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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 . 50 - 1 0 3 - 2 0 8 9 3 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 8 8 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 12 / 1 0 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 1 1 1 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 18 5 7 5 TV D 83 4 3 Cu r r e n t S t a t u s 1- O I L 10 / 8 / 2 0 2 5 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : GR , R E S , D E N , D I R , A Z I , P W D , N E U , S O N I C 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 12 / 3 / 2 0 2 4 10 4 1 4 2 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 : C P A I _ M T 7 - 88 _ C O M P _ M E M _ C o m p r e h e n s i v e H e a d e r . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 10 4 1 4 2 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 : C P A I _ M T 7 - 88 _ C O M P _ M E M _ F u l l H e a d e r . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 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 : C P A I _ M T 7 - 88 _ A P - L O G _ M E M _ R u n 1 . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 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 : C P A I _ M T 7 - 88 _ A P - L O G _ M E M _ R u n 2 . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 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 : C P A I _ M T 7 - 88 _ A P - L O G _ M E M _ R u n 3 . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 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 : C P A I _ M T 7 - 88 _ V S S - T I M E _ M E M _ R u n 1 . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 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 : C P A I _ M T 7 - 88 _ V S S - T I M E _ M E M _ R u n 2 . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 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 : C P A I _ M T 7 - 88 _ V S S - T I M E _ M E M _ R u n 3 . l a s 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 8 8 _ B a k e r MW D _ L W D _ D i s t r i b u t i o n A O G C C . d o c x 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ A P - LO G _ M E M _ R u n 1 . a s c 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ A P - LO G _ M E M _ R u n 2 . a s c 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ A P - LO G _ M E M _ R u n 3 . a s c 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - TI M E _ M E M _ R u n 1 . a s c 39 8 0 2 ED Di g i t a l D a t a We d n e s d a y , O c t o b e r 8 , 2 0 2 5 AO G C C P a g e 1 o f 5 CP A I _ M T 7 - , 88_ CO MP _ M E M _ F u l l H e a d e r . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 9 3 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 8 8 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 12 / 1 0 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 1 1 1 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 18 5 7 5 TV D 83 4 3 Cu r r e n t S t a t u s 1- O I L 10 / 8 / 2 0 2 5 UI C No DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - TI M E _ M E M _ R u n 2 . a s c 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - TI M E _ M E M _ R u n 3 . a s c 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 2 M D _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 2 T V D _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 5 M D _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 5 T V D _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ A P - TI M E _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - DE P T H _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - TI M E _ M E M . c g m 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 2 M D _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 2 T V D _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 5 M D _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ 5 T V D _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ A P - TI M E _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - DE P T H _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 8 8 _ V S S - TI M E _ M E M . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 2 7 D e f i n i t i v e Su r v e y s 1 4 2 3 9 f t M D . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 2 7 D e f i n i t i v e Su r v e y s 1 4 2 3 9 f T M D . t x t 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 8 3 D e f i n i t i v e Su r v e y s t o 1 4 2 3 9 f t M D . p d f 39 8 0 2 ED Di g i t a l D a t a DF 12 / 3 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 8 3 D e f i n i t i v e Su r v e y s t o 1 4 2 3 9 f t M D . t x t 39 8 0 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 40 0 0 1 4 2 0 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 : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ L A S _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 1 4 2 0 0 f t . l a s 39 8 4 2 ED Di g i t a l D a t a We d n e s d a y , O c t o b e r 8 , 2 0 2 5 AO G C C P a g e 2 o f 5 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 9 3 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 8 8 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 12 / 1 0 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 1 1 1 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 18 5 7 5 TV D 83 4 3 Cu r r e n t S t a t u s 1- O I L 10 / 8 / 2 0 2 5 UI C No DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ R M _ T O C _ S o n i c S c o p e 4 7 5 _ R e p o r t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 1 0 0 0 M D _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 2 0 0 0 M D _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 2 0 0 M D _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 4 0 0 0 M D _ R M _ L a b e l e d _ N o v 3 0 - 24 _ 3 0 0 0 f t - 1 4 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 4 0 0 0 M D _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 5 0 0 M D _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ 6 0 0 0 M D _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . p d f 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ D L I S _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . d l i s 39 8 4 2 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 88 _ T O C _ D L I S _ R M _ N o v 3 0 - 2 4 _ 3 0 0 0 f t - 14 2 0 0 f t . h t m l 39 8 4 2 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 10 4 1 8 5 7 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 : M T 7 - 8 8 co m p o s i t e d l o g s . l a s 40 1 8 9 ED Di g i t a l D a t a We d n e s d a y , O c t o b e r 8 , 2 0 2 5 AO G C C P a g e 3 o f 5 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 9 3 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 8 8 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 12 / 1 0 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 1 1 1 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 18 5 7 5 TV D 83 4 3 Cu r r e n t S t a t u s 1- O I L 10 / 8 / 2 0 2 5 UI C No DF 3/ 7 / 2 0 2 5 14 0 5 0 1 8 5 7 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 : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ F i n a l L W D . l a s 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 14 2 1 5 1 8 5 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 : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ S T S Q u a d r a n t s A l l Cu r v e s . l a s 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L W D F i n a l M D . c g m 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L W D F i n a l TV D . c g m 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ A G R _ I m a g e . d l i s 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ A G R _ I m a g e . v e r 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L i t h o S t a r _ I m a g e . d l i s 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L i t h o S t a r _ I m a g e . v e r 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ S T S _ I m a g e . d l i s 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ S T S _ I m a g e . v e r 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L W D F i n a l M D . p d f 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L W D F i n a l T V D . p d f 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L W D F i n a l M D . t i f 40 1 8 9 ED Di g i t a l D a t a DF 3/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U M T 7 - 88 _ L W D _ R M _ 1 4 2 3 9 _ 1 8 5 7 5 _ L W D F i n a l T V D . t i f 40 1 8 9 ED Di g i t a l D a t a DF 3/ 1 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 2 7 D e f i n i t i v e Su r v e y s t o 1 8 5 7 5 f t M D . p d f 40 1 8 9 ED Di g i t a l D a t a DF 3/ 1 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 2 7 D e f i n i t i v e Su r v e y s t o 1 8 5 7 5 f t M D . t x t 40 1 8 9 ED Di g i t a l D a t a We d n e s d a y , O c t o b e r 8 , 2 0 2 5 AO G C C P a g e 4 o f 5 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 9 3 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 8 8 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 12 / 1 0 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 1 1 1 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 18 5 7 5 TV D 83 4 3 Cu r r e n t S t a t u s 1- O I L 10 / 8 / 2 0 2 5 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D 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 0 / 2 0 2 4 Re l e a s e D a t e : 10 / 3 1 / 2 0 2 4 DF 3/ 1 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 8 3 D e f i n i t i v e Su r v e y s t o 1 8 5 7 5 f t M D . p d f 40 1 8 9 ED Di g i t a l D a t a DF 3/ 1 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 8 8 N A D 8 3 D e f i n i t i v e Su r v e y s t o 1 8 5 7 5 f t M D . t x t 40 1 8 9 ED Di g i t a l D a t a We d n e s d a y , O c t o b e r 8 , 2 0 2 5 AO G C C P a g e 5 o f 5 10 / 9 / 2 0 2 5 M. G u h l Transmittal #1424 Detail Date: 3/10/2025 To (External Party): From (CPAI Contact): Email*: aogcc.data@alaska.gov Email*: Anu.Ambatipudi@conocophillips.com First Name*: Meredith First Name*: Anu Last Name*: Guhl Last Name*: Ambatipudi Phone Number:Phone Number: Company: AOGCC Company: Conoco Phillips Address: 333 W. 7th Ave., Suite 100 Address: 700 G Street City: Anchorage City: Anchorage State: Alaska State: Alaska Zip Code: 99501-3539 Zip Code: 99501 Transmittal Info Sent Via: Sharefile Tracking #: Justification: Data Detail Quantity*: Description*: Type*: 1 MT7-88 NAD83 Definitive Surveys to 18575ftMD pdf,txt 1 MT7-88 NAD27 Definitive Surveys to 18575ftMD pdf,txt Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ 224-111 T40189 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.12 09:58:56 -08'00' 111111117114r ConocoPh i l l I ps Transmittal #1422 Detail Date: 3/5/2025 To (External Party): Email*: aogcc.data@alaska.gov First Name*: Meredith Last Name*: Guhl Phone Number: Company: AOGCC Address: 333 W. 7th Ave., Suite 100 City: Anchorage State: Alaska Zip Code: 99501-3539 Sent Via: Sharefile Justification: Quantity*: 1 1 Attachments: Received By: Gavin Gluyas Approver: 224-111 T40189 From (CPAI Contact): Email*: Anu.Ambatipudi@conocophillips.com First Name*: Anu Last Name*: Ambatipudi Phone Number: Company: Conoco Phillips Address: 700 G Street City: Anchorage State: Alaska Zip Code: 99501 Transmittal Info Tracking #: Data Detail Description*: MT7-88 Halliburton final LWD data MT7-88 composite logs Signature: Digitally signed by Gavin Gluyas Date: 2025.03.07 08:45:40-09'00' Signature: Type*: cgm,emf, las, d lis, pdf, of Is$ Date: Date: 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 85' FSL, 338 ' FEL S33 T10N R2E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 100.8 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 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: 23. BOTTOM 20" H-40 134' 13-5/8 L-80 3078' 9-7/8" L-80 7400' 7-5/8" P110-S 8325' 4 1/2" P110 8359' 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 Sr Res EngSr Pet GeoSr Pet Eng 91 N/A 37 Oil-Bbl: Water-Bbl: 2582 Water-Bbl: PRODUCTION TEST 12/23/2024 Date of Test: Oil-Bbl: 5496771050 12/23/2024 24 Flow Tubing 549 6733 10586733 Flowing If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner (12/7/2024): 14095'MD/8290'TVD - 18158'MD/8359'TVD 2582 Gas-Oil Ratio:Choke Size: 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 54' 54' Per 20 AAC 25.283 (i)(2) attach electronic information 62.8 14229' 52' 7263' 94 88 134' 52' 12427' SIZE DEPTH SET (MD) 10 Yards PACKER SET (MD/TVD) 14095' 42" 12.6 5915943 Greater Mooses Tooth/Rendezvous AA081800, AA098885, AA081781 932535000, 932516000, 369446000 54' 33.7 54' 12239' 4104' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): WT. PER FT.GRADE 298274 296571 CEMENTING RECORD 5914681 998'MD/995'TVD SETTING DEPTH TVD 5918383 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD GR, RES, DEN, DIR, AZI, PWD, NEU, SONIC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 12/10/2024 224-111 50-103-20893-00-00 GMT MT7-88 11/6/2024 18575'MD/8343'TVD N/A 155.1 P.O.Box 100360, Anchorage, AK 99510-0360 290241 1129' FSL, 3120' FEL S32 T10N R2E 3741' FSL, 2132' FEL S33 T10N R2E 12/3/2024 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, 68bbls of 15.8ppg Class G8.5"x9-7/8" TUBING RECORD 18158' Lead:90.1 bbl 13.0ppg Class G Tail: 108bbl 15.8ppg Class G 8290' 12-1/4" 6-1/2" 14100'4.5" 14045'MD/8275'TVD BOTTOM 16" Lead: 423bbl 11.0ppg Deep Crete Tail: 69bbl 15.8 G-Blend CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by J. Brooks on 1/7/2025 at 1:05PM Complete 12/10/2024 JSB RBDMS JSB 011325 GDSR-4/7/25VTL 7/29/2025 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 998 995 C-30 1458 1437 2137 2027 K-2 4823 3409 Albian 97 5446 3695 Albian 96 5858 3884 HRZ 12389 7373 Kuparuk C 12753 7527 12762 7627 14375 8356 18575 8343 31. List of Attachments: Directional Survey, Well Schematic, Cement Operations, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Hilda Dupont Digital Signature with Date: Contact Phone:907-265-6675 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: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. LCU/Miluveach C-10 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. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Contact Email:hilda.dupont@conocophillips.com Authorized Title: Drilling Engineer 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. Attached Seperately Formation Name at TD: Alpine C Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval: Alpine C Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG 4-5 (3x) 3) HES Opsis Downhole Gauge 4) 4-½” X Landing Nipple (3.813" ID) 5) HES TNT Production Packer 6) 4-½” DB Landing Nipple (3.75" ID) 7) Baker Hanger w/ Tie Back sleeve 8) Swell Packer and Sleeve Completion 4-½” 12.6# L-80/P110S Hyd563 Liner w/ swell packers and AU sleeve MW: 8.8 Visc Brine 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-1/2” Production Hole TD at 18,575' MD / 8,343' TVD Tubing 4-1/2" 12.6# L-80 Hyd563 MT7-88 As Drilled 12-10-24 X GLGL GLGL 12/10/2024 Baker LH & Packer Baker LH & Packer 16" Surface Hole Surface Casing 13-3/8" 68# L80 / 13-5/8" 88.2# L80-IC Hyd563 Set at 4,104' MD / 3,078' TVD 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7-5/8" 33.7# L-80 / P-110S HYD523 Liner top at +/- 12,239' MD / 7,293' TVD Shoe set @ 14,229' MD / 8,325' TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8" 47# / 9-7/8" 62.8# L-80 HYD563 Set @ 12,427' MD / 7,401' TVD Top HRZ 12,389' MD / 7,373' TVD 4-String Producer Schematic Int1 TOC 8,800' MD / 5,225' TVD (determined by sonic log) Top Alpine C - Prognosed 14,375' MD / 8,356' TVD 14,056' MD / 8,279' TVD Top Sub Albian 93 10,151 MD / 5,846' TVD Top Alpine D 14,185' MD / 8,314' TVD Int2 TOC 14,002' MD / 8,262' TVD (determined by sonic log) Page 1/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/3/2024 07:00 11/3/2024 08:00 1.00 MIRU, MOVE RURD P Pulled the mouse hole & racked back in the derrick. Blew down the steam to the BOP module. Disconnected mud pump room high pressure interconnects. 0.0 0.0 11/3/2024 08:00 11/3/2024 10:00 2.00 MIRU, MOVE RURD P Rigged down rig floor interconnects in flow line room. Blew down steam in pipe shed & rigged down interconnects. Rigged down auger, hammer mill & interconnects in the CPU. SIMOPS: Cut off top of the mouse hole at ground level & capped; rigged down transformer skid & site control shack; unplugged ground wires between modules; installed scaffolding in BOP deck for work on the RCD. 0.0 0.0 11/3/2024 10:00 11/3/2024 12:00 2.00 MIRU, MOVE RURD P Rigged down high pressure lines in Miller's corridor. Blew down steam to the rig floor. Electrician disconnecting electrical interconnects between modules. 0.0 0.0 11/3/2024 12:00 11/3/2024 13:00 1.00 MIRU, MOVE RURD P Finished rigging down steam, water, & air interconnects. Finished disconnecting electrical interconnects. Prepped rig floor for skidding. 0.0 0.0 11/3/2024 13:00 11/3/2024 17:00 4.00 MIRU, MOVE MOB P Moved pipe shed away from the sub base. Stomped CPU away from the pits & set on tires. Moved generator module down the well row out of the way. Staged the CPU down the pad out of the way. Moved the pump & pits modules down the well row out of the way. 0.0 0.0 11/3/2024 17:00 11/3/2024 18:30 1.50 MIRU, MOVE RURD P Skidded rig floor into travel position on the sub base. 0.0 0.0 11/3/2024 18:30 11/3/2024 19:15 0.75 MIRU, MOVE RURD P Unpinned the sub base from the BOP module. Rolled tires to warm up moving system. Jacked up sub base. 0.0 0.0 11/3/2024 19:15 11/3/2024 21:00 1.75 MIRU, MOVE MOB P Moved the sub base forward away from BOP module. Turned tires 90° & moved sub base out of the way of the BOP module. 0.0 0.0 11/3/2024 21:00 11/3/2024 22:00 1.00 MIRU, MOVE RURD P Retracted outriggers on the BOP module. Set wheels down & jacked up BOP module. Hooked up BOP module to truck. 0.0 0.0 11/3/2024 22:00 11/3/2024 22:30 0.50 MIRU, MOVE MOB P Moved the BOP module off of MT7-83. Staged to move onto MT7-88. 0.0 0.0 11/3/2024 22:30 11/4/2024 00:00 1.50 MIRU, MOVE PRLO P Lowered & leveled footprint of the BOP module around MT7-88. SIMOPS: Cleaned up around MT7-83; rebuilt MPD isolation valves on mud pump 4. 0.0 0.0 11/4/2024 00:00 11/4/2024 04:30 4.50 MIRU, MOVE PRLO P Lowered & leveled footprint of the BOP module around MT7-88 conductor. SIMOPS: Cleaned around the rig. 0.0 0.0 11/4/2024 04:30 11/4/2024 06:30 2.00 MIRU, MOVE RURD P Laid pit liner around the cellar area. Sat rig mats around the cellar. Staged wellhead & tote in cellar area. Removed snow & ice from rig mats in preparation for moving BOP module. SIMOPS: Disassembled mud pump 3 discharge Demco valve to rebuild. 0.0 0.0 11/4/2024 06:30 11/4/2024 08:45 2.25 MIRU, MOVE MOB P Spotted BOP module over MT7-88 well center with truck. 0.0 0.0 11/4/2024 08:45 11/4/2024 12:00 3.25 MIRU, MOVE MOB P Spotted sub-base into place & pinned to BOP module. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 2/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/4/2024 12:00 11/4/2024 14:45 2.75 MIRU, MOVE RURD P Shimmed / leveled BOP module & sub- base. Sat outriggers on BOP module. 0.0 0.0 11/4/2024 14:45 11/4/2024 17:30 2.75 MIRU, MOVE RURD P Skidded rig floor into drill postion. SIMOPS: Moved & spotted pipe shed into place. 0.0 0.0 11/4/2024 17:30 11/5/2024 00:00 6.50 MIRU, MOVE MOB P Moved & spotted pits, pumps, CPU, motor modules. Leveled & shimmed all modules. Worked on making up all interconnects. Started plugging in electrical interconnects. 0.0 0.0 11/5/2024 00:00 11/5/2024 04:45 4.75 MIRU, MOVE RURD P Finished hooking up service & electrical interconnects. Completed rig acceptance checklist. Rig accepted at 04:45 hrs. 0.0 0.0 11/5/2024 04:45 11/5/2024 06:00 1.25 MIRU, MOVE RURD P Installed 4" valves on the conductor. Performed pre-spud derrick inspection. Greased the crown, blocks & top drive. Obtained RKBs. SIMOPS cleaned up around the rig from move. Ground Level 54.34' Landing Ring 54.46' 0.0 0.0 11/5/2024 06:00 11/5/2024 07:00 1.00 MIRU, MOVE NUND P Dressed landing ring & load should per FMC Rep. Installed starting head with low pressure riser on the 20" conductor. Tested the seals to 500 psi for 15 minutes. 0.0 0.0 11/5/2024 07:00 11/5/2024 16:30 9.50 MIRU, MOVE NUND P Nipple up low pressure riser from the BOP deck to the rig floor. Secured the riser in the BOP deck. Inflate and check air boots. Installed valves on the starting head for black water line. Installed mouse hole & inspected saver sub. SIMOPS: Loaded & processed 5-7/8" drill pipe; took on KlaShield mud to the pits; rebuilt mud pump 3 isolation valve; repaired hydraulic leak on the ST-120; installed new Baker BPA on the rig floor mud manifold. 0.0 0.0 11/5/2024 16:30 11/5/2024 18:00 1.50 MIRU, MOVE PULD P Picked up and racked back 5 stands of 5-7/8" HWDP & the Jars. Tagged fill at 118' MD. 0.0 0.0 11/5/2024 18:00 11/5/2024 22:15 4.25 MIRU, MOVE BHAH P Made up 16" BHA 1 per Baker DD to 103' MD. 0.0 103.0 11/5/2024 22:15 11/6/2024 00:00 1.75 MIRU, MOVE SEQP P Fluid packed surface lines. Filled the conductor with mud & circulated back to the pits. Pumped mud with all 4 mud pumps. Pressure tested high pressure mud lines to 3500 psi. Blew down the top drive. 103.0 103.0 11/6/2024 00:00 11/6/2024 01:00 1.00 MIRU, MOVE PULD P P/U 7" drill collar and 1 joint of HWDP. RIH and tag at 118' MD. 103.0 118.0 11/6/2024 01:00 11/6/2024 01:30 0.50 MIRU, MOVE REAM P Wash and ream down conductor from 118' to 135' MD. 450 gpm, 429 psi. 40 rpm, 2K Tq 118.0 135.0 11/6/2024 01:30 11/6/2024 06:00 4.50 SURFAC, DRILL DDRL P Drill 16" hole section from 135' to 594' MD. 650 gpm, 1084 psi. 50 rpm, 5K Tq on, 3K Tq off. 8K WOB, ECD 11.93 ppg. P/U 110K, S/O 118K Total gas 1 unit. Rotating time 2.5 hrs, sliding time 0.3 hrs. Total bit hrs, 55.4, Jar hrs 0 135.0 594.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 3/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/6/2024 06:00 11/6/2024 12:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole section from 594' to 1,137' MD. 800 gpm, 1539 psi. 50 rpm, 7K Tq on, 3K Tq off. 16K WOB, ECD 11.45 ppg. P/U 110K, S/O 118K Total gas 1 unit. Rotating time 2.0 hrs, sliding time 1.3 hrs. Total bit hrs, 58.7, Jar hrs 3.3 594.0 1,137.0 11/6/2024 12:00 11/6/2024 18:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole section from 1,137' to 1,713' MD. 800 gpm, 1540 psi. 50 rpm, 8K Tq on, 5K Tq off. 12K WOB, ECD 11.53 ppg. P/U 110K, S/O 118K Total gas 1 unit. Rotating time 1.9 hrs, sliding time 1.5 hrs. Total bit hrs, 62.1, Jar hrs 6.7 1,137.0 1,713.0 11/6/2024 18:00 11/7/2024 00:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole section from 1,713' to 2,444' MD. 900 gpm, 1930 psi. 50 rpm, 9K Tq on, 3K Tq off. 16K WOB, ECD 11.55 ppg. Total gas 0 unit. Rotating time 2.4 hrs, sliding time 1.4 hrs. Total bit hrs, 66, Jar hrs 10.6 1,713.0 2,444.0 11/7/2024 00:00 11/7/2024 06:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole section from 2,444' to 3,012' MD. 900 gpm, 2050 psi. 60 rpm, 9K Tq on, 3K Tq off. 16K WOB, ECD 11.65 ppg. Total gas 0 unit. Rotating time 2.5 hrs, sliding time 1.4 hrs. Total bit hrs 70.3, Jar hrs 17.7 2,444.0 3,012.0 11/7/2024 06:00 11/7/2024 08:30 2.50 SURFAC, DRILL DDRL P Drill 16" hole section from 3,012' to 3,081' MD. 900 gpm, 2050 psi. 60 rpm, 9K Tq on, 3K Tq off. 16K WOB, ECD 11.65 ppg. Total gas 0 unit. Rotating time 1.5 hrs, sliding time 0.4 hrs. Total bit hrs 72.2, Jar hrs 19.6 3,012.0 3,081.0 11/7/2024 08:30 11/7/2024 10:00 1.50 SURFAC, DRILL CIRC P Observe pump pressure increase from 2050 PSI to 2170 PSI, ECD climb to 11.99 PPG. Circulate at 900 GPM, 1850 PSI, 70 RPM, 5K TQ, until hole clean up and unload Note: ECD's climb to 14.48 PPG, turn down pumps to 450 GPM and stage back up to 900 GPM as hole conditions allowed, circulate a bottoms up. 3,081.0 3,081.0 11/7/2024 10:00 11/7/2024 12:00 2.00 SURFAC, DRILL DDRL P Drill 16" hole section from 3,081' to 3,326' MD. 900 gpm, 1923 psi. 70 rpm, 6K Tq on, 4K Tq off. 16K WOB, ECD 11.50 ppg. Total gas 1 unit. P/U 159K, S/O 144K, RTW 147K. Rotating time 1.1 hrs, sliding time .4 hrs. Total bit hrs 73.7, Jar hrs 21.1 3,081.0 3,326.