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DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 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 , C A L I P E R No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 1/ 2 9 / 2 0 2 4 23 3 2 0 7 9 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ F E _ C O M P _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ A P - L O G T I M E _ R U N 0 1 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 46 4 4 0 0 9 9 0 0 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ A P - L O G T I M E _ R U N 0 2 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 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 - 93 _ A P - L O G T I M E _ R U N 0 3 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ A P - L O G T I M E _ R U N 0 4 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ A P - L O G T I M E _ R U N 0 5 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ A P - L O G T I M E _ R U N 0 6 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 23 3 2 0 7 9 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ 5 M D _ V S S - L O G D E P T H _ C O M P _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ V S S - L O G _ T I M E _ R U N 0 1 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 46 4 4 0 0 9 9 0 0 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ V S S - L O G _ T I M E _ R U N 0 2 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 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 - 93 _ V S S - L O G _ T I M E _ R U N 0 3 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ V S S - L O G _ T I M E _ R U N 0 4 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ V S S - L O G _ T I M E _ R U N 0 5 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 1 o f 8 CP A I _ M T 7 - , 93_ F E _ 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 . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No DF 1/ 2 9 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ V S S - L O G _ T I M E _ R U N 0 6 _ M E M . l a s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - _ 9 3 _ 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 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ R U N 0 1 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ R U N 0 2 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ R U N 0 3 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ R U N 0 4 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ R U N 0 5 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ R U N 0 6 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - LO G _ T I M E _ R U N 0 1 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - LO G _ T I M E _ R U N 0 2 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - LO G _ T I M E _ R U N 0 3 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - LO G _ T I M E _ R U N 0 4 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - LO G _ T I M E _ R U N 0 5 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - LO G _ T I M E _ R U N 0 6 _ M E M . a s c 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ L T K _ 2 4 0 _ 1 3 1 4 5 f t - 18 6 5 0 f t . m e t a 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ L T K _ 2 4 0 _ 1 3 1 4 5 f t - 18 6 5 0 f t . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ L T K _ P R O C . d l i s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 2 4 0 _ 1 3 1 4 5 f t - 18 6 5 0 f t . m e t a 38 4 4 6 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 2 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 2 4 0 _ 1 3 1 4 5 f t - 18 6 5 0 f t . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 4 8 _ 1 3 1 4 5 f t - 18 6 5 0 f t . m e t a 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 4 8 _ 1 3 1 4 5 f t - 18 6 5 0 f t . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ P R O C . d l i s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ L T K _ 2 4 0 _ 1 8 5 0 0 f t - 20 7 5 0 f t . m e t a 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ L T K _ 1 8 5 0 0 f t - 20 7 5 0 f t . d l i s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ L T K _ 2 4 0 _ 1 8 5 0 0 f t - 20 7 5 0 f t . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 1 8 5 0 0 f t - 20 7 5 0 f t . d l i s 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 2 4 0 _ 1 8 5 0 0 f t - 20 7 5 0 f t . m e t a 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 2 4 0 _ 1 8 5 0 0 f t - 20 7 5 0 f t . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 4 8 _ 1 8 5 0 0 f t - 20 7 5 0 f t . m e t a 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 _ m e m _ S T K _ 4 8 _ 1 8 5 0 0 f t - 20 7 5 0 f t . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 2 M D _ C O M P _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 2 T V D _ C O M P _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 5 M D _ C O M P _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 5 T V D _ C O M P _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ 5 M D _ V S S - DE P T H _ C O M P _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 3 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No DF 1/ 2 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 - 9 3 _ V S S - L O G TI M E _ M E M . c g m 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 2 M D _ C O M P _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 2 T V D _ C O M P _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 5 M D _ C O M P _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 93 _ 5 T V D _ C O M P _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ A P - L O G TI M E _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ 5 M D _ V S S - DE P T H _ C O M P _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 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 - 9 3 _ V S S - L O G TI M E _ M E M . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 N A D 2 7 D e f i n i t i v e Su r v e y s . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 N A D 2 7 D e f i n i t i v e Su r v e y s . t x t 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 N A D 8 3 D e f i n i t i v e Su r v e y s . p d f 38 4 4 6 ED Di g i t a l D a t a DF 1/ 2 9 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 3 N A D 8 3 D e f i n i t i v e Su r v e y s . t x t 38 4 4 6 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 46 0 0 1 3 0 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ R M . l a s 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ 1 0 0 0 M D _ R M . P d f 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ 2 0 0 0 M D _ R M . P d f 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ 2 0 0 M D _ R M . P d f 38 5 0 2 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 4 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ 4 0 0 0 M D _ R M . P d f 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ 5 0 0 M D _ R M . P d f 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ 6 0 0 0 M D _ R M . P d f 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ R M . d l i s 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 93 _ T O C _ R M . h t m l 38 5 0 2 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : MT 7 _ 9 3 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 . 