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223-051
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-043 50103208590000 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-043 Lithotrak Caliper data LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 PDF file NDBi-043 (50-103-20859-0000) NDBi-043A (20-103-20859-0100) Well clean up report Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@santos.com DATE: 12/5/2024 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/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: 223-051: T39833 223-052: T39834 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.06 08:20:13 -09'00' DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : GR - R E S - N E U - D E N - S o n i c , M u d l o g s , C B L Ye s Ye s Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 9/ 1 8 / 2 0 2 3 22 6 8 5 8 8 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 0 4 3 _ C A S T - CB L _ 1 6 A U G 2 3 _ P r o c e s s e d L o g . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 95 1 0 9 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ A P _ R 0 1 _ R M _ 2 0 2 3 0 7 1 3 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ A P _ R 0 2 _ R M _ 2 0 2 3 0 7 2 0 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ A P _ R 0 3 _ R M _ 2 0 2 3 0 7 2 5 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ A P _ R 0 4 _ R M _ 2 0 2 3 0 8 0 2 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 95 1 0 9 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D M D _ R M _ 1 0 9 4 7 f t . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D M T _ R 0 1 _ R M _ 2 0 2 3 0 7 1 3 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D M T _ R 0 2 _ R M _ 2 0 2 3 0 7 2 0 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D M T _ R 0 3 _ R M _ 2 0 2 3 0 7 2 5 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D M T _ R 0 4 _ R M _ 2 0 2 3 0 8 0 2 . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 25 0 0 6 0 8 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 0 8 0 f t _ S D T K _ M E M _ T O C. l a s 38 0 0 0 ED Di g i t a l D a t a Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 1 o f 8 ND B i - , 043 _ L W D _ R M _10 9 4 7ft. l as DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No DF 9/ 1 8 / 2 0 2 3 25 0 0 6 1 2 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 1 2 0 f t _ S D T K _ M E M _ C B L .l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 62 4 0 1 0 9 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 43 _ G 5 _ G E O I S O T O P E S _ C o r r e c t e d da t a _ 1 0 9 4 7 f t . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 12 9 1 0 9 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D r i l l G a s _ A S C I I _ d e p t h _ 1 0 9 4 7 f t . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 12 9 1 0 9 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ D r i l l G a s _ A S C I I _ d e p t h _ L i t h o l o g y _ 1 0 9 4 7 f t . l a s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 C o m p a s s S u r v e y Re p o r t s . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 N A D 2 7 C o m p a s s Su r v e y R e p o r t s . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 N A D 2 7 . t x t 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 W A S u r v e y Re p o r t s . x l s x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 . t x t 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 C o m p a s s S u r v e y Re p o r t s . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 N A D 2 7 C o m p a s s Su r v e y R e p o r t s . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 N A D 2 7 . t x t 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 W A S u r v e y Re p o r t s . x l s x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 . t x t 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : C a s t - M E v a l u a t i o n T a b l e . x l s x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ C A S T - CB L _ 1 6 A U G 2 3 _ D e t a i l e d A n a l y s i s . p p t x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ C A S T - CB L _ 1 6 A U G 2 3 _ P r o c e s s e d L o g . d l i s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ C A S T - CB L _ 1 6 A U G 2 3 _ P r o c e s s e d L o g . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ C A S T - CB L _ 1 6 A U G 2 3 _ P r o c e s s e d L o g . t i f 38 0 0 0 ED Di g i t a l D a t a Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 2 o f 8 ND B i - , 043 _ D r i l l G a s _ A S C I I _ d e p t h _ 1 0 9 4 7 f t . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : S a n t o s - N D B I 0 4 3 - 9 . 6 2 5 G S G Li n e r C e m e n t - 2 7 J u l y 2 0 2 3 . d o c x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K . d l i s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ D T C .m e t a 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ D T C .P D F 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ D T C _D T S . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ D T C _D T S . m e t a 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ D T C _D T S . P D F 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ W I D EB E D . m e t a 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 2 _ 2 4 5 0 f t _ 6 2 4 0 f t _ 5 M D _ S D T K _ W I D EB E D . P D F 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 0 8 0 f t _ S D T K _ M E M _ T O C. c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 0 8 0 f t _ S D T K _ M E M _ T O C. d l i s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 0 8 0 f t _ S D T K _ M E M _ T O C. m e t a 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 0 8 0 f t _ S D T K _ M E M _ T O C. P D F 38 0 0 0 ED Di g i t a l D a t a Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 3 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 0 8 0 f t _ S D T K _ M E M _ T O C_ d l i s . t x t 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 1 2 0 f t _ S D T K _ M E M _ C B L .c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 1 2 0 f t _ S D T K _ M E M _ C B L .d l i s 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 1 2 0 f t _ S D T K _ M E M _ C B L .m e t a 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 1 2 0 f t _ S D T K _ M E M _ C B L .P D F 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R 0 4 _ 2 5 0 0 f t _ 6 1 2 0 f t _ S D T K _ M E M _ C B L _d l i s . t x t 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ A P _ R M _ 2 0 2 3 0 8 0 2 . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ D M D _ R M _ 1 0 9 4 7 f t . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ D M T _ R M _ 2 0 2 3 0 8 0 2 . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 2 M D . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 2 T V D . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 5 M D . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 5 T V D . c g m 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : p a n e l s _ k e l t o . p n d 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ A P _ R M _ 2 0 2 3 0 8 0 2 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ D M D _ R M _ 1 0 9 4 7 f t . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ D M T _ R M _ 2 0 2 3 0 8 0 2 . p d f 38 0 0 0 ED Di g i t a l D a t a Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 4 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 2 M D . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 2 T V D . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 5 M D . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ R M _ 1 0 9 4 7 f t _ 5 T V D . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 a n d B D B i - 0 4 3 A Mu d l o g g i n g F i n a l R e p o r t . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 a n d N D B i - 0 4 3 A Mu d l o g g i n g F i n a l R e p o r t . d o c x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : Mu d l o g g i n g D a i l y R e p o r t s _ C o m p i l a t i o n _ N D B i - 04 3 _ N D B i - 0 4 3 A . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ G a s R a t i o L o g _ 1 0 9 4 7 ft _ M D _ 2 i n . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ G a s R a t i o L o g _ 1 0 9 4 7 ft _ M D _ 5 i n . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ L i t h o l o g y . x l s x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ M u d L o g _ 1 0 9 4 7 ft _ M D _ 2 i n . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ M u d L o g _ 1 0 9 4 7 ft _ M D _ 5 i n . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 1 2 8 8 0 - 30 4 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 0 9 5 8 0 - 96 2 8 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 1 9 7 2 0 - 97 5 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 2 9 8 8 0 - 99 3 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 5 10 4 5 0 - 1 0 5 0 5 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 6 10 5 4 5 - 1 0 5 9 5 . p d f 38 0 0 0 ED Di g i t a l D a t a Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 5 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 7 10 6 6 0 - 1 0 7 8 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 8 10 9 7 0 - 1 1 0 7 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 1 9 11 1 1 5 - 1 1 2 0 5 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 2 5 2 3 0 - 53 2 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 0 11 3 1 6 - 1 1 3 7 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 1 11 5 2 7 - 1 1 5 9 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 2 11 6 3 0 - 1 1 6 6 5 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 3 11 7 1 5 - 1 1 7 5 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 4 12 0 1 0 - 1 2 1 8 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 5 12 2 3 0 - 1 2 3 3 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 6 12 3 7 0 - 1 2 6 6 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 7 12 7 6 0 - 1 2 8 4 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 8 12 8 6 0 - 1 2 9 6 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 2 9 13 1 2 0 - 1 3 1 8 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 3 5 3 8 0 - 54 7 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 4 8 2 8 0 - 84 4 3 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 5 8 4 7 7 - 85 6 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 6 8 5 6 0 - 87 8 0 . p d f 38 0 0 0 ED Di g i t a l D a t a Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 6 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 7 8 8 8 0 - 90 2 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w r e p o r t # 8 9 0 2 0 - 91 3 8 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 S h o w R e p o r t # 9 9 1 9 0 - 92 5 0 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : N D B i - 0 4 3 _ G a s R p t _ F i n a l . x l s x 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : F o r m a t i o n _ T o p s _ T a b l e _ N D B i - 04 3 . p d f 38 0 0 0 ED Di g i t a l D a t a DF 9/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : W e l l s i t e G e o l o g i s t F W R N D B i - 04 3 & N D B i - 0 4 3 A . p d f 38 0 0 0 ED Di g i t a l D a t a DF 2/ 2 3 / 2 0 2 4 12 0 1 0 9 4 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : N D B i - 04 3 _ L W D _ G R _ R e s _ D e n s _ N e u _ C a l _ A z i R e s _ D e ep A z i R e s _ 1 0 9 4 7 . l a s 38 5 3 2 ED Di g i t a l D a t a DF 3/ 2 0 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ G R _ R e s _ D e n _ N e u _ C a l _ D e e p A z i R e s _R M _ 1 0 9 4 7 f t _ 2 M D . c g m 38 5 3 2 ED Di g i t a l D a t a DF 3/ 2 0 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ G R _ R e s _ D e n _ N e u _ C a l _ D e e p A z i R e s _R M _ 1 0 9 4 7 f t _ 2 T V D . c g m 38 5 3 2 ED Di g i t a l D a t a DF 3/ 2 0 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ G R _ R e s _ D e n _ N e u _ C a l _ D e e p A z i R e s _R M _ 1 0 9 4 7 f t _ 2 M D . p d f 38 5 3 2 ED Di g i t a l D a t a DF 3/ 2 0 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 3 _ L W D _ G R _ R e s _ D e n _ N e u _ C a l _ D e e p A z i R e s _R M _ 1 0 9 4 7 f t _ 2 T V D . p d f 38 5 3 2 ED Di g i t a l D a t a 8/ 1 7 / 2 0 2 3 12 8 1 0 9 4 7 61 8 5 5 Cu t t i n g s Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 7 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 9 - 0 0 - 0 0 We l l N a m e / N o . PI K K A N D B i - 0 4 3 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 8/ 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 5 1 0 Op e r a t o r Oi l S e a r c h ( A l a s k a ) , L L C MD 10 9 4 7 TV D 40 4 9 Cu r r e n t S t a t u s P& A 5/ 2 0 / 2 0 2 4 UI C No Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 8/ 1 / 2 0 2 3 Re l e a s e D a t e : 6/ 3 0 / 2 0 2 3 Mo n d a y , M a y 2 0 , 2 0 2 4 AO G C C P a g e 8 o f 8 M. G u h l 5/ 2 0 / 2 0 2 4 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 4 files NDBi-043 (50-103-20859-0000) جؐؐؐCGM ؒ NDBi-043_LWD_GR_Res_Den_Neu_Cal_DeepAziRes_RM_10947ft_2MD.cgm ؒ NDBi-043_LWD_GR_Res_Den_Neu_Cal_DeepAziRes_RM_10947ft_2TVD.cgm ؒ ؤؐؐؐPDF NDBi-043_LWD_GR_Res_Den_Neu_Cal_DeepAziRes_RM_10947ft_2MD.pdf NDBi-043_LWD_GR_Res_Den_Neu_Cal_DeepAziRes_RM_10947ft_2TVD.pdf 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: 3/19/2024 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Kayla Junke 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: 223-051: T38532 additional Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.20 16:05:50 -08'00' LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDBi-043 (50-103-20859-0000) NDBi-043A (20-103-20859-0100) NDBi-043_LWD_GR_Res_Dens_Neu_Cal_AziRes_DeepAziRes_10947.las NDBi-043A_LWD_GR_Res_Dens_Neu_Cal_AziRes_13210.las 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: 2/23/2024 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Kayla Junke 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: NDBi-043 PTD: 223-051 T38532 NDBi-043A PTD: 223-052 T38533 2/23/2024 NDBi-043 (50-103-20859-0000) NDBi-043_LWD_GR_Res_Dens_Neu_Cal_AziRes_DeepAziRes_10947.las Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.23 14:44:44 -09'00' LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDBi-043 (50-103-20859-0000) NDBi-043A (20-103-20859-0100) Final well data submittal – details on following pages Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@santos.com DATE: 9/14/2023 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Kayla Junke 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: 9/18/2023 NDBi-043 PTD: 223-051 T38000 NDBi-043A PTD:223-052 T38001 NDBi-043 (50-103-20859-0000) Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.18 15:46:39 -08'00' LETTER OF TRANSMITTAL NDBi-043 (50-103-20859-0000) جؐؐؐAnalyses ؒ NO_DATA.docx ؒ جؐؐؐCore Data - Conventional Core and Sidewall Cores Lab Studies ؒ NO_DATA.docx ؒ جؐؐؐDirectional Survey ؒ NDBi-043 Compass Survey Reports.pdf ؒ NDBi-043 NAD27 Compass Survey Reports.pdf ؒ NDBi-043 NAD27.txt ؒ NDBi-043 WA Survey Reports.xlsx