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 4/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/7/2024 12:00 11/7/2024 12:30 0.50 SURFAC, DRILL DDRL P Drill 16" hole section from 3,326' to 3,343' MD. 900 gpm, 1931 psi. 70 rpm, 6.5K Tq on, 4K Tq off. 8K WOB, ECD 11.71 ppg. Total gas 0 unit. Rotating time .1 hrs, sliding time .4 hrs. Total bit hrs, 73.7, Jar hrs 21.1 3,326.0 3,343.0 11/7/2024 12:30 11/7/2024 14:15 1.75 SURFAC, DRILL CIRC P Observe ECD climb to 12.34 PPG Circulate at 450 GPM, 630 PSI, 30 RPM, 5K TQ Note: ECD's climb to 12.34 PPG, turn down pumps to 450 GPM and stage back up to 900 GPM as hole conditions allowed, circulate a bottoms up. 3,343.0 3,343.0 11/7/2024 14:15 11/7/2024 18:00 3.75 SURFAC, DRILL DDRL P Drill 16" hole section from 3,343' to 3,582' MD. 900 gpm, 1945 psi. 70 rpm, 7K Tq on, 4K Tq off. 19K WOB, ECD 11.65 ppg. Total gas 1 unit. Rotating time 2.4 hrs, sliding time 0.3 hrs. Total bit hrs 76.7, Jar hrs 21.3 3,343.0 3,582.0 11/7/2024 18:00 11/7/2024 18:30 0.50 SURFAC, DRILL DDRL P Drill 16" hole section from 3,582' to 3,631' MD. 900 gpm, 2100 psi. 70 rpm, 8K Tq on, 5K Tq off. 20K WOB, ECD 11.60 ppg. Total gas 1 unit. Rotating time .3 hrs, sliding time 0 hrs. Total bit hrs 77.2, Jar hrs 21.8 3,582.0 3,631.0 11/7/2024 18:30 11/7/2024 20:45 2.25 SURFAC, DRILL CIRC P 3,631' MD encountered increased ECD spikes indicating well is packing off. reduce pump rate to 400 and rotary to 30 rpm. Work pipe. Circulating and increasing rates while clearing clay. Slow pumps down several times during circulation to manage material at surface safely and avoid packing off flow line. Noted large amounts of clay of at shakers. Once able to sustain 900 gpm circulate for 15 minutes and resume drilling. 3,631.0 3,631.0 11/7/2024 20:45 11/7/2024 23:30 2.75 SURFAC, DRILL DDRL P Drill 16" hole section from 3,631' to 3,795' MD. 900 gpm, 2100 psi. 70 rpm, 8K Tq on, 5K Tq off. 20K WOB, ECD 11.60 ppg. Total gas 1 unit. Rotating time 1.8 hrs, sliding time .4 hrs. Total bit hrs 79.4, Jar hrs 24.0 3,631.0 3,795.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 5/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/7/2024 23:30 11/8/2024 00:00 0.50 SURFAC, DRILL CIRC P 3,795' MD encountered increased ECD spikes indicating well is packing off. reduce pump rate to 400 and rotary to 30 rpm. Work pipe. Circulating and increasing rates while clearing clay. Slow pumps down several times during circulation to manage material at surface safely and avoid packing off flow line. Noted large amounts of clay of at shakers. Once able to sustain 900 gpm circulate for 15 minutes and resume drilling. 3,795.0 3,795.0 11/8/2024 00:00 11/8/2024 00:45 0.75 SURFAC, DRILL CIRC P At 3,795' MD encountered increased ECD spikes indicating well is packing off. Reduce pump rate to 400 gpm and rotary to 30 rpm. Work pipe. Circulating and increasing rates while clearing clay. Slow pumps down several times during circulation to manage material at surface safely and avoid packing off flow line. Noted large amounts of clay at shakers. Once able to sustain 900 gpm circulate for 15 minutes and resume drilling. 3,795.0 3,795.0 11/8/2024 00:45 11/8/2024 05:00 4.25 SURFAC, DRILL DDRL P Drill 16" hole section from 3,795' to 4,003' MD. 900 gpm, 2120 psi. 70 rpm, 10K Tq on, 5K Tq off. 5-30K WOB, ECD 11.53 ppg. Rotating time 2.8 hrs, sliding time 0 hrs. Total bit hrs 82.2, Jar hrs 26.8. 3,795.0 4,003.0 11/8/2024 05:00 11/8/2024 06:00 1.00 SURFAC, DRILL CIRC P At 4,003' MD encountered increased ECD spikes indicating well is packing off. Reduce pump rate to 400 gpm and rotary to 30 rpm. Work pipe. Circulating and increasing rates while clearing clay. Slow pumps down several times during circulation to manage material at surface safely and avoid packing off flow line. Noted large amounts of clay at shakers. Once able to sustain 900 gpm circulate for 15 minutes and resume drilling. 4,003.0 4,003.0 11/8/2024 06:00 11/8/2024 07:00 1.00 SURFAC, DRILL DDRL P Drill 16" hole section from 4,003' to 4,109' MD, section TD. 900 gpm, 2120 psi. 70 rpm, 10K Tq on, 5K Tq off. 5-30K WOB, ECD 11.53 ppg. Rotating time .9 hrs, sliding time 0 hrs. Total bit hrs 83.1, Jar hrs 27.7. 4,003.0 4,109.0 11/8/2024 07:00 11/8/2024 10:00 3.00 SURFAC, TRIPCAS CIRC P Circulate at 900 GPM, 1900 PSI, 70 RPM, 6K TQ for 20 min. Obtain final surveys. Pump 40 BBL low-vis 10 PPB NP sweep, followed by 40 BBL hi-vis sweeps 2x, one per surface to surface. See a large increase in cuttings on first set of sweeps. 900 GPM, 1950 PSI ICP ECD 11.40 PPG at start 900 GPM, 1865 PSI FCP ECD 11.21 PPG at end 4,109.0 3,937.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 6/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/8/2024 10:00 11/8/2024 10:30 0.50 SURFAC, TRIPCAS OWFF P Flow check - static. 3,937.0 3,937.0 11/8/2024 10:30 11/8/2024 12:00 1.50 SURFAC, TRIPCAS BKRM P Back ream out of hole from 3,937' to 3,740' MD. Racking back stands in derrick. 900 GPM, 1900 PSI 70 RPM, 5-7 K TQ RTW -150K 3,937.0 3,740.0 11/8/2024 12:00 11/8/2024 18:30 6.50 SURFAC, TRIPCAS BKRM P Back ream out of hole from 3,740' to 2,608' MD. Racking back stands in derrick. 900 GPM, 1890 PSI 70 RPM, 3-7 K TQ RTW -140K 3,740.0 2,608.0 11/8/2024 18:30 11/8/2024 19:00 0.50 SURFAC, TRIPCAS SVRG P Top drive unable to rotate Perform rig service while troubleshooting and replacing encoder. 2,608.0 2,608.0 11/8/2024 19:00 11/8/2024 21:00 2.00 SURFAC, TRIPCAS RGRP T Top drive unable to rotate. Troubleshoot and replace encoder. 2,608.0 2,608.0 11/8/2024 21:00 11/9/2024 00:00 3.00 SURFAC, TRIPCAS BKRM P Back ream out of hole from 2,608' to 1800' MD. Racking back stands in derrick. 900 GPM, 1754 PSI 70 RPM, 4K TQ RTW -127K 2,608.0 1,800.0 11/9/2024 00:00 11/9/2024 01:45 1.75 SURFAC, TRIPCAS CIRC P Circulate 40 BBL Low-Vis and 40 BBL High-Vis sweeps to clean hole. 900 GPM, 1752 PSI, 70 RPM, 4K TQ ECD = 11.48 PPG 1,800.0 1,708.0 11/9/2024 01:45 11/9/2024 04:30 2.75 SURFAC, TRIPCAS BKRM P Backream out of hole from 1,708' MD to 1,039' MD. 900 GPM, 1602 PSI, 70 RPM, 2K TQ At ~1,200' MD notice ECD climb from 11.42 PPG to 11.65 PPG and hole start to unload. 1,708.0 1,039.0 11/9/2024 04:30 11/9/2024 05:30 1.00 SURFAC, TRIPCAS CIRC P Circulate hole clean at 900 GPM, 1690 PSI, 70 RPM, 5K TQ. 1,039.0 965.0 11/9/2024 05:30 11/9/2024 05:45 0.25 SURFAC, TRIPCAS OWFF P Flow check - static. Blow down top drive. 965.0 965.0 11/9/2024 05:45 11/9/2024 07:30 1.75 SURFAC, TRIPCAS TRIP P Trip out of hole from 965' MD to 139' MD. 135K UP 965.0 139.0 11/9/2024 07:30 11/9/2024 09:30 2.00 SURFAC, TRIPCAS BHAH P Flow check and PJSM with all personnel on L/D BHA #1. Lay down BHA #1 as per Baker DD. 139.0 0.0 11/9/2024 09:30 11/9/2024 10:00 0.50 SURFAC, TRIPCAS BHAH P Clean and clear rig floor of BHA components. 0.0 0.0 11/9/2024 10:00 11/9/2024 11:00 1.00 SURFAC, CASING RURD P Mobilize casing running tools to rig floor and rig up to run 13-5/8" casing. PJSM on running casing with all personnel. 0.0 0.0 11/9/2024 11:00 11/9/2024 12:45 1.75 SURFAC, CASING PUTB P RIH with 13-5/8" 88.2# L-80 IC HYD 563 casing as per detail to 169' MD. BakerLoc connections to pin end of JT #4. Break circulation to confirm flow path and check floats. M/U TQ = 76,700 FT-LBS with BakerLoc. Double bump connections. 0.0 169.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 7/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/9/2024 12:45 11/9/2024 18:00 5.25 SURFAC, CASING PUTB P RIH with 13-5/8" 88.2# L-80 IC HYD 563 casing as per detail from 169' MD to 1,128' MD. Fill pipe on the fly topping off every 10 joints. SOW 144K Monitor displacement via pit #5 M/U TQ = 65K, Double bump connections Use BOL 2000 AG pipe dope 169.0 1,128.0 11/9/2024 18:00 11/10/2024 00:00 6.00 SURFAC, CASING PUTB P RIH with 13-5/8" 88.2# L-80 IC HYD 563 casing as per detail from 1,128' MD to 2,934' MD. Fill pipe on the fly topping off every 10 joints. SOW 249K, PUW 272K Monitor displacement via pit #5 M/U TQ = 65K, Double bump connections Use BOL 2000 AG pipe dope 1,128.0 2,934.0 11/10/2024 00:00 11/10/2024 02:30 2.50 SURFAC, CASING PUTB P RIH with 13-5/8" 88.2# L-80 IC HYD 563 casing as per detail from 2,934' MD to 4,046' MD. Fill pipe on the fly topping off every 10 joints. SOW 257K, PUW 305K Monitor displacement via pit #5 M/U TQ = 65K, Double bump connections Use BOL 2000 AG pipe dope 2,934.0 4,046.0 11/10/2024 02:30 11/10/2024 03:30 1.00 SURFAC, CASING PUTB P M/U FMC hanger, landing joint and pup. Wash down at 2 BPM from 4046' MD to 4103' MD. Tag hanger on depth. SOW 266K, PUW 319K. 4,046.0 4,103.0 11/10/2024 03:30 11/10/2024 05:45 2.25 SURFAC, CEMENT CIRC P Stage up pumps up to 8 BPM in 1/2 BBL increments. Meanwhile reciprocate pipe. 8 BPM, 219 PSI 310K UP 260K DN 4,103.0 4,103.0 11/10/2024 05:45 11/10/2024 06:00 0.25 SURFAC, CEMENT RURD P Blow down top drive. Rig up cemnet hose to Volant tool. 4,103.0 4,103.0 11/10/2024 06:00 11/10/2024 07:00 1.00 SURFAC, CEMENT CIRC P Circulate thru cement hose and stage up to 8 BPM, 425 PSI. 305K UP 260K DN Blow air to cement unit from rig floor. Confirm black water line to cellar is clear. PJSM with all parties on cementing 13- 5/8" casing. 4,103.0 4,103.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 8/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/10/2024 07:00 11/10/2024 11:15 4.25 SURFAC, CEMENT CMNT P Break circulation with water and SLB cementing unit test lines to 3500 PSI. Perform surface cement job as per SLB. Pump 100 BBLS 11 PPG mud push @ 4.5 BPM while reciprocating, 306K UP, 260K DN. Drop bottom wiper plug and follow with 423.5 BBLS 11.0 PPG DeepCRETE Lead Cement. Pump at average 6.4 BPM. Follow with 69 BBLS 15.8 PPG G blend tail cement at 4 BPM. Drop top wiper plug and chase with 20 BBLS water @ 4.5 BPM from cement unit. Land hanger while mud push is exiting casing shoe. Pick up and reciprocate after interface clears shoe track. Displace with 581.7 BBLS 11 PPG Klashield using rig pumps. ICP at 8 BPM, 247 PSI, FCP at 8 BPM, 622 PSI. Stop reciprocating casing at 533.5 BBLS into chase. Slow to 3 BPM at 562 BBLS pumped – 3 BPM, 321 ICP; 3 BPM, 400 FCP. Bump plug at 581.6 BBLS, 4926 STKS. Build pressure to 900 PSI and hold for 5 minutes. Bleed pressure off and check floats – floats holding. Note: Lead cement wet at 07:57 HRS, Tail cement wet @ 09:16 HRS. Note: Landed hanger at 4518 STKS into displacement. CIP @ 11:12 HRS. Note: Full returns during job. Spacer back at 313 BBLS into chase. Cement/interface back to surface at 434.6 BBLS pumped. S/O 187K prior to landing. 4,103.0 4,103.0 11/10/2024 11:15 11/10/2024 14:45 3.50 SURFAC, CEMENT RURD P Blow down lines, L/D landing joint and pup joint. Rig down Volant tool. Service break swivel and Volant tool and lay down same. Clean rig floor of casing equipment. Make up stack washer. Flush stack, flow box and flow line with black water. Drain riser and blow down top drive. 4,103.0 0.0 11/10/2024 14:45 11/10/2024 18:45 4.00 SURFAC, WHDBOP NUND P N/D low pressure riser, orientate and nipple up FMC well head as per FMC rep. Top of cement measured 24" from casing hanger. SIMOPs: Clean pits and flush lines after cement job. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 9/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/10/2024 18:45 11/11/2024 00:00 5.25 SURFAC, WHDBOP NUND P Nipple up high pressure riser to FMC wellhead. Nipple up BOP's. M/U choke and kill lines and install low pressure riser. Test lower hanger seals to 1000 psi for 15 minutes as per FMC rep. Cut low pressure riser to fit. Rig up MPD hoses and related equipment. Obtain RKB's. Change out handling equipment . P/U and M/U test 5-7/8" test joint. Fluid pack lines. 0.0 0.0 11/11/2024 00:00 11/11/2024 01:30 1.50 SURFAC, WHDBOP RURD P Set test plug with 5-7/8" test joint. Flood stack and surface lines with water. Shell test BOP to 3500 psi. C/O out chart recorder. 0.0 0.0 11/11/2024 01:30 11/11/2024 09:30 8.00 SURFAC, WHDBOP BOPE P Initial BOP test. Test annular preventer with 5-7/8" test joint to 250 PSI low for 5 min and 3500 PSI high for 10 Min. All other test to 250 PSI low for 5 min and 5,000 PSI high for 10 min. Test 3-1/2" x 6-5/8" UVBR and LVBR with 5-7/8" test joint. Test 3" Demco kill line valve, choke valves 1 thru 16, needle valve down stream of choke valve #1, blind rams, auto/manual IBOP, HCR kill/choke valves, manual kill/choke valves, 5-7/8" FOSV and Dart valves. Test manual and electric super chokes to 1,500 PSI and observe pressure drop when opening. Fail pass on Totco alarms and kill line Oteco Accumulator drawdown ISP = 3050 PSI. PSI after functioning = 1750 PSI. 200 PSI obtained = 13 seconds. Full system recovery = 81 seconds. 10 bottles back up average = 3850 PSI. Closing times: annular = 14 seconds, UPR = 13 seconds, simulated blind rams = 13 seconds, LPR = 13 seconds, choke HCR = 1 seconds, kill HCR = 1 seconds. Test all gas alarms, PVT gain/loss, flow paddle. Witness by AOGCC Brian Bixby. Witness by BLM Quinn Sawyer. 0.0 0.0 11/11/2024 09:30 11/11/2024 10:30 1.00 SURFAC, WHDBOP RURD P Rig down test equipment, blow down lines, drain stack, set wear ring ID = 12.375" 0.0 0.0 11/11/2024 10:30 11/11/2024 11:15 0.75 SURFAC, DRILLOUT RURD P Fill stack with mud, flood lines, purge air from system Rig up to test casing, confirm all sensors working 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 10/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/11/2024 11:15 11/11/2024 12:30 1.25 SURFAC, DRILLOUT PRTS P Pressure test 13-5/8" casing to 3500 PSI for 30 Min with 11 PPG mud. Charted on Totco on the OA sensor. Pump total 8.2 BBLS. PSI loss over 30 Min = 7 PSI. Casing held 99.8%. Total bled back = 8.2 BBLS. R/D and B/D lines and test equipment. Initial pressure = 3688 PSI 15 min pressure = 3687 PSI 30 min pressure = 3681 PSI 0.0 0.0 11/11/2024 12:30 11/11/2024 15:15 2.75 SURFAC, DRILLOUT BHAH P PJSM on making up 12 1/4" BHA #2 for INT 1 section Make up BHA from surface to 104' SOW 98K 0.0 104.0 11/11/2024 15:15 11/11/2024 16:30 1.25 SURFAC, DRILLOUT TRIP P Trip in the hole from 104' to 2,047' SOW 120K 104.0 2,047.0 11/11/2024 16:30 11/11/2024 17:15 0.75 SURFAC, DRILLOUT DHEQ P Shallow test MWD tools at 2047' MD 850 gpm, 1000 psi. 2,047.0 2,047.0 11/11/2024 17:15 11/11/2024 18:00 0.75 SURFAC, DRILLOUT TRIP P Trip in the hole from 104' to 2047' MD SOW 94K 2,047.0 3,738.0 11/11/2024 18:00 11/11/2024 19:15 1.25 SURFAC, DRILLOUT REAM P Ream down from 3738' to 4011' MD 140 gpm, 100 PSI 60 rpm, 11k TQ Note tag up on plugs at 4011' with 10K 3,738.0 4,011.0 11/11/2024 19:15 11/11/2024 22:00 2.75 SURFAC, DRILLOUT DRLG P Drill wiper plugs from 4011' to 4014' MD Tag FC at 4014' MD and drill float collar from 4014' to 4017' MD Work through FC 2 with rotary and once without rotation. Ream cement from 4017' to 4099' MD. Drill Shoe from 4100' to 4104' MD Wash and ream to 4109' MD. Work through shoe several times to ensure it is clean. 650 to 850 gpm, 680 to 1020 psi. 120 rpm, 10 to 20K TQ. WOB 5 to 15K 4,011.0 4,109.0 11/11/2024 22:00 11/11/2024 22:30 0.50 SURFAC, DRILLOUT DDRL P Drill 20' of new formation from 4109' to 4129' MD 875 gpm, 1349 psi. 120 rpm, 5 to 13K TQ. ADT = .3 HRS Bit HRS = .3 Jar HRS = 28 4,109.0 4,129.0 11/11/2024 22:30 11/11/2024 23:30 1.00 SURFAC, DRILLOUT CIRC P Circulate and condition mud for FIT test. 850 gpm, 1020 psi. 120 rpm, 5 to 15K TQ. 4,129.0 4,129.0 11/11/2024 23:30 11/12/2024 00:00 0.50 SURFAC, DRILLOUT FIT P Pull into casing shoe and R/U and perform FIT test . Close upper VBR and pump down drill string and Kill line. Pump 24 strokes 2.8 bbls of 11.0 ppg Kla-Shield to 1233 psi, for a 18.7 PPG EMW, shut in and record pressure for 10 minutes. Bleed back too trip tank #2 , 2.3 bbls bled back. Test recorded on Totco OA sensor. 4,129.0 4,129.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 11/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2024 00:00 11/12/2024 00:30 0.50 SURFAC, DRILLOUT RURD P Pull into casing shoe and R/U and perform FIT test . Close upper VBR and pump down drill string and Kill line. Pump 24 strokes 2.8 BBLS of 11.0 ppg Kla-Shield to 1233 PSI for a 18.7 PPG EMW, shut in and record pressure for 10 minutes. Bleed back too trip tank #2 , 2.3 BBLS bled back. Test recorded on Totco OA sensor. 4,129.0 4,129.0 11/12/2024 00:30 11/12/2024 01:00 0.50 INTRM1, DRILL SVRG P Perform rig service 4,129.0 4,129.0 11/12/2024 01:00 11/12/2024 02:30 1.50 INTRM1, DRILL RGRP T Pull into shoe and troubleshoot rotation problems with top drive. Unable to resolve root cause but top drive started working as intended. 4,129.0 4,092.0 11/12/2024 02:30 11/12/2024 02:45 0.25 INTRM1, DRILL REAM P Wash and ream back to bottom from 4092' to 4129'. 900 gpm, 1345 psi. 70 rpm, 9K TQ. 4,092.0 4,129.0 11/12/2024 02:45 11/12/2024 06:00 3.25 INTRM1, DRILL DDRL P Drill 12.25" hole section from 4129' to 4,399' 1290 GPM 2245 PSI 150 RPM, 12K TQ on, 8K TQ off 18K WOB, ECD 11.64 PPG ADT = 2.2 HRS Bit HRS = 2.5 Jar HRS = 30.2 Displace on the fly to 11.0 ppg FWP on stand #39 Finish complete displacement before making connection. 4,129.0 4,399.0 11/12/2024 06:00 11/12/2024 07:45 1.75 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 4,399' to 4,652' 1290 GPM 2338 PSI 150 RPM, 12K TQ on, 8K TQ off 12K WOB, ECD 11.63 PPG Control drill at 175 FPH ROP 4,399.0 4,652.0 11/12/2024 07:45 11/12/2024 08:30 0.75 INTRM1, DRILL OTHR P Change out top drive grabber dies 4,652.0 4,652.0 11/12/2024 08:30 11/12/2024 12:00 3.50 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 4,652' to 5,113' 1290 GPM 2385 PSI 150 RPM, 13K TQ on, 8K TQ off 17K WOB, ECD 11.80 PPG 174K UP 144K DN 158K Rot ADT = 4 HRS Bit HRS = 6.5 Jar HRS = 34.2 Note: Increase ROP to 200 FPH at 4,900' 4,652.0 5,113.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 12/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2024 12:00 11/12/2024 18:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 5,113' to 6,027' MD 1290 GPM 2554 PSI 150 RPM, 17K TQ on, 7K TQ off 21K WOB, ECD 12.18 PPG 176K UP 143K DN 170K Rot ADT = 4.3 HRS Bit HRS = 10.8 Jar HRS = 38.5 Note: Increase ROP to 225 FPH at 5,300' 5,113.0 6,027.0 11/12/2024 18:00 11/13/2024 00:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 6.027' to 6,921' MD 1290 GPM 2759 PSI 150 RPM, 17K TQ on, 9K TQ off 16K WOB, ECD 12.28 PPG 208K UP 157K DN 170K Rot ADT = 4.2 HRS Bit HRS = 15.0 Jar HRS = 42.7 6,027.0 6,921.0 11/13/2024 00:00 11/13/2024 06:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 6,921' to 7,847' MD 1290 GPM 2988 PSI 150 RPM, 20K TQ on, 10K TQ off 25K WOB, ECD 12.49 PPG 245K PUW 161K SOW 188K RTW ADT = 4.3 HRS Bit HRS = 19.3 Jar HRS = 47 Note: Slow down ROP to 200 FPH at 7,760' when ECD reached 12.5 PPG 6,921.0 7,847.0 11/13/2024 06:00 11/13/2024 12:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 7,847' to 8,546' MD 1290 GPM 3068 PSI 150 RPM, 20K TQ on, 12K TQ off 25K WOB, ECD 12.39 PPG 260K PUW 163K SOW 195K RTW ADT = 4.6 HRS Bit HRS = 23.9 Jar HRS = 51.6 Note: Slow down ROP to 125 FPH at 8,273' when ECD reached 12.61 PPG 7,847.0 8,546.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 13/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/13/2024 12:00 11/13/2024 18:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 8,546' to 9259' MD 1290 GPM 3280 PSI 150 RPM, 22K TQ on, 15K TQ off 25K WOB, ECD 12.41 PPG 270K PUW 170K SOW 190K RTW ADT = 4.8 HRS Bit HRS = 28.7 Jar HRS = 56.4 Note: Increase ROP to 150 FPH at 8,600' Note: Increase ROP to 175 FPH at 8,900' 8,546.0 9,259.0 11/13/2024 18:00 11/13/2024 22:45 4.75 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 9,259' to 9,754' MD 1290 GPM 3359 PSI 150 RPM, 22K TQ on, 12K TQ off 25K WOB, ECD 12.41 PPG 270K PUW 170K SOW 190K RTW ADT = 4.8 HRS Bit HRS = 28.7 Jar HRS = 56.4 Note: decreased ROP to 150 FPH at 9,391' Note: decreased ROP to 125 FPH at 9,141' 9,259.0 9,754.0 11/13/2024 22:45 11/13/2024 23:15 0.50 INTRM1, DRILL SVRG P Perform rig service. 9,754.0 9,754.0 11/13/2024 23:15 11/14/2024 00:00 0.75 INTRM1, DRILL RGRP T Replace air boots on low pressure riser. 9,754.0 9,754.0 11/14/2024 00:00 11/14/2024 01:45 1.75 INTRM1, DRILL RGRP T Replace air boots on low pressure riser. 9,754.0 9,745.0 11/14/2024 01:45 11/14/2024 02:15 0.50 INTRM1, DRILL CIRC P Circulate while clean and clear rig floor. 9,745.0 9,745.0 11/14/2024 02:15 11/14/2024 06:00 3.75 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 9,754' to 10,057' MD 1290 GPM 3445 PSI 150 RPM, 21K TQ on, 16K TQ off 16K WOB, ECD 12.38 PPG 295K PUW 173K SOW 209K RTW ADT = 2.5 HRS Bit HRS = 34.7 Jar HRS = 62.4 9,745.0 10,057.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 14/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/14/2024 06:00 11/14/2024 12:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 10,057' to 10,665' MD 1290 GPM 3484 PSI 150 RPM, 26K TQ on, 19K TQ off 21K WOB, ECD 12.43 PPG 323K PUW 173K SOW 218K RTW ADT = 5.0 HRS Bit HRS = 39.7 Jar HRS = 67.4 10,057.0 10,665.0 11/14/2024 12:00 11/14/2024 18:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 10,665' to 11,239' MD 1290 GPM 3485 PSI 150 RPM, 30K TQ on, 20K TQ off 30K WOB, ECD 12.35 PPG 357K PUW 178K SOW 219K RTW ADT = 4.3 HRS Bit HRS = 44 Jar HRS = 71.7 10,665.0 11,239.0 11/14/2024 18:00 11/15/2024 00:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 11,239' to 11,840' MD 1290 GPM 3570 PSI 150 RPM, 30K TQ on, 20K TQ off 30K WOB, ECD 12.45 PPG 377K PUW 181K SOW 225K RTW ADT = 4.5 HRS Bit HRS = 48.5 Jar HRS = 76.2 11,239.0 11,840.0 11/15/2024 00:00 11/15/2024 06:00 6.00 INTRM1, DRILL DDRL P Drill 12.25" hole section utilizing NOVOS from 11,840' to 12,432' MD 1290 GPM 3786 PSI 150 RPM, 32K TQ on, 20K TQ off 31K WOB, ECD 12.48 PPG 430K PUW 191K SOW 251K RTW ADT = 4.9 HRS Bit HRS = 53.4 Jar HRS = 81.1 11,840.0 12,432.0 11/15/2024 06:00 11/15/2024 09:30 3.50 INTRM1, TRIPCAS BKRM P BROOH from 12,432' to 12,068' MD. One BU per stand. 1290 GPM 3685 PSI 120 RPM, 31K TQ ECD 12.19 PPG 12,432.0 12,068.0 11/15/2024 09:30 11/15/2024 10:00 0.50 INTRM1, TRIPCAS OWFF P Perform open well flow check. 12,068.0 12,068.0 11/15/2024 10:00 11/15/2024 10:30 0.50 INTRM1, TRIPCAS BKRM P BROOH from 12,068' to 11,977' MD. 1290 GPM 3714 PSI 120 RPM, 30K TQ ECD 12.22 PPG RTW 227K 12,068.0 11,977.