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DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 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 , P O R , S O N I C , m u d l o g s No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 6/ 1 5 / 2 0 2 3 40 4 2 2 4 8 0 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ L A S _ R M . l a s 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : MT 7 _ 9 5 _ R 2 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ c a s i n g s _ S o n i c S c op e 4 7 5 _ R M _ T O C _ 4 4 5 0 f t _ 1 1 0 4 0 f t . p p t . p p t x 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 1 0 0 0 M D _ R M . p d f 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 2 0 0 M D _ R M . p d f 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 4 0 0 0 M D _ R M . p d f 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 4 0 0 0 M D _ R M _ L a b e l e d . p d f 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 5 0 0 M D _ R M . p d f 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 6 0 0 0 M D _ R M . p d f 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ 8 0 0 0 M D _ R M . p d f 37 7 5 5 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 1 o f 8 Su p p l i e d b y Op Su p p l i e d b y Op DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ R M . d l i s 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : O. 1 0 1 3 0 1 1 . 1 8 _ C P A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T7 - 9 5 _ T O C _ R M . h t m l 37 7 5 5 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 15 0 2 4 8 0 4 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 - 95 _ C O M P _ M E M . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 1 _ M E M _ A P - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 2 _ M E M _ A P - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 3 _ M E M _ A P - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 4 _ M E M _ A P - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 1 _ M E M _ V S S - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 2 _ M E M _ V S S - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 3 _ M E M _ V S S - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 95 _ R U N 0 4 _ M E M _ V S S - L O G _ T I M E . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 18 0 2 4 8 0 4 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 - 95 _ V S S - D E P T H _ C O M P _ M E M . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 37 3 0 9 6 2 2 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 - 95 _ S D T K _ M E M _ 3 7 3 0 _ 9 8 2 2 . l a s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ 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 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ B a k e r MW D _ L W D _ D i s t r i b u t i o n A S R C . d o c x 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ B a k e r MW D _ L W D _ D i s t r i b u t i o n B L M . d o c x 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 01 _ M E M _ A P - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 2 o f 8 CP A I _ M T 7 - , 95_ CO MP _ M E M . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 02 _ M E M _ A P - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 03 _ M E M _ A P - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 04 _ M E M _ A P - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 01 _ M E M _ V S S - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 02 _ M E M _ V S S - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 03 _ M E M _ V S S - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ R U N 04 _ M E M _ V S S - L O G _ T I M E . a s c 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ A Z C A L - BH P _ R 2 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ A Z C A L - BH P _ R 2 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ L T K - AZ C A L _ R 2 . d l i s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ L T K _ R 2 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ L T K _ R 2 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ S D T K _ M E M _ D T C _ 3 7 3 0 _ 9 8 2 2 . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ S D T K _ M E M _ D T C _ 3 7 3 0 _ 9 8 2 2 . P D F 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ S D T K _ M E M _ D T S _ 3 7 3 0 _ 9 8 2 2 . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ S D T K _ M E M _ D T S _ 3 7 3 0 _ 9 8 2 2 . P D F 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ S D T K _ M E M _ W I D E B E D _ 3 7 3 0 _ 9 8 2 2 . c g m 37 7 5 8 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 3 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ S D T K _ M E M _ W I D E B E D _ 3 7 3 0 _ 9 8 2 2 . P DF 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ S D T K _ M E M _ 3 7 3 0 _ 9 8 2 2 . d l i s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ S D T K _ M E M _ 3 7 3 0 _ 9 8 2 2 _ d l i s . t x t 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : R N S F i n a l Re p o r t _ C o n o c o P h i l l i p s A l a s k a _ G M T 2 M T 7 - 9 5 - Az i T r a k - V i s i T r a k A h e a d . p p t x 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ L T K _ R 4 . d l i s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ L T K _ R 4 . d l i s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ S T K _ R 4 . d l i s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 0 4 8 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 0 4 8 s c l . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 0 4 8 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ m e m _ S T K _ R 4 . d l i s 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 2 M D _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 4 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 2 T V D _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ Q U A D _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 T V D _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 T V D _ Q U A D _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ A P - TI M E _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ V S S - DE P T H _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ V S S - TI M E _ C O M P _ M E M . c g m 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 2 M D _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 2 T V D _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 M D _ Q U A D _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 T V D _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 95 _ 5 T V D _ Q U A D _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ A P - TI M E _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ V S S - DE P T H _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 9 5 _ V S S - TI M E _ C O M P _ M E M . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 2 7 C o m p a s s Ca n v a s . t x t 37 7 5 8 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 5 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 2 7 C o m p a s s De f i n i t i v e . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 2 7 C o m p a s s P e t r e l (1 ) . t x t 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 2 7 C o m p a s s Pe t r e l . t x t 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 8 3 C o m p a s s Su r v e y s C a n v a s . t x t 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 8 3 C o m p a s s Su r v e y s D e f i n i t i v e . p d f 37 7 5 8 ED Di g i t a l D a t a DF 6/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 N A D 8 3 C o m p a s s Su r v e y s P e t r e l . t x t 37 7 5 8 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 11 0 9 4 9 7 8 1 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 - 9 5 2 0 2 3 - 0 7 - 03 P r o c e s s e d D a t a . l a s 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : 2 0 2 2 - 0 7 - 0 3 _ 2 2 1 0 4 _ G M T U _ M T 7 - 95 _ C a l i p e r S u r v e y _ L o g D a t a _ T r a n s m i t t a l . d o c x 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 95 _ M F C 2 4 _ 0 3 J u l 2 0 2 3 _ I n t e g r i t y R e p o r t . p d f 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : 6 3 0 B 0 9 4 0 . j p g 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : G M T U _ M T 7 - 9 5 _ 0 3 - J u l - 23 _ C a l i p e r S u r v e y L o g . p d f 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : G M T U _ M T 7 - 9 5 _ 0 3 - J u l - 23 _ C a l i p e r S u r v e y L o g . t i f 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 2 0 2 3 - 0 7 - 0 3 4 . 5 ' ' T u b i n g an d L i n e r . I D X 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 2 0 2 3 - 0 7 - 0 3 4 . 5 ' ' T u b i n g an d L i n e r . R G B 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 2 0 2 3 - 0 7 - 0 3 4 . 5 ' ' T u b i n g an d L i n e r . s r v 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 2 0 2 3 - 0 7 - 0 3 4 . 5 ' ' T u b i n g an d L i n e r . U N W 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : P D S V i e w e r . i c o 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : S a m p l e D a t a . I D X 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : S a m p l e D a t a . r g b 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : S a m p l e D a t a . U N W 37 8 0 7 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 6 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 2 0 2 5 UI C No DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : P D S 3 - D C a l i p e r D a t a V i e w e r He l p . d o c 37 8 0 7 ED Di g i t a l D a t a DF 7/ 6 / 2 0 2 3 E l e c t r o n i c F i l e : P D S 3 - D C a l i p e r D a t a V i e w e r He l p . p d f 37 8 0 7 ED Di g i t a l D a t a DF 7/ 2 8 / 2 0 2 3 37 5 3 2 4 8 0 4 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 - 95 _ G 8 _ C o r r e c t e d G a s D a t a _ 3 7 5 3 - 24 8 0 4 f t _ F I N A L . l a s 37 8 8 2 ED Di g i t a l D a t a DF 7/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 _ M T 7 - 95 _ M U D L O G _ 2 4 8 0 3 f t M D 2 i n c h _ F I N A L . p d f 37 8 8 2 ED Di g i t a l D a t a DF 7/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 _ M T 7 - 95 _ M U D L O G _ 2 4 8 0 3 f t M D 5 i n c h _ F I N A L . p d f 37 8 8 2 ED Di g i t a l D a t a DF 7/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 9 5 _ C u t t i n g s Pe r c e n t a g e s . x l s x 37 8 8 2 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 10 6 0 1 1 0 9 0 2 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ R u n 1 _ S h o o t i n g P a ss _ C o n C u _ R 0 1 _ L 0 1 1 U p _ P U N C H E R _ U P C T _ E R S. l a s 38 4 3 0 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 10 1 2 0 1 0 3 5 4 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ R u n 2 _ S h o o t i n g P a ss _ C o n C u _ R 0 2 _ L 0 0 4 U p _ P U N C H E R _ U P C T _ E R S. l a s 38 4 3 0 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 99 0 6 1 0 2 5 5 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ R u n 3 _ S h o o t i n g P a ss _ C o n C u _ R 0 3 _ L 0 0 4 U p _ P U N C H E R _ U P C T _ E R S. l a s 38 4 3 0 ED Di g i t a l D a t a DF 1/ 1 9 / 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ R u n 1 _ S h o o t i n g P a ss _ C o n C u _ R 0 1 _ L 0 1 1 U p _ P U N C H E R _ U P C T _ E R S. d l i s 38 4 3 0 ED Di g i t a l D a t a DF 1/ 1 9 / 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ R u n 2 _ S h o o t i n g P a ss _ C o n C u _ R 0 2 _ L 0 0 4 U p _ P U N C H E R _ U P C T _ E R S. d l i s 38 4 3 0 ED Di g i t a l D a t a DF 1/ 1 9 / 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ R u n 3 _ S h o o t i n g P a ss _ C o n C u _ R 0 3 _ L 0 0 4 U p _ P U N C H E R _ U P C T _ E R S. d l i s 38 4 3 0 ED Di g i t a l D a t a DF 1/ 1 9 / 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 - 95 _ T u b i n g P u n c h e r _ 1 2 J u n e 2 3 _ F i e l d P r i n t . P d f 38 4 3 0 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 7 o f 8 MT 7 - , 95 _ G 8 _ C o r r e c t e d G a s D a t a _ 3 7 5 3 - __ 24 8 0 4 f t _ F I N A L . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 5 4 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 5 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 6/ 4 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 3 5 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 24 8 0 3 TV D 84 6 1 Cu r r e n t S t a t u s 1- O I L 11 / 1 7 / 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 : 6/ 4 / 2 0 2 3 Re l e a s e D a t e : 4/ 2 0 / 2 0 2 3 6/ 3 0 / 2 0 2 3 37 8 0 2 4 8 0 3 61 8 5 0 Cu t t i n g s Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 8 o f 8 11 / 1 9 / 2 0 2 5 M. G u h l MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT7-95 GMTU MT7-95 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 MT7-95 50-103-20854-00-00 223-035-0 W SPT 7541 2230350 1885 873 873 871 872 90 90 90 90 4YRTST P Sully Sullivan 7/15/2024 4 year MIT-IA, Operator had to take returns to production due to gas 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:GMTU MT7-95 Inspection Date: Tubing OA Packer Depth 1410 2280 2220 2215IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240717095452 BBL Pumped:4.3 BBL Returned:0.1 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 9 99 9 9 9 Operator had to take returns to production due to gas 0.1 James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:38:03 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Mooses Tooth DATE: 12/19/2023 Transmitted: North Slope, Mooses Tooth Unit Via hard drive data drop MT7-07 50-103-20841-00 222052_MT7-07_CBP_15Feb2023 222052_MT7-07_IPROF_14Aug23 222052_MT7-07_IPROF_14Mar23 222052_MT7-07_IPROF_25Nov22 222052_MT7-07_Patch_Setting_28Oct23 222052_MT7-07_PPROF_22Aug2022 222052_MT7-07_WFL_16Mar23 MT7-08 50-103-20846-00 222116_MT7-08_IPROF_17Aug23 222116_MT7-08_TTiX-IPROF_2Oct2023 MT7-09 50-103-20837-00 222011_MT7-09_PPROF_01Nov2022 222011_MT7-09_PPROF_03Jul2022 222011_MT7-09_TTiXPerf_04Oct23 MT7-94 50-103-20858-00 223049_MT7-94_MDT-XLROCK- GR_10Sep2023 MT7-95 50-103-20854-00 223035_MT7-95_TubingPuncher_12Jun2023 2of 3 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38426 T38427 T38428 T38429 T38430 2/29/2024 MT7-95 50-103-20854-00 223035_MT7-95_TubingPuncher_12Jun2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:00:23 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, October 13, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT7-95 GMTU MT7-95 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/13/2023 MT7-95 50-103-20854-00-00 223-035-0 W SPT 7541 2230350 1885 1102 1102 1102 1100 147 162 163 163 INITAL P Austin McLeod 8/19/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:GMTU MT7-95 Inspection Date: Tubing OA Packer Depth 445 2180 2140 2130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230820161118 BBL Pumped:5 BBL Returned:5 Friday, October 13, 2023 Page 1 of 1 PTD: 223-035 T37882 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.28 14:16:57 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-07-03_22104_GMTU_MT7-95_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22104 GMTU MT7-95 50-103-20854-00 Caliper Survey w/ Log Data 03-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 223-035 T37807 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.06 13:07:59 -08'00' a2 3- 03 5-- I bSo TO: AOGCC 333 WEST 7TH SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: MT7-95 3780-24803 6 Boxes SENT BY: M. McCRACKEN RECEIVED JUN 3 0 2023 SAMPLE TRANSMITTAL AO V CC DATE: 06/30/2023 AIR BILL: NIA CPAI: CPAI2023063001 CHARGE CODE: N/A e15 NAME: MT74S NUMBER OF BOXES: 6 Boxes UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN:MIKE McCRACKEN Mike.mccracken@conocophillips.com 1�2)-gDNkS�-fs123 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:3073' FSL, 4779' FWL S31 T10N R2E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 100.6 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"L-80 120'10yards 13 3/8"L-80 3037' 9 5/8"T-95 7458' 7"L-80 8173' 4 1/2"P110 8482' 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 N/A Oil-Bbl:Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: Flow Tubing If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner: 9808'MD/7541' TVD - 23257'MD/8482'TVD 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 GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, 37' 39' Per 20 AAC 25.283 (i)(2) attach electronic information 47 11032' 37' 7324' 94 68 120' 37'9700' SIZE DEPTH SET (MD)PACKER SET (MD/TVD) 9808' 42" 12.6 5915881 Greater Mooses Tooth/Rendevous Pool AA081780 932535000, 932516000 37' 29 39' 9532' 3742' 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 287774 293576 CEMENTING RECORD 5917957 983'MD/982'TVD SETTING DEPTH TVD 5905735 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 6/4/2023 223-035 50-103-20854-00-00 GMT/MT7-95 5/3/2023 24803'MD/8461'TVD N/A 139.8 P.O.Box 100360, Anchorage, AK 99510-0360 290115 1063' FSL, 2035' FWL S32 T10N R2E 1576' FSL, 464' FWL S9 T9N R2E 5/27/2023 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, Tail: 62bbl 15.8ppg Class G 8.5"x9 7/8" TUBING RECORD 23257' Lead: 135bbl 13ppg Class G Tail: 79bbl 15.8ppg Class G 7541 12 1/4" 6 1/8" 9816'4.5 9770'MD/7513'TVD 9808'MD/7541'TVD BOTTOM 16"Lead: 417bbl 11ppg Class G Tail: 71bbl 15.8ppg Class G CASING G s d 1b 0 D p op and B om; Per L s (att Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 10:25 am, Jun 27, 2023 Completed 6/4/2023 JSB RBDMS JSB 062923 mudlogs 5/31/2023 G DSR-7/19/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 983 982 C-30 1432 1419 2086 1997 3673 2998 K-2 4260 3335 Albian 97 4719 3597 Albian 96 5064 3794 HRZ 9710 7467 Kalubik 9795 7532 Kuparuk C 9834 7561 9835 7562 11264 8227 24803 8461 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: Brad Gorham Digital Signature with Date: Contact Phone:907-265-6487 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: brad.gorham@conocophillips.com Authorized Title: Drilling Engineer K-3 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. Formation Name at TD: Alpine D 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 N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Tubing / Liner Completion: 1) 4-½” Landing Nipple (3.813" ID) 2) 4-½” x 1” GLM KBG 4-5 (3x) 3) HES Downhole Gauge 4) Production Packer 5) 4-½” Landing Nipple (3.75" ID) 6) Liner Top Packer / Hanger w/ Tie Back sleeve 7) Recloseable Frac Sleeve / Swell Packers 4-½” 12.6# L80 H563 Liner (Set @ Approx. 