ؒ NDBi-043.txt ؒ جؐؐؐLog Digital Data (LWD and WL) ؒ جؐؐؐCement Evaluation Logs ؒ ؒ Cast-M Evaluation Table.xlsx ؒ ؒ NDBi-043_CAST-CBL_16AUG23_DetailedAnalysis.pptx ؒ ؒ NDBi-043_CAST-CBL_16AUG23_ProcessedLog.dlis ؒ ؒ NDBi-043_CAST-CBL_16AUG23_ProcessedLog.las ؒ ؒ NDBi-043_CAST-CBL_16AUG23_ProcessedLog.pdf ؒ ؒ NDBi-043_CAST-CBL_16AUG23_ProcessedLog.tif ؒ ؒ Santos-NDBI 043-9.625 GSG Liner Cement-27 July 2023.docx ؒ ؒ ؒ ؤؐؐؐLWD ؒ جؐؐؐDigital Data ؒ ؒ جؐؐؐLWD ؒ ؒ ؒ NDBi-043_LWD_RM_10947ft.las ؒ ؒ ؒ ؒ ؒ جؐؐؐPWD ؒ ؒ ؒ NDBi-043_AP_R01_RM_20230713.las ؒ ؒ ؒ NDBi-043_AP_R02_RM_20230720.las ؒ ؒ ؒ NDBi-043_AP_R03_RM_20230725.las ؒ ؒ ؒ NDBi-043_AP_R04_RM_20230802.las ؒ ؒ ؒ ؒ ؒ ؤؐؐؐVSS ؒ ؒ NDBi-043_DMD_RM_10947ft.las ؒ ؒ NDBi-043_DMT_R01_RM_20230713.las ؒ ؒ NDBi-043_DMT_R02_RM_20230720.las ؒ ؒ NDBi-043_DMT_R03_RM_20230725.las ؒ ؒ NDBi-043_DMT_R04_RM_20230802.las ؒ ؒ ؒ جؐؐؐGeoscience Deliverables ؒ ؒ جؐؐؐRun 2 ؒ ؒ ؒ ؤؐؐؐSoundTrak - Acoustic ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK.dlis PTD: 223-051 T38000 LETTER OF TRANSMITTAL ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_DTC.meta ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_DTC.PDF ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_DTC_DTS.cgm ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_DTC_DTS.meta ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_DTC_DTS.PDF ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_WIDEBED.meta ؒ ؒ ؒ NDBi-043_LWD_R02_2450ft_6240ft_5MD_SDTK_WIDEBED.PDF ؒ ؒ ؒ ؒ ؒ ؤؐؐؐRun 4 ؒ ؒ ؤؐؐؐSoundTrak - Cement Evaluation ؒ ؒ NDBi-043_LWD_R04_2500ft_6080ft_SDTK_MEM_TOC.cgm ؒ ؒ NDBi-043_LWD_R04_2500ft_6080ft_SDTK_MEM_TOC.dlis ؒ ؒ NDBi-043_LWD_R04_2500ft_6080ft_SDTK_MEM_TOC.las ؒ ؒ NDBi-043_LWD_R04_2500ft_6080ft_SDTK_MEM_TOC.meta ؒ ؒ NDBi-043_LWD_R04_2500ft_6080ft_SDTK_MEM_TOC.PDF ؒ ؒ NDBi-043_LWD_R04_2500ft_6080ft_SDTK_MEM_TOC_dlis.txt ؒ ؒ NDBi-043_LWD_R04_2500ft_6120ft_SDTK_MEM_CBL.cgm ؒ ؒ NDBi-043_LWD_R04_2500ft_6120ft_SDTK_MEM_CBL.dlis ؒ ؒ NDBi-043_LWD_R04_2500ft_6120ft_SDTK_MEM_CBL.las ؒ ؒ NDBi-043_LWD_R04_2500ft_6120ft_SDTK_MEM_CBL.meta ؒ ؒ NDBi-043_LWD_R04_2500ft_6120ft_SDTK_MEM_CBL.PDF ؒ ؒ NDBi-043_LWD_R04_2500ft_6120ft_SDTK_MEM_CBL_dlis.txt ؒ ؒ ؒ ؤؐؐؐGraphics Images ؒ جؐؐؐCGM ؒ ؒ NDBi-043_AP_RM_20230802.cgm ؒ ؒ NDBi-043_DMD_RM_10947ft.cgm ؒ ؒ NDBi-043_DMT_RM_20230802.cgm ؒ ؒ NDBi-043_LWD_RM_10947ft_2MD.cgm ؒ ؒ NDBi-043_LWD_RM_10947ft_2TVD.cgm ؒ ؒ NDBi-043_LWD_RM_10947ft_5MD.cgm ؒ ؒ NDBi-043_LWD_RM_10947ft_5TVD.cgm ؒ ؒ panels_kelto.pnd ؒ ؒ ؒ ؤؐؐؐPDF ؒ NDBi-043_AP_RM_20230802.pdf ؒ NDBi-043_DMD_RM_10947ft.pdf ؒ NDBi-043_DMT_RM_20230802.pdf ؒ NDBi-043_LWD_RM_10947ft_2MD.pdf ؒ NDBi-043_LWD_RM_10947ft_2TVD.pdf ؒ NDBi-043_LWD_RM_10947ft_5MD.pdf ؒ NDBi-043_LWD_RM_10947ft_5TVD.pdf ؒ جؐؐؐMudlog ؒ جؐؐؐEOW ؒ ؒ NDBi-043 and BDBi-043A Mudlogging Final Report.pdf ؒ ؒ NDBi-043 and NDBi-043A Mudlogging Final Report.docx LETTER OF TRANSMITTAL ؒ ؒ ؒ جؐؐؐMudlogging Daily Reports ؒ ؒ MudloggingDailyReports_Compilation_NDBi-043_NDBi-043A.pdf ؒ ؒ ؒ جؐؐؐMudlogging final data ؒ ؒ ND Bi-43_G5_GEOISOTOPES_Corrected data_10947ft.las ؒ ؒ NDBi-043_DrillGas_ASCII_depth_10947ft.las ؒ ؒ NDBi-043_DrillGas_ASCII_depth_Lithology_10947ft.las ؒ ؒ NDBi-043_GasRatioLog_10947 ft_MD_2in.pdf ؒ ؒ NDBi-043_GasRatioLog_10947 ft_MD_5in.pdf ؒ ؒ NDBi-043_Lithology.xlsx ؒ ؒ NDBi-043_MudLog_10947 ft_MD_2in.pdf ؒ ؒ NDBi-043_MudLog_10947 ft_MD_5in.pdf ؒ ؒ ؒ ؤؐؐؐOil, Gas and Gas Hydrate Shows List ؒ NDBi-043 Show report #1 2880-3040.pdf ؒ NDBi-043 Show Report #10 9580-9628.pdf ؒ NDBi-043 Show Report #11 9720-9750.pdf ؒ NDBi-043 Show Report #12 9880-9930.pdf ؒ NDBi-043 Show Report #15 10450-10505.pdf ؒ NDBi-043 Show Report #16 10545-10595.pdf ؒ NDBi-043 Show Report #17 10660-10780.pdf ؒ NDBi-043 Show Report #18 10970-11070.pdf ؒ NDBi-043 Show Report #19 11115-11205.pdf ؒ NDBi-043 Show report #2 5230-5320.pdf ؒ NDBi-043 Show Report #20 11316-11370.pdf ؒ NDBi-043 Show Report #21 11527-11590.pdf ؒ NDBi-043 Show Report #22 11630-11665.pdf ؒ NDBi-043 Show Report #23 11715-11750.pdf ؒ NDBi-043 Show Report #24 12010-12180.pdf ؒ NDBi-043 Show Report #25 12230-12330.pdf ؒ NDBi-043 Show Report #26 12370-12660.pdf ؒ NDBi-043 Show Report #27 12760-12840.pdf ؒ NDBi-043 Show Report #28 12860-12960.pdf ؒ NDBi-043 Show Report #29 13120-13180.pdf ؒ NDBi-043 Show report #3 5380-5470.pdf ؒ NDBi-043 Show report #4 8280-8443.pdf ؒ NDBi-043 Show report #5 8477-8560.pdf ؒ NDBi-043 Show report #6 8560-8780.pdf ؒ NDBi-043 Show report #7 8880-9020.pdf ؒ NDBi-043 Show report #8 9020-9138.pdf ؒ NDBi-043 Show Report #9 9190-9250.pdf ؒ NDBi-043_GasRpt_Final.xlsx ؒ ؤؐؐؐWellsite Geologist Formation_Tops_Table_NDBi-043.pdf Wellsite Geologist FWR NDBi-043 & NDBi-043A.pdf 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: 50-103-20859-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 2308 FSL, 3342 FEL, S4, T11N, R6E, UM Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): N/A GL: 22.80 BF: 46.62 Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 832.6 FSL, 3850 FEL, S32, T12N, R6E, UM 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- N/A 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, Mudlogs, CBL 23. BOTTOM 20"x34" X-65 58' 13-3/8" L-80 2241' 9-5/8" L-80 4319' 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, TUBING RECORD See attached Int Cement Rpt12-1/4" N/A 07/11/23 10,947'MD/ 4,049' TVD 69.42 900 E Benson Boulevard, Anchorage, AK 99508 421,902.72 5,972,694.41 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil Search Alaska, LLC WAG Gas 08/01/23 223-051 CASING WT. PER FT.GRADE 08/01/23 CEMENTING RECORD N/A 1,411' MD / 1,390'TVD SETTING DEPTH TVD 5,976,561.49 TOP HOLE SIZE AMOUNT PULLED N/A 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. NDBi-043 LONS 19-003 N/A BOTTOM SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 42" 16" Grouted to Surface Surface See attached Surf Cement Rpt Surface 2502'Surface Surface 47# 2127' 215# 68# 128' 2332' 6237' Flow Tubing Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Pikka/Nanushuk Oil Pool N/A Oil-Bbl: Water-Bbl: ADL 392984, ADL 391445, ADL 393020 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 Grace Christianson at 8:23 am, Sep 14, 2023 Abandoned 8/1/2023 JSB RBDMS JSB 100323 G 2307 FSL 1938 FWL on the surveyor's plat SFD SFD 11/8/2023BJM 10/25/23 DSR-10/13/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1411' 1390' Top of Productive Interval N/A N/A 1037' 1033' 1155' 1148' 1411' 1390' 1799' 1735' 2354' 2142' 2805' 2449' 2894' 2510' 3780' 3121' Nanushuk 4955' 3866' NT8 MFS 4992' 3885' NT7 MFS 5026' 3903' NT6 MFS 5191' 3985' NT5 MFS 5292' 4032' NT4 MFS 5465' 4106' NT3 MFS 6387' 4338' NT3.2 Top Reservoir 6830' 4351' 31. List of Attachments: Summary of Daily Operations, Cement Reports, Definitive Surveys, Wellbore Schematic, As Built Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jacob Thompson Digital Signature with Date:Contact Email:jacob.thompson@santos.com Contact Phone: 907-854-4377 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: MCU Tuluvak Shale 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 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. Seabee Base Permafrost Transition Middle Schrader Bluff 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. Tuluvak Sand TPI (Top of Producing Interval). Authorized Name and Upper Schrader Bluff Base Ice Bearing Permafrost Formation Name at TD: INSTRUCTIONS 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. 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. N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov e foregoing is true and correct to the best of m : rilling Engineer 9/14/23 NDBi-043 Well Schematic 20" Insulated Conductor80' MD 9-5/8" Liner Hanger and Liner Top Packer2331' MD 13-3/8" 68 ppf L-80 Surface Casing2502' MD 9-5/8", 47ppf L-80 Production Liner6237' MD 4-½”, 12.6ppf P-110S Production Liner13207' MD Plug Back TD10947' MDKOP10136' MD 4-½” Liner Hanger/Top Packer6071' MD GL 46.6' RKB – Bottom Flange 08/19/2023 #CompletionItem Depth(MD') Depth(TVD') Inc ID" OD" 1XLandingNipple 1431 1408 23 3.813 4.773 2GLMw/1.5"Pocket 1486 1458 24 3.958 7.575 3XLandingNipple 1550 1516 26 3.813 4.773 4XLandingNipple 5938 4262 75 3.813 4.773 5P/TD.H.Gauge 5993 4275 77 3.958 5.500 6XLandingNipple 6008 4279 77 3.813 4.773 7TiebackSealAssy 6104 4298 79 3.890 5.280 8 9.625"x4.5"LH/Packer 6071 4292 78 6.040 8.430 9#13OpenholePacker 6757 4355 91 3.918 8.000 10 Stage11ͲFracSleeve 6980 4350 91 3.735 5.627 11 #12OpenholePacker 7244 4344 91 3.918 8.000 12 Stage10ͲFracSleeve 7465 4340 91 3.735 5.627 13 #11OpenholePacker 7728 4334 91 3.918 8.000 14 Stage9ͲFracSleeve 8075 4326 91 3.735 5.627 15 #10OpenholePacker 8378 4320 91 3.918 8.000 16 Stage8ͲFracSleeve 8602 4315 91 3.735 5.627 17 #9OpenholePacker 8864 4309 91 3.918 8.000 18 Stage7ͲFracSleeve 9130 4304 91 3.735 5.627 19 #8OpenholePacker 9351 4299 91 3.918 8.000 20 Stage6ͲFracSleeve 9658 4292 91 3.735 5.627 21 #7OpenholePacker 9879 4287 91 3.918 8.000 22 #6OpenholePacker 10351 4277 91 3.918 8.000 23 Stage5ͲFracSleeve 10823 4267 91 3.735 5.627 24 #5OpenholePacker 11085 4261 91 3.918 8.000 25 Stage4ͲFracSleeve 11351 4256 91 3.735 5.627 26 #4OpenholePacker 11655 4249 91 3.918 8.000 27 Stage3ͲFracSleeve 11839 4245 91 3.735 5.627 28 #3OpenholePacker 12101 4239 91 3.918 8.000 29 Stage2ͲFracSleeve 12325 4234 91 3.735 5.627 30 #2OpenholePacker 12587 4229 91 3.918 8.000 31 Stage1ͲFracSleeve 12851 4223 91 3.735 5.627 32 #1OpenholePacker 13073 4218 91 3.918 8.000 33 #2ToeSleeve 13133 4217 91 3.500 5.875 34 #1ToeSleeve 13141 4217 91 3.500 5.875 35 WIVCollar 13196 4216 91 5.620 36 Eccentricshoe 13205 4215 91 3.930 5.220 1 2 3 4 5 6 7 8 9 r¢Ď Ď @GĎ ÕËĎ Ď Ď hĎ Ď ;Ď ÙþĎ <VĎ öĎ 5Ď Ď y ''4Ď Ď Ď Ď Ď "PĎ Ď i]$Ď 1á,Ď Ď äĎ ¸ Ď _ Ď 8Ď / Ď Ď °Ď m CĎ Ď Ď K Ď ^!Ď Ď mCĎ Ď åĎ Ď ßHĎ o Ď Ď ã8kĎ *ÌĎ ć h|Ď !Ď Ď 8Ď U }Ď Ď Ď o Ď Ď OĎ /Ď Ď ) ÿĎ ! 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Finish breaking lines & separating rig modules. L/D rig mats from DW-02 to NDBi-043. Mobilize mud module & drilling module to side of location so utility module could mobilize into position at well. Mobilize drilling module into position over well. 7/10/2023 7/11/2023 0 10.50 No accidents, incidents or spills. Finish moving rig modules over new well. R/U interconnect lines, communications & power supply. Raise derrick, skid rig floor in place. Prep rig floor & pipeshed for drilling operations. R/U mud lines & flow lines. Prep mud pits & bring on spud mud. Dress mud pumps with 6" liners & swabs. N/U diverter system, install speed head on conductor, install HP surface risers, diverter tee & surface annular. Change out saver sub to Delta 576. Strap, talley & M/U stands of 5-7/8" DP. Load, strap & talley 13-3/8" casing into pipeshed. 7/11/2023 7/12/2023 128 85.00 10.60 No accidents, incidents or spills. Finish N/U diverter, knife valve & bell nipple. Conduct diverter/knife valve test, test witness waived by AOGCC rep Adam Earl. Finish prepping 13-3/8" casing in pipeshed. R/U 5-7/8" handling tools. M/U stands of 5-7/8" DP & 5-7/8" HWDP. Tested gas alarms. Slip & cut drill line. Pressure tested surface lines, no leaks. P/U & M/U 16" Surface BHA. RIH & tag bottom at 128' MD. Service Rig. Drill 16" Surface hole section from 128' MD to 213' MD. 7/12/2023 7/13/2023 213 817.00 10.50 No accidents, incidents or spills. Drill 16” Surface hole from 213’ MD to 540’ MD. Circulate hole clean. Drop Gyro. POOH from 540' to retrieve Gyro. RIH. Drill 16” Surface hole from 540’ MD to 1030’ MD. Circulate & condition mud at 1030'. POOH to 128' MD, due to blower motor failure on mud pump #2. Replace blower motor. RIH from 128' MD to 390' MD, tagged bridge at 360' MD with 15k P/U, no over pull, rotated pipe 180° & run though with no issues. Continue RIH. 7/13/2023 7/14/2023 1,030 1,482.00 10.50 No accidents, incidents or spills. RIH from 390' MD to 1030' MD. Drill 16” Surface hole from 1030’ MD to 2137’ MD. Service Rig. Continue drilling 16” Surface hole from 2137’ MD to TD at 2512’ MD. Circulate bottoms up 4 times while reciprocating pipe 216 ft/min from 2512' MD to 2160' MD. 7/14/2023 7/15/2023 2,512 0.00 10.50 No accidents, incidents or spills. Backream out of hole from 2160' MD to 261' MD. Pump out of hole from 261' MD to 120' MD. Circulate inside Conductor. Flow check - Static, RIH from 120' to 1047' MD. Tight spot at 1047' MD. Circulate bottoms up at 1047' MD. Wash & ream from 1047' MD to 1871' MD. Circulate bottoms up at 1871' MD. RIH from 1871' MD to 2444' MD on elevators. Wash to bottom from 2444' MD to 2512' MD. Circulate & condition mud at 2512' MD. Check flow - Static. POOH on elevators from 2512' MD to 2350' MD, tight spot with 30k overpull at 2350' MD. Slack off below tight spot - no-go. M/U to top drive, rotate pipe 180°, pulled tight again. Backream out of hole from 2350' MD to 1687' MD. 7/15/2023 7/16/2023 2,512 0.00 10.50 No accidents, incidents or spills. Backream out of hole from 1687' MD to 871' MD. POOH on elevators from 871' to 162' MD. L/D 16" Surface BHA. Clean & clear rig floor. R/U TESCO casing equip. M/U landing assembly & hanger for dummy run. RIH with 13-3/8” Surface casing to 1666' MD. 7/16/2023 7/17/2023 2,512 0.00 10.50 No accidents, incidents or spills. Run in hole with 13-3/8" 68#, L-80 Surface casing from 1666' MD to 2502’ MD. P/U & M/U 13- 3/8" fluted hanger. Condition mud for cement job. Pumped 80 bbls of 10.7 ppg Spacer. Shut down, drop bottom plug. Pump 477 bbls of 11.0 ppg Lead cement. Pump 68 bbls of 15.3 ppg Tail cement. Shut down, drop top plug. Pump 10 bbls of H20. Shut down, swap to rig pumps. Displace at 3 bpm. Bump second plug at 3420 strokes, 344 bbls. 70 bbls contaminated cement and 70 bbls of good cement back. Observed FCP at 3 bpm with 420 psi. Held 920 psi for 5 mins, bled off pressure & check floats; floats held. Cement in place at 12:45 hrs. R/D TESCO casing equip. Flush stack, N/D diverter, annular, knife valve & riser pipe. N/U tubing spool on wellhead. Cleaning pits. Note: Submitted 24 hr. notice to AOGCC to test BOP at 06:00 on 7-16-23. 7/17/2023 7/18/2023 2,512 0.00 10.50 No accidents, incidents or spills. Finish N/U 13-3/8" BOPE. R/U to test. Test 13-3/8" BOPE to 250/3000 psi with 4-1/2" & 5-7/8" for 5 minutes on chart - Good Test. Test witness waived by AOGCC rep Brian Bixby at 08:47 hrs on 7/16/23. R/D BOP test equip, pull test plug. Set wear ring. R/U & test 13-3/8" Surface casing to 3000 psi for 30 minutes on chart - Good Test. Well Name Wellbore Name PTD # Start Drill Date End Drill Date Page 1 of 3 Well Name NDBi-043 Wellbore Name Original Hole PTD # 223-051 Start Drill Date 6/23/2022 End Drill Date 8/2/2023 ,p Run in hole with 13-3/8" 68#, L-80 Surface casing f py qp,p test 13-3/8" Surface casing to 3000 psi for 30 minutes on chart n mud for cement job. Pumped 80 bbls of 10.7 ppg Spacer. Shut ,g gjpppgp down, drop bottom plug. Pump 477 bbls of 11.0 ppg Lead cement. Pump 68 bbls of 15.3 ppg Tail,p pg p ppg p cement. Shut down, drop top plug. Pump 10 bbls of H20. Shut down, swap to rig pumps.,pppg p , p gpp Displace at 3 bpm. Bump second plug at 3420 strokes, 344 bbls. 70 bbls contaminated cementppp and 70 bbls of good cement back. Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 7/18/2023 7/19/2023 2,512 519.00 11.05 No accidents, incidents or spills. R/D BOP test equip. R/U & P/U 12-1/4" Intermediate Hole section BHA. RIH to 1268' MD, shallow test MWD - good test. RIH to 2411' MD to 2532' MD. Displace 10.5 ppg spud mud with 11.0 ppg MOBM. Drill cement plugs & shoe track from 2,417’ MD to 2,502’ MD (2,240’ TVD). Cleaned rat hole from 2502' MD to 2512' MD. Drill 20' of new formation to 2532' MD. Circulate bottoms up twice. Perform LOT to 16.8 ppg EMW - good test. Service Rig. Drill 12-1/4” Intermediate hole from 2532’ MD to 3031’ MD (2605’ TVD). Note: Notified Jacob Thompson of LOT results. 7/19/2023 7/20/2023 3,031 1,775.00 11.00 No accidents, incidents or spills. Drill 12-1/4” Intermediate hole from 3031’ MD to 4806' MD. 7/20/2023 7/21/2023 4,806 1,434.00 11.00 No accidents, incidents or spills. Drill 12-1/4” Intermediate hole from 4806’ MD to 6240' MD. Circulate bottoms-up 4 times. Flow check well prior to POOH. 7/21/2023 7/22/2023 6,240 0.00 11.05 No accidents, incidents or spills. Attempt to POH on elevators per plan, difficulty with overpulls when picking up and stacking weight on movement down. Follow well plan for moving pipe without success. Consult with Engineer, decision is to Backream out. Backream from 5814' to 3735' at 900 gpm, avg circulation pressure of 1900 psi, vary rotation from 120-180 rpm and pulling speeds of 200-500 fph. 7/22/2023 7/23/2023 6,240 0.00 11.00 No accidents, incidents or spills. Continue to backream from 3735' MD to 3262' MD. Encounter pack off at 3262’ MD, after racking back stand #27. Rotate down 3 stands 40-80 rpm to 3480' MD attempt circulate 2 bpm pressure up to 580 psi. Pump 4 bpm 630 psi notice pressure release and stage to 900 gpm 1870 psi initial circulating pressure. Continue to backream from 3540' MD to 2,883' MD. Circulate and condition mud, CBU 5 times. Backream out of hole from 2,883’ MD to 2,788’ MD. Circulate and condition mud, CBU 5 times. Backream out of hole from 2,788’ MD to 2,218’ MD. POOH from 2218‘ MD to 800‘ MD with 5 7/8” DP. PU 124k, SO 112k. Monitor well 10 min prior to laying down BHA. Well static. 7/23/2023 7/24/2023 6,240 0.00 11.00 No accidents, incidents or spills. POH from 800‘ MD to surface with BHA. Pull Wear Ring, mobilize 9-5/8” test joint to rig floor, install and test 9-5/8” rams to 250 psi low / 3000 psi high 5 minutes each. Rig down test equipment. Rig up to run 9-5/8”, RIH with 9-5/8", 47# Hydril 563 casing per running tally using torque turn to 15.8k, fill the shoe track and check floats, floats held. Thread lock shoe track and pin of joint #4. RIH from surface to 2492’ MD. CBU 1 time staging pumps up to 10 bpm. Record weights before exiting shoe. Continue RIH with 9-5/8" 47# Hydril 563 casing from 2492' to 2785’ MD, tag up and unable to move past 2785'. Work pipe in attempt to move past bridge. 7/24/2023 7/25/2023 6,240 0.00 11.05 No accidents, incidents or spills. Continue to RIH with 9-5/8", 47# Hydril 563 csg from 2642', tag up at 2785'. Attempt to work through with pumps and rotation. No success. Monitor well 10 min. POOH laying down 9-5/8” casing joints from 2785' MD to surface. Cut 9-5/8" casing shoe track BAKERLOK joints and lay down from 115' MD to surface. Rig down casing running tools, change upper rams from 9-5/8" to 4.5" x 7" VBR. Pull wear ring, install test plug. Test upper 4.5" x 7" VBR. Pull test plug and install wear ring 12-5/8" ID. PJSM, stage equipment to MU 12.25" clean out BHA. 7/25/2023 7/26/2023 6,240 0.00 11.20 No accidents, incidents or spills. P/U 12.25" Cleanout BHA with MWD tools. RIH to 2495' MD, circulate bottoms up 1 time. RIH to 2785' and set down weight (same spot as previously worked). Work through with 650 gpm, 7-12k drag during PU, SO with pumps off took 10k down. Pick up working single and work stabilizer to dress at 2775' MD to 2800' MD. Ream from 2838' MD to 3197' MD. Run in on elevators from 3197' MD to 3670' MD. Ream occasional tight spots from 3,670' MD to 6,155'MD. Wash and ream down from 6,155' MD to 6,240' MD per plan. Circulate to add mud products and weight up active system from 11.0 ppg to 11.2 ppg. Flow check for 10 minutes, well static. POOH on elevators from 6,240‘ MD to 5883', 40k overpull at 5883'. Work pipe through tight area without rotation or circulation until back to normal PUW of 200k, SOW of 120k. Continue to POH on elevators to 3828'. 7/26/2023 7/27/2023 6,240 0.00 11.20 No accidents, incidents or spills. POH with 12.25" Cleanout BHA on elevators from 3800' MD to 829' MD, conduct flow check - well static. Lay down BHA. Change out Upper Rams from 4-1/2" x 7 VBR to 9-5/8" Fixed, test. Rig up to run casing. RIH with 9 5/8", 47#, Hydril 563 casing: MU Torque to 15,800 ft/lbs, run 1 centralizer per joint to include shoe track (total 95 run) from surface, to 2,480’ md. CBU @ 2,480‘md, stage pumps up from 2bpm, 96psi to 10bpm, 250psi. Continue RIH with 9 5/8", 47# Hydril 563 casing from 2,480' to 2931' at 30 fpm, no losses and no tight spots. Page 2 of 3 Perform LOT to 16.8 ppg EMW - good test. gpp RIH with 9 5/8", 47#, Hydril 563 casing: Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 7/27/2023 7/28/2023 6,240 0.00 11.25 No accidents, incidents or spills. Continue RIH with 9-5/8”, 47#, Hydril 563 Casing, from 2931’ to 3876’ MD. Circulate and stage up to 10 BPH. P/U Baker Liner Hanger as per Baker rep. Circulate liner volume. 412gpm, 465psi, reciprocate string 50'. Run 9-5/8”, 47#, Hydril 563 Casing, from 3950’ to 5624’ MD. PU 10' pup and TIH with 5-7/8" HWDP from 5624' MD to 6202' MD. M/U Baker Cement Swivel and cement hose as per Baker rep on top of 5 7/8" HWDP. Circulate and condition mud as per Mud Engineer. Stage pumps to 8 bpm. Cement 9-5/8” Intermediate liner. 7/28/2023 7/29/2023 6,240 0.00 9.20 No accidents, incidents or spills. Circulate bottoms up at 630gpm, 450psi 1-1/2 times, no cement to surface. Rig down Baker cement head. Drop wiper ball in string, circulate surface to surface no cement to surface. POOH with running BHA, break apart running tool per Baker and lay down. Change upper rams to 4-1/2 X 7 variables. Rig up BOP test equipment for full test. Test BOPE, all tests T/250PSI Low, 3000PSI High for 5 minutes charted with 4-1/2" X 5-7/8" test joints. Pull test plug and rig down testing equipment. Install wear ring. Blow down choke and kill lines, choke manifold, top drive. P/U 8-1/2" Production BHA as per Baker rep. plug-in upload tools. Load radioactive sources as per MWD. 7/29/2023 7/30/2023 6,240 89.00 9.20 No accidents, incidents or spills. Complete M/U 8.5" Drilling BHA as per Baker DD. RIH on 5" DP. Wash down from 6068'md to 6106'md, tag cement. Displace 11.2ppg VersaClean OBM to 9.2ppg VersaPro OBM. 30 minute negative pressure test. Good test. Well Control Drill at 10:30, followed by Rig Evacuation Drill, Man Down Drill and Rescue Drill. Conduct AAR on all drills. Test casing to 3,000 psi, 30 minutes on chart. Perform Well Kill Drill. Wash and ream from 6,068'md to 6,159'md. Tag top of plugs @ 6,159'. Drill out casing shoe from 6,159‘md to 6,238‘md. Drill 8.5” production hole from 6,240’md to 6,260’md (4319’ tvd). RU and perform LOT, Mud weight: 9.2 ppg, 6260’ md, 4319’tvd, Pump 4.2bbls to 1290psi, bleed back 4.2bbls. FIT EMW 15ppg. Drill 8.5” production hole from 6,260’md to 6349’md (4333’tvd). 7/30/2023 7/31/2023 6,349 1,491.00 9.25 No accidents, incidents or spills. Drill 8.5" Production hole from 6349’ MD to 7840' MD. 7/31/2023 8/1/2023 7,840 1,478.00 9.25 No accidents, incidents or spills. Drill ahead from 7840’ to 7861’. At 7861’, encounter increased circulation pressures / ECD even when varying rates, increased torque on rotary rpm, reduced flow rates out, reductions in Rot Wt and SOW, increase in PUW. MW consistent at 9.3 ppg. Work string from 7860' to 7774' to work wellbore clean. Circulate bottoms up from 7774' to 7800' at 300 gpm with initial returned flow from previous losses of ~5 bbls and then consistent returns. Move string back down cleanly to bottom. Increase flow to 600 GPM with initial 1 BPH losses and rotary to 160 GPM with erratic torque. Drill ahead from 7861' to 9318' md. 24 hour losses for the tour 0bbls. 8/1/2023 8/2/2023 9,318 1,629.00 9.20 No accidents, incidents or spills. Drill ahead in 8-1/2" Production Hole from 9318' md to TD PB1 at 10,947’ md after Geologist analyze formation data and call TD. Circulate an open hole annular volume off bottom before beginning Backream back to sidetrack initiation of 10,138’ md. Backream at 15 fpm from 10,947’ md to 10,799’ md. Page 3 of 3 Cement 9-5/8” Intermediate liner. , RU and perform,p ,,()p LOT, Mud weight: 9.2 ppg, 6260’ md, 4319’tvd, Pump 4.2bbls to 1290psi, bleed back 4.2bbls.,g FIT EMW 15ppg. This wellbore was plugged back and OH sidetrack performed per plan. Sidetracked to NDB-043A (PTD 223-052) -bjm yg , Test casing to 3,000 psi, 30 minutes on chart. Drill ahead in 8-1/2" Production Hole from 9318' md to TD PB1 at 10,947’ md ,g p 30 minute negative pressure test. Good test. Page 1 of 1 Well Name: NDBi-043 Cement Surface Casing Cement Surface Casing Cement, Casing, 7/16/2023 09:00 Type Casing Cementing Start Date 7/16/2023 Cementing End Date 7/16/2023 Wellbore Original Hole String Surface, 2,501.9ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement Evaluation Results Comment 1, 0.0-2,512.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 2,512.0 Full Return? Yes Vol Cement Ret (bbl) 140.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 6 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 5 Final Pump Pressure (psi) 420.0 Plug Bump Pressure (psi) 420.0 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 PRIME CEMENT SPACER SYSTEM Amount (sacks) 135 Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 0.0 Yield (ft³/sack) 3.32 Mix H20 Ratio (gal/sack) 21.92 Free Water (%) Density (lb/gal) 10.80 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Lead Fluid Type Lead Fluid Description SBM CEM ARCTICCEM BBL Amount (sacks) 1,050 Class Type I/II Volume Pumped (bbl) 477.0 Estimated Top (ftKB) 0.0 Estimated Bottom Depth (ftKB) 2,000.0 Percent Excess Pumped (%) 350.0 Yield (ft³/sack) 2.56 Mix H20 Ratio (gal/sack) 12.38 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 43.5 Thickening Time (hr) 10.10 1st Compressive Strength (psi) 402.5 Tail Fluid Type Tail Fluid Description SBM CEM HALCEM™ SYS Amount (sacks) 310 Class Type I/II Volume Pumped (bbl) 68.0 Estimated Top (ftKB) 2,000.0 Estimated Bottom Depth (ftKB) 2,512.0 Percent Excess Pumped (%) 40.0 Yield (ft³/sack) 1.25 Mix H20 Ratio (gal/sack) 5.66 Free Water (%) Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Displacement Fluid Type Displacement Fluid Description Fresh water Amount (sacks) Class Volume Pumped (bbl) 10.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Page 1 of 1 Well Name: NDBi-043 Cement Intermediate Casing Cement Intermediate Casing Cement, Casing, 7/27/2023 19:30 Type Casing Cementing Start Date 7/27/2023 Cementing End Date 7/27/2023 Wellbore Original Hole String Intermediate, 6,237.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement Evaluation Results Comment 1, 2,502.0-6,240.0ftKB Top Depth (ftKB) 2,502.0 Bottom Depth (ftKB) 6,240.0 Full Return? Yes Vol Cement Ret (bbl) 0.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 6 Final Pump Rate (bbl/min) 6 Avg Pump Rate (bbl/min) 6 Final Pump Pressure (psi) 340.0 Plug Bump Pressure (psi) 920.0 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 PRIME CEMENT SPACER SYSTEM Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 1.41 Mix H20 Ratio (gal/sack) 8.66 Free Water (%) Density (lb/gal) 11.80 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Lead Fluid Type Lead Fluid Description SBM CEM ARCTICCEM BBL Amount (sacks) 665 Class Volume Pumped (bbl) 277.0 Estimated Top (ftKB) 2,502.0 Estimated Bottom Depth (ftKB) 5,740.0 Percent Excess Pumped (%) Yield (ft³/sack) 2.35 Mix H20 Ratio (gal/sack) 13.94 Free Water (%) Density (lb/gal) 12.00 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Tail Fluid Type Tail Fluid Description SBM CEM HALCEM SYS Amount (sacks) 200 Class Volume Pumped (bbl) 44.0 Estimated Top (ftKB) 5,740.0 Estimated Bottom Depth (ftKB) 6,240.0 Percent Excess Pumped (%) Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 15.30 Free Water (%) Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Displacement Fluid Type Displacement Fluid Description FRESH WATER Amount (sacks) Class Volume Pumped (bbl) 331.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Santos Definitive Survey Report 11 September, 2023 Design: NDBi-043 Santos NAD27 Conversion Pikka NDB NDBi-043 NDBi-043 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Pikka, North Slope Alaska, United States Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: NDB usft Map usft usft °-0.59Slot Radius:"20 5,972,909.70 423,383.56 7.0 70° 20' 10.138 N 150° 37' 17.796 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: NDBi-043 usft usft 0.0 0.0 5,972,694.41 421,902.72 22.8Wellhead Elevation:0.0 usft0.5 70° 20' 7.870 N 150° 38' 0.979 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) NDBi-043 Model NameMagnetics BGGM2023 26/06/2023 14.64 80.60 57,193.31905544 Phase:Version: Audit Notes: Design NDBi-043 1.0 ACTUAL Vertical Section:Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:46.6 303.290.00.046.6 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 2 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 11/09/2023 SDI_KPR_ADK SDI Keeper ADK110.1 421.3 01 SDI_Gyro_16in Hole<46-421> (NDBi-04 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag464.2 2,436.0 02 BH OntraK_16in Hole <464-2436> (ND 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag2,530.2 6,199.2 03 BH OntraK_12.25in Hole <2530-6199> 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag6,282.2 10,916.8 04 BH AzitraK_8.5in Hole <6282-10917> ( MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 46.6 0.00 0.00 46.6 -22.8 0.0 0.0 5,972,694.41 421,902.72 0.00 0.0 110.1 0.08 27.55 110.1 40.7 0.0 0.0 5,972,694.45 421,902.74 0.13 0.0 127.0 0.08 50.47 127.0 57.6 0.1 0.0 5,972,694.47 421,902.76 0.18 0.0 20" Conductor Casing 138.2 0.08 65.48 138.2 68.8 0.1 0.0 5,972,694.47 421,902.77 0.18 0.0 232.6 0.12 56.09 232.6 163.2 0.1 0.2 5,972,694.56 421,902.91 0.05 -0.1 327.3 0.18 46.17 327.3 257.9 0.3 0.4 5,972,694.71 421,903.10 0.07 -0.1 421.3 0.22 95.20 421.3 351.9 0.4 0.7 5,972,694.79 421,903.39 0.18 -0.3 464.2 0.24 113.47 464.2 394.8 0.3 0.8 5,972,694.75 421,903.55 0.18 -0.5 559.3 1.73 153.11 559.3 489.9 -1.0 1.7 5,972,693.38 421,904.37 1.63 -1.9 661.3 5.76 153.19 661.1 591.7 -7.0 4.7 5,972,687.41 421,907.32 3.95 -7.7 764.8 7.41 168.33 763.9 694.5 -18.1 8.4 5,972,676.20 421,910.89 2.30 -16.9 857.1 9.51 184.34 855.2 785.8 -31.6 9.0 5,972,662.75 421,911.38 3.40 -24.8 890.1 10.89 191.88 887.6 818.2 -37.3 8.1 5,972,657.00 421,910.47 5.82 -27.3 920.6 12.11 197.97 