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 15/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/15/2024 10:30 11/15/2024 11:00 0.50 INTRM1, TRIPCAS SVRG P Unable to break out of connection with rig tongs. C/O top drive grabber dies. 11,977.0 11,977.0 11/15/2024 11:00 11/15/2024 12:00 1.00 INTRM1, TRIPCAS BKRM P BROOH from 11,977' to 11,885' MD. 1290 GPM 3712 PSI 120 RPM, 30K TQ ECD 12.27 PPG RTW 227K Unable to break out of stand #122 11,977.0 11,885.0 11/15/2024 12:00 11/15/2024 13:00 1.00 INTRM1, TRIPCAS CIRC T Circulate and rotate while prepping to C/O saver sub. 1290 GPM 3666 PSI 80 RPM, 30K TQ ECD 12.17 PPG RTW 233K 11,885.0 11,885.0 11/15/2024 13:00 11/15/2024 15:15 2.25 INTRM1, TRIPCAS RGRP T C/O grabber dies, blow down top drive and C/O saver sub. Break over string every 20 minutes. PUW 364K SOW 203K 11,885.0 11,885.0 11/15/2024 15:15 11/15/2024 18:00 2.75 INTRM1, TRIPCAS BKRM P BROOH from 11,885' to 11,324' MD. 1290 GPM 3635 PSI 120 RPM, 30K TQ ECD 12.43 PPG RTW 211K 11,885.0 11,324.0 11/15/2024 18:00 11/16/2024 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 11,324' to 10.121' MD. 1290 GPM 3510 PSI 120 RPM, 25K TQ ECD 12.3 PPG RTW 197K 11,324.0 10,121.0 11/16/2024 00:00 11/16/2024 06:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 10,121' to 8,398' MD. 1290 GPM 3208 PSI 120 RPM, 18K TQ ECD 12.36 PPG RTW 180K 10,121.0 8,398.0 11/16/2024 06:00 11/16/2024 12:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 8,398' to 7,524' MD. 1290 GPM 3071 PSI 120 RPM, 21K TQ ECD 11.93 PPG RTW 179K At 7,723 experienced ECD spike to 13.1 and losses, recorded 85 bbl loss. Slowed pump rate to 900 gpm and work pipe as needed. 8,398.0 7,524.0 11/16/2024 12:00 11/16/2024 18:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 7,524' to 7,010' MD. 1290 GPM 2775 PSI 120 RPM, 18.5K TQ ECD 11.77 PPG RTW 175K 7,524.0 7,010.0 11/16/2024 18:00 11/17/2024 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 7,010' to 6,246' MD. 1290 GPM 2557 PSI 120 RPM, 14K TQ ECD 11.76 PPG RTW 166K 7,010.0 6,246.0 11/17/2024 00:00 11/17/2024 06:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 6,246' to 4,280' MD. 1290 GPM 2360 PSI 120 RPM, 13K TQ ECD 11.68 PPG RTW 146K 6,246.0 4,280.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 16/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/17/2024 06:00 11/17/2024 12:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 4,280' to 1,862' MD. 1290 GPM 1926 PSI 120 RPM, 3K TQ ECD 11.12 PPG RTW 127K 4,280 MD pump 25 bbl LowVis sweep and 50 bbl HiVis sweep and circulate until shakers clean. 1,800 MD pump 25 bbl LowVis sweep and 50 bbl HiVis sweep and circulate until shakers clean. 4,280.0 1,862.0 11/17/2024 12:00 11/17/2024 12:30 0.50 INTRM1, TRIPCAS CIRC P Circulate while rotate and reciprocate from 1,862 to 1,768' MD Circulate until sweeps out of hole and shakers are clean. 1290 GPM 1880 PSI 120 RPM, 3-5K TQ 1,862.0 1,862.0 11/17/2024 12:30 11/17/2024 13:30 1.00 INTRM1, TRIPCAS TRIP P Blow down top drive. POOH on elevators from 1,862' to 661' MD PUW 110K 1,862.0 661.0 11/17/2024 13:30 11/17/2024 13:45 0.25 INTRM1, TRIPCAS OWFF P Perform flow check. 661.0 661.0 11/17/2024 13:45 11/17/2024 14:45 1.00 INTRM1, TRIPCAS TRIP P POOH with HWDP drill pipe racking back in derrick. from 661' to 100' MD. PUW 82K. 661.0 100.0 11/17/2024 14:45 11/17/2024 17:00 2.25 INTRM1, TRIPCAS BHAH T L/D BHA from 100' to 62' MD Observe 20K overpull at 62' MD, string would not go back down. Turn string with rig tongs, did not free string. L/D NMDC from string and P/U stand of HWDP then M/U to top drive. Apply 20K down weight to string to free from tight area. RIH to 88' MD, Circulate at 1290 GPM, 1340 PSI. 10 RPM 1K TQ. Work string from 88' to 52'. Run back in hole to 64' and shut down rotation. and straight pull to 48' with no hang up. Rack back stand of heavy weight. 100.0 64.0 11/17/2024 17:00 11/17/2024 18:45 1.75 INTRM1, CASING BHAH P Blow down top drive, P/U NMDC and break off float and filter sub, L/D remaining BHA parts and break off bit. 64.0 0.0 11/17/2024 18:45 11/17/2024 19:45 1.00 INTRM1, CASING WWWH P M/U stack washer on stand of 5-7/8 drillpipe, Wash stack 2 function rams and flush again. Perform weekly function test of blind rams, upper and lower VBR rams.and annular from tool pusher office. 0.0 0.0 11/17/2024 19:45 11/17/2024 20:30 0.75 INTRM1, CASING RURD P Rig up running tool and pull wear ring as per FMC rep. 0.0 0.0 11/17/2024 20:30 11/17/2024 22:30 2.00 INTRM1, CASING RURD P Remove XO and wear ring running tool, stand back 5-7/8" drillpipe. Change upper pipe rams to 9-7/8" solid body rams. SIMOPS: M/U 9-7/8" test joint. Clean & clear rig floor Clean pits #1-4 0.0 0.0 11/17/2024 22:30 11/17/2024 23:00 0.50 INTRM1, CASING RURD P Install test plug and flood stack with H2O 0.0 0.0 11/17/2024 23:00 11/17/2024 23:30 0.50 INTRM1, CASING SVRG P Service rig while replace ram door seal. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 17/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/17/2024 23:30 11/18/2024 00:00 0.50 INTRM1, CASING RURD P Install test plug and flood stack with H2O 0.0 0.0 11/18/2024 00:00 11/18/2024 00:45 0.75 INTRM1, CASING RURD P Continue install test plug and flood stack with H2O 0.0 0.0 11/18/2024 00:45 11/18/2024 02:45 2.00 INTRM1, CASING BOPE P Test upper 9-7/8" solid body rams with 9 -7/8" test joint and test joint and test to 250 psi low for 5 minutes and 3500 high for 10 minutes charted. L/D 9-7/8" test joint and M/U 9-5/8" test joint and test to 250 psi low for 5 minutes and 2500 high for 10 minutes charted. 0.0 0.0 11/18/2024 02:45 11/18/2024 03:15 0.50 INTRM1, CASING RURD P Pull test plug and drain BOP stack, blow down mud and kill line. L/D test joints. 0.0 0.0 11/18/2024 03:15 11/18/2024 04:30 1.25 INTRM1, CASING RURD P R/U Doyon casing running equipment. Conduct PJSM with all crews. 0.0 0.0 11/18/2024 04:30 11/18/2024 07:00 2.50 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 0' to 1229' MD. Bakerlock joints #2-5 torque to 34,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe and check floats on JT#5 (floats holding) Torque all remaining 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 0.0 1,229.0 11/18/2024 07:00 11/18/2024 07:30 0.50 INTRM1, CASING SFTY P Conduct well control drill as per plan. Using "9-7/8" Kick Stand" with 9-5/8" x 9-7/8" XO, TIW and annular. 13 minutes to shut in time. 1,229.0 1,229.0 11/18/2024 07:30 11/18/2024 12:00 4.50 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 1,229' to 3,200' MD. Torque all remaining 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 1,229.0 3,200.0 11/18/2024 12:00 11/18/2024 14:45 2.75 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 3200' to 4,082' MD. Torque all remaining 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 3,200.0 4,082.0 11/18/2024 14:45 11/18/2024 15:00 0.25 INTRM1, CASING SFTY P Conduct well control drill as per plan. Using "9-7/8" Kick Stand" with 9-5/8" x 9-7/8" XO, TIW and annular. 13 minutes to shut in time. 4,082.0 4,082.0 11/18/2024 15:00 11/18/2024 16:15 1.25 INTRM1, CASING CIRC P Circulate bottoms up while working casing from 4,082' to 4,038' MD. Stage pumps up to 6 BPM in .5 bbl increments. PUW 246K SOW 211K at 20 RPM 8- 10K TQ. 4,082.0 4,082.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 18/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2024 16:15 11/18/2024 18:00 1.75 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 4,082' to 5,023' MD. Torque all remaining 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 4,082.0 5,023.0 11/18/2024 18:00 11/18/2024 20:30 2.50 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 5,023' to 5,717' MD. Torque all remaining 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 5,023.0 5,717.0 11/18/2024 20:30 11/18/2024 21:00 0.50 INTRM1, CASING SVRG P Service rig while troubleshoot top drive rotation problem. Found loose Amphenol plug on plug board above drillers cabin. Circulate at 1 Bpm while trouble shoot, 175 psi. 5,717.0 5,717.0 11/18/2024 21:00 11/19/2024 00:00 3.00 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 5,717' to 6,907' MD. Torque all remaining 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 5,717.0 6,907.0 11/19/2024 00:00 11/19/2024 06:00 6.00 INTRM1, CASING PUTB P RIH with 9-7/8" 62.8# H563 Casing as per tally. from 6,907' to 8,336' MD. Torque 9-7/8" to 29,000 Ft lbs with BOL artic grade 2000 pipe dope. 8,336' install XO to 9-5/8" 47# H563 And continue RIH with 9-5/8" 47# H563 from 8,336' to 10,349' MD. Torque 9-5/8" to 15,800 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 6,907.0 10,349.0 11/19/2024 06:00 11/19/2024 08:00 2.00 INTRM1, CASING PUTB P RIH with 9-5/8" 47# H563 from 10,349' to 11,742' MD. Torque 9-5/8" to 15,800 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 10,349.0 11,742.0 11/19/2024 08:00 11/19/2024 09:15 1.25 INTRM1, CASING CIRC P 11,742' MD encounter tight hole, stage up pumps slowly to 2 BPM at 378 PSI. Work string to clean up hole max PUW 650K PUW 580K SOW 268K 11,742.0 11,742.0 11/19/2024 09:15 11/19/2024 12:00 2.75 INTRM1, CASING PUTB P Washing hole with 9-5/8" 47# H563 from 11,742' to 11,980' MD. 2 BPM , 410 PSI. Torque 9-5/8" to 15,800 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 11,742.0 11,980.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 19/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/19/2024 12:00 11/19/2024 16:45 4.75 INTRM1, CASING PUTB P Washing hole with 9-5/8" 47# H563 from 11,980' to 12,368' MD. 2 BPM , 367 PSI. SOW 267K Torque 9-5/8" to 15,800 Ft lbs with BOL artic grade 2000 pipe dope. Fill pipe on the fly topping off every 10 joints. 11,980.0 12,368.0 11/19/2024 16:45 11/19/2024 17:15 0.50 INTRM1, CASING THGR P M/U hanger as per FMC rep, and wash in hole then M/U landing joint . 12,368.0 12,368.0 11/19/2024 17:15 11/19/2024 18:30 1.25 INTRM1, CASING HOSO P Wash down landing joint from 12,368' to 12,426.68' MD Land at 12428.68' 2 BPM, 367 PSI SOW 250K 12,368.0 12,426.7 11/19/2024 18:30 11/19/2024 20:30 2.00 INTRM1, CASING CIRC P Stage up pumps from 2 BPM increasing by .5 BPM every 15 minutes staging up to 6 BPM cementing rates. R/U cementers and prepare rig for cement job. Prepare pits for LCM displacement. 12,426.7 12,426.7 11/19/2024 20:30 11/19/2024 21:30 1.00 INTRM1, CASING RURD P Rig up cement lines and flood with H2O Pressure test cement lines 500 low and 3500 high PSI. 12,426.7 12,426.7 11/19/2024 21:30 11/19/2024 22:00 0.50 INTRM1, CEMENT CIRC P Circulate through cement line bring rate up to 6 BPM 12,426.7 12,426.7 11/19/2024 22:00 11/20/2024 00:00 2.00 INTRM1, CEMENT CMNT P Perform 9 7/8" x 9-5/8" intermediate cement job as per SLB Pump 5 BBLS H2O with cement unit, test pump trips at 250, test lines to 3500 PSI Pumped 60 BBLS 12.5 PPG spacer at 4 BPM Dropped 1st bottom wiper plug and followed with 90 BBLS 13 PPG class G lead cement, pumped at average 5 BPM Followed with 108 BBLS 15.8 PPG class G tail cement, pumped at average 5 BPM, dropped top plug, SLBG displaced with 10 BBLS H2O Displaced 165.6 BBLS 1395 STKS with 11 PPG NAF mud using rig pump at 6 BPM 160-410 psi at 24:00 hrs. 12,426.7 12,426.7 11/20/2024 00:00 11/20/2024 02:45 2.75 INTRM1, CEMENT CMNT P Continued displacing with 11 ppg NAF mud using rig pump at 6-3 bpm, 410- 1070 psi. Observed first plug land at 628.6 bbls, 5926 strokes into displacement (3.08 BBLS late), pressured up from 230 psi to 411 psi and observed plug shear. Recalculated plug bump. Bumped plugs at 901.6 bbls 7596 strokes, pressured up from 1072 psi to 1689 psi, held for 5 minutes. Bled pressure off (2.5 bbls back to pits) and floats held. CIP at 02:45 hrs, Note: Lead cement wet at 22:19 hrs; tail cement wet at 22:50 hrs. Note: Shoe at 12,426.68'; float collar at 12,337.92'; no losses circulating and cementing 12,426.7 0.0 11/20/2024 02:45 11/20/2024 03:45 1.00 INTRM1, CEMENT RURD P Drained the stack. Backed out the landing joint. Broke apart landing joint and laid down. SIMOPS blew down cement line. 0.0 0.0 11/20/2024 03:45 11/20/2024 04:15 0.50 INTRM1, CEMENT RURD P Rigged down casing equipment. Cleared and cleaned rig floor. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 20/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2024 04:15 11/20/2024 05:30 1.25 INTRM1, WHDBOP WWSP P Made up running tool with a stand of HWDP. Set pack-off per FMC Rep. Tested pack-off to 5000 psi for 10 minutes, witnessed by CPAI Rep. Laid down running tool and racked back stand. 0.0 0.0 11/20/2024 05:30 11/20/2024 07:00 1.50 INTRM1, WHDBOP RURD P Closed the blind rams & de-energized accumulator. Changed upper rams to 4- 1/2" X 7-5/8" VBRs. SIMOPS prepped test equipment. 0.0 0.0 11/20/2024 07:00 11/20/2024 08:00 1.00 INTRM1, WHDBOP RURD P Set test plug with 5-7/8" test joint. Flooded stack and lines with water. Shell tested to 3500 psi. 0.0 0.0 11/20/2024 08:00 11/20/2024 08:30 0.50 INTRM1, WHDBOP BOPE P Tested upper VBRs with 5-7/8" test joint to 250 psi low for 5 minutes & 3500 psi high for 10 minutes. 0.0 0.0 11/20/2024 08:30 11/20/2024 09:00 0.50 INTRM1, WHDBOP RURD P Laid down 5-7/8" test joint. Made up 7- 5/8" test joint to test plug in the stack. 0.0 0.0 11/20/2024 09:00 11/20/2024 09:30 0.50 INTRM1, WHDBOP BOPE P Tested upper VBRs with 7-5/8" test joint to 250 psi low for 5 minutes & 3500 psi high for 10 minutes. 0.0 0.0 11/20/2024 09:30 11/20/2024 09:45 0.25 INTRM1, WHDBOP RURD P Pulled test plug. Drained the stack & blew down surface lines. 0.0 0.0 11/20/2024 09:45 11/20/2024 10:15 0.50 INTRM1, WHDBOP RURD P Set wear bushing as per FMC. Laid down the test joint & pups. ID 8.75"; OD 13.875"; length 12.5" 0.0 0.0 11/20/2024 10:15 11/20/2024 14:30 4.25 INTRM1, DRILLOUT BHAH P Picked up 8-1/2" X 9-7/8" intermediate 2 BHA per Baker Rep to 706' MD. Plugged in tools and checked at surface. SOW 112K 0.0 706.0 11/20/2024 14:30 11/20/2024 14:45 0.25 INTRM1, DRILLOUT PULD P Picked up 1 stand of 5-7/8" drill pipe and ran in the hole from 706'-795' MD. 706.0 795.0 11/20/2024 14:45 11/20/2024 18:00 3.25 INTRM1, DRILLOUT SLPC P Cut and slipped 85' of drilling line. Greased the drawworks & inspected the brakes. Calibrated the blocks in Amphion. SIMOPS repaired the ST-120. 795.0 795.0 11/20/2024 18:00 11/20/2024 19:00 1.00 INTRM1, DRILLOUT PULD P Singled in the hole with 5-7/8" drill pipe from 795'-1353' MD. SOW 118K 795.0 1,353.0 11/20/2024 19:00 11/20/2024 19:30 0.50 INTRM1, DRILLOUT RURD P Installed PS-21 slips & changed out inserts to 5-7/8". 1,353.0 1,353.0 11/20/2024 19:30 11/20/2024 19:45 0.25 INTRM1, DRILLOUT SVRG P Serviced PS-21 & ST-120. 1,353.0 1,353.0 11/20/2024 19:45 11/20/2024 21:15 1.50 INTRM1, DRILLOUT PULD P Singled in the hole with 5-7/8" drill pipe from 1353'-2563' MD. SOW 136K 1,353.0 2,563.0 11/20/2024 21:15 11/20/2024 22:00 0.75 INTRM1, DRILLOUT DHEQ P Filled pipe, tested tools, & sent downlinks. Blew down top drive. 550 gpm; 1774 psi 2,563.0 2,563.0 11/20/2024 22:00 11/20/2024 22:30 0.50 INTRM1, DRILLOUT PULD P Singled in the hole with 5-7/8" drill pipe from 2563'-2843' MD. SOW 139K 2,563.0 2,843.0 11/20/2024 22:30 11/21/2024 00:00 1.50 INTRM1, DRILLOUT TRIP P Tripped in the hole on 5-7/8" drill pipe from 2843'-4789' MD. Filled pipe every 20 stands. SOW 152K 2,843.0 4,789.0 11/21/2024 00:00 11/21/2024 03:15 3.25 INTRM1, DRILLOUT TRIP P Tripped in the hole on 5-7/8" drill pipe from 4789'-12,212' MD. Filled pipe every 20 stands. SOW 156K 4,789.0 12,212.0 11/21/2024 03:15 11/21/2024 03:45 0.50 INTRM1, DRILLOUT RURD P Blew down top drive & rigged up for casing pressure test. Test surface equipment to 500 psi. 12,212.0 12,212.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 21/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2024 03:45 11/21/2024 04:45 1.00 INTRM1, DRILLOUT PRTS P Performed casing pressure test, monitored on Totco Cellar IA sensor. Pumped 10.6 bbls, 89 strokes to 3602 psi at .5 bpm. Monitored pressure for 30 minutes with a final pressure of 3500 psi. Bled back 10.6 bbls. 12,212.0 12,212.0 11/21/2024 04:45 11/21/2024 05:00 0.25 INTRM1, DRILLOUT RURD P Rigged down test equipment & blew down lines. 12,212.0 12,212.0 11/21/2024 05:00 11/21/2024 05:30 0.50 INTRM1, DRILLOUT REAM P Reamed down from 12,212'-12,337' MD. 500 gpm; 2563 psi; FO 15% 20 rpm; Tq 13K ECD 13.3 RW 220K 12,212.0 12,337.0 11/21/2024 05:30 11/21/2024 08:45 3.25 INTRM1, DRILLOUT DRLG P Drilled plugs & float collar from 12,337'- 12,340' MD. Reamed through 3 times and drifted twice. 400 gpm; 1590 psi; FO 14% 120 rpm; Tq on 20K; off 16K ECD 12.63 WOB 15-20K PUW 312K SOW 197K RW 243K 12,337.0 12,340.0 11/21/2024 08:45 11/21/2024 09:45 1.00 INTRM1, DRILLOUT DRLG P Drill out cement in shoe track from 12,340'-12,424' MD. SIMOPS freeze protect annulus with 75 bbls of diesel starting at 09:03 hrs. 500 gpm; 2564 psi; FO 17% 120 rpm; Tq on 22K; off 16K ECD 13.27 WOB 2-12K PUW 312K SOW 197K RW 243K 12,340.0 12,424.0 11/21/2024 09:45 11/21/2024 10:00 0.25 INTRM1, DRILLOUT DRLG P Drill out shoe from 12,424'-12,428' MD. Reamed 3 times & drifted twice. SIMOPS freeze protect annulus with 75 bbls of diesel starting at 09:03 hrs. 400 gpm; 1830 psi; FO 14% 120 rpm; Tq on 20K ECD 12.73 WOB 2-27K 12,424.0 12,428.0 11/21/2024 10:00 11/21/2024 10:15 0.25 INTRM1, DRILLOUT DRLG P Drilled out cement from rat hole from 12,428'-12,432' MD. SIMOPS freeze protect annulus with 75 bbls of diesel finishing at 10:19 hrs. 500 gpm; 2473 psi 80 rpm; Tq 18K ECD 13.14 WOB 15K 12,428.0 12,432.0 11/21/2024 10:15 11/21/2024 11:00 0.75 INTRM1, DRILLOUT DDRL P Drilled intermediate 2 section from 12,432'-12,452' MD, 7419' TVD. 500 gpm; 2454 psi; FO 17% 80 rpm; Tq on 22K, off 20K WOB 15-20K ECD 13.03 ADT .5; BIT .5; JARS 81.6 hrs. 12,432.0 12,452.0 11/21/2024 11:00 11/21/2024 12:30 1.50 INTRM1, DRILLOUT CIRC P Circulated & reciprocated from 12,425'- 12,395' MD. 500 gpm; 2400 psi; FO 15% 80 rpm; Tq 20K ECD 12.94 RW 228K 12,452.0 12,395.0 11/21/2024 12:30 11/21/2024 13:00 0.50 INTRM1, DRILLOUT OWFF P Monitored the well, static. SIMOPS blew down the top drive; PJSM for installing the RCD. 12,395.0 12,395.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 22/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2024 13:00 11/21/2024 13:45 0.75 INTRM1, DRILLOUT MPDA P Installed the RCD as per MPD Advisor. Tested MPD lines & chokes.SIMOPS rigged up test equipment for FIT. 12,395.0 12,395.0 11/21/2024 13:45 11/21/2024 14:45 1.00 INTRM1, DRILLOUT CIRC P Circulated at 205 gpm; 1005 psi. 12,395.0 12,395.0 11/21/2024 14:45 11/21/2024 15:15 0.50 INTRM1, DRILLOUT FIT P Perform FIT to 14.1 ppg EMW. Pumped 4.4 bbls, 36 strokes at .5 bpm pressuring up to 1198 psi. Shut in and monitored the pressure for 10 minutes. Final shut in pressure 1129 psi. Bled back 4.1 bbls. 12,395.0 12,395.0 11/21/2024 15:15 11/21/2024 15:30 0.25 INTRM2, DRILL RURD P Rigged down test equipment & blew down lines. 12,395.0 12,395.0 11/21/2024 15:30 11/21/2024 16:00 0.50 INTRM2, DRILL CIRC P Circulated to pump up FIT data from Baker tools. 500 gpm; 2390 psi; FO 16% 12,395.0 12,395.0 11/21/2024 16:00 11/21/2024 16:30 0.50 INTRM2, DRILL REAM P Reamed down from 12,395'-12,442' MD. Observed 150-280 psi pressure increase, 15K WOB, & 8K torque increase at 12,442' MD. 600 gpm; 3300 psi; FO 17-25% 80 rpm; Tq 17-20K ECD 13.3 - 13.55 12,395.0 12,442.0 11/21/2024 16:30 11/21/2024 18:00 1.50 INTRM2, DRILL REAM T Attempted to ream past 12,442' MD 5 times. 600 gpm; 3150 psi; FO 20% 80 rpm; Tq 17-21K ECD 13.55 WOB 5-21 12,442.0 12,436.0 11/21/2024 18:00 11/21/2024 18:45 0.75 INTRM2, DRILL REAM T Worked the string to try to clear debris from 12,436'-12,405' MD. 600 gpm; 3100-3300 psi, FO 17-25% 80-120 rpm; Tq 17-24K ECD 13.38-13.98 RW 221K 12,436.0 12,405.0 11/21/2024 18:45 11/21/2024 19:15 0.50 INTRM2, DRILL REAM T Worked the string from 12,405'-12,305' MD to try to clear debris. Observed RCD rubber coming out of the hole on the tool joints. Decision made to change out the RCD. 550 gpm; 2545 psi, FO 14-23% 120 rpm; Tq 20-23K ECD 13.35 RW 220K 12,405.0 12,405.0 11/21/2024 19:15 11/21/2024 19:45 0.50 INTRM2, DRILL OWFF T Drained the MPD head. Monitored the well, static. SIMOPS mouse hole a double; blew down the top drive. 12,405.0 12,405.0 11/21/2024 19:45 11/21/2024 21:00 1.25 INTRM2, DRILL MPDA T Changed out the 5-7/8" RCD bearing per MPD Advisor. Sheppard's hooks were used to pull bearing from the head. 12,405.0 12,405.0 11/21/2024 21:00 11/21/2024 23:00 2.00 INTRM2, DRILL REAM T Reamed down from 12,405'-12,452' MD working to bottom with debris in the hole. Noticed parameter changes ~12,450' MD and started seeing chunks of shoe & plug rubber debris at the shakers. 500 gpm; 2480 psi; FO 18% 120 rpm; Tq 23K ECD 13.06 12,405.0 12,452.0 11/21/2024 23:00 11/22/2024 00:00 1.00 INTRM2, DRILL DDRL P Drilled intermediate 2 section from 12,452'-12,492' MD, 7446' TVD. 500 gpm; 2460 psi; FO 17% 120 rpm; Tq on 23K, off 19K WOB 15-20K ECD 13.08 ADT 1.3; BIT 1.8; JARS 82.9 hrs. 12,452.0 12,492.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 23/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2024 00:00 11/22/2024 00:45 0.75 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section from 12,492'-12,538' MD, 7480' TVD. 500 gpm; 2438 psi; FO 17% 120 rpm; Tq on 24K, off 19K WOB 15-20K ECD 13.09 ADT .5; BIT 2.3; JARS 83.4 hrs. 12,492.0 12,538.0 11/22/2024 00:45 11/22/2024 02:30 1.75 INTRM2, DRILL CIRC P Obtained baseline parameters prior to opening reamer. 500 gpm; 2423 psi; 80 rpm; Tq 19K; TRPM 3729; PUW 294K; SOW 171K. Pumped 1.25" ball at 250 gpm; 1181 psi; 30 rpm; Tq 15K for 1390 strokes, 165 bbls. Reduced rate to 100 gpm; 858 psi; 5 rpm; Tq 9K. Ball on seat at 2469 strokes, 293 bbls. Pressured up to 1566 psi to see blades open. Compared parameters 500 gpm; 2260 psi; TRPM 3381, reamer opened. Pulled 10K over to verify reamer opened. 12,538.0 12,538.0 11/22/2024 02:30 11/22/2024 06:00 3.50 INTRM2, DRILL DDRL P Drilled 8-1/2"X9-7/8" intermediate 2 section from 12,538'-12,797' MD, 7659' TVD. 550 gpm; 2546 psi; FO 18% 120 rpm; Tq on 24K, off 21K WOB 15-25K ECD 13.3 ADT 2.7; BIT 5.0; JARS 87.9 hrs. 12,538.0 12,797.0 11/22/2024 06:00 11/22/2024 12:00 6.00 INTRM2, DRILL DDRL P Drilled 8-1/2"X9-7/8" intermediate 2 section from 12,797'-13,233' MD, 7930' TVD. 550 gpm; 2480 psi; FO 16-21% 120 rpm; Tq on 27K, off 21K WOB 17-20K ECD 13.21 ADT 4.7; BIT 9.7; JARS 92.6 hrs. 12,797.0 13,233.0 11/22/2024 12:00 11/22/2024 18:00 6.00 INTRM2, DRILL DDRL P Drilled 8-1/2"X9-7/8" intermediate 2 section from 13,233'-13,695' MD, 8155' TVD. 500 gpm; 2175 psi; FO 20% 130-150 rpm; Tq on 29K, off 24K WOB 18-23K ECD 12.97 ADT 4.8; BIT 14.5; JARS 97.4 hrs. 13,233.0 13,695.0 11/22/2024 18:00 11/23/2024 00:00 6.00 INTRM2, DRILL DDRL P Drilled 8-1/2"X9-7/8" intermediate 2 section from 13,695'-14,142' MD, 8305' TVD. 500 gpm; 2162 psi; FO 16% 150 rpm; Tq on 29K, off 26K WOB 18-23K ECD 12.95 ADT 4.7; BIT 19.2; JARS 102.1 hrs. 13,695.0 14,142.0 11/23/2024 00:00 11/23/2024 02:00 2.00 INTRM2, DRILL DDRL P Drilled 8-1/2"X9-7/8" intermediate 2 section from 14,142'-14,239' MD, 8323' TVD. Obtained final survey & down linked tools off. 500 gpm; 2156 psi; FO 16% 150 rpm; Tq on 27K, off 25K WOB 14-18K ECD 12.92 RW 236K ADT 1.3; BIT 20.5; JARS 103.4 hrs. 14,142.0 14,239.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 24/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2024 02:00 11/23/2024 05:00 3.00 INTRM2, TRIPCAS CIRC P Obtained parameters prior to closing under reamer 500 gpm; 2200 psi; TRPM 3336; 30 rpm; Tq 16K. Dropped 1.625" ball and pumped down at 250 gpm; 1080 psi; 30 rpm; Tq 16K for half of the string volume. Pumped at 100 gpm; 853 psi; 5 rpm; Tq 10K till ball on seat at 2574 strokes, 305 bbls. Pressured up to 1822 psi with no shift. Bled of pressure. Pressured up several times to see reamer shift closed with 2280 psi. Staged up pump rate to 500 gpm; 2328 psi; TRPM 3774. Confirmed reamer closed. 14,239.0 14,239.0 11/23/2024 05:00 11/23/2024 05:45 0.75 INTRM2, TRIPCAS CIRC P Circulated 3 open hole volumes reciprocating at 550 gpm; 2530 psi; 125 rpm; Tq 27K. Racked back stand in the derrick. 