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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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s 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 No No 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 1/ 2 4 / 2 0 2 4 20 6 8 1 1 1 2 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 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 20 6 8 1 1 1 2 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 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 79 4 8 1 0 8 9 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ P r o c e s s e d L o g - Pr e l i m i n a r y . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 79 4 8 1 0 8 9 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ R a w . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 22 8 9 5 1 1 3 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ P r o c e s s e d L o g - Pr e l i m i n a r y . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 22 8 9 5 1 1 3 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ R a w . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 10 9 9 9 1 7 8 3 9 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 4 L W D Re s i s t i v i t y F i n a l . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 1 _ R M _ 2 0 2 3 1 1 0 5 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 2 _ R M _ 2 0 2 3 1 1 1 6 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 3 _ R M _ 2 0 2 3 1 1 2 8 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 4 _ R M _ 2 0 2 3 1 2 0 5 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 5 _ R M _ 2 0 2 3 1 2 1 5 . l a s 38 3 3 9 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 1 o f 1 1 Su p p l i e d b y Op Su p p l i e d b y Op 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 1/ 2 4 / 2 0 2 4 95 1 7 8 4 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 4 _ D M D _ R M _ 1 7 8 3 9 f t . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 1 _ R M _ 2 0 2 3 1 1 0 5 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 2 _ R M _ 2 0 2 3 1 1 1 6 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 3 _ R M _ 2 0 2 3 1 1 2 8 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 4 _ R M _ 2 0 2 3 1 2 0 5 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 5 _ R M _ 2 0 2 3 1 2 1 5 . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 11 0 1 7 8 4 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 4 _ L W D _ R M _ 1 7 8 3 9 f t . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 11 0 0 0 1 7 8 3 9 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 : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 11 1 1 8 1 7 8 4 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 - 0 4 4 Ad v a n c e d Ga s _ G e o I s o t o p e s _ C O R R E C T E D _ 1 7 8 3 9 f t . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 12 8 1 7 8 3 9 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 4 _ D r i l l G a s L i t h o _ d e p t h _ 1 7 8 3 9 f t M D . l a s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 P l a n v i e w . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 V e r t i c a l S e c t i o n . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 - N A D 2 7 . t x t 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 . t x t 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 . x l s x 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e f i n i t i v e S u r v e y Re p o r t - N A D 2 7 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e f i n i t i v e S u r v e y Re p o r t - N A D 8 3 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . d l i s 38 3 3 9 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 2 o f 1 1 ND B i - , 044 _ L W D _ R M _ 1 7 8 3 9 ft. l a s ND B i - , 044 _ D r i l l Gas L i t h o _ d e p t h _ 1 7 8 3 9 ft M D . 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . P D F 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 _ d l i s . t x t 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . P D F 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 _ d l i s . t x t 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ P r o c e s s e d L o g - Pr e l i m i n a r y . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ R a w . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r e l i m i n a r y R e p o r t . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y - V2 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y - V 2 . t i f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y . t i f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ P r o c e s s e d L o g - Pr e l i m i n a r y . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ R a w . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ E a r t h S t a r _ I m a g e s . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ E a r t h S t a r _ I m a g e s . v e r 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ S t r a t a s t a r _ I m a g e s . d l i s 38 3 3 9 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 3 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ S t r a t a s t a r _ I m a g e s . v e r 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . d l i s 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l M D . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l T V D . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ A P _ R M _ 2 0 2 3 1 2 1 5 . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ A P _ R M _ 2 0 2 3 1 2 1 5 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ D M D _ R M _ 1 7 8 3 9 f t . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ D M D _ R M _ 1 7 8 3 9 f t . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ D M T _ R M _ 2 0 2 3 1 2 1 5 . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ D M T _ R M _ 2 0 2 3 1 2 1 5 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 M D G a m m a Re s i s t i v i t y . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 M D G a m m a Re s i s t i v i t y . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 T V D G a m m a Re s i s t i v i t y . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 T V D G a m m a Re s i s t i v i t y . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 M D G a m m a R e s i s t i v i t y De n s i t y N e u t r o n . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 M D G a m m a R e s i s t i v i t y De n s i t y N e u t r o n . p d f 38 3 3 9 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 4 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 T V D G a m m a Re s i s t i v i t y D e n s i t y N e u t r o n . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 T V D G a m m a Re s i s t i v i t y D e n s i t y N e u t r o n . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . c g m 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . P D F 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 M u d l o g g i n g D a i l y Re p o r t s c o m p i l a t i o n . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 A d v a n c e d Ga s _ G 5 _ C o m p o s i t e _ 1 7 8 3 9 f t _ F i n a l . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 A d v a n c e d Ga s _ G e o I s o t o p e s _ C o m p o s i t e _ 1 7 8 3 9 f t _ F i n a l . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ G a s R a t i o L o g _ 2 ' ' _ 1 7 8 3 f t M D . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ G a s R a t i o L o g _ 5 ' ' _ 1 7 8 3 f t M D . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ L i t h o l o g y . x l s x 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ M u d l o g _ 2 ' ' _ 1 7 8 3 9 f t MD . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ M u d l o g _ 5 ' ' G R _ 1 7 8 3 9 f t M D . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 0 0 0 0 - 1 0 0 5 0 f t _ # 0 3 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 0 4 0 0 - 1 0 4 4 0 f t _ # 0 4 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 0 6 5 0 - 1 0 6 8 0 f t _ # 0 5 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 0 8 4 0 - 1 0 8 9 0 f t _ # 0 6 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 1 0 8 5 - 1 1 1 0 0 f t _ # 0 7 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 1 1 9 0 - 1 1 4 0 0 f t _ # 0 8 . p d f 38 3 3 9 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 5 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 1 4 0 0 - 1 1 8 0 0 f t _ # 0 9 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 1 7 0 0 - 1 2 1 0 0 f t _ # 1 0 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 2 1 0 0 - 1 2 6 0 0 f t _ # 1 1 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 2 6 0 0 - 1 3 1 0 0 f t _ # 1 2 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 3 1 0 0 - 1 3 6 0 0 f t _ # 1 3 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 3 6 0 0 - 1 4 1 0 0 f t _ # 1 4 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 4 1 0 0 - 1 4 6 0 0 f t _ # 1 5 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 4 6 0 0 - 1 5 1 0 0 f t _ # 1 6 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 5 1 0 0 - 1 5 6 0 0 f t _ # 1 7 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 1 5 6 0 0 - 1 6 1 0 0 f t _ # 1 8 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 9 7 1 0 - 9 7 4 0 f t _ # 0 1 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 4 E l e c t r o n i c F i l e : S h o w R e p o r t G e o l o g _ N D B i - 04 4 _ 9 8 4 0 - 9 8 7 0 f t _ # 0 2 . p d f 38 3 3 9 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 11 0 1 7 8 4 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 4 _ L W D _ R M _ 1 7 8 3 9 f t . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 1 _ R M _ 2 0 2 3 1 1 0 5 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 2 _ R M _ 2 0 2 3 1 1 1 6 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 3 _ R M _ 2 0 2 3 1 1 2 8 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 4 _ R M _ 2 0 2 3 1 2 0 5 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ A P _ R 0 5 _ R M _ 2 0 2 3 1 2 1 5 . l a s 38 4 5 0 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 6 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 2/ 9 / 2 0 2 4 95 1 7 8 4 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 4 _ D M D _ R M _ 1 7 8 3 9 f t . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 1 _ R M _ 2 0 2 3 1 1 0 5 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 2 _ R M _ 2 0 2 3 1 1 1 6 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 3 _ R M _ 2 0 2 3 1 1 2 8 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 4 _ R M _ 2 0 2 3 1 2 0 5 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 ### # # # # #### # # # # # 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 4 _ D M T _ R 0 5 _ R M _ 2 0 2 3 1 2 1 5 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 20 6 8 1 1 1 2 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 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 20 6 8 1 1 1 2 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 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 79 4 8 1 0 8 9 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ P r o c e s s e d L o g - Pr e l i m i n a r y . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 79 4 8 1 0 8 9 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ R a w . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 22 8 9 5 1 1 3 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ P r o c e s s e d L o g - Pr e l i m i n a r y . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 22 8 9 5 1 1 3 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 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ R a w . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 11 0 0 0 1 7 8 3 9 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 : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 10 9 9 9 1 7 8 3 9 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 4 L W D Re s i s t i v i t y F i n a l . l a s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 . P D F 38 4 5 0 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 7 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ C B L _ 2 0 6 0 _ 1 1 1 2 0 _ d l i s . t x t 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 . P D F 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ S D T K _ T O C _ 2 0 6 0 _ 1 1 1 2 0 _ d l i s . t x t 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ P r o c e s s e d L o g - Pr e l i m i n a r y . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ B o t t o m _ R a w . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r e l i m i n a r y R e p o r t . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y - V2 . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y - V 2 . t i f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ P r o c e s s e d L o g - P r e l i m i n a r y . t i f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ P r o c e s s e d L o g - Pr e l i m i n a r y . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ C A S T - CB L _ 0 2 D E C 2 3 _ T o p _ R a w . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : S a n t o s _ N D B i - 04 4 _ M D 5 _ M E M _ S D T K _ D T S . P D F 38 4 5 0 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 8 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 M D G a m m a Re s i s t i v i t y . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 T V D G a m m a Re s i s t i v i t y . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 M D G a m m a R e s i s t i v i t y De n s i t y N e u t r o n . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 T V D G a m m a Re s i s t i v i t y D e n s i t y N e u t r o n . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ A P _ R M _ 2 0 2 3 1 2 1 5 . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ D M D _ R M _ 1 7 8 3 9 f t . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ D M T _ R M _ 2 0 2 3 1 2 1 5 . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 M D G a m m a Re s i s t i v i t y . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 2 T V D G a m m a Re s i s t i v i t y . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 M D G a m m a R e s i s t i v i t y De n s i t y N e u t r o n . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ L W D _ R M _ 1 7 8 3 9 f t _ 5 T V D G a m m a Re s i s t i v i t y D e n s i t y N e u t r o n . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ A P _ R M _ 2 0 2 3 1 2 1 5 . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ D M D _ R M _ 1 7 8 3 9 f t . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 04 4 _ D M T _ R M _ 2 0 2 3 1 2 1 5 . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l M D . c g m 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l T V D . c g m 38 4 5 0 ED Di g i t a l D a t a Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 9 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s 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 DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 F i n a l S u r v e y R e p o r t fr o m S a n t o s . x l s x 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l M D . e m f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l T V D . e m f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ E a r t h S t a r _ I m a g e s . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ E a r t h S t a r _ I m a g e s . v e r 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ S t r a t a s t a r _ I m a g e s . d l i s 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 _ S t r a t a s t a r _ I m a g e s . v e r 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l M D . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l T V D . p d f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l M D . t i f 38 4 5 0 ED Di g i t a l D a t a DF 2/ 9 / 2 0 2 4 E l e c t r o n i c F i l e : N D B i - 0 4 4 D e e p R e s i s t i v i t y L W D Fi n a l T V D . t i f 38 4 5 0 ED Di g i t a l D a t a DF 12 / 6 / 2 0 2 4 E l e c t r o n i c F i l e : W T - X A K - 0 1 2 7 . 3 _ E n d o f W e l l Re p o r t _ N D B i - 0 4 4 _ R e v A _ S i g n e d . p d f 39 8 3 5 ED Di g i t a l D a t a DF 11 / 2 1 / 2 0 2 5 E l e c t r o n i c F i l e : S a n t o s _ P i k k a _ N D B i - 0 4 4 _ E n d o f We l l C l e a n - U p D a t a R e p o r t _ 1 - m i n _ F i n a l . x l s x 39 8 3 5 ED Di g i t a l D a t a DF 11 / 2 1 / 2 0 2 5 E l e c t r o n i c F i l e : S a n t o s _ P i k k a _ N D B i - 0 4 4 _ E n d o f We l l C l e a n - U p D a t a R e p o r t _ 3 0 - m i n _ F i n a l . x l s x 39 8 3 5 ED Di g i t a l D a t a DF 11 / 2 1 / 2 0 2 5 E l e c t r o n i c F i l e : W T - X A K - 0 1 2 7 . 3 _ E n d o f W e l l Re p o r t _ N D B i - 0 4 4 _ R e v A _ S i g n e d . p d f 39 8 3 5 ED Di g i t a l D a t a DF 11 / 1 9 / 2 0 2 5 10 9 1 3 1 7 8 5 8 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 : S A N T O S _ N D B i - 04 4 _ B H P _ 8 _ 5 i n _ 1 1 1 1 4 _ 1 7 7 8 3 f t _ R U N 5 . l a s 41 1 2 4 ED Di g i t a l D a t a DF 11 / 1 9 / 2 0 2 5 E l e c t r o n i c F i l e : S A N T O S _ N D B i - 04 4 _ B H P _ 8 _ 5 i n _ 1 1 1 1 4 _ 1 7 7 8 3 f t _ R U N 5 . d l i s 41 1 2 4 ED Di g i t a l D a t a 12 / 2 8 / 2 0 2 3 12 8 1 7 8 3 9 91 8 6 7 Cu t t i n g s Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 1 0 o f 1 1 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 . 5 0 - 1 0 3 - 2 0 8 6 5 - 0 0 - 0 0 We l l N a m e / N o . P I K K A N D B i - 0 4 4 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 12 / 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 8 7 0 Op e r a t o r O i l S e a r c h ( A l a s k a ) , L L C MD 17 8 3 9 TV D 41 4 9 Cu r r e n t S t a t u s WA G I N 1/ 9 / 2 0 2 6 UI C Ye s IN F O R M A T I O N R E C E I V E D 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 : 12 / 1 9 / 2 0 2 3 Re l e a s e D a t e : 10 / 1 7 / 2 0 2 3 Fr i d a y , J a n u a r y 9 , 2 0 2 6 AO G C C Pa g e 1 1 o f 1 1 M. G u h l 1 / 9 / 2 0 2 6 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION Well clean up data for 19 wells Details are provided on following pages with well name and API table as reference. Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh 601 W 5th Ave., Anchorage, AK 99501 shannon.koh@santos.com DATE: 11/20/2025 From: Shannon Koh Santos 601 W 5th Ave. Anchorage, AK 99501 To: Gavin Glutas AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 TRANSMISSION TYPE: ܈External Request ܆Internal Request TRANSMISSION METHOD: ܆CD ܆ Thumb Drive ܆Email ܆SharePoint/Teams ܆Hardcopy ܈Other - FTP REASON FOR TRANSMITTAL: ܆Approved ܆Approved with Comments ܆For Approval ܈Information Only ܆For Your Review ܆For Your Use ܆To Be Returned ܆With Our Comments ܆Other COMMENTS: Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.21 09:00:44 -09'00' LETTER OF TRANSMITTAL Well API NDB-010 50103209200000 NDB-011 50103209160000 NDBi-014 50103208690000 NDBi-016 50103208920000 NDBi-018 50103208880000 NDB-024 50103208620000 NDB-025 50103208770000 NDBi-030 50103208730000 NDB-031 50103209120000 NDB-032 50103208600000 NDBi-036 50103209080000 NDB-037 50103208950000 NDBi-043A 50103208590100 NDBi-044 50103208650000 NDBi-046L1 50103208830000 NDB-048 50103209020000 NDBi-049 50103208940000 NDBi-050 50103209040000 NDB-051 50103208800000 جؐؐؐNDB-010 ؒ Santos_Pikka_NDB-010_End of Well Data Report_1 min_FINAL (1).xlsx ؒ Santos_Pikka_NDB-010_End of Well Data Report_30 min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-010_Rev A (1).pdf ؒ جؐؐؐNDB-011 ؒ Santos_Pikka_NDB-011_End of Well Data Report_1 min_FINAL (1).xlsx ؒ Santos_Pikka_NDB-011_End of Well Data Report_30 Min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-011_Rev A (1).pdf ؒ جؐؐؐNDB-014 ؒ Santos_Pikka_NDBi-014_End of Well Clean-up Data Report_30 Minute_Final Data.xlsx ؒ Santos_Pikka_NDBi-014__End of Well Clean-up Data Report_1 Minute_Final Data.xlsx ؒ WT-XAK-0127.3_NDBi-014_Rev A_Signed.pdf ؒ جؐؐؐNDB-024 ؒ Santos_Pikka_NDB-024_End of Well Clean-Up Data Report_ 30-min_Final (2).xlsx ؒ Santos_Pikka_NDB-024_End of Well Clean-Up Data Report_1-min_Final (2).xlsx ؒ WT-XAK-0127.2_End of Well Clean-Up Data Report_NDB-024_Rev A_Signed.pdf 225-061 T41152 225-048 T41153 223-076 T39828 223-105 T39831 NDBi-044 50103208650000 LETTER OF TRANSMITTAL ؒ جؐؐؐNDB-025 ؒ Santos_Pikka_NDB-025_End of Well Clean-up Data Report_1-min_Final Data.xlsx ؒ Santos_Pikka_NDB-025_End of Well Clean-up Data Report_30-min_Final Data.xlsx ؒ WT-XAK-0127.4_NDB-025_Rev A signed End of Well Clean-up Data Report.pdf ؒ جؐؐؐNDB-031 ؒ Santos_Pikka_NDB-031_End of Well Clean-up Data Report_1 min_FINAL.xlsx ؒ Santos_Pikka_NDB-031_End of Well Clean-up Data Report_30 min_FINAL.xlsx ؒ WT-XAK-0127.5_NDB-031_Rev A Signed (1).pdf ؒ جؐؐؐNDB-032 ؒ Santos_Pikka_NDB-032_End of Well Clean-up Data Report_ 30 min_Final Data (1).xlsx ؒ Santos_Pikka_NDB-032_End of Well Clean-up Data Report_1 min_Final Data (1).xlsx ؒ WT-XAK-0127.3_NDB-032_Rev A_Signed (2).pdf ؒ جؐؐؐNDB-037 ؒ Santos_Pikka_NDB-037_End of Well Clean-up Data Report_1-min_FINAL (1).xlsx ؒ Santos_Pikka_NDB-037_End of Well Clean-up Data Report_30-min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-037_Rev A_Signed (2).pdf ؒ جؐؐؐNDB-048 ؒ Santos_Pikka_NDB-048_End of Well Clean-up Data Report_1 min_FINAL.xlsx ؒ Santos_Pikka_NDB-048_End of Well Clean-up Data Report_30 min_FINAL (1).xlsx ؒ WT-XAK-0127.5_NDB-048_Rev A_Signed (2).pdf ؒ جؐؐؐNDB-051 ؒ Santos_Pikka_NDB-051_End of Well Clean-up Data Report_1 min_Final Data.xlsx ؒ Santos_Pikka_NDB-051_End of Well Clean-up Data Report_30 min_Final Data.xlsx ؒ WT-XAK-0127.4_NDB-051_Rev A_Signed.pdf ؒ جؐؐؐNDBi-016 ؒ Santos_Pikka_NDBi-016_End of Well Clean-Up_ Data Report_ 1 min_Final Data.xlsx ؒ Santos_Pikka_NDBi-016_End of Well Clean-Up_ Data Report_30 min_Final Data.xlsx ؒ WT-XAK-0127.4_NDBi-016_Rev A_Signed.pdf ؒ جؐؐؐNDBi-018 ؒ Santos_Pikka_NDBi-018_End of Well Clean-up_Build-up Data Report_1 min_Final.xlsx ؒ Santos_Pikka_NDBi-018_End of Well Clean-up_Build-up Data Report_30 min_Final.xlsx ؒ WT-XAK-0127.4_NDBi-018_Rev A_Signed.pdf ؒ جؐؐؐNDBi-030 224-006 T41154 225-028 T41155 224-124 T41156 224-143 T41157 224-105 T41158 224-085 T41159 224-013 T39830 223-006 T39829 223-120 T39832 LETTER OF TRANSMITTAL ؒ Santos_Pikka_NDBi-030_End of Well Clean-up Data Report_1-min_Final Data.xlsx ؒ Santos_Pikka_NDBi-030_End of Well Clean-up Data Report_30 minute_Final Data.xlsx ؒ WT-XAK-0127.3_NDBi-030_Rev A_Signed.pdf ؒ جؐؐؐNDBi-036 ؒ Santos_Pikka_NDBi-036_End of Well Clean-up Data Report_1 min_FINAL.xlsx ؒ Santos_Pikka_NDBi-036_End of Well Clean-up Data Report_30 min_FINAL.xlsx ؒ WT-XAK-0127.5_NDBi-036_Rev A Signed (1).pdf ؒ جؐؐؐNDBi-043A ؒ Santos_Pikka_NDBi-043_Daily Well Test Data Report_09152023_0830 - 09202023_2200_Final (1).xlsx ؒ WT-XAK-0127.1_NDBI-043_End of Well Report_Rev A (1).pdf ؒ جؐؐؐNDBi-044 ؒ Santos_Pikka_NDBi-044_End of Well Clean-Up Data Report_1-min_Final .xlsx ؒ Santos_Pikka_NDBi-044_End of Well Clean-Up Data Report_30-min_Final.xlsx ؒ WT-XAK-0127.3_End of Well Report_NDBi-044_Rev A_Signed.pdf ؒ جؐؐؐNDBi-046L1 ؒ Santos_Pikka_NDBi-046_End of Well Clean-up Data Report_1 min_Final Data.xlsx ؒ Santos_Pikka_NDBi-046_End of Well Clean-up Data Report_30 min_Final Data.xlsx ؒ WT-XAK-0127.4_NDBi-046_Rev A_Signed.pdf ؒ جؐؐؐNDBi-049 ؒ Santos_Pikka_NDBi-049_End of Well Clean-up Data Report_1-min_Final.xlsx ؒ Santos_Pikka_NDBi-049_End of Well Clean-up Data Report_30-min_Final.xlsx ؒ WT-XAK-0127.5_NDBi-049_Rev A Signed.pdf ؒ ؤؐؐؐNDBi-050 Santos_Pikka_NDBi-050_End of Well Clean-up Data Report_1-min_FINAL.xlsx Santos_Pikka_NDBi-050_End of Well Clean-up_Data Report_30-min_FINAL.xlsx WT-XAK-0127.5_NDBi-050_Rev A_Signed (1).pdf 225-012 T41160 224-119 T41161 224-154 T41162 223-052 T39834 223-087 T39835 224-029 T39837 NDBi-044 ؐ 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-044 50103208650000 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-044 Lithotrak Caliper data 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Well Cleanup Oil Search Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,839 feet N/A feet true vertical 4,149 feet N/A feet Effective Depth measured 17,832 feet See attached feet true vertical 4,048 feet feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 4-1/2" P-110S 17,832' MD 4,149' TVD Packers and SSSV (type, measured and true vertical depth) See attached report 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Scott Leahy Contact Email:scott.leahy@santos.com Authorized Title: Completions Specialist Contact Phone: 907-646-7063 324-012 Sr Pet Eng: 9,210 Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD See attached report from Schlumberger measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 392984, 391445, 393021, 393019 Pikka / Nanushuk Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-087 50-103-20865-00-00 900 E Benson Boulevard, Suite 500 Anchorage, AK 99508 3. Address: NDBi-044 See attached report from Schlumberger Length 128 2,514 128Conductor Surface Intermediate 20"x34" 13-3/8" Size 128 9-5/8" 11,590 4-1/2" measured TVD Production Liner 8,751 10,858 7,009 Casing Structural 4,112 4,149 4-1/2" 11,114 17,832 10,859 4,056 Plugs Junk measured Collapse 2,260 4,750 9,210 5,020 6,870 11,590 6,870 4,750Tie-Back 2,363 9-5/8" 2,363 2,197 2,514 2,300 Burst p k ft t Fra O s 223 6.A G L PG , p Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 03/26/2024 By Meredith Guhl at 9:53 am, Dec 06, 2024 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Well Cleanup Oil Search Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,839 feet N/A feet true vertical 4,149 feet N/A feet Effective Depth measured 17,832 feet See attached feet true vertical 4,048 feet feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 4-1/2" P-110S 17,832' MD 4,149' TVD Packers and SSSV (type, measured and true vertical depth) See attached report 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Scott Leahy Contact Email:scott.leahy@santos.com Authorized Title: Completions Specialist Contact Phone: 907-646-7063 324-012 Sr Pet Eng: 9,210 Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD See attached report from Schlumberger measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 392984, 391445, 393021, 393019 Pikka / Nanushuk Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-087 50-103-20865-00-00 900 E Benson Boulevard, Suite 500 Anchorage, AK 99508 3. Address: NDBi-044 See attached report from Schlumberger Length 128 2,514 128Conductor Surface Intermediate 20"x34" 13-3/8" Size 128 9-5/8" 11,590 4-1/2" measured TVD Production Liner 8,751 10,858 7,009 Casing Structural 4,112 4,149 4-1/2" 11,114 17,832 10,859 4,056 Plugs Junk measured Collapse 2,260 4,750 9,210 5,020 6,870 11,590 6,870 4,750Tie-Back 2,363 9-5/8" 2,363 2,197 2,514 2,300 Burst p k ft t Fra O s 223 6. A G L PG , p Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 03/26/2024 By Grace Christianson at 2:11 pm, Aug 07, 2024 CDW 08/16/2024 DSR-8/12/24 RBDMS JSB 080824 RBDMS JSB 091924 Superseded Page 1 of 1 Well Name: NDBi-044 Packer Set Depths Item Des Btm (ftKB) Btm (TVD) (ftKB) SLZXP Liner Top Hanger Packer 10,845.1 4,052.8 OH Packer #13 11,269.1 4,140.2 OH Packer #12 11,333.1 4,149.3 OH Packer #11 11,947.2 4,167.3 OH Packer #10 12,558.6 4,164.7 OH Packer #9 13,174.4 4,163.9 OH Packer #8 13,788.8 4,162.1 OH Packer #7 14,403.6 4,160.2 OH Packer #6 15,014.4 4,158.2 OH Packer #5 15,586.2 4,156.3 OH Packer #4 16,155.2 4,154.2 OH Packer #3 16,724.8 4,152.4 OH Packer #2 17,298.8 4,150.7 OH Packer #1 17,703.1 4,149.2 NDBi-044 Well Schematic GL 20" Insulated Conductor128' MD 9-5/8" Tieback and Seal Assembly2,363' MD 13-3/8" 68 ppf L-80 Surface Casing2,514' MD 9-5/8", 47ppf L-80 Production Liner11,114' MD 4-½, 12.6ppf P-110S Production Liner 17,832' MD 4-½ Liner Hanger Liner Top Packer10,823' MD Archer C-Flex Two-Stage Cementing Tool 4,158' MD 16" Hole Size 12-1/4" Hole Size 8-½ Openhole 17,837' MD 12.21.202346.8' RKB Bottom Flange 1 2 3 4 5 6 7 8 9 9-5/8" Liner Hanger and Liner Top Packer2,363' MD 1 X Landing Nipple 1490 1471 20 3.813 4.772 2 GasliftMandrel 1.5" 2075 1986 38 3.865 7.684 3 X Landing Nipple 2138 2034 40 3.813 4.772 4 X Landing Nipple 10686 4016 76 3.813 4.776 5 D/HPsi Temp Gauge 10747 4030 76 3.905 6.002 6 X Landing Nipple 10761 4033 76 3.813 4.778 7 Tieback Seal Assy 10858 4055 76 3.860 5.230 8 9.625" x 4.5"LH/Packer 10823 4047 76 6.180 8.430 9 #13Openhole Packer 11221 4132 80 3.918 8.000 10 #12Openhole Packer 11285 4167 80 3.898 8.000 11 Stage 11 FracSleeve 11718 4167 90 3.735 5.628 12 #11Openhole Packer 11980 4167 90 3.918 8.000 13 Stage 10 FracSleeve 12206 4166 90 3.735 5.628 14 #10Openhole Packer 12428 4165 90 3.918 8.000 15 Stage 9 FracSleeve 12863 4165 90 3.735 5.650 16 #9Openhole Packer 13085 4164 90 3.918 8.000 17 Stage 8 FracSleeve 13477 4163 90 3.735 5.635 18 #8Openhole Packer 13823 4162 90 3.898 8.000 19 Stage 7 FracSleeve 14175 4161 90 3.735 5.636 20 #7Openhole Packer 14602 4159 90 3.918 8.000 21 Stage 6 FracSleeve 14868 4158 90 3.735 5.625 22 #6Openhole Packer 15090 4158 90 3.898 8.000 23 Stage 5 FracSleeve 15399 4157 90 3.735 5.625 24 #5Openhole Packer 15662 4156 90 3.898 8.000 25 Stage 4 FracSleeve 16008 4154 90 3.735 5.632 26 #4Openhole Packer 16354 4153 90 3.898 8.000 27 Stage 3 FracSleeve 16622 4152 90 3.735 5.629 28 #3Openhole Packer 16800 4152 90 3.898 8.000 29 Stage 2 FracSleeve 17070 4151 90 3.735 5.624 30 #2Openhole Packer 17373 4150 90 3.898 8.000 31 Stage 1 FracSleeve 17598 4149 90 3.735 5.625 32 #1Openhole Packer 17696 4149 90 3.898 8.000 33 #2Toe Sleeve 17760 4149 90 3.500 5.750 34 #1Toe Sleeve 17768 4149 90 3.500 5.750 35 WIV Collar 17821 4148 90 0.870 5.620 36 Eccentricshoe 17830 4148 90 3.900 5.210 Frac Ops Summary Report - AOGCC Well Name NDBi-044 Primary Job Type Fracture Treatment Start Date End Date Summary 2/4/2024 2/5/2024 Prepare to Frac Stages 1-4. Pressure test surface lines. Open wellhead and pressurize tubing to 7800psi to open P-Sleeve. 2/5/2024 2/6/2024 Frac stages 1-3 Finish RU of frac equipment and chemical/water testing. DataFrac: 673.5 bbls clean fluid (473.5 bbls WF125 and 200 bbls YF125ST fluid) at 40bpm. Pumpcheck volume extended to 220 bbls. Pump Frac Stages 1-3: Frac stage 1: 1,652.2 bbls slurry (YF125ST fluid), 176,970lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,464.5 bbls clean fluid at 40bpm as per design. Frac stage 2: 3,063 bbls slurry (3,013 bbls YF125ST fluid and 50 bbls of WF125), 193,862lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7ppa), 2,858.2 bbls clean fluid at 40bpm; Had issues with tank valves, couldn't get water to hydration unit, cut sand and overflushed by 250 bbls, restarted stage. Frac stage 3: 2,089.6 bbls slurry (YF125ST fluid), 152,059lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7ppa), 1,929.6 bbls clean fluid at 40bpm; Pressure was trending up, cut sand on 7ppa, flushed away, Step Down 40-32-24-16bpm Cleaned up equipment. Prepare to reload for next Frac. Total Load to Recover (TLTR) 6,925.8 bbls 2/6/2024 2/7/2024 Resupply Proppant and Frac Fluid for Stages 4-7 2/7/2024 2/8/2024 Resupply Proppant and heat Frac Fluid for Stages 4-7 2/8/2024 2/9/2024 Resupply Proppant and heat Frac Fluid for Stages 4-7 2/9/2024 2/10/2024 Heat Frac Tanks, Prime Frac Equipment, Pressure Test Lines 2/10/2024 2/11/2024 Frac stages 4-7 Finish RU of frac equipment and chemical/water testing. Pump Frac Stages 4-7: Frac stage 4: 1,892.4 bbls slurry (YF125ST fluid), 227,236 lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,652.3 bbls clean fluid at 40bpm as per design. Frac stage 5: 1,691.9 bbls slurry (YF125ST fluid), 224,950 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,454.2 bbls clean fluid at 40bpm as per design. Frac stage 6: 1,709.3 bbls slurry (YF125ST fluid), 223,567 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,473.1 bbls clean fluid at 40bpm as per design. Frac stage 7: 2,616.6 bbls slurry (YF125ST fluid), 17,398 lbs 40/70 Carbolite (1, 3ppa), 227,387 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 2,358.3 bbls clean fluid at 40bpm as per design. Cleaned up equipment. Prepare to reload for next Frac. Total Load to Recover (4-7) - 6,937.9 bbls Total Load to Recover (Well) - 13,863.7 bbls 2/11/2024 2/12/2024 Resupply Proppant and Frac Fluid for Stages 8-11 2/12/2024 2/13/2024 Resupply Proppant and Frac Fluid for Stages 8-11 2/13/2024 2/14/2024 Resupply Proppant and Frac Fluid for Stages 8-11 2/14/2024 2/15/2024 Heat Frac Fluid for Stages 8-11 Page 1 of 2 Frac Ops Summary Report - AOGCC Start Date End Date Summary 2/15/2024 2/16/2024 Frac stages 8-11 Finish RU of frac equipment and chemical/water testing. Pump Frac Stages 8-11: Frac stage 8: 2,027.2 bbls slurry (YF125ST fluid), 242,605 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,786.2 bbls clean fluid at 40bpm as per design. Frac stage 9: 1,733.3 bbls slurry (YF125ST fluid), 241,854 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,493.7 bbls clean fluid at 40bpm as per design. DataFrac: 249.4 bbls clean fluid (WF125 fluid) at 40bpm. Frac stage 10: 1,714.7 bbls slurry (YF125ST fluid), 240,700 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,475.5 bbls clean fluid at 40bpm as per design. Frac stage 11: 1,749.5 bbls slurry (YF125ST fluid), 226,289 lbs 16/20 Carbolite (1, 3, 5, 7, 9, 10ppa), 1,525.8 bbls clean fluid at 40bpm as per design. Cleaned up equipment. Rig Down for Well Clean Up. Total Load to Recover (8-11) 6,693.5 bbls Total Load to Recover (Well) 20,557.2 bbls 2/16/2024 2/17/2024 Rig Down Frac Equipment, Remove Ball Launcher 2/17/2024 2/18/2024 Continue to RD Frac Equipment 2/18/2024 2/19/2024 ND Frac Tree, NU Production Tree, RD Complete Page 2 of 2 Flowback Ops Summary Report - AOGCC Well Name NDBi-044 Primary Job Type Flowback/Testing Start Date End Date Summary 2/5/2024 2/6/2024 Rig up Well Testing Equipment. 2/6/2024 2/7/2024 Rig up Well Testing Equipment. 2/7/2024 2/8/2024 Rig up Well Testing Equipment. 2/8/2024 2/9/2024 Rig up Well Testing Equipment. 2/9/2024 2/10/2024 Rig up Well Testing Equipment. 2/10/2024 2/11/2024 Rig up Well Testing Equipment. Did a safety walk through of the Expro work area with Wess Santos safety representative, all good. 2/11/2024 2/12/2024 Rig up Well Testing Equipment. 2/12/2024 2/13/2024 Rig up Well Testing Equipment. 2/13/2024 2/14/2024 Rig up Well Testing Equipment. 2/14/2024 2/15/2024 Rig up Well Testing Equipment. 2/15/2024 2/16/2024 Rig up Well Testing Equipment. 2/16/2024 2/17/2024 Rig up Well Testing Equipment. 2/17/2024 2/18/2024 Rig up Well Testing Equipment. Expro was able to remove Utilidor located at NE corner of pad to installed liner then ran the temporary flow line through then put back the 1 plating and rig matt back in place, while working simultaneously on other flow lines going toward NDBi044. 2/18/2024 2/19/2024 Rig up Well Testing Equipment. Expro work on doing a mock ESD system set up to function test the system as whole while waiting on spotting equipment at wellhead alone with installing timbers alone the temp piping for protection. 2/19/2024 2/20/2024 Start spotting Expro equipment (Sand Trap, Manifold, Sparge Tank and Lad) in berm at well head and running associated piping to connect to inlet of Expro separator and also installing Ball Catcher at wing valve assembly. 2/20/2024 2/21/2024 Expro continue to rig up at wellhead and working on the EDGE and D2D. Preparing equipment for pressure test. 2/21/2024 2/22/2024 Stand by due to Phase 3 weather. Expro continue to work on ESD system and DAQ equipment. 2/22/2024 2/23/2024 Expro Day crew stand by due to Phase weather conditions. Expro night crew continue to work on ESD system, DAQ equipment and start snow removal. 2/23/2024 2/24/2024 Expro contuing to work on ESD ssytem, DAQ equipment, pressure test, snow removal and pressure test lines. held safety meeting with both day and night crew. 2/24/2024 2/25/2024 Expro continue to work on ESD system, DAQ equipment, snow removal along flow lines. 2/25/2024 2/26/2024 Expro continue to trouble shoot ESD system, DAQ equipment, wrappings at Separator and line going to DW-02 tank farm. Work on inlet valve at sand trap, changed out stem packing then retest valve. 2/26/2024 2/27/2024 Expro finisned prepping equipment and started flowing well. 2/27/2024 2/28/2024 Expro flowing well per clean up procedure. 2/28/2024 2/29/2024 Expro flowing well per clean up procedure. 2/29/2024 3/1/2024 Expro flowing well per cleanup procedure. 3/1/2024 3/2/2024 Expro flowing well per cleanup procedure. Page 1 of 2 Flowback Ops Summary Report - AOGCC Start Date End Date Summary 3/2/2024 3/3/2024 Expro flowing well per cleanup procedure. 3/3/2024 3/4/2024 Expro flowing well per cleanup procedure. 3/4/2024 3/5/2024 Expro flowing well per cleanup procedure. 3/5/2024 3/6/2024 Expro flowing well per cleanup procedure. Shutting in well at Midnight. 3/6/2024 3/7/2024 Expro begins evacuating lines and rigging down. 3/7/2024 3/8/2024 Expro continued rigging down. 3/8/2024 3/9/2024 Expro preparing to stage equipment near WT package 3/9/2024 3/10/2024 Expro preparing to stage equipment near WT package 3/10/2024 3/11/2024 Expro preparing to stage equipment near WT package 3/11/2024 3/12/2024 Expro preparing to stage equipment near WT package 3/12/2024 3/13/2024 Expro preparing to stage equipment near WT package 3/13/2024 3/14/2024 Expro preparing to stage equipment near WT package 3/14/2024 3/15/2024 Expro Prep Equipment to move. Monitor Build up BHP and BHT. Build up scheduled until 3/19/2024 3/15/2024 3/16/2024 Expro Prep Equipment to move. Monitor Build up BHP and BHT. 3/16/2024 3/17/2024 Monitor Build up BHP and BHT. 3/17/2024 3/18/2024 Monitor Build up BHP and BHT. 3/18/2024 3/19/2024 Monitor Build up BHP and BHT. 3/19/2024 3/20/2024 Monitor Build up BHP and BHT. 3/20/2024 3/21/2024 Build up complete, Testing operations completed. Page 2 of 2 Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 7.0 gal F103 Surfactant 1.0 Gal/mGal 862.0 gal J134 Breaker 0.0 lb/mGal 9.0 lbm J450 Stabilizing Agent 0.6 Gal/mGal 504.0 gal J475 Breaker J475 5.6 lb/mGal 4,922.5 lbm J511 Stabilizing Agent 1.7 lb/mGal 1,469.0 lbm J532 Crosslinker 2.1 Gal/mGal 1,848.0 gal J580 Gel J580 24.0 lb/mGal 20,997.0 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 46.6 gal M002 Additive 0.0 lb/mGal 1.3 lbm M117 Clay Control Agent 342.9 lb/mGal 300,103.0 lbm M275 Bactericide 0.3 lb/mGal 274.6 lbm S522-1620 Propping Agent varied concentrations 2,378,900.0 lbm S522-2040 Propping Agent varied concentrations 16,000.0 lbm 72.62027 % 23.93755 % 2.90961 % 0.20935 % 0.08999 % 0.04860 % 0.03936 % 0.03812 % 0.03113 % 0.01468 % 0.01347 % 0.01347 % 0.01238 % 0.00935 % 0.00672 % 0.00148 % 0.00137 % 0.00108 % 0.00052 % 0.00027 % 0.00025 % 0.00025 % 0.00016 % 0.00014 % 0.00009 % 0.00009 % 0.00006 % 0.00004 % 0.00004 % 0.00003 % 0.00003 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % 100 % State: Alaska County/Parish: North Slope Borough Case: Client: Oil Search Alaska Well: PIKKA NDBi-044 Basin/Field: Pikka Report ID: RPT-1934 Fluid Name & Volume Concentration Volume Disclosure Type: Post-Job Well Completed: Date Prepared: 8/2/2024 CAS Number Chemical Name Mass Fraction - Water (Including Mix Water Supplied by Client)* YF125ST:WF125 875,303 gal Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. 7647-14-5 Sodium chloride 102-71-6 2,2`,2"-nitrilotriethanol 7727-54-0 Diammonium peroxodisulphate 66402-68-4 Ceramic materials and wares, chemicals 7447-40-7 Potassium chloride 9000-30-0 Guar gum 67-63-0 Propan-2-ol 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 56-81-5 1, 2, 3 - Propanetriol 1303-96-4 Sodium tetraborate decahydrate 50-70-4 Sorbitol 91053-39-3 Diatomaceous earth, calcined 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 25038-72-6 Vinylidene chloride/methylacrylate copolymer 68131-39-5 Ethoxylated Alcohol 9025-56-3 Hemicellulase 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 7786-30-3 Magnesium chloride 63148-62-9 Dimethyl siloxanes and silicones 10377-60-3 Magnesium nitrate 9002-84-0 poly(tetrafluoroethylene) 14807-96-6 Magnesium silicate hydrate (talc) 9000-90-2 Amylase, alpha 14808-60-7 Quartz, Crystalline silica 14464-46-1 Cristobalite 63-42-3 Lactose 67762-90-7 Siloxanes and silicones, dimethyl, reaction products with silica 127-08-2 Acetic acid, potassium salt (impurity) 64-19-7 Acetic acid (impurity) 68937-55-3 Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 68308-89-4 Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 1310-73-2 Sodium hydroxide 1338-41-6 Sorbitan stearate 532-32-1 Sodium benzoate 9004-32-4 Sodium carboxymethylcellulose 11138-66-2 Xanthan Gum 7632-00-0 Sodium nitrite 36089-45-9 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2-hydroxyethyl 2-propenoate 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 9005-65-6 Sorbitan monooleate, ethoxylated * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. 9004-53-9 Dextrin 9012-54-8 Hemicellulase enzyme Total 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione 9050-36-6 Maltodextrin 2634-33-5 1,2-benzisothiazolin-3-one # SLB-Private Page: 1 / 1 Updated 7/18/2024INPUT2-5-24 to 2-15-24AK TSCA Status50-103-20865-00-00Post875,30374.86657%10,058,653Trade Name Supplier Purpose Ingredients Name CAS #Percentage by Mass of IngredientPercent of Ingredient in Total Mass PumpedMass of Ingredient (lbs)SME Tracerco Carrier Fluid Soy Methyl Ester 67784-80-9 100 0.0007546246 75.9050666000T-160C Tracerco Chemical Tracer 2,4,6-Tribromotoluene 6320-40-7 100 0.0000043835 0.4409240000T-758 Tracerco Chemical Tracer 3,4-Difluorobenzophenone 85118-07-6 100 0.0000043835 0.4409240000T-166A Tracerco Chemical Tracer 5-Iodo-m-xylene 22445-41-6 100 0.0000109588 1.1023100000T-164B Tracerco Chemical Tracer 2-Bromonaphthalene 580-13-2 100 0.0000109588 1.1023100000T-772 Tracerco Chemical Tracer 2-(Trifluoromethyl)Benzophenone 727-99-1 100 0.0000043835 0.4409240000T-165B Tracerco Chemical Tracer 2-Iodobiphenyl 2113-51-1 100 0.0000043835 0.4409240000T-757 Tracerco Chemical Tracer 3,3'-Difluorobenzophenone 345-70-0 100 0.0000065753 0.6613860000T-716 Tracerco Chemical Tracer 1,3,5-Tribromobenzene 626-39-1 100 0.0000043835 0.4409240000T-161B Tracerco Chemical Tracer 4-Iodotoluene 624-31-7 100 0.0000043835 0.4409240000T-168CTracercoChemical Tracer1-Bromo-4-iodobenzene589-87-71000.00000438350.4409240000T-168B Tracerco Chemical Tracer 1,2-Dichloro-4-iodobenzene 20555-91-3 100 0.0000043835 0.4409240000Water Tracerco Carrier Fluid Water 7732-18-5 100 0.0007473918 75.1775420000T-176D Tracerco Chemical Tracer Sodium-3,4,5-trifluorobenzoate 1180493-12-2 100 0.0000076712 0.7716170000T-942 Tracerco Chemical Tracer Sodium-2-chloro-5-methylbenzoate 118537-88-5 100 0.0000076712 0.7716170000T-953TracercoChemical TracerSodium-3-fluoro-5-(Trifluoromethyl)-benzoate1535169-59-51000.00000767120.7716170000T-929TracercoChemical TracerSodium-3-fluoro-2-methylbenzoate1708942-24-81000.00000767120.7716170000T-921TracercoChemical TracerSodium-3-chloro-2-fluorobenzoate1421029-89-11000.00000767120.7716170000T-158FTracercoChemical TracerSodium-2,3-Difluorobenzoate1604819-08-01000.00000767120.7716170000T-944TracercoChemical TracerSodium-3-chloro-4-methylbenzoate1708942-15-71000.00000767120.7716170000T-158ATracercoChemical TracerSodium-2,4-Difluorobenzoate1765-08-81000.00000767120.7716170000T-140CTracercoChemical TracerSodium-4-Fluorobenzoate499-90-11000.00000767120.7716170000T-176BTracercoChemical TracerSodium-2,3,6-trifluorobenzoate1803845-07-91000.00000767120.7716170000T-919TracercoChemical TracerSodium-4-chloro-3-fluorobenzoate1421029-88-01000.00000767120.7716170000Report Type (Pre or Post Job)Total Water Volume (gal):Water Mass FractionTotal Mass Pumped (lbs)County:API Number:Operator Name: SantosWell Name and Number: NDBi-044Hydraulic Fracturing Fluid Product Component Information DisclosureManufacturer Contact Tracerco 4106 New West Dr. Pasadena Texas 77507 Tel: 281-291-7769Fracture DateState: Approved For Tracerco SLB-Private FracCAT Treatment Report Well : NDBi-044 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : February 6, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi) 380 Initial BHP at Gauge (psi) 1,849 Final Surface ISIP (psi) 785 Final ISIP at Gauge (psi) 2576 Surface Shut in Pressure(psi) 1,555 BH Shut in Pressure (psi) 2,827 Maximum Treating Pressure (psi) 7,719 BH Gauge at 10,747 ft MD, 4,030 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)7,487.9 Total Proppant Pumped (lb) (per FracCAT) 522,892 Total YF125ST Past Wellhead (bbl) 5,637.6 Total Proppant in Formation (lb) 522,892 Total WF125 Past Wellhead (bbl) 1,232.6 Total Freeze Protect Past Wellhead (bbl) 52.1 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal) 276 276 M275 (lb) 96 90 J450 (gal) 150 150 J753 (gal) 14.8 14.8 J580 (lb) 6,279 6,279 J475 (lb) 1,650 1,650 J532 (gal) 557 557 J134 (lb) 9 9 J511 (lb) 600 442 D206 (gal) 2 2 M002 (lb) 0.5 0.4 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimat es as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Summary On February 4, 2024, SLB successfully opened Toe Sleeve and on February 5, 2024, performed a hydraulic fracturing treatment on Stages 1-3 of NBDi-044. The initial plan called for the completion of stages 1-4, on Stage 2 there was a suction loss from Frac tanks to PCM during 3PPA step, the decision along with Santos Company Rep was made to go on Flush. When water tank issues were resolved, Stage 2 resumed from beginning, then Stage 3 was pumped and the Ball/Collet#4launched.The Ball/Collet#4 was seated successfully.Postshutdown pressure decline was monitored for 60 min. Remaining WF from PCM was pumped downhole followed by Freeze Protect. By FracCAT totals, a total of 522,890 pounds of proppant was pumped and 522,890 was placed into formation in 7,487.9 bbl of slurry. Please note, that proppant Volumes are as per densitometer and not physical strap due to split loads. Stages 1 through 3 consisted of a PAD, and 8 proppant steps from 1-8 PPA. Pump trips were staggered from 7,600 to 8,000 psi. The GORV was set to 8,300 psi. The highlight of the stages was that the collet launch sequence greatly improved with the addition of a second line going to the wellhead. Summary of Stages 1-3 Material Actual Design Slurry Volume (bbl)7,488 5,928 Clean Fluid Volume(bbl) 6,870 5,336 Proppant (lb) 522,892 559,389 11:30:26 14:17:06 17:03:46 19:50:26 22:37:06 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-43 08-26-2023 Stage1 Stage2 (1) Stage3 Stage2 (2) Emptied PCM FPDF Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Toe Sleeve Activation Toe Sleeve activation was successful. When the well was opened the pressure was 380 psi. Toe Sleevewas activated atthe pressure 7719 psi at average Slurry Rate of 3.6 bbl/min. In the end of pumping there was a hard shutdown with an ISIP of 870 psi. A summary of the Stage below: Summary of Toe Sleeve Activation Stage Total Slurry Pumped (bbl)9.9 Max pumping Rate (bpm)4.7 Average Treating Pressure (psi)3,364 Average Pumping Rate (bpm)3.6 Average Water Temperature (F)87.4 Maximum Treating Pressure (psi)7,719 As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT Open Toe Sleeve 9.9 3.6 3.2 Freeze Protect 420 0.0 0.0 0.0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT Open Toe Sleeve 3.6 4.7 3,364 7,719 599 17:25:13 17:33:33 17:41:53 17:50:13 17:58:33 Time - hh:mm:ss -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 1 2 3 4 5 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Toe Sleve ActivationFracCAT*SantosNDBi-4402-04-2024 Toe Sleeve activation Open well Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States DF Stage DF included a pump check that was placed in the schedule to test the equipment and ensure the pumps were job ready, DataFRAC Pad and Displace DF. After step Displace DF was pumped, there was a hard shutdown with an ISIP of 862 psi and recording of pressure decline. A summary of the stage and pressures as follows: Summary of Stage DataFrac (Pump check and DataFrac) Total Proppant Pumped (lb)0 Max pumping Rate (bpm)40.3 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)25.0 Total Slurry Pumped (bbl)673.3 Maximum Treating Pressure (psi)6,997 YF125ST Pumped (bbl)249.4 Average Treating Pressure (psi)3,035 WF125 Pumped (bbl)423.9 Average Water Temperature (F)89.1 Average Viscosity (cP)21.8 As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT 40.3 3.2 12.8 WF125 1692 0.0 0.0 0 2 Pump Check 103.4 30.8 4.1 WF125 4341 0.0 0.0 0 3 Shut Down 0.0 0.0 0.0 -0 0.0 0.0 0 4 DataFrac XL 249.4 16.0 16.0 YF125ST 10476 0.0 0.0 0 5 DataFrac WF 50.0 16.1 3.1 WF125 2100 0.0 0.0 0 6 Displace DF 230.2 37.9 6.3 WF125 9671 0.0 0.0 0 7 Shut Down 0.0 0.0 0.0 --0.0 0.0 0 11:33:55 12:11:25 12:48:55 13:26:25 14:03:55 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con DFFracCAT*Santos NDBi-4402-05-2024 PT Displacement DataFRAC Pump Check Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT 3.2 3.5 1066 1184 152 2 Pump Check 30.8 39.5 5610 6997 368 3 Shut Down 0.0 0.0 3650 1029 459 4 DataFrac XL 16.0 16.4 2033 2229 530 5 DataFrac WF 16.1 16.1 2126 2146 2110 6 Displace DF 37.9 40.3 3520 3803 478 7 Shut Down 0.0 0.0 953 478 478 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 1 The treating pressure on PAD was around 2,700 psi before the Collet/Ball#1 hit the sleeve, then Treating pressure on PAD was around 3,450 psi and slowly fell to about 3,100 psi when 2PPA was going into the formation. At this point, the treating pressure was gradually increasing from 3,100 to 5,720 psi. There was an issue with POD gates during early proppant steps due to frozen gates. Issue was troubleshooted and addressed prior staging over to 4PPA step. Additionally, during the stage briefly one pump had issues and it was offline from 3PPA until 6PPA. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #1 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,009 3,104 3,373 Bottomhole Pressure 3,110 4,157 3,818 Summary of Stage 1 Total Proppant Pumped (lb)176,971 Max pumping Rate (bpm)40.7 Total Proppant in Formation (lb)176,971 Average Pumping Rate (bpm)36.9 Total Slurry Pumped (bbl)1,652.1 Maximum Treating Pressure (psi)5,177 YF125ST Pumped (bbl)1,464.5 Average Treating Pressure (psi)3,357 WF125 Pumped (bbl)0 Average Water Temperature (F)90.8 Average Viscosity (cP)19.9 13:50:44 14:07:24 14:24:04 14:40:44 14:57:24 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 1FracCAT*Santos NDBi-44 02-05-2024 Bringing the pump back Problem with the POD Blender gates Collet/Ball#1 hit the sleeve Lost pump Drop Rate for Ball/Collet#1 Drop Rate for Ball/Collet#2 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Line out XL 40.0 18.9 2.9 YF125ST 1665 0.0 0.0 0 2 Drop Collet#1 3.0 21.0 0.1 YF125ST 126 0.0 0.0 0 3 PAD st1 237.0 28.9 8.3 YF125ST 9948 0.0 0.0 0 4 Slow for Seat 50.0 20.0 2.6 YF125ST 2099 0.0 0.0 0 5 Resume Pad 34.6 36.3 0.9 YF125ST 1447 0.0 0.0 0 6 1.0 PPA 140.0 40.0 3.5 YF125ST 5757 CarboLite 16/20 0.7 0.5 2753 7 2.0 PPA 160.0 38.6 4.2 YF125ST 6286 CarboLite 16/20 2.3 1.6 9787 8 3.0 PPA 160.0 39.6 4.0 YF125ST 6168 CarboLite 16/20 3.6 2.0 12376 9 4.0 PPA 170.0 39.7 4.3 YF125ST 6114 CarboLite 16/20 4.0 3.8 23097 10 5.0 PPA 170.0 39.7 4.3 YF125ST 5865 CarboLite 16/20 5.4 4.9 28696 11 6.0 PPA 170.0 39.7 4.3 YF125ST 5664 CarboLite 16/20 6.4 5.9 33247 12 7.0 PPA 125.0 39.6 3.2 YF125ST 4020 CarboLite 16/20 7.1 6.9 27706 13 8.0 PPA 167.4 39.8 4.2 YF125ST 5295 CarboLite 16/20 8.1 7.5 39305 14 Clean line & Spacer 22.1 40.2 0.6 YF125ST 928 CarboLite 16/20 0.2 0.0 4 15 Drop Collet#2 3.0 40.2 0.1 YF125ST 126 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Line out XL 18.9 21.8 2216 2544 478 2 Drop Collet#1 21.0 21.0 2404 2508 2289 3 PAD st1 28.9 30.0 2724 2975 2244 4 Slow for Seat 20.0 30.0 2262 3013 1645 5 Resume Pad 36.3 39.9 3180 3418 2980 6 1.0 PPA 40.0 40.0 3417 3541 3374 7 2.0 PPA 38.6 40.0 3153 3374 2573 8 3.0 PPA 39.6 39.7 3145 3186 3007 9 4.0 PPA 39.7 39.7 3174 3230 3127 10 5.0 PPA 39.7 39.7 3363 3544 3230 11 6.0 PPA 39.7 40.7 3661 3809 3547 12 7.0 PPA 39.6 39.7 3971 4138 3812 13 8.0 PPA 39.8 40.2 4412 4769 4146 14 Clean Line & Spacer 40.2 40.2 5001 5152 4774 15 Drop Collet#2 40.2 40.2 5169 5177 5163 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 2 (attempt 1) Once the Collet/Ball#2 hit the sleeve the pressure transition from Stage 1 to 2 was typical. Treating pressure on PAD was around 3,000 psi. Suction was lost on the PCM at stage 3PPA, this led to decision of cutting sand early and overflush the pumped prop into the formation. The rate was decreased to 36 BPM to keep up with the suction on PCM. Flushed with YF125ST fluid and then overflushed it with WF125 fluid. While the suction loss was being resolved, the pumps were rolled pumping fluid downhole at rate 3.0 bpm per pump at 1 minute each pump to warm the lines and pumps. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #2 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,115 2,760 2,083 Bottomhole Pressure 3,165 3,583 3,140 Summary of Stage 2 (attempt 1) Total Proppant Pumped (lb) 26,556 Max pumping Rate (bpm) 40.2 Total Proppant in Formation (lb) 26,556 Average Pumping Rate (bpm) 35.4 Total Slurry Pumped (bbl) 1,465.9 Maximum Treating Pressure (psi) 5,637 YF125ST Pumped (bbl) 1,175.6 Average Treating Pressure (psi) 3,018 WF125 Pumped (bbl) 262.9 Average Water Temperature (F) 93.3 Average Viscosity (cP) 18.8 14:48:19 15:04:59 15:21:39 15:38:19 15:54:59 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 2FracCAT*Santos NDBi-44 02-05-2024 Collet/Ball#2 hit the sleeve.PCM suction loss Overflushing YF125 gel with WF125 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st2 229.0 38.5 6.0 YF125ST 9635 0.0 0.0 0 2 Slow For Seat 50.0 17.8 2.8 YF125ST 2090 0.0 0.0 0 3 Resume Pad 63.8 38.1 1.7 YF125ST 2675 0.0 0.0 0 4 1.0 PPA 140.0 39.6 3.5 YF125ST 5660 CarboLite 16/20 1.0 0.9 4995 5 2.0 PPA 160.0 38.5 4.2 YF125ST 6196 CarboLite 16/20 2.1 1.9 11796 6 3.0 PPA 124.3 34.9 3.7 YF125ST 4808 CarboLite 16/20 3.0 2.0 9760 7 Flush XL 436 33.8 20 YF125ST 18313 CarboLite 16/20 0 0 5.0 8 Flush WF 262.8 33.8 6.8 WF125 11043 0 0 0.0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st2 38.5 40.2 4411 5637 1358 2 Slow For Seat 17.8 29.6 2169 3094 1358 3 Resume Pad 38.1 40.1 3035 3200 2858 4 1.0 PPA 39.6 40.1 3143 3242 2744 5 2.0 PPA 38.5 40.2 2906 3047 2392 6 3.0 PPA 34.9 35.0 2503 2656 24 7 8 Flush XL WF Flush 33.8 40.1 2711 3648 444 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 2 (attempt 2) The decisionfrom Santos officewas madeto refractureStage 2. Ball was launched and pumped at the rate 16 BPM with the Volume 260bbl, then Rate was increased to target rate 40BPM. Treating pressure on PAD was around 1,800 psi (at 17 BPM) and 3,130 psi (at 40BPM) and was stable until 1ppa reach into formation. At this point, the treating pressure was gradually increasing from 2,920 to 3,600 psi then it was gradually decreasing to 3,320 psi while 3PPA was going to formation. Once 4PPA reached the formation pressure started slowly growing from 3,320 psi to 4,340 psi. The decision was made to cut the proppant early due to pressure increase during 7PPA step at the surface. The proppant was cut, brought back and cut again at customer's request. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#3 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Stage 2 (attempt 2) Total Proppant Pumped (lb) 167,305 Max pumping Rate (bpm) 40.2 Total Proppant in Formation (lb) 167,305 Average Pumping Rate (bpm) 36.1 Total Slurry Pumped (bbl) 1,597.0 Maximum Treating Pressure (psi) 5,366 YF125ST Pumped (bbl) 1,419.6 Average Treating Pressure (psi) 3,183 WF125 Pumped (bbl) 0 Average Water Temperature (F) 94.3 Average Viscosity (cP) 19.5 17:23:36 17:40:16 17:56:56 18:13:36 18:30:16 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 2 (Second Attempt)FracCAT*Santos NDBi-44 02-05-2024 Pump the ball to Sleeve#2 at rate 17BPM Cut proppant due to pressure growth. Drop Rate for Ball/Collet#3 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st2(2) 16.8 17.4 1834 2152 592 2 Resume Pad 35.4 40.1 2787 3136 1796 3 1.0 PPA 40.1 40.2 3047 3144 3011 4 2.0 PPA 40.1 40.1 2943 3017 2905 5 3.0 PPA 40.1 40.1 3144 3395 2909 6 4.0 PPA 40.1 40.1 3525 3600 3401 7 5.0 PPA 40.1 40.1 3433 3510 3379 8 6.0 PPA 40.1 40.1 3678 3851 3484 9 7.0 PPA 40.1 40.1 4111 4710 3852 10 Clean line & Spacer 40.1 40.1 5160 5366 4713 11 Drop Collet#3 40.1 40.1 5148 5321 4984 As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st2(2)260.0 16.8 15.7 YF125ST 10908 0.0 0.0 0 2 Resume Pad 90.0 35.4 2.6 YF125ST 3764 0.0 0.0 0 3 1.0 PPA 140.0 40.1 3.5 YF125ST 5645 CarboLite 16/20 1.0 0.9 5260 4 2.0 PPA 160.0 40.1 4.0 YF125ST 6163 CarboLite 16/20 2.1 2.0 12534 5 3.0 PPA 180.0 40.1 4.5 YF125ST 6647 CarboLite 16/20 3.2 3.1 20548 6 4.0 PPA 180.0 40.1 4.5 YF125ST 6470 CarboLite 16/20 4.1 3.8 24542 7 5.0 PPA 180.1 40.1 4.5 YF125ST 6199 CarboLite 16/20 5.2 5.0 30743 8 6.0 PPA 180.0 40.1 4.5 YF125ST 5973 CarboLite 16/20 6.2 6.0 35758 9 7.0 PPA 186.5 40.1 4.6 YF125ST 6159 CarboLite 16/20 7.1 6.2 37865 10 Clean line & Spacer 37.4 40.1 0.9 YF125ST 1570 CarboLite 16/20 0.5 0.0 53 11 Drop Collet#3 3.0 40.1 0.1 YF125ST 126 CarboLite 16/20 0.0 0.0 2 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 3 Once the Collet/Ball#3 hit the sleeve the pressure transition from Stage 2 to 3 was typical. Treating pressure on PAD was around 2,950 psi and was stable until 2PPA reached into formation. At this point, the treating pressure was gradually increasing from 2,950 to 3,240 psi and then the angle of pressure growth changed when 5PPA was going into formation. At 7PPA on surface, the decision was made to cut the proppant and go to Flush. The Collet/Ball#4 was launched, successfully seated, and followed by a stepdown shutdown (with rates 40-32-24-16BPM) with an ISIP of 862 psi and recording of pressure decline for 60 mins. Then the PCM was emptied and WF125 fluid was pumped downhole followed by Freeze Protect. To be noted that one tank (tank 14) couldnt not be open during pumping operations due to stuck butterfly valve. Due to early prop cuts from stage 2 this volume was not necessary for the job. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #3 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,190 3,021 2,272 Bottomhole Pressure 3,242 3,901 3,275 Summary of Stage 3 Total Proppant Pumped (lb) 152,060 Max pumping Rate (bpm) 40.2 Total Proppant in Formation (lb) 152,060 Average Pumping Rate (bpm) 35.3 Total Slurry Pumped (bbl) 2,089.7 Maximum Treating Pressure (psi) 4,962 YF125ST Pumped (bbl) 1,328.4 Average Treating Pressure (psi) 3,095 WF125 Pumped (bbl) 545.8 Average Water Temperature (F) 94.5 Average Viscosity (cP) 20.1 18:23:57 18:48:57 19:13:57 19:38:57 20:03:57 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 3FracCAT*SantosNDBi-44 02-05-2024 Collet/Ball#3 hit the sleeve.Collet/Ball#4 hit the sleeve. Drop Rate for Ball/Collet#4 Step Down Shutdown Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st3 179.7 39.9 4.6 YF125ST 7566 0.0 0.0 0 2 Slow For Seat 50.0 16.9 3.0 YF125ST 2100 0.0 0.0 0 3 Resume Pad 82.2 20.9 4.2 YF125ST 3438 0.0 0.0 0 4 1.0 PPA 140.1 39.7 3.5 YF125ST 5648 CarboLite 16/20 1.0 0.9 5191 5 2.0 PPA 160.0 40.1 4.0 YF125ST 6187 CarboLite 16/20 2.1 1.9 12025 6 3.0 PPA 180.1 40.1 4.5 YF125ST 6686 CarboLite 16/20 3.1 3.0 19721 7 4.0 PPA 180.0 40.1 4.5 YF125ST 6433 CarboLite 16/20 4.1 4.0 25422 8 5.0 PPA 180.1 39.5 4.6 YF125ST 6201 CarboLite 16/20 5.1 5.0 30692 9 6.0 PPA 180.1 40.0 4.5 YF125ST 5981 CarboLite 16/20 6.1 6.0 35623 10 7.0 PPA 114.8 40.0 2.9 YF125ST 3789 CarboLite 16/20 7.2 6.2 23384 11 Clean line & Spacer 14.0 40.0 0.4 YF125ST 588 CarboLite 16/20 0.1 0.0 2 12 Drop Collet#4 3.0 40.0 0.1 YF125ST 126 0.0 0.0 0 13 XL Flush 25.0 38.6 0.7 YF125ST 1051 0.0 0.0 0 14 WF Flush 185.0 37.8 4.9 WF125 7768 0.0 0.0 0 15 Slow For Seat 51.0 21.3 2.6 WF125 2142 0.0 0.0 0 16 Step Down(40)80.0 39.6 2.0 WF125 3357 0.0 0.0 0 17 Step Down(32)50.0 34.1 1.5 WF125 2105 0.0 0.0 0 18 Step Down(24)40.0 25.2 1.6 WF125 1687 0.0 0.0 0 19 Step Down(16)30.0 16.1 2.2 WF125 1274 0.0 0.0 0 20 Emptied PCM 109.5 15.7 7.7 WF125 4590 0.0 0.0 0 21 Freeze Protect 55.1 16.9 3.3 Freeze Protect 2326 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st3 39.9 40.2 4167 4904 1469 2 Slow For Seat 16.9 18.2 2237 2751 1469 3 Resume Pad 20.9 36.5 2485 3097 2287 4 1.0 PPA 39.7 40.1 2959 3002 2807 5 2.0 PPA 40.1 40.1 2901 2983 2849 6 3.0 PPA 40.1 40.1 2895 3009 2847 7 4.0 PPA 40.1 40.1 3095 3125 3018 8 5.0 PPA 39.5 40.1 3078 3198 2891 9 6.0 PPA 40.0 40.0 3506 3849 3192 10 7.0 PPA 40.0 40.0 4107 4477 3853 11 Clean line & Spacer 40.0 40.0 4527 4590 4492 12 Drop Collet#4 40.0 40.0 4644 4704 4596 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 13 XL Flush 38.6 40.0 4887 4962 4731 14 WF Flush 37.8 37.9 3841 4886 3238 15 Slow For Seat 21.3 37.8 1989 3235 1253 16 StepDown(40) 39.6 40.1 3104 3149 2945 17 StepDown(32) 34.1 40.1 2610 3108 2442 18 StepDown(24) 25.2 32.5 1998 2531 1733 19 StepDown(16) 16.1 22.9 1450 1902 366 20 Emptied PCM 15.7 17.1 1626 1702 729 21 Freeze Protect 16.9 17.0 1756 1970 827 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Toe Sleeve Activation Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 15:20:50 Prime Up 60 22 0.0 5.4 0.0 2 15:59:25 Low Pressure Test 860 22 0.0 0.0 0.0 3 16:13:58 Setting Seats & Valves on Pumps 5428 21 0.0 0.0 0.0 4 16:27:51 Searching for Leaks 6023 22 0.0 0.0 0.0 5 16:34:27 Mid Pressure Test 5656 21 0.0 0.0 0.0 6 16:36:20 High Pressure Test 9476 22 0.0 0.0 0.0 7 16:44:50 High Pressure Test 9481 21 0.0 0.0 0.0 8 17:34:18 LR Pressuring Up IA To 3400 PSI 394 979 0.0 0.0 0.0 9 17:42:10 Open Well 382 3377 0.0 0.0 0.0 10 17:43:51 Start Displ PT Automatically 2077 3495 0.0 4.7 0.0 11 17:43:51 Start Propped Frac Automatically 2077 3495 0.0 4.7 0.0 12 17:43:51 Start DF Automatically 2077 3495 0.0 4.7 0.0 13 17:43:55 Started Pumping 2519 3512 0.0 4.7 0.0 14 17:49:22 Closed Well 704 2894 9.9 0.0 0.0 15 17:52:01 Fanning Out Pumps To Bleed Off Tank 2 2026 9.9 4.0 0.0 DF Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 7:53:14 Priming Pumps with Diesel 28 871 0.0 5.4 0.0 2 8:22:05 Finished Prime Up 27 871 0.0 0.0 0.0 3 8:23:41 Low Pressure Test 659 871 0.0 0.0 0.0 4 8:29:49 Mid Pressure Test 5655 871 0.0 0.0 0.0 5 8:40:57 High Pressure Test 9712 871 0.0 0.0 0.0 6 8:49:00 High Pressure Test 9523 871 0.0 0.0 0.0 7 8:54:47 Good Test 9212 871 0.0 0.0 0.0 8 8:58:56 Fueling Frac Equipment 1373 871 0.0 0.0 0.0 9 9:00:07 Safety Meeting 1426 871 0.0 0.0 0.0 10 9:40:19 Radio Check 1253 871 0.0 0.0 0.0 11 10:10:10 Troubleshooting PCM Eductor 1016 3190 0.0 0.0 0.0 12 11:03:56 Mixing Gel 25 #733 3153 0.0 0.0 0.0 13 11:35:32 Open Well 155 3140 0.0 0.0 0.0 14 11:36:16 Start Displ PT Automatically 153 3142 0.0 0.0 0.0 15 11:36:55 Started Pumping 152 3143 0.0 0.0 0.0 16 11:50:37 Stopped Pumping 836 3133 40.3 0.0 0.0 19 12:09:21 Started Pumping 369 3159 40.3 0.0 0.0 20 12:09:25 Start Pump Check Automatically 369 3159 40.3 0.0 0.0 21 12:13:46 Stopped Pumping 495 3114 143.7 0.8 0.0 22 12:20:28 Started Pumping 623 3258 143.7 0.0 0.0 23 12:20:29 Start Shut Down Automatically 622 3250 143.7 0.0 0.0 24 12:27:16 Stopped Pumping 476 3250 143.7 0.0 0.0 25 12:28:32 Started Pumping 461 3249 143.7 0.0 0.0 26 12:28:49 Start DataFrac XL Automatically 741 3255 143.7 0.2 0.0 27 12:37:15 Stage at Perfs: Displ PT 1976 3353 271.8 16.1 0.0 28 12:39:46 Stage at Perfs: Pump Check 1989 3384 312.3 16.1 0.0 29 12:44:48 Start DataFrac WF Manually 2115 3409 393.3 16.1 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 30 12:46:11 Stage at Perfs: DataFrac XL 2106 3368 415.6 16.1 0.0 31 12:47:55 Start Displace DF Automatically 2153 3405 443.5 16.1 0.0 32 12:53:57 Stage at Perfs: DataFrac WF 3639 3439 666.0 40.3 0.0 33 12:54:13 Start Shut Down Automatically 546 3326 673.5 12.2 0.0 34 12:54:13 Stopped Pumping 546 3326 673.5 12.2 0.0 Stage 1 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:54:27 Started Pumping 617 3154 673.5 0.2 0.0 2 13:54:28 Start Line out XL Automatically 616 3153 0.0 0.2 0.0 3 13:58:19 Start Drop Collet1 Automatically 2440 3224 40.1 21.0 0.0 4 13:58:25 Stage at Perfs: Displace DF 2551 3223 42.2 20.9 0.0 5 13:58:28 Start PAD st1 Automatically 2581 3223 43.2 20.9 0.0 6 14:06:29 Stage at Perfs: Line out XL 2562 3389 272.3 30.0 0.0 7 14:06:45 Start Slow for Seat Automatically 2395 3389 280.3 30.0 0.0 8 14:08:19 Stage at Perfs: Drop Collet#1 2305 3418 309.1 17.1 0.0 9 14:08:30 Stage at Perfs: PAD st1 2222 3412 312.2 17.1 0.0 10 14:09:21 Start Resume Pad Automatically 2808 3420 330.3 31.5 0.0 11 14:10:17 Start 1.0 PPA Manually 3448 3442 364.6 40.0 0.0 12 14:10:17 Started Pumping Prop 3448 3442 364.6 40.0 0.0 13 14:13:48 Start 2.0 PPA Automatically 3366 3446 505.2 40.0 0.5 14 14:14:55 Stage at Perfs: Slow for Sea 3323 3401 549.8 40.0 1.3 15 14:16:10 Stage at Perfs: Resume Pad 3252 3397 599.8 40.0 2.1 16 14:17:06 Stage at Perfs: 1.0 PPA 2822 3398 633.5 35.7 1.4 17 14:17:57 Start 3.0 PPA Automatically 2948 3427 664.8 38.0 1.2 18 14:20:43 Stage at Perfs: 2.0 PPA 3152 3472 774.1 39.7 1.7 19 14:22:00 Start 4.0 PPA Automatically 3200 3484 825.0 39.7 2.8 20 14:24:44 Stage at Perfs: 3.0 PPA 3142 3510 933.6 39.7 4.0 21 14:26:17 Start 5.0 PPA Automatically 3229 3518 995.2 39.7 3.4 22 14:28:46 Stage at Perfs: 4.0 PPA 3389 3355 1093.9 39.7 4.8 23 14:30:33 Start 6.0 PPA Automatically 3549 3362 1164.7 39.7 5.0 24 14:33:03 Stage at Perfs: 5.0 PPA 3720 3371 1264.6 39.9 5.7 25 14:34:50 Start 7.0 PPA Automatically 3828 3387 1334.9 39.7 5.8 26 14:37:20 Stage at Perfs: 6.0 PPA 4065 3378 1434.0 39.7 6.8 27 14:37:59 Start 8.0 PPA Automatically 4174 3382 1459.8 39.8 7.0 28 14:41:37 Stage at Perfs: 7.0 PPA 4671 3414 1604.3 40.0 7.9 29 14:42:11 Start Clean line & Spacer Manually 4865 3422 1627.1 40.2 0.0 30 14:42:14 Stopped Pumping Prop 4930 3428 1629.1 40.1 0.0 31 14:42:42 Launch Ball & Collet#2 5171 3436 1647.8 40.2 0.0 32 14:42:44 Start Drop Collet#2 Manually 5184 3437 1649.2 40.2 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 2 (attempt 1) Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 14:42:49 Start PAD st2 Automatically 5263 3439 0.0 40.2 0.0 2 14:42:49 Start Propped Frac Automatically 5263 3439 0.0 40.2 0.0 3 14:42:49 Start Stage 2 Automatically 5263 3439 0.0 40.2 0.0 4 14:44:52 Stage at Perfs: 8.0 PPA 4500 3435 76.5 37.5 0.0 5 14:48:49 Start Slow For Seat Automatically 1722 3377 228.7 16.2 0.0 6 14:49:40 Stage at Perfs: Spacer 2075 3388 243.2 17.0 0.0 7 14:50:28 Ball & Collet#2 Seated 2683 3419 256.8 17.0 0.0 8 14:50:59 Stage at Perfs: Drop Collet2 2095 3389 265.5 17.0 0.0 9 14:51:10 Stage at Perfs: PAD st2 2211 3385 268.6 17.0 0.0 10 14:51:36 Start Resume Pad Automatically 2751 3402 278.7 31.3 0.0 11 14:53:16 Start 1.0 PPA Manually 3209 3384 342.5 40.1 0.0 12 14:53:16 Started Pumping Prop 3209 3384 342.5 40.1 0.0 13 14:56:49 Start 2.0 PPA Automatically 2740 3356 482.6 35.5 0.9 14 14:57:01 Stage at Perfs: Slow For Seat 2750 3358 489.7 35.5 1.2 15 14:58:21 Stage at Perfs: Resume Pad 2996 3376 540.2 39.7 2.1 16 14:59:56 Stage at Perfs: 1.0 PPA 3015 3384 603.6 40.2 2.0 17 15:01:00 Start 3.0 PPA Automatically 2559 3368 642.8 35.0 2.0 18 15:03:30 Stopped Pumping Prop 2515 3367 730.3 35.0 2.4 19 15:03:36 Started Pumping Prop 2536 3368 733.8 35.0 0.0 20 15:03:53 Stage at Perfs: 2.0 PPA 2579 3369 743.7 35.0 0.1 21 15:05:00 Start Clean line & Spacer Manually 1626 3394 766.7 2.9 0.0 22 15:08:17 Stopped Pumping Prop 2894 3387 851.3 34.9 0.0 23 15:09:47 Stage at Perfs: 3.0 PPA 3016 3415 903.6 34.9 0.0 24 15:13:21 Stage At Perfs 2927 3422 1027.9 34.9 0.0 25 15:29:01 Stopped Pumping 857 3394 1449.1 0.0 0.0 26 16:30:00 Started Pumping 779 3039 1449.1 3.1 0.0 27 16:31:10 Rolling Pumps DH Prevent Freezing 768 3037 1452.2 3.3 0.0 28 16:41:58 Stopped Pumping 592 2981 1465.4 0.0 0.0 Stage 2 (attempt 2) Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 17:30:30 Started Pumping 685 3159 1465.5 0.0 0.0 2 17:30:33 Start PAD st2(2) Manually 881 3164 1465.5 0.0 0.0 3 17:30:33 Start Propped Frac Manually 881 3164 1465.5 0.0 0.0 4 17:30:33 Start Stage 2 (2) Automatically 881 3164 1465.5 0.0 0.0 5 17:46:21 Start Resume Pad Automatically 1798 3339 260.1 17.0 0.0 6 17:46:24 Stage At Perfs 1796 3340 261.0 17.0 0.0 7 17:48:58 Start 1.0 PPA Automatically 3132 3379 350.2 40.1 0.0 8 17:48:58 Started Pumping Prop 3132 3379 350.2 40.1 0.0 9 17:52:28 Start 2.0 PPA Automatically 3014 3355 490.6 40.1 1.0 10 17:53:14 Stage At Perfs 2974 3377 521.4 40.1 2.1 11 17:55:28 Stage At Perfs 2914 3423 611.0 40.1 2.1 12 17:56:27 Start 3.0 PPA Automatically 2912 3441 650.5 40.1 2.1 13 17:58:58 Stage At Perfs 3189 3482 751.5 40.1 3.1 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 14 18:00:56 Start 4.0 PPA Automatically 3402 3351 830.4 40.1 2.9 15 18:02:57 Stage At Perfs 3550 3377 911.3 40.1 3.8 16 18:05:25 Start 5.0 PPA Automatically 3510 3393 1010.3 40.1 4.0 17 18:07:26 Stage At Perfs 3387 3390 1091.2 40.1 5.0 18 18:09:54 Start 6.0 PPA Automatically 3484 3391 1190.2 40.1 5.5 19 18:11:55 Stage At Perfs 3662 3407 1271.1 40.1 5.9 20 18:14:24 Start 7.0 PPA Automatically 3858 3415 1370.8 40.1 6.0 21 18:16:24 Stage At Perfs 4052 3382 1451.0 40.1 7.1 22 18:19:02 Start Clean line & Spacer Manually 4809 3375 1556.7 40.1 0.2 23 18:19:58 Start Drop Collet#3 Manually 4953 3393 1594.1 40.1 0.0 Stage 3 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 18:20:03 Start PAD s3 Automatically 4798 3387 0.0 40.2 0.0 2 18:20:03 Start Propped Frac Automatically 4798 3387 0.0 40.2 0.0 3 18:20:03 Start Stage 3 Automatically 4798 3387 0.0 40.2 0.0 4 18:20:55 Stage At Perfs 4513 3391 34.8 40.1 0.0 5 18:24:36 Start Slow For Seat Manually 2246 3413 179.4 16.4 0.0 6 18:25:48 Ball & Collet#3 Seated 3004 3452 199.6 16.8 0.0 7 18:27:00 Stage At Perfs 2260 3420 219.9 16.9 0.0 8 18:27:35 Start Resume Pad Automatically 2298 3424 229.8 16.9 0.0 9 18:29:13 Stage At Perfs 2318 3438 257.4 16.9 0.0 10 18:29:25 Stage At Perfs 2321 3439 260.8 16.9 0.0 11 18:31:45 Start 1.0 PPA Manually 2847 3472 311.6 36.8 0.0 12 18:31:45 Started Pumping Prop 2847 3472 311.6 36.8 0.0 13 18:34:50 Stage At Perfs 2986 3333 433.9 40.1 1.0 14 18:35:17 Start 2.0 PPA Automatically 2986 3344 451.9 40.1 1.0 15 18:36:05 Stage At Perfs 2953 3354 484.0 40.1 2.0 16 18:38:08 Stage At Perfs 2876 3369 566.2 40.1 2.0 17 18:39:17 Start 3.0 PPA Automatically 2854 3374 612.3 40.1 2.0 18 18:41:38 Stage At Perfs 2878 3363 706.5 40.1 3.0 19 18:43:46 Start 4.0 PPA Automatically 3010 3349 792.0 40.1 3.0 20 18:45:38 Stage At Perfs 3117 3344 866.8 40.1 3.9 21 18:48:16 Start 5.0 PPA Automatically 3092 3328 972.4 40.1 4.0 22 18:50:07 Stage At Perfs 2896 3315 1046.0 37.8 5.1 23 18:52:49 Start 6.0 PPA Automatically 3187 3309 1152.0 40.0 5.1 24 18:54:41 Stage At Perfs 3456 3300 1226.7 40.0 6.0 25 18:57:19 Start 7.0 PPA Automatically 3869 3272 1332.0 40.0 6.0 26 18:59:10 Stage At Perfs 4235 3321 1406.1 40.0 7.0 27 19:00:11 Start Clean line & Spacer Manually 4513 3319 1446.7 40.0 0.0 28 19:00:15 Stopped Pumping Prop 4522 3320 1449.4 40.0 -0.0 29 19:00:32 Start Drop Collet#4 Manually 4731 3326 1460.7 40.0 0.0 30 19:00:37 Start XL Flush Automatically 4962 3331 1464.1 39.9 0.0 31 19:01:16 Start WF Flush Automatically 4880 3326 1489.0 37.8 0.0 32 19:03:50 Stage At Perfs 3767 3311 1586.1 37.8 0.0 33 19:06:09 Start Slow For Seat Manually 2962 3308 1673.7 37.8 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 34 19:07:34 Ball & Collet#4 Seated 2218 3280 1699.8 16.8 0.0 35 19:07:37 Stage At Perfs 2265 3312 1700.7 16.7 0.0 36 19:08:27 Stage At Perfs 2354 3307 1714.9 21.7 0.0 37 19:08:35 Stage At Perfs 2784 3326 1718.1 26.7 0.0 38 19:08:47 Start StepDown(40) Manually 2945 3304 1724.7 35.7 0.0 39 19:09:16 Stage At Perfs 3130 3352 1743.3 40.0 0.0 40 19:10:48 Start StepDown(32) Automatically 3107 3356 1804.7 40.0 0.0 41 19:12:18 Start StepDown(24) Automatically 2531 3350 1854.9 32.5 0.0 42 19:13:57 Start StepDown(16) Automatically 1903 3346 1894.9 22.9 0.0 43 19:15:58 Stopped Pumping 927 3360 1924.1 0.0 0.0 44 20:16:45 Started Pumping 366 3265 1924.1 0.0 0.0 45 20:17:16 Start PCM Leftover Downhole 841 3292 1924.7 3.4 0.0 46 20:18:04 Stage At Perfs 1254 3295 1927.4 5.2 0.0 47 20:21:40 Stage At Perfs 1691 3289 1978.7 17.0 0.0 48 20:24:56 Start Freeze Protect Manually 1535 3300 2034.2 17.0 0.0 49 20:26:22 Stage At Perfs 1791 3305 2058.5 17.0 0.0 50 20:28:29 Stopped Pumping 897 3309 2089.3 0.0 0.0 51 20:31:45 Well Closed 998 2220 2089.3 0.0 0.0 52 20:33:33 Fanning Pumps To Bleed Tanks 40 1537 2089.3 14.9 0.0 SLB-Private FracCAT Treatment Report Well : NDBi-044 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : February 11, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi) 301 Initial BHP at Gauge (psi) 1,903 Final Surface ISIP (psi) 953 Final ISIP at Gauge (psi) 2,595 Surface Shut in Pressure(psi) 1,899 BH Shut in Pressure (psi) 2,823 Maximum Treating Pressure (psi) 5,770 BH Gauge at 10,747 ft MD, 4,030 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)8,252.2 Total Proppant Pumped (lb) (per FracCAT and BOL weight) 920,541 Total YF125ST Past Wellhead (bbl) 6,272.2 Total Proppant in Formation (lb) 920,541 Total WF125 Past Wellhead (bbl) 964.0 Total Freeze Protect Past Wellhead (bbl) 42.8 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal) 302 302 M275 (lb) 90 90 J450 (gal) 171 171 J753 (gal) 16.1 16.1 J580 (lb) 7,458 7,453 J475 (lb) 1,595 1,595 J532 (gal) 645 645 J134 (lb) 0 0 J511 (lb) 600 545 D206 (gal) 2 2 M002 0.5 0.4 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown d ata and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's be st estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Summary On February 10, 2024, SLB successfully performed a hydraulic fracturing treatment on Stages 4-7 of NDBi-044. According to the initial plan called for the completion of stages 4-7, there was change of Resume Pad step volumes before pumping started: for Stage 5 (from 61bbl to 91bbl), for Stage 6 (from 69bbl to 99bbl), and Stage 7 (from 40bbl to 70bbl). While pumping stage 6 the crew encountered an issue to offload the J580 gel from the ABT unit to the PCM. SLB immediately informed Santos Representatives, and option were to resolve the issue and reload before the spacer step between stage 6 and 7 or shutdown for that purpose as there was not enough J580 gel in the PCM hopper to complete the job. Decision was made to launch the Ball/Collet #7, pump flush and shutdown unit the issue could be resolved. After the issue was resolved, stage 7 was pumped successfully, and the Ball/Collet#8 launched. The Ball/Collet#8 was seated successfully followed by Freeze Protect.Postshutdownpressure decline wasmonitored for 60 min. By FracCAT totals, a total of 920,541pounds of proppant was pumped and 920,541 was placed into formation in 8,252.2 bbl of slurry. Please note, that proppant Volumes for 16/20 Carbolite are as per densitometer and not physical strap due to split loads, and for 40/70 Carbolite as per BOL weight (16,000lbs). Stage 4 consisted of a PAD, and 8 proppant steps from 1-8 PPA, Stages 5 through 6 consisted of a PAD, and 6 proppant steps from 1-10 PPA and Stage 7 consisted of a PAD, two Scour steps 1-3PPA with proppant 20/40 CBL, and 6 proppant steps from 1-10 PPA. Pump trips were staggered from 7,600 to 8,000 psi. The GORV was set to 8,300 psi. The highlight of the stages was that the collet launch sequence greatly improved with the addition of a second line going to the wellhead. Summary of Stages 4-7 Material Actual Design Slurry Volume (bbl)8,252 7,742 Clean Fluid Volume(bbl) 7,236 6,720 Proppant (lb) 920,541 914,338 16:00:42 17:24:02 18:47:22 20:10:42 21:34:02 22:57:22 Time - hh:mm:ss 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 0 5 10 15 20 25 30 35 40 45 50 0 2 4 6 8 10 12 14 16 18 20 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT* Santos NDBi-044 02-10-2024 Stage4 Stage5 Stage7 Stage6Displ PT Ball to Seat Pump Check Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check. Stage included PT displacement, pumping Ball#4 to seat and pump check that was placed in the schedule to test the equipment and ensure the pumps were job ready. After step Pump Check was pumped, then moved to pumping Stage#4 without shutdown. A summary of the stage and pressures as follows: Summary of Stage Displacement PT, Ball to Seat and Pump Check Total Proppant Pumped (lb)0 Max pumping Rate (bpm)43.0 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)11.8 Total Slurry Pumped (bbl)341.4 Maximum Treating Pressure (psi)3,905 YF125ST Pumped (bbl)0 Average Treating Pressure (psi)1,522 WF125 Pumped (bbl)341.4 Average Water Temperature (F)97.7 Average Viscosity (cP)19.0 15:36:14 15:56:14 16:16:14 16:36:14 16:56:14 17:16:14 17:36:14 17:56:14 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 2 4 6 8 10 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT* SantosNDBi-04402-10-2024 PT Displacement Pumping Ball to Seat Pump Check Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT 69.1 3.4 20.4 WF125 2900 0.0 0.0 0 2 Shut Down - - - - - - - - 3 Ball#4 to Seat 175.3 3.9 44.5 WF125 7363 0.0 0.0 0 4 Pump Check 97.0 32.8 3.5 WF125 4074 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT 3.4 4.0 751 985 304 2 Shut Down 3.4 2.3 751 701 249 3 Ball#4 to Seat 3.9 5.8 1003 1181 240 4 Pump Check 32.8 43.0 3028 3905 1170 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 4 The treating pressure on PAD was around 3,430 psi and slowly fell to about 2,850 psi when 1PPA was going into the formation. At this point, the treating pressure was gradually increasing from 2,850 to 5,885 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#5 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #4 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,700 2,233 1,720 Bottomhole Pressure 3,000 3,377 3,022 Summary of Stage 4 Total Proppant Pumped (lb)227,237 Max pumping Rate (bpm)40.1 Total Proppant in Formation (lb)227,237 Average Pumping Rate (bpm)40.0 Total Slurry Pumped (bbl)1,892.4 Maximum Treating Pressure (psi)5,421 YF125ST Pumped (bbl)1,652.3 Average Treating Pressure (psi)3,394 WF125 Pumped (bbl)0 Average Water Temperature (F)90.5 Average Viscosity (cP)18.4 17:46:14 17:55:24 18:04:34 18:13:44 18:22:54 18:32:04 18:41:14 18:50:24 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-4 FracCAT* SantosNDBi-04402-10-2024 Collet/Ball#5 hit the sleeveDrop Rate for Ball/Collet#5 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st4 350.0 40.0 8.7 YF125ST 14700 0.0 0.0 0 2 1.0 PPA 180.0 40.0 4.5 YF125ST 7256 CarboLite 16/20 1.0 0.9 6844 3 2.0 PPA 180.0 40.0 4.5 YF125ST 6958 CarboLite 16/20 2.1 2.0 13593 4 3.0 PPA 200.1 40.0 5.0 YF125ST 7427 CarboLite 16/20 3.1 3.0 21955 5 4.0 PPA 200.1 40.0 5.0 YF125ST 7148 CarboLite 16/20 4.2 4.0 28271 6 5.0 PPA 200.1 40.0 5.0 YF125ST 6891 CarboLite 16/20 5.2 4.9 34092 7 6.0 PPA 200.1 40.0 5.0 YF125ST 6646 CarboLite 16/20 6.2 6.0 39612 8 7.0 PPA 180.1 40.0 4.5 YF125ST 5784 CarboLite 16/20 7.2 6.9 40120 9 8.0 PPA 173.9 40.0 4.4 YF125ST 5416 CarboLite 16/20 8.3 7.9 42556 10 Clean line & Spacer 25.0 40.0 0.6 YF125ST 1044 CarboLite 16/20 7.1 0.2 194 11 Drop Collet#5 3.0 40.0 0.1 YF125ST 126 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st4 40.0 40.0 3393 3448 3291 2 1.0 PPA 40.0 40.1 3100 3290 2997 3 2.0 PPA 40.0 40.0 2916 2998 2872 4 3.0 PPA 40.0 40.0 2881 2917 2847 5 4.0 PPA 40.0 40.0 2960 2990 2915 6 5.0 PPA 40.0 40.0 3108 3241 2990 7 6.0 PPA 40.0 40.0 3440 3647 3238 8 7.0 PPA 40.0 40.0 3942 4234 3653 9 8.0 PPA 40.0 40.0 4850 5092 4243 10 Clean line & Spacer 40.0 40.0 5233 5336 5092 11 Drop Collet#5 40.0 40.0 5390 5421 5338 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 5 Once the Collet/Ball#5 hit the sleeve the pressure transition from Stage 4 to 5 was typical. Treating pressure on PAD was around 4,450 psi and slowly fell to about 2,610 psi when 1PPA was going into the formation. When 2 PPA started going into the formation the treating pressure was gradually increasing from 2,816 to 5,750 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#6 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #5 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,904 2,960 1,973 Bottomhole Pressure 3,000 3,686 3,042 Summary of Stage 5 Total Proppant Pumped (lb) 224,950 Max pumping Rate (bpm) 41.5 Total Proppant in Formation (lb) 224,950 Average Pumping Rate (bpm) 38.9 Total Slurry Pumped (bbl) 1,691.9 Maximum Treating Pressure (psi) 5,770 YF125ST Pumped (bbl) 1,454.2 Average Treating Pressure (psi) 3,685 WF125 Pumped (bbl) 0 Average Water Temperature (F) 91.1 Average Viscosity (cP)18.9 18:49:05 18:57:25 19:05:45 19:14:05 19:22:25 19:30:45 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-5FracCAT* Santos NDBi-044 02-10-2024 Collet/Ball#5 hit the sleeve. Drop Rate for Ball/Collet#6 Collet/Ball#6 hit the sleeve. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st5 204.4 39.6 5.3 YF125ST 8584 0.0 0.0 0 2 Slow For Seat 45.8 17.1 2.7 YF125ST 1922 0.0 0.0 0 3 Resume Pad 87.2 37.3 2.4 YF125ST 3663 0.0 0.0 0 4 1.0 PPA 180.0 39.6 4.5 YF125ST 7242 CarboLite 16/20 1.0 1.0 7141 5 2.0 PPA 220.0 39.7 5.6 YF125ST 8475 CarboLite 16/20 2.1 2.0 17259 6 4.0 PPA 240.1 39.7 6.1 YF125ST 8507 CarboLite 16/20 4.3 4.2 35495 7 6.0 PPA 240.2 39.7 6.1 YF125ST 7991 CarboLite 16/20 6.2 5.9 47244 8 8.0 PPA 240.2 39.5 6.1 YF125ST 7465 CarboLite 16/20 8.2 7.9 59118 9 10.0 PPA 211.7 39.6 5.4 YF125ST 6294 CarboLite 16/20 10.5 9.4 58676 10 Clean line & Spacer 19.3 41.3 0.5 YF125ST 808 CarboLite 16/20 0.6 0.0 17 11 Drop Collet#6 3.0 41.0 0.1 YF125ST 126 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st5 39.6 40.0 4454 5421 1396 2 Slow For Seat 17.1 17.4 1985 2540 1716 3 Resume Pad 37.3 40.9 2782 2921 1986 4 1.0 PPA 39.6 40.3 2768 2831 2704 5 2.0 PPA 39.7 40.4 2670 2751 2620 6 4.0 PPA 39.7 40.4 3106 3536 2753 7 6.0 PPA 39.7 40.4 3578 3675 3475 8 8.0 PPA 39.5 39.9 4340 4965 3609 9 10.0 PPA 39.6 40.9 5343 5770 4966 10 Clean line & Spacer 41.3 41.5 5644 5770 5503 11 Drop Collet#6 41.0 41.0 5504 5511 5503 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 6 Once the Collet/Ball#6 hit the sleeve the pressure transition from Stage 5 to 6 was typical. Treating pressure on PAD was around 4,200 psi and stayed stable until 4PPA hit the formation, then the treating pressure was gradually increasing from 2,690 to 5,620 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#7 to seat. While pumping stage 6 the crew encounter with the issue to offload the gel from ABT unit to PCM. The cause was found to be the product hose was plugged with J580 preventing further product to be loaded to the PCM J580 gel hopper. SLB immediately informed Santos Representatives, and option were to resolve the issue and reload before the spacer step between stage 6 and 7 or shut down for that purpose as there was not enough J580 gel in the PCM hopper to complete the job. Decision was made to launch the Ball/Collet #7, pump flush and shutdown unit the issue could be resolved. A summary of the Stage and its measured pump schedule is below: Summary of Stage 6 Total Proppant Pumped (lb) 223,569 Max pumping Rate (bpm) 42.4 Total Proppant in Formation (lb) 223,569 Average Pumping Rate (bpm) 38.8 Total Slurry Pumped (bbl) 1,942.7 Maximum Treating Pressure (psi) 5,672 YF125ST Pumped (bbl) 1,473.1 Average Treating Pressure (psi) 3,457 WF125 Pumped (bbl) 233.4 Average Water Temperature (F) 89.7 Average Viscosity (cP)18.9 19:32:47 19:44:27 19:56:07 20:07:47 20:19:27 20:31:07 20:42:47 20:54:27 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-6FracCAT* Santos NDBi-044 02-10-2024 Collet/Ball#6 hit the sleeve. Drop Rate for Ball/Collet#7 Collet/Ball#7 hit the sleeve. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st6 194.3 39.1 5 YF125ST 8165 0 0 0 2 Slow For Seat 50 16.8 3 YF125ST 2102 0 0 0 3 Resume Pad 101.2 34.3 3.3 YF125ST 4244 0 0 0 4 1.0 PPA 180 39.9 4.5 YF125ST 7248 CarboLite 16/20 1 1 6986 5 2.0 PPA 220 39.9 5.5 YF125ST 8511 CarboLite 16/20 2 1.9 16438 6 4.0 PPA 240.1 39.9 6 YF125ST 8615 CarboLite 16/20 3.9 3.8 33071 7 6.0 PPA 240.2 39.8 6 YF125ST 8005 CarboLite 16/20 6 5.9 46926 8 8.0 PPA 240.2 39.8 6 YF125ST 7478 CarboLite 16/20 8.1 7.9 58825 9 10.0 PPA 219.5 39.8 5.5 YF125ST 6503 CarboLite 16/20 10.4 9.5 61315 10 Clean line & Spacer 20.8 41.7 0.5 YF125ST 874 CarboLite 16/20 0.3 0 8 11 Drop Collet#7 3 40.1 0.1 YF125ST 126 0 0 0 12 Flush WF 179.30 39.9 4.5 WF125 7528 0 0 0 13 Slow For Seat 54.10 18.5 3.2 WF125 2273 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st6 39.1 41.0 4215 5524 1435 2 Slow For Seat 16.8 20.5 1968 2612 1767 3 Resume Pad 34.3 40.9 2558 2710 1977 4 1.0 PPA 39.9 40.4 2682 2731 2627 5 2.0 PPA 39.9 40.2 2597 2662 2567 6 4.0 PPA 39.9 40.1 2605 2702 2550 7 6.0 PPA 39.8 40.1 3000 3540 2702 8 8.0 PPA 39.8 40.3 4363 5042 3547 9 10.0 PPA 39.8 40.7 5261 5476 5043 10 Clean line & Spacer 41.7 42.4 5455 5672 5144 11 Drop Collet#7 40.1 40.3 5171 5186 5150 12 Flush WF 39.9 40.3 4279 5190 2330 13 Slow For Seat 18.5 39.2 1663 2152 221 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 7 Once the Collet/Ball#7 hit the sleeve the pressure transition from Stage 6 to 7 was typical. Treating pressure on PAD was around 2,780 psi and slowly fell to about 2,365 psi after 1PPA Scour passed through the frac port. When 2 PPA started going into the formation the treating pressure was gradually increasing from 2,450 to 5,557 psi. The Collet/Ball#8 was launched, successfully seated, and followed by a pumping Freeze Protect and hard shutdown with an ISIP of 953 psi and recording of pressure decline for 60 mins. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #7 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,640 2,356 1,640 Bottomhole Pressure 2,950 3,450 2,940 Summary of Stage 7 Total Proppant Pumped (lb) 244,785 Max pumping Rate (bpm) 42.0 Total Proppant in Formation (lb) 244,785 Average Pumping Rate (bpm) 38.3 Total Slurry Pumped (bbl) 2,383.8 Maximum Treating Pressure (psi) 5,568 YF125ST Pumped (bbl) 1,692.6 Average Treating Pressure (psi) 3,205 WF125 Pumped (bbl) 389.3 Average Water Temperature (F) 94.5 Average Viscosity (cP) 17.4 20:52:47 21:04:27 21:16:07 21:27:47 21:39:27 21:51:07 22:02:47 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-7FracCAT* Santos NDBi-04402-10-2024 Collet/Ball#8 hit the sleeve. Drop Rate for Ball/Collet#8 Suction loss from Frac Tank Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st7 275.2 37.2 8.1 YF125ST 11555 0 0 0 2 1.0PPA Scour 50.0 39.6 1.3 YF125ST 2029 CarboLite 40/70 1.1 0.8 1466 3 3.0PPA Scour 154.4 40.1 3.9 YF125ST 5777 CarboLite 40/70 3.1 2.7 14497 4 Spacer 99.8 40.2 2.5 YF125ST 4189 CarboLite 40/70 1 0 37 5 1.0 PPA 180.1 39.9 4.5 YF125ST 7259 CarboLite 16/20 1.2 0.9 6882 6 2.0 PPA 220.0 39.9 5.5 YF125ST 8503 CarboLite 16/20 2 2 16733 7 4.0 PPA 240.0 40.1 6 YF125ST 8586 CarboLite 16/20 4.1 3.9 33877 8 6.0 PPA 240.2 39.9 6 YF125ST 7986 CarboLite 16/20 6.1 5.9 47581 9 8.0 PPA 240.2 39.9 6 YF125ST 7461 CarboLite 16/20 8.2 7.9 59509 10 10.0 PPA 225.9 39.8 5.7 YF125ST 6663 CarboLite 16/20 10.3 9.6 64193 11 Clean line & Spacer 22.8 41.3 0.6 YF125ST 955 CarboLite 16/20 0.5 0 10 12 Drop Collet#8 3 40.8 0.1 YF125ST 126 0 0 0 13 WF Flush 168.7 39.3 4.3 WF125 7084 0 0 0 14 Slow For Seat 50.5 17.9 3 WF125 2119 0 0 0 15 Overflush 170.2 37.6 4.7 WF125 7146 0 0 0 16 Freeze Protect 42.8 20.3 2.1 Freeze Protect 1811 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st7 37.2 40.6 2778 3461 219 2 1.0PPA Scour 39.6 40.4 2647 2727 2543 3 3.0PPA Scour 40.1 40.5 2696 2763 2601 4 Spacer 40.2 40.6 2620 2656 2575 5 1.0 PPA 39.9 40.2 2455 2574 2370 6 2.0 PPA 39.9 40.3 2402 2465 2369 7 4.0 PPA 40.1 40.4 2563 2744 2465 8 6.0 PPA 39.9 40.1 3055 3553 2739 9 8.0 PPA 39.9 40.5 4270 4854 3555 10 10.0 PPA 39.8 40.2 5098 5384 4855 11 Clean line & Spacer 41.3 42.0 5443 5568 5168 12 Drop Collet#8 40.8 41.1 5136 5167 5091 13 WF Flush 39.3 40.2 4163 5042 2420 14 Slow For Seat 17.9 38.7 1615 2072 1544 15 Overflush 37.6 40.1 2742 2960 1653 16 Freeze Protect 20.3 20.8 1728 1898 812 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:22:48 Starter fixed. Warming up POD -0 163 0.0 0.0 0.0 2 13:38:23 Giving Blender Pressure 1 163 0.0 0.0 0.0 3 13:43:39 Priming Pumps With Diesel 44 163 0.0 5.4 0.0 4 14:11:06 Low Pressure test 221 162 0.0 0.0 0.0 5 14:16:45 High Pressure Test 9178 162 0.0 0.0 0.0 6 14:20:28 Bleeding off the pressure. PT passed 1934 163 0.0 0.0 0.0 7 14:33:41 Safety meeting 1065 162 0.0 0.0 0.0 8 15:03:23 Finished meeting 478 162 0.0 0.0 0.0 9 15:04:08 Final equipment checks 470 162 0.0 0.0 0.0 10 15:05:59 Loading the ball 452 162 0.0 0.0 0.0 11 15:06:11 Mixing 25 gel 450 162 0.0 0.0 0.0 12 16:06:57 Radio Check 155 3211 0.0 0.0 0.0 13 16:10:03 Equalize To Well Pressure 150 3207 0.0 0.0 0.0 14 16:11:39 Open Well 310 3190 0.0 0.0 0.0 15 16:12:02 Start Displ PT Automatically 310 3205 0.0 0.0 0.0 16 16:12:02 Start Propped Frac Automatically 310 3205 0.0 0.0 0.0 17 16:12:02 Start Displacement Automatically 310 3205 0.0 0.0 0.0 18 16:12:18 Started Pumping 305 3204 0.0 0.0 0.0 19 16:33:07 Stopped Pumping 669 3218 69.1 0.0 0.0 20 16:46:00 Started Pumping 249 3229 69.1 0.0 0.0 21 16:46:01 Start Shut Down Automatically 248 3229 69.1 0.0 0.0 22 16:46:16 Start Displ PT Manually 248 3229 69.1 0.0 0.0 23 16:49:11 Stopped Pumping 646 3249 75.2 0.0 0.0 24 17:08:55 Started Pumping 241 3233 75.2 0.0 0.0 25 17:08:59 Start Ball to Seat Manually 241 3233 75.2 0.0 0.0 26 17:52:07 Ball & Collet Seated 1044 3387 242.1 4.0 0.0 27 17:52:38 Start Pump Check Manually 1314 3402 244.5 5.8 0.0 28 17:53:19 Stage at Perfs: Displ PT 1934 3435 257.1 14.5 0.0 Stage 4 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 17:56:05 Start PAD st4 Manually 3352 3440 342.0 39.9 0.0 2 17:56:05 Start Propped Frac Manually 3352 3440 342.0 39.9 0.0 3 17:56:05 Start Stage 4 Automatically 3352 3440 342.0 39.9 0.0 4 18:00:05 Stage at Perfs: Ball to Seat 3431 3458 160.0 40.0 0.0 5 18:02:31 Stage at Perfs: PAD st4 3405 3482 257.4 40.0 0.0 6 18:04:50 Start 1.0 PPA Automatically 3290 3414 350.1 40.0 0.0 7 18:04:50 Started Pumping Prop 3290 3414 350.1 40.0 0.0 8 18:09:20 Start 2.0 PPA Automatically 3001 3421 530.1 40.0 1.0 9 18:11:15 Stage at Perfs: 1.0 PPA 2914 3465 606.8 40.0 1.9 10 18:13:50 Start 3.0 PPA Automatically 2876 3440 710.2 40.0 2.0 11 18:15:45 Stage at Perfs: 2.0 PPA 2855 3478 786.9 40.0 3.0 12 18:18:50 Start 4.0 PPA Automatically 2912 3415 910.3 40.0 3.0 13 18:20:15 Stage at Perfs: 3.0 PPA 2926 3443 966.9 40.0 4.1 14 18:23:50 Start 5.0 PPA Automatically 3001 3437 1110.3 40.0 4.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 15 18:25:15 Stage at Perfs: 4.0 PPA 3048 3449 1167.0 40.0 4.9 16 18:28:50 Start 6.0 PPA Automatically 3241 3480 1310.3 40.0 5.1 17 18:30:15 Stage at Perfs: 5.0 PPA 3376 3436 1367.0 40.0 5.9 18 18:33:51 Start 7.0 PPA Automatically 3653 3467 1511.1 40.1 6.1 19 18:35:15 Stage at Perfs: 6.0 PPA 3847 3483 1567.1 40.0 6.9 20 18:38:21 Start 8.0 PPA Automatically 4243 3452 1691.1 40.0 6.9 21 18:40:16 Stage at Perfs: 7.0 PPA 4681 3462 1767.7 40.0 7.9 22 18:42:31 Start Clean line & Spacer Manually 5089 3468 1857.7 40.0 7.8 23 18:42:34 Start 8.0 PPA Manually 5089 3469 1859.7 40.0 7.8 24 18:42:41 Start Clean line & Spacer Manually 5099 3468 1864.4 40.0 1.8 25 18:42:52 Stopped Pumping Prop 5239 3470 1871.7 40.0 0.0 26 18:43:19 Start Drop Collet#5 Automatically 5463 3482 1889.7 40.0 0.0 Stage 5 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 18:43:24 Start PAD st5 Automatically 5393 3479 0.0 39.9 0.0 2 18:43:24 Start Propped Frac Automatically 5393 3479 0.0 39.9 0.0 3 18:43:24 Start Stage 5 Automatically 5393 3479 0.0 39.9 0.0 4 18:44:46 Stage at Perfs: 8.0 PPA 5015 3442 54.7 40.0 0.0 5 18:48:39 Start Slow For Seat Automatically 1634 3360 203.5 17.0 0.0 6 18:49:41 Stage at Perfs: Clean line &Spacer 1914 3367 221.0 17.0 0.0 7 18:49:49 Stage at Perfs: 8.0 PPA 1919 3371 223.3 16.9 0.0 8 18:50:05 Stage at Perfs: Clean line &Spacer 1929 3375 227.8 17.0 0.0 9 18:50:18 Ball & Collet Seated 2173 3379 231.5 17.1 0.0 10 18:51:19 Start Resume Pad Manually 1992 3377 249.1 17.4 0.0 11 18:51:33 Stage at Perfs: 8.0 PPA 2873 3396 253.3 20.1 0.0 12 18:51:41 Stage at Perfs: Clean line & Spacer 2769 3411 256.5 28.6 0.0 13 18:53:44 Deactivated Extend Stage 2829 3425 336.7 40.1 0.0 14 18:53:44 Start 1.0 PPA Manually 2829 3425 336.7 40.1 0.0 15 18:53:44 Started Pumping Prop 2829 3425 336.7 40.1 0.0 16 18:56:38 Stage at Perfs: Drop Collet#5 2776 3458 451.2 40.2 1.0 17 18:57:47 Stage at Perfs: PAD st5 2732 3469 496.9 40.0 1.0 18 18:58:17 Start 2.0 PPA Automatically 2708 3473 517.0 40.5 1.0 19 18:59:59 Stage at Perfs: Slow For Seat 2629 3427 584.2 39.4 2.1 20 19:03:50 Start 4.0 PPA Automatically 2756 3485 737.0 40.2 2.1 21 19:04:32 Stage at Perfs: Resume Pad 2845 3496 764.7 39.2 4.2 22 19:09:53 Start 6.0 PPA Automatically 3518 3446 976.9 39.6 4.0 23 19:10:05 Stage at Perfs: 1.0 PPA 3557 3450 984.8 39.4 5.4 24 19:15:57 Start 8.0 PPA Automatically 3613 3408 1217.6 39.6 6.0 25 19:16:07 Stage at Perfs: 2.0 PPA 3636 3406 1224.2 39.5 6.8 26 19:22:01 Start 10.0 PPA Automatically 5004 3423 1457.3 39.7 8.0 27 19:22:13 Stage at Perfs: 4.0 PPA 5013 3425 1465.3 39.8 9.2 28 19:27:22 Start Clean line &Spacer Manually 5764 3439 1669.0 41.1 0.2 29 19:27:25 Stopped Pumping Prop 5723 3441 1671.1 41.2 0.2 30 19:27:50 Start Drop Collet#6 Manually 5523 3439 1688.3 40.8 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 6 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 19:27:55 Start PAD st6 Automatically 5565 3441 0.0 40.8 0.0 2 19:27:55 Start Propped Frac Automatically 5565 3441 0.0 40.8 0.0 3 19:27:55 Start Stage 6 Automatically 5565 3441 0.0 40.8 0.0 4 19:28:15 Stage at Perfs: 6.0 PPA 5316 3437 13.5 40.2 0.0 5 19:32:56 Start Slow For Seat Manually 1808 3415 193.6 19.4 0.0 6 19:34:46 Stage at Perfs: 8.0 PPA 1949 3425 224.5 16.5 0.0 7 19:35:18 Ball & Collet Seated 1926 3430 233.2 16.4 0.0 8 19:35:56 Stage at Perfs: 10.0 PPA 2062 3436 243.6 16.5 0.0 9 19:35:56 Start Resume Pad Automatically 2062 3436 243.6 16.5 0.0 10 19:36:09 Stage at Perfs: Clean line & Spacer 2071 3442 247.2 16.4 0.0 11 19:39:12 Start 1.0 PPA Manually 2702 3487 345.1 40.0 0.0 12 19:39:12 Started Pumping Prop 2702 3487 345.1 40.0 0.0 13 19:41:25 Stage at Perfs: Drop Collet#6 2716 3411 433.2 39.9 1.0 14 19:42:40 Stage at Perfs: PAD st6 2651 3433 483.2 40.0 1.0 15 19:43:43 Start 2.0 PPA Automatically 2638 3435 525.2 40.0 1.0 16 19:45:12 Stage at Perfs: SlowForSeat 2588 3433 584.4 40.1 2.0 17 19:49:14 Start 4.0 PPA Automatically 2606 3434 745.4 39.9 2.0 18 19:49:43 Stage at Perfs: Resume Pad 2635 3437 764.7 40.1 3.9 19 19:55:14 Stage at Perfs: 1.0 PPA 2704 3442 984.6 39.8 3.9 20 19:55:15 Start 6.0 PPA Automatically 2708 3440 985.3 39.8 3.9 21 20:01:16 Stage at Perfs: 2.0 PPA 3551 3457 1224.5 39.6 5.9 22 20:01:18 Start 8.0 PPA Automatically 3571 3455 1225.8 39.8 5.9 23 20:07:19 Stage at Perfs: 4.0 PPA 5065 3472 1465.1 40.3 7.9 24 20:07:20 Start 10.0 PPA Automatically 5067 3473 1465.8 40.1 7.9 27 20:12:51 Start Clean line & Spacer Manually 5650 3473 1685.1 41.2 0.1 28 20:12:55 Stopped Pumping Prop 5682 3479 1687.9 41.9 0.0 29 20:13:20 Stage at Perfs: 6.0 PPA 5188 3466 1705.3 40.0 0.0 30 20:13:21 Start Drop Collet#7 Manually 5198 3464 1705.9 39.9 0.0 31 20:13:26 Start PAD s7 Automatically 5212 3465 0.0 39.8 0.0 32 20:13:26 Start Propped Frac Automatically 5212 3465 0.0 39.8 0.0 33 20:13:26 Start Stage 7 Automatically 5212 3465 0.0 39.8 0.0 34 20:17:55 Start Slow For Seat Manually 1219 3380 178.8 32.0 0.0 35 20:19:55 Ball & Collet Seated 2187 3450 214.3 17.2 0.0 36 20:19:57 Stage at Perfs: 8.0 PPA 2123 3384 214.9 17.0 0.0 37 20:21:04 Stopped Pumping 881 3381 232.4 2.6 0.0 Stage 7 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 20:58:04 Started Pumping 218 3184 232.4 0.0 0.0 2 20:58:10 Start Resume Pad Automatically 220 3212 232.4 0.0 0.0 3 20:59:10 Stage at Perfs: 10.0 PPA 3153 3421 235.8 22.4 0.0 4 20:59:18 Stage at Perfs: Clean line & Spacer 2934 3412 239.4 30.2 0.0 5 21:03:37 Stage at Perfs: Drop Collet#7 2391 3423 407.9 34.1 0.0 6 21:05:12 Stage at Perfs: PAD s7 2222 3453 461.9 34.1 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 7 21:06:28 Start 1.0PPA Scour Manually 2655 3492 508.2 40.1 0.0 8 21:06:28 Started Pumping Prop 2655 3492 508.2 40.1 0.0 9 21:07:44 Start 3.0PPA Scour Automatically 2727 3445 558.3 40.0 1.0 10 21:11:35 Start Spacer Manually 2623 3441 712.6 39.8 0.4 11 21:11:40 Stopped Pumping Prop 2588 3439 715.9 39.9 0.1 12 21:12:12 Stage at Perfs: Slow For Seat 2652 3445 737.4 40.7 0.0 13 21:13:27 Stage at Perfs: Resume Pad 2595 3452 787.6 40.1 0.0 14 21:14:04 Start 1.0 PPA Manually 2562 3458 812.4 40.1 0.0 15 21:14:13 Started Pumping Prop 2561 3459 818.4 39.8 0.0 16 21:17:18 Stage at Perfs: 1.0PPA Scour 2369 3477 941.3 40.0 1.0 17 21:18:35 Start 2.0 PPA Automatically 2375 3482 992.7 40.1 1.0 18 21:19:48 Stage at Perfs: 3.0PPA Scour 2375 3485 1041.3 40.0 2.0 19 21:24:06 Start 4.0 PPA Automatically 2464 3418 1212.8 39.9 2.0 20 21:24:19 Stage at Perfs: Spacer 2481 3412 1221.4 39.7 3.3 21 21:29:49 Stage at Perfs: 1.0 PPA 2719 3382 1441.8 40.1 4.0 22 21:30:06 Start 6.0 PPA Automatically 2741 3385 1453.2 40.0 4.0 23 21:35:50 Stage at Perfs: 2.0 PPA 3514 3356 1681.8 39.7 6.0 24 21:36:07 Start 8.0 PPA Automatically 3565 3357 1693.1 39.7 5.9 25 21:41:51 Stage at Perfs: 4.0 PPA 4844 3376 1921.8 39.9 8.1 26 21:42:08 Start 10.0 PPA Automatically 4890 3380 1933.0 39.7 8.1 27 21:47:48 Start Clean line & Spacer Manually 5458 3389 2158.8 40.1 0.1 28 21:47:52 Stopped Pumping Prop 5574 3393 2161.5 40.6 0.0 29 21:47:53 Stage at Perfs: 6.0 PPA 5554 3389 2162.1 40.7 0.0 30 21:48:21 Start Drop Collet#8 Manually 5076 3386 2181.5 40.4 0.0 31 21:48:26 Start WF Flush Automatically 4975 3385 2184.9 39.9 0.0 32 21:52:43 Start Slow For Seat Manually 1231 3319 2353.1 32.9 0.0 33 21:54:44 Stage at Perfs: 8.0 PPA 1491 3336 2387.2 15.8 0.0 34 21:54:46 Ball & Collet Seated 1782 3363 2387.7 15.8 0.0 35 21:55:45 Start Overflush Manually 2307 3392 2403.3 18.6 0.0 36 21:56:01 Stage at Perfs: 10.0 PPA 2581 3397 2410.5 30.5 0.0 37 21:56:07 Stage at Perfs: Clean line & Spacer 2657 3393 2413.8 34.9 0.0 38 22:00:25 Start Freeze Protect Manually 1665 3419 2573.5 20.8 0.0 39 22:00:49 Stage at Perfs: WF Flush 1665 3420 2581.6 20.3 0.0 40 22:02:34 Stopped Pumping 1248 3407 2616.3 0.0 0.0 41 22:04:13 Close Well 959 3381 2616.3 0.0 0.0 42 22:06:36 Fanning Pumps, Cleaning the line and equipment 7 3363 2616.3 4.7 0.0 FracCAT Treatment Report Well : NDBi-044 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : February 16, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi) 292 Initial BHP at Gauge (psi) - Final Surface ISIP (psi) 1,078 Final ISIP at Gauge (psi) 2,629 Surface Shut in Pressure(psi) 2,106 BH Shut in Pressure (psi) 2,119 Maximum Treating Pressure (psi) 8,153 BH Gauge at 10,747 ft MD, 4,030 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)7,736.8 Total Proppant Pumped (lb) (per Load Tickets)951,448 Total YF125ST Past Wellhead (bbl) 5,895.7 Total Proppant in Formation (lb) 951,448 Total WF125 Past Wellhead (bbl) 838.5 Total Freeze Protect Past Wellhead (bbl) 46.4 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal) 284 284 M275 (lb) 96 94.6 J450 (gal) 183 183 J753 (gal) 17.4 15.7 J580 (lb) 7,380 7,265 J475 (lb) 1677.5 1677.5 J532 (gal) 646 646 J134 (lb) 11 0 J511 (lb) 500 482 D206 (gal) 3 3 M002 0.5 0.48 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown d ata and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's be st estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Summary On February 15, 2024, SLB successfully performed a hydraulic fracturing treatment on Stages 8-11 of NDBi-044. According to the initial plan called for the completion of stages 8-11, there was change of PAD step volume for stage 8 (from 350bbl to 380bbl) and Resume Pad step volume for Stage 9 (from 135bbl to 165bbl) before pumping started. When started pumping Displacement PT step there was an accidental well shut in, GORV popped off. The pumping was continued after GORV was rebuilt and the incident was investigated. When Ball/Collet#10 was seated successfully then moved to DFIT step and hard shutdown followed by monitor pressure decline. Before resuming pumping, there was change of Resume Pad step volume for Stage 11 (from 77bbl to 202bbl, during pumping step volume was changed again from 202bbl to 152bbl), step 1PPA slurry volume (from 150bbl to 180bbl), step 3PPA slurry volume (from 200bbl to220bbl), step 5PPA slurry volume (from 240bbl to 260bbl), step 7PPA slurry volume (from 215bbl to230bbl), step 10PPA slurry volume (from 190bbl to200bbl) to pump all proppant from the Sandchiefs. Once stage 11 was completed successfully it was followed by hard shutdown. Post shutdown pressure decline was monitored for 60 min. By BOL Physical count, a total of 951,448 pounds of proppant was pumped and 951,448 lbs were placed into formation in 7,734 bbl of slurry. Please note, that proppant Volumes are as per BOL physical weight count. Stages 8, 9 and 10 consisted of a PAD, and 6 proppant steps from 1-2-4-6-8-10 PPA, Stages 11 consisted of a PAD, and 6 proppant steps from 1-3-5-7-9-10 PPA. Pump trips were staggered from 7,600 to 8,000 psi. The GORV was set to 8,300 psi. The highlight of the stages was that the collet launch sequence greatly improved with the addition of a second line going to the wellhead. Summary of Stages 8-11 Material Actual Design Slurry Volume (bbl)7,737 7,827 Clean Fluid Volume(bbl) 6,734 6,786 Proppant (lb) 951,448 932,277 08:45:20 10:17:00 11:48:40 13:20:20 14:52:00 16:23:40 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 16 18 20 22 24 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 02-15-2024 Stage8 Stage9 Stage11Stage10 Displ PT Ball to Seat Pump Check Displ PT Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check. Stage included PT displacement, pumping Ball#8 to seat and pump check that was placed in the schedule to test the equipment and ensure the pumps were job ready. After step Pump Check was pumped, then moved to pumping Stage#8 without shutdown. A summary of the stage and pressures as follows: Summary of Stage Displacement PT, Ball to Seat and Pump Check Total Proppant Pumped (lb)0 Max pumping Rate (bpm)40.0 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)8.6 Total Slurry Pumped (bbl)270.6 Maximum Treating Pressure (psi)8,153 YF125ST Pumped (bbl)0 Average Treating Pressure (psi)1,483 WF125 Pumped (bbl)270.6 Average Water Temperature (F)95.1 Average Viscosity (cP)19.0 08:09:13 08:42:33 09:15:53 09:49:13 10:22:33 10:55:53 11:29:13 12:02:33 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 10 20 30 40 50 0 5 10 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-43 08-26-2023 PT Displacement Pumping Ball to Seat Pump Check PT Displacement Pressure Test Accidental master valve shut in Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT(1)26.5 3.4 8 WF125 1114 0 0 0 2 Displ PT (2)40 3.4 11.9 WF125 1678 0 0 0 3 Shut Down 4 Ball to Seat 154.7 4 38.8 WF125 6497 0 0 0 5 Pump Check 49.4 31.4 1.8 WF125 2076 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT (1) 3.4 0.0 1199 8153 8152 2 Displ PT (2) 3.4 3.9 1132 8153 294 3 Shut Down 3.4 3.9 1132 8153 294 4 Ball to Seat 4.0 4.2 1131 1176 688 5 Pump Check 31.4 40.0 3098 3651 1118 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 8 Before the job was started, Santos changed PAD volume from 350bbl to 380bbl. The treating pressure on PAD was around 3,200 psi and slowly fell to about 2,580 psi when 1PPA was going into the formation. When 2PPA was going into formation the treating pressure was gradually increasing from 2,580 to 5,160 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#9 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #8 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,564 2,360 1,564 Bottomhole Pressure 2,898 3,310 2,869 Summary of Stage 8 Total Proppant Pumped (lb) 242,605 Max pumping Rate (bpm)42.1 Total Proppant in Formation (lb) 242,605 Average Pumping Rate (bpm)40.0 Total Slurry Pumped (bbl) 1,756.0 Maximum Treating Pressure (psi)5,150 YF125ST Pumped (bbl) 1,515.5 Average Treating Pressure (psi)3,311 WF125 Pumped (bbl) 0 Average Water Temperature (F)96.2 Average Viscosity (cP)18.5 12:10:18 12:31:08 12:51:58 13:12:48 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 8 02-15-2024 Collet/Ball#9 hit the sleeve Drop Rate for Ball/Collet#9 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st8 380 40.1 9.5 YF125ST 15961 0 0 0 2 1.0 PPA 180 39.9 4.5 YF125ST 7261 CarboLite 16/20 1 0.9 7137 3 2.0 PPA 220 40 5.5 YF125ST 8503 CarboLite 16/20 2.1 2 17693 4 4.0 PPA 240 39.8 6 YF125ST 8587 CarboLite 16/20 4.1 3.9 35817 5 6.0 PPA 240 40 6 YF125ST 7986 CarboLite 16/20 6.1 5.9 50253 6 8.0 PPA 240 39.7 6 YF125ST 7461 CarboLite 16/20 8.2 7.9 62872 7 10.0 PPA 236.4 40 5.9 YF125ST 7069 CarboLite 16/20 10.2 9.2 68831 8 Clean line & Spacer 16.6 41.6 0.4 YF125ST 698 CarboLite 16/20 0.1 0 2 9 Drop Collet#9 3 41.2 0.1 YF125ST 126 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st8 40.1 42.1 2929 3438 2697 2 1.0 PPA 39.9 40.2 2695 2719 2668 3 2.0 PPA 40.0 40.4 2597 2680 2568 4 4.0 PPA 39.8 40.0 2678 2861 2579 5 6.0 PPA 40.0 40.4 3139 3589 2861 6 8.0 PPA 39.7 40.2 4163 4618 3589 7 10.0 PPA 40.0 41.6 4872 5150 4538 8 Clean line & Spacer 41.6 41.7 4950 5074 4821 9 Drop Collet#9 41.2 41.2 4831 4839 4821 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 9 Before the job was started, Santos changed Resume PAD step volume from 135bbl to 165bbl and. Once the Collet/Ball#9 hit the sleeve the pressure transition from Stage 8to 9was typical. Treating pressure on PAD was around 2,350psi and slowly fell to about 2,280 psi when 1PPA was going into the formation. When 2 PPA started going into the formation the treating pressure was gradually increasing from 2,280 to 4,750 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#10 to seat, then was pumped DFIT for stage 10 with further hard shutdown and pressure decline recording (Resume LG DFITstep volume was changed from 300bbl to 250bbl by Santos during the pumping to make sure there will be enough clean fluid to finish all stages). A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #9 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,005 2,430 1,821 Bottomhole Pressure 2,956 3,225 2,853 Summary of Stage 9 Total Proppant Pumped (lb) 241,854 Max pumping Rate (bpm) 41.6 Total Proppant in Formation (lb) 241,854 Average Pumping Rate (bpm) 38.1 Total Slurry Pumped (bbl) 2,245.5 Maximum Treating Pressure (psi) 4,839 YF125ST Pumped (bbl) 1,563.5 Average Treating Pressure (psi) 2,998 WF125 Pumped (bbl) 442.6 Average Water Temperature (F) 99.2 Average Viscosity (cP) 18.5 13:13:41 13:38:41 14:03:41 14:28:41 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 9 02-15-2024 Collet/Ball#9 hit the sleeve. Drop Rate for Ball/Collet#10 Collet/Ball#10 hit the sleeve. DFIT Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st9 164.4 39.2 4.3 YF125ST 6946 CarboLite 16/20 0 0 0 2 Slow For Seat 102.4 17.6 6.6 YF125ST 4299 CarboLite 16/20 0 0 0 3 Resume Pad 164.9 37.1 4.6 YF125ST 6921 0 0 0 4 1.0 PPA 180 39.9 4.5 YF125ST 7260 CarboLite 16/20 1.1 0.9 7194 5 2.0 PPA 220 39.9 5.5 YF125ST 8501 CarboLite 16/20 2.1 2 17687 6 4.0 PPA 240 40 6 YF125ST 8590 CarboLite 16/20 4.1 3.9 35645 7 6.0 PPA 240 39.9 6 YF125ST 7984 CarboLite 16/20 6.3 5.9 50161 8 8.0 PPA 240 40 6 YF125ST 7460 CarboLite 16/20 8.2 7.9 62768 9 10.0 PPA 229.5 40 5.7 YF125ST 6800 CarboLite 16/20 10.5 9.5 68392 10 Clean line & Spacer 18.6 41.4 0.5 YF125ST 780 CarboLite 16/20 0.2 0 7 11 Drop Collet#10 3 40.7 0.1 YF125ST 126 0 0 0 12 LG DFIT 153.1 40 3.8 WF125 6429 0 0 0 13 Slow For Seat 43.5 21.8 2.2 WF125 1827 0 0 0 14 Resume LG DFIT 246.1 38.1 6.7 WF125 10333 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st9 39.2 41.1 3750 4839 1447 2 Slow For Seat 17.6 21.8 1959 2820 781 3 Resume Pad 37.1 41.4 2307 2454 1830 4 1.0 PPA 39.9 40.3 2290 2373 2252 5 2.0 PPA 39.9 40.1 2265 2321 2224 6 4.0 PPA 40.0 40.2 2369 2495 2293 7 6.0 PPA 39.9 40.2 2792 3281 2493 8 8.0 PPA 40.0 40.3 3959 4504 3276 9 10.0 PPA 40.0 41.4 4679 4767 4464 10 Clean line & Spacer 41.4 41.6 4508 4644 4356 11 Drop Collet#10 40.7 40.8 4371 4403 4356 12 LG DFIT 40.0 40.6 3642 4403 2901 13 Slow For Seat 21.8 40.1 1669 2891 1535 14 Resume LG DFIT 38.1 40.3 2568 2704 383 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 10 Once the Collet/Ball#10hit the sleeve the pressure transition from Stage 10to 11 was typical. Treating pressure on PAD was around 2,220 psi and stayed stable until 3 PPA hit the formation, then the treating pressure was gradually increasing from 2,330 to 4,080 psi. Collet/Ball#11 was launched, successfully seated. While pumping stage 10 there was electronic glitch when taking the POD from remote back to manual (physically blender gates were not moving like concentration pattern). A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet#10 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,570 2,030 1,526 Bottomhole Pressure 2,852 3,148 2,846 Summary of Stage 10 Total Proppant Pumped (lb) 240,700 Max pumping Rate (bpm) 42.4 Total Proppant in Formation (lb) 240,700 Average Pumping Rate (bpm) 39.7 Total Slurry Pumped (bbl) 1,714.8 Maximum Treating Pressure (psi) 4,863 YF125ST Pumped (bbl) 1,475.6 Average Treating Pressure (psi) 2,847 WF125 Pumped (bbl) 0 Average Water Temperature (F) 99.0 Average Viscosity (cP) 18.4 14:55:15 15:05:15 15:15:15 15:25:15 15:35:15 15:45:15 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 10 02-15-2024 Electronic glitch Collet/Ball#11 hit the sleeve. Drop Rate for Ball/Collet#11 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st10 350 38.3 10 YF125ST 14672 0 0 0 2 1.0 PPA 180 39.9 4.5 YF125ST 7259 CarboLite 16/20 1.1 0.9 7199 3 2.0 PPA 220 40.1 5.5 YF125ST 8503 CarboLite 16/20 2.1 2 17684 4 4.0 PPA 240 40 6 YF125ST 8586 CarboLite 16/20 4.2 3.9 35844 5 6.0 PPA 240 39.9 6 YF125ST 7989 CarboLite 16/20 7.3 5.9 50198 6 8.0 PPA 240 39.9 6 YF125ST 7463 CarboLite 16/20 8.2 7.9 62846 7 10.0 PPA 224.1 40.1 5.6 YF125ST 6634 CarboLite 16/20 11 9.5 66914 8 Clean line & Spacer 17.7 41 0.4 YF125ST 742 CarboLite 16/20 0.5 0 15 9 Drop Collet#11 3 39.9 0.1 YF125ST 126 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st10 38.3 42.4 2481 3109 380 2 1.0 PPA 39.9 40.4 2303 2338 2280 3 2.0 PPA 40.1 40.4 2245 2299 2216 4 4.0 PPA 40.0 40.4 2312 2445 2226 5 6.0 PPA 39.9 40.4 2633 2979 2436 6 8.0 PPA 39.9 40.1 3472 3956 2923 7 10.0 PPA 40.1 41.5 4435 4863 3946 8 Clean line & Spacer 41.0 41.6 4529 4787 4339 9 Drop Collet#11 39.9 40.0 4370 4410 4340 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 11 Once the Collet/Ball#11hit the sleeve the pressure transition from Stage 10to 11was typical. Treating pressure on PAD was around 2,850 psi and stayed stable until 3 PPA started going into the formation. then the treating pressure was gradually increasing from 2,850 to 4,080 psi. Flush step followed by pumping Freeze Protect and hard shutdown with an ISIP of 1,078 psi and recording of pressure decline for 60 mins. While pumping stage 11 was electronic glitch when taking the POD from remote back to manual (physically blender gates were not moving like concentration pattern). A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet#11 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,859 2,347 1,893 Bottomhole Pressure 2,786 3,123 2,798 Summary of Stage 11 Total Proppant Pumped (lb) 226,289 Max pumping Rate (bpm) 41.6 Total Proppant in Formation (lb) 226,289 Average Pumping Rate (bpm) 38.4 Total Slurry Pumped (bbl) 1,749.9 Maximum Treating Pressure (psi) 4,515 YF125ST Pumped (bbl) 1,341.1 Average Treating Pressure (psi) 2,889 WF125 Pumped (bbl) 125.3 Average Water Temperature (F) 98.3 Average Viscosity (cP) 19.2 15:46:53 15:59:23 16:11:53 16:24:23 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 5 10 15 20 25 30 35 40 45 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 11 02-15-2024 Collet/Ball#11 hit the sleeve. Brought pump#7 back Electronic glitch Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st11 145.9 39.3 3.7 YF125ST 6128 0 0 0 2 Slow For Seat 44.9 20.8 2.3 YF125ST 1887 0 0 0 3 Resume Pad 156.9 36.4 4.6 YF125ST 6587 0 0 0 4 1.0 PPA 180.0 40 4.5 YF125ST 7257 CarboLite 16/20 1.1 0.9 7268 5 3.0 PPA 220.0 40.1 5.5 YF125ST 8182 CarboLite 16/20 3.1 2.9 25331 6 5.0 PPA 260.0 40 6.5 YF125ST 8965 CarboLite 16/20 5.3 4.9 46902 7 7.0 PPA 230.0 39.8 5.8 YF125ST 7392 CarboLite 16/20 7.3 6.9 54438 8 9.0 PPA 230.0 40 5.8 YF125ST 6926 CarboLite 16/20 9.7 8.9 65649 9 10.0 PPA 97.8 40 2.4 YF125ST 3001 CarboLite 16/20 10.2 8.5 26697 10 WF Flush 125.1 39.2 3.3 WF125 5262 CarboLite 16/20 0.2 0 4 11 Freeze Protect 59.3 20.5 2.9 FP 2495 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st11 39.3 40.8 3558 4515 2210 2 Slow For Seat 20.8 39.8 1784 1915 1657 3 Resume Pad 36.4 40.3 2217 2404 1837 4 1.0 PPA 40.0 40.8 2243 2271 2186 5 3.0 PPA 40.1 41.5 2261 2338 2177 6 5.0 PPA 40.0 40.5 2477 2707 2333 7 7.0 PPA 39.8 40.2 3201 3578 2705 8 9.0 PPA 40.0 40.4 3875 4054 3506 9 10.0 PPA 40.0 41.6 3954 4066 3869 10 WF Flush 39.2 41.6 3476 3973 1782 11 Freeze Protect 20.5 23.4 1936 2114 1777 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 6:47:15 Priming Pumps With Diesel 29 150 0.0 0.0 0.0 2 7:00:36 Mixing gel #25 41 150 0.0 0.0 0.0 3 7:15:53 Low Pressure Test 338 150 0.0 0.0 0.0 4 7:19:41 Mid Pressure Test 5093 150 0.0 0.0 0.0 5 7:24:09 Mid Pressure Test 4359 150 0.0 0.0 0.0 6 7:28:25 High Pressure Test 9501 150 0.0 0.0 0.0 7 7:33:58 Bump up the pressure to 9500 9514 149 0.0 0.0 0.0 8 7:39:18 Pressure test is good 9160 149 0.0 0.0 0.0 9 7:45:54 LR pressure test their line 954 149 0.0 0.0 0.0 10 7:55:13 LR pressure IA to 3400psi 918 149 0.0 0.0 0.0 11 8:10:43 Safety Meeting 679 3217 0.0 0.0 0.0 12 8:44:55 Safety Meeting Completed 220 3259 0.0 0.0 0.0 13 8:50:39 Radio check 189 3194 0.0 0.0 0.0 14 9:03:26 Bump Up To Equalize 935 3129 0.0 0.0 0.0 15 9:03:58 Open Well 303 3124 0.0 0.0 0.0 16 9:04:49 Start Displ PT (1) Automatically 291 3122 0.0 0.0 0.0 17 9:04:49 Start Displacement Automatically 291 3122 0.0 0.0 0.0 18 9:05:01 Started Pumping 425 3125 0.0 0.0 0.0 19 9:08:01 Loading ball in the Ball/Collet launcher 1153 3235 9.6 3.5 0.0 20 9:14:18 Stopped Pumping 8142 3159 26.5 0.0 0.0 21 9:16:26 GORV popped off. 619 3146 26.5 0.0 0.0 22 9:19:38 Master valve accidentally shut in 455 3131 26.5 0.0 0.0 23 9:20:15 Rebuilding the GORV 429 3128 26.5 0.0 0.0 24 9:29:38 Flushing the gel to bleed off tank 193 3082 26.5 1.8 0.0 25 9:43:04 Rolling up the pumps with diesel 213 2997 26.5 5.3 0.0 26 10:03:25 GORV set 3 2871 26.5 0.0 0.0 27 10:20:43 Refilling the diesel transport -1 2800 26.5 0.0 0.0 28 10:44:52 Spot & Rig Up Diesel Transport 0 2709 26.5 0.0 0.0 29 10:51:57 Low Pressure Test 553 2685 26.5 0.0 0.0 30 10:58:15 High Pressure Test 9481 2663 26.5 0.0 0.0 31 10:58:39 High Pressure Test 9591 2662 26.5 0.0 0.0 32 11:05:07 Pressure test is good 811 3135 26.5 0.0 0.0 33 11:05:16 Bleed off the pressure 842 3181 26.5 0.0 0.0 34 11:07:13 Open well 252 3260 26.5 0.0 0.0 35 11:08:22 Restart Treatment 294 3262 26.5 0.0 0.0 36 11:08:22 Start Displ PT (2) Automatically 294 3262 26.5 0.0 0.0 37 11:08:22 Started Pumping 294 3262 26.5 0.0 0.0 38 11:17:53 Launched /the ball 1197 3211 56.3 3.5 0.0 39 11:20:55 Start Shut Down Automatically 1123 3203 66.6 3.5 0.0 40 11:20:56 Start Ball to Seat Automatically 1102 3203 66.6 3.5 0.0 41 11:21:04 Stopped Pumping 979 3199 66.9 0.0 0.0 42 11:33:55 Start Displ PT Automatically 415 3323 66.9 0.0 0.0 43 11:33:55 Started Pumping 415 3323 66.9 0.0 0.0 44 11:34:11 Start Ball to Seat Manually 702 3334 67.2 3.5 0.0 45 12:09:08 Stage at Perfs: Displ PT 1095 3479 206.3 4.0 0.0 46 12:12:35 Ball Seated 1121 3482 220.2 4.0 0.0 47 12:12:50 Start Pump Check Manually 1160 3482 221.2 4.0 0.0 48 12:13:35 Stage at Perfs: Displ PT 2729 3525 233.4 25.9 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 8 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 12:14:39 Start PAD st8 Manually 3414 3566 271.3 40.0 0.0 2 12:14:39 Start Propped Frac Manually 3414 3566 271.3 40.0 0.0 3 12:14:39 Start Stage 8 Automatically 3414 3566 271.3 40.0 0.0 4 12:14:43 Stage at Perfs: Shut Down 3384 3561 2.7 40.0 0.0 5 12:14:44 Stage at Perfs: Shut Down 3385 3564 3.3 40.0 0.0 6 12:18:35 Stage at Perfs: Ball to Seat 2879 3515 157.3 40.0 0.0 7 12:19:50 Stage at Perfs: Ball to Seat 2921 3523 207.3 40.0 0.0 8 12:24:08 Start 1.0 PPA Automatically 2718 3458 380.1 40.0 0.0 9 12:24:08 Started Pumping Prop 2718 3458 380.1 40.0 0.0 10 12:28:39 Start 2.0 PPA Automatically 2681 3464 560.3 39.9 1.0 11 12:29:18 Stage at Perfs: Pump Check 2661 3477 586.3 40.0 2.0 12 12:33:49 Stage at Perfs: PAD st8 2588 3429 767.1 40.2 2.0 13 12:34:09 Start 4.0 PPA Automatically 2599 3432 780.4 40.0 2.0 14 12:39:20 Stage at Perfs: 1.0 PPA 2811 3476 986.9 39.8 4.0 15 12:40:10 Start 6.0 PPA Automatically 2865 3487 1020.2 39.7 4.0 16 12:45:20 Stage at Perfs: 2.0 PPA 3475 3403 1226.5 40.1 6.0 17 12:46:10 Start 8.0 PPA Automatically 3602 3421 1260.0 40.0 6.0 18 12:51:22 Stage at Perfs: 4.0 PPA 4543 3496 1466.4 39.8 8.0 19 12:52:13 Start 10.0 PPA Automatically 4617 3504 1500.4 40.2 7.9 20 12:57:23 Stage at Perfs: 6.0 PPA 5111 3511 1706.5 40.4 9.4 21 12:58:07 Start Clean line & Spacer Manually 5083 3513 1736.3 41.7 0.0 22 12:58:31 Start Drop Collet#9 Manually 4870 3502 1752.9 41.5 -0.0 Stage 9 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 12:58:36 Start PAD st9 Automatically 4705 3502 0.0 40.9 -0.0 2 12:58:36 Start Propped Frac Automatically 4705 3502 0.0 40.9 -0.0 3 12:58:36 Start Stage 9 Automatically 4705 3502 0.0 40.9 -0.0 4 13:02:55 Start Slow For Seat Automatically 1685 3427 164.8 18.7 0.0 5 13:04:13 Stage at Perfs: 8.0 PPA 1852 3413 186.0 15.9 0.0 6 13:05:16 Stage at Perfs: 10.0 PPA 1897 3407 202.7 15.9 0.0 7 13:05:29 Stage at Perfs: Clean line & Spacer 1906 3407 206.1 15.9 0.0 8 13:07:30 shutdown because don't see that collet is seated 853 3349 229.2 0.9 0.1 9 13:07:51 Stopped Pumping 845 3352 229.3 0.0 0.2 10 13:11:47 Started Pumping 788 3290 229.3 0.0 0.0 11 13:11:51 Stopped Pumping Prop 787 3290 229.3 0.0 -0.4 12 13:14:38 Ball & Collet Seated 2053 3311 263.7 21.4 0.0 13 13:14:47 Start Resume Pad Manually 2006 3313 266.9 21.6 0.0 14 13:17:39 Stage at Perfs: Drop Collet#9 2384 3333 362.1 40.0 0.0 15 13:19:24 Start 1.0 PPA Manually 2372 3411 432.0 40.0 0.0 16 13:19:30 Started Pumping Prop 2375 3405 436.0 40.0 0.0 17 13:20:13 Stage at Perfs: PAD st9 2351 3419 464.4 39.3 1.0 18 13:23:55 Start 2.0 PPA Automatically 2256 3465 612.3 40.1 1.