23,256’MD/8482'TVD) AU dart-drop recloseable sliding sleeves spaced evenly throughout lateral & isolated by swell packers Liner Top Packer @9,808' MD / 7541' TVD Int1 TOC ~6,000' MD / ~4,331' TVD MT7-95 4-String Northern Combined Lateral Injector Proposed Schematic 20" 94 ppf H-40 Insulated Conductor 120 feet, cemented to surface 16" Surface Hole Surface Casing 13-3/8" 68# L80 H563 Set at 3,742' MD / 3'037 TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8 9-5/8" 47# T95 H563 Set @ +/- 9,699' MD / 7,458' TVD Top Confining Zone 9,672' MD / 7,436' TVD Top Alpine D 11,001' MD / 8,167' TVD Top Alpine C 11,264' MD / 8,226' TVD 6-1/8” Production Hole TD at 24,803' MD / 8,460' TVD Int2 TOC 627ft TVD above Alpine D ~9,806' MD / ~7,540' TVD 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7" 29# L80 H563 Liner top at +/- 9,532' MD / 7,324' TVD Shoe set @ +/- 11,032' MD / 8,173' TVD GL X GL DHG GL Tubing 4-1/2" 12.6# L80 H563 Injection Packer @ 9778'MD / 7519' TVD Page 1/44 MT7-95 Report Printed: 6/19/2023 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) 5/1/2023 06:00 5/1/2023 08:00 2.00 MIRU, MOVE RURD P Prep Derrick to scop down, Install Yokes, Raise top drive and install sheave pins, Prep to lower cattle shute. 0.0 0.0 5/1/2023 08:00 5/1/2023 09:00 1.00 MIRU, MOVE RURD P Scop down derrick and pin top drive, Remove drill line, Lower cattle chute, Support energy track in derrick. 0.0 0.0 5/1/2023 09:00 5/1/2023 10:00 1.00 MIRU, MOVE RURD P Swap to moving generators, Blow down steam system, Raise C section, Un plug enter connections, Prep to skid rig. 0.0 0.0 5/1/2023 10:00 5/1/2023 12:00 2.00 MIRU, MOVE RURD P PJSM, Skid rig floor and lower derrick, Stump motor complex from pump complex. 0.0 0.0 5/1/2023 12:00 5/1/2023 15:00 3.00 MIRU, MOVE MOB P Stomp Pump, pit and pipe shed away from Sub. 0.0 0.0 5/1/2023 15:00 5/1/2023 18:00 3.00 MIRU, MOVE MOB P Stomp sub over and center onto MT7-95 well, continue stopm pipe shed, pits, and pump complex to sub. 0.0 0.0 5/1/2023 18:00 5/1/2023 21:00 3.00 MIRU, MOVE MOB P Shim and pin pipe shed to sub. Spot pump and pit complex. 0.0 0.0 5/1/2023 21:00 5/2/2023 00:00 3.00 MIRU, MOVE RURD P Stomp and spot motor complex, Hook up interconnections. Raise derrick and skid to drilling position. Raise cattle shute and lower C section. 0.0 0.0 5/2/2023 00:00 5/2/2023 01:00 1.00 MIRU, MOVE RURD P Install cattle shute hatches, 0.0 0.0 5/2/2023 01:00 5/2/2023 02:00 1.00 MIRU, MOVE RURD P Stomp and set motor complex, M/U electrical innerconnect. Energize steam on rig floor. 0.0 0.0 5/2/2023 02:00 5/2/2023 05:30 3.50 MIRU, MOVE RURD P Continue electrical innerconnect, water, cement, air. Lower cellar amd install conductor valves. 0.0 0.0 5/2/2023 05:30 5/2/2023 06:30 1.00 MIRU, MOVE RURD P Swap from moving generators to main generators. Spool drill line onto drum, Unpin topdrive/block, Install yokes and bridle lines, Pin sheaves. 0.0 0.0 5/2/2023 06:30 5/2/2023 08:00 1.50 MIRU, MOVE RURD P Scope up derrick. Prep rig acceptance checklist. 0.0 0.0 5/2/2023 08:00 5/2/2023 09:00 1.00 MIRU, MOVE RURD P Install 50' slings on top drive, float out 21-1/4" annular, P/U and float in new 21 -1/4" annular and secure in place. Accept rig at 0900hrs 5-2-23 0.0 0.0 5/2/2023 09:00 5/2/2023 12:00 3.00 MIRU, MOVE NUND P N/U 10' and 17' 21-1/4" risers. 0.0 0.0 5/2/2023 12:00 5/2/2023 17:00 5.00 MIRU, MOVE NUND P N/U air boot flange on 21-1/4" risers, Slide Joe's box into p lace, M/U flow line and install riser nipple, Chink up Joe's box. Calibrate Block. SIMOPS: Install mouse holes, Working on #3 shacker scalper deck, Load 5" drill pipe in shed. 0.0 0.0 5/2/2023 17:00 5/2/2023 19:00 2.00 MIRU, MOVE BHAH P P/U and rack back 5" HWT 0.0 0.0 5/2/2023 19:00 5/2/2023 20:00 1.00 MIRU, MOVE PRTS P Prime pumps and surface equipment. Test equipment to 3500psi. (good test) 0.0 0.0 5/2/2023 20:00 5/2/2023 20:30 0.50 MIRU, MOVE BHAH P PJSM for P/U BHA #1. 0.0 0.0 5/2/2023 20:30 5/2/2023 21:00 0.50 MIRU, MOVE SVRG P Service SUB HPU system. 0.0 0.0 5/2/2023 21:00 5/2/2023 22:00 1.00 MIRU, MOVE BHAH P P/U 16" BHA to 65' MD. 0.0 65.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 2/44 MT7-95 Report Printed: 6/19/2023 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) 5/2/2023 22:00 5/2/2023 23:00 1.00 MIRU, MOVE WASH P Fill conductor with 32bbls, Wash in hole from 65' MD to 120' MD, Tagged at 102' MD. 65.0 120.0 5/2/2023 23:00 5/3/2023 00:00 1.00 MIRU, MOVE DDRL P Drill 16" surface hole section from 120' MD to 245' MD. GPM: 575 PSI: 660 RPM: 40 TRQ: 3k WOB: 6k F/O: 31% 120.0 245.0 5/3/2023 00:00 5/3/2023 01:00 1.00 MIRU, MOVE BKRM P BROOH from 245' MD to 50' MD. GPM: 572 PSI: 558 RPM: 40 TRQ: 3k PU: 58k SO: 62k ROT: 54k 245.0 50.0 5/3/2023 01:00 5/3/2023 04:00 3.00 MIRU, MOVE BHAH P Continue P/U surface 16" BHA #1 50.0 243.0 5/3/2023 04:00 5/3/2023 04:30 0.50 MIRU, MOVE CIRC P Tag bottom at 245' MD, Gyro survey. 243.0 245.0 5/3/2023 04:30 5/3/2023 12:00 7.50 SURFAC, DRILL DDRL P Drill 16" surface hole section from 245' MD to 753' MD. GPM: 672 PSI: 1360 RPM: 60 TRQ: 4k WOB: 9k F/O: 56% ECD: 11.6ppg PU: 87k SO: 82k ROT: 85k AST: 0.90hrs ART: 3.0hrs TBH: 5.6hrs TJH: 0.5hrs 245.0 753.0 5/3/2023 12:00 5/3/2023 16:00 4.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 753' MD to 1080' MD. GPM: 725 PSI: 1850 RPM: 60 TRQ: 6k WOB: 10k F/O: 33% ECD: 11.5ppg PU: 91k SO: 84k ROT: 88k AST: 1.0hrs ART: 1.8hrs TBH: 8.4hrs TJH: 3.4hrs 753.0 1,080.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 3/44 MT7-95 Report Printed: 6/19/2023 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) 5/3/2023 16:00 5/3/2023 19:45 3.75 SURFAC, DRILL CIRC T Circulate at 1080' MD, Clean out cuttings pit packoff. GPM:400 PSI: 550 RPM: 20 TRQ: 1k SIMOPS: Clear cuttings pit. 1,080.0 1,080.0 5/3/2023 19:45 5/3/2023 23:00 3.25 SURFAC, DRILL DDRL P Drill 16" surface hole section from 1080' MD to 1365' MD. GPM: 800 PSI: 1850 RPM: 60 TRQ: 8k WOB: 10k F/O: 33% ECD: 11.5ppg PU: 91k SO: 84k ROT: 88k AST: 1.2hrs ART: 1.5hrs TBH: 11.1hrs TJH: 6.1hrs 1,080.0 1,365.0 5/3/2023 23:00 5/3/2023 23:30 0.50 SURFAC, DRILL SVRG P Service top drive and mud pump suction screens. SIMOPS: Ball Mill centrifugal packed off. Manage cutting tanks 1,365.0 1,365.0 5/3/2023 23:30 5/4/2023 00:00 0.50 SURFAC, DRILL CIRC T Circulate at 1362' MD while managing cuttings. Unable to keep up with one super sucker. Two of the three trucks in for repairs. 1,365.0 1,365.0 5/4/2023 00:00 5/4/2023 06:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 1,365' MD to 1,877' MD 1,822' TVD. GPM: 800 PSI: 2080 RPM: 60 TRQ: 7k WOB: 9k F/O: 61% ECD: 11.5ppg PU: 91k SO: 84k ROT: 88k AST: 2.1hrs ART: 2.1hrs TBH: 15.3hrs TJH: 10.2hrs 1,365.0 1,877.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 4/44 MT7-95 Report Printed: 6/19/2023 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) 5/4/2023 06:00 5/4/2023 12:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 1,877' MD to 2,440' MD 2,265' TVD. GPM: 800 PSI: 2530 RPM: 60 TRQ: 7k WOB: 12k F/O: 61% ECD: 11.5ppg PU: 91k SO: 84k ROT: 88k AST: 2.1hrs ART: 2.3hrs TBH: 19.7hrs TJH: 14.6hrs 1,877.0 2,440.0 5/4/2023 12:00 5/4/2023 18:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 2,265' MD to 3,153' MD 2,700' TVD. GPM: 800 PSI: 2800 RPM: 60 TRQ: 7k WOB: 15k F/O: 61% ECD: 11.6ppg PU: 91k SO: 84k ROT: 88k AST: 1.1hrs ART: 4.1hrs TBH: 24.9hrs TJH: 19.8hrs 2,440.0 3,153.0 5/4/2023 18:00 5/5/2023 00:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 3,153' MD to 3,719' MD 3,023' TVD. GPM: 800 PSI: 3000 RPM: 60 TRQ: 10k WOB: 25k F/O: 61% ECD: 11.7ppg PU: 91k SO: 84k ROT: 88k AST: 0.3hrs ART: 3.8hrs TBH: 29.0hrs TJH: 24.0hrs 3,153.0 3,719.0 5/5/2023 00:00 5/5/2023 00:30 0.50 SURFAC, DRILL DDRL P Drill 16" surface hole section from 3,719' MD to 3,752' MD 3,043' TVD. GPM: 800 PSI: 3000 RPM: 60 TRQ: 9k WOB: 16k F/O: 66% ECD: 11.7ppg ROT: 105k AST: 0.0hrs ART: 0.4hrs TBH: 29.4hrs TJH: 24.4hrs 3,719.0 3,752.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 5/44 MT7-95 Report Printed: 6/19/2023 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) 5/5/2023 00:30 5/5/2023 02:30 2.00 SURFAC, TRIPCAS CIRC P OWFF (Static), Circulate and Condition mud, pump 40bbls Lo-Vis NP sweeps and BROOH one stand/BTM's up from 3,752' MD to 3,625' MD. GPM: 900 PSI: 2780 RPM: 60 TRQ: 9k 3,752.0 3,625.0 5/5/2023 02:30 5/5/2023 14:00 11.50 SURFAC, TRIPCAS BKRM P BROOH from 3,625' MD to 608' MD. Speed 400-700'/hr. Pumped 40bbls Lo- Vis sweeps at 1700' MD and 1000' MD. Minor increase cuttings returned. GPM: 900 PSI: 2430 RPM: 90 TRQ: 6k ECD: 11.8ppg 1) Pack off at 3,453' MD, ECD spike to 14.7ppg. 2) Flow line and shakers packed off at 3,380' MD 3) Overpull observed at 608' MD 31k 3,625.0 608.0 5/5/2023 14:00 5/5/2023 14:30 0.50 SURFAC, TRIPCAS OWFF P OWFF Static) Blow down top drive. 608.0 608.0 5/5/2023 14:30 5/5/2023 15:00 0.50 SURFAC, TRIPCAS TRIP P POOH from 608' MD to 240' MD. 608.0 240.0 5/5/2023 15:00 5/5/2023 18:30 3.50 SURFAC, TRIPCAS BHAH P POOH and L/D #1 16" surface BHA. 240.0 0.0 5/5/2023 18:30 5/5/2023 19:30 1.00 SURFAC, TRIPCAS CLEN P Clean and clear surface tools from rig floor. 0.0 0.0 5/5/2023 19:30 5/5/2023 21:00 1.50 SURFAC, CASING RURD P R/U Volant and 13-3/8" casing running tools. 0.0 0.0 5/5/2023 21:00 5/5/2023 21:45 0.75 SURFAC, CASING PUTB P P/U 13-3/8" 68ppf L-80 H563 shoe track thread lock same. Circulate shoe track (all good) 0.0 133.0 5/5/2023 21:45 5/6/2023 00:00 2.25 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 133' MD to 608' MD. 133.0 608.0 5/6/2023 00:00 5/6/2023 01:30 1.50 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 608' MD to 1076' MD. Worked through tight spots at 423' MD and 567' MD. 608.0 1,076.0 5/6/2023 01:30 5/6/2023 02:00 0.50 SURFAC, CASING CIRC P Circulate and stage pumps up to 8bpm, CBU at 1,076' MD. GPM: 336 PSI: 116 1,076.0 1,076.0 5/6/2023 02:00 5/6/2023 05:00 3.00 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 1078' MD to 2,193' MD. Tagged up and attempt to work through without sucess. 1,076.0 2,193.0 5/6/2023 05:00 5/6/2023 06:00 1.00 SURFAC, CASING WASH P Break circulation at 120gpm 150psi work through from 2,193' MD to 2,210' MD, Continue wash to 2,270' MD for safety. GPM: 120 PSI: 150 PU: 185k SO: 145k 2,193.0 2,270.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 6/44 MT7-95 Report Printed: 6/19/2023 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) 5/6/2023 06:00 5/6/2023 06:30 0.50 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 2,270' MD to 2,401' MD. Tagged up and attempt to work through without sucess. 2,270.0 2,401.0 5/6/2023 06:30 5/6/2023 07:30 1.00 SURFAC, CASING WASH P Break circulation at 120gpm 150psi work through from 2,401' MD to 2,441' MD, Continue wash to 2,283' MD for safety. GPM: 120 PSI: 100 PU: 190k SO: 150k 2,401.0 2,483.0 5/6/2023 07:30 5/6/2023 11:00 3.50 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 2,483' MD to 3,692' MD. PU: 232k SO: 172k 2,483.0 3,692.0 5/6/2023 11:00 5/6/2023 12:00 1.00 SURFAC, CASING HOSO P M/U FMC hanger. Break circulation at 120gpm 134psi and land hanger with 172k. 3,692.0 3,742.0 5/6/2023 12:00 5/6/2023 13:30 1.50 SURFAC, CEMENT CIRC P Stage pumps up to 8 BPM. Circulate and condition mud. Reciprocating casing 5/10'. GPM: 336 PSI: 200 PU: 232k SO: 172k 3,742.0 3,742.0 5/6/2023 13:30 5/6/2023 18:30 5.00 SURFAC, CEMENT CMNT P Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4.0 bbls/min, 354 psi, Dropped bottom plug. Start batching lead. Pump 417 bbls of 11.0 ppg DeepCRETE cement at 4.8 bbls/min, 450 psi ICP. Batch and pump 70 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 290 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 231 psi ICP, 515 psi FCP. Slow pumps 20 bbls prior to calculated bump to 3 bbls/min, 336 psi ICP, Bump plug with 850 psi (531 bbls + 20 bbls). 4493 strokes, final circ. PSI 350 Pressure up to 850 psi & hold for 5 minutes. Bleed off pressure, Check floats good (7.3bbls pumped, 6.4bbls returned). 165 bbls cement to surface. Cement in place @ 18:00hrs 05/06/23 3,742.0 3,742.0 5/6/2023 18:30 5/6/2023 19:30 1.00 SURFAC, CEMENT PRTS P Pressure test 13-3/8" casing to 3500psi 30min (good test) pumped 7.3bbls, 6.4bbls returned. 3,742.0 3,742.0 5/6/2023 19:30 5/6/2023 21:00 1.50 SURFAC, CEMENT RURD P R/D test equipment and blow down lines. R/D Volant, Pump out riser and L/D landing joint. Flush surface equipment with black water. 0.0 0.0 5/6/2023 21:00 5/7/2023 00:00 3.00 SURFAC, CEMENT NUND P R/D surface lines and pull master bushings. Pull bell nipple, move Joes box, N/D and remove risers. 0.0 0.0 5/7/2023 00:00 5/7/2023 01:30 1.50 SURFAC, WHDBOP OTHR P NU and orientate WH. Test seals to 1000psi (CPAI witnessed) 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 7/44 MT7-95 Report Printed: 6/19/2023 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) 5/7/2023 01:30 5/7/2023 07:00 5.50 SURFAC, WHDBOP NUND P Nipple up drilling riser & BOPE SIMOPS - Clean pits, slide Joe's box, install flow line, choke & kill lines, N/U MPD equipment. 0.0 0.0 5/7/2023 07:00 5/7/2023 09:30 2.50 SURFAC, WHDBOP PRTS P Set test plug and install MPD test cap, Attempt to test, trouble shoot leak, Change o-ring on test cap, test to 250/1250psi 5/10min. 0.0 0.0 5/7/2023 09:30 5/7/2023 10:00 0.50 SURFAC, WHDBOP RURD P M/U 9-5/8" test jointm purge air from system. 0.0 0.0 5/7/2023 10:00 5/7/2023 17:00 7.00 SURFAC, WHDBOP BOPE P Test BOPE all test T/ 250 low for 5 min and 5,000 high for 10 min charted. W/ exception of annular T/ 250 low for 5 min and 3,500 high for 10 min. Manual operated & super choke tested T/2,000 psi charted, W/ 9-5/8" test JT test annular, 9-5/8" UPR, Test choke valves 1-15, manual operated & super choke, Choke & kill manuals, HCR's, 4" valves on kill line, 5" FOSV, 5" Dart valve, Upper and lower IBOP on TD; Blind/shear rams; Perform KOOMEY drawdown, ACC = 3000 PSI. MANIF. = 1650 PSI. ACC = 1650 PSI After all functions on bottles, 19 sec for 200 psi. Build W/ 2 Elec. pumps, 97 sec T/ Build full system. Pressure W/ 2 Elec. & 2 Air pumps, Closing times, Annular = 19 sec. UPR = 16 sec. Blind / Shears = 14 sec. LPR = 14 sec. Choke HCR = 2 Ssec. Kill HCR = 2 sec; Test PVT G/L and flow out alarms, Test LEL and H2S alarms. Waived Witness by AOGCC Austin McLeod 5-4-23 @ 1923hrs. Waived Witness by BLM Quinn Sawyer 5-5-23 @ 16:50hrs. 0.0 0.0 5/7/2023 17:00 5/7/2023 18:00 1.00 SURFAC, WHDBOP RURD P R/D test equipment, Blow down test and surface equipment. 0.0 0.0 5/7/2023 18:00 5/7/2023 18:30 0.50 SURFAC, WHDBOP OTHR P M/U and set 12.375" wear ring. 0.0 0.0 5/7/2023 18:30 5/7/2023 20:00 1.50 SURFAC, WHDBOP SLPC P Cut and slip 71' dril line, calibrate rig systems. 0.0 0.0 5/7/2023 20:00 5/7/2023 23:00 3.00 SURFAC, DRILLOUT BHAH P PJSM, P/U Baker 12-1/4" BHA #2 0.0 46.0 5/7/2023 23:00 5/8/2023 00:00 1.00 SURFAC, DRILLOUT BHAH P Trouble shoot LWD tools, Conection issues. 46.0 46.0 5/8/2023 00:00 5/8/2023 01:30 1.50 SURFAC, DRILLOUT BHAH T Trouble shoot LWD tools, Conection issues. Surface test (all good) 46.0 46.0 5/8/2023 01:30 5/8/2023 04:00 2.50 SURFAC, DRILLOUT BHAH P Continue P/U BHA to 668' MD. 46.0 668.0 5/8/2023 04:00 5/8/2023 06:00 2.00 SURFAC, DRILLOUT TRIP P Trip in hole with BHA #2 from 668' MD to 3,400' MD. 668.0 3,400.0 5/8/2023 06:00 5/8/2023 06:30 0.50 SURFAC, DRILLOUT CIRC P Take SCR at 3,6400' MD. Perform choke drill with crews. 3,400.0 3,400.0 5/8/2023 06:30 5/8/2023 07:30 1.00 SURFAC, DRILLOUT WASH P Wash in hole to 3,643' MD. tagged cement. GPM: 120 PSI: 165 PU: 145k SO: 105k 3,400.0 3,643.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 8/44 MT7-95 Report Printed: 6/19/2023 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) 5/8/2023 07:30 5/8/2023 09:00 1.50 SURFAC, DRILLOUT DRLG P Drill shoe track and clean out rat hole to 3,752' MD. GPM: 700 PSI: 1600 RPM: 80 TRQ: 12k PU: 140k SO: 100k ROT: 120k 3,400.0 3,752.0 5/8/2023 09:00 5/8/2023 09:30 0.50 SURFAC, DRILLOUT DDRL P Drill 12-1/4" hole from 3,752' MD to 3,772' MD 3,055' TVD. WOB: 10k GPM: 700 PSI: 1580 MW: 11.0ppg ECD: 11.3ppg RPM: 80 TQ on: 12k ft/lbs F/O: 34% PU: 140k SO: 100k ROT: 120k ADT: 0.4hrs TBH: 0.4 TJH: 29.8 3,752.0 3,772.0 5/8/2023 09:30 5/8/2023 10:00 0.50 SURFAC, DRILLOUT CIRC P Circulate BTM's up at 3,772' MD. GPM: 700 PSI: 1600 3,772.0 3,742.0 5/8/2023 10:00 5/8/2023 11:00 1.00 SURFAC, DRILLOUT LOT P Perform LOT at 3,742' MD 3,042' TVD 911psi EMW 16.8ppg pumped 2.5bbls 1.0bbls returned. 3,742.0 3,742.0 5/8/2023 11:00 5/8/2023 12:00 1.00 SURFAC, DRILLOUT WASH P T&D and wash to 3,772' MD. GPM: 900 PSI: 2400 RPM: 80 TRQ: 13k 3,742.0 3,772.0 5/8/2023 12:00 5/8/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 3,772' MD to 4,320' MD 3,370' TVD. WOB: 14k GPM: 1000 PSI: 1950 MW: 11.0ppg ECD: 11.7ppg RPM: 150 TQ on: 7k ft/lbs TQ off: 6k ft/lbs F/O: 65% PU: 130k SO: 122k ROT: 129k ADT: 4.2hrs TBH: 4.6 TJH: 34 3,772.0 4,320.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 9/44 MT7-95 Report Printed: 6/19/2023 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) 5/8/2023 18:00 5/9/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4,320' MD to 4,930' MD 3,718' TVD. WOB: 16k GPM: 1000 PSI: 2750 MW: 11.0ppg ECD: 11.8ppg RPM: 150 TQ on: 8k ft/lbs TQ off: 6k ft/lbs F/O: 50% PU: 136k SO: 127k ROT: 1128k ADT: 4.4hrs TBH: 9.0 TJH: 38.4 4,320.0 4,930.0 5/9/2023 00:00 5/9/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4,930' MD to 5,616' MD 4,110' TVD. WOB: 17k GPM: 1040 PSI: 3000 MW: 11.0ppg ECD: 11.9ppg RPM: 150 TQ on: 10k ft/lbs TQ off: 5k ft/lbs F/O: 52% PU: 154k SO: 132k ROT: 128k ADT: 4.7hrs TBH: 13.7 TJH: 43.1 4,930.0 5,616.0 5/9/2023 06:00 5/9/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5,616' MD to 6,276' MD 4,490' TVD. WOB: 21k GPM: 1040 PSI: 3160 MW: 11.0ppg ECD: 11.8ppg RPM: 150 TQ on: 11k ft/lbs TQ off: 5k ft/lbs F/O: 52% PU: 159k SO: 127k ROT: 137k ADT: 4.5hrs TBH: 18.2 TJH: 47.6 5,616.0 6,276.