14,239.0 14,158.0 11/23/2024 05:45 11/23/2024 06:00 0.25 INTRM2, TRIPCAS OWFF P Monitored the well, static. SIMOPS blew down top drive. 14,158.0 14,158.0 11/23/2024 06:00 11/23/2024 08:45 2.75 INTRM2, TRIPCAS SMPD P Stripped out of the hole holding an EMW of 12.0 ppg at the shoe with MPD from 14,158'-12,401' MD. PUW 348K 14,158.0 12,401.0 11/23/2024 08:45 11/23/2024 10:30 1.75 INTRM2, TRIPCAS CIRC P Circulated casing clean reciprocating at 375-400 gpm; 1540-1407 psi; 100 gpm; Tq 20K; ECD 12.34. 12,401.0 12,401.0 11/23/2024 10:30 11/23/2024 13:00 2.50 INTRM2, TRIPCAS CIRC P Performed roll over from 11.0 ppg to 11.5 ppg VersaClean mud as per schedule reciprocating from 12,401'- 12.309' MD. 400-150 gpm; 1480-495 psi 100 rpm; Tq 20K ECD 12.34-12.51 12,401.0 12,309.0 11/23/2024 13:00 11/23/2024 14:00 1.00 INTRM2, TRIPCAS OWFF P Monitored the well static for 30 minutes from the RCD head side outlet. SIMOPS blew down top drive; installed PS-21 slips; dropped 2.88" hollow drift with wire on stand 125. 12,309.0 12,309.0 11/23/2024 14:00 11/23/2024 18:00 4.00 INTRM2, TRIPCAS SMPD P Stripped out of the hole holding an EMW of 12.0 ppg at the shoe from 12,309'- 8208' MD. PUW 232K 12,309.0 8,028.0 11/23/2024 18:00 11/24/2024 00:00 6.00 INTRM2, TRIPCAS SMPD P Stripped out of the hole holding an EMW of 12.0 ppg at the shoe from 8208'-984' MD. PUW 115K 8,028.0 984.0 11/24/2024 00:00 11/24/2024 00:15 0.25 INTRM2, TRIPCAS SMPD P Stripped out of the hole holding an EMW of 12.0 ppg at the shoe from 984'-798' MD. PUW 115K 984.0 798.0 11/24/2024 00:15 11/24/2024 00:45 0.50 INTRM2, TRIPCAS OWFF P Monitored the well, static. SIMOPS clean rig floor; move out Baker backup tools & spare joints from the shed. 798.0 798.0 11/24/2024 00:45 11/24/2024 01:15 0.50 INTRM2, TRIPCAS MPDA P Removed RCD bearing on stand of 5- 7/8" drill pipe & racked back in the derrick from 798'-706' MD. 798.0 706.0 11/24/2024 01:15 11/24/2024 02:15 1.00 INTRM2, TRIPCAS BHAH P Racked back HWDP in the derrick from 706'-149' MD. PUW 88K 706.0 149.0 11/24/2024 02:15 11/24/2024 04:00 1.75 INTRM2, TRIPCAS BHAH P Laid down 8-1/2" X 9-7/8" BHA per Baker DD from 149' to surface. Weekly function of blind / shear rams while out of the hole. 149.0 0.0 11/24/2024 04:00 11/24/2024 05:30 1.50 INTRM2, TRIPCAS BHAH P Cleaned & cleared rig floor. Sent down tools to ground. SIMOPS made up FOSV to XO. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 25/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2024 05:30 11/24/2024 07:00 1.50 INTRM2, CASING RURD P Mobilized casing equipment to the rig floor. Rigged up CRT, bail extensions & elevators. SIMOPS clean & prep mud pump 1 for cementing. 0.0 0.0 11/24/2024 07:00 11/24/2024 08:30 1.50 INTRM2, CASING PUTB P Made up 7-5/8", 33.7#, L80 & P110 shoe track to 200' MD. Torque connections to 14K with BakerLok to the pin end of joint 5. Pumped 10 bbls through the shoe track and checked floats, good. 0.0 200.0 11/24/2024 08:30 11/24/2024 13:45 5.25 INTRM2, CASING PUTB P Run in the hole with 7-5/8", 33.7#, P110S, H523 liner as per tally from 200'- 1968' MD. Torque connections to 11.9K with BOL 2000AG thread compound. Filled pipe on the fly with 11.5 ppg VersaClean mud, topping off every 10 joints. Installed 7-5/8" X 10" Centek centralizers, with stop rings on each side, on joints 3-19 for a total of 17 ran. 200.0 1,968.0 11/24/2024 13:45 11/24/2024 14:30 0.75 INTRM2, CASING RURD P Rigged down the CRT, bail extensions & elevators. Mobilized equipment off the rig floor. Blew down the top drive. 1,968.0 1,968.0 11/24/2024 14:30 11/24/2024 15:00 0.50 INTRM2, CASING OTHR P Made up 10', 5-7/8" pup joint & XO to the 7-5/8" X 9-7/8" liner hanger. Made up the liner hanger, per Dril-Quip Rep and run in the hole to 2031' MD. 1,968.0 2,031.0 11/24/2024 15:00 11/24/2024 15:15 0.25 INTRM2, CASING RUNL P Run 7-5/8" liner on 5-7/8" drill pipe from 2031'-2115' MD. PUW 138K SOW 117K 2,031.0 2,115.0 11/24/2024 15:15 11/24/2024 15:45 0.50 INTRM2, CASING CIRC P Circulated at 2 bpm, 181 psi. SIMOPS made up Baker cement head / swivel per Baker Rep. 2,115.0 2,115.0 11/24/2024 15:45 11/24/2024 16:45 1.00 INTRM2, CASING CIRC P Filled liner with 11.0 ppg VersaClean mud at 2 bpm, 237 psi. 2,115.0 2,115.0 11/24/2024 16:45 11/24/2024 17:30 0.75 INTRM2, CASING MPDA P Installed 5-7/8" RCD bearing as per MPD Advisor. Blew down top drive. 2,115.0 2,115.0 11/24/2024 17:30 11/25/2024 00:00 6.50 INTRM2, CASING RUNL P Stripped in the hole with 7-5/8" liner on 5-7/8" drill pipe from 2115'-7875' MD. Maintained a 12.2 ppg EMW at TD with MPD, using Beyond's surge schedule. Filled pipe every 20 stands with 11.0 ppg VersaClean mud. Installed PS-21 slips after filling pipe at 4178' MD. SOW 140K 2,115.0 7,875.0 11/25/2024 00:00 11/25/2024 07:00 7.00 INTRM2, CASING RUNL P Stripped in the hole with 7-5/8" liner on 5-7/8" drill pipe from 7875'-13,912' MD. Maintained a 12.2 ppg EMW at TD with MPD, using Beyond's surge schedule. Filled pipe every 20 stands with 11.0 ppg VersaPro mud. Obtained parameters at 9-7/8" shoe, 12,426' MD. 20 rpm; Tq 14K PUW 319K SOW 170K RW 238K 7,875.0 13,912.0 11/25/2024 07:00 11/25/2024 12:00 5.00 INTRM2, CASING WASH P Washed down as needed from 13,912'- 14,187' MD. Worked varying parameters as hole conditions dictated. 10-25 gpm; 485-575 psi PUW 360-390K SOW 140-170K 13,912.0 14,187.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 26/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2024 12:00 11/25/2024 13:45 1.75 INTRM2, CASING WASH P Picked up a single of drill pipe & 15' pup joint. Washed down from 14,187'- 14,233' MD. Used varying pump rates to keep pump pressure at ~600 psi. 10-20 gpm PUW 360-380K SOW 140-170K 14,187.0 14,233.0 11/25/2024 13:45 11/25/2024 16:00 2.25 INTRM2, CEMENT CIRC P Reciprocated the string ~20' establishing circulation. Staged up to 35 gpm, 668 psi. PUW 360-380K SOW 140-170K 14,233.0 14,231.0 11/25/2024 16:00 11/25/2024 21:00 5.00 INTRM2, CEMENT CIRC P Staged up pump rate from 35-53 gpm, 668-760 psi. 14,231.0 14,231.0 11/25/2024 21:00 11/26/2024 00:00 3.00 INTRM2, CEMENT CIRC P Circulated & reciprocated the string as needed to clear restrictions. 12-38 gpm; 597-731 psi. PUW 360-385K SOW 140-170K 14,231.0 14,229.0 11/26/2024 00:00 11/26/2024 09:15 9.25 INTRM2, CEMENT CIRC P Staged up pump rate as conditions allowed, circulating 11.0 ppg NAF to surface. Reduced back pressure while increasing flow rate. 22 gpm; 630 psi to 87 gpm; 643 psi 14,229.0 14,229.0 11/26/2024 09:15 11/26/2024 11:30 2.25 INTRM2, CEMENT RURD P Rigged up Baker cement head. Blew down the top drive. Rigged up cement line to cement head. Pressure tested lines to 5700 psi. SIMOPS blew air through cement line to cementing unit. 14,229.0 14,229.0 11/26/2024 11:30 11/26/2024 14:00 2.50 INTRM2, CEMENT CIRC P Circulated 11.0 ppg NAF to surface. Staged up pump rate. 15 gpm; 480 psi to 84 gpm; 624 psi 14,229.0 14,229.0 11/26/2024 14:00 11/26/2024 15:45 1.75 INTRM2, CEMENT CMNT P Pumped cement as per program. Lined up to cementing unit & pumped 3 bbl of water. Pressure tested lines to 3500 psi, good. Pumped 70 bbls of 8.8 ppg KCL spacer with the rig pump at 2 bpm, 94- 590 psi. Dropped bottom dart. Swapped line up to cementing unit. Pumped 68 bbls of 15.8 ppg cement at 2 bpm, 790- 237 psi. Dropped top dart. Pumped 10 bbls of H2O at 2.1 bpm, 357 psi. Swapped to the rig for displacement. 14,229.0 14,229.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 27/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/26/2024 15:45 11/26/2024 21:15 5.50 INTRM2, CEMENT CMNT T The rig displaced cement with 11.0 ppg NAF at 2 bpm, 968 psi till 140 bbls pumped. Dropped Bozo plug with 76.6 bbls pumped. Reduced rate to 1.6 bpm, 915-1026 psi with increased pressure. Losses observed with 232 bbls of displacement pumped. Losses stopped with 260 bbls pumped, lost 20 bbls. Reduced rate to 1 bpm, 523-901 psi. Observed bottom dart latch with 224 bbls pumped, pressuring up to 979 psi. Observed top dart latch with 292.7 bbls pumped, pressuring up to 1966 psi. Observed bottom plug land with 304 bbls pumped, pressuring up to 1823 psi. Reduce rate to .5 bpm, 600 psi with pressure decrease & losses observed. Worked the pipe with PUW to 430K & SOW to 140K. Continued to work the pipe with no returns pumping at .75 bpm, 1375 psi, PUW 530K, SOW 140K. Attempted to apply back pressure & dumping pressure to free pack off. Stopped working pipe with 365 bbls pumped. Bumped the plug with 376.8 bbls pumped at .7 bpm, 1200 psi. Pressured up to 1700 psi & held for 5 minutes. Checked the floats, good. CIP at 21:05 hrs. Lost 20 bbls while displacing with cement inside the string. Lost 64 bbls starting when cement was coming out of the shoe. Total lost during the job, 84 bbls. 14,229.0 14,229.0 11/26/2024 21:15 11/26/2024 22:00 0.75 INTRM2, CEMENT WAIT T Waited for forward plan from town. 14,229.0 14,229.0 11/26/2024 22:00 11/26/2024 22:45 0.75 INTRM2, CEMENT PACK P Set liner hanger / packer per Dril-Quip Rep. Pressured up to 3756 psi to shear the shear ring. Continued pressuring up to 5065 psi & held for 10 minutes. Bled down to 425 psi. Picked up to 300K and bled of the pressure. Picked up to 440K. Slacked off to 149K. 14,229.0 14,229.0 11/26/2024 22:45 11/26/2024 23:30 0.75 INTRM2, CEMENT RURD P Rigged down the cementing equipment. Layed down the cement head. 14,229.0 14,229.0 11/26/2024 23:30 11/26/2024 23:45 0.25 INTRM2, CEMENT PACK P Picked up working single. Continued slacking off from 149K to 130K. 14,229.0 14,229.0 11/26/2024 23:45 11/27/2024 00:00 0.25 INTRM2, CEMENT PRTS P Tested 7-5/8" liner top. Closed upper pipe rams & flooded lines. Pressured up to 3591 psi. Monitored pressure for 10 minutes on the Totco cellar IA sensor. 14,229.0 14,229.0 11/27/2024 00:00 11/27/2024 00:15 0.25 INTRM2, CEMENT PRTS P Finished testing 7-5/8" liner top. Monitored pressure 3591-3530 psi for 10 minutes on the Totco cellar IA sensor. Opened rams & blew down lines. 14,229.0 14,229.0 11/27/2024 00:15 11/27/2024 01:00 0.75 INTRM2, CEMENT PACK P Released from liner hanger 14,229'- 12,175' MD. Picked up to 340K to see CX pins shear, PUW 300K. Laid down 2 working singles & one 15' drill pipe pup. Top of liner at 12,238.5' MD. 7-5/8" shoe at 14,228.5' MD. 14,229.0 12,175.0 11/27/2024 01:00 11/27/2024 01:15 0.25 INTRM2, CEMENT CIRC P Pumped at 1.5 bpm, 311 psi to pump Bozo plug on seat with 16 bbls pumped. Reduced rate to .5 bpm & pressured up to 5970 psi to blow the ball seat. 12,175.0 12,175.0 11/27/2024 01:15 11/27/2024 01:45 0.50 INTRM2, CEMENT OWFF P Broke a double of drill pipe and observed the well u-tubing with mud coming out the drill pipe. 12,175.0 12,175.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 28/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/27/2024 01:45 11/27/2024 03:15 1.50 INTRM2, CEMENT CIRC P Loaded foam wiper ball & circulated surface to surface for 11.0 ppg mud. Observed some 12.0 ppg returns & trace amounts of KCL brine spacer at surface. SIMOPS: Laid down 5 stands of 5-7/8" HWDP and cleaned out valves on rig floor manifold used for cementing. 625 gpm; 2350 psi; FO 20% 12,175.0 12,175.0 11/27/2024 03:15 11/27/2024 03:45 0.50 INTRM2, CEMENT OWFF P Drained a double & RCD head for removing the bearing. Monitored the well for 15 minutes - static. 12,175.0 12,175.0 11/27/2024 03:45 11/27/2024 04:15 0.50 INTRM2, CEMENT MPDA P Pulled the RCD bearing from the head. Removed the bearing from the double of 5-7/8" drill pipe, per MPD Advisor. 12,175.0 12,175.0 11/27/2024 04:15 11/27/2024 04:45 0.50 INTRM2, CEMENT SVRG P Serviced the top drive & investigated a hydraulic leak. 12,175.0 12,175.0 11/27/2024 04:45 11/27/2024 05:15 0.50 INTRM2, CEMENT RGRP T Changed out hydraulic fitting on the top drive. 12,175.0 12,175.0 11/27/2024 05:15 11/27/2024 12:30 7.25 INTRM2, CEMENT TRIP P Tripped out of the hole from 12,175'-45' MD. SIMOPS: Greased choke manifold, kill / choke HCRs & manuals. 12,175.0 45.0 11/27/2024 12:30 11/27/2024 13:45 1.25 INTRM2, CEMENT RURD P Laid down liner hanger running tools as per TIW Rep. Cleared & cleaned the rig floor. 45.0 0.0 11/27/2024 13:45 11/27/2024 17:15 3.50 INTRM2, WHDBOP RURD P Removed the Baker stand pipe pressure transducer from the goose neck. Installed HES pressure transducer. SIMOPS: Greased upper & lower IBOPs; tested high pressure test pump; made up 5-7/8" & 4-1/2" FOSV & Darts; changed out upper rams to 3-1/2" X 6- 5/8" VBRs; tested the gas alarm system; made up wear bushing puller to a double of drill pipe. 0.0 0.0 11/27/2024 17:15 11/27/2024 18:30 1.25 INTRM2, WHDBOP WWWH P Pulled wear bushing per FMC Rep. Washed the stack & well head. Laid down wash tool & racked back stand of drill pipe. 0.0 0.0 11/27/2024 18:30 11/27/2024 19:15 0.75 INTRM2, WHDBOP RURD P Changed out elevators to 4-1/2". Drained the stack. Made up 4-1/2" test joint & XOs. 0.0 0.0 11/27/2024 19:15 11/27/2024 20:00 0.75 INTRM2, WHDBOP RURD P Rigged up test lines. Filled the stack & purged all lines of air. 0.0 0.0 11/27/2024 20:00 11/28/2024 00:00 4.00 INTRM2, WHDBOP BOPE P Tested BOPE with 4-1/2" & 5-7/8" test joints. All tests charted. Annular was tested to 250 psi low for 5 minutes & 2500 psi high for 10 minutes. All other tests were to 250 psi low for 5 minutes & 3500 psi for 10 minutes. Test witness waived by BLM Rep Quinn Sawyer & AOGCC Rep Austin McLeod. #1 Annular with 4-1/2" test joint. #2 Upper 3-1/2" X 6-5/8" VBRs with 4- 1/2" test joint; CMV 1, 14, 15, 16, & kill line #3. #3 CMV 10, 13; needle valve above #1; HCR Kill; lower IBOP. #4 CMV 4, 9, 12; manual kill; 5-7/8" dart valve. #5 CMV 6,8,11; 5-7/8" FOSV #6 CMV 5, 7; 4-1/2" dart valve. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 29/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/28/2024 00:00 11/28/2024 04:30 4.50 INTRM2, WHDBOP BOPE P Continued to test BOPE with 4-1/2" & 5- 7/8" test joints. All tests charted. Annular was tested to 250 psi low for 5 minutes & 2500 psi high for 10 minutes. All other tests were to 250 psi low for 5 minutes & 3500 psi for 10 minutes. Test witness waived by BLM Rep Quinn Sawyer & AOGCC Rep Austin McLeod. #7 CMV 2; 4-1/2" FOSV #8 HCR Choke #9 Manual choke valve; manual kill valve #10 Lower 3-1/2" X 6-5/8" VBRs with 4- 1/2" test joint - Performed accumulator drawdown test. #11 CMV 3; blind / shear rams #12B Manual choke to 1500 psi #12A Remote manifold choke to 1500 psi #13 Upper 3-1/2" X 6-5/8" VBRs with 5- 7/8" test joint #14 Lower 3-1/2" X 6-5/8" VBRs with 5- 7/8" test joint Accumulator system initial pressure 3000 psi, after closure 1650 psi. Attained 200 psi with 2 electric pumps in 11 seconds. Full system pressure attained in 87 seconds with 2 electric pumps & 6 air pumps. Control system response times: annular 18 sec.; UPR 13 sec.; blind / shear 15 sec.; LPR 15 sec.; choke HCR 1 sec.; kill HCR 1 sec. Average pressure of 10 nitrogen bottles 3600 psi. Tested PVT & flow out alarms. Tested gas detection system. 0.0 0.0 11/28/2024 04:30 11/28/2024 05:00 0.50 INTRM2, WHDBOP RURD P Pulled the test plug & drained the stack. Installed wear bushing per FMC. 0.0 0.0 11/28/2024 05:00 11/28/2024 05:45 0.75 INTRM2, WHDBOP RURD P Rigged down test equipment. Laid down test joint. Blew down all lines & choke manifold. 0.0 0.0 11/28/2024 05:45 11/28/2024 06:45 1.00 INTRM2, DRILLOUT BHAH P Mobilize BHA tools to the rig floor. Prepped floor to pick up the BHA. 0.0 0.0 11/28/2024 06:45 11/28/2024 08:30 1.75 INTRM2, DRILLOUT BHAH P Picked up 6-1/2" clean out assembly per HES DD to 139' MD. SOW 90K 0.0 139.0 11/28/2024 08:30 11/28/2024 11:00 2.50 INTRM2, DRILLOUT PULD P Singled in the hole picking up 69 joints of 4-1/2" drill pipe from the pipe shed, from 139'-2309' MD. SOW 103K 139.0 2,309.0 11/28/2024 11:00 11/28/2024 12:00 1.00 INTRM2, DRILLOUT TRIP P Tripped in the hole with 5-7/8" drill pipe from 2309'-3053' MD. Filled pipe every 25 stands. SOW 120K 2,309.0 3,053.0 11/28/2024 12:00 11/28/2024 21:45 9.75 INTRM2, DRILLOUT QEVL P Tripped in the hole logging cement with Sonic tool from 3053'-12,256' MD. Filled pipe every 20 stands. SOW 194K. Tagged DPOB at 12,256' MD with 5K WOB. 3000'-4500' @ 5400 fph 4500'-4700' @ 1800 fph 4700'-8135' @ 5400 fph 8135'-12,256' @ 1800 fph 3,053.0 12,256.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 30/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/28/2024 21:45 11/28/2024 23:30 1.75 INTRM2, DRILLOUT DRLG P Obtained SCR. Mill out DPOB from 12,256'-12,257' MD & reamed down to 12,270' MD. Reamed from 12,250'- 12,270' 3 times. Drifted DPOB 3 times with no ledges. 249 gpm; 1235 psi; FO 5-12% 50 rpm; Tq on 14-16K; off 11-14K PUW 281K SOW 194K RW 225K 12,256.0 12,256.0 11/28/2024 23:30 11/29/2024 00:00 0.50 INTRM2, DRILLOUT QEVL P Tripped in the hole logging cement with Sonic tool from 12,256'-12,700' MD at 1800 fpm. PUW 286K SOW 188K 12,256.0 12,700.0 11/29/2024 00:00 11/29/2024 01:15 1.25 INTRM2, DRILLOUT QEVL P Tripped in the hole logging cement with sonic tool from 12,700'-13,792' MD at 1800 fpm. SOW 184K 12,700.0 13,792.0 11/29/2024 01:15 11/29/2024 03:15 2.00 INTRM2, DRILLOUT CIRC P Circulated 11.0 ppg mud weight in & out reciprocating the string. SIMOPS: Laid down 13 stands of 5-7/8" drill pipe from the derrick. 400 gpm; 2361 psi; FO 10% 20 rpm; Tq 11K 13,792.0 13,819.0 11/29/2024 03:15 11/29/2024 04:00 0.75 INTRM2, DRILLOUT RURD P Rigged up pressure test equipment. Purged surface lines. Pressure tested surface equipment to 3600 psi. 13,819.0 13,819.0 11/29/2024 04:00 11/29/2024 05:00 1.00 INTRM2, DRILLOUT PRTS P Pressure tested 7-5/8" X 9-7/8" casing to 3600 psi for 30 minutes. Pumped 12.5 bbls of 11.0 ppg NAF at .8 bpm, pressuring up to 3609 psi. Shut in and monitored on Totco Cellar IA sensor, with a final pressure of 3492 psi. Bled back 12.5 bbls. 13,819.0 13,819.0 11/29/2024 05:00 11/29/2024 05:30 0.50 INTRM2, DRILLOUT RURD P Rigged down test equipment. Blew down surface lines & kill line. 13,819.0 13,819.0 11/29/2024 05:30 11/29/2024 06:30 1.00 INTRM2, DRILLOUT REAM P Reamed in the hole from 13,819'- 14,063' MD. 160 gpm; 683 psi; FO 3% 20 rpm; Tq 11K RW 242K 13,819.0 14,063.0 11/29/2024 06:30 11/29/2024 13:30 7.00 INTRM2, DRILLOUT DRLG P Cleaned out cement plugs, landing collar, cement in liner, & float collar from 14,063'-14,221' MD. Picked up periodically to clear debris around watermelon mill. SIMOPS: Laid down 17 stands of 5-7/8" drill pipe. 160-400 gpm; 638-2450 psi 40-80 rpm; Tq 11-24K WOB 2-15K RW 246K 14,063.0 14,221.0 11/29/2024 13:30 11/29/2024 15:00 1.50 INTRM2, DRILLOUT CIRC P Circulated bottoms up, reciprocating. 400 gpm; 2439 psi 30 rpm; Tq 15K 14,221.0 14,221.0 11/29/2024 15:00 11/29/2024 15:30 0.50 INTRM2, DRILLOUT OWFF P Monitored the well, static. SIMOPS installed PS-21 slips. 14,221.0 14,221.0 11/29/2024 15:30 11/29/2024 15:45 0.25 INTRM2, DRILLOUT CIRC P Pumped 40 bbls of 13.0 ppg dry job. 300 gpm; 1430 psi 14,221.0 14,221.0 11/29/2024 15:45 11/29/2024 21:30 5.75 INTRM2, DRILLOUT TRIP P Tripped out of the hole racking back 5- 7/8" drill pipe from 14,221'-4541' MD; PUW 295-195K. 14,221.0 4,541.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 31/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/29/2024 21:30 11/29/2024 22:30 1.00 INTRM2, DRILLOUT PULD T Attempted to break over torque connections on a stand of 5-7/8" drill pipe. Steamed connections & used rig tongs with no success. Racked back on drillers side out of the way. 4,541.0 4,541.0 11/29/2024 22:30 11/30/2024 00:00 1.50 INTRM2, DRILLOUT TRIP P Tripped out of the hole racking back 5- 7/8" drill pipe from 4541'-2404' MD; PUW 129K. 4,541.0 2,404.0 11/30/2024 00:00 11/30/2024 02:00 2.00 INTRM2, DRILLOUT TRIP P Tripped out of the hole racking back 5- 7/8" drill pipe from 2404'-46' MD; PUW 88K. 2,404.0 46.0 11/30/2024 02:00 11/30/2024 02:30 0.50 INTRM2, DRILLOUT BHAH P Laid down clean out BHA per Sperry DD. 46.0 0.0 11/30/2024 02:30 11/30/2024 03:45 1.25 INTRM2, DRILLOUT BHAH P Sent down BHA components. Cleaned rig floor. 0.0 0.0 11/30/2024 03:45 11/30/2024 04:15 0.50 INTRM2, DRILLOUT SVRG P Serviced top drive & ST-120. 0.0 0.0 11/30/2024 04:15 11/30/2024 09:30 5.25 INTRM2, DRILLOUT BHAH P Picked up 6-1/2" production section BHA to 354' MD. Plugged in and tested tools on the rig floor. Pressure tested Geo-span skid to 3500 psi. SOW 90K 0.0 354.0 11/30/2024 09:30 11/30/2024 16:45 7.25 INTRM2, DRILLOUT PULD P Singled production BHA in the hole with 4-1/2" drill pipe from the shed, from 354'-6015' MD. Filled pipe every 25 stands. PUW 129K SOW 115K 354.0 6,015.0 11/30/2024 16:45 11/30/2024 18:00 1.25 INTRM2, DRILLOUT DHEQ P Shallow hole tested MWD per Sperry. 200 gpm; 1700 psi; FO 4% PUW 146K SOW 131K 6,015.0 6,015.0 11/30/2024 18:00 11/30/2024 21:00 3.00 INTRM2, DRILLOUT PULD P Singled production BHA in the hole with 4-1/2" drill pipe from the shed, from 6015'-8468' MD. Filled pipe every 25 stands. PUW 174K SOW 142K 6,015.0 8,468.0 11/30/2024 21:00 11/30/2024 22:00 1.00 INTRM2, DRILLOUT TRIP P Tripped in the hole with 4-1/2" drill pipe from 8468'-10,683' MD. PUW 195K SOW 154K 8,468.0 10,683.0 11/30/2024 22:00 11/30/2024 23:00 1.00 INTRM2, DRILLOUT DHEQ P Shallow hole tested MWD per Sperry. Blew down the top drive. SIMOPS changed out handling equipment & changed PS-21 slip inserts to 5-7/8". 200 gpm; 1800 psi; FO 5% PUW 207K SOW 154K 10,683.0 10,683.0 11/30/2024 23:00 12/1/2024 00:00 1.00 INTRM2, DRILLOUT TRIP P Tripped in the hole with 4-1/2" drill pipe from 10,683'-12,218' MD. PUW 222K SOW 159K 10,683.0 12,218.0 12/1/2024 00:00 12/1/2024 01:45 1.75 INTRM2, DRILLOUT TRIP P Tripped in the hole with 4-1/2" drill pipe from 12,218'-13,983' MD. Filled pipe every 25 stands. Removed PS-21 slips. PUW 222K SOW 171K 12,218.0 13,983.0 12/1/2024 01:45 12/1/2024 02:15 0.50 INTRM2, DRILLOUT MPDA P Installed 5-7/8" RCD bearing per MPD Advisor. 13,983.0 13,983.0 12/1/2024 02:15 12/1/2024 02:30 0.25 INTRM2, DRILLOUT TRIP P Tripped in the hole with 4-1/2" drill pipe from 13,983'-14,218' MD. SOW 173K 13,983.0 14,218.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 32/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/1/2024 02:30 12/1/2024 06:30 4.00 INTRM2, DRILLOUT DISP P Displaced well, reciprocating, from 11.0 ppg NAF to 8.8 ppg FloPro system. Pumped 20 bbls of LVT; 100 bbls of transition spacer; 100 bbls of cleaning spacer; 35 bbls of tail spacer; chased with 881 bbls of 8.8 ppg FloPro NT. Dumped 240 bbls of spacer & interface. 225 gpm; 1277 psi 40 rpm; Tq 9-12K RW 226K 14,218.0 14,218.0 12/1/2024 06:30 12/1/2024 07:00 0.50 INTRM2, DRILLOUT TRIP P Mouse holed a double to space out for cut & slip. Blew down top drive. SIMOPS prepped floor for cut & slip; cleaned surface equipment in the pits. 14,218.0 14,195.0 12/1/2024 07:00 12/1/2024 11:00 4.00 INTRM2, DRILLOUT SLPC P Cut & slipped 92' of drill line. Inspected drawworks brakes, deadman brass & dog nut. Calibrated block height on Totco & Amphion. Made up double in the mouse hole and ran into 14,223' MD. 14,195.0 14,223.0 12/1/2024 11:00 12/1/2024 17:15 6.25 INTRM2, DRILLOUT DRLG P Cleaned out cement, shoe & rat hole from 14,223'-14,239' MD. 200 gpm; 1140 psi; FO 2% 80 rpm; Tq 4-8K WOB 13 ECD 9.1 PUW 250K SOW 202K RW 225K 14,223.0 14,239.0 12/1/2024 17:15 12/1/2024 19:45 2.50 INTRM2, DRILLOUT CIRC P Circulated bottoms up reciprocating. SIMOPS: Prepped equipment for the shoe test. 200 gpm; 1150 psi; FO 2% 40 rpm; Tq 5-7K 14,239.0 14,196.0 12/1/2024 19:45 12/1/2024 20:15 0.50 INTRM2, DRILLOUT RURD P Rigged up to test the shoe. Broke off a double and put in the mouse hole. Rigged up high pressure hose to the drill pipe. Purged air out of lines. 