4,855.8 1,792.1 1,633.0 14.286 CCB-45 - NDB-045 - Plan: NDB-045 Rev A.0 375.0 375.2 78.8 69.6 15.382 ESB-45 - NDB-045 - Plan: NDB-045 Rev A.0 400.0 400.2 78.8 69.6 15.223 SFB-45 - NDB-045 - Plan: NDB-045 Rev A.0 6,100.0 6,131.1 293.2 141.8 2.444 CCB-46 - NDBi-046 - NDBi-046 542.4 546.0 56.0 46.8 10.636 ESB-46 - NDBi-046 - NDBi-046 550.0 553.6 56.0 46.8 10.610 SFB-46 - NDBi-046 - NDBi-046 12,800.0 13,751.1 161.2 60.6 2.025 CCB-46 - NDBi-046 L1 - NDBi-046 L1 542.4 546.0 56.0 46.8 10.636 ESB-46 - NDBi-046 L1 - NDBi-046 L1 550.0 553.6 56.0 46.8 10.610 SFB-46 - NDBi-046 L1 - NDBi-046 L1 12,800.0 13,751.1 161.2 60.6 2.025 CCB-47 - NDB-047 - NDB-047 Rev12 375.0 375.2 38.8 29.9 7.606 ESB-47 - NDB-047 - NDB-047 Rev12 400.0 400.2 38.8 29.9 7.559 SFB-47 - NDB-047 - NDB-047 Rev12 425.0 425.2 39.0 30.0 7.543 CCB-48 - NDB-048 - NDB-048 Rev E.1 375.0 375.0 20.1 11.1 3.678 ESB-48 - NDB-048 - NDB-048 Rev E.1 400.0 400.0 20.1 11.1 3.656 Normal Operations, SFB-48 - NDB-048 - NDB-048 Rev E.1 14,150.0 12,755.4 385.0 84.9 1.608 CCB-50 - NDBi-050 - Plan: NDBi-050 Rev D.2 328.0 328.0 19.9 11.0 3.681 ESB-50 - NDBi-050 - Plan: NDBi-050 Rev D.2 350.0 350.0 19.9 11.0 3.664 SFB-50 - NDBi-050 - Plan: NDBi-050 Rev D.2 12,150.0 11,939.1 490.3 194.0 2.077 CC, ESB-51 - NDB-051 - NDB-051 209.1 208.7 39.8 31.1 8.025 SFB-51 - NDB-051 - NDB-051 5,000.0 4,785.9 548.6 388.0 4.320 25/09/2024 9:27:18AM COMPASS 5000.17 Build 02 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 3 Anticollision Summary Report Well B-49 - Slot B-49Local Co-ordinate Reference:SantosCompany: P272 As Plan @ 69.8usftTVD Reference:PikkaProject: P272 As Plan @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-49Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDBi-049 Database:EDM STO Alaska Offset DatumReference Design:Plan: NDBi-049 Rev J.0 Offset TVD Reference: 0 550 1100 1650 2200 Centre to Centre Separation0 3500 7000 10500 14000 17500 21000 Measured Depth Ladder Plot B-11, NDB-011, Plan: NDB-011 Rev A.0 V0 B-14, NDBi-014, NDBi-014 V0 B-33, NDB-033, Plan: NDB-033 Rev A.0 V0 B-36, NDBi-036, Plan: NDBi-036 Rev B.0 V0 B-37, NDB-037, Plan: NDB-037 Rev C.1 V0 B-38, NDBi-038, NDBi-038 Rev A.0 V0 B-39, NDB-039, Plan: NDB-039 Rev A.0 V0 B-40, NDB-040, Plan: NDB-040 Rev A.0 V0 B-41, NDBi-041, Plan: NDBi-041 Rev A.0 V0 B-42, NDB-042, NDB-042 Rev12 V0 B-43, NDBi-043, NDBi-043 V0 B-43, NDBi-043A, NDBi-043A V0 B-44, NDBi-044, NDBi-044 V0 B-45, NDB-045, Plan: NDB-045 Rev A.0 V0 B-46, NDBi-046, NDBi-046 V0 B-46, NDBi-046 L1, NDBi-046 L1 V0 B-47, NDB-047, NDB-047 Rev12 V0 B-48, NDB-048, NDB-048 Rev E.1 V0 B-50, NDBi-050, Plan: NDBi-050 Rev D.2 V0 B-51, NDB-051, NDB-051 V0 L E G E N D Coordinates are relative to: B-49 - Slot B-49 Coordinate System is US State Plane 1983, Alaska Zone 4 Grid Convergence at Surface is: -0.60°Central Meridian is 150° 0' 0.000 W Offset Depths are relative to Offset Datum Reference Depths are relative to P272 As Plan @ 69.8usft 25/09/2024 9:27:18AM COMPASS 5000.17 Build 02 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 4 Anticollision Summary Report Well B-49 - Slot B-49Local Co-ordinate Reference:SantosCompany: P272 As Plan @ 69.8usftTVD Reference:PikkaProject: P272 As Plan @ 69.8usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-49Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDBi-049 Database:EDM STO Alaska Offset DatumReference Design:Plan: NDBi-049 Rev J.0 Offset TVD Reference: 0.00 3.00 6.00 9.00 Separation Factor0 3500 7000 10500 14000 17500 