917.6 848.2 -43.2 6.6 5,972,651.14 421,908.83 5.63 -29.2 948.7 13.09 203.88 945.0 875.6 -48.9 4.4 5,972,645.45 421,906.57 5.76 -30.5 981.0 13.73 210.89 976.4 907.0 -55.5 0.9 5,972,638.87 421,903.06 5.42 -31.3 1,011.1 14.37 213.19 1,005.6 936.2 -61.7 -3.0 5,972,632.71 421,899.11 2.82 -31.4 1,036.0 14.44 216.29 1,029.7 960.3 -66.8 -6.5 5,972,627.67 421,895.54 3.11 -31.3 Upper Schrader Bluff 1,042.3 14.46 217.07 1,035.8 966.4 -68.1 -7.4 5,972,626.41 421,894.58 3.11 -31.2 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 3 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 1,137.7 13.92 225.34 1,128.2 1,058.8 -85.6 -22.8 5,972,609.01 421,879.07 2.20 -28.0 1,154.0 14.13 225.96 1,144.1 1,074.7 -88.4 -25.6 5,972,606.28 421,876.21 1.58 -27.1 Base Ice Bearing Permafrost 1,233.4 15.17 228.75 1,220.9 1,151.5 -102.0 -40.4 5,972,592.85 421,861.29 1.58 -22.2 1,327.3 18.35 229.96 1,310.8 1,241.4 -119.6 -60.9 5,972,575.45 421,840.55 3.41 -14.7 1,410.0 20.83 230.70 1,388.7 1,319.3 -137.3 -82.3 5,972,557.98 421,819.02 3.02 -6.6 Base Permafrost Transition 1,421.6 21.18 230.79 1,399.6 1,330.2 -139.9 -85.5 5,972,555.38 421,815.77 3.02 -5.3 1,517.4 23.97 236.33 1,488.0 1,418.6 -161.7 -115.1 5,972,533.96 421,785.94 3.66 7.5 1,610.9 27.02 240.35 1,572.4 1,503.0 -182.7 -149.4 5,972,513.27 421,751.44 3.75 24.6 1,705.8 30.25 242.45 1,655.7 1,586.3 -204.4 -189.3 5,972,491.97 421,711.29 3.57 46.0 1,798.0 33.42 242.69 1,734.0 1,664.6 -226.8 -232.5 5,972,470.03 421,667.90 3.44 69.8 Middle Schrader Bluff 1,801.6 33.54 242.70 1,737.1 1,667.7 -227.8 -234.3 5,972,469.13 421,666.11 3.44 70.8 1,896.0 36.88 243.61 1,814.2 1,744.8 -252.3 -282.8 5,972,445.08 421,617.31 3.58 97.9 1,990.7 40.24 244.75 1,888.2 1,818.8 -278.0 -336.0 5,972,419.95 421,563.91 3.63 128.2 2,084.8 44.55 246.50 1,957.7 1,888.3 -304.1 -393.8 5,972,394.42 421,505.86 4.75 162.2 2,179.1 47.34 248.27 2,023.3 1,953.9 -330.2 -456.3 5,972,369.03 421,443.02 3.25 200.2 2,275.2 47.28 249.02 2,088.4 2,019.0 -355.9 -522.1 5,972,344.00 421,376.98 0.58 241.1 2,353.0 47.70 247.65 2,141.0 2,071.6 -377.1 -575.4 5,972,323.39 421,323.50 1.41 274.0 MCU (Post DW-02) 2,369.0 47.79 247.37 2,151.8 2,082.4 -381.6 -586.3 5,972,318.97 421,312.49 1.41 280.7 2,436.0 48.07 247.07 2,196.6 2,127.2 -400.9 -632.2 5,972,300.19 421,266.44 0.53 308.4 2,501.0 47.72 247.54 2,240.2 2,170.8 -419.5 -676.7 5,972,282.06 421,221.78 0.75 335.4 13-3/8" Surface Casing 2,530.2 47.57 247.75 2,259.9 2,190.5 -427.7 -696.6 5,972,274.06 421,201.74 0.75 347.6 2,556.9 46.82 247.01 2,278.0 2,208.6 -435.2 -714.7 5,972,266.71 421,183.56 3.46 358.6 2,651.6 46.34 247.41 2,343.1 2,273.7 -461.9 -778.1 5,972,240.73 421,119.89 0.59 396.9 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 4 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 2,747.3 46.30 247.18 2,409.2 2,339.8 -488.6 -841.9 5,972,214.70 421,055.81 0.18 435.6 2,804.0 46.38 246.79 2,448.3 2,378.9 -504.6 -879.7 5,972,199.05 421,017.87 0.52 458.4 Tuluvak Shale (Post DW-02) 2,842.3 46.44 246.52 2,474.7 2,405.3 -515.6 -905.2 5,972,188.32 420,992.30 0.52 473.7 2,893.0 46.39 246.64 2,509.7 2,440.3 -530.2 -938.9 5,972,174.08 420,958.44 0.20 493.8 Tuluvak Sand (Post DW-02) 2,937.4 46.35 246.75 2,540.3 2,470.9 -542.9 -968.4 5,972,161.67 420,928.80 0.20 511.5 3,030.8 46.38 245.55 2,604.8 2,535.4 -570.2 -1,030.2 5,972,135.00 420,866.72 0.93 548.2 3,125.6 46.40 245.66 2,670.2 2,600.8 -598.6 -1,092.7 5,972,107.30 420,803.92 0.09 584.9 3,225.1 46.45 245.70 2,738.8 2,669.4 -628.3 -1,158.4 5,972,078.30 420,737.93 0.06 623.5 3,313.8 46.37 245.40 2,799.9 2,730.5 -654.9 -1,216.9 5,972,052.32 420,679.18 0.26 657.8 3,409.7 46.45 245.42 2,866.0 2,796.6 -683.8 -1,280.1 5,972,024.08 420,615.72 0.08 694.7 3,504.0 46.47 244.92 2,931.0 2,861.6 -712.5 -1,342.1 5,971,996.02 420,553.38 0.38 730.8 3,599.1 46.46 244.73 2,996.5 2,927.1 -741.8 -1,404.5 5,971,967.35 420,490.71 0.15 766.9 3,693.1 46.44 244.91 3,061.3 2,991.9 -770.8 -1,466.2 5,971,939.01 420,428.75 0.14 802.5 3,779.0 46.30 245.82 3,120.6 3,051.2 -796.7 -1,522.7 5,971,913.68 420,371.97 0.78 835.5 Seabee (Post DW-02) 3,788.7 46.28 245.92 3,127.2 3,057.8 -799.6 -1,529.1 5,971,910.89 420,365.56 0.78 839.3 3,883.5 46.45 250.77 3,192.7 3,123.3 -824.9 -1,592.8 5,971,886.26 420,301.58 3.71 878.7 3,977.7 47.39 254.87 3,257.1 3,187.7 -845.2 -1,658.5 5,971,866.63 420,235.61 3.33 922.5 4,072.6 47.40 257.75 3,321.3 3,251.9 -861.7 -1,726.4 5,971,850.82 420,167.62 2.23 970.1 4,167.6 48.13 260.30 3,385.2 3,315.8 -875.1 -1,795.4 5,971,838.16 420,098.44 2.13 1,020.5 4,261.4 49.03 264.15 3,447.2 3,377.8 -884.6 -1,865.1 5,971,829.39 420,028.68 3.22 1,073.5 4,357.6 49.95 265.94 3,509.8 3,440.4 -890.9 -1,938.0 5,971,823.84 419,955.75 1.71 1,131.0 4,452.2 49.99 268.42 3,570.6 3,501.2 -894.4 -2,010.3 5,971,821.03 419,883.38 2.01 1,189.5 4,546.5 51.82 271.41 3,630.1 3,560.7 -894.5 -2,083.5 5,971,821.71 419,810.24 3.13 1,250.6 4,639.8 53.25 274.44 3,686.8 3,617.4 -890.7 -2,157.4 5,971,826.27 419,736.38 3.00 1,314.5 4,736.8 54.66 277.85 3,743.9 3,674.5 -882.3 -2,235.3 5,971,835.50 419,658.53 3.19 1,384.2 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 5 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 4,830.7 56.03 281.43 3,797.3 3,727.9 -869.4 -2,311.5 5,971,849.24 419,582.52 3.46 1,455.0 4,926.3 57.17 285.23 3,849.9 3,780.5 -851.0 -2,389.1 5,971,868.46 419,505.09 3.53 1,530.0 4,954.0 57.63 286.19 3,864.9 3,795.5 -844.6 -2,411.6 5,971,875.01 419,482.71 3.35 1,552.2 Nanushuk 4,991.0 58.26 287.45 3,884.5 3,815.1 -835.6 -2,441.6 5,971,884.39 419,452.80 3.35 1,582.3 NT8 MFS 5,021.2 58.78 288.47 3,900.3 3,830.9 -827.6 -2,466.1 5,971,892.60 419,428.35 3.35 1,607.2 5,025.0 58.84 288.63 3,902.2 3,832.8 -826.6 -2,469.2 5,971,893.65 419,425.31 3.97 1,610.3 NT7 MFS 5,114.8 60.38 292.36 3,947.7 3,878.3 -799.5 -2,541.7 5,971,921.53 419,353.08 3.97 1,685.8 5,190.0 61.34 294.95 3,984.3 3,914.9 -773.1 -2,601.8 5,971,948.52 419,293.21 3.27 1,750.6 NT6 MFS 5,209.3 61.60 295.61 3,993.5 3,924.1 -765.9 -2,617.2 5,971,955.92 419,277.95 3.27 1,767.4 5,291.0 62.99 298.13 4,031.5 3,962.1 -733.2 -2,681.7 5,971,989.28 419,213.79 3.22 1,839.2 NT5 MFS 5,304.8 63.23 298.55 4,037.8 3,968.4 -727.3 -2,692.5 5,971,995.25 419,203.00 3.22 1,851.5 5,398.9 65.19 300.08 4,078.7 4,009.3 -685.8 -2,766.4 5,972,037.49 419,129.60 2.55 1,936.0 5,464.0 66.50 301.87 4,105.3 4,035.9 -655.3 -2,817.3 5,972,068.58 419,079.00 3.21 1,995.3 NT4 MFS 5,492.8 67.08 302.65 4,116.7 4,047.3 -641.1 -2,839.7 5,972,082.96 419,056.74 3.21 2,021.9 5,587.4 68.50 304.92 4,152.4 4,083.0 -592.4 -2,912.5 5,972,132.42 418,984.48 2.68 2,109.4 5,683.8 70.56 306.67 4,186.1 4,116.7 -539.6 -2,985.7 5,972,185.96 418,911.85 2.73 2,199.6 5,777.3 72.35 308.68 4,215.9 4,146.5 -485.4 -3,055.9 5,972,240.90 418,842.22 2.79 2,288.0 5,873.3 74.11 310.20 4,243.6 4,174.2 -427.0 -3,126.8 5,972,299.99 418,771.90 2.38 2,379.3 5,968.1 76.07 312.07 4,268.0 4,198.6 -366.7 -3,195.9 5,972,361.00 418,703.52 2.81 2,470.1 6,062.9 78.25 314.28 4,289.0 4,219.6 -303.6 -3,263.2 5,972,424.87 418,636.86 3.24 2,561.1 6,157.9 80.25 316.36 4,306.8 4,237.4 -237.2 -3,328.8 5,972,491.92 418,571.93 3.01 2,652.4 6,199.2 81.09 317.45 4,313.5 4,244.1 -207.4 -3,356.7 5,972,522.02 418,544.35 3.30 2,692.1 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 6 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 6,236.0 81.64 318.17 4,319.0 4,249.6 -180.5 -3,381.1 5,972,549.19 418,520.23 2.45 2,727.2 9-5/8" Intermediate Liner 6,282.2 82.34 319.07 4,325.4 4,256.0 -146.1 -3,411.4 5,972,583.83 418,490.35 2.45 2,771.4 6,321.4 83.05 319.83 4,330.4 4,261.0 -116.6 -3,436.7 5,972,613.66 418,465.36 2.64 2,808.7 6,386.0 84.10 322.06 4,337.6 4,268.2 -66.7 -3,477.1 5,972,663.89 418,425.47 3.80 2,869.9 NT3 MFS 6,416.3 84.60 323.10 4,340.6 4,271.2 -42.8 -3,495.4 5,972,688.01 418,407.40 3.80 2,898.3 6,509.9 86.69 326.17 4,347.7 4,278.3 33.3 -3,549.4 5,972,764.70 418,354.17 3.96 2,985.3 6,605.5 88.69 328.12 4,351.6 4,282.2 113.5 -3,601.2 5,972,845.44 418,303.21 2.92 3,072.6 6,700.6 90.16 329.34 4,352.5 4,283.1 194.9 -3,650.6 5,972,927.24 418,254.69 2.01 3,158.5 6,795.1 91.12 329.67 4,351.5 4,282.1 276.2 -3,698.5 5,973,009.13 418,207.61 1.07 3,243.2 6,829.0 91.11 329.75 4,350.8 4,281.4 305.5 -3,715.6 5,973,038.56 418,190.83 0.25 3,273.6 NT3.2 Top Reservoir 6,889.9 91.08 329.90 4,349.7 4,280.3 358.1 -3,746.2 5,973,091.51 418,160.77 0.25 3,328.1 6,984.3 91.21 329.63 4,347.8 4,278.4 439.7 -3,793.8 5,973,173.57 418,114.08 0.32 3,412.6 7,079.3 91.11 328.59 4,345.9 4,276.5 521.2 -3,842.5 5,973,255.57 418,066.18 1.10 3,498.1 7,173.6 91.08 328.46 4,344.1 4,274.7 601.6 -3,891.8 5,973,336.48 418,017.80 0.14 3,583.4 7,267.5 91.05 328.98 4,342.3 4,272.9 681.8 -3,940.5 5,973,417.16 417,969.92 0.55 3,668.1 7,363.0 91.12 328.54 4,340.5 4,271.1 763.5 -3,990.0 5,973,499.34 417,921.24 0.47 3,754.3 7,457.7 91.15 328.36 4,338.6 4,269.2 844.2 -4,039.5 5,973,580.50 417,872.56 0.19 3,840.0 7,552.9 91.12 327.98 4,336.7 4,267.3 925.0 -4,089.8 5,973,661.91 417,823.20 0.40 3,926.4 7,647.7 91.08 327.69 4,334.9 4,265.5 1,005.2 -4,140.2 5,973,742.61 417,773.61 0.31 4,012.5 7,742.3 91.08 327.06 4,333.1 4,263.7 1,084.9 -4,191.2 5,973,822.84 417,723.43 0.67 4,099.0 7,837.2 91.12 327.33 4,331.3 4,261.9 1,164.7 -4,242.6 5,973,903.12 417,672.85 0.29 4,185.7 7,931.5 91.05 327.72 4,329.5 4,260.1 1,244.2 -4,293.2 5,973,983.14 417,623.09 0.42 4,271.6 8,024.8 91.30 328.47 4,327.6 4,258.2 1,323.4 -4,342.5 5,974,062.84 417,574.61 0.85 4,356.3 8,120.8 91.24 329.57 4,325.5 4,256.1 1,405.7 -4,391.9 5,974,145.61 417,526.08 1.15 4,442.8 8,215.3 91.24 329.71 4,323.4 4,254.0 1,487.2 -4,439.7 5,974,227.61 417,479.19 0.15 4,527.4 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 7 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 8,309.9 91.21 330.07 4,321.4 4,252.0 1,569.0 -4,487.1 5,974,309.92 417,432.60 0.38 4,612.0 8,404.1 91.24 330.48 4,319.4 4,250.0 1,650.8 -4,533.8 5,974,392.22 417,386.73 0.44 4,696.0 8,499.2 91.21 330.10 4,317.4 4,248.0 1,733.4 -4,581.0 5,974,475.28 417,340.48 0.40 4,780.7 8,593.6 91.27 329.09 4,315.3 4,245.9 1,814.8 -4,628.7 5,974,557.12 417,293.59 1.07 4,865.2 8,687.9 91.24 329.50 4,313.3 4,243.9 1,895.9 -4,676.9 5,974,638.70 417,246.28 0.44 4,950.0 8,783.9 91.24 330.04 4,311.2 4,241.8 1,978.8 -4,725.2 5,974,722.09 417,198.85 0.56 5,035.9 8,878.0 91.21 330.39 4,309.2 4,239.8 2,060.4 -4,771.9 5,974,804.20 417,152.98 0.37 5,119.8 8,972.3 91.15 330.07 4,307.2 4,237.8 2,142.3 -4,818.7 5,974,886.58 417,107.00 0.34 5,203.9 9,066.4 91.24 329.97 4,305.3 4,235.9 2,223.8 -4,865.7 5,974,968.51 417,060.86 0.14 5,287.9 9,162.0 91.21 329.95 4,303.2 4,233.8 2,306.5 -4,913.6 5,975,051.77 417,013.86 0.04 5,373.3 9,257.3 91.18 329.54 4,301.2 4,231.8 2,388.8 -4,961.6 5,975,134.56 416,966.72 0.43 5,458.6 9,352.5 91.24 329.57 4,299.2 4,229.8 2,470.8 -5,009.8 5,975,217.06 416,919.38 0.07 5,543.9 9,447.3 91.30 329.14 4,297.1 4,227.7 2,552.4 -5,058.1 5,975,299.07 416,871.93 0.46 5,629.0 9,542.0 91.24 329.04 4,295.0 4,225.6 2,633.6 -5,106.7 5,975,380.81 416,824.15 0.12 5,714.3 9,636.7 91.21 328.52 4,293.0 4,223.6 2,714.6 -5,155.8 5,975,462.32 416,775.90 0.55 5,799.8 9,731.6 91.21 328.56 4,291.0 4,221.6 2,795.5 -5,205.3 5,975,543.70 416,727.26 0.04 5,885.5 9,824.8 91.24 328.88 4,289.0 4,219.6 2,875.2 -5,253.7 5,975,623.85 416,679.70 0.34 5,969.7 9,920.8 91.18 328.98 4,287.0 4,217.6 2,957.4 -5,303.3 5,975,706.56 416,631.04 0.12 6,056.2 10,014.8 91.18 329.44 4,285.0 4,215.6 3,038.1 -5,351.4 5,975,787.81 416,583.76 0.49 6,140.8 10,109.3 91.21 329.59 4,283.1 4,213.7 3,119.5 -5,399.3 5,975,869.70 416,536.69 0.16 6,225.5 10,204.0 94.41 330.63 4,278.4 4,209.0 3,201.6 -5,446.5 5,975,952.20 416,490.41 3.55 6,310.0 10,298.9 98.36 331.12 4,267.9 4,198.5 3,283.9 -5,492.3 5,976,034.97 416,445.41 4.20 6,393.5 10,393.1 101.98 330.53 4,251.2 4,181.8 3,364.9 -5,537.5 5,976,116.44 416,401.04 3.89 6,475.7 10,479.0 105.46 330.43 4,230.9 4,161.5 3,437.4 -5,578.6 5,976,189.42 416,360.71 4.06 6,549.9 NT 3.24 10,488.3 105.84 330.42 4,228.4 4,159.0 3,445.2 -5,583.1 5,976,197.28 416,356.36 4.06 6,557.9 10,582.3 109.54 329.57 4,199.8 4,130.4 3,522.8 -5,627.8 5,976,275.26 416,312.41 4.03 6,637.9 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 8 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True MD (usft) Inc (°) Azi (azimuth) (°) N/S (usft) E/W (usft) Northing (usft) TVDSS (usft) Easting (usft) Survey TVD (usft) DLeg (°/100usft) V. Sec (usft) 10,678.0 113.20 329.10 4,165.0 4,095.6 3,599.4 -5,673.2 5,976,352.33 416,267.80 3.85 6,717.9 10,722.0 114.56 329.26 4,147.1 4,077.7 3,634.0 -5,693.9 5,976,387.12 416,247.53 3.11 6,754.1 NT3.2 Top Reservoir 10,773.1 116.14 329.46 4,125.3 4,055.9 3,673.7 -5,717.4 5,976,427.10 416,224.41 3.11 6,795.6 10,830.0 116.12 328.96 4,100.2 4,030.8 3,717.6 -5,743.5 5,976,471.24 416,198.73 0.78 6,841.5 NT3 MFS 10,867.2 116.11 328.64 4,083.8 4,014.4 3,746.2 -5,760.9 5,976,500.01 416,181.72 0.78 6,871.7 10,916.8 116.10 328.48 4,062.0 3,992.6 3,784.2 -5,784.1 5,976,538.26 416,158.87 0.29 6,912.0 10,947.0 116.10 328.48 4,048.7 3,979.3 3,807.3 -5,798.3 5,976,561.49 416,144.96 0.00 6,936.5 TD Projection Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 20" Conductor Casing127.0127.0 20 20 13-3/8" Surface Casing2,240.22,501.0 13-3/8 16 9-5/8" Intermediate Liner4,319.06,236.0 9-5/8 12-1/4 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 9 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Santos NAD27 Conversion Pikka NDB Santos Definitive Survey Report Well: Wellbore: NDBi-043 NDBi-043 Survey Calculation Method:Minimum Curvature Parker 272 @ 69.4usft Design:NDBi-043 Database:EDM STO Alaska MD Reference:Parker 272 @ 69.4usft North Reference: Well NDBi-043 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations 6,386.0 4,337.6 NT3 MFS 6,829.0 4,350.8 NT3.2 Top Reservoir 1,154.0 1,144.1 Base Ice Bearing Permafrost 1,410.0 1,388.7 Base Permafrost Transition 3,779.0 3,120.6 Seabee (Post DW-02) 5,025.0 3,902.2 NT7 MFS 10,830.0 4,100.2 NT3 MFS 0.00 2,353.0 2,141.0 MCU (Post DW-02) 10,722.0 4,147.1 NT3.2 Top Reservoir 0.00 5,190.0 3,984.3 NT6 MFS 1,798.0 1,734.0 Middle Schrader Bluff 4,991.0 3,884.5 NT8 MFS 2,804.0 2,448.3 Tuluvak Shale (Post DW-02) 5,464.0 4,105.3 NT4 MFS 4,954.0 3,864.9 Nanushuk 2,893.0 2,509.7 Tuluvak Sand (Post DW-02) 5,291.0 4,031.5 NT5 MFS 1,036.0 1,029.7 Upper Schrader Bluff 10,479.0 4,230.9 NT 3.24 0.00 Measured Depth (usft) Vertical Depth (usft)+E/-W (usft) +N/-S (usft) Local Coordinates Comment Design Annotations 10,947.0 4,048.7 -5,798.33,807.3 TD Projection Approved By:Checked By:Date: 11/09/2023 2:10:51PM COMPASS 5000.17 Build 02 Page 10 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION Dry cutting samples NDBi-043 (50-103-20859-0000) NDBi-043A (50-103-20859-0100) Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@santos.com DATE: 8/28/2023 From: Shannon Koh Santos P.O. Box 240927 Anchorage, AK 99524-0927 To: Meredith Guhl AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/Teams ܈Hardcopy ܆Other REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܈Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܆Other COMMENTS: Samples received 8/17/2023 Entered into RBDMS 8/29/2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.08.29 14:54:24 -08'00' f I N —1 —4 r. O � c v w — r� —CA z m CW N 1--` m 0 w fD, x .