14,196.0 14,196.0 12/1/2024 20:15 12/1/2024 20:45 0.50 INTRM2, DRILLOUT PRTS P Performed shoe test to an EMW of 12.0 ppg. Pressured up with 8.8 ppg FloPro NT with 3.9 bbls to 1392 psi. Observed pressure for 10 minutes on the Totco Test Pump 1 sensor, with a final pressure of 1381 psi. Bled back 3.9 bbls. 14,196.0 14,196.0 12/1/2024 20:45 12/1/2024 21:15 0.50 INTRM2, DRILLOUT RURD P Rigged down test equipment. Blew down high pressure lines. Made up double from the mouse hole and ran back in. 14,196.0 14,239.0 12/1/2024 21:15 12/1/2024 21:45 0.50 INTRM2, DRILLOUT DDRL P Drilled 6-1/2" production section from 14,239'-14.259' MD, 8332' TVD. 200 gpm; 1170 psi; FO 3% 80 rpm; Tq on 5-10K; off 4K WOB 8-10K ECD 9.1 PUW 250K SOW 201K RW 226K ADT .38; BIT .38 14,239.0 14,259.0 12/1/2024 21:45 12/2/2024 00:00 2.25 INTRM2, DRILLOUT CIRC P Circulated bottoms up reciprocating. SIMOPS prepped equipment for the FIT test. 200 gpm; 1159 psi; FO 2% 40 rpm; Tq 4-7K 14,259.0 14,259.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 33/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2024 00:00 12/2/2024 00:15 0.25 INTRM2, DRILLOUT CIRC P Finished circulating bottoms up reciprocating. SIMOPS: Prepped equipment for the FIT test. 200 gpm; 1159 psi; FO 2% 40 rpm; Tq 4-7K 14,259.0 14,195.0 12/2/2024 00:15 12/2/2024 00:30 0.25 INTRM2, DRILLOUT OWFF P Monitored well shut in with MPD. No pressure built. SIMOPS: Mouse hole a double to space out for FIT. 14,195.0 14,195.0 12/2/2024 00:30 12/2/2024 01:00 0.50 INTRM2, DRILLOUT RURD P Blew down top drive. Rigged up equipment on drill string. Purged air from high pressure lines. 14,195.0 14,195.0 12/2/2024 01:00 12/2/2024 01:15 0.25 INTRM2, DRILLOUT FIT P Performed FIT at the shoe, 8324' TVD, to an EMW of 12.0 ppg. Pressured up with 8.8 ppg FloPro NT with 4.0 bbls to 1399 psi. Observed pressure for 10 minutes on the Totco Test Pump 1 sensor, with a final pressure of 1379 psi. Bled back 4.0 bbls. 14,195.0 14,195.0 12/2/2024 01:15 12/2/2024 01:30 0.25 PROD1, DRILL RURD P Rigged down test equipment. Blew down lines. Made up double from mouse hole. 14,195.0 14,195.0 12/2/2024 01:30 12/2/2024 01:45 0.25 PROD1, DRILL REAM P Washed & reamed down from 14,195'- 14,259' MD. Obtained SCRs. 200 gpm; 1170 psi; FO 3% 80 rpm; Tq 7K 14,195.0 14,259.0 12/2/2024 01:45 12/2/2024 06:00 4.25 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 14,259'-14,541' MD, 8385' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. 225 gpm; 1503 psi; FO 7% 120 rpm; Tq on 10K; off 7K WOB 10K ECD 9.44 Gas 0 PUW 259K SOW 199K RW 224K ADT 2.96; BIT 3.34 14,259.0 14,541.0 12/2/2024 06:00 12/2/2024 12:00 6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 14,541'-15,110' MD, 8417' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. 225 gpm; 1567 psi; FO 6% 135 rpm; Tq on 10K; off 8K WOB 9K ECD 9.54 Gas 0 PUW 259K SOW 192K RW 221K ADT 4.05; BIT 7.39 14,541.0 15,110.0 12/2/2024 12:00 12/2/2024 18:00 6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 15,110'-15,742' MD, 8411' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. 225 gpm; 1727 psi; FO 6% 150 rpm; Tq on 10K; off 8K WOB 4-10K ECD 9.75 Gas 89 PUW 260K SOW 191K RW 220K ADT 4.36; BIT 11.75 15,110.0 15,742.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 34/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2024 18:00 12/2/2024 18:30 0.50 PROD1, DRILL EQRP T Troubleshoot down hole weight on bit. Reboot computers. Waited for reboot due to need for down link to turn up away from UJU formation. 15,742.0 15,742.0 12/2/2024 18:30 12/3/2024 00:00 5.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 15,742'-16,318' MD, 8389' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. Obtained SCRs at 15,934' MD. 225 gpm; 1660 psi; FO 7% 150 rpm; Tq on 12K; off 9K WOB 7K ECD 9.82 Gas 116 PUW 264K SOW 192K RW 221K ADT 4.04; BIT 15.79 15,742.0 16,318.0 12/3/2024 00:00 12/3/2024 06:00 6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 16,318'-16,986' MD, 8384' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. 225 gpm; 1577 psi; FO 4% 150 rpm; Tq on 12K; off 9K WOB 7K ECD 9.8 Gas 125 PUW 268K SOW 195K RW 224K ADT 4.71; BIT 20.5 16,318.0 16,986.0 12/3/2024 06:00 12/3/2024 12:00 6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 16,986'-17,650' MD, 8366' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. Obtained SCRs at 17,043' MD. 225 gpm; 1623 psi; FO 4% 135 rpm; Tq on 14K; off 10K WOB 5-20K ECD 9.87 Gas 84 PUW 273K SOW 193K RW 224K ADT 4.31; BIT 24.81 16,986.0 17,650.0 12/3/2024 12:00 12/3/2024 18:00 6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 17,650'-18,254' MD, 8354' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. 225 gpm; 1630 psi; FO 4% 150 rpm; Tq on 14K; off 11K WOB 7K ECD 9.89 Gas 300 PUW 279K SOW 189K RW 225K ADT 4.15; BIT 28.96 17,650.0 18,254.0 12/3/2024 18:00 12/3/2024 18:30 0.50 PROD1, DRILL DHEQ P Down linked for increased data rates. Did not see good data. Down linked to go back to original data rates. 110 rpm; Tq 11K 18,254.0 18,254.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 35/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2024 18:30 12/3/2024 21:45 3.25 PROD1, DRILL DDRL P Drilled 6-1/2" production section from 18,254'-18,575' MD, 8343' TVD. Drilled with NOVOS & obtained torque / drag every 5 stands. Shut in MPD chokes on connections. 225 gpm; 1687 psi; FO 6% 150 rpm; Tq on 14K; off 11K WOB 19K ECD 9.90 Gas 200 PUW 294K SOW 183K RW 234K ADT2.84; BIT 31.80 18,254.0 18,575.0 12/3/2024 21:45 12/4/2024 00:00 2.25 PROD1, TRIPCAS CIRC P Began circulating bottoms up. Mouse holed a single to reciprocate most of a stand. SCRs taken at 18,435' MD. 225 gpm; 1620 psi; FO 6% 135 rpm; Tq 10K ECD 9.95 18,575.0 18,575.0 12/4/2024 00:00 12/4/2024 00:30 0.50 PROD1, TRIPCAS CIRC P Circulate bottoms up while reciprocating and rotating from 18,575' to 18,491' MD. 225 gpm; 1620 psi; FO 6% 135 rpm; Tq 10K ECD 9.76 Obtain final survey at 18,575' MD. 18,575.0 18,575.0 12/4/2024 00:30 12/4/2024 01:00 0.50 PROD1, TRIPCAS OWFF P Shut in on MPD system and monitor well while rotating at 5 rpm for 30 minutes, no pressure build up observed. 8K TQ at 5 rpm 18,575.0 18,575.0 12/4/2024 01:00 12/4/2024 01:30 0.50 PROD1, TRIPCAS SMPD P SOOH at 8 FPM while utilizing MPD to offset swab from 18,575' to 18,556' MD. L/D single and blow down top drive while performing flow check, well is static. 18,575.0 18,556.0 12/4/2024 01:30 12/4/2024 04:00 2.50 PROD1, TRIPCAS BKRM P Circulate 1st bottoms up while reciprocating from 18,575' to 18,491' MD. Rack back one stand per bottoms up. 250 gpm, 1,685 psi. ECD 9.77 135 rpm, 10K tq. 18,556.0 18,520.0 12/4/2024 04:00 12/4/2024 06:15 2.25 PROD1, TRIPCAS BKRM P Circulate 2nd bottoms up while reciprocating from 18,520' to 18,431' MD. Rack back one stand per bottoms up. 250 gpm, 1,685 psi. ECD 9.72 135 rpm, 10K tq. RTW 225K 18,520.0 18,431.0 12/4/2024 06:15 12/4/2024 08:45 2.50 PROD1, TRIPCAS BKRM P Circulate 3rd bottoms up while reciprocating from 18,431' to 18,338' MD. Rack back one stand per bottoms up. 250 gpm, 1,530 psi. ECD 9.72 135 rpm, 14K tq. RTW 224K 18,431.0 18,338.0 12/4/2024 08:45 12/4/2024 10:30 1.75 PROD1, TRIPCAS BKRM P Encountered higher than normal torque at 18,338' MD while CBU racking back stands per BU. Begin low energy backreaming from 18,338' MD to 18,066' MD. 250 gpm, 1,545 psi, ECD 9.70 30 rpm, 10K tq. RTW 227K Holding 9.6 eqv at TD with MPD with pumps off. 18,338.0 18,066.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 36/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/4/2024 10:30 12/4/2024 12:00 1.50 PROD1, TRIPCAS BKRM P BROOH from 18,066' to 17,967' MD. 250 gpm, 1,554 psi, ECD 9.74 100 rpm, 20 -25K tq. RTW 227K Holding 9.6 eqv at TD with MPD with pumps off. 18,066.0 17,967.0 12/4/2024 12:00 12/4/2024 13:30 1.50 PROD1, TRIPCAS CIRC P CBU while reciprocating from 17,967' to 17,871' MD. 250 gpm, 1,540 psi, ECD 9.7 100 rpm, 20 -25K tq. PUW 290K, SOW 187K, RTW 227K Holding 9.6 eqv at TD with MPD with pumps off. 17,967.0 17,967.0 12/4/2024 13:30 12/4/2024 13:45 0.25 PROD1, TRIPCAS OWFF P Perform flow check while rotating at 10 rpm, Blow down top drive. 17,967.0 17,967.0 12/4/2024 13:45 12/4/2024 18:00 4.25 PROD1, TRIPCAS SMPD P Strip out of hole from 17,967' to 14,224' MD utilizing MPD to offset swab as per Beyond stripping schedule, holding 9.6 eqv at TD with MPD. Monitor displacement via pit #5 PUW 270K 17,967.0 14,224.0 12/4/2024 18:00 12/4/2024 19:15 1.25 PROD1, TRIPCAS CIRC P Circulate 3x liner volume at 14,224' MD. 225 gpm, 1,380 psi, ECD 9.72 20 rpm, 7K tq. 14,224.0 14,224.0 12/4/2024 19:15 12/4/2024 19:45 0.50 PROD1, TRIPCAS SVRG P Perform rig service. Troubleshoot drawworks brakes. 14,224.0 14,224.0 12/4/2024 19:45 12/4/2024 20:30 0.75 PROD1, TRIPCAS SMPD T Troubleshoot drawworks brake release problem. Replace WAGO card. 14,224.0 14,224.0 12/4/2024 20:30 12/4/2024 22:15 1.75 PROD1, TRIPCAS SMPD P Strip out of hole from 14,224' to 12,214' MD utilizing MPD to offset swab as per Beyond stripping schedule, holding 9.6 eqv at TD with MPD. Monitor displacement via pit #5 PUW 250K 14,224.0 12,214.0 12/4/2024 22:15 12/4/2024 23:15 1.00 PROD1, TRIPCAS CIRC P Obtain baseline parameters, 225 gpm / 1225 psi, 84 gpm / 360 psi. Pump 1.75" well commander closing ball down at 84 GPM, 20 rpm ball on seat at 444 strokes. Stage up pressure in 500 psi increments. Well commander shift open at 1620 psi, 447 strokes. 12,214.0 12,214.0 12/4/2024 23:15 12/5/2024 00:00 0.75 PROD1, TRIPCAS CIRC P CBU while rotating and reciprocating at 12,214' MD. 500 gpm, 1,531 psi 20 rpm, 6K tq. RTW 192K 12,214.0 12,214.0 12/5/2024 00:00 12/5/2024 00:30 0.50 PROD1, TRIPCAS CIRC P CBU while rotating and reciprocating at 12,214' MD. 500 gpm, 1,531 psi. 20 rpm, 6K tq. RTW 192K 12,214.0 12,214.0 12/5/2024 00:30 12/5/2024 01:15 0.75 PROD1, TRIPCAS CIRC P Drop 1.75" well commander closing ball and pump down at 2 BPM. 84 gpm, 162 psi. 20 rpm, 4K tq. Ball on seat at 450 strokes, 1300 psi. Well commander function closed at 1722 psi. Pump at 250 gpm and verify parameters for WC closed. 12,214.0 12,214.0 12/5/2024 01:15 12/5/2024 01:30 0.25 PROD1, TRIPCAS RURD P Blow down top drive and blow down sperry manifold. 12,214.0 12,214.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 37/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/5/2024 01:30 12/5/2024 02:45 1.25 PROD1, TRIPCAS SMPD P SOOH utilizing MPD to offset swab from 12,214' to 10,630' MD. PUW = 196K Monitor displacement via pit #5 Hold 9.2 ESD at TD. 12,214.0 10,630.0 12/5/2024 02:45 12/5/2024 03:00 0.25 PROD1, TRIPCAS OWFF P Perform flow check. 10,630.0 10,630.0 12/5/2024 03:00 12/5/2024 04:30 1.50 PROD1, TRIPCAS MPDA P Pull 5-7/8 RCD and rack back in derrick. C/O elevators to 4-1/2". Install 4-1/2" RCD. Install PS21 slips and change inserts to 4-1/2". 10,630.0 10,630.0 12/5/2024 04:30 12/5/2024 12:00 7.50 PROD1, TRIPCAS SMPD P SOOH utilizing MPD to offset swab from 10,630' to 826' MD. PUW = 95K. Monitor displacement via pit #5. Hold 9.2 ESD at TD. 10,630.0 826.0 12/5/2024 12:00 12/5/2024 12:30 0.50 PROD1, TRIPCAS SMPD P SOOH utilizing MPD to offset swab from 826' to 388' MD. PUW = 95K. Monitor displacement via pit #5. Hold 9.2 ESD at TD. 826.0 381.0 12/5/2024 12:30 12/5/2024 13:00 0.50 PROD1, TRIPCAS OWFF P Perform 30 minute flow check. PJSM for pulling RCD bearing. 381.0 381.0 12/5/2024 13:00 12/5/2024 13:45 0.75 PROD1, TRIPCAS MPDA P Pull RCD bearing as per MPD advisor. Pull rabbit from pipe. 381.0 381.0 12/5/2024 13:45 12/5/2024 19:00 5.25 PROD1, TRIPCAS BHAH P L/D BHA as per HES reps from 381' to 0'. PUW 83K. Monitor displacement via TT. Plug in MWD and download. Close blind rams and break bit. Open rams and run back in hole to 70'. Continue break down BHA and L/D. Close rams via pushers office. Clean and clear rig floor. 381.0 0.0 12/5/2024 19:00 12/5/2024 20:00 1.00 COMPZN, CASING RURD P PJSM. Rig up casing running equipment. Open blind rams, (blind weekly function). 0.0 0.0 12/5/2024 20:00 12/5/2024 22:30 2.50 COMPZN, CASING PUTB P M/U 4-1/2" shoe and check floats. RIH with 4-1/2" H563 lower completion as per tally from surface to 830' MD. Monitor displacement via trip tank. Torque connections to 5600 ft/lbs with BOL Arctic grade 2000. SOW 85K. 0.0 830.0 12/5/2024 22:30 12/5/2024 23:00 0.50 COMPZN, CASING SVRG P Service skate and elevators in pipeshed. 830.0 830.0 12/5/2024 23:00 12/6/2024 00:00 1.00 COMPZN, CASING PUTB P M/U 4-1/2" shoe and check floats. RIH with 4-1/2" H563 lower completions as per tally from 830' to 1,333' MD. Monitor displacement via trip tank. Torque connections to 5600 ft/lbs with BOL Arctic grade 2000. SOW 93K. 830.0 1,333.0 12/6/2024 00:00 12/6/2024 05:15 5.25 COMPZN, CASING PUTB P RIH with 4-1/2" H563 lower completion as per tally from 1,333' to 4,033' MD. Torque connections to 5600 ft/lbs with BOL Arctic grade 2000. 1,333.0 4,033.0 12/6/2024 05:15 12/6/2024 05:45 0.50 COMPZN, CASING RURD P Change out handling equipment from 4- 1/2" to 3-1/2" to pick up liner hanger 4,033.0 4,033.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 38/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/6/2024 05:45 12/6/2024 08:00 2.25 COMPZN, CASING OTHR P Make up SLZXP liner hanger. Iinstall XanPlex in liner tie back sleeve. Lower hanger to floor. Change out handling equipment from 3-1/2" to 4- 1/2". Trip in hole one stand 4-1/2" drill pipe to 4,174' MD. R/D casing running equipment. PUW 108K SOW 112K 111K RTW at 20 RPM, 1K TQ 4,033.0 4,174.0 12/6/2024 08:00 12/6/2024 12:00 4.00 COMPZN, CASING RUNL P Trip in hole on 4-1/2" stands of drill pipe from 4,172' to 8,798' MD. Fill pipe every 25 stands. Monitor displacement via trip tank. SOW 130K 4,174.0 8,798.0 12/6/2024 12:00 12/6/2024 13:30 1.50 COMPZN, CASING RUNL P Trip in hole on 4-1/2" stands of drill pipe from 8,798' to 11,165' MD. Fill pipe every 25 stands. Monitor displacement via trip tank. SOW 130K 8,798.0 11,165.0 12/6/2024 13:30 12/6/2024 14:00 0.50 COMPZN, CASING SVRG P Perform rig service while troubleshooting draw-works breaks. 11,165.0 11,165.0 12/6/2024 14:00 12/6/2024 17:30 3.50 COMPZN, CASING RUNL T Draw-works brakes would not release. Troubleshoot system. HPU accumulators lost pre-charge. Make repairs and charge system. 11,165.0 11,165.0 12/6/2024 17:30 12/6/2024 20:00 2.50 COMPZN, CASING RUNL P Trip in hole on 4-1/2" stands of drill pipe from 11,165' to 13,889' MD. Fill pipe every 25 stands. Monitor displacement via trip tank. Collect baseline parameters before RCD install. 13,512' MD: PUW 213K, SOW 164K, RTW @ 20 rpm 188K, 5K TQ. 11,165.0 13,889.0 12/6/2024 20:00 12/6/2024 20:45 0.75 COMPZN, CASING MPDA P PJSM install 5-7/8" RCD bearing change out handling equipment to 5- 7/8" and change PS21 inserts. Collect baseline parameters after RCD install. 13,889' MD: PUW 230K, SOW 170K, RTW @ 20 rpm 188K 5K TQ. 13,889.0 13,889.0 12/6/2024 20:45 12/7/2024 00:00 3.25 COMPZN, CASING RUNL P Trip in hole on 5-7/8" stands of drill pipe from 13,889' to 17,052' MD. Fill pipe every 25 stands. Monitor displacement via trip tank. Monitor displacement via pit #6. SOW 178K 13,889.0 17,052.0 12/7/2024 00:00 12/7/2024 01:00 1.00 COMPZN, CASING RUNL P Trip in hole on 5-7/8" stands of drill pipe from 17,052' to 18,150' MD. Fill pipe every 25 stands. PUW 278K SOW 180K 17,052.0 18,150.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 39/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/7/2024 01:00 12/7/2024 03:15 2.25 COMPZN, CASING DISP P Break circulation and spot Enzyme Breaker. Pump 36 BBLS safe vis spacer at 4 BPM, 667 PSI. Pump 270 BBLS 9.2 PPG breaker fluid at 4 BPM, 635 PSI. Pump 5 BBLS Hi Vis 9.0 PPG CI brine at 4 BPM, 589 PSI. 18,150.0 18,150.0 12/7/2024 03:15 12/7/2024 04:30 1.25 COMPZN, CASING PACK P Drop 1.125" ball and let it fall for 15 min. Pump ball down with 30 BBL Hi-Vis CI brine. Chase with 9.0 PPG CI brine at 4 BPM, 610 PSI. At 611 STKS seen small pressure spike from 615 to 858 PSI. Continue pumping. At 1580 STKS, pressure up from 615 PSI to 2477 PSI. Shut down pumps and pump pressure bleed off on its own. Bring pump back on line at 2 BPM, 760 PSI with no returns or increase in pump pressure. Shut down pump with a total of 5 BBLS pumped. Slack off to see if liner hanger set. Slack off to 164K on the hook setting down 16K. Pick up to 265K and pipe seems to be free of liner with loss of 13K. 18,150.0 18,150.0 12/7/2024 04:30 12/7/2024 05:00 0.50 COMPZN, CASING PRTS P Line up and test liner top to 3500 PSI - slowly bleed off to 3270 PSI in 5 min. Bleed off pressure and open up rams. Blow down top drive. 18,150.0 18,150.0 12/7/2024 05:00 12/7/2024 05:30 0.50 COMPZN, CASING PACK P Pick up 7' to expose dog sub - 260K up weight. Slack off to 106K on hook - didn't see a shear indicating dog sub sheared. Pick up to up weight. Rotate at 20 RPM, 7.5K TQ, 225K rotating weight. Slack off to 110K on the hook, TQ increase to 9- 10K. 4-1/2" liner shoe at 18,150' MD. 4 1/2" liner top at 14,087' MD. 18,150.0 18,150.0 12/7/2024 05:30 12/7/2024 06:00 0.50 COMPZN, CASING PRTS P Line up and test liner top to 3500 PSI for 5 min - good test. 18,150.0 14,129.0 12/7/2024 06:00 12/7/2024 07:15 1.25 COMPZN, WELLPR DISP P Pick up from 14,129' to 14,078' MD. Displace to 9.0 PPG CI brine at 10 BPM, 1610 PSI. Pump at total of 736 BBLS. CI brine come back 126 BBLS late and shakers were full of breaker fluid. PUW 262K 14,129.0 14,078.0 12/7/2024 07:15 12/7/2024 08:30 1.25 COMPZN, WELLPR OWFF P Flow check while off loading more CI brine to pits to circulate hole clean. SIMOPS: Lay down 5-7/8" drill pipe from derrick. Blow down MPD equipment and pull RCD. 14,078.0 13,997.0 12/7/2024 08:30 12/7/2024 09:15 0.75 COMPZN, WELLPR CIRC P Circulate at 10 BPM, 1340 PSI until shakers clean up and have good fluid at surface. 13,997.0 13,997.0 12/7/2024 09:15 12/7/2024 13:00 3.75 COMPZN, WELLPR PULD P Trip out of hole laying down drill pipe from 13,997' to 9,856' MD. 13,997.0 9,856.0 12/7/2024 13:00 12/7/2024 13:15 0.25 COMPZN, WELLPR RURD P Change out pipe handling equipment to 4-1/2". 9,856.0 9,856.0 12/7/2024 13:15 12/7/2024 18:00 4.75 COMPZN, WELLPR PULD P Trip out of hole laying down drill pipe from 9,856' to 3,854' MD. 9,856.0 3,854.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 40/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/7/2024 18:00 12/7/2024 19:15 1.25 COMPZN, WELLPR PULD P Trip out of hole laying down drill pipe from 3,854' to 2404' MD. PUW 107K Monitor hole via trip tank. 3,854.0 2,404.0 12/7/2024 19:15 12/7/2024 19:30 0.25 COMPZN, WELLPR RURD P Rig down PS21's and install master cushings. 2,404.0 2,404.0 12/7/2024 19:30 12/7/2024 21:45 2.25 COMPZN, WELLPR PULD P Trip out of hole laying down drill pipe from 2,404' to 0' MD. PUW 107K Monitor hole via trip tank. 2,404.0 0.0 12/7/2024 21:45 12/7/2024 22:30 0.75 COMPZN, WELLPR BHAH P L/D running tools as per Baker reps. Clean and clear rig floor. 0.0 0.0 12/7/2024 22:30 12/7/2024 23:15 0.75 COMPZN, WELLPR PULD P L/D 5 stands of 4-1/2" drillpipe from derrick to make room for TEC wire spool. 0.0 0.0 12/7/2024 23:15 12/8/2024 00:00 0.75 COMPZN, RPCOMP RURD P Change out handling equipment. M/U wear ring puller. Drain BOP stack. Mobilize upper completion to the rig floor. Remove lock down screws and pull wear ring. 0.0 0.0 12/8/2024 00:00 12/8/2024 01:00 1.00 COMPZN, RPCOMP WWWH P Make up stack washing tool. Flush BOP stack at 8 BPM. Lay down stack washer and blow down top drive. SimOps: Bring up upper completion tools and equipment to rig floor. 0.0 0.0 12/8/2024 01:00 12/8/2024 01:30 0.50 COMPZN, RPCOMP RURD P Rig up to run 4-1/2" upper completion. Hang HES sheave in derrick and install TEC wire. Rig up casing tongs. 0.0 0.0 12/8/2024 01:30 12/8/2024 02:00 0.50 COMPZN, RPCOMP SFTY P PJSM with all employees on running 4- 1/2" upper completion. 0.0 0.0 12/8/2024 02:00 12/8/2024 02:45 0.75 COMPZN, RPCOMP PUTB P Run 4-1/2" HYD 563 upper completion as per detail to 170' MD. Make up TQ = 3800 FT/LBS Use BOL 2000 AG pipe dope 0.0 170.0 12/8/2024 02:45 12/8/2024 03:30 0.75 COMPZN, RPCOMP PRTS P Hook up 1/4" x .035" TEC wire to HES Opsis gauge mandrel. Test line to 10,000 PSI for 10 min - good test. Record readings at surface: 13.3 PSI 37 Volts 3.62mA 170.0 170.0 12/8/2024 03:30 12/8/2024 06:00 2.50 COMPZN, RPCOMP PUTB P Run 4-1/2" HYD 563 upper completion as per detail from 170' to 2094' MD. Make up TQ = 3800 FT/LBS Use BOL 2000 AG pipe dope Install cross collar clamps on TEC wire over collars Test TEC wire every 30 joints Monitor displacement Via trip tank. 170.0 2,094.0 12/8/2024 06:00 12/8/2024 12:00 6.00 COMPZN, RPCOMP PUTB P Run 4-1/2" HYD 563 upper completion as per detail from 2,094' to 7,757' MD. Make up TQ = 3800 FT/LBS Use BOL 2000 AG pipe dope Install cross collar clamps on TEC wire over collars Test TEC wire every 30 joints Monitor displacement Via trip tank. 2,094.0 7,757.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 41/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/8/2024 12:00 12/8/2024 18:00 6.00 COMPZN, RPCOMP PUTB P Run 4-1/2" HYD 563 upper completion as per detail from 7,757' to 12,129' MD. Make up TQ = 3800 FT/LBS Use BOL 2000 AG pipe dope Install cross collar clamps on TEC wire over collars Test TEC wire every 30 joints Monitor displacement Via trip tank. 7,757.0 12,129.0 12/8/2024 18:00 12/8/2024 20:45 2.75 COMPZN, RPCOMP PUTB P Run 4-1/2" HYD 563 upper completion as per detail from 12,129' to 13,937' MD. Make up TQ = 3800 FT/LBS Use BOL 2000 AG pipe dope Install cross collar clamps on TEC wire over collars Test TEC wire every 30 joints Monitor displacement Via trip tank. 12,129.0 13,937.0 12/8/2024 20:45 12/8/2024 21:30 0.75 COMPZN, RPCOMP PUTB P Run 4-1/2" HYD 563 upper completion as per detail from 13,937' to 14,061' MD. Joints #335 to #337 wash in hole at 2 BPM to clear potential debris from breaker pill from liner top. 84 gpm, 64 psi. Make up TQ = 3800 FT/LBS Use BOL 2000 AG pipe dope Install cross collar clamps on TEC wire over collars Test TEC wire every 30 joints Monitor displacement Via trip tank. 13,937.0 14,061.0 12/8/2024 21:30 12/8/2024 22:30 1.00 COMPZN, RPCOMP HOSO P Run 4-1/2" HYD 563 joint #338 in and observe shear with 14K down at 36' in and tag no-go at 37' feet in 14102.89' MD. Set down 20K to confirm tag depth. TOL 14,094.57' MD Perform space out calculations. 14,061.0 14,102.0 12/8/2024 22:30 12/8/2024 23:30 1.00 COMPZN, RPCOMP HOSO P Lay down 3 joints, from 14,102' to 13,983 MD. Pick up pups for space out. Make up 4.07', 8.08', and 9.80' space out pups, total pup length 21.95' Make up joint #336 to 14,046' MD. 187K UP 148K DN 14,102.0 14,046.0 12/8/2024 23:30 12/9/2024 00:00 0.50 COMPZN, RPCOMP THGR P Make up FMC hanger and landing joint. Terminate TEC wire through hanger. Install 341 full cross collar clamps and 10 - 1/2 clamps. 14,046.0 14,046.0 12/9/2024 00:00 12/9/2024 00:30 0.50 COMPZN, RPCOMP THGR P Terminate TEC wire through hanger, test fittings to 5000 PSI for 10 min 14,046.0 14,046.0 12/9/2024 00:30 12/9/2024 01:00 0.50 COMPZN, RPCOMP THGR P Slack off from 14,046' to 14,099' Land out hanger in well head Run in lock down screws 148K DN TEC wire readings after landing hanger 3812 PSI, 180°, 36.6 V, 4.25 mA 14,046.0 14,099.0 12/9/2024 01:00 12/9/2024 01:30 0.50 COMPZN, RPCOMP RURD P Drop 1 7/8" ball and rod with 2" rollers Rig up to set packer and test tubing and IA 14,099.0 14,099.