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 19 13:24:20 Stage at Perfs: Slow For Seat 2255 3470 628.9 39.8 2.0 20 13:28:51 Stage at Perfs: Resume Pad 2299 3431 809.1 39.9 2.0 21 13:29:26 Start 4.0 PPA Automatically 2336 3442 832.3 39.8 2.0 22 13:34:22 Stage at Perfs: 1.0 PPA 2438 3431 1029.6 39.8 4.0 23 13:35:26 Start 6.0 PPA Automatically 2494 3423 1072.2 39.9 4.0 24 13:40:22 Stage at Perfs: 2.0 PPA 3086 3405 1269.0 39.9 6.1 25 13:41:26 Start 8.0 PPA Automatically 3293 3402 1311.8 40.1 6.1 26 13:46:22 Stage at Perfs: 4.0 PPA 4386 3395 1509.2 39.9 8.0 27 13:47:26 Start 10.0 PPA Automatically 4495 3400 1551.7 40.1 8.2 28 13:52:22 Stage at Perfs: 6.0 PPA 4755 3395 1748.7 40.2 10.0 29 13:53:10 Start Clean line & Spacer Manually 4645 3391 1781.0 41.5 0.1 30 13:53:13 Stopped Pumping Prop 4679 3395 1783.1 41.5 0.0 31 13:53:37 Start DropCollet#10 Manually 4441 3390 1799.6 40.6 0.0 32 13:53:42 Start LG DFIT Automatically 4399 3387 1803.0 40.3 0.0 33 13:57:31 Start Slow For Seat Manually 1939 3376 1955.7 40.0 0.0 34 13:58:33 Stage at Perfs: 8.0 PPA 1614 3374 1977.9 17.6 0.0 35 13:59:35 Stage at Perfs: 10.0 PPA 1915 3382 1996.2 17.7 0.0 36 13:59:40 Ball & Collet Seated 1511 3352 1997.6 17.6 0.0 37 13:59:44 Start Res LG DFIT Manually 1612 3381 1998.8 17.8 0.0 38 13:59:47 Stage at Perfs: Clean line & Spacer 1596 3389 1999.7 17.5 0.0 39 14:04:07 Stage at Perfs: DropCollet#10 2633 3463 2152.8 40.0 0.0 40 14:05:12 Stage at Perfs: LG DFIT 2637 3478 2196.1 40.0 0.0 41 14:06:26 Stopped Pumping 372 3422 2245.0 22.3 0.0 42 14:08:56 Recording Pressure decline 789 3414 2245.0 0.0 0.0 Stage 10 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 14:57:02 Started Pumping 383 3237 2245.0 0.0 0.0 2 14:57:06 Start PAD st10 Manually 383 3235 2245.0 0.0 0.0 3 14:57:06 Start Propped Frac Manually 383 3235 2245.0 0.0 0.0 4 14:57:06 Start Stage 10 Automatically 383 3235 2245.0 0.0 0.0 5 15:04:42 Stage at Perfs: Res LG DFIT 2402 3391 197.2 39.5 0.0 6 15:08:32 Start 1.0 PPA Automatically 2336 3464 350.3 39.9 0.0 7 15:08:32 Started Pumping Prop 2336 3464 350.3 39.9 0.0 8 15:13:02 Start 2.0 PPA Automatically 2301 3494 530.1 40.1 1.0 9 15:13:13 Stage at Perfs: PAD st10 2270 3496 537.5 40.3 1.4 10 15:17:42 Stage at Perfs: 1.0 PPA 2251 3499 717.3 39.9 2.0 11 15:18:32 Start 4.0 PPA Automatically 2251 3502 750.6 39.9 2.0 12 15:23:13 Stage at Perfs: 2.0 PPA 2382 3468 937.6 40.3 4.0 13 15:24:32 Start 6.0 PPA Automatically 2448 3458 990.6 40.4 3.9 14 15:29:13 Stage at Perfs: 4.0 PPA 2899 3424 1177.4 39.9 6.0 15 15:30:32 Start 8.0 PPA Automatically 2964 3419 1230.0 40.0 6.1 16 15:35:14 Stage at Perfs: 6.0 PPA 3792 3389 1417.4 39.6 8.0 17 15:36:34 Start 10.0 PPA Automatically 3935 3386 1470.5 40.2 8.1 18 15:41:14 Stage at Perfs: 8.0 PPA 4773 3383 1657.6 40.4 10.1 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 19 15:42:08 Start Clean line & Spacer Manually 4700 3376 1694.0 41.6 0.1 20 15:42:13 Stopped Pumping Prop 4624 3373 1697.5 41.3 0.0 21 15:42:34 Start DropCollet#11 Manually 4425 3370 1711.7 39.8 0.0 Stage 11 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 15:42:39 Start PAD st11 Automatically 4521 3376 0.0 39.7 0.0 2 15:42:39 Start Propped Frac Automatically 4521 3376 0.0 39.7 0.0 3 15:42:39 Start Stage 11 Automatically 4521 3376 0.0 39.7 0.0 4 15:46:22 Start Slow For Seat Manually 1218 3335 145.5 35.3 0.0 5 15:47:21 Stage at Perfs: 10.0 PPA 1800 3375 165.9 17.9 0.0 6 15:48:19 Stage at Perfs: Clean line & Spacer 1857 3386 183.3 18.0 0.0 7 15:48:30 Stage at Perfs: DropCollet11 1857 3389 186.6 18.0 0.0 8 15:48:36 Ball & Collet Seated 2347 3406 188.4 17.9 0.0 9 15:48:42 Start Resume Pad Manually 1711 3346 190.2 17.6 0.0 10 15:52:45 Stage at Perfs: PAD st11 2269 3486 325.3 40.0 0.0 11 15:53:18 Start 1.0 PPA Manually 2242 3489 347.4 40.1 0.0 12 15:53:18 Started Pumping Prop 2242 3489 347.4 40.1 0.0 13 15:53:52 Stage at Perfs: Slow For Seat 2209 3502 369.8 38.9 1.1 14 15:57:48 Stage at Perfs: Resume Pad 2253 3522 527.2 40.1 0.9 15 15:57:49 Start 3.0 PPA Automatically 2229 3519 527.9 40.1 0.9 16 16:02:18 Stage at Perfs: 1.0 PPA 2302 3471 707.7 40.0 3.0 17 16:03:18 Start 5.0 PPA Automatically 2338 3463 748.0 40.2 3.1 18 16:07:47 Stage at Perfs: 3.0 PPA 2551 3388 927.4 40.3 5.0 19 16:09:47 Start 7.0 PPA Automatically 2714 3367 1007.5 40.0 5.0 20 16:14:18 Stage at Perfs: 5.0 PPA 3487 3448 1187.4 39.8 6.9 21 16:15:34 Start 9.0 PPA Automatically 3556 3438 1237.8 39.8 7.0 22 16:20:04 Stage at Perfs: 7.0 PPA 4020 3391 1417.3 40.3 9.1 23 16:21:19 Start 10.0 PPA Automatically 3944 3380 1467.5 39.8 8.7 24 16:23:45 Start WF Flush Manually 3837 3347 1565.0 41.5 0.0 25 16:23:48 Stopped Pumping Prop 3779 3348 1567.1 41.3 0.0 26 16:25:49 Stage at Perfs: 9.0 PPA 3523 3347 1647.2 39.9 0.0 27 16:27:00 Start Freeze Protect Manually 1891 3303 1690.0 23.1 0.0 28 16:29:40 Stage at Perfs: 10.0 PPA 2116 3293 1744.3 20.0 0.0 29 16:29:55 Stopped Pumping 164 3207 1749.2 6.7 0.0 30 16:33:38 Close Well 60 3211 1749.2 0.0 0.0 31 16:40:25 Fanning Out Pumps, Cleaning line, PCM, POD, rig down.37 3090 1749.2 5.5 0.0 Santos Definitive Survey Report04 January, 2024Design: NDBi-044Santos NAD27 ConversionPikkaNDBNDBi044NDBi044 ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMap SystemGeo DatumProjectMap ZoneSystem DatumUS State Plane 1927 (Exact solution)NAD 1927 (NADCON CONUS)Pikka, North Slope Alaska, United StatesAlaska Zone 04Mean Sea LevelUsing Well Reference PointUsing geodetic scale factorSite PositionFromSiteLatitudeLongitudePosition UncertaintyNorthingEastingGrid ConvergenceNDBusftMap usftusft-0.59Slot Radius205,972,909.31423,383.620.970° 20' 10.134 N150° 37' 17.794 WWellWell PositionLongitudeLatitudeEastingNorthingusft/-/-Position UncertaintyusftusftusftGround Level:NDBi-044usftusft0.00.05,972,689.12421,883.4322.8Wellhead Elevation:0.0usft0.370° 20' 7.816 N150° 38' 1.541 WWellboreDeclinationField StrengthnTSample Date Dip AngleNDBi-044Model NameMagneticsBGGM2023 7/11/2023 14.47 80.58 57,180.41664386PhaseVersionAudit NotesDesignNDBi-0441.0 ACTUALVertical SectionDepth From TVDusft/-usftDirection/-usftTie On Depth46.8301.640.00.046.8012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueFromusftSurvey ProgramDescriptionTool NameSurvey WellboreTousftDate4/01/2024SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISCWSA Rev 4)114.7 1,037.301 SDIGyroMWD16in Hole 461037> 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag1,064.7 2,450.902 BH Ontrak16in Hole 10642450> ND3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag2,548.4 11,078.503 BH Ontrak1225in Hole 254811078>3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag11,143.8 11,192.004 BH Ontrakin HS 1114311192> N3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag11,287.8 17,839.005 BH Ontrakin HS 1128717809> NMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft46.8 0.00 0.00 46.8 -22.8 0.0 0.0 5,972,689.12 421,883.43 0.00 0.0114.7 0.09 194.77 114.7 45.1 -0.1 0.0 5,972,689.07 421,883.42 0.13 0.0128.0 0.10 207.71 128.0 58.4 -0.1 0.0 5,972,689.05 421,883.41 0.17 0.020" Conductor Casing187.4 0.17 239.77 187.4 117.8 -0.2 -0.1 5,972,688.96 421,883.31 0.17 0.0282.0 0.25 330.82 282.0 212.4 -0.1 -0.3 5,972,689.07 421,883.09 0.32 0.3376.2 1.68 329.77 376.2 306.6 1.3 -1.1 5,972,690.45 421,882.31 1.52 1.7468.7 3.97 335.39 468.5 398.9 5.4 -3.2 5,972,694.56 421,880.33 2.49 5.5565.1 5.95 336.80 564.6 495.0 13.0 -6.5 5,972,702.22 421,877.05 2.06 12.4659.5 6.71 330.47 658.4 588.8 22.3 -11.2 5,972,711.56 421,872.50 1.09 21.2753.7 7.24 320.98 752.0 682.4 31.7 -17.6 5,972,721.03 421,866.15 1.34 31.6849.1 7.68 311.84 846.6 777.0 40.7 -26.1 5,972,730.04 421,857.71 1.32 43.6944.3 9.08 304.80 940.7 871.1 49.2 -37.0 5,972,738.68 421,846.90 1.82 57.31,037.3 9.25 304.10 1,032.5 962.9 57.6 -49.3 5,972,747.19 421,834.77 0.22 72.11,038.49.25 304.07 1,033.6 964.0 57.7 -49.4 5,972,747.29 421,834.63 0.59 72.3Upper Schrader Bluff1,064.7 9.14 303.36 1,059.6 990.0 60.0 -52.9 5,972,749.66 421,831.15 0.59 76.51,134.7 9.93 300.94 1,128.6 1,059.0 66.2 -62.7 5,972,755.92 421,821.40 1.27 88.1Base Ice Bearing Permafrost1,160.9 10.23 300.13 1,154.4 1,084.8 68.5 -66.7 5,972,758.29 421,817.47 1.27 92.7012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft1,253.8 14.18 292.17 1,245.2 1,175.6 76.9 -84.4 5,972,766.91 421,799.88 4.61 112.21,349.2 16.47 287.49 1,337.2 1,267.6 85.4 -108.1 5,972,775.63 421,776.25 2.73 136.81,397.7 17.41 286.87 1,383.6 1,314.0 89.6 -121.6 5,972,779.94 421,762.80 1.97 150.5Base Permafrost Transition1,443.8 18.30 286.33 1,427.5 1,357.9 93.6 -135.1 5,972,784.12 421,749.29 1.97 164.21,538.9 20.95 285.81 1,517.0 1,447.4 102.4 -165.8 5,972,793.27 421,718.70 2.79 194.91,633.6 23.76 285.04 1,604.6 1,535.0 112.0 -200.5 5,972,803.19 421,684.10 2.98 229.51,727.2 25.85 283.93 1,689.6 1,620.0 121.8 -238.6 5,972,813.40 421,646.16 2.29 267.01,779.7 27.08 283.24 1,736.6 1,667.0 127.3 -261.3 5,972,819.13 421,623.48 2.42 289.3Middle Schrader Bluff1,821.1 28.06 282.74 1,773.3 1,703.7 131.6 -280.0 5,972,823.62 421,604.87 2.42 307.41,919.1 31.51 283.42 1,858.3 1,788.7 142.6 -327.4 5,972,835.15 421,557.57 3.54 353.62,012.2 35.36 284.07 1,936.01,866.4154.8 -377.2 5,972,847.86 421,507.93 4.16 402.32,104.8 39.69 283.64 2,009.4 1,939.8 168.3 -431.9 5,972,861.93 421,453.30 4.68 456.02,197.2 42.73 282.99 2,078.9 2,009.3 182.3 -491.2 5,972,876.55 421,394.23 3.32 513.82,291.0 44.94 280.79 2,146.6 2,077.0 195.7 -554.8 5,972,890.57 421,330.78 2.86 575.0MCU2,294.3 45.02 280.72 2,148.9 2,079.3 196.1 -557.1 5,972,891.03 421,328.50 2.86 577.12,390.5 46.94 278.21 2,215.8 2,146.2 207.5 -625.2 5,972,903.08 421,260.43 2.74 641.12,450.9 47.04 279.15 2,257.02,187.4214.2 -668.9 5,972,910.21 421,216.83 1.15 681.82,514.0 47.76 280.32 2,299.7 2,230.1 222.0 -714.7 5,972,918.53 421,171.15 1.78 724.913-3/8" Surface Casing2,548.4 48.16 280.94 2,322.7 2,253.1 226.7 -739.8 5,972,923.51 421,146.11 1.78 748.72,643.4 51.32 279.05 2,384.1 2,314.5 239.3 -811.2 5,972,936.80 421,074.84 3.65 816.12,738.5 55.42 278.48 2,440.9 2,371.3 250.9 -886.6 5,972,949.21 420,999.54 4.34 886.42,754.1 56.08 278.42 2,449.6 2,380.0 252.8 -899.3 5,972,951.23 420,986.85 4.28 898.3Tuluvak Shale2,833.6 59.48 278.11 2,492.0 2,422.4 262.4 -965.9 5,972,961.59 420,920.39 4.28 960.0012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft2,871.1 61.00 277.72 2,510.6 2,441.0 266.9 -998.2 5,972,966.40 420,888.21 4.15 989.8Tuluvak Sand2,928.4 63.32 277.15 2,537.4 2,467.8 273.5 -1,048.4 5,972,973.48 420,838.00 4.15 1,036.03,023.466.70 277.15 2,577.5 2,507.9 284.2 -1,133.9 5,972,985.09 420,752.70 3.56 1,114.43,117.9 70.09 276.70 2,612.3 2,542.7 294.8 -1,221.0 5,972,996.57 420,665.69 3.62 1,194.13,212.9 73.13 276.55 2,642.2 2,572.6 305.2 -1,310.5 5,973,007.90 420,576.28 3.20 1,275.83,307.5 76.41 277.93 2,667.1 2,597.5 316.7 -1,401.1 5,973,020.36 420,485.81 3.74 1,359.03,382.7 78.92277.442,683.2 2,613.6 326.5 -1,473.9 5,973,030.93 420,413.17 3.40 1,426.03,428.5 79.95 277.83 2,691.6 2,622.0 332.5 -1,518.5 5,973,037.39 420,368.58 2.40 1,467.23,497.2 80.20 277.56 2,703.4 2,633.8 341.6 -1,585.6 5,973,047.15 420,301.61 0.53 1,529.13,592.6 80.14 277.28 2,719.7 2,650.1 353.7 -1,678.8 5,973,060.24 420,208.61 0.30 1,614.73,686.480.20 277.08 2,735.7 2,666.1 365.2 -1,770.5 5,973,072.75 420,117.03 0.22 1,698.93,781.8 79.88 276.36 2,752.2 2,682.6 376.2 -1,863.8 5,973,084.72 420,023.82 0.82 1,784.13,876.6 79.82 276.28 2,768.9 2,699.3 386.5 -1,956.5 5,973,095.95 419,931.22 0.10 1,868.43,971.1 79.82 276.53 2,785.6 2,716.0 396.9 -2,049.0 5,973,107.30 419,838.84 0.26 1,952.64,065.7 79.89 276.05 2,802.3 2,732.7 407.1 -2,141.5 5,973,118.45 419,746.49 0.51 2,036.74,160.7 79.76 276.18 2,819.1 2,749.5 417.1 -2,234.5 5,973,129.39 419,653.56 0.19 2,121.14,255.479.76 275.72 2,835.9 2,766.3 426.7 -2,327.3 5,973,140.01 419,560.97 0.48 2,205.14,350.3 79.82 275.19 2,852.7 2,783.1 435.6 -2,420.2 5,973,149.86 419,468.15 0.55 2,288.94,444.7 79.76 275.32 2,869.5 2,799.9 444.1 -2,512.7 5,973,159.33 419,375.70 0.15 2,372.14,539.8 79.79 274.02 2,886.3 2,816.7 451.7 -2,606.0 5,973,167.92 419,282.51 1.35 2,455.54,634.3 79.86 275.52 2,903.02,833.4459.5 -2,698.6 5,973,176.61 419,190.00 1.57 2,538.44,729.3 79.70 275.84 2,919.9 2,850.3 468.7 -2,791.7 5,973,186.84 419,096.99 0.37 2,622.64,823.8 79.76 276.20 2,936.7 2,867.1 478.5 -2,884.2 5,973,197.55 419,004.67 0.38 2,706.44,918.4 79.89 276.18 2,953.4 2,883.8 488.5 -2,976.7 5,973,208.55 418,912.22 0.14 2,790.45,013.0 79.79 276.06 2,970.1 2,900.5 498.4 -3,069.3 5,973,219.44 418,819.79 0.16 2,874.45,107.9 79.80 276.10 2,986.9 2,917.3 508.3 -3,162.2 5,973,230.30 418,727.04 0.04 2,958.7012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft5,203.0 79.79 276.28 3,003.8 2,934.2 518.4 -3,255.3 5,973,241.36 418,634.05 0.19 3,043.35,298.0 79.82 276.49 3,020.6 2,951.0 528.8 -3,348.2 5,973,252.73 418,541.24 0.22 3,127.85,393.3 79.67 276.46 3,037.6 2,968.0 539.4 -3,441.4 5,973,264.27 418,448.18 0.16 3,212.75,487.8 79.60 276.40 3,054.6 2,985.0 549.8 -3,533.8 5,973,275.65 418,355.92 0.10 3,296.85,582.4 79.64 275.98 3,071.6 3,002.0 559.8 -3,626.2 5,973,286.63 418,263.58 0.44 3,380.85,677.6 79.70 275.69 3,088.7 3,019.1 569.3 -3,719.4 5,973,297.12 418,170.53 0.31 3,465.15,772.1 79.67 275.33 3,105.6 3,036.0 578.3 -3,812.0 5,973,307.02 418,078.04 0.38 3,548.65,866.8 79.57 275.58 3,122.7 3,053.1 587.1 -3,904.6 5,973,316.83 417,985.47 0.28 3,632.15,961.6 79.61 275.29 3,139.8 3,070.2 596.0 -3,997.5 5,973,326.63 417,892.73 0.30 3,715.86,038.2 79.63 275.36 3,153.6 3,084.0 603.0 -4,072.5 5,973,334.41 417,817.82 0.10 3,783.3Seabee6,055.5 79.63 275.38 3,156.7 3,087.1 604.6 -4,089.5 5,973,336.18 417,800.84 0.10 3,798.76,151.0 79.64 275.42 3,173.9 3,104.3 613.4 -4,183.0 5,973,345.99 417,707.44 0.04 3,882.96,245.8 79.64 275.19 3,191.0 3,121.4 622.0 -4,275.9 5,973,355.58 417,614.67 0.24 3,966.56,340.2 79.61 275.20 3,207.9 3,138.3 630.4 -4,368.3 5,973,364.95 417,522.36 0.03 4,049.66,435.0 79.61 275.67 3,225.03,155.4639.3 -4,461.1 5,973,374.75 417,429.62 0.49 4,133.26,530.3 79.70 276.13 3,242.2 3,172.6 648.9 -4,554.4 5,973,385.35 417,336.51 0.48 4,217.76,624.8 79.88 276.25 3,258.9 3,189.3 658.9 -4,646.9 5,973,396.35 417,244.08 0.23 4,301.76,719.7 79.82 276.53 3,275.6 3,206.0 669.3 -4,739.7 5,973,407.71 417,151.38 0.30 4,386.26,814.3 79.79 276.65 3,292.4 3,222.8 680.0 -4,832.2 5,973,419.35 417,059.04 0.13 4,470.56,908.4 79.73 276.26 3,309.1 3,239.5 690.4 -4,924.2 5,973,430.72 416,967.15 0.41 4,554.37,003.2 79.89 276.11 3,325.9 3,256.3 700.5 -5,016.9 5,973,441.73 416,874.54 0.23 4,638.57,098.3 79.73 275.59 3,342.7 3,273.1 710.0 -5,110.1 5,973,452.25 416,781.48 0.56 4,722.87,193.2 79.70 275.85 3,359.7 3,290.1 719.3 -5,203.0 5,973,462.52 416,688.69 0.27 4,806.87,287.9 79.82 275.54 3,376.5 3,306.9 728.6 -5,295.7 5,973,472.73 416,596.05 0.35 4,890.67,383.0 79.86 275.53 3,393.3 3,323.7 737.6 -5,388.9 5,973,482.73 416,503.01 0.04 4,974.77,477.8 79.76 275.80 3,410.0 3,340.4 746.8 -5,481.7 5,973,492.90 416,410.29 0.30 5,058.5012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft7,572.1 79.95275.943,426.6 3,357.0 756.3 -5,574.0 5,973,503.35 416,318.09 0.25 5,142.17,666.4 79.88 276.05 3,443.1 3,373.5 766.0 -5,666.4 5,973,514.01 416,225.87 0.14 5,225.87,761.2 79.76 275.96 3,459.9 3,390.3 775.8 -5,759.2 5,973,524.74 416,133.13 0.16 5,310.07,856.5 79.80 275.98 3,476.8 3,407.2 785.5 -5,852.5 5,973,535.46 416,040.01 0.05 5,394.47,951.1 79.89 276.22 3,493.5 3,423.9 795.4 -5,945.1 5,973,546.33 415,947.49 0.27 5,478.58,046.1 79.79 276.23 3,510.3 3,440.7 805.5 -6,038.0 5,973,557.43 415,854.69 0.11 5,562.98,139.6 79.73 276.39 3,526.9 3,457.3 815.7 -6,129.5 5,973,568.49 415,763.37 0.18 5,646.18,235.6 79.57 276.45 3,544.1 3,474.5 826.2 -6,223.3 5,973,580.03 415,669.64 0.18 5,731.58,330.3 79.58 276.34 3,561.3 3,491.7 836.6 -6,315.9 5,973,591.36 415,577.21 0.11 5,815.78,424.9 79.64 276.53 3,578.3 3,508.7 847.0 -6,408.3 5,973,602.75 415,484.90 0.21 5,899.98,519.7 79.57276.443,595.4 3,525.8 857.5 -6,501.0 5,973,614.25 415,392.35 0.12 5,984.38,613.2 79.64 276.36 3,612.3 3,542.7 867.8 -6,592.4 5,973,625.45 415,301.07 0.11 6,067.58,709.4 79.67 276.17 3,629.6 3,560.0 878.1 -6,686.4 5,973,636.75 415,207.12 0.20 6,153.08,804.7 79.60 276.02 3,646.7 3,577.1 888.1 -6,779.6 5,973,647.68 415,114.04 0.17 6,237.68,898.8 79.73276.243,663.6 3,594.0 898.0 -6,871.7 5,973,658.52 415,022.12 0.27 6,321.18,993.2 79.52 275.99 3,680.6 3,611.0 907.9 -6,964.1 5,973,669.38 414,929.83 0.34 6,405.09,088.2 79.61 275.96 3,697.8 3,628.2 917.6 -7,056.9 5,973,680.06 414,837.09 0.10 6,489.19,182.6 79.70 275.77 3,714.8 3,645.2 927.1 -7,149.4 5,973,690.52 414,744.75 0.22 6,572.89,277.1 79.64 275.41 3,731.7 3,662.1 936.1 -7,241.9 5,973,700.54 414,652.34 0.38 6,656.39,371.8 79.67 275.39 3,748.7 3,679.1 944.9 -7,334.6 5,973,710.26 414,559.78 0.04 6,739.89,464.479.57 275.78 3,765.4 3,695.8 953.8 -7,425.3 5,973,720.07 414,469.19 0.43 6,821.79,558.6 79.64 275.88 3,782.4 3,712.8 963.2 -7,517.4 5,973,730.44 414,377.12 0.13 6,905.19,653.4 79.63 276.35 3,799.4 3,729.8 973.1 -7,610.1 5,973,741.34 414,284.56 0.49 6,989.29,676.5 79.63 277.20 3,803.6 3,734.0 975.8 -7,632.7 5,973,744.26 414,262.01 3.63 7,009.8Nanushuk9,747.3 79.64 279.82 3,816.3 3,746.7 986.1 -7,701.6 5,973,755.28 414,193.25 3.63 7,073.99,791.7 78.94 281.73 3,824.6 3,755.0 994.3 -7,744.5 5,973,763.89 414,150.44 4.50 7,114.7NT8 MFS012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft9,843.5 78.15 283.96 3,834.9 3,765.3 1,005.5 -7,793.9 5,973,775.67 414,101.13 4.50 7,162.79,915.3 78.18 285.83 3,849.6 3,780.0 1,023.6 -7,861.8 5,973,794.44 414,033.41 2.56 7,230.0NT7 MFS9,941.2 78.20 286.51 3,854.9 3,785.3 1,030.6 -7,886.2 5,973,801.75 414,009.15 2.56 7,254.410,036.5 78.13 288.79 3,874.5 3,804.9 1,059.0 -7,975.1 5,973,830.98 413,920.51 2.34 7,345.010,130.7 77.46 291.79 3,894.4 3,824.8 1,090.9 -8,061.4 5,973,863.78 413,834.54 3.19 7,435.210,226.2 77.51 295.74 3,915.1 3,845.5 1,128.4 -8,146.7 5,973,902.22 413,749.65 4.04 7,527.510,320.7 77.57 298.92 3,935.5 3,865.9 1,170.8 -8,228.7 5,973,945.43 413,668.14 3.29 7,619.510,339.9 77.51 299.51 3,939.6 3,870.0 1,179.9 -8,245.0 5,973,954.73 413,651.91 3.04 7,638.2NT6 MFS10,414.8 77.29 301.84 3,955.9 3,886.3 1,217.2 -8,307.9 5,973,992.69 413,589.41 3.04 7,711.310,506.9 77.03 305.33 3,976.4 3,906.8 1,266.9 -8,382.7 5,974,043.11 413,515.17 3.71 7,801.010,534.4 77.01 306.43 3,982.6 3,913.0 1,282.6 -8,404.4 5,974,059.05 413,493.60 3.90 7,827.8NT5 MFS10,605.5 76.97 309.28 3,998.6 3,929.0 1,325.1 -8,459.1 5,974,102.12 413,439.37 3.90 7,896.610,640.7 76.90 311.11 4,006.6 3,937.0 1,347.2 -8,485.3 5,974,124.50 413,413.44 5.07 7,930.510,668.1 77.01 312.41 4,012.8 3,943.2 1,365.0 -8,505.2 5,974,142.51 413,393.68 4.63 7,956.810,699.0 76.97 313.78 4,019.7 3,950.1 1,385.6 -8,527.2 5,974,163.33 413,371.88 4.31 7,986.410,738.4 76.93 315.75 4,028.6 3,959.0 1,412.6 -8,554.4 5,974,190.58 413,344.98 4.87 8,023.7NT4 MFS10,794.2 76.90318.544,041.2 3,971.6 1,452.4 -8,591.4 5,974,230.82 413,308.41 4.87 8,076.110,888.4 76.94 322.93 4,062.6 3,993.0 1,523.5 -8,649.5 5,974,302.45 413,251.094.548,162.810,983.8 77.04 326.52 4,084.1 4,014.5 1,599.3 -8,703.2 5,974,378.87 413,198.22 3.67 8,248.311,072.6 77.53 330.63 4,103.6 4,034.0 1,673.2 -8,748.3 5,974,453.20 413,153.86 4.55 8,325.5NT3 MFS11,078.5 77.57 330.90 4,104.9 4,035.3 1,678.3 -8,751.1 5,974,458.27 413,151.09 4.55 8,330.511,114.0 78.33 331.21 4,112.3 4,042.7 1,708.6 -8,767.9 5,974,488.82 413,134.60 2.30 8,360.79-5/8" Intermediate Casing012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft11,143.8 78.97 331.46 4,118.2 4,048.6 1,734.3 -8,781.9 5,974,514.62 413,120.85 2.30 8,386.111,183.5 79.41 331.99 4,125.6 4,056.0 1,768.6 -8,800.4 5,974,549.14 413,102.74 1.71 8,419.9NT3.2 Top Reservoir11,192.0 79.50 332.10 4,127.2 4,057.6 1,776.0 -8,804.3 5,974,556.59 413,098.89 1.71 8,427.111,287.8 81.40 332.39 4,143.04,073.41,859.6 -8,848.3 5,974,640.57 413,055.80 2.01 8,508.411,382.0 84.38 331.35 4,154.7 4,085.1 1,942.0 -8,892.4 5,974,723.42 413,012.61 3.35 8,589.111,478.0 87.61 330.23 4,161.4 4,091.8 2,025.6 -8,939.1 5,974,807.51 412,966.74 3.56 8,672.811,572.0 88.50 329.72 4,164.6 4,095.0 2,106.9 -8,986.1 5,974,889.33 412,920.58 1.09 8,755.511,666.9 88.74 329.62 4,166.9 4,097.3 2,188.8 -9,034.0 5,974,971.74 412,873.51 0.27 8,839.311,763.1 90.21 330.70 4,167.8 4,098.2 2,272.2 -9,081.9 5,975,055.59 412,826.56 1.90 8,923.711,856.8 90.09330.844,167.5 4,097.9 2,354.0 -9,127.6 5,975,137.84 412,781.66 0.20 9,005.611,953.5 90.22 330.73 4,167.3 4,097.7 2,438.4 -9,174.8 5,975,222.74 412,735.33 0.18 9,090.112,048.2 90.43 330.16 4,166.7 4,097.1 2,520.8 -9,221.5 5,975,305.56 412,689.50 0.64 9,173.012,143.4 90.18 329.56 4,166.2 4,096.6 2,603.1 -9,269.4 5,975,388.42 412,642.54 0.68 9,256.912,238.5 90.18 329.69 4,165.9 4,096.3 2,685.2 -9,317.4 5,975,470.93 412,595.33 0.14 9,340.912,333.5 90.37 329.78 4,165.5 4,095.9 2,767.2 -9,365.3 5,975,553.48 412,548.30 0.22 9,424.712,428.1 90.21 329.32 4,165.0 4,095.4 2,848.8 -9,413.3 5,975,635.50 412,501.23 0.51 9,508.312,523.7 90.12 329.43 4,164.7 4,095.1 2,931.1 -9,462.0 5,975,718.30 412,453.37 0.15 9,593.012,619.6 89.91329.144,164.7 4,095.1 3,013.5 -9,510.9 5,975,801.21 412,405.28 0.37 9,677.912,714.2 89.75 328.65 4,165.0 4,095.4 3,094.5 -9,559.8 5,975,882.69 412,357.27 0.54 9,762.012,809.3 90.03 329.58 4,165.1 4,095.5 3,176.1 -9,608.6 5,975,964.81 412,309.30 1.02 9,846.412,903.9 90.28 329.35 4,164.9 4,095.3 3,257.6 -9,656.7 5,976,046.77 412,262.10 0.36 9,930.012,998.9 90.21 329.41 4,164.5 4,094.9 3,339.3 -9,705.1 5,976,129.02 412,214.57 0.10 10,014.113,094.0 90.21 328.83 4,164.1 4,094.5 3,421.0 -9,753.9 5,976,211.19 412,166.59 0.61 10,098.513,189.0 90.18 328.81 4,163.8 4,094.2 3,502.2 -9,803.1 5,976,292.90 412,118.29 0.04 10,183.013,283.7 90.12 328.75 4,163.6 4,094.0 3,583.2 -9,852.1 5,976,374.39 412,070.06 0.09 10,267.213,379.1 90.12 328.80 4,163.4 4,093.8 3,664.8 -9,901.6 5,976,456.50 412,021.44 0.05 10,352.2012024 113525AMCOMPASS 500017 Build 02 Page ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft13,474.1 90.21 328.79 4,163.1 4,093.5 3,746.0 -9,950.8 5,976,538.23 411,973.09 0.10 10,436.713,568.8 90.18 328.90 4,162.8 4,093.2 3,827.1 -9,999.8 5,976,619.77 411,924.95 0.12 10,520.913,664.8 90.18 329.33 4,162.5 4,092.9 3,909.5 -10,049.1 5,976,702.70 411,876.51 0.45 10,606.113,758.8 90.18 329.51 4,162.2 4,092.6 3,990.4 -10,096.9 5,976,784.06 411,829.57 0.19 10,689.213,854.2 90.15 329.81 4,161.9 4,092.3 4,072.7 -10,145.1 5,976,866.90 411,782.24 0.32 10,773.513,949.6 90.15 329.81 4,161.6 4,092.0 4,155.2 -10,193.1 5,976,949.87 411,735.11 0.00 10,857.614,044.8 90.21 329.92 4,161.3 4,091.7 4,237.5 -10,240.9 5,977,032.67 411,688.19 0.13 10,941.514,140.1 90.15 329.82 4,161.0 4,091.4 4,320.0 -10,288.7 5,977,115.61 411,641.21 0.12 11,025.514,234.8 90.15 329.87 4,160.8 4,091.2 4,401.8 -10,336.3 5,977,197.95 411,594.51 0.05 11,108.914,330.1 90.18 329.78 4,160.5 4,090.9 4,484.2 -10,384.2 5,977,280.80 411,547.49 0.10 11,192.914,424.7 90.25329.744,160.2 4,090.6 4,565.9 -10,431.8 5,977,363.02 411,500.70 0.09 11,276.314,520.6 90.15 329.53 4,159.8 4,090.2 4,648.7 -10,480.3 5,977,446.26 411,453.09 0.24 11,361.014,614.4 90.21 328.91 4,159.5 4,089.9 4,729.3 -10,528.3 5,977,527.37 411,405.91 0.66 11,444.214,710.2 90.18 329.40 4,159.2 4,089.6 4,811.6 -10,577.5 5,977,610.14 411,357.64 0.51 11,529.214,805.2 90.21 329.40 4,158.9 4,089.3 4,893.3 -10,625.8 5,977,692.34 411,310.18 0.03 11,613.214,899.2 90.18 329.35 4,158.6 4,089.0 4,974.2 -10,673.7 5,977,773.71 411,263.15 0.06 11,696.414,994.8 90.18 329.60 4,158.3 4,088.7 5,056.5 -10,722.2 5,977,856.56 411,215.46 0.26 11,780.915,089.9 90.18 329.62 4,158.04,088.45,138.6 -10,770.4 5,977,939.13 411,168.18 0.02 11,865.015,185.2 90.15 329.74 4,157.7 4,088.1 5,220.9 -10,818.5 5,978,021.90 411,120.92 0.13 11,949.115,280.0 90.15 329.83 4,157.4 4,087.8 5,302.7 -10,866.1 5,978,104.24 411,074.12 0.10 12,032.615,375.2 90.21 330.00 4,157.1 4,087.5 5,385.1 -10,913.9 5,978,187.12 411,027.24 0.19 12,116.515,470.2 90.22 330.07 4,156.8 4,087.2 5,467.4 -10,961.3 5,978,269.87 410,980.68 0.07 12,200.015,565.3 90.25 330.23 4,156.4 4,086.8 5,549.9 -11,008.7 5,978,352.87 410,934.19 0.17 12,283.615,660.1 90.21 330.01 4,156.0 4,086.4 5,632.1 -11,055.9 5,978,435.51 410,887.85 0.24 12,366.915,755.4 90.18 329.91 4,155.7 4,086.1 5,714.6 -11,103.6 5,978,518.50 410,841.00 0.11 12,450.815,850.2 90.18 329.46 4,155.4 4,085.8 5,796.5 -11,151.5 5,978,600.88 410,793.98 0.47 12,534.615,945.4 90.25 329.39 4,155.0 4,085.4 5,878.4 -11,199.9 5,978,683.29 410,746.44 0.10 12,618.8012024 113525AMCOMPASS 500017 Build 02 Page 10 ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueMDusftIncAzi azimuthusftusftNorthingusftTVDSSusftEastingusftSurveyTVDusftDLeg100usft. Secusft16,040.3 90.18 329.09 4,154.7 4,085.1 5,959.9 -11,248.4 5,978,765.32 410,698.77 0.32 12,702.816,134.6 90.25 329.13 4,154.3 4,084.7 6,040.9 -11,296.8 5,978,846.79 410,651.17 0.09 12,786.616,229.7 90.15 328.84 4,154.0 4,084.4 6,122.3 -11,345.8 5,978,928.73 410,603.06 0.32 12,871.016,325.2 90.12 328.69 4,153.8 4,084.2 6,204.0 -11,395.3 5,979,010.93 410,554.38 0.16 12,956.016,420.4 90.15 328.65 4,153.6 4,084.0 6,285.4 -11,444.9 5,979,092.77 410,505.72 0.05 13,040.816,515.5 90.25 328.90 4,153.2 4,083.6 6,366.7 -11,494.1 5,979,174.55 410,457.30 0.28 13,125.416,610.0 90.18328.644,152.9 4,083.3 6,447.5 -11,543.2 5,979,255.92 410,409.12 0.28 13,209.616,705.3 90.18 328.40 4,152.6 4,083.0 6,528.8 -11,592.9 5,979,337.66 410,360.23 0.25 13,294.616,799.5 90.21 329.12 4,152.2 4,082.6 6,609.3 -11,641.7 5,979,418.67 410,312.24 0.77 13,378.416,895.9 90.18 329.16 4,151.9 4,082.3 6,692.0 -11,691.2 5,979,501.92 410,263.66 0.05 13,463.916,990.0 90.18 328.99 4,151.6 4,082.0 6,772.7 -11,739.6 5,979,583.14 410,216.15 0.18 13,547.417,086.3 90.12 329.54 4,151.4 4,081.8 6,855.5 -11,788.8 5,979,666.43 410,167.79 0.57 13,632.817,181.0 90.15 329.53 4,151.1 4,081.5 6,937.2 -11,836.8 5,979,748.53 410,120.64 0.03 13,716.417,274.8 90.18 329.31 4,150.9 4,081.3 7,017.9 -11,884.5 5,979,829.75 410,073.78 0.24 13,799.417,370.7 90.18 329.53 4,150.6 4,081.0 7,100.5 -11,933.3 5,979,912.87 410,025.82 0.23 13,884.317,464.6 90.22 329.21 4,150.2 4,080.6 7,181.3 -11,981.2 5,979,994.16 409,978.83 0.34 13,967.517,560.3 90.25 329.17 4,149.9 4,080.3 7,263.5 -12,030.1 5,980,076.80 409,930.71 0.05 14,052.217,655.7 90.21 329.23 4,149.5 4,079.9 7,345.4 -12,079.0 5,980,159.26 409,882.70 0.08 14,136.917,750.2 90.18328.544,149.1 4,079.5 7,426.3 -12,127.8 5,980,240.64 409,834.74 0.73 14,220.817,809.5 90.15 328.98 4,149.0 4,079.4 7,477.1 -12,158.6 5,980,291.71 409,804.48 0.74 14,273.717,832.0 90.15 328.98 4,148.9 4,079.3 7,496.3 -12,170.2 5,980,311.08 409,793.11 0.00 14,293.64-1/2" Production Casing17,839.0 90.15 328.98 4,148.9 4,079.3 7,502.3 -12,173.8 5,980,317.11 409,789.56 0.00 14,299.9Projection012024 113525AMCOMPASS 500017 Build 02 Page 11 ProjectCompanyLocal Coordinate ReferenceTVD ReferenceSiteSantos NAD27 ConversionPikkaNDBSantos Definitive Survey ReportWellWellboreNDBi-044NDBi-044Survey Calculation MethodMinimum CurvatureParker 272 As Drilled @ 69.6usftDesignNDBi-044DatabaseEDM STO AlaskaMD ReferenceParker 272 As Drilled @ 69.6usftNorth ReferenceWell NDBi044TrueVertical DepthusftMeasured DepthusftCasingDiameter(")HoleDiameter(")NameCasing Points20" Conductor Casing128.0128.0 20 2013-3/8" Surface Casing2,299.72,514.0 13-3/8 169-5/8" Intermediate Casing4,112.311,114.0 9-5/8 12-1/44-1/2" Production Casing4,148.917,832.0 4-1/2 8-1/2MeasuredDepthusftVerticalDepthusftDipDirectionName LithologyDipFormations1,397.7 1,383.6 Base Permafrost Transition10,339.9 3,939.6 NT6 MFS2,754.1 2,449.6 Tuluvak Shale1,134.7 1,128.6 Base Ice Bearing Permafrost1,038.4 1,033.6 Upper Schrader Bluff11,183.5 4,125.6 NT3.2 Top Reservoir11,072.6 4,103.6 NT3 MFS9,791.7 3,824.6 NT8 MFS6,038.2 3,153.6 Seabee10,534.4 3,982.6 NT5 MFS2,291.0 2,146.6 MCU1,779.7 1,736.6 Middle Schrader Bluff10,738.4 4,028.6 NT4 MFS2,871.1 2,510.6 Tuluvak Sand9,676.5 3,803.6 Nanushuk9,915.3 3,849.6 NT7 MFSMeasuredDepthusftVerticalDepthusft/-usft/-usftLocal CoordinatesCommentDesign Annotations17,839.0 4,148.9 -12,173.87,502.3 Projection012024 113525AMCOMPASS 500017 Build 02 Page 12 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Well Cleanup Oil Search Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,839 feet N/A feet true vertical 4,149 feet N/A feet Effective Depth measured 17,832 feet See attached feet true vertical 4,048 feet feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 4-1/2" P-110S 17,832' MD 4,149' TVD Packers and SSSV (type, measured and true vertical depth) See attached report 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Scott Leahy Contact Email:scott.leahy@santos.com Authorized Title: Completions Specialist Contact Phone: 907-646-7063 324-012 Sr Pet Eng: 9,210 Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD See attached report from Schlumberger measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 392984, 391445, 393021, 393019 Pikka / Nanushuk Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-087 50-103-20865-00-00 900 E Benson Boulevard, Suite 500 Anchorage, AK 99508 3. Address: NDBi-044 See attached report from Schlumberger Length 128 2,514 128Conductor Surface Intermediate 20"x34" 13-3/8" Size 128 9-5/8" 11,590 4-1/2" measured TVD Production Liner 8,751 10,858 7,009 Casing Structural 4,112 4,149 4-1/2" 11,114 17,832 10,859 4,056 Plugs Junk measured Collapse 2,260 4,750 9,210 5,020 6,870 11,590 6,870 4,750Tie-Back 2,363 9-5/8" 2,363 2,197 2,514 2,300 Burst p k ft t Fra O s 223 6.A G L PG , p Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 03/26/2024 By Grace Christianson at 8:23 am, Mar 28, 2024 RBDMS JSB 040424 CDW 03/31/2024 DSR-4/12/24 Page 1 of 1 Well Name: NDBi-044 Packer Set Depths Item Des Btm (ftKB) Btm (TVD) (ftKB) SLZXP Liner Top Hanger Packer 10,845.1 4,052.8 OH Packer #13 11,269.1 4,140.2 OH Packer #12 11,333.1 4,149.3 OH Packer #11 11,947.2 4,167.3 OH Packer #10 12,558.6 4,164.7 OH Packer #9 13,174.4 4,163.9 OH Packer #8 13,788.8 4,162.1 OH Packer #7 14,403.6 4,160.2 OH Packer #6 15,014.4 4,158.2 OH Packer #5 15,586.2 4,156.3 OH Packer #4 16,155.2 4,154.2 OH Packer #3 16,724.8 4,152.4 OH Packer #2 17,298.8 4,150.7 OH Packer #1 17,703.1 4,149.2 Frac Ops Summary Report - AOGCC Well Name NDBi-044 Primary Job Type Fracture Treatment Start Date End Date Summary 2/4/2024 2/5/2024 Prepare to Frac Stages 1-4. Pressure test surface lines. Open wellhead and pressurize tubing to 7800psi to open P-Sleeve. 2/5/2024 2/6/2024 Frac stages 1-3 Finish RU of frac equipment and chemical/water testing. DataFrac: 673.5 bbls clean fluid (473.5 bbls WF125 and 200 bbls YF125ST fluid) at 40bpm. Pumpcheck volume extended to 220 bbls. Pump Frac Stages 1-3: Frac stage 1: 1,652.2 bbls slurry (YF125ST fluid), 176,970lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,464.5 bbls clean fluid at 40bpm as per design. Frac stage 2: 3,063 bbls slurry (3,013 bbls YF125ST fluid and 50 bbls of WF125), 193,862lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7ppa), 2,858.2 bbls clean fluid at 40bpm; Had issues with tank valves, couldn't get water to hydration unit, cut sand and overflushed by 250 bbls, restarted stage. Frac stage 3: 2,089.6 bbls slurry (YF125ST fluid), 152,059lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7ppa), 1,929.6 bbls clean fluid at 40bpm; Pressure was trending up, cut sand on 7ppa, flushed away, Step Down 40-32-24-16bpm Cleaned up equipment. Prepare to reload for next Frac. Total Load to Recover (TLTR) 6,925.8 bbls 2/6/2024 2/7/2024 Resupply Proppant and Frac Fluid for Stages 4-7 2/7/2024 2/8/2024 Resupply Proppant and heat Frac Fluid for Stages 4-7 2/8/2024 2/9/2024 Resupply Proppant and heat Frac Fluid for Stages 4-7 2/9/2024 2/10/2024 Heat Frac Tanks, Prime Frac Equipment, Pressure Test Lines 2/10/2024 2/11/2024 Frac stages 4-7 Finish RU of frac equipment and chemical/water testing. Pump Frac Stages 4-7: Frac stage 4: 1,892.4 bbls slurry (YF125ST fluid), 227,236 lbs 16/20 Carbolite (1, 2, 3, 4, 5, 6, 7, 8ppa), 1,652.3 bbls clean fluid at 40bpm as per design. Frac stage 5: 1,691.9 bbls slurry (YF125ST fluid), 224,950 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,454.2 bbls clean fluid at 40bpm as per design. Frac stage 6: 1,709.3 bbls slurry (YF125ST fluid), 223,567 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,473.1 bbls clean fluid at 40bpm as per design. Frac stage 7: 2,616.6 bbls slurry (YF125ST fluid), 17,398 lbs 40/70 Carbolite (1, 3ppa), 227,387 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 2,358.3 bbls clean fluid at 40bpm as per design. Cleaned up equipment. Prepare to reload for next Frac. Total Load to Recover (4-7) - 6,937.9 bbls Total Load to Recover (Well) - 13,863.7 bbls 2/11/2024 2/12/2024 Resupply Proppant and Frac Fluid for Stages 8-11 2/12/2024 2/13/2024 Resupply Proppant and Frac Fluid for Stages 8-11 2/13/2024 2/14/2024 Resupply Proppant and Frac Fluid for Stages 8-11 2/14/2024 2/15/2024 Heat Frac Fluid for Stages 8-11 Page 1 of 2 Frac Ops Summary Report - AOGCC Start Date End Date Summary 2/15/2024 2/16/2024 Frac stages 8-11 Finish RU of frac equipment and chemical/water testing. Pump Frac Stages 8-11: Frac stage 8: 2,027.2 bbls slurry (YF125ST fluid), 242,605 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,786.2 bbls clean fluid at 40bpm as per design. Frac stage 9: 1,733.3 bbls slurry (YF125ST fluid), 241,854 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,493.7 bbls clean fluid at 40bpm as per design. DataFrac: 249.4 bbls clean fluid (WF125 fluid) at 40bpm. Frac stage 10: 1,714.7 bbls slurry (YF125ST fluid), 240,700 lbs 16/20 Carbolite (1, 2, 4, 6, 8, 10ppa), 1,475.5 bbls clean fluid at 40bpm as per design. Frac stage 11: 1,749.5 bbls slurry (YF125ST fluid), 226,289 lbs 16/20 Carbolite (1, 3, 5, 7, 9, 10ppa), 1,525.8 bbls clean fluid at 40bpm as per design. Cleaned up equipment. Rig Down for Well Clean Up. Total Load to Recover (8-11) 6,693.5 bbls Total Load to Recover (Well) 20,557.2 bbls 2/16/2024 2/17/2024 Rig Down Frac Equipment, Remove Ball Launcher 2/17/2024 2/18/2024 Continue to RD Frac Equipment 2/18/2024 2/19/2024 ND Frac Tree, NU Production Tree, RD Complete Page 2 of 2 Flowback Ops Summary Report - AOGCC Well Name NDBi-044 Primary Job Type Flowback/Testing Start Date End Date Summary 2/5/2024 2/6/2024 Rig up Well Testing Equipment. 2/6/2024 2/7/2024 Rig up Well Testing Equipment. 2/7/2024 2/8/2024 Rig up Well Testing Equipment. 2/8/2024 2/9/2024 Rig up Well Testing Equipment. 2/9/2024 2/10/2024 Rig up Well Testing Equipment. 2/10/2024 2/11/2024 Rig up Well Testing Equipment. Did a safety walk through of the Expro work area with Wess Santos safety representative, all good. 2/11/2024 2/12/2024 Rig up Well Testing Equipment. 2/12/2024 2/13/2024 Rig up Well Testing Equipment. 2/13/2024 2/14/2024 Rig up Well Testing Equipment. 2/14/2024 2/15/2024 Rig up Well Testing Equipment. 2/15/2024 2/16/2024 Rig up Well Testing Equipment. 2/16/2024 2/17/2024 Rig up Well Testing Equipment. 2/17/2024 2/18/2024 Rig up Well Testing Equipment. Expro was able to remove Utilidor located at NE corner of pad to installed liner then ran the temporary flow line through then put back the 1 plating and rig matt back in place, while working simultaneously on other flow lines going toward NDBi044. 2/18/2024 2/19/2024 Rig up Well Testing Equipment. Expro work on doing a mock ESD system set up to function test the system as whole while waiting on spotting equipment at wellhead alone with installing timbers alone the temp piping for protection. 2/19/2024 2/20/2024 Start spotting Expro equipment (Sand Trap, Manifold, Sparge Tank and Lad) in berm at well head and running associated piping to connect to inlet of Expro separator and also installing Ball Catcher at wing valve assembly. 2/20/2024 2/21/2024 Expro continue to rig up at wellhead and working on the EDGE and D2D. Preparing equipment for pressure test. 2/21/2024 2/22/2024 Stand by due to Phase 3 weather. Expro continue to work on ESD system and DAQ equipment. 2/22/2024 2/23/2024 Expro Day crew stand by due to Phase weather conditions. Expro night crew continue to work on ESD system, DAQ equipment and start snow removal. 2/23/2024 2/24/2024 Expro contuing to work on ESD ssytem, DAQ equipment, pressure test, snow removal and pressure test lines. held safety meeting with both day and night crew. 2/24/2024 2/25/2024 Expro continue to work on ESD system, DAQ equipment, snow removal along flow lines. 2/25/2024 2/26/2024 Expro continue to trouble shoot ESD system, DAQ equipment, wrappings at Separator and line going to DW-02 tank farm. Work on inlet valve at sand trap, changed out stem packing then retest valve. 2/26/2024 2/27/2024 Expro finisned prepping equipment and started flowing well. 2/27/2024 2/28/2024 Expro flowing well per clean up procedure. 2/28/2024 2/29/2024 Expro flowing well per clean up procedure. 2/29/2024 3/1/2024 Expro flowing well per cleanup procedure. 3/1/2024 3/2/2024 Expro flowing well per cleanup procedure. Page 1 of 2 Flowback Ops Summary Report - AOGCC Start Date End Date Summary 3/2/2024 3/3/2024 Expro flowing well per cleanup procedure. 3/3/2024 3/4/2024 Expro flowing well per cleanup procedure. 3/4/2024 3/5/2024 Expro flowing well per cleanup procedure. 3/5/2024 3/6/2024 Expro flowing well per cleanup procedure. Shutting in well at Midnight. 3/6/2024 3/7/2024 Expro begins evacuating lines and rigging down. 3/7/2024 3/8/2024 Expro continued rigging down. 3/8/2024 3/9/2024 Expro preparing to stage equipment near WT package 3/9/2024 3/10/2024 Expro preparing to stage equipment near WT package 3/10/2024 3/11/2024 Expro preparing to stage equipment near WT package 3/11/2024 3/12/2024 Expro preparing to stage equipment near WT package 3/12/2024 3/13/2024 Expro preparing to stage equipment near WT package 3/13/2024 3/14/2024 Expro preparing to stage equipment near WT package 3/14/2024 3/15/2024 Expro Prep Equipment to move. Monitor Build up BHP and BHT. Build up scheduled until 3/19/2024 3/15/2024 3/16/2024 Expro Prep Equipment to move. Monitor Build up BHP and BHT. 3/16/2024 3/17/2024 Monitor Build up BHP and BHT. 3/17/2024 3/18/2024 Monitor Build up BHP and BHT. 3/18/2024 3/19/2024 Monitor Build up BHP and BHT. 3/19/2024 3/20/2024 Monitor Build up BHP and BHT. 3/20/2024 3/21/2024 Build up complete, Testing operations completed. Page 2 of 2 Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 7.0 gal F103 Surfactant 1.0 Gal/mGal 862.0 gal J134 Breaker 0.0 lb/mGal 9.0 lbm J450 Stabilizing Agent 0.6 Gal/mGal 504.0 gal J475 Breaker J475 5.6 lb/mGal 4,922.5 lbm J511 Stabilizing Agent 1.7 lb/mGal 1,469.0 lbm J532 Crosslinker 2.1 Gal/mGal 1,848.0 gal J580 Gel J580 24.0 lb/mGal 20,997.0 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 46.6 gal M002 Additive 0.0 lb/mGal 1.3 lbm M275 Bactericide 0.3 lb/mGal 274.6 lbm S522-1620 Propping Agent varied concentrations 2378900.0 lbm S522-2040 Propping Agent varied concentrations 16,000.0 lbm 74.86657 % 24.67842 % 0.21583 % 0.05010 % 0.04058 % 0.03860 % 0.03152 % 0.01514 % 0.01389 % 0.01389 % 0.01276 % 0.00964 % 0.00693 % 0.00152 % 0.00141 % 0.00111 % 0.00054 % 0.00028 % 0.00025 % 0.00025 % 0.00017 % 0.00014 % 0.00009 % 0.00009 % 0.00006 % 0.00004 % 0.00004 % 0.00003 % 0.00003 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % 100 % State: Alaska County/Parish: North Slope Borough Case: Client: Oil Search Alaska Well: NDBi-044 Basin/Field: Pikka Report ID: RPT-1798 Fluid Name & Volume Concentration Volume Disclosure Type: Post-Job Well Completed: 2/15/2024 Date Prepared: 2/21/2024 CAS Number Chemical Name Mass Fraction - Water (Including Mix Water Supplied by Client)* YF125ST:WF125 875,303 gal Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. 7727-54-0 Diammonium peroxidisulphate 56-81-5 1, 2, 3 - Propanetriol 1303-96-4 Sodium tetraborate decahydrate 66402-68-4 Ceramic materials and wares, chemicals 9000-30-0 Guar gum 102-71-6 2,2`,2"-nitrilotriethanol 34398-01-1 Ethoxylated C11 Alcohol 25038-72-6 Vinylidene chloride/methylacrylate copolymer 68131-39-5 Ethoxylated Alcohol 50-70-4 Sorbitol 67-63-0 Propan-2-ol 111-76-2 2-butoxyethanol 7631-86-9 Silicon Dioxide (Impurity) 10377-60-3 Magnesium nitrate 14807-96-6 Magnesium silicate hydrate (talc) 9025-56-3 Hemicellulase 91053-39-3 Diatomaceous earth, calcined 112-42-5 1-undecanol (impurity) 63148-62-9 Dimethyl siloxanes and silicones 63-42-3 Lactose 67762-90-7 Siloxanes and silicones, dimethyl, reaction products with silica 9002-84-0 poly(tetrafluoroethylene) 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 7786-30-3 Magnesium chloride 14464-46-1 Cristobalite 1310-73-2 Sodium hydroxide 1338-41-6 Sorbitan stearate 127-08-2 Acetic acid, potassium salt (impurity) 9000-90-2 Amylase, alpha 14808-60-7 Quartz, Crystalline silica 68308-89-4 Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 36089-45-9 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2-hydroxyethyl 2-propenoate 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 532-32-1 Sodium benzoate 64-19-7 Acetic acid (impurity) 68937-55-3 Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 7632-00-0 Sodium nitrite 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione 9050-36-6 Maltodextrin 9005-65-6 Sorbitan monooleate, ethoxylated 9004-32-4 Sodium carboxymethylcellulose 11138-66-2 Xanthan Gum Total * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. 2634-33-5 1,2-benzisothiazolin-3-one 9004-53-9 Dextrin 9012-54-8 Hemicellulase enzyme # SLB-Private Page: 1 / 1 SLB-Private FracCAT Treatment Report Well : NDBi-044 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : February 6, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi) 380 Initial BHP at Gauge (psi) 1,849 Final Surface ISIP (psi) 785 Final ISIP at Gauge (psi) 2576 Surface Shut in Pressure(psi) 1,555 BH Shut in Pressure (psi) 2,827 Maximum Treating Pressure (psi) 7,719 BH Gauge at 10,747 ft MD, 4,030 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)7,487.9 Total Proppant Pumped (lb) (per FracCAT) 522,892 Total YF125ST Past Wellhead (bbl) 5,637.6 Total Proppant in Formation (lb) 522,892 Total WF125 Past Wellhead (bbl) 1,232.6 Total Freeze Protect Past Wellhead (bbl) 52.1 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal) 276 276 M275 (lb) 96 90 J450 (gal) 150 150 J753 (gal) 14.8 14.8 J580 (lb) 6,279 6,279 J475 (lb) 1,650 1,650 J532 (gal) 557 557 J134 (lb) 9 9 J511 (lb) 600 442 D206 (gal) 2 2 M002 (lb) 0.5 0.4 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimat es as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 7,719 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Summary On February 4, 2024, SLB successfully opened Toe Sleeve and on February 5, 2024, performed a hydraulic fracturing treatment on Stages 1-3 of NBDi-044. The initial plan called for the completion of stages 1-4, on Stage 2 there was a suction loss from Frac tanks to PCM during 3PPA step, the decision along with Santos Company Rep was made to go on Flush. When water tank issues were resolved, Stage 2 resumed from beginning, then Stage 3 was pumped and the Ball/Collet#4launched.The Ball/Collet#4 was seated successfully.Postshutdown pressure decline was monitored for 60 min. Remaining WF from PCM was pumped downhole followed by Freeze Protect. By FracCAT totals, a total of 522,890 pounds of proppant was pumped and 522,890 was placed into formation in 7,487.9 bbl of slurry. Please note, that proppant Volumes are as per densitometer and not physical strap due to split loads. Stages 1 through 3 consisted of a PAD, and 8 proppant steps from 1-8 PPA. Pump trips were staggered from 7,600 to 8,000 psi. The GORV was set to 8,300 psi. The highlight of the stages was that the collet launch sequence greatly improved with the addition of a second line going to the wellhead. Summary of Stages 1-3 Material Actual Design Slurry Volume (bbl)7,488 5,928 Clean Fluid Volume(bbl) 6,870 5,336 Proppant (lb) 522,892 559,389 11:30:26 14:17:06 17:03:46 19:50:26 22:37:06 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-43 08-26-2023 Stage1 Stage2 (1) Stage3 Stage2 (2) Emptied PCM FPDF Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Toe Sleeve Activation Toe Sleeve activation was successful. When the well was opened the pressure was 380 psi. Toe Sleevewas activated atthe pressure 7719 psi at average Slurry Rate of 3.6 bbl/min. In the end of pumping there was a hard shutdown with an ISIP of 870 psi. A summary of the Stage below: Summary of Toe Sleeve Activation Stage Total Slurry Pumped (bbl)9.9 Max pumping Rate (bpm)4.7 Average Treating Pressure (psi)3,364 Average Pumping Rate (bpm)3.6 Average Water Temperature (F)87.4 Maximum Treating Pressure (psi)7,719 As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT Open Toe Sleeve 9.9 3.6 3.2 Freeze Protect 420 0.0 0.0 0.0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT Open Toe Sleeve 3.6 4.7 3,364 7,719 599 17:25:13 17:33:33 17:41:53 17:50:13 17:58:33 Time - hh:mm:ss -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 1 2 3 4 5 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Toe Sleve ActivationFracCAT*SantosNDBi-4402-04-2024 Toe Sleeve activation Open well Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States DF Stage DF included a pump check that was placed in the schedule to test the equipment and ensure the pumps were job ready, DataFRAC Pad and Displace DF. After step Displace DF was pumped, there was a hard shutdown with an ISIP of 862 psi and recording of pressure decline. A summary of the stage and pressures as follows: Summary of Stage DataFrac (Pump check and DataFrac) Total Proppant Pumped (lb)0 Max pumping Rate (bpm)40.3 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)25.0 Total Slurry Pumped (bbl)673.3 Maximum Treating Pressure (psi)6,997 YF125ST Pumped (bbl)249.4 Average Treating Pressure (psi)3,035 WF125 Pumped (bbl)423.9 Average Water Temperature (F)89.1 Average Viscosity (cP)21.8 As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT 40.3 3.2 12.8 WF125 1692 0.0 0.0 0 2 Pump Check 103.4 30.8 4.1 WF125 4341 0.0 0.0 0 3 Shut Down 0.0 0.0 0.0 -0 0.0 0.0 0 4 DataFrac XL 249.4 16.0 16.0 YF125ST 10476 0.0 0.0 0 5 DataFrac WF 50.0 16.1 3.1 WF125 2100 0.0 0.0 0 6 Displace DF 230.2 37.9 6.3 WF125 9671 0.0 0.0 0 7 Shut Down 0.0 0.0 0.0 --0.0 0.0 0 11:33:55 12:11:25 12:48:55 13:26:25 14:03:55 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con DFFracCAT*Santos NDBi-4402-05-2024 PT Displacement DataFRAC Pump Check 6,997 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT 3.2 3.5 1066 1184 152 2 Pump Check 30.8 39.5 5610 6997 368 3 Shut Down 0.0 0.0 3650 1029 459 4 DataFrac XL 16.0 16.4 2033 2229 530 5 DataFrac WF 16.1 16.1 2126 2146 2110 6 Displace DF 37.9 40.3 3520 3803 478 7 Shut Down 0.0 0.0 953 478 478 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 1 The treating pressure on PAD was around 2,700 psi before the Collet/Ball#1 hit the sleeve, then Treating pressure on PAD was around 3,450 psi and slowly fell to about 3,100 psi when 2PPA was going into the formation. At this point, the treating pressure was gradually increasing from 3,100 to 5,720 psi. There was an issue with POD gates during early proppant steps due to frozen gates. Issue was troubleshooted and addressed prior staging over to 4PPA step. Additionally, during the stage briefly one pump had issues and it was offline from 3PPA until 6PPA. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #1 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,009 3,104 3,373 Bottomhole Pressure 3,110 4,157 3,818 Summary of Stage 1 Total Proppant Pumped (lb)176,971 Max pumping Rate (bpm)40.7 Total Proppant in Formation (lb)176,971 Average Pumping Rate (bpm)36.9 Total Slurry Pumped (bbl)1,652.1 Maximum Treating Pressure (psi)5,177 YF125ST Pumped (bbl)1,464.5 Average Treating Pressure (psi)3,357 WF125 Pumped (bbl)0 Average Water Temperature (F)90.8 Average Viscosity (cP)19.9 13:50:44 14:07:24 14:24:04 14:40:44 14:57:24 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 1FracCAT*Santos NDBi-44 02-05-2024 Bringing the pump back Problem with the POD Blender gates Collet/Ball#1 hit the sleeve Lost pump Drop Rate for Ball/Collet#1 Drop Rate for Ball/Collet#2 5,177 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Line out XL 40.0 18.9 2.9 YF125ST 1665 0.0 0.0 0 2 Drop Collet#1 3.0 21.0 0.1 YF125ST 126 0.0 0.0 0 3 PAD st1 237.0 28.9 8.3 YF125ST 9948 0.0 0.0 0 4 Slow for Seat 50.0 20.0 2.6 YF125ST 2099 0.0 0.0 0 5 Resume Pad 34.6 36.3 0.9 YF125ST 1447 0.0 0.0 0 6 1.0 PPA 140.0 40.0 3.5 YF125ST 5757 CarboLite 16/20 0.7 0.5 2753 7 2.0 PPA 160.0 38.6 4.2 YF125ST 6286 CarboLite 16/20 2.3 1.6 9787 8 3.0 PPA 160.0 39.6 4.0 YF125ST 6168 CarboLite 16/20 3.6 2.0 12376 9 4.0 PPA 170.0 39.7 4.3 YF125ST 6114 CarboLite 16/20 4.0 3.8 23097 10 5.0 PPA 170.0 39.7 4.3 YF125ST 5865 CarboLite 16/20 5.4 4.9 28696 11 6.0 PPA 170.0 39.7 4.3 YF125ST 5664 CarboLite 16/20 6.4 5.9 33247 12 7.0 PPA 125.0 39.6 3.2 YF125ST 4020 CarboLite 16/20 7.1 6.9 27706 13 8.0 PPA 167.4 39.8 4.2 YF125ST 5295 CarboLite 16/20 8.1 7.5 39305 14 Clean line & Spacer 22.1 40.2 0.6 YF125ST 928 CarboLite 16/20 0.2 0.0 4 15 Drop Collet#2 3.0 40.2 0.1 YF125ST 126 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Line out XL 18.9 21.8 2216 2544 478 2 Drop Collet#1 21.0 21.0 2404 2508 2289 3 PAD st1 28.9 30.0 2724 2975 2244 4 Slow for Seat 20.0 30.0 2262 3013 1645 5 Resume Pad 36.3 39.9 3180 3418 2980 6 1.0 PPA 40.0 40.0 3417 3541 3374 7 2.0 PPA 38.6 40.0 3153 3374 2573 8 3.0 PPA 39.6 39.7 3145 3186 3007 9 4.0 PPA 39.7 39.7 3174 3230 3127 10 5.0 PPA 39.7 39.7 3363 3544 3230 11 6.0 PPA 39.7 40.7 3661 3809 3547 12 7.0 PPA 39.6 39.7 3971 4138 3812 13 8.0 PPA 39.8 40.2 4412 4769 4146 14 Clean Line & Spacer 40.2 40.2 5001 5152 4774 15 Drop Collet#2 40.2 40.2 5169 5177 5163 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 2 (attempt 1) Once the Collet/Ball#2 hit the sleeve the pressure transition from Stage 1 to 2 was typical. Treating pressure on PAD was around 3,000 psi. Suction was lost on the PCM at stage 3PPA, this led to decision of cutting sand early and overflush the pumped prop into the formation. The rate was decreased to 36 BPM to keep up with the suction on PCM. Flushed with YF125ST fluid and then overflushed it with WF125 fluid. While the suction loss was being resolved, the pumps were rolled pumping fluid downhole at rate 3.0 bpm per pump at 1 minute each pump to warm the lines and pumps. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #2 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,115 2,760 2,083 Bottomhole Pressure 3,165 3,583 3,140 Summary of Stage 2 (attempt 1) Total Proppant Pumped (lb) 26,556 Max pumping Rate (bpm) 40.2 Total Proppant in Formation (lb) 26,556 Average Pumping Rate (bpm) 35.4 Total Slurry Pumped (bbl) 1,465.9 Maximum Treating Pressure (psi) 5,637 YF125ST Pumped (bbl) 1,175.6 Average Treating Pressure (psi) 3,018 WF125 Pumped (bbl) 262.9 Average Water Temperature (F) 93.3 Average Viscosity (cP) 18.8 14:48:19 15:04:59 15:21:39 15:38:19 15:54:59 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 2FracCAT*Santos NDBi-44 02-05-2024 Collet/Ball#2 hit the sleeve.PCM suction loss Overflushing YF125 gel with WF125 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st2 229.0 38.5 6.0 YF125ST 9635 0.0 0.0 0 2 Slow For Seat 50.0 17.8 2.8 YF125ST 2090 0.0 0.0 0 3 Resume Pad 63.8 38.1 1.7 YF125ST 2675 0.0 0.0 0 4 1.0 PPA 140.0 39.6 3.5 YF125ST 5660 CarboLite 16/20 1.0 0.9 4995 5 2.0 PPA 160.0 38.5 4.2 YF125ST 6196 CarboLite 16/20 2.1 1.9 11796 6 3.0 PPA 124.3 34.9 3.7 YF125ST 4808 CarboLite 16/20 3.0 2.0 9760 7 Flush XL 436 33.8 20 YF125ST 18313 CarboLite 16/20 0 0 5.0 8 Flush WF 262.8 33.8 6.8 WF125 11043 0 0 0.0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st2 38.5 40.2 4411 5637 1358 2 Slow For Seat 17.8 29.6 2169 3094 1358 3 Resume Pad 38.1 40.1 3035 3200 2858 4 1.0 PPA 39.6 40.1 3143 3242 2744 5 2.0 PPA 38.5 40.2 2906 3047 2392 6 3.0 PPA 34.9 35.0 2503 2656 24 7 8 Flush XL WF Flush 33.8 40.1 2711 3648 444 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 2 (attempt 2) The decisionfrom Santos officewas madeto refractureStage 2. Ball was launched and pumped at the rate 16 BPM with the Volume 260bbl, then Rate was increased to target rate 40BPM. Treating pressure on PAD was around 1,800 psi (at 17 BPM) and 3,130 psi (at 40BPM) and was stable until 1ppa reach into formation. At this point, the treating pressure was gradually increasing from 2,920 to 3,600 psi then it was gradually decreasing to 3,320 psi while 3PPA was going to formation. Once 4PPA reached the formation pressure started slowly growing from 3,320 psi to 4,340 psi. The decision was made to cut the proppant early due to pressure increase during 7PPA step at the surface. The proppant was cut, brought back and cut again at customer's request. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#3 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Stage 2 (attempt 2) Total Proppant Pumped (lb) 167,305 Max pumping Rate (bpm) 40.2 Total Proppant in Formation (lb) 167,305 Average Pumping Rate (bpm) 36.1 Total Slurry Pumped (bbl) 1,597.0 Maximum Treating Pressure (psi) 5,366 YF125ST Pumped (bbl) 1,419.6 Average Treating Pressure (psi) 3,183 WF125 Pumped (bbl) 0 Average Water Temperature (F) 94.3 Average Viscosity (cP) 19.5 17:23:36 17:40:16 17:56:56 18:13:36 18:30:16 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 2 (Second Attempt)FracCAT*Santos NDBi-44 02-05-2024 Pump the ball to Sleeve#2 at rate 17BPM Cut proppant due to pressure growth. Drop Rate for Ball/Collet#3 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st2(2) 16.8 17.4 1834 2152 592 2 Resume Pad 35.4 40.1 2787 3136 1796 3 1.0 PPA 40.1 40.2 3047 3144 3011 4 2.0 PPA 40.1 40.1 2943 3017 2905 5 3.0 PPA 40.1 40.1 3144 3395 2909 6 4.0 PPA 40.1 40.1 3525 3600 3401 7 5.0 PPA 40.1 40.1 3433 3510 3379 8 6.0 PPA 40.1 40.1 3678 3851 3484 9 7.0 PPA 40.1 40.1 4111 4710 3852 10 Clean line & Spacer 40.1 40.1 5160 5366 4713 11 Drop Collet#3 40.1 40.1 5148 5321 4984 As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st2(2)260.0 16.8 15.7 YF125ST 10908 0.0 0.0 0 2 Resume Pad 90.0 35.4 2.6 YF125ST 3764 0.0 0.0 0 3 1.0 PPA 140.0 40.1 3.5 YF125ST 5645 CarboLite 16/20 1.0 0.9 5260 4 2.0 PPA 160.0 40.1 4.0 YF125ST 6163 CarboLite 16/20 2.1 2.0 12534 5 3.0 PPA 180.0 40.1 4.5 YF125ST 6647 CarboLite 16/20 3.2 3.1 20548 6 4.0 PPA 180.0 40.1 4.5 YF125ST 6470 CarboLite 16/20 4.1 3.8 24542 7 5.0 PPA 180.1 40.1 4.5 YF125ST 6199 CarboLite 16/20 5.2 5.0 30743 8 6.0 PPA 180.0 40.1 4.5 YF125ST 5973 CarboLite 16/20 6.2 6.0 35758 9 7.0 PPA 186.5 40.1 4.6 YF125ST 6159 CarboLite 16/20 7.1 6.2 37865 10 Clean line & Spacer 37.4 40.1 0.9 YF125ST 1570 CarboLite 16/20 0.5 0.0 53 11 Drop Collet#3 3.0 40.1 0.1 YF125ST 126 CarboLite 16/20 0.0 0.0 2 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 3 Once the Collet/Ball#3 hit the sleeve the pressure transition from Stage 2 to 3 was typical. Treating pressure on PAD was around 2,950 psi and was stable until 2PPA reached into formation. At this point, the treating pressure was gradually increasing from 2,950 to 3,240 psi and then the angle of pressure growth changed when 5PPA was going into formation. At 7PPA on surface, the decision was made to cut the proppant and go to Flush. The Collet/Ball#4 was launched, successfully seated, and followed by a stepdown shutdown (with rates 40-32-24-16BPM) with an ISIP of 862 psi and recording of pressure decline for 60 mins. Then the PCM was emptied and WF125 fluid was pumped downhole followed by Freeze Protect. To be noted that one tank (tank 14) couldnt not be open during pumping operations due to stuck butterfly valve. Due to early prop cuts from stage 2 this volume was not necessary for the job. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #3 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,190 3,021 2,272 Bottomhole Pressure 3,242 3,901 3,275 Summary of Stage 3 Total Proppant Pumped (lb) 152,060 Max pumping Rate (bpm) 40.2 Total Proppant in Formation (lb) 152,060 Average Pumping Rate (bpm) 35.3 Total Slurry Pumped (bbl) 2,089.7 Maximum Treating Pressure (psi) 4,962 YF125ST Pumped (bbl) 1,328.4 Average Treating Pressure (psi) 3,095 WF125 Pumped (bbl) 545.8 Average Water Temperature (F) 94.5 Average Viscosity (cP) 20.1 18:23:57 18:48:57 19:13:57 19:38:57 20:03:57 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con Stage 3FracCAT*SantosNDBi-44 02-05-2024 Collet/Ball#3 hit the sleeve.Collet/Ball#4 hit the sleeve. Drop Rate for Ball/Collet#4 Step Down Shutdown Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st3 179.7 39.9 4.6 YF125ST 7566 0.0 0.0 0 2 Slow For Seat 50.0 16.9 3.0 YF125ST 2100 0.0 0.0 0 3 Resume Pad 82.2 20.9 4.2 YF125ST 3438 0.0 0.0 0 4 1.0 PPA 140.1 39.7 3.5 YF125ST 5648 CarboLite 16/20 1.0 0.9 5191 5 2.0 PPA 160.0 40.1 4.0 YF125ST 6187 CarboLite 16/20 2.1 1.9 12025 6 3.0 PPA 180.1 40.1 4.5 YF125ST 6686 CarboLite 16/20 3.1 3.0 19721 7 4.0 PPA 180.0 40.1 4.5 YF125ST 6433 CarboLite 16/20 4.1 4.0 25422 8 5.0 PPA 180.1 39.5 4.6 YF125ST 6201 CarboLite 16/20 5.1 5.0 30692 9 6.0 PPA 180.1 40.0 4.5 YF125ST 5981 CarboLite 16/20 6.1 6.0 35623 10 7.0 PPA 114.8 40.0 2.9 YF125ST 3789 CarboLite 16/20 7.2 6.2 23384 11 Clean line & Spacer 14.0 40.0 0.4 YF125ST 588 CarboLite 16/20 0.1 0.0 2 12 Drop Collet#4 3.0 40.0 0.1 YF125ST 126 0.0 0.0 0 13 XL Flush 25.0 38.6 0.7 YF125ST 1051 0.0 0.0 0 14 WF Flush 185.0 37.8 4.9 WF125 7768 0.0 0.0 0 15 Slow For Seat 51.0 21.3 2.6 WF125 2142 0.0 0.0 0 16 Step Down(40)80.0 39.6 2.0 WF125 3357 0.0 0.0 0 17 Step Down(32)50.0 34.1 1.5 WF125 2105 0.0 0.0 0 18 Step Down(24)40.0 25.2 1.6 WF125 1687 0.0 0.0 0 19 Step Down(16)30.0 16.1 2.2 WF125 1274 0.0 0.0 0 20 Emptied PCM 109.5 15.7 7.7 WF125 4590 0.0 0.0 0 21 Freeze Protect 55.1 16.9 3.3 Freeze Protect 2326 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st3 39.9 40.2 4167 4904 1469 2 Slow For Seat 16.9 18.2 2237 2751 1469 3 Resume Pad 20.9 36.5 2485 3097 2287 4 1.0 PPA 39.7 40.1 2959 3002 2807 5 2.0 PPA 40.1 40.1 2901 2983 2849 6 3.0 PPA 40.1 40.1 2895 3009 2847 7 4.0 PPA 40.1 40.1 3095 3125 3018 8 5.0 PPA 39.5 40.1 3078 3198 2891 9 6.0 PPA 40.0 40.0 3506 3849 3192 10 7.0 PPA 40.0 40.0 4107 4477 3853 11 Clean line & Spacer 40.0 40.0 4527 4590 4492 12 Drop Collet#4 40.0 40.0 4644 4704 4596 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 13 XL Flush 38.6 40.0 4887 4962 4731 14 WF Flush 37.8 37.9 3841 4886 3238 15 Slow For Seat 21.3 37.8 1989 3235 1253 16 StepDown(40) 39.6 40.1 3104 3149 2945 17 StepDown(32) 34.1 40.1 2610 3108 2442 18 StepDown(24) 25.2 32.5 1998 2531 1733 19 StepDown(16) 16.1 22.9 1450 1902 366 20 Emptied PCM 15.7 17.1 1626 1702 729 21 Freeze Protect 16.9 17.0 1756 1970 827 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Toe Sleeve Activation Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 15:20:50 Prime Up 60 22 0.0 5.4 0.0 2 15:59:25 Low Pressure Test 860 22 0.0 0.0 0.0 3 16:13:58 Setting Seats & Valves on Pumps 5428 21 0.0 0.0 0.0 4 16:27:51 Searching for Leaks 6023 22 0.0 0.0 0.0 5 16:34:27 Mid Pressure Test 5656 21 0.0 0.0 0.0 6 16:36:20 High Pressure Test 9476 22 0.0 0.0 0.0 7 16:44:50 High Pressure Test 9481 21 0.0 0.0 0.0 8 17:34:18 LR Pressuring Up IA To 3400 PSI 394 979 0.0 0.0 0.0 9 17:42:10 Open Well 382 3377 0.0 0.0 0.0 10 17:43:51 Start Displ PT Automatically 2077 3495 0.0 4.7 0.0 11 17:43:51 Start Propped Frac Automatically 2077 3495 0.0 4.7 0.0 12 17:43:51 Start DF Automatically 2077 3495 0.0 4.7 0.0 13 17:43:55 Started Pumping 2519 3512 0.0 4.7 0.0 14 17:49:22 Closed Well 704 2894 9.9 0.0 0.0 15 17:52:01 Fanning Out Pumps To Bleed Off Tank 2 2026 9.9 4.0 0.0 DF Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 7:53:14 Priming Pumps with Diesel 28 871 0.0 5.4 0.0 2 8:22:05 Finished Prime Up 27 871 0.0 0.0 0.0 3 8:23:41 Low Pressure Test 659 871 0.0 0.0 0.0 4 8:29:49 Mid Pressure Test 5655 871 0.0 0.0 0.0 5 8:40:57 High Pressure Test 9712 871 0.0 0.0 0.0 6 8:49:00 High Pressure Test 9523 871 0.0 0.0 0.0 7 8:54:47 Good Test 9212 871 0.0 0.0 0.0 8 8:58:56 Fueling Frac Equipment 1373 871 0.0 0.0 0.0 9 9:00:07 Safety Meeting 1426 871 0.0 0.0 0.0 10 9:40:19 Radio Check 1253 871 0.0 0.0 0.0 11 10:10:10 Troubleshooting PCM Eductor 1016 3190 0.0 0.0 0.0 12 11:03:56 Mixing Gel 25 #733 3153 0.0 0.0 0.0 13 11:35:32 Open Well 155 3140 0.0 0.0 0.0 14 11:36:16 Start Displ PT Automatically 153 3142 0.0 0.0 0.0 15 11:36:55 Started Pumping 152 3143 0.0 0.0 0.0 16 11:50:37 Stopped Pumping 836 3133 40.3 0.0 0.0 19 12:09:21 Started Pumping 369 3159 40.3 0.0 0.0 20 12:09:25 Start Pump Check Automatically 369 3159 40.3 0.0 0.0 21 12:13:46 Stopped Pumping 495 3114 143.7 0.8 0.0 22 12:20:28 Started Pumping 623 3258 143.7 0.0 0.0 23 12:20:29 Start Shut Down Automatically 622 3250 143.7 0.0 0.0 24 12:27:16 Stopped Pumping 476 3250 143.7 0.0 0.0 25 12:28:32 Started Pumping 461 3249 143.7 0.0 0.0 26 12:28:49 Start DataFrac XL Automatically 741 3255 143.7 0.2 0.0 27 12:37:15 Stage at Perfs: Displ PT 1976 3353 271.8 16.1 0.0 28 12:39:46 Stage at Perfs: Pump Check 1989 3384 312.3 16.1 0.0 29 12:44:48 Start DataFrac WF Manually 2115 3409 393.3 16.1 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 30 12:46:11 Stage at Perfs: DataFrac XL 2106 3368 415.6 16.1 0.0 31 12:47:55 Start Displace DF Automatically 2153 3405 443.5 16.1 0.0 32 12:53:57 Stage at Perfs: DataFrac WF 3639 3439 666.0 40.3 0.0 33 12:54:13 Start Shut Down Automatically 546 3326 673.5 12.2 0.0 34 12:54:13 Stopped Pumping 546 3326 673.5 12.2 0.0 Stage 1 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:54:27 Started Pumping 617 3154 673.5 0.2 0.0 2 13:54:28 Start Line out XL Automatically 616 3153 0.0 0.2 0.0 3 13:58:19 Start Drop Collet1 Automatically 2440 3224 40.1 21.0 0.0 4 13:58:25 Stage at Perfs: Displace DF 2551 3223 42.2 20.9 0.0 5 13:58:28 Start PAD st1 Automatically 2581 3223 43.2 20.9 0.0 6 14:06:29 Stage at Perfs: Line out XL 2562 3389 272.3 30.0 0.0 7 14:06:45 Start Slow for Seat Automatically 2395 3389 280.3 30.0 0.0 8 14:08:19 Stage at Perfs: Drop Collet#1 2305 3418 309.1 17.1 0.0 9 14:08:30 Stage at Perfs: PAD st1 2222 3412 312.2 17.1 0.0 10 14:09:21 Start Resume Pad Automatically 2808 3420 330.3 31.5 0.0 11 14:10:17 Start 1.0 PPA Manually 3448 3442 364.6 40.0 0.0 12 14:10:17 Started Pumping Prop 3448 3442 364.6 40.0 0.0 13 14:13:48 Start 2.0 PPA Automatically 3366 3446 505.2 40.0 0.5 14 14:14:55 Stage at Perfs: Slow for Sea 3323 3401 549.8 40.0 1.3 15 14:16:10 Stage at Perfs: Resume Pad 3252 3397 599.8 40.0 2.1 16 14:17:06 Stage at Perfs: 1.0 PPA 2822 3398 633.5 35.7 1.4 17 14:17:57 Start 3.0 PPA Automatically 2948 3427 664.8 38.0 1.2 18 14:20:43 Stage at Perfs: 2.0 PPA 3152 3472 774.1 39.7 1.7 19 14:22:00 Start 4.0 PPA Automatically 3200 3484 825.0 39.7 2.8 20 14:24:44 Stage at Perfs: 3.0 PPA 3142 3510 933.6 39.7 4.0 21 14:26:17 Start 5.0 PPA Automatically 3229 3518 995.2 39.7 3.4 22 14:28:46 Stage at Perfs: 4.0 PPA 3389 3355 1093.9 39.7 4.8 23 14:30:33 Start 6.0 PPA Automatically 3549 3362 1164.7 39.7 5.0 24 14:33:03 Stage at Perfs: 5.0 PPA 3720 3371 1264.6 39.9 5.7 25 14:34:50 Start 7.0 PPA Automatically 3828 3387 1334.9 39.7 5.8 26 14:37:20 Stage at Perfs: 6.0 PPA 4065 3378 1434.0 39.7 6.8 27 14:37:59 Start 8.0 PPA Automatically 4174 3382 1459.8 39.8 7.0 28 14:41:37 Stage at Perfs: 7.0 PPA 4671 3414 1604.3 40.0 7.9 29 14:42:11 Start Clean line & Spacer Manually 4865 3422 1627.1 40.2 0.0 30 14:42:14 Stopped Pumping Prop 4930 3428 1629.1 40.1 0.0 31 14:42:42 Launch Ball & Collet#2 5171 3436 1647.8 40.2 0.0 32 14:42:44 Start Drop Collet#2 Manually 5184 3437 1649.2 40.2 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 2 (attempt 1) Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 14:42:49 Start PAD st2 Automatically 5263 3439 0.0 40.2 0.0 2 14:42:49 Start Propped Frac Automatically 5263 3439 0.0 40.2 0.0 3 14:42:49 Start Stage 2 Automatically 5263 3439 0.0 40.2 0.0 4 14:44:52 Stage at Perfs: 8.0 PPA 4500 3435 76.5 37.5 0.0 5 14:48:49 Start Slow For Seat Automatically 1722 3377 228.7 16.2 0.0 6 14:49:40 Stage at Perfs: Spacer 2075 3388 243.2 17.0 0.0 7 14:50:28 Ball & Collet#2 Seated 2683 3419 256.8 17.0 0.0 8 14:50:59 Stage at Perfs: Drop Collet2 2095 3389 265.5 17.0 0.0 9 14:51:10 Stage at Perfs: PAD st2 2211 3385 268.6 17.0 0.0 10 14:51:36 Start Resume Pad Automatically 2751 3402 278.7 31.3 0.0 11 14:53:16 Start 1.0 PPA Manually 3209 3384 342.5 40.1 0.0 12 14:53:16 Started Pumping Prop 3209 3384 342.5 40.1 0.0 13 14:56:49 Start 2.0 PPA Automatically 2740 3356 482.6 35.5 0.9 14 14:57:01 Stage at Perfs: Slow For Seat 2750 3358 489.7 35.5 1.2 15 14:58:21 Stage at Perfs: Resume Pad 2996 3376 540.2 39.7 2.1 16 14:59:56 Stage at Perfs: 1.0 PPA 3015 3384 603.6 40.2 2.0 17 15:01:00 Start 3.0 PPA Automatically 2559 3368 642.8 35.0 2.0 18 15:03:30 Stopped Pumping Prop 2515 3367 730.3 35.0 2.4 19 15:03:36 Started Pumping Prop 2536 3368 733.8 35.0 0.0 20 15:03:53 Stage at Perfs: 2.0 PPA 2579 3369 743.7 35.0 0.1 21 15:05:00 Start Clean line & Spacer Manually 1626 3394 766.7 2.9 0.0 22 15:08:17 Stopped Pumping Prop 2894 3387 851.3 34.9 0.0 23 15:09:47 Stage at Perfs: 3.0 PPA 3016 3415 903.6 34.9 0.0 24 15:13:21 Stage At Perfs 2927 3422 1027.9 34.9 0.0 25 15:29:01 Stopped Pumping 857 3394 1449.1 0.0 0.0 26 16:30:00 Started Pumping 779 3039 1449.1 3.1 0.0 27 16:31:10 Rolling Pumps DH Prevent Freezing 768 3037 1452.2 3.3 0.0 28 16:41:58 Stopped Pumping 592 2981 1465.4 0.0 0.0 Stage 2 (attempt 2) Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 17:30:30 Started Pumping 685 3159 1465.5 0.0 0.0 2 17:30:33 Start PAD st2(2) Manually 881 3164 1465.5 0.0 0.0 3 17:30:33 Start Propped Frac Manually 881 3164 1465.5 0.0 0.0 4 17:30:33 Start Stage 2 (2) Automatically 881 3164 1465.5 0.0 0.0 5 17:46:21 Start Resume Pad Automatically 1798 3339 260.1 17.0 0.0 6 17:46:24 Stage At Perfs 1796 3340 261.0 17.0 0.0 7 17:48:58 Start 1.0 PPA Automatically 3132 3379 350.2 40.1 0.0 8 17:48:58 Started Pumping Prop 3132 3379 350.2 40.1 0.0 9 17:52:28 Start 2.0 PPA Automatically 3014 3355 490.6 40.1 1.0 10 17:53:14 Stage At Perfs 2974 3377 521.4 40.1 2.1 11 17:55:28 Stage At Perfs 2914 3423 611.0 40.1 2.1 12 17:56:27 Start 3.0 PPA Automatically 2912 3441 650.5 40.1 2.1 13 17:58:58 Stage At Perfs 3189 3482 751.5 40.1 3.1 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 14 18:00:56 Start 4.0 PPA Automatically 3402 3351 830.4 40.1 2.9 15 18:02:57 Stage At Perfs 3550 3377 911.3 40.1 3.8 16 18:05:25 Start 5.0 PPA Automatically 3510 3393 1010.3 40.1 4.0 17 18:07:26 Stage At Perfs 3387 3390 1091.2 40.1 5.0 18 18:09:54 Start 6.0 PPA Automatically 3484 3391 1190.2 40.1 5.5 19 18:11:55 Stage At Perfs 3662 3407 1271.1 40.1 5.9 20 18:14:24 Start 7.0 PPA Automatically 3858 3415 1370.8 40.1 6.0 21 18:16:24 Stage At Perfs 4052 3382 1451.0 40.1 7.1 22 18:19:02 Start Clean line & Spacer Manually 4809 3375 1556.7 40.1 0.2 23 18:19:58 Start Drop Collet#3 Manually 4953 3393 1594.1 40.1 0.0 Stage 3 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 18:20:03 Start PAD s3 Automatically 4798 3387 0.0 40.2 0.0 2 18:20:03 Start Propped Frac Automatically 4798 3387 0.0 40.2 0.0 3 18:20:03 Start Stage 3 Automatically 4798 3387 0.0 40.2 0.0 4 18:20:55 Stage At Perfs 4513 3391 34.8 40.1 0.0 5 18:24:36 Start Slow For Seat Manually 2246 3413 179.4 16.4 0.0 6 18:25:48 Ball & Collet#3 Seated 3004 3452 199.6 16.8 0.0 7 18:27:00 Stage At Perfs 2260 3420 219.9 16.9 0.0 8 18:27:35 Start Resume Pad Automatically 2298 3424 229.8 16.9 0.0 9 18:29:13 Stage At Perfs 2318 3438 257.4 16.9 0.0 10 18:29:25 Stage At Perfs 2321 3439 260.8 16.9 0.0 11 18:31:45 Start 1.0 PPA Manually 2847 3472 311.6 36.8 0.0 12 18:31:45 Started Pumping Prop 2847 3472 311.6 36.8 0.0 13 18:34:50 Stage At Perfs 2986 3333 433.9 40.1 1.0 14 18:35:17 Start 2.0 PPA Automatically 2986 3344 451.9 40.1 1.0 15 18:36:05 Stage At Perfs 2953 3354 484.0 40.1 2.0 16 18:38:08 Stage At Perfs 2876 3369 566.2 40.1 2.0 17 18:39:17 Start 3.0 PPA Automatically 2854 3374 612.3 40.1 2.0 18 18:41:38 Stage At Perfs 2878 3363 706.5 40.1 3.0 19 18:43:46 Start 4.0 PPA Automatically 3010 3349 792.0 40.1 3.0 20 18:45:38 Stage At Perfs 3117 3344 866.8 40.1 3.9 21 18:48:16 Start 5.0 PPA Automatically 3092 3328 972.4 40.1 4.0 22 18:50:07 Stage At Perfs 2896 3315 1046.0 37.8 5.1 23 18:52:49 Start 6.0 PPA Automatically 3187 3309 1152.0 40.0 5.1 24 18:54:41 Stage At Perfs 3456 3300 1226.7 40.0 6.0 25 18:57:19 Start 7.0 PPA Automatically 3869 3272 1332.0 40.0 6.0 26 18:59:10 Stage At Perfs 4235 3321 1406.1 40.0 7.0 27 19:00:11 Start Clean line & Spacer Manually 4513 3319 1446.7 40.0 0.0 28 19:00:15 Stopped Pumping Prop 4522 3320 1449.4 40.0 -0.0 29 19:00:32 Start Drop Collet#4 Manually 4731 3326 1460.7 40.0 0.0 30 19:00:37 Start XL Flush Automatically 4962 3331 1464.1 39.9 0.0 31 19:01:16 Start WF Flush Automatically 4880 3326 1489.0 37.8 0.0 32 19:03:50 Stage At Perfs 3767 3311 1586.1 37.8 0.0 33 19:06:09 Start Slow For Seat Manually 2962 3308 1673.7 37.8 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 34 19:07:34 Ball & Collet#4 Seated 2218 3280 1699.8 16.8 0.0 35 19:07:37 Stage At Perfs 2265 3312 1700.7 16.7 0.0 36 19:08:27 Stage At Perfs 2354 3307 1714.9 21.7 0.0 37 19:08:35 Stage At Perfs 2784 3326 1718.1 26.7 0.0 38 19:08:47 Start StepDown(40) Manually 2945 3304 1724.7 35.7 0.0 39 19:09:16 Stage At Perfs 3130 3352 1743.3 40.0 0.0 40 19:10:48 Start StepDown(32) Automatically 3107 3356 1804.7 40.0 0.0 41 19:12:18 Start StepDown(24) Automatically 2531 3350 1854.9 32.5 0.0 42 19:13:57 Start StepDown(16) Automatically 1903 3346 1894.9 22.9 0.0 43 19:15:58 Stopped Pumping 927 3360 1924.1 0.0 0.0 44 20:16:45 Started Pumping 366 3265 1924.1 0.0 0.0 45 20:17:16 Start PCM Leftover Downhole 841 3292 1924.7 3.4 0.0 46 20:18:04 Stage At Perfs 1254 3295 1927.4 5.2 0.0 47 20:21:40 Stage At Perfs 1691 3289 1978.7 17.0 0.0 48 20:24:56 Start Freeze Protect Manually 1535 3300 2034.2 17.0 0.0 49 20:26:22 Stage At Perfs 1791 3305 2058.5 17.0 0.0 50 20:28:29 Stopped Pumping 897 3309 2089.3 0.0 0.0 51 20:31:45 Well Closed 998 2220 2089.3 0.0 0.0 52 20:33:33 Fanning Pumps To Bleed Tanks 40 1537 2089.3 14.9 0.0 SLB-Private FracCAT Treatment Report Well : NDBi-044 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : February 11, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi) 301 Initial BHP at Gauge (psi) 1,903 Final Surface ISIP (psi) 953 Final ISIP at Gauge (psi) 2,595 Surface Shut in Pressure(psi) 1,899 BH Shut in Pressure (psi) 2,823 Maximum Treating Pressure (psi) 5,770 BH Gauge at 10,747 ft MD, 4,030 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)8,252.2 Total Proppant Pumped (lb) (per FracCAT and BOL weight) 920,541 Total YF125ST Past Wellhead (bbl) 6,272.2 Total Proppant in Formation (lb) 920,541 Total WF125 Past Wellhead (bbl) 964.0 Total Freeze Protect Past Wellhead (bbl) 42.8 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal) 302 302 M275 (lb) 90 90 J450 (gal) 171 171 J753 (gal) 16.1 16.1 J580 (lb) 7,458 7,453 J475 (lb) 1,595 1,595 J532 (gal) 645 645 J134 (lb) 0 0 J511 (lb) 600 545 D206 (gal) 2 2 M002 0.5 0.4 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown d ata and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's be st estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 5,770 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Summary On February 10, 2024, SLB successfully performed a hydraulic fracturing treatment on Stages 4-7 of NDBi-044. According to the initial plan called for the completion of stages 4-7, there was change of Resume Pad step volumes before pumping started: for Stage 5 (from 61bbl to 91bbl), for Stage 6 (from 69bbl to 99bbl), and Stage 7 (from 40bbl to 70bbl). While pumping stage 6 the crew encountered an issue to offload the J580 gel from the ABT unit to the PCM. SLB immediately informed Santos Representatives, and option were to resolve the issue and reload before the spacer step between stage 6 and 7 or shutdown for that purpose as there was not enough J580 gel in the PCM hopper to complete the job. Decision was made to launch the Ball/Collet #7, pump flush and shutdown unit the issue could be resolved. After the issue was resolved, stage 7 was pumped successfully, and the Ball/Collet#8 launched. The Ball/Collet#8 was seated successfully followed by Freeze Protect.Postshutdownpressure decline wasmonitored for 60 min. By FracCAT totals, a total of 920,541pounds of proppant was pumped and 920,541 was placed into formation in 8,252.2 bbl of slurry. Please note, that proppant Volumes for 16/20 Carbolite are as per densitometer and not physical strap due to split loads, and for 40/70 Carbolite as per BOL weight (16,000lbs). Stage 4 consisted of a PAD, and 8 proppant steps from 1-8 PPA, Stages 5 through 6 consisted of a PAD, and 6 proppant steps from 1-10 PPA and Stage 7 consisted of a PAD, two Scour steps 1-3PPA with proppant 20/40 CBL, and 6 proppant steps from 1-10 PPA. Pump trips were staggered from 7,600 to 8,000 psi. The GORV was set to 8,300 psi. The highlight of the stages was that the collet launch sequence greatly improved with the addition of a second line going to the wellhead. Summary of Stages 4-7 Material Actual Design Slurry Volume (bbl)8,252 7,742 Clean Fluid Volume(bbl) 7,236 6,720 Proppant (lb) 920,541 914,338 16:00:42 17:24:02 18:47:22 20:10:42 21:34:02 22:57:22 Time - hh:mm:ss 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 0 5 10 15 20 25 30 35 40 45 50 0 2 4 6 8 10 12 14 16 18 20 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT* Santos NDBi-044 02-10-2024 Stage4 Stage5 Stage7 Stage6Displ PT Ball to Seat Pump Check Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check. Stage included PT displacement, pumping Ball#4 to seat and pump check that was placed in the schedule to test the equipment and ensure the pumps were job ready. After step Pump Check was pumped, then moved to pumping Stage#4 without shutdown. A summary of the stage and pressures as follows: Summary of Stage Displacement PT, Ball to Seat and Pump Check Total Proppant Pumped (lb)0 Max pumping Rate (bpm)43.0 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)11.8 Total Slurry Pumped (bbl)341.4 Maximum Treating Pressure (psi)3,905 YF125ST Pumped (bbl)0 Average Treating Pressure (psi)1,522 WF125 Pumped (bbl)341.4 Average Water Temperature (F)97.7 Average Viscosity (cP)19.0 15:36:14 15:56:14 16:16:14 16:36:14 16:56:14 17:16:14 17:36:14 17:56:14 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 2 4 6 8 10 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT* SantosNDBi-04402-10-2024 PT Displacement Pumping Ball to Seat Pump Check Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT 69.1 3.4 20.4 WF125 2900 0.0 0.0 0 2 Shut Down - - - - - - - - 3 Ball#4 to Seat 175.3 3.9 44.5 WF125 7363 0.0 0.0 0 4 Pump Check 97.0 32.8 3.5 WF125 4074 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT 3.4 4.0 751 985 304 2 Shut Down 3.4 2.3 751 701 249 3 Ball#4 to Seat 3.9 5.8 1003 1181 240 4 Pump Check 32.8 43.0 3028 3905 1170 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 4 The treating pressure on PAD was around 3,430 psi and slowly fell to about 2,850 psi when 1PPA was going into the formation. At this point, the treating pressure was gradually increasing from 2,850 to 5,885 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#5 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #4 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,700 2,233 1,720 Bottomhole Pressure 3,000 3,377 3,022 Summary of Stage 4 Total Proppant Pumped (lb)227,237 Max pumping Rate (bpm)40.1 Total Proppant in Formation (lb)227,237 Average Pumping Rate (bpm)40.0 Total Slurry Pumped (bbl)1,892.4 Maximum Treating Pressure (psi)5,421 YF125ST Pumped (bbl)1,652.3 Average Treating Pressure (psi)3,394 WF125 Pumped (bbl)0 Average Water Temperature (F)90.5 Average Viscosity (cP)18.4 17:46:14 17:55:24 18:04:34 18:13:44 18:22:54 18:32:04 18:41:14 18:50:24 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-4 FracCAT* SantosNDBi-04402-10-2024 Collet/Ball#5 hit the sleeveDrop Rate for Ball/Collet#5 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st4 350.0 40.0 8.7 YF125ST 14700 0.0 0.0 0 2 1.0 PPA 180.0 40.0 4.5 YF125ST 7256 CarboLite 16/20 1.0 0.9 6844 3 2.0 PPA 180.0 40.0 4.5 YF125ST 6958 CarboLite 16/20 2.1 2.0 13593 4 3.0 PPA 200.1 40.0 5.0 YF125ST 7427 CarboLite 16/20 3.1 3.0 21955 5 4.0 PPA 200.1 40.0 5.0 YF125ST 7148 CarboLite 16/20 4.2 4.0 28271 6 5.0 PPA 200.1 40.0 5.0 YF125ST 6891 CarboLite 16/20 5.2 4.9 34092 7 6.0 PPA 200.1 40.0 5.0 YF125ST 6646 CarboLite 16/20 6.2 6.0 39612 8 7.0 PPA 180.1 40.0 4.5 YF125ST 5784 CarboLite 16/20 7.2 6.9 40120 9 8.0 PPA 173.9 40.0 4.4 YF125ST 5416 CarboLite 16/20 8.3 7.9 42556 10 Clean line & Spacer 25.0 40.0 0.6 YF125ST 1044 CarboLite 16/20 7.1 0.2 194 11 Drop Collet#5 3.0 40.0 0.1 YF125ST 126 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st4 40.0 40.0 3393 3448 3291 2 1.0 PPA 40.0 40.1 3100 3290 2997 3 2.0 PPA 40.0 40.0 2916 2998 2872 4 3.0 PPA 40.0 40.0 2881 2917 2847 5 4.0 PPA 40.0 40.0 2960 2990 2915 6 5.0 PPA 40.0 40.0 3108 3241 2990 7 6.0 PPA 40.0 40.0 3440 3647 3238 8 7.0 PPA 40.0 40.0 3942 4234 3653 9 8.0 PPA 40.0 40.0 4850 5092 4243 10 Clean line & Spacer 40.0 40.0 5233 5336 5092 11 Drop Collet#5 40.0 40.0 5390 5421 5338 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 5 Once the Collet/Ball#5 hit the sleeve the pressure transition from Stage 4 to 5 was typical. Treating pressure on PAD was around 4,450 psi and slowly fell to about 2,610 psi when 1PPA was going into the formation. When 2 PPA started going into the formation the treating pressure was gradually increasing from 2,816 to 5,750 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#6 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #5 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,904 2,960 1,973 Bottomhole Pressure 3,000 3,686 3,042 Summary of Stage 5 Total Proppant Pumped (lb) 224,950 Max pumping Rate (bpm) 41.5 Total Proppant in Formation (lb) 224,950 Average Pumping Rate (bpm) 38.9 Total Slurry Pumped (bbl) 1,691.9 Maximum Treating Pressure (psi) 5,770 YF125ST Pumped (bbl) 1,454.2 Average Treating Pressure (psi) 3,685 WF125 Pumped (bbl) 0 Average Water Temperature (F) 91.1 Average Viscosity (cP)18.9 18:49:05 18:57:25 19:05:45 19:14:05 19:22:25 19:30:45 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-5FracCAT* Santos NDBi-044 02-10-2024 Collet/Ball#5 hit the sleeve. Drop Rate for Ball/Collet#6 Collet/Ball#6 hit the sleeve. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st5 204.4 39.6 5.3 YF125ST 8584 0.0 0.0 0 2 Slow For Seat 45.8 17.1 2.7 YF125ST 1922 0.0 0.0 0 3 Resume Pad 87.2 37.3 2.4 YF125ST 3663 0.0 0.0 0 4 1.0 PPA 180.0 39.6 4.5 YF125ST 7242 CarboLite 16/20 1.0 1.0 7141 5 2.0 PPA 220.0 39.7 5.6 YF125ST 8475 CarboLite 16/20 2.1 2.0 17259 6 4.0 PPA 240.1 39.7 6.1 YF125ST 8507 CarboLite 16/20 4.3 4.2 35495 7 6.0 PPA 240.2 39.7 6.1 YF125ST 7991 CarboLite 16/20 6.2 5.9 47244 8 8.0 PPA 240.2 39.5 6.1 YF125ST 7465 CarboLite 16/20 8.2 7.9 59118 9 10.0 PPA 211.7 39.6 5.4 YF125ST 6294 CarboLite 16/20 10.5 9.4 58676 10 Clean line & Spacer 19.3 41.3 0.5 YF125ST 808 CarboLite 16/20 0.6 0.0 17 11 Drop Collet#6 3.0 41.0 0.1 YF125ST 126 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st5 39.6 40.0 4454 5421 1396 2 Slow For Seat 17.1 17.4 1985 2540 1716 3 Resume Pad 37.3 40.9 2782 2921 1986 4 1.0 PPA 39.6 40.3 2768 2831 2704 5 2.0 PPA 39.7 40.4 2670 2751 2620 6 4.0 PPA 39.7 40.4 3106 3536 2753 7 6.0 PPA 39.7 40.4 3578 3675 3475 8 8.0 PPA 39.5 39.9 4340 4965 3609 9 10.0 PPA 39.6 40.9 5343 5770 4966 10 Clean line & Spacer 41.3 41.5 5644 5770 5503 11 Drop Collet#6 41.0 41.0 5504 5511 5503 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 6 Once the Collet/Ball#6 hit the sleeve the pressure transition from Stage 5 to 6 was typical. Treating pressure on PAD was around 4,200 psi and stayed stable until 4PPA hit the formation, then the treating pressure was gradually increasing from 2,690 to 5,620 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#7 to seat. While pumping stage 6 the crew encounter with the issue to offload the gel from ABT unit to PCM. The cause was found to be the product hose was plugged with J580 preventing further product to be loaded to the PCM J580 gel hopper. SLB immediately informed Santos Representatives, and option were to resolve the issue and reload before the spacer step between stage 6 and 7 or shut down for that purpose as there was not enough J580 gel in the PCM hopper to complete the job. Decision was made to launch the Ball/Collet #7, pump flush and shutdown unit the issue could be resolved. A summary of the Stage and its measured pump schedule is below: Summary of Stage 6 Total Proppant Pumped (lb) 223,569 Max pumping Rate (bpm) 42.4 Total Proppant in Formation (lb) 223,569 Average Pumping Rate (bpm) 38.8 Total Slurry Pumped (bbl) 1,942.7 Maximum Treating Pressure (psi) 5,672 YF125ST Pumped (bbl) 1,473.1 Average Treating Pressure (psi) 3,457 WF125 Pumped (bbl) 233.4 Average Water Temperature (F) 89.7 Average Viscosity (cP)18.9 19:32:47 19:44:27 19:56:07 20:07:47 20:19:27 20:31:07 20:42:47 20:54:27 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-6FracCAT* Santos NDBi-044 02-10-2024 Collet/Ball#6 hit the sleeve. Drop Rate for Ball/Collet#7 Collet/Ball#7 hit the sleeve. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st6 194.3 39.1 5 YF125ST 8165 0 0 0 2 Slow For Seat 50 16.8 3 YF125ST 2102 0 0 0 3 Resume Pad 101.2 34.3 3.3 YF125ST 4244 0 0 0 4 1.0 PPA 180 39.9 4.5 YF125ST 7248 CarboLite 16/20 1 1 6986 5 2.0 PPA 220 39.9 5.5 YF125ST 8511 CarboLite 16/20 2 1.9 16438 6 4.0 PPA 240.1 39.9 6 YF125ST 8615 CarboLite 16/20 3.9 3.8 33071 7 6.0 PPA 240.2 39.8 6 YF125ST 8005 CarboLite 16/20 6 5.9 46926 8 8.0 PPA 240.2 39.8 6 YF125ST 7478 CarboLite 16/20 8.1 7.9 58825 9 10.0 PPA 219.5 39.8 5.5 YF125ST 6503 CarboLite 16/20 10.4 9.5 61315 10 Clean line & Spacer 20.8 41.7 0.5 YF125ST 874 CarboLite 16/20 0.3 0 8 11 Drop Collet#7 3 40.1 0.1 YF125ST 126 0 0 0 12 Flush WF 179.30 39.9 4.5 WF125 7528 0 0 0 13 Slow For Seat 54.10 18.5 3.2 WF125 2273 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st6 39.1 41.0 4215 5524 1435 2 Slow For Seat 16.8 20.5 1968 2612 1767 3 Resume Pad 34.3 40.9 2558 2710 1977 4 1.0 PPA 39.9 40.4 2682 2731 2627 5 2.0 PPA 39.9 40.2 2597 2662 2567 6 4.0 PPA 39.9 40.1 2605 2702 2550 7 6.0 PPA 39.8 40.1 3000 3540 2702 8 8.0 PPA 39.8 40.3 4363 5042 3547 9 10.0 PPA 39.8 40.7 5261 5476 5043 10 Clean line & Spacer 41.7 42.4 5455 5672 5144 11 Drop Collet#7 40.1 40.3 5171 5186 5150 12 Flush WF 39.9 40.3 4279 5190 2330 13 Slow For Seat 18.5 39.2 1663 2152 221 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 7 Once the Collet/Ball#7 hit the sleeve the pressure transition from Stage 6 to 7 was typical. Treating pressure on PAD was around 2,780 psi and slowly fell to about 2,365 psi after 1PPA Scour passed through the frac port. When 2 PPA started going into the formation the treating pressure was gradually increasing from 2,450 to 5,557 psi. The Collet/Ball#8 was launched, successfully seated, and followed by a pumping Freeze Protect and hard shutdown with an ISIP of 953 psi and recording of pressure decline for 60 mins. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #7 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,640 2,356 1,640 Bottomhole Pressure 2,950 3,450 2,940 Summary of Stage 7 Total Proppant Pumped (lb) 244,785 Max pumping Rate (bpm) 42.0 Total Proppant in Formation (lb) 244,785 Average Pumping Rate (bpm) 38.3 Total Slurry Pumped (bbl) 2,383.8 Maximum Treating Pressure (psi) 5,568 YF125ST Pumped (bbl) 1,692.6 Average Treating Pressure (psi) 3,205 WF125 Pumped (bbl) 389.3 Average Water Temperature (F) 94.5 Average Viscosity (cP) 17.4 20:52:47 21:04:27 21:16:07 21:27:47 21:39:27 21:51:07 22:02:47 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con St-7FracCAT* Santos NDBi-04402-10-2024 Collet/Ball#8 hit the sleeve. Drop Rate for Ball/Collet#8 Suction loss from Frac Tank Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st7 275.2 37.2 8.1 YF125ST 11555 0 0 0 2 1.0PPA Scour 50.0 39.6 1.3 YF125ST 2029 CarboLite 40/70 1.1 0.8 1466 3 3.0PPA Scour 154.4 40.1 3.9 YF125ST 5777 CarboLite 40/70 3.1 2.7 14497 4 Spacer 99.8 40.2 2.5 YF125ST 4189 CarboLite 40/70 1 0 37 5 1.0 PPA 180.1 39.9 4.5 YF125ST 7259 CarboLite 16/20 1.2 0.9 6882 6 2.0 PPA 220.0 39.9 5.5 YF125ST 8503 CarboLite 16/20 2 2 16733 7 4.0 PPA 240.0 40.1 6 YF125ST 8586 CarboLite 16/20 4.1 3.9 33877 8 6.0 PPA 240.2 39.9 6 YF125ST 7986 CarboLite 16/20 6.1 5.9 47581 9 8.0 PPA 240.2 39.9 6 YF125ST 7461 CarboLite 16/20 8.2 7.9 59509 10 10.0 PPA 225.9 39.8 5.7 YF125ST 6663 CarboLite 16/20 10.3 9.6 64193 11 Clean line & Spacer 22.8 41.3 0.6 YF125ST 955 CarboLite 16/20 0.5 0 10 12 Drop Collet#8 3 40.8 0.1 YF125ST 126 0 0 0 13 WF Flush 168.7 39.3 4.3 WF125 7084 0 0 0 14 Slow For Seat 50.5 17.9 3 WF125 2119 0 0 0 15 Overflush 170.2 37.6 4.7 WF125 7146 0 0 0 16 Freeze Protect 42.8 20.3 2.1 Freeze Protect 1811 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st7 37.2 40.6 2778 3461 219 2 1.0PPA Scour 39.6 40.4 2647 2727 2543 3 3.0PPA Scour 40.1 40.5 2696 2763 2601 4 Spacer 40.2 40.6 2620 2656 2575 5 1.0 PPA 39.9 40.2 2455 2574 2370 6 2.0 PPA 39.9 40.3 2402 2465 2369 7 4.0 PPA 40.1 40.4 2563 2744 2465 8 6.0 PPA 39.9 40.1 3055 3553 2739 9 8.0 PPA 39.9 40.5 4270 4854 3555 10 10.0 PPA 39.8 40.2 5098 5384 4855 11 Clean line & Spacer 41.3 42.0 5443 5568 5168 12 Drop Collet#8 40.8 41.1 5136 5167 5091 13 WF Flush 39.3 40.2 4163 5042 2420 14 Slow For Seat 17.9 38.7 1615 2072 1544 15 Overflush 37.6 40.1 2742 2960 1653 16 Freeze Protect 20.3 20.8 1728 1898 812 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:22:48 Starter fixed. Warming up POD -0 163 0.0 0.0 0.0 2 13:38:23 Giving Blender Pressure 1 163 0.0 0.0 0.0 3 13:43:39 Priming Pumps With Diesel 44 163 0.0 5.4 0.0 4 14:11:06 Low Pressure test 221 162 0.0 0.0 0.0 5 14:16:45 High Pressure Test 9178 162 0.0 0.0 0.0 6 14:20:28 Bleeding off the pressure. PT passed 1934 163 0.0 0.0 0.0 7 14:33:41 Safety meeting 1065 162 0.0 0.0 0.0 8 15:03:23 Finished meeting 478 162 0.0 0.0 0.0 9 15:04:08 Final equipment checks 470 162 0.0 0.0 0.0 10 15:05:59 Loading the ball 452 162 0.0 0.0 0.0 11 15:06:11 Mixing 25 gel 450 162 0.0 0.0 0.0 12 16:06:57 Radio Check 155 3211 0.0 0.0 0.0 13 16:10:03 Equalize To Well Pressure 150 3207 0.0 0.0 0.0 14 16:11:39 Open Well 310 3190 0.0 0.0 0.0 15 16:12:02 Start Displ PT Automatically 310 3205 0.0 0.0 0.0 16 16:12:02 Start Propped Frac Automatically 310 3205 0.0 0.0 0.0 17 16:12:02 Start Displacement Automatically 310 3205 0.0 0.0 0.0 18 16:12:18 Started Pumping 305 3204 0.0 0.0 0.0 19 16:33:07 Stopped Pumping 669 3218 69.1 0.0 0.0 20 16:46:00 Started Pumping 249 3229 69.1 0.0 0.0 21 16:46:01 Start Shut Down Automatically 248 3229 69.1 0.0 0.0 22 16:46:16 Start Displ PT Manually 248 3229 69.1 0.0 0.0 23 16:49:11 Stopped Pumping 646 3249 75.2 0.0 0.0 24 17:08:55 Started Pumping 241 3233 75.2 0.0 0.0 25 17:08:59 Start Ball to Seat Manually 241 3233 75.2 0.0 0.0 26 17:52:07 Ball & Collet Seated 1044 3387 242.1 4.0 0.0 27 17:52:38 Start Pump Check Manually 1314 3402 244.5 5.8 0.0 28 17:53:19 Stage at Perfs: Displ PT 1934 3435 257.1 14.5 0.0 Stage 4 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 17:56:05 Start PAD st4 Manually 3352 3440 342.0 39.9 0.0 2 17:56:05 Start Propped Frac Manually 3352 3440 342.0 39.9 0.0 3 17:56:05 Start Stage 4 Automatically 3352 3440 342.0 39.9 0.0 4 18:00:05 Stage at Perfs: Ball to Seat 3431 3458 160.0 40.0 0.0 5 18:02:31 Stage at Perfs: PAD st4 3405 3482 257.4 40.0 0.0 6 18:04:50 Start 1.0 PPA Automatically 3290 3414 350.1 40.0 0.0 7 18:04:50 Started Pumping Prop 3290 3414 350.1 40.0 0.0 8 18:09:20 Start 2.0 PPA Automatically 3001 3421 530.1 40.0 1.0 9 18:11:15 Stage at Perfs: 1.0 PPA 2914 3465 606.8 40.0 1.9 10 18:13:50 Start 3.0 PPA Automatically 2876 3440 710.2 40.0 2.0 11 18:15:45 Stage at Perfs: 2.0 PPA 2855 3478 786.9 40.0 3.0 12 18:18:50 Start 4.0 PPA Automatically 2912 3415 910.3 40.0 3.0 13 18:20:15 Stage at Perfs: 3.0 PPA 2926 3443 966.9 40.0 4.1 14 18:23:50 Start 5.0 PPA Automatically 3001 3437 1110.3 40.0 4.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 15 18:25:15 Stage at Perfs: 4.0 PPA 3048 3449 1167.0 40.0 4.9 16 18:28:50 Start 6.0 PPA Automatically 3241 3480 1310.3 40.0 5.1 17 18:30:15 Stage at Perfs: 5.0 PPA 3376 3436 1367.0 40.0 5.9 18 18:33:51 Start 7.0 PPA Automatically 3653 3467 1511.1 40.1 6.1 19 18:35:15 Stage at Perfs: 6.0 PPA 3847 3483 1567.1 40.0 6.9 20 18:38:21 Start 8.0 PPA Automatically 4243 3452 1691.1 40.0 6.9 21 18:40:16 Stage at Perfs: 7.0 PPA 4681 3462 1767.7 40.0 7.9 22 18:42:31 Start Clean line & Spacer Manually 5089 3468 1857.7 40.0 7.8 23 18:42:34 Start 8.0 PPA Manually 5089 3469 1859.7 40.0 7.8 24 18:42:41 Start Clean line & Spacer Manually 5099 3468 1864.4 40.0 1.8 25 18:42:52 Stopped Pumping Prop 5239 3470 1871.7 40.0 0.0 26 18:43:19 Start Drop Collet#5 Automatically 5463 3482 1889.7 40.0 0.0 Stage 5 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 18:43:24 Start PAD st5 Automatically 5393 3479 0.0 39.9 0.0 2 18:43:24 Start Propped Frac Automatically 5393 3479 0.0 39.9 0.0 3 18:43:24 Start Stage 5 Automatically 5393 3479 0.0 39.9 0.0 4 18:44:46 Stage at Perfs: 8.0 PPA 5015 3442 54.7 40.0 0.0 5 18:48:39 Start Slow For Seat Automatically 1634 3360 203.5 17.0 0.0 6 18:49:41 Stage at Perfs: Clean line &Spacer 1914 3367 221.0 17.0 0.0 7 18:49:49 Stage at Perfs: 8.0 PPA 1919 3371 223.3 16.9 0.0 8 18:50:05 Stage at Perfs: Clean line &Spacer 1929 3375 227.8 17.0 0.0 9 18:50:18 Ball & Collet Seated 2173 3379 231.5 17.1 0.0 10 18:51:19 Start Resume Pad Manually 1992 3377 249.1 17.4 0.0 11 18:51:33 Stage at Perfs: 8.0 PPA 2873 3396 253.3 20.1 0.0 12 18:51:41 Stage at Perfs: Clean line & Spacer 2769 3411 256.5 28.6 0.0 13 18:53:44 Deactivated Extend Stage 2829 3425 336.7 40.1 0.0 14 18:53:44 Start 1.0 PPA Manually 2829 3425 336.7 40.1 0.0 15 18:53:44 Started Pumping Prop 2829 3425 336.7 40.1 0.0 16 18:56:38 Stage at Perfs: Drop Collet#5 2776 3458 451.2 40.2 1.0 17 18:57:47 Stage at Perfs: PAD st5 2732 3469 496.9 40.0 1.0 18 18:58:17 Start 2.0 PPA Automatically 2708 3473 517.0 40.5 1.0 19 18:59:59 Stage at Perfs: Slow For Seat 2629 3427 584.2 39.4 2.1 20 19:03:50 Start 4.0 PPA Automatically 2756 3485 737.0 40.2 2.1 21 19:04:32 Stage at Perfs: Resume Pad 2845 3496 764.7 39.2 4.2 22 19:09:53 Start 6.0 PPA Automatically 3518 3446 976.9 39.6 4.0 23 19:10:05 Stage at Perfs: 1.0 PPA 3557 3450 984.8 39.4 5.4 24 19:15:57 Start 8.0 PPA Automatically 3613 3408 1217.6 39.6 6.0 25 19:16:07 Stage at Perfs: 2.0 PPA 3636 3406 1224.2 39.5 6.8 26 19:22:01 Start 10.0 PPA Automatically 5004 3423 1457.3 39.7 8.0 27 19:22:13 Stage at Perfs: 4.0 PPA 5013 3425 1465.3 39.8 9.2 28 19:27:22 Start Clean line &Spacer Manually 5764 3439 1669.0 41.1 0.2 29 19:27:25 Stopped Pumping Prop 5723 3441 1671.1 41.2 0.2 30 19:27:50 Start Drop Collet#6 Manually 5523 3439 1688.3 40.8 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 6 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 19:27:55 Start PAD st6 Automatically 5565 3441 0.0 40.8 0.0 2 19:27:55 Start Propped Frac Automatically 5565 3441 0.0 40.8 0.0 3 19:27:55 Start Stage 6 Automatically 5565 3441 0.0 40.8 0.0 4 19:28:15 Stage at Perfs: 6.0 PPA 5316 3437 13.5 40.2 0.0 5 19:32:56 Start Slow For Seat Manually 1808 3415 193.6 19.4 0.0 6 19:34:46 Stage at Perfs: 8.0 PPA 1949 3425 224.5 16.5 0.0 7 19:35:18 Ball & Collet Seated 1926 3430 233.2 16.4 0.0 8 19:35:56 Stage at Perfs: 10.0 PPA 2062 3436 243.6 16.5 0.0 9 19:35:56 Start Resume Pad Automatically 2062 3436 243.6 16.5 0.0 10 19:36:09 Stage at Perfs: Clean line & Spacer 2071 3442 247.2 16.4 0.0 11 19:39:12 Start 1.0 PPA Manually 2702 3487 345.1 40.0 0.0 12 19:39:12 Started Pumping Prop 2702 3487 345.1 40.0 0.0 13 19:41:25 Stage at Perfs: Drop Collet#6 2716 3411 433.2 39.9 1.0 14 19:42:40 Stage at Perfs: PAD st6 2651 3433 483.2 40.0 1.0 15 19:43:43 Start 2.0 PPA Automatically 2638 3435 525.2 40.0 1.0 16 19:45:12 Stage at Perfs: SlowForSeat 2588 3433 584.4 40.1 2.0 17 19:49:14 Start 4.0 PPA Automatically 2606 3434 745.4 39.9 2.0 18 19:49:43 Stage at Perfs: Resume Pad 2635 3437 764.7 40.1 3.9 19 19:55:14 Stage at Perfs: 1.0 PPA 2704 3442 984.6 39.8 3.9 20 19:55:15 Start 6.0 PPA Automatically 2708 3440 985.3 39.8 3.9 21 20:01:16 Stage at Perfs: 2.0 PPA 3551 3457 1224.5 39.6 5.9 22 20:01:18 Start 8.0 PPA Automatically 3571 3455 1225.8 39.8 5.9 23 20:07:19 Stage at Perfs: 4.0 PPA 5065 3472 1465.1 40.3 7.9 24 20:07:20 Start 10.0 PPA Automatically 5067 3473 1465.8 40.1 7.9 27 20:12:51 Start Clean line & Spacer Manually 5650 3473 1685.1 41.2 0.1 28 20:12:55 Stopped Pumping Prop 5682 3479 1687.9 41.9 0.0 29 20:13:20 Stage at Perfs: 6.0 PPA 5188 3466 1705.3 40.0 0.0 30 20:13:21 Start Drop Collet#7 Manually 5198 3464 1705.9 39.9 0.0 31 20:13:26 Start PAD s7 Automatically 5212 3465 0.0 39.8 0.0 32 20:13:26 Start Propped Frac Automatically 5212 3465 0.0 39.8 0.0 33 20:13:26 Start Stage 7 Automatically 5212 3465 0.0 39.8 0.0 34 20:17:55 Start Slow For Seat Manually 1219 3380 178.8 32.0 0.0 35 20:19:55 Ball & Collet Seated 2187 3450 214.3 17.2 0.0 36 20:19:57 Stage at Perfs: 8.0 PPA 2123 3384 214.9 17.0 0.0 37 20:21:04 Stopped Pumping 881 3381 232.4 2.6 0.0 Stage 7 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 20:58:04 Started Pumping 218 3184 232.4 0.0 0.0 2 20:58:10 Start Resume Pad Automatically 220 3212 232.4 0.0 0.0 3 20:59:10 Stage at Perfs: 10.0 PPA 3153 3421 235.8 22.4 0.0 4 20:59:18 Stage at Perfs: Clean line & Spacer 2934 3412 239.4 30.2 0.0 5 21:03:37 Stage at Perfs: Drop Collet#7 2391 3423 407.9 34.1 0.0 6 21:05:12 Stage at Perfs: PAD s7 2222 3453 461.9 34.1 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 7 21:06:28 Start 1.0PPA Scour Manually 2655 3492 508.2 40.1 0.0 8 21:06:28 Started Pumping Prop 2655 3492 508.2 40.1 0.0 9 21:07:44 Start 3.0PPA Scour Automatically 2727 3445 558.3 40.0 1.0 10 21:11:35 Start Spacer Manually 2623 3441 712.6 39.8 0.4 11 21:11:40 Stopped Pumping Prop 2588 3439 715.9 39.9 0.1 12 21:12:12 Stage at Perfs: Slow For Seat 2652 3445 737.4 40.7 0.0 13 21:13:27 Stage at Perfs: Resume Pad 2595 3452 787.6 40.1 0.0 14 21:14:04 Start 1.0 PPA Manually 2562 3458 812.4 40.1 0.0 15 21:14:13 Started Pumping Prop 2561 3459 818.4 39.8 0.0 16 21:17:18 Stage at Perfs: 1.0PPA Scour 2369 3477 941.3 40.0 1.0 17 21:18:35 Start 2.0 PPA Automatically 2375 3482 992.7 40.1 1.0 18 21:19:48 Stage at Perfs: 3.0PPA Scour 2375 3485 1041.3 40.0 2.0 19 21:24:06 Start 4.0 PPA Automatically 2464 3418 1212.8 39.9 2.0 20 21:24:19 Stage at Perfs: Spacer 2481 3412 1221.4 39.7 3.3 21 21:29:49 Stage at Perfs: 1.0 PPA 2719 3382 1441.8 40.1 4.0 22 21:30:06 Start 6.0 PPA Automatically 2741 3385 1453.2 40.0 4.0 23 21:35:50 Stage at Perfs: 2.0 PPA 3514 3356 1681.8 39.7 6.0 24 21:36:07 Start 8.0 PPA Automatically 3565 3357 1693.1 39.7 5.9 25 21:41:51 Stage at Perfs: 4.0 PPA 4844 3376 1921.8 39.9 8.1 26 21:42:08 Start 10.0 PPA Automatically 4890 3380 1933.0 39.7 8.1 27 21:47:48 Start Clean line & Spacer Manually 5458 3389 2158.8 40.1 0.1 28 21:47:52 Stopped Pumping Prop 5574 3393 2161.5 40.6 0.0 29 21:47:53 Stage at Perfs: 6.0 PPA 5554 3389 2162.1 40.7 0.0 30 21:48:21 Start Drop Collet#8 Manually 5076 3386 2181.5 40.4 0.0 31 21:48:26 Start WF Flush Automatically 4975 3385 2184.9 39.9 0.0 32 21:52:43 Start Slow For Seat Manually 1231 3319 2353.1 32.9 0.0 33 21:54:44 Stage at Perfs: 8.0 PPA 1491 3336 2387.2 15.8 0.0 34 21:54:46 Ball & Collet Seated 1782 3363 2387.7 15.8 0.0 35 21:55:45 Start Overflush Manually 2307 3392 2403.3 18.6 0.0 36 21:56:01 Stage at Perfs: 10.0 PPA 2581 3397 2410.5 30.5 0.0 37 21:56:07 Stage at Perfs: Clean line & Spacer 2657 3393 2413.8 34.9 0.0 38 22:00:25 Start Freeze Protect Manually 1665 3419 2573.5 20.8 0.0 39 22:00:49 Stage at Perfs: WF Flush 1665 3420 2581.6 20.3 0.0 40 22:02:34 Stopped Pumping 1248 3407 2616.3 0.0 0.0 41 22:04:13 Close Well 959 3381 2616.3 0.0 0.0 42 22:06:36 Fanning Pumps, Cleaning the line and equipment 7 3363 2616.3 4.7 0.0 FracCAT Treatment Report Well : NDBi-044 Field : Pikka Formation : Nanushuk Well Location : County : North Slope State : Alaska Country : United States Prepared for Client : Santos Client Rep : Scott Leahy Date Prepared : February 16, 2024 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630-780-0058 Pressure (All Zones) Initial Wellhead Pressure (psi) 292 Initial BHP at Gauge (psi) - Final Surface ISIP (psi) 1,078 Final ISIP at Gauge (psi) 2,629 Surface Shut in Pressure(psi) 2,106 BH Shut in Pressure (psi) 2,119 Maximum Treating Pressure (psi) 8,153 BH Gauge at 10,747 ft MD, 4,030 ft TVD Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)7,736.8 Total Proppant Pumped (lb) (per Load Tickets)951,448 Total YF125ST Past Wellhead (bbl) 5,895.7 Total Proppant in Formation (lb) 951,448 Total WF125 Past Wellhead (bbl) 838.5 Total Freeze Protect Past Wellhead (bbl) 46.4 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH F103 (gal) 284 284 M275 (lb) 96 94.6 J450 (gal) 183 183 J753 (gal) 17.4 15.7 J580 (lb) 7,380 7,265 J475 (lb) 1677.5 1677.5 J532 (gal) 646 646 J134 (lb) 11 0 J511 (lb) 500 482 D206 (gal) 3 3 M002 0.5 0.48 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown d ata and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's be st estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Summary On February 15, 2024, SLB successfully performed a hydraulic fracturing treatment on Stages 8-11 of NDBi-044. According to the initial plan called for the completion of stages 8-11, there was change of PAD step volume for stage 8 (from 350bbl to 380bbl) and Resume Pad step volume for Stage 9 (from 135bbl to 165bbl) before pumping started. When started pumping Displacement PT step there was an accidental well shut in, GORV popped off. The pumping was continued after GORV was rebuilt and the incident was investigated. When Ball/Collet#10 was seated successfully then moved to DFIT step and hard shutdown followed by monitor pressure decline. Before resuming pumping, there was change of Resume Pad step volume for Stage 11 (from 77bbl to 202bbl, during pumping step volume was changed again from 202bbl to 152bbl), step 1PPA slurry volume (from 150bbl to 180bbl), step 3PPA slurry volume (from 200bbl to220bbl), step 5PPA slurry volume (from 240bbl to 260bbl), step 7PPA slurry volume (from 215bbl to230bbl), step 10PPA slurry volume (from 190bbl to200bbl) to pump all proppant from the Sandchiefs. Once stage 11 was completed successfully it was followed by hard shutdown. Post shutdown pressure decline was monitored for 60 min. By BOL Physical count, a total of 951,448 pounds of proppant was pumped and 951,448 lbs were placed into formation in 7,734 bbl of slurry. Please note, that proppant Volumes are as per BOL physical weight count. Stages 8, 9 and 10 consisted of a PAD, and 6 proppant steps from 1-2-4-6-8-10 PPA, Stages 11 consisted of a PAD, and 6 proppant steps from 1-3-5-7-9-10 PPA. Pump trips were staggered from 7,600 to 8,000 psi. The GORV was set to 8,300 psi. The highlight of the stages was that the collet launch sequence greatly improved with the addition of a second line going to the wellhead. Summary of Stages 8-11 Material Actual Design Slurry Volume (bbl)7,737 7,827 Clean Fluid Volume(bbl) 6,734 6,786 Proppant (lb) 951,448 932,277 08:45:20 10:17:00 11:48:40 13:20:20 14:52:00 16:23:40 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 10 20 30 40 50 0 2 4 6 8 10 12 14 16 18 20 22 24 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 02-15-2024 Stage8 Stage9 Stage11Stage10 Displ PT Ball to Seat Pump Check Displ PT Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check. Stage included PT displacement, pumping Ball#8 to seat and pump check that was placed in the schedule to test the equipment and ensure the pumps were job ready. After step Pump Check was pumped, then moved to pumping Stage#8 without shutdown. A summary of the stage and pressures as follows: Summary of Stage Displacement PT, Ball to Seat and Pump Check Total Proppant Pumped (lb)0 Max pumping Rate (bpm)40.0 Total Proppant in Formation (lb)0 Average Pumping Rate (bpm)8.6 Total Slurry Pumped (bbl)270.6 Maximum Treating Pressure (psi)8,153 YF125ST Pumped (bbl)0 Average Treating Pressure (psi)1,483 WF125 Pumped (bbl)270.6 Average Water Temperature (F)95.1 Average Viscosity (cP)19.0 08:09:13 08:42:33 09:15:53 09:49:13 10:22:33 10:55:53 11:29:13 12:02:33 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 10 20 30 40 50 0 5 10 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-43 08-26-2023 PT Displacement Pumping Ball to Seat Pump Check PT Displacement Pressure Test Accidental master valve shut in Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displ PT(1)26.5 3.4 8 WF125 1114 0 0 0 2 Displ PT (2)40 3.4 11.9 WF125 1678 0 0 0 3 Shut Down 4 Ball to Seat 154.7 4 38.8 WF125 6497 0 0 0 5 Pump Check 49.4 31.4 1.8 WF125 2076 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displ PT (1) 3.4 0.0 1199 8153 8152 2 Displ PT (2) 3.4 3.9 1132 8153 294 3 Shut Down 3.4 3.9 1132 8153 294 4 Ball to Seat 4.0 4.2 1131 1176 688 5 Pump Check 31.4 40.0 3098 3651 1118 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 8 Before the job was started, Santos changed PAD volume from 350bbl to 380bbl. The treating pressure on PAD was around 3,200 psi and slowly fell to about 2,580 psi when 1PPA was going into the formation. When 2PPA was going into formation the treating pressure was gradually increasing from 2,580 to 5,160 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#9 to seat. A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #8 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,564 2,360 1,564 Bottomhole Pressure 2,898 3,310 2,869 Summary of Stage 8 Total Proppant Pumped (lb) 242,605 Max pumping Rate (bpm)42.1 Total Proppant in Formation (lb) 242,605 Average Pumping Rate (bpm)40.0 Total Slurry Pumped (bbl) 1,756.0 Maximum Treating Pressure (psi)5,150 YF125ST Pumped (bbl) 1,515.5 Average Treating Pressure (psi)3,311 WF125 Pumped (bbl) 0 Average Water Temperature (F)96.2 Average Viscosity (cP)18.5 12:10:18 12:31:08 12:51:58 13:12:48 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 8 02-15-2024 Collet/Ball#9 hit the sleeve Drop Rate for Ball/Collet#9 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st8 380 40.1 9.5 YF125ST 15961 0 0 0 2 1.0 PPA 180 39.9 4.5 YF125ST 7261 CarboLite 16/20 1 0.9 7137 3 2.0 PPA 220 40 5.5 YF125ST 8503 CarboLite 16/20 2.1 2 17693 4 4.0 PPA 240 39.8 6 YF125ST 8587 CarboLite 16/20 4.1 3.9 35817 5 6.0 PPA 240 40 6 YF125ST 7986 CarboLite 16/20 6.1 5.9 50253 6 8.0 PPA 240 39.7 6 YF125ST 7461 CarboLite 16/20 8.2 7.9 62872 7 10.0 PPA 236.4 40 5.9 YF125ST 7069 CarboLite 16/20 10.2 9.2 68831 8 Clean line & Spacer 16.6 41.6 0.4 YF125ST 698 CarboLite 16/20 0.1 0 2 9 Drop Collet#9 3 41.2 0.1 YF125ST 126 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st8 40.1 42.1 2929 3438 2697 2 1.0 PPA 39.9 40.2 2695 2719 2668 3 2.0 PPA 40.0 40.4 2597 2680 2568 4 4.0 PPA 39.8 40.0 2678 2861 2579 5 6.0 PPA 40.0 40.4 3139 3589 2861 6 8.0 PPA 39.7 40.2 4163 4618 3589 7 10.0 PPA 40.0 41.6 4872 5150 4538 8 Clean line & Spacer 41.6 41.7 4950 5074 4821 9 Drop Collet#9 41.2 41.2 4831 4839 4821 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 9 Before the job was started, Santos changed Resume PAD step volume from 135bbl to 165bbl and. Once the Collet/Ball#9 hit the sleeve the pressure transition from Stage 8to 9was typical. Treating pressure on PAD was around 2,350psi and slowly fell to about 2,280 psi when 1PPA was going into the formation. When 2 PPA started going into the formation the treating pressure was gradually increasing from 2,280 to 4,750 psi. Slurry rate remained steady at 40bpm until it was slowed for the Collet/Ball#10 to seat, then was pumped DFIT for stage 10 with further hard shutdown and pressure decline recording (Resume LG DFITstep volume was changed from 300bbl to 250bbl by Santos during the pumping to make sure there will be enough clean fluid to finish all stages). A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet #9 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 2,005 2,430 1,821 Bottomhole Pressure 2,956 3,225 2,853 Summary of Stage 9 Total Proppant Pumped (lb) 241,854 Max pumping Rate (bpm) 41.6 Total Proppant in Formation (lb) 241,854 Average Pumping Rate (bpm) 38.1 Total Slurry Pumped (bbl) 2,245.5 Maximum Treating Pressure (psi) 4,839 YF125ST Pumped (bbl) 1,563.5 Average Treating Pressure (psi) 2,998 WF125 Pumped (bbl) 442.6 Average Water Temperature (F) 99.2 Average Viscosity (cP) 18.5 13:13:41 13:38:41 14:03:41 14:28:41 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 9 02-15-2024 Collet/Ball#9 hit the sleeve. Drop Rate for Ball/Collet#10 Collet/Ball#10 hit the sleeve. DFIT Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st9 164.4 39.2 4.3 YF125ST 6946 CarboLite 16/20 0 0 0 2 Slow For Seat 102.4 17.6 6.6 YF125ST 4299 CarboLite 16/20 0 0 0 3 Resume Pad 164.9 37.1 4.6 YF125ST 6921 0 0 0 4 1.0 PPA 180 39.9 4.5 YF125ST 7260 CarboLite 16/20 1.1 0.9 7194 5 2.0 PPA 220 39.9 5.5 YF125ST 8501 CarboLite 16/20 2.1 2 17687 6 4.0 PPA 240 40 6 YF125ST 8590 CarboLite 16/20 4.1 3.9 35645 7 6.0 PPA 240 39.9 6 YF125ST 7984 CarboLite 16/20 6.3 5.9 50161 8 8.0 PPA 240 40 6 YF125ST 7460 CarboLite 16/20 8.2 7.9 62768 9 10.0 PPA 229.5 40 5.7 YF125ST 6800 CarboLite 16/20 10.5 9.5 68392 10 Clean line & Spacer 18.6 41.4 0.5 YF125ST 780 CarboLite 16/20 0.2 0 7 11 Drop Collet#10 3 40.7 0.1 YF125ST 126 0 0 0 12 LG DFIT 153.1 40 3.8 WF125 6429 0 0 0 13 Slow For Seat 43.5 21.8 2.2 WF125 1827 0 0 0 14 Resume LG DFIT 246.1 38.1 6.7 WF125 10333 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st9 39.2 41.1 3750 4839 1447 2 Slow For Seat 17.6 21.8 1959 2820 781 3 Resume Pad 37.1 41.4 2307 2454 1830 4 1.0 PPA 39.9 40.3 2290 2373 2252 5 2.0 PPA 39.9 40.1 2265 2321 2224 6 4.0 PPA 40.0 40.2 2369 2495 2293 7 6.0 PPA 39.9 40.2 2792 3281 2493 8 8.0 PPA 40.0 40.3 3959 4504 3276 9 10.0 PPA 40.0 41.4 4679 4767 4464 10 Clean line & Spacer 41.4 41.6 4508 4644 4356 11 Drop Collet#10 40.7 40.8 4371 4403 4356 12 LG DFIT 40.0 40.6 3642 4403 2901 13 Slow For Seat 21.8 40.1 1669 2891 1535 14 Resume LG DFIT 38.1 40.3 2568 2704 383 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 10 Once the Collet/Ball#10hit the sleeve the pressure transition from Stage 10to 11 was typical. Treating pressure on PAD was around 2,220 psi and stayed stable until 3 PPA hit the formation, then the treating pressure was gradually increasing from 2,330 to 4,080 psi. Collet/Ball#11 was launched, successfully seated. While pumping stage 10 there was electronic glitch when taking the POD from remote back to manual (physically blender gates were not moving like concentration pattern). A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet#10 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,570 2,030 1,526 Bottomhole Pressure 2,852 3,148 2,846 Summary of Stage 10 Total Proppant Pumped (lb) 240,700 Max pumping Rate (bpm) 42.4 Total Proppant in Formation (lb) 240,700 Average Pumping Rate (bpm) 39.7 Total Slurry Pumped (bbl) 1,714.8 Maximum Treating Pressure (psi) 4,863 YF125ST Pumped (bbl) 1,475.6 Average Treating Pressure (psi) 2,847 WF125 Pumped (bbl) 0 Average Water Temperature (F) 99.0 Average Viscosity (cP) 18.4 14:55:15 15:05:15 15:15:15 15:25:15 15:35:15 15:45:15 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 10 20 30 40 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 10 02-15-2024 Electronic glitch Collet/Ball#11 hit the sleeve. Drop Rate for Ball/Collet#11 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st10 350 38.3 10 YF125ST 14672 0 0 0 2 1.0 PPA 180 39.9 4.5 YF125ST 7259 CarboLite 16/20 1.1 0.9 7199 3 2.0 PPA 220 40.1 5.5 YF125ST 8503 CarboLite 16/20 2.1 2 17684 4 4.0 PPA 240 40 6 YF125ST 8586 CarboLite 16/20 4.2 3.9 35844 5 6.0 PPA 240 39.9 6 YF125ST 7989 CarboLite 16/20 7.3 5.9 50198 6 8.0 PPA 240 39.9 6 YF125ST 7463 CarboLite 16/20 8.2 7.9 62846 7 10.0 PPA 224.1 40.1 5.6 YF125ST 6634 CarboLite 16/20 11 9.5 66914 8 Clean line & Spacer 17.7 41 0.4 YF125ST 742 CarboLite 16/20 0.5 0 15 9 Drop Collet#11 3 39.9 0.1 YF125ST 126 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st10 38.3 42.4 2481 3109 380 2 1.0 PPA 39.9 40.4 2303 2338 2280 3 2.0 PPA 40.1 40.4 2245 2299 2216 4 4.0 PPA 40.0 40.4 2312 2445 2226 5 6.0 PPA 39.9 40.4 2633 2979 2436 6 8.0 PPA 39.9 40.1 3472 3956 2923 7 10.0 PPA 40.1 41.5 4435 4863 3946 8 Clean line & Spacer 41.0 41.6 4529 4787 4339 9 Drop Collet#11 39.9 40.0 4370 4410 4340 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 11 Once the Collet/Ball#11hit the sleeve the pressure transition from Stage 10to 11was typical. Treating pressure on PAD was around 2,850 psi and stayed stable until 3 PPA started going into the formation. then the treating pressure was gradually increasing from 2,850 to 4,080 psi. Flush step followed by pumping Freeze Protect and hard shutdown with an ISIP of 1,078 psi and recording of pressure decline for 60 mins. While pumping stage 11 was electronic glitch when taking the POD from remote back to manual (physically blender gates were not moving like concentration pattern). A summary of the Stage and its measured pump schedule is below: Summary of Pressures When Collet Seats Collet#11 Before Collet Hit (psi)Collet Hit (psi)After Collet (psi) Wellhead Pressure 1,859 2,347 1,893 Bottomhole Pressure 2,786 3,123 2,798 Summary of Stage 11 Total Proppant Pumped (lb) 226,289 Max pumping Rate (bpm) 41.6 Total Proppant in Formation (lb) 226,289 Average Pumping Rate (bpm) 38.4 Total Slurry Pumped (bbl) 1,749.9 Maximum Treating Pressure (psi) 4,515 YF125ST Pumped (bbl) 1,341.1 Average Treating Pressure (psi) 2,889 WF125 Pumped (bbl) 125.3 Average Water Temperature (F) 98.3 Average Viscosity (cP) 19.2 15:46:53 15:59:23 16:11:53 16:24:23 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 0 5 10 15 20 25 30 35 40 45 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Treating Pressure Annulus Pressure BH Pressure Slurry Rate Prop Conc BH Prop Con FracCAT*Santos NDBi-044 Stage 11 02-15-2024 Collet/Ball#11 hit the sleeve. Brought pump#7 back Electronic glitch Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 PAD st11 145.9 39.3 3.7 YF125ST 6128 0 0 0 2 Slow For Seat 44.9 20.8 2.3 YF125ST 1887 0 0 0 3 Resume Pad 156.9 36.4 4.6 YF125ST 6587 0 0 0 4 1.0 PPA 180.0 40 4.5 YF125ST 7257 CarboLite 16/20 1.1 0.9 7268 5 3.0 PPA 220.0 40.1 5.5 YF125ST 8182 CarboLite 16/20 3.1 2.9 25331 6 5.0 PPA 260.0 40 6.5 YF125ST 8965 CarboLite 16/20 5.3 4.9 46902 7 7.0 PPA 230.0 39.8 5.8 YF125ST 7392 CarboLite 16/20 7.3 6.9 54438 8 9.0 PPA 230.0 40 5.8 YF125ST 6926 CarboLite 16/20 9.7 8.9 65649 9 10.0 PPA 97.8 40 2.4 YF125ST 3001 CarboLite 16/20 10.2 8.5 26697 10 WF Flush 125.1 39.2 3.3 WF125 5262 CarboLite 16/20 0.2 0 4 11 Freeze Protect 59.3 20.5 2.9 FP 2495 0 0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 PAD st11 39.3 40.8 3558 4515 2210 2 Slow For Seat 20.8 39.8 1784 1915 1657 3 Resume Pad 36.4 40.3 2217 2404 1837 4 1.0 PPA 40.0 40.8 2243 2271 2186 5 3.0 PPA 40.1 41.5 2261 2338 2177 6 5.0 PPA 40.0 40.5 2477 2707 2333 7 7.0 PPA 39.8 40.2 3201 3578 2705 8 9.0 PPA 40.0 40.4 3875 4054 3506 9 10.0 PPA 40.0 41.6 3954 4066 3869 10 WF Flush 39.2 41.6 3476 3973 1782 11 Freeze Protect 20.5 23.4 1936 2114 1777 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Displacement PT, Ball to Seat and Pump Check Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 6:47:15 Priming Pumps With Diesel 29 150 0.0 0.0 0.0 2 7:00:36 Mixing gel #25 41 150 0.0 0.0 0.0 3 7:15:53 Low Pressure Test 338 150 0.0 0.0 0.0 4 7:19:41 Mid Pressure Test 5093 150 0.0 0.0 0.0 5 7:24:09 Mid Pressure Test 4359 150 0.0 0.0 0.0 6 7:28:25 High Pressure Test 9501 150 0.0 0.0 0.0 7 7:33:58 Bump up the pressure to 9500 9514 149 0.0 0.0 0.0 8 7:39:18 Pressure test is good 9160 149 0.0 0.0 0.0 9 7:45:54 LR pressure test their line 954 149 0.0 0.0 0.0 10 7:55:13 LR pressure IA to 3400psi 918 149 0.0 0.0 0.0 11 8:10:43 Safety Meeting 679 3217 0.0 0.0 0.0 12 8:44:55 Safety Meeting Completed 220 3259 0.0 0.0 0.0 13 8:50:39 Radio check 189 3194 0.0 0.0 0.0 14 9:03:26 Bump Up To Equalize 935 3129 0.0 0.0 0.0 15 9:03:58 Open Well 303 3124 0.0 0.0 0.0 16 9:04:49 Start Displ PT (1) Automatically 291 3122 0.0 0.0 0.0 17 9:04:49 Start Displacement Automatically 291 3122 0.0 0.0 0.0 18 9:05:01 Started Pumping 425 3125 0.0 0.0 0.0 19 9:08:01 Loading ball in the Ball/Collet launcher 1153 3235 9.6 3.5 0.0 20 9:14:18 Stopped Pumping 8142 3159 26.5 0.0 0.0 21 9:16:26 GORV popped off. 619 3146 26.5 0.0 0.0 22 9:19:38 Master valve accidentally shut in 455 3131 26.5 0.0 0.0 23 9:20:15 Rebuilding the GORV 429 3128 26.5 0.0 0.0 24 9:29:38 Flushing the gel to bleed off tank 193 3082 26.5 1.8 0.0 25 9:43:04 Rolling up the pumps with diesel 213 2997 26.5 5.3 0.0 26 10:03:25 GORV set 3 2871 26.5 0.0 0.0 27 10:20:43 Refilling the diesel transport -1 2800 26.5 0.0 0.0 28 10:44:52 Spot & Rig Up Diesel Transport 0 2709 26.5 0.0 0.0 29 10:51:57 Low Pressure Test 553 2685 26.5 0.0 0.0 30 10:58:15 High Pressure Test 9481 2663 26.5 0.0 0.0 31 10:58:39 High Pressure Test 9591 2662 26.5 0.0 0.0 32 11:05:07 Pressure test is good 811 3135 26.5 0.0 0.0 33 11:05:16 Bleed off the pressure 842 3181 26.5 0.0 0.0 34 11:07:13 Open well 252 3260 26.5 0.0 0.0 35 11:08:22 Restart Treatment 294 3262 26.5 0.0 0.0 36 11:08:22 Start Displ PT (2) Automatically 294 3262 26.5 0.0 0.0 37 11:08:22 Started Pumping 294 3262 26.5 0.0 0.0 38 11:17:53 Launched /the ball 1197 3211 56.3 3.5 0.0 39 11:20:55 Start Shut Down Automatically 1123 3203 66.6 3.5 0.0 40 11:20:56 Start Ball to Seat Automatically 1102 3203 66.6 3.5 0.0 41 11:21:04 Stopped Pumping 979 3199 66.9 0.0 0.0 42 11:33:55 Start Displ PT Automatically 415 3323 66.9 0.0 0.0 43 11:33:55 Started Pumping 415 3323 66.9 0.0 0.0 44 11:34:11 Start Ball to Seat Manually 702 3334 67.2 3.5 0.0 45 12:09:08 Stage at Perfs: Displ PT 1095 3479 206.3 4.0 0.0 46 12:12:35 Ball Seated 1121 3482 220.2 4.0 0.0 47 12:12:50 Start Pump Check Manually 1160 3482 221.2 4.0 0.0 48 12:13:35 Stage at Perfs: Displ PT 2729 3525 233.4 25.9 0.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Stage 8 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 12:14:39 Start PAD st8 Manually 3414 3566 271.3 40.0 0.0 2 12:14:39 Start Propped Frac Manually 3414 3566 271.3 40.0 0.0 3 12:14:39 Start Stage 8 Automatically 3414 3566 271.3 40.0 0.0 4 12:14:43 Stage at Perfs: Shut Down 3384 3561 2.7 40.0 0.0 5 12:14:44 Stage at Perfs: Shut Down 3385 3564 3.3 40.0 0.0 6 12:18:35 Stage at Perfs: Ball to Seat 2879 3515 157.3 40.0 0.0 7 12:19:50 Stage at Perfs: Ball to Seat 2921 3523 207.3 40.0 0.0 8 12:24:08 Start 1.0 PPA Automatically 2718 3458 380.1 40.0 0.0 9 12:24:08 Started Pumping Prop 2718 3458 380.1 40.0 0.0 10 12:28:39 Start 2.0 PPA Automatically 2681 3464 560.3 39.9 1.0 11 12:29:18 Stage at Perfs: Pump Check 2661 3477 586.3 40.0 2.0 12 12:33:49 Stage at Perfs: PAD st8 2588 3429 767.1 40.2 2.0 13 12:34:09 Start 4.0 PPA Automatically 2599 3432 780.4 40.0 2.0 14 12:39:20 Stage at Perfs: 1.0 PPA 2811 3476 986.9 39.8 4.0 15 12:40:10 Start 6.0 PPA Automatically 2865 3487 1020.2 39.7 4.0 16 12:45:20 Stage at Perfs: 2.0 PPA 3475 3403 1226.5 40.1 6.0 17 12:46:10 Start 8.0 PPA Automatically 3602 3421 1260.0 40.0 6.0 18 12:51:22 Stage at Perfs: 4.0 PPA 4543 3496 1466.4 39.8 8.0 19 12:52:13 Start 10.0 PPA Automatically 4617 3504 1500.4 40.2 7.9 20 12:57:23 Stage at Perfs: 6.0 PPA 5111 3511 1706.5 40.4 9.4 21 12:58:07 Start Clean line & Spacer Manually 5083 3513 1736.3 41.7 0.0 22 12:58:31 Start Drop Collet#9 Manually 4870 3502 1752.9 41.5 -0.0 Stage 9 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 12:58:36 Start PAD st9 Automatically 4705 3502 0.0 40.9 -0.0 2 12:58:36 Start Propped Frac Automatically 4705 3502 0.0 40.9 -0.0 3 12:58:36 Start Stage 9 Automatically 4705 3502 0.0 40.9 -0.0 4 13:02:55 Start Slow For Seat Automatically 1685 3427 164.8 18.7 0.0 5 13:04:13 Stage at Perfs: 8.0 PPA 1852 3413 186.0 15.9 0.0 6 13:05:16 Stage at Perfs: 10.0 PPA 1897 3407 202.7 15.9 0.0 7 13:05:29 Stage at Perfs: Clean line & Spacer 1906 3407 206.1 15.9 0.0 8 13:07:30 shutdown because don't see that collet is seated 853 3349 229.2 0.9 0.1 9 13:07:51 Stopped Pumping 845 3352 229.3 0.0 0.2 10 13:11:47 Started Pumping 788 3290 229.3 0.0 0.0 11 13:11:51 Stopped Pumping Prop 787 3290 229.3 0.0 -0.4 12 13:14:38 Ball & Collet Seated 2053 3311 263.7 21.4 0.0 13 13:14:47 Start Resume Pad Manually 2006 3313 266.9 21.6 0.0 14 13:17:39 Stage at Perfs: Drop Collet#9 2384 3333 362.1 40.0 0.0 15 13:19:24 Start 1.0 PPA Manually 2372 3411 432.0 40.0 0.0 16 13:19:30 Started Pumping Prop 2375 3405 436.0 40.0 0.0 17 13:20:13 Stage at Perfs: PAD st9 2351 3419 464.4 39.3 1.0 18 13:23:55 Start 2.0 PPA Automatically 2256 3465 612.3 40.1 1.0 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 19 13:24:20 Stage at Perfs: Slow For Seat 2255 3470 628.9 39.8 2.0 20 13:28:51 Stage at Perfs: Resume Pad 2299 3431 809.1 39.9 2.0 21 13:29:26 Start 4.0 PPA Automatically 2336 3442 832.3 39.8 2.0 22 13:34:22 Stage at Perfs: 1.0 PPA 2438 3431 1029.6 39.8 4.0 23 13:35:26 Start 6.0 PPA Automatically 2494 3423 1072.2 39.9 4.0 24 13:40:22 Stage at Perfs: 2.0 PPA 3086 3405 1269.0 39.9 6.1 25 13:41:26 Start 8.0 PPA Automatically 3293 3402 1311.8 40.1 6.1 26 13:46:22 Stage at Perfs: 4.0 PPA 4386 3395 1509.2 39.9 8.0 27 13:47:26 Start 10.0 PPA Automatically 4495 3400 1551.7 40.1 8.2 28 13:52:22 Stage at Perfs: 6.0 PPA 4755 3395 1748.7 40.2 10.0 29 13:53:10 Start Clean line & Spacer Manually 4645 3391 1781.0 41.5 0.1 30 13:53:13 Stopped Pumping Prop 4679 3395 1783.1 41.5 0.0 31 13:53:37 Start DropCollet#10 Manually 4441 3390 1799.6 40.6 0.0 32 13:53:42 Start LG DFIT Automatically 4399 3387 1803.0 40.3 0.0 33 13:57:31 Start Slow For Seat Manually 1939 3376 1955.7 40.0 0.0 34 13:58:33 Stage at Perfs: 8.0 PPA 1614 3374 1977.9 17.6 0.0 35 13:59:35 Stage at Perfs: 10.0 PPA 1915 3382 1996.2 17.7 0.0 36 13:59:40 Ball & Collet Seated 1511 3352 1997.6 17.6 0.0 37 13:59:44 Start Res LG DFIT Manually 1612 3381 1998.8 17.8 0.0 38 13:59:47 Stage at Perfs: Clean line & Spacer 1596 3389 1999.7 17.5 0.0 39 14:04:07 Stage at Perfs: DropCollet#10 2633 3463 2152.8 40.0 0.0 40 14:05:12 Stage at Perfs: LG DFIT 2637 3478 2196.1 40.0 0.0 41 14:06:26 Stopped Pumping 372 3422 2245.0 22.3 0.0 42 14:08:56 Recording Pressure decline 789 3414 2245.0 0.0 0.0 Stage 10 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 14:57:02 Started Pumping 383 3237 2245.0 0.0 0.0 2 14:57:06 Start PAD st10 Manually 383 3235 2245.0 0.0 0.0 3 14:57:06 Start Propped Frac Manually 383 3235 2245.0 0.0 0.0 4 14:57:06 Start Stage 10 Automatically 383 3235 2245.0 0.0 0.0 5 15:04:42 Stage at Perfs: Res LG DFIT 2402 3391 197.2 39.5 0.0 6 15:08:32 Start 1.0 PPA Automatically 2336 3464 350.3 39.9 0.0 7 15:08:32 Started Pumping Prop 2336 3464 350.3 39.9 0.0 8 15:13:02 Start 2.0 PPA Automatically 2301 3494 530.1 40.1 1.0 9 15:13:13 Stage at Perfs: PAD st10 2270 3496 537.5 40.3 1.4 10 15:17:42 Stage at Perfs: 1.0 PPA 2251 3499 717.3 39.9 2.0 11 15:18:32 Start 4.0 PPA Automatically 2251 3502 750.6 39.9 2.0 12 15:23:13 Stage at Perfs: 2.0 PPA 2382 3468 937.6 40.3 4.0 13 15:24:32 Start 6.0 PPA Automatically 2448 3458 990.6 40.4 3.9 14 15:29:13 Stage at Perfs: 4.0 PPA 2899 3424 1177.4 39.9 6.0 15 15:30:32 Start 8.0 PPA Automatically 2964 3419 1230.0 40.0 6.1 16 15:35:14 Stage at Perfs: 6.0 PPA 3792 3389 1417.4 39.6 8.0 17 15:36:34 Start 10.0 PPA Automatically 3935 3386 1470.5 40.2 8.1 18 15:41:14 Stage at Perfs: 8.0 PPA 4773 3383 1657.6 40.4 10.1 Client: Santos Well: NDBi-044 Formation: Nanushuk District: Pikka Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 19 15:42:08 Start Clean line & Spacer Manually 4700 3376 1694.0 41.6 0.1 20 15:42:13 Stopped Pumping Prop 4624 3373 1697.5 41.3 0.0 21 15:42:34 Start DropCollet#11 Manually 4425 3370 1711.7 39.8 0.0 Stage 11 Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 15:42:39 Start PAD st11 Automatically 4521 3376 0.0 39.7 0.0 2 15:42:39 Start Propped Frac Automatically 4521 3376 0.0 39.7 0.0 3 15:42:39 Start Stage 11 Automatically 4521 3376 0.0 39.7 0.0 4 15:46:22 Start Slow For Seat Manually 1218 3335 145.5 35.3 0.0 5 15:47:21 Stage at Perfs: 10.0 PPA 1800 3375 165.9 17.9 0.0 6 15:48:19 Stage at Perfs: Clean line & Spacer 1857 3386 183.3 18.0 0.0 7 15:48:30 Stage at Perfs: DropCollet11 1857 3389 186.6 18.0 0.0 8 15:48:36 Ball & Collet Seated 2347 3406 188.4 17.9 0.0 9 15:48:42 Start Resume Pad Manually 1711 3346 190.2 17.6 0.0 10 15:52:45 Stage at Perfs: PAD st11 2269 3486 325.3 40.0 0.0 11 15:53:18 Start 1.0 PPA Manually 2242 3489 347.4 40.1 0.0 12 15:53:18 Started Pumping Prop 2242 3489 347.4 40.1 0.0 13 15:53:52 Stage at Perfs: Slow For Seat 2209 3502 369.8 38.9 1.1 14 15:57:48 Stage at Perfs: Resume Pad 2253 3522 527.2 40.1 0.9 15 15:57:49 Start 3.0 PPA Automatically 2229 3519 527.9 40.1 0.9 16 16:02:18 Stage at Perfs: 1.0 PPA 2302 3471 707.7 40.0 3.0 17 16:03:18 Start 5.0 PPA Automatically 2338 3463 748.0 40.2 3.1 18 16:07:47 Stage at Perfs: 3.0 PPA 2551 3388 927.4 40.3 5.0 19 16:09:47 Start 7.0 PPA Automatically 2714 3367 1007.5 40.0 5.0 20 16:14:18 Stage at Perfs: 5.0 PPA 3487 3448 1187.4 39.8 6.9 21 16:15:34 Start 9.0 PPA Automatically 3556 3438 1237.8 39.8 7.0 22 16:20:04 Stage at Perfs: 7.0 PPA 4020 3391 1417.3 40.3 9.1 23 16:21:19 Start 10.0 PPA Automatically 3944 3380 1467.5 39.8 8.7 24 16:23:45 Start WF Flush Manually 3837 3347 1565.0 41.5 0.0 25 16:23:48 Stopped Pumping Prop 3779 3348 1567.1 41.3 0.0 26 16:25:49 Stage at Perfs: 9.0 PPA 3523 3347 1647.2 39.9 0.0 27 16:27:00 Start Freeze Protect Manually 1891 3303 1690.0 23.1 0.0 28 16:29:40 Stage at Perfs: 10.0 PPA 2116 3293 1744.3 20.0 0.0 29 16:29:55 Stopped Pumping 164 3207 1749.2 6.7 0.0 30 16:33:38 Close Well 60 3211 1749.2 0.0 0.0 31 16:40:25 Fanning Out Pumps, Cleaning line, PCM, POD, rig down.37 3090 1749.2 5.5 0.0 NDBi-044 Well Schematic GL 20" Insulated Conductor128' MD 9-5/8" Tieback and Seal Assembly2,363' MD 13-3/8" 68 ppf L-80 Surface Casing2,514' MD 9-5/8", 47ppf L-80 Production Liner11,114' MD 4-½, 12.6ppf P-110S Production Liner 17,832' MD 4-½ Liner Hanger Liner Top Packer10,823' MD Archer C-Flex Two-Stage Cementing Tool 4,158' MD 16" Hole Size 12-1/4" Hole Size 8-½ Openhole 17,837' MD 12.21.202346.8' RKB Bottom Flange 1 2 3 4 5 6 7 8 9 9-5/8" Liner Hanger and Liner Top Packer2,363' MD 1 X Landing Nipple 1490 1471 20 3.813 4.772 2 GasliftMandrel 1.5" 2075 1986 38 3.865 7.684 3 X Landing Nipple 2138 2034 40 3.813 4.772 4 X Landing Nipple 10686 4016 76 3.813 4.776 5 D/HPsi Temp Gauge 10747 4030 76 3.905 6.002 6 X Landing Nipple 10761 4033 76 3.813 4.778 7 Tieback Seal Assy 10858 4055 76 3.860 5.230 8 9.625" x 4.5"LH/Packer 10823 4047 76 6.180 8.430 9 #13Openhole Packer 11221 4132 80 3.918 8.000 10 #12Openhole Packer 11285 4167 80 3.898 8.000 11 Stage 11 FracSleeve 11718 4167 90 3.735 5.628 12 #11Openhole Packer 11980 4167 90 3.918 8.000 13 Stage 10 FracSleeve 12206 4166 90 3.735 5.628 14 #10Openhole Packer 12428 4165 90 3.918 8.000 15 Stage 9 FracSleeve 12863 4165 90 3.735 5.650 16 #9Openhole Packer 13085 4164 90 3.918 8.000 17 Stage 8 FracSleeve 13477 4163 90 3.735 5.635 18 #8Openhole Packer 13823 4162 90 3.898 8.000 19 Stage 7 FracSleeve 14175 4161 90 3.735 5.636 20 #7Openhole Packer 14602 4159 90 3.918 8.000 21 Stage 6 FracSleeve 14868 4158 90 3.735 5.625 22 #6Openhole Packer 15090 4158 90 3.898 8.000 23 Stage 5 FracSleeve 15399 4157 90 3.735 5.625 24 #5Openhole Packer 15662 4156 90 3.898 8.000 25 Stage 4 FracSleeve 16008 4154 90 3.735 5.632 26 #4Openhole Packer 16354 4153 90 3.898 8.000 27 Stage 3 FracSleeve 16622 4152 90 3.735 5.629 28 #3Openhole Packer 16800 4152 90 3.898 8.000 29 Stage 2 FracSleeve 17070 4151 90 3.735 5.624 30 #2Openhole Packer 17373 4150 90 3.898 8.000 31 Stage 1 FracSleeve 17598 4149 90 3.735 5.625 32 #1Openhole Packer 17696 4149 90 3.898 8.000 33 #2Toe Sleeve 17760 4149 90 3.500 5.750 34 #1Toe Sleeve 17768 4149 90 3.500 5.750 35 WIV Collar 17821 4148 90 0.870 5.620 36 Eccentricshoe 17830 4148 90 3.900 5.210 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 1 PDF file NDBi-044 (50-103-20865-0000) 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 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: 223-087 T39835 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.06 08:23:51 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 7, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Oil Search (Alaska), LLC NDBi-044 PIKKA NDBi-044 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/07/2024 NDBi-044 50-103-20865-00-00 223-087-0 N SPT 4047 2230870 4000 3023 3656 3719 3759 -8 -6 -6 -6 OTHER P Sully Sullivan 1/30/2024 Post completion, pre Frac MIT of the IA to 4000 psi Per Santos Procedures 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PIKKA NDBi-044 Inspection Date: Tubing OA Packer Depth 14 4365 4309 4281IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240131093003 BBL Pumped:10.3 BBL Returned:9.2 Thursday, March 7, 2024 Page 1 of 1 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 2302 FSL, 3361 FEL, S4, T11N, R6E, UM Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): 4031 FSL, 1598 FEL, S6, T11N, R6E, UM GL: 22.8 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4514 FSL, 91 FEL, S36, T12N, R5E, 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- 4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: GR-RES-NEU-DEN-Sonic, Mudlogs 23. BOTTOM 20"x34" X-52 128' 13-3/8" L-80 2300' 9-5/8" L-80 4112' Tieback L-80 2197' 4-1/2" P-110S 4149' 4-1/2" P-110S 4056' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, See attached cement rpt12-1/4" TUBING RECORD N/A 10859' 17832' See attached cement rpt 4048' Surface 12-1/4" 8-1/2" 17832'4-1/2" N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil Search Alaska, LLC WAG Gas 12/19/23 223-087 50-103-20865-00-00 NDBi-044 LONS 19-003 11/03/23 17,839' / 4,149' N/A 69.8 900 E Benson Boulevard, Anchorage, AK 99508 421,883.43 5,972,689.12 CASING WT. PER FT.GRADE 12/13/23 CEMENTING RECORD 5,974,551.31 1,351' MD / 1,339' TVD SETTING DEPTH TVD 5,980,317.11 TOP HOLE SIZE AMOUNT PULLED 47 413,101.61 409,789.56 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) See attached packer rpt PACKER SET (MD/TVD) 12.6# 10823' Surface 42" 12.6# Tubing 16" Grouted to surface Surface See attached cement rpt 47# Surface Surface 2514'Surface Surface 47# 2364' 2218' Surface 215# 68# 128' 2393' 11114' 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 3922984, 391445, 393021, 393019 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 9:37 am, Jan 19, 2024 Completed 12/19/2023 JSB RBDMS JSB 012224 4068 JSB GBJM 1/5/26 Pikka DSR-2/13/24A.Dewhurst 29FEB24 CDW 09/17/2024 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1,398 1,384 Top of Productive Interval 11,114 4,112 Upper Schrader Bluff 1,038' 1,033 Middle Schrader Bluff 1,784 1,740 MCU 2,295 2,149 Tuluvak Shale 2,756 2,450 Tuluvak Sand 2,873 2,512 Seabee 6,037 3,153 9,678 3,804 9,792 3,825 NT7 MFS 9,916 3,850 NT6 MFS 10,338 3,939 NT5 MFS 10,534 3,983 NT4 MFS 10,736 4,028 NT3 MFS 11,071 4,103 Nanushuk 3.2 11,186 4,126 31. List of Attachments: 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: 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 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. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. NT8 MFS NT3 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. Nanushuk Formation Name at TD: TPI (Top of Producing Interval). Authorized Name and 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. N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov egoing is true and correct to g Engineer 1/18/2024 wellbore schematic, daily operations summary, directional survey, cement reports NDBi-044 Well Schematic GL 20" Insulated Conductor128' MD 9-5/8" Tieback and Seal Assembly2,363' MD 13-3/8" 68 ppf L-80 Surface Casing2,514' MD 9-5/8", 47ppf L-80 Production Liner11,114' MD 4-½”, 12.6ppf P-110S Production Liner 17,832' MD 4-½” Liner Hanger Liner Top Packer10,823' MD Archer C-Flex Two-Stage Cementing Tool4,158' MD 16" Hole Size 12-1/4" Hole Size 8-½” Openhole 17,837' MD 12.21.202346.8' RKB – Bottom Flange 1 2 3 4 5 6 7 8 9 9-5/8" Liner Hanger and Liner Top Packer2,363' MD #CompletionItem TopDepth(MD')Depth(TVD') Inc ID" OD" 1XLandingNipple 1490 1471 20 3.813 4.772 2GasliftMandrel 1.5" 2075 1986 38 3.865 7.684 3XLandingNipple 2138 2034 40 3.813 4.772 4XLandingNipple 10686 4016 76 3.813 4.776 5D/HPsiͲTempGauge 10747 4030 76 3.905 6.002 6XLandingNipple 10761 4033 76 3.813 4.778 7TiebackSealAssy 10858 4055 76 3.860 5.230 89.625"x4.5"LH/Packer 10823 4047 76 6.180 8.430 9#13OpenholePacker 11221 4132 80 3.918 8.000 10 #12OpenholePacker 11285 4167 80 3.898 8.000 11 Stage 11ͲFracSleeve 11718 4167 90 3.735 5.628 12 #11OpenholePacker 11980 4167 90 3.918 8.000 13 Stage 10ͲFracSleeve 12206 4166 90 3.735 5.628 14 #10OpenholePacker 12428 4165 90 3.918 8.000 15 Stage 9ͲFracSleeve 12863 4165 90 3.735 5.650 16 #9OpenholePacker 13085 4164 90 3.918 8.000 17 Stage 8ͲFracSleeve 13477 4163 90 3.735 5.635 18 #8OpenholePacker 13823 4162 90 3.898 8.000 19 Stage 7ͲFracSleeve 14175 4161 90 3.735 5.636 20 #7OpenholePacker 14602 4159 90 3.918 8.000 21 Stage 6ͲFracSleeve 14868 4158 90 3.735 5.625 22 #6OpenholePacker 15090 4158 90 3.898 8.000 23 Stage 5ͲFracSleeve 15399 4157 90 3.735 5.625 24 #5OpenholePacker 15662 4156 90 3.898 8.000 25 Stage 4ͲFracSleeve 16008 4154 90 3.735 5.632 26 #4OpenholePacker 16354 4153 90 3.898 8.000 27 Stage 3ͲFracSleeve 16622 4152 90 3.735 5.629 28 #3OpenholePacker 16800 4152 90 3.898 8.000 29 Stage 2ͲFracSleeve 17070 4151 90 3.735 5.624 30 #2OpenholePacker 17373 4150 90 3.898 8.000 31 Stage 1ͲFracSleeve 17598 4149 90 3.735 5.625 32 #1OpenholePacker 17696 4149 90 3.898 8.000 33 #2ToeSleeve 17760 4149 90 3.500 5.750 34 #1ToeSleeve 17768 4149 90 3.500 5.750 35 WIV Collar 17821 4148 90 0.870 5.620 36 Eccentricshoe 17830 4148 90 3.900 5.210 Page 1 of 1 Well Name: NDBi-044 Packer Set Depths Item Des Btm (ftKB) Btm (TVD) (ftKB) SLZXP Liner Top Hanger Packer 10,845.1 4,052.8 OH Packer #13 11,269.1 4,140.2 OH Packer #12 11,333.1 4,149.3 OH Packer #11 11,947.2 4,167.3 OH Packer #10 12,558.6 4,164.7 OH Packer #9 13,174.4 4,163.9 OH Packer #8 13,788.8 4,162.1 OH Packer #7 14,403.6 4,160.2 OH Packer #6 15,014.4 4,158.2 OH Packer #5 15,586.2 4,156.3 OH Packer #4 16,155.2 4,154.2 OH Packer #3 16,724.8 4,152.4 OH Packer #2 17,298.8 4,150.7 OH Packer #1 17,703.1 4,149.2 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/1/2023 11/2/2023 0 No accidents, incidents or spills. Rig release from NDB-024, begin move operations to NDBi-044. Split rig modules, stage Mud Module and Drilling Module in front of well NDBi-044. Move and spot Utility Module. 11/2/2023 11/3/2023 0 10.00 1 Incident. No accidents or spills. Attempted to remove the wellhouse from NDB-024 with the Worley loader. Loader had a mechanical failure, and a crane was mobilized from K pad to remove the well house. Spot and center wellhouse on NDBi-044. Move and spot drill module over well. Move and spot utility module and mud module. Plug in module interconnects. Raise derrick and skid into position. Complete Rig Acceptance at 16:00 hrs. Start N/U surface stack/diverter system. * 24 hour notice given to AOGCC for diverter test at 04:30. 11/3/2023 11/4/2023 127 165.00 10.00 No accidents, incidents or spills. Finish rigging up diverter. Tested the diverter system and gas alarms. Test witnessed by Guy Cook of AOGCC. Annular close time 28.5 sec. Knife valve opened in 25 sec. Tested the PVT sensors and flow paddle. Finish building 5-7/8" HWDP stands and jar stand. Test surface mud lines. Perform rig evacuation drill with all personnel. Make up 16” directional BHA. Upload to the MWD tools. Tag bottom of conductor at 127’. Spud NDBi-044 and drill 16” surface hole from 127’ to 292’ md. Rig service. 11/4/2023 11/5/2023 292 1,510.00 10.00 No accidents, incidents or spills. Drill Surface hole from 292' md to 574' md. Shoot survey and circulate bottoms up. Trip to insert HWDP from 574' md to 196' md. Trip in hole to 574' md. Drill Surface hole from 574' md to 1046' md. Trip to insert HWDP and Jars from 1046' md to 470' md. Trip in hole to 1046' md. Drill Surface hole from 1046' md to 1802' md. Circulate bottoms up twice. Rig Service. 11/5/2023 11/6/2023 1,802 722.00 10.00 No accidents, incidents or spills. POOH on elevators from 1607’ md to 853’ md. Trip in hole on elevators from 853’ md to 1709’ md. Wash down from 1709’ md to tag bottom at 1802’ md. Drill 16” surface hole from 1802’ md to 2524' md. CBU 3 times. Rack back 1 stand per bottoms up from 2524’ md to 2273’ md. BROOH 2273’ md to 1515’ md. POOH on elevators from 1515’ md to 850’ md. RIH from 850’ md to 1084’ md. Work past bridge at 1084' md continue running in hole to 1800' md. Circulate Bottoms up 2 times while B/R a stand per B/U 1800’ md to 1610’ md. POOH on elevators from 1610’ md to 196’ md. LD BHA. Rig service. 11/6/2023 11/7/2023 2,524 0.00 10.00 No accidents, incidents or spills. Rig up and run 13-3/8” casing, 68#, L-80, BTC/TXP casing from surface to 1788' md. Stage up pumps and vary to 7 BPM while slowly RIH without any losses. Continue to RIH with 13-3/8”, 68#, L-80, TXP casing from 1788' md to 2514' md. Circulate and condition the mud for cementing. Cement 13-3/8” casing. 11/7/2023 11/8/2023 2,524 0.00 10.00 No accidents, incidents or spills. Rig down HES cementers. Flush lines, clean and clear rig floor. Rig down casing running equipment. Nipple down diverter line. Nipple up and test 13-5/8" BOPE, witnessed by AOGCC rep Sully Sullivan. Rig up to pressure test casing. Rig service. 11/8/2023 11/9/2023 2,524 0.00 10.00 No accidents, incidents or spills. Pressure test 13-3/8” casing to 2600 PSI for 30 mins - good test. Run in hole with 12-1/4" Intermediate BHA from surface to 2114' md. -Waiting on Weather. 11/9/2023 11/10/2023 2,524 0.00 10.00 No accidents, incidents or spills. -Entire field under Phase 3 conditions as of 00:30 hrs. -Rig on critical ops only due to Phase 3 weather. -Wait on weather. 11/10/2023 11/11/2023 2,524 0.00 10.00 No accidents, incidents or spills. -Wait on weather. 11/11/2023 11/12/2023 2,524 99.00 12.00 No accidents, incidents or spills. Displaced 10 ppg spud mud to 12 ppg Versaclean MOBM. Perform Choke Drill. Drill out plugs, float collar, shoe track and shoe. Clean old hole and drill 20' of new formation. Perform FIT. Drill 12.25” Intermediate hole from 2,544’ md to 2,623’ md (2357' TVD). Well Name Wellbore Name PTD # Start Drill Date End Drill Date Page 1 of 5 Well Name NDBi-044 Wellbore Name Original Hole PTD # 223-087 Start Drill Date 4/1/2023 End Drill Date 12/22/2023 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/12/2023 11/13/2023 2,623 2,243.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 2,623’ md to 4,866' md. 11/13/2023 11/14/2023 4,866 2,667.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 4,866’ md to 7,533' md. 11/14/2023 11/15/2023 7,533 1,407.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 7,533’ md to 8,226' md. Problem with #2 suction pod. Make repairs. Circulate at reduced rate during pump repairs. Drill 12.25” Intermediate hole from 8,226’ to 8,940’ md. 11/15/2023 11/16/2023 8,940 1,774.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 8,940’ md to 9,947' md. Mud pump #3 suction module washing, make repairs. Drill 12.25” Intermediate hole from 9,947’ md to 10,714' md. 11/16/2023 11/17/2023 10,714 403.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 10,714’ md to 11,117' md (4,113' TVD). Circulate B/U X5 while rack back stand every 30 min from 11,117’ to 10,456’. Low energy back reaming to 13 3/8” casing shoe from 10,456’ to 9,225' md. Run 2 stands back in to 9,410’. 11/17/2023 11/18/2023 11,117 0.00 12.00 No accidents, incidents or spills. Backream out of hole from 9410' to 9,009' MD. Lost returns at 9,009’ with increased torque. Reduced flow, regained returns. Increased flow rate and resumed BROOH with reduced flow rate 850 gpm from 9,009’ to 8,901’. RIH from 8,901’ to 10,000’ on elevators to spot 80 bbl, 20 ppb, LCM Pill. Pump and spot 80 bbls LCM Pill. POOH above Pill to 9,300' md. Discussion with Engineer, decision was made to mix and pump an 80 bbl, 40 ppb, 80 LCM pill. Pump and spot pill in annulus. POOH while pumping 80 GPM, 0 RPM from 9,313’ to 8,650’ with no issues. No overpull. POOH while pumping 80 GPM, 0 RPM 200k PU Wt. @20 ft/min. from 8,650’ to 8,460’. Run 1 stand back in and stage up pumps to 850 gpm for BROOH due to overpull. 11/18/2023 11/19/2023 11,117 0.00 12.00 No accidents, incidents or spills. BROOH from 8,370’ to 7,784’ at 2-3 ft/min for 3x BU. Packed off @ 7784’ attempted to regain circ 2 times, no returns. RIH 1 std. to 7,885 - Staged pumps up and regained circulation @ 7,885’. BROOH from 7,885’ to 7,417'. POH with 3 bpm. 0 rpm from 7,417’ to 7,320’. BROOH from 7,320’ to 7,235’. Trip back in hole on elevators from 7,235’ to 10,002’ with no issues, no tight spots. Pump and spot 80 bbl, 50 lb/bbl LCM pill. Pump out of the hole with 80 gpm and no rotary to 9,560’. 11/19/2023 11/20/2023 11,117 0.00 12.00 No accidents, incidents or spills. Pump out of the hole with 80 gpm and no rotary from 9,560’ to 9,350’. Mix and spot 80 bbl, 50 lb/bbl LCM pill at 210 gpm. Pump out of hole with 80 GPM and 0 RPM at 50 ft/min from 9,350’ to 8,843’. RIH from 8,843’ to 10,350’ to pump 80 bbl LCM Pill. Pump out of hole with 84 GPM, 152 psi and 0 RPM at 40 ft/min from 10,350’ to 8,843’. Pump out of hole from 8,843’ to 7,225’ with 84 GPM 200 psi and 0 RPM at 40 ft/min. RIH 2 stands from 7,225’ to 7,410’. Break circulation and Stage pumps up. Back ream out of hole from 7,410’ to 7,322’. Pump out of the hole with 82 GPM, 0 RPM from 7,322’ to 5,205’. 11/20/2023 11/21/2023 11,117 0.00 12.00 No accidents, incidents or spills. Pump out of the hole with 82 GPM, 0 RPM from 5,205 to 2,415’. BROOH from 2,415’ to 1,800’. POOH on elevators from 1,800’ to HWDP & lay down. Lay Down BHA. Clean & Clear rig floor. R/U & test all BOPE to 250 psi low, 3000 psi high per test procedure. R/D test equip. Rig up casing 9 5/8” casing running equipment. 11/21/2023 11/22/2023 11,117 0.00 12.05 No accidents, incidents or spills. Rig up to run 9 5/8” liner. MU 9 5/8” 47# L-80 BTC casing shoe track, XO, and 9 5/8” 47# L-80 Hyd 563 casing and run in hole to 246’. RIH with 9 5/8” 47# L-80 Hyd 563 liner from 246’ to 2,511’. Circulate & condition Mud. Prior to entering open hole. RIH with 9 5/8” 47# L- 80 Hyd 563 liner from 2,511’ to 4,270'. 11/22/2023 11/23/2023 11,117 0.00 12.00 No accidents, incidents or spills. RIH with 9 5/8” 47# L-80 Hyd 563 liner from 4,270’ to 8,475'. 11/23/2023 11/24/2023 11,117 0.00 11.95 No accidents, incidents or spills. RIH with 9 5/8” 47# L-80 Hyd 563 liner from 8,475' to 11,114'. Page 2 of 5 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/24/2023 11/25/2023 11,117 0.00 12.00 No accidents, incidents or spills. Set Baker Liner Top Hanger at 2362’. Cement 9-5/8” 47# Intermediate Liner. Release from Baker ZXP Liner Top Packer assembly. Lay down cement head. POH with the liner running assembly and LD / stand back as planned for second stage cement run. Inspect liner running tools at surface, observed one of the pump down darts was protruding from the end of the running tool. After further inspection observed the 5k psi rupture disk had ruptured. Both liner wiper plugs were gone. M/U Archer Cementing tool and crossover and RIH. Tagged obstruction at 2,402', POOH for cleanout run. 11/25/2023 11/26/2023 11,117 0.00 12.00 No accidents, incidents or spills. MU 8-1/2” cleanout BHA #3. Shallow hole test MWD. RIH to Liner Top at 2362’. Conduct cleanout run with 8-1/2” Cleanout BHA per plan from 2,362’ to 4,273’. Change out Top drive saver sub. Continue cleanout run from 4,273’ to 6,945’. Conduct Well Control drill. Continue cleanout run from 6,945’ to 9,000’. Circulate wellbore. 11/26/2023 11/27/2023 11,117 0.00 12.00 No accidents, incidents or spills. Conduct clean out run with 8-1/2” Clean out BHA #3 per plan from 9,000’ to 10,861’. Conduct milling operation from 10,861’ to 11,031’. Discussed plan forward with ODE. Decision was made to Drill out shoe track. Drilled Shoe Track from 11,031’ to 11,117’. POOH with Clean out BHA. 11/27/2023 11/28/2023 11,117 0.00 12.00 No accidents, incidents or spills. POOH with Cleanout BHA from 10,838’ to 680’. POOH laying down 5-7/8” drill pipe. Lay down BHA. 11/28/2023 11/29/2023 11,117 0.00 12.00 No accidents, incidents or spills. POOH with Cleanout BHA from 680’ to Surface. Lay down BHA. Prepare for remedial cement job. RIH with Cement Retainer BHA. Set cement retainer on depth at 11,010’. Circulate and condition wellbore. 11/29/2023 11/30/2023 11,117 0.00 12.10 No accidents, incidents or spills. Conduct remedial cement job. Sting out of the cement retainer drop wiper balls and circulate wellbore. Drop 2.5" rabbit. POOH with Cement Retainer running tool from 10,840’ to surface. Recover rabbit. Prep the cement swivel for the 2nd stage cement job. MU, RIH with Archer C-Flex BHA to 3560’ md. 11/30/2023 12/1/2023 11,117 0.00 11.95 No accidents, incidents or spills. Make up, RIH with Archer cementing tool from 3560’ md to 4145' md. Stage Archer cementing tool on depth and open C-Flex. Circulate to condition wellbore fluids. Close the C-Flex tool. Spot spacer at top of liner. Open C-Flex and Circulate Bottoms Up. Conduct Stage 2 primary cement job. Pick up to 220k close C-Flex Stage Tool. Set Liner Top Packer. Circulate wellbore. POOH with Archer cementing tool from 4176’ md to 2360’ md. Circulate wellbore above Liner Top Packer at 2362’ md. POOH on elevators from 2362’ md to 1845’ md. 12/1/2023 12/2/2023 11,117 0.00 12.00 No accidents, incidents or spills. POOH with C-Flex cementing BHA. MU, RIH with Baker Polish Mill / Liner Top Dressing BHA. RIH with Baker 9-5/8” Model “L” Retrievamatic Test Packer. Conduct Liner Top Packer pressure test. Pressure up to 2920 psi down backside. Bled down to 2880 psi in 30 min. Record on chart, good test. POOH. RU and run 9-5/8” 47# L-80 Hyd 563 Tie-back string to 2363’ md. Pump Freeze Protect. 12/2/2023 12/3/2023 11,117 0.00 12.00 No accidents, incidents or spills. Land out 9-5/8” Tie-Back Assembly string into Sealbore. Conduct 13-3/8” x 9-5/8” annulus in-flow test. Pressure test against sealbore element / Liner Top Packer to 2600 psi. Install casing packoff. Pull packoff. RIH with new packoff #2. Test pack-off and R/D casing tools. P/U & RIH with E-Line Logging Tools and Tractor to 9050’ md. 12/3/2023 12/4/2023 11,117 0.00 12.00 No accidents, incidents or spills. Complete E-line Logging of cemented zones. Rig Down E-Line. Test 13-5/8" BOPE, AOGCC witness waived by Austin McLeod. Perform casing test. Pressure up casing to 3300 psi. -11 bbls to get to 3300 psi. Record test on chart, 20 psi lost in first 15 minutes, 20 psi lost last 15 minutes, total pressure lost 40 psi, good test. Make Up 8-1/2” Production Drilling BHA #4 to 280’ md. 12/4/2023 12/5/2023 11,117 6.00 10.00 No accidents, incidents or spills. Complete MU of 8-1/2” Drilling BHA, RIH and conduct shallow hole test. Slip and Cut drilling line. Displace to 10.0 ppg MOBM. Drill out retainer 11,117’ md. Page 3 of 5 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/5/2023 12/6/2023 11,123 149.00 10.00 No accidents, incidents or spills. Drill ahead in new formation from 11,123’ to 11,137' md. Pull into casing, circulate bottoms up while reciprocating pipe. Conduct FIT to 14.0 ppg EMW, good test. Drill 8-1/2” Production Hole from 11,137’ md to 11,222’ md. P/U and work bit back through the 9-5/8” liner shoe. Downlink to MWD tools to get a survey, signal difficult to decode. Drill 8-1/2” Production Hole from 11,222’ md to 11,272’ md. Very slow drilling at 30 ft/hr, 100+ ft/hr expected. Suspect the bit is damaged or debris is keeping the bit from drilling. Pump out of the hole from 11,272’ md to 5000’ md. 12/6/2023 12/7/2023 11,272 0.00 9.95 No accidents, incidents or spills. POOH on elevators from 5000’ md to 4239’ md. Attempt to work past overpull at 4238' md. Work free from obstruction. Circulate at 3995' md. POOH from 3995’ md. Suspect hanging up at bottom of seal bore area bit depth 2395’ md. Continue to POOH from 2350’ md to surface. Rig service. PU & MU 8-1/2” Milltooth Fishing BHA. RIH with 8-1/2” Fishing BHA from 336’ md to 5085’ md. 12/7/2023 12/8/2023 11,272 0.00 10.00 No accidents, incidents or spills. RIH with 8-1/2” Fishing BHA from 5085’ md to 10,830’ md. Wash down from 10,792’ md & work past obstruction at shoe at 11115' md. Ream down from 11,115’ md to 11272' md. Milling Operation from 11,272’ md. Circulate wellbore at 11,272’ md. Wash out of hole from 11,272’ md to 11,114’ md (liner shoe). POOH with BHA to 7360’ md. Pump out of hole with BHA from 7360’ md to 4609’ md. 12/8/2023 12/9/2023 11,272 7.00 10.00 No accidents, incidents or spills. Pump out of the hole from 4609' md to 2330' md. POOH on elevators from 2330' md. Inspect BHA. MU & RIH with 8-1/2” 3-Blade Junk Mill BHA to 10800' md. Wash down from 10800’ md to 10969' md. Ream down from 10969’ md to 11005' md. Wash down from 11005’ md to 11274' md. Milling Operation from 11,274’ md to 11,279' md. 12/9/2023 12/10/2023 11,279 1.00 9.95 No accidents, incidents or spills. POOH from 11,279’ md to 11,005’ md. RIH from 11,005’ md to 11,274’ md. Milling Operation from 11,279’ md to 11,280' md. Circulate wellbore at 11,280’ md. Pump out of hole from 11,280' md to 5,190' md. POOH on elevators from 5,190’ md to 4,212' md. Pump out of hole from 4,212’ md to surface. Lay down BHA. MU 8-1/2” Production Drilling BHA #5. 12/10/2023 12/11/2023 11,280 620.00 10.00 No accidents, incidents or spills. Complete MU of Drilling BHA #5, RIH and conduct shallow hole test. RIH to 10,974' md. Wash & ream from 10,974’ md to 11,280’ md. Drill 8-1/2” Production Hole from 11,280’ md to 11,900’ md. 12/11/2023 12/12/2023 11,900 2,265.00 10.00 No accidents, incidents or spills. Drill 8-1/2” Production Hole from 12,350’ md to 14,165’ md. 12/12/2023 12/13/2023 14,165 2,085.00 10.00 No accidents, incidents or spills. Drill 8-1/2” Production Hole from 14,165’ md to 14,551’ md. Circulate bottoms up at 14,551’ md. Drill 8-1/2” Production Hole from 14,551’ md to 16,250’ md. 12/13/2023 12/14/2023 16,250 1,589.00 10.00 No accidents, incidents or spills. Drill 8-1/2” Production Hole from 16,250’ MD to TD at 17,839’ MD. Circulate 3 bottoms up from 17,839’ MD backreaming at 3 fph to 17,492’ MD. Continue to backream out of hole from 17,492’ MD to 16,828’ MD. 12/14/2023 12/15/2023 17,839 0.00 10.00 No accidents, incidents or spills. Continue to backream out of hole from 16,828’ to 16,256’. Poor caliper log data received from 16,393’. Run back in two stands from 16,256’ to 16,452’ and re-log interval. Continue to backream out of hole at from 16,452’ to 11,219’. Pull BHA through the shoe with no rotary from 11,219’ to 11,100’. Circulate bottoms up twice. Pump out of the hole from 10,940’ to 9,513’. 12/15/2023 12/16/2023 17,839 0.00 10.00 No accidents, incidents or spills. POOH from 9,513' to BHA. Lay down 8-1/2" drilling BHA. R/U & run 4-1/2”, 12.6#, P-110S, TSH 563 Production Liner to 1,908' md. Page 4 of 5 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/16/2023 12/17/2023 17,839 0.00 10.00 No accidents, incidents. We had a 5 gallon diesel spill to containment and 2 cups contacted the ground. Run 4-1/2”, 12.6#, P-110S, TSH 563 Production Liner from 1,908’ to 6,944’ MD. Make up Baker SBE and SLXP Liner top hanger packer assemblies. RIH with 4-1/2” Production Liner on 5” DP to 9-5/8” casing shoe at 11,016'. Break circulation and obtain P/U, S/O and rotating parameters. Continue RIH with 4-1/2” Production Liner on 5” DP from 11,264’ to 17,688’. Rig Service. 12/17/2023 12/18/2023 17,839 0.00 10.01 No accidents, incidents or spills. Contacted Jim Regg, AOGCC commisioner, and he granted an extension to the scheduled BOPE test. Continue to RIH with 4-1/2” Production Liner on 5” DP from 17,688’ to 17,828’. Circulate and condition while preparing pits for displacement. Displace MOBM with 10.0 ppg NaCl/KCl brine. Set Baker liner hanger SLXP packer & open hole packers. Prep Pits for Displacement to 9.4 ppg NaCl inhibited brine. Displace to 9.4 ppg NaCl Inhibited brine with Safelube. Slip & cut. POOH with Liner running tools & L/D. R/U & run 4.5”, 12.6#, P-110S Upper Completion tubing from surface to 159’ MD. 12/18/2023 12/19/2023 17,839 0.00 10.01 No accidents, incidents or spills. Continue to make up and test the downhole psi/temp gauge. Run 4.5”, 12.6#, P-110S, TSH563 Upper Completion tubing from 159’ MD to 10,750' MD. PU XO and stand of drill pipe. Run in to 10’ above liner hanger. Circulate to clean seal assembly. Slack off to NO-GO with 10k down weight, PU & SO to verify NO-GO. Space out PU hanger, terminate TEC wire & land tubing. 12/19/2023 12/20/2023 17,839 0.00 10.01 No accidents, incidents or spills. Laid down landing joint and RU to pressure test tubing and IA. MIT-T to 4,000 psi and MIT-IA to 4,000 (Production Tubing & IA). RU & pump 110 bbls freeze protect. Install TWC & test. Bleed down accumulator. ND bell nipple, BOP & riser. NU dry hole tree. Test hanger void. Test dry hole tree. Perform rig maintenance. 12/20/2023 12/21/2023 17,839 0.00 10.01 No accidents, incidents or spills. Perform rig maintenance, while waiting on Site Availability. 12/21/2023 12/22/2023 17,839 0.00 10.01 No accidents, incidents or spills. Perform rig maintenance, while waiting on Site Availability. 12/22/2023 12/22/2023 17,839 0.00 10.01 No accidents, icidents or spills. Perform rig maintenance, while waiting on Site Availability. Roads and Pads prepping pad for move to NDBi-014. Prep to Skid floor and lay down derrick. Set Mats for NDBi-014. Page 5 of 5 Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/1/2023 11/2/2023 0 No accidents, incidents or spills. Rig release from NDB-024, begin move operations to NDBi-044. Split rig modules, stage Mud Module and Drilling Module in front of well NDBi-044. Move and spot Utility Module. 11/2/2023 11/3/2023 0 10.00 1 Incident. No accidents or spills. Attempted to remove the wellhouse from NDB-024 with the Worley loader. Loader had a mechanical failure, and a crane was mobilized from K pad to remove the well house. Spot and center wellhouse on NDBi-044. Move and spot drill module over well. Move and spot utility module and mud module. Plug in module interconnects. Raise derrick and skid into position. Complete Rig Acceptance at 16:00 hrs. Start N/U surface stack/diverter system. * 24 hour notice given to AOGCC for diverter test at 04:30. 11/3/2023 11/4/2023 127 165.00 10.00 No accidents, incidents or spills. Finish rigging up diverter. Tested the diverter system and gas alarms. Test witnessed by Guy Cook of AOGCC. Annular close time 28.5 sec. Knife valve opened in 25 sec. Tested the PVT sensors and flow paddle. Finish building 5-7/8" HWDP stands and jar stand. Test surface mud lines. Perform rig evacuation drill with all personnel. Make up 16” directional BHA. Upload to the MWD tools. Tag bottom of conductor at 127’. Spud NDBi-044 and drill 16” surface hole from 127’ to 292’ md. Rig service. 11/4/2023 11/5/2023 292 1,510.00 10.00 No accidents, incidents or spills. Drill Surface hole from 292' md to 574' md. Shoot survey and circulate bottoms up. Trip to insert HWDP from 574' md to 196' md. Trip in hole to 574' md. Drill Surface hole from 574' md to 1046' md. Trip to insert HWDP and Jars from 1046' md to 470' md. Trip in hole to 1046' md. Drill Surface hole from 1046' md to 1802' md. Circulate bottoms up twice. Rig Service. 11/5/2023 11/6/2023 1,802 722.00 10.00 No accidents, incidents or spills. POOH on elevators from 1607’ md to 853’ md. Trip in hole on elevators from 853’ md to 1709’ md. Wash down from 1709’ md to tag bottom at 1802’ md. Drill 16” surface hole from 1802’ md to 2524' md. CBU 3 times. Rack back 1 stand per bottoms up from 2524’ md to 2273’ md. BROOH 2273’ md to 1515’ md. POOH on elevators from 1515’ md to 850’ md. RIH from 850’ md to 1084’ md. Work past bridge at 1084' md continue running in hole to 1800' md. Circulate Bottoms up 2 times while B/R a stand per B/U 1800’ md to 1610’ md. POOH on elevators from 1610’ md to 196’ md. LD BHA. Rig service. 11/6/2023 11/7/2023 2,524 0.00 10.00 No accidents, incidents or spills. Rig up and run 13-3/8” casing, 68#, L-80, BTC/TXP casing from surface to 1788' md. Stage up pumps and vary to 7 BPM while slowly RIH without any losses. Continue to RIH with 13-3/8”, 68#, L-80, TXP casing from 1788' md to 2514' md. Circulate and condition the mud for cementing. Cement 13-3/8” casing. 11/7/2023 11/8/2023 2,524 0.00 10.00 No accidents, incidents or spills. Rig down HES cementers. Flush lines, clean and clear rig floor. Rig down casing running equipment. Nipple down diverter line. Nipple up and test 13-5/8" BOPE, witnessed by AOGCC rep Sully Sullivan. Rig up to pressure test casing. Rig service. 11/8/2023 11/9/2023 2,524 0.00 10.00 No accidents, incidents or spills. Run in hole with 12-1/4" Intermediate BHA from surface to 2114' md. -Waiting on Weather. 11/9/2023 11/10/2023 2,524 0.00 10.00 No accidents, incidents or spills. -Entire field under Phase 3 conditions as of 00:30 hrs. -Rig on critical ops only due to Phase 3 weather. -Wait on weather. 11/10/2023 11/11/2023 2,524 0.00 10.00 No accidents, incidents or spills. -Wait on weather. 11/11/2023 11/12/2023 2,524 99.00 12.00 No accidents, incidents or spills. Displaced 10 ppg spud mud to 12 ppg Versaclean MOBM. Perform Choke Drill. Drill out plugs, float collar, shoe track and shoe. Clean old hole and drill 20' of new formation. Perform FIT. Drill 12.25” Intermediate hole from 2,544’ md to 2,623’ md (2357' TVD). Well Name Wellbore Name PTD # Start Drill Date End Drill Date Page 1 of 5 Well Name NDBi-044 Wellbore Name Original Hole PTD # 223-087 Start Drill Date 4/1/2023 End Drill Date 12/22/2023 Superseded g Cement 13-3/8” casing ,p Rig up and run 13-3/8” casing, 68#, L-80, BTC/TXP casing ,gggg Nipple up and test 13-5/8" BOPE, witnessed by AOGCCqp pp rep Sully Sullivan pp Spud NDBi-044 and drill 16” surface hole from 127’g to 292’ md. Rig service. What were results of casing test? Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/12/2023 11/13/2023 2,623 2,243.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 2,623’ md to 4,866' md. 11/13/2023 11/14/2023 4,866 2,667.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 4,866’ md to 7,533' md. 11/14/2023 11/15/2023 7,533 1,407.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 7,533’ md to 8,226' md. Problem with #2 suction pod. Make repairs. Circulate at reduced rate during pump repairs. Drill 12.25” Intermediate hole from 8,226’ to 8,940’ md. 11/15/2023 11/16/2023 8,940 1,774.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 8,940’ md to 9,947' md. Mud pump #3 suction module washing, make repairs. Drill 12.25” Intermediate hole from 9,947’ md to 10,714' md. 11/16/2023 11/17/2023 10,714 403.00 12.00 No accidents, incidents or spills. Drill 12.25” Intermediate hole from 10,714’ md to 11,117' md (4,113' TVD). Circulate B/U X5 while rack back stand every 30 min from 11,117’ to 10,456’. Low energy back reaming to 13 3/8” casing shoe from 10,456’ to 9,225' md. Run 2 stands back in to 9,410’. 11/17/2023 11/18/2023 11,117 0.00 12.00 No accidents, incidents or spills. Backream out of hole from 9410' to 9,009' MD. Lost returns at 9,009’ with increased torque. Reduced flow, regained returns. Increased flow rate and resumed BROOH with reduced flow rate 850 gpm from 9,009’ to 8,901’. RIH from 8,901’ to 10,000’ on elevators to spot 80 bbl, 20 ppb, LCM Pill. Pump and spot 80 bbls LCM Pill. POOH above Pill to 9,300' md. Discussion with Engineer, decision was made to mix and pump an 80 bbl, 40 ppb, 80 LCM pill. Pump and spot pill in annulus. POOH while pumping 80 GPM, 0 RPM from 9,313’ to 8,650’ with no issues. No overpull. POOH while pumping 80 GPM, 0 RPM 200k PU Wt. @20 ft/min. from 8,650’ to 8,460’. Run 1 stand back in and stage up pumps to 850 gpm for BROOH due to overpull. 11/18/2023 11/19/2023 11,117 0.00 12.00 No accidents, incidents or spills. BROOH from 8,370’ to 7,784’ at 2-3 ft/min for 3x BU. Packed off @ 7784’ attempted to regain circ 2 times, no returns. RIH 1 std. to 7,885 - Staged pumps up and regained circulation @ 7,885’. BROOH from 7,885’ to 7,417'. POH with 3 bpm. 0 rpm from 7,417’ to 7,320’. BROOH from 7,320’ to 7,235’. Trip back in hole on elevators from 7,235’ to 10,002’ with no issues, no tight spots. Pump and spot 80 bbl, 50 lb/bbl LCM pill. Pump out of the hole with 80 gpm and no rotary to 9,560’. 11/19/2023 11/20/2023 11,117 0.00 12.00 No accidents, incidents or spills. Pump out of the hole with 80 gpm and no rotary from 9,560’ to 9,350’. Mix and spot 80 bbl, 50 lb/bbl LCM pill at 210 gpm. Pump out of hole with 80 GPM and 0 RPM at 50 ft/min from 9,350’ to 8,843’. RIH from 8,843’ to 10,350’ to pump 80 bbl LCM Pill. Pump out of hole with 84 GPM, 152 psi and 0 RPM at 40 ft/min from 10,350’ to 8,843’. Pump out of hole from 8,843’ to 7,225’ with 84 GPM 200 psi and 0 RPM at 40 ft/min. RIH 2 stands from 7,225’ to 7,410’. Break circulation and Stage pumps up. Back ream out of hole from 7,410’ to 7,322’. Pump out of the hole with 82 GPM, 0 RPM from 7,322’ to 5,205’. 11/20/2023 11/21/2023 11,117 0.00 12.00 No accidents, incidents or spills. Pump out of the hole with 82 GPM, 0 RPM from 5,205 to 2,415’. BROOH from 2,415’ to 1,800’. POOH on elevators from 1,800’ to HWDP & lay down. Lay Down BHA. Clean & Clear rig floor. R/U & test all BOPE to 250 psi low, 3000 psi high per test procedure. R/D test equip. Rig up casing 9 5/8” casing running equipment. 11/21/2023 11/22/2023 11,117 0.00 12.05 No accidents, incidents or spills. Rig up to run 9 5/8” liner. MU 9 5/8” 47# L-80 BTC casing shoe track, XO, and 9 5/8” 47# L-80 Hyd 563 casing and run in hole to 246’. RIH with 9 5/8” 47# L-80 Hyd 563 liner from 246’ to 2,511’. Circulate & condition Mud. Prior to entering open hole. RIH with 9 5/8” 47# L- 80 Hyd 563 liner from 2,511’ to 4,270'. 11/22/2023 11/23/2023 11,117 0.00 12.00 No accidents, incidents or spills. RIH with 9 5/8” 47# L-80 Hyd 563 liner from 4,270’ to 8,475'. 11/23/2023 11/24/2023 11,117 0.00 11.95 No accidents, incidents or spills. RIH with 9 5/8” 47# L-80 Hyd 563 liner from 8,475' to 11,114'. Page 2 of 5 Superseded y si high , test all BOPE to 250 psi low, 3000 ps MU 9 5/8” 47# L-80 BTC casing shoe,pgp track, XO, and 9 5/8” 47# L-80 Hyd 563 casing and run in hole Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 11/24/2023 11/25/2023 11,117 0.00 12.00 No accidents, incidents or spills. Set Baker Liner Top Hanger at 2362’. Cement 9-5/8” 47# Intermediate Liner. Release from Baker ZXP Liner Top Packer assembly. Lay down cement head. POH with the liner running assembly and LD / stand back as planned for second stage cement run. Inspect liner running tools at surface, observed one of the pump down darts was protruding from the end of the running tool. After further inspection observed the 5k psi rupture disk had ruptured. Both liner wiper plugs were gone. M/U Archer Cementing tool and crossover and RIH. Tagged obstruction at 2,402', POOH for cleanout run. 11/25/2023 11/26/2023 11,117 0.00 12.00 No accidents, incidents or spills. MU 8-1/2” cleanout BHA #3. Shallow hole test MWD. RIH to Liner Top at 2362’. Conduct cleanout run with 8-1/2” Cleanout BHA per plan from 2,362’ to 4,273’. Change out Top drive saver sub. Continue cleanout run from 4,273’ to 6,945’. Conduct Well Control drill. Continue cleanout run from 6,945’ to 9,000’. Circulate wellbore. 11/26/2023 11/27/2023 11,117 0.00 12.00 No accidents, incidents or spills. Conduct clean out run with 8-1/2” Clean out BHA #3 per plan from 9,000’ to 10,861’. Conduct milling operation from 10,861’ to 11,031’. Discussed plan forward with ODE. Decision was made to Drill out shoe track. Drilled Shoe Track from 11,031’ to 11,117’. POOH with Clean out BHA. 11/27/2023 11/28/2023 11,117 0.00 12.00 No accidents, incidents or spills. POOH with Cleanout BHA from 10,838’ to 680’. POOH laying down 5-7/8” drill pipe. Lay down BHA. 11/28/2023 11/29/2023 11,117 0.00 12.00 No accidents, incidents or spills. POOH with Cleanout BHA from 680’ to Surface. Lay down BHA. Prepare for remedial cement job. RIH with Cement Retainer BHA. Set cement retainer on depth at 11,010’. Circulate and condition wellbore. 11/29/2023 11/30/2023 11,117 0.00 12.10 No accidents, incidents or spills. Conduct remedial cement job. Sting out of the cement retainer drop wiper balls and circulate wellbore. Drop 2.5" rabbit. POOH with Cement Retainer running tool from 10,840’ to surface. Recover rabbit. Prep the cement swivel for the 2nd stage cement job. MU, RIH with Archer C-Flex BHA to 3560’ md. 11/30/2023 12/1/2023 11,117 0.00 11.95 No accidents, incidents or spills. Make up, RIH with Archer cementing tool from 3560’ md to 4145' md. Stage Archer cementing tool on depth and open C-Flex. Circulate to condition wellbore fluids. Close the C-Flex tool. Spot spacer at top of liner. Open C-Flex and Circulate Bottoms Up. Conduct Stage 2 primary cement job. Pick up to 220k close C-Flex Stage Tool. Set Liner Top Packer. Circulate wellbore. POOH with Archer cementing tool from 4176’ md to 2360’ md. Circulate wellbore above Liner Top Packer at 2362’ md. POOH on elevators from 2362’ md to 1845’ md. 12/1/2023 12/2/2023 11,117 0.00 12.00 No accidents, incidents or spills. POOH with C-Flex cementing BHA. MU, RIH with Baker Polish Mill / Liner Top Dressing BHA. RIH with Baker 9-5/8” Model “L” Retrievamatic Test Packer. Conduct Liner Top Packer pressure test & POOH. RU and run 9-5/8” 47# L-80 Hyd 563 Tie-back string to 2363’ md. Pump Freeze Protect. 12/2/2023 12/3/2023 11,117 0.00 12.00 No accidents, incidents or spills. Land out 9-5/8” Tie-Back Assembly string into Sealbore. Conduct 13-3/8” x 9-5/8” annulus in-flow test. Pressure test against sealbore element / Liner Top Packer to 2600 psi. Install casing packoff. Pull packoff. RIH with new packoff #2. Test pack-off and R/D casing tools. P/U & RIH with E-Line Logging Tools and Tractor to 9050’ md. 12/3/2023 12/4/2023 11,117 0.00 12.00 No accidents, incidents or spills. Complete E-line Logging of cemented zones. Rig Down E-Line. Test 13-5/8" BOPE, AOGCC witness waived by Austin McLeod. Perform casing test. Make Up 8-1/2” Production Drilling BHA #4 to 280’ md. 12/4/2023 12/5/2023 11,117 6.00 10.00 No accidents, incidents or spills. Complete MU of 8-1/2” Drilling BHA, RIH and conduct shallow hole test. Slip and Cut drilling line. Displace to 10.0 ppg MOBM. Drill out retainer 11,117’ md. Page 3 of 5 pg, Displace to 10.0 ppg MOBM. Drill out retainer 11,117’ md. ,, p Drilled Shoe Track from 11,031’ to 11,117’. H with Clean out BHA.POOH py dial cement job. RIH with Cement Retainer BHA. Set cement retainer on depth , Prepare for remedip at 11,010’. gy p g Inspect liner running tools at surface, observed one of the pump down darts waspg , pp protruding from the end of the running tool. After further inspection observed the 5k psi rupturepg g p pp disk had ruptured. Both liner wiper plugs were gone. M/U Archer Cementing tool and crossoverpppgg and RIH. Tagged obstruction at 2,402', POOH for cleanout run. yg Pressure test against sealbore element / Liner Top Packer to 2600 psisi Cement 9-5/8” 47#,p pg Intermediate Liner. Release from Baker ZXP Liner Top Packer assembly. Superseded onduct remedial cement job. Sting out of the cement retainerp ate wellbore , drop wiper balls and circulat pp p p ement job. Pick up to 220k close C-Flex Stage Tool. Set p Conduct Stage 2 primary cempgp Liner Top Packer. Circulate wellbore pg Conduct Liner Top Packer pressure test & POOH. g Perform casing test What was test pressure and result of casing test? string to 2363’ md. Pump Freezerun 9-5/8” 47# L-80 Hyd 563 Tie-back s pp Protect. Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/5/2023 12/6/2023 11,123 149.00 10.00 No accidents, incidents or spills. Drill ahead in new formation from 11,123’ to 11,137' md. Pull into casing, circulate bottoms up while reciprocating pipe. Conduct FIT to 14.0 ppg EMW, good test. Drill 8-1/2” Production Hole from 11,137’ md to 11,222’ md. P/U and work bit back through the 9-5/8” liner shoe. Downlink to MWD tools to get a survey, signal difficult to decode. Drill 8-1/2” Production Hole from 11,222’ md to 11,272’ md. Very slow drilling at 30 ft/hr, 100+ ft/hr expected. Suspect the bit is damaged or debris is keeping the bit from drilling. Pump out of the hole from 11,272’ md to 5000’ md. 12/6/2023 12/7/2023 11,272 0.00 9.95 No accidents, incidents or spills. POOH on elevators from 5000’ md to 4239’ md. Attempt to work past overpull at 4238' md. Work free from obstruction. Circulate at 3995' md. POOH from 3995’ md. Suspect hanging up at bottom of seal bore area bit depth 2395’ md. Continue to POOH from 2350’ md to surface. Rig service. PU & MU 8-1/2” Milltooth Fishing BHA. RIH with 8-1/2” Fishing BHA from 336’ md to 5085’ md. 12/7/2023 12/8/2023 11,272 0.00 10.00 No accidents, incidents or spills. RIH with 8-1/2” Fishing BHA from 5085’ md to 10,830’ md. Wash down from 10,792’ md & work past obstruction at shoe at 11115' md. Ream down from 11,115’ md to 11272' md. Milling Operation from 11,272’ md. Circulate wellbore at 11,272’ md. Wash out of hole from 11,272’ md to 11,114’ md (liner shoe). POOH with BHA to 7360’ md. Pump out of hole with BHA from 7360’ md to 4609’ md. 12/8/2023 12/9/2023 11,272 7.00 10.00 No accidents, incidents or spills. Pump out of the hole from 4609' md to 2330' md. POOH on elevators from 2330' md. Inspect BHA. MU & RIH with 8-1/2” 3-Blade Junk Mill BHA to 10800' md. Wash down from 10800’ md to 10969' md. Ream down from 10969’ md to 11005' md. Wash down from 11005’ md to 11274' md. Milling Operation from 11,274’ md to 11,279' md. 12/9/2023 12/10/2023 11,279 1.00 9.95 No accidents, incidents or spills. POOH from 11,279’ md to 11,005’ md. RIH from 11,005’ md to 11,274’ md. Milling Operation from 11,279’ md to 11,280' md. Circulate wellbore at 11,280’ md. Pump out of hole from 11,280' md to 5,190' md. POOH on elevators from 5,190’ md to 4,212' md. Pump out of hole from 4,212’ md to surface. Lay down BHA. MU 8-1/2” Production Drilling BHA #5. 12/10/2023 12/11/2023 11,280 620.00 10.00 No accidents, incidents or spills. Complete MU of Drilling BHA #5, RIH and conduct shallow hole test. RIH to 10,974' md. Wash & ream from 10,974’ md to 11,280’ md. Drill 8-1/2” Production Hole from 11,280’ md to 11,900’ md. 12/11/2023 12/12/2023 11,900 2,265.00 10.00 No accidents, incidents or spills. Drill 8-1/2” Production Hole from 12,350’ md to 14,165’ md. 12/12/2023 12/13/2023 14,165 2,085.00 10.00 No accidents, incidents or spills. Drill 8-1/2” Production Hole from 14,165’ md to 14,551’ md. Circulate bottoms up at 14,551’ md. Drill 8-1/2” Production Hole from 14,551’ md to 16,250’ md. 12/13/2023 12/14/2023 16,250 1,589.00 10.00 No accidents, incidents or spills. Drill 8-1/2” Production Hole from 16,250’ MD to TD at 17,839’ MD. Circulate 3 bottoms up from 17,839’ MD backreaming at 3 fph to 17,492’ MD. Continue to backream out of hole from 17,492’ MD to 16,828’ MD. 12/14/2023 12/15/2023 17,839 0.00 10.00 No accidents, incidents or spills. Continue to backream out of hole from 16,828’ to 16,256’. Poor caliper log data received from 16,393’. Run back in two stands from 16,256’ to 16,452’ and re-log interval. Continue to backream out of hole at from 16,452’ to 11,219’. Pull BHA through the shoe with no rotary from 11,219’ to 11,100’. Circulate bottoms up twice. Pump out of the hole from 10,940’ to 9,513’. 12/15/2023 12/16/2023 17,839 0.00 10.00 No accidents, incidents or spills. POOH from 9,513' to BHA. Lay down 8-1/2" drilling BHA. R/U & run 4-1/2”, 12.6#, P-110S, TSH 563 Production Liner to 1,908' md. Page 4 of 5 ,, Conduct FIT to 14.0 ppg EMW, good test Superseded 839’ MD ,p Drill 8-1/2” Production Hole from 16,250’ MD to TD at 17,83 R/U & run 4-1/2”, 12.6#, P-110S, TSH, 563 Production Liner to Operations Summary Report - AOGCC Start Date End Date Start Depth (ftKB) Depth Prog (ft) Dens Last Mud (lb/gal) Summary 12/16/2023 12/17/2023 17,839 0.00 10.00 No accidents, incidents. We had a 5 gallon diesel spill to containment and 2 cups contacted the ground. Run 4-1/2”, 12.6#, P-110S, TSH 563 Production Liner from 1,908’ to 6,944’ MD. Make up Baker SBE and SLXP Liner top hanger packer assemblies. RIH with 4-1/2” Production Liner on 5” DP to 9-5/8” casing shoe at 11,016'. Break circulation and obtain P/U, S/O and rotating parameters. Continue RIH with 4-1/2” Production Liner on 5” DP from 11,264’ to 17,688’. Rig Service. 12/17/2023 12/18/2023 17,839 0.00 10.01 No accidents, incidents or spills. Contacted Jim Regg, AOGCC commisioner, and he granted an extension to the scheduled BOPE test. Continue to RIH with 4-1/2” Production Liner on 5” DP from 17,688’ to 17,828’. Circulate and condition while preparing pits for displacement. Displace MOBM with 10.0 ppg NaCl/KCl brine. Set Baker liner hanger SLXP packer & open hole packers. Prep Pits for Displacement to 9.4 ppg NaCl inhibited brine. Displace to 9.4 ppg NaCl Inhibited brine with Safelube. Slip & cut. POOH with Liner running tools & L/D. R/U & run 4.5”, 12.6#, P-110S Upper Completion tubing from surface to 159’ MD. 12/18/2023 12/19/2023 17,839 0.00 10.01 No accidents, incidents or spills. Continue to make up and test the downhole psi/temp gauge. Run 4.5”, 12.6#, P-110S, TSH563 Upper Completion tubing from 159’ MD to 10,750' MD. PU XO and stand of drill pipe. Run in to 10’ above liner hanger. Circulate to clean seal assembly. Slack off to NO-GO with 10k down weight, PU & SO to verify NO-GO. Space out PU hanger, terminate TEC wire & land tubing. 12/19/2023 12/20/2023 17,839 0.00 10.01 No accidents, incidents or spills. Laid down landing joint and RU to pressure test tubing and IA. MIT-T to 4,000 psi and MIT-IA to 4,000 (Production Tubing & IA). RU & pump 110 bbls freeze protect. Install TWC & test. Bleed down accumulator. ND bell nipple, BOP & riser. NU dry hole tree. Test hanger void. Test dry hole tree. Perform rig maintenance. 12/20/2023 12/21/2023 17,839 0.00 10.01 No accidents, incidents or spills. Perform rig maintenance, while waiting on Site Availability. 12/21/2023 12/22/2023 17,839 0.00 10.01 No accidents, incidents or spills. Perform rig maintenance, while waiting on Site Availability. 12/22/2023 12/22/2023 17,839 0.00 10.01 No accidents, icidents or spills. Perform rig maintenance, while waiting on Site Availability. Roads and Pads prepping pad for move to NDBi-014. Prep to Skid floor and lay down derrick. Set Mats for NDBi-014. Page 5 of 5 ,, Displace MOBM with 10.0 ppg NaCl/KCl brine g, RIH with 4-1/2” Production Liner on 5” DP ,, p RIH with 4-1/2” Production Liner on 5” DP p run 4.5”, 12.6#, P-110S Upper Completion tubing from Superseded ppp p p Displace to 9.4 ppg NaCl Inhibited brine with Safelube. ppg MIT-T to 4,000 psi and MIT-IA togj 4,000 (Production Tubing & IA). Page 1 of 1 Well Name: NDBi-044 Cement Surface Casing Cement Surface Casing Cement, Casing, 11/6/2023 20:00 Type Casing Cementing Start Date 11/6/2023 Cementing End Date 11/7/2023 Wellbore Original Hole String Surface, 2,514.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results 295 bbls of cement returned to surface. Comment PJSM - Cement 13-3/8” casing as follows: -Fill lines with water and pressure test to 500/4500 PSI for 5 minutes. -Release bottom plug. -Pump 80 bbls of 10.5 ppg mud push spacer at 5 BPM, 175 PSI. -Release 2nd Bottom plug. -Pump 506 bbls of 11.0 ppg Arcticem Lead Cement at 5 BPM. (340% excess). -Pump 69 bbls of 15.3 ppg Tail Cement at 5 BPM. -Release top plug. -Pump 2 bbls of 15.3 ppg Tail Cement at 5 BPM on top of plug. -Pump 10 bbls of water from cementers at 5 BPM. -Displace with rig pumps and 10.0 ppg spud mud. -300 bbls at 10 BPM: ICP 485 PSI and 8% return flow. FCP 725 PSI and 8% return flow. -20 bbls at 8 BPM: ICP 560 PSI and 7% return flow. FCP 645 PSI and 7% return flow. -Reduce rate to 3 BPM to bump plug. Final circulating pressure 430 PSI. -Bump plug at 361 bbls displaced measured by strokes. -Increased pressure to 930 psi. Held for 5 mins. Blead off pressure. Plugs held. -295 bbls of cement returned to surface. *Cement in place at 00:00 hrs. 1, 0.0-2,514.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 2,514.0 Full Return? Yes Vol Cement Ret (bbl) 295.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 6 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 5 Final Pump Pressure (psi) 430.0 Plug Bump Pressure (psi) 430.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) 0.00 Reciprocation Rate (spm) 0 Pipe Rotated? No Pipe RPM (rpm) 0 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Mud Push Spacer Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 1.72 Mix H20 Ratio (gal/sack) 11.51 Free Water (%) Density (lb/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Lead Fluid Type Lead Fluid Description ArcticCem Amount (sacks) 1,063 Class Type I/II Volume Pumped (bbl) 506.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 300.0 Yield (ft³/sack) 2.54 Mix H20 Ratio (gal/sack) 12.21 Free Water (%) 0.00 Density (lb/gal) 11.00 Plastic Viscosity (cP) 18.0 Thickening Time (hr) 10.20 1st Compressive Strength (psi) 38.8 Tail Fluid Type Tail Fluid Description HalCem Type I/II Amount (sacks) 303 Class Type I/II Volume Pumped (bbl) 69.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 50.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.66 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 4.70 1st Compressive Strength (psi) 739.0 Page 1 of 1 Well Name: NDBi-044 Cement Intermediate Casing Cement - 1st Stage Intermediate Casing Cement - 1st Stage, Casing, 11/24/2023 01:44 Type Casing Cementing Start Date 11/24/2023 Cementing End Date 11/24/2023 Wellbore Original Hole String Intermediate, 11,114.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Ultrasonic Cement Evaluation Results A HES CAST Ultrasonic bond log was tractored into the 9-5/8" liner to log above the 9-5/8" Cement Retainer set to perform the remedial cement squeeze out of the shoe. -7,964' MD was the TOC for the primary stage cement job. -Cement was brought up to the Top of the 9-5/8" liner top packer at 2,362' MD Detailed cement evaluation summary is included as an attachement. A secondary Soundtrak LWD log was conducted to log below the cement retainer, and across intervals missed by the CAST Log. Comment Cement 9-5/8” 47# Intermediate Liner as follows: - PJSM with personnel regarding cement and displacement plan. - Fill lines with water and check pop-off trips, pressure test to 4000 psi for 5 minutes. - Mix and pump 80 bbls of 12.5 ppg MudPush II spacer with 8 ppb Bridgemaker 2 LCM @ 4 BPM, 650-700 psi. No returns during pumping. - Release bottom dart. - Mix and pump 131 bbls of 13 ppg EconoCem Type I-II lead cement with 4 ppb Bridgemaker 2 LCM @ 4 BPM, 425-650 psi. Excess Volume 30% (400 sacks, yield 1.844 cu ft/sk). No returns during pumping. - Mix and pump 80 bbls of 15.3 ppg Versacem Type I-II tail @ 1.6-3.15 BPM, 155-355 psi. Excess Volume 30% (365 sacks, yield 1.237 cu ft/sk). No returns during pumping. - 290 bbls OBM lost during pumping of cement by Halliburton unit. - Drop top dart and kick out with 10 bbls. water from cement unit. - No reciprocation of pipe during cement job as planned. Perform displacement with rig pumps and 12.0 ppg OBM mud. - 678 bbls displaced at 8 BPM: ICP 540 psi 0% return flow (no returns), FCP 730 psi at 6 bpm with no return flow. - Reduce rate to 3 BPM prior to plug bump: Final circulating pressure 415 psi. - Did not have plug bump on calculated strokes; pumped additional 3.1 bbls (1/2 shoe track volume) without bump. Wait 5 minutes, check floats, no flow back. CIP@ 05:30hrs. - Total displacement volume 692 bbls (measured by strokes @ 96% pump efficiency). 1, 2,393.0-11,117.0ftKB Top Depth (ftKB) 2,393.0 Bottom Depth (ftKB) 11,117.0 Full Return? No Vol Cement Ret (bbl) 0.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 700.0 Plug Bump Pressure (psi) 0.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) 0.00 Reciprocation Rate (spm) 0 Pipe Rotated? No Pipe RPM (rpm) 0 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description MudPush II Spacer Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.30 Mix H20 Ratio (gal/sack) 13.54 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Lead Fluid Type Lead Fluid Description EconoCem Type I-II Amount (sacks) 400 Class Type I/II Volume Pumped (bbl) 131.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.84 Mix H20 Ratio (gal/sack) 10.13 Free Water (%) 0.00 Density (lb/gal) 13.00 Plastic Viscosity (cP) 49.9 Thickening Time (hr) 10.65 1st Compressive Strength (psi) 260.0 Tail Fluid Type Tail Fluid Description Versacem Type I-II Amount (sacks) 365 Class Type I/II Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 6.18 1st Compressive Strength (psi) 975.0 Displacement Fluid Type Displacement Fluid Description MOBM Amount (sacks) Class Volume Pumped (bbl) 678.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) 12.00 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Page 1 of 1 Well Name: NDBi-044 Cement Remedial Intermediate Casing Cement Remedial Intermediate Casing Cement, Casing - Remedial, 11/29/2023 00:30 Type Casing - Remedial Cementing Start Date 11/29/2023 Cementing End Date 11/29/2023 Wellbore Original Hole String Intermediate, 11,114.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Ultrasonic Cement Evaluation Results A HES CAST Ultrasonic bond log was tractored into the 9-5/8" liner to log above the 9-5/8" Cement Retainer set to perform the remedial cement squeeze out of the shoe. -7,964' MD was the TOC for the primary stage cement job. -Cement was brought up to the Top of the 9-5/8" liner top packer at 2,362' MD Detailed cement evaluation summary is included as an attachement. A secondary Soundtrak LWD log was conducted to log below the cement retainer, and across intervals missed by the CAST Log. Comment Conduct remedial cement job. -Pump cement job per plan. -Pump 30 bbls 12.0 ppg Lead Tuned Spacer at 3 bpm, 780 psi. -Pump 100 bbls 15.3 ppg Versacem (yield 1.237 cu ft per sack) at .5 to 1.4 bpm, 200-340 (380-520) psi holding ~180 psi backpressure to prevent cement falling away. Planned circulation rate of 3 bpm but could not maintain due to cement equipment issues. -Pump 10 bbls 12.0 pp/g Tail Tuned Spacer at 1.5 bpm, 135 (315) psi holding backpressure. -Pump 5 bbls fresh water. -79 bbl loss of 12.0 ppg OBM during cement pumping. -Displace 58 bbls with rig pumps at 3 bpm, 280 (460) psi initial, 460 (640) psi final holding ~180 psi back pressure, no returns. -Circulate 15 bbls Lead Spacer above retainer top at 11,010’ md. -With Lead Spacer at retainer, sting in with 30k set down weight and open choke to release back side pressure. Monitor flowback with pumps off, 58 bbls flowed back with diminishing gas-entrained returns entire time. -Continue with displacement through mud gas separator line up: Squeeze 15 bbls Lead Spacer and 50 bbls of the 15.3 ppg cement into formation at 2 bpm, Initial 325 psi, Final 488 psi, 50% returns during squeeze at 2 bpm. -Drop rate to 1 bpm to pump next 35 bbls cement, Initial 343 psi, Final 400 psi with return flow of 66%. -Hesitate for 25 minutes, pump last 10 bbls at .5 bpm, initial 340 psi, final 368 psi, 90% returns. 1, <DepthTop>-11,117.0ftKB Top Depth (ftKB) Bottom Depth (ftKB) 11,117.0 Full Return? No Vol Cement Ret (bbl) 0.0 Top Plug? No Bottom Plug? No Initial Pump Rate (bbl/min) 3 Final Pump Rate (bbl/min) 1 Avg Pump Rate (bbl/min) 2 Final Pump Pressure (psi) 368.0 Plug Bump Pressure (psi) 0.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) 0.00 Reciprocation Rate (spm) 0 Pipe Rotated? No Pipe RPM (rpm) 0 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Tuned Spacer Amount (sacks) Class Volume Pumped (bbl) 30.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.56 Mix H20 Ratio (gal/sack) 16.15 Free Water (%) Density (lb/gal) 12.00 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Squeeze Fluid Type Squeeze Fluid Description Versacem Amount (sacks) 454 Class Type I/II Volume Pumped (bbl) 100.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 0.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.56 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Spacer Fluid Type Spacer Fluid Description Tuned Spacer Amount (sacks) Class Volume Pumped (bbl) 10.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.56 Mix H20 Ratio (gal/sack) 16.15 Free Water (%) Density (lb/gal) 12.00 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Page 1 of 1 Well Name: NDBi-044 Cement Intermediate Casing Cement - 2nd Stage Intermediate Casing Cement - 2nd Stage, Casing, 11/30/2023 14:30 Type Casing Cementing Start Date 11/30/2023 Cementing End Date 11/30/2023 Wellbore Original Hole String Intermediate Tie-Back, 2,363.5ftKB Cementing Company Halliburton Energy Services Evaluation Method Ultrasonic Cement Evaluation Results A HES CAST Ultrasonic bond log was tractored into the 9-5/8" liner to log above the 9-5/8" Cement Retainer set to perform the remedial cement squeeze out of the shoe. -7,964' MD was the TOC for the primary stage cement job. -Cement was brought up to the Top of the 9-5/8" liner top packer at 2,362' MD Detailed cement evaluation summary is included as an attachement. A secondary Soundtrak LWD log was conducted to log below the cement retainer, and across intervals missed by the CAST Log. Comment Conduct Stage 2 primary cement job of 9-5/8” x 13-3/8” annulus. Pump cement job per plan: -Pump 80 bbls 12.5 ppg Lead Tuned Spacer at 4 bpm, 450 psi with 100% returns. -Pump 214 bbls 15.3 ppg Versacem (yield 1.237 cu ft per sack) at 4-4.5 bpm, 450-475 psi. -Pump 10 bbls fresh water (cleanup). -80 bbl loss during cement pumping (65% returns during cement pumping). -Displace 53 bbls with rig pumps at 3 bpm, 303 psi initial, 400 psi final, with 49 bbls lost (8% returns). 