+ •� 00 H m S , A Z z tNi+ 0 aNi 3 N cn D cn O N p -A S 0.)v C 3 3 O W v ° o (D n m C- D O c N F-� M In A W N m In A W N O O O O O O O O O O O O O O O N N Ol O'1 Ql Ol 01 6l Ol 61 Ol 01 O� Ql x n O A a d aj aj N N A to to A A A A In to A A A LA 3 O U7 In (n F-+ V 1--' A U'7 In F- J 1--` A m (D to rr A "4 a � 0 `n m O � � v s R.v A. fcu D nai a. Q —i a s o3 cu cu y tD .W m Q fl Vt V, Q Q Q N M O " N .3•r C n d q W F, F- w m O O C CD v w to cn o w to cn o c 3 v+ ao au O O to in O O cn O v+ cn O_ O to O In N 1+ cn O O O O O O 7 C W OQ UQ W O N m W In A F' N M W In A ~' m 'C O 0Un V W O W� J 0 to 0 O 0 Cn 0 � - 3— A 7 rF O AO � 00 O Ln � N Owl 00 O U "G PQ O J `N O 0 0 0 0 v O O O O O C 41 � J D A v; fD 00 ;,7- °' m' w O L w — �- � Gl D w M O• S :3C) 7 � C [7 S O O V v f�D O O •O <• Gl fD J n p V Vf M p (J7 O cu w D 3 w D H D N J D D Q n ram, w �° m °' m 0 P m 0 ul Ull N O A Ut O S. n oc F-� 4u m F' o rn x cu o o 3 a N O 3 J • J to .�•' O N Ln O rt Ln O cp,P3 -bsl RECEIVED tf3ss DM„5 AUG 17 2023 GLab SWdim EOLOG Innovation Hub Santos DRILL CUTTINGS SAMPO E WELL NAME : NDBI-043 WELL API : 501032085900040 Date Drilled : FROM: 07/10/2023 1 08/05/2023 Area/Location . North Slope Borough OVEN DRIED SAMPLES (SETS A, B) Box 1 Box 2 Box 3 Box 4 Box 5 Box 6 1 150 1500 3550 5900 6680 9300 2 180 1550 3600 5950 6690 9350 3 210 1600 3650 6000 6700 9400 4 240 1650 3700 6050 6710 9450 5 270 1700 3750 6100 6750 9500 6 300 1750 3800 6150 6800 9550 7 330 1800 3850 6200 6850 9600 8 360 1850 3900 6240 6900 9650 9 390 1900 3950 6250 6950 9700 10 420 1950 4000 6260 7000 9750 11 450 2000 4050 6270 7050 9800 12 480 2050 4100 6280 7100 9850 13 510 2100 4150 6290 7150 9900 14 540 2150 4200 6300 7200 9950 15 570 2200 4250 6310 7250 10000 16 600 2250 4300 6320 7300 10050 17 630 2300 4350 6330 7350 10100 18 660 2350 4400 6340 7400 10150 19 690 2400 4450 6350 7450 10180 20 720 2450 4500 6360 7500 10210 21 750 2500 4550 6370 7550 10240 22 780 2550 4600 6380 7600 10270 23 810 2600 4650 6390 7650 10300 24 840 2650 4700 6400 7700 10330 25 870 2700 4750 6410 7750 10360 26 900 2750 4800 6420 7800 10390 27 930 2800 4850 6430 7850 10420 28 960 2850 4900 6440 7900 10450 29 990 2900 4950 6450 7950 10480 30 1020 2950 5000 6460 8000 10510 31 1050 3000 5050 6470 8050 10540 32 1080 3050 5100 6480 8100 10570 33 1110 3100 5150 6490 8150 10600 34 1140 3150 5200 6500 8200 10630 35 1170 3200 5250 6510 8250 10660 36 1200 3250 5300 6520 8300 10690 37 1230 3300 5350 6530 8350 10720 38 1260 3350 5400 6540 8400 10750 39 1290 3400 5450 6550 8450 10780 40 1320 3450 5500 6560 8500 10810 41 1350 3500 5550 6570 8550 10840 42 1380 5600 6580 8600 10870 43 1400 5650 6590 8650 10900 44 1450 5700 6600 8700 10930 45 5750 6610 8750 10947 46 5800 6620 8800 47 5850 6630 8850 48 6640 8900 49 6650 8950 50 6660 9000 51 6670 9050 52 9100 53 9150 54 9200 55 9250 56 Preparation Date: 05-Aug-23 Prepared By: Geolog Contact: lab327(a geoloq.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Thompson, Jacob (Jacob) Subject:RE: NDBi-043 PTD223-051 9-5/8" Liner Cement Evaluation Date:Wednesday, July 19, 2023 12:17:00 PM Attachments:image007.png image008.png image009.png Jake, Oil Search Alaska has approval to make the changes described below. Let’s discuss the results of the 9-5/8” liner cement jobs to see if there will be any requirements to submit cement logs prior to running tubing. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Sent: Wednesday, July 19, 2023 11:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: NDBi-043 PTD223-051 9-5/8" Liner Cement Evaluation Bryan, Per our conversation we have slightly changed the order of operations on the NBi-043 well and plan on drilling the 8-1/2” Production Hole and running the 4-1/2” Lower Completion prior to running the ultrasonic cement evaluation tool on wireline. This is different than the planned PTD where we were going to run the Ultrasonic E-line log prior to drilling out. We will contact you after the 9-5/8” liner cement job and confirm if any abnormal results were observed. Thanks, Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@santos.com https://www.santos.com/ 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 Jake Thompson Senior Drilling Engineer Oil Search Alaska, LLC 900 E Benson Boulevard Anchorage, AK, 99508 Re: Pikka Field, Nanushuk Oil Pool, NDBi-043 PB1 Oil Search Alaska, LLC Permit to Drill Number: 223-051 Surface Location: 2307’ FSL, 1739’ FEL, Sec 4, T11N, R6E, UM Bottomhole Location: 700’ FSL, 3785’ FEL, Sec 32, T12N, R6E, UM Dear Mr. Thompson: 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. 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, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of June, 2023. 30 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.30 11:34:46 -05'00' 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: 11,061'TVD:3,998' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 6678' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70.8 15. Distance to Nearest Well Open Surface: x- 1561935 y- 5972441 Zone- 4 23.8 to Same Pool: 1930' 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 116 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20"x34" 215# X-65 Welded 80’ Surface Surface 128' 53' 16” 13-3/8” 68# L-80 BTC 2,590’ Surface Surface 2,591' 2,230' 12-1/4” 9-5/8” 47# L-80 Hydril 563 3,430’ 2,440’2,210' 6,195' 4,249' 8-1/2” - - - - 961' 10,100'11,061' 3,927' 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: Jake Thompson Jake Thompson Contact Email:jacob.thompson@santos.com Senior Drilling Engineer Contact Phone:1-907-854-4377 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 Please see Attachment 6 for details Plug back wellbore uncemented. Effect. Depth MD (ft): Effect. Depth TVD (ft): 640, 640, 640 = 1920 acres total 18. Casing Program: Top - Setting Depth - BottomSpecifications 1976 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 Please see Attachment 6 for details 1545 2521' FSL, 1739' FEL, Sec 4, T11N, R6E, UM 700' FSL, 3785' FEL, Sec 12, T32N, R6E, UM LONS 19-003 900 E Benson Boulevard, Anchorage, AK 99508 Oil Search Alaska, LLC 2307' FSL, 1938' FEL, Sec 4, T11N, R6E, UM ADL 392984, ADL 391445, ADL 393020 NDBi-043 PB1 Pikka / Nanushuk Oil Pool 07/10/23 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 Nooo s N oooo D s s s D t o : well is s G S S 20 S S S s Nooo s No S s G y E S s No ooo 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) Senior Drilling Engineer API N b 06/13/2023 By Grace Christianson at 3:33 pm, Jun 13, 2023 SFD This PB1 PTD includes all scope up until the point of sidetracking at 10100' md. BOP test to 3000 psi. SFD Submit FIT/LOT data to AOGCC within 24 hrs of performing test Submit Cement log data to AOGCC and obtain approval before drilling out Production Casing Shoe NAD 27) Sec 32, T12N 5972694 BJM 6/22/23 223-051 SFD 6/29/2023 50-103-20859-00-00 421903 DSR-6/28/23JLC 6/30/23 06/30/23 06/30/23 RBDMS JSB 063023 FWL Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.06.30 11:35:14 -05'00' Page 1 of 2 07 June 2023 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-043 PB1 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-043 is planned to be a horizontal Injector targeting the Nanushuk 3. The approximate spud date is anticipated to be July 10th, 2023. Parker Rig 272 will be used to drill this well. The NDBi-043 PB1 well is a planned plug back that will TD in the upper portion of the Nanushuk 3 formation in the 8-1/2” production hole. The 16” surface hole will TD above the Tuluvak sand and then 13-3/8” casing will be set and cemented. The 12-1/4” intermediate hole will be drilled to above the top of the Nanushuk 3 formation at an inclination of ~46 degrees. A 9-5/8” liner will be set and cemented from TD to secure the shoe and cover the Tuluvak sand. The 8-1/2” production hole will be geo-steered in the Nanushuk 3 sand. A plug back wellbore will be steered upward reaching total depth when the top of the Nanushuk 3 Maximum flood surface is logged with the LWD suite. The objective is to ascertain the reservoir quality in the upper portion of the Nanushuk 3, as well as obtain a structural top for the Nanushuk 3 to optimally place the rest of the lateral. An open hole sidetrack will be performed at ~10,100 MD and the NDBi-043 production 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. Please find enclosed for your review Form 10-401 Permit to Drill with a supporting Application for Permit to Drill containing information as required by 20 AAC 25.005. If there are any questions and/or additional information desired, please contact me at (907) 854- 4377 or Jacob.Thompson@santos.com. Respectfully, Jacob Thompson Respectfully, service injection SFD A plug back wellbore will be steered upward reaching total depth when the top of the Nanushuk 3 Maximum flood surface is logged with the LWD suite. T NDBi-043 PB1 well is a planned plug back surface hole will TD above the Tuluvak sand Page 2 of 2 Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill NDBi-043 PTD AOGCC 6-7-23 - 1 - 06-Jun-23 Application for Permit to Drill NDBi-043 Well PB1 NDBi-043 PTD AOGCC 6-7-23 - 2 - 06-Jun-23 Table of Contents 1. Well Name.................................................................................................................................3 2. Location Summary.....................................................................................................................3 3. Blowout Prevention Equipment Information..............................................................................4 4. Drilling Hazards Information......................................................................................................5 5. Procedure for Conducting Formation Integrity Tests ..................................................................6 6. Casing and Cementing Program.................................................................................................6 7. Diverter System Information......................................................................................................7 8. Drilling Fluid Program................................................................................................................7 9. Abnormally Pressured Formation Information...........................................................................7 10. Seismic Analysis.......................................................................................................................7 11. Seabed Condition Analysis.......................................................................................................8 12. Evidence of Bonding................................................................................................................8 13. Proposed Drilling Program.......................................................................................................8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ..............................................10 15. Proposed Variance Request...................................................................................................10 Attachments............................................................................................................................................11 Attachment 1: Location Map.......................................................................................................12 Attachment 2: Directional Plan....................................................................................................14 Attachment 3: BOPE Equipment..................................................................................................2 2 Attachment 4: Drilling Hazards....................................................................................................27 Attachment 5: Leak Off Test Procedure .......................................................................................29 Attachment 6: Cement Summary.................................................................................................30 Attachment 7: Prognosed Formation Tops...................................................................................31 Attachment 8: Well Schematic.....................................................................................................32 Attachment 9: Formation Evaluation Program.............................................................................33 Attachment 10: Wellhead & Tree Diagram ..................................................................................34 Attachment 11: Area of Review...................................................................................................35 NDBi-043 PTD AOGCC 6-7-23 - 3 - 06-Jun-23 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-043. 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 2,307’ FSL, 1,938’ FWL, Sec 4, T11N, R6E, UM NAD 27 Coordinate System N 5,972,694.41 E 421,902.72 Rig KB Elevation 47.0’ above conductor level Conductor Level 23.8’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 2,521’ FSL, 1739’ FEL Sec 4, T11N, R6E, UM NAD 27 Coordinate System N 5,972,956 E 418,227 Measured Depth, Rig KB (MD)6,705’ Total Vertical Depth, Rig KB (TVD)4,355’ Total vertical Depth, Subsea (TVDSS)4,285’ Location at Bottom of Productive Interval Reference to Government Section Lines 2,806’ FSL, 5,034’ FEL, Sec 12, T32N, R6E, UM NAD 27 Coordinate System N 5,978,548 E 414,975 Measured Depth, Rig KB (MD)13,176’ Total Vertical Depth, Rig KB (TVD)4,215’ Total vertical Depth, Subsea (TVDSS)4,145’ NDBi-043 PB1 -bjmservice injection well. Sec 32, T12N NDBi-043 PTD AOGCC 6-7-23 - 4 - 06-Jun-23 Location at Bottom Hole NDBi-043 PB1 Reference to Government Section Lines 700 FSL, 3,785’ FEL, Sec 12, T32N, R6E, UM NAD 27 Coordinate System N 5,976,428 E 416,208 Measured Depth, Rig KB (MD)11,744’ Total Vertical Depth, Rig KB (TVD)4,132’ Total vertical Depth, Subsea (TVDSS)4,062’ (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-043 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 11,061 MD / 3998' TVD SFD NDBi-043 PTD AOGCC 6-7-23 - 5 - 06-Jun-23 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 1,976 psi in the TN4 at 4,315’ TVD (8.8ppg EMW top Nanushuk 4 to TD of the section) Maximum surface pressure 1,545 psi from TN4 at 4,315’ TVD (0.10 psi/ft gas gradient to surface, 4,315’ TVD) Planned BOP test pressure Rams test to 3,000 psi / 250 psi Annular test to 3,000 psi / 250 psi [Test pressure driven by frac back pressure requirement] Integrity Test – 12-1/4” hole LOT after drilling 20’-50’ of new hole. 12.9 ppg LOT required for Kick Tolerance, 17 ppg maximum EMW LOT. 13-3/8” Casing Test 3,000 psi surface pressure [Test pressure driven by Maximum Surface Pressure] 8-1/2” Production Hole Pressure Data Maximum anticipated BHP 1,970 psi in the Nanushuk 3 at 4,355’ TVD (8.7ppg EMW top NT3) Maximum surface pressure 1,535 psi in the Nanushuk 3 at 4,355’ TVD (0.10 psi/ft gas gradient to surface, 4,355’ TVD) Planned BOP test pressure Rams test to 3,000 psi / 250 psi Annular test to 3,000 psi / 250 psi [Test pressure driven by frac back pressure requirement] Integrity Test – 8-1/2” hole LOT after drilling 20’-50’ of new hole. 10.0 ppg for minimum kick tolerance. 