Measured Depth Stop Drilling Caution - Monitor Closely Normal Operations Separation Factor Plot B-11, NDB-011, Plan: NDB-011 Rev A.0 V0 B-14, NDBi-014, NDBi-014 V0 B-33, NDB-033, Plan: NDB-033 Rev A.0 V0 B-36, NDBi-036, Plan: NDBi-036 Rev B.0 V0 B-37, NDB-037, Plan: NDB-037 Rev C.1 V0 B-38, NDBi-038, NDBi-038 Rev A.0 V0 B-39, NDB-039, Plan: NDB-039 Rev A.0 V0 B-40, NDB-040, Plan: NDB-040 Rev A.0 V0 B-41, NDBi-041, Plan: NDBi-041 Rev A.0 V0 B-42, NDB-042, NDB-042 Rev12 V0 B-43, NDBi-043, NDBi-043 V0 B-43, NDBi-043A, NDBi-043A V0 B-44, NDBi-044, NDBi-044 V0 B-45, NDB-045, Plan: NDB-045 Rev A.0 V0 B-46, NDBi-046, NDBi-046 V0 B-46, NDBi-046 L1, NDBi-046 L1 V0 B-47, NDB-047, NDB-047 Rev12 V0 B-48, NDB-048, NDB-048 Rev E.1 V0 B-50, NDBi-050, Plan: NDBi-050 Rev D.2 V0 B-51, NDB-051, NDB-051 V0 L E G E N D Coordinates are relative to: B-49 - Slot B-49 Coordinate System is US State Plane 1983, Alaska Zone 4 Grid Convergence at Surface is: -0.60°Central Meridian is 150° 0' 0.000 W Offset Depths are relative to Offset Datum Reference Depths are relative to P272 As Plan @ 69.8usft 25/09/2024 9:27:18AM COMPASS 5000.17 Build 02 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 5 Northing (4000 usft/in)Easting (4000 usft/in)Northing (4000 usft/in)Easting (4000 usft/in)Plan: NDB-011 Rev A.0NDBi-014Plan: NDB-033 Rev A.0Plan: NDBi-036 Rev B.0Plan: NDB-037 Rev C.1NDBi-038 Rev A.0Plan: NDB-039 Rev A.0Plan: NDB-040 Rev A.0Plan: NDBi-041 Rev A.0NDB-042 Rev12NDBi-043NDBi-043ANDBi-044Plan: NDB-045 Rev A.0NDBi-046NDBi-046 L1NDB-047 Rev12NDB-048 Rev E.1Plan: NDBi-050 Rev D.2NDB-0511 0 0 0 2 0 0 0 3 0 0 0 4000Plan: NDBi-049 Rev J.0NDBNPF9:36, September 25 2024 0 30 60 Centre to Centre Separation0 450 900 1350 1800 2250 Partial Measured DepthNDBi-046NDBi-046 L1NDB-047 Rev12NDB-048 Rev E.1Plan: NDBi-050 Rev D.2NDB-051Equivalent Magnetic Distance Plan: NDBi-049 Rev J.0 Ladder View 0 150 300 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 Measured DepthPlan: NDBi-036 Rev B.0Plan: NDB-037 Rev C.1NDBi-038 Rev A.0Plan: NDB-039 Rev A.0Plan: NDB-040 Rev A.0Plan: NDBi-041 Rev A.0NDB-042 Rev12NDBi-043NDBi-043ANDBi-044Plan: NDB-045 Rev A.0NDBi-046NDBi-046 L1NDB-047 Rev12NDB-048 Rev E.1Plan: NDBi-050 Rev D.2NDB-051Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 47.0 600.0 Plan: NDBi-049 Rev J.0 (NDBi-049) SDI_URSA1_I4 600.0 1800.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 600.0 2625.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 2625.0 3825.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 2625.0 4280.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 4280.0 5000.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD_Interp Azi+Sag 5000.0 6200.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 5000.0 11610.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 11610.0 12810.0 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+Sag 11610.0 19467.4 Plan: NDBi-049 Rev J.0 (NDBi-049) 3_MWD+IFR2+MS+Sag 9:41, September 25 2024 CASING DETAILS TVD MD Name 127.0 127.0 20" Conductor Casing 2286.8 2625.0 13-3/8" Surface Casing 3823.6 11610.09-5/8" Intermediate Liner 4040.2 19467.4 4-1/2" Production Liner Plan:NDBiͲ049RevJ.0ACFlipbookSURVEY PROGRAMDepth From Depth To Tool47.0 600.0 SDI_URSA1_I4600.0 1800.0 3_MWD+IFR2+Sag600.0 2625.0 3_MWD+IFR2+MS+Sag2625.0 3825.0 3_MWD+IFR2+Sag2625.0 4280.0 3_MWD+IFR2+MS+Sag4280.0 5000.0 3_MWD_Interp Azi+Sag5000.0 6200.0 3_MWD+IFR2+Sag5000.0 11610.0 3_MWD+IFR2+MS+Sag11610.0 12810.0 3_MWD+IFR2+Sag11610.0 