6 2 5 i n _ C a s i n g s _ S o n i cS c o p e 4 7 5 _ R e a m D o w n 1 _ R M _ T O C _ 4 6 0 0 f t _ 1 3 0 46 f t . p p t x 38 5 0 2 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 78 9 1 0 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 1 2 0 F P M _ D o w n _ C a l i b r a t io n P a s s _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 1 2 _ D o w n . l as 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 78 9 1 0 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 1 2 0 F P M _ U p _ C a l i b r a t i o n Pa s s _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 1 1 _ U p . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 12 6 9 6 2 0 3 6 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 3 0 F P M _ D o w n _ 7 M M S C FP D _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 4 _ D o w n . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 12 5 7 7 2 0 6 3 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 3 0 F P M _ D o w n _ S h u t - In _ R e p e a t _ R u n _ 1 _ _ T T i x _ P P R O F _ _ L o g _ 4 _ D o w n .l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 12 5 8 6 2 0 7 1 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 3 0 F P M _ D o w n _ S h u t - In _ R u n _ 1 _ _ T T i x _ P P R O F _ _ L o g _ 2 _ D o w n _ 1 . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 79 0 1 0 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 4 0 F P M _ D o w n _ C a l i b r a t i on P a s s _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 8 _ D o w n . l a s 39 3 5 0 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 5 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No DF 8/ 2 / 2 0 2 4 12 6 1 8 2 0 6 8 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 : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 4 0 F P M _ U p _ 7 M M S C F P D_ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 3 _ U p . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 79 0 1 0 0 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 : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 4 0 F P M _ U p _ C a l i b r a t i o n Pa s s _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 7 _ U p . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 12 5 9 6 2 0 7 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 6 0 F P M _ U p _ S h u t - In _ R u n _ 1 _ _ T T i x _ P P R O F _ _ L o g _ 3 _ U p . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 78 8 1 0 0 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 : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 8 0 F P M _ D o w n _ C a l i b r a t i on P a s s _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 1 0 _ D o w n . l as 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 12 5 7 4 2 0 3 4 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 8 0 F P M _ U p _ 7 M M S C F P D_ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 5 _ U p . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 79 0 1 0 0 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 : C P A I _ M T 7 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 8 0 F P M _ U p _ C a l i b r a t i o n Pa s s _ R u n _ 2 _ _ T T i x _ P P R O F _ _ L o g _ 9 _ U p . l a s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 1 2 0 F P M _ D o w n _ C a l i b r a t io n P a s s _ C o n C u _ R 0 7 _ L 0 1 2 D o w n . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 1 2 0 F P M _ U p _ C a l i b r a t i o n Pa s s _ C o n C u _ R 0 7 _ L 0 1 1 U p . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 3 0 F P M _ D o w n _ 7 M M S C FP D _ C o n C u _ R 0 7 _ L 0 0 4 D o w n . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 3 0 F P M _ D o w n _ S h u t - In _ C o n C u _ R 0 2 _ L 0 0 2 D o w n . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 3 0 F P M _ D o w n _ S h u t - In _ R e p e a t _ C o n C u _ R 0 2 _ L 0 0 4 D o w n . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 4 0 F P M _ D o w n _ C a l i b r a t i on P a s s _ C o n C u _ R 0 7 _ L 0 0 8 D o w n . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 4 0 F P M _ U p _ 7 M M S C F P D_ C o n C u _ R 0 7 _ L 0 0 3 U p . d l i s 39 3 5 0 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 6 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 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 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 : 1/ 2 9 / 2 0 2 4 Re l e a s e D a t e : 10 / 3 1 / 2 0 2 3 DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 4 0 F P M _ U p _ C a l i b r a t i o n Pa s s _ C o n C u _ R 0 7 _ L 0 0 7 U p . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 6 0 F P M _ U p _ S h u t - In _ C o n C u _ R 0 2 _ L 0 0 3 U p . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 8 0 F P M _ D o w n _ C a l i b r a t i on P a s s _ C o n C u _ R 0 7 _ L 0 1 0 D o w n . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 8 0 F P M _ U p _ 7 M M S C F P D_ C o n C u _ R 0 7 _ L 0 0 5 U p . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ 8 0 F P M _ U p _ C a l i b r a t i o n Pa s s _ C o n C u _ R 0 7 _ L 0 0 9 U p . d l i s 39 3 5 0 ED Di g i t a l D a t a DF 8/ 2 / 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 - 93 _ P P R O F _ 1 1 J u n 2 0 2 4 _ F i e l d P r i n t . P d f 39 3 5 0 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 7 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 6 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 9 3 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 1/ 2 9 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 9 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 20 7 9 5 TV D 83 1 9 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No 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 : Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 8 o f 8 1/ 1 5 / 2 0 2 6 M. G u h l Originated: `§1 600 E 57th Place Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: TRANSMITTAL DATE31-Ju424 Alaska Oil & Gas Conservation Commis 37JUITA-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 MT7-93 50-103-20866-00.00 ICE ORDE4� # 223-099 FIELD NAME DESCRIPTION Greater Mooses Tooth SERVICE WL DELIVERABLE TTiX PPROF FINAL FIELD r 11-Jun-24 r MT7-05 50-103-20833-00.00 227-087 Greater Mooses Tooth WL TTiX PPROF FINAL FIELD 18-Jun-24 MT7-96 1 50-103-20834-00-00 1 221-100 Greater Mooses Tooth WL TTiX PPROF I FINAL FIELD I 21-Jun-24 2N-347 1 50-103-20337-00-00 1 200-063 Kupamk River WL LDL I FINAL FIELD I 17-Jul-24 T3935O T39351 T39352 T39353 'mittal Receipt Digitally signed by Gavin p Gavin Gluyas Gl"y" A Delivery Receipt signature confirms that a package (box, envelope, Dzte:3024A8.020833,16 etc.) has been received. The package will be handled/delivered per X -0900standard company reception procedures. The package's contents hai Name Signature Date not been verified but should be assumed to contain the above noted media. e return via courier or sign/scan and email a copy to Schlumberger. 