9-5/8” Liner Test 3,000 psi surface pressure [Test pressure driven by Maximum Surface Pressure] (B) data on potential gas zones; and The Tuluvak formation is expected in this area and has a high potential for gas based on offset Exploration and Appraisal well data. The Tuluvak is expected to be overpressured at 10.0ppg 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. BOPE will be installed before entering any hydrocarbon zones and appropriate mud weights will be utilized to provide sufficient overbalance. high potential for gas based o e Tuluvak is expected to be overpressured at 10.0ppg NDBi-043 PTD AOGCC 6-7-23 - 6 - 06-Jun-23 (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; Nearby offset Exploration and Appraisal wells in the area suggest that no significant hole problems are to be expected. 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 / TVDss 42”20” x 34”215# X-65 Welded 80’Surface 128’ / 53’ 16”13-3/8”68# L-80 BTC 2,590’Surface 2,591’/2,230’ 12-1/4”9-5/8”47# L-80 Hydril 563 3,430’ 2,440’6,195’ / 4,249’ 8-1/2” PB1 --- --- --- --- 961’10,100’11,061’ / 3,927’ 8-1/2”4-1/2”12.6 P-110S Hydril 563 7,130’6,045’13,175’ / 4,145’ Tubing 4-1/2”12.6# P-110S Hydril 563 6,065’Surface 6,065’ / 4,225’ Please refer to Attachment 6: Cement Summary for further details. NDBi-043 PTD AOGCC 6-7-23 - 7 - 06-Jun-23 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, model GK, 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 10.5ppg 85-275 seconds 30-50 30-80 < 14 ml/30min n/a 9.5-10 <35 10.7-11.2ppg 50-100 seconds 20-40 15-30 n/a < 10 ml/30min n/a n/a 9.0-9.8ppg 50-80 seconds 15-20 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. Tuluvak Sand at ~2940' MD (2550' TVD) expected to be over-pressured at 10.0 ppg. (See p. 31.) SFD 6/29/2023 NDBi-043 PTD AOGCC 6-7-23 - 8 - 06-Jun-23 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-043 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-043 is listed below. Please refer to Attachments 8-10 for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed Drilling Program 1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing ring on conductor. 2. Move in / rig up Parker 272. 3. Nipple up spacer spools and diverter over the 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” assembly with motor, MWD, and LWD tools. 6. Spud well and drill surface hole section to TD. CBU and clean well prior to trip. 7. POOH and lay down drilling assembly. 8. Run 13-3/8” 68# BTC surface casing as per casing tally and land on pre-installed landing ring. Circulate and condition mud prior to commencing cement job. 9. Cement 13-3/8” casing as per cement program. Verify cement returns to surface. 10. 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, 4-1/2” x 7” VBR). Test rams to 3000 psi high, and annular to 3000 psi. Give the AOGCC 24 hrs notice prior to testing. 11. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, pressure test casing to 3000 psi for 30 min, clean out to top of float equipment and displace well to 11.0 ppg MOBM. pressure test casing to 3000 psi displace well to 11.0 ppg MOBM. NDBi-043 PTD AOGCC 6-7-23 - 9 - 06-Jun-23 12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test and submit results to AOGCC. 13. Directionally drill 12-1/4” intermediate hole section to TD ~15’ TVD above the NT3 MFS. Perform wiper trips as required. Circulate and condition hole to run casing. POOH. 14. Change out upper BOP rams from 4-1/2” x 7” VBR to 9-5/8” solid body and test to 3,000 psi. 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. Cement 9-5/8” Liner with single stage cement job as per cement program. Monitor returns during displacement. Bump plug pressure up to set liner hanger, release the running tool, and set liner top packer. 17. Un-sting from the liner hanger and circulate cement returns from the top of the liner. 18. POOH and lay down liner running tools. 19. RU wireline and run ultrasonic cement evaluation log. Submit results to AOGCC. 20. Pressure test 9-5/8” production liner to 3,000 psi for 30 mins. 21. Change out upper BOP rams from 9-5/8” solid body to 4-1/2” x 7” VBR and test to 3,000 psi. 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 9.2 ppg MOBM. 23. Drill out shoe track and 20 - 50’ of new formation. Perform LOT and submit results to AOGCC. 24. Directionally drill 8-1/2” hole section as per well plan to TD of NDBi-043 PB1 wellbore. Perform wiper trips as required. 25. POOH to the kick-off point of ~10,100’ and open hole sidetrack. 26. Directionally drill 8-1/2” hole section as per well plan to TD of NDBi-043. Perform wiper trips as required. 27. POOH and lay down 8-1/2” Drilling BHA. 28. RU and run 4-1/2” production liner with frac sleeves and mechanical packers. 29. Run 4-1/2” liner to TD. Set liner hanger and Liner top packer and release the running tool. 30. Pressure test 9-5/8” x 4-1/2” production liner to 3,000 psi for 30 mins. 31. POOH and lay down the running tool. 32. RU and run the 4-1/2” completion w/tech wire. 33. Run 4-1/2” upper completion. Space out and stab seals inside the polish bore below the 9- 5/8” x 4-1/2” Production liner top packer. 34. Pressure test tubing to 4,000 psi for 30 mins, pressure up on annulus to 4,000 psi for 30 mins. Bleed pressure on tubing and shear upper gas lift valve. 35. Circulate diesel to freeze protect annulus. Submit LOT results and obtain approval from AOGCC before drilling additional hole. -bjm RU wireline and run ultrasonic cement evaluation log. Submit results to AOGCC. t to 3,000 psi. Submit cement log to AOGCC and obtain approval before drilling out liner shoe. -bjm End of PB1 Permit. Remainder of procedure after step 25 is on separate PTD -bjm Perform LOT and submit results to AOGCC. NDBi-043 PTD AOGCC 6-7-23 - 10 - 06-Jun-23 36. Install TWC pressure test to 3,000 psi for 5 mins, ND, BOP, NU dry hole tree. Pressure test to 3,000 psi for 5 mins. 37. RDMO 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. 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 25.412. Casing, cementing, and tubing of injection wells for enhanced recovery, disposal, and storage. (c) Before injection begins, a well must be pressure-tested to demonstrate the mechanical integrity of the tubing and packer and of the casing immediately surrounding the injection tubing string. The casing must be tested at a surface pressure of 1,500 psig or at a surface pressure of 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, but the casing may not be subjected to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. A variance is requested to the above underlined regulation 20 AAC 25.412 (c) allowing the 13-3/8” 68# L-80 casing to be pressure tested to an internal yield pressure greater than 70% of its internal hoop stress. The pressure test is to be conducted after the upper completion has been run and the well has been displaced to completion brine. The pressure test will allow the inner annulus (A annulus) to maintain backpressure during the hydraulic fracturing operations to optimally fracture the productive interval. All operational and test pressure will be below the internal yield pressure of the tubulars, and within industry standard design specifications. N/A for this PTD. Applicable to NDBi-043 PTD. NDBi-043 PTD AOGCC 6-7-23 - 11 - 06-Jun-23 Attachments NDBi-043 PTD AOGCC 6-7-23 - 12 - 06-Jun-23 Attachment 1: Location Map OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD PLANNED WELLS RIG OUTLINES DIVERTER (50-ft) DATE: 5/1/2023. By: JB 0204010 Feet Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDBi43_well GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 010205 Meters PIKKA DEVELOPMENT NDBi43 WELL DIVERTER Latitude (decimal degree) Long (decimal degree)Latitude Longitude Y (ft) x (ft) 70.33520 -150.637 70° 20' 06.7188" N 150° 38' 12.2558" W 5,972,442.40 1,561,935.53 Latitude (decimal degree) Long (decimal degree)Latitude Longitude y (ft) x (ft) 70.33552 -150.634 70° 20' 07.8701" N 150° 38' 00.9791" W 5,972,694.41 421,902.72 State Plane NAD83 Zone 4 StatePlane NAD27 Zone 4 NDBi-043 PTD AOGCC 6-7-23 - 14 - 06-Jun-23 Attachment 2: Directional Plan NDBi-043 Heel v.0 NDBi-043 TD v.0 Tie On 3.00°/100ftEnd of Tangent End of Build 3.00°/100ft End of 3D Arc 13.375in Casing Surface End of Tangent 3.00°/100ft End of 3D Arc 9.625in Casing Intermediate End of Tangent Tr u e V e r t i c a l D e p t h ( f t ) Vertical Section (ft) Azimuth 309.60° with reference 0.00 N, 0.00 E 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 -1000 0 1000 2000 3000 4000 5000 Scale 1 inch = 2000 Sc a l e 1 i n c h = 2 0 0 0 Offset wellpath MDs are referenced to each path's default MD datum Mean Sea Level to Ground level (At Slot: B-43): 0 feet RigonB-43(RT)toMeanSeaLevel:70.8feet Reference wellpath measured depths are referenced to Rig on B-43 (RT) True vertical depths are referenced to Rig on B-43 (RT) Plot reference wellpath is NDBi-043 Rev C.1 Created by: meyedavr on 2023-04-21; Database: WellArchitectDB Depths are in feet Coordinates are in feet referenced to Slot Scale: True distance North Reference: True north Grid System: NAD83 / TM Alaska SP, Zone 4 (5004), US feet Location: Facility: Field: Pikka Pikka Alaska Santos Wellbore: Well: Slot: NDBi-043 NDBi-043 B-43 NDBi-043 TD v.0 NDBi-043 Heel v.0 B-43 9.625in Casing Intermediate 13.375in Casing Surface No r t h i n g ( f t ) Easting (ft) -7500 -6250 -5000 -3750 -2500 -1250 0 1250 -1250 0 1250 2500 3750 5000 6250 Scale 1 inch = 2500 End of Tangent End of 3D Arc End of Tangent End of 3D Arc End of Build End of Tangent Tie On Design Comment 13175.91 6704.94 3862.45 2232.94 91.240 91.240 46.535 46.535 700.00 6.000 500.00 0.000 47.00 0.000 MD (ft) Inc (°) 329.220 329.220 246.924 246.924 165.000 165.000 165.000 Az (°) 4215.80 4355.80 3184.14 2063.18 699.63 500.00 47.00 TVD (ft) Well Profile Data 5782.33 224.14 -786.05 -322.49 -10.11 0.00 0.00 Local N (ft) -6989.08 -3678.43 -1604.57 -516.52 2.71 0.00 0.00 Local E (ft) DLS (°/100ft) 0.00 3.00 0.00 3.00 3.00 0.00 0.00 9070.98 2977.07 735.23 192.40 -8.53 0.00 0.00 VS (ft) Rig on B-43 (RT) to Mean Sea Level Mean Sea Level to Ground level (At Slot: B-43) Rig on B-43 (RT) to Ground level (At Slot: B-43) B-43 Slot -230.73 Local N (ft) Pikka Facility Name -1478.65 Local E (ft) 1561935.530 Grid East (US ft) 1563416.330 Grid East (US ft) Location Information 5972442.400 Grid North (US ft) 5972657.910 Grid North (US ft) 70.8ft 0ft 70.8ft 70°20'6.7188"N 70°20'8.9895"N Latitude Latitude 150°38'12.2560"W Longitude 150°37'29.0730"W Longitude REFERENCE WELLPATH IDENTIFICATION Operator Santos Well NDBi-043 NAD27 Field Pikka NAD27 API/Legal Facility Pikka NAD27 Wellbore NDBi-043 NAD27 Slot B-43 NAD 27 REPORT SETUP INFORMATION Projection System NAD27 / TM Alaska SP, Zone 4 (5004), US feet Software System WellArchitect® 6.0 North Reference True User Meyedavr Scale 0.999907 Report Generated 5/1/2023 at 8:48:19 AM Convergence at slot 0.60° West Database WellArchitectDB WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude Slot Location -230.42 -1478.70 421902.72 5972694.41 70°20'7.8702"N 150°38'0.9792"W Facility Reference Pt 423383.56 5972909.70 70°20'10.1378"N 150°37'17.7961"W Field Reference Pt 423383.56 5972909.70 70°20'10.1378"N 150°37'17.7961"W WELLPATH DATUM Calculation method Minimum curvature Rig on B-43 (RT) to Facility Vertical Datum 70.80ft Horizontal Reference Pt Slot Rig on B-43 (RT) to Mean Sea Level 70.80ft Vertical Reference Pt Rig on B-43 (RT) RigonB-43(RT)toGroundLevelat Slot (B-43 NAD 27) 70.80ft MD Reference Pt Rig on B-43 (RT)Section Origin N 0.00, E 0.00 ft Field Vertical Reference Mean Sea Level Section Azimuth 309.60° Actual Wellpath Report NDBi-43 Rev C.1 NAD27 Page1of6 Page 1 of 6Wellpath Report 5/1/2023file:///C:/WellArchitect/NDBi-43_Rev_C.1_NAD27.xml REFERENCE WELLPATH IDENTIFICATION Operator Santos Well NDBi-043 NAD27 Field Pikka NAD27 API/Legal Facility Pikka NAD27 Wellbore NDBi-043 NAD27 Slot B-43 NAD 27 Actual Wellpath Report NDBi-43 Rev C.1 NAD27 Page2of6 WELLPATH DATA (139 stations)† = interpolated, ‡ = extrapolated station MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVDSS [ft] Vert Sect [ft] North [ft] East [ft] Grid East [US ft] Grid North [US ft] DLS [°/100ft] 0.00† 0.000 165.000 0.00 -70.80 0.00 0.00 0.00 421902.72 5972694.41 0.00 47.00 0.000 165.000 47.00 -23.80 0.00 0.00 0.00 421902.72 5972694.41 0.00 147.00 0.000 165.000 147.00 76.20 0.00 0.00 0.00 421902.72 5972694.41 0.00 247.00 0.000 165.000 247.00 176.20 0.00 0.00 0.00 421902.72 5972694.41 0.00 347.00 0.000 165.000 347.00 276.20 0.00 0.00 0.00 421902.72 5972694.41 0.00 447.00 0.000 165.000 447.00 376.20 0.00 0.00 0.00 421902.72 5972694.41 0.00 500.00 0.000 165.000 500.00 429.20 0.00 0.00 0.00 421902.72 5972694.41 0.00 547.00 1.410 165.000 547.00 476.20 -0.47 -0.56 0.15 421902.86 5972693.85 3.00 647.00 4.410 165.000 646.85 576.05 -4.61 -5.46 1.46 421904.13 5972688.93 3.00 700.00 6.000 165.000 699.63 628.83 -8.53 -10.11 2.71 421905.32 5972684.28 3.00 747.00 6.219 178.118 746.37 675.57 -12.22 -15.02 3.43 421905.99 5972679.35 3.00 847.00 7.586 200.589 845.66 774.86 -17.96 -26.62 1.28 421903.73 5972667.78 3.00 947.00 9.714 214.794 944.53 873.73 -20.82 -39.73 -5.85 421896.45 5972654.75 3.00 1047.00 12.210 223.605 1042.70 971.90 -20.78 -54.32 -17.96 421884.19 5972640.29 3.00 1147.00 14.892 229.376 1139.92 1069.12 -17.86 -70.34 -35.01 421866.98 5972624.44 3.00 1247.00 17.674 233.394 1235.90 1165.10 -12.06 -87.77 -56.96 421844.86 5972607.25 3.00 1347.00 20.516 236.338 1330.39 1259.59 -3.39 -106.54 -83.73 421817.89 5972588.76 3.00 1447.00 23.396 238.589 1423.13 1352.33 8.11 -126.60 -115.27 421786.15 5972569.03 3.00 1547.00 26.302 240.369 1513.86 1443.06 22.43 -147.91 -151.48 421749.72 5972548.10 3.00 1647.00 29.225 241.817 1602.34 1531.54 39.52 -170.40 -192.27 421708.71 5972526.04 3.00 1747.00 32.162 243.022 1688.32 1617.52 59.33 -194.01 -237.52 421663.22 5972502.91 3.00 1847.00 35.108 244.045 1771.57 1700.77 81.82 -218.67 -287.10 421613.38 5972478.76 3.00 1947.00 38.061 244.929 1851.86 1781.06 106.91 -244.32 -340.89 421559.34 5972453.67 3.00 2047.00 41.021 245.703 1928.97 1858.17 134.54 -270.90 -398.73 421501.22 5972427.71 3.00 2147.00 43.984 246.390 2002.69 1931.89 164.63 -298.31 -460.47 421439.21 5972400.94 3.00 2232.94 46.535 246.924 2063.18 1992.38 192.40 -322.49 -516.52 421382.92 5972377.35 3.00 2247.00 46.535 246.924 2072.85 2002.05 197.09 -326.49 -525.91 421373.49 5972373.44 0.00 2347.00 46.535 246.924 2141.64 2070.84 230.40 -354.94 -592.68 421306.43 5972345.70 0.00 2447.00 46.535 246.924 2210.43 2139.63 263.71 -383.39 -659.45 421239.38 5972317.95 0.00 2547.00 46.535 246.924 2279.22 2208.42 