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 10/44 MT7-95 Report Printed: 6/19/2023 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) 5/9/2023 12:00 5/9/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 6,276' MD to 6,885' MD 4,900' TVD. WOB: 17k GPM: 1040 PSI: 3440 MW: 11.0ppg ECD: 11.8ppg RPM: 150 TQ on: 12k ft/lbs TQ off: 7k ft/lbs F/O: 53% PU: 177k SO: 150k ROT: 150k ADT: 4.4hrs TBH: 22.6 TJH: 52 6,276.0 6,885.0 5/9/2023 18:00 5/10/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 6,885' MD to 7360' MD 5295' TVD. WOB: 21k GPM: 1040 PSI: 3540 MW: 11.0ppg ECD: 11.9ppg RPM: 150 TQ on: 11k ft/lbs TQ off: 7k ft/lbs F/O: 52% PU: 181k SO: 158k ROT: 162k ADT: 4.7hrs TBH: 27.3 TJH: 56.7 6,885.0 7,360.0 5/10/2023 00:00 5/10/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 7,360' MD to 7,837' MD 5,295' TVD. WOB: 25k GPM: 1040 PSI: 3642 MW: 11.0ppg ECD: 11.8ppg RPM: 150 TQ on: 13k ft/lbs TQ off: 8k ft/lbs F/O: 52% PU: 209k SO: 167k ROT: 175k ADT: 5.0hrs TBH: 32.3 TJH: 61.7 7,360.0 7,837.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 11/44 MT7-95 Report Printed: 6/19/2023 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) 5/10/2023 06:00 5/10/2023 11:00 5.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 7,837' MD to 8,239' MD 6,129' TVD. WOB: 22k GPM: 963 PSI: 3970 MW: 12.0ppg ECD: 12.7ppg RPM: 150 TQ on: 17k ft/lbs TQ off: 10k ft/lbs F/O: 49% PU: 218k SO: 170k ROT: 179k ADT: 4.3hrs TBH: 36.6 TJH: 66 7,837.0 8,239.0 5/10/2023 11:00 5/10/2023 12:00 1.00 INTRM1, DRILL CIRC T Lost total returns at 8239' MD. (No torque or pack off observed) Reduce rotary and P/U off botton, reduce pump rate to 1bpm and top fill backside (232bbls) 8,239.0 8,200.0 5/10/2023 12:00 5/10/2023 14:30 2.50 INTRM1, DRILL CIRC T Circulate and regain returns (~155bph) 42gpm 135psi, cut mud weight back from 12.0ppg to 11.0ppg staging up pumps to 165gpm 560psi. Adding 2ppb background LCM. 8,200.0 8,200.0 5/10/2023 14:30 5/10/2023 16:00 1.50 INTRM1, DRILL BKRM T BROOH from 8,200' MD to 7,923' MD GPM: 120 PSI: 630 RPM: 15 TRQ: 9k PU: 180k 8,200.0 7,923.0 5/10/2023 16:00 5/10/2023 18:00 2.00 INTRM1, DRILL CIRC T Continue circulate and stage pumps up to drilling rate. Stop adding background LCM. GPM: 1000 PSI: 3500 ECD: 12.2ppg RPM: 60 TRQ: 9k 7,923.0 7,923.0 5/10/2023 18:00 5/10/2023 18:30 0.50 INTRM1, DRILL REAM T Wash and ream in hole from 7,923' MD to 8,239' MD. (no losses) GPM: 1000 PSI: 3500 ECD: 12.2ppg RPM: 60 TRQ: 9k 7,923.0 8,239.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 12/44 MT7-95 Report Printed: 6/19/2023 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) 5/10/2023 18:30 5/11/2023 00:00 5.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8,239' MD to 8,625' MD 6,505' TVD. Max gas 645 units @ 8,251' MD. Increase of resistivity at ~ 8,230' MD to 8,269' MD. WOB: 17k GPM: 1040 PSI: 3690 MW: 11.1ppg ECD: 11.8ppg RPM: 150 TQ on: 16k ft/lbs TQ off: 12k ft/lbs F/O: 51% PU: 238k SO: 1167k ROT: 183k ADT: 3.7hrs TBH: 40.3 TJH: 69.7 8,239.0 8,625.0 5/11/2023 00:00 5/11/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8,625' MD to 9,161' MD 7,007' TVD. WOB: 30k GPM: 1020 PSI: 3600 MW: 11.0ppg ECD: 11.7ppg RPM: 150 TQ on: 19k ft/lbs TQ off: 13k ft/lbs F/O: 52% PU: 276k SO: 165k ROT: 204k ADT: 4.7hrs TBH: 45 TJH: 74.4 8,625.0 9,161.0 5/11/2023 06:00 5/11/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,161' MD to 9,707' MD 7,464' TVD. TD of hole section WOB: 20k GPM: 1003 PSI: 3791 MW: 11.0ppg ECD: 11.8ppg RPM: 150 TQ on: 20k ft/lbs TQ off: 17k ft/lbs F/O: 52% PU: 305k SO: 170k ROT: 208k ADT: 4.8hrs TBH: 49.8 TJH: 79.2 9,161.0 9,707.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 13/44 MT7-95 Report Printed: 6/19/2023 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) 5/11/2023 12:00 5/11/2023 17:30 5.50 INTRM1, TRIPCAS BKRM P Final survey at 9.707' MD, BROOH from 9,707' MD to 8,296' MD. GPM: 1000 PSI: 3550 RPM: 120 TRQ: 12k ECD: 11.9ppg 9,707.0 8,296.0 5/11/2023 17:30 5/11/2023 20:00 2.50 INTRM1, TRIPCAS BKRM P BROOH while circulate BTM's while racking back 1 stand/BTM's up. from 8,296' MD to 8,014' MD. GPM: 1040 PSI: 3500 RPM: 120 TRQ: 12k ECD: 11.9ppg 8,296.0 8,014.0 5/11/2023 20:00 5/12/2023 00:00 4.00 INTRM1, TRIPCAS BKRM P OWFF (static) continue BROOH from 8,014' MD to 6,980' MD at 400-600'/hr. GPM: 1000 PSI: 2900 RPM: 120 TRQ: 11k ECD: 11.7ppg 8,014.0 6,980.0 5/12/2023 00:00 5/12/2023 12:30 12.50 INTRM1, TRIPCAS BKRM P BROOH from 6,980' MD to 3,872' MD at 400-600'/hr. Shakers loading up at 6,800' MD. Pumped 20bbls sweep at 5,865' MD, 5,399' MD, 4,808' MD and 4,151' MD (50% increase in cuttings returned) No drag entering shoe GPM: 1000 PSI: 2450 RPM: 120 TRQ: 10k ECD: 11.7ppg 6,980.0 3,742.0 5/12/2023 12:30 5/12/2023 13:30 1.00 INTRM1, TRIPCAS CIRC P Pump 40bbls sweep Circulate 2 BTM's up. (50% increase in cuttings returned) GPM: 1000 PSI: 2450 RPM: 40 TRQ: 10k ECD: 11.7ppg 3,742.0 3,742.0 5/12/2023 13:30 5/12/2023 17:00 3.50 INTRM1, TRIPCAS TRIP P POOH from 3,742' MD to 668' MD. 3,742.0 668.0 5/12/2023 17:00 5/12/2023 17:30 0.50 INTRM1, TRIPCAS OWFF P OWFF (Slight drop) 668.0 668.0 5/12/2023 17:30 5/12/2023 18:00 0.50 INTRM1, TRIPCAS BHAH P POOH rack back BHA fro 668' to 300' MD 668.0 300.0 5/12/2023 18:00 5/13/2023 00:00 6.00 INTRM1, TRIPCAS BHAH P L/D Baker/Schlumberger Intermedate 1 BHA 300.0 0.0 5/13/2023 00:00 5/13/2023 01:00 1.00 INTRM1, CASING WWWH P Pull wear ring and jet BOP stack 0.0 0.0 5/13/2023 01:00 5/13/2023 02:30 1.50 INTRM1, CASING RURD P PJSM, R/U 9-5/8" casing equipment. 0.0 0.0 5/13/2023 02:30 5/13/2023 09:00 6.50 INTRM1, CASING PUTB P M/U shoe track, Circulate and check floats (Good) Continue run 9-5/8" 47# T95 H563 Casing to 3,718' MD 0.0 3,718.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 14/44 MT7-95 Report Printed: 6/19/2023 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) 5/13/2023 09:00 5/13/2023 10:00 1.00 INTRM1, CASING CIRC P Fill pipe, break circulation and stage pumps up to 336gpm 204psi. Full returns with no change in cutting on BTM's up. GPM: 336 PSI: 204 RPM: 20 TRQ: 8k PU: 164k SO: 152k ROT: 162 3,718.0 3,718.0 5/13/2023 10:00 5/13/2023 18:00 8.00 INTRM1, CASING PUTB P Continue running 9-5/8" 47# H563 casing from 3,742' MD to 8,135' MD. 3,718.0 8,135.0 5/13/2023 18:00 5/13/2023 19:00 1.00 INTRM1, CASING CIRC P Circulate at 8,135' MD, stage pumps up to 252gpm. GPM: 252 PSI: 300 PU: 310k SO: 226k 8,135.0 8,135.0 5/13/2023 19:00 5/13/2023 22:00 3.00 INTRM1, CASING PUTB P Continue running 9-5/8" 47# H563 casing from 8,135' MD to 9,657' MD. Set down 30k, Wash sting down to 9,670' MD at 1bpm 300psi. 8,119.0 9,670.0 5/13/2023 22:00 5/13/2023 23:00 1.00 INTRM1, CASING HOSO P PU hanger/LJ. MU and land casing @ 9,699' MD. washing down a 42gpm 300psi, Land hanger with 237k PU: 340k SO: 238k 9,670.0 9,699.0 5/13/2023 23:00 5/14/2023 00:00 1.00 INTRM1, CEMENT CIRC P Circulate and condition mud f/ cement job. Stage rates up from 1bpm to 4 BPM 361psi. Pop off released on mud pump #2 at 360psi, reset pop off and continue staging pumps up. 9,699.0 9,699.0 5/14/2023 00:00 5/14/2023 02:00 2.00 INTRM1, CEMENT CIRC P Circulate and condition mud f/ cement job. Stage rates up from 1bpm to 6 BPM 393psi. Blow down top drive 9,699.0 9,699.0 5/14/2023 02:00 5/14/2023 07:00 5.00 INTRM1, CEMENT CMNT P Blow down top drive, test lines to 3500psi (all ok) Mix and pump 60 bbls of 12.5 ppg Mud Push II @ 4.0 bbls/min, 464 psi, Dropped bottom plug. Start batching lead. Pump 135 bbls of 13.0 ppg Extended class G cement at 3.5 bbls/min, 375 psi ICP. Batch and pump 79 bbls of G Blend Tail 15.8 ppg cement @ 4.0 bbls/min, 500 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 6 bbls/min, 252 psi ICP, 950 psi FCP. Slow pumps 14 bbls prior to calculated bump to 3 bbls/min, 700 psi FCP, Plug didn't bump (697.3 bbls + 20 bbls water + 1.85bbls compression). 8264 strokes, final circ. 700 PSI. Bleed off pressure, Check floats good. Full returns. Cement in place @ 06:12hrs 5/14/23 full. Check floats (all good) BLM Quinn Sawyer witnessed cement job. 9,699.0 9,699.0 5/14/2023 07:00 5/14/2023 08:00 1.00 INTRM1, CEMENT RURD P Start R/D Volant and equipment, Observed slight flow out Volant, Make Volant back up and WOC. 9,699.0 9,699.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 15/44 MT7-95 Report Printed: 6/19/2023 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) 5/14/2023 08:00 5/14/2023 11:30 3.50 INTRM1, CEMENT WOC T WOC, Service break on top sub for next BHA, Stage BHA #3, cleanning pits, General rig cleanning. 9,699.0 9,699.0 5/14/2023 11:30 5/14/2023 13:30 2.00 INTRM1, CEMENT RURD P R/D volant and back out landing joint. Clear casing equipment from rig floor. 0.0 0.0 5/14/2023 13:30 5/14/2023 15:00 1.50 INTRM1, WHDBOP WWSP P Set pack off and test to 5000psi 10min. 0.0 0.0 5/14/2023 15:00 5/14/2023 17:00 2.00 INTRM1, WHDBOP RURD P Change out UPR to 4-1/2" X 7" VBR's. SIMOPS: adjust linktilt clamps on top drive. Blow down top drive and mud lines. 0.0 0.0 5/14/2023 17:00 5/14/2023 19:00 2.00 INTRM1, WHDBOP RURD P R/U to test upper pipe rams and Annular with 5" test joint. Change out test plug seal. 0.0 0.0 5/14/2023 19:00 5/14/2023 19:30 0.50 INTRM1, WHDBOP SVRG P Rig service, change out annular 4-way valve on koomey unit. 0.0 0.0 5/14/2023 19:30 5/14/2023 23:30 4.00 INTRM1, WHDBOP PRTS P Pressure test annular and UPR with 5" and 7" test joints 250/3500psi 5/10min. Trouble shoot intermitting surface leek. AOGCC Kam StJohn waived witness of BOP test 06:27hrs 5-11-23 BLM Quinn Sawyer verbal waived witness 5-14-23 0.0 0.0 5/14/2023 23:30 5/15/2023 00:00 0.50 INTRM1, WHDBOP RURD P R/D test equipment and set wear ring. 0.0 0.0 5/15/2023 00:00 5/15/2023 01:30 1.50 INTRM1, WHDBOP SLPC P Cut and slip 59' Drill line, calibrate pason and amphion. 0.0 0.0 5/15/2023 01:30 5/15/2023 05:30 4.00 INTRM1, DRILLOUT BHAH P P/U Baker 8-1/2" X 9-7/8" intermediate #3 BHA. 0.0 590.0 5/15/2023 05:30 5/15/2023 07:00 1.50 INTRM1, DRILLOUT TRIP P TIH with BHA #3 to 2,855' MD 590.0 2,855.0 5/15/2023 07:00 5/15/2023 07:30 0.50 INTRM1, DRILLOUT CIRC P Fill pipe and surface test MWD tools. (all good) GPM: 622 PSI: 2000 2,855.0 2,855.0 5/15/2023 07:30 5/15/2023 11:30 4.00 INTRM1, DRILLOUT TRIP P TIH with BHA #3 from 2,855' MD to 9,354' MD. Fill pipe every 25 stands 2,855.0 9,354.0 5/15/2023 11:30 5/15/2023 13:00 1.50 INTRM1, DRILLOUT WASH P Wash in hole from 9,354' MD to 9,537' MD. GPM: 600 PSI: 3700 P/U: 212k SO: 158k 9,354.0 9,540.0 5/15/2023 13:00 5/15/2023 14:00 1.00 INTRM1, DRILLOUT PRTS P Pressure test casing to 3500psi 30min Pumped/bled back 9bbls. (good test) 9,540.0 9,540.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 16/44 MT7-95 Report Printed: 6/19/2023 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) 5/15/2023 14:00 5/15/2023 18:30 4.50 INTRM1, DRILLOUT DRLG P Tagged cement at 9.540' MD, plugs at 9,584' MD, Drill cement, shoe track and clean out rat hole from 9,584' MD to 9,707' MD. GPM: 600 PSI: 3500 ECD: 12.2ppg WOB: 15k PU: 215k SO: 168k ROT: 198k RPM: 80 TRQ: 11k Freeze protect OA LOT 6bbls Diesel Water flush 335bbls LOT 6bbls Diesel Freeze protect 66bbls Diesel 9,540.0 9,707.0 5/15/2023 18:30 5/15/2023 19:00 0.50 INTRM1, DRILLOUT DDRL P Drill 8 1/2" Interm 2 hole from 9,707' MD to 9,727' MD 7,458' TVD. WOB: 10k GPM: 600 PSI: 3,500 ECD: 12.2ppg RPM: 80 TQ on: 11k ft/lbs TQ off: 9k ft/lbs F/O: 27% MW: 11.3 ppg PU: 215k SO: 168k ROT: 198k ADT: 0.4 hrs TBH: 0.4 hrs TJH: 50.2 hrs 9,707.0 9,727.0 5/15/2023 19:00 5/15/2023 20:00 1.00 INTRM1, DRILLOUT CIRC P Circulate and condition mud at 9,699' MD. Drift through shoe with no overpull noted. GPM: 600 PSI: 3550 ECD: 12.2ppg RPM: 80 TRQ: 10k 9,727.0 9,699.0 5/15/2023 20:00 5/15/2023 20:45 0.75 INTRM1, DRILLOUT FIT P Purge air from system with 11.3ppg mud, Pump 0.5bpm to 1080psi , hold 10min and bled off 3.0bbls pumped 2.9bbls returned. EMW 14.1ppg 9,699.0 9,699.0 5/15/2023 20:45 5/15/2023 21:00 0.25 INTRM1, DRILLOUT OWFF P OWFF (static) 9,699.0 9,699.0 5/15/2023 21:00 5/15/2023 21:30 0.50 INTRM1, DRILLOUT MPDA P Pull trip nipple and install 5" RCD. PU: 230k SO: 155k 9,699.0 9,699.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 17/44 MT7-95 Report Printed: 6/19/2023 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) 5/15/2023 21:30 5/15/2023 23:00 1.50 INTRM2, DRILL OTHR P NOVOS updated 5-14-23, set up and friction test at 9699' MD GPM: 100 PSI: 330 ROT: 20 TRQ: 11 PU: 217k SO: 181k ROT: 198k 9,699.0 9,699.0 5/15/2023 23:00 5/16/2023 00:00 1.00 INTRM2, DRILL DDRL P Drill 8 1/2" Interm 2 hole from 9,727' MD to 9,780' MD 7,520' TVD. WOB: 12k GPM: 600 PSI: 3,500 ECD: 12.2ppg RPM: 120 TQ on: 13k ft/lbs TQ off: 9k ft/lbs F/O: 27% MW: 11.3 ppg PU: 215k SO: 168k ROT: 195k ADT: 1.0 hrs TBH: 1.4 hrs TJH: 51.2 hrs 9,699.0 9,780.0 5/16/2023 00:00 5/16/2023 02:00 2.00 INTRM2, DRILL DDRL P Drill 8-1/2" Interm 2 hole from 9,780' MD to 9,857' MD 7,573' TVD. WOB: 15k GPM: 600 PSI: 3,440 ECD: 12.7ppg RPM: 120 TQ on: 16k ft/lbs TQ off: 12k ft/lbs F/O: 29% MW: 11.3 ppg PU: 220k SO: 162k ROT: 184k ADT: 1.6 hrs TBH: 2.3 hrs TJH: 52.1 hrs 9,780.0 9,857.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 18/44 MT7-95 Report Printed: 6/19/2023 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) 5/16/2023 02:00 5/16/2023 04:00 2.00 INTRM2, DRILL CIRC P Place bit at 9,842' MD (reamer 9,702' MD) Take base parameters f/ underreamer. Drop 1.25" Torlon ball. Pump down string. Pump down at 250 GPM for 500stks (slow down rate to 125gpm due to 1000psi max pressure) and reduce rate to 100 GPM. Ball landed at 1660stks. under reamer shift open at 1550psi. Check parameters to confirm under reamer open. Cut ledge from 9,707' MD to 9,712' MD ( bit 9,852' MD 5' from btm) Perform ledge test with 20k. Good test Base parameters: Turbine RPM: 4437 GPM: 600 3750 PSI: 3535 RPM 30 TRQ: 10k Post parameters: Turbine RPM: 3861 GPM: 600 PSI: 3160 RPM:30 TRQ: 11k 9,857.0 9,857.0 5/16/2023 04:00 5/16/2023 12:00 8.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 9,857' MD to 10,385' MD 7,914' TVD. WOB: 18k GPM: 650 PSI: 3,560 ECD: 12.8ppg RPM: 160 TQ on: 15k ft/lbs TQ off: 12k ft/lbs F/O: 29% MW: 11.5 ppg ROT: 184k ADT: 1.6 hrs TBH: 4.6 hrs TJH: 54.4 hrs 9,857.0 10,385.0 5/16/2023 12:00 5/16/2023 18:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,385' MD to 10,835' MD 8,115' TVD. WOB: 16k GPM: 650 PSI: 3,400 ECD: 12.7ppg RPM: 120 TQ on: 16k ft/lbs TQ off: 12k ft/lbs F/O: 29% MW: 11.4 ppg PU: 240k SO: 155k ROT: 187k ADT: 4.7 hrs TBH: 13.6 hrs TJH: 63.4 hrs 10,385.0 10,835.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 19/44 MT7-95 Report Printed: 6/19/2023 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) 5/16/2023 18:00 5/16/2023 19:00 1.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,835' MD to 10,866' MD 8,126' TVD. WOB: 15k GPM: 650 PSI: 3,385 ECD: 12.7ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg PU: 240k SO: 155k ROT: 187k 10,835.0 10,866.0 5/16/2023 19:00 5/16/2023 20:00 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 10,866' MD (For GEO data) GPM: 650 PSI: 3360 RPM:80 TRQ: 16 ROT: 188k 10,866.0 10,866.0 5/16/2023 20:00 5/16/2023 21:00 1.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,866' MD to 10,911' MD 8,140' TVD. WOB: 15k GPM: 650 PSI: 3,385 ECD: 12.7ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg PU: 240k SO: 155k ROT: 187k 10,866.0 10,911.0 5/16/2023 21:00 5/16/2023 22:00 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 10,911' MD (For GEO data) GPM: 650 PSI: 3340 RPM:80 TRQ: 16 ROT: 188k 10,911.0 10,911.0 5/16/2023 22:00 5/16/2023 22:30 0.50 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,911' MD to 10,927' MD 8,145' TVD. WOB: 15k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg PU: 240k SO: 155k ROT: 187k 10,911.0 10,927.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 20/44 MT7-95 Report Printed: 6/19/2023 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) 5/16/2023 22:30 5/16/2023 23:30 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 10,927' MD (For GEO data) GPM: 650 PSI: 3355 RPM:80 TRQ: 16 ROT: 188k 10,927.0 10,927.0 5/16/2023 23:30 5/17/2023 00:00 0.50 INTRM2, DRILL COND P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,927' MD to 10,942' MD 8,150' TVD. WOB: 17k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 31% MW: 11.5 ppg PU: 240k SO: 155k ROT: 187k Data below from 1800hrs to 2400hrs ADT: 2.5 hrs TBH: 16.1 hrs TJH: 65.9 hrs 10,927.0 10,942.0 5/17/2023 00:00 5/17/2023 01:00 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 10,942' MD (For GEO data) GPM: 650 PSI: 3360 RPM:80 TRQ: 16 ROT: 188k 10,942.0 10,942.0 5/17/2023 01:00 5/17/2023 02:00 1.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,942' MD to 10,963' MD 8,155' TVD. WOB: 15k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg ROT: 189k 10,942.0 10,963.0 5/17/2023 02:00 5/17/2023 03:00 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 10,963' MD (For GEO data) GPM: 650 PSI: 3370 RPM:80 TRQ: 16 ROT: 189k 10,963.0 10,963.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 21/44 MT7-95 Report Printed: 6/19/2023 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) 5/17/2023 03:00 5/17/2023 03:15 0.25 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,963' MD to 10,970' MD 8,158' TVD. WOB: 15k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg ROT: 189k 10,963.0 10,970.0 5/17/2023 03:15 5/17/2023 03:45 0.50 INTRM2, DRILL CIRC T Rack back stand, Blow down top drive, install safety valve and hose.Rotate in slips. Change out swivel packing. GPM: 124 PSI: 750 RPM: 1 TRQ: 8k 10,970.0 10,970.0 5/17/2023 03:45 5/17/2023 04:15 0.50 INTRM2, DRILL SVRG P Service rig, change out swivel packing. 