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 42/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/9/2024 01:30 12/9/2024 02:30 1.00 COMPZN, RPCOMP PRTS P Pressure up down tubing to 4500 PSI to set TNT packer and test tubing, pump 8.1 BBLS Pressure bleed from 4350 to 4150 PSI in 4 min, pressure up to 4330, pressure bleed to 3720 in 10 min Discuss path forward with town, believe the ball and rod is leaking by due to foreign material on ball seat from tripping in hole Decision made to test IA Test charted on Totco on IA and cement pressure channels 14,099.0 14,099.0 12/9/2024 02:30 12/9/2024 03:30 1.00 COMPZN, RPCOMP PRTS P Pressure up on tubing to 2700 PSI, bleed to 2475 PSI in 5 min Pressure up on IA to 3600 PSI, TBG come up to 2700 PSI 10 min reading IA =3560, TBG = 2212 PSI 18 min reading IA = 3548, TBG = 2056 PSI Bump up pressure on tubing for SOV concerns to 2300 PSI, IA = 3570 PSI 10 min readings IA = 3550, TBG = 2000 PSI Test charted on Totco on IA and cement pressure channels Pump 16.7 BBLS Decide to move with plan forward and test tubing post rig Shear out SOV 14,099.0 14,099.0 12/9/2024 03:30 12/9/2024 04:00 0.50 COMPZN, RPCOMP OWFF P Flow check for 30 min, static Lay down landing joint 14,099.0 0.0 12/9/2024 04:00 12/9/2024 04:45 0.75 COMPZN, RPCOMP MPSP P Install HP-BPV Test from below to 3000 PSI for 10 min, good test Charted on IA sensor on Totco 0.0 0.0 12/9/2024 04:45 12/9/2024 06:00 1.25 COMPZN, WHDBOP RURD P Flush MPD lines with fresh water, blow down all lines Blow down all lines, power down koomey unit, pull low pressure riser Start laying down 5 7/8" drill pipe via mouse hole - lay down 7 stands 0.0 0.0 12/9/2024 06:00 12/9/2024 09:00 3.00 COMPZN, WHDBOP NUND P Nipple down BOP stack and high pressure riser SimOps: Lay down 5 7/8" drill pipe via mouse hole - lay down 77 stands 0.0 0.0 12/9/2024 09:00 12/9/2024 12:00 3.00 COMPZN, WHDBOP RURD P Mob production tree to and tubing spool adapter. Blow down mud lines. Clean and offload fluid from pits. Swap to Gen power at 11:15 hrs. SIMOPS L/D 5-7/8" drill pipe from derrick. 0.0 0.0 12/9/2024 12:00 12/9/2024 14:30 2.50 COMPZN, WHDBOP NUND P Nipple up tubing adapter flange as per FMC rep. Cut TEC wire and perform final termination at wellhead. SIMOPS: L/D 5-7/8" drillpipe, continue cleaning and offloading pits. Install Dart in HPBPV. 0.0 0.0 12/9/2024 14:30 12/9/2024 15:00 0.50 COMPZN, WHDBOP PRTS P Rig up and test tubing adapter flange. Test tubing adapter flange to 5000 psi for 10 minutes. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 12/10/2024 Page 43/43 MT7-88 Report Printed: 12/23/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/9/2024 15:00 12/9/2024 16:30 1.50 COMPZN, WHDBOP NUND P Nipple up 5 K production tree as per FMC. SIMOPS: L/D 5-7/8" drillpipe, continue cleaning and offloading pits, clean and vac lines and interconnects. 0.0 0.0 12/9/2024 16:30 12/9/2024 17:15 0.75 COMPZN, WHDBOP PRTS P Fill tree with diesel and pressure test lines. Pressure test 5K production tree to 250 psi low and 5000 psi high for 10 minutes each. Recorded on Totco with Test pump #1. 0.0 0.0 12/9/2024 17:15 12/9/2024 18:30 1.25 COMPZN, WHDBOP RURD P PJSM and rig up to freeze protect well. Pull dart and HPBPV. Pressure test lines to 1000 psi. 0.0 0.0 12/9/2024 18:30 12/9/2024 22:30 4.00 COMPZN, WHDBOP FRZP P Pumped 80 bbls of diesel down the IA, taking brine returns from the tubing. Pumped at 2 bpm, Max psi 678. Lined up and allowed well to U-tube. Rigged down Little Red lines. Final pressure: Tubing = 297, IA = 297, OA = 0 psi. 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( 7!22)--!7,')26 ,76'.7!62)'' 6 7!!() ' ')!! 276. )-' +=/++&,0 '-7!!,).- !!)' ..')!6 !7-(6)!6 ,6.)'6 7!.),!!7,-) , ,76'.76!.)( 6 7!,)2( ().. 276.().6 +=/++&,0 '-76 6)!, ! ) ' ..')2- !7-'.), ,(6)6! 7 !)6(!7,!)'' ,76'-7( .)(' 6 7!.)' (),6 276)!( +=/++&,0 ',7( ) ( !!)' ..),! !7-'2),6 - )6 7 .,)-6!72')-, ,76'-7'2'),- 6 7 6-) ! ')'. 276',)!6 +=/++&,0 ',7'2,)!2 6()! ..-),! !7-' )!, .--),2 726-)(,!72) ' ,76'-7,')'' 6 7 2!),! .)' 276'').- +=/++&,0 ',7,!)'- !6)2- ..)(! !7-' )6' 2)'( 72,)2.!72) ,76'-7..6) - 6 7 -)- )!( 276(2)-- +=/++&,0 ',7.,')!- 6()(, ..), !7-'!)' ' 6)- 72(!)!!!72.)(. ,76'-7-6)' 6 7 '.)22 ()- 27!66),, +=/++&,0 ',7---)-, 6').( ...)( !7-' )( 6 )(( 7,22).!72')6. ,76'-7,' ) ! 6 72!2)', '),6 27!6.),( +=/++&,0 ',7,.2)6, 6')' ..).' !7-',)(, '-)!, 7,.)!,!7,6)6' ,76'-72(2)! 6 72,!) () 27!! ),' +=/++&,0 ( ) * ) +&# ) ", ) ) ) - ) !! !! ! #) "" # $%&'(()!*+,-).-/01',,)'- & 2 .) !! - )3' 4 ! )# $%&'(()!*+,-).-/01',,)'- & 2 ) !! ! 4 6 9 456 $ 456 102& 4 6 1 2& 4 6 ", 4 6 ", 4 6 ! . 4 6 ! 0 . 4 6 , 4 6 + 452:;6 " * ',72.()( 6()!. ..')!( !7-'.).6 2 ),' 7-!()'2!7,!), ,76'-726,)' 6 72.()'' ()2! 27!!()-! +=/++&,0 ',7 ),6 6')., ..)62 !7-'')2. '-6).2 7-. ).-!7,2)-6 ,76'-7 !.)-! 6 72() ').! 27! -)(- +=/++&,0 ',7!',).( 6)'2 ...)(, !7-(!) 6 .')6 7.6,)!!7,.)2, ,76'-7! ).. 6 7, ,).' ()!! 27!2!),6 +=/++&,0 ',76( )2 6)- ..)- !7-(,), .'.)6( 7.,)!2!7,()'' ,76'-762()22 6 7,- )6( ()!! 27!2),! +=/++&,0 '27(('),- 6),! ..')6- !7-(').( .62) ! 7.(!)62!7-2)'2 ,76',7(,()'. 6 7,'6)'! ()-! 27!,,), +=/++&,0 '27(6-)' 6)-' ..()!2 !7.6 )2 - !)( 72-)2,!7-)' ,76',7'.!)'' 6 7-!6) ')'! 27!- ),. +=/++&,0 '27'!2) ! 6). ..') . !7.6.), ,,6)'6 7()!7.!).! ,76',7,)6, 6 7-2() ()62 27!.6).. +=/++&,0 '27!(), 6').( ..)(' !7.6()2. 2-')! 7' 2)(,!7.,)-6 ,76',7.',) 6 7-.')'6 ')(- 27!.')6 +=/++&,0 '27. .)(' 6().2 ..)! !7.!6)6 .)!( 7'..)2!7.-)', ,76',7-(.)2 6 7-(.)-' ').! 27!,)2 +=/++&,0 '27-2,)!. 6()! ..-).( !7.!!) !(2)6. 7(6')6 !7..)2. ,76',7-6)!! 6 7. ).' '),- 27!')(6 +=/++&,0 '27,,!),, 6().( ..-).. !7.!!).( !6()-6 7(,') !!7..)'2 ,76',7,!).! 6 7.,). ()(- 27!' ) , +=/++&,0 '272,()2. 6(),6 ..)-( !7.! ),6 6 ) 6 7('(),'!7.)-, ,76',72 ()! 6 7.2)'- )' 27!')6' +=/++&,0 '27 --)( 6()- ..')62 !7.!2)6' '7(,,)-. 27622)6(!7.') ,76',7 2()(' 6 76 )2 ()2( 27!(2)( +=/++&,0 '27!. ),, 6()2( ..')!. !7.!2). '7'. )!! 276)!2!7.')(6 ,76',7!-6)(6 6 72!) - ()-' 27 6!) 2 +=/++&,0 '276!)-( 6() 6 ..). !7.!,)' '7'!)', 27!!().!76)6! ,76',76.,) , 6 7-()6( (),! 27 6')6, +=/++&,0 ' 7()', 6'),( ..)! !7.!.), '7.(').- 27!. )'-!7!)'' ,76'27(,)-' 6 7')6- ()6. 27 !,) +=/++&,0 ' 7''2)( 6'),( ...)( !7.!() 6 '7.!,)( 27 6-).!!7,)2, ,76'27'',),. 6 7'!,),( () 27 !()(6 +=/++&,0 ' 7(!), 6')!, ...)!, !7. !)(6 '7-2 )2 27 ,.)'!7)6, ,76'27(-)2 6 7',6).- ()6. 27 ,).6 +=/++&,0 ' 7.(')', 6')! ...)2( !7. ,)' '7,,()2- 27 ')'2!7'6)6! ,76'276.).' 6 7'..),. () 27 ')'( +=/++&,0 ' 7.6.)! 6') ( ...). !7. )! '72..),, 272 () ,!7' )'- ,76'27.!).! 6 7'( ) ().. 27 22).! +=/++&,0 ' 7-!2), 6)(6 ..) 6 !7.26)' '7 '2)'- 272!) !7'-)( ,76'27- ')- 6 7(!().6 () ' 27 2')(' +=/++&,0 ' 7, !)(, 6')(! ..).( !7.22)2! '7 6 )6 27,!2)2'!7''),- ,76'27,,!) ( 6 7(,.)(6 '). 27 ,-)6( +=/++&,0 ' 72 ')'. 6() , ..')6 !7.2,)'6 '7! 6),2 27,-.)''!7'()(, ,76'272- ),' 6 7(-)22 (),( 27 -!)(' +=/++&,0 ' 7 2.)!( 6()26 ..-),- !7.2-)(. '762).' 27,(')-'!7(!)!6 ,76'27 .2)-2 62766!)(6 ) 27 -)62 +=/++&,0 ' 7!,2)6 6() . ..) - !7.2)! 7(-,) . 27-2()( !7( ) . ,76'27!2)(. 6276 ')66 ')6. 27 .!),' +=/++&,0 ' 76-6).6 6')- ..)(. !7.2')'( 7' )2, 27-' )!7(,)62 ,76'276'-).! 6276--)'. ')'' 27 .)( +=/++&,0 '!7(-)., 6(),. ..),, !7.,6)-! 7(6)6- 27. -)((!7(-).- ,76' 7((.)', 6276',)6! ')'2 27 ,)-, +=/++&,0 '!7'.-),( 6(). ...), !7.,!) 6 76)( 27..)'!7(.)2, ,76' 7(6'),' 627!!6) ')(! 27 ()( +=/++&,0 '!7!),, 6')22 ..)- !7., )' 7. ,) 2 27!6).,!7()(. ,76' 7'!')2' 627!2')22 ')6 27 '-).. +=/++&,0 '!7.')(2 6')6- ..(), !7.,-)2 7-,2)! 27--)! !7'66)' ,76' 726).6 627!.)(, )' 27 (2)(2 +=/++&,0 '!7-'.), 6')-! .!)6' !7.,'),' 7,.2)! 27'6!)'!7'62). ,76' 7.,,)6! 627!(()(' '),- 2726,)', +=/++&,0 '!7,(,)-. 6.)2 . ),, !7.- ) ( 72'-),! 27'-6) .!7'6),2 ,76' 7--') , 627 2,)62 )-. 272!)'( +=/++&,0 '!7,,-)2' 6.)- . ).' !7.--)6' 72,,)62 27'.)6!7'!6) ,76' 7-! )' 627 - )' ()-6 272 -)-2 +=/++&,0 '!7, ,)(( 6.)- . ).' !7.-.) 2 72 .)(6 27'').(!7'!!)2 ,76' 7,(2)(, 627 .6).- ()(( 272 '), AB33 Page 1/1 MT7-88 Report Printed: 12/23/2024 Cement Cement Details Description Conductor String Cement Cementing Start Date 4/14/2024 12:00 Cementing End Date 4/14/2024 18:00 Wellbore Name MT7-88 Comment Cement Stages Stage # 1 Description Primary – Full Bore Objective Top Depth (ftKB) 58.5 Bottom Depth (ftKB) 134.3 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Conductor String Cement Page 1/1 MT7-88 Report Printed: 12/23/2024 Cement Cement Details Description Surface String Cement Cementing Start Date 11/10/2024 07:00 Cementing End Date 11/10/2024 11:15 Wellbore Name MT7-88 Comment Break circulation with water and SLB cementing unit - test lines to 3500 PSI Perform surface cement job as per SLB. Pump 100 BBLS 11 PPG mud push @ 4.5 BPM while reciprocating, 306K UP, 260K DN Drop bottom wiper plug and follow with 423.5 BBLS 11.0 PPG DeepCRETE Lead Cement. Pump at average 6.4 BPM Follow with 69 BBLS 15.8 PPG G blend tail cement at 4 BPM Drop top wiper plug and chase with 20 BBLS water @ 4.5 BPM from cement unit Land hanger while mud push exiting casing shoe. Pick up and reciprocate after interface clears shoe track Displace with 581.7 BBLS 11 PPG Klashield using rig pumps. ICP at 8 BPM, 247 PSI, FCP at 8 BPM, 622 PSI Stop reciprocating casing at 533.5 BBLS into chase Slow to 3 BPM at 562 BBLS pumped 3 BPM 321 ICP, 3 BPM 400 FCP Bump plug at 581.6 BBLS, 4926 STKS. Build pressure to 900 PSI and hold for 5 minutes. Bleed pressure off and check floats - floats holding Note: Lead cement wet at 7:57 HRS, Tail cement wet @ 9:16 HRS Note: Landed hanger 4518 STKS into displacement. CIP @ 11:12 HRS Note: Full returns during job, spacer back at 313 BBLS into chase. Cement/interface back to surface at 434.6 BBLS pumped Cement Stages Stage # 1 Description Surface String Cement Objective Cement 13 5/8" casing to surface Top Depth (ftKB) 54.4 Bottom Depth (ftKB) 4,103.6 Full Return? Yes Vol Cement … 147.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/…P Pump Final (psi) 400.0 P Plug Bump (psi) 400.0 Recip? Yes Stroke (ft) 15.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Perform surface cement job as per SLB. Pump 100 BBLS 11 PPG mud push @ 4.5 BPM while reciprocating, 306K UP, 260K DN Drop bottom wiper plug and follow with 423.5 BBLS 11.0 PPG DeepCRETE Lead Cement. Pump at average 6.4 BPM Follow with 69 BBLS 15.8 PPG G blend tail cement at 4 BPM Drop top wiper plug and chase with 20 BBLS water @ 4.5 BPM from cement unit Land hanger while mud push exiting casing shoe. Pick up and reciprocate after interface clears shoe track Displace with 581.7 BBLS 11 PPG Klashield using rig pumps. ICP at 8 BPM, 247 PSI, FCP at 8 BPM, 622 PSI Stop reciprocating casing at 533.5 BBLS into chase Slow to 3 BPM at 562 BBLS pumped 3 BPM 321 ICP, 3 BPM 400 FCP Bump plug at 581.6 BBLS, 4926 STKS. Build pressure to 900 PSI and hold for 5 minutes. Bleed pressure off and check floats - floats holding Note: Lead cement wet at 7:57 HRS, Tail cement wet @ 9:16 HRS Note: Landed hanger 4518 STKS into displacement. CIP @ 11:12 HRS Note: Full returns during job, spacer back at 313 BBLS into chase. Cement/interface back to surface at 434.6 BBLS pumped Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 54.4 Est Btm (ftKB) 3,603.0 Amount (sacks) 1,243 Class *NOT IN LIBRARY Volume Pumped (bbl) 423.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 6.67 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) Thickening Time (hr) 6.81 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 3,603.0 Est Btm (ftKB) 4,103.6 Amount (sacks) 334 Class G Volume Pumped (bbl) 69.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 5.08 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 4.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 MT7-88 Report Printed: 12/23/2024 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 11/19/2024 18:30 Cementing End Date 11/20/2024 03:00 Wellbore Name MT7-88 Comment Perform 9 7/8" x 9-5/8" intermediate cement job as per SLBG Pump 5 BBLS H2O with cement unit, test pump trips at 250, test lines to 3500 PSI Pumped 60 BBLS 12.5 PPG spacer at 4 BPM Dropped 1st bottom wiper plug and followed with 90 BBLS 13 PPG class G lead cement, pumped at average 5 BPM Followed with 108 BBLS 15.8 PPG class G tail cement, pumped at average 5 BPM, dropped top plug, SLBG displaced with 10 BBLS H2O Displaced 901.6 BBLS 7596 STKS with 11 PPG NAF mud using rig pump at 3-5 BPM 160 ICP, Observed first plug land at 628.6 BBLS 5926 STKS into displacement (3.08 BBLS late) pressure up from 230 PSI to 411 PSI and observe plug shear. Recalculate plug bump. Bump plugs at 901.6 BBLS 7596 STKS pressure up from 1072 PSI to 1689 PSI, hold for 5 min CIP at 1713 at 02;45 HRS, bleed pressure off (2.5 BBLS back to pits) and floats holding Note: Lead cement wet at 22:19 hrs, tail cement wet at 22:50 hrs. Note: Shoe at 12,426.68', float collar at 12,337.92', No losses circulating and cementing Note: Bleed off pressure to check floats, floats holding, Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 9,426.0 Bottom Depth (ftKB) 12,432.0 Full Return? Yes Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 1,048.0 P Plug Bump (psi) 1,072.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Perform 9 7/8" x 9-5/8" intermediate cement job as per SLBG Pump 5 BBLS H2O with cement unit, test pump trips at 250, test lines to 3500 PSI Pumped 60 BBLS 12.5 PPG spacer at 4 BPM Dropped 1st bottom wiper plug and followed with 90 BBLS 13 PPG class G lead cement, pumped at average 5 BPM Followed with 108 BBLS 15.8 PPG class G tail cement, pumped at average 5 BPM, dropped top plug, SLBG displaced with 10 BBLS H2O Displaced 901.6 BBLS 7596 STKS with 11 PPG NAF mud using rig pump at 3-5 BPM 160 ICP, Observed first plug land at 628.6 BBLS 5926 STKS into displacement (3.08 BBLS late) pressure up from 230 PSI to 411 PSI and observe plug shear. Recalculate plug bump. Bump plugs at 901.6 BBLS 7596 STKS pressure up from 1072 PSI to 1689 PSI, hold for 5 min CIP at 1713 at 02;45 HRS, bleed pressure off (2.5 BBLS back to pits) and floats holding Note: Lead cement wet at 22:19 hrs, tail cement wet at 22:50 hrs. Note: Shoe at 12,426.68', float collar at 12,337.92', No losses circulating and cementing Note: Bleed off pressure to check floats, floats holding, Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 9,426.0 Est Btm (ftKB) 10,798.0 Amount (sacks) 268 Class G Volume Pumped (bbl) 90.1 Yield (ft³/sack) 1.89 Mix H20 Ratio (gal/sack) 10.24 Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (cP) 56.0 Thickening Time (hr) 16.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 10,798.0 Est Btm (ftKB) 12,432.0 Amount (sacks) 518 Class G Volume Pumped (bbl) 108.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 4.75 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 77.0 Thickening Time (hr) 11.50 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 1 Cement Page 1/1 MT7-88 Report Printed: 12/23/2024 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 11/26/2024 14:00 Cementing End Date 11/26/2024 21:15 Wellbore Name MT7-88 Comment Pumped cement as per program. Lined up to cementing unit & pumped 3 bbl of water. Pressure tested lines to 3500 psi, good. Pumped 70 bbls of 8.8 ppg KCL spacer with the rig pump at 2 bpm, 94-590 psi. Dropped bottom dart. Swapped line up to cementing unit. Pumped 68 bbls of 15.8 ppg cement at 2 bpm, 790-237 psi. Dropped top dart. Pumped 10 bbls of H2O at 2.1 bpm, 357 psi. Swapped to the rig for displacement. The rig displaced cement with 11.0 ppg NAF at 2 bpm, 968 psi till 140 bbls pumped. Dropped Bozo plug with 76.6 bbls pumped. Reduced rate to 1.6 bpm, 915-1026 psi with increased pressure. Losses observed with 232 bbls of displacement pumped. Losses stopped with 260 bbls pumped, lost 20 bbls. Reduced rate to 1 bpm, 523-901 psi. Observed bottom dart latch with 224 bbls pumped, pressuring up to 979 psi. Observed top dart latch with 292.7 bbls pumped, pressuring up to 1966 psi. Observed bottom plug land with 304 bbls pumped, pressuring up to 1823 psi. Reduce rate to .5 bpm, 600 psi with pressure decrease & losses observed. Worked the pipe with PUW to 430K & SOW to 140K. Continued to work the pipe with no returns pumping at .75 bpm, 1375 psi, PUW 530K, SOW 140K. Attempted to apply back pressure & dumping pressure to free pack off. Stopped working pipe with 365 bbls pumped. Bumped the plug with 376.8 bbls pumped at .7 bpm, 1200 psi. Pressured up to 1700 psi & held for 5 minutes. Checked the floats, good. CIP at 21:05 hrs. Lost 20 bbls while displacing with cement inside the string. Lost 64 bbls starting when cement was coming out of the shoe. Total lost during the job, 84 bbls. Cement Stages Stage # 1 Description Intermediate String 2 Cement Objective Top Depth (ftKB) 14,002.0 Bottom Depth (ftKB) 14,239.0 Full Return? No Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 1 Q Pump Avg (bbl/… 1 P Pump Final (psi) 1,200.0 P Plug Bump (psi) 1,700.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 14,002.0 Est Btm (ftKB) 14,239.0 Amount (sacks) 326 Class G Volume Pumped (bbl) 68.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 4.75 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 71.0 Thickening Time (hr) 8.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 2 Cement t >>ED W/η^ Zs/ KZ Zη &/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' K>KZWZ/Ed^ ͲĞůŝǀĞƌLJ3T-608 50-103-20890-00-00 224-094 KUPARUK RIVER MWD/LWD/DD VISION Service FINAL FIELD 26-Nov-24 1GMTU MT7-88 50-103-20893-00-00 224-111EATER MOOSES TOOMEMORY Top of Cement PROCESSED 29-Nov-24 1dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺWƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞWůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘ďŚĂƚƚĂĐŚĂƌLJĂΛƐůď͘ĐŽŵ^>ƵĚŝƚŽƌͲdƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĂŶĚƚŚĞĐŽŶƚĞŶƚƐŽĨƚŚĞƉĂĐŬĂŐĞŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐĐŽŶƚĞŶƚŽĨƚŚĞƐĂŶĚͬŽƌŚĂƌĚĐŽƉLJƉƌŝŶƚƐŵĂLJŽƌŵĂLJŶŽƚŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚĨŽƌĐŽƌƌĞĐƚŶĞƐƐŽƌƋƵĂůŝƚLJůĞǀĞůĂƚƚŚŝƐƉŽŝŶƚ͘η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ224-094: T39841224-111: T39842Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.12.09 14:28:13 -09'00'224 094: T39841224-111: T39842GMTU MT7-8850-103-20893-00-00224-111EATER MOOSES TOOMEMORYTop of CementPROCESSED29-Nov-241 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Dec 03, 2024 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-88 Greater Mooses Tooth API #: 50-103-20893-00-00 Permit No: 224-111 Rig: Doyon 26 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-88 are located in a federal oil and gas unit. Only with respect to the MT7-88 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: Please return transmittal letter to: Benjamin Jacobi Benjamin.M.Jacobi@conocophillips.com Luis Arismendi Luis.arismendi@bakerhughes.com 224-111 T39802 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.03 08:17:43 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-88 JBR 01/13/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 5 7/8" test joint, FP on kill line flange and FP on PVT alarm speaker was unplugged. Precharge bottles = 32@1000psi each and 4@975psi each. Good Test. Test Results TEST DATA Rig Rep:J. Newman / A. AgnesOperator:ConocoPhillips Alaska, Inc.Operator Rep:D. Pickworth / K. Hinrichs Rig Owner/Rig No.:Doyon 26 PTD#:2241110 DATE:11/11/2024 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopBDB241113103753 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 2937 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 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 18 3/4"P #1 Rams 1 3 1/2"x6 5/8"P #2 Rams 1 Blind/Shear P #3 Rams 1 3 1/2"x6 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 1/16",3 1/8"P Kill Line Valves 2 3", 3 1/16"P Check Valve 0 NA BOP Misc 1 Flange FP System Pressure P3050 Pressure After Closure P1750 200 PSI Attained P13 Full Pressure Attained P81 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P10@3850 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 1 FPMS Misc Inside Reel Valves 0 NA Annular Preventer P14 #1 Rams P13 #2 Rams P13 #3 Rams P13 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 FP FP FP on kill line flange FP on PVT alarm speaker 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 Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Greater Mooses Tooth Field, Rendezvous Oil Pool, GMTU MT7-88 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-111 Revised Surface Location: 1130' FSL, 2158' FWL, S32 T10N R2E, UM Bottomhole Location: 1895' FSL, 1262' FWL, S28 T10N R2E, UM Dear Mr.Brillon: 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 AOGCCreserves 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 AOGCCspecifically 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 AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie /Chmielowski Commissioner DATED this 5thday of November2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.05 09:30:41 -09'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:12. Field/Pool(s): 4a. Location of Well (Governmental Section): Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 11/5/2024 Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 1256' to AA092341 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 155.3 15. Distance to Nearest Well Open Surface: x- 290238 y- 5915943 Zone- 4 100.7 to Same Pool: 1220' to MT7-15 16. Deviated wells: Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H-40 Welded 80 40 40 120 120 16" 13-3/8" / 13-5/8" 68 / 88.2 L-80 Hyd563 4012 40 40 4052 3066 12-1/4" 9-5/8" / 9-7/8" 47 / 62.8 L-80 Hyd563 12389 40 40 12429 7402 8.5" x 9-7/8" 7-5/8" 33.7 L-80/P-110s Hyd523 1976 12279 7487 14255 8333 6-1/2" 4-1/2" 12.6 L-80 Hyd563 8272 14105 8328 22377 8240 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: Hilda Dupont Chris Brillon Contact Email:hilda.dupont@conocophillips.com Wells Engineering Manager Contact Phone:907-265-6675 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 Effect. Depth MD (ft): Effect. Depth TVD (ft): 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): Commission Use Only See cover letter for other requirements. Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: 1400 sx of 11.0 ppg + 322 sx of 15.8 ppg Conductor/Structural LengthCasing 230 sx of 15.8 ppg N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 297 sx of 13.0 ppg + 560 sx of 15.8 ppg 2937 30' FSL, 319' FEL, S33 T10N R2E, UM 1895' FSL, 1262' FWL, S28 T10N R2E, UM 369446000, 932516000, 932535000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips Alaska Inc. 1130' FSL, 2158' FWL, S32 T10N R2E, UM AA098885, AA081781, AA081800 1262.68, 5720, 5756, 2515 18. Casing Program:Top - Setting Depth - Bottom GMTU MT7-88 Greater Mooses Tooth Rendezvous Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 Specifications 3770 Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 6. Proposed Depth: MD: 22,377 7. Property Designation: TVD: 8,240 1RY By Grace Christianson at 7:45 am, Nov 05, 2024 7:45 am, Nov 05, 2024 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available. BOPE testing on a 21-day interval is approved with the attached conditions VTL 11/5/2024 X DSR-11/5/24 7,366 50-103-20893-00-00 8,297 A.Dewhurst 05NOV24 Diverter variance granted per 20 AAC 25.035(h)(2) *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.05 09:30:53 -09'00'11/05/24 7,292 8,294 RBDMS JSB 110824 'DdDdϳͲϴϴ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. *0707 CPAI’s request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 4, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-88 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand producer well from the MT7 drilling pad. The intended spud date for this well is 11/5/2024. It is intended that Doyon 26 be used to drill the well. MT7-88 will utilize a 16” surface hole and will TD above the K3 sand and then 13-3/8" / 13-5/8” casing will be set and cemented to surface. The 12-1/4" intermediate 1 section will be drilled to the top of HRZ formation. A 9-5/8" / 9-7/8” casing string will be run and cemented in place with a 500’ MD or 250’ TVD column of cement above the highest hydrocarbon bearing zone per AOGCC regulation. If an additional hydrocarbon zone is present, a 2nd stage cement job will be performed to cover 50’ TVD above and below the interval. The 8-1/2" x 9-7/8" intermediate 2 section will be drilled and landed in the Alpine D. A 7-5/8” liner string will be set and cemented from TD to secure the shoe and cover 500’ MD or 250’ TVD above any hydrocarbon bearing zone. The production interval will be comprised of a 6-1/2" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as a producer with 4.5” liner with sleeves and swell packers. The upper completion will include a production packer with GLM’s and tied back to surface. It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. A variance is also requested for a BOPE test interval of 21 days for this project. Doyon 26 is a strong participant in the CPAI BOPE between well maintenance program reflected by low failure rates in BOP tests since its entry in the CPAI fleet. The variance allows effective drilling and completion of problematic intermediate shale sections and efficient management of losses in the production sections when they are encountered. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Hilda Dupont at 907-265-6675 (Hilda.Dupont@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com). Sincerely, cc: MT7-88 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1552 Hilda Dupont Chris Brillon ATO 1548 Drilling Engineer variance of the diverter Recommend granting diverter variance based on CPAI review of offset wells and AOGCC review of MT7-04 mudlog and offset wells. -A.Dewhurst 05NOV24 MT7-88 Saved: 4-Nov-24 MT7-88 Page 1 of 13 Printed: 4-Nov-24 MT7-88 Well Plan – Updated Casing Depths and Well Path AOGCC Application for Permit to Drill Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3. Proposed Drilling Program ...................................................................................... 5 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) .................. 6 5. MASP Calculation..................................................................................................... 6 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 8 7. Casing and Cementing Program ............................................................................. 8 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 9 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................. 10 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ........................................ 10 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ....................... 10 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................. 10 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ..................... 10 (Requirements of 20 AAC 25.005 (c)(14)) ........................................................................... 10 14. Drilling Hazards Summary ..................................................................................... 11 15. Proposed Completion Schematic ......................................................................... 13 MT7-88 Saved: 4-Nov-24 MT7-88 Page 2 of 13 Printed: 4-Nov-24 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-88 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1130' FSL, 2158' FWL, S32 T10N R2E, UM NAD27 Northings: 5915943 Eastings: 290238 RKB Elevation 54.6’ AMSL Pad Elevation 100.7’ AMSL Top of Productive Horizon (Heel) 30‘ FSL, 319' FEL, S33 T10N R2E, UM NAD27 Northings: 5914625 Eastings: 298291 Measured Depth, RKB:14,309’ Total Vertical Depth, RKB:8,345’ Total Vertical Depth, SS:8,190’ Total Depth (Toe) 1895' FSL, 1262' FWL, S28 T10N R2E, UM NAD27 Northings: 5921866 Eastings: 294770 Measured Depth, RKB:22,367’ Total Vertical Depth, RKB:8,240’ Total Vertical Depth, SS:8,085’ Please see attached well stick diagram for the current planned development of the pad. MT7-88 Saved: 4-Nov-24 MT7-88 Page 3 of 13 Printed: 4-Nov-24 Pad Layout Well Stick Diagram MT7-88 Saved: 4-Nov-24 MT7-88 Page 4 of 13 Printed: 4-Nov-24 MT7-88 Saved: 4-Nov-24 MT7-88 Page 5 of 13 Printed: 4-Nov-24 3. Proposed Drilling Program 1. MIRU rig Doyon 26 onto well over pre-installed 20” insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan (LWD Program: GR/RES). 4. Run and cement new 13-3/8” / 13-5/8” surface casing to surface. Results of the cement operation will be submitted as soon as possible. 5. Install BOPE with the following equipment/configuration: 13-5/8” annular preventer, 5-1/2” x 7-1/2” VBR and 3-1/2” x 6-5/8” VBR. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4” drilling BHA to drill intermediate #1. (LWD Program: GR/RES). 8. Chart casing pressure test to 3,500 psi for 30 minutes. 9. Drill out shoe track and 20’ of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. 1. Send results to AOGCC as soon as available. 11. Displace well to 11.0 ppg Fresh water polymer WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and trip out of hole. 14. Change upper 5-1/2” x 7-1/2” VBRs to 9-7/8” fixed casing rams and test same to 250/3,500 psi (24-48 hr regulatory notice) 15. Run 9-5/8” x 9-7/8” intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe or 500’ MD above uppermost hydro-carbon bearing zone. A 2nd stage cement job will be performed to isolate reservoir quality sand if exists at shallower depth. Submit results of the cement operation to AOGCC as soon as possible. 1. There is potential for the presence of the Tusk sand, which may be hydrocarbon bearing and require a second stage cement job to place cement 50’ TVD above and below the interval. The required equipment and cement plans are prepared if this becomes necessary. 17. Change upper 9-7/8” fixed casing ram to 4-1/2” x 7-5/8” VBRs. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 18. Pick up and run in hole with 8-1/2” x 9-7/8” drilling BHA to drill intermediate 2. Simops – perform 9.625” annulus freeze protect. (LWD Program: GR/RES) 19. Chart casing pressure test to 3,500 psi for 30 minutes. 20. Drill out shoe track and 20’ of new hole. 21. Perform FIT to max 14.0 ppg EMW. 22. Drill 8-1/2" x 9-7/8” hole to ~14,255’MD / 8,335’ TVD section TD with OBM. 23. Circulate wellbore clean and trip OOH. 24. Change upper 5-1/2” x 7-1/2” VBR to 7-5/8” fix casing ram and test the same. 25. Pick up and run in hole with the 7-5/8” liner to section TD. 26. Circulate and condition mud in preparation for cementing. 27. Cement 7-5/8” liner to required TOC. Set liner top packer. Circulate excess cement from top of liner. POOH laying down drill pipe. Submit results to AOGCC as soon as possible. 28. Change out upper rams to 3-1/2” x 6-5/8” VBR. MT7-88 Saved: 4-Nov-24 MT7-88 Page 6 of 13 Printed: 4-Nov-24 29. Pick up DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 30. Pick up and RIH with 6-1/2” drilling assembly. (LWD Program: GR/Azimuthal RES, Neu/Den). 31. Chart casing pressure test to 3,500 psi for 30 minutes and record results. 32. Drill out and perform FIT to 12.0 ppg EMW. 33. Drill 6-1/2” horizontal hole to TD. 34. Circulate the hole clean, displace to vis brine, POOH. 35. Run 4-1/2” liner on DP, set liner hanger and top packer. Test to confirm packer set. Release from hanger and displace well to CI brine. POOH and laying down DP. 36. Run 4-1/2” tubing with production packer, DHG, GLMs and landing nipples. Locate and space out tubing. Terminate TEC wire and land tubing hanger. 37. Test tubing hanger seals from above to 2,500 psi for 15 mins. 38. Drop ball and rod. Pressure up to set production packer. 39. Pressure test tubing to 4,200 psi for 30 mins. Test IA to 3,500 psi for 30 mins. Shear SOV. 40. Install BPV, test same and tubing hanger seals from below to 2,500 psi. 41. Nipple down BOP, terminate TEC wire. 42. Install tubing head adaptor. Pressure test adaptor to 5,000 psi. 43. Install tree and test. 44. Pull BPV, freeze protect IA and tubing. 45. Secure well. Rig down and move out. 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP and diverter schematics on file for Doyon 26. 5. MASP Calculation The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD (ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 / 13.625 4,052 / 3,066 14.5 1387 2005 9.625 / 9.875 12,429 / 7,402 16.5 3349 2937 7.625 14,255 / 8,333 12.5 3770 2904 4.5 22,377 / 8,240 12.5 3728 NA PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi 8.7 ppg MT7-88 Saved: 4-Nov-24 MT7-88 Page 7 of 13 Printed: 4-Nov-24 FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 115 = 54 psi OR ASP = FPP – (0.1 x D) = 1387 – (0.1 x 3066) = 1080 psi 2. Drilling below 13.375” / 13.625” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3066= 2005 psi OR ASP = FPP – (0.1 x D) = 3349 – (0.1 x 7402) = 2609 psi 3. Drilling below first 9.625” x 9.875” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 7402= 5610 psi OR ASP = FPP – (0.1 x D) = 3770– (0.1 x 8333) = 2937 psi 4. Drilling below 7.625” production liner ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8333 = 4583 psi OR ASP = FPP – (0.1 x D) = 3728 – (0.1 x 8240) = 2904 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary MT7-88 Saved: 4-Nov-24 MT7-88 Page 8 of 13 Printed: 4-Nov-24 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) Drill out casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Csg Setting Depth MD/TVD (ft) Cement Program 20 42 94 H-40 Welded 115 / 115 Cemented to surface with 10 yds slurry 13.375 / 13.625 16 68 / 88.2 L-80 Hyd563 4,052 / 3,066 Cement to Surface 9.625 / 9.875 12.25 47 / 62.8 L-80 Hyd563 12,429 / 7,402 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7.625 8.5 x 9.875 33.7 P-110s Hyd523 14,255 / 8,333 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 4.5 6.125 12.6 L-80 Hyd563 22,377 / 8,240 Uncemented open hole liner with frac ports and swell packers 13.375” / 13.625” Surface Casing run to 4,052’ MD / 3,066’ TVD Cement Plan: Cement from 4,259’ MD to 3,759' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,759' to surface with 11.0 ppg DeepCrete. Assume 120% excess annular volume in permafrost and 50% excess below the permafrost (997’ MD), zero excess in 20” conductor. Lead slurry from 3,552’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 2,659 ft3 => 1,400 sx of 11.0 ppg Deepcrete + Add's @ 1.91 ft 3 /sk Tail slurry from 4,052’ MD to 3,552’ MD with 15.8 ppg Deepcrete + Add's Total Volume = 377 ft3 => 322 sx of 15.8 ppg Class G + Adds @ 1.17 ft3/sk 9.625” / 9.875” Intermediate Casing run to 12,430’ MD / 7,402’ TVD Cement Plan: Primary cement job consists of 1500 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 9,583’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Sub Albian 93. If a shallower hydrocarbon zone of producible volumes is encountered while drilling, a 2nd stage cement job will be performed to isolate this zone. Assume 30% excess annular volume. Lead slurry from 10,930’ MD to 9,583’ MD with 13.0 ppg Class G + Add’s Total Volume = 567 ft3 => 297 sx of 13.0 ppg Class G + Add's @ 1.91 ft3 /sk 9,583’ MD, y j ppg y p ppg y g which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Sub Albian 93 MT7-88 Saved: 4-Nov-24 MT7-88 Page 9 of 13 Printed: 4-Nov-24 Tail slurry from 12,435’ MD to 10,930’ MD with 15.8 ppg Class G + Add's Total Volume = 648 ft3 => 560 sx of 15.8 ppg Class G + Adds @ 1.16 ft3/sk 7-5/8” Intermediate Casing run to 15,950’ MD /8,373’ TVD Cement Plan: Top of slurry is designed to be at 13,503’ MD, which is 500’MD or 250’ TVD above Alpine D. Assume 40% excess annular volume. Tail slurry from 14,255’ MD to 13,503’ MD with 15.8 ppg Class G + Adds Total Volume = 269 ft3 => 230 sx of 15.8 ppg Class G + Adds@ 1.17 ft3/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Intermediate #2 Production Hole Size in. 16 12.25 8.5 x 9.875 6.125 Casing Size in. 13.375 / 13.625 9.625 / 9.875 7.625 4.5 Density PPG 9.0 – 10.0 11.0 – 12.0 10.0 – 11.5 8.5 – 8.8 PV cP 13 10 40 15 YP lb./100 ft2 35-50 20 - 28 20 - 35 15 - 20 Funnel Viscosity s/qt. 200 40 - 50 70 - 90 60 - 80 Initial Gels lb./100 ft2 50 10 14 10 10 Minute Gels lb./100 ft2 60 15 42 15 API Fluid Loss cc/30 min. N.C. – 15.0 10 N/A 4 HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 5.0 10.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A freshwater drilling fluid (KSI) will be used for the surface interval. Keep flow line viscosity at 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight P10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-12.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: The intermediate 2-hole section will be drilled with OBM weighted to 11.0 ppg. Ensure good hole cleaning by maximizing fluid annular velocity. There is slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. MT7-88 Saved: 4-Nov-24 MT7-88 Page 10 of 13 Printed: 4-Nov-24 Maintain mud weight will be 11.0 targeting 12.0 EMW using MPD. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with water-based mud drill-in fluid weighted to 8.8-9.5 ppg. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 26 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Drill cuttings and drilling mud from the well will be disposed of by hauling to Alpine injection facility where they will be disposed by injecting to approved Class I or Class II Disposal wells. MT7-88 Saved: 4-Nov-24 MT7-88 Page 11 of 13 Printed: 4-Nov-24 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375” x 13.625” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Surface Formations Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running speeds 12.25” Hole / 9.625” x 9.875” Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8.5x9.875” Hole / 7.625” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well MT7-88 Saved: 4-Nov-24 MT7-88 Page 12 of 13 Printed: 4-Nov-24 control practices, mud scavengers 6.5” Hole / 4.5” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in intermediate #1 and #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. INT2 section has overpressured shale zones in HRZ to upper Alpine D that CPAI state are not capable of flowing. See emails associated with PTD 224-020. -A.Dewhurst 05NOV24 MT7-88 Saved: 4-Nov-24 MT7-88 Page 13 of 13 Printed: 4-Nov-24 15. Proposed Completion Schematic 55 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3500 3500 4500 4500 10000 10000 15000 15000 20000 20000 22378 MT7-88 wp06 Plan Summary MT7-88 wp06 MT7-01 MT7-01PB1 MT7-15 MT7-83 MT7-83 wp06 MT7-83PH1 MT7-89 MT7-89PB1MT7-91 MT7-92MT7-93 MT7-94 MT7-95 MT7-96 MT7-97 MT7-98 MT7-81 Well2 PlanA wp01 MT7-81 Well2 PlanB wp01 MT7-84 wp00 SaverSlot Saver wp00 0 4 Dogleg Severity0 3500 7000 10500 14000 17500 21000 Measured Depth 13-5/8" SURFACE 9-7/8" INT1 7-5/8" INT2 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] MT7-83 MT7-83 wp06 MT7-83PH1 MT7-89 MT7-89PB1 MT7-91 MT7-92 MT7-93 MT7-84 wp00 Saver Slot Saver wp00 Slot Saver wp00 0 5000 True Vertical Depth0 1500 3000 4500 6000 7500 Vertical Section at 35.82° 13-5/8" SURFACE 9-7/8" INT1 7-5/8" INT2 0 1500 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured Depth Equivalent Magnetic Distance DDI 7.145 SURVEY PROGRAM Date: 2024-04-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.70 1600.00 MT7-88 wp06 (MT7-88)r.5 SDI_URSA1 1600.00 4052.00 MT7-88 wp06 (MT7-88) MWD+IFR2+SAG+MS 4052.00 12430.00 MT7-88 wp06 (MT7-88) MWD+IFR2+SAG+MS 12430.00 14255.00 MT7-88 wp06 (MT7-88) MWD+IFR2+SAG+MS 14255.00 22377.61 MT7-88 wp06 (MT7-88) MWD+IFR2+SAG+MS Surface Location North / 5915688.98 East / 1430275.92Ground / 100.80 CASING DETAILS TVD MD Name 3066.12 4052.02 13-5/8" SURFACE 7401.76 12429.44 9-7/8" INT1 8332.56 14255.00 7-5/8" INT2 8240.67 22377.61 4-1/2" PROD Mag Model & Date: BGGM2024 03-Nov-24 Magnetic North is 13.36° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.32° 57049.33nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 54.70 0.00 0.00 54.70 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 113.77 699.91 -2.11 4.79 1.50 113.77 1.09 Start Build 2.00 4 800.00 5.00 113.77 799.66 -4.92 11.17 2.00 0.00 2.55 Start DLS 2.50 TFO 0.00 5 3117.12 62.93 113.77 2640.64 -504.69 1146.09 2.50 0.00 261.59 Start 6945.20 hold at 3117.12 MD 6 10062.32 62.93 113.77 5801.46 -2996.97 6805.90 0.00 0.00 1553.46 Start DLS 3.00 TFO -132.71 7 12380.04 43.53 25.61 7365.94 -2649.35 8280.91 3.00 -132.71 2698.63 Start 49.96 hold at 12380.04 MD 8 12430.00 43.53 25.61 7402.17 -2618.32 8295.78 0.00 0.00 2732.49 Start 30.00 hold at 12430.00 MD 9 12460.00 43.53 25.61 7423.92 -2599.69 8304.71 0.00 0.00 2752.83 Start DLS 3.30 TFO -71.79 10 13957.65 72.06 336.29 8249.36 -1407.49 8236.92 3.30 -71.79 3679.81 Start 79.90 hold at 13957.65 MD 11 14037.55 72.06 336.29 8273.97 -1337.89 8206.36 0.00 0.00 3718.35 Start DLS 3.00 TFO -43.49 12 14217.16 76.00 332.47 8323.40 -1182.28 8131.68 3.00 -43.49 3800.81 Start 50.00 hold at 14217.16 MD 13 14267.16 76.00 332.47 8335.50 -1139.26 8109.25 0.00 0.00 3822.57 Start 50.00 hold at 14267.16 MD 14 14317.16 76.00 332.47 8347.60 -1096.24 8086.83 0.00 0.00 3844.33 Start DLS 3.00 TFO 0.00 15 14825.10 91.24 332.47 8403.88 -649.92 7854.20 3.00 0.00 4070.06 Start 4552.51 hold at 14825.10 MD 16 19377.61 91.24 332.47 8305.50 3386.20 5750.54 0.00 0.00 6111.37 Start 3000.00 hold at 19377.61 MD 17 22377.61 91.24 332.47 8240.67 6045.91 4364.28 0.00 0.00 7456.54 TD at 22377.61 FORMATION TOP DETAILS TVDPath Formation 995.50 Permafrost_Base 1104.50 C40 1439.50 C30 1672.50 C20 2026.50 C10 3043.50 K3 3676.50 Albian_97 3892.50 Albian_96 4082.50 Albian_95 5011.50 Albian_94 5539.50 Albian_93 5810.50 Sub 93 6367.50 Albian_92 6431.50 Albian_91 7366.50 HRZ 7578.50 LCU 8322.50 Alpine_D 8347.50 Alpine_C By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan KB (100.8PL+54.7 DF) @ 155.50usft (Doyon 26) 0300060009000True Vertical Depth (1500 usft/in)-3000 0 3000 6000 9000Vertical Section at 35.82° (1500 usft/in)13-5/8" SURFACE9-7/8" INT17-5/8" INT24-1/2" PRODStart Build 1.50Start Build 2.00Start DLS 2.50 TFO 0.00Start 6945.20 hold at 3117.12 MDStart DLS 3.00 TFO -132.71Start 49.96 hold at 12380.04 MDStart 30.00 hold at 12430.00 MDStart DLS 3.30 TFO -71.79Start DLS 3.00 TFO -43.49Start 50.00 hold at 14217.16 MDStart 50.00 hold at 14267.16 MDStart DLS 3.00 TFO 0.00Start 3000.00 hold at 19377.61 MDTD at 22377.61Section View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-88Wellbore: MT7-88MT7-88 wp06 Plan View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-88Wellbore: MT7-88Design: MT7-88 wp06-4000040008000South(-)/North(+) (2000 usft/in)-4000 0 4000 8000 12000West(-)/East(+) (2000 usft/in)MT7-88 South TD rev2MT7-88 South Landing (INT2) Rev3MT7-83PH1MT7-83MT7-92MT7-82 Well1 PlanA wp01 M T7-82 Well1 Plan B wp0 1 MT7-99MT7-84 wp00 SaverSlot Saver wp00MT7-94MT7-89PB1MT7-89MT7-98MT7-96Slot Saver wp00MT7-97MT7-93MT7-95MT7-91MT7-01PB1MT7-01MT7-15M T7-81 We ll2 PlanA w p01 MT7-81 Well2 PlanB wp01 13-5/8" SURFACE9-7/8" INT17-5/8" INT24-1/2" PROD500100015002000250030003500400045005000550060006 50 0700075008000 8241MT7-88 wp06 ! ! 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ewhurst, Andrew D (OGC) From:Dupont, Hilda <Hilda.Dupont@conocophillips.com> Sent:Tuesday, 5 November, 2024 08:37 To:Dewhurst, Andrew D (OGC); Hobbs, Greg S Cc:Davies, Stephen F (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMTU MT7-88 Revised PTD (224-111): Question Andrew, Apologies for the incorrect TVD number in the 10-401 form. The MD and TVD in the schematic are correct. Here’s an updated TVD for the 10-401 form: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Thank you, Hilda Dupont | Drilling Engineer | ConocoPhillips O: 907.265.6675 | C: 661.577.7338 | 700 G Street, ATO-1554, Anchorage, AK 99501 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, November 5, 2024 8:08 AM 3 To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Dupont, Hilda <Hilda.Dupont@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]GMTU MT7-88 Revised PTD (224-111): Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hilda, We are working to expedite the review of the revised GMTU MT7-88 PTD. I have one quesƟon: x Would you conĮrm that the TVD values on the schemaƟc are correct. Some of the TVD values on the 10-401 are diīerent: Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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. 224-111 RENDEZVOUS OILGRTR MOOSES TOOTH GMTU MT7-88 3&7*4&% WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-88Initial Class/TypeDEV / PENDGeoArea890Unit10750On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241110GRTR MOOSES TOOTH, RENDEZV OIL - 2822NA1Permit fee attachedYesAA098885, AA081781, and AA0818002Lease number appropriateYes3Unique well name and numberYesGRTR MOOSES TOOTH, RENDEZV OIL - 282200 - governed by CO 7934Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' driven conductor18Conductor string providedYesSC set at 4259' MD19Surface casing protects all known USDWsYes76% excess planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoswell packers, frac sleeves no cement22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedYesDiverter variance granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax reservoir pressure is 3770 psig(8.7 ppg EMW); will drill w/ 8.5-8.8 ppg EMW and maintain 8.8-9.5 w/ MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2937 psig; will test BOPE to 5000 psig initially and 3500 psig subsuquently30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)YesH2S not expected; rig has sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure gradient is 8.7 ppg EMW.36Data presented on potential overpressure zonesNAINT2 section has overpressured shale zones in HRZ to upper Alpine D that CPAI state are not capable of flowing37Seismic analysis of shallow gas zonesNAMPD used to control wellbore stability.