297.03 -411.83 -726.22 421172.32 5972290.20 0.00 Page 2 of 6Wellpath Report 5/1/2023file:///C:/WellArchitect/NDBi-43_Rev_C.1_NAD27.xml REFERENCE WELLPATH IDENTIFICATION Operator Santos Well NDBi-043 NAD27 Field Pikka NAD27 API/Legal Facility Pikka NAD27 Wellbore NDBi-043 NAD27 Slot B-43 NAD 27 Actual Wellpath Report NDBi-43 Rev C.1 NAD27 Page 3 of 6 WELLPATH DATA (139 stations) MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVDSS [ft] Vert Sect [ft] North [ft] East [ft] Grid East [US ft] Grid North [US ft] DLS [°/100ft] 2647.00 46.535 246.924 2348.01 2277.21 330.34 -440.28 -793.00 421105.26 5972262.45 0.00 2747.00 46.535 246.924 2416.80 2346.00 363.65 -468.73 -859.77 421038.20 5972234.70 0.00 2847.00 46.535 246.924 2485.59 2414.79 396.97 -497.18 -926.54 420971.14 5972206.96 0.00 2947.00 46.535 246.924 2554.39 2483.59 430.28 -525.62 -993.31 420904.08 5972179.21 0.00 3047.00 46.535 246.924 2623.18 2552.38 463.59 -554.07 -1060.08 420837.03 5972151.46 0.00 3147.00 46.535 246.924 2691.97 2621.17 496.91 -582.52 -1126.86 420769.97 5972123.71 0.00 3247.00 46.535 246.924 2760.76 2689.96 530.22 -610.97 -1193.63 420702.91 5972095.96 0.00 3347.00 46.535 246.924 2829.55 2758.75 563.53 -639.41 -1260.40 420635.85 5972068.21 0.00 3447.00 46.535 246.924 2898.34 2827.54 596.85 -667.86 -1327.17 420568.79 5972040.47 0.00 3547.00 46.535 246.924 2967.13 2896.33 630.16 -696.31 -1393.94 420501.73 5972012.72 0.00 3647.00 46.535 246.924 3035.92 2965.12 663.47 -724.76 -1460.72 420434.68 5971984.97 0.00 3747.00 46.535 246.924 3104.71 3033.91 696.79 -753.21 -1527.49 420367.62 5971957.22 0.00 3847.00 46.535 246.924 3173.51 3102.71 730.10 -781.65 -1594.26 420300.56 5971929.47 0.00 3862.45 46.535 246.924 3184.13 3113.33 735.25 -786.05 -1604.58 420290.20 5971925.19 0.00 3947.00 46.861 250.380 3242.13 3171.33 765.12 -808.44 -1661.87 420232.68 5971903.40 3.00 4047.00 47.380 254.413 3310.19 3239.39 804.80 -830.58 -1731.69 420162.64 5971881.99 3.00 4147.00 48.038 258.370 3377.50 3306.70 849.10 -847.96 -1803.57 420090.59 5971865.35 3.00 4247.00 48.829 262.238 3443.86 3373.06 897.88 -860.54 -1877.29 420016.75 5971853.54 3.00 4347.00 49.746 266.007 3509.10 3438.30 951.03 -868.29 -1952.67 419941.30 5971846.58 3.00 4447.00 50.782 269.669 3573.03 3502.23 1008.38 -871.17 -2029.49 419864.46 5971844.50 3.00 4547.00 51.929 273.218 3635.49 3564.69 1069.79 -869.18 -2107.54 419786.44 5971847.30 3.00 4647.00 53.180 276.653 3696.31 3625.51 1135.08 -862.33 -2186.62 419707.45 5971854.97 3.00 4747.00 54.525 279.974 3755.30 3684.50 1204.08 -850.64 -2266.50 419627.70 5971867.50 3.00 4847.00 55.959 283.182 3812.32 3741.52 1276.59 -834.14 -2346.96 419547.43 5971884.84 3.00 4947.00 57.474 286.280 3867.21 3796.41 1352.43 -812.87 -2427.78 419466.84 5971906.94 3.00 5047.00 59.061 289.273 3919.81 3849.01 1431.37 -786.89 -2508.75 419386.15 5971933.76 3.00 5147.00 60.716 292.167 3969.98 3899.18 1513.21 -756.27 -2589.64 419305.59 5971965.22 3.00 5247.00 62.430 294.966 4017.59 3946.79 1597.72 -721.10 -2670.23 419225.39 5972001.22 3.00 5347.00 64.199 297.678 4062.51 3991.71 1684.67 -681.47 -2750.29 419145.75 5972041.68 3.00 5447.00 66.017 300.309 4104.60 4033.80 1773.82 -637.50 -2829.61 419066.89 5972086.47 3.00 Page 3 of 6Wellpath Report 5/1/2023file:///C:/WellArchitect/NDBi-43_Rev_C.1_NAD27.xml 07/006/07/2023 REFERENCE WELLPATH IDENTIFICATION Operator Santos Well NDBi-043 NAD27 Field Pikka NAD27 API/Legal Facility Pikka NAD27 Wellbore NDBi-043 NAD27 Slot B-43 NAD 27 Actual Wellpath Report NDBi-43 Rev C.1 NAD27 Page4of6 WELLPATH DATA (139 stations) MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVDSS [ft] Vert Sect [ft] North [ft] East [ft] Grid East [US ft] Grid North [US ft] DLS [°/100ft] 5547.00 67.879 302.866 4143.76 4072.96 1864.92 -589.30 -2907.97 418989.04 5972135.48 3.00 5647.00 69.779 305.356 4179.88 4109.08 1957.73 -537.00 -2985.16 418912.41 5972188.57 3.00 5747.00 71.713 307.785 4212.86 4142.06 2052.00 -480.75 -3060.96 418837.21 5972245.61 3.00 5847.00 73.678 310.160 4242.61 4171.81 2147.45 -420.70 -3135.17 418763.63 5972306.42 3.00 5947.00 75.668 312.488 4269.04 4198.24 2243.84 -357.02 -3207.59 418691.90 5972370.84 3.00 6047.00 77.681 314.774 4292.09 4221.29 2340.89 -289.88 -3278.00 418622.19 5972438.71 3.00 6147.00 79.712 317.025 4311.69 4240.89 2438.35 -219.46 -3346.23 418554.70 5972509.82 3.00 6247.00 81.759 319.248 4327.79 4256.99 2535.94 -145.96 -3412.09 418489.62 5972583.99 3.00 6347.00 83.818 321.447 4340.35 4269.55 2633.40 -69.59 -3475.38 418427.13 5972661.02 3.00 6447.00 85.886 323.630 4349.32 4278.52 2730.45 9.46 -3535.95 418367.40 5972740.69 3.00 6547.00 87.960 325.801 4354.69 4283.89 2826.84 90.96 -3593.62 418310.58 5972822.78 3.00 6647.00 90.036 327.966 4356.44 4285.64 2922.30 174.70 -3648.24 418256.84 5972907.07 3.00 6704.94 91.240 329.220 4355.79 4284.99 2977.08 224.15 -3678.43 418227.17 5972956.82 3.00 6747.00 91.240 329.220 4354.88 4284.08 3016.69 260.27 -3699.95 418206.03 5972993.17 0.00 6847.00 91.240 329.220 4352.72 4281.92 3110.87 346.17 -3751.11 418155.77 5973079.58 0.00 6947.00 91.240 329.220 4350.56 4279.76 3205.04 432.06 -3802.28 418105.51 5973166.00 0.00 7047.00 91.240 329.220 4348.39 4277.59 3299.21 517.95 -3853.44 418055.25 5973252.41 0.00 7147.00 91.240 329.220 4346.23 4275.43 3393.39 603.85 -3904.60 418004.99 5973338.82 0.00 7247.00 91.240 329.220 4344.06 4273.26 3487.56 689.74 -3955.76 417954.73 5973425.24 0.00 7347.00 91.240 329.220 4341.90 4271.10 3581.73 775.63 -4006.93 417904.47 5973511.65 0.00 7447.00 91.240 329.220 4339.74 4268.94 3675.90 861.53 -4058.09 417854.21 5973598.06 0.00 7547.00 91.240 329.220 4337.57 4266.77 3770.08 947.42 -4109.25 417803.95 5973684.48 0.00 7647.00 91.240 329.220 4335.41 4264.61 3864.25 1033.32 -4160.41 417753.69 5973770.89 0.00 7747.00 91.240 329.220 4333.24 4262.44 3958.42 1119.21 -4211.57 417703.43 5973857.30 0.00 7847.00 91.240 329.220 4331.08 4260.28 4052.60 1205.10 -4262.74 417653.17 5973943.72 0.00 7947.00 91.240 329.220 4328.92 4258.12 4146.77 1291.00 -4313.90 417602.91 5974030.13 0.00 8047.00 91.240 329.220 4326.75 4255.95 4240.94 1376.89 -4365.06 417552.65 5974116.55 0.00 8147.00 91.240 329.220 4324.59 4253.79 4335.12 1462.78 -4416.22 417502.39 5974202.96 0.00 8247.00 91.240 329.220 4322.42 4251.62 4429.29 1548.68 -4467.39 417452.13 5974289.37 0.00 8347.00 91.240 329.220 4320.26 4249.46 4523.46 1634.57 -4518.55 417401.87 5974375.79 0.00 Page 4 of 6Wellpath Report 5/1/2023file:///C:/WellArchitect/NDBi-43_Rev_C.1_NAD27.xml REFERENCE WELLPATH IDENTIFICATION Operator Santos Well NDBi-043 NAD27 Field Pikka NAD27 API/Legal Facility Pikka NAD27 Wellbore NDBi-043 NAD27 Slot B-43 NAD 27 Actual Wellpath Report NDBi-43 Rev C.1 NAD27 Page5of6 WELLPATH DATA (139 stations) MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVDSS [ft] Vert Sect [ft] North [ft] East [ft] Grid East [US ft] Grid North [US ft] DLS [°/100ft] 8447.00 91.240 329.220 4318.10 4247.30 4617.64 1720.47 -4569.71 417351.61 5974462.20 0.00 8547.00 91.240 329.220 4315.93 4245.13 4711.81 1806.36 -4620.87 417301.35 5974548.61 0.00 8647.00 91.240 329.220 4313.77 4242.97 4805.98 1892.25 -4672.04 417251.09 5974635.03 0.00 8747.00 91.240 329.220 4311.60 4240.80 4900.16 1978.15 -4723.20 417200.82 5974721.44 0.00 8847.00 91.240 329.220 4309.44 4238.64 4994.33 2064.04 -4774.36 417150.56 5974807.86 0.00 8947.00 91.240 329.220 4307.28 4236.48 5088.50 2149.93 -4825.52 417100.30 5974894.27 0.00 9047.00 91.240 329.220 4305.11 4234.31 5182.67 2235.83 -4876.68 417050.04 5974980.68 0.00 9147.00 91.240 329.220 4302.95 4232.15 5276.85 2321.72 -4927.85 416999.78 5975067.10 0.00 9247.00 91.240 329.220 4300.78 4229.98 5371.02 2407.62 -4979.01 416949.52 5975153.51 0.00 9347.00 91.240 329.220 4298.62 4227.82 5465.19 2493.51 -5030.17 416899.26 5975239.92 0.00 9447.00 91.240 329.220 4296.45 4225.65 5559.37 2579.40 -5081.33 416849.00 5975326.34 0.00 9547.00 91.240 329.220 4294.29 4223.49 5653.54 2665.30 -5132.50 416798.74 5975412.75 0.00 9647.00 91.240 329.220 4292.13 4221.33 5747.71 2751.19 -5183.66 416748.48 5975499.16 0.00 9747.00 91.240 329.220 4289.96 4219.16 5841.89 2837.08 -5234.82 416698.22 5975585.58 0.00 9847.00 91.240 329.220 4287.80 4217.00 5936.06 2922.98 -5285.98 416647.96 5975671.99 0.00 9947.00 91.240 329.220 4285.63 4214.83 6030.23 3008.87 -5337.15 416597.70 5975758.41 0.00 10047.00 91.240 329.220 4283.47 4212.67 6124.41 3094.77 -5388.31 416547.44 5975844.82 0.00 10147.00 91.240 329.220 4281.31 4210.51 6218.58 3180.66 -5439.47 416497.18 5975931.23 0.00 10247.00 91.240 329.220 4279.14 4208.34 6312.75 3266.55 -5490.63 416446.92 5976017.65 0.00 10347.00 91.240 329.220 4276.98 4206.18 6406.92 3352.45 -5541.79 416396.66 5976104.06 0.00 10447.00 91.240 329.220 4274.81 4204.01 6501.10 3438.34 -5592.96 416346.40 5976190.47 0.00 10547.00 91.240 329.220 4272.65 4201.85 6595.27 3524.23 -5644.12 416296.14 5976276.89 0.00 10647.00 91.240 329.220 4270.49 4199.69 6689.44 3610.13 -5695.28 416245.88 5976363.30 0.00 10747.00 91.240 329.220 4268.32 4197.52 6783.62 3696.02 -5746.44 416195.62 5976449.71 0.00 10847.00 91.240 329.220 4266.16 4195.36 6877.79 3781.92 -5797.61 416145.36 5976536.13 0.00 10947.00 91.240 329.220 4263.99 4193.19 6971.96 3867.81 -5848.77 416095.10 5976622.54 0.00 11047.00 91.240 329.220 4261.83 4191.03 7066.14 3953.70 -5899.93 416044.84 5976708.96 0.00 11147.00 91.240 329.220 4259.67 4188.87 7160.31 4039.60 -5951.09 415994.58 5976795.37 0.00 11247.00 91.240 329.220 4257.50 4186.70 7254.48 4125.49 -6002.26 415944.32 5976881.78 0.00 11347.00 91.240 329.220 4255.34 4184.54 7348.66 4211.38 -6053.42 415894.06 5976968.20 0.00 Page 5 of 6Wellpath Report 5/1/2023file:///C:/WellArchitect/NDBi-43_Rev_C.1_NAD27.xml REFERENCE WELLPATH IDENTIFICATION Operator Santos Well NDBi-043 NAD27 Field Pikka NAD27 API/Legal Facility Pikka NAD27 Wellbore NDBi-043 NAD27 Slot B-43 NAD 27 Actual Wellpath Report NDBi-43 Rev C.1 NAD27 Page6of6 WELLPATH DATA (139 stations) MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVDSS [ft] Vert Sect [ft] North [ft] East [ft] Grid East [US ft] Grid North [US ft] DLS [°/100ft] 11447.00 91.240 329.220 4253.17 4182.37 7442.83 4297.28 -6104.58 415843.80 5977054.61 0.00 11547.00 91.240 329.220 4251.01 4180.21 7537.00 4383.17 -6155.74 415793.54 5977141.02 0.00 11647.00 91.240 329.220 4248.85 4178.05 7631.17 4469.07 -6206.90 415743.28 5977227.44 0.00 11747.00 91.240 329.220 4246.68 4175.88 7725.35 4554.96 -6258.07 415693.02 5977313.85 0.00 11847.00 91.240 329.220 4244.52 4173.72 7819.52 4640.85 -6309.23 415642.76 5977400.26 0.00 11947.00 91.240 329.220 4242.35 4171.55 7913.69 4726.75 -6360.39 415592.49 5977486.68 0.00 12047.00 91.240 329.220 4240.19 4169.39 8007.87 4812.64 -6411.55 415542.23 5977573.09 0.00 12147.00 91.240 329.220 4238.03 4167.23 8102.04 4898.53 -6462.72 415491.97 5977659.51 0.00 12247.00 91.240 329.220 4235.86 4165.06 8196.21 4984.43 -6513.88 415441.71 5977745.92 0.00 12347.00 91.240 329.220 4233.70 4162.90 8290.39 5070.32 -6565.04 415391.45 5977832.33 0.00 12447.00 91.240 329.220 4231.53 4160.73 8384.56 5156.22 -6616.20 415341.19 5977918.75 0.00 12547.00 91.240 329.220 4229.37 4158.57 8478.73 5242.11 -6667.37 415290.93 5978005.16 0.00 12647.00 91.240 329.220 4227.21 4156.41 8572.91 5328.00 -6718.53 415240.67 5978091.57 0.00 12747.00 91.240 329.220 4225.04 4154.24 8667.08 5413.90 -6769.69 415190.41 5978177.99 0.00 12847.00 91.240 329.220 4222.88 4152.08 8761.25 5499.79 -6820.85 415140.15 5978264.40 0.00 12947.00 91.240 329.220 4220.71 4149.91 8855.42 5585.68 -6872.01 415089.89 5978350.81 0.00 13047.00 91.240 329.220 4218.55 4147.75 8949.60 5671.58 -6923.18 415039.63 5978437.23 0.00 13147.00 91.240 329.220 4216.39 4145.59 9043.77 5757.47 -6974.34 414989.37 5978523.64 0.00 13175.91 91.240 329.220 4215.76 4144.96 9071.00 5782.30 -6989.13 414974.84 5978548.62 0.00 WELLPATH COMPOSITION - Ref Wellbore: NDBi-043 NAD27 Ref Wellpath: NDBi-43 Rev C.1 NAD27 Start MD [ft] End MD [ft] Positional Uncertainty Model Log Name/Comment Wellbore Survey Date 47.00 13175.91 BH No Uncertainty Plan NDBi-043 NAD27 4/30/2023 Page 6 of 6Wellpath Report 5/1/2023file:///C:/WellArchitect/NDBi-43_Rev_C.1_NAD27.xml NDBi-043 PTD AOGCC 6-7-23 - 22 - 06-Jun-23 Attachment 3: BOPE Equipment 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # 21 - 1 / 4 " X 2 , 0 0 0 # FO R W A R D 13 - 5 / 8 " X 5 , 0 0 0 # 13 - 5 / 8 " X 5 , 0 0 0 # 30 " 13 - 5 / 8 " X 5 , 0 0 0 # 18 6 " 13 - 5 / 8 " X 5 , 0 0 0 # DU T C H L O C K D O W N Ch o k e Li n e fr o m BO P Pr e s s u r e Ga u g e 15 0 2 Pr e s s u r e Se n s o r Pr e s s u r e Tr a n s d u c e r Bi l l o f Ma t e r i a l It e m De s c r i p t i o n To Pa n i c Li n e It e m De s c r i p t i o n A3 Ͳ1/ 8 ” – 5 , 0 0 0 ps i W . P . Re m o t e Hy d r a u l i c Op e r a t e d Ch o k e B3 Ͳ1/ 8 ” – 5, 0 0 0 ps i W. P . Ad j u s t a b l e Ma n u a l Ch o k e 1– 1 4 3 Ͳ1/ 8 ” – 5 , 0 0 0 ps i W . P . Ma n u a l Ga t e Va l v e 15 2 1/ 1 6 ” 5 0 0 0 i W P 15 2Ͳ1/ 1 6 ” – 5,00 0 ps iW.P. Ma n u a l Ga t e Va l v e To Mu d Ga s Le g e n d Bl i n d Sp a r e To Ti g e r Ta n k Se p a r a t o r Va l v e No r m a l l y O p e n Va l v e No r m a l l y C l o s e d NDBi-043 PTD AOGCC 6-7-23 - 27 - 06-Jun-23 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. Washouts/Hole Enlargement Keep mud cool, optimize pump rates, minimize any excess circulation. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Shallow Gas Shallow hazards assessment, sufficient mud weight, on site surveillance (mud loggers, trained drilling personnel). Shallow Fault Fault crossing in shallow hole section. Well trajectory is parallel to the fault, but the fault appears to be very small but could potentially present a lost circulation or WBS risk 12-1/4” Production Hole Section Hazard Mitigations Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Washouts/Hole Enlargement Drill with oil based mud, maintain mud in specifications, use sufficient mud weight to hold back formations. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight to hold back formations. 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. NDBi-043 PTD AOGCC 6-7-23 - 28 - 06-Jun-23 8-1/2” Production Hole Section Hazard Mitigations Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Monitor ECD with MWD tools. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight to hold back formations. Wellbore Instability Maintain adequate mud weight for wellbore stability. Monitor cuttings returns, LWD logs, and drilling parameters for signsof washout. Limit time out of TN3 in PB1 wellbore. Unable To Sidetrack Drill PB1 wellbore first with hard turn up. Follow proper open hole sidetrack procedure and plan to Kick off low side where PB1 plan deviates from original wellbore. Have bent motor assembly on location if sidetrack cannot be achieved with RSS. *Note that no H2S has been encountered on nearby offset well, and H2S is not anticipated in this well. NDBi-043 PTD AOGCC 6-7-23 - 29 - 06-Jun-23 Attachment 5: Leak Off Test Procedure 1. Drill out shoe track, cement plus minimum of 20’ of new formation. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight-in is equal to mud weight-out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe. 4. Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above expected test pressure. a. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string. 6. Verify the hole is filled up and close the BOP (annular or upper pipe ram). 7. Perform the LOT or FIT pumping at a constant rate of 0.25bbl/min. Record pump pressures at 0.25bbl increments. 8. Record and plot the volume pumped against pressure until leak-off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak-off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in-situ stress. c. If FIT skip step 9. 9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 11. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to establish the volume of mud lost to the formation. Top up and close the annulus valve between the casing and the previous casing string. 13. Open the BOP. NDBi-043 PTD AOGCC 6-7-23 - 30 - 06-Jun-23 Attachment 6: Cement Summary Surface Casing Cement Casing Size 13-3/8” 68# L-80 BTC Surface Casing Basis Lead Open hole volume + 250% excess in permafrost / 40% excess below permafrost Lead TOC Surface Tail Open hole volume + 40% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~60 bbls of 10.7 ppg Clean Spacer Lead 10.7ppg Lead: 380.7bbls, 2138cuft, 747.6sks, ArcticCemYield: 2.86 cuft/sk Tail 15.3ppg Tail: 65.2bbls, 366cuft, 292.8sks HalCem Type I/II– 1.25 cuft/sk Temp BHST 53° F Verification Method Cement returns to surface Notes Job will be mixed on the fly Swap to tail cement when lead cement is seen at surface Intermediate Liner Cement Casing Size 9-5/8” 47# L-80 Hydril 563 Intermediate Liner Basis Lead Open hole volume + 30% excess Lead TOC Top of the 9-5/8” Liner. Tail Open hole volume + 30% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 11.8 ppg Clean Spacer Lead 12.0ppg Lead: 244.9bbls, 1375.3cuft, 577.8sks ExtendaCem, Yield: 2.38 cuft/sk Tail 15.3ppg Tail: 42.5bbls, 238.5cuft, 194sks VersaCem Type I/II– 1.23 cuft/sk Temp BHST 99° F Verification Method Cement returns off of top of liner, Ultra Sonic Wireline log, and Monopole Sonic Notes Job will be mixed on the fly Verified cement calcs. -bjm Swap to tail cement when lead cement is seen at surface NDBi-043 PTD AOGCC 6-7-23 - 31 - 06-Jun-23 Attachment 7: Prognosed Formation Tops NDBi-043 Prognosed Tops Formation MD (ft) TVD KB (ft) TVD Path (ft) Uncertainty Range (±ft) Pore Pressure (ppg) Upper Schrader Bluff 1047 901 972 100 7.3 Permafrost Base 1138 990 1061 100 7.6 Middle Schrader Bluff 1798 1590 1661 100 7.8 MCU (Lwr. Sch. Bluff)2371 2017 2088 100 7.9 Tuluvak Shale 2861 2354 2425 100 7.9 Tuluvak Sand 2941 2409 2480 100 10 Seabee 3924 3085 3156 100 9.1 Nanushuk 4964 3735 3806 100 8.9 NT6 MFS 5130 3820 3891 100 8.8 NT5 MFS 5313 3906 3977 100 8.8 NT4 MFS 5454 3966 4037 100 8.8 NT3 MFS 6299 4193 4264 100 8.7 NT 3.2 Top Reservoir (NT3)6585 4214 4285 100 8.7 NDBi-043 PTD AOGCC 6-7-23 - 32 - 06-Jun-23 Attachment 8: Well Schematic NDBi-043 PTD AOGCC 6-7-23 - 33 - 06-Jun-23 Attachment 9: Formation Evaluation Program Hole Section Logging Tool Requirements Surface LWD GR/RES Intermediate I LWD GR/RES/Neu-Den/ Multipole Sonic Intermediate Liner Wireline Ultra Sonic Production Hole LWD GR / RES / Neu-Den / Monopole Sonic (Cement Evaluation 9-5/8” liner)/ Ultradeep Res PB1 LWD GR / RES / Neu-Den / Monopole Sonic / Ultradeep Res Mud Logging Sample Collection Program Depth Interval (ft)*Sampling type Frequency Comments Conductor- TD Samplex Sample Trays Samples available for Wellsite Geologist for every cuttings sample collected Conductor - TD Mud At the beginning, middle and the end of each section and any significant change of mud properties Conductor –6,150’Washed & Dried 2 sets (Santos, AOGCC)30’ –50’ MD Additional spot samples if shows or if requested by WSG. Sampling rate is dependent on ROP 4900’ MD -6150’ MD (Upper Nanushuk) Washed & Dried 2 sets (Santos, AOGCC)30’ –50’ MD Be prepared to catch additional samples by request w/in Upper Nanushuk Sampling rate is dependent on ROP 6,150’ MD –6700’ MD (NT3 MFS to landing) Washed & Dried 2 sets (Santos, AOGCC)10’ MD Increased density through zone-of- interest: NT3 MFS to landing *Request to Slow ROP 6,700-13,173 (TD) (Lateral) Washed & Dried 2 sets (Santos, AOGCC)30’ MD Target 30’ samples but 50’ acceptable as needed based on ROP PB1 Washed & Dried 2 sets (Santos, AOGCC)30’ MD 30’ samples for depofacies evaluation and identifying top reservoir *All Depth intervals are approximate and depend on as drilled formation markers. NDBi-043 PTD AOGCC 6-7-23 - 34 - 06-Jun-23 Attachment 10: Wellhead & Tree Diagram NDBi-043 PTD AOGCC 6-7-23 - 35 - 06-Jun-23 Attachment 11: Area of Review There will be no existing wells that are within ¼ mile of the planned trajectory in the injection zone Nanushuk 3 reservoir. 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:Thompson, Jacob (Jacob) To:McLellan, Bryan J (OGC) Subject:RE: NDBi-043 Anti-collision scan Date:Friday, June 23, 2023 10:56:16 AM Attachments:image002.jpg image003.png image004.png image005.png image006.jpg B-43_Rev_C.0_CR.pdf Brian, There are no existing wells in the clearance scan area. Just planned well to be drilled later in the development. The attached clearance scan is in NAD83, but that does not change the scan results. The clearance scan indicates a failed result against NDBi-030 however, this is because it has crossed a clearance factor threshold requiring us to perform a risk assessment and secure the well while drilling by. As I mentioned above this well does not exist, but we will have a close approach when we drill the NDBi-030 well. Probably more than you wanted to know but just giving you a heads up. Thanks, Jacob Thompson – Senior Drilling Engineer Oil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) 646-7079| m: +1 (907) 854-4377 Jacob.Thompson@santos.com https://www.santos.com/ From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 22, 2023 3:55 PM To: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Subject: ![EXT]: NDBi-043 Anti-collision scan Jake, Can you send me the anti-collision scan for the directional plan on this well? I am assuming there are no wellbores nearby, but just checking. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 REFERENCE WELLPATH IDENTIFICATION Operator Santos Well B-43 Field Pikka API/Legal Facility Pikka Wellbore B-43 Slot B-43 REPORT SETUP INFORMATION Projection System NAD83 / TM Alaska SP, Zone 4 (5004), US feet Software System WellArchitect® 6.0 North Reference True User Meyedavr Scale 0.999907 Report Generated 4/19/2023 at 3:37:47 PM Convergence at slot 0.60° West Database WellArchitectDB WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude Slot Location -230.73 -1478.65 1561935.53 5972442.40 70°20'6.7188"N 150°38'12.2560"W Facility Reference Pt 1563416.33 5972657.91 70°20'8.9895"N 150°37'29.0730"W Field Reference Pt 1563416.33 5972657.91 70°20'8.9895"N 150°37'29.0730"W WELLPATH DATUM Calculation method Minimum Curvature Rig on B-43 (RT) to Facility Vertical Datum 70.80ft Horizontal Reference Pt Slot RigonB-43(RT)toMeanSeaLevel 70.80ft Vertical Reference Pt Rig on B-43 (RT) RigonB-43(RT)toGroundLevelat Slot (B-43) 70.80ft MD Reference Pt Rig on B-43 (RT) Field Vertical Reference Mean Sea Level Closest Approach Clearance Summary Report B-43 Rev C.0 -Santos - Stop Drilling HSE Risk (SF <1.25) Page 1 of 3 POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 2.79 Std Dev Ellipse Start MD 47.00ft Surface Position Uncertainty included Declination 14.80° East of TN Dip Angle 80.59°Mag Field Strength 57197 nT Slot Surface Uncertainty @1SD Horizontal 0.500ft Vertical 0.500ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal planes Page 1 of 3Clearance Summary Report 4/19/2023file:///C:/WellArchitect/B-43_Rev_C.0_CR.xml.html REFERENCE WELLPATH IDENTIFICATION Operator Santos Well B-43 Field Pikka API/Legal Facility Pikka Wellbore B-43 Slot B-43 Closest Approach Clearance Summary Report B-43 Rev C.0 -Santos - Stop Drilling HSE Risk (SF <1.25) Page 2 of 3 PROXIMITY-SCAN RULE Rule Name Santos - Stop Drilling HSE Risk (SF <1.25)Rule Based On Ratio Plane of Rule Closest Approach Threshold Value 1.25 IncludeCasing&HoleSize yes Apply Cone of Safety no SURVEY PROGRAM - Ref Wellbore: B-43 Ref Wellpath: B-43 Rev C.0 Start MD [ft] End MD [ft] Positional Uncertainty Model Log Name/Comment Wellbore 47.00 2591.10 OWSG MWD rev2 (MS+IFR2, SAG) B-43 2591.10 6125.00 OWSG MWD rev2 (MS+IFR2, SAG) B-43 6125.00 13438.44 OWSG MWD rev2 (MS+IFR2, SAG) B-43 Page 2 of 3Clearance Summary Report 4/19/2023file:///C:/WellArchitect/B-43_Rev_C.0_CR.xml.html REFERENCE WELLPATH IDENTIFICATION Operator Santos Well B-43 Field Pikka API/Legal Facility Pikka Wellbore B-43 Slot B-43 CALCULATION RANGE & CUTOFF From:47.00ft MD To:13175.91ft MD C-C Cutoff:(none) Closest Approach Clearance Summary Report B-43 Rev C.0 -Santos - Stop Drilling HSE Risk (SF <1.25) Page 3 of 3 OFFSET WELL CLEARANCE SUMMARY (17 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane Offset Facility Offset Slot Offset Well Offset Wellbore Offset Wellpath Wellbore Status C-C Clearance Distance Rule Separation Ratio Ref MD [ft] Min C-C Clear Dist [ft] Diverging from MD [ft] Ref MD of Min Ratio [ft] Min Ratio Min Ratio Dvrg from [ft] Rule Status Pikka B-30 B-30 B-30 B-30 Rev B.0 Planned 13175.91 87.87 13175.91 13175.91 1.13 13175.91 FAIL Pikka B-44 B-44 B-44 B-44 Rev A.0 Planned 443.97 21.20 13175.91 501.54 2.17 13175.91 PASS Pikka B-40 B-40 B-40 B-40 Rev A.0 Planned 1163.12 37.67 1163.12 1268.07 2.57 6247.00 PASS Pikka B-37 B-37 B-37 B-37 Rev A.0 Planned 47.00 118.98 13175.91 13175.91 3.60 13175.91 PASS Pikka B-34 B-34 B-34 B-34 Rev A.0 Planned 47.00 179.11 11247.00 13175.91 3.61 13175.91 PASS Pikka B-41 B-41 B-41 B-41 Rev A.0 Planned 47.00 38.93 7747.00 521.58 4.40 10247.00 PASS Pikka B-38 B-38 B-38 B-38 Rev A.0 Planned 1233.84 73.00 1233.84 1506.87 4.56 5947.00 PASS Pikka B-45 B-45 B-45 B-45 Rev A.0 Planned 47.00 41.24 347.00 610.75 4.60 6547.00 PASS Pikka B-36 B-36 B-36 B-36 Rev A.0 Planned 47.00 139.02 500.00 2647.13 5.70 2647.13 PASS Pikka B-39 B-39 B-39 B-39 Rev A.0 Planned 47.00 78.99 8847.00 11373.44 6.24 11373.44 PASS Pikka B-33 B-33 B-33 B-33 Rev A.0 Planned 1388.00 162.00 1388.00 2149.11 6.87 2247.00 PASS Pikka B-46 B-46 B-46 B-46 Rev A.0 Planned 484.99 61.19 6347.00 602.91 6.99 8347.00 PASS Pikka B-31 B-31 B-31 B-31 Rev A.0 Planned 1365.16 228.35 1365.16 2647.00 7.34 2647.00 PASS Pikka B-51 B-51 B-51 B-51 Rev A.0 Planned 47.00 161.38 13175.91 12885.06 8.70 13175.91 PASS Pikka B-50 B-50 B-50 B-50 Rev A.0 Planned 457.60 141.35 457.60 2720.90 9.71 7247.00 PASS Pikka B-48 B-48 B-48 B-48 Rev A.0 Planned 519.58 101.27 519.58 667.38 11.61 8147.00 PASS Pikka B-49 B-49 B-49 B-49 Rev A.0 Planned 47.00 121.32 13175.91 2304.35 12.22 13175.91 PASS Page 3 of 3Clearance Summary Report 4/19/2023file:///C:/WellArchitect/B-43_Rev_C.0_CR.xml.html Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. obtained according to the sampling program described in Attachment 9. SFD 223-051 PIKKA NDB-043 PB1 PIKKA, NANUSHUK OIL EC K L I S T pa n y Oi l S e a r c h ( A l a s k a ) , L L C We l l N a m e : PI K K A N D B i - 0 4 3 P B 1 In i t i a l C l a s s / T y p e SE R / W A G I N Ge o A r e a 89 0 Un i t 11 5 8 0 On / O f f S h o r e On Pr o g r a m SE R Fi e l d & P o o l We l l b o r e s An n u l a r D i PI K K A , N A N U S H U K O I L - 6 0 0 1 0 0 NA Pe r m i t f e e a t t a c h e d Ye s S u r f a c e L o c a t i o n l i e s w i t h i n A D L 0 3 9 2 9 8 4 ; T o p P r o d u c t i v e I n t e r v a l l i e s i n A D L 0 3 9 1 4 4 5 ; T D l i e s i n A D L 0 3 9 3 0 2 Le a s e n u m b e r a p p r o p r i a t e Ye s Un i q u e w e l l n a m e a n d n u m b e r No P I K K A , N A N U S H U K O I L - 6 0 0 1 0 0 P o o l R u l e s o r d e r c u r r e n t l y i n p r o g r e s s . We l l l o c a t e d i n a d e f i n e d p o o l Ye s I n i t i a l w e l l t o d e t e r m i n e r e s e r v o i r d e p t h a n d t h i c k n e s s i n t h i s a r e a . W i l l b e s u b s e q u e n t l y r e d r i l l e d a s a We l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y Ye s s e r v i c e i n j e c t i o n w e l l . We l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s Su f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s If d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s Op e r a t o r o n l y a f f e c t e d p a r t y Ye s 0 Op e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s Pe r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 2 Pe r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 3 Ca n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 4 We l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r s NA N o n e c u r r e n t l y 5 Al l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 6 Pr e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 7 No n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) Ye s 8 Co n d u c t o r s t r i n g p r o v i d e d Ye s 9 Su r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s 0 CM T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s CM T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s 2 CM T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 3 Ca s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s 4 Ad e q u a t e t a n k a g e o r r e s e r v e p i t NA 5 If a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s 6 Ad e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d Ye s 7 If d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s 8 Dr i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s 9 BO P E s , d o t h e y m e e t r e g u l a t i o n Ye s M P S P = 1 5 4 5 p s i . B O P r a t e d t o 5 k p s i , ( T e s t t o 3 0 0 0 p s i ) 0 BO P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s Ch o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 2 Wo r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n No 3 Is p r e s e n c e o f H 2 S g a s p r o b a b l e Ye s T h i s i s t h e f i r s t w e l l t o b e d r i l l e d i n t h e a r e a . 4 Me c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) Ye s N o n e a n t i c i p a t e d b a s e d o n n e a r b y w e l l s . 5 Pe r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s T u l u v a k s a n d s a t a b o u t 2 9 4 1 ' M D a r e e x p e c t e d t o b e o v e r - p r e s s u r e d ( 1 0 . 0 p p g ) a n d l i k e l y g a s - b e a r i n g . 6 Da t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA E x p e c t e d P r e s s u r e R a n g e i s 0 . 3 7 9 t o 0 . 5 1 9 p s i / f t ( 7 . 3 t o 1 0 p p g E M W ) . O p e r a t o r ' s p l a n n e d m u d p r o g r a m 7 Se i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA a p p e a r s s u f f i c i e n t t o c o n t r o l a n t i c i p a t e d p r e s s u r e s a n d m a i n t a i n w e l l b o r e s t a b i l i t y . 8 Se a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 9 Co n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e JL C 6 / 3 0 / 2 3