10,970.0 10,970.0 5/17/2023 04:15 5/17/2023 04:45 0.50 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,970' MD to 10,980' MD 8,160' TVD. WOB: 17k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg ROT: 189k 10,970.0 10,980.0 5/17/2023 04:45 5/17/2023 05:45 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 10,980' MD (For GEO data) GPM: 650 PSI: 3370 RPM:80 TRQ: 16 ROT: 189k 10,980.0 10,980.0 5/17/2023 05:45 5/17/2023 06:15 0.50 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 10,980' MD to 11,000' MD 8,165' TVD. WOB: 17k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg ROT: 189k 10,980.0 11,000.0 5/17/2023 06:15 5/17/2023 07:15 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 11,000' MD (For GEO data) GPM: 650 PSI: 3370 RPM:80 TRQ: 16 ROT: 189k 11,000.0 11,000.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 22/44 MT7-95 Report Printed: 6/19/2023 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) 5/17/2023 07:15 5/17/2023 08:00 0.75 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 11,000' MD to 11,020' MD 8,170' TVD. WOB: 14k GPM: 650 PSI: 3,450 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg ROT: 192k 11,000.0 11,020.0 5/17/2023 08:00 5/17/2023 09:00 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 11,020' MD (For GEO data) GPM: 650 PSI: 3370 RPM:80 TRQ: 16 ROT: 189k 11,020.0 11,020.0 5/17/2023 09:00 5/17/2023 09:30 0.50 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" Interm 2 hole from 11,020' MD to 11,040' MD 8,175' TVD. WOB: 12k GPM: 650 PSI: 3,470 ECD: 12.6ppg RPM: 160 TQ on: 19k ft/lbs TQ off: 17k ft/lbs F/O: 30% MW: 11.4 ppg ROT: 192k TBH: 18.6 TJH: 68.4 11,020.0 11,040.0 5/17/2023 09:30 5/17/2023 10:30 1.00 INTRM2, DRILL CIRC P Circulate BTM's up at 11,040' MD (For GEO data) GPM: 650 PSI: 3370 RPM:80 TRQ: 16 ROT: 189k 11,040.0 11,040.0 5/17/2023 10:30 5/17/2023 11:00 0.50 INTRM2, TRIPCAS CIRC P Take final survey, downlink tools GPM: 650 PSI: 3370 RPM:80 TRQ: 16 PU: 235k SO: 158k ROT: 191k 11,040.0 11,040.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 23/44 MT7-95 Report Printed: 6/19/2023 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) 5/17/2023 11:00 5/17/2023 12:00 1.00 INTRM2, TRIPCAS CIRC P Take base parameters f/ underreamer. Drop 1.625" Torlon ball. Pump down string. Pump down at 250 GPM for 900stks and reduce rate to 100 GPM. Ball landed at 1822stks. under reamer shift close at 2100psi. Check parameters to confirm under closed. Base parameters: Turbine RPM: 3972 GPM: 600 PSI: 2890 RPM 80 TRQ: 15k Post parameters: Turbine RPM: 4440 GPM: 600 PSI: 3240 RPM:30 TRQ: 11k 11,040.0 11,040.0 5/17/2023 12:00 5/17/2023 12:30 0.50 INTRM2, TRIPCAS STRP P OWFF (static) Blow down top drive, line up surface equipment for stripping. 11,040.0 11,040.0 5/17/2023 12:30 5/17/2023 16:00 3.50 INTRM2, TRIPCAS STRP P SOOH from 11,040' MD to 9,632' MD holding 12.5ppg EMW. 11,040.0 9,632.0 5/17/2023 16:00 5/17/2023 17:00 1.00 INTRM2, TRIPCAS CIRC P Circulate BTM's up at 9,632' MD GPM: 650 PSI: 3515 RPM: 120 TRQ: 14 9,632.0 9,632.0 5/17/2023 17:00 5/17/2023 20:00 3.00 INTRM2, TRIPCAS STRP P Continue SOOH from 9,632' MD to 7,299' MD holding 12.5ppg EMW. Dropped 2.55" hallow drift with 110' tail. 9,632.0 7,299.0 5/17/2023 20:00 5/17/2023 20:30 0.50 INTRM2, TRIPCAS MPDA P Rubber plugged chokes, Clean out same. 7,299.0 7,299.0 5/17/2023 20:30 5/18/2023 00:00 3.50 INTRM2, TRIPCAS STRP P Continue SOOH from 7,299' MD to 3,611' MD holding 12.5ppg EMW. 7,299.0 3,611.0 5/18/2023 00:00 5/18/2023 02:30 2.50 INTRM2, TRIPCAS STRP P Continue SOOH from 3,611' MD to 781' MD holding 12.5ppg EMW. 3,611.0 781.0 5/18/2023 02:30 5/18/2023 03:00 0.50 INTRM2, TRIPCAS MPDA P Bled off MPD back pressure to 0psi, OWFF (Static), Pull RCD and install trip nipple. 781.0 781.0 5/18/2023 03:00 5/18/2023 04:00 1.00 INTRM2, TRIPCAS PULD P Lay down 5" HWT drill pipe and jars. 781.0 242.0 5/18/2023 04:00 5/18/2023 06:30 2.50 INTRM2, TRIPCAS PULD P Continue L/D Baker Intermediate 2 directional BHA. 242.0 0.0 5/18/2023 06:30 5/18/2023 07:30 1.00 INTRM2, TRIPCAS CLEN P Clean and clear rig floor, L/D tools and equipment out of beaver slide. 0.0 0.0 5/18/2023 07:30 5/18/2023 09:00 1.50 INTRM2, CASING RURD P R/U all 7" casing running equipment, P/U and L/D Baker swivel with joint of 5" drill pipe. Function safety valve with X/O on floor. 0.0 0.0 5/18/2023 09:00 5/18/2023 11:30 2.50 INTRM2, CASING PUTB P PJSM, P/U and run shoe track (check floats all ok), apply thread lock on shoe track to joint #4. Continue RIH with 7" 29ppf L80 H563 liner to 1,466' MD. MU: 10,100ft/lbs PU: 75k SO: 80k NOTE: PU and SO readings seems backwards but thats the correct readings. 0.0 1,466.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 24/44 MT7-95 Report Printed: 6/19/2023 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) 5/18/2023 11:30 5/18/2023 13:00 1.50 INTRM2, CASING CIRC P PU and RIH with 7" liner hanger HRD-E running tools per Baker. Fill hanger w/ Zanplex. Fill liner and break circulation . GPM: 168 PSI: 170 PU: 94k SO:98k 1,466.0 1,603.0 5/18/2023 13:00 5/18/2023 15:00 2.00 INTRM2, CASING OTHR P Pull trip nipple and install RCD. 1,603.0 1,603.0 5/18/2023 15:00 5/18/2023 23:00 8.00 INTRM2, CASING SMPD P SIH with 7" 29ppf L80 H563 liner on 5" drill pipe from 1,603' MD to 9,678' MD. 1,603.0 9,678.0 5/18/2023 23:00 5/19/2023 00:00 1.00 INTRM2, CASING CIRC P Stage up pump to 6bpm 695/110psi, rotate 20 RPM, 11k torque. (Full returns). PU: 210k SO: 145k ROT: 174 RPM: 20 TRQ: 11 GPM: 84 PSI: 485/200 2bpm - 485/200 3bpm - 520/170 4bpm - 560/150 5bpm - 616/128 6bpm - 695/110 9,678.0 9,678.0 5/19/2023 00:00 5/19/2023 00:30 0.50 INTRM2, CASING CIRC P Circulate at 9,678' MD. GPM: 252 PSI: 100 9,678.0 9,678.0 5/19/2023 00:30 5/19/2023 02:00 1.50 INTRM2, CASING STRP P SIH with 7" 29ppf L80 H563 liner on 5" drill pipe from 9,678' MD to 11,021' MD. 9,678.0 11,021.0 5/19/2023 02:00 5/19/2023 02:30 0.50 INTRM2, CEMENT RURD P Blow down top drive and M/U Baker cement swivel and lines. 11,021.0 11,021.0 5/19/2023 02:30 5/19/2023 03:00 0.50 INTRM2, CEMENT WASH P Wash in hole from 11,021' MD to 11,040' MD. Tag with 10k. GPM: 42 PSI: 500 PU: 250k SO: 151k 11,021.0 11,040.0 5/19/2023 03:00 5/19/2023 05:00 2.00 INTRM2, CEMENT CIRC P P/U and set shoe on depth at 11,032' MD. Circulate and stage pumps up from 1 to 5bpm. GPM: 210 PSI: 690 11,040.0 11,032.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 25/44 MT7-95 Report Printed: 6/19/2023 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) 5/19/2023 05:00 5/19/2023 07:00 2.00 INTRM2, CEMENT CMNT P Pressure test line to 4500psi. Pump 70bbls KCL spacer w/ rig. Drop bottom dart. Swap to cementers. Mix and pump 62bbls 15.8ppg cement @ 4.3BPM. SD and drop top dart. Pump 10bbl FW w/ cementers. Swap over to rig pumps and displace cement w/ 203.7bls 11.5ppg NAF. 2408stks pumped. FCP 411psi. Pressure up to 1184psi and hold f/ 5 min. Bleed off and check floats. Good. Cement in place @ 0637hrs, 5-19-23. Note: Bottom dart lands and shears bottom plug at 1060stks 900psi while pumping at 3bpm 78psi. Staged up pumps to 6bpm 290psi. Drop pump rate to 3bpm. Bottom plug land at 1675stks and shear at 1353psi. Top dart lands 1776stks and shears at 1500psi, Increase rate to 5bpm. Bump plug at 2408stks 3.2bbls early. FCP at 3bpm 411psi. Bump and pressure up to 1184psi, and hold for 5mins. Bled off and floats holding. Full returns. Cement in place at 0637hrs. TOL @ 9,532', FS @ 11,032' MD. 11,032.0 11,032.0 5/19/2023 07:00 5/19/2023 07:30 0.50 INTRM2, CEMENT OTHR P Set Baker hanger. Pressure up to 2900psi. SO 50k verify set. Pressure up to 3900psi and release HRD running tool. Free weight - 210k. Expose dog sub. Slack off string and packer set at 145k (44k shear). PU rotate and set back down to 50k at 20rpm and 9k torque for 3mins. 11,032.0 11,032.0 5/19/2023 07:30 5/19/2023 08:00 0.50 INTRM2, CEMENT PRTS P Open drill string to atmosphere, pressure test liner top to 1000psi for 10mins (good test). 11,032.0 9,529.0 5/19/2023 08:00 5/19/2023 10:30 2.50 INTRM2, CEMENT CIRC P Circulate and clear drill string. Install 7" wipper ball and continue to circulate S/S. GPM: 504 PSI: 1400 9,529.0 9,529.0 5/19/2023 10:30 5/19/2023 12:00 1.50 INTRM2, CEMENT MPDA P OWFF (static). Pull RCD and install trip nipple. SIMOPS: Prep drift and mix dry job. 9,529.0 9,529.0 5/19/2023 12:00 5/19/2023 18:30 6.50 INTRM2, CEMENT TRIP P POOH from 9,529' MD to surface. L/D Baker running tools. Good set indication on dog sub and no damages to tools. 9,529.0 0.0 5/19/2023 18:30 5/19/2023 20:00 1.50 INTRM2, WHDBOP CLEN P Clean and clear rig floor. M/U test joint and wear ring retrieving tool. Prep to change rams. SIMOPS: Test casing to 3500psi 30 min (pumped 11.5bbls returned 11.5bbls (good test). Cement in place at 06:37 hrs Cement at 500psi @ 15:11 hrs. Cement at 1000psi @ 16:14 hrs 0.0 0.0 5/19/2023 20:00 5/19/2023 21:00 1.00 INTRM2, WHDBOP BOPE P Pull wear ring and change out upper rams from 4-1/2" X 7" to 2-7/8" X 5-1/2". 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 26/44 MT7-95 Report Printed: 6/19/2023 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) 5/19/2023 21:00 5/19/2023 22:00 1.00 INTRM2, WHDBOP WWWH P Install test plug with 4" test joint. R/U test equipment and purge air from system. 0.0 0.0 5/19/2023 22:00 5/20/2023 00:00 2.00 INTRM2, WHDBOP BOPE P BOPE Test: All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 2500psi/10min. 4” Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR, AOGCC Sean Sullivan witness BOP test. BLM Quinn M Sawyer waived witness 08:28am 5-16-23. 0.0 0.0 5/20/2023 00:00 5/20/2023 06:30 6.50 INTRM2, WHDBOP BOPE P BOPE Test: All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 2500psi/10min w/ exception of manual and super choke t/ 2000 psi. 4” Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR, W/ 5" Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR,Test choke valves 1-15. Manual operated and super choke. Choke manuals and HCR valves. 4" kill line valve. Test 2x 4" FO safety valves. 4" dart valve. 2x 5" FO safety valves. 5" dart valve. Test upper and lower IBOP. Blind ram. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1600 psi, ACC = 1600 psi after all functions on bottles,16 sec for 200 psi. Build w/ 2 electric pumps, 115 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 22 sec. UPR = 13 sec, Blind ram = 13 sec, LPR = 14 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. Trouble shooting intermitting leaks 00:00hrs to 02:00hrs. Found grease bucket used to grease valves was almost empty. Re Grease valves and all tested good. Fail/Pass on #2 choke manifold valve and manuel choke line valve. Re grease and retested (good test). AOGCC Sean Sullivan witness BOP test. BLM Quinn M Sawyer waived witness 08:28am 5-16-23. 0.0 0.0 5/20/2023 06:30 5/20/2023 08:00 1.50 INTRM2, WHDBOP OTHR P R/D test equipment, Blow down surface equipment. Set wear ring. 0.0 0.0 5/20/2023 08:00 5/20/2023 10:30 2.50 INTRM2, DRILLOUT BHAH P PJSM, P/U Baker production BHA #4. Tool offset from bit: NB inc. 5.62' Gamma 12.73' Pressure 15.36' Resistivity 19.92' Directional 25.89' Density 48.95' Azimuthal Caliper 51.30' Neutron 57.82' Resistivity Image 69.77' 0.0 230.0 5/20/2023 10:30 5/20/2023 12:00 1.50 INTRM2, DRILLOUT PUTB P Single in 4" drill pipe from 230' MD to 545' MD. 230.0 545.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 27/44 MT7-95 Report Printed: 6/19/2023 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) 5/20/2023 12:00 5/20/2023 18:00 6.00 INTRM2, DRILLOUT PUTB P Continue single in 4" drill pipe from 545' MD to 4,801' MD. Log free ring pipe from 4,175' MD to 4,242' MD at 1800'/hr. 545.0 4,801.0 5/20/2023 18:00 5/21/2023 00:00 6.00 INTRM2, DRILLOUT PULD P Continue single in 4" drill pipe from 4801' MD to 8,150' MD. Logging from 5,800' at 1800'/min. at 19:45 hrs. Note: For future reference 6,400' MD at 20:45hrs (9:15 hrs for P/U singles to 6400' MD). 4,801.0 8,150.0 5/21/2023 00:00 5/21/2023 04:30 4.50 INTRM2, DRILLOUT PUTB P Continue single in 4" drill pipe from 8,150' MD to 10,735' MD. Logging at 1800'/min. 8,150.0 10,735.0 5/21/2023 04:30 5/21/2023 05:30 1.00 INTRM2, DRILLOUT WASH P Fill pipe and wash in hole from 10,735' MD to 10,965' MD. Tagged cement at 10,945' MD GPM: 216 PSI: 1970 RPM: 60 TRQ: 9k PU: 178k SO: 125k ROT: 141k 10,735.0 10,945.0 5/21/2023 05:30 5/21/2023 08:00 2.50 INTRM2, DRILLOUT COCF P Drill cement, plug set, landing collar and float collar from 10,945' MD to 11,027' MD. GPM: 240 PSI: 2380 ECD: 12.1ppg WOB: 10k RPM: 80 TRQ: 11k PU: 178k SO: 125k ROT: 141k 10,945.0 11,027.0 5/21/2023 08:00 5/21/2023 11:00 3.00 INTRM2, DRILLOUT CIRC P Displace well with 8.8ppg Flo Pro, Rotate and reciprocate pipe from 11,027' MD to 10,985' MD. 40bbls LVT 100bbls 13.5ppbTransition spacer 100bbls cleanning spacer 50bbls hi Vis Flo Pro GPM: 245 PSI: 2600 ECD: 10.4ppg RPM: 80 TRQ: 11k PU: 169k SO: 143k ROT: 159k 11,027.0 11,027.0 5/21/2023 11:00 5/21/2023 14:30 3.50 INTRM2, DRILLOUT OTHR P Remove PS-21's, clean flow box, flow line and surface equipment. SIMOPS: Cut and slip 94' Drill line and survice rig 11,027.0 11,027.0 5/21/2023 14:30 5/21/2023 15:30 1.00 INTRM2, DRILLOUT MPDA P Pull trip nipple and instal 4" RCD. Establish circulation and take SCR's 11,027.0 11,027.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 28/44 MT7-95 Report Printed: 6/19/2023 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) 5/21/2023 15:30 5/21/2023 16:00 0.50 INTRM2, DRILLOUT COCF P Drill cement and shoe, Clean out rat hole from 11,027' MD to 11,038' MD. Slight pack off at 11,032' MD, String packed off at 11,038' MD. Shoe @ 11,032' MD GPM: 240 PSI: 1175 ECD: 12.1ppg WOB: 12k RPM: 80 TRQ: 11k PU: 178k SO: 125k ROT: 141k 11,027.0 11,038.0 5/21/2023 16:00 5/21/2023 18:30 2.50 INTRM2, DRILLOUT OTHR T String packed off at 11,038' MD with 1100psi, Bled off pressure and attempt to work free without sucess, continue work pipe with/without torque and pressure up to 200/500psi. Continue work pipe up to 310k, pipe free, Pull into shoe at 11,032' MD. staging pumps up and rotary. 11,038.0 11,032.0 5/21/2023 18:30 5/21/2023 20:15 1.75 INTRM2, DRILLOUT REAM P Continue clean out shoe and rat hole from 11,032' MD to 11,038' MD. Slight packoff around shoe area after passing through area several times. GPM: 200 PSI: 975 ECD: 9.6ppg RPM: 80 TRQ: 7k 11,032.0 11,040.0 5/21/2023 20:15 5/21/2023 20:45 0.50 INTRM2, DRILLOUT DDRL P Drill 6-1/8" production hole from 11,040' MD to 11,060' MD. WOB: 12k GPM: 225 PSI: 1300 ECD: 9.3ppg RPM: 50 TQ on: 8k ft/lbs TQ off: 6k ft/lbs F/O: 13% MW: 8.8 ppg PU: 171k SO: 136k ROT: 155k ADT: 0.7hrs TBH: 0.7 hrs 11,040.0 11,060.0 5/21/2023 20:45 5/21/2023 21:15 0.50 INTRM2, DRILLOUT CIRC P Pull into shoe from 11,060' MD to 11,020' MD, R/U safety valve and circulating hose. Circulate at 220gpm 1120psi Mud 8.8in/out. T&D 20/20/45 At 11,020' MD PU:172k SO: 135k ROT: 150 TRQ: 5k 11,060.0 11,020.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 29/44 MT7-95 Report Printed: 6/19/2023 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) 5/21/2023 21:15 5/21/2023 21:45 0.50 INTRM2, DRILLOUT FIT P Line up BOP equipment and purge air from system. Perform FIT @ 11,032' MD 8,173' TVD with 8.8 mud pump at 0.5bpm to 1390psi, held for 10min final pressure 1383psi, Pumped 4.4bbls returned 4.0bbls 12.1ppg EMW. 11,020.0 11,020.0 5/21/2023 21:45 5/21/2023 22:00 0.25 INTRM2, DRILLOUT WASH P Wash and ream in hole from 11,020' MD to 11,060' MD. GPM: 220 PSI: 1120 RPM: 80 TRQ: 5k ROT: 154k 11,020.0 11,060.0 5/21/2023 22:00 5/22/2023 00:00 2.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 11,060' MD to 11,113' MD 8,194' TVD. Close MPD on connections 0psi. WOB: 10k GPM: 200 PSI: 975 ECD: 9.6ppg RPM: 80 TQ on: 7k ft/lbs TQ off: 4k ft/lbs F/O: 9% MW: 8.8 ppg PU: 173k SO: 135k ROT: 155k ADT: 0.8hrs TBH: 0.8hrs 11,060.0 11,113.0 5/22/2023 00:00 5/22/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 11,113' MD to 11,584' MD 8,268' TVD. Close MPD on connections 0psi. WOB: 20k GPM: 230 PSI: 1200 ECD: 9.3ppg RPM: 140 TQ on: 8k ft/lbs TQ off: 4k ft/lbs F/O: 9% MW: 8.8 ppg PU: 172k SO: 135k ROT: 150k ADT: 4.8hrs TBH: 5.9hrs 11,113.0 11,584.0 5/22/2023 06:00 5/22/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 11,584' MD to 12,318' MD 8,309' TVD. Close MPD on connections 0psi. WOB: 16k GPM: 240 PSI: 1152 ECD: 9.5ppg RPM: 140 TQ on: 8k ft/lbs TQ off: 4k ft/lbs F/O: 14% MW: 8.8 ppg PU: 172k SO: 135k ROT: 150k ADT: 4.4hrs TBH: 10.3hrs 11,584.0 12,318.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 30/44 MT7-95 Report Printed: 6/19/2023 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) 5/22/2023 12:00 5/22/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 12,318' MD to 12,867' MD 8,333' TVD. Close MPD on connections 0psi. Slight losses seen at 12,445' MD ~15bph. Max gas 1226units @ 12,845' MD WOB: 16k GPM: 240 PSI: 1152 ECD: 9.5ppg RPM: 140 TQ on: 8k ft/lbs TQ off: 4k ft/lbs F/O: 14% MW: 8.8 ppg PU: 176k SO: 131k ROT: 147k ADT: 3.9hrs TBH: 14.2hrs 12,318.0 12,867.0 5/22/2023 18:00 5/23/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 12,867' MD to 13,478' MD 8,364' TVD. Close MPD on connections 0psi. Losses increased at 13,380' MD Adding BG LCM 2ppb Total losses on connection at 13,480' MD. Regain returns with losses ~200bph. Max gas 1230units @13,475' MD WOB: 16k GPM: 230 PSI: 1470 ECD: 9.5ppg RPM: 140 TQ on: 8k ft/lbs TQ off: 3k ft/lbs F/O: 14% MW: 8.8 ppg PU: 180k SO: 132k ROT: 150k ADT: 3.7hrs TBH: 17.9hrs 12,867.0 13,478.