50lu mberger-Private 1a. Well Status:SuspendedAbandonedOtherSPLUGOil 1b. Well Class: 20AAC 25.11020AAC 25.105 ExploratoryDevelopment WDSPLGINJ WINJ No. of Completions: __________________Stratigraphic TestService 14. Permit to Drill Number / Sundry:6. Date Comp., Susp., or2. Operator Name: Aband.: 15. API Number:7. Date Spudded:3. Address: 16. Well Name and Number:8. Date TD Reached:4a. Location of Well (Governmental Section): Surface: 9. Ref Elevations: KB: 17. Field / Pool(s):1838' FSL, 1000' FEL S5 T9N R2ETop of Productive Interval: GL: 100.6 BF: 10. Plug Back Depth MD/TVD: 18. Property Designation:Total Depth: 11. Total Depth MD/TVD: 19. DNR Approval Number:4b. Location of Well (State Base Plane Coordinates, NAD 27): Zone- 4y-x-Surface: 20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4y-x-TPI: Zone- 4y-x-Total Depth: 5. Directional or Inclination Survey: Yes (attached) No 21. Re-drill/Lateral Top Window MD/TVD:13. Water Depth, if Offshore: N/A (ft MSL)Submit electronic information per 20 AAC 25.050 22. Logs Obtained: 23. BOTTOM 120'H-4020" 3042'L-8013-3/8 7493'T-959-5/8" 8324'TN110SS7-5/8" 8321'P1104 1/2" 25.NoYes24. Open to production or injection? 26. NoWas hydraulic fracturing used during completion? Yes AMOUNT AND KIND OF MATERIAL USEDDEPTH INTERVAL (MD) 27. Method of Operation (Flowing, gas lift, etc.):Date First Production: Gas-MCF:Production forHours Tested: Test Period Oil Gravity - API (corr):Gas-MCF:CalculatedCasing Press: Press. 24-Hour Rate 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: 64.5ppg 15.8ppg Class G8.5"x9-7/8" TUBING RECORD 20574' Lead:64bbl 13.0ppg Class G Tail: 120bbl 15.8ppg Class G 8288' 12-1/4" 6-3/4" 12986'4.5" BOTTOM Lead: 502bbl 11.0ppg Blend16" Tail: 70bbl 15.8 Class G CASING 50-103-20866-00-00 GMT MT7-93 12/12/2023 20795'MD/8319'TVD N/A 140.4 P.O.Box 100360, Anchorage, AK 99510-0360 290151 1083' FSL, 3210' FEL S32 T10N R2E 3454' FSL, 4503' FEL S32 T10N R2E 1/18/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 223-0991/29/2024 982'MD/980'TVD SETTING DEPTH TVD 5918306 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER PACKER SET (MD/TVD) 12980' 42" 12.6 5915899 Greater Mooses Tooth/Rendezvous AA081800, AA081803, AA081781 932535000, 932516000 40' 29.7 40' 11380' 4216' 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 292248 288916 CEMENTING RECORD 5911315 18504430 Gas Lift If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner (1/24/2024): 12980'MD/8288'TVD - 20574'MD/8321'TVD 2400 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 40' 40' Per 20 AAC 25.283 (i)(2) attach electronic information 47 13137' 37' 7347' 94 68 120' 11559'37' DEPTH SET (MD)SIZE 10 Yards Sr Res EngSr Pet GeoSr Pet Eng 100 N/A 37 Water-Bbl:Oil-Bbl: 2400 Water-Bbl: PRODUCTION TEST 2/19/2024 Oil-Bbl:Date of Test: 4404812000 2/19/2024 1/24/1900 Flow Tubing 440 4430 Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022 12890'MD/8263' TVD 12980'MD/8288'TVD By Grace Christianson at 12:54 pm, Mar 01, 2024 Completed 1/29/2024 JSB RBDMS JSB 030724 GDSR-3/21/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 982 980 C-30 1435 1420 2082 1993 4145 3024 K-2 5373 3384 Albian 97 6353 3669 Albian 96 7024 3859 HRZ 11537 7477 Kalubik 11625 7547 Kuparuk C 11764 7653 11767 7655 13039 8304 20795 8283 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: Weifeng Dai Digital Signature with Date: Contact Phone:907-947-4323 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: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Attached Seperately Formation Name at TD: Alpine C Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval: Alpine C 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:weifeng.dai@conocophillips.com Authorized Title: Drilling Engineer K-3 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Weifeng Dai DN: O=ConocoPhillps, CN=Weifeng Dai, E=weifeng.dai@cop.com Reason: I am the author of this document Location: Date: 2024.02.28 09:54:02-09'00' Foxit PDF Editor Version: 13.0.0 Weifeng Dai Page 1/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/10/2023 00:00 12/10/2023 01:00 1.00 MIRU, MOVE MOB P Continue to unplug complexes. Raise C- Section and prep to skid rig. 0.0 0.0 12/10/2023 01:00 12/10/2023 02:00 1.00 MIRU, MOVE MOB P Skid rig floor and stomp out casing shed. 0.0 0.0 12/10/2023 02:00 12/10/2023 03:30 1.50 MIRU, MOVE MOB P PJSM. Lower derrick and stomp out motor complex. 0.0 0.0 12/10/2023 03:30 12/10/2023 04:30 1.00 MIRU, MOVE MOB P Raise cellar. Put motor complex on suspension. 0.0 0.0 12/10/2023 04:30 12/10/2023 07:00 2.50 MIRU, MOVE MOB P Unpin pipe shed from Sub. Raise sub and stomp out pipe shed. Put casing shed on suspension. 0.0 0.0 12/10/2023 07:00 12/10/2023 11:30 4.50 MIRU, MOVE MOB T Set and position rig mats. Trucks arrive at 11:30 hrs. SIMOPS: Change out mud pump liners to 6.5". Change valves in pits. 0.0 0.0 12/10/2023 11:30 12/10/2023 15:00 3.50 MIRU, MOVE MOB P Spot truck under Ball MIll and pull forward. Move pump and pit modules and put on suspension. Pin Jeep onto sub. Pull and align sub with MT7-93 well. 0.0 0.0 12/10/2023 15:00 12/10/2023 18:00 3.00 MIRU, MOVE MOB P Back Sub onto mats. Stomp pipe shed into position for Truck. 0.0 0.0 12/10/2023 18:00 12/10/2023 21:00 3.00 MIRU, MOVE MOB P Spot and level Sub (Centered on well at 20:30hrs). Lay mats to spot pit and pump modules. 0.0 0.0 12/10/2023 21:00 12/11/2023 00:00 3.00 MIRU, MOVE MOB P Position pit and pump modules close to Sub. Lay mats for pipe shed. 0.0 0.0 12/11/2023 00:00 12/11/2023 01:00 1.00 MIRU, MOVE MOB P Move pipe shed with truck and spot on mats in front of Sub. 0.0 0.0 12/11/2023 01:00 12/11/2023 03:00 2.00 MIRU, MOVE MOB P Stomp pipe shed under sub (turn 90 deg) SIMOPS: Lay mats for motor complex and spot on mats with trucks. 0.0 0.0 12/11/2023 03:00 12/11/2023 05:00 2.00 MIRU, MOVE MOB P Continue position and stomp pipe shed under sub. SIMOPS: Lay mats for casing shed and spot on mats with trucks. 0.0 0.0 12/11/2023 05:00 12/11/2023 07:30 2.50 MIRU, MOVE MOB P Continue position and stomp pipe shed under sub, shim and pin pipe shed to sub. 0.0 0.0 12/11/2023 07:30 12/11/2023 08:00 0.50 MIRU, MOVE MOB P Stomp pits into position with sub. 0.0 0.0 12/11/2023 08:00 12/11/2023 09:00 1.00 MIRU, MOVE MOB P Stomp casing, pump and motor complex into position, Raise derrick and hook up pump room inter-connections. 