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate11/4/2024ApprVTLDate11/5/2024ApprADDDate11/4/2024AdministrationEngineeringGeologyGeologic Commissioner:GCWDate:Engineering Commissioner:JLCDatePublic CommissionerDateJLC 11/5/2024 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 Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Greater Mooses Tooth Field, Rendezvous Oil Pool, GMTU MT7-88 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-111 Surface Location: 1130' FSL, 2158' FWL, S32 T10N R2E, UM Bottomhole Location: 765' FNL, 2640' FWL, S33 T10N R2E, UM Dear Mr. Brillon: 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, Jessie Chmielowski Commissioner DATED this 31st day of October 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.31 07:46:15 -06'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 23,233 TVD: 8,305 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 11/3/2024 Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 2640' to AA081799 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 155.3 15. Distance to Nearest Well Open Surface: x- 290238 y- 5915943 Zone- 4 100.7 to Same Pool: 3339' to MT7-91 16. Deviated wells: Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H-40 Welded 80 40 40 120 120 16" 13-3/8" / 13-5/8" 68 / 88.2 L-80 Hyd563 4219 40 40 4259 3095 12-1/4" 9-5/8" / 9-7/8" 47 / 62.8 L-80 Hyd563 14283 40 40 14323 7594 8.5" x 9-7/8" 7-5/8" 33.7 L-80/P-110s Hyd523 1777 14173 7487 15950 8373 6-1/2" 4-1/2" 12.6 L-80 Hyd563 7433 15800 8328 23233 8305 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: Hilda Dupont Chris Brillon Contact Email:hilda.dupont@conocophillips.com Wells Engineering Manager Contact Phone:907-265-6675 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 GMTU MT7-88 Greater Mooses Tooth Rendezvous Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 Specifications 3784 Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 335 sx of 13.0 ppg + 608 sx of 15.8 ppg 2948 1901' FNL, 680' FWL, S3 T9N R2E, UM 765' FNL, 2640' FWL, S33 T10N R2E, UM 369446000, 932516000, 932515000, 932535000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips Alaska Inc. 1130' FSL, 2158' FWL, S32 T10N R2E, UM AA098885, AA081781, AA081780, AA081800 1262.68, 5720, 5756, 2515 18. Casing Program:Top - Setting Depth - Bottom 1464 sx of 11.0 ppg + 322 sx of 15.8 ppg Conductor/Structural LengthCasing 247 sx of 15.8 ppg N/A Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Commission Use Only See cover letter for other requirements. 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): Effect. Depth MD (ft): Effect. Depth TVD (ft): Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 11:27 am, Aug 08, 2024 224-111 X A.Dewhurst 09OCT24 50-103-20893-00-00 10/26/2024 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available. BOPE testing on a 21-day interval is approved with the attached conditions Diverter variance granted per 20 AAC 25.035(h(2) VTL 10/29/2024 DSR-8/12/24 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.31 07:46:26 -06'00' *&:0/31 10/31/24 10/31/24 RBDMS JSB 110124 'DdDdϳͲϴϴ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. *0707 CPAI’s request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 6, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-88 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand producer well from the MT7 drilling pad. The intended spud date for this well is 11/3/2024. It is intended that Doyon 26 be used to drill the well. MT7-88 will utilize a 16” surface hole and will TD above the K3 sand and then 13-3/8" / 13-5/8” casing will be set and cemented to surface. The 12-1/4" intermediate 1 section will be drilled to the top of HRZ formation. A 9-5/8" / 9-7/8” casing string will be run and cemented in place with a 500’ MD or 250’ TVD column of cement above the highest hydrocarbon bearing zone per AOGCC regulation. If an additional hydrocarbon zone is present, a 2nd stage cement job will be performed to cover 50’ TVD above and below the interval. The 8-1/2" x 9-7/8" intermediate 2 section will be drilled and landed in the Alpine D. A 7-5/8” liner string will be set and cemented from TD to secure the shoe and cover 500’ MD or 250’ TVD above any hydrocarbon bearing zone. The production interval will be comprised of a 6-1/2" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as a producer with 4.5” liner with sleeves and swell packers. The upper completion will include a production packer with GLM’s and tied back to surface. It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. A variance is also requested for a BOPE test interval of 21 days for this project. Doyon 26 is a strong participant in the CPAI BOPE between well maintenance program reflected by low failure rates in BOP tests since its entry in the CPAI fleet. The variance allows effective drilling and completion of problematic intermediate shale sections and efficient management of losses in the production sections when they are encountered. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Hilda Dupont at 907-265-6675 (Hilda.Dupont@conocophillips.com) or Greg Hobbs at 907-263-4794 (greg.s.hobbs@conocophillips.com). Sincerely, cc: MT7-88 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1552 Hilda Dupont Chris Brillon ATO 1548 Drilling Engineer Andy Mack Kuukpik Corp variance of the diverter requirement Recommend granting diverter variance based on CPAI review of offset wells and AOGCC review of MT7-04 mudlog and offset wells. -A.Dewhurst 09OCT24 MT7-88 Saved: 30-Jul-24 MT7-88 Page 1 of 13 Printed: 30-Jul-24 MT7-88 Well Plan Application for Permit to Drill Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3. Proposed Drilling Program ...................................................................................... 5 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) .................. 6 5. MASP Calculations ................................................................................................... 6 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 7 7. Casing and Cementing Program ............................................................................. 8 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 9 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................. 10 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ........................................ 10 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ....................... 10 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................. 10 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ..................... 10 (Requirements of 20 AAC 25.005 (c)(14)) ........................................................................... 10 14. Drilling Hazards Summary ..................................................................................... 11 15. Proposed Completion Schematic ......................................................................... 13 MT7-88 Saved: 30-Jul-24 MT7-88 Page 2 of 13 Printed: 30-Jul-24 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-88 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1130' FSL, 2158' FWL, S32 T10N R2E, UM NAD27 Northings: 5915943 Eastings: 290238 RKB Elevation 54.6’ AMSL Pad Elevation 100.7’ AMSL Top of Productive Horizon (Heel) 1901' FNL, 680' FWL, S3 T9N R2E, UM NAD27 Northings: 5912667 Eastings: 299242 Measured Depth, RKB:15,999’ Total Vertical Depth, RKB:8,374’ Total Vertical Depth, SS:8,219’ Total Depth (Toe) 765' FNL, 2640' FWL, S33 T10N R2E, UM NAD27 Northings: 5919169 Eastings: 296082 Measured Depth, RKB:23,233’ Total Vertical Depth, RKB:8,305’ Total Vertical Depth, SS:8,150’ Please see attached well stick diagram for the current planned development of the pad. MT7-88 Saved: 30-Jul-24 MT7-88 Page 3 of 13 Printed: 30-Jul-24 Pad Layout Well Stick Diagram MT7-88 Saved: 30-Jul-24 MT7-88 Page 4 of 13 Printed: 30-Jul-24 MT7-88 Saved: 30-Jul-24 MT7-88 Page 5 of 13 Printed: 30-Jul-24 3. Proposed Drilling Program 1. MIRU rig Doyon 26 onto well over pre-installed 20” insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan. (LWD Program: GR/RES). 4. Run and cement new 13-3/8” / 13-5/8” surface casing to surface. Results of the cement operation will be submitted as soon as possible. 5. Install BOPE with the following equipment/configuration: 13-5/8” annular preventer, 5-1/2” x 7-1/2” VBR and 3-1/2” x 6-5/8” VBR. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4” drilling BHA to drill intermediate #1. (LWD Program: GR/RES). 8. Chart casing pressure test to 3,500 psi for 30 minutes. 9. Drill out shoe track and 20’ of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. 1. Send results to AOGCC as soon as available. 11. Displace well to 11.0 ppg Fresh water polymer WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and trip out of hole. 14. Change upper 5-1/2” x 7-1/2” VBRs to 9-7/8” fixed casing rams and test same to 250/3,500 psi (24-48 hr regulatory notice) 15. Run 9-5/8” x 9-7/8” intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe or 500’ MD above uppermost hydro-carbon bearing zone. A 2nd stage cement job will be performed to isolate reservoir quality sand if exists at shallower depth. Submit results of the cement operation to AOGCC as soon as possible. 1. There is potential for the presence of the Tusk sand, which may be hydrocarbon bearing and require a second stage cement job to place cement 50’ TVD above and below the interval. The required equipment and cement plans are prepared if this becomes necessary. 17. Change upper 9-7/8” fixed casing ram to 4-1/2” x 7-5/8” VBRs. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 18. Pick up and run in hole with 8-1/2” x 9-7/8” drilling BHA to drill intermediate 2. Simops – perform 9.625” annulus freeze protect. (LWD Program: GR/RES) 19. Chart casing pressure test to 3,500 psi for 30 minutes. 20. Drill out shoe track and 20’ of new hole. 21. Perform FIT to max 14.0 ppg EMW. 22. Drill 8-1/2" x 9-7/8” hole to section TD with OBM. 23. Circulate wellbore clean and trip OOH. 24. Change upper 5-1/2” x 7-1/2” VBR to 7-5/8” fix casing ram and test the same. 25. Pick up and run in hole with the 7-5/8” liner to section TD. 26. Circulate and condition mud in preparation for cementing. 27. Cement 7-5/8” liner to required TOC. Set liner top packer. Circulate excess cement from top of liner. POOH laying down drill pipe. Submit results to AOGCC as soon as possible. 28. Change out upper rams to 3-1/2” x 6-5/8” VBR. MT7-88 Saved: 30-Jul-24 MT7-88 Page 6 of 13 Printed: 30-Jul-24 29. Pick up DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 30. Pick up and RIH with 6-1/2” drilling assembly. (LWD Program: GR/Azimuthal RES, Neu/Den). 31. Chart casing pressure test to 3,500 psi for 30 minutes and record results. 32. Drill out and perform FIT to 13.5 ppg EMW. 33. Drill 6-1/2” horizontal hole to TD. 34. Circulate the hole clean, displace to vis brine, POOH. 35. Run 4-1/2” liner on DP, set liner hanger and top packer. Test to confirm packer set. Release from hanger and displace well to CI brine. POOH and laying down DP. 36. Run 4-1/2” tubing with production packer, DHG, GLMs and landing nipples. Locate and space out tubing. Terminate TEC wire and land tubing hanger. 37. Test tubing hanger seals from above to 2,500 psi for 15 mins. 38. Drop ball and rod. Pressure up to set production packer. 39. Pressure test tubing to 4,200 psi for 30 mins. Test IA to 3,500 psi for 30 mins. Shear SOV. 40. Install BPV, test same and tubing hanger seals from below to 2,500 psi. 41. Nipple down BOP, terminate TEC wire. 42. Install tubing head adaptor. Pressure test adaptor to 5,000 psi. 43. Install tree and test. 44. Pull BPV, freeze protect IA and tubing. 45. Secure well. Rig down and move out. 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP and diverter schematics on file for Doyon 26. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD (ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 / 13.625 4,259 / 3,095 14.5 1400 2024 9.625 / 9.875 14,323 / 7,594 16.5 3436 2948 7.625 15,950 / 8,362 12.5 3784 2928 4.5 23,233 / 8,305 12.5 3758 NA PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft MT7-88 Saved: 30-Jul-24 MT7-88 Page 7 of 13 Printed: 30-Jul-24 D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 115 = 54 psi OR ASP = FPP – (0.1 x D) = 1400 – (0.1 x 3095) = 1091 psi 2. Drilling below 13.375” / 13.625” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3095 = 2024 psi OR ASP = FPP – (0.1 x D) = 3436 – (0.1 x 7594) = 2677 psi 3. Drilling below first 9.625” x 9.875” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 7594 = 5756 psi OR ASP = FPP – (0.1 x D) = 3784– (0.1 x 8362) = 2948 psi 4. Drilling below 7.625” production liner ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8362 = 4600 psi OR ASP = FPP – (0.1 x D) = 3758 – (0.1 x 8305) = 2928 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) Drill out casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. MT7-88 Saved: 30-Jul-24 MT7-88 Page 8 of 13 Printed: 30-Jul-24 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 / 13.625 16 68 / 88.2 L-80 Hyd563 Cement to Surface 9.625 / 9.875 12.25 47 / 62.8 L-80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7.625 8.5 x 9.875 33.7 P-110s Hyd523 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 4.5 6.125 12.6 L-80 Hyd563 Uncemented open hole liner with frac ports and swell packers 13.375” / 13.625” Surface Casing run to 4,259’ MD /3,095’ TVD Cement Plan: Cement from 4,259’ MD to 3,759' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,759' to surface with 11.0 ppg DeepCrete. Assume 120% excess annular volume in permafrost and 50% excess below the permafrost (997’ MD), zero excess in 20” conductor. Lead slurry from 3,759’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 2,796 ft3 => 1,464 sx of 11.0 ppg Deepcrete + Add's @ 1.91 ft 3 /sk Tail slurry from 4,259’ MD to 3,759’ MD with 15.8 ppg Deepcrete + Add's Total Volume = 377 ft3 => 322 sx of 15.8 ppg Class G + Adds @ 1.17 ft3/sk 9.625” / 9.875” Intermediate Casing run to 14,323’ MD / 7,594’ TVD Cement Plan: Primary cement job consists of 1500 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 11,428’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Albian Sub 93. If a shallower hydrocarbon zone of producible volumes is encountered while drilling, a 2nd stage cement job will be performed to isolate this zone. Assume 30% excess annular volume. Lead slurry from 12,818’ MD to 11,428’ MD with 13.0 ppg Class G + Add’s Total Volume = 640 ft3 => 335 sx of 13.0 ppg Class G + Add's @ 1.91 ft3 /sk Tail slurry from 14,323’ MD to 12,818’ MD with 15.8 ppg Class G + Add's Total Volume = 705 ft3 => 608 sx of 15.8 ppg Class G + Adds @ 1.16 ft3/sk If a shallower hydrocarbon zone of producible volumes Deepcrete 11,428’,y j ppg y p ppg y g MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Albian Sub 93,pg Arctic Lite Crete MT7-88 Saved: 30-Jul-24 MT7-88 Page 9 of 13 Printed: 30-Jul-24 7-5/8” Intermediate Casing run to 15,950’ MD /8,373’ TVD Cement Plan: Top of slurry is designed to be at 15,134’ MD, which is 500’MD or 250’ TVD above Alpine D. Assume 40% excess annular volume. Tail slurry from 15,950’ MD to 15,134’ MD with 15.8 ppg Class G + Adds Total Volume = 290 ft3 => 247 sx of 15.8 ppg Class G + Adds@ 1.17 ft3/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Intermediate #2 Production Hole Size in. 16 12.25 8.5 x 9.875 6.125 Casing Size in. 13.375 / 13.625 9.625 / 9.875 7.625 4.5 Density PPG 9.0 – 10.0 11.0 – 12.0 10.0 – 11.5 8.5 – 8.8 PV cP 13 10 40 15 YP lb./100 ft2 35-50 20 - 28 20 - 35 15 - 20 Funnel Viscosity s/qt. 200 40 - 50 70 - 90 60 - 80 Initial Gels lb./100 ft2 50 10 14 10 10 Minute Gels lb./100 ft2 60 15 42 15 API Fluid Loss cc/30 min. N.C. – 15.0 10 N/A 4 HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 5.0 10.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A fresh water drilling fluid (KSI) will be used for the surface interval. Keep flow line viscosity at 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight N10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-12.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: The intermediate 2-hole section will be drilled with OBM weighted to 11.0 ppg. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight will be 11.0 targeting 12.0 EMW using MPD. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: 15,134’ MD, which is 500’MD or 250’ TVD above Alpine D MT7-88 Saved: 30-Jul-24 MT7-88 Page 10 of 13 Printed: 30-Jul-24 The horizontal production interval will be drilled with water-based mud drill-in fluid weighted to 8.8-9.5 ppg. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 26 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Drill cuttings and drilling mud from the well will be disposed of by hauling to Alpine injection facility where they will be disposed by injecting to approved Class I or Class II Disposal wells. MT7-88 Saved: 30-Jul-24 MT7-88 Page 11 of 13 Printed: 30-Jul-24 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375” x 13.625” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Surface Formations Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running speeds 12.25” Hole / 9.625” x 9.875” Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8.5x9.875” Hole / 7.625” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well MT7-88 Saved: 30-Jul-24 MT7-88 Page 12 of 13 Printed: 30-Jul-24 control practices, mud scavengers 6.5” Hole / 4.5” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in intermediate #1 and #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT7-88 Saved: 30-Jul-24 MT7-88 Page 13 of 13 Printed: 30-Jul-24 15. Proposed Completion Schematic 55 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3500 3500 4500 4500 10000 10000 15000 15000 20000 20000 23234 MT7-88 wp04 South Plan Summary MT7-88 wp04 South MT7-01 MT7-01PB1 MT7-02 MT7-03 MT7-03A RWO Redrill MT7-04 MT7-05 MT7-06MT7-06AMT7-06PB1 MT7-07 MT7-08PB1 MT7-09 MT7-11 MT7-14 MT7-14A MT7-15MT7-91 MT7-92 MT7-93 MT7-94 MT7-95 MT7-96 MT7-97 MT7-98 MT7-99 MT7-83 wp04 MT7-83PH1 wp03 MT7-89 wp05 South MT7-84 Saver MT7-90 Saver 0 4 Dogleg Severity0 3500 7000 10500 14000 17500 21000 Measured Depth 13-3/8" Surface 9-5/8" INT1 7-5/8" INT2 4-1/2" PROD 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] MT7-91 MT7-92 MT7-93 MT7-83 wp04 MT7-83PH1 wp03 MT7-89 wp05 South MT7-84 Saver MT7-90 Saver 0 5000 True Vertical Depth-10500 -9000 -7500 -6000 -4500 -3000 -1500 0 Vertical Section at 300.00° 13-3/8" Surface 9-5/8" INT1 7-5/8" INT2 4-1/2" PROD 0 1500 Centre to Centre Separation0 3500 7000 10500 14000 17500 21000 Measured Depth Equivalent Magnetic Distance DDI 7.156 SURVEY PROGRAM Date: 2024-04-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.70 1000.00 MT7-88 wp04 South (MT7-88 South)r.5 SDI_URSA1 1000.00 4259.00 MT7-88 wp04 South (MT7-88 South) MWD+IFR2+SAG+MS 4259.00 14324.00 MT7-88 wp04 South (MT7-88 South) MWD+IFR2+SAG+MS 14324.00 15955.00 MT7-88 wp04 South (MT7-88 South) MWD+IFR2+SAG+MS 15955.00 23233.75 MT7-88 wp04 South (MT7-88 South) MWD+IFR2+SAG+MS Surface Location North / 5915688.98 East / 1430275.92Ground / 100.80 CASING DETAILS TVD MD Name 3095.50 4259.52 13-3/8" Surface 7595.50 14324.08 9-5/8" INT1 8363.50 15954.76 7-5/8" INT2 8305.50 23233.75 4-1/2" PROD Mag Model & Date: BGGM2024 01-Sep-24 Magnetic North is 13.44° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.32° 57055.40nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 54.70 0.00 0.00 54.70 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 122.65 699.91 -2.82 4.41 1.50 122.65 -5.23 Start Build 2.00 4 800.00 5.00 122.65 799.66 -6.59 10.28 2.00 0.00 -12.20 Start DLS 2.50 TFO 0.00 5 3271.85 66.80 122.65 2706.36 -751.14 1172.35 2.50 0.00 -1390.85 Start 987.67 hold at 3271.85 MD 6 4259.52 66.80 122.65 3095.50 -1240.86 1936.69 0.00 0.00 -2297.65 Start DLS 2.50 TFO -12.94 7 4344.18 68.86 122.14 3127.45 -1282.86 2002.89 2.50 -12.94 -2375.98 Start 7060.54 hold at 4344.18 MD 8 11404.73 68.86 122.14 5673.82 -4786.21 7579.07 0.00 0.00 -8956.77 Start DLS 3.00 TFO -136.19 9 14120.01 44.01 22.29 7449.59 -4545.01 9311.14 3.00 -136.19 -10336.19 Start 49.99 hold at 14120.01 MD 10 14170.00 44.01 22.29 7485.54 -4512.87 9324.32 0.00 0.00 -10331.53 Start 50.00 hold at 14170.00 MD 11 14220.00 44.01 22.29 7521.51 -4480.73 9337.49 0.00 0.00 -10326.87 Start DLS 3.35 TFO -68.31 12 15806.71 76.95 332.53 8330.07 -3191.10 9178.52 3.35 -68.31 -9544.39 Start 152.48 hold at 15806.71 MD 13 15959.19 76.95 332.53 8364.50 -3059.31 9110.01 0.00 0.00 -9419.15 Start 50.00 hold at 15959.19 MD 14 16009.19 76.95 332.53 8375.79 -3016.09 9087.55 0.00 0.00 -9378.09 Start DLS 3.00 TFO -0.27 15 16477.89 91.01 332.47 8424.81 -2603.67 8872.86 3.00 -0.27 -8985.96 Start 6755.86 hold at 16477.89 MD 16 23233.75 91.01 332.47 8305.50 3386.20 5750.54 0.00 0.00 -3287.01 TD at 23233.75 FORMATION TOP DETAILS TVDPath Formation 995.39 Permafrost 1104.06 C40 1439.32 C30 1671.74 C20 2026.20 C10 3040.91 K3 3675.31 Albian_97 3885.63 Albian_96 4073.62 Albian_95 5122.08 Albian_94 5657.30 Albian_93 5908.84 Top_Stareater 6369.97 Albian_92 6463.94 Albian_91 7572.61 HRZ_Prog 7657.01 LCU_Prog 8337.34 Top_Alpine 8374.50 Alpine_C Isopach D By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan KB (100.8PL+54.7 DF) @ 155.50usft (Doyon 26) Plan View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-88Wellbore: MT7-88 SouthDesign: MT7-88 wp04 South-700007000South(-)/North(+) (3500 usft/in)-14000 -7000 0 7000 14000West(-)/East(+) (3500 usft/in)MT7-88 South T2MT7-88 South T1MT7-01MT7-01PB1MT7-02MT7-03MT7-03A RWO RedrillMT7-04MT7-05MT7-06MT7-06AMT7-06PB1MT7-07MT7-08MT7-08PB1MT7-09MT7-11MT7-14MT7-14AMT7-15MT7-91MT7-92MT7-93MT7-94MT7-95MT7-96MT7-97MT7-98MT7-99MT7-83 wp04MT7-83PH1 wp03MT7-89 wp05 SouthMT7-10_wp04MT7-12_wp02_EXT_PetrelM T7-84 SaverMT7-90 Saver13-3/8" Surface9-5/8" INT17-5/8" INT24-1/2" PROD500100015002000250030003500400045005000550060006 50 0700075008000 8305MT7-88 wp04 South 0300060009000True Vertical Depth (1500 usft/in)-12000 -9000 -6000 -3000 0Vertical Section at 300.00° (1500 usft/in)13-3/8" Surface9-5/8" INT17-5/8" INT24-1/2" PRODMT7-88 wp04 SouthStart Build 1.50Start Build 2.00Start DLS 2.50 TFO 0.00Start 987.67 hold at 3271.85 MDStart DLS 2.50 TFO -12.94Start 7060.54 hold at 4344.18 MDStart DLS 3.00 TFO -136.19Start 49.99 hold at 14120.01 MDStart 50.00 hold at 14170.00 MDStart DLS 3.35 TFO -68.31Start DLS 3.00 TFO -0.27TD at 23233.75Section View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-88Wellbore: MT7-88 SouthMT7-88 wp04 South ! 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"#$$%&'()% *+, - #((%($ 2 45 > + . > 6 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. 224-111 RENDEZVOUS OIL GMTU MT7-88 GREATER MOOSES TOOTH WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-88Initial Class/TypeDEV / PENDGeoArea890Unit10750On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241110GRTR MOOSES TOOTH, RENDEZV OIL - 282200NA1Permit fee attachedYesAA098885, AA081781, AA081780 , and AA0818002Lease number appropriateYes3Unique well name and numberYesGRTR MOOSES TOOTH, RENDEZV OIL - 282200 - governed by CO 7934Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' driven conductor18Conductor string providedYesSC set at 4259' MD19Surface casing protects all known USDWsYes74% excess planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoswell packers, frac sleeves no cement22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedYesDiverter variance granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax reservoir pressure is 3784 psig(8.7 ppg EMW); will drill w/ 8.5-12.0 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2948 psig; will test BOPE to 5000 psig initially and 3500 psig subsuquently30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)YesH2S not expected; rig has sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure gradient is 8.7 ppg EMW.36Data presented on potential overpressure zonesNAINT2 section has overpressured shale zones in HRZ to upper Alpine D that CPAI state are not capable of flowing37Seismic analysis of shallow gas zonesNAMPD used to control wellbore stability.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate10/9/2024ApprVTLDate10/29/2024ApprADDDate10/9/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/31/2024