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 31/44 MT7-95 Report Printed: 6/19/2023 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) 5/23/2023 00:00 5/23/2023 02:45 2.75 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 13,478' MD to 13,750' MD 8,378' TVD. Close MPD on connections 0psi. Losses increased at 13,380' MD Adding BG LCM 2ppb Total losses on connection at 13,480' MD. 8,364' TVD, Regain returns with losses ~200bph. 0100hrs: 179bph 0200hrs: 140bph 0220hrs: 90bph Max gas 1347units @13,568' MD WOB: 13k GPM: 200 PSI: 1200 ECD: 9.5ppg RPM: 140 TQ on: 8k ft/lbs TQ off: 3k ft/lbs F/O: 7% MW: 8.8 ppg PU: 180k SO: 132k ROT: 150k ADT: 1.9hrs TBH: 19.8hrs 13,478.0 13,750.0 5/23/2023 02:45 5/23/2023 03:45 1.00 PROD1, DRILL CIRC P At 13,750' MD pump 50bbls 35ppb LCM at 100gpm to clear bit. Losses reduced from 90bph to 22bph. 0300hrs: 53bph 13,750.0 13,750.0 5/23/2023 03:45 5/23/2023 06:00 2.25 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 13,750' MD to 13,973' MD 8,383' TVD. Close MPD on connections 0psi. Losses increased at 13,380' MD Adding BG LCM 2ppb Max gas 420units @13,857' MD WOB: 17k GPM: 220 PSI: 1430 ECD: 9.7ppg RPM: 140 TQ on: 10k ft/lbs TQ off: 4k ft/lbs F/O: 8% MW: 8.8 ppg PU: 188k SO: 128k ROT: 160k ADT: 1.3hrs TBH: 21.1hrs 13,750.0 13,973.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 32/44 MT7-95 Report Printed: 6/19/2023 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) 5/23/2023 06:00 5/23/2023 09:30 3.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 13,973' MD to 14,424' MD 8,384' TVD. Close MPD on connections 0psi. Losses increased at 14,245' MD 8,383.9' TVD, 120-150bph Losses increased at 14,310' MD 8,384 TVD, 200bph, Losses reducing to 80bph. Adding BG LCM 6ppb Max gas 1253units @14374' MD WOB: 12k GPM: 180 PSI: 1050 ECD: 9.5ppg RPM: 140 TQ on: 9k ft/lbs TQ off: 4k ft/lbs F/O: 2% MW: 8.8 ppg PU: 188k SO: 128k ROT: 160k ADT: 2.7hrs TBH: 23.8hrs 13,973.0 14,424.0 5/23/2023 09:30 5/23/2023 10:30 1.00 PROD1, DRILL CIRC P At 14,424' MD pump 50bbls 35ppb LCM at 100gpm to clear bit. Losses reduced from 80bph to 41bph. 1000hrs: 41bph 14,424.0 14,424.0 5/23/2023 10:30 5/23/2023 12:00 1.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 14,424' MD to 14,560' MD 8,384' TVD. Close MPD on connections 0psi. Losses at 1200hrs 23bph Max gas 893units @14,518' MD WOB: 19k GPM: 210 PSI: 1340 ECD: 9.5ppg RPM: 140 TQ on: 10k ft/lbs TQ off: 5k ft/lbs F/O: 8% MW: 8.8 ppg PU: 184k SO: 126k ROT: 150k ADT: 0.7hrs TBH: 24.6hrs 14,424.0 14,560.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 33/44 MT7-95 Report Printed: 6/19/2023 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) 5/23/2023 12:00 5/23/2023 16:30 4.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 14,560' MD to 15,086' MD 8,381' TVD. Close MPD on connections 0psi. Losses: 1300hrs 33bph 1400hrs 40bph 1500hrs 32bph 1600hrs 17bph Adding BG LCM 6ppb Max gas 1163units @15,000' MD WOB: 18k GPM: 210 PSI: 1435 ECD: 9.8ppg RPM: 140 TQ on: 10k ft/lbs TQ off: 7k ft/lbs F/O: 10% MW: 8.8 ppg PU: 188k SO: 128k ROT: 160k ADT: 3.1hrs TBH: 27.7hrs 14,560.0 15,086.0 5/23/2023 16:30 5/23/2023 17:00 0.50 PROD1, DRILL OWFF P Perform static lost rate of 18bph. 15,086.0 15,086.0 5/23/2023 17:00 5/24/2023 00:00 7.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 15,086' MD to 15,843' MD 8,376' TVD. Close MPD on connections 0psi. Losses: 1800hrs 40bph 1900hrs 32bph 2000hrs: 13bph 2100hrs: 10bph 2200hrs: 23bph 2300hrs: 19bph 2400hrs: 32bph Adding BG LCM 6ppb Max gas 1453units @15,380' MD WOB: 14k GPM: 210 PSI: 1465 ECD: 9.8ppg RPM: 140 TQ on: 10k ft/lbs TQ off: 8k ft/lbs F/O: 9% MW: 8.8 ppg PU: 190k SO: 126k ROT: 160k ADT: 4.0hrs TBH: 32.3hrs 15,086.0 15,843.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 34/44 MT7-95 Report Printed: 6/19/2023 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) 5/24/2023 00:00 5/24/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 15,843' MD to 16,523' MD 8,377' TVD. Close MPD on connections 0psi. Losses: 0600hrs: 28bph Adding BG LCM 6ppb WOB: 14k GPM: 210 PSI: 1465 ECD: 9.8ppg RPM: 140 TQ on: 10k ft/lbs TQ off: 8k ft/lbs F/O: 9% MW: 8.8 ppg PU: 190k SO: 126k ROT: 160k ADT: 4.0hrs TBH: 32.3hrs 15,843.0 16,523.0 5/24/2023 06:00 5/24/2023 11:15 5.25 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 16523 MD to 17109' MD 8,388' TVD. Close MPD on connections 0psi. Losses: 1100hrs - 31bph Adding BG LCM 6ppb WOB: 13k GPM: 210 PSI: 1540 ECD: 9.9ppg RPM: 140 TQ on: 11k ft/lbs TQ off: 5k ft/lbs F/O: 8% MW: 8.8 ppg PU: 189k SO: 119k ROT: 151k ADT: 43.4hrs TBH: 39.7hrs 16,523.0 17,109.0 5/24/2023 11:15 5/24/2023 14:00 2.75 PROD1, DRILL MPDA P Retrieve 4" MPD bearing assembly. Observed debris at top of hole after removing assembly. Install trip nipple and circulate out. Recovered pieces of 7" shoe from drill out. Retrieve trip nipple and install 5" bearing assembly. 17,109.0 17,109.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 35/44 MT7-95 Report Printed: 6/19/2023 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) 5/24/2023 14:00 5/25/2023 00:00 10.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 17109' MD to 18208' MD 8,390' TVD. Close MPD on connections 0psi. Losses: 0000hrs- 33bph Adding BG LCM 6ppb WOB: 14k GPM: 210 PSI: 1650 ECD: 10.0ppg RPM: 140 TQ on: 10k ft/lbs TQ off: 8k ft/lbs F/O: 10% MW: 8.8 ppg PU: 189k SO: 119k ROT: 151k ADT: 6.7hrs TBH: 41.4hrs 17,109.0 18,208.0 5/25/2023 00:00 5/25/2023 03:30 3.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 18208' MD to 18680' MD 8,392' TVD. Close MPD on connections 0psi. Losses: Observed losses increase @ 18555'. Pump 40bbls of 35ppb LCM pill while drilling. Adding BG LCM 6ppb WOB: 11k GPM: 180 PSI: 1370 ECD: 10.0ppg RPM: 130 TQ on: 12k ft/lbs TQ off: 8k ft/lbs F/O: 7% MW: 8.8 ppg PU: 189k SO: 119k ROT: 151k ADT: 2.7hrs TBH: 49.1hrs 18,208.0 18,680.0 5/25/2023 03:30 5/25/2023 04:15 0.75 PROD1, DRILL CIRC P Slow rate to turn off pulser while pumping pill through BHA. Losses had decreased before pill exited bit. GPM 130 PSI 930 RPM 80 TQ 10k 18,680.0 18,680.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 36/44 MT7-95 Report Printed: 6/19/2023 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) 5/25/2023 04:15 5/25/2023 12:00 7.75 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 18680' MD to 19620' MD 8,393' TVD. Close MPD on connections 0psi. Losses: 20-40 BPH Adding BG LCM 6ppb WOB: 17k GPM: 210 PSI: 1620 ECD: 10.1ppg RPM: 130 TQ on: 12k ft/lbs TQ off: 8k ft/lbs F/O: 9% MW: 8.8 ppg PU: 204k SO: 126k ROT: 164k ADT: 5.4hrs TBH: 54.6hrs 18,680.0 19,620.0 5/25/2023 12:00 5/25/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 19620' MD to 20350' MD 8,452' TVD. Close MPD on connections 0psi. Losses: 20-40 BPH Adding BG LCM 6ppb WOB: 15k GPM: 210 PSI: 1840 ECD: 10.3ppg RPM: 130 TQ on: 15k ft/lbs TQ off: 8k ft/lbs F/O: 10% MW: 8.8 ppg PU: 208k SO: 123k ROT: 166k ADT: 4.4hrs TBH: 63.3hrs 19,620.0 20,350.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 37/44 MT7-95 Report Printed: 6/19/2023 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) 5/25/2023 18:00 5/26/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20350' MD to 21068' MD 8,450' TVD. Close MPD on connections 0psi. Losses: 20-40 BPH Adding BG LCM 6ppb WOB: 17k GPM: 210 PSI: 1885 ECD: 10.4ppg RPM: 130 TQ on: 13k ft/lbs TQ off: 7k ft/lbs F/O: 10% MW: 8.8 ppg PU: 214k SO: 121k ROT: 166k ADT: 4.4hrs TBH: 63.3hrs 20,350.0 21,068.0 5/26/2023 00:00 5/26/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 21068' MD to 21789' MD 8,446' TVD. Close MPD on connections 0psi. Losses: 30 BPH Adding BG LCM 6ppb WOB: 9k GPM: 210 PSI: 1920 ECD: 10.4ppg RPM: 130 TQ on: 12k ft/lbs TQ off: 7k ft/lbs F/O: 8% MW: 8.8 ppg PU: 213k SO: 124k ROT: 169k ADT: 4.3hrs TBH: 67.6hrs 21,068.0 21,789.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 38/44 MT7-95 Report Printed: 6/19/2023 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) 5/26/2023 06:00 5/26/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 21789' MD to 22576' MD 8,446' TVD. Close MPD on connections 0psi. Losses: 30 BPH Adding BG LCM 6ppb WOB: 16k GPM: 210 PSI: 1900 ECD: 10.4ppg RPM: 130 TQ on: 14k ft/lbs TQ off: 8k ft/lbs F/O: 9% MW: 8.8 ppg PU: 221k SO: 124k ROT: 174k ADT: 4.6hrs TBH: 72.2hrs 21,789.0 22,576.0 5/26/2023 12:00 5/26/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 22576' MD to 23297' MD 8,460' TVD. Close MPD on connections 0psi. Losses: 30 BPH Adding BG LCM 6ppb WOB: 17k GPM: 210 PSI: 2000 ECD: 10.6ppg RPM: 130 TQ on: 15k ft/lbs TQ off: 7k ft/lbs F/O: 10% MW: 8.8 ppg PU: 227k SO: 121k ROT: 176k ADT: 4.2hrs TBH: 76.4hrs 22,576.0 23,297.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 39/44 MT7-95 Report Printed: 6/19/2023 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) 5/26/2023 18:00 5/27/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 23297' MD to 23985' MD 8,476' TVD. Close MPD on connections 0psi. Losses: 30 BPH Adding BG LCM 6ppb WOB: 19k GPM: 210 PSI: 2045 ECD: 10.6ppg RPM: 130 TQ on: 15k ft/lbs TQ off: 13k ft/lbs F/O: 11% MW: 8.8 ppg PU: 233k SO: 115k ROT: 176k ADT: 4.2hrs TBH: 80.6hrs 23,297.0 23,985.0 5/27/2023 00:00 5/27/2023 07:15 7.25 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 23985' MD to 24803' MD 8,476' TVD. Close MPD on connections 60-150psi. Losses: 30-40 BPH Adding BG LCM 6ppb WOB: 23k GPM: 210 PSI: 2330 ECD: 10.8ppg RPM: 130 TQ on: 17k ft/lbs TQ off: 8k ft/lbs F/O: 11% MW: 8.8 ppg PU: 242k SO: ROT: 180k ADT: 5.0hrs TBH: 85.6hrs 23,985.0 24,803.0 5/27/2023 07:15 5/27/2023 08:00 0.75 PROD1, TRIPCAS CIRC P Take final survey. Downlink and turn off tools.Rack back 1 std. 24,803.0 24,707.0 5/27/2023 08:00 5/27/2023 10:30 2.50 PROD1, TRIPCAS CIRC P Circulate BU. 250 GPM 2450 PSI 12% FO 120 RPM 13k TQ 10.6ppg ECD 24,707.0 24,707.0 5/27/2023 10:30 5/27/2023 12:00 1.50 PROD1, TRIPCAS OWFF P Fingerprint well. reduce flow and let well relax. 5 RPM/14k TQ 1st-132 psi 2nd- 80 psi 3rd - 52 psi 4th- 33 psi 5th - 20 psi 24,707.0 24,707.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 40/44 MT7-95 Report Printed: 6/19/2023 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) 5/27/2023 12:00 5/27/2023 23:00 11.00 PROD1, TRIPCAS CIRC P Circulate and clean hole. Racking back 1 std every 2 BU. 4 BU total. 248 GPM 2400 PSI 120 RPM 13k TQ 24,707.0 24,523.0 5/27/2023 23:00 5/28/2023 00:00 1.00 PROD1, TRIPCAS DISP P RIH 1 std to 24700'. Prep to displace to 9.1ppg Vis brine. Pump 91 bbls HiVis spacer. chase w/ 9.1 Vis brine. 248 GPM 2175 PSI 120 RPM 14k TQ 24,523.0 24,707.0 5/28/2023 00:00 5/28/2023 02:30 2.50 PROD1, TRIPCAS DISP P Displace hole with 9.1 ppg Vis Brine. Observed total losses just before spacer returned to surface. 24,707.0 24,707.0 5/28/2023 02:30 5/28/2023 04:00 1.50 PROD1, TRIPCAS DISP T Slow rate. Line up pump on annulus. Fill annulus. Initial loss rate 300 BPH. Continue punping while discussing with town plan forward. 24,707.0 24,707.0 5/28/2023 04:00 5/28/2023 04:30 0.50 PROD1, TRIPCAS DISP T Lost power on rig. Troubleshoot and get power back on. 24,707.0 24,707.0 5/28/2023 04:30 5/28/2023 05:30 1.00 PROD1, TRIPCAS CIRC T Fill annulus and continue pumping keeping hole full. Decision made to swap back to 8.8ppg FloPro and pump LCM pill. Prep to swap back over to FloPro. 24,707.0 24,707.0 5/28/2023 05:30 5/28/2023 13:00 7.50 PROD1, TRIPCAS CIRC T Pump 50 bbls 8.8ppg FloPro. Pump 60 bbls 35ppb LCM pill. Chase with 8.8ppg FloPro. Continue keeping annulus full. Losses improved as pill made it to loss zone (60-70 BPH). Pumped 2nd LCM pill. 95bbls of 35ppb pill. 24,707.0 24,707.0 5/28/2023 13:00 5/28/2023 13:30 0.50 PROD1, TRIPCAS OWFF T Flow check. Static loss rate 36 bph. 24,707.0 24,707.0 5/28/2023 13:30 5/28/2023 23:00 9.50 PROD1, TRIPCAS SMPD P SOOH f/ 24707' to 17075'. Pumped slug @ 23770 due to floats not holding. 24,707.0 17,075.0 5/28/2023 23:00 5/29/2023 00:00 1.00 PROD1, TRIPCAS MPDA P Flow check. Slight losses. Rertrieve 5" MPD bearing assembly and install 4" MPD bearing assembly. 17,075.0 17,075.0 5/29/2023 00:00 5/29/2023 09:00 9.00 PROD1, TRIPCAS SMPD P SOOH LD 4 " DP f/17075' to 11020' MD. Retake survey @ 11143' MD 17,075.0 11,020.0 5/29/2023 09:00 5/29/2023 09:30 0.50 PROD1, TRIPCAS CIRC P Circulate liner volume at shoe. 220 GPM 990 PSi 80 RPM 6k TQ Note: Drop WC opening ball after circulating. Performed weekly BOP function test. 11,020.0 11,020.0 5/29/2023 09:30 5/29/2023 11:30 2.00 PROD1, TRIPCAS SMPD P SOOH f/ 11020' to 9600'. 11,020.0 9,600.0 5/29/2023 11:30 5/29/2023 14:00 2.50 PROD1, TRIPCAS CIRC P Pressure up and shift WC open @ 2250psi. RIH to 9660'. (TOL @ 9532') Circulate hole clean f/ TOL. 500 GPM 1135 PSI 30 RPM 4k TQ 9,600.0 9,600.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 41/44 MT7-95 Report Printed: 6/19/2023 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) 5/29/2023 14:00 5/29/2023 15:00 1.00 PROD1, TRIPCAS MPDA P Flow check. Slow loss observed. Retrieve MPD bearing assembly and install trip nipple. 9,600.0 9,600.0 5/29/2023 15:00 5/29/2023 22:00 7.00 PROD1, TRIPCAS PULD P POOH laying down 4" DP. from 9660' to 3510''. 9,600.0 3,510.0 5/29/2023 22:00 5/29/2023 23:00 1.00 PROD1, TRIPCAS RURD P Swap elevators. Confirm 4" DP count. RD BPA. 3,510.0 3,510.0 5/29/2023 23:00 5/30/2023 00:00 1.00 PROD1, TRIPCAS TRIP P RIH w/ 5" DP f/ 3510' to 4830'. 3,510.0 4,830.0 5/30/2023 00:00 5/30/2023 03:45 3.75 PROD1, TRIPCAS TRIP P RIH f/ 4830' to 9662'. 4,830.0 9,662.0 5/30/2023 03:45 5/30/2023 06:15 2.50 PROD1, TRIPCAS DISP P Pump 95 bbls of hiVis spacer and displace f/ TOL to surface with 8.8 High chloride FloPro mud. 480 GPM 780 PSI 30 RPM 5k TQ 9,662.0 9,662.0 5/30/2023 06:15 5/30/2023 07:00 0.75 PROD1, TRIPCAS TRIP P Drop 1.75" WC closing ball and 2.125" hollow drift. POOH f/ 9662' to 8890'. 9,662.0 8,890.0 5/30/2023 07:00 5/30/2023 08:00 1.00 PROD1, TRIPCAS CIRC P Pressure and attempt to shift WC closed. Stage up to 4300psi 3 times. No success. 8,890.0 8,890.0 5/30/2023 08:00 5/30/2023 12:00 4.00 PROD1, TRIPCAS TRIP P POOH f/ 8890' to 3510'. Racking back 5" DP. Swap out inserts in PS-21s f/ 4" DP. 8,890.0 3,510.0 5/30/2023 12:00 5/30/2023 13:00 1.00 PROD1, TRIPCAS TRIP P POOH f/ 3510' to 2153'. Rack back 15 stds of 4" DP 3,510.0 2,153.0 5/30/2023 13:00 5/30/2023 15:30 2.50 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 2153' to 200'. 2,153.0 200.0 5/30/2023 15:30 5/30/2023 16:00 0.50 PROD1, TRIPCAS OWFF P Flow check. Slow loss observed. PJSM f/ LD BHA. 200.0 200.0 5/30/2023 16:00 5/30/2023 18:00 2.00 PROD1, TRIPCAS BHAH P LD BHA. Note: Well Commander was closed. Filter sub and bit were plugged. 200.0 0.0 5/30/2023 18:00 5/30/2023 18:30 0.50 COMPZN, CASING CLEN P Clean and clear rig floor 0.0 0.0 5/30/2023 18:30 5/30/2023 20:00 1.50 COMPZN, CASING SLPC P Slip/Cut drill line. Service TD. 0.0 0.0 5/30/2023 20:00 5/30/2023 21:30 1.50 COMPZN, CASING RURD P RU to run lower completion. 0.0 0.0 5/30/2023 21:30 5/31/2023 00:00 2.50 COMPZN, CASING PULD P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion to 1960'. MU TQ 5600 ft/lbs. 0.0 1,960.0 5/31/2023 00:00 5/31/2023 08:30 8.50 COMPZN, CASING PULD P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion f/ 1960' to 11000'. MU TQ 5600 ft/lbs. 1,960.0 11,000.0 5/31/2023 08:30 5/31/2023 10:00 1.50 COMPZN, CASING PULD P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion f/ 11000' to 12760''. SO wt at shoe 81k. 11000' - 12760' - 59-70k MU TQ 5600 ft/lbs. 11,000.0 12,760.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 42/44 MT7-95 Report Printed: 6/19/2023 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) 5/31/2023 10:00 5/31/2023 12:00 2.00 COMPZN, CASING PULD P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion f/ 12760' to 13070'. Work through tight spots. SO wt 12760-13070' - 49-60k MU TQ 5600 ft/lbs. 12,760.0 13,070.0 5/31/2023 12:00 5/31/2023 13:00 1.00 COMPZN, CASING CIRC P Decision made to leave shear sub out. Fill liner 13,070.0 13,070.0 5/31/2023 13:00 5/31/2023 14:30 1.50 COMPZN, CASING PULD P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion f/ 13070' to 13420'. Work through tight spots. MU TQ 5600 ft/lbs. 13,070.0 13,420.0 5/31/2023 14:30 5/31/2023 15:00 0.50 COMPZN, CASING PULD P MU liner hanger and packer. RIH. 13,420.0 13,420.0 5/31/2023 15:00 6/1/2023 00:00 9.00 COMPZN, CASING RUNL P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion f/ 13420' to 22130'. Work through tight spots. MU TQ 5600 ft/lbs. 13,420.0 22,130.0 6/1/2023 00:00 6/1/2023 04:00 4.00 COMPZN, CASING RUNL P RIH w/ 4 1/2" 12.6" HYD 563 tbg lower completion f/ 22130' to 22940'. Work through tight spots. MU TQ 5600 ft/lbs. 22,130.0 22,940.0 6/1/2023 04:00 6/1/2023 05:30 1.50 COMPZN, CASING RUNL T Set down at 22940'. Work pipe w/ no success. PU 245k. Break circulation @ 1/2 BPM/ 680 PSI Stage up to 1 BPM/815 PSI. 50% returns. Continue working pipe w/ no success. 22,940.0 22,947.0 6/1/2023 05:30 6/1/2023 07:00 1.50 COMPZN, CASING TRIP T Make a 5 std wiper trip 22947' to 22507'. 22,947.0 22,507.0 6/1/2023 07:00 6/1/2023 12:00 5.00 COMPZN, CASING RUNL T RIH 22507' to 23238'. Able to get past spot at 22947'. PU 250k SO 90k 22,507.0 23,238.0 6/1/2023 12:00 6/1/2023 13:30 1.50 COMPZN, CASING RUNL T Work liner down f/ 23238' to 23256'. Attempt to rotate string. Stalled at15k TQ. Attempt to circulate @ 26 GPM 540 PSI. No success. 23,238.0 23,250.0 6/1/2023 13:30 6/1/2023 20:00 6.50 COMPZN, CASING RUNL T Attempt to work through obstruction f/ 23256'. No success. 23,238.0 23,250.0 6/1/2023 20:00 6/2/2023 00:00 4.00 COMPZN, CASING RUNL T Clean rig and wait on approval from AOGCC to move forward setting liner at current depth. 23,238.0 23,250.0 6/2/2023 00:00 6/2/2023 09:00 9.00 COMPZN, CASING RUNL T Clean rig and wait on approval from AOGCC to move forward setting liner at current depth. 23,238.0 23,256.0 6/2/2023 09:00 6/2/2023 12:00 3.00 COMPZN, CASING PACK P Pump 5 BBLS down drill string. Insert 1.5" ball in DS and let drop to release hanger. 23,256.0 23,256.0 6/2/2023 12:00 6/2/2023 13:00 1.00 COMPZN, CASING PACK P Pump down DS 8 BBLS. Observed pressure increase (ball landed). Set liner and hanger as per Baker. TOL @ 9808'. Note: used test pump to shear ball seat (4870 PSI) 23,256.0 23,256.