0.0 0.0 12/11/2023 09:00 12/11/2023 09:30 0.50 MIRU, MOVE MOB P Skid rig floor into drilling position. SIMOPS: Spot Ball Mill with trucks. Released trucks at 09:30hrs. 0.0 0.0 12/11/2023 09:30 12/11/2023 10:30 1.00 MIRU, MOVE MOB P Raise cattle chute, Lower C-Section. Energize steam and air on rig floor. 0.0 0.0 12/11/2023 10:30 12/11/2023 12:00 1.50 MIRU, MOVE MOB P Lower cellar and energize steam in BOP deck. 0.0 0.0 12/11/2023 12:00 12/11/2023 13:00 1.00 MIRU, MOVE MOB P Install grating in cellar, Continue prep pits to take on fluid. SIMOPS: Thaw out cellar. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 2/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/11/2023 13:00 12/11/2023 16:30 3.50 MIRU, MOVE RURD P Spool on drill line onto drawworks, Unhang block and bridle up. Pin sheaves and scope up derrick. Bridle down and remove yokes. Calibrate block and safety devices. On highline power at 14:00 hrs. Rig accepted at 16:00hrs 12-11-2023 0.0 0.0 12/11/2023 16:30 12/11/2023 21:00 4.50 MIRU, MOVE RURD P Install 4" valves on conductor, PJSM, N/U surface riser and flow line. Seal Joe's box. 0.0 0.0 12/11/2023 21:00 12/12/2023 00:00 3.00 MIRU, MOVE RURD P Change out top drive saver sub to 4-1/2" IF. SIMOPS: Move BHA components to rig floor. 0.0 0.0 12/12/2023 00:00 12/12/2023 01:00 1.00 MIRU, MOVE RURD P R/U 5" handling equipment, Fill surface lines and equipment and prime pumps. 0.0 0.0 12/12/2023 01:00 12/12/2023 03:00 2.00 MIRU, MOVE BHAH P P/U 5" HWT and Jars, rack back in derrick. 0.0 0.0 12/12/2023 03:00 12/12/2023 04:15 1.25 MIRU, MOVE PRTS P Attempt to pressure test surface system, #2 mud pump pop off released at 982psi (Set at 4300psi) Unable to reset pop off. Isolate #2 mud pump. Attempt to pressure test with #1 mud pump. Unable to pressure up system. Trouble shoot Mud pump system. (Pump not fully primed) 0.0 0.0 12/12/2023 04:15 12/12/2023 06:00 1.75 MIRU, MOVE BHAH P P/U 16" BHA, Fill hole and tag at 112' MD. Pressure test surface system to 3500psi. 0.0 112.0 12/12/2023 06:00 12/12/2023 08:15 2.25 MIRU, MOVE DDRL P Drill 16" hole from 120' MD to 300' MD. WOB: 4k GPM: 490 PSI: 613 RPM: 40 3.0TQ on bttm 3.0 k TQ off bttm FO: 67% PU: 63k SO: 63k ROT: 63k 112.0 300.0 12/12/2023 08:15 12/12/2023 09:00 0.75 MIRU, MOVE BKRM P BROOH from 300' MD to surface. GPM: 550 PSI: 600 RPM: 40 TRQ: 3k PU: 55k SO: 55k ROT: 55k 300.0 0.0 12/12/2023 09:00 12/12/2023 13:00 4.00 MIRU, MOVE BHAH P P/U final 16" surface BHA and scrib. Continue RIH with BHA to 300' MD. 0.0 300.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 3/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/12/2023 13:00 12/12/2023 18:00 5.00 SURFAC, DRILL DDRL P Drill 16" hole from 300' MD to 635' MD 634' TVD WOB: 11k GPM: 675 PSI: 1480 RPM: 60 5.0 k TQ on bttm 5.0 k TQ off bttm FO: 63% PU: 92k SO: 92k ROT: 92k ADT: 2.3 hrs ART: 2.3 hrs TBH: 3.8 hrs TJH: 0.2 hrs 300.0 635.0 12/12/2023 18:00 12/12/2023 21:45 3.75 SURFAC, DRILL DDRL P Drill 16" hole from 635' MD 634' TVD to 986' MD 983' TVD WOB: 14k GPM: 675 PSI: 1520 RPM: 60 6.0 k TQ on bttm 6.0 k TQ off bttm FO: 61% PU: 98k SO: 98k ROT: 98k 635.0 986.0 12/12/2023 21:45 12/12/2023 22:30 0.75 SURFAC, DRILL CIRC P Circulate at 986' MD while trouble shoot BPA system. Found cement in dump line. Changed 2" swing and cleaned out connection of 2" HP hose. Note: Base of permafrost on BTM's up, hole unloaded. GPM: 600 PSI: 1340 RPM: 60 986.0 986.0 12/12/2023 22:30 12/13/2023 00:00 1.50 SURFAC, DRILL DDRL P Drill 16" hole from 986' MD 983' TVD to 1115' MD 1110' TVD. WOB: 18k GPM: 700 PSI: 1740 ECD: 11.4ppg RPM: 60 10.0 k TQ on bttm 10.0 k TQ off bttm FO: 61% PU: 108k SO: 108k ROT: 108k ADT: 2.2 hrs ART: 2.2 hrs TBH: 6.8 hrs TJH: 3.2 hrs 986.0 1,115.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 4/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/13/2023 00:00 12/13/2023 06:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole from 986' MD 983' TVD to 1,836' MD 1,784' TVD. WOB: 10k GPM: 850 PSI: 2250 ECD: 11.4ppg RPM: 60 7.0 k TQ on bttm 7.0 k TQ off bttm FO: 79% PU: 108k SO: 108k ROT: 108k ADT: 4.5 hrs ART: 2.9 hrs TBH: 11.3 hrs TJH: 7.7 hrs 1,115.0 1,836.0 12/13/2023 06:00 12/13/2023 08:45 2.75 SURFAC, DRILL DDRL P Drill 16" hole from 1,836' MD 1,784' TVD to 2,121' MD 2,024' TVD. WOB: 7k GPM: 900 PSI: 2660 ECD: 11.4ppg RPM: 60 7.0 k TQ on bttm 7.0 k TQ off bttm FO: 78% ROT: 120k ADT: 2.2hrs ART: 1.2 hrs AST: 1.0 TBH: 13.5 hrs TJH: 9.9 hrs 1,836.0 2,121.0 12/13/2023 08:45 12/13/2023 09:45 1.00 SURFAC, DRILL CIRC T Investigate Chopper issue, Circulate 2,121' MD. GPM: 900 PSI: 2660 ECD: 11.4ppg 2,121.0 2,121.0 12/13/2023 09:45 12/13/2023 12:00 2.25 SURFAC, DRILL DDRL P Drill 16" hole from 2,121' MD 2,024' TVD to 2,343' MD 2,195' TVD. WOB: 12k GPM: 900 PSI: 2650 ECD: 11.3ppg RPM: 60 7.0 k TQ on bttm 7.0 k TQ off bttm FO: 78% ROT: 123k ADT: 1.5 hrs ART: 0.4 hrs AST: 1.1 TBH: 15 hrs TJH: 11.4 hrs 2,121.0 2,343.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 5/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/13/2023 12:00 12/13/2023 18:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole from 2,343' MD 2,195' TVD to 2,967' MD 2,583' TVD. WOB: 14k GPM: 900 PSI: 3010 ECD: 11.4ppg RPM: 60 8.0 k TQ on bttm 8.0 k TQ off bttm FO: 78% ROT: 120k ADT: 4.4 hrs ART: 3.0 hrs AST: 1.4 TBH: 19.5 hrs TJH: 15.9 hrs 2,343.0 2,967.0 12/13/2023 18:00 12/13/2023 19:30 1.50 SURFAC, DRILL DDRL P Drill 16" hole from 2,967' MD 2,583' TVD to 3,154' MD 2,675' TVD. WOB: 15k GPM: 900 PSI: 3070 ECD: 12ppg RPM: 60 9.0 k TQ on bttm 9.0 k TQ off bttm FO: 79% ROT: 124k ADT: 1.5 hrs ART: 0.9 hrs AST: 0.6 TBH: 21.0 hrs TJH: 17.4 hrs 2,967.0 3,154.0 12/13/2023 19:30 12/13/2023 20:30 1.00 SURFAC, DRILL CIRC T Circulate at 3,154' MD. ECD increased from 11.4ppg to 12.6ppg, hole unloading, Stage pumps up while cleaning out Joes box. 3,154.0 3,154.0 12/13/2023 20:30 12/13/2023 21:30 1.00 SURFAC, DRILL DDRL P Drill 16" hole from 3,154' MD 2,675' TVD to 3,247' MD 2,717' TVD.9 WOB: 12k GPM: 900 PSI: 3070 ECD: 11.8ppg RPM: 60 8.0 k TQ on bttm 8.0 k TQ off bttm FO: 78% ROT: 124k ADT: 0.7 hrs ART: 0.4 hrs AST: 0.3 TBH: 21.7 hrs TJH: 18.1 hrs 3,154.0 3,247.0 12/13/2023 21:30 12/13/2023 22:00 0.50 SURFAC, DRILL CIRC T Circulate at 3,247' MD. ECD increased from 11.7ppg to 12.0ppg, hole unloading, Stage pumps up while cleanning out Joes box. 3,247.0 3,247.