19467.4 3_MWD+IFR2+MS+SagCASING DETAILSTVD MD Name127.0 127.0 20" Conductor Casing2286.8 2625.0 13-3/8" Surface Casing3823.6 11610.0 9-5/8" Intermediate Liner4040.2 19467.4 4-1/2" Production Liner1515303045456060757590900901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [30 usft/in]475075100125150175200225250275300325350375400424448472496520543NDBi-0447075100125150175200225250275300325350375400424448472496520544568592616640664688712736760784Plan: NDB-045 Rev A.04750751001251501752002252502753003253503754004244494734985225465715956196446686927167417657898138378618859089329569791003NDBi-0464750751001251501752002252502753003253503754004244494734985225465715956196446686927167417657898138378618859089329569791003NDBi-046 L1475075100125150175200225250275300325350375400424449473498523547572596620645669693717741765789813837860884907931NDB-047 Rev12475075100125150175200225250275300325350375400425450474499524549573598623647672697721746771795820844869893918942967991101610401065109011151139116411881212123612601284130813321355NDB-048 Rev E.1475075100125150175200225250275300325350375400425450476501526551577602627652678703728753779804829854879905930955980100510301055108011051130115511811206123112561281130713321357138214071432145814831508153315581583160816341659168417091734175917841809183418591884190919341960198520102035206020852110213521602185220922342259228423092334235923842409243424592484250925332558258326082633Plan: NDBi-050 Rev D.247507510012515017520022525027530032535037540042645147750252855357960463065668170773275878480983586188791293896499010151040106510901115114011651191121712441270129613221348137414001426145214781504153015561582NDB-05147 500500 10001000 15001500 20002000 25002500 30003000 50005000 80008000 1200012000 1600016000 20700From Colour To MD47.0To19467.4MD Azi TFace47.0 0.00 0.00397.0 247.45 247.45997.0 247.45 247.451154.0 247.45 0.003287.3 247.45 0.003367.1 247.46 0.1410460.6 247.46 0.0012345.9 305.00 101.1413083.8 328.40 74.3213183.8 328.40 0.0013707.0 328.70 2.6213731.1 329.29 54.4618790.0 329.29 0.0019268.5 313.98 -52.1419467.4 314.00 125.40 Attachment 3: BOPE Equipment 21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000# 21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#FORWARD 13-5/8" X 5,000#13-5/8" X 5,000#30"13-5/8" X 5,000#186"13-5/8" X 5,000#DUTCH LOCK DOWN ChokeLinefromBOPPressureGauge1502PressureSensorPressureTransducerBill ofMaterialItemDescriptionToPanicLineItemDescriptionA3Ͳ1/8”– 5,000psi W.P.RemoteHydraulicOperatedChokeB3Ͳ1/8”–5,000psiW.P.AdjustableManualChoke1 – 14 3Ͳ1/8”– 5,000psi W.P.ManualGateValve1521/16”5 000 i WP152Ͳ1/16”–5,000psiW.P.ManualGateValveToMudGasLegendBlindSpareToTigerTankSeparatorValveNormally OpenValveNormally Closed Attachment 4: Drilling Hazards 16” Surface Hole Section Hazard Mitigations Conductor Broach Monitor conductor for any indications of broaching. Monitor pit volumes for any losses. Gas Hydrates Keep mud cool, optimize pump rates, minimize any excess circulation. Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Shallow Gas Shallow hazards assessment, sufficient mud weight, on site surveillance (trained drilling personnel). 12-1/4” Intermediate Hole Section Hazard Mitigations Lost Returns MPD to be used to control ECD loading. Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Challenging liner run The Intermediate liner requires a 0.25 OH friction factor to make TD. The Liner and hanger are set up to rotate down in the event the friction factor is higher than anticipated. Washouts/Hole Enlargement Drill with oil-based mud, maintain mud in specifications, use sufficient mud weight / back-pressure to hold back formations. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Hole Cleaning in 82q Sail Conduct hydraulics modeling and control ROP limits based on cuttings returns and observed ECD’s compared to model. Pack Off During Cementing Proper wellbore cleanup procedure prior to running in hole. Stage circulation rates up while running in hole with liner. Circulate bottoms up at multiple depths to condition mud the way in the hole. Circulate at TD to planned cementing rates and ensure hole is clean. Wireline Inaccessibility The sail angle on this section is too high for wireline to be run conventionally. If wireline logs are required for operations a tractor will be required. Operational complexity with Mechanical two stage cement equipment The 2nd stage of the cement job will be conducted through a mechanically shifted sleeve. This will require the LTP to not be set until the 2nd stage is pumped giving a higher complexity leading to complications with setting the LTP. 8-1/2” Production Hole Section Hazard Mitigations Lost Returns MPD to be used to control ECD loading. Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Wellbore Instability Maintain adequate mud weight / back-pressure for wellbore stability. Monitor cuttings returns, LWD logs, and drilling parameters for signs of washout. MPD to minimize pressure cycles on formation. * Note that no H2S has been encountered on nearby offset wells, and H2S is not anticipated in this well. Attachment 5: Leak Off Test Procedure ϭ͘Drill out shoe track, cement plus minimum of 20’ of new formation. Circulate bottoms up and confirm cuttings are observed at surface. Ϯ͘Circulate and condition the mud: Ă͘While 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. ď͘Accurately measure the mud weight with a recently calibrated pressurized mud balance; Đ͘Confirm that mud weight-in is equal to mud weight-out; Ě͘Do not change the mud weight until after the test. ϯ͘Pull the bit back into the casing shoe. ϰ͘Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above expected test pressure. Ă͘Record pressure at surface with calibrated chart recorder. ϱ͘Break circulation down the string. ϲ͘Verify the hole is filled up and close the BOP (annular or upper pipe ram). ϳ͘Perform the LOT or FIT pumping at a constant rate of 0.5bbl/min ;ŽƌĂƐůŽǁĂƐƉŽƐƐŝďůĞͿ. Record pump pressures at 0.25bbl increments;ΕϮƐƚƌŽŬĞƐͿ. ϴ͘Record 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. Ă͘Leak-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. ď͘If 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. Đ͘If FIT skip step 9. ϵ͘Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. ϭϬ͘Stop 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. ϭϭ͘If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. ϭϮ͘Bleed 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. ϭϯ͘Open the BOP. Attachment 6: Cement Summary Surface Casing Cement Casing Size 13-3/8” 68# L-80 BTC/TXP-BTC Surface Casing Basis Lead Open hole volume + 150% excess in permafrost / 50% excess below permafrost Lead TOC Surface Tail Open hole volume + 50% excess + 85 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 10.5 ppg Tuned Spacer Lead 11.0ppg Lead: 336.4 bbls, 1888 cuft, 746 sks ArcticCem, Yield: 2.53 cuft/sk Tail 15.3ppg Tail: 69 bbls, 387 cuft, 312 sks HalCem Type I/II – 1.24 