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 43/44 MT7-95 Report Printed: 6/19/2023 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) 6/2/2023 13:00 6/2/2023 14:00 1.00 COMPZN, CASING PRTS P Test liner top packer to 3500 PSI for 5 minutes. Good test. 23,256.0 23,256.0 6/2/2023 14:00 6/2/2023 16:30 2.50 COMPZN, WELLPR DISP P Displace to 8.8ppg CI brine. 331 GPM 440 PSI 23,256.0 9,808.0 6/2/2023 16:30 6/3/2023 00:00 7.50 COMPZN, WELLPR PULD P POOH LD drill pipe. f/ 9808' to 2593'. 9,808.0 2,593.0 6/3/2023 00:00 6/3/2023 03:00 3.00 COMPZN, WELLPR PULD P POOH LD drill pipe. f/ 2593' to surface. 9,808.0 0.0 6/3/2023 03:00 6/3/2023 03:30 0.50 COMPZN, WELLPR PULD P LD running tool. All good. 0.0 0.0 6/3/2023 03:30 6/3/2023 04:00 0.50 COMPZN, WELLPR RURD P Retrieve wear bushing. 0.0 0.0 6/3/2023 04:00 6/3/2023 05:00 1.00 COMPZN, WELLPR CIRC P MU jetting tool and jet wellhead and BOP area. 0.0 0.0 6/3/2023 05:00 6/3/2023 06:30 1.50 COMPZN, RPCOMP RURD P RU to run upper completion 0.0 0.0 6/3/2023 06:30 6/3/2023 08:00 1.50 COMPZN, RPCOMP PULD P MU locator sub/DB nipple/Packer/Gauge mandrel. Terminate TEC line and test to 9500 PSI. 0.0 114.0 6/3/2023 08:00 6/3/2023 12:00 4.00 COMPZN, RPCOMP PULD P RIH f/ 114' to 3211' w/ 4 1/2" H563 tbg installing clamps at each connection. Test TEC line every 25 jts. 114.0 3,211.0 6/3/2023 12:00 6/3/2023 19:30 7.50 COMPZN, RPCOMP PULD P RIH f/ 3211' to 9816' w/ 4 1/2" H563 tbg installing clamps at each connection. Test TEC line every 25 jts. 3,211.0 9,817.0 6/3/2023 19:30 6/3/2023 20:00 0.50 COMPZN, RPCOMP PULD P Tag NO GO @ 9816'. Observe shear on NO GO @ 13 K down. P/U and L/D 3 Jts of tubing. 9,817.0 9,817.0 6/3/2023 20:00 6/3/2023 21:00 1.00 COMPZN, RPCOMP PULD P MU pup joints for space out. 9.67'/9.76'/3.84'/1.76'. MU JT # 233. RIH. MU Tbg hanger and landing joint. 1.45' off fully located. 9,817.0 9,817.0 6/3/2023 21:00 6/3/2023 22:30 1.50 COMPZN, RPCOMP PRTS P Terminate TEC line through Tbg hanger and test to 9500 PSi f/ 10 minutes. Good test. 9,817.0 9,817.0 6/3/2023 22:30 6/3/2023 23:30 1.00 COMPZN, RPCOMP PULD P Land hanger. RILDS. RU and test hanger 3000 PSi f/ 5 minutes. Good test. 9,817.0 9,817.0 6/3/2023 23:30 6/4/2023 00:00 0.50 COMPZN, RPCOMP RURD P RU to set packer and test. 9,817.0 9,817.0 6/4/2023 00:00 6/4/2023 01:30 1.50 COMPZN, RPCOMP PRTS P Pressure up tbg to 500 PSi. Hold f/ 5 minutes. Pressure up to 4200 PSI and set packer. Hold for 30 minutes testing tbg. Charted. Good test. 9,817.0 9,817.0 6/4/2023 01:30 6/4/2023 02:15 0.75 COMPZN, RPCOMP PRTS P Bleed off tbg pressure to 3000 PSI. Pressure up IA to 3500PSI. Hold f/ 30 minutes. Charted good test. Bleed off tbg to 0 PSi. Observed shear and verify Tbg and IA bled to 0 PSI. 9,817.0 9,817.0 6/4/2023 02:15 6/4/2023 02:45 0.50 COMPZN, RPCOMP OWFF P Flow check. Static. 9,817.0 9,817.0 6/4/2023 02:45 6/4/2023 04:00 1.25 COMPZN, WHDBOP PRTS P Pull landing joint and LD, Install HP BPV. Pressure up to 3500 PSi on IA f/ 10 minutesto test BPV. Charted. Good test. 0.0 0.0 6/4/2023 04:00 6/4/2023 06:30 2.50 COMPZN, WHDBOP NUND P ND riser,Joes box, ND BOP. Prep wellhead. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 44/44 MT7-95 Report Printed: 6/19/2023 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) 6/4/2023 06:30 6/4/2023 12:00 5.50 COMPZN, WHDBOP NUND P Terminate TEC line Install test dart in BPV. NU wellhead adapter and 5k tree. Perform final termination of TEC wire. Test adapter flange to 5000 PSI. f/ 10 minutes. Good test. Test tree to 250/5000 PSi f/ 10 minutes each. Good test. SimOps: Bridal up top drive and lower derrick. 0.0 0.0 6/4/2023 12:00 6/4/2023 13:30 1.50 COMPZN, WHDBOP RURD P Pull HP BPV. RU to freeze protect. 0.0 0.0 6/4/2023 13:30 6/4/2023 15:30 2.00 COMPZN, WHDBOP FRZP P Test lines to 3500 PSi. Pump 85 BBLS diesel down IA. 2 BPM FCP 839 PSI. Line up and Utube Tbg/IA. Final pressure. IA 120 PSI/ OA 70 PSI/ TBG 40 PSI. 0.0 0.0 6/4/2023 15:30 6/4/2023 16:00 0.50 DEMOB, MOVE RURD P RD circulating lines. Clean and clear cellar. Note: Release rig @ 16:00hrs 6/4/23 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 6/4/2023 Page 1/1 MT7-95 Report Printed: 6/19/2023 Cement Cement Details Description Surface String Cement Cementing Start Date 5/6/2023 14:38 Cementing End Date 3/8/2023 18:00 Wellbore Name MT7-95 Comment Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4.0 bbls/min, 354 psi, Dropped bottom plug. Start batching lead. Pump 417 bbls of 11.0 ppg DeepCRETE cement at 4.8 bbls/min, 450 psi ICP. Batch and pump 70 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 290 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 231 psi ICP, 515 psi FCP. Slow pumps 20 bbls prior to calculated bump to 3 bbls/min, 336 psi ICP, Bump plug with 850 psi (531 bbls + 20 bbls). 4493 strokes, final circ. PSI 350 Pressure up to 850 psi & hold for 5 minutes. Bleed off pressure, Check floats good (7.3bbls pumped, 6.4bbls returned). 165 bbls cement to surface. Cement in place @ 18:00hrs 05/06/23 Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 39.2 Bottom Depth (ftKB) 3,742.0 Full Return? Yes Vol Cement … 165.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 8 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 6 P Pump Final (psi) 336.0 P Plug Bump (psi) 850.0 Recip? Yes Stroke (ft) 10.00 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 Lead Cement Fluid Description Estimated Top (ftKB) 39.0 Est Btm (ftKB) 3,242.0 Amount (sacks) 1,220 Class G Volume Pumped (bbl) 417.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 6.81 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 343.0 Thickening Time (hr) 6.59 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 3,242.0 Est Btm (ftKB) 3,742.0 Amount (sacks) 337 Class G Volume Pumped (bbl) 70.8 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 5.13 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 105.0 Thickening Time (hr) 5.01 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 MT7-95 Report Printed: 6/19/2023 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 5/14/2023 02:00 Cementing End Date 5/14/2023 06:12 Wellbore Name MT7-95 Comment Blow down top drive, test lines to 3500psi (all ok) Mix and pump 60 bbls of 12.5 ppg Mud Push II @ 4.0 bbls/min, 464 psi, Dropped bottom plug. Start batching lead. Pump 135 bbls of 13.0 ppg Extended class G cement at 3.5 bbls/min, 375 psi ICP. Batch and pump 79 bbls of G Blend Tail 15.8 ppg cement @ 4.0 bbls/min, 500 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 6 bbls/min, 252 psi ICP, 950 psi FCP. Slow pumps 14 bbls prior to calculated bump to 3 bbls/min, 700 psi FCP, Plug didn't bump (697.3 bbls + 20 bbls water + 1.85bbls compression). 8264 strokes, final circ. 700 PSI. Bleed off pressure, Check floats good. Full returns. Cement in place @ 06:12hrs 5/14/23 full. Check floats (all good) Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 6,892.0 Bottom Depth (ftKB) 9,699.5 Full Return? Yes Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 700.0 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 Plug didn't bump Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 6,892.0 Est Btm (ftKB) 8,699.0 Amount (sacks) 387 Class G Volume Pumped (bbl) 135.0 Yield (ft³/sack) 1.89 Mix H20 Ratio (gal/sack) 10.27 Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 8,699.0 Est Btm (ftKB) 9,699.5 Amount (sacks) 380 Class G Volume Pumped (bbl) 79.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 5.05 Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 1 Cement Page 1/1 MT7-95 Report Printed: 6/19/2023 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 5/19/2023 05:00 Cementing End Date 5/19/2023 06:37 Wellbore Name MT7-95 Comment Pressure test line to 4500psi. Pump 70bbls KCL w/ rig. Drop bottom dart. Swap to cementers.Mix and pump 62bbls 15.8ppg cement @ 4.3BPM. SD and drop top dart.Pump 10bbl FW w/ cementers. Swap over to rig pumps and displace cement w/ 203.7bls 11.5ppg NAF. 2408stks pumped. FCP 411 PSI. Pressure up to 1184 PSI and hold f/ 5 min. Bleed off and check floats. Good. Cement in place. @ 0631hrs 5-19-23 Note: Bottom dart lands and shears bottom plug at 1060stks 900psi while pumping at 3bpm 78psi. Staged up pumps to 6bpm 290psi. Alow pump rate to 3bpm, Bottom plug land at 1675stks and shear at 1353psi, Top dart lands 1776stks and shears at 1500psi, Increase rate to 5bpm, Bump plug at 2408stks 3.2bbls early. FCP at 3bpm 411psi, bumped and pressure up to 1184psi, held for 5min. Bled off and floats holding. Full returns, Cement in place at 0637hrs. TOL @ 9,532' FS @ 11,032' MD. Cement Stages Stage # 1 Description Liner Cement Objective Top Depth (ftKB) 10,384.0 Bottom Depth (ftKB) 11,032.0 Full Return? Yes Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 411.0 P Plug Bump (psi) 1,184.0 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 Tail Cement Fluid Description Estimated Top (ftKB) 10,384.0 Est Btm (ftKB) 11,032.0 Amount (sacks) 295 Class G Volume Pumped (bbl) 62.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 4.59 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 2 Cement ! " # $" !%&'( ) * + $* ,$&"$ * !- * * * . * !" !" $$ "* ## "$ %&'()!* " /* !" $$.$ *+( , * "$ %&'()!* " * !" $ +* $+* ) $ 0 * + $+*- (! .+/ $ 0 (! .11-0 2 , 2- , 345 6 - 7 $ - 77 $ $ $ ,/" * ,$" * 1$ /* /* 213& 2 3& 4 $ ", * !" 4*44 4*44 "2!("288(* !42((5*! (44*94 $"1 $*4*44 4*44 4:(4;5*5(! 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B=CBB."0 52)!!*9 !(*88 ("*!8 8259 *9" !2989*( )2""8*482) *!4 "2!492(44*" !)254*!4 4*() (42)(8*!8 B=CBB."0 525!5*( !4* ) (")*(( 8259"*"4 !2 4*5 )294(*482)"* " "2!4924("*(9 !)255)*) (* (425(*8" B=CBB."0 52"8 *)) !4* ("*!4 82595*) !28")*5 )295)*))82)5*" "2!4"2!)4*!8 !)258)*)" 4*) (42"4"*55 B=CBB."0 5298*4" !(*58 (")*(5 8259*"4 !2!) *8 )2989*!82)* " "2!4"285"*5) !)2")*!9 4*85 (42"!!*" B=CBB."0 52 9*9" !4*"( (")*( 82594*89 (424* )2 8*!882)(*(( "2!4"2 "!*8 !)2"95*8 (*4) (429!)*"( B=CBB."0 5284)*44 !4*"( (")*( 82594*9 (4245"* ! )2 54*8"82)4*8 "2!4"2 )9*4) !)2" "*"4 4*44 (42 (!* 4 B=CBB."0 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Jun 19, 2023 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-95 Greater Mooses Tooth API #: 50-103-20854-00 Permit No: 223-035 Rig: Doyon 25 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. MT7-95 is located in a federal oil and gas unit. Only with respect to the MT7-95 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: Garrett Brown Garrett.Brown@conocophillips.com Luis Arismendi Luis.arismendi@bakerhughes.com PTD:223-035 T37758 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.19 15:36:58 -08'00' t >>ED W/η^ Zs/ KZ Zη&/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' K>KZWZ/Ed^ ƐGMTU MT7-95 50-103-20854-00-00 223-035 GMTU MEMORY Top of CementPROCESSED 29-May-23 1ĞůŝǀĞƌLJZĞĐĞŝƉƚͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺWƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞWůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘sdƵŽŶŐΛƐůď͘ĐŽŵ^>ƵĚŝƚŽƌͲĞůŝǀĞƌLJZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚ͘dŚĞƉĂĐŬĂŐĞǁŝůůďĞŚĂŶĚůĞĚͬĚĞůŝǀĞƌĞĚƉĞƌƐƚĂŶĚĂƌĚĐŽŵƉĂŶLJƌĞĐĞƉƚŝŽŶƉƌŽĐĞĚƵƌĞƐ͘dŚĞƉĂĐŬĂŐĞΖƐĐŽŶƚĞŶƚƐŚĂǀĞŶŽƚďĞĞŶǀĞƌŝĨŝĞĚďƵƚƐŚŽƵůĚďĞĂƐƐƵŵĞĚƚŽĐŽŶƚĂŝŶƚŚĞĂďŽǀĞŶŽƚĞĚŵĞĚŝĂ͘η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞPTD: 223-035T37755Kayla JunkeDigitally signed by Kayla Junke Date: 2023.06.15 13:51:37 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?MT7-95 Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Greater Mooses Tooth Rendezvous 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 24803 8460.62 23209 8480 3063 None None Casing Collapse Structural Conductor Surface 2260 Intermediate 1 5090 Intermediate 2 7030 Liner 7500 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Planned 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Yes Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Dustin Morrow Contact Email: Contact Phone: 832-493-9141 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): 9699 NA 1499.7 4.5 NA 2325613448 4-1/2" 8482 7 20 13.375 80 9.6259739 3782 8160 MD 8150 5020 40 3037 7458 40 3742 817311032 Length Size Proposed Pools: TVD Burst Rendezvous PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA081800,AA081781 223-035 P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20854-00-00 ConocoPhillips 8430 Victoria Loepp 6/2/2023 Tubing Grade: Tubing MD (ft): Packer set planned @ 9778' MD / 7519' TVD Perforation Depth TVD (ft): Tubing Size: L-80 9812 6/2/2023 Halliburton TNT Production Packer / NO SSSV 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY dustin.w.morrow@cop.com Staff Completions Engineer Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:57 am, Jun 05, 2023 323-326 Pre-produced Injector VTL 6/12/2023 X 120' ? SFD file with PTD 10-407 SFD SFD 6/5/2023 120' ? SFD Pre-produced Injector BOP test to 3500 psig All conditions listed on the original PTD are effective. Variance is granted to Rendevous AIO 2 to allow the liner top packer(9808' MD) to be placed at the 7" TOC(9806' MD) based on the attached analysis. SFD X DSR-6/12/23GCW 06/13/2023 JLC 6/13/2023 06/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.13 17:09:48 -08'00' RBDMS JSB 061423 Tubing / Liner Completion: 1) 4-½” Landing Nipple (3.813" ID) 2) 4-½” x 1” GLM KBG 4-5 (3x) 3) HES Downhole Gauge 4) Production Packer 5) 4-½” Landing Nipple (3.75" ID) 6) Liner Top Packer / Hanger w/ Tie Back sleeve 7) Recloseable Frac Sleeve / Swell Packers 4-½” 12.6# L80 H563 Liner (Set @ Approx. 23,256’MD/8482'TVD) AU dart-drop recloseable sliding sleeves spaced evenly throughout lateral & isolated by swell packers Liner Top Packer @9,808' MD / 7541' TVD Int1 TOC ~6,000' MD / ~4,331' TVD MT7-95 4-String Northern Combined Lateral Injector Proposed Schematic 20" 94 ppf H-40 Insulated Conductor 120 feet, cemented to surface 16" Surface Hole Surface Casing 13-3/8" 68# L80 H563 Set at 3,742' MD / 3'037 TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8 9-5/8" 47# T95 H563 Set @ +/- 9,699' MD / 7,458' TVD Top Confining Zone 9,672' MD / 7,436' TVD Top Alpine D 11,001' MD / 8,167' TVD Top Alpine C 11,264' MD / 8,226' TVD 6-1/8” Production Hole TD at 24,803' MD / 8,460' TVD Int2 TOC 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7" 29# L80 H563 Liner top at +/- 9,532' MD / 7,324' TVD Shoe set @ +/- 11,032' MD / 8,173' TVD GL X GL DHG GL ubingT 4-1/2" 12.6# L80 H563 Injection Packer @ 9778'MD / 7519' TVD 627ft TVD above Alpine D ~9,806' MD / ~7,540' TVD 1 Morrow, Dustin W From:Metzgar, Kyle N Sent:Friday, June 2, 2023 12:59 PM To:victoria.loepp@alaska.gov; melvin.rixse@alaska.gov Cc:Morrow, Dustin W; Livingston, Erica J; Hobbs, Greg S; Taylor, Jenna Subject:MT7-95 Variance Request for AOGCC Victoria and Mel, We appreciate you meeƟng with us this morning to beƩer understand our proposed path forward on MT7-95 due to landing the producƟon liner shallower than planned. This e-mail is to document the verbal approval given during the meeƟng and will also be followed up with a 10-403 Sundry. As discussed, our 4.5 in. liner top packer (LTP) and injecƟon packer will be set above the 7 in. top of cement (TOC) and below the 9-5/8 in. casing shoe in the ~107 Ō MD exposed to the HRZ (which is a part of the con Įning interval) on the backside. This interval is prone to collapse and is an Ɵcipated to provide isolaƟon in this area. AddiƟonally, the 9-5/8” shoe is set within the HRZ with a TOC at 6,000 Ō MD. AƩached are cement quality logs of both the 7 in. and the 9-5/8 in. cement as well as a schemaƟc showing the depths of the 4.5 in. liner top packer (LTP), the 7 in. and 9-5/8 in. cement, and top of the HRZ (conĮning interval). Below you can Įnd the log with the various per Ɵnent depths for our case. MT7-95 real Ɵme logs showing the Rendezvous Oil Pool (ROP) and Upper ConĮning Zone (UCZ). The UCZ for the ROP is the deep marine shales of the HRZ, Kalubik, and Miluveach as deĮned in AIO 43. INT1 of the MT7-95 is set below the top of the HRZ and within the UCZ. The fracture loss gradient of the UCZ ranges between 14.7 and 15.8 PPG. The fracture loss gradient of the HRZ is 15.4 PPG. The fracture loss gradient of the Alpine C within the ROP is 11.3 PPG 2 This e-mail requests a variance to the Rendezvous AIO Rule 2 requirement that states “shall have outer casing cement volume suĸcient to place cement a minimum of 300 feet measured depth above the planned packer depth” as the new design will have the conĮning HRZ interval outside the 7 in. at the injec Ɵon packer depth and 78Ō above to the 9-5/8 in. casing shoe. The 9-5/8 in. intermediate 1 string has 3,672 Ō of good quality cement above that. Thank you again for the conversaƟon. Kyle Metzgar Kyle Metzgar| Completions Engineering Supervisor – Alaska | ConocoPhillips | w +1 (832) 486-2732 | c +1 (832) 785-2646 | f +1 (918) 662-6415 | e kyle.n.metzgar@cop.com 1 Christianson, Grace K (OGC) From:Metzgar, Kyle N <Kyle.N.Metzgar@conocophillips.com> Sent:Friday, June 2, 2023 2:12 PM To:Loepp, Victoria T (OGC) Cc:Rixse, Melvin G (OGC); Livingston, Erica J Subject:RE: [EXTERNAL]MT7-95 Variance Request for AOGCC APPROVAL through email ThankyoufornotingthatdistinctionVictoria.Weappreciateyoursupport. Thanks, Kyle (832)785Ͳ2646 From:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Sent:Friday,June2,20231:50PM To:Metzgar,KyleN<Kyle.N.Metzgar@conocophillips.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Livingston,EricaJ<Erica.J.Livingston@conocophillips.com> Subject:[EXTERNAL]MT7Ͳ95VarianceRequestforAOGCCAPPROVALthroughemail 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. Kyle, Theapprovalisgrantedthroughthisemailandnotthroughthedialogueinthemeetingthismorning.Isaidinthe meetingwewouldgrantverbalapprovalthroughtheapprovalofasubmittedemail.Theapprovalisgrantedforthepath forwardasoutlinedbelowthroughthisemail. Pleasesubmita10Ͳ403ChangeofApprovedSundryassoonaspossible. VictoriaLoepp SentfrommyiPhone OnJun2,2023,at2:58PM,Metzgar,KyleN<Kyle.N.Metzgar@conocophillips.com>wrote: VictoriaandMel, Weappreciateyoumeetingwithusthismorningtobetterunderstandourproposedpathforwardon MT7Ͳ95duetolandingtheproductionlinershallowerthanplanned.ThiseͲmailistodocumentthe verbalapprovalgivenduringthemeetingandwillalsobefollowedupwitha10Ͳ403Sundry. 