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 6/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/13/2023 22:00 12/14/2023 00:00 2.00 SURFAC, DRILL DDRL P Drill 16" hole from 3,247' MD 2,717' TVD to 3,438' MD 2,792' TVD. WOB: 15k GPM: 900 PSI: 3070 ECD: 12ppg RPM: 60 9.0 k TQ on bttm 9.0 k TQ off bttm FO: 78% ROT: 124k ADT: 1.7 hrs ART: 1.0 hrs AST: 0.7 TBH: 23.4 hrs TJH: 19.8 hrs 3,247.0 3,438.0 12/14/2023 00:00 12/14/2023 06:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole from 3,438' MD 2,792' TVD to 3,907' MD 2,952' TVD. WOB: 32k GPM: 900 PSI: 3350 ECD: 11.6ppg RPM: 60 9.0 k TQ on btm 9.0 k TQ off btm FO: 78% ROT: 122k ADT: 4.6 hrs ART: 4.0 hrs AST: 0.6 TBH: 28 hrs TJH: 24.4 hrs 3,438.0 3,907.0 12/14/2023 06:00 12/14/2023 11:30 5.50 SURFAC, DRILL DDRL P Drill 16" hole from 3,907' MD 2,952' TVD to 4,226' MD 3,015' TVD. WOB: 20k GPM: 900 PSI: 3400 ECD: 11.6ppg RPM: 60 8.0 k TQ on btm 8.0 k TQ off btm FO: 83% ROT: 127k DAT: 3.6 hrs ART: 2.7 hrs SAT: 0.9 TBH: 31.6 hrs TJH: 28 hrs 3,907.0 4,226.0 12/14/2023 11:30 12/14/2023 14:00 2.50 SURFAC, TRIPCAS CIRC P Obtain final survey, Pump 2- 50bbls nut plug sweeps, Circulate and back ream from 4,226' MD to 4,098' MD. 1st sweep observed cutting increased on BTM's up. 2nd sweep observed no increase in cuttings. GPM: 900 PSI: 3100 RPM: 60 4.0 k TQ off btm 4,226.0 4,098.0 12/14/2023 14:00 12/14/2023 14:30 0.50 SURFAC, TRIPCAS OWFF P OWFF (Static) 4,098.0 4,098.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 7/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/14/2023 14:30 12/15/2023 00:00 9.50 SURFAC, TRIPCAS BKRM P BROOH from 4,098' MD to 1390' MD GPM: 900 PSI: 2690 RPM: 60 4.0 k TQ off btm SIMOPS: Attempt to bulk doubles, Digital monitor not working on unit. 4,098.0 1,390.0 12/15/2023 00:00 12/15/2023 01:15 1.25 SURFAC, TRIPCAS BKRM P BROOH from 1,390' MD to 985' MD, 900 gpm 2600psi 1,390.0 985.0 12/15/2023 01:15 12/15/2023 02:30 1.25 SURFAC, TRIPCAS BKRM P BROOH from 980' MD to 604' MD, 750 gpm 1800psi 985.0 604.0 12/15/2023 02:30 12/15/2023 03:00 0.50 SURFAC, TRIPCAS CIRC P OWFF (Static), Pump 50bbls nut plug sweep around at 604' MD. Increase in cutting before sweep returns to surface. 604.0 604.0 12/15/2023 03:00 12/15/2023 04:15 1.25 SURFAC, TRIPCAS BKRM P Attempt to pull on elevators from 604' MD, At 596' MD pull 30k. Continue BROOH pumping at 500gpm 850psi. rack back 5" HWT drill pipe to 243' MD. 604.0 243.0 12/15/2023 04:15 12/15/2023 07:30 3.25 SURFAC, TRIPCAS BHAH P Blow down top drive and surface equipment, Rack back drill collars (20- 30k pull, work BHA out hole) L/D 16" surface BHA. (Bit and Stabilizer balled up) Note: Trouble breaking bit +70k 243.0 0.0 12/15/2023 07:30 12/15/2023 08:00 0.50 SURFAC, CASING CLEN P Clean and clear rig floor. Prep for R/U casing equipment. 0.0 0.0 12/15/2023 08:00 12/15/2023 10:00 2.00 SURFAC, CASING RURD P R/U Doyon Volant and 13-3/8" casing equipment. 0.0 0.0 12/15/2023 10:00 12/15/2023 14:00 4.00 SURFAC, CASING PUTB P PJSM, P/U and run 13-3/8" 68# L-80 H563 shoe track to 133' MD. Taking weight below conductor at 120'. Circulate and work through to 160' MD. Continue P/U and run casing to 1,118' MD. Torque casing 25k Baker-Loc shoe track to joint #4. Floats checked good FC 2.24' 2- joints 86.62' Shoe 2.32' 0.0 1,118.0 12/15/2023 14:00 12/15/2023 14:30 0.50 SURFAC, CASING CIRC P Circulate BTM's up at 1,118' MD, stage pumps up to 8bpm 107psi. Noticed increase of cuttings at surface. 1,118.0 1,118.0 12/15/2023 14:30 12/15/2023 23:00 8.50 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68# L-80 H563 Casing from 1,118' MD to 4,176' MD, Torque casing 25k Worked casing from 2,192' MD to 2,230' MD. BPM: 3 PSI: 130 PU: 217k SO: 165k 1,118.0 4,176.0 12/15/2023 23:00 12/15/2023 23:30 0.50 SURFAC, CASING HOSO P M/U FMC hanger and landing joint. Break circulation at 1/2bpm 80psi and land hanger at 4,216' MD 3,021.80' TVD with 224k. PU: 274k SO: 224k 4,176.0 4,216.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 8/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/15/2023 23:30 12/16/2023 00:00 0.50 SURFAC, CEMENT CIRC P Stage pumps up from 1bpm to 3bpm. Circulate and condition mud. Reciprocating casing 15' PU: 274k SO: 224k GPM: 126 PSI: 80 SIMOPS: Testing choke manifold offline to 250/5000psi 4,216.0 4,216.0 12/16/2023 00:00 12/16/2023 01:30 1.50 SURFAC, CEMENT CIRC P Stage pumps up from 1bpm to 8bpm. Circulate and condition mud. Reciprocating casing 15', PU: 274k, SO: 224k, GPM: 336, PSI: 205 SIMOPS: Testing choke manifold offline to 250/5000psi 4,216.0 4,216.0 12/16/2023 01:30 12/16/2023 01:45 0.25 SURFAC, CEMENT PRTS P R/U cement lines, Break circulation and test lines to 4500psi. 4,216.0 4,216.0 12/16/2023 01:45 12/16/2023 06:00 4.25 SURFAC, CEMENT CMNT P Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 6 bbls/min, 230 psi, Dropped bottom plug, Add two gallons dye. Start batching lead (Cement wet @02:10hrs). Pump 470 bbls of 11.0 ppg DeepCRETE cement at 6 bbls/min, 277 psi ICP. Batch tail cement (Cement wet @ 03:53hrs) and pump 70 bbls of G Blend Tail 15.8 ppg cement @ 6.0 bbls/min, 312 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 351 psi ICP 508 psi FCP, (Slowed pump rate from 8bpm to 6bpm at 2536stks out running cuttings pit). Slow pumps 18 bbls prior to calculated bump to 3 bbls/min, 315 psi ICP, Bump plug with 840 psi (595.5 bbls + 20 bbls). 5039 strokes, final circ. PSI 315. Pressure up to 840 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 148 bbls cement to surface. Cement in place @ 05:48hrs 12/16/23 Lead: 11ppg D047: 0.5 gal/sk Antifoam D185: 0.09 gal/sk Dispersant D167: 0.450% BWOB Fluid Loss D177: 0.02 gal/sk Retarder Tail: 15.8ppg D047: 0.2 gal/sk Antifoam D065: 0.65 % BWOC Dispersant D225: 0.3% BWOB Fluid Loss D186: 0.5 gal/sk Accelerator 4,216.0 4,216.0 12/16/2023 06:00 12/16/2023 07:30 1.50 SURFAC, CEMENT PRTS P Drain and flush stack with black water, Pressure test casing to 3500psi 30min. pressure 3500psi. pumped 8.5bbls returned 8.5bbls. 4,216.0 4,216.0 12/16/2023 07:30 12/16/2023 08:30 1.00 SURFAC, CEMENT RURD P Remove landing joint and R/D casing equipment. Clear rig floor. 0.0 0.0 12/16/2023 08:30 12/16/2023 10:00 1.50 SURFAC, CEMENT CLEN P Remove master bushings and clean flow box and jet flow line. Blow down surface equipment. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 9/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/16/2023 10:00 12/16/2023 14:30 4.50 SURFAC, WHDBOP NUND P Flush riser and cap 4" conductor lines, N/D surface riser. Pull SLA off conductor. SIMOPS: Test choke manifold offline to 250/5000psi 5/10min. 0.0 0.0 12/16/2023 14:30 12/16/2023 15:30 1.00 SURFAC, WHDBOP NUND P NU and orientate WH. Test seals to 1000psi (CPAI witnessed) 0.0 0.0 12/16/2023 15:30 12/16/2023 20:30 5.00 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 NOTE: Rig contract 15hrs to N/U and test BOPs Time started at 1530hrs 12- 16-23 0.0 0.0 12/16/2023 20:30 12/16/2023 22:00 1.50 SURFAC, WHDBOP PRTS P Set test plug and install MPD test cap. Attempt to test to 250/1800psi. 0.0 0.0 12/16/2023 22:00 12/16/2023 23:30 1.50 SURFAC, WHDBOP PRTS P M/U 9-5/8" test joint, Purge air from system. Attempt to test, Change out seat on 3" kill demco valve. 