cuft/sk Temp BHST 53° F Verification Method Cement returns to surface Notes Job will be mixed on the fly NDBi-049 13-3/8" SURFACE CEMENT JOB Description TOP BOTTOM LENGTH CAPACITY VOLUME Shoe track length 2540 2625 85 0.14973 12.7 TAIL LENGTH 2125 2625 500 0.07491 37.5 TAIL EXCESS 50% 18.7 LEAD TOP TO BASE OF PERMA 1420 2125 705 0.07491 52.8 EXCESS FACTOR FOR ABOVE 50% 26.4 PERMAFROST ANNULUS (Lead) 128 1420 1292 0.07491 96.8 EXCESS FACTOR FOR ABOVE 150% 145.2 CASED HOLE ANNULUS 46 128 82 0.18620 15.3 Intermediate Liner Cement Casing Size 9-5/8” 47# L-80 Hydril 563 Intermediate Liner Basis Lead Open hole volume + excess Lead TOC Stage 1: N/A Stage 2: N/A Tail Open hole volume + excess + 85 ft shoe track Tail TOC Stage 1: 250’ TVD above top Nanushuk Stage 2: Top of the 9-5/8” Liner Total Cement Volume Spacer ~80 bbls of 12.5 ppg Clean Spacer Lead Stage 1: N/A Stage 2: N/A Tail Stage 1: 30% Open Hole Excess 15.3ppg Tail: 107 bbls, 601cuft, 485sks VersaCem Type I/II – 1.24 cuft/sk Stage 2: 100% Open Hole Excess 15.3ppg Tail: 304 bbls, 1707cuft, 13sks VersaCem Type I/II – 1.24 cuft/sk13sks VersaCem verified cement calcs. -bjm Typo, should be 1378 sks - bjm Temp BHST 87° F Notes Job will be mixed on the fly Verification Method - LWD Sonic will be used to log the 1 st Stage Cement Job Only. -2ndStage Cement Job will not be logged, assuming job parameters are as expected (No losses, good lift pressures, circulate cement off top of liner). Justification: - Stage tool allows for precise placement of base cement column at base Tuluvak hydrocarbon. - Bond log not required for 2 nd Stage per Regulation 20 AAC 25.030(d)(5) -2ndStage bond evaluation does not affect 1st Stage bond evaluation and frac decision. - Logging of 1 st Stage cement will demonstrate isolation between Nanushuk and Tuluvak, ensuring no potential crossflow. -2ndStage cement job will isolate Tuluvak with cement and a V0-rated LTP above it as a redundant means of isolation. - Well design allows for the OA annulus to be freeze protected by circulating in place (with Tieback) vs. bullheaded into place. With a sufficient initial LOT/FIT at the surface casing shoe, any potential Tuluvak pressures will be contained by the surface casing shoe and not cross flow into shallower formations. - Future hydraulic fracture operations will only be done in the Nanushuk formation. Log verification of the 1st stage cement job will verify proper isolation has been achieved for frac operations. - Tuluvak isolation has been achieved on all historical Pikka development wells. - Seeking to simplify an already complicated operation, saving time/money. NDBi-049 9.625" Production Liner - 1st Stage Description TOP BOTTOM LENGTH CAPACITY VOLUME Shoe track length 11525 11610 85 0.07321 6.2 TAIL LENGTH 10220 11610 1390 0.05578 77.5 TAIL EXCESS 30% 23.3 NDBi-049 9.625" Production Liner - 2nd Stage Description TOP BOTTOM LENGTH CAPACITY VOLUME TAIL LENGTH 2625 5270 2645 0.05578 147.5 TAIL EXCESS 100% 147.5 Liner Lap 13-3/8" 68# x 9-5/8" 47# LNR 2475 2625 150 0.05974 9.0 Attachment 7: Prognosed Formation Tops NDBi-049 Prognosed Tops Formation MD (ft) TVD KB (ft) TVDss (ft) Uncertainty Range (±ft) Pore Pressure (ppg) Upper Schrader Bluff 1050 1041 971 100 7.2 Permafrost Base Transition 1420 1393 1323 100 7.3 Middle Schrader Bluff 1807 1732 1662 100 7.6 MCU (Lower Schrader Bluff) 2375 2145 2075 100 7.8 Tuluvak Shale 3001 2447 2377 100 7.9 Tuluvak Sand 3222 2509 2439 100 10.2 TS 790 5257 2819 2749 100 9.4 