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 Asdiscussed,our4.5in.linertoppacker(LTP)andinjectionpackerwillbesetabovethe7in.topof cement(TOC)andbelowthe9Ͳ5/8in.casingshoeinthe~107ftMDexposedtotheHRZ(whichisapart oftheconfininginterval)onthebackside.Thisintervalispronetocollapseandisanticipatedtoprovide isolationinthisarea.Additionally,the9Ͳ5/8”shoeissetwithintheHRZwithaTOCat6,000ftMD. Attachedarecementqualitylogsofboththe7in.andthe9Ͳ5/8in.cementaswellasaschematic showingthedepthsofthe4.5in.linertoppacker(LTP),the7in.and9Ͳ5/8in.cement,andtopofthe HRZ(confininginterval). Belowyoucanfindthelogwiththevariouspertinentdepthsforourcase.MT7Ͳ95realtimelogs showingtheRendezvousOilPool(ROP)andUpperConfiningZone(UCZ).TheUCZfortheROPisthe deepmarineshalesoftheHRZ,Kalubik,andMiluveachasdefinedinAIO43.INT1oftheMT7Ͳ95isset belowthetopoftheHRZandwithintheUCZ.ThefracturelossgradientoftheUCZrangesbetween14.7 3 and15.8PPG.ThefracturelossgradientoftheHRZis15.4PPG.ThefracturelossgradientoftheAlpine CwithintheROPis11.3PPG ThiseͲmailrequestsavariancetotheRendezvousAIORule2requirementthatstates“shallhaveouter casingcementvolumesufficienttoplacecementaminimumof300feetmeasureddepthabovethe plannedpackerdepth”asthenewdesignwillhavetheconfiningHRZintervaloutsidethe7in.atthe 4 injectionpackerdepthand78ftabovetothe9Ͳ5/8in.casingshoe.The9Ͳ5/8in.intermediate1string has3,672ftofgoodqualitycementabovethat. Thankyouagainfortheconversation. KyleMetzgar KyleMetzgar|CompletionsEngineeringSupervisor–Alaska|ConocoPhillips | w+1(832)486Ͳ2732|c+1(832)785Ͳ2646|f+1(918)662Ͳ6415|ekyle.n.metzgar@cop.com STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-95 JBR 07/24/2023 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 21 day test cycle. BLM 5 min low/10 min high. Tested with 4" and 5" test joints. CMV #2 was a FP greased and excercised, Manual choke valve was also a FP greased and passed. While greasing the Manual choke valve they took the time to grease all valves and had zero failures after that. Test Results TEST DATA Rig Rep:Zach ColemanOperator:ConocoPhillips Alaska, Inc.Operator Rep:Percy Angelle Rig Owner/Rig No.:Doyon 25 PTD#:2230350 DATE:5/20/2023 Type Operation:DRILL Annular: 250/2500Type Test:OTH Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSTS230519130725 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 3063 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 4 P Inside BOP 2 P FSV Misc 0 NA 15 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 2 7/8X5 1/2 P #2 Rams 1 blind shear P #3 Rams 1 2 7/8X5 1/2 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 FP HCR Valves 2 3 1/8 P Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1600 200 PSI Attained P16 Full Pressure Attained P115 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2025 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P13 #2 Rams P14 #3 Rams P14 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9999 9 9 9 7HVW&KDUWVDWWDFKHG FP FP CMV #2 was a FP Manual choke valve was also a FP %23(7HVW'R\RQ *07807 $2*&&,QVS5SWERS676 %23(7HVW'R\RQ *07807 $2*&&,QVS5SWERS676 %PZPO 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 ConocoPhillips P.O. Box 100360 Anchorage, AK, 99510 Re: Greater Mooses Tooth, Rendezvous, MT7-95 ConocoPhillips Permit to Drill Number: 223-035 Surface Location: 1063' FSL, 2035' FWL, SESW S32 T10N R2E, UM Bottomhole Location: 599' FSL, 957' FWL, SESE S9 T9N 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, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of April, 2023. 20 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.20 16:12:15 -08'00' 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 25,892 TVD: 8,443 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: 2/28/2023 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4323' to AA081780 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 139.5 15. Distance to Nearest Well Open Surface: x-290115 y- 5915881 Zone- 4 100.8 to Same Pool: 5518' to MT7-96 16. Deviated wells:Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 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" 68 L-80 Hyd563 3653 40 40 3693 3009 12-1/4" 9-5/8" 43.5/47 L-80/T-95 Hyd563 9689 40 40 9729 7485 8.5" x 9-7/8"7" 29.00 L-80/P-110 Hyd563 1453 9579 7373 11032 8174 6-1/8" 4.5" 12.60 P-110 Hyd563 15010 10882 8062 25892 8443 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: Weifeng Dai Chris Brillon Contact Email:Weifeng.Dai@conocophillips.com Wells Engineering Manager Contact Phone:907-947-4323 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 125 sx 15.8 ppg Class G Uncemented liner w/frac sleeves & swell packers Effect. Depth MD (ft):Effect. Depth TVD (ft): Authorized Title: Authorized Signature: Authorized Name: LengthCasing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 18. Casing Program:Top - Setting Depth - BottomSpecifications 3907 3063 ConocoPhillips 1063' FSL, 2035' FWL, SESW S32 T10N R2E, UM AA081800,AA081781 3776, 5720 59-52-180 3213' FSL, 4707' FWL , SESW S31 T10N R2E, UM 599' FSL, 957' FWL, SESE S9 T9N R2E, UM 932535000, 932516000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry 424 sx 13.0 ppg Class G + 250 sx 15.8 ppg C Total Depth MD (ft):Total Depth TVD (ft): 1332 sx 11.0 ppg DC + 238 sx 15.8 ppg Clas MT7-95 Greater Mooses Tooth Rendezvous Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. d:: Y: Y YYYYYYYYYYYYYYYYYYYYYYYeeees ype of W l 1b S Class: os N d:::Yeeees NNNNo s N NNNNo Dril s s s T Dril 0 o haaaaleslessseeeeeeeeeeeeeeeeeee: well is G S S 2 SS S d:::Yeeees NNNNo s No S G y E S d:::YeYeees NNNNo s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Kayla Junke at 10:56 am, Apr 17, 2023 223-035 DSR-4/17/23 X 50-103-20854-00-00 Initial BOP test to 5000 psig Subsequesnt BOP test to 3500 psig Annular preventer test to 2500 psig BOP test to 3000 psig approved while drilling the Int1 section The alternate BOP configuration attached while drilling the Int 1 is approved Diverter variance granted per 20 AAC 25.035(h)(2) Waiver for CPAI Rotary Ric BOPE Test Frequency applies according to order OTH-21-018 extension attached 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. 4/27/2023 VTL 04/20/2023 MDG 4/20/2023 Service - WAGSSSSSS GCW 04/20/23JLC 4/20/2023 4/20/2023Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.04.20 16:13:19 -08'00' 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 2, 2023 Mr. Luke Lawrence Wells Manager ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Re: Docket Number: OTH-21-018 CPAI Rotary Rig BOPE Test Frequency Dear Mr. Lawrence: By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope. OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25, 2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6, 2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of the CPAI-operated rigs during 2022 in considering the requested continuance.1 During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21- day intervals.2 CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions: - The pilot test duration is for ONE year from the approval date of this letter, subject to potential extension and expansion to include other CPAI operated rigs with at least 3 months of continuous rig work and AOGCC review of a rig’s BOPE system reliability. 1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of component failures during BOPE testing by replacing components that indicate suspect integrity before those components fail during testing. 2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre- determined time intervals while drilling specific sections in an ultra-extended reach well. Docket Number: OTH-21-018 March 2, 2023 Page 2 of 2 - CPAI must continue to implement the BWM program as approved by AOGCC. - Development drilling wells only are included in this approval. - 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. - 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. - 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to witness. If you have questions regarding this, please contact Jim Regg at (907) 793-1236. Sincerely, Brett W. Huber, Sr. Chair, Commissioner cc: Greg Hobbs (CPAI) Mike Kneale (CPAI) Victoria Loepp (AOGCC) AOGCC Inspectors (email) Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.02 11:09:23 -09'00' GMT MT7-ϵϱ 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. g as soon as they become available. Saved: 1/4/2023 Page 1 MT7-95 Intermediate 1 MPSP Review & Ram Configuration Proposal Requesting approval to use a BOPE stack equipped with an annular preventer, fixed 9-5/8” solid body rams, blind/shear rams and, variable rams (2-7/8” x 5-1/2”) while drilling and running casing in the Intermediate 1 section of MT7-95. The Maximum Potential Surface Pressure (MPSP) is expected to be 1,983 psi while drilling the 12-1/4” Intermediate 1 hole section with 5” drill pipe, satisfying 20 AAC 25.035.e.1.A. Please find the review below for more detail. 20 AAC 25.035.e.1.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sixed to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Proposed Configuration: x Annular Preventer (iii) x 9-5/8” Solid Body Rams x Blind/Shear Rams (ii) x 2-7/8” x 5-1/2” VBR’s (i) Saved: 1/4/2023 Page 2 Pore Pressure Assessment A Normal Compaction Trend (NCT) is defined using the Bowers Method on a calibration well with little/no erosion and global constants as a starting point. Both source rock and non-source rock NCTs are then defined. For a given unit/zone, deviations slower than NCP indicate overpressure and allow calculation of its magnitude. The NCT for individual wells is defined by modifying Bowers parameters to account for specific erosion amounts. The maximum estimated reservoir pressure in the Intermediate 1 section is 9.4 ppg Interval TVD Top TVD Base Max PPG Note Surface to Permafrost_Base 0 977 8.3 Hydrostatic Permafrost_Base to C40 977 1079 9.1 Hydrostatic C40 to C30 1079 1405 9.2 Rendezvous-2 DT Estimate C30 to C20 1405 1642 8.45 Hydrostatic C20 to C10 1642 1986 8.475 Hydrostatic C10 to K3 1986 2999 9.3 Rendezvous-2 DT Estimate K3 to Albian_97 2999 3607 8.55 Hydrostatic Albian_97 to Albian_96 3607 3788 8.56 Hydrostatic Albian_96 to Albian_95 3788 3972 8.56 Hydrostatic Albian_95 to Albian_94 (Tusk Sand if present) 3972 4240 8.56 Hydrostatic Albian_94 to Albian_93 4240 4895 8.57 Hydrostatic Albian_93 to Albian_92 4895 6061 8.6 Hydrostatic Albian_92 to Albian_91 6061 6121 8.6 Hydrostatic Albian_91 to HRZ (Susitna Sand if present) 6121 7396 9.4 Offset Well DT/ Res Estimates HRZ to LCU 7396 7591 11.6 Offset Well DT/ Res Estimates LCU to Alpine_D 7591 8237 11.75 Offset Well DT/ Res Estimates Alpine_D to Alpine_C 8237 8263 11.4 MT7-04 Res Est. Alpine_C to UJU 8263 8359 8.8 Offset MDT’s Saved: 1/4/2023 Page 3 Maximum Potential Surface Pressure Surface Casing Point: 3693' MD/ 3008' TVD Intermediate 1 Casing Point: 9729' MD/ 7486' TVD Max Anticipated Pore Pressure: 9.4 ppg | Albian 91 > HRZ Surface Casing Shoe FG: 14.5 ppg EMW | K3 Maximum Potential Surface Pressure (MPSP) 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: Method 1 Method 2 ܯܲܵܲ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ ܯܲܵܲ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ) × ܸܶܦ Where: FG – Fracture gradient at the casing seat in lb/gal 0.052 – Conversion from lb/gal to psi/ft Gas Gradient – 0.1 psi/ft TVD – True Vertical Depth of casing seat in ft RKB Where: FPP – Formation Pore Pressure at the next casing point MPSP CALCULATIONS: Method 1: ࡹࡼࡿࡼ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ MPSP = [(14.5 ݃ ܧܯܹ × 0.052 )െ 0.1] × ͵ͲͲͺԢ MPSP = 1967 psi Method 2: ࡹࡼࡿࡼ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ) × ܸܶܦ MPSP = (9.4 ݃ ×0.052× ͶͺԢ )െ (0.1 × 7486 ᇱ ) MPSP = 2910 psi ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 19, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-95 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand injector well from the MT7 drilling pad. The intended spud date for this well is 2/28/2023. It is intended that Doyon 25 be used to drill the well. MT7-95 will utilize a 16” surface hole and will TD above the K3 sand and then 13-3/8" 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" 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”liner string will be set and cemented from TD to seccure the shoe and cover 500’ MD or 250’ TVD above any hydrocarbon bearing zone. The production interval will be comprised of a 6-1/8" x 6-5/16" 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 frac 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. 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) 7. Area of review 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 Joe Longo at 907-265-6936 (Weifeng.Dai@conocophillips.com) or Greg Hobbs at 907-263-4794 (greg.s.hobbs@conocophillips.com). Sincerely, cc: MT7-95 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1552 Weifeng Dai Chris Brillon ATO 1548 Staff Drilling Engineer Andy Mack Kuukpik Corp pgg a 500’ MD or 250’ TVD column of cement above the highest hydrocarbon bearing zone p MT7-95 Saved: 19-Jan-23 MT7-95 Page 1 of 14 Printed: 19-Jan-23 MT7-95 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 ...................................................................................... 4 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)) ............................................................................................................... 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 ..................................................................................... 12 15. Proposed Completion Schematic ......................................................................... 14 MT7-95 Saved: 19-Jan-23 MT7-95 Page 2 of 14 Printed: 19-Jan-23 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-95 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1063' FSL, 2035' FWL, SESW S32 T10N R2E, UM NAD27 Northings: 5915881 Eastings: 290115 RKB Elevation 38.7’ AMSL Pad Elevation 100.8’ AMSL Top of Productive Horizon (Heel) 3213' FSL, 4707' FWL , SESW S31 T10N R2E, UM NAD27 Northings:5918099 Eastings: 287706 Measured Depth, RKB: 11,100’ Total Vertical Depth, RKB: 8,191’ Total Vertical Depth, SS: 8,052’ Total Depth (Toe) 599' FSL, 957' FWL, SESE S9 T9N R2E, UM NAD27 Northings: 5904745 Eastings: 294044 Measured Depth, RKB: 25,892’ Total Vertical Depth, RKB: 8,443’ Total Vertical Depth, SS: 8,303’ Please see attached well stick diagram for the current planned development of the pad. MT7-95 Saved: 19-Jan-23 MT7-95 Page 3 of 14 Printed: 19-Jan-23 Pad Layout Well Stick Diagram MT7-95 Saved: 19-Jan-23 MT7-95 Page 4 of 14 Printed: 19-Jan-23 3. Proposed Drilling Program MT7-95 Saved: 19-Jan-23 MT7-95 Page 5 of 14 Printed: 19-Jan-23 1. MIRU Doyon 25 onto well over pre-installed 20” insulated conductor. Install diverter and function test. 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” 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, 9-5/8” casing ram, blind ram and 2-7/8” x 5-1/2” 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 12.0 ppg Versaclean OBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and POOH. 14. Send OH logs to AOGCC to review shallow hydrocarbon bearing sands as soon as available. 15. Run 9-5/8” 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 9-5/8” solid body rams to 4-1/2” x 7” 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 LOT, flush and freeze protect with the ball mill. 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. As an identified contingency plan: If Casing Drilling is required due to Geologic Instability in intermediate 2 section, refer to below steps: 1. Pick up and run in hole with the 7” steerable drilling liner. Pick up and stab in 6” pilot BHA assembly (LWD program: GR/RES) 2. RIH to bottom with 7” SDL on 5” drill pipe. 3. Drill 7” SDL hole to production casing point into the Alpine C sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD program: GR/RES) 4. Land 7” liner at TD. Disconnect SDL and POOH to surface with inner string and pilot BHA. 5. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparation for cementing. potential for the presence of the Tusk sand, MT7-95 Saved: 19-Jan-23 MT7-95 Page 6 of 14 Printed: 19-Jan-23 6. Cement 7” liner to top of liner. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5” drill pipe. 7. Continue to Step 24 below 23. Circulate wellbore clean, wait up to tripping MW and POOH. 24. Pick up and run in hole with the 7” liner on 5” DP to section TD. 25. Circulate and condition mud in preparation for cementing. 26. Cement 7” liner to required TOC. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5” drill pipe. Submit results to AOGCC as soon as possible. 27. Change out upper rams to 2-7/8” x 5-1/2” VBR. 28. Pick up 4” DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 29. Pick up and RIH with 6-1/8” drilling assembly. (LWD Program: GR/Azimuthal RES). 30. Chart casing pressure test to 3,500 psi for 30 minutes and record results. 31. Drill out and perform FIT to 13.5 ppg EMW. 32. Drill 6-1/8” horizontal hole to TD (LWD Program: GR/Azimuthal RES, Neu/Den). 33. Circulate the hole clean and POOH. 34. Run 4-1/2” liner on 4” x 5” DP, set liner hanger and top packer. Test to confirm packer set. Release from hanger and displace well to KW brine. POOH and laying down DP. 35. 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. 36. Test tubing hanger seals from above to 2,500 psi for 15 mins. 37. Drop ball and rod. Pressure up to set TNT production packer. 38. Pressure test tubing to 4,200 psi for 30 mins. Test IA to 3,500 psi for 30 mins. Shear SOV. 39. Install BPV, test same and tubing hanger seals from below to 2,500 psi. 40. Nipple down BOP, terminate TEC wire. 41. Install tubing head adaptor. Pressure test adaptor to 5,000 psi. 42. Install 5k tree and test. 43. Pull BPV, freeze protect IA and tubing. 