0.0 0.0 12/16/2023 23:30 12/17/2023 00:00 0.50 SURFAC, WHDBOP PRTS P Continue pressure test BOP's with 9- 5/8" test joint. 0.0 0.0 12/17/2023 00:00 12/17/2023 04:00 4.00 SURFAC, WHDBOP BOPE P Test BOPE all tests 250 psi low for 5 min, 5,000 psi high for 10 minutes each with 2 7/8" x 5" LPR and 9-5/8" UPR - test annular to 250 psi low for 5 min, 3,500 psi high for 10 minutes with 5" and 9-5/8", test choke valves 1,4,5,&7 manual and super choke, choke and kill manual's and HCR's, 4" valve on kill line, 2 x 4" FOSV, upper and lower IBOP, blind/shear rams. Perform Koomey drawdown, ACC=3000 psi, manifold=1500 psi initial. After all functions, accumulator=1800 psi, 13 secs to 200 psi with two electric pumps, 76 secs to build to full system pressure with two electric and two air pumps. Closing times, annular=26 secs, UPR=14 secs, blind/shears=15 secs, LPR=13 secs, choke HCR=2 secs, kill HCR=2 secs. 6 Nitrogen bottles back-up avg=1875 psi, CPAI witnessed. Tested PVT, gain/loss, flow out, LEL and H2S alarms. Note: Choke manifold tested offline 250 psi low for 5 min, 5,000 psi high for 10 minutes BLM Quinn Sawyer waived witness of running/cementing surface casing. Also waived witness initial BOP test at 12:46hrs 12/12/2023. AOGCC Guy Cook waived witness initial BOP test at 18:00hrs 12/13/2023. 0.0 0.0 12/17/2023 04:00 12/17/2023 04:30 0.50 SURFAC, WHDBOP RURD P Pull test plug and install 12-15/16" wear ring. 0.0 0.0 12/17/2023 04:30 12/17/2023 05:30 1.00 SURFAC, WHDBOP RURD P L/D 5" test joint, Blow down surface and test equipment. 0.0 0.0 12/17/2023 05:30 12/17/2023 07:00 1.50 SURFAC, WHDBOP SLPC P Cut and slip 84' drill line. Recalibrate block, COM and hook load. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 10/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/17/2023 07:00 12/17/2023 10:00 3.00 SURFAC, DRILLOUT BHAH P P/U and run 12-1/4" Interm 1 BHA #2 to 561' MD. Sensor offset: Near bit Inc.: 5.61' Gamma: 26.43' Pressure: 27.20' Resisitivity: 31,82 Directional/ VSS: 38.60' 0.0 561.0 12/17/2023 10:00 12/17/2023 12:00 2.00 SURFAC, DRILLOUT TRIP P TIH with 12-1/4" BHA from 561' MD to 2,915' MD. Shallow test tools at 900gpm 2300psi (good test) 561.0 2,915.0 12/17/2023 12:00 12/17/2023 13:00 1.00 SURFAC, DRILLOUT TRIP P Continue TIH with 12-1/4" BHA from 2,915' MD to 4,050' MD. 2,915.0 4,050.0 12/17/2023 13:00 12/17/2023 13:30 0.50 SURFAC, DRILLOUT CIRC P Break circulate, Perform choke drill with crews. Blow down surface equipment. 4,050.0 4,050.0 12/17/2023 13:30 12/17/2023 14:30 1.00 SURFAC, DRILLOUT WASH P Wash in hole from 4,050' MD, tagged cement stringer at 4,064' MD. Fan bottom and stage up pumps to 890gpm 2420psi.. GPM: 84 PSI: 140 RPM: 10 6.0 TQ on btm 4,050.0 4,064.0 12/17/2023 14:30 12/17/2023 15:30 1.00 SURFAC, DRILLOUT DRLG P Continue drill shoe track to 4,216' MD. (everything tagged on depth) Shoe at 4,216' MD 3,021' TVD GPM: 670 PSI: 1500 RPM: 60 8.0 TQ on btm 4,064.0 4,216.0 12/17/2023 15:30 12/17/2023 16:00 0.50 SURFAC, DRILLOUT REAM P Wash and ream rat hole from 4,216' MD to 4,226' MD GPM: 800 PSI: 2015 RPM: 80 12.0 TQ on btm 4,216.0 4,226.0 12/17/2023 16:00 12/17/2023 16:30 0.50 SURFAC, DRILLOUT DDRL P Drill 12-1/4" hole from 4,226' MD to 4,246' MD 3,030' TVD WOB: 12k GPM: 800 PSI: 2999 RPM: 80 12.0 k TQ on bttm 12.0 k TQ off bttm 4,226.0 4,246.0 12/17/2023 16:30 12/17/2023 17:00 0.50 SURFAC, DRILLOUT CIRC P BROOH to 4,205' MD, Circulate hole clean. GPM: 1000 PSI: 2960 RPM: 30 7.0 TQ on btm 4,246.0 4,205.0 12/17/2023 17:00 12/17/2023 18:30 1.50 SURFAC, DRILLOUT LOT P R/U and perform LOT at 4,205' MD Shoe at 4,216' MD 3,042' TVD LOP: 830psi with 10.9ppg mud. EMW 16.1ppg 4,205.0 4,205.0 12/17/2023 18:30 12/17/2023 19:00 0.50 SURFAC, DRILLOUT REAM P Wash and ream rat hole from 4,205' MD to 4,246' MD 4,205.0 4,246.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 11/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/17/2023 19:00 12/18/2023 00:00 5.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4,246' MD to 4,640' MD 3,165' TVD. Displaced to 11.0ppg FWP on the fly. SIMOPS: Processing 9-5/8" casing. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 11k GPM: 900 PSI: 1700 ECD: 11.7ppg RPM: 150 10.0 k TQ on btm FO: 63% ROT: 127k ADT: 3.4 hrs TBH: 3.4 hrs TJH: 31.4 hrs 4,246.0 4,640.0 12/18/2023 00:00 12/18/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4,640' MD to 5,269' MD 3,352' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 11k GPM: 1040 PSI: 2480 ECD: 11.9ppg RPM: 160 9.0 k TQ on btm 4.0 k TQ off btm FO: 67% ROT: 1132k PU: 140k SO: 122k ADT: 4.5 hrs TBH: 7.9 hrs TJH: 35.9 hrs 4,640.0 5,269.0 12/18/2023 06:00 12/18/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5,269' MD to 5,929' MD 3,548' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 20k GPM: 1040 PSI: 2700 ECD: 12.0ppg RPM: 160 10.0 k TQ on btm 4.0 k TQ off btm FO: 65% ROT: 142k PU: 142k SO: 122k ADT: 4.4 hrs TBH: 12.3 hrs TJH: 40.3 hrs 5,269.0 5,929.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 12/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/18/2023 12:00 12/18/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5,929' MD to 6,589' MD 3,734' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 17k GPM: 1040 PSI: 2780 ECD: 12.0ppg RPM: 160 10.0 k TQ on btm 4.0 k TQ off btm FO: 65% ROT: 141k PU: 157K SO: 127k ADT: 4.3 hrs TBH: 16.6 hrs TJH: 32.6 hrs 5,929.0 6,589.0 12/18/2023 18:00 12/19/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 6,589' MD to 7,320' MD 3,954' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 28k GPM: 1040 PSI: 3130 ECD: 12.3ppg RPM: 160 11.0 k TQ on btm 4.0 k TQ off btm FO: 65% ROT: 144k PU: 163k SO: 128k ADT: 4.5 hrs TBH: 21.1 hrs TJH: 49.1hrs 6,589.0 7,320.0 12/19/2023 00:00 12/19/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 7,320' MD to 8,068' MD 4,333' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 27k GPM: 1040 PSI: 3450 ECD: 12.9ppg RPM: 170 12.0 k TQ on btm 8.0 k TQ off btm FO: 64% ROT: 158k PU: 177k SO: 135k ADT: 4.3 hrs TBH: 25.4 hrs TJH: 53.4hrs 7,320.0 8,068.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 13/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/19/2023 06:00 12/19/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8,068' MD to 8,632' MD 4,750' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 35k GPM: 1040 PSI: 3650 ECD: 12.6ppg RPM: 170 18.0 k TQ on btm 11.0 k TQ off btm FO: 64% ROT: 177k PU: 220k SO: 151k ADT: 4.2 hrs TBH: 29.6 hrs TJH: 57.6hrs 8,068.0 8,632.0 12/19/2023 12:00 12/19/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8,632' MD to 9,342' MD 5,382' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 38k GPM: 1000 PSI: 3560 ECD: 12.5ppg RPM: 170 18.0 k TQ on btm 10.0 k TQ off btm FO: 63% ROT: 196k PU: 259k SO: 162k ADT: 4.4 hrs TBH: 34.0 hrs TJH: 62.0hrs 8,632.0 9,342.0 12/19/2023 18:00 12/19/2023 20:30 2.