2, 2,376.0-4,126.0ftKB Top Depth (ftKB) 2,376.0 Bottom Depth (ftKB) 4,126.0 Full Return? No Vol Cement Ret (bbl) 0.0 Top Plug? No Bottom Plug? No Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 400.0 Plug Bump Pressure (psi) 0.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) 0.00 Reciprocation Rate (spm) 0 Pipe Rotated? No Pipe RPM (rpm) 0 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Tuned Spacer Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.30 Mix H20 Ratio (gal/sack) 13.54 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Tail Fluid Type Tail Fluid Description Versacem Amount (sacks) 969 Class Type I/II Volume Pumped (bbl) 214.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 100.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.56 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 7.65 1st Compressive Strength (psi) 0.0 See attached email from Jacob Thompson 2/22/24 for description of cement returns to surface. -bjm Sa n t o s D e f i n i t i v e S u r v e y R e p o r t 04 J a n u a r y , 2 0 2 4 De s i g n : N D B i - 0 4 4 Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B ND B i -04 4 ND B i -04 4 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e Ma p S y s t e m : Ge o D a t u m : Pr o j e c t Ma p Z o n e : Sy s t e m D a t u m : US S t a t e P l a n e 1 9 2 7 ( E x a c t s o l u t i o n ) NA D 1 9 2 7 ( N A D C O N C O N U S ) Pi k k a , N o r t h S l o p e A l a s k a , U n i t e d S t a t e s Al a s k a Z o n e 0 4 Me a n S e a L e v e l Us i n g W e l l R e f e r e n c e P o i n t Us i n g g e o d e t i c s c a l e f a c t o r Si t e P o s i t i o n : Fr o m : Si t e La t i t u d e : Lo n g i t u d e : Po s i t i o n U n c e r t a i n t y : No r t h i n g : Ea s t i n g : Gr i d C o n v e r g e n c e : ND B us f t Ma p us f t us f t ° -0 . 5 9 Sl o t R a d i u s : " 20 5, 9 7 2 , 9 0 9 . 3 1 42 3 , 3 8 3 . 6 2 0. 9 70 ° 2 0 ' 1 0 . 1 3 4 N 15 0 ° 3 7 ' 1 7 . 7 9 4 W We l l We l l P o s i t i o n Lo n g i t u d e : La t i t u d e : Ea s t i n g : No r t h i n g : us f t +E /- W +N /- S Po s i t i o n U n c e r t a i n t y us f t us f t us f t Gr o u n d L e v e l : ND B i - 0 4 4 us f t us f t 0. 0 0. 0 5, 9 7 2 , 6 8 9 . 1 2 42 1 , 8 8 3 . 4 3 22 . 8 We l l h e a d E l e v a t i o n : 0. 0 us f t 0. 3 70 ° 2 0 ' 7 . 8 1 6 N 15 0 ° 3 8 ' 1 . 5 4 1 W We l l b o r e De c l i n a t i o n (° ) Fi e l d S t r e n g t h (nT ) Sa m p l e D a t e D i p A n g l e (° ) ND B i - 0 4 4 Mo d e l N a m e Ma g n e t i c s BG G M 2 0 2 3 7 / 1 1 / 2 0 2 3 1 4 . 4 7 8 0 . 5 8 5 7 , 1 8 0 . 4 1 6 6 4 3 8 6 Ph a s e : Ve r s i o n : Au d i t N o t e s : De s i g n ND B i - 0 4 4 1. 0 A C T U A L Ve r t i c a l S e c t i o n : De p t h F r o m (TV D ) (us f t ) +N /- S (us f t ) Di r e c t i o n (° ) +E /- W (us f t ) Ti e O n D e p t h : 46 . 8 30 1 . 6 4 0. 0 0. 0 46 . 8 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 2 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e Fr o m (us f t ) Su r v e y P r o g r a m De s c r i p t i o n To o l N a m e Su r v e y (We l l b o r e ) To (us f t )Da t e 4/ 0 1 / 2 0 2 4 SD I _ U R S A 1 _ I 4 S D I U R S A - 1 g y r o M W D ( I S C W S A R e v 4 ) 11 4 . 7 1 , 0 3 7 . 3 01 SD I _Gy r o M W D _16 i n H o l e <46 -10 3 7 > ( 3_ M W D + I F R 2 + M S + S a g A 0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 1, 0 6 4 . 7 2 , 4 5 0 . 9 02 B H O n t r a k _16 i n H o l e <10 6 4 -24 5 0 > (ND 3_ M W D + I F R 2 + M S + S a g A 0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 2, 5 4 8 . 4 1 1 , 0 7 8 . 5 03 B H O n t r a k _12 .25 i n H o l e <25 4 8 -11 0 7 8 > 3_ M W D + I F R 2 + M S + S a g A 0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 11 , 1 4 3 . 8 1 1 , 1 9 2 . 0 04 B H O n t r a k _8 . 5 in H S <11 1 4 3 -11 1 9 2 > (N 3_ M W D + I F R 2 + M S + S a g A 0 1 3 M b : I I F R d e c & m u l t i - s t a t i o n a n a l y s i s + s a g 11 , 2 8 7 . 8 1 7 , 8 3 9 . 0 05 B H O n t r a k _8 . 5 in H S <11 2 8 7 -17 8 0 9 > (N MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 46 . 8 0 . 0 0 0 . 0 0 4 6 . 8 - 2 2 . 8 0 . 0 0 . 0 5 , 9 7 2 , 6 8 9 . 1 2 4 2 1 , 8 8 3 . 4 3 0 . 0 0 0 . 0 11 4 . 7 0 . 0 9 1 9 4 . 7 7 1 1 4 . 7 4 5 . 1 - 0 . 1 0 . 0 5 , 9 7 2 , 6 8 9 . 0 7 4 2 1 , 8 8 3 . 4 2 0 . 1 3 0 . 0 12 8 . 0 0 . 1 0 2 0 7 . 7 1 1 2 8 . 0 5 8 . 4 - 0 . 1 0 . 0 5 , 9 7 2 , 6 8 9 . 0 5 4 2 1 , 8 8 3 . 4 1 0 . 1 7 0 . 0 20 " C o n d u c t o r C a s i n g 18 7 . 4 0 . 1 7 2 3 9 . 7 7 1 8 7 . 4 1 1 7 . 8 - 0 . 2 - 0 . 1 5 , 9 7 2 , 6 8 8 . 9 6 4 2 1 , 8 8 3 . 3 1 0 . 1 7 0 . 0 28 2 . 0 0 . 2 5 3 3 0 . 8 2 2 8 2 . 0 2 1 2 . 4 - 0 . 1 - 0 . 3 5 , 9 7 2 , 6 8 9 . 0 7 4 2 1 , 8 8 3 . 0 9 0 . 3 2 0 . 3 37 6 . 2 1 . 6 8 3 2 9 . 7 7 3 7 6 . 2 3 0 6 . 6 1 . 3 - 1 . 1 5 , 9 7 2 , 6 9 0 . 4 5 4 2 1 , 8 8 2 . 3 1 1 . 5 2 1 . 7 46 8 . 7 3 . 9 7 3 3 5 . 3 9 4 6 8 . 5 3 9 8 . 9 5 . 4 - 3 . 2 5 , 9 7 2 , 6 9 4 . 5 6 4 2 1 , 8 8 0 . 3 3 2 . 4 9 5 . 5 56 5 . 1 5 . 9 5 3 3 6 . 8 0 5 6 4 . 6 4 9 5 . 0 1 3 . 0 - 6 . 5 5 , 9 7 2 , 7 0 2 . 2 2 4 2 1 , 8 7 7 . 0 5 2 . 0 6 1 2 . 4 65 9 . 5 6 . 7 1 3 3 0 . 4 7 6 5 8 . 4 5 8 8 . 8 2 2 . 3 - 1 1 . 2 5 , 9 7 2 , 7 1 1 . 5 6 4 2 1 , 8 7 2 . 5 0 1 . 0 9 2 1 . 2 75 3 . 7 7 . 2 4 3 2 0 . 9 8 7 5 2 . 0 6 8 2 . 4 3 1 . 7 - 1 7 . 6 5 , 9 7 2 , 7 2 1 . 0 3 4 2 1 , 8 6 6 . 1 5 1 . 3 4 3 1 . 6 84 9 . 1 7 . 6 8 3 1 1 . 8 4 8 4 6 . 6 7 7 7 . 0 4 0 . 7 - 2 6 . 1 5 , 9 7 2 , 7 3 0 . 0 4 4 2 1 , 8 5 7 . 7 1 1 . 3 2 4 3 . 6 94 4 . 3 9 . 0 8 3 0 4 . 8 0 9 4 0 . 7 8 7 1 . 1 4 9 . 2 - 3 7 . 0 5 , 9 7 2 , 7 3 8 . 6 8 4 2 1 , 8 4 6 . 9 0 1 . 8 2 5 7 . 3 1, 0 3 7 . 3 9 . 2 5 3 0 4 . 1 0 1 , 0 3 2 . 5 9 6 2 . 9 5 7 . 6 - 4 9 . 3 5 , 9 7 2 , 7 4 7 . 1 9 4 2 1 , 8 3 4 . 7 7 0 . 2 2 7 2 . 1 1, 0 3 8 . 4 9. 2 5 3 0 4 . 0 7 1 , 0 3 3 . 6 9 6 4 . 0 5 7 . 7 - 4 9 . 4 5 , 9 7 2 , 7 4 7 . 2 9 4 2 1 , 8 3 4 . 6 3 0 . 5 9 7 2 . 3 Up p e r S c h r a d e r B l u f f 1, 0 6 4 . 7 9 . 1 4 3 0 3 . 3 6 1 , 0 5 9 . 6 9 9 0 . 0 6 0 . 0 - 5 2 . 9 5 , 9 7 2 , 7 4 9 . 6 6 4 2 1 , 8 3 1 . 1 5 0 . 5 9 7 6 . 5 1, 1 3 4 . 7 9 . 9 3 3 0 0 . 9 4 1 , 1 2 8 . 6 1 , 0 5 9 . 0 6 6 . 2 - 6 2 . 7 5 , 9 7 2 , 7 5 5 . 9 2 4 2 1 , 8 2 1 . 4 0 1 . 2 7 8 8 . 1 Ba s e I c e B e a r i n g P e r m a f r o s t 1, 1 6 0 . 9 1 0 . 2 3 3 0 0 . 1 3 1 , 1 5 4 . 4 1 , 0 8 4 . 8 6 8 . 5 - 6 6 . 7 5 , 9 7 2 , 7 5 8 . 2 9 4 2 1 , 8 1 7 . 4 7 1 . 2 7 9 2 . 7 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 3 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 1, 2 5 3 . 8 1 4 . 1 8 2 9 2 . 1 7 1 , 2 4 5 . 2 1 , 1 7 5 . 6 7 6 . 9 - 8 4 . 4 5 , 9 7 2 , 7 6 6 . 9 1 4 2 1 , 7 9 9 . 8 8 4 . 6 1 1 1 2 . 2 1, 3 4 9 . 2 1 6 . 4 7 2 8 7 . 4 9 1 , 3 3 7 . 2 1 , 2 6 7 . 6 8 5 . 4 - 1 0 8 . 1 5 , 9 7 2 , 7 7 5 . 6 3 4 2 1 , 7 7 6 . 2 5 2 . 7 3 1 3 6 . 8 1, 3 9 7 . 7 1 7 . 4 1 2 8 6 . 8 7 1 , 3 8 3 . 6 1 , 3 1 4 . 0 8 9 . 6 - 1 2 1 . 6 5 , 9 7 2 , 7 7 9 . 9 4 4 2 1 , 7 6 2 . 8 0 1 . 9 7 1 5 0 . 5 Ba s e P e r m a f r o s t T r a n s i t i o n 1, 4 4 3 . 8 1 8 . 3 0 2 8 6 . 3 3 1 , 4 2 7 . 5 1 , 3 5 7 . 9 9 3 . 6 - 1 3 5 . 1 5 , 9 7 2 , 7 8 4 . 1 2 4 2 1 , 7 4 9 . 2 9 1 . 9 7 1 6 4 . 2 1, 5 3 8 . 9 2 0 . 9 5 2 8 5 . 8 1 1 , 5 1 7 . 0 1 , 4 4 7 . 4 1 0 2 . 4 - 1 6 5 . 8 5 , 9 7 2 , 7 9 3 . 2 7 4 2 1 , 7 1 8 . 7 0 2 . 7 9 1 9 4 . 9 1, 6 3 3 . 6 2 3 . 7 6 2 8 5 . 0 4 1 , 6 0 4 . 6 1 , 5 3 5 . 0 1 1 2 . 0 - 2 0 0 . 5 5 , 9 7 2 , 8 0 3 . 1 9 4 2 1 , 6 8 4 . 1 0 2 . 9 8 2 2 9 . 5 1, 7 2 7 . 2 2 5 . 8 5 2 8 3 . 9 3 1 , 6 8 9 . 6 1 , 6 2 0 . 0 1 2 1 . 8 - 2 3 8 . 6 5 , 9 7 2 , 8 1 3 . 4 0 4 2 1 , 6 4 6 . 1 6 2 . 2 9 2 6 7 . 0 1, 7 7 9 . 7 2 7 . 0 8 2 8 3 . 2 4 1 , 7 3 6 . 6 1 , 6 6 7 . 0 1 2 7 . 3 - 2 6 1 . 3 5 , 9 7 2 , 8 1 9 . 1 3 4 2 1 , 6 2 3 . 4 8 2 . 4 2 2 8 9 . 3 Mi d d l e S c h r a d e r B l u f f 1, 8 2 1 . 1 2 8 . 0 6 2 8 2 . 7 4 1 , 7 7 3 . 3 1 , 7 0 3 . 7 1 3 1 . 6 - 2 8 0 . 0 5 , 9 7 2 , 8 2 3 . 6 2 4 2 1 , 6 0 4 . 8 7 2 . 4 2 3 0 7 . 4 1, 9 1 9 . 1 3 1 . 5 1 2 8 3 . 4 2 1 , 8 5 8 . 3 1 , 7 8 8 . 7 1 4 2 . 6 - 3 2 7 . 4 5 , 9 7 2 , 8 3 5 . 1 5 4 2 1 , 5 5 7 . 5 7 3 . 5 4 3 5 3 . 6 2, 0 1 2 . 2 3 5 . 3 6 2 8 4 . 0 7 1 , 9 3 6 . 0 1, 8 6 6 . 4 15 4 . 8 - 3 7 7 . 2 5 , 9 7 2 , 8 4 7 . 8 6 4 2 1 , 5 0 7 . 9 3 4 . 1 6 4 0 2 . 3 2, 1 0 4 . 8 3 9 . 6 9 2 8 3 . 6 4 2 , 0 0 9 . 4 1 , 9 3 9 . 8 1 6 8 . 3 - 4 3 1 . 9 5 , 9 7 2 , 8 6 1 . 9 3 4 2 1 , 4 5 3 . 3 0 4 . 6 8 4 5 6 . 0 2, 1 9 7 . 2 4 2 . 7 3 2 8 2 . 9 9 2 , 0 7 8 . 9 2 , 0 0 9 . 3 1 8 2 . 3 - 4 9 1 . 2 5 , 9 7 2 , 8 7 6 . 5 5 4 2 1 , 3 9 4 . 2 3 3 . 3 2 5 1 3 . 8 2, 2 9 1 . 0 4 4 . 9 4 2 8 0 . 7 9 2 , 1 4 6 . 6 2 , 0 7 7 . 0 1 9 5 . 7 - 5 5 4 . 8 5 , 9 7 2 , 8 9 0 . 5 7 4 2 1 , 3 3 0 . 7 8 2 . 8 6 5 7 5 . 0 MC U 2, 2 9 4 . 3 4 5 . 0 2 2 8 0 . 7 2 2 , 1 4 8 . 9 2 , 0 7 9 . 3 1 9 6 . 1 - 5 5 7 . 1 5 , 9 7 2 , 8 9 1 . 0 3 4 2 1 , 3 2 8 . 5 0 2 . 8 6 5 7 7 . 1 2, 3 9 0 . 5 4 6 . 9 4 2 7 8 . 2 1 2 , 2 1 5 . 8 2 , 1 4 6 . 2 2 0 7 . 5 - 6 2 5 . 2 5 , 9 7 2 , 9 0 3 . 0 8 4 2 1 , 2 6 0 . 4 3 2 . 7 4 6 4 1 . 1 2, 4 5 0 . 9 4 7 . 0 4 2 7 9 . 1 5 2 , 2 5 7 . 0 2, 1 8 7 . 4 21 4 . 2 - 6 6 8 . 9 5 , 9 7 2 , 9 1 0 . 2 1 4 2 1 , 2 1 6 . 8 3 1 . 1 5 6 8 1 . 8 2, 5 1 4 . 0 4 7 . 7 6 2 8 0 . 3 2 2 , 2 9 9 . 7 2 , 2 3 0 . 1 2 2 2 . 0 - 7 1 4 . 7 5 , 9 7 2 , 9 1 8 . 5 3 4 2 1 , 1 7 1 . 1 5 1 . 7 8 7 2 4 . 9 13 - 3 / 8 " S u r f a c e C a s i n g 2, 5 4 8 . 4 4 8 . 1 6 2 8 0 . 9 4 2 , 3 2 2 . 7 2 , 2 5 3 . 1 2 2 6 . 7 - 7 3 9 . 8 5 , 9 7 2 , 9 2 3 . 5 1 4 2 1 , 1 4 6 . 1 1 1 . 7 8 7 4 8 . 7 2, 6 4 3 . 4 5 1 . 3 2 2 7 9 . 0 5 2 , 3 8 4 . 1 2 , 3 1 4 . 5 2 3 9 . 3 - 8 1 1 . 2 5 , 9 7 2 , 9 3 6 . 8 0 4 2 1 , 0 7 4 . 8 4 3 . 6 5 8 1 6 . 1 2, 7 3 8 . 5 5 5 . 4 2 2 7 8 . 4 8 2 , 4 4 0 . 9 2 , 3 7 1 . 3 2 5 0 . 9 - 8 8 6 . 6 5 , 9 7 2 , 9 4 9 . 2 1 4 2 0 , 9 9 9 . 5 4 4 . 3 4 8 8 6 . 4 2, 7 5 4 . 1 5 6 . 0 8 2 7 8 . 4 2 2 , 4 4 9 . 6 2 , 3 8 0 . 0 2 5 2 . 8 - 8 9 9 . 3 5 , 9 7 2 , 9 5 1 . 2 3 4 2 0 , 9 8 6 . 8 5 4 . 2 8 8 9 8 . 3 Tu l u v a k S h a l e 2, 8 3 3 . 6 5 9 . 4 8 2 7 8 . 1 1 2 , 4 9 2 . 0 2 , 4 2 2 . 4 2 6 2 . 4 - 9 6 5 . 9 5 , 9 7 2 , 9 6 1 . 5 9 4 2 0 , 9 2 0 . 3 9 4 . 2 8 9 6 0 . 0 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 4 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 2, 8 7 1 . 1 6 1 . 0 0 2 7 7 . 7 2 2 , 5 1 0 . 6 2 , 4 4 1 . 0 2 6 6 . 9 - 9 9 8 . 2 5 , 9 7 2 , 9 6 6 . 4 0 4 2 0 , 8 8 8 . 2 1 4 . 1 5 9 8 9 . 8 Tu l u v a k S a n d 2, 9 2 8 . 4 6 3 . 3 2 2 7 7 . 1 5 2 , 5 3 7 . 4 2 , 4 6 7 . 8 2 7 3 . 5 - 1 , 0 4 8 . 4 5 , 9 7 2 , 9 7 3 . 4 8 4 2 0 , 8 3 8 . 0 0 4 . 1 5 1 , 0 3 6 . 0 3, 0 2 3 . 4 66 . 7 0 2 7 7 . 1 5 2 , 5 7 7 . 5 2 , 5 0 7 . 9 2 8 4 . 2 - 1 , 1 3 3 . 9 5 , 9 7 2 , 9 8 5 . 0 9 4 2 0 , 7 5 2 . 7 0 3 . 5 6 1 , 1 1 4 . 4 3, 1 1 7 . 9 7 0 . 0 9 2 7 6 . 7 0 2 , 6 1 2 . 3 2 , 5 4 2 . 7 2 9 4 . 8 - 1 , 2 2 1 . 0 5 , 9 7 2 , 9 9 6 . 5 7 4 2 0 , 6 6 5 . 6 9 3 . 6 2 1 , 1 9 4 . 1 3, 2 1 2 . 9 7 3 . 1 3 2 7 6 . 5 5 2 , 6 4 2 . 2 2 , 5 7 2 . 6 3 0 5 . 2 - 1 , 3 1 0 . 5 5 , 9 7 3 , 0 0 7 . 9 0 4 2 0 , 5 7 6 . 2 8 3 . 2 0 1 , 2 7 5 . 8 3, 3 0 7 . 5 7 6 . 4 1 2 7 7 . 9 3 2 , 6 6 7 . 1 2 , 5 9 7 . 5 3 1 6 . 7 - 1 , 4 0 1 . 1 5 , 9 7 3 , 0 2 0 . 3 6 4 2 0 , 4 8 5 . 8 1 3 . 7 4 1 , 3 5 9 . 0 3, 3 8 2 . 7 7 8 . 9 2 27 7 . 4 4 2, 6 8 3 . 2 2 , 6 1 3 . 6 3 2 6 . 5 - 1 , 4 7 3 . 9 5 , 9 7 3 , 0 3 0 . 9 3 4 2 0 , 4 1 3 . 1 7 3 . 4 0 1 , 4 2 6 . 0 3, 4 2 8 . 5 7 9 . 9 5 2 7 7 . 8 3 2 , 6 9 1 . 6 2 , 6 2 2 . 0 3 3 2 . 5 - 1 , 5 1 8 . 5 5 , 9 7 3 , 0 3 7 . 3 9 4 2 0 , 3 6 8 . 5 8 2 . 4 0 1 , 4 6 7 . 2 3, 4 9 7 . 2 8 0 . 2 0 2 7 7 . 5 6 2 , 7 0 3 . 4 2 , 6 3 3 . 8 3 4 1 . 6 - 1 , 5 8 5 . 6 5 , 9 7 3 , 0 4 7 . 1 5 4 2 0 , 3 0 1 . 6 1 0 . 5 3 1 , 5 2 9 . 1 3, 5 9 2 . 6 8 0 . 1 4 2 7 7 . 2 8 2 , 7 1 9 . 7 2 , 6 5 0 . 1 3 5 3 . 7 - 1 , 6 7 8 . 8 5 , 9 7 3 , 0 6 0 . 2 4 4 2 0 , 2 0 8 . 6 1 0 . 3 0 1 , 6 1 4 . 7 3, 6 8 6 . 4 80 . 2 0 2 7 7 . 0 8 2 , 7 3 5 . 7 2 , 6 6 6 . 1 3 6 5 . 2 - 1 , 7 7 0 . 5 5 , 9 7 3 , 0 7 2 . 7 5 4 2 0 , 1 1 7 . 0 3 0 . 2 2 1 , 6 9 8 . 9 3, 7 8 1 . 8 7 9 . 8 8 2 7 6 . 3 6 2 , 7 5 2 . 2 2 , 6 8 2 . 6 3 7 6 . 2 - 1 , 8 6 3 . 8 5 , 9 7 3 , 0 8 4 . 7 2 4 2 0 , 0 2 3 . 8 2 0 . 8 2 1 , 7 8 4 . 1 3, 8 7 6 . 6 7 9 . 8 2 2 7 6 . 2 8 2 , 7 6 8 . 9 2 , 6 9 9 . 3 3 8 6 . 5 - 1 , 9 5 6 . 5 5 , 9 7 3 , 0 9 5 . 9 5 4 1 9 , 9 3 1 . 2 2 0 . 1 0 1 , 8 6 8 . 4 3, 9 7 1 . 1 7 9 . 8 2 2 7 6 . 5 3 2 , 7 8 5 . 6 2 , 7 1 6 . 0 3 9 6 . 9 - 2 , 0 4 9 . 0 5 , 9 7 3 , 1 0 7 . 3 0 4 1 9 , 8 3 8 . 8 4 0 . 2 6 1 , 9 5 2 . 6 4, 0 6 5 . 7 7 9 . 8 9 2 7 6 . 0 5 2 , 8 0 2 . 3 2 , 7 3 2 . 7 4 0 7 . 1 - 2 , 1 4 1 . 5 5 , 9 7 3 , 1 1 8 . 4 5 4 1 9 , 7 4 6 . 4 9 0 . 5 1 2 , 0 3 6 . 7 4, 1 6 0 . 7 7 9 . 7 6 2 7 6 . 1 8 2 , 8 1 9 . 1 2 , 7 4 9 . 5 4 1 7 . 1 - 2 , 2 3 4 . 5 5 , 9 7 3 , 1 2 9 . 3 9 4 1 9 , 6 5 3 . 5 6 0 . 1 9 2 , 1 2 1 . 1 4, 2 5 5 . 4 79 . 7 6 2 7 5 . 7 2 2 , 8 3 5 . 9 2 , 7 6 6 . 3 4 2 6 . 7 - 2 , 3 2 7 . 3 5 , 9 7 3 , 1 4 0 . 0 1 4 1 9 , 5 6 0 . 9 7 0 . 4 8 2 , 2 0 5 . 1 4, 3 5 0 . 3 7 9 . 8 2 2 7 5 . 1 9 2 , 8 5 2 . 7 2 , 7 8 3 . 1 4 3 5 . 6 - 2 , 4 2 0 . 2 5 , 9 7 3 , 1 4 9 . 8 6 4 1 9 , 4 6 8 . 1 5 0 . 5 5 2 , 2 8 8 . 9 4, 4 4 4 . 7 7 9 . 7 6 2 7 5 . 3 2 2 , 8 6 9 . 5 2 , 7 9 9 . 9 4 4 4 . 1 - 2 , 5 1 2 . 7 5 , 9 7 3 , 1 5 9 . 3 3 4 1 9 , 3 7 5 . 7 0 0 . 1 5 2 , 3 7 2 . 1 4, 5 3 9 . 8 7 9 . 7 9 2 7 4 . 0 2 2 , 8 8 6 . 3 2 , 8 1 6 . 7 4 5 1 . 7 - 2 , 6 0 6 . 0 5 , 9 7 3 , 1 6 7 . 9 2 4 1 9 , 2 8 2 . 5 1 1 . 3 5 2 , 4 5 5 . 5 4, 6 3 4 . 3 7 9 . 8 6 2 7 5 . 5 2 2 , 9 0 3 . 0 2, 8 3 3 . 4 45 9 . 5 - 2 , 6 9 8 . 6 5 , 9 7 3 , 1 7 6 . 6 1 4 1 9 , 1 9 0 . 0 0 1 . 5 7 2 , 5 3 8 . 4 4, 7 2 9 . 3 7 9 . 7 0 2 7 5 . 8 4 2 , 9 1 9 . 9 2 , 8 5 0 . 3 4 6 8 . 7 - 2 , 7 9 1 . 7 5 , 9 7 3 , 1 8 6 . 8 4 4 1 9 , 0 9 6 . 9 9 0 . 3 7 2 , 6 2 2 . 6 4, 8 2 3 . 8 7 9 . 7 6 2 7 6 . 2 0 2 , 9 3 6 . 7 2 , 8 6 7 . 1 4 7 8 . 5 - 2 , 8 8 4 . 2 5 , 9 7 3 , 1 9 7 . 5 5 4 1 9 , 0 0 4 . 6 7 0 . 3 8 2 , 7 0 6 . 4 4, 9 1 8 . 4 7 9 . 8 9 2 7 6 . 1 8 2 , 9 5 3 . 4 2 , 8 8 3 . 8 4 8 8 . 5 - 2 , 9 7 6 . 7 5 , 9 7 3 , 2 0 8 . 5 5 4 1 8 , 9 1 2 . 2 2 0 . 1 4 2 , 7 9 0 . 4 5, 0 1 3 . 0 7 9 . 7 9 2 7 6 . 0 6 2 , 9 7 0 . 1 2 , 9 0 0 . 5 4 9 8 . 4 - 3 , 0 6 9 . 3 5 , 9 7 3 , 2 1 9 . 4 4 4 1 8 , 8 1 9 . 7 9 0 . 1 6 2 , 8 7 4 . 4 5, 1 0 7 . 9 7 9 . 8 0 2 7 6 . 1 0 2 , 9 8 6 . 9 2 , 9 1 7 . 3 5 0 8 . 3 - 3 , 1 6 2 . 2 5 , 9 7 3 , 2 3 0 . 3 0 4 1 8 , 7 2 7 . 0 4 0 . 0 4 2 , 9 5 8 . 7 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 5 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 5, 2 0 3 . 0 7 9 . 7 9 2 7 6 . 2 8 3 , 0 0 3 . 8 2 , 9 3 4 . 2 5 1 8 . 4 - 3 , 2 5 5 . 3 5 , 9 7 3 , 2 4 1 . 3 6 4 1 8 , 6 3 4 . 0 5 0 . 1 9 3 , 0 4 3 . 3 5, 2 9 8 . 0 7 9 . 8 2 2 7 6 . 4 9 3 , 0 2 0 . 6 2 , 9 5 1 . 0 5 2 8 . 8 - 3 , 3 4 8 . 2 5 , 9 7 3 , 2 5 2 . 7 3 4 1 8 , 5 4 1 . 2 4 0 . 2 2 3 , 1 2 7 . 8 5, 3 9 3 . 3 7 9 . 6 7 2 7 6 . 4 6 3 , 0 3 7 . 6 2 , 9 6 8 . 0 5 3 9 . 4 - 3 , 4 4 1 . 4 5 , 9 7 3 , 2 6 4 . 2 7 4 1 8 , 4 4 8 . 1 8 0 . 1 6 3 , 2 1 2 . 7 5, 4 8 7 . 8 7 9 . 6 0 2 7 6 . 4 0 3 , 0 5 4 . 6 2 , 9 8 5 . 0 5 4 9 . 8 - 3 , 5 3 3 . 8 5 , 9 7 3 , 2 7 5 . 6 5 4 1 8 , 3 5 5 . 9 2 0 . 1 0 3 , 2 9 6 . 8 5, 5 8 2 . 4 7 9 . 6 4 2 7 5 . 9 8 3 , 0 7 1 . 6 3 , 0 0 2 . 0 5 5 9 . 8 - 3 , 6 2 6 . 2 5 , 9 7 3 , 2 8 6 . 6 3 4 1 8 , 2 6 3 . 5 8 0 . 4 4 3 , 3 8 0 . 8 5, 6 7 7 . 6 7 9 . 7 0 2 7 5 . 6 9 3 , 0 8 8 . 7 3 , 0 1 9 . 1 5 6 9 . 3 - 3 , 7 1 9 . 4 5 , 9 7 3 , 2 9 7 . 1 2 4 1 8 , 1 7 0 . 5 3 0 . 3 1 3 , 4 6 5 . 1 5, 7 7 2 . 1 7 9 . 6 7 2 7 5 . 3 3 3 , 1 0 5 . 6 3 , 0 3 6 . 0 5 7 8 . 3 - 3 , 8 1 2 . 0 5 , 9 7 3 , 3 0 7 . 0 2 4 1 8 , 0 7 8 . 0 4 0 . 3 8 3 , 5 4 8 . 6 5, 8 6 6 . 8 7 9 . 5 7 2 7 5 . 5 8 3 , 1 2 2 . 7 3 , 0 5 3 . 1 5 8 7 . 1 - 3 , 9 0 4 . 6 5 , 9 7 3 , 3 1 6 . 8 3 4 1 7 , 9 8 5 . 4 7 0 . 2 8 3 , 6 3 2 . 1 5, 9 6 1 . 6 7 9 . 6 1 2 7 5 . 2 9 3 , 1 3 9 . 8 3 , 0 7 0 . 2 5 9 6 . 0 - 3 , 9 9 7 . 5 5 , 9 7 3 , 3 2 6 . 6 3 4 1 7 , 8 9 2 . 7 3 0 . 3 0 3 , 7 1 5 . 8 6, 0 3 8 . 2 7 9 . 6 3 2 7 5 . 3 6 3 , 1 5 3 . 6 3 , 0 8 4 . 0 6 0 3 . 0 - 4 , 0 7 2 . 5 5 , 9 7 3 , 3 3 4 . 4 1 4 1 7 , 8 1 7 . 8 2 0 . 1 0 3 , 7 8 3 . 3 Se a b e e 6, 0 5 5 . 5 7 9 . 6 3 2 7 5 . 3 8 3 , 1 5 6 . 7 3 , 0 8 7 . 1 6 0 4 . 6 - 4 , 0 8 9 . 5 5 , 9 7 3 , 3 3 6 . 1 8 4 1 7 , 8 0 0 . 8 4 0 . 1 0 3 , 7 9 8 . 7 6, 1 5 1 . 0 7 9 . 6 4 2 7 5 . 4 2 3 , 1 7 3 . 9 3 , 1 0 4 . 3 6 1 3 . 4 - 4 , 1 8 3 . 0 5 , 9 7 3 , 3 4 5 . 9 9 4 1 7 , 7 0 7 . 4 4 0 . 0 4 3 , 8 8 2 . 9 6, 2 4 5 . 8 7 9 . 6 4 2 7 5 . 1 9 3 , 1 9 1 . 0 3 , 1 2 1 . 4 6 2 2 . 0 - 4 , 2 7 5 . 9 5 , 9 7 3 , 3 5 5 . 5 8 4 1 7 , 6 1 4 . 6 7 0 . 2 4 3 , 9 6 6 . 5 6, 3 4 0 . 2 7 9 . 6 1 2 7 5 . 2 0 3 , 2 0 7 . 9 3 , 1 3 8 . 3 6 3 0 . 4 - 4 , 3 6 8 . 3 5 , 9 7 3 , 3 6 4 . 9 5 4 1 7 , 5 2 2 . 3 6 0 . 0 3 4 , 0 4 9 . 6 6, 4 3 5 . 0 7 9 . 6 1 2 7 5 . 6 7 3 , 2 2 5 . 0 3, 1 5 5 . 4 63 9 . 3 - 4 , 4 6 1 . 1 5 , 9 7 3 , 3 7 4 . 7 5 4 1 7 , 4 2 9 . 6 2 0 . 4 9 4 , 1 3 3 . 2 6, 5 3 0 . 3 7 9 . 7 0 2 7 6 . 1 3 3 , 2 4 2 . 2 3 , 1 7 2 . 6 6 4 8 . 9 - 4 , 5 5 4 . 4 5 , 9 7 3 , 3 8 5 . 3 5 4 1 7 , 3 3 6 . 5 1 0 . 4 8 4 , 2 1 7 . 7 6, 6 2 4 . 8 7 9 . 8 8 2 7 6 . 2 5 3 , 2 5 8 . 9 3 , 1 8 9 . 3 6 5 8 . 9 - 4 , 6 4 6 . 9 5 , 9 7 3 , 3 9 6 . 3 5 4 1 7 , 2 4 4 . 0 8 0 . 2 3 4 , 3 0 1 . 7 6, 7 1 9 . 7 7 9 . 8 2 2 7 6 . 5 3 3 , 2 7 5 . 6 3 , 2 0 6 . 0 6 6 9 . 3 - 4 , 7 3 9 . 7 5 , 9 7 3 , 4 0 7 . 7 1 4 1 7 , 1 5 1 . 3 8 0 . 3 0 4 , 3 8 6 . 2 6, 8 1 4 . 3 7 9 . 7 9 2 7 6 . 6 5 3 , 2 9 2 . 4 3 , 2 2 2 . 8 6 8 0 . 0 - 4 , 8 3 2 . 2 5 , 9 7 3 , 4 1 9 . 3 5 4 1 7 , 0 5 9 . 0 4 0 . 1 3 4 , 4 7 0 . 5 6, 9 0 8 . 4 7 9 . 7 3 2 7 6 . 2 6 3 , 3 0 9 . 1 3 , 2 3 9 . 5 6 9 0 . 4 - 4 , 9 2 4 . 2 5 , 9 7 3 , 4 3 0 . 7 2 4 1 6 , 9 6 7 . 1 5 0 . 4 1 4 , 5 5 4 . 3 7, 0 0 3 . 2 7 9 . 8 9 2 7 6 . 1 1 3 , 3 2 5 . 9 3 , 2 5 6 . 3 7 0 0 . 5 - 5 , 0 1 6 . 9 5 , 9 7 3 , 4 4 1 . 7 3 4 1 6 , 8 7 4 . 5 4 0 . 2 3 4 , 6 3 8 . 5 7, 0 9 8 . 3 7 9 . 7 3 2 7 5 . 5 9 3 , 3 4 2 . 7 3 , 2 7 3 . 1 7 1 0 . 0 - 5 , 1 1 0 . 1 5 , 9 7 3 , 4 5 2 . 2 5 4 1 6 , 7 8 1 . 4 8 0 . 5 6 4 , 7 2 2 . 8 7, 1 9 3 . 2 7 9 . 7 0 2 7 5 . 8 5 3 , 3 5 9 . 7 3 , 2 9 0 . 1 7 1 9 . 3 - 5 , 2 0 3 . 0 5 , 9 7 3 , 4 6 2 . 5 2 4 1 6 , 6 8 8 . 6 9 0 . 2 7 4 , 8 0 6 . 8 7, 2 8 7 . 9 7 9 . 8 2 2 7 5 . 5 4 3 , 3 7 6 . 5 3 , 3 0 6 . 9 7 2 8 . 6 - 5 , 2 9 5 . 7 5 , 9 7 3 , 4 7 2 . 7 3 4 1 6 , 5 9 6 . 0 5 0 . 3 5 4 , 8 9 0 . 6 7, 3 8 3 . 0 7 9 . 8 6 2 7 5 . 5 3 3 , 3 9 3 . 3 3 , 3 2 3 . 7 7 3 7 . 6 - 5 , 3 8 8 . 9 5 , 9 7 3 , 4 8 2 . 7 3 4 1 6 , 5 0 3 . 0 1 0 . 0 4 4 , 9 7 4 . 7 7, 4 7 7 . 8 7 9 . 7 6 2 7 5 . 8 0 3 , 4 1 0 . 0 3 , 3 4 0 . 4 7 4 6 . 8 - 5 , 4 8 1 . 7 5 , 9 7 3 , 4 9 2 . 9 0 4 1 6 , 4 1 0 . 2 9 0 . 3 0 5 , 0 5 8 . 5 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 6 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 7, 5 7 2 . 1 7 9 . 9 5 27 5 . 9 4 3, 4 2 6 . 6 3 , 3 5 7 . 0 7 5 6 . 3 - 5 , 5 7 4 . 0 5 , 9 7 3 , 5 0 3 . 3 5 4 1 6 , 3 1 8 . 0 9 0 . 2 5 5 , 1 4 2 . 1 7, 6 6 6 . 4 7 9 . 8 8 2 7 6 . 0 5 3 , 4 4 3 . 1 3 , 3 7 3 . 5 7 6 6 . 0 - 5 , 6 6 6 . 4 5 , 9 7 3 , 5 1 4 . 0 1 4 1 6 , 2 2 5 . 8 7 0 . 1 4 5 , 2 2 5 . 8 7, 7 6 1 . 2 7 9 . 7 6 2 7 5 . 9 6 3 , 4 5 9 . 9 3 , 3 9 0 . 3 7 7 5 . 8 - 5 , 7 5 9 . 2 5 , 9 7 3 , 5 2 4 . 7 4 4 1 6 , 1 3 3 . 1 3 0 . 1 6 5 , 3 1 0 . 0 7, 8 5 6 . 5 7 9 . 8 0 2 7 5 . 9 8 3 , 4 7 6 . 8 3 , 4 0 7 . 2 7 8 5 . 5 - 5 , 8 5 2 . 5 5 , 9 7 3 , 5 3 5 . 4 6 4 1 6 , 0 4 0 . 0 1 0 . 0 5 5 , 3 9 4 . 4 7, 9 5 1 . 1 7 9 . 8 9 2 7 6 . 2 2 3 , 4 9 3 . 5 3 , 4 2 3 . 9 7 9 5 . 4 - 5 , 9 4 5 . 1 5 , 9 7 3 , 5 4 6 . 3 3 4 1 5 , 9 4 7 . 4 9 0 . 2 7 5 , 4 7 8 . 5 8, 0 4 6 . 1 7 9 . 7 9 2 7 6 . 2 3 3 , 5 1 0 . 3 3 , 4 4 0 . 7 8 0 5 . 5 - 6 , 0 3 8 . 0 5 , 9 7 3 , 5 5 7 . 4 3 4 1 5 , 8 5 4 . 6 9 0 . 1 1 5 , 5 6 2 . 9 8, 1 3 9 . 6 7 9 . 7 3 2 7 6 . 3 9 3 , 5 2 6 . 9 3 , 4 5 7 . 3 8 1 5 . 7 - 6 , 1 2 9 . 5 5 , 9 7 3 , 5 6 8 . 4 9 4 1 5 , 7 6 3 . 3 7 0 . 1 8 5 , 6 4 6 . 1 8, 2 3 5 . 6 7 9 . 5 7 2 7 6 . 4 5 3 , 5 4 4 . 1 3 , 4 7 4 . 5 8 2 6 . 2 - 6 , 2 2 3 . 3 5 , 9 7 3 , 5 8 0 . 0 3 4 1 5 , 6 6 9 . 6 4 0 . 1 8 5 , 7 3 1 . 5 8, 3 3 0 . 3 7 9 . 5 8 2 7 6 . 3 4 3 , 5 6 1 . 3 3 , 4 9 1 . 7 8 3 6 . 6 - 6 , 3 1 5 . 9 5 , 9 7 3 , 5 9 1 . 3 6 4 1 5 , 5 7 7 . 2 1 0 . 1 1 5 , 8 1 5 . 7 8, 4 2 4 . 9 7 9 . 6 4 2 7 6 . 5 3 3 , 5 7 8 . 3 3 , 5 0 8 . 7 8 4 7 . 0 - 6 , 4 0 8 . 3 5 , 9 7 3 , 6 0 2 . 7 5 4 1 5 , 4 8 4 . 9 0 0 . 2 1 5 , 8 9 9 . 9 8, 5 1 9 . 7 7 9 . 5 7 27 6 . 4 4 3, 5 9 5 . 4 3 , 5 2 5 . 8 8 5 7 . 5 - 6 , 5 0 1 . 0 5 , 9 7 3 , 6 1 4 . 2 5 4 1 5 , 3 9 2 . 3 5 0 . 1 2 5 , 9 8 4 . 3 8, 6 1 3 . 2 7 9 . 6 4 2 7 6 . 3 6 3 , 6 1 2 . 3 3 , 5 4 2 . 7 8 6 7 . 8 - 6 , 5 9 2 . 4 5 , 9 7 3 , 6 2 5 . 4 5 4 1 5 , 3 0 1 . 0 7 0 . 1 1 6 , 0 6 7 . 5 8, 7 0 9 . 4 7 9 . 6 7 2 7 6 . 1 7 3 , 6 2 9 . 6 3 , 5 6 0 . 0 8 7 8 . 1 - 6 , 6 8 6 . 4 5 , 9 7 3 , 6 3 6 . 7 5 4 1 5 , 2 0 7 . 1 2 0 . 2 0 6 , 1 5 3 . 0 8, 8 0 4 . 7 7 9 . 6 0 2 7 6 . 0 2 3 , 6 4 6 . 7 3 , 5 7 7 . 1 8 8 8 . 1 - 6 , 7 7 9 . 6 5 , 9 7 3 , 6 4 7 . 6 8 4 1 5 , 1 1 4 . 0 4 0 . 1 7 6 , 2 3 7 . 6 8, 8 9 8 . 8 7 9 . 7 3 27 6 . 2 4 3, 6 6 3 . 6 3 , 5 9 4 . 0 8 9 8 . 0 - 6 , 8 7 1 . 7 5 , 9 7 3 , 6 5 8 . 5 2 4 1 5 , 0 2 2 . 1 2 0 . 2 7 6 , 3 2 1 . 1 8, 9 9 3 . 2 7 9 . 5 2 2 7 5 . 9 9 3 , 6 8 0 . 6 3 , 6 1 1 . 0 9 0 7 . 9 - 6 , 9 6 4 . 1 5 , 9 7 3 , 6 6 9 . 3 8 4 1 4 , 9 2 9 . 8 3 0 . 3 4 6 , 4 0 5 . 0 9, 0 8 8 . 2 7 9 . 6 1 2 7 5 . 9 6 3 , 6 9 7 . 8 3 , 6 2 8 . 2 9 1 7 . 6 - 7 , 0 5 6 . 9 5 , 9 7 3 , 6 8 0 . 0 6 4 1 4 , 8 3 7 . 0 9 0 . 1 0 6 , 4 8 9 . 1 9, 1 8 2 . 6 7 9 . 7 0 2 7 5 . 7 7 3 , 7 1 4 . 8 3 , 6 4 5 . 2 9 2 7 . 1 - 7 , 1 4 9 . 4 5 , 9 7 3 , 6 9 0 . 5 2 4 1 4 , 7 4 4 . 7 5 0 . 2 2 6 , 5 7 2 . 8 9, 2 7 7 . 1 7 9 . 6 4 2 7 5 . 4 1 3 , 7 3 1 . 7 3 , 6 6 2 . 1 9 3 6 . 1 - 7 , 2 4 1 . 9 5 , 9 7 3 , 7 0 0 . 5 4 4 1 4 , 6 5 2 . 3 4 0 . 3 8 6 , 6 5 6 . 3 9, 3 7 1 . 8 7 9 . 6 7 2 7 5 . 3 9 3 , 7 4 8 . 7 3 , 6 7 9 . 1 9 4 4 . 9 - 7 , 3 3 4 . 6 5 , 9 7 3 , 7 1 0 . 2 6 4 1 4 , 5 5 9 . 7 8 0 . 0 4 6 , 7 3 9 . 8 9, 4 6 4 . 4 79 . 5 7 2 7 5 . 7 8 3 , 7 6 5 . 4 3 , 6 9 5 . 8 9 5 3 . 8 - 7 , 4 2 5 . 3 5 , 9 7 3 , 7 2 0 . 0 7 4 1 4 , 4 6 9 . 1 9 0 . 4 3 6 , 8 2 1 . 7 9, 5 5 8 . 6 7 9 . 6 4 2 7 5 . 8 8 3 , 7 8 2 . 4 3 , 7 1 2 . 8 9 6 3 . 2 - 7 , 5 1 7 . 4 5 , 9 7 3 , 7 3 0 . 4 4 4 1 4 , 3 7 7 . 1 2 0 . 1 3 6 , 9 0 5 . 1 9, 6 5 3 . 4 7 9 . 6 3 2 7 6 . 3 5 3 , 7 9 9 . 4 3 , 7 2 9 . 8 9 7 3 . 1 - 7 , 6 1 0 . 1 5 , 9 7 3 , 7 4 1 . 3 4 4 1 4 , 2 8 4 . 5 6 0 . 4 9 6 , 9 8 9 . 2 9, 6 7 6 . 5 7 9 . 6 3 2 7 7 . 2 0 3 , 8 0 3 . 6 3 , 7 3 4 . 0 9 7 5 . 8 - 7 , 6 3 2 . 7 5 , 9 7 3 , 7 4 4 . 2 6 4 1 4 , 2 6 2 . 0 1 3 . 6 3 7 , 0 0 9 . 8 Na n u s h u k 9, 7 4 7 . 3 7 9 . 6 4 2 7 9 . 8 2 3 , 8 1 6 . 3 3 , 7 4 6 . 7 9 8 6 . 1 - 7 , 7 0 1 . 6 5 , 9 7 3 , 7 5 5 . 2 8 4 1 4 , 1 9 3 . 2 5 3 . 6 3 7 , 0 7 3 . 9 9, 7 9 1 . 7 7 8 . 9 4 2 8 1 . 7 3 3 , 8 2 4 . 6 3 , 7 5 5 . 0 9 9 4 . 3 - 7 , 7 4 4 . 5 5 , 9 7 3 , 7 6 3 . 8 9 4 1 4 , 1 5 0 . 4 4 4 . 5 0 7 , 1 1 4 . 7 NT 8 M F S 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 7 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 9, 8 4 3 . 5 7 8 . 1 5 2 8 3 . 9 6 3 , 8 3 4 . 9 3 , 7 6 5 . 3 1 , 0 0 5 . 5 - 7 , 7 9 3 . 9 5 , 9 7 3 , 7 7 5 . 6 7 4 1 4 , 1 0 1 . 1 3 4 . 5 0 7 , 1 6 2 . 7 9, 9 1 5 . 3 7 8 . 1 8 2 8 5 . 8 3 3 , 8 4 9 . 6 3 , 7 8 0 . 0 1 , 0 2 3 . 6 - 7 , 8 6 1 . 8 5 , 9 7 3 , 7 9 4 . 4 4 4 1 4 , 0 3 3 . 4 1 2 . 5 6 7 , 2 3 0 . 0 NT 7 M F S 9, 9 4 1 . 2 7 8 . 2 0 2 8 6 . 5 1 3 , 8 5 4 . 9 3 , 7 8 5 . 3 1 , 0 3 0 . 6 - 7 , 8 8 6 . 2 5 , 9 7 3 , 8 0 1 . 7 5 4 1 4 , 0 0 9 . 1 5 2 . 5 6 7 , 2 5 4 . 4 10 , 0 3 6 . 5 7 8 . 1 3 2 8 8 . 7 9 3 , 8 7 4 . 5 3 , 8 0 4 . 9 1 , 0 5 9 . 0 - 7 , 9 7 5 . 1 5 , 9 7 3 , 8 3 0 . 9 8 4 1 3 , 9 2 0 . 5 1 2 . 3 4 7 , 3 4 5 . 0 10 , 1 3 0 . 7 7 7 . 4 6 2 9 1 . 7 9 3 , 8 9 4 . 4 3 , 8 2 4 . 8 1 , 0 9 0 . 9 - 8 , 0 6 1 . 4 5 , 9 7 3 , 8 6 3 . 7 8 4 1 3 , 8 3 4 . 5 4 3 . 1 9 7 , 4 3 5 . 2 10 , 2 2 6 . 2 7 7 . 5 1 2 9 5 . 7 4 3 , 9 1 5 . 1 3 , 8 4 5 . 5 1 , 1 2 8 . 4 - 8 , 1 4 6 . 7 5 , 9 7 3 , 9 0 2 . 2 2 4 1 3 , 7 4 9 . 6 5 4 . 0 4 7 , 5 2 7 . 5 10 , 3 2 0 . 7 7 7 . 5 7 2 9 8 . 9 2 3 , 9 3 5 . 5 3 , 8 6 5 . 9 1 , 1 7 0 . 8 - 8 , 2 2 8 . 7 5 , 9 7 3 , 9 4 5 . 4 3 4 1 3 , 6 6 8 . 1 4 3 . 2 9 7 , 6 1 9 . 5 10 , 3 3 9 . 9 7 7 . 5 1 2 9 9 . 5 1 3 , 9 3 9 . 6 3 , 8 7 0 . 0 1 , 1 7 9 . 9 - 8 , 2 4 5 . 0 5 , 9 7 3 , 9 5 4 . 7 3 4 1 3 , 6 5 1 . 9 1 3 . 0 4 7 , 6 3 8 . 2 NT 6 M F S 10 , 4 1 4 . 8 7 7 . 2 9 3 0 1 . 8 4 3 , 9 5 5 . 9 3 , 8 8 6 . 3 1 , 2 1 7 . 2 - 8 , 3 0 7 . 9 5 , 9 7 3 , 9 9 2 . 6 9 4 1 3 , 5 8 9 . 4 1 3 . 0 4 7 , 7 1 1 . 3 10 , 5 0 6 . 9 7 7 . 0 3 3 0 5 . 3 3 3 , 9 7 6 . 4 3 , 9 0 6 . 8 1 , 2 6 6 . 9 - 8 , 3 8 2 . 7 5 , 9 7 4 , 0 4 3 . 1 1 4 1 3 , 5 1 5 . 1 7 3 . 7 1 7 , 8 0 1 . 0 10 , 5 3 4 . 4 7 7 . 0 1 3 0 6 . 4 3 3 , 9 8 2 . 6 3 , 9 1 3 . 0 1 , 2 8 2 . 6 - 8 , 4 0 4 . 4 5 , 9 7 4 , 0 5 9 . 0 5 4 1 3 , 4 9 3 . 6 0 3 . 9 0 7 , 8 2 7 . 8 NT 5 M F S 10 , 6 0 5 . 5 7 6 . 9 7 3 0 9 . 2 8 3 , 9 9 8 . 6 3 , 9 2 9 . 0 1 , 3 2 5 . 1 - 8 , 4 5 9 . 1 5 , 9 7 4 , 1 0 2 . 1 2 4 1 3 , 4 3 9 . 3 7 3 . 9 0 7 , 8 9 6 . 6 10 , 6 4 0 . 7 7 6 . 9 0 3 1 1 . 1 1 4 , 0 0 6 . 6 3 , 9 3 7 . 0 1 , 3 4 7 . 2 - 8 , 4 8 5 . 3 5 , 9 7 4 , 1 2 4 . 5 0 4 1 3 , 4 1 3 . 4 4 5 . 0 7 7 , 9 3 0 . 5 10 , 6 6 8 . 1 7 7 . 0 1 3 1 2 . 4 1 4 , 0 1 2 . 8 3 , 9 4 3 . 2 1 , 3 6 5 . 0 - 8 , 5 0 5 . 2 5 , 9 7 4 , 1 4 2 . 5 1 4 1 3 , 3 9 3 . 6 8 4 . 6 3 7 , 9 5 6 . 8 10 , 6 9 9 . 0 7 6 . 9 7 3 1 3 . 7 8 4 , 0 1 9 . 7 3 , 9 5 0 . 1 1 , 3 8 5 . 6 - 8 , 5 2 7 . 2 5 , 9 7 4 , 1 6 3 . 3 3 4 1 3 , 3 7 1 . 8 8 4 . 3 1 7 , 9 8 6 . 4 10 , 7 3 8 . 4 7 6 . 9 3 3 1 5 . 7 5 4 , 0 2 8 . 6 3 , 9 5 9 . 0 1 , 4 1 2 . 6 - 8 , 5 5 4 . 4 5 , 9 7 4 , 1 9 0 . 5 8 4 1 3 , 3 4 4 . 9 8 4 . 8 7 8 , 0 2 3 . 7 NT 4 M F S 10 , 7 9 4 . 2 7 6 . 9 0 31 8 . 5 4 4, 0 4 1 . 2 3 , 9 7 1 . 6 1 , 4 5 2 . 4 - 8 , 5 9 1 . 4 5 , 9 7 4 , 2 3 0 . 8 2 4 1 3 , 3 0 8 . 4 1 4 . 8 7 8 , 0 7 6 . 1 10 , 8 8 8 . 4 7 6 . 9 4 3 2 2 . 9 3 4 , 0 6 2 . 6 3 , 9 9 3 . 0 1 , 5 2 3 . 5 - 8 , 6 4 9 . 5 5 , 9 7 4 , 3 0 2 . 4 5 4 1 3 , 2 5 1 . 0 9 4. 5 4 8, 1 6 2 . 8 10 , 9 8 3 . 8 7 7 . 0 4 3 2 6 . 5 2 4 , 0 8 4 . 1 4 , 0 1 4 . 5 1 , 5 9 9 . 3 - 8 , 7 0 3 . 2 5 , 9 7 4 , 3 7 8 . 8 7 4 1 3 , 1 9 8 . 2 2 3 . 6 7 8 , 2 4 8 . 3 11 , 0 7 2 . 6 7 7 . 5 3 3 3 0 . 6 3 4 , 1 0 3 . 6 4 , 0 3 4 . 0 1 , 6 7 3 . 2 - 8 , 7 4 8 . 3 5 , 9 7 4 , 4 5 3 . 2 0 4 1 3 , 1 5 3 . 8 6 4 . 5 5 8 , 3 2 5 . 5 NT 3 M F S 11 , 0 7 8 . 5 7 7 . 5 7 3 3 0 . 9 0 4 , 1 0 4 . 9 4 , 0 3 5 . 3 1 , 6 7 8 . 3 - 8 , 7 5 1 . 1 5 , 9 7 4 , 4 5 8 . 2 7 4 1 3 , 1 5 1 . 0 9 4 . 5 5 8 , 3 3 0 . 5 11 , 1 1 4 . 0 7 8 . 3 3 3 3 1 . 2 1 4 , 1 1 2 . 3 4 , 0 4 2 . 7 1 , 7 0 8 . 6 - 8 , 7 6 7 . 9 5 , 9 7 4 , 4 8 8 . 8 2 4 1 3 , 1 3 4 . 6 0 2 . 3 0 8 , 3 6 0 . 7 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 8 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 11 , 1 4 3 . 8 7 8 . 9 7 3 3 1 . 4 6 4 , 1 1 8 . 2 4 , 0 4 8 . 6 1 , 7 3 4 . 3 - 8 , 7 8 1 . 9 5 , 9 7 4 , 5 1 4 . 6 2 4 1 3 , 1 2 0 . 8 5 2 . 3 0 8 , 3 8 6 . 1 11 , 1 8 3 . 5 7 9 . 4 1 3 3 1 . 9 9 4 , 1 2 5 . 6 4 , 0 5 6 . 0 1 , 7 6 8 . 6 - 8 , 8 0 0 . 4 5 , 9 7 4 , 5 4 9 . 1 4 4 1 3 , 1 0 2 . 7 4 1 . 7 1 8 , 4 1 9 . 9 NT 3 . 2 T o p R e s e r v o i r 11 , 1 9 2 . 0 7 9 . 5 0 3 3 2 . 1 0 4 , 1 2 7 . 2 4 , 0 5 7 . 6 1 , 7 7 6 . 0 - 8 , 8 0 4 . 3 5 , 9 7 4 , 5 5 6 . 5 9 4 1 3 , 0 9 8 . 8 9 1 . 7 1 8 , 4 2 7 . 1 11 , 2 8 7 . 8 8 1 . 4 0 3 3 2 . 3 9 4 , 1 4 3 . 0 4, 0 7 3 . 4 1, 8 5 9 . 6 - 8 , 8 4 8 . 3 5 , 9 7 4 , 6 4 0 . 5 7 4 1 3 , 0 5 5 . 8 0 2 . 0 1 8 , 5 0 8 . 4 11 , 3 8 2 . 0 8 4 . 3 8 3 3 1 . 3 5 4 , 1 5 4 . 7 4 , 0 8 5 . 1 1 , 9 4 2 . 0 - 8 , 8 9 2 . 4 5 , 9 7 4 , 7 2 3 . 4 2 4 1 3 , 0 1 2 . 6 1 3 . 3 5 8 , 5 8 9 . 1 11 , 4 7 8 . 0 8 7 . 6 1 3 3 0 . 2 3 4 , 1 6 1 . 4 4 , 0 9 1 . 8 2 , 0 2 5 . 6 - 8 , 9 3 9 . 1 5 , 9 7 4 , 8 0 7 . 5 1 4 1 2 , 9 6 6 . 7 4 3 . 5 6 8 , 6 7 2 . 8 11 , 5 7 2 . 0 8 8 . 5 0 3 2 9 . 7 2 4 , 1 6 4 . 6 4 , 0 9 5 . 0 2 , 1 0 6 . 9 - 8 , 9 8 6 . 1 5 , 9 7 4 , 8 8 9 . 3 3 4 1 2 , 9 2 0 . 5 8 1 . 0 9 8 , 7 5 5 . 5 11 , 6 6 6 . 9 8 8 . 7 4 3 2 9 . 6 2 4 , 1 6 6 . 9 4 , 0 9 7 . 3 2 , 1 8 8 . 8 - 9 , 0 3 4 . 0 5 , 9 7 4 , 9 7 1 . 7 4 4 1 2 , 8 7 3 . 5 1 0 . 2 7 8 , 8 3 9 . 3 11 , 7 6 3 . 1 9 0 . 2 1 3 3 0 . 7 0 4 , 1 6 7 . 8 4 , 0 9 8 . 2 2 , 2 7 2 . 2 - 9 , 0 8 1 . 9 5 , 9 7 5 , 0 5 5 . 5 9 4 1 2 , 8 2 6 . 5 6 1 . 9 0 8 , 9 2 3 . 7 11 , 8 5 6 . 8 9 0 . 0 9 33 0 . 8 4 4, 1 6 7 . 5 4 , 0 9 7 . 9 2 , 3 5 4 . 0 - 9 , 1 2 7 . 6 5 , 9 7 5 , 1 3 7 . 8 4 4 1 2 , 7 8 1 . 6 6 0 . 2 0 9 , 0 0 5 . 6 11 , 9 5 3 . 5 9 0 . 2 2 3 3 0 . 7 3 4 , 1 6 7 . 3 4 , 0 9 7 . 7 2 , 4 3 8 . 4 - 9 , 1 7 4 . 8 5 , 9 7 5 , 2 2 2 . 7 4 4 1 2 , 7 3 5 . 3 3 0 . 1 8 9 , 0 9 0 . 1 12 , 0 4 8 . 2 9 0 . 4 3 3 3 0 . 1 6 4 , 1 6 6 . 7 4 , 0 9 7 . 1 2 , 5 2 0 . 8 - 9 , 2 2 1 . 5 5 , 9 7 5 , 3 0 5 . 5 6 4 1 2 , 6 8 9 . 5 0 0 . 6 4 9 , 1 7 3 . 0 12 , 1 4 3 . 4 9 0 . 1 8 3 2 9 . 5 6 4 , 1 6 6 . 2 4 , 0 9 6 . 6 2 , 6 0 3 . 1 - 9 , 2 6 9 . 4 5 , 9 7 5 , 3 8 8 . 4 2 4 1 2 , 6 4 2 . 5 4 0 . 6 8 9 , 2 5 6 . 9 12 , 2 3 8 . 5 9 0 . 1 8 3 2 9 . 6 9 4 , 1 6 5 . 9 4 , 0 9 6 . 3 2 , 6 8 5 . 2 - 9 , 3 1 7 . 4 5 , 9 7 5 , 4 7 0 . 9 3 4 1 2 , 5 9 5 . 3 3 0 . 1 4 9 , 3 4 0 . 9 12 , 3 3 3 . 5 9 0 . 3 7 3 2 9 . 7 8 4 , 1 6 5 . 5 4 , 0 9 5 . 9 2 , 7 6 7 . 2 - 9 , 3 6 5 . 3 5 , 9 7 5 , 5 5 3 . 4 8 4 1 2 , 5 4 8 . 3 0 0 . 2 2 9 , 4 2 4 . 7 12 , 4 2 8 . 1 9 0 . 2 1 3 2 9 . 3 2 4 , 1 6 5 . 0 4 , 0 9 5 . 4 2 , 8 4 8 . 8 - 9 , 4 1 3 . 3 5 , 9 7 5 , 6 3 5 . 5 0 4 1 2 , 5 0 1 . 2 3 0 . 5 1 9 , 5 0 8 . 3 12 , 5 2 3 . 7 9 0 . 1 2 3 2 9 . 4 3 4 , 1 6 4 . 7 4 , 0 9 5 . 1 2 , 9 3 1 . 1 - 9 , 4 6 2 . 0 5 , 9 7 5 , 7 1 8 . 3 0 4 1 2 , 4 5 3 . 3 7 0 . 1 5 9 , 5 9 3 . 0 12 , 6 1 9 . 6 8 9 . 9 1 32 9 . 1 4 4, 1 6 4 . 7 4 , 0 9 5 . 1 3 , 0 1 3 . 5 - 9 , 5 1 0 . 9 5 , 9 7 5 , 8 0 1 . 2 1 4 1 2 , 4 0 5 . 2 8 0 . 3 7 9 , 6 7 7 . 9 12 , 7 1 4 . 2 8 9 . 7 5 3 2 8 . 6 5 4 , 1 6 5 . 0 4 , 0 9 5 . 4 3 , 0 9 4 . 5 - 9 , 5 5 9 . 8 5 , 9 7 5 , 8 8 2 . 6 9 4 1 2 , 3 5 7 . 2 7 0 . 5 4 9 , 7 6 2 . 0 12 , 8 0 9 . 3 9 0 . 0 3 3 2 9 . 5 8 4 , 1 6 5 . 1 4 , 0 9 5 . 5 3 , 1 7 6 . 1 - 9 , 6 0 8 . 6 5 , 9 7 5 , 9 6 4 . 8 1 4 1 2 , 3 0 9 . 3 0 1 . 0 2 9 , 8 4 6 . 4 12 , 9 0 3 . 9 9 0 . 2 8 3 2 9 . 3 5 4 , 1 6 4 . 9 4 , 0 9 5 . 3 3 , 2 5 7 . 6 - 9 , 6 5 6 . 7 5 , 9 7 6 , 0 4 6 . 7 7 4 1 2 , 2 6 2 . 1 0 0 . 3 6 9 , 9 3 0 . 0 12 , 9 9 8 . 9 9 0 . 2 1 3 2 9 . 4 1 4 , 1 6 4 . 5 4 , 0 9 4 . 9 3 , 3 3 9 . 3 - 9 , 7 0 5 . 1 5 , 9 7 6 , 1 2 9 . 0 2 4 1 2 , 2 1 4 . 5 7 0 . 1 0 1 0 , 0 1 4 . 1 13 , 0 9 4 . 0 9 0 . 2 1 3 2 8 . 8 3 4 , 1 6 4 . 1 4 , 0 9 4 . 5 3 , 4 2 1 . 0 - 9 , 7 5 3 . 9 5 , 9 7 6 , 2 1 1 . 1 9 4 1 2 , 1 6 6 . 5 9 0 . 6 1 1 0 , 0 9 8 . 5 13 , 1 8 9 . 0 9 0 . 1 8 3 2 8 . 8 1 4 , 1 6 3 . 8 4 , 0 9 4 . 2 3 , 5 0 2 . 2 - 9 , 8 0 3 . 1 5 , 9 7 6 , 2 9 2 . 9 0 4 1 2 , 1 1 8 . 2 9 0 . 0 4 1 0 , 1 8 3 . 0 13 , 2 8 3 . 7 9 0 . 1 2 3 2 8 . 7 5 4 , 1 6 3 . 6 4 , 0 9 4 . 0 3 , 5 8 3 . 2 - 9 , 8 5 2 . 1 5 , 9 7 6 , 3 7 4 . 3 9 4 1 2 , 0 7 0 . 0 6 0 . 0 9 1 0 , 2 6 7 . 2 13 , 3 7 9 . 1 9 0 . 1 2 3 2 8 . 8 0 4 , 1 6 3 . 4 4 , 0 9 3 . 8 3 , 6 6 4 . 8 - 9 , 9 0 1 . 6 5 , 9 7 6 , 4 5 6 . 5 0 4 1 2 , 0 2 1 . 4 4 0 . 0 5 1 0 , 3 5 2 . 2 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 9 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 13 , 4 7 4 . 1 9 0 . 2 1 3 2 8 . 7 9 4 , 1 6 3 . 1 4 , 0 9 3 . 5 3 , 7 4 6 . 0 - 9 , 9 5 0 . 8 5 , 9 7 6 , 5 3 8 . 2 3 4 1 1 , 9 7 3 . 0 9 0 . 1 0 1 0 , 4 3 6 . 7 13 , 5 6 8 . 8 9 0 . 1 8 3 2 8 . 9 0 4 , 1 6 2 . 8 4 , 0 9 3 . 2 3 , 8 2 7 . 1 - 9 , 9 9 9 . 8 5 , 9 7 6 , 6 1 9 . 7 7 4 1 1 , 9 2 4 . 9 5 0 . 1 2 1 0 , 5 2 0 . 9 13 , 6 6 4 . 8 9 0 . 1 8 3 2 9 . 3 3 4 , 1 6 2 . 5 4 , 0 9 2 . 9 3 , 9 0 9 . 5 - 1 0 , 0 4 9 . 1 5 , 9 7 6 , 7 0 2 . 7 0 4 1 1 , 8 7 6 . 5 1 0 . 4 5 1 0 , 6 0 6 . 1 13 , 7 5 8 . 8 9 0 . 1 8 3 2 9 . 5 1 4 , 1 6 2 . 2 4 , 0 9 2 . 6 3 , 9 9 0 . 4 - 1 0 , 0 9 6 . 9 5 , 9 7 6 , 7 8 4 . 0 6 4 1 1 , 8 2 9 . 5 7 0 . 1 9 1 0 , 6 8 9 . 2 13 , 8 5 4 . 2 9 0 . 1 5 3 2 9 . 8 1 4 , 1 6 1 . 9 4 , 0 9 2 . 3 4 , 0 7 2 . 7 - 1 0 , 1 4 5 . 1 5 , 9 7 6 , 8 6 6 . 9 0 4 1 1 , 7 8 2 . 2 4 0 . 3 2 1 0 , 7 7 3 . 5 13 , 9 4 9 . 6 9 0 . 1 5 3 2 9 . 8 1 4 , 1 6 1 . 6 4 , 0 9 2 . 0 4 , 1 5 5 . 2 - 1 0 , 1 9 3 . 1 5 , 9 7 6 , 9 4 9 . 8 7 4 1 1 , 7 3 5 . 1 1 0 . 0 0 1 0 , 8 5 7 . 6 14 , 0 4 4 . 8 9 0 . 2 1 3 2 9 . 9 2 4 , 1 6 1 . 3 4 , 0 9 1 . 7 4 , 2 3 7 . 5 - 1 0 , 2 4 0 . 9 5 , 9 7 7 , 0 3 2 . 6 7 4 1 1 , 6 8 8 . 1 9 0 . 1 3 1 0 , 9 4 1 . 5 14 , 1 4 0 . 1 9 0 . 1 5 3 2 9 . 8 2 4 , 1 6 1 . 0 4 , 0 9 1 . 4 4 , 3 2 0 . 0 - 1 0 , 2 8 8 . 7 5 , 9 7 7 , 1 1 5 . 6 1 4 1 1 , 6 4 1 . 2 1 0 . 1 2 1 1 , 0 2 5 . 5 14 , 2 3 4 . 8 9 0 . 1 5 3 2 9 . 8 7 4 , 1 6 0 . 8 4 , 0 9 1 . 2 4 , 4 0 1 . 8 - 1 0 , 3 3 6 . 3 5 , 9 7 7 , 1 9 7 . 9 5 4 1 1 , 5 9 4 . 5 1 0 . 0 5 1 1 , 1 0 8 . 9 14 , 3 3 0 . 1 9 0 . 1 8 3 2 9 . 7 8 4 , 1 6 0 . 5 4 , 0 9 0 . 9 4 , 4 8 4 . 2 - 1 0 , 3 8 4 . 2 5 , 9 7 7 , 2 8 0 . 8 0 4 1 1 , 5 4 7 . 4 9 0 . 1 0 1 1 , 1 9 2 . 9 14 , 4 2 4 . 7 9 0 . 2 5 32 9 . 7 4 4, 1 6 0 . 2 4 , 0 9 0 . 6 4 , 5 6 5 . 9 - 1 0 , 4 3 1 . 8 5 , 9 7 7 , 3 6 3 . 0 2 4 1 1 , 5 0 0 . 7 0 0 . 0 9 1 1 , 2 7 6 . 3 14 , 5 2 0 . 6 9 0 . 1 5 3 2 9 . 5 3 4 , 1 5 9 . 8 4 , 0 9 0 . 2 4 , 6 4 8 . 7 - 1 0 , 4 8 0 . 3 5 , 9 7 7 , 4 4 6 . 2 6 4 1 1 , 4 5 3 . 0 9 0 . 2 4 1 1 , 3 6 1 . 0 14 , 6 1 4 . 4 9 0 . 2 1 3 2 8 . 9 1 4 , 1 5 9 . 5 4 , 0 8 9 . 9 4 , 7 2 9 . 3 - 1 0 , 5 2 8 . 3 5 , 9 7 7 , 5 2 7 . 3 7 4 1 1 , 4 0 5 . 9 1 0 . 6 6 1 1 , 4 4 4 . 2 14 , 7 1 0 . 2 9 0 . 1 8 3 2 9 . 4 0 4 , 1 5 9 . 2 4 , 0 8 9 . 6 4 , 8 1 1 . 6 - 1 0 , 5 7 7 . 5 5 , 9 7 7 , 6 1 0 . 1 4 4 1 1 , 3 5 7 . 6 4 0 . 5 1 1 1 , 5 2 9 . 2 14 , 8 0 5 . 2 9 0 . 2 1 3 2 9 . 4 0 4 , 1 5 8 . 9 4 , 0 8 9 . 3 4 , 8 9 3 . 3 - 1 0 , 6 2 5 . 8 5 , 9 7 7 , 6 9 2 . 3 4 4 1 1 , 3 1 0 . 1 8 0 . 0 3 1 1 , 6 1 3 . 2 14 , 8 9 9 . 2 9 0 . 1 8 3 2 9 . 3 5 4 , 1 5 8 . 6 4 , 0 8 9 . 0 4 , 9 7 4 . 2 - 1 0 , 6 7 3 . 7 5 , 9 7 7 , 7 7 3 . 7 1 4 1 1 , 2 6 3 . 1 5 0 . 0 6 1 1 , 6 9 6 . 4 14 , 9 9 4 . 8 9 0 . 1 8 3 2 9 . 6 0 4 , 1 5 8 . 3 4 , 0 8 8 . 7 5 , 0 5 6 . 5 - 1 0 , 7 2 2 . 2 5 , 9 7 7 , 8 5 6 . 5 6 4 1 1 , 2 1 5 . 4 6 0 . 2 6 1 1 , 7 8 0 . 9 15 , 0 8 9 . 9 9 0 . 1 8 3 2 9 . 6 2 4 , 1 5 8 . 0 4, 0 8 8 . 4 5, 1 3 8 . 6 - 1 0 , 7 7 0 . 4 5 , 9 7 7 , 9 3 9 . 1 3 4 1 1 , 1 6 8 . 1 8 0 . 0 2 1 1 , 8 6 5 . 0 15 , 1 8 5 . 2 9 0 . 1 5 3 2 9 . 7 4 4 , 1 5 7 . 7 4 , 0 8 8 . 1 5 , 2 2 0 . 9 - 1 0 , 8 1 8 . 5 5 , 9 7 8 , 0 2 1 . 9 0 4 1 1 , 1 2 0 . 9 2 0 . 1 3 1 1 , 9 4 9 . 1 15 , 2 8 0 . 0 9 0 . 1 5 3 2 9 . 8 3 4 , 1 5 7 . 4 4 , 0 8 7 . 8 5 , 3 0 2 . 7 - 1 0 , 8 6 6 . 1 5 , 9 7 8 , 1 0 4 . 2 4 4 1 1 , 0 7 4 . 1 2 0 . 1 0 1 2 , 0 3 2 . 6 15 , 3 7 5 . 2 9 0 . 2 1 3 3 0 . 0 0 4 , 1 5 7 . 1 4 , 0 8 7 . 5 5 , 3 8 5 . 1 - 1 0 , 9 1 3 . 9 5 , 9 7 8 , 1 8 7 . 1 2 4 1 1 , 0 2 7 . 2 4 0 . 1 9 1 2 , 1 1 6 . 5 15 , 4 7 0 . 2 9 0 . 2 2 3 3 0 . 0 7 4 , 1 5 6 . 8 4 , 0 8 7 . 2 5 , 4 6 7 . 4 - 1 0 , 9 6 1 . 3 5 , 9 7 8 , 2 6 9 . 8 7 4 1 0 , 9 8 0 . 6 8 0 . 0 7 1 2 , 2 0 0 . 0 15 , 5 6 5 . 3 9 0 . 2 5 3 3 0 . 2 3 4 , 1 5 6 . 4 4 , 0 8 6 . 8 5 , 5 4 9 . 9 - 1 1 , 0 0 8 . 7 5 , 9 7 8 , 3 5 2 . 8 7 4 1 0 , 9 3 4 . 1 9 0 . 1 7 1 2 , 2 8 3 . 6 15 , 6 6 0 . 1 9 0 . 2 1 3 3 0 . 0 1 4 , 1 5 6 . 0 4 , 0 8 6 . 4 5 , 6 3 2 . 1 - 1 1 , 0 5 5 . 9 5 , 9 7 8 , 4 3 5 . 5 1 4 1 0 , 8 8 7 . 8 5 0 . 2 4 1 2 , 3 6 6 . 9 15 , 7 5 5 . 4 9 0 . 1 8 3 2 9 . 9 1 4 , 1 5 5 . 7 4 , 0 8 6 . 1 5 , 7 1 4 . 6 - 1 1 , 1 0 3 . 6 5 , 9 7 8 , 5 1 8 . 5 0 4 1 0 , 8 4 1 . 0 0 0 . 1 1 1 2 , 4 5 0 . 8 15 , 8 5 0 . 2 9 0 . 1 8 3 2 9 . 4 6 4 , 1 5 5 . 4 4 , 0 8 5 . 8 5 , 7 9 6 . 5 - 1 1 , 1 5 1 . 5 5 , 9 7 8 , 6 0 0 . 8 8 4 1 0 , 7 9 3 . 9 8 0 . 4 7 1 2 , 5 3 4 . 6 15 , 9 4 5 . 4 9 0 . 2 5 3 2 9 . 3 9 4 , 1 5 5 . 0 4 , 0 8 5 . 4 5 , 8 7 8 . 4 - 1 1 , 1 9 9 . 9 5 , 9 7 8 , 6 8 3 . 2 9 4 1 0 , 7 4 6 . 4 4 0 . 1 0 1 2 , 6 1 8 . 8 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 1 0 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e MD (us f t ) In c (° ) Az i (az i m u t h ) (° ) N/ S (us f t ) E/ W (us f t ) No r t h i n g (us f t ) TV D S S (us f t ) Ea s t i n g (us f t ) Su r v e y TV D (us f t ) DL e g (° / 10 0 u s f t ) V. S e c (us f t ) 16 , 0 4 0 . 3 9 0 . 1 8 3 2 9 . 0 9 4 , 1 5 4 . 7 4 , 0 8 5 . 1 5 , 9 5 9 . 9 - 1 1 , 2 4 8 . 4 5 , 9 7 8 , 7 6 5 . 3 2 4 1 0 , 6 9 8 . 7 7 0 . 3 2 1 2 , 7 0 2 . 8 16 , 1 3 4 . 6 9 0 . 2 5 3 2 9 . 1 3 4 , 1 5 4 . 3 4 , 0 8 4 . 7 6 , 0 4 0 . 9 - 1 1 , 2 9 6 . 8 5 , 9 7 8 , 8 4 6 . 7 9 4 1 0 , 6 5 1 . 1 7 0 . 0 9 1 2 , 7 8 6 . 6 16 , 2 2 9 . 7 9 0 . 1 5 3 2 8 . 8 4 4 , 1 5 4 . 0 4 , 0 8 4 . 4 6 , 1 2 2 . 3 - 1 1 , 3 4 5 . 8 5 , 9 7 8 , 9 2 8 . 7 3 4 1 0 , 6 0 3 . 0 6 0 . 3 2 1 2 , 8 7 1 . 0 16 , 3 2 5 . 2 9 0 . 1 2 3 2 8 . 6 9 4 , 1 5 3 . 8 4 , 0 8 4 . 2 6 , 2 0 4 . 0 - 1 1 , 3 9 5 . 3 5 , 9 7 9 , 0 1 0 . 9 3 4 1 0 , 5 5 4 . 3 8 0 . 1 6 1 2 , 9 5 6 . 0 16 , 4 2 0 . 4 9 0 . 1 5 3 2 8 . 6 5 4 , 1 5 3 . 6 4 , 0 8 4 . 0 6 , 2 8 5 . 4 - 1 1 , 4 4 4 . 9 5 , 9 7 9 , 0 9 2 . 7 7 4 1 0 , 5 0 5 . 7 2 0 . 0 5 1 3 , 0 4 0 . 8 16 , 5 1 5 . 5 9 0 . 2 5 3 2 8 . 9 0 4 , 1 5 3 . 2 4 , 0 8 3 . 6 6 , 3 6 6 . 7 - 1 1 , 4 9 4 . 1 5 , 9 7 9 , 1 7 4 . 5 5 4 1 0 , 4 5 7 . 3 0 0 . 2 8 1 3 , 1 2 5 . 4 16 , 6 1 0 . 0 9 0 . 1 8 32 8 . 6 4 4, 1 5 2 . 9 4 , 0 8 3 . 3 6 , 4 4 7 . 5 - 1 1 , 5 4 3 . 2 5 , 9 7 9 , 2 5 5 . 9 2 4 1 0 , 4 0 9 . 1 2 0 . 2 8 1 3 , 2 0 9 . 6 16 , 7 0 5 . 3 9 0 . 1 8 3 2 8 . 4 0 4 , 1 5 2 . 6 4 , 0 8 3 . 0 6 , 5 2 8 . 8 - 1 1 , 5 9 2 . 9 5 , 9 7 9 , 3 3 7 . 6 6 4 1 0 , 3 6 0 . 2 3 0 . 2 5 1 3 , 2 9 4 . 6 16 , 7 9 9 . 5 9 0 . 2 1 3 2 9 . 1 2 4 , 1 5 2 . 2 4 , 0 8 2 . 6 6 , 6 0 9 . 3 - 1 1 , 6 4 1 . 7 5 , 9 7 9 , 4 1 8 . 6 7 4 1 0 , 3 1 2 . 2 4 0 . 7 7 1 3 , 3 7 8 . 4 16 , 8 9 5 . 9 9 0 . 1 8 3 2 9 . 1 6 4 , 1 5 1 . 9 4 , 0 8 2 . 3 6 , 6 9 2 . 0 - 1 1 , 6 9 1 . 2 5 , 9 7 9 , 5 0 1 . 9 2 4 1 0 , 2 6 3 . 6 6 0 . 0 5 1 3 , 4 6 3 . 9 16 , 9 9 0 . 0 9 0 . 1 8 3 2 8 . 9 9 4 , 1 5 1 . 6 4 , 0 8 2 . 0 6 , 7 7 2 . 7 - 1 1 , 7 3 9 . 6 5 , 9 7 9 , 5 8 3 . 1 4 4 1 0 , 2 1 6 . 1 5 0 . 1 8 1 3 , 5 4 7 . 4 17 , 0 8 6 . 3 9 0 . 1 2 3 2 9 . 5 4 4 , 1 5 1 . 4 4 , 0 8 1 . 8 6 , 8 5 5 . 5 - 1 1 , 7 8 8 . 8 5 , 9 7 9 , 6 6 6 . 4 3 4 1 0 , 1 6 7 . 7 9 0 . 5 7 1 3 , 6 3 2 . 8 17 , 1 8 1 . 0 9 0 . 1 5 3 2 9 . 5 3 4 , 1 5 1 . 1 4 , 0 8 1 . 5 6 , 9 3 7 . 2 - 1 1 , 8 3 6 . 8 5 , 9 7 9 , 7 4 8 . 5 3 4 1 0 , 1 2 0 . 6 4 0 . 0 3 1 3 , 7 1 6 . 4 17 , 2 7 4 . 8 9 0 . 1 8 3 2 9 . 3 1 4 , 1 5 0 . 9 4 , 0 8 1 . 3 7 , 0 1 7 . 9 - 1 1 , 8 8 4 . 5 5 , 9 7 9 , 8 2 9 . 7 5 4 1 0 , 0 7 3 . 7 8 0 . 2 4 1 3 , 7 9 9 . 4 17 , 3 7 0 . 7 9 0 . 1 8 3 2 9 . 5 3 4 , 1 5 0 . 6 4 , 0 8 1 . 0 7 , 1 0 0 . 5 - 1 1 , 9 3 3 . 3 5 , 9 7 9 , 9 1 2 . 8 7 4 1 0 , 0 2 5 . 8 2 0 . 2 3 1 3 , 8 8 4 . 3 17 , 4 6 4 . 6 9 0 . 2 2 3 2 9 . 2 1 4 , 1 5 0 . 2 4 , 0 8 0 . 6 7 , 1 8 1 . 3 - 1 1 , 9 8 1 . 2 5 , 9 7 9 , 9 9 4 . 1 6 4 0 9 , 9 7 8 . 8 3 0 . 3 4 1 3 , 9 6 7 . 5 17 , 5 6 0 . 3 9 0 . 2 5 3 2 9 . 1 7 4 , 1 4 9 . 9 4 , 0 8 0 . 3 7 , 2 6 3 . 5 - 1 2 , 0 3 0 . 1 5 , 9 8 0 , 0 7 6 . 8 0 4 0 9 , 9 3 0 . 7 1 0 . 0 5 1 4 , 0 5 2 . 2 17 , 6 5 5 . 7 9 0 . 2 1 3 2 9 . 2 3 4 , 1 4 9 . 5 4 , 0 7 9 . 9 7 , 3 4 5 . 4 - 1 2 , 0 7 9 . 0 5 , 9 8 0 , 1 5 9 . 2 6 4 0 9 , 8 8 2 . 7 0 0 . 0 8 1 4 , 1 3 6 . 9 17 , 7 5 0 . 2 9 0 . 1 8 32 8 . 5 4 4, 1 4 9 . 1 4 , 0 7 9 . 5 7 , 4 2 6 . 3 - 1 2 , 1 2 7 . 8 5 , 9 8 0 , 2 4 0 . 6 4 4 0 9 , 8 3 4 . 7 4 0 . 7 3 1 4 , 2 2 0 . 8 17 , 8 0 9 . 5 9 0 . 1 5 3 2 8 . 9 8 4 , 1 4 9 . 0 4 , 0 7 9 . 4 7 , 4 7 7 . 1 - 1 2 , 1 5 8 . 6 5 , 9 8 0 , 2 9 1 . 7 1 4 0 9 , 8 0 4 . 4 8 0 . 7 4 1 4 , 2 7 3 . 7 17 , 8 3 2 . 0 9 0 . 1 5 3 2 8 . 9 8 4 , 1 4 8 . 9 4 , 0 7 9 . 3 7 , 4 9 6 . 3 - 1 2 , 1 7 0 . 2 5 , 9 8 0 , 3 1 1 . 0 8 4 0 9 , 7 9 3 . 1 1 0 . 0 0 1 4 , 2 9 3 . 6 4- 1 / 2 " P r o d u c t i o n C a s i n g 17 , 8 3 9 . 0 9 0 . 1 5 3 2 8 . 9 8 4 , 1 4 8 . 9 4 , 0 7 9 . 3 7 , 5 0 2 . 3 - 1 2 , 1 7 3 . 8 5 , 9 8 0 , 3 1 7 . 1 1 4 0 9 , 7 8 9 . 5 6 0 . 0 0 1 4 , 2 9 9 . 9 Pr o j e c t i o n 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 1 1 Pr o j e c t : Co m p a n y : Lo c a l C o -or d i n a t e R e f e r e n c e : TV D R e f e r e n c e : Si t e : Sa n t o s N A D 2 7 C o n v e r s i o n Pi k k a ND B Sa n t o s D e f i n i t i v e S u r v e y R e p o r t We l l : We l l b o r e : ND B i - 0 4 4 ND B i - 0 4 4 Su r v e y C a l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t De s i g n : ND B i - 0 4 4 Da t a b a s e : ED M S T O A l a s k a MD R e f e r e n c e : Pa r k e r 2 7 2 A s D r i l l e d @ 6 9 . 6 u s f t No r t h R e f e r e n c e : We l l N D B i -04 4 Tr u e Ve r t i c a l De p t h (us f t ) Me a s u r e d De p t h (us f t ) Ca s i n g Di a m e t e r (" ) Ho l e Di a m e t e r (" ) Na m e Ca s i n g P o i n t s 20 " C o n d u c t o r C a s i n g 12 8 . 0 12 8 . 0 20 2 0 13 - 3 / 8 " S u r f a c e C a s i n g 2, 2 9 9 . 7 2, 5 1 4 . 0 13 - 3 / 8 1 6 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 4, 1 1 2 . 3 11 , 1 1 4 . 0 9- 5 / 8 1 2 - 1 / 4 4- 1 / 2 " P r o d u c t i o n C a s i n g 4, 1 4 8 . 9 17 , 8 3 2 . 0 4- 1 / 2 8 - 1 / 2 Me a s u r e d De p t h (us f t ) Ve r t i c a l De p t h (us f t ) Di p Di r e c t i o n (° ) Na m e L i t h o l o g y Di p (° ) Fo r m a t i o n s 1, 3 9 7 . 7 1 , 3 8 3 . 6 B a s e P e r m a f r o s t T r a n s i t i o n 10 , 3 3 9 . 9 3 , 9 3 9 . 6 N T 6 M F S 2, 7 5 4 . 1 2 , 4 4 9 . 6 T u l u v a k S h a l e 1, 1 3 4 . 7 1 , 1 2 8 . 6 B a s e I c e B e a r i n g P e r m a f r o s t 1, 0 3 8 . 4 1 , 0 3 3 . 6 U p p e r S c h r a d e r B l u f f 11 , 1 8 3 . 5 4 , 1 2 5 . 6 N T 3 . 2 T o p R e s e r v o i r 11 , 0 7 2 . 6 4 , 1 0 3 . 6 N T 3 M F S 9, 7 9 1 . 7 3 , 8 2 4 . 6 N T 8 M F S 6, 0 3 8 . 2 3 , 1 5 3 . 6 S e a b e e 10 , 5 3 4 . 4 3 , 9 8 2 . 6 N T 5 M F S 2, 2 9 1 . 0 2 , 1 4 6 . 6 M C U 1, 7 7 9 . 7 1 , 7 3 6 . 6 M i d d l e S c h r a d e r B l u f f 10 , 7 3 8 . 4 4 , 0 2 8 . 6 N T 4 M F S 2, 8 7 1 . 1 2 , 5 1 0 . 6 T u l u v a k S a n d 9, 6 7 6 . 5 3 , 8 0 3 . 6 N a n u s h u k 9, 9 1 5 . 3 3 , 8 4 9 . 6 N T 7 M F S Me a s u r e d De p t h (us f t ) Ve r t i c a l De p t h (us f t ) +E /- W (us f t ) +N /- S (us f t )Lo c a l C o o r d i n a t e s Co m m e n t De s i g n A n n o t a t i o n s 17 , 8 3 9 . 0 4 , 1 4 8 . 9 - 1 2 , 1 7 3 . 8 7, 5 0 2 . 3 P r o j e c t i o n 4/ 01 /20 2 4 1 1 :35 :25 A M CO M P A S S 5 0 0 0 .17 B u i l d 0 2 Pa g e 1 2 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: NDB-044 (PTD 223-0-87) 10-407 Date:Thursday, February 22, 2024 12:58:42 PM Attachments:image003.png image004.png image005.png Bryan, There was cement circulated off the top of the liner as well as the bond logs. We had a large amount of contaminated mud, spacer and cement that was dumped on the initial circulation after shutting the stage cementing tool. We dumped a total of 263 bbls of contaminated fluids with trace amounts of cement detected by phenolphthalein. After we performed our initial circulation we pulled the running tool to the liner top packer and circulated a large amount of cement returns from liner top, ~5 bbls solid cement returns sucked by Super Sucker at cuttings box. Let me know if you need anything else. 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) Sent: Thursday, February 22, 2024 12:24 PM To: Thompson, Jacob (Jacob) Subject: ![EXT]: RE: NDB-044 (PTD 223-0-87) 10-407 Jake, Was cement circulated off the liner top and observed at surface on the second stage intermediate casing cement job? I can’t find that in the cementing report. 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, February 21, 2024 3:38 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: NDB-044 (PTD 223-0-87) 10-407 Bryan, We’ve updated the report with the requested information. Let me know if there is anything else you need from us. 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: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Sent: Wednesday, February 21, 2024 3:24 PM To: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Subject: RE: NDB-044 (PTD 223-0-87) 10-407 Hi Jake, Please review revised Ops Summary Report attached. Pressure test mentioned on 11/7/23 took place on 11/8/23. If all looks good, please forward this to Bryan. Thanks! Rachel From: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Sent: February 21, 2024 3:10 PM To: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Subject: FW: NDB-044 (PTD 223-0-87) 10-407 Rachel, Looks like I missed that the pressure testing values and results for casing tests were not documented in the State Report. We’ll need to get the clerks to start putting these in the 24 hr summary. Can we get the Report updated and sent in to them again. 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: Wednesday, February 21, 2024 2:00 PM To: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Subject: ![EXT]: NDB-044 (PTD 223-0-87) 10-407 Jake, There is some missing information in the operations summary report in the 10-407 for this well. Please provide the following: 1. Surface Casing test pressure and results. It says they rigged up to test casing, but no mention of actually testing casing on 11/7/23. 2. Results of liner-top packer pressure test on 12/1/23 3. Results of casing test on 12/3/23. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email From:Davis, Rachel (Rachel) To:Brooks, James S (OGC) Subject:RE: Logged 10-407 Oil Search NDBi-044 Date:Tuesday, February 13, 2024 9:46:04 AM Attachments:image004.png image005.png image006.png image007.png Hi, Please use these coordinates for TPI: 4068 FLS, 1598 FEL, S6, T11N, R6E, UM x – 413,101.61 y – 5,974,551.31 Zone – 4 Please let me know if you have any questions! Thanks, Rachel Davis Technical Assistant t:1 (907) 375-4678 | e: rachel.davis@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: February 13, 2024 9:42 AM To: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Subject: ![EXT]: RE: Logged 10-407 Oil Search NDBi-044 That is the coordinate that I have and it is a little off. thanx -$0(6%522.6 5(6($5&+$1$/<67,,E $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Sent: Tuesday, February 13, 2024 9:32 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: Logged 10-407 Oil Search NDBi-044 Morning James, I see the “Y” TPI on the 10-407 matches what you have highlighted below? Please confirm if I’m looking at the correct coordinate? Appreciate it! Thanks, Rachel From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: February 13, 2024 8:45 AM To: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Subject: ![EXT]: FW: Logged 10-407 Oil Search NDBi-044 Hi, The tpi ‘Y’ coordinate is slightly off. Can you take a look at this ? 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. thanx -$0(6%522.6 5(6($5&+$1$/<67,,E $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Friday, January 19, 2024 9:41 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: Logged 10-407 Oil Search NDBi-044 Hi James, Attached is stamped 10-407 for NDBi-044; it is logged in the 10-407 Excel spreadsheet. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 From: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Sent: Thursday, January 18, 2024 10:17 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: NDBi-044 10-407 Completion Report Morning, Please see attached the 10-407 Completion Report for NDBi-044. Thank you, Rachel Davis Technical Assistant t:1 (907) 375-4678 | e: rachel.davis@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter 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:Brooks, Phoebe L (OGC) To:Buzby, Brian (Brian) Cc:Regg, James B (OGC) Subject:RE: BOP Test Report Parker Rig 272 11-20-23 Date:Wednesday, January 3, 2024 11:35:52 AM Attachments:Parker 272 11-20-23 Revised.xlsx Brian, Attached is a revised report changing the MASP to reflect 1473 based on PTD #2230870. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Buzby, Brian (Brian) <Brian.Buzby@contractor.santos.com> Sent: Wednesday, November 22, 2023 11:04 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: BOP Test Report Parker Rig 272 11-20-23 All Here is the test report from Santos, Parker Rig 272, 11-20-23 Thanks Brian Buzby Brian Buzby – Well Site Supervisor Parker 272Oil Search (Alaska), LLC a subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska 99524-0927 o: +1 (907) xxx-xxx | m: +1 (907) 355-4253 Brian.buzby@contractor.santos.com https://www.santos.com/ Pikka NDB-44 PTD 2230870 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:272 DATE:11/20/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2230870 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:X Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1473 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 2 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13-5/8" 5M P Pit Level Indicators P P #1 Rams 1 4-1/2 x 7" VBR P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 9-5/8" FBR P H2S Gas Detector P P #4 Rams 0 N/A NA MS Misc 0 NA #5 Rams 0 N/A NA #6 Rams 0 N/A NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8 P Time/Pressure Test Result HCR Valves 2 3-1/8 P System Pressure (psi)3100 P Kill Line Valves 2 2-1/16" 3-1/8"P Pressure After Closure (psi)2000 P Check Valve 0 N/A NA 200 psi Attained (sec)16 P BOP Misc 0 N/A NA Full Pressure Attained (sec)65 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):14@2200 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 26 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/20/23 05:00hrs Waived By Test Start Date/Time:11/20/2023 17:00 (date)(time)Witness Test Finish Date/Time:11/20/2023 21:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Parker Tested with 4½ 5-7/8" and 9-5/8" test joints. Pat Lynch Oil Search (Alaska) LLC Brian Buzby Pikka NDBi-044 Test Pressure (psi): 72.seniormanager@parkerwellbore D&C.wss.NDB@santos.com Form 10-424 (Revised 08/2022)2023-1120_BOP_Parker272_Pikka_NDB-44 J. Regg; 5/3/2024 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Friday, February 16, 2024 2:11 PM To:Brake, Jared (Jared) Cc:Regg, James B (OGC) Subject:RE: Pikka NDBi-044 Test Report Attachments:MIT Pikka NDBi-044 01-30-24 Waived.xlsx; MIT Pikka NDBi-044 01-30-24 Revised.xlsx Jared, AƩached are revised reports based on the inspector’s report, separaƟng the waived and witnessed reports. Per the inspector only the MIT‐IA was witnessed, the type of test should be “P”, BBL Returned on the MIT‐IA is 9.2, and the AOGCC Rep should reflect Sully Sullivan on the witnessed report. Please review and update your copies or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brake, Jared (Jared) <Jared.Brake@contractor.santos.com> Sent: Wednesday, January 31, 2024 11:41 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com> Subject: Pikka NDBi‐044 Test Report Folks, Here is the copy of the iniƟal witnessed MIT‐IA for injecƟon well NDBi‐044 at Santos. Jared Brake Well Integrity & Well IntervenƟon Engineer You don't often get email from jared.brake@contractor.santos.com. Learn why this is important 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. Pikka NDB-44PTD 2230870 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2230870 Type Inj N Tubing -2 6558 6495 6466 Type Test P Packer TVD 4047 BBL Pump 5.8 IA 3 17 18 18 Interval O Test psi 6000 BBL Return 4.8 OA -8 -8 -8 -8 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2230870 Type Inj N Tubing 2978 3541 3595 3629 Type Test P Packer TVD 4047 BBL Pump 9.0 IA 17 4367 4307 4284 Interval O Test psi 4000 BBL Return 9.0 OA -8 -6 -7 -6 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj N Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj N Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Tested as per PTD # 223-0870. Pre-Frac sundry MIT-IA. Note: MIT-T. Pressured up tubing to 2978psi prior to pressure testing the IA. Repeated due to digital chart not recording on first test. AOGCC rep did not witness test. Notes: Notes: Santos Oil Search Pikka NDB Pere Keniye 01/30/24 Notes:MIT - T for Pre-Frac on injection well Tested to 6550psi.(Diesel was used for testing). AOGCC rep did not witness test. Notes: Notes: Notes: NDBi 044 NDBi 044 Form 10-426 (Revised 01/2017)2024-0130_MIT_Pikka_NDB-044_2tests J. Regg; 4/5/2024 LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDBi-044 (50-103-20865-0000) Supplemental Submittal Details on following page 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: 2/8/2024 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: PTD: 223-087 T38450 Note: Includes Revisions 2/9/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.09 11:25:19 -09'00' LETTER OF TRANSMITTAL Digital Data FE NDBi-044_LWD_RM_17839ft.las PWD NDBi-044_AP_R01_RM_20231105.las NDBi-044_AP_R02_RM_20231116.las NDBi-044_AP_R03_RM_20231128.las NDBi-044_AP_R04_RM_20231205.las NDBi-044_AP_R05_RM_20231215.las VSS NDBi-044_DMD_RM_17839ft.las NDBi-044_DMT_R01_RM_20231105.las NDBi-044_DMT_R02_RM_20231116.las NDBi-044_DMT_R03_RM_20231128.las NDBi-044_DMT_R04_RM_20231205.las NDBi-044_DMT_R05_RM_20231215.las Geoscience deliverables CBL Baker SoundTrak LWD NDBi-044_SDTK_CBL_2060_11120.cgm NDBi-044_SDTK_CBL_2060_11120.dlis NDBi-044_SDTK_CBL_2060_11120.las NDBi-044_SDTK_CBL_2060_11120.PDF NDBi-044_SDTK_CBL_2060_11120_dlis.txt NDBi-044_SDTK_TOC_2060_11120.cgm NDBi-044_SDTK_TOC_2060_11120.dlis NDBi-044_SDTK_TOC_2060_11120.las NDBi-044_SDTK_TOC_2060_11120.PDF NDBi-044_SDTK_TOC_2060_11120_dlis.txt Halliburton Cast M Wireline NDBi-044_CAST-CBL_02DEC23_Bottom_ProcessedLog-Preliminary.dlis NDBi-044_CAST-CBL_02DEC23_Bottom_ProcessedLog-Preliminary.las NDBi-044_CAST-CBL_02DEC23_Bottom_Raw.dlis NDBi-044_CAST-CBL_02DEC23_Bottom_Raw.las NDBi-044_CAST-CBL_02DEC23_PreliminaryReport.pdf NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary-V2.pdf NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary-V2.tif NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary.pdf NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary.tif NDBi-044_CAST-CBL_02DEC23_Top_ProcessedLog-Preliminary.dlis NDBi-044_CAST-CBL_02DEC23_Top_ProcessedLog-Preliminary.las LETTER OF TRANSMITTAL NDBi-044_CAST-CBL_02DEC23_Top_Raw.dlis NDBi-044_CAST-CBL_02DEC23_Top_Raw.las SoundTrak Acoustic Santos_NDBi-044_MD5_MEM_SDTK_DTS.cgm Santos_NDBi-044_MD5_MEM_SDTK_DTS.dlis Santos_NDBi-044_MD5_MEM_SDTK_DTS.las Santos_NDBi-044_MD5_MEM_SDTK_DTS.PDF Graphics Images CGM FE NDBi-044_LWD_RM_17839ft_2MD Gamma Resistivity.cgm NDBi-044_LWD_RM_17839ft_2TVD Gamma Resistivity.cgm NDBi-044_LWD_RM_17839ft_5MD Gamma Resistivity Density Neutron.cgm NDBi-044_LWD_RM_17839ft_5TVD Gamma Resistivity Density Neutron.cgm PWD NDBi-044_AP_RM_20231215.cgm VSS NDBi-044_DMD_RM_17839ft.cgm NDBi-044_DMT_RM_20231215.cgm PDF FE NDBi-044_LWD_RM_17839ft_2MD Gamma Resistivity.pdf NDBi-044_LWD_RM_17839ft_2TVD Gamma Resistivity.pdf NDBi-044_LWD_RM_17839ft_5MD Gamma Resistivity Density Neutron.pdf NDBi-044_LWD_RM_17839ft_5TVD Gamma Resistivity Density Neutron.pdf PWD NDBi-044_AP_RM_20231215.pdf VSS NDBi-044_DMD_RM_17839ft.pdf NDBi-044_DMT_RM_20231215.pdf NDBi-044_Sperry_Logging_Final Data LWD CGM NDBi-044 Deep Resistivity LWD Final MD.cgm NDBi-044 Deep Resistivity LWD Final TVD.cgm Definitive Survey LETTER OF TRANSMITTAL NDBi-044 Final Survey Report from Santos.xlsx EMF NDBi-044 Deep Resistivity LWD Final MD.emf NDBi-044 Deep Resistivity LWD Final TVD.emf LWD Data NDBi-044 LWD Resistivity Final.las NDBi-044_EarthStar_Images.dlis NDBi-044_EarthStar_Images.ver NDBi-044_Stratastar_Images.dlis NDBi-044_Stratastar_Images.ver PDF NDBi-044 Deep Resistivity LWD Final MD.pdf NDBi-044 Deep Resistivity LWD Final TVD.pdf TIFF NDBi-044 Deep Resistivity LWD Final MD.tif NDBi-044 Deep Resistivity LWD Final TVD.tif LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDBi-044 (50-103-20865-0000) Supplemental Submittal Details on following page Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 shannon.koh@santos.com DATE: 1/30/2024 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: PTD: 223-087 T38450 1/30/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.30 12:53:59 -09'00' LETTER OF TRANSMITTAL جؐؐؐCGM ؒ NDBi-044 Deep Resistivity LWD Final MD.cgm ؒ NDBi-044 Deep Resistivity LWD Final TVD.cgm ؒ جؐؐؐDefinitive Survey ؒ NDBi-044 Final Survey Report from Santos.xlsx ؒ جؐؐؐEMF ؒ NDBi-044 Deep Resistivity LWD Final MD.emf ؒ NDBi-044 Deep Resistivity LWD Final TVD.emf ؒ ؤؐؐؐTIFF NDBi-044 Deep Resistivity LWD Final MD.tif NDBi-044 Deep Resistivity LWD Final TVD.tif LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION 5 files NDBi-044 (50-103-20865-0000) NDBi-044 Plan view.pdf NDBi-044 Vertical Section.pdf NDBi-044.xls NDBi-044.txt NDBi-044.txt Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 shannon.koh@santos.com DATE: 1/24/2024 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 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: PTD: 223-087 T38339 1/24/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.24 15:42:06 -09'00' LETTER OF TRANSMITTAL DETAIL QTY DESCRIPTION NDBi-044 (50-103-20865-0000) Final well data submittal – details on following pages Received by:_____________________________ Date: _____________ Please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 907-375-4607 phone shannon.koh@santos.com DATE: 1/18/2024 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: PTD: 223-087 T38339 1/18/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 16:10:46 -09'00' LETTER OF TRANSMITTAL NDBi-044 (50-103-20865-0000) جؐؐؐDirectional Survey ؒ NDBi-044 Definitive Survey Report - NAD27.pdf ؒ NDBi-044 Definitive Survey Report - NAD83.pdf ؒ جؐؐؐLog Digital Data (LWD and WL) ؒ جؐؐؐCement Evaluation Logs ؒ ؒ جؐؐؐBaker SoundTrak LWD ؒ ؒ ؒ NDBi-044_SDTK_CBL_2060_11120.cgm ؒ ؒ ؒ NDBi-044_SDTK_CBL_2060_11120.dlis ؒ ؒ ؒ NDBi-044_SDTK_CBL_2060_11120.las ؒ ؒ ؒ NDBi-044_SDTK_CBL_2060_11120.PDF ؒ ؒ ؒ NDBi-044_SDTK_CBL_2060_11120_dlis.txt ؒ ؒ ؒ NDBi-044_SDTK_TOC_2060_11120.cgm ؒ ؒ ؒ NDBi-044_SDTK_TOC_2060_11120.dlis ؒ ؒ ؒ NDBi-044_SDTK_TOC_2060_11120.las ؒ ؒ ؒ NDBi-044_SDTK_TOC_2060_11120.PDF ؒ ؒ ؒ NDBi-044_SDTK_TOC_2060_11120_dlis.txt ؒ ؒ ؒ ؒ ؒ ؤؐؐؐHalliburton Cast M Wireline ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Bottom_ProcessedLog-Preliminary.dlis ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Bottom_ProcessedLog-Preliminary.las ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Bottom_Raw.dlis ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Bottom_Raw.las ؒ ؒ NDBi-044_CAST-CBL_02DEC23_PreliminaryReport.pdf ؒ ؒ NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary-V2.pdf ؒ ؒ NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary-V2.tif ؒ ؒ NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary.pdf ؒ ؒ NDBi-044_CAST-CBL_02DEC23_ProcessedLog-Preliminary.tif ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Top_ProcessedLog-Preliminary.dlis ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Top_ProcessedLog-Preliminary.las ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Top_Raw.dlis ؒ ؒ NDBi-044_CAST-CBL_02DEC23_Top_Raw.las ؒ ؒ ؒ ؤؐؐؐLWD ؒ جؐؐؐDigital Data ؒ ؒ NDBi-044 LWD Resistivity Final.las ؒ ؒ NDBi-044_AP_R01_RM_20231105.las ؒ ؒ NDBi-044_AP_R02_RM_20231116.las ؒ ؒ NDBi-044_AP_R03_RM_20231128.las ؒ ؒ NDBi-044_AP_R04_RM_20231205.las ؒ ؒ NDBi-044_AP_R05_RM_20231215.las ؒ ؒ NDBi-044_DMD_RM_17839ft.las ؒ ؒ NDBi-044_DMT_R01_RM_20231105.las ؒ ؒ NDBi-044_DMT_R02_RM_20231116.las LETTER OF TRANSMITTAL ؒ ؒ NDBi-044_DMT_R03_RM_20231128.las ؒ ؒ NDBi-044_DMT_R04_RM_20231205.las ؒ ؒ NDBi-044_DMT_R05_RM_20231215.las ؒ ؒ NDBi-044_EarthStar_Images.dlis ؒ ؒ NDBi-044_EarthStar_Images.ver ؒ ؒ NDBi-044_LWD_RM_17839ft.las ؒ ؒ NDBi-044_Stratastar_Images.dlis ؒ ؒ NDBi-044_Stratastar_Images.ver ؒ ؒ Santos_NDBi-044_MD5_MEM_SDTK_DTS.dlis ؒ ؒ Santos_NDBi-044_MD5_MEM_SDTK_DTS.las ؒ ؒ ؒ ؤؐؐؐGraphics ؒ NDBi-044 Deep Resistivity LWD Final MD.pdf ؒ NDBi-044 Deep Resistivity LWD Final TVD.pdf ؒ NDBi-044_AP_RM_20231215.cgm ؒ NDBi-044_AP_RM_20231215.pdf ؒ NDBi-044_DMD_RM_17839ft.cgm ؒ NDBi-044_DMD_RM_17839ft.pdf ؒ NDBi-044_DMT_RM_20231215.cgm ؒ NDBi-044_DMT_RM_20231215.pdf ؒ NDBi-044_LWD_RM_17839ft_2MD Gamma Resistivity.cgm ؒ NDBi-044_LWD_RM_17839ft_2MD Gamma Resistivity.pdf ؒ NDBi-044_LWD_RM_17839ft_2TVD Gamma Resistivity.cgm ؒ NDBi-044_LWD_RM_17839ft_2TVD Gamma Resistivity.pdf ؒ NDBi-044_LWD_RM_17839ft_5MD Gamma Resistivity Density Neutron.cgm ؒ NDBi-044_LWD_RM_17839ft_5MD Gamma Resistivity Density Neutron.pdf ؒ NDBi-044_LWD_RM_17839ft_5TVD Gamma Resistivity Density Neutron.cgm ؒ NDBi-044_LWD_RM_17839ft_5TVD Gamma Resistivity Density Neutron.pdf ؒ Santos_NDBi-044_MD5_MEM_SDTK_DTS.cgm ؒ Santos_NDBi-044_MD5_MEM_SDTK_DTS.PDF ؒ ؤؐؐؐMudlog جؐؐؐGeological Reports (compilation in PDF) ؒ NDBi-044 Mudlogging Daily Reports compilation.pdf ؒ جؐؐؐMudlogging final data ؒ NDB-044 Advanced Gas_GeoIsotopes_CORRECTED_17839 ft.las ؒ NDBi-044 Advanced Gas_G5_Composite_17839 ft_Final.pdf ؒ NDBi-044 Advanced Gas_GeoIsotopes_Composite_17839 ft_Final.pdf ؒ NDBi-044_DrillGasLitho_depth_17839ft MD.las ؒ NDBi-044_GasRatioLog_2''_1783ft MD .pdf ؒ NDBi-044_GasRatioLog_5''_1783ft MD.pdf ؒ NDBi-044_Lithology.xlsx ؒ NDBi-044_Mudlog_2''_17839ft MD.pdf ؒ NDBi-044_Mudlog_5''GR_17839ft MD.pdf ؒ ؤؐؐؐOil, Gas and Gas Hydrate Shows List LETTER OF TRANSMITTAL Show Report Geolog_NDBi-044_10000-10050ft_#03.pdf Show Report Geolog_NDBi-044_10400-10440ft_#04.pdf Show Report Geolog_NDBi-044_10650-10680ft_#05.pdf Show Report Geolog_NDBi-044_10840-10890ft_#06.pdf Show Report Geolog_NDBi-044_11085-11100ft_#07.pdf Show Report Geolog_NDBi-044_11190-11400ft_#08.pdf Show Report Geolog_NDBi-044_11400-11800ft_#09.pdf Show Report Geolog_NDBi-044_11700-12100ft_#10.pdf Show Report Geolog_NDBi-044_12100-12600ft_#11.pdf Show Report Geolog_NDBi-044_12600-13100ft_#12.pdf Show Report Geolog_NDBi-044_13100-13600ft_#13.pdf Show Report Geolog_NDBi-044_13600-14100ft_#14.pdf Show Report Geolog_NDBi-044_14100-14600ft_#15.pdf Show Report Geolog_NDBi-044_14600-15100ft_#16.pdf Show Report Geolog_NDBi-044_15100-15600ft_#17.pdf Show Report Geolog_NDBi-044_15600-16100ft_#18.pdf Show Report Geolog_NDBi-044_9710-9740ft_#01.pdf Show Report Geolog_NDBi-044_9840-9870ft_#02.pdf 324-01 By Grace Christianson at 2:23 pm, Jan 11, 2024 10-404 CDW 01/30/2024 SFD BJM 1/31/24 Gas flaring during well flow back is authorized in accordance with 20 AAC 25.235.