Seabee 6908 3066 2996 100 9.2 Nanushuk 11559 3812 3742 100 8.9 NT8 MFS 11790 3866 3796 100 8.9 NT7 MFS 11974 3910 3840 100 8.9 NT6 MFS 12135 3949 3879 100 8.9 NT5 MFS 12324 3995 3925 100 8.9 NT4 MFS 12516 4039 3969 100 8.8 NT3 MFS 13023 4126 4056 100 8.8 Nanushuk 3.2 (NT3) 13235 4150 4080 100 8.8 Attachment 8: Well Schematic Attachment 9: Formation Evaluation Program 16” Surface Hole LWD Gamma Ray Resistivity 12-1/4” Intermediate Hole LWD Gamma Ray Resistivity LWD Caliper 8-1/2” Production Hole LWD Gamma Ray Resistivity Sonic (9-5/8” Liner Cement Evaluation Only) Medium Resistivity Density Neutron Mudlogging No mudlogging is planned for NDBi-049 Attachment 10: Wellhead & Tree Diagram Attachment 11: Injector Area of Review Wells within ¼ mile of proposed injection well. Distance Annulus integrity Area of Review Information NDBi-046 360’ Passing MIT-TxIA to 3,500 on 7/28/24 9-5/8” x 13-3/8” Primary cement job - Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol at 3.7-4 bpm, release bottom pump down plug for bottom plug, chase with 15.3 ppg Versacem Tail Cement Type I/II, pump total of 197 bbls at 4 bpm, release top pump down plug, chase with 20 bbls of water from Halliburton. Perform displacement with rig pumps, displace with 11.8 ppg OBM at 4 bpm, ICP 395 psi 8% flow, FCP 596 psi, 2% return flow, reduce rate to 3 bpm prior to plug bump: Final circulating pressure 596 psi. pressured up 500 psi over FCP 1,080 psi. Held 5 min, bled off checked floats. Floats held. CIP @ 12:45 hrs. - Total losses from cement exit shoe to cement in place: 43 bbls. Cement Evaluation Results: TOC was found to be 911’ above the Top of the Nanushuk Pool (11,166’ MD) at 10,255’ MD. Cement isolation from the TOC down to the casing shoe was found to be in good quality ranging down to partial coverage in limited areas based on LWD sonic interpretation. Attachment 12: Managed Pressure Drilling Managed Pressure Drilling (MPD) will be implemented on NDBi-049 in both the Intermediate and Production sections of the well. The MPD system will be provided by Beyond Energy Services and Technology with an integrated piping and choke manifold on the Parker 272 rig. The only MPD equipment located outside of the rig will be the nitrogen rack. The plan in the 12-1/4” Intermediate hole will be to drill with a conventional 11.0 - 12.0ppg mud weight and utilize MPD to trap back-pressure on connections and minimize pressure swings on the formation. Using conventional mud weights will allow for all tripping and liner running operations to be done without MPD or performing any fluid swaps, if desired. The plan in the 8-1/2” Production hole will be to drill with a reduced 9.0 – 10.0ppg mud weight with MPD utilized to trap back-pressure in order to manage ECD for losses as well as providing adequate pressures to maintain wellbore stability through the Nanushuk formations. Weighted trip fluids will be utilized to maintain downhole pressures for the final trip out and running of the 4-1/2” liner without MPD. See below for a schematic of the BOP/MPD stack with the choke flow diagram. AS BUILT CERTIFICATION 3230 "C" Street, Ste. 201 Anchorage, Alaska 99503 PHONE: (907) 272-5451 FAX : (907) 272-9065 http://www.LOUNSBURYINC.com Certificate of Authorization No. AECC391 DATE: SHEET: FIELD BOOK: DRAWING NAME: DRAWN: CHECKED: GRID: OF SCALE: NORTH SLOPE BOROUGH PROJECT LOCATION: STATE OF ALASKA PIKKA UNIT AS BUILT SURVEY WELL 49 ND-B PAD CONDUCTORS WITHIN SECTION 4, TOWNSHIP 11 