44. 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 25 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 3,693 / 3,009 14.5 1364 1064 9.625 9,729 / 7,485 16.5 3353 1994 7.00 11,032 / 8,174 12.5 3712 2895 4.5 25,892 / 8,443 12.5 3907 3063 MT7-95 Saved: 19-Jan-23 MT7-95 Page 7 of 14 Printed: 19-Jan-23 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 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) = 1364 – (0.1 x 3009’) = 1064 psi Minimum MW needed = 8.7 ppg 2. Drilling below 13.375” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3049’ = 1994 psi OR ASP = FPP – (0.1 x D) = 3353 – (0.1 x 7485) = 2605 psi Minimum MW needed = 8.8 ppg 3. Drilling below first 9.625” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 7498 = 5683 psi OR ASP = FPP – (0.1 x D) = 3712– (0.1 x 8174’) = 2895 psi Minimum MW needed = 8.7 ppg 4. Drilling below 7” production liner ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8300 = 4565 psi OR MT7-95 Saved: 19-Jan-23 MT7-95 Page 8 of 14 Printed: 19-Jan-23 ASP = FPP – (0.1 x D) = 3907 – (0.1 x 8443) = 3063 psi Minimum MW needed = 9.0 ppg (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. 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 16 68 L-80 Hyd563 Cement to Surface 9.625 12.25 43.5/47 L-80/T-95 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7 8.5 x 9.875 29 L-80/ P-110 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 4.5 6.125 12.6 L-80 Hyd563 Uncemeneted open hole liner with frac ports and swell packers 13.375” Surface Casing run to 3,693’ MD /3,009’ TVD Cement Plan: Cement from 3,693’ MD to 3,193' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,193' to surface with 11.0 ppg DeepCrete. Assume 120% excess annular volume in permafrost and 50% excess below the permafrost (981’ MD), zero excess in 20” conductor. Lead slurry from 3,193’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 2,303 ft3 => 1,332 sx of 11.0 ppg Deepcrete + Add's @ 1.73 ft3 /sk Tail slurry from 3’693 MD to 3,193’ MD with 15.8 ppg Deepcrete + Add's Total Volume = 316 ft3 => 238.0 sx of 15.8 ppg Class G + Adds @ 1.33 ft3/sk VTL 4/19/2023 8.9 ppg EMW MT7-95 Saved: 19-Jan-23 MT7-95 Page 9 of 14 Printed: 19-Jan-23 9.625” Intermediate Casing run to 9,729’ MD / 7,485’ TVD Cement Plan: Primary cement job consists of 1000 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 6,982’ 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 8,729’ MD to 6,982’ with 13.0 ppg Class G + Add’s Total Volume = 711 ft3 => 424 sx of 13.0 ppg Class G + Add's @ 1.68 ft3 /sk Tail slurry from 9,729’ MD to 8,729’ MD with 15.8 ppg Class G + Add's Total Volume = 407 ft3 => 250.0 sx of 15.8 ppg Class G + Adds @ 1.63 ft3/sk 7” Intermediate Casing run to 11,032’ MD / 8,174’ TVD Cement Plan: Top of slurry is designed to be at 10,481’ MD, which is 500’MD or 250’ TVD above Alpine D. Assume 40% excess annular volume. Tail slurry from 11,032’ MD to 10,481’ MD with 15.8 ppg Class G + Adds Total Volume = 204 ft3 => 125 sx of 15.8 ppg Class G + Adds@ 1.63 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 9.625 7 4.5 Density PPG 9.0 – 10.0 11.0 – 12.0 10.0 – 13.0 8.5 – 9.5 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 r 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 10.0 ppg by use of solids control system and dilutions where necessary. MT7-95 Saved: 19-Jan-23 MT7-95 Page 10 of 14 Printed: 19-Jan-23 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 11.5 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 11.5 targeting 13.0 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 25 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)) Incidental fluids developed from drilling operations on well MT7-95 will be injected into a permitted annulus on the MT7 pad, or hauled to the Class 1 disposal well on CD1. The MT7-95 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to ~2000' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre- drill interpretations. Once MT7-95 has been drilled and completed, consideration may be given to permit this well for annular injection. MPD (y Managed Pressure Drilling (MPD) w MT7-95 Saved: 19-Jan-23 MT7-95 Page 11 of 14 Printed: 19-Jan-23 An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the C10 formation, above the K3. These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig’s specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3009’) + 1,500 psi = 3378 psi Pore Pressure = 1,381 psi Therefore Differential = 3378 – 1,364 = 2014 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 13.375” 68 L-80 3 Hyd563 2260 psi 1921 psi 5020 psi 4267 psi 9.625” 43.5 / 47 L-80 3 Hyd563 3810 psi 3238 psi 6330 psi 5380 psi MT7-95 Saved: 19-Jan-23 MT7-95 Page 12 of 14 Printed: 19-Jan-23 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375” 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” 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” 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 MT7-95 Saved: 19-Jan-23 MT7-95 Page 13 of 14 Printed: 19-Jan-23 control practices, mud scavengers 6.125” 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 the pilot and intermediate #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. Managed Pressure Drilling w Lower Shale Stability: MT7-95 Saved: 19-Jan-23 MT7-95 Page 14 of 14 Printed: 19-Jan-23 15. Proposed Completion Schematic 39 514514 10141014 15151515 20152015 25152515 30153015 50155015 80148014 1201512015 1601516015 19814MT7-95_wp02Plan SummaryMT7-95_wp0206Dogleg Severity0 3000 6000 9000 12000 15000 18000 21000 24000Measured DepthSurface CasingINT1INT250500901802703021060240 120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in]39273523769MT7-963927552577610271274MT7-97_wp0339275525774MT7-98392755257761027MT7-9907500True Vertical Depth-5250 -3500 -1750 0 1750 3500 5250 7000 8750 10500 12250Vertical Section at 158.97°Surface CasingINT1INT2075Centre to Centre Separation0 2500 5000 7500 10000 12500 15000 17500 20000 22500 25000Measured DepthMT7-01MT7-01MT7-01PB1MT7-01PB1MT7-96MT7-96MT7-97_wp03MT7-97_wp03MT7-97_wp03MT7-98MT7-98MT7-98MT7-99MT7-99MT7-99Equivalent Magnetic DistanceDDI7.122SURVEY PROGRAMDate: 2022-10-14T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool38.90 1000.00 MT7-95_wp02 (MT7-95) SDI_Keeper_ADK1000.00 2000.00 MT7-95_wp02 (MT7-95) MWD OWSG2000.00 3885.00 MT7-95_wp02 (MT7-95) MWD+IFR2+SAG+MS3885.00 4285.00 MT7-95_wp02 (MT7-95) MWD-INC_ONLY (INC>10°)4285.00 4700.00 MT7-95_wp02 (MT7-95) MWD OWSG4700.00 9729.00 MT7-95_wp02 (MT7-95) MWD+IFR2+SAG+MS9729.00 10029.00 MT7-95_wp02 (MT7-95) MWD-INC_ONLY (INC>10°)10029.00 10529.00 MT7-95_wp02 (MT7-95) MWD OWSG10529.00 11032.00 MT7-95_wp02 (MT7-95) MWD-INC_ONLY (INC>10°)11032.00 11532.00 MT7-95_wp02 (MT7-95) MWD OWSG11532.00 25892.21 MT7-95_wp02 (MT7-95) MWD+IFR2+SAG+MSSurface LocationNorth / 5915625.35East / 1430151.04Ground / 100.60CASING DETAILSTVD MDName3008.50 3692.62 Surface Casing7485.12 9729.00 INT18173.89 11032.00 INT28442.84 25892.21 PRODMag Model & Date: BGGM2016 31-Dec-17Magnetic North is 16.60° East of True North (Magnetic Declination)Mag Dip & Field Strength: 80.67° 57482.45nTSECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation1 38.90 0.00 0.00 38.90 0.00 0.00 0.00 0.00 0.002 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.003 700.00 3.00 325.00 699.91 4.29 -3.00 1.50 325.00 -5.084 1000.00 9.00 325.00 998.13 29.96 -20.98 2.00 0.00 -35.505 2831.92 54.80 325.73 2512.33 807.69 -553.29 2.50 0.83 -952.446 6309.61 54.80 325.73 4517.12 3155.95 -2153.54 0.00 0.00 -3718.577 9678.54 40.00 167.50 7446.47 3260.00 -2854.00 2.75 -166.19 -4067.078 9728.54 40.00 167.50 7484.77 3228.62 -2847.04 0.00 0.00 -4035.289 9778.54 40.00 167.50 7523.07 3197.24 -2840.09 0.00 0.00 -4003.5010 10981.81 75.00 156.63 8160.90 2254.85 -2515.05 3.00 -18.01 -3007.2411 11031.81 75.00 156.63 8173.84 2210.52 -2495.89 0.00 0.00 -2958.9812 11081.81 75.00 156.63 8186.78 2166.19 -2476.73 0.00 0.00 -2910.7213 11504.94 84.64 152.19 8261.53 1791.21 -2296.89 2.50 -24.82 -2496.1914 11762.82 84.64 152.19 8285.64 1564.12 -2177.11 0.00 0.00 -2241.2415 12004.40 89.40 153.00 8298.20 1350.00 -2066.10 2.00 9.65 -2001.5416 25892.21 89.41 153.00 8442.84 -11023.50 4238.40 0.00 7.27 11810.23FORMATION TOP DETAILSTVDPath Formation979.51 Perma_Frost1084.69 C401417.43 C301645.04 C201995.66 C102980.14 K33008.96 SCP3588.27 Albian_973786.13 Albian_963993.30 Albian_954543.51 Albian_944963.85 Albian_935412.66 Sub Albian_936139.75 Albian_926192.70 Albian_916523.43 Susitna7446.97 HRZ7485.27 INT17562.90 LCU8160.81 Alpine_D8173.75 INT28201.14 Alpine_CPlan KB @ 139.50usft Plan View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-95Wellbore: MT7-95Design: MT7-95_wp02-12000-600006000South(-)/North(+) (3000 usft/in)-12000 -6000 0 6000 12000West(-)/East(+) (3000 usft/in)MT7-01MT7-01PB1MT7-02MT7-03MT7-04MT7-05MT7-06MT7-06AMT7-06PB1MT7-07MT7-08 wp04MT7-09MT7-10_wp03MT7-96MT7-97_wp03MT7-98MT7-99Surface CasingINT1INT2PROD50010001500200025003000350040004500500055006000 65007000750080008443MT7-95_wp02 040008000True Vertical Depth (2000 usft/in)-4000 0 4000 8000 12000Vertical Section at 158.97° (2000 usft/in)Surface CasingINT1INT2PROD10002000300040005000600070008000900010000110001200013000140001500016000170001800019000200002100022000230002400025000MT7-95/MT7-95_wp02Start Build 1.50Start Build 2.00Start DLS 2.50 TFO 0.83Start 3477.69 hold at 2831.92 MDStart DLS 2.75 TFO -166.19Start 50.00 hold at 9728.54 MDStart DLS 3.00 TFO -18.01Start 50.00 hold at 11031.81 MDStart DLS 2.50 TFO -24.82Start 257.88 hold at 11504.94 MDStart DLS 2.00 TFO 9.65Start DLS 0.00 TFO 7.27TD at 25892.21Section View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-95Wellbore: MT7-95Design: MT7-95_wp02 !" 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(? <""= ))3#%%$%% 2$5% "#$%% 235%$2 "$)" #$#7)#)$7 %$77"$"7 #$#2 #$2 "#$)#)$ #$"7 0?@ )? (? <""= ))35%%$%% 2$5% "#$%% 235%7$7) "$7 #$#7)#5$)7 %$77"$7% #$#2 #$2 "#$)#5$)2 #$)2 0?@ )? (? <""= ))3%%$%% 2$5% "#$%% 235%$77 )$%2 #$#7)#$ %$77)$%# #$#2 #$2 "#$)#$ #$5" 0?@ )? (? <""= ))37%%$%% 2$5% "#$%% 235%2$% )$" #$#7)#$7 %$77)$5 #$#2 #$2 "#$)#$% #$# 0?@ )? (? <""= ))3%%$%% 2$5" "#$%% 235%$# )$ #$#7)#$5% %$77)$% #$#2 #$2 "#$)#$5" #$77 0?@ )? (? <""= ))32%%$%% 2$5" "#$%% 235"%$ #$#2 #$#7)5"$") %$77#$#5 #$#2 #$2 "#$)5"$"# #$2 0?@ )? (? <""= ))3%%$%% 2$5" "#$%% 235""$2" #$2) #$#7)5)$2 %$77#$ #$#2 #$2 "#$)5)$27 #$" 0?@ )? (? <""= )#3%%%$%% 2$5" "#$%% 235")$2 5$) #$#7)55$ %$775$)" #$#2 #$2 "#$2)55$2 5%$%# 0?@ )? (? <""= )#3"%%$%% 2$5" "#$%% 235"#$2 5$7 #$#7)57$#% %$775$75 #$#2 #$2 "#$2)57$#" 5%$"7 0?@ )? (? <""= )#3)%%$%% 2$5" "#$%% 235"5$) $"# #$#7)52$%# %$77$%2 #$#2 #$2 "#$2)52$% 5%$) 0?@ )? (? <""= )#3#%%$%% 2$5" "#$%% 235"$7 $7 #$#7)5$ %$77$) #$#2 #$2 "#$2)5$2 5%$5" 0?@ )? (? <""= )#35%%$%% 2$5" "#$%% 235"$%% 7$%% #$#7)"$" %$77$ #$#2 #$2 "#$2)"$) 5%$5 0?@ )? (? <""= )#3%%$%% 2$5" "#$%% 235"2$%5 7$55 #$#7)#$) %$777$# #$#2 #$2 "#$2)#$) 5%$7 0?@ )? (? <""= )#37%%$%% 2$5" "#$%% 235"$%2 7$2 #$#7)$%% %$777$2# #$#2 #$2 "#$)$%" 5%$2% 0?@ )? (? <""= )#3%%$%% 2$5" "#$%% 235)%$"" $#" #$#7)7$ %$77$) #$#2 #$2 "#$)7$7 5%$# 0?@ )? (? <""= )#32%%$%% 2$5" "#$%% 235)"$" $ #$#7)2$% %$77$% #$#2 #$2 "#$)2$" 5"$%7 0?@ )? (? <""= )#3%%$%% 2$5" "#$%% 235))$" 2$" #$#7)7%$) %$772$"5 #$#2 #$2 "#$)7%$) 5"$" 0?@ )? (? <""= )53%%%$%% 2$5" "#$%% 235)#$)# 2$7# #$#7)7)$%" %$772$2 #$#2 #$2 "#$)7)$%) 5"$#) 0?@ )? (? <""= )53"%%$%% 2$5" "#$%% 235)5$)7 $%7 #$#7)7#$ %$77$%) #$#2 #$2 "#$7)7#$2 5"$5 0?@ )? (? <""= )53)%%$%% 2$5" "#$%% 235)$#% $% #$#7)7$# %$77$57 #$#2 #$2 "#$7)7$5 5"$2 0?@ )? (? <""= )53#%%$%% 2$5" "#$%% 235)7$#5 $5 #$#7)7$#% %$77$% #$#2 #$2 "#$7)7$#" 5"$" 0?@ )? (? <""= )535%%$%% 2$5" "#$%% 235)$# 7%$#2 #$#7)7$%7 %$777%$#5 #$#2 #$2 "#$7)7$%2 5"$25 0?@ )? (? <""= )53%%$%% 2$5" "#$%% 235)2$5" 7%$2) #$#7)%$2# %$777%$2 #$#2 #$2 "#$7)%$2 5"$ 0?@ )? (? <""= )537%%$%% 2$5" "#$%% 235)$5 7"$)7 #$#7))$7" %$777"$)) #$#2 #$2 "#$7))$7) 5)$"% 0?@ )? (? <""= )53%%$%% 2$5" "#$%% 235#%$5 7"$% #$#7)5$#2 %$777"$77 #$#2 #$2 "#$)5$# 5)$)# 0?@ )? (? <""= )532%%$%% 2$5" "#$%% 235#"$) 7)$"5 #$#7)7$"7 %$777)$"% #$#2 #$2 "#$)7$" 5)$# 0?@ )? (? <""= )53%%$%% 2$5" "#$%% 235#)$7 7)$2 #$#7)$5 %$777)$5 #$#2 #$2 "#$)$ 5)$% 0?@ )? (? <""= )3%%%$%% 2$5" "#$%% 235##$7% 7#$%) #$#7)$) %$777)$2 #$#2 #$2 "#$)$# 5)$7# 0?@ )? (? <""= )3"%%$%% 2$5" "#$%% 235#5$7# 7#$57 #$#7)2"$% %$777#$5) #$#2 #$2 "#$)2"$" 5)$7 0?@ )? (? <""= )3)%%$%% 2$5" "#$%% 235#$7 7#$% #$#7)2#$) %$777#$27 #$#2 #$2 "#$5)2#$#% 5)$% 0?@ )? (? <""= )3#%%$%% 2$5" "#$%% 235#7$% 75$#5 #$#7)2$%2 %$7775$#% #$#2 #$2 "#$5)2$% 5#$%# 0?@ )? (? <""= )35%%$%% 2$5" "#$%% 235#$5 75$ #$#7)27$2 %$7775$5 #$#2 #$2 "#$5)27$22 5#$" 0?@ )? (? <""= )3%%$%% 2$5" "#$%% 235#2$2 7$)# #$#7)22$77 %$777$" #$#2 #$2 "#$5)22$7 5#$#% 0?@ )? (? <""= )37%%$%% 2$5" "#$%% 235#$2" 7$7 #$#7)%$5 %$777$7# #$#2 #$2 "#$5)%$5 5#$55 0?@ )? (? <""= )3%%$%% 2$5" "#$%% 2355%$2 77$"" #$#7))$) %$7777$% #$#2 #$2 "#$#))$)7 5#$ 0?@ )? (? <""= )32%%$%% 2$5" "#$%% 2355"$2 77$ #$#7)5$% %$7777$" #$#2 #$2 "#$#)5$%7 5#$" 0?@ )? (? <""= )32)$)" 2$5" "#$%% 2355)$25 77$7 #$#7)$" %$7777$) #$#2 #$2 "#$#)$) 5#$2# 0?@ )? (? <""= 0 ) & 1 . . !"#$%&' %21 . 3. !"#$%&' $1 .( ) * +,&*. & " 1 . !. -&-&, & $ &. ! . .%)4.5 )$%%/- .0"* 2 ;1= $ & ;1= 4 ;= > ;=" 4 &' /#3%%2$%#37)$7)"#$# "7$%%% "352$")3)$%%$7) ")$)% )23"#$2""3%#)$%%$%%% 2$%% >02355)$25)32)$)"5$%% 7$") $ & ;1= 2 ;1= ;<=" 0 4 ;<= 7 2"$"7 - @ $" "3%2$# 5%"3%25$7 "35##$ #%"35"$5# "372%$25 )%"375$%5 )3%"$% "%"3$77 #375#$5) #)32%$"5 #37#$5) #3%%2$7 5372$#5 C #322$) 3%5"$7 C 7#327$"# 35%%$5 C #3#$#% 73#5$) C 5535#$" 73$5) C #537#$2 352"$2 &CC #35")$77 23)5)$"% C )73"#$ 23)7$%2 C "73")$% 237#$"" & 73)#$5# 37$)% D 43557$ 3)$)% "352$) 32#"$") 6137)$% "%32"$55 023"7%$2" ""3%#"$55 )23"#$ ""3"#$ 23)%"$"5 , * EF * EF 0 F Attachment 1 – MT7-95 Area of Review (AOR) An Area of Review plot is show below of the MT7-95 Injector planned wellpath and offset wells. MT7-96 and MT7-97 are the only offset wells from the planned MT7-95 injector. MT7-96 is currently on production and MT7-97 is scheduled to be drilled and completed before MT7-95. Refer to MT7-97 PTD for more details. Well Name Status Top of Alpine Pool (MD/TVD) TOC (MD/TVD) TOC – Determined By Reservoir Status Zonal Isolation Cement Operations Summary MT7-96 On production 10,239’ / 8,333’ 8,770’ / 7,532’ Sonicscope Liner TOC and production Packer 66.9 bbls of 15.8 ppg Class G MT7-96 8-1/2” x 9-7/8” intermediate 2 section was drilled to 10,139’ MD in the Alpine D and 7” liner run to 10,129’ (10 ft rat hole). Pumped 66.9 bbls of 15.8 ppg class G cement as per plan, full return during cement job, the TOC was measured with Sonicscope at approximately 8,770 MD. A horizontal production section was drilled in the Alpine C to 17,286’ MD, run and set 4-1/2” liner shoe at 16,494’ MD. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Dai, Weifeng To:Guhl, Meredith D (OGC) Cc:Hobbs, Greg S; Davies, Stephen F (OGC) Subject:RE: [EXTERNAL]GMTU MT7-95 (PTD #223-035) - Question Date:Wednesday, April 19, 2023 11:24:48 AM Hi Meredith, We plan to pre-produce for 1 month. From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Wednesday, April 19, 2023 10:39 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL]GMTU MT7-95 (PTD #223-035) - 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. Hello Weifeng, Wil GMTU MT7-95 be pre-produced? If so, how long will production last? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. X X GMTU MT7-95 Greater Mooses Tooth 223-035 X Rendezvous Oil WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-95Initial Class/TypeSER / WAGINGeoArea890Unit10750On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230350GRTR MOOSES TOOTH, RENDEZV OIL - 28220NA1Permit fee attachedYesSurf Loc & Top Prod Int lie in AA081800; TD lies in AA081781.2Lease number appropriateYes3Unique well name and numberYesGRTR MOOSES TOOTH, RENDEZV OIL - governed by CO 7934Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well 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 waitYesAIO 4314Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYesGMTU MT7-96 (PTD 221-100)15All wells within 1/4 mile area of review identified (For service well only)YesPre-production planned for up to 1 month16Pre-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' conductor18Conductor string providedYes3694 MD SC shoe19Surface casing protects all known USDWsYes69% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNouncemented liner with swell packers and frac sleeves22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesrig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision complete; no major risk failures26Adequate wellbore separation proposedYesDiverter variance granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax formation pressure is 3907 psig(8.9 ppg EMW); will drill w/ 8.5-9.5 in production section28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 3063 psig; will test BOPs to 3500 psig; Int 1 will test BOPs to 3000 psig(MPSP 1967)30BOPE 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 probableYesMT7-96 well cemented34Mechanical 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 measuresYesNo abnormal pressures expected. Managed Pressure Drilling used during pilot and Interm 2 hole sections36Data presented on potential overpressure zonesNAdue to HRZ/Kalubik/Miluv low shale stability-noted high risk in Interm2 section. LCM material on site.37Seismic analysis of shallow gas zonesNAMedium risk of hole swabbing throughout drill plan. Mitigation on p. 20-2138Seabed condition survey (if off-shore)NAPotential presence of the "Tusk" sand in Interm leg, which may be hydrocarbon bearing.39Contact name/phone for weekly progress reports [exploratory only]ApprMDGDate4/19/2023ApprVTLDate4/20/2023ApprMDGDate4/19/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateGCWJLC 4/20/2023