(d)(6) DSR-1/26/24SFD 1/28/2024($8 2/1/24 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.01 16:27:41 -09'00' RBDMS JSB 020624 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:D&C WSS NDB To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:BOP form, Parker 272 12-3-2023 Date:Tuesday, December 5, 2023 7:58:15 PM Attachments:ParkerWellBore3_2558de44-3614-4f77-a0f8-1477d64b87bc.png BOPE Test State Form 12-3-23.xlsx BOP Test chart 12-03-2023.pdf BOPE Test Order 12-03-2023.docx You don't often get email from d&c.wss.ndb@santos.com. Learn why this is important Jim, Please see attached and let us know if we can correct or clarify anything. Rob From: Woods, Russell <Russell.Woods@parkerwellbore.com> Sent: Tuesday, December 5, 2023 6:11 PM To: D&C WSS NDB <D&C.WSS.NDB@santos.com> Subject: ![EXT]: State BOP form Russell Woods Jr. Rig Manager Russell.Woods@parkerwellbore.com Pouch 340110, Prudhoe Bay, AK 99734 United States www.parkerwellbore.com Energy. Well engineered. NOTICE BY Parker Wellbore Company This message, as well as any attached document, contains information from Parker Wellbore Company that is confidential and/or privileged. The information is intended only for the use of the addressee named above. If you are not the intended recipient, you are hereby notified that any use, disclosure, copying, 3LNND1'% 37' distribution or the taking of any action in reliance on the contents of this message or its attachments is strictly prohibited, and may be unlawful. If you have received this message in error, please delete all electronic copies of this message and its attachments, if any, destroy any hard copies you may have created, without disclosing the contents, and notify the sender immediately. Unless expressly stated otherwise, nothing contained in this message should be construed as a digital or electronic signature, nor is it intended to reflect an intention to make an agreement by electronic means. Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:272 DATE: 12/3/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2230870 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1473 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP #1 Rams 1 4-1/2 x 7" VBR P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 4-1/2 x 7" VBR P H2S Gas Detector PP #4 Rams 0 N/A NA MS Misc 0NA #5 Rams 0 N/A NA #6 Rams 0 N/A NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8 P Time/Pressure Test Result HCR Valves 2 3-1/8 P System Pressure (psi)3100 P Kill Line Valves 2 2-1/16" 3-1/8"P Pressure After Closure (psi)2050 P Check Valve 0 N/A NA 200 psi Attained (sec)17 P BOP Misc 0 N/A NA Full Pressure Attained (sec)70 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 14@2400 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1FP Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 20 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams N/A NA Test Results #5 Rams N/A NA #6 Rams N/A NA Number of Failures:1 Test Time:6.5 Hours HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/01/2023 21:12hrs Waived By Test Start Date/Time:12/3/2023 14:30 (date) (time)Witness Test Finish Date/Time:12/3/2023 21:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Parker Tested with 5" and 4-1/2" test joints. Fail/Pass on Manual choke valve (seat backed off and needed tightened). Sonny Clark Oil Search (Alaska) LLC Rowland Lawson Pikka NDB-044 Test Pressure (psi): 72.seniormanager@parkerwellbore D&C.WSS.NDB@santos.com Form 10-424 (Revised 08/2022) 2023-1203_BOP_Parker272_Pikka_NDB-044 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ FP Fail/Pass on Manual choke valve BOPE Test Order Parker Rig 272 12/03/2023 WELL NDBi-044 Test Annular, Rams, & all valves to 250 PSI LowFor 5-Min, 3000 PSI High For 5-MIN, as per permit to drill Rig up 5” Test joint 1. Close: 4½” X 7” Upper Rams-U-IBOP, D544 Dart Valve, Choke #1, 2, 3, 4 & 15, K-4. Open: Everything else. 2. Close: L-IBOP, D544 FOSV, HCR Kill, Choke #5, 6. Open: U-IBOP, D544 Dart Valve, K-4 and Choke #2 3. Close: Choke #7,8,9, Manual Kill Open: HCR Kill, Choke #5, 6, D544 FOSV. 4. Close: Choke#10, 11, 12, Open: Choke#7, 8, 9, 5. Close: Choke#13 Open: Choke#12 6. Close: 4 ½’’ X 7’’ Lower Pipe Rams Open: Open Upper Pipe Rams *Bleed pressure and perform draw down test. “Function all BOP Components from remote panels located in the LER & Rig Managers office, and Accumulator.” Remove Test Joint. 7. Close: Blind Rams, Choke #10, 11, 14. Open: Choke #13 8. Close: Super Choke A & Choke B To 1500 PSI Open: Choke #10 Change out to 4-1/2” Test joint 9. Close: Annular, HCR Choke Open: Choke #14 BOPE Test Order Parker Rig 272 12/03/2023 10. Close: 4 ½’’ X 7’’ Upper Pipe Rams, Manual Choke Open: HCR Choke 11. Close: 4 ½’’ X 7’’ VBR LPR Open 4½” X 7” Upper Pipe Rams Closing Times for BOP Components: Annular Preventer = Sec. Upper Pipe rams = Sec. Blind/Shear rams = Sec. Lower Pipe Rams = Sec. HCR Choke = Sec. HCR Kill = Sec. Accumulator Test: Time/Pressure System Pressure = PSI Pressure after Closure = PSI 200 psi Attained = Sec. Full Pressure Attained = Sec. Nitrogen Bottle Average = PSI X 14 Bottles Electric pump kick on pressure = PSI Electric pump kick off pressure = PSI Air pump kick on pressure = PSI Air pump kick off pressure = PSI 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 1 F e b r u a r y 1 , 2 0 2 4 (a ) A p p l i c a t i o n f o r Su n d r y A p p r o v a l (a ) ( 1 ) A f f i d a v i t Pr o v i d e d w i t h a p p l i c a t i o n . SF D 1/ 2 8 / 2 0 2 4 ( a ) ( 2 ) P l a t Pr o v i d e d w i t h a p p l i c a t i o n . SF D 1/ 2 8 / 2 0 2 4 ( a ) ( 2 ) ( A ) W e l l l o c a t i o n Pr o v i d e d w i t h a p p l i c a t i o n . S u r f a c e l o c a t i o n l i e s i n S e c t i o n 4 of T 1 1 N , R 6 E , U M . T h e w e l l p a s s e s t h r o u g h S e c t i o n s 5 a n d 6 of T 1 1 N , R 6 E , U M . T h e p r o d u c t i v e i n t e r v a l a n d T D l i e i n Se c t i o n 3 1 o f T 1 2 N , R 6 E , U M . SF D 1/ 2 8 / 2 0 2 4 ( a ) ( 2 ) ( B ) E a c h w a t e r w e l l w i t h i n ½ m i l e No n e : Ac c o r d i n g t o t h e W a t e r E s t a t e m a p a v a i l a b l e t h r o u g h DN R ’ s A l a s k a M a p p e r a p p l i c a t i o n ( a c c e s s e d o n l i n e J a n . 2 8 , 20 2 4 ) , t h e r e a r e n o w e l l s a r e u s e d f o r d r i n k i n g w a t e r pu r p o s e s a r e k n o w n t o l i e w i t h i n ½ m i l e o f t h e s u r f a c e lo c a t i o n o f N D B - 0 4 4 . T h e r e a r e n o s u b s u r f a c e w a t e r r i g h t s or t e m p o r a r y s u b s u r f a c e w a t e r r i g h t s w i t h i n 1 4 m i l e s o f t h e su r f a c e l o c a t i o n o f N D B - 0 4 4 . SF D 1/ 2 8 / 2 0 2 4 (a ) ( 2 ) ( C ) I d e n t i f y a l l w e l l t y p e s w i t h i n ½ mi l e Ye s . T h e r e a r e t h r e e w e l l s a n d w e l l b o r e s w i t h i n ½ m i l e o f ND B - 0 4 4 t h a t t r a n s e c t t h e c o n f i n i n g z o n e : Q u g r u k 3 , Q u g r u k 3A , a n d Q u g r u k 3 0 1 . SF D 1/ 2 8 / 2 0 2 4 (a ) ( 3 ) F r e s h w a t e r a q u i f e r s : g e o l o g i c a l na m e ; m e a s u r e d a n d t r u e v e r t i c a l d e p t h No n e . N o f r e s h w a t e r a q u i f e r s a r e p r e s e n t w i t h i n t h e P i k k a Un i t p e r s a l i n i t y c a l c u l a t i o n s p r o v i d e d b y t h e o p e r a t o r o n Au g . 2 1 , 2 0 2 3 a s p a r t o f t h e i r S u n d r y A p p l i c a t i o n t o hy d r a u l i c a l l y f r a c t u r e n e a r b y w e l l N D B - 0 2 4 ( s e e A O G C C ’ s We l l H i s t o r y F i l e 2 2 3 - 0 7 6 , p . 1 0 1 - 1 0 7 o f S u n d r y A p p l i c a t i o n 32 3 - 5 9 1 ) . P i c k e t t P l o t w e l l - l o g a n a l y s e s w e r e p e r f o r m e d o n th r e e w e l l s w i t h i n t h e u n i t t h a t h a v e w i r e l i n e l o g c o v e r a g e fr o m s u r f a c e t h r o u g h t h e f r a c t u r i n g i n t e r v a l : C o l v i l l e R i v e r 1 , Ti l l 1 , a n d P i k k a D W - 0 2 . E s t i m a t e d s a l i n i t y v a l u e s f o r c l e a n , po r o u s 1 0 0 % w a t e r - s a t u r a t e d s a n d s b e n e a t h t h e b a s e o f t h e pe r m a f r o s t l a y e r i n t h e s e t h r e e w e l l s a r e : Co l v i l l e R i v e r 1 (1 9 2 - 1 5 3 ) ~2 0 , 0 0 0 m g / l be t w e e n 1 , 4 0 0 a n d 2 , 0 0 0 ’ M D SF D 1/ 2 8 / 2 0 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 2 F e b r u a r y 1 , 2 0 2 4 (- 1 , 3 5 4 ’ t o 1 , 9 5 4 ' T V D S S ; b a s e o f p e r m a f r o s t 1 , 3 5 0 ’ M D (- 1 , 3 1 3 ’ T V D S S ) ) ; Ti l l 1 (1 9 3 - 0 0 4 ) 16 , 7 0 0 t o ~ 2 3 , 0 0 0 m g / l be t w e e n 1 , 4 0 0 ’ a n d 1 , 5 0 0 ’ M D ( - 1 , 4 6 3 ’ t o - 1 , 3 6 3 ’ T V D S S ; ba s e o f p e r m a f r o s t 1 , 3 5 0 ’ M D ( - 1 , 3 0 5 ’ T V D S S ) ) ; a n d DW - 0 2 (2 2 3 - 0 3 9 ) ~2 1 , 5 0 0 m g / l b e t w e e n 1 , 5 5 0 ’ a n d 1 , 6 5 0 ’ M D (- 1 , 4 0 8 ’ t o - 1 , 4 8 6 ’ T V D S S ; b a s e o f p e r m a f r o s t ~ 1 , 1 7 0 ’ M D (~ - 1 , 0 8 0 ’ T V D S S ) . ( a ) ( 4 ) B a s e l i n e w a t e r s a m p l i n g p l a n No n e r e q u i r e d : No f r e s h w a t e r a q u i f e r s a r e p r e s e n t . SF D 1/ 2 8 / 2 0 2 4 ( a ) ( 5 ) C a s i n g a n d c e m e n t i n g i n f o r m a t i o n Pr o v i d e d w i t h a p p l i c a t i o n . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 6 ) C a s i n g a n d c e m e n t i n g o p e r a t i o n as s e s s m e n t Si g n i f i c a n t i s s u e s w i t h c e m e n t i n g o n t h e w e l l . T w o s t a g e ce m e n t j o b i n 9 - 5 / 8 ” c a s i n g h a s m u l t i p l e l o g s a n d ev a l u a t i o n s w i t h p o o r c e m e n t a n d a g g r e g a t e d l o g g i n g re q u i r e d t o g e t t o a p p r o v a l o f c e m e n t i s o l a t i o n s . Pr e s s u r e t e s t i n g h a s b e e n c o m p l e t e d a n d w i l l b e r e d o n e pr i o r t o f r a c t o e n s u r e c o n t a i n m e n t . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 6 ) ( A ) C a s i n g c e m e n t e d b e l o w lo w e r m o s t f r e s h w a t e r a q u i f e r a n d co n f o r m s t o 2 0 A A C 2 5 . 0 3 0 No f r e s h w a t e r a q u i f e r s p r e s e n t . ( S e e S e c t i o n ( a ) ( 3 ) , a b o v e . ) SF D 1/ 2 8 / 2 0 2 4 (a ) ( 6 ) ( B ) E a c h h y d r o c a r b o n z o n e i s is o l a t e d Ye s : Su r f a c e c a s i n g ( 1 3 - 3 / 8 ” ) w a s s e t a t 2 , 5 1 4 ’ M D ( - 2 , 2 3 3 ’ TV D S S ) a n d c e m e n t e d . I n t e r m e d i a t e h o l e w a s d r i l l e d th r o u g h t h e T u l u v a k I n t e r v a l ( U p p e r T u l u v a k f r o m 2 , 8 7 0 ’ t o 4, 1 7 6 ’ M D , o r - 2 , 4 4 0 ’ t o - 2 , 7 5 2 ’ T V D S S ) i n t o t h e N a n u s h u k (9 , 9 4 0 ’ M D , 3 , 7 8 5 ’ T V D S S ) . C a s i n g ( 9 - 5 / 8 ” ) w a s s e t a t 11 , 1 1 4 ’ M D ( - 4 , 0 8 5 ’ T V D S S ) a n d c e m e n t e d i n t w o s t a g e s . Fi r s t s t a g e s a w n o r e t u r n s w h i l e d i s p l a c i n g c e m e n t . A ce m e n t r e t a i n e r w a s r u n a n d s e t a t 1 1 , 0 1 0 ’ M D a n d a s e c o n d SF D 1/ 2 8 / 2 0 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 3 F e b r u a r y 1 , 2 0 2 4 ce m e n t j o b w a s p u m p e d t h r o u g h t h e s h o e . T h e s e c o n d s t a g e to o l w a s s e t a t 4 , 1 5 8 ’ M D ( - 2 , 7 4 9 ’ T V D S S ) a t t h e b a s e o f t h e Up p e r T u l u v a k . 2 1 4 b b l s o f V e r s a c e m 1 5 . 3 c e m e n t w e r e pu m p e d , o f w h i c h 1 2 9 b a r r e l s w e r e l o s t w h i l e d i s p l a c i n g . Fo l l o w i n g c e m e n t i n g , a H a l i b u r t o n C A S T t o o l w a s r u n v i a tr a c t o r t o 1 0 , 8 3 9 ’ M D ( - 3 , 9 8 2 ’ T V D S S ) , w h i c h i s b e n e a t h t h e to p o f t h e N a n u s h u k i n t e r v a l ( a t 9 , 9 4 0 ’ M D , - 3 , 7 8 5 ’ T V D S S ) bu t a b o v e t h e r e s e r v o i r t h a t w i l l b e f r a c ’ d ( N T 3 . 2 a t 1 1 , 1 8 0 ’ MD , - 4 , 0 5 3 ’ T V D S S ) . A c c o r d i n g t o H a l i b u r t o n ’ s A d v a n c e d Ce m e n t E v a l u a t i o n R e p o r t d a t e d 1 2 / 3 / 2 0 2 3 , t h e r e i s n o go o d q u a l i t y c e m e n t w i t h i n e i t h e r o f t h e t w o i n t e r m e d i a t e ce m e n t s t a g e s . I n t h a t C e m e n t E v a l u a t i o n R e p o r t , f a i r - qu a l i t y c e m e n t i s i n d i c a t e d b y a c e m e n t b o n d i n d e x b e t w e e n 50 % a n d 8 0 % . T a l l y i n g t h e f o o t a g e s o f c e m e n t q u a l i t y ( a s in t e r p r e t e d b y H a l l i b u r t o n ) w i t h i n t h e r e p o r t y i e l d s t h e fo l l o w i n g a g g r e g a t e t o t a l s : x Ab o v e U p p e r T u l u v a k : 1 8 9 ’ M D f a i r , 3 3 2 ’ M D o f p o o r . x Up p e r T u l u v a k : 5 4 7 ’ M D o f f a i r , 7 1 5 ’ M D o f p o o r . x Be l o w U p p e r T u l u v a k : 9 3 6 ’ o f p o o r - q u a l i t y c e m e n t . x Lo g g i n g i n t e r p r e t a t i o n g a p f r o m 5 , 1 1 3 ’ t o 7 , 9 6 4 ’ M D . x Ab o v e N a n u s h u k F o r m a t i o n : 9 1 ’ M D f a i r , 1 , 8 8 5 ’ o f p o o r . x Wi t h i n N a n u s h u k t o b o t t o m o f t h e C A S T l o g ( f r o m 9, 9 4 0 ’ t o 1 0 , 8 3 9 ’ M D , - 3 , 7 8 5 ’ t o - 3 , 9 8 1 ’ T V D S S , w i t h t h e to p o f r e s e r v o i r l o c a t e d a t 1 1 , 1 8 0 ’ M D ( - 4 , 0 5 3 ’ T V D S S ) : 21 6 ’ M D o f f a i r c e m e n t , 5 9 8 ’ M D o f p o o r c e m e n t , a n d 95 ’ o f a p p a r e n t f r e e p i p e . Th e a g g r e g a t e f o o t a g e s o f f a i r - q u a l i t y c e m e n t a c r o s s e a c h zo n e l i s t e d a b o v e i n d i c a t e t h a t c e m e n t v e r y l i k e l y i s o l a t e s ea c h h y d r o c a r b o n z o n e . SF D 1/ 2 8 / 2 0 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 4 F e b r u a r y 1 , 2 0 2 4 (a ) ( 7 ) P r e s s u r e t e s t : i n f o r m a t i o n a n d pr e s s u r e - t e s t p l a n s f o r c a s i n g a n d t u b i n g in s t a l l e d i n w e l l Pr o v i d e d w i t h a p p l i c a t i o n . 4 0 0 0 p s i M I T I A p l a n n e d , 6 0 0 0 p s i MI T T p l a n . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 8 ) P r e s s u r e r a t i n g s a n d s c h e m a t i c s : we l l b o r e , w e l l h e a d , B O P E , t r e a t i n g h e a d Pr o v i d e d w i t h a p p l i c a t i o n . 1 0 K p s i w e l l h e a d m a x . f r a c . Pr e s s u r e 5 2 0 0 p s i e x p e c t e d , M A W P 8 9 0 0 p s i . P u m p k n o c k ou t 7 4 0 0 a n d G O R V 8 3 0 0 p s i . , l i n e s t e s t 9 0 0 0 p s i . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 9 ) ( A ) F r a c t u r i n g a n d c o n f i n i n g z o n e s : li t h o l o g i c d e s c r i p t i o n f o r e a c h z o n e (a ) ( 9 ) ( B ) G e o l o g i c a l n a m e o f e a c h z o n e (a ) ( 9 ) ( C ) a n d ( a ) ( 9 ) ( D ) M e a s u r e d a n d t r u e ve r t i c a l d e p t h s (a ) ( 9 ) ( E ) F r a c t u r e p r e s s u r e f o r e a c h z o n e Up p e r C o n f i n i n g Z o n e s : A b o u t 9 0 0 ’ t r u e v e r t i c a l t h i c k n e s s (T V T ) o f s h a l e a n d t h i n l y i n t e r b e d d e d s i l t s t o n e a s s i g n e d t o th e U p p e r T o r o k / H u e S h a l e h a v i n g a n e s t i m a t e d f r a c t u r e gr a d i e n t o f 1 3 . 7 p p g E M W ( 0 . 7 1 p s i / f t ) . Fr a c t u r i n g Z o n e : P e r f o r a t e d z o n e l i e s w i t h i n a s u b d i v i s i o n o f th e N a n u s h u k F o r m a t i o n t h a t i s a b o u t 6 5 0 ’ T V T i n t h i s a r e a an d h a s a n e s t i m a t e d f r a c t u r e g r a d i e n t o f 1 1 . 7 p p g E M W (0 . 6 1 p s i / f t ) . Lo w e r C o n f i n i n g Z o n e s : L o w e r T o r o k si l t s t o n e a n d s h a l e t h a t is a b o u t 1 7 0 ’ t h i c k i n t h i s a r e a w i t h a n e s t i m a t e d f r a c t u r e gr a d i e n t o f 1 3 . 3 p p g E M W ( 0 . 6 9 p s i / f t ) . T h i s i s u n d e r l a i n b y ab o u t 2 2 5 ’ o f c o n d e n s e d m a r i n e s h a l e a s s i g n e d t o t h e H R Z . SF D 1/ 2 8 / 2 0 2 4 (a ) ( 1 0 ) L o c a t i o n , o r i e n t a t i o n , a n d a r e p o r t on t h e m e c h a n i c a l c o n d i t i o n o f e a c h w e l l th a t m a y t r a n s e c t t h e c o n f i n i n g z o n e s , an d i n f o r m a t i o n s u f f i c i e n t t o s u p p o r t a de t e r m i n a t i o n t h a t t h e w e l l w i l l n o t in t e r f e r e w i t h c o n t a i n m e n t o f t h e hy d r a u l i c f r a c t u r i n g f l u i d w i t h i n t h e o n e - ha l f m i l e r a d i u s o f t h e p r o p o s e d w e l l b o r e tr a j e c t o r y 3 w e l l s P & A . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 1 1 ) S u f f i c i e n t i n f o r m a t i o n t o d e t e r m i n e we l l s w i l l n o t i n t e r f e r e w i t h c o n t a i n m e n t wi t h i n ½ m i l e Ye s . T h e r e a r e t h r e e w e l l s a n d w e l l b o r e s w i t h i n ½ m i l e o f ND B - 0 4 4 t h a t t r a n s e c t t h e c o n f i n i n g z o n e : Q u g r u k 3 , Q u g r u k 3A , a n d Q u g r u k 3 0 1 . N o n e o f t h e s e w e l l s w i l l i n t e r f e r e w i t h co n t a i n m e n t o f f r a c f l u i d s . SF D 1/ 2 8 / 2 0 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 5 F e b r u a r y 1 , 2 0 2 4 Qu g r u k 3 : Su r f a c e c a s i n g ( 1 3 - 3 / 8 ” ) s e t a t 2 , 1 2 0 ’ M D ( - 2 , 0 7 4 ’ TV D S S ) a n d c e m e n t e d t o s u r f a c e w i t h 5 3 b a r r e l s o f c e m e n t re t u r n s t o s u r f a c e . W e l l d r i l l e d t o N u i q s u t t h e n p l u g g e d b a c k wi t h p l u g s s e t ( t h e n t a g g e d ) a c r o s s t h e N u i q s u t a n d A l p i n e , Na n u s h u k , a n d T u l u v a k . Qu g r u k 3 A : Ki c k e d o f f f r o m Q u g r u k 3 a t 2 , 7 0 8 ’ M D ( - 2 , 6 6 0 ’ TV D S S ) a n d d r i l l e d a g a i n t o N u i q s u t . P l u g 1 s e t a c r o s s Nu i q s u t , A l p i n e , K u p C ( e s t i m a t e d c e m e n t t o p a t 8 , 0 0 3 ’ M D , -5 8 1 2 ’ T V D S S ) t h e n P l u g 2 s e t a c r o s s N a n u s h u k r e s e r v o i r (t a g g e d a t 4 , 2 1 2 ’ M D , - 3 , 9 1 3 ’ T V D S S ) . Qu g r u k 3 0 1 : S u r f a c e c a s i n g ( 1 3 - 3 / 8 ’ ) s e t a t 2 , 1 0 7 ’ M D (- 2 , 0 7 0 ’ T V D S S ) a n d c e m e n t e d t o s u r f a c e w i t h 6 0 b b l s o f ce m e n t r e t u r n s a t s u r f a c e ; r e t u r n s t h e n l o s t a n d c e m e n t f e l l ba c k t o 4 0 ’ M D . T o p j o b p e r f o r m e d w i t h 3 . 4 b b l s c e m e n t re t u r n s a t s u r f a c e . I n t e r m e d i a t e c a s i n g ( 9 - 5 / 8 ” ) s e t a t 5 , 3 2 5 ’ MD ( - 4 , 1 4 7 ’ T V D S S ) a n d c e m e n t e d i n t w o s t a g e s . S t a g e 1 pu m p e d 8 9 b b l s o f C l a s s G 1 4 . 0 p p g w i t h S F D c a l c u l a t e d t o p at 4 , 1 0 0 ’ M D ( - 3 , 8 1 2 ’ T V D S S ) , w h i c h i s o l a t e s t h e t a r g e t re s e r v o i r a n d m o s t , i f n o t a l l , o f t h e o v e r l y i n g N a n u s h u k . St a g e 2 c o l l a r i s s e t a t 3 0 0 8 ’ M D ( - 2 , 9 5 3 ’ T V D S S ) a n d ce m e n t e d w i t h 1 8 7 b b l s o f T y p e I / I I 1 2 . 2 c e m e n t a n d f u l l re t u r n s . S F D e s t i m a t e d t o p o f c e m e n t i s a b o u t 5 0 0 ’ M D , wh i c h i s o l a t e s t h e T u l u v a k , S c h r a d e r B l u f f a n d W e s t S a k st r a t a . . SF D 1/ 2 8 / 2 0 2 4 (a ) ( 1 1 ) F a u l t s a n d f r a c t u r e s , L o c a t i o n , or i e n t a t i o n (a ) ( 1 1 ) F a u l t s a n d f r a c t u r e s , S u f f i c i e n t in f o r m a t i o n t o d e t e r m i n e n o i n t e r f e r e n c e wi t h c o n t a i n m e n t w i t h i n ½ m i l e On e . T h e o p e r a t o r h a s i d e n t i f i e d o n e l o w - c o n f i d e n c e f a u l t / st r a t i g r a p h i c f e a t u r e o n s e i s m i c d a t a w i t h i n a ½ - m i l e r a d i u s of N D B - 0 4 4 t h a t i s c o n t a i n e d w i t h i n t h e N a n u s h u k . It i s un l i k e l y t h i s p o s s i b l e f a u l t w i l l i n t e r f e r e w i t h c o n t a i n m e n t of t h e i n j e c t e d f r a c t u r i n g f l u i d s ; h o w e v e r , i f t h e r e a r e in d i c a t i o n s t h a t a f r a c t u r e h a s i n t e r s e c t e d a f a u l t o r na t u r a l - f r a c t u r e i n t e r v a l d u r i n g f r a c o p e r a t i o n s , t h e SF D 1/ 2 8 / 2 0 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 6 F e b r u a r y 1 , 2 0 2 4 op e r a t o r w i l l g o t o f l u s h a n d t e r m i n a t e t h e s t a g e im m e d i a t e l y . (a ) ( 1 2 ) P r o p o s e d p r o g r a m f o r f r a c t u r i n g op e r a t i o n Pr o v i d e d w i t h a p p l i c a t i o n . CD W 01 / 3 0 / 2 0 2 4 ( a ) ( 1 2 ) ( A ) E s t i m a t e d v o l u m e Pr o v i d e d w i t h a p p l i c a t i o n . F r a C A D E h a s 1 8 4 7 2 b b l t o t a l d i r t y vo l . 2 . 4 M l b t o t a l p r o p p a n t , p u m p s c h e d u l e h a s s m a l l va r i a t i o n s i n t o t a l p l a n n e d 2 1 5 2 2 b b l , . 2 . 4 M l b p r o p p a n t . B i g fr a c , 6 7 s t a g e s . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 1 2 ) ( B ) A d d i t i v e s : n a m e s , p u r p o s e s , co n c e n t r a t i o n s Pr o v i d e d w i t h a p p l i c a t i o n . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 1 2 ) ( C ) C h e m i c a l n a m e a n d C A S nu m b e r o f e a c h Pr o v i d e d w i t h a p p l i c a t i o n . S c h l u m b e r g e r d i s c l o s u r e pr o v i d e d . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 1 2 ) ( D ) I n e r t s u b s t a n c e s , w e i g h t o r vo l u m e o f e a c h Pr o v i d e d w i t h a p p l i c a t i o n . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 1 2 ) ( E ) M a x i m u m t r e a t i n g p r e s s u r e w i t h su p p o r t i n g i n f o t o d e t e r m i n e ap p r o p r i a t e n e s s f o r p r o g r a m Si m u l a t i o n s h o w s m a x s u r f a c e p r e s s u r e 5 2 2 5 p s i . M a x . 89 0 0 p s i a l l o w a b l e t r e a t i n g p r e s s u r e . M a x p r e s s u r e i s 7 4 0 0 ps i t o 8 3 0 0 p s i t o P u m p s h u t d o w n . W i t h 3 5 0 0 p s i b a c k pr e s s u r e I A ( I A p o p o f f s e t 3 8 0 0 p s i ) , m a x t u b i n g d i f f e r e n t i a l sh o u l d b e 5 4 0 0 p s i . CD W 01 / 3 0 / 2 0 2 4 (a ) ( 1 2 ) ( F ) F r a c t u r e s – h e i g h t , l e n g t h , M D an d T V D t o t o p , d e s c r i p t i o n o f f r a c t u r i n g mo d e l Pr o v i d e d w i t h a p p l i c a t i o n . T h e a n t i c i p a t e d h a l f - l e n g t h s o f th e i n d u c e d f r a c t u r e s w i l l r a n g e f r o m a b o u t 3 4 0 ’ t o 4 2 0 ’ ac c o r d i n g t o t h e O p e r a t o r ’ s c o m p u t e r s i m u l a t i o n . Co m p u t e r s i m u l a t i o n i n d i c a t e s t h e a n t i c i p a t e d h e i g h t o f t h e in d u c e d f r a c t u r e s w i l l r a n g e f r o m a b o u t 2 2 0 ’ t o 2 4 0 ’ , a n d th e s h a l l o w e s t f r a c t o p T V D S S o f a b o u t - 4 , 0 7 9 ’ , w h i c h i s ab o u t 3 3 0 t r u e v e r t i c a l f e e t d e e p e r t h a n t h e b a s e o f t h e up p e r c o n f i n i n g l a y e r . S o , S c h l u m b e r g e r ’ s F r a c C A D E co m p u t e r m o d e l i n d i c a t e s t h a t t h e i n d u c e d f r a c t u r e s s h o u l d no t p e n e t r a t e i n t o t h e o v e r l y i n g c o n f i n i n g i n t e r v a l t h a t h a s SF D 1/ 2 8 / 2 0 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 7 F e b r u a r y 1 , 2 0 2 4 an e s t i m a t e d a g g r e g a t e t h i c k n e s s o f m o r e t h a n 9 0 0 ’ i n t h i s ar e a . (a ) ( 1 3 ) P r o p o s e d p r o g r a m f o r p o s t - fr a c t u r i n g w e l l c l e a n u p a n d f l u i d r e c o v e r y We l l c l e a n o u t a n d f l o w b a c k p r o c e d u r e p r o v i d e d w i t h ap p l i c a t i o n . N o d i s p o s a l i d e n t i f i e d CD W 01 / 3 0 / 2 0 2 4 (b ) T e s t i n g o f c a s i n g or i n t e r m e d i a t e ca s i n g Te s t e d > 1 1 0 % o f m a x a n t i c i p a t e d p r e s s u r e 35 0 0 p s i b a c k p r e s s u r e , p l a n t o t e s t t o 4 0 0 0 p s i , p o p o f f s e t as 3 8 0 0 p s i CD W 01 / 3 0 / 2 0 2 4 (c ) F r a c t u r i n g s t r i n g (c ) ( 1 ) P a c k e r > 1 0 0 ’ b e l o w T O C o f pr o d u c t i o n o r i n t e r m e d i a t e c a s i n g 4. 5 ” t u b i n g w i l l b e a n c h o r e d t o t h e 4 . 5 ” l i n e r w i t h a p a c k e r se t a t a p p r o x . . 1 0 8 2 3 f t w i t h f r a c s l e e v e p l a n n e d f o r 1 1 7 1 8 ft . 9 - 5 / 8 ” p r o d u c t i o n c a s i n g p o o r l y c e m e n t e d f r o m s h o e @ 11 1 1 4 a n d t h e n f r o m s t a g e t o o l @ 4 1 5 8 f t t o a p p r o x . 2 3 6 3 f t MD . M u l t i p l e l o g g i n g r u n s e v al u a t i n g c e m e n t w i t h v a r y i n g re s u l t s – s e e S t e v e r e v i e w (a ) ( 6 ) ( B ) . C u m u l a t i v e l y – c e m e n t is a d e q u a t e . CD W 01 / 3 0 / 2 0 2 4 (c ) ( 2 ) T e s t e d > 1 1 0 % o f m a x a n t i c i p a t e d pr e s s u r e d i f f e r e n t i a l Tu b i n g t e s t o f 6 0 0 0 p s i . M a x p r e s s u r e d i f f e r e n t i a l i s es t i m a t e d a s 5 4 0 0 p s i ( 8 9 0 0 w i t h 3 5 0 0 p s i b a c k p r e s s u r e ) s o te s t o f 6 0 0 0 p s i s a t i s f i e s 1 1 0 % CD W 01 / 3 0 / 2 0 2 4 (d ) P r e s s u r e r e l i e f va l v e Li n e p r e s s u r e < = t e s t p r e s s u r e , r e m o t e l y co n t r o l l e d s h u t - i n d e v i c e 90 0 0 p s i l i n e p r e s s u r e t e s t , p u m p k n o c k o u t 7 4 0 0 p s i w i t h ma x . g l o b a l k i c k o u t 8 3 0 0 p s i . I A P R V s e t a s 3 8 0 0 p s i . CD W 01 / 3 0 / 2 0 2 4 (e ) C o n f i n e m e n t Fr a c f l u i d s c o n f i n e d t o a p p r o v e d fo r m a t i o n s Pr o v i d e d w i t h a p p l i c a t i o n . CD W 01 / 3 0 / 2 0 2 4 (f ) S u r f a c e c a s i n g pr e s s u r e s Mo n i t o r e d w i t h g a u g e a n d p r e s s u r e r e l i e f de v i c e IA P R V s e t a t 3 8 0 0 p s i . S u r f a c e a n n u l u s o p e n . F r a c p r e s s u r e s co n t i n u o u s l y m o n i t o r e d . CD W 01 / 3 0 / 2 0 2 4 (g ) A n n u l u s pr e s s u r e mo n i t o r i n g & no t i f i c a t i o n 50 0 p s i c r i t e r i a Du r i n g h y d r a u l i c f r a c t u r i n g o p e r a t i o n s , a l l a n n u l u s p r e s s u r e s mu s t b e c o n t i n u o u s l y m o n i t o r e d a n d r e c o r d e d . I f a t a n y ti m e d u r i n g h y d r a u l i c f r a c t u r i n g o p e r a t i o n s t h e a n n u l u s pr e s s u r e i n c r e a s e s m o r e t h a n 5 0 0 p s i g a b o v e t h o s e an t i c i p a t e d i n c r e a s e s c a u s e d b y p r e s s u r e o r t h e r m a l tr a n s f e r , t h e o p e r a t o r s h a l l : CD W 01 / 3 0 / 2 0 2 4 ( g ) ( 1 ) N o t i f y A O G C C w i t h i n 2 4 h o u r s 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n – C h e c k l i s t Pi k k a N D B - 0 4 4 ( P T D N o . 2 2 3 - 0 8 7 ; S u n d r y N o . 3 2 4 - 0 1 2 ) Pa r a g r a p h Su b - P a r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 8 F e b r u a r y 1 , 2 0 2 4 ( g ) ( 2 ) C o r r e c t i v e a c t i o n o r s u r v e i l l a n c e ( g ) ( 3 ) S u n d r y t o A O G C C (h ) S u n d r y R e p o r t (i ) R e p o r t i n g ( i ) ( 1 ) F r a c F o c u s R e p o r t i n g (i ) ( 2 ) A O G C C R e p o r t i n g : p r i n t e d & el e c t r o n i c (j ) P o s t - f r a c w a t e r sa m p l i n g p l a n No t r e q u i r e d . No f r e s h w a t e r a q u i f e r s p r e s e n t . ( S e e S e c t i o n (a ) ( 3 ) , a b o v e . ) SF D 1/ 2 8 / 2 0 2 4 (k ) C o n f i d e n t i a l in f o r m a t i o n Cl e a r l y m a r k e d a n d s p e c i f i c f a c t s su p p o r t i n g n o n d i s c l o s u r e No t a p p l i c a b l e : T h i s w e l l i s n o t c o n f i d e n t i a l . SF D 1/ 2 8 / 2 0 2 4 (l ) V a r i a n c e s re q u e s t e d Mo d i f i c a t i o n s o f d e a d l i n e s , r e q u e s t s f o r va r i a n c e s o r w a i v e r s No p l a n f o r p o s t f r a c t u r e w a t e r w e l l a n a l y s i s . C o m m i s s i o n m a y r e q u i r e t h i s d e p e n d i n g o n p e r f o r m a n c e o f t h e f r a c t u r i n g o p e r a t i o n. �Lc.z Santos LETTER OF TRANSMITTAL DATE: 1/2/2024 From: To: Shannon Koh Meredith Guhl Santos AOGCC P.O. Box 240927 333 W. 71h Avenue, Suite 100 Anchorage, AK 99524-0927 Anchorage, AK 99501 TRANSMISSION TYPE: TRANSMISSION METHOD: ®External Request ❑CD ❑ Thumb Drive ❑Internal Request ❑Email ❑SharePoint/Teams ❑Hardcopy ®Other— Dry cutting samples REASON FOR TRANSMITTAL: ❑To Be Returned ❑Approved ❑Information Only ❑Approved with Comments ❑For Your Review ❑With Our Comments El For Approval ®For Your Use ❑Other COMMENTS: CITY 9 boxes of washed and dried cutting samples RECEIVED DEC 2 8 2023 AOGCC DETAIL DESCRIPTION NDBi-044 (50-103-20865-0000) Box Quantity Of Contalnes (bags, )ate etc) Type Sampling Frequency Sampling Interval Enclosed 1 of 9 40 Washed and Dried 50' 128'-2100' 2 of 9 39 50' 2100'-4000' 3 01`9 41 50' 4000'-6050' 4 of 9 41 s0' 6050'-8100' 5 of 9 41 50' 8100'-10150' 6 of 9 41 So' 10150'-12100' 7 o1`9 41 So' 12100'14150' 8 of 9 41 50' 14150'-16200' 9 of 9 33 50' 16200-17839' Received by- b ' Date: please sign and return one copy to: Santos ATTN: Shannon Koh P.O. Box 240927, Anchorage, AK 99524-0927 shannon.koh@santos.com |\ } | \�u _ > CA\ ƒ ) § R a � , 7 / a 2 / , > o } \ ( J 0 / t $ $ ƒ r eD k a) c f e« w c e�� N w z« w e z aLu & % « & & J & < & & < $ & & & & \ \ _ m e m< z e e e m< e e m z e e e e 2 \/ j a a$ a a a k w w w w w f A j©%^©%©$ w w w w G(D m �_ J /j 3 � / / A / 7 \ � // \ \ k m M c o ] \ \ rD �o ) ) 7 3 m \ \ \ \ \ \ G \ \ \ \ \ \ G \ \ f \ § m - - , _ $ § �® ƒ 9 / « / / g y © w % / « / © j \ \ / \ / R / \ \ \ } \ \ E / @ @ \ \ R - / o R , 2 o ,- \ \ \ \ ,- / § \ \ / \ \ \ k \ \ E n ; \ \ g \ R ® \ \ \ R 7 j - 3 - / - - \ - / - - \ R R � � f § < a ƒ / LA 0 ° ^ 0 0 u _ I » > R §§ k 0 / w) 7£§ aa > = � E > q n > ) , >fD # m ' ° ° � V § � � \ \ » 2 § STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PIKKA NDBi-044 JBR 01/12/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Started testing gas alarms @ 1530 and left rig @ 2215. Tested with 5 7/8 and 9 5/8 test joints. Test #7 Man chk failed, test around. No other failures. Left location before replace and retest of man chk. Operator sent passing chart. Chart attached with passing man chk. Test Results TEST DATA Rig Rep:Sonny ClarkOperator:Oil Search (Alaska), LLC Operator Rep:Rowland Lawson Rig Owner/Rig No.:Parker 272 PTD#:2230870 DATE:11/7/2023 Type Operation:DRILL Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSTS231109123558 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.8 MASP: 1473 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P FSV Misc 0 NA 15 PNo. Valves 1 FManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 4 1/2 x 7 vari P #2 Rams 1 blind/shear P #3 Rams 1 9 5/8 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 2 2 1/16, 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P2050 200 PSI Attained P16 Full Pressure Attained P65 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P14@2300 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P30 #1 Rams P6 #2 Rams P7 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9999 9 9 9 &KDUWIRUWHVWDIWHUUHSDLURIPDQXDOFKRNH QRWDWWDFKHG-5HJJ F Man chk failed, Left location before replace and retest of man chk. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: Reviewed By: P.I. Suprv Comm ________PIKKA NDBi-044 JBR 12/13/2023 MISC. INSPECTIONS: GAS DETECTORS: DIVERTER SYSTEM:MUD SYSTEM: P/F P/F P/F Alarm Visual Alarm Visual Time/Pressure Size Number of Failures:1 Remarks:Warning signs that the rig was on diverter and the warning signs to keep traffic out of the exclusion zone needed to be staged in place. The signs were put in place to let people know the rig was on diverter and to stop people from entering the diverter line exclusion zone. TEST DATA Rig Rep:S. Clark/N. WherleyOperator:Oil Search (Alaska), LLC Operator Rep:R. Lawson/J. Whitlatch Contractor/Rig No.:Parker 272 PTD#:2230870 DATE:11/3/2023 Well Class:DEV Inspection No:divGDC231102190305 Inspector Guy Cook Inspector Insp Source Related Insp No: Test Time:2 ACCUMULATOR SYSTEM: Location Gen.:P Housekeeping:P Warning Sign FP 24 hr Notice:P Well Sign:P Drlg. Rig.P Misc:NA Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:NA NA Designed to Avoid Freeze-up?P Remote Operated Diverter?P No Threaded Connections?P Vent line Below Diverter?P Diverter Size:21.25 P Hole Size:16 P Vent Line(s) Size:16 P Vent Line(s) Length:40.25 P Closest Ignition Source:100 P Outlet from Rig Substructure:51 P Vent Line(s) Anchored:P Turns Targeted / Long Radius:NA Divert Valve(s) Full Opening:P Valve(s) Auto & Simultaneous: Annular Closed Time:29 P Knife Valve Open Time:25 P Diverter Misc:NA Systems Pressure:P3000 Pressure After Closure:P2300 200 psi Recharge Time:P14 Full Recharge Time:P48 Nitrogen Bottles (Number of):P14 Avg. Pressure:P2225 Accumulator Misc:NA P PTrip Tank: P PMud Pits: P PFlow Monitor: NA NAMud System Misc: 99 9 9 9 9 Warning signs 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 Jacob Thompson Senior Drilling Engineer Oil Search Alaska, LLC 900 E Benson Boulevard Anchorage, AK, 99508 Re: Pikka Field, Nanushuk Oil Pool, NDBi-044A Oil Search Alaska, LLC Permit to Drill Number: 223-087 Surface Location: 2302’ FSL, 3361 FEL, Sec 4, T11N, R6E, UM Bottomhole Location: 4362’ FSL, 4860’ FEL, Sec 31, 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 October 2023. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.17 21:12:19 -06'00' 17 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: 17447'TVD:4157' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2302’ FSL, 3361 FEL, Sec 4, T11N, R6E, UM Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 10/29/23 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 5034' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70.68 15. Distance to Nearest Well Open Surface: x-421883.43 y- 5972689.12 Zone- 4 22 to Same Pool:4227' 16. Deviated wells: N/A Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20"x34" 215# X-52 Welded 80' Surface Surface 128' 54' 16" 13-3/8" 68# L-80 BTC 2822' Surface Surface 2822' 2302' 12-1/4" 9-5/8" 47# L-80 HYD 563 8234' 2672' 2240' 10902' 4106' 8-1/2" 4-1/2" 12.6# P-110S HYD 563 6792' 10756' 4080' 17548' 4150' Tubing 4-1/2" 12.6# P-110S HYD 563 10776' Surface Surface 10776' 4083' 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: Jacob Thompson Jacob Thompson Contact Email:jacob.thompson@santos.com Senior Drilling Engineer Contact Phone: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 4402’ FSL, 1769’ FEL, Sec 31, T12N, R6E, UM 4362’ FSL, 4860’ FEL, Sec 31, T12N, R6E, UM 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): N/A N/A Production Liner Intermediate Conductor/Structural Authorized Title: Authorized Signature: Authorized Name: LengthCasing Specifications 1907 Cement Volume MDSize Plugs (measured): (including stage data) Grouted to Surface See attachment 6 Effect. Depth MD (ft): Effect. Depth TVD (ft):Total Depth MD (ft): Total Depth TVD (ft): IS000361277U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 See attachment 6 1473 LONS 19-003 900 E Benson Boulevard, Anchorage, AK 99508 Oil Search Alaska, LLC ADL 3922984, 391445, 393021, 393019 2464 acres 18. Casing Program: Top - Setting Depth - Bottom NDBi-044 Pikka/Nanushuk Oil Pool Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. s N ype of W L l R L 1b S Class: os N s No s N o D s s sD o well is p G S S 20 S S S S s No s No S G y E S s No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Senior Drilling Engineer API Number: September 26, 2023 By Grace Christianson at 2:30 pm, Sep 26, 2023 DSR-9/27/23 500 Pikka 4118'2243' BJM 10/16/23 17446' 69.8 223-087 4088' 10906' See attached conditions of approval. 4156' A.Dewhurst 09OCT23 4084' 50-103-20865-00-00 90.1 128' *&:JLC 10/17/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.10.17 21:12:46 -06'00'10/17/23 10/17/23 NDB-044 (PTD 223-087) WĞƌŵŝƚƚŽƌŝůůŽŶĚŝƟŽŶƐŽĨĂƉƉƌŽǀĂů 1. 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Đ͘ KŝůƐĞĂƌĐŚ ǁŝůůƉƌŽǀŝĚĞĂĐĞŵĞŶƚũŽďƐƵŵŵĂƌLJƌĞƉŽƌƚĂŶĚĞǀĂůƵĂƟŽŶĂůŽŶŐǁŝƚŚƚŚĞ ĐĞŵĞŶƚůŽŐĂŶĚĞǀĂůƵĂƟŽŶƚŽƚŚĞK'ǁŚĞŶƚŚĞLJďĞĐŽŵĞĂǀĂŝůĂďůĞ. d. ĞƉĞŶĚŝŶŐŽŶƚŚĞĐĞŵĞŶƚũŽďƌĞƐƵůƚƐŝŶĚŝĐĂƚĞĚďLJƚŚĞĐĞŵĞŶƚũŽďƌĞƉŽƌƚ͕ƚŚĞůŽŐƐĂŶĚ ƚŚĞ&/d͕ƌĞŵĞĚŝĂůŵĞĂƐƵƌĞƐŽƌĂĚĚŝƟŽŶĂůůŽŐŐŝŶŐŵĂLJďĞƌĞƋƵŝƌĞĚ͘ Page 1 of 1 September 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-044 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-044 is planned to be a horizontal Injector targeting the Nanushuk 3. The approximate spud date is anticipated to be October 24th, 2023. Parker Rig 272 will be used to drill this well. The 16” surface hole will TD above the Tuluvak sand and then 13-3/8” casing will be set and cemented. The 12-1/4” intermediate hole will be drilled to above the top of the Nanushuk 3 formation at an inclination of ~77 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 and the lateral will be drilled to TD. The well will be completed as a stimulated 4-1/2” liner with frac sleeves and isolation packers. The production liner will be tied back to surface with a 4-1/2” tubing upper completion string. Please find enclosed for your review Form 10-401 Permit to Drill with a supporting Application for Permit to Drill containing information as required by 20 AAC 25.005. If there are any questions and/or additional information desired, please contact me at (907) 854-4377 or Jacob.Thompson@santos.com. Respectfully, Jacob Thompson Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Oil Search (Alaska), LLC Enclosures: NDBi-044 PTD AOGCC - 1 - 19-Sep-23 Application for Permit to Drill NDBi-044 Well NDBi-044 PTD AOGCC - 2 - 19-Sep-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...........................................................................8 10. Seismic Analysis.......................................................................................................................8 11. Seabed Condition Analysis.......................................................................................................9 12. Evidence of Bonding................................................................................................................9 13. Proposed Drilling Program.......................................................................................................9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal..............................................11 15. Proposed Variance Request...................................................................................................11 Attachments............................................................................................................................................12 Attachment 1: Location Maps......................................................................................................13 Attachment 2: Directional Plan....................................................................................................16 Attachment 3: BOPE Equipment..................................................................................................2 9 Attachment 4: Drilling Hazards....................................................................................................34 * Note that no H2S has been encountered on nearby offset wells, and H2S is not anticipated in this well.......................................................................................................................................35 Attachment 5: Leak Off Test Procedure.......................................................................................36 Attachment 6: Cement Summary.................................................................................................37 Attachment 7: Prognosed Formation Tops...................................................................................38 Attachment 8: Well Schematic.....................................................................................................39 Attachment 9: Formation Evaluation Program.............................................................................40 Attachment 10: Wellhead & Tree Diagram ..................................................................................41 Attachment 11: Injector Area of Review......................................................................................42 NDBi-044 PTD AOGCC - 3 - 19-Sep-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-044. 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 2302’ FSL, 3361 FEL, Sec 4, T11N, R6E, UM NAD 27 Coordinate System N 5,972,689 E 421,883 Rig KB Elevation 47’ above GL Ground Level 22.8’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 4402’ FSL, 1769’ FEL, Sec 31, T12N, R6E, UM NAD 27 Coordinate System N 5,974,883 E 412,934 Measured Depth, Rig KB (MD) 11,348’ Total Vertical Depth, Rig KB (TVD) 4,168’ Total vertical Depth, Subsea (TVDSS) 4,099’ Location at Bottom of Productive Interval Reference to Government Section Lines 4362’ FSL, 4860’ FEL, Sec 31, T12N, R6E, UM NAD 27 Coordinate System N 5,980,164’ E 409,883’ Measured Depth, Rig KB (MD) 17,446’ Total Vertical Depth, Rig KB (TVD) 4,157’ Total vertical Depth, Subsea (TVDSS) 4,087’ NDBi-044 PTD AOGCC - 4 - 19-Sep-23 (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-044 will be 14-days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14-day BOP test period should not be requested. Parker 272 BOP Equipment: BOP Equipment x NOV Shaffer Spherical annular BOP, 13-5/8” x 5000 psi x NOV T3 6012 double gate, 13-5/8” x 5000 psi x Mud cross, 13-5/8” x 5000 psi with 2 ea. 3-1/8" x 5000 psi side outlets x Choke Line, 3-1/8” x 5000 psi with 3-1/8” manual and HCR valve x Kill Line, 2-1/16” x 5000 psi with 3-1/8” manual and HCR valve x NOV T3 6012 single gate, 13-5/8” x 5000 psi Choke Manifold x 3-1/8” x 5000 psi working pressure with Axon Type S remote controlled chokes and NRG mud/gas separator BOP Closing Unit x NOV SARA Koomey Control System, 316 gallon, 299 gallon reservoir. Twenty Four 15 gallon bottles. Equipped with 1 electric and 3 air pumps with emergency power. Please refer to Attachment 3: BOPE Equipment for further details. NDBi-044 PTD AOGCC - 5 - 19-Sep-23 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 1,885 psi in the @10,906’ MD at 4,119’ TVD (8.8ppg EMW Nan 3.2 formation to section TD) Maximum surface pressure 1,473 psi from the NT4 (0.10 psi/ft gas gradient to surface, 4,119’ 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 annular pressure during frac job] Integrity Test – 12-1/4” hole LOT after drilling 20’-50’ of new hole. 13.2 ppg LOT required for Kick Tolerance. 13-3/8” Casing Test 4,000 psi surface pressure [Test pressure driven by frac back pressure requirements] 8-1/2” Production Hole Pressure Data Maximum anticipated BHP 1,907 psi in the Nanushuk 3 at 4,168’ TVD (8.8ppg EMW top NT3 formation to heel target) Maximum surface pressure 1,491 psi from the NT3 (0.10 psi/ft gas gradient to surface, 4,168’ 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 annular pressure during frac job] Integrity Test – 8-1/2” hole FIT after drilling 20’-50’ of new hole. 15.0 ppg. (10.6 ppg EMW LOT Required for infinite kick tolerance.) 9-5/8” Liner Test 4,000 psi surface pressure [Test pressure driven by annular pressure during frac job] (B) data on potential gas zones; and The Tuluvak formation is expected in this area and has a high potential for gas as based on offset Exploration and Appraisal well data. The Tuluvak is expected to be overpressured at 10.1 ppg pore pressure. The well plan is designed to safely manage pressures consistent with offset wells in the same manner that hydrocarbons are handled in the reservoir zone. BOPE will be installed before entering any hydrocarbon zones and appropriate mud weights will be utilized to provide sufficient overbalance. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; NDBi-044 PTD AOGCC - 6 - 19-Sep-23 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 / TVD Cement Program 42” 20”x34” 215# X-52 Welded 80’ Surface 128’ / 54’ Grouted to Surface 16” 13-3/8” 68# L-80 BTC 2,822’ Surface 2822’ / 2,302’ Perm 300% OH Excess 50% below BPERM 11.0ppg Lead: 554.4bbls, 3113cuft, 1092sks ArcticCem, Yield: 2.85 cuft/sk 15.3ppg Tail:68.9bbls, 387cuft, 309.5sks HalCem Type I/II – 1.25cuft/sk 12-1/4” 9-5/8” 47# L-80 HYD 563 8,234’ 2,672’ 10,902’ / 4,106’ Stage 1: 30% Open Hole Excess 12.0ppg Lead: 141.8bbls, 796.4cuft, 338.2sks ExtendaCem, Yield: 2.34 cuft/sk 15.3ppg Tail: 42.5bbls, 238.5cuft, 192.9sks VersaCem Type I/II – 1.23 cuft/sk Stage 2: 50% Open Hole Excess 12.0ppg Lead:341.2bbls, 1915.9cuft, 815.2sks ExtendaCem, Yield: 2.35 cuft/sk 15.3ppg Tail: 41.8bbls, 234.9cuft, 190.9sks VersaCem Type I/II – 1.23 cuft/sk 8-1/2” 4-1/2” 12.6# P-110S HYD 563 6,792’ 10,756’ 17,548’ / 4,150’ Production Liner is uncemented Tubing 4-1/2” 12.6# P-110S HYD 563 10,776’ Surface 10,776’ n/a Please refer to Attachment 6: Cement Summary for further details. 17,548’ / NDBi-044 PTD AOGCC - 7 - 19-Sep-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, 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 10ppg 100-300 seconds ALAP 30-80 < 10 ml/30min n/a 8.6-10.5 <35 11.5-12 ppg 50-80 seconds ALAP 15-30 n/a < 5 ml/30min n/a n/a 10ppg 50-80 seconds ALAP 10-20 n/a < 5 ml/30min n/a n/a A diagram of drilling fluid system on Parker 272 is on file with AOGCC. NDBi-044 PTD AOGCC - 8 - 19-Sep-23 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. NDBi-044 PTD AOGCC - 9 - 19-Sep-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-044 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-044 is listed below. Please refer to Attachments 8-10 for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed Drilling Program NDBi-044 1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing ring on conductor. 2. Move in / rig up Parker 272. 3. Nipple up spacer spools and diverter over the 20” conductor. Verify that the diverter line is at least 75’ away from a potential source of ignition and beyond the drill rig substructure. 4. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC 24hrs notice for witnessing diverter test. 5. Pick up 5-7/8” drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up 16” motor BHA with MWD and LWD tools. 6. Spud well and drill surface hole section to TD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH and lay down BHA. 7. Run 13-3/8” 68# surface casing as per casing tally and land on pre-installed landing ring. Circulate and condition mud prior to commencing cement job. 8. Cement 13-3/8” casing as per cement program. Verify cement returns to surface. 9. ND diverter and NU casing head and spacer spool. NU BOPE (configured from top to bottom: annular preventor, 4-1/2” x 7” VBR, blind/shear, mud cross, 9-5/8” Fixed Rams). Test rams to 3000 psi high and annular to 3000 psi high as per AOGCC regulations. Provide AOGCC 24hrs notice for witnessing BOP test. NDBi-044 PTD AOGCC - 10 - 19-Sep-23 10. Close blind shear rams and pressure test casing to 3000 psi for 30 min. 11. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and Displace well to 12 ppg MOBM. 12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test. 13. Directionally drill 12-1/4” intermediate hole section to the top NT3.2 reservoir. Perform wiper trips as required. Circulate and condition hole to run casing. POOH. 14. 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. 15. Cement 9-5/8” liner with 1st stage cement job as per cement program. Monitor returns during displacement. Bump plug then pressure up to set liner hanger and release running tool. 16. Un-sting from liner hanger and POOH and LD liner running tools. 17. RIH with mechanical shifting tool and open 2 nd stage cement job tools. Sting into second stage tool pump secondary stage, SO and set liner top packer. POOH and lay down running tool . 18. Pressure test 13-3/8” x 9-5/8” to 3000 psi for 30 min. 19. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to 10.0 ppg MOBM. 20. Drill out shoe track and 20 - 50’ of new formation. Perform formation integrity test and submit results to AOGCC. 21. Directionally drill 8-1/2” hole section as per well plan to TD. Perform wiper trips as required. POOH. Log first stage cement with LWD. 22. RU and run 4-1/2” production liner with frac sleeves and mechanical packers. 23. Run 4-1/2” liner to TD. Set liner hanger and liner top packer and release the running tool. 24. Pressure test the 9-5/8” x 4-1/2” production liner to 3,000 psi for 30 min. 25. POOH and LD liner running tool. 26. RU and run 4-1/2” upper completion with tech wire. Space out seals. 27. Circulate diesel to freeze protect and corrosion inhibited brine into annulus and stab seals inside the polish bore below the 9-5/8” x 4-1/2” liner top packer. 28. Pressure test tubing to 4,000 psi for 30 mins. Pressure up on the annulus to 4,000 psi for 30 mins. Bleed pressure on tubing and shear upper gas lift valve. 29. Install TWC, pressure test to 3,000 psi for 5 mins. ND BOPE, NU dry hole tree. Pressure test to 3,000 psi for 5 mins. 30. RDMO Second stage cement must be logged as well. See conditions of approval. -bjm o 10.0 ppg MOBM. NDBi-044 PTD AOGCC - 11 - 19-Sep-23 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. Variance approved. -bjm NDBi-044 PTD AOGCC - 12 - 19-Sep-23 Attachments NDBi-044 PTD AOGCC - 13 - 19-Sep-23 Attachment 1: Location Maps OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD PLANNED WELLS DIVERTER (50-ft) RIG OUTLINES DATE: 9/18/2023. By: JB 0 50 100 Feet Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDBi44_well_diverter GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 02040 Meters PIKKA DEVELOPMENT NDBi44 WELL DIVERTER Latitude (decimal degree) Long (decimal degree)Latitude Longitude Y (ft) x (ft) 70.33519 -150.63689 N 70° 20' 06.6648" W 150° 38' 12.8177" 5,972,437.11 1,561,916.24 Latitude (decimal degree) Long (decimal degree)Latitude Longitude y (ft) x (ft) 70.33550 -150.63379 N 70° 20' 07.8162" W 150° 38' 01.5409" 5,972,689.12 421,883.43 State Plane NAD83 Zone 4 StatePlane NAD27 Zone 4 AD L 3 9 2 9 9 1 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 4 1 . 5 8 % D N R - 5 8 . 4 2 % AD L 3 9 2 9 8 4 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 5 0 % D N R - 5 0 % AD L 3 9 2 9 5 8 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 3 6 . 3 1 % D N R - 6 3 . 6 9 % AD L 3 9 2 9 7 0 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 4 0 . 2 9 % D N R - 5 9 . 7 1 % AD L 3 9 3 0 2 1 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 1 9 . 2 2 % D N R - 8 0 . 7 8 % AD L 3 9 3 0 1 9 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 3 3 . 1 % D N R - 6 6 . 9 % AD L 3 9 3 0 1 8 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 2 9 . 6 7 % D N R - 7 0 . 3 3 % AD L 3 9 3 0 2 0 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 2 6 . 5 9 % D N R - 7 3 . 4 1 % AD L 3 9 3 0 1 5 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 3 1 . 6 9 % D N R - 6 8 . 3 1 % AD L 3 9 3 0 1 6 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 3 3 . 1 7 % D N R - 6 6 . 8 3 % AD L 3 9 1 4 4 5 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 4 1 . 9 8 % D N R - 5 8 . 0 2 % AD L 3 9 1 4 5 5 Su r f a c e O w n e r s : K u u k p i k OS A - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 4 6 . 4 % D N R - 5 3 . 6 % U0 1 2 N 0 0 6 E 2 9 U0 1 1 N 0 0 6 E 0 4 U0 1 2 N 0 0 6 E 3 2 U0 1 1 N 0 0 6 E 0 5 U0 1 2 N 0 0 6 E 3 3 U0 1 2 N 0 0 5 E 2 5 U0 1 2 N 0 0 6 E 2 8 U0 1 2 N 0 0 5 E 3 6 U0 1 1 N 0 0 5 E 0 1 U0 1 2 N 0 0 6 E 3 1 U0 1 1 N 0 0 6 E 0 6 U0 1 2 N 0 0 6 E 3 0 OI L S E A R C H ( A L A S K A ) , L L C A S U B S I D I A R Y O F S A N T O S L T D ND B i 0 4 4 W E L L A R E A TA R G E T BO T T O M H O L E SU R F A C E L O C A T I O N WE L L T R A J E C T O R Y LE A S E S B O U N D A R Y KU U K P I K B O U N D A R Y .5 - m i l e B u f f e r TO W N S H I P SE C T I O N DA T E : 9 / 1 9 / 2 0 2 3 . R E V : 1 . 0 . B y : J B 0 4 0 0 8 0 0 US F e e t Pr o j e c t : A P - D R L - G E N _ a s s o r t e d La y o u t : A P - D R L - P E - M _ N D B i 0 4 4 _ w e l l _ o w n e r s h i p GC S : N A D 1 9 8 3 S t a t e P l a n e A l a s k a 4 F I P S 5 0 0 4 F e e t 0 1 0 0 2 0 0 Me t e r s PI K K A P R O J E C T ND B NDBi-044 PTD AOGCC - 16 - 19-Sep-23 Attachment 2: Directional Plan Standard Planning Report -Geographic 18 September, 2023 Plan: Plan: NDBi-044 Rev D.0 Santos NAD27 Conversion Pikka NDB NDBi-044 NDBi-044 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Pikka, North Slope Alaska, United States Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: NDB Map Slot Radius:7.0 usft usft usft " 5,972,909.70 423,383.56 20 70° 20' 10.138 N 150° 37' 17.796 W Well Well Position Longitude: Latitude: Easting: Northing: +E/-W +N/-S Position Uncertainty Ground Level: NDBi-044 Wellhead Elevation:0.5 0.0 0.0 5,972,689.12 421,883.43 0.0 70° 20' 7.816 N 150° 38' 1.541 W 22.8 usft usft usft usft usft usft usft °-0.60Grid Convergence: Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) NDBi-044 Model NameMagnetics BGGM2023 31/12/2023 14.41 80.58 57,176.23063230 Phase:Version: Audit Notes: Design Plan: NDBi-044 Rev D.0 PLAN Vertical Section:Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:47.0 301.320.00.047.0 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 2 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Plan Survey Tool Program RemarksTool NameSurvey (Wellbore) Date 13/09/2023 Depth To (usft) Depth From (usft) 2_MWD_Interp Azi H002Mb: Interpolated azim Plan: NDBi-044 Rev D.0 (NDBi-04147.0 300.0 2_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-044 Rev D.0 (NDBi-042300.0 1,800.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-044 Rev D.0 (NDBi-043300.0 2,822.0 SDI_KPR_ADK SDI Keeper ADK Plan: NDBi-044 Rev D.0 (NDBi-04447.0 300.0 3_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-044 Rev D.0 (NDBi-0452,822.0 4,322.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-044 Rev D.0 (NDBi-0462,822.0 10,906.0 3_MWD+IFR2+Sag A012Mb: IIFR dec correctio Plan: NDBi-044 Rev D.0 (NDBi-04710,906.0 12,406.