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,342' MD to 9,598' MD 5,629' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 32k GPM: 1000 PSI: 3680 ECD: 12.5ppg RPM: 170 18.0 k TQ on btm 12.0 k TQ off btm FO: 63% ROT: 206k PU: 265k SO: 154k ADT: 2.2 hrs TBH: 36.2 hrs TJH: 64.2hrs 9,342.0 9,598.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 14/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/19/2023 20:30 12/19/2023 21:00 0.50 INTRM1, DRILL SVRG P Circulate at 9,598' MD, Service rig, Change suction valve and seat in #1 mud pump, Add oil in top drive and adjust link tilt. GPM: 518 PSI: 1285 9,598.0 9,598.0 12/19/2023 21:00 12/20/2023 00:00 3.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,598' MD to 9,880' MD 5,908' TVD. At 23:00hrs 9,787' MD, adding black product spike fluid. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 28k GPM: 1000 PSI: 3740 ECD: 12.3ppg RPM: 170 20.0 k TQ on btm 13.0 k TQ off btm FO: 63% ROT: 213k PU: 280k SO: 173k ADT: 1.8 hrs TBH: 38 hrs TJH: 66hrs 9,598.0 9,880.0 12/20/2023 00:00 12/20/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,880' MD to 10,446' MD 6,472' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 38k GPM: 980 PSI: 3590 ECD: 12.3ppg RPM: 170 22.0 k TQ on btm 12.0 k TQ off btm FO: 63% ROT: 230k PU: 290k SO: 191k ADT: 4.6 hrs TBH: 42.6 hrs TJH: 70.6hrs 9,880.0 10,446.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 15/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/20/2023 06:00 12/20/2023 12:15 6.25 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 10,446' MD to 10,967' MD 6,950' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 38k GPM: 950 PSI: 3660 ECD: 12.3ppg RPM: 170 22.0 k TQ on btm 12.0 k TQ off btm FO: 62% ROT: 239k PU: 305k SO: 198k ADT: 4.4 hrs TBH: 47.0 hrs TJH: 75.0hrs 10,446.0 10,967.0 12/20/2023 12:15 12/20/2023 12:45 0.50 INTRM1, DRILL CIRC P High torque 30k at 10,967' MD, string stalled. Back ream stand and clean up to 10,917' MD. GPM: 900 PSI: 3350 ECD: 11.7ppg RPM: 80 25.0 k TQ off btm 10,967.0 10,967.0 12/20/2023 12:45 12/20/2023 18:00 5.25 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 10,967' MD to 11,209' MD 7,199' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 31k GPM: 950 PSI: 3500 ECD: 12.1ppg RPM: 170 25.0 k TQ on btm 12.0 k TQ off btm FO: 63% ROT: 238k PU: 305k SO: 198k ADT: 3.1 hrs TBH: 50.1 hrs TJH: 78.1hrs 10,967.0 11,209.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 16/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/20/2023 18:00 12/20/2023 20:45 2.75 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 11,209' MD to 11,388' MD 7,353' TVD. Note: Drilling with 1 of the 3 ribs not functioning. Indications of hyd pressure issue. WOB: 31k GPM: 950 PSI: 3500 ECD: 12.1ppg RPM: 170 25.0 k TQ on btm 12.0 k TQ off btm FO: 63% ROT: 238k PU: 305k SO: 198k ADT: 1.2 hrs TBH: 51.3 hrs TJH: 79.3hrs 11,209.0 11,388.0 12/20/2023 20:45 12/20/2023 21:30 0.75 INTRM1, DRILL BKRM P At 11,388' MD, Attempt to take T&D, Observed 130k over normal PU weight without breaking over. Back ream stand and take T&D again, back close to normal. PU:430k Did not break over SO: 192k ROT: 240k After back ream PU: 338k SO: 193 ROT: 240k 11,388.0 11,388.0 12/20/2023 21:30 12/21/2023 00:00 2.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 11,388' MD to 11,570.67' MD 7,502' TVD. Top of HRZ 11,537' MD 7,475' TVD WOB: 24k GPM: 950 PSI: 3680 ECD: 12.0ppg RPM: 170 25.0 k TQ on btm 18.0 k TQ off btm FO: 60% ROT: 246k PU: 360k SO: 194k ADT: 2.0 hrs TBH: 53.3 hrs TJH: 81.3hrs 11,388.0 11,570.7 12/21/2023 00:00 12/21/2023 02:45 2.75 INTRM1, TRIPCAS BKRM P TD at 11,570.70' MD 7,502' TVD, Take final survey, Back ream to 11,015' MD at 400'/hr. GPM: 980 PSI: 3800 ECD: 11.9ppg RPM: 170 22.0 k TQ off btm ROT: 228k 11,571.0 11,015.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 17/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2023 02:45 12/21/2023 05:00 2.25 INTRM1, TRIPCAS REAM P Ream in hole from 11,015' MD to 11,571' MD. GPM: 980 PSI: 3800 ECD: 11.9ppg RPM: 170 22.0 k TQ off btm ROT: 228k 11,015.0 11,571.0 12/21/2023 05:00 12/21/2023 06:30 1.50 INTRM1, TRIPCAS CIRC P Circulate at 11,571' MD 5 min, BR up to 11,537' MD (top HRZ) Continue BROOH rack back stand after 1 btm's up 11,484' MD. GPM: 980 PSI: 3800 ECD: 11.8ppg RPM: 170 22.0 k TQ off btm ROT: 230k PU: 308k SO: 198k 11,571.0 11,484.0 12/21/2023 06:30 12/21/2023 07:00 0.50 INTRM1, TRIPCAS OWFF P OWFF (Static) 11,484.0 11,484.0 12/21/2023 07:00 12/21/2023 12:15 5.25 INTRM1, TRIPCAS BKRM P BROOH from 11,484' MD (34°) to 10,459' MD. (7°) Note: L/D double from stand 110, unable to break connection. GPM: 950 PSI: 3450 ECD: 11.4ppg RPM: 170 22.0 k TQ off btm ROT: 205k 11,484.0 10,459.0 12/21/2023 12:15 12/21/2023 14:30 2.25 INTRM1, TRIPCAS CIRC P Pack off at 10,459' MD, reduce pump rate to 200gpm 775psi and regained full returns, Continue stage pump rate up to 900gpm. GPM: 900 PSI: 2980 ECD: 11.3ppg RPM: 80 21.0 k TQ off btm ROT: 210k 10,459.0 10,459.0 12/21/2023 14:30 12/21/2023 18:00 3.50 INTRM1, TRIPCAS BKRM P BROOH from 10,459' MD (7°) to 9,600' MD. (11°) SIMOPS: Building 4" doubles and place in tubs. GPM: 900 PSI: 2900 ECD: 11.7ppg RPM: 120 19.0 k TQ off btm ROT: 193k 10,459.0 9,600.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 18/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2023 18:00 12/22/2023 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 9,600' MD (11°) to 8,070' MD. (50°) SIMOPS: Building 4" doubles and place in tubs, total 205 doubles. GPM: 900 PSI: 2900 ECD: 11.7ppg RPM: 120 19.0 k TQ off btm ROT: 193k Pumped 25bbl LoVis sweep at 8,460' MD, Increase in cuttings at 8,200' MD when sweep returned. 9,600.0 8,070.0 12/22/2023 00:00 12/22/2023 06:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 8,070' MD (50°inc) to 6,740' MD. (73°inc) GPM: 990 PSI: 2980 ECD: 11.6ppg RPM: 120-140 14.0-20.0 k TQ off btm ROT: 156k Pumped 25bbl LoVis NP sweeps as needed 8,028' MD and 7,181' MD. 8,070.0 6,740.0 12/22/2023 06:00 12/22/2023 07:00 1.00 INTRM1, TRIPCAS CIRC P High torque at 6,740' MD, Pumped 25bbl LoVis NP sweep. GPM: 990 PSI: 2980 ECD: 11.6ppg RPM: 120-140 14.0-20.0 k TQ off btm ROT: 156k 6,740.0 6,740.0 12/22/2023 07:00 12/22/2023 12:00 5.00 INTRM1, TRIPCAS BKRM P BROOH from 6,740' MD (73°inc) to 5,735' MD. (73°inc) GPM: 990 PSI: 2880 ECD: 11.6ppg RPM: 120 14.0-20.0 k TQ off btm ROT: 125k Pumped 25bbl LoVis NP sweeps as needed 6,710' MD and 5,750' MD. 6,740.0 5,735.0 12/22/2023 12:00 12/22/2023 22:00 10.00 INTRM1, TRIPCAS BKRM P BROOH from 5,735' MD (73°inc) to 4,175' MD (74°inc) Note: High torque/pipe stalled at 4,291' MD bit depth, worked string and torque dropped from 17.5 to 10k. (Shoe at 4,216' MD, Base of rat hole 4,226' MD, Upper stab at 4,244' MD) Possible chunk of cement worked down hole while drilling. GPM: 990 PSI: 2880 ECD: 11.6ppg RPM: 120 14.0-20.0 k TQ off btm ROT: 125k 5,735.0 4,175.