NORTH, RANGE 6 EAST, UMIAT MERIDIAN VICINITY MAP N 1 Dewhurst, Andrew D (OGC) From:Conwell, Russell (Russell) <Russell.Conwell@santos.com> Sent:Thursday, 24 October, 2024 07:36 To:Dewhurst, Andrew D (OGC) Cc:McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC) Subject:RE: Pikka NDBi-049 Revised PTD (224-119): Questions Hi Andrew, Thanks for your note and I have provided answers below. Apologies for the corrections. Please let me know if you have any further questions or concerns. Russell Conwell Senior Drilling Engineer m: +1 907 615 2234| e: russell.conwell@santos.com From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, 23 October 2024 5:59 PM To: Conwell, Russell (Russell) <Russell.Conwell@santos.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: ![EXT]: Pikka NDBi-049 Revised PTD (224-119): Questions Russell, I am conducƟng my review of the revised NDBi-049 PTD and have a few quesƟons: x It appears that the SHL informaƟon on the direcƟonal plan Rev J0 and the as-built match, but the SHL informaƟon in SecƟon 2 (LocaƟon Summary) does not. Would you please conĮrm that the correct SHL coordinates (State Plane, Zone 4, NAD27) are as follows: o EasƟng: 421,795.71’ Should be 421,786.71 – this is correct in all references other than SecƟon 2 (LocaƟon summary) which does have a typo (424,786) o Northing: 5,972,663.37’ Correct in all locaƟons x It also appears that there is a discrepancy in the SHL for governmental secƟon coordinates. Again, the as-built looks right, but diīers from the informaƟon in SecƟon 2 (LocaƟon Summary). Would you please conĮrm that the correct locaƟon is: o 2,275’ FSL, 1,823’ FWL, Sec 4, T11N, R6E, UM I have conĮrmed that this is the correct locaƟon and should replace the incorrect locaƟon in secƟon 4a on page 2, and SecƟon 2 on page 5 of the PTD applicaƟon. x Would you conĮrm that there are no plans to pre-produce this well before injecƟon? No plans beyond normal Ňow-back for cleanup. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. NANUSHUK OILPIKKA 224-119 Pikka NDBi-049 WELL PERMIT CHECKLISTCompanyOil Search (Alaska), LLCWell Name:PIKKA NDBi-049Initial Class/TypeSER / PENDGeoArea890Unit11580On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2241190PIKKA, NANUSHUK OIL - 600100NA1 Permit fee attachedYes ADL392984, ADL391445, ADL393023, ADL323022, ADL323021ADL3929582 Lease number appropriateYes3 Unique well name and numberYes PIKKA, NANUSHUK OIL - 600100 - governed by CO 8074 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes AIO 4414 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYes15 All wells within 1/4 mile area of review identified (For service well only)Yes Short (2-3 day) well test as part of cleanup procuedures16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgNo Variance approved for 2-stage cement of 9-5/8" csg to cover all significant hydrocarbon zones with cement.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 1493 psi, BOP rated to 5000 psi (BOP test to 3600 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableYes34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S not anticipated; rig equiped with sensor and alarms35 Permit can be issued w/o hydrogen sulfide measuresYes Tuluvak (with shallow gas) pressures anticipated to be 10.2 ppg EMW. Nanushuk reservoir at 8.9 ppg EMW36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate10/24/2024ApprBJMDate10/24/2024ApprADDDate10/23/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 10/25/2024