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan: NDBi-044 Rev D.0 (NDBi-04810,906.0 17,446.3 Inclination (°) Azimuth (°) +E/-W (usft) TFO (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections Target 0.000.000.000.000.00.047.00.000.0047.0 345.000.000.000.000.00.0400.0345.000.00400.0 345.000.003.003.00-2.710.1599.6345.006.00600.0 -70.22-2.742.843.00-1,472.0312.82,386.4276.1577.393,109.8 0.000.000.000.00-7,677.7981.13,782.5276.1577.399,505.5 97.144.11-0.064.00-8,696.81,635.94,094.4329.3876.6810,800.0 0.000.000.000.00-8,746.31,719.64,117.4329.3876.6810,900.0 0.000.003.003.00-8,972.42,101.54,168.8329.3890.1111,347.7 NDBi-044 Heel v.0 93.060.000.000.00-12,078.47,350.14,156.8329.3990.1117,446.5 NDBi-044 Toe v.0 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 3 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 47.0 0.00 47.0 0.0 0.00.00 421,883.435,972,689.12 70° 20' 7.816 N 150° 38' 1.541 W 100.0 0.00 100.0 0.0 0.00.00 421,883.435,972,689.12 70° 20' 7.816 N 150° 38' 1.541 W 200.0 0.00 200.0 0.0 0.00.00 421,883.435,972,689.12 70° 20' 7.816 N 150° 38' 1.541 W 300.0 0.00 300.0 0.0 0.00.00 421,883.435,972,689.12 70° 20' 7.816 N 150° 38' 1.541 W 400.0 0.00 400.0 0.0 0.00.00 421,883.435,972,689.12 70° 20' 7.816 N 150° 38' 1.541 W Start Build 3.00 500.0 3.00 500.0 2.5 -0.7345.00 421,882.785,972,691.66 70° 20' 7.841 N 150° 38' 1.561 W 600.0 6.00 599.6 10.1 -2.7345.00 421,880.835,972,699.26 70° 20' 7.916 N 150° 38' 1.620 W Start DLS 3.00 TFO -70.22 700.0 7.56 698.9 20.4 -8.0323.02 421,875.625,972,709.62 70° 20' 8.017 N 150° 38' 1.775 W 800.0 9.81 797.8 31.1 -18.5309.74 421,865.235,972,720.43 70° 20' 8.122 N 150° 38' 2.082 W 900.0 12.38 895.9 42.2 -34.2301.64 421,849.665,972,731.66 70° 20' 8.231 N 150° 38' 2.540 W 1,000.0 15.11 993.1 53.6 -55.0296.36 421,828.985,972,743.29 70° 20' 8.343 N 150° 38' 3.148 W 1,051.7 16.55 1,042.8 59.6 -67.8294.30 421,816.295,972,749.44 70° 20' 8.403 N 150° 38' 3.520 W Upper Schrader Bluff 1,100.0 17.92 1,088.9 65.3 -80.9292.68 421,803.225,972,755.28 70° 20' 8.459 N 150° 38' 3.904 W 1,200.0 20.79 1,183.3 77.3 -111.8289.97 421,772.475,972,767.59 70° 20' 8.577 N 150° 38' 4.805 W 1,293.4 23.49 1,269.8 88.7 -145.1288.02 421,739.315,972,779.36 70° 20' 8.689 N 150° 38' 5.778 W TM_BRO_030_39 1,300.0 23.68 1,275.8 89.6 -147.6287.90 421,736.815,972,780.20 70° 20' 8.697 N 150° 38' 5.851 W 1,400.0 26.60 1,366.3 102.0 -188.2286.26 421,696.335,972,793.07 70° 20' 8.819 N 150° 38' 7.037 W 1,430.8 27.50 1,393.8 105.9 -201.7285.82 421,682.905,972,797.08 70° 20' 8.857 N 150° 38' 7.430 W Permafrost Base Transition 1,500.0 29.53 1,454.6 114.6 -233.5284.93 421,651.155,972,806.16 70° 20' 8.943 N 150° 38' 8.360 W 1,600.0 32.48 1,540.3 127.4 -283.4283.81 421,601.405,972,819.44 70° 20' 9.069 N 150° 38' 9.817 W 1,700.0 35.43 1,623.2 140.2 -337.7282.87 421,547.195,972,832.87 70° 20' 9.195 N 150° 38' 11.405 W 1,800.0 38.39 1,703.2 153.2 -396.4282.05 421,488.705,972,846.42 70° 20' 9.323 N 150° 38' 13.117 W 1,842.0 39.64 1,735.8 158.6 -422.3281.73 421,462.895,972,852.13 70° 20' 9.376 N 150° 38' 13.873 W Middle Schrader Bluff 1,900.0 41.36 1,779.9 166.2 -459.2281.33 421,426.075,972,860.04 70° 20' 9.450 N 150° 38' 14.950 W 2,000.0 44.32 1,853.2 179.1 -525.9280.69 421,359.475,972,873.70 70° 20' 9.578 N 150° 38' 16.899 W 2,100.0 47.30 1,922.9 192.1 -596.4280.11 421,289.105,972,887.37 70° 20' 9.705 N 150° 38' 18.959 W 2,200.0 50.27 1,988.8 204.9 -670.5279.59 421,215.145,972,901.00 70° 20' 9.831 N 150° 38' 21.123 W 2,300.0 53.25 2,050.7 217.7 -748.0279.11 421,137.805,972,914.56 70° 20' 9.957 N 150° 38' 23.386 W 2,400.0 56.22 2,108.4 230.3 -828.7278.67 421,057.285,972,928.01 70° 20' 10.081 N 150° 38' 25.742 W 2,482.5 58.68 2,152.8 240.6 -897.4278.33 420,988.655,972,939.00 70° 20' 10.182 N 150° 38' 27.750 W MCU (Lower Schrader Bluff) 2,500.0 59.20 2,161.8 242.7 -912.3278.26 420,973.825,972,941.32 70° 20' 10.203 N 150° 38' 28.183 W 2,600.0 62.18 2,210.8 255.0 -998.6277.87 420,887.635,972,954.44 70° 20' 10.323 N 150° 38' 30.705 W 2,700.0 65.17 2,255.1 266.9 -1,087.4277.50 420,798.955,972,967.35 70° 20' 10.441 N 150° 38' 33.299 W 2,800.0 68.15 2,294.7 278.6 -1,178.5277.15 420,708.035,972,980.00 70° 20' 10.556 N 150° 38' 35.958 W 2,822.0 68.81 2,302.8 281.2 -1,198.8277.08 420,687.755,972,982.74 70° 20' 10.581 N 150° 38' 36.551 W 13-3/8" Surface Casing 2,900.0 71.13 2,329.5 290.0 -1,271.5276.82 420,615.115,972,992.36 70° 20' 10.668 N 150° 38' 38.675 W 3,000.0 74.12 2,359.4 301.1 -1,366.3276.49 420,520.465,973,004.40 70° 20' 10.776 N 150° 38' 41.444 W 3,100.0 77.10 2,384.2 311.8 -1,462.6276.18 420,424.325,973,016.08 70° 20' 10.881 N 150° 38' 44.255 W 3,109.8 77.39 2,386.4 312.8 -1,472.0276.15 420,414.865,973,017.20 70° 20' 10.891 N 150° 38' 44.531 W Start 6395.8 hold at 3109.8 MD 3,200.0 77.39 2,406.1 322.2 -1,559.6276.15 420,327.435,973,027.54 70° 20' 10.984 N 150° 38' 47.088 W 3,300.0 77.39 2,427.9 332.7 -1,656.6276.15 420,230.525,973,039.00 70° 20' 11.086 N 150° 38' 49.922 W 3,400.0 77.39 2,449.7 343.1 -1,753.6276.15 420,133.625,973,050.46 70° 20' 11.189 N 150° 38' 52.756 W 3,496.4 77.39 2,470.8 353.2 -1,847.2276.15 420,040.165,973,061.51 70° 20' 11.288 N 150° 38' 55.489 W Tuluvak Shale 3,500.0 77.39 2,471.6 353.6 -1,850.7276.15 420,036.715,973,061.91 70° 20' 11.291 N 150° 38' 55.590 W 3,551.4 77.39 2,482.8 358.9 -1,900.6276.15 419,986.885,973,067.81 70° 20' 11.344 N 150° 38' 57.047 W TM_BRO_030_37 3,600.0 77.39 2,493.4 364.0 -1,947.7276.15 419,939.815,973,073.37 70° 20' 11.394 N 150° 38' 58.423 W 3,700.0 77.39 2,515.2 374.5 -2,044.7276.15 419,842.905,973,084.83 70° 20' 11.496 N 150° 39' 1.257 W 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 4 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 3,789.6 77.39 2,534.8 383.8 -2,131.7276.15 419,756.035,973,095.10 70° 20' 11.588 N 150° 39' 3.797 W Tuluvak Sand 3,800.0 77.39 2,537.1 384.9 -2,141.8276.15 419,746.005,973,096.29 70° 20' 11.599 N 150° 39' 4.091 W 3,900.0 77.39 2,558.9 395.4 -2,238.8276.15 419,649.095,973,107.75 70° 20' 11.701 N 150° 39' 6.925 W 4,000.0 77.39 2,580.7 405.8 -2,335.8276.15 419,552.195,973,119.20 70° 20' 11.804 N 150° 39' 9.758 W 4,100.0 77.39 2,602.5 416.3 -2,432.8276.15 419,455.295,973,130.66 70° 20' 11.906 N 150° 39' 12.592 W 4,200.0 77.39 2,624.4 426.7 -2,529.9276.15 419,358.385,973,142.12 70° 20' 12.009 N 150° 39' 15.426 W 4,300.0 77.39 2,646.2 437.2 -2,626.9276.15 419,261.485,973,153.58 70° 20' 12.111 N 150° 39' 18.260 W 4,400.0 77.39 2,668.0 447.6 -2,723.9276.15 419,164.575,973,165.03 70° 20' 12.213 N 150° 39' 21.094 W 4,500.0 77.39 2,689.9 458.1 -2,820.9276.15 419,067.675,973,176.49 70° 20' 12.316 N 150° 39' 23.928 W 4,600.0 77.39 2,711.7 468.5 -2,918.0276.15 418,970.765,973,187.95 70° 20' 12.418 N 150° 39' 26.761 W 4,700.0 77.39 2,733.5 479.0 -3,015.0276.15 418,873.865,973,199.41 70° 20' 12.521 N 150° 39' 29.595 W 4,800.0 77.39 2,755.3 489.4 -3,112.0276.15 418,776.955,973,210.87 70° 20' 12.623 N 150° 39' 32.429 W 4,900.0 77.39 2,777.2 499.9 -3,209.1276.15 418,680.055,973,222.32 70° 20' 12.725 N 150° 39' 35.263 W 4,916.6 77.39 2,780.8 501.6 -3,225.2276.15 418,663.925,973,224.23 70° 20' 12.742 N 150° 39' 35.735 W TM_BRO_030_38 5,000.0 77.39 2,799.0 510.3 -3,306.1276.15 418,583.145,973,233.78 70° 20' 12.828 N 150° 39' 38.097 W 5,100.0 77.39 2,820.8 520.7 -3,403.1276.15 418,486.245,973,245.24 70° 20' 12.930 N 150° 39' 40.931 W 5,200.0 77.39 2,842.7 531.2 -3,500.1276.15 418,389.345,973,256.70 70° 20' 13.032 N 150° 39' 43.765 W 5,300.0 77.39 2,864.5 541.6 -3,597.2276.15 418,292.435,973,268.16 70° 20' 13.135 N 150° 39' 46.598 W 5,400.0 77.39 2,886.3 552.1 -3,694.2276.15 418,195.535,973,279.61 70° 20' 13.237 N 150° 39' 49.432 W 5,500.0 77.39 2,908.1 562.5 -3,791.2276.15 418,098.625,973,291.07 70° 20' 13.339 N 150° 39' 52.266 W 5,600.0 77.39 2,930.0 573.0 -3,888.3276.15 418,001.725,973,302.53 70° 20' 13.442 N 150° 39' 55.100 W 5,700.0 77.39 2,951.8 583.4 -3,985.3276.15 417,904.815,973,313.99 70° 20' 13.544 N 150° 39' 57.934 W 5,800.0 77.39 2,973.6 593.9 -4,082.3276.15 417,807.915,973,325.44 70° 20' 13.646 N 150° 40' 0.768 W 5,900.0 77.39 2,995.4 604.3 -4,179.3276.15 417,711.005,973,336.90 70° 20' 13.748 N 150° 40' 3.602 W 6,000.0 77.39 3,017.3 614.8 -4,276.4276.15 417,614.105,973,348.36 70° 20' 13.851 N 150° 40' 6.436 W 6,100.0 77.39 3,039.1 625.2 -4,373.4276.15 417,517.195,973,359.82 70° 20' 13.953 N 150° 40' 9.270 W 6,200.0 77.39 3,060.9 635.7 -4,470.4276.15 417,420.295,973,371.28 70° 20' 14.055 N 150° 40' 12.104 W 6,300.0 77.39 3,082.8 646.1 -4,567.4276.15 417,323.395,973,382.73 70° 20' 14.157 N 150° 40' 14.938 W 6,400.0 77.39 3,104.6 656.6 -4,664.5276.15 417,226.485,973,394.19 70° 20' 14.259 N 150° 40' 17.772 W 6,500.0 77.39 3,126.4 667.0 -4,761.5276.15 417,129.585,973,405.65 70° 20' 14.361 N 150° 40' 20.606 W 6,600.0 77.39 3,148.2 677.5 -4,858.5276.15 417,032.675,973,417.11 70° 20' 14.464 N 150° 40' 23.440 W 6,700.0 77.39 3,170.1 687.9 -4,955.6276.15 416,935.775,973,428.56 70° 20' 14.566 N 150° 40' 26.274 W 6,753.7 77.39 3,181.8 693.5 -5,007.7276.15 416,883.695,973,434.72 70° 20' 14.621 N 150° 40' 27.797 W Seabee 6,800.0 77.39 3,191.9 698.4 -5,052.6276.15 416,838.865,973,440.02 70° 20' 14.668 N 150° 40' 29.108 W 6,900.0 77.39 3,213.7 708.8 -5,149.6276.15 416,741.965,973,451.48 70° 20' 14.770 N 150° 40' 31.942 W 7,000.0 77.39 3,235.6 719.3 -5,246.6276.15 416,645.055,973,462.94 70° 20' 14.872 N 150° 40' 34.776 W 7,100.0 77.39 3,257.4 729.7 -5,343.7276.15 416,548.155,973,474.40 70° 20' 14.974 N 150° 40' 37.610 W 7,200.0 77.39 3,279.2 740.2 -5,440.7276.15 416,451.245,973,485.85 70° 20' 15.076 N 150° 40' 40.444 W 7,300.0 77.39 3,301.0 750.6 -5,537.7276.15 416,354.345,973,497.31 70° 20' 15.178 N 150° 40' 43.278 W 7,400.0 77.39 3,322.9 761.1 -5,634.8276.15 416,257.445,973,508.77 70° 20' 15.280 N 150° 40' 46.112 W 7,500.0 77.39 3,344.7 771.5 -5,731.8276.15 416,160.535,973,520.23 70° 20' 15.382 N 150° 40' 48.946 W 7,600.0 77.39 3,366.5 782.0 -5,828.8276.15 416,063.635,973,531.68 70° 20' 15.484 N 150° 40' 51.780 W 7,700.0 77.39 3,388.3 792.4 -5,925.8276.15 415,966.725,973,543.14 70° 20' 15.586 N 150° 40' 54.614 W 7,800.0 77.39 3,410.2 802.9 -6,022.9276.15 415,869.825,973,554.60 70° 20' 15.688 N 150° 40' 57.448 W 7,900.0 77.39 3,432.0 813.3 -6,119.9276.15 415,772.915,973,566.06 70° 20' 15.790 N 150° 41' 0.282 W 8,000.0 77.39 3,453.8 823.8 -6,216.9276.15 415,676.015,973,577.52 70° 20' 15.892 N 150° 41' 3.116 W 8,100.0 77.39 3,475.7 834.2 -6,313.9276.15 415,579.105,973,588.97 70° 20' 15.994 N 150° 41' 5.951 W 8,200.0 77.39 3,497.5 844.7 -6,411.0276.15 415,482.205,973,600.43 70° 20' 16.096 N 150° 41' 8.785 W 8,300.0 77.39 3,519.3 855.1 -6,508.0276.15 415,385.305,973,611.89 70° 20' 16.198 N 150° 41' 11.619 W 8,400.0 77.39 3,541.1 865.6 -6,605.0276.15 415,288.395,973,623.35 70° 20' 16.300 N 150° 41' 14.453 W 8,500.0 77.39 3,563.0 876.0 -6,702.1276.15 415,191.495,973,634.81 70° 20' 16.402 N 150° 41' 17.287 W 8,600.0 77.39 3,584.8 886.5 -6,799.1276.15 415,094.585,973,646.26 70° 20' 16.504 N 150° 41' 20.121 W 8,700.0 77.39 3,606.6 896.9 -6,896.1276.15 414,997.685,973,657.72 70° 20' 16.606 N 150° 41' 22.955 W 8,800.0 77.39 3,628.5 907.4 -6,993.1276.15 414,900.775,973,669.18 70° 20' 16.708 N 150° 41' 25.790 W 8,900.0 77.39 3,650.3 917.8 -7,090.2276.15 414,803.875,973,680.64 70° 20' 16.810 N 150° 41' 28.624 W 9,000.0 77.39 3,672.1 928.3 -7,187.2276.15 414,706.965,973,692.09 70° 20' 16.912 N 150° 41' 31.458 W 9,100.0 77.39 3,693.9 938.7 -7,284.2276.15 414,610.065,973,703.55 70° 20' 17.013 N 150° 41' 34.292 W 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 5 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 9,200.0 77.39 3,715.8 949.1 -7,381.2276.15 414,513.155,973,715.01 70° 20' 17.115 N 150° 41' 37.126 W 9,300.0 77.39 3,737.6 959.6 -7,478.3276.15 414,416.255,973,726.47 70° 20' 17.217 N 150° 41' 39.960 W 9,400.0 77.39 3,759.4 970.0 -7,575.3276.15 414,319.355,973,737.93 70° 20' 17.319 N 150° 41' 42.795 W 9,500.0 77.39 3,781.3 980.5 -7,672.3276.15 414,222.445,973,749.38 70° 20' 17.421 N 150° 41' 45.629 W 9,505.5 77.39 3,782.5 981.1 -7,677.7276.15 414,217.105,973,750.01 70° 20' 17.426 N 150° 41' 45.785 W 9,505.6 77.39 3,782.5 981.1 -7,677.8276.15 414,217.015,973,750.03 70° 20' 17.426 N 150° 41' 45.788 W Start DLS 4.00 TFO 97.14 9,600.0 76.95 3,803.4 994.0 -7,768.9280.00 414,126.055,973,763.89 70° 20' 17.552 N 150° 41' 48.449 W 9,662.9 76.69 3,817.8 1,006.0 -7,829.0282.57 414,066.095,973,776.51 70° 20' 17.670 N 150° 41' 50.205 W Nanushuk 9,700.0 76.54 3,826.4 1,014.3 -7,864.0284.08 414,031.105,973,785.18 70° 20' 17.751 N 150° 41' 51.230 W 9,800.0 76.20 3,849.9 1,041.3 -7,957.4288.19 413,938.065,973,813.15 70° 20' 18.016 N 150° 41' 53.956 W 9,900.0 75.93 3,874.0 1,074.9 -8,048.4292.30 413,847.385,973,847.66 70° 20' 18.345 N 150° 41' 56.617 W 10,000.0 75.73 3,898.5 1,114.8 -8,136.7296.42 413,759.505,973,888.55 70° 20' 18.737 N 150° 41' 59.197 W 10,049.7 75.66 3,910.8 1,137.0 -8,179.5298.47 413,717.005,973,911.19 70° 20' 18.955 N 150° 42' 0.446 W NT6 MFS 10,100.0 75.60 3,923.3 1,161.0 -8,221.9300.54 413,674.865,973,935.62 70° 20' 19.191 N 150° 42' 1.685 W 10,200.0 75.54 3,948.2 1,213.2 -8,303.4304.67 413,593.855,973,988.64 70° 20' 19.703 N 150° 42' 4.069 W 10,300.0 75.55 3,973.2 1,271.1 -8,381.0308.80 413,516.885,974,047.35 70° 20' 20.271 N 150° 42' 6.337 W 10,354.7 75.59 3,986.8 1,305.1 -8,421.6311.06 413,476.665,974,081.74 70° 20' 20.605 N 150° 42' 7.524 W NT5 MFS 10,400.0 75.64 3,998.1 1,334.5 -8,454.2312.93 413,444.335,974,111.47 70° 20' 20.894 N 150° 42' 8.478 W 10,492.1 75.78 4,020.8 1,397.4 -8,517.5316.73 413,381.735,974,175.01 70° 20' 21.512 N 150° 42' 10.328 W NT4 MFS 10,500.0 75.79 4,022.7 1,403.0 -8,522.8317.06 413,376.545,974,180.67 70° 20' 21.567 N 150° 42' 10.482 W 10,600.0 76.02 4,047.1 1,476.3 -8,586.2321.18 413,313.855,974,254.64 70° 20' 22.287 N 150° 42' 12.338 W 10,700.0 76.32 4,071.0 1,554.1 -8,644.3325.28 413,256.565,974,332.99 70° 20' 23.051 N 150° 42' 14.038 W 10,788.8 76.64 4,091.8 1,626.6 -8,691.2328.92 413,210.425,974,405.98 70° 20' 23.764 N 150° 42' 15.410 W NT3 MFS 10,800.0 76.68 4,094.4 1,635.9 -8,696.8329.38 413,204.975,974,415.33 70° 20' 23.855 N 150° 42' 15.572 W 10,800.1 76.68 4,094.4 1,636.0 -8,696.9329.38 413,204.905,974,415.45 70° 20' 23.856 N 150° 42' 15.575 W Start 100.0 hold at 10800.1 MD 10,900.0 76.68 4,117.4 1,719.6 -8,746.3329.38 413,156.285,974,499.58 70° 20' 24.678 N 150° 42' 17.023 W 10,900.1 76.68 4,117.4 1,719.7 -8,746.4329.38 413,156.215,974,499.70 70° 20' 24.679 N 150° 42' 17.025 W Start Build 3.00 10,906.0 76.86 4,118.8 1,724.7 -8,749.3329.38 413,153.345,974,504.67 70° 20' 24.728 N 150° 42' 17.111 W 9-5/8" Intermediate Liner 10,906.1 76.86 4,118.8 1,724.7 -8,749.4329.38 413,153.315,974,504.71 70° 20' 24.728 N 150° 42' 17.112 W Nanushuk 3.2 (NT3) 11,000.0 79.68 4,137.9 1,803.9 -8,796.2329.38 413,107.305,974,584.34 70° 20' 25.506 N 150° 42' 18.483 W 11,100.0 82.68 4,153.2 1,888.9 -8,846.5329.38 413,057.865,974,669.88 70° 20' 26.342 N 150° 42' 19.956 W 11,200.0 85.68 4,163.4 1,974.5 -8,897.2329.38 413,008.095,974,756.00 70° 20' 27.183 N 150° 42' 21.439 W 11,300.0 88.68 4,168.3 2,060.4 -8,948.1329.38 412,958.135,974,842.45 70° 20' 28.028 N 150° 42' 22.928 W 11,347.7 90.11 4,168.8 2,101.5 -8,972.4329.38 412,934.255,974,883.77 70° 20' 28.431 N 150° 42' 23.639 W 11,347.9 90.11 4,168.8 2,101.6 -8,972.5329.38 412,934.185,974,883.89 70° 20' 28.433 N 150° 42' 23.641 W Start 6098.7 hold at 11347.9 MD 11,400.0 90.11 4,168.7 2,146.5 -8,999.0329.38 412,908.105,974,929.02 70° 20' 28.874 N 150° 42' 24.419 W 11,500.0 90.11 4,168.5 2,232.5 -9,049.9329.38 412,858.075,975,015.60 70° 20' 29.719 N 150° 42' 25.909 W 11,600.0 90.11 4,168.3 2,318.6 -9,100.9329.38 412,808.035,975,102.17 70° 20' 30.565 N 150° 42' 27.400 W 11,700.0 90.11 4,168.1 2,404.7 -9,151.8329.38 412,758.005,975,188.75 70° 20' 31.411 N 150° 42' 28.891 W 11,800.0 90.11 4,167.9 2,490.7 -9,202.8329.38 412,707.975,975,275.32 70° 20' 32.257 N 150° 42' 30.382 W 11,900.0 90.11 4,167.7 2,576.8 -9,253.7329.38 412,657.945,975,361.89 70° 20' 33.102 N 150° 42' 31.874 W 12,000.0 90.11 4,167.5 2,662.8 -9,304.6329.38 412,607.915,975,448.47 70° 20' 33.948 N 150° 42' 33.365 W 12,100.0 90.11 4,167.3 2,748.9 -9,355.6329.38 412,557.885,975,535.04 70° 20' 34.794 N 150° 42' 34.856 W 12,200.0 90.11 4,167.1 2,834.9 -9,406.5329.38 412,507.855,975,621.62 70° 20' 35.639 N 150° 42' 36.347 W 12,300.0 90.11 4,166.9 2,921.0 -9,457.4329.38 412,457.825,975,708.19 70° 20' 36.485 N 150° 42' 37.838 W 12,400.0 90.11 4,166.7 3,007.1 -9,508.4329.38 412,407.795,975,794.76 70° 20' 37.331 N 150° 42' 39.329 W 12,500.0 90.11 4,166.5 3,093.1 -9,559.3329.38 412,357.765,975,881.34 70° 20' 38.177 N 150° 42' 40.820 W 12,600.0 90.11 4,166.3 3,179.2 -9,610.2329.38 412,307.735,975,967.91 70° 20' 39.022 N 150° 42' 42.312 W 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 6 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 12,700.0 90.11 4,166.1 3,265.2 -9,661.2329.38 412,257.715,976,054.49 70° 20' 39.868 N 150° 42' 43.803 W 12,800.0 90.11 4,165.9 3,351.3 -9,712.1329.38 412,207.685,976,141.06 70° 20' 40.714 N 150° 42' 45.294 W 12,900.0 90.11 4,165.7 3,437.3 -9,763.0329.38 412,157.655,976,227.64 70° 20' 41.559 N 150° 42' 46.786 W 13,000.0 90.11 4,165.5 3,523.4 -9,814.0329.38 412,107.625,976,314.22 70° 20' 42.405 N 150° 42' 48.277 W 13,100.0 90.11 4,165.3 3,609.5 -9,864.9329.38 412,057.595,976,400.79 70° 20' 43.251 N 150° 42' 49.768 W 13,200.0 90.11 4,165.1 3,695.5 -9,915.8329.38 412,007.575,976,487.37 70° 20' 44.097 N 150° 42' 51.260 W 13,300.0 90.11 4,164.9 3,781.6 -9,966.7329.38 411,957.545,976,573.94 70° 20' 44.942 N 150° 42' 52.751 W 13,400.0 90.11 4,164.7 3,867.6 -10,017.7329.38 411,907.515,976,660.52 70° 20' 45.788 N 150° 42' 54.243 W 13,500.0 90.11 4,164.5 3,953.7 -10,068.6329.38 411,857.495,976,747.09 70° 20' 46.634 N 150° 42' 55.734 W 13,600.0 90.11 4,164.3 4,039.7 -10,119.5329.38 411,807.465,976,833.67 70° 20' 47.479 N 150° 42' 57.226 W 13,700.0 90.11 4,164.1 4,125.8 -10,170.5329.38 411,757.435,976,920.25 70° 20' 48.325 N 150° 42' 58.717 W 13,800.0 90.11 4,163.9 4,211.9 -10,221.4329.38 411,707.415,977,006.82 70° 20' 49.171 N 150° 43' 0.209 W 13,900.0 90.11 4,163.8 4,297.9 -10,272.3329.38 411,657.385,977,093.40 70° 20' 50.016 N 150° 43' 1.700 W 14,000.0 90.11 4,163.6 4,384.0 -10,323.3329.38 411,607.365,977,179.98 70° 20' 50.862 N 150° 43' 3.192 W 14,100.0 90.11 4,163.4 4,470.0 -10,374.2329.38 411,557.335,977,266.55 70° 20' 51.708 N 150° 43' 4.684 W 14,200.0 90.11 4,163.2 4,556.1 -10,425.1329.38 411,507.315,977,353.13 70° 20' 52.554 N 150° 43' 6.175 W 14,300.0 90.11 4,163.0 4,642.2 -10,476.0329.38 411,457.285,977,439.71 70° 20' 53.399 N 150° 43' 7.667 W 14,400.0 90.11 4,162.8 4,728.2 -10,527.0329.38 411,407.265,977,526.29 70° 20' 54.245 N 150° 43' 9.159 W 14,500.0 90.11 4,162.6 4,814.3 -10,577.9329.38 411,357.235,977,612.86 70° 20' 55.091 N 150° 43' 10.650 W 14,600.0 90.11 4,162.4 4,900.3 -10,628.8329.38 411,307.215,977,699.44 70° 20' 55.936 N 150° 43' 12.142 W 14,700.0 90.11 4,162.2 4,986.4 -10,679.8329.38 411,257.185,977,786.02 70° 20' 56.782 N 150° 43' 13.634 W 14,800.0 90.11 4,162.0 5,072.5 -10,730.7329.38 411,207.165,977,872.60 70° 20' 57.628 N 150° 43' 15.126 W 14,900.0 90.11 4,161.8 5,158.5 -10,781.6329.38 411,157.145,977,959.18 70° 20' 58.473 N 150° 43' 16.618 W 15,000.0 90.11 4,161.6 5,244.6 -10,832.5329.38 411,107.115,978,045.75 70° 20' 59.319 N 150° 43' 18.110 W 15,100.0 90.11 4,161.4 5,330.6 -10,883.5329.39 411,057.095,978,132.33 70° 21' 0.165 N 150° 43' 19.602 W 15,200.0 90.11 4,161.2 5,416.7 -10,934.4329.39 411,007.075,978,218.91 70° 21' 1.010 N 150° 43' 21.094 W 15,300.0 90.11 4,161.0 5,502.8 -10,985.3329.39 410,957.055,978,305.49 70° 21' 1.856 N 150° 43' 22.586 W 15,400.0 90.11 4,160.8 5,588.8 -11,036.2329.39 410,907.025,978,392.07 70° 21' 2.702 N 150° 43' 24.078 W 15,500.0 90.11 4,160.6 5,674.9 -11,087.2329.39 410,857.005,978,478.65 70° 21' 3.547 N 150° 43' 25.570 W 15,600.0 90.11 4,160.4 5,760.9 -11,138.1329.39 410,806.985,978,565.23 70° 21' 4.393 N 150° 43' 27.062 W 15,700.0 90.11 4,160.2 5,847.0 -11,189.0329.39 410,756.965,978,651.81 70° 21' 5.239 N 150° 43' 28.554 W 15,800.0 90.11 4,160.0 5,933.1 -11,239.9329.39 410,706.945,978,738.39 70° 21' 6.084 N 150° 43' 30.046 W 15,900.0 90.11 4,159.8 6,019.1 -11,290.9329.39 410,656.925,978,824.96 70° 21' 6.930 N 150° 43' 31.538 W 16,000.0 90.11 4,159.6 6,105.2 -11,341.8329.39 410,606.905,978,911.54 70° 21' 7.776 N 150° 43' 33.030 W 16,100.0 90.11 4,159.4 6,191.3 -11,392.7329.39 410,556.885,978,998.12 70° 21' 8.621 N 150° 43' 34.522 W 16,200.0 90.11 4,159.2 6,277.3 -11,443.6329.39 410,506.865,979,084.70 70° 21' 9.467 N 150° 43' 36.015 W 16,300.0 90.11 4,159.0 6,363.4 -11,494.6329.39 410,456.845,979,171.28 70° 21' 10.313 N 150° 43' 37.507 W 16,400.0 90.11 4,158.8 6,449.4 -11,545.5329.39 410,406.825,979,257.86 70° 21' 11.158 N 150° 43' 38.999 W 16,500.0 90.11 4,158.6 6,535.5 -11,596.4329.39 410,356.805,979,344.45 70° 21' 12.004 N 150° 43' 40.491 W 16,600.0 90.11 4,158.4 6,621.6 -11,647.3329.39 410,306.785,979,431.03 70° 21' 12.849 N 150° 43' 41.984 W 16,700.0 90.11 4,158.2 6,707.6 -11,698.3329.39 410,256.765,979,517.61 70° 21' 13.695 N 150° 43' 43.476 W 16,800.0 90.11 4,158.0 6,793.7 -11,749.2329.39 410,206.745,979,604.19 70° 21' 14.541 N 150° 43' 44.968 W 16,900.0 90.11 4,157.9 6,879.8 -11,800.1329.39 410,156.725,979,690.77 70° 21' 15.386 N 150° 43' 46.461 W 17,000.0 90.11 4,157.7 6,965.8 -11,851.0329.39 410,106.715,979,777.35 70° 21' 16.232 N 150° 43' 47.953 W 17,100.0 90.11 4,157.5 7,051.9 -11,901.9329.39 410,056.695,979,863.93 70° 21' 17.078 N 150° 43' 49.446 W 17,200.0 90.11 4,157.3 7,137.9 -11,952.9329.39 410,006.675,979,950.51 70° 21' 17.923 N 150° 43' 50.938 W 17,300.0 90.11 4,157.1 7,224.0 -12,003.8329.39 409,956.655,980,037.09 70° 21' 18.769 N 150° 43' 52.431 W 17,400.0 90.11 4,156.9 7,310.1 -12,054.7329.39 409,906.645,980,123.68 70° 21' 19.614 N 150° 43' 53.923 W 17,446.3 90.11 4,156.8 7,350.0 -12,078.3329.39 409,883.455,980,163.80 70° 21' 20.006 N 150° 43' 54.615 W TD at 17446.6 17,446.5 90.11 4,156.8 7,350.1 -12,078.4329.39 409,883.405,980,163.90 70° 21' 20.007 N 150° 43' 54.617 W 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 7 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Design Targets LongitudeLatitude Dip Angle (°) Dip Dir. (°) NDBi-044 Toe v.0 4,156.8 5,980,163.90 409,883.407,350.1 -12,078.40.00 0.00 70° 21' 20.007 N 150° 43' 54.617 W - plan hits target center - Point NDBi-044 Heel v.0 4,168.8 5,974,883.77 412,934.252,101.5 -8,972.40.00 0.00 70° 20' 28.431 N 150° 42' 23.639 W - plan hits target center - Point NDBi-044 Polygon 4,168.8 5,974,883.77 412,934.252,101.5 -8,972.40.00 0.00 70° 20' 28.431 N 150° 42' 23.639 W - plan hits target center - Polygon -131.2Point 1 5,974,748.75 413,301.234,168.8 368.4 True 5,827.8Point 2 5,980,743.62 409,835.914,168.8 -3,159.5 True 5,573.2Point 3 5,980,493.54 409,402.934,168.8 -3,589.9 True -385.7Point 4 5,974,498.77 412,868.244,168.8 -62.0 True Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 13-3/8" Surface Casing2,302.82,822.0 13-3/8 16 9-5/8" Intermediate Liner4,118.810,906.0 9-5/8 12-1/4 4-1/2" Production Liner4,156.817,446.5 4-1/2 8-1/2 Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations 1,051.7 Upper Schrader Bluff 0.001,042.8 1,293.4 TM_BRO_030_39 0.001,269.8 1,430.8 Permafrost Base Transition 0.001,393.8 1,842.0 Middle Schrader Bluff 0.001,735.8 2,482.5 MCU (Lower Schrader Bluff) 0.002,152.8 3,496.4 Tuluvak Shale 0.002,470.8 3,551.4 TM_BRO_030_37 0.002,482.8 3,789.6 Tuluvak Sand 0.002,534.8 4,916.6 TM_BRO_030_38 0.002,780.8 6,753.7 Seabee 0.003,181.8 9,662.9 Nanushuk 0.003,817.8 10,049.7 NT6 MFS 0.003,910.8 10,354.7 NT5 MFS 0.003,986.8 10,492.1 NT4 MFS 0.004,020.8 10,788.8 NT3 MFS 0.004,091.8 10,906.1 Nanushuk 3.2 (NT3) 0.004,118.8 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 8 Planning Report -Geographic Well NDBi-044Local Co-ordinate Reference:Database:EDM STO Alaska Parker 272 As PPlanned @ 69.8usftTVD Reference:Santos NAD27 ConversionCompany: Parker 272 As PPlanned @ 69.8usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:NDBi-044Well: NDBi-044Wellbore: Plan: NDBi-044 Rev D.0Design: Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 400.0 400.0 0.0 0.0 Start Build 3.00 600.0 599.6 10.1 -2.7 Start DLS 3.00 TFO -70.22 3,109.8 2,386.4 312.8 -1,472.0 Start 6395.8 hold at 3109.8 MD 9,505.6 3,782.5 981.1 -7,677.8 Start DLS 4.00 TFO 97.14 10,800.1 4,094.4 1,636.0 -8,696.9 Start 100.0 hold at 10800.1 MD 10,900.1 4,117.4 1,719.7 -8,746.4 Start Build 3.00 11,347.9 4,168.8 2,101.6 -8,972.5 Start 6098.7 hold at 11347.9 MD 17,446.3 4,156.8 7,350.0 -12,078.3 TD at 17446.6 18/09/2023 4:45:46PM COMPASS 5000.17 Build 02 Page 9 0 15 0 0 30 0 0 45 0 0 60 0 0 75 0 0 South(-)/North(+) -1 2 0 0 0 - 1 0 5 0 0 - 9 0 0 0 - 7 5 0 0 - 6 0 0 0 - 4 5 0 0 - 3 0 0 0 - 1 5 0 0 0 We s t ( - ) / E a s t ( + ) ND B i - 0 4 4 H e e l v . 0 ND B i - 0 4 4 T o e v . 0 13 - 3 / 8 " S u r f a c e C a s i n g 9- 5 / 8 " I n t e r m e d i a t e L i n e r 4- 1 / 2 " P r o d u c t i o n L i n e r P l a n : N D B i - 0 4 4 R e v D . 0 Pl a n : N D B i - 0 4 4 R e v D . 0 16 : 3 0 , S e p t e m b e r 1 8 2 0 2 3 Northing (4500 usft/in) Ea s t i n g ( 4 5 0 0 u s f t / i n ) Northing (4500 usft/in) Ea s t i n g ( 4 5 0 0 u s f t / i n ) Qu g u r u k 3 A Qu g r u k 3 0 1 Pl a n : N D B - 2 5 R e v A . 0 Pl a n : N D B - 0 3 1 R e v A . 0 ND B - 0 3 2 Pl a n : N D B - 0 3 3 R e v A . 0 Pl a n : N D B - 0 3 7 R e v A . 0 Pl a n : N D B - 0 3 9 R e v A . 0 Pl a n : N D B - 0 4 0 R e v A . 0 Pl a n : N D B - 0 4 5 R e v A . 0 Pl a n : N D B - 0 4 8 R e v A . 0 Pl a n : N D B - 0 5 1 R e v A . 0 Pl a n : N D B i - 0 1 4 R e v B . 0 Pl a n : N D B i - 0 3 0 R e v B . 2 Pl a n : N D B i - 0 3 4 R e v A . 0 Pl a n : N D B i - 0 3 6 R e v A . 0 ND B i - 0 3 8 R e v A . 0 Pl a n : N D B i - 0 4 1 R e v A . 0 ND B i - 0 4 3 ND B i - 0 4 3 A Pl a n : N D B i - 0 4 6 R e v A . 0 Pl a n : N D B i - 0 4 9 R e v A . 0 Pl a n : N D B i - 0 5 0 R e v A . 0 Qu g r u k - 3 A Qu g r u k - 3 0 1 Pl a n : N D B i - 0 4 4 R e v D . 0 ND B NP F 16 : 3 5 , S e p t e m b e r 1 8 2 0 2 3 -1 5 0 0 0 15 0 0 30 0 0 45 0 0 60 0 0 True Vertical Depth 0 2 0 0 0 4 0 0 0 6 0 0 0 8 0 0 0 1 0 0 0 0 1 2 0 0 0 1 4 0 0 0 Ve r t i c a l S e c t i o n a t 3 0 1 . 3 2 ° 13 - 3 / 8 " S u r f a c e C a s i n g 9- 5 / 8 " I n t e r m e d i a t e L i n e r 4- 1 / 2 " P r o d u c t i o n L i n e r 20 " C o n d u c t o r D r i v e n 1 0 0 0 2 0 0 0 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 17447 0° 3 0 ° 60 ° 77° 90° 90° Plan: NDBi-044 Rev D.0 Up p e r S c h r a d e r B l u f f Pe r m a f r o s t B a s e T r a n s i t i o n Mi d d l e S c h r a d e r B l u f f MC U ( L o w e r S c h r a d e r B l u f f ) Tu l u v a k S h a l e Tu l u v a k S a n d Se a b e e Na n u s h u k NT 6 M F S NT 5 M F S NT 4 M F S NT 3 M F S Na n u s h u k 3 . 2 ( N T 3 ) TM _ B R O _ 0 3 0 _ 3 7 TM _ B R O _ 0 3 0 _ 3 8 TM _ B R O _ 0 3 0 _ 3 9 Pl a n : N D B i - 0 4 4 R e v D . 0 16 : 3 3 , S e p t e m b e r 1 8 2 0 2 3 NDBi-044 PTD AOGCC - 29 - 19-Sep-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-044 PTD AOGCC - 34 - 19-Sep-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). 12-1/4” Intermediate 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. Hole Cleaning in 77q Sail Conduct hydraulics modeling and control ROP limits based on cuttings returns and observed ECD’s compared to model. Pack Off During Cementing Proper wellbore cleanup procedure prior to running in hole. Stage circulation rates up while running in hole with liner. Circulate bottoms up at multiple depths to condition mud the way in the hole. Circulate at TD to planned cementing rates and ensure hole is clean. Wireline Inaccessibility The sail angle on this section is too high for wireline to be run conventionally. If wireline logs are required for operations a tractor will be required. Operational complexity with Mechanical two stage cement equipment. The 2nd stage of the cement job will be conducted through a mechanically shifted sleeve. This will require the LTP to not be set until the second stage is pumped giving a higher complexity leading to complication with setting the LTP. 8-1/2” Production Hole Section NDBi-044 PTD AOGCC - 35 - 19-Sep-23 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 signs of washout. Close Approach NDBi-043 The heel to toe separation between NDBi-034 production liner is ~500’. NDBi-034 will not have production, injection or frac operations happening when production hole drilling commences. * Note that no H2S has been encountered on nearby offset wells, and H2S is not anticipated in this well. The heel to toe separation between NDBi-034 production liner is ~500’. NDBi-034 will not have production, injection or frac operations happening when production hole drilling commences. NDBi-044 PTD AOGCC - 36 - 19-Sep-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-044 PTD AOGCC - 37 - 19-Sep-23 Attachment 6: Cement Summary Surface Casing Cement Casing Size 13-3/8” 68# L-80 BTC Surface Casing Basis Lead Open hole volume + 300% excess in permafrost / 50% excess below permafrost Lead TOC Surface Tail Open hole volume + 50% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 10.5 ppg Clean Spacer Lead 11.0ppg Lead:554.4bbls, 3113cuft, 1092sks ArcticCem, Yield: 2.85 cuft/sk Tail 15.3ppg Tail:68.9bbls, 387cuft, 309.5sks 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 Intermediate Liner Cement Casing Size 9-5/8” 47# L-80 Hydril 563 Intermediate Liner Basis Lead Open hole volume + 30% excess + 150’ liner lap Lead TOC Stage 1: 250’ TVD above top Nanushuk Stage 2: Top of the 9-5/8” Liner Tail Open hole volume + 85 ft shoe track Tail TOC Stage 1: 500 ft above casing shoe Stage 2: 500 ft above stage collar Total Cement Volume Spacer ~80 bbls of 12.2 ppg Clean Spacer Lead Stage 1: 30% Open Hole Excess 12.0ppg Lead:141.8bbls, 796.4cuft, 338.2sks ExtendaCem, Yield: 2.34 cuft/sk Stage 2: 50% Open Hole Excess 12.0ppg Lead:341.2bbls, 1915.9cuft, 815.2sks ExtendaCem, Yield: 2.35 cuft/sk Tail Stage 1: 30% Open Hole Excess 15.3ppg Tail: 42.5bbls, 238.5cuft, 192.9sks VersaCem Type I/II – 1.23 cuft/sk Stage 2: 50% Open Hole Excess 15.3ppg Tail: 41.8bbls, 234.9cuft, 190.9sks VersaCem Type I/II – 1.23 cuft/sk Temp BHST 99° F Verification Method LWD TOC Notes Job will be mixed on the fly NDBi-044 PTD AOGCC - 38 - 19-Sep-23 Attachment 7: Prognosed Formation Tops NDBi-044 Prognosed Tops Formation MD (ft) TVD KB (ft) TVD Path (ft) Uncertainty Range (±ft) Pore Pressure (ppg) Upper Schrader Bluff 1051 1043 973 100 7.2 Permafrost Base Transition 1430 1393 1324 100 7.3 Middle Schrader Bluff 1842 1736 1666 100 7.6 MCU (Lower Schrader Bluff) 2482 2153 2083 100 7.8 Tuluvak Shale 3496 2470. 2401 100 7.9 Tuluvak Sand 3789 2534 2465 100 10.1 Seabee 6753 3182 3112 100 9.2 Nanushuk 9663 3818 3748 100 8.9 NT6 MFS 10049 3910 3841 100 8.9 NT5 MFS 10354 3986 3917 100 8.8 NT4 MFS 10492 4020 3951 100 8.8 NT3 MFS 10789 4091 4022 100 8.8 Nanushuk 3.2 (NT3) 10906 4119 4049 100 8.8 NDBi-044 PTD AOGCC - 39 - 19-Sep-23 Attachment 8: Well Schematic NDBi-044 PTD AOGCC - 40 - 19-Sep-23 Attachment 9: Formation Evaluation Program 16” Surface Hole LWD Gamma Ray Resistivity 12-1/4” Intermediate Hole LWD Gamma Ray Resistivity 8-1/2” Production Hole LWD Gamma Ray Resistivity Sonic Density Neutron Ultra Deep Resistivity (Contingent on Availability) Mudlogging Mudlogging will be utilized from surface to TD. NDBi-044 PTD AOGCC - 41 - 19-Sep-23 Attachment 10: Wellhead & Tree Diagram NDBi-044 PTD AOGCC - 42 - 19-Sep-23 Attachment 11: Injector Area of Review Wells within ¼ mile of proposed injection well. Distance Annulus integrity Area of Review Information No Wells are within ¼ mile radius at the time of drilling NDBi-044. Q-301 P&A Exploration Well. See attached email correspondence for documentation -A.Dewhurst 03OCT23 Q3A 1.) 1st plug (open hole plug): An open hole balanced cement plug was attempted to be laid in the well from 10,420’ MD by pumping a 136 bbls of 15.8 ppg cement. Cement was pumped with full returns, but while laying in the balanced plug in the well the string including the drill pipe and 4-1/2” 2,000’ 12.6 ppf tubing stinger became stuck at 10,383’ MD. The pipe was severed at 6,243’ MD. TOC was estimated to be at 8,003’ MD in the annulus and 8,650’ MD inside the drill pipe. 2.) 2nd plug (open hole balanced plug): A second open hole balanced plug was placed in the well by circulating 73 bbls of 15.8 ppg class G cement into the hole at 4950’ MD. TOC was confirmed at 4,177’ MD by tagging and placing 15k WOB several times. 1.) 3rd plug (Cased hole plug): A cement retainer was placed at 2,060’ MD and 37.5 bbl balanced cement plug was placed on top of the retainer with TOC estimated to be at 1,810’ MD. 2.) 4th plug (Cased hole plug): A final cement retainer was placed at 280’ MD and 42 bbls of 15.7 ppg AS1 cement was placed on top of the retainer to surface. An additional cement top off job was performed after the rig moved off location and the well was secured with a weld on metal cap. 183’ 1,239’ Q-301 was an exploration/appraisal well that was drilled in 2015. It was hydraulic fractured in the Nanushuk reservoir, flowed back, and plugged and abandoned in the same winter season. • The Nanushuk formation top was identified at 4042’ MD, with Nanushuk target formation at 4631’ MD. • 9-5/8” Intermediate casing is set at 5241’ MD in the Nanushuk reservoir. The primary cement job has the TOC at 3810’ MD (96.7 bbls 13.9ppg Extended Class G), with a second stage cement job from 3008’ MD to surface (187 bbls of 12.2ppg Extended Type I/II). • The 4-1/2” production liner in the Nanushuk reservoir is set at 7495’ MD. The liner was P&A with a cement retainer set at 4503’ MD and 48 bbls squeezed below the retainer (4-1/2” liner volume). • 3 cement abandonment plugs were set in the 9-5/8” casing: 1. 1st Plug (300’ above cement retainer): 18 bbls of 15.8 ppg cement laid above the cement retainer at 4503’. 2. 2nd Plug (300’ across 13-3/8” casing shoe): A 9-5/8” bridge plug was set at 2207’ MD (100’ below the surface casing shoe) with 19.1 bbls of 15.6ppg Class G cement plug laid on top of it. • The 13-3/8”casing was abandoned with two cased hole cement plugs placed on top of retainers. Q3A was an exploration/appraisal well that was sidetracked off the abandoned Q3 mother bore drilled in 2013. • The Q3A well’s 8-1/2”open hole section was drilled to TD at 10,546’ MD. The Tuluvak, Nanushuk, Kupaurk C, and Alpine formations were drilled at 2472’, 4,678’, 9,342’, and 9,718’ MD respectively. • The 8-1/2” open hole section was abandoned with two open hole plugs: SANTOS LIMITED-EBUS Critical Static Gel Strength and Heat of Hydration Report For: Date: Wednesday, October 04, 2023 NDB NDB-024 13-3/8" Surface Sincerely, Halliburton Alaska Legal Notice Warning Disclaimer: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk. 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Customer: SANTOS LIMITED-EBUS Job: NDB-024 13-3/8" Surface Case: NDB-024 13-3/8" Surface Page 3 (v. 7.0.192.0) Created: Wednesday, October 04, 2023 Table of Contents Temperature Modeling ........................................................................................................................................... 4 Wait on Cement Plot ............................................................................................................................................................................. 4 Appendix ................................................................................................................................................................. 5 Wellbore Geometry - Outer (Casing/Liners) .......................................................................................................................................... 5 Wellbore Geometry - Outer (Open Hole) .............................................................................................................................................. 5 Wellbore Geometry - Inner (Inner) ....................................................................................................................................................... 5 Cu s t o m e r : S A N T O S L I M I T E D - E B U S Jo b : N D B - 0 2 4 1 3 - 3/ 8 " S u r f a c e Ca s e : N D B - 0 2 4 1 3 - 3 / 8 " S u r f a c e Pa g e 4 (v . 7 . 0 . 1 9 2 . 0 ) Cr e a t e d : W e d n e s d a y , O c t o b e r 0 4 , 2 0 2 3 1. 0 Te m p e r a t u r e M o d e l i n g 1. 1 Wa i t o n C e m e n t P l o t Th i s c h a r t s h o w s o u r s p e c i f i c h e a t o f h y d r a t i o n f o r e a c h s l u r r y ( 1 1 P P G L e a d , 1 5 . 3 P P G T a i l ) t h a t w a s p u m p e d o n t h e l a s t s u r f a c e j o b . T h e B l u e l i n e i s o u r t a i l b l e n d a n d t h e R e d l i n e i s o u r l e a d bl e n d . W e c a n s e e t h e r e i s a c o n s i d e r a b l e t e m p e r a t u r e d i f f e r e n c e b e t w e e n o u r l e a d w h i c h w a s p u m p e d a c r o s s t h e p e r m a f r o s t z o n e a nd o u r t a i l . Customer: SANTOS LIMITED-EBUS Job: NDB-024 13-3/8" Surface Case: NDB-024 13-3/8" Surface Page 5 (v. 7.0.192.0) Created: Wednesday, October 04, 2023 2.0 Appendix 2.1 Wellbore Geometry - Outer (Casing/Liners) Top MD Bottom MD Length Constant Friction Factor Outer Diameter Inner Diameter (ft) (ft) (ft) (in) (in) 0.0 80.0 80.0 0.25 20.000 18.874 2.2 Wellbore Geometry - Outer (Open Hole) Top MD Bottom MD Length Constant Friction Factor Inner Diameter Annular Excess (ft) (ft) (ft) (in) (%) 80.0 1,453.0 1,373.0 0.30 16.000 300.00 1,453.0 3,245.0 1,792.0 0.30 16.000 50.00 2.3 Wellbore Geometry - Inner (Inner) Type Top MD Bottom MD Length Outer Diameter Weight Grade Inner Diameter Avg. Joint Length (ft) (ft) (ft) (in) (ppf) (in) (ft) Casing 0.0 3,245.0 3,245.0 13.375 68.00 L80 12.415 40.0 Customer: SANTOS LIMITED-EBUS Job: NDB-024 13-3/8" Surface Case: NDB-024 13-3/8" Surface Page 6 (v. 7.0.192.0) Created: Wednesday, October 04, 2023 1 De w h u r s t , A n d r e w D ( O G C ) Fr o m : Th o m p s o n , J a c o b ( J a c o b ) < J a c o b . T h o m p s o n @ s a n t o s . c o m > Se n t : Mo n d a y , O c t o b e r 9 , 2 0 2 3 1 3 : 0 9 To : De w h u r s t , A n d r e w D ( O G C ) Cc : Da v i e s , S t e p h e n F ( O G C ) ; G u h l , M e r e d i t h D ( O G C ) ; M c L e l l a n , B r y a n J ( O G C ) ; R o b y , D a v i d S ( O G C ) Su b j e c t : RE : P i k k a N D B i - 0 4 4 ( P T D 2 2 3 - 0 8 7 ) - Q u e s t i o n s An d r e w , Ido no t be l i e v e th i s is co n Įde n Ɵal . Fe e l fr e e to ad d it to ou r co r r e s p o n d e n c e . Th a n k s , Ja c o b T h o m p s o n – S e n i o r D r i l l i n g E n g i n e e r Oi l S e a r c h ( A l a s k a ) , L L C a s u b s i d i a r y o f S a n t o s L i m i t e d P. O . B o x 2 4 0 9 2 7 A n c h o r a g e , A l a s k a 9 9 5 2 4 - 0 9 2 7 o: + 1 ( 9 0 7 ) 6 4 6 - 7 0 7 9 | m : + 1 ( 9 0 7 ) 8 5 4 - 4 3 7 7 Ja c o b . T h o m p s o n @ s a n t o s . c o m ht t p s : / / w w w . s a n t o s . c o m / Fr o m : De w h u r s t , An d r e w D(O G C ) <a n d r e w . d e w h u r s t @ a l a s k a . g o v > Se n t : Mo n d a y , Oc t o b e r 9, 20 2 3 12 : 4 0 PM To : Th o m p s o n , Ja c o b (J a c o b ) <J a c o b . T h o m p s o n @ s a n t o s . c o m > Cc : Da v i e s , St e p h e n F(O G C ) <s t e v e . d a v i e s @ a l a s k a . g o v > ; Gu h l , Me r e d i t h D(O G C ) <m e r e d i t h . g u h l @ a l a s k a . g o v > ; Mc L e l l a n , Br y a n J(O G C ) <b r y a n . m c l e l l a n @ a l a s k a . g o v > ; Ro b y , Da v i d S(O G C ) <d a v e . r o b y @ a l a s k a . g o v > Su b j e c t : ![ E X T ] : RE : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s Ja c o b , Th a n k yo u . Th i s su m m a r y is ve r y he l p f u l . Is th e im a g e yo u pr o v i d e d co n Įde n Ɵal ? If no t , it wi l l be in c l u d e d in th e PT D as pa r t of are c o r d of ou r co r r e s p o n d e n c e . An d y Fr o m : Th o m p s o n , Ja c o b (J a c o b ) <Ja c o b . T h o m p s o n @ s a n t o s . c o m > Se n t : Mo n d a y , Oc t o b e r 9, 20 2 3 08 : 5 4 To : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v > Cc : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Gu h l , Me r e d i t h D(O G C ) <me r e d i t h . g u h l @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) <br y a n . m c l e l l a n @ a l a s k a . g o v >; Ro b y , Da v i d S(O G C ) <da v e . r o b y @ a l a s k a . g o v > Su b j e c t : RE : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s An d r e w , I’ v e co n s u l t e d wi t h ou r su b s u r f a c e te a m an d we be l i e v e th e pe r m e a b l e se c Ɵon of th e Na n u s h u k 3to be is o l a t e d by ce m e n t pl u g #2 wh i c h wi l l ke e p th e in j e c Ɵon Ň ui d s wi t h i n th e in j e c Ɵon zo n e . Be l o w ar e afe w po i n t s as we l l as adi a g r a m to he l p ex p l a i n ou r po i n t of vi e w . 1. Th e en Ɵre Na n u s h u k ͲTo r o k in t e r v a l is no t ce m e n t e d , bu t th e ab a n d o n m e n t of Q3 A le Ō ce m e n t ov e r th y ke y pe r m e a b l e zo n e s in th e Na n u s h u k 3cl i n o f o r m . Ce m e n t Pl u g #2 fr o m 49 5 0 ’ MD –4, 2 1 2 ’ MD is o l a t e s th e Na n u s h u k 3pe r m e a b l e zo n e s (L o w e r Sh o r e f a c e , Up p e r Oīsh o r e , Lo w e r Oīsh o r e ) . 2. Th e ba s e of th e ce m e n t pl u g is in th e Up p e r Sl o p e (g r e y ) of th e Na n u s h u k 3cl i n o f o r m . Th e Up p e r Sl o p e de p o f a c i e s is Į ll e d wi t h M1 mu d s th a t ar e no n re s e r v o i r an d no t pe r m e a b l e . 2 Th e ab o v e an a l y s i s sh o w s th a t Q3 A ha s ce m e n t ac r o s s th e pe r m e a b l e in j e c Ɵon zo n e wi t h i n th e Na n u s h u k an d ha s ad e q u a t e is o l a Ɵon . Th a n k s fo r yo u r de t a i l e d re v i e w le t us kn o w if yo u ha v e an y ot h e r qu e s Ɵon s . Th a n k s , Ja c o b T h o m p s o n – S e n i o r D r i l l i n g E n g i n e e r Oi l S e a r c h ( A l a s k a ) , L L C a s u b s i d i a r y o f S a n t o s L i m i t e d P. O . B o x 2 4 0 9 2 7 A n c h o r a g e , A l a s k a 9 9 5 2 4 - 0 9 2 7 o: + 1 ( 9 0 7 ) 6 4 6 - 7 0 7 9 | m : + 1 ( 9 0 7 ) 8 5 4 - 4 3 7 7 Ja c o b . T h o m p s o n @ s a n t o s . c o m ht t p s : / / w w w . s a n t o s . c o m / Fr o m : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v > Se n t : Th u r s d a y , Oc t o b e r 5, 20 2 3 9: 4 5 AM To : Th o m p s o n , Ja c o b (J a c o b ) <Ja c o b . T h o m p s o n @ s a n t o s . c o m > Cc : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Gu h l , Me r e d i t h D(O G C ) <me r e d i t h . g u h l @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) <br y a n . m c l e l l a n @ a l a s k a . g o v >; Ro b y , Da v i d S(O G C ) <da v e . r o b y @ a l a s k a . g o v > Su b j e c t : ![ E X T ] : RE : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s Ja c o b , It ap p e a r s th a t th e Qu g r u k Ͳ3A we l l is op e n fr o m th e Na n u s h u k re s e r v o i r do w n to To k o k sa n d s an d si l t s at ~7 , 5 0 0 Ͳ7, 8 0 0 ’ M D . Th i s apo t e n Ɵal pa t h w a y fo r in j e c t e d Ň ui d s to mi g r a t e ou t of th e ta r g e t e d st r a t a . Ha v e yo u no t e d th i s po t e n Ɵal pa t h w a y ? Wo u l d yo u pl e a s e ha v e yo u r te a m ta k e alo o k at th i s an d re s p o n d wi t h yo u r ow n an a l y s i s , in c l u d i n g wh a t po s s i b l e me a s u r e s wo u l d ke e p in j e c t e d Ň ui d s wi t h i n th e in t e n d e d st r a t a . Th a n k s , An d y 3 Fr o m : Th o m p s o n , Ja c o b (J a c o b ) <Ja c o b . T h o m p s o n @ s a n t o s . c o m > Se n t : Tu e s d a y , Oc t o b e r 3, 20 2 3 16 : 2 4 To : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v > Cc : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Gu h l , Me r e d i t h D(O G C ) <me r e d i t h . g u h l @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) <br y a n . m c l e l l a n @ a l a s k a . g o v >; Ro b y , Da v i d S(O G C ) <da v e . r o b y @ a l a s k a . g o v > Su b j e c t : RE : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s Yo u ar e co r r e c t . Th e ta b l e ha s be e n co r r e c t e d be l o w . Ja c o b T h o m p s o n – S e n i o r D r i l l i n g E n g i n e e r Oi l S e a r c h ( A l a s k a ) , L L C a s u b s i d i a r y o f S a n t o s L i m i t e d P. O . B o x 2 4 0 9 2 7 A n c h o r a g e , A l a s k a 9 9 5 2 4 - 0 9 2 7 o: + 1 ( 9 0 7 ) 6 4 6 - 7 0 7 9 | m : + 1 ( 9 0 7 ) 8 5 4 - 4 3 7 7 Ja c o b . T h o m p s o n @ s a n t o s . c o m ht t p s : / / w w w . s a n t o s . c o m / Fr o m : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v > Se n t : Tu e s d a y , Oc t o b e r 3, 20 2 3 3: 0 3 PM To : Th o m p s o n , Ja c o b (J a c o b ) <Ja c o b . T h o m p s o n @ s a n t o s . c o m > Cc : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Gu h l , Me r e d i t h D(O G C ) <me r e d i t h . g u h l @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) <br y a n . m c l e l l a n @ a l a s k a . g o v >; Ro b y , Da v i d S(O G C ) <da v e . r o b y @ a l a s k a . g o v > Su b j e c t : ![ E X T ] : RE : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s Ja c o b , Th a n k s . Wo u l d yo u pl e a s e co n Įrm th e fo l l o w i n g : to p of 9Ͳ5/ 8 ” at 26 7 2 ’ MD =22 4 3 ’ TV D .Yo u r em a i l ha s 23 2 0 ’ TV D an d Iju s t wa n t to be su r e . An d y Fr o m : Th o m p s o n , Ja c o b (J a c o b ) <Ja c o b . T h o m p s o n @ s a n t o s . c o m > Se n t : Tu e s d a y , Oc t o b e r 3, 20 2 3 14 : 2 1 To : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v > Cc : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Gu h l , Me r e d i t h D(O G C ) <me r e d i t h . g u h l @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) <br y a n . m c l e l l a n @ a l a s k a . g o v >; Ro b y , Da v i d S(O G C ) <da v e . r o b y @ a l a s k a . g o v > Su b j e c t : RE : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s An d r e w , Iap o l o g i z e fo r th e di s c r e p a n c i e s in th e 10 Ͳ40 1 . I’ v e co r r e c t e d th e de p t h s in th e be l o w ta b l e . Ial s o mi s s e d th e tw o ex p l o r a Ɵon we l l s in th e ar e a of re v i e w . I’ v e in c l u d e d th e di s t a n c e s fr o m ou r we l l s al o n g wi t h asu m m a r y of th e me c h a n i c a l co n d i Ɵon of ea c h we l l . Th e r e is no cu r r e n t pl a n to pr e Ͳpr o d u c e ND B i Ͳ04 4 . Pl e a s e fe e l fr e e to re a c h ou t if yo u ha v e an y fu r t h e r qu e s Ɵon s an d Iap o l o g i z e fo r th e mu l Ɵpl e er r o r s . 18 . C a s i n g P r o g r a m : Sp e c i f i c a t i o n s To p - S e t t i n g D e p t h - B o t t o m Ce m e n t Q u a n t i t y , c . f . o r s a c k s Ho l e Ca s i n g We i g h t Gr a d e Co u p l i n g Le n g t h MD TV D MD TV D (i n c l u d i n g s t a g e d a t a ) 42 " 20 " x 3 4 " 21 5 # X- 5 2 We l d e d 80 ' Su r f a c e Su r f a c e 12 8 ' 12 8 ' Gr o u t e d t o S u r f a c e 16 " 13 - 3 / 8 " 68 # L- 8 0 BT C 28 2 2 ' Su r f a c e Su r f a c e 28 2 2 ' 23 0 2 ' Se e a t t a c h m e n t 6 12 - 1 / 4 " 9- 5 / 8 " 47 # L- 8 0 HY D 5 6 3 82 3 4 ' 26 7 2 ' 22 4 3 ' 1 0 9 0 6 ' 41 1 8 ' Se e a t t a c h m e n t 6 8- 1 / 2 " 4- 1 / 2 " 12 . 6 # P- 1 1 0 S HY D 5 6 3 66 9 0 ' 10 7 5 6 ' 40 8 4 ' 17 4 4 6 ' 41 5 6 ' N/ A Tu b i n g 4- 1 / 2 " 12 . 6 # P- 1 1 0 S HY D 5 6 3 10 7 7 6 ' Su r f a c e Su r f a c e 10 7 7 6 ' 40 8 8 ' N/ A CA U T I O N : T h i s e m a i l o r i gin a t e d f r o m o u t s i d e t h e S t a t e o f A l a s k a m a i l s yst e m . D o n o t c l i c k l i n k s o r o p e n a t t a c h m e n t s u n l e s s you r e c o gni z e t h e s e n d e r a n d k n o w t h e c o n t e n t i s s a f e . 4 We l l s wi t h i n ¼ mi l e of pr o p o s e d in j e c Ɵon we l l . Di s t a n c e An n u l u s in t e g r i t y Ar e a of Re v i e w In f o r m a Ɵon QͲ30 1 18 3 ’ P& A Ex p l o r a Ɵon We l l . QͲ30 1 wa s an ex p l o r a t i o n / a p p r a i s a l we l l th a t wa s dr i l l e d in 20 1 5 . It wa s hy d r a u l i c fr a c t u r e d in th e Na n u s h u k re s e r v o i r , fl o w e d ba c k , an d pl u g g e d an d ab a n d o n e d in th e sa m e wi n t e r se a s o n . x Th e Na n u s h u k fo r m a t i o n to p wa s id e n t i f i e d at 40 4 2 ’ MD , wi t h Na n u s h u k ta r g e t fo r m a t i o n at 46 3 1 ’ MD . x 9Ͳ5/ 8 ” In t e r m e d i a t e ca s i n g is se t at 52 4 1 ’ MD in th e Na n u s h u k re s e r v o i r . Th e pr i m a r y ce m e n t jo b ha s th e TO C at 38 1 0 ’ MD (9 6 . 7 bb l s 13 . 9 p p g Ex t e n d e d Cl a s s G) , wi t h ase c o n d st a g e ce m e n t jo b fr o m 30 0 8 ’ MD to su r f a c e (1 8 7 bb l s of 12 . 2 p p g Ex t e n d e d Ty p e I/ I I ) . x Th e 4Ͳ1/ 2 ” pr o d u c t i o n li n e r in th e Na n u s h u k re s e r v o i r is se t at 74 9 5 ’ MD . Th e li n e r wa s P& A wi t h ace m e n t re t a i n e r se t at 45 0 3 ’ MD an d 48 bb l s sq u e e z e d be l o w th e re t a i n e r (4 Ͳ1/ 2 ” li n e r vo l u m e ) . x 3ce m e n t ab a n d o n m e n t pl u g s we r e se t in th e 9Ͳ5/ 8 ” ca s i n g : 1. 1st Pl u g (3 0 0 ’ ab o v e ce m e n t re t a i n e r ) : 18 bb l s of 15 . 8 pp g ce m e n t la i d ab o v e th e ce m e n t re t a i n e r at 45 0 3 ’ . 2. 2nd Pl u g (3 0 0 ’ ac r o s s 13 Ͳ3/ 8 ” ca s i n g sh o e ) : A9Ͳ5/ 8 ” br i d g e pl u g wa s se t at 22 0 7 ’ MD (1 0 0 ’ be l o w th e su r f a c e ca s i n g sh o e ) wi t h 19 . 1 bb l s of 15 . 6 p p g Cl a s s Gce m e n t pl u g la i d on to p of it . 3. 3rd Pl u g (2 8 0 ’ RK B to su r f a c e ) : A9Ͳ5/ 8 ” br i d g e pl u g wa s se t at 28 0 ’ wi t h 25 0 ’ (1 8 bb l s ) of 15 . 6 p p g Pe r m a f r o s t C ce m e n t la i d on to p of th e pl u g . Q3 A 1, 2 3 9 ’ P& A Ex p l o r a Ɵon We l l . Q3 A wa s an ex p l o r a Ɵon / a p p r a i s a l we l l th a t wa s si d e t r a c k e d oī th e ab a n d o n e d Q3 mo t h e r bo r e dr i l l e d in 20 1 3 . x Th e Q3 A we l l ’ s 8Ͳ1/ 2 ” o p e n ho l e se c Ɵon wa s dr i l l e d to TD at 10 , 5 4 6 ’ MD . Th e Tu l u v a k , Na n u s h u k , Ku p a u r k C, an d Al p i n e fo r m a Ɵon s we r e dr i l l e d at 24 7 2 ’ , 4, 6 7 8 ’ , 9, 3 4 2 ’ , an d 9, 7 1 8 ’ MD re s p e c Ɵve l y . x Th e 8Ͳ1/ 2 ” op e n ho l e se c Ɵon wa s ab a n d o n e d wi t h tw o op e n ho l e pl u g s : 1. ) 1st pl u g (o p e n ho l e pl u g ) : An op e n ho l e ba l a n c e d ce m e n t pl u g wa s aƩem p t e d to be la i d in th e we l l fr o m 10 , 4 2 0 ’ MD by pu m p i n g a13 6 bb l s of 15 . 8 pp g ce m e n t . Ce m e n t wa s pu m p e d wi t h fu l l re t u r n s , bu t wh i l e la y i n g in th e ba l a n c e d pl u g in th e we l l th e st r i n g in c l u d i n g th e dr i l l pi p e an d 4Ͳ1/ 2 ” 2, 0 0 0 ’ 12 . 6 pp f tu b i n g sƟng e r be c a m e st u c k at 10 , 3 8 3 ’ MD . Th e pi p e wa s se v e r e d at 6, 2 4 3 ’ MD . TO C wa s es Ɵma t e d to be at 8, 0 0 3 ’ MD in th e an n u l u s an d 8, 6 5 0 ’ MD in s i d e th e dr i l l pi p e . 2. ) 2nd pl u g (o p e n ho l e ba l a n c e d pl u g ) : Ase c o n d op e n ho l e ba l a n c e d pl u g wa s pl a c e d in th e we l l by ci r c u l a Ɵng 73 bb l s of 15 . 8 pp g cl a s s Gce m e n t in t o th e ho l e at 49 5 0 ’ MD . TO C wa s co n Įrm e d at 4, 1 7 7 ’ MD by ta g g i n g an d pl a c i n g 15 k WO B se v e r a l Ɵ me s . x Th e 13 Ͳ3/ 8 ” c a s i n g wa s ab a n d o n e d wi t h tw o ca s e d ho l e ce m e n t pl u g s pl a c e d on to p of re t a i n e r s . 1. ) 3rd pl u g (C a s e d ho l e pl u g ) : Ace m e n t re t a i n e r wa s pl a c e d at 2, 0 6 0 ’ MD an d 37 . 5 bb l ba l a n c e d ce m e n t pl u g wa s pl a c e d on to p of th e re t a i n e r wi t h TO C es Ɵma t e d to be at 1, 8 1 0 ’ MD . 2. ) 4th pl u g (C a s e d ho l e pl u g ) : AĮ na l ce m e n t re t a i n e r wa s pl a c e d at 28 0 ’ MD an d 42 bb l s of 15 . 7 pp g AS 1 ce m e n t wa s pl a c e d on to p of th e re t a i n e r to su r f a c e . An ad d i Ɵon a l ce m e n t to p oī jo b wa s pe r f o r m e d aŌer th e ri g mo v e d oī lo c a Ɵon an d th e we l l wa s se c u r e d wi t h awe l d on me t a l ca p . Ja c o b T h o m p s o n – S e n i o r D r i l l i n g E n g i n e e r Oi l S e a r c h ( A l a s k a ) , L L C a s u b s i d i a r y o f S a n t o s L i m i t e d P. O . B o x 2 4 0 9 2 7 A n c h o r a g e , A l a s k a 9 9 5 2 4 - 0 9 2 7 o: + 1 ( 9 0 7 ) 6 4 6 - 7 0 7 9 | m : + 1 ( 9 0 7 ) 8 5 4 - 4 3 7 7 Ja c o b . T h o m p s o n @ s a n t o s . c o m ht t p s : / / w w w . s a n t o s . c o m / 5 Fr o m : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v > Se n t : Mo n d a y , Oc t o b e r 2, 20 2 3 2: 5 5 PM To : Th o m p s o n , Ja c o b (J a c o b ) <Ja c o b . T h o m p s o n @ s a n t o s . c o m > Cc : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Gu h l , Me r e d i t h D(O G C ) <me r e d i t h . g u h l @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) <br y a n . m c l e l l a n @ a l a s k a . g o v >; Ro b y , Da v i d S(O G C ) <da v e . r o b y @ a l a s k a . g o v > Su b j e c t : ![ E X T ] : Pi k k a ND B i Ͳ04 4 (P T D 22 3 Ͳ08 7 ) Ͳ Qu e s t i o n s Ja c o b , Ja c o b , Iam re v i e w i n g th e ND B i Ͳ04 4 PT D ap p l i c a Ɵon an d ha v e afe w qu e s Ɵon s fo r yo u : x Th e r e ap p e a r to be va r i o u s de p t h di s c r e p a n c i e s on th e 10 Ͳ40 1 pa g e re l a t e d to th e ca s i n g de p t h s . Wo u l d yo u pl e a s e re v i e w th e hi g h l i g h t e d va l u e s an d re p l y wi t h an y co r r e c Ɵon s ? Fo r ex a m p l e , th e ba s e of th e 8. 5 ” li n e r sh o w s 17 , 5 4 8 ’ MD bu t th e pr o p o s e d TD is 17 , 4 4 7 ’ MD . Th e ot h e r s lo o k li k e MD / T V D di s c r e p a n c i e s . Yo u do no t ne e d to su b m i t ane w fo r m . Si m p l y re p l y wi t h th e co r r e c t e d va l u e s an d Iwi l l ma k e th e ad j u s t m e n t s . x Wo u l d yo u ch e c k to se e if th e Qu g r u k 3A an d / o r Qu g r u k 30 1 we l l s en t e r in t o th e qu a r t e r mi l e ra d i u s ? If so , pl e a s e pr o v i d e are p o r t on th e i r me c h a n i c a l co n d i Ɵon fo r th e Ar e a of Re v i e w . x Fi n a l l y , ar e yo u pl a n n i n g to pr e Ͳpr o d u c e th i s in j e c t o r ? Th a n k s , An d y An d r e w De w h u r s t Se n i o r Pe t r o l e u m Ge o l o g i s t Al a s k a Oi l an d Ga s Co n s e r v a Ɵon Co m m i s s i o n 33 3 W. 7t h Av e , An c h o r a g e , AK 99 5 0 1 an d r e w . d e w h u r s t @ a l a s k a . g o v Di r e c t : (9 0 7 ) 79 3 Ͳ12 5 4 Sa n t o s L t d A . B . N . 8 0 0 0 7 5 5 0 9 2 3 Di s c l a i m e r : T h e i n f o r m a t i o n c o n t a i n e d i n t h i s e m a i l i s i n t e n d e d o n l y f o r t h e u s e o f t h e p e r s o n ( s ) t o w h o m i t i s a d d r e s s e d a n d m ay b e c o n f i d e n t i a l o r c o n t a i n p r i v i l e g e d i n f o r m a t i o n . I f y o u a r e n o t t h e i n t e n d e d r e c i p i e n t y o u a r e h e r e b y n o t i f i e d t h a t a n y p e ru s a l , u s e , d i s t r i b u t i o n , c o p y i n g o r d i s c l o s u r e i s s t r i c t l y p r o h i b i t e d . I f y o u h a v e r e c e i v e d t h i s e m a i l i n er r o r p l e a s e i m m e d i a t e l y a d v i s e u s b y r e t u r n e m a i l a n d d e l e t e t h e e m a i l w i t h o u t m a k i n g a c o p y . Pl e a s e c o n s i d e r t h e e n v i r o n m e n t b e f o r e p r i n t i n g t h i s e m a i l 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: NDB-044 info request Date:Monday, October 9, 2023 1:10:25 PM Attachments:image002.jpg image003.png image004.png image005.png image006.jpg CSGS HoH Report NDB-024 13.375 Surface.pdf Bryan, Below is a summary of the QA/QC process for our cementing testing. I’ve also attached the report that Garret sent which has testing on our surface leads cement’s heat of hydration and critical static gel strength transition time. We are not planning on making changes to the surface lead cement blend but are focusing on our approach to drilling the section and operational improvements to help mitigate parting surface casing. Altered directional plan – Planned for reduced DLS in the upper surface hole and a tangent section through an interval where a hard formation has been seen on offsets. It is suspected that this hard streak created a micro dog leg or ledge which could have contributed to the pipe parting. The Planned NDBi-044 is next to NDBi-043. We expect NDBi-044’s surface hole to be analogous to the NDBi-043 which had no issues with the surface casing cement. If losses or other operational issues are experienced while drilling, a tam port collar can be run in the well to allow a top job to be pumped. Plant Received Base Cement QA/QC: 1. All base cements are tested per Halliburton’s global work method. a. This is to achieve a base line result that can be compared over time for each specific base cement when it reaches our plant in Prudhoe Bay and to ensure consistency in the base blends. b. This QA/QC process is completed every time we receive cement from the distributor. Pre-Job Pilot Testing and Slurry Design: 1. Well in advance to any cement job, the design process takes place. a. Design a slurry to meet customer/state requirements for each specific hole section with fresh water (if field water not available at that time) b. Surface Casing Requirements: Low Heat of Hydration, Fast Build Critical Static Gel Strength (per API), Fluid Loss >100cc/30mins c. Pilot Testing Completed to Confirm Results: i. Lead Slurry Æ Mixability, Mud Balance Density Check, API Rheology, API Fluid Loss, API 10B-2 Free Fluid, Thickening Time at BHCT, UCA Compressive, Crush Compressive, Static Gel Strength (MACS II) ii. Tail Slurry Æ Mixability, Mud Balance Density Check, API Rheology, API Fluid Loss, API 10B-2 Free Fluid, Thickening Time at BHCT, UCA Compressive d. Once Slurry has been designed it is then added to our Tri-Annual Slurry Registry, where each of these pilot tests are re-ran to confirm consistency in blends and additives. i. If job design specifications/regulations are changed at any time we will re-run these pilot tests to confirm the new slurry prior to pumping downhole. Pre-Job Bulk Testing: 1. Prior to every cement job we will sample our blended slurry while it is being loaded to the specific job truck. a. Trucks are confirmed empty prior to loading with documentation. b. Blend sampling is conducted across entire blend during loading to ensure representative sample taken. c. Once sample has been collected it is sent directly to the lab in Prudhoe and checked into the queue for testing 2. Each cement sample is tested to confirm thickening time, compressive strength and mixability at the very least. Depending on job type additional tests may be run to confirm additional properties on bulk sample. 3. If Bulk Sample does not meet thickening time job requirements, mixability job requirement or compressive job requirements the slurry will be re-blended and re-tested prior to being delivered to location. If the bulk sample also shows discrepancies to the original pilot testing or tri-annual testing, re-testing or confirmation testing will take place prior to being delivered to location. 4. Pre-Job bulk testing results are always completed prior to pumping with field water samples supplied by the operating company. Post-Job Testing (if required) 1. On-location a sample is taken from every pod of cement on location while pumping downhole 2. If any additional post-job testing is required, we will use these location samples to confirm results with 3. On location a slurry sample for both lead and tail is also taken and supplied to the customer SIDE NOTE: If at any point in this process a base cement, an additive, a pilot slurry, or bulk slurry does not meet requirements or match historical results we will begin the design process from the beginning to meet the requirements again and then confirm results before pumping downhole. Feel free to reach out if you have any questions, 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 https://www.santos.com/ From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, October 3, 2023 6:05 PM To: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> Subject: ![EXT]: NDB-044 info request Jacob, Can you send over the following: 1. Anti-collision scan report 2. QA/QC plan for surface casing cement and describe what will be done differently from NDB-24 to provide a better cementing result. I’m also interested to know if the heat of hydration for this blend of ArcticCem cement is low compared to normal class G or compared to other permafrost cements. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. NANUSHUK OIL POOL X PIKKA 223-087 Pikka NDBi-044 W E L L P E R M I T C H E C K L I S T Co m p a 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 4 In i t i a l C l a s s / T y p e SE R / P E N D 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 e g An n u l a r D i s p o s a l PT D # : 22 3 0 8 7 0 PI K K A , N A N U S H U K O I L - 6 0 0 1 0 0 NA 1 P e r m i t f e e a t t a c h e d Ye s A D L 3 9 2 2 9 8 4 , A D L 3 9 1 4 4 5 , A D L 3 9 3 0 2 1 , a n d A D L 3 9 3 0 1 9 2 L e a s e n u m b e r a p p r o p r i a t e Ye s 3 U n i q u e w e l l n a m e a n d n u m b e r Ye s P I K K A , N A N U S H U K O I L - 6 0 0 1 0 0 - g o v e r n e d b y C O 8 0 7 4 W e 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 5 W e 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 NA 6 W e 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 7 S u 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 8 I f 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 9 O p 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 10 O p 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 11 P e 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 12 P e 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 13 C a 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 No P e n d i n g i s s u a n c e o f P i k k a A I O 14 W e 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 e r v Ye s Q u g r u k 3 A a n d Q u g r u k 3 0 1 15 A l 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 ) No 16 P r 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 17 N o 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 18 C o n d u c t o r s t r i n g p r o v i d e d Ye s 19 S u 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 20 C M 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 T w o s t a g e c e m e n t j o b , s e c o n d s t a g e t i e s i n t o s u r f a c e c a s i n g . 21 C M 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 22 C M 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 23 C a 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 24 A d 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 25 I f 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 26 A d 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 27 I f 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 28 D r 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 29 B O 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 4 7 3 p s i , B O P r a t e d t o 5 k , ( B O P t e s t t o 3 0 0 0 p s i ) 30 B O 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 31 C h 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 32 W o 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 33 I s 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 34 M e 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 H 2 S n o t a n t i c i p a t e d a t t h i s w e l l 35 P e 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 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 t o 1 0 . 1 p p g E M W a n d g a s b e a r i n g 36 D a 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 37 S e 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 38 S e 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 39 C o 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 ] Ap p r AD D Da t e 10 / 3 / 2 0 2 3 Ap p r BJ M Da t e 10 / 9 / 2 0 2 3 Ap p r AD D Da t e 10 / 2 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : 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 1 0 / 1 7 / 2 0 2 3