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 19/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/22/2023 22:00 12/23/2023 00:00 2.00 INTRM1, TRIPCAS CIRC P Circulate at 4,175' MD, pump 40bbls LoVis NP sweep and circulate SS. (Very little increase in cuttings) Pump 2nd 40bbls LoVis NP sweep and circulate SS. (Very little increase in cuttings) Note: Well hasn't unloaded yet, 4,175' MD (74°inc) GPM: 1040 PSI: 2100 ECD: 11.1ppg RPM: 80 9.0 k TQ off btm ROT: 116k 4,175.0 4,175.0 12/23/2023 00:00 12/23/2023 01:30 1.50 INTRM1, TRIPCAS BKRM P BROOH 850'/hr from 4,175' MD (74°inc) to 3,605' MD. (70°inc) GPM: 1040 PSI: 1900 ECD: 11.4ppg RPM: 80 TRQ: 10 4,175.0 3,605.0 12/23/2023 01:30 12/23/2023 06:00 4.50 INTRM1, TRIPCAS BKRM P BROOH 400'/hr from 3,605' MD (70°inc) to 2,595' MD. (48°inc) GPM: 510 PSI: 665 RPM: 80 TRQ: 10 Pump LoVis NP sweep as needed. Note: Pump #2, washed out discharge cylinder #1. 3,605.0 2,595.0 12/23/2023 06:00 12/23/2023 07:00 1.00 INTRM1, TRIPCAS CIRC P Pump Hi/LoVis sweep and circulate SS. No increase in cuttings. Blow down TD. 2,595.0 2,595.0 12/23/2023 07:00 12/23/2023 08:45 1.75 INTRM1, TRIPCAS TRIP P POOH from 2,595' MD (48°inc) to 561' MD 2,595.0 561.0 12/23/2023 08:45 12/23/2023 09:00 0.25 INTRM1, TRIPCAS OWFF P OWFF (Static) 561.0 561.0 12/23/2023 09:00 12/23/2023 11:00 2.00 INTRM1, TRIPCAS BHAH P POOH and L/D intermediate 1 BHA. One pad slight exposed. BHA clean. One broken cutter. 561.0 0.0 12/23/2023 11:00 12/23/2023 12:30 1.50 INTRM1, CASING WWWH P Pull wear ring and Jet BOP stack. 0.0 0.0 12/23/2023 12:30 12/23/2023 15:00 2.50 INTRM1, CASING RURD P R/U 9-5/8" casing equipment. SIMOPS: Found second discharge module creacked on #2 pump #3 cylinder. Monitor well: Static 0.0 0.0 12/23/2023 15:00 12/23/2023 16:00 1.00 INTRM1, CASING PUTB P PJSM, M/U 9-5/8" shoe track. Check floor equipment (all good) Float collar 2.78' 2-joints 84.34' Shoe 3.8' 0.0 125.0 12/23/2023 16:00 12/23/2023 18:00 2.00 INTRM1, CASING PUTB P Continue P/U and run 9-5/8" 47# T95 H563 casing from 125' MD to 1,293' MD. 125.0 1,293.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 20/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/23/2023 18:00 12/23/2023 23:00 5.00 INTRM1, CASING PUTB P Continue P/U and run 9-5/8" 47# T95 H563 casing from 1,293' MD to 4,180' MD. 1,293.0 4,180.0 12/23/2023 23:00 12/24/2023 00:00 1.00 INTRM1, CASING CIRC P Break circulation at 4,180' MD and stage pumps up 1/2bbl increments to 6bpm 165psi. Circulate btms up. GPM: 252 PSI: 165 PU: 195k SO: 169k ROT: 183k RPM: 20 TRQ: 8-11 No pump PU:199k SO: 175k ROT: 191k 4,180.0 4,180.0 12/24/2023 00:00 12/24/2023 06:00 6.00 INTRM1, CASING PUTB P Continue P/U and run 9-5/8" 47# T95 H563 casing from 4,180' MD to 7,160' MD. SO: 164k 4,180.0 7,160.0 12/24/2023 06:00 12/24/2023 12:00 6.00 INTRM1, CASING PUTB P Continue P/U and run 9-5/8" 47# T95 H563 casing from 7,160' MD to 10,850' MD. SO: 275k 7,160.0 10,850.0 12/24/2023 12:00 12/24/2023 13:30 1.50 INTRM1, CASING PUTB P Continue P/U and run 9-5/8" 47# T95 H563 casing from 10,850' MD to 11,516' MD. SO: 280k 10,850.0 11,516.0 12/24/2023 13:30 12/24/2023 14:00 0.50 INTRM1, CASING HOSO P Make up hanger/ landing joint. Break circulation 1/2bpm and wash in hole. String packed off, work string and regained circulation. Land string with 280K. PU: 530k SO: 240k GPM: 21 PSI 330 11,516.0 11,599.0 12/24/2023 14:00 12/24/2023 16:45 2.75 INTRM1, CEMENT CIRC P Stage pumps up to 8bpm 480psi. Circulate and condition mud. 11,599.0 11,599.0 12/24/2023 16:45 12/24/2023 17:45 1.00 INTRM1, CEMENT OWFF P Change out Volant cup. OWFF (Static) 11,599.0 11,599.0 12/24/2023 17:45 12/24/2023 18:15 0.50 INTRM1, CEMENT CIRC P Stage pumps up to 8bpm 480psi. Circulate and condition mud. 11,599.0 11,599.0 12/24/2023 18:15 12/24/2023 18:30 0.25 INTRM1, CEMENT PRTS P R/U cement lines, Break circulation and test lines to 4000psi. 11,599.0 11,599.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 21/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/24/2023 18:30 12/24/2023 22:30 4.00 INTRM1, CEMENT CMNT P Mix and pump 64 bbls of 12.5 ppg Mud Push II @ 5 bbls/min, 385 psi, Dropped bottom plug. Start batching lead. Pump 69 bbls of 13.0 ppg G-Blend cement at 4.5 bbls/min, 365 psi ICP. Batch and pump 10 bbls of G Blend Tail 15.8 ppg cement @ 4.9 bbls/min, 173 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 5/6 bbls/min, 255 psi ICP, 851 psi FCP. Slow pumps 30 bbls prior to calculated bump to 3 bbls/min, 851 psi ICP, Bump plug with 1410 psi (822 bbls + 20 bbls). 6955 strokes, final circ. PSI 851 Pressure up to 1410 psi & hold for 5 minutes. Bleed off pressure, Check floats good. Cement in place @ 22:10hrs 12/24/23 (No mud losses) 11,599.0 11,599.0 12/24/2023 22:30 12/25/2023 00:00 1.50 INTRM1, WHDBOP PRTS P RU to test casing. Pressure test casing to 3500psi 30 min. Good test.17.8bbls pumped/returned. RD test equipment. 11,599.0 11,599.0 12/25/2023 00:00 12/25/2023 01:30 1.50 INTRM1, WHDBOP RURD P Blow down all surface lines and equipment, R/D casing equipment and pump out BOPs. SIMOPS: Cleaning mud pits and changing mud pump liners to 5.5". 0.0 0.0 12/25/2023 01:30 12/25/2023 02:30 1.00 INTRM1, WHDBOP PRTS P R/U and set packoff, RILD and test to 5k (good test) 0.0 0.0 12/25/2023 02:30 12/25/2023 06:00 3.50 INTRM1, WHDBOP BOPE P Change top rams from 9-5/8" to 2-7/8" X 5" VBR's. Test with 5" drill pipe 250/3500 5min/10min. Note: Adam Earl AOGCC waived witness 19:17hrs 12/24/23. Note: Quinn Sawyer BLM waived witness 20:21hrs 12/25/23. 0.0 0.0 12/25/2023 06:00 12/25/2023 08:00 2.00 INTRM1, WHDBOP SLPC P Cut and slip 79' Drill line, Calibrate block and C-O-M. 0.0 0.0 12/25/2023 08:00 12/25/2023 08:30 0.50 INTRM1, WHDBOP SVRG P Service rig, Weekly derrick inspection. 0.0 0.0 12/25/2023 08:30 12/25/2023 09:30 1.00 INTRM1, WHDBOP BHAH P Change out Choke HCR valve. Leaking hydralic oil when cycled. SIMOPS: Load BHA tools and equipment on to rig floor. 0.0 0.0 12/25/2023 09:30 12/25/2023 10:30 1.00 INTRM1, WHDBOP RGRP T Test choke HCR valve 250/5000psi 5/10min. R/D test equipment. 0.0 0.0 12/25/2023 10:30 12/25/2023 11:15 0.75 INTRM1, WHDBOP OTHR P Set 8.75" wear ring. FMC lock down and marked. 0.0 0.0 12/25/2023 11:15 12/25/2023 14:00 2.75 INTRM1, DRILLOUT BHAH P P/U Baker 8.5" X 9-7/8" intermediate 2 BHA to 548' MD. 70k. Sensor offset: Near bit Inc.: 6.80' Near bit VSS.: 6.80' Pressure: 12.73' Gamma: 13.62' Resisitivity: 17.66 Directional / VSS: 23.45' 0.0 548.0 12/25/2023 14:00 12/25/2023 17:00 3.00 INTRM1, DRILLOUT TRIP P TIH with Intermediate 2 BHA from 548' MD to 2,900' MD. 548.0 2,900.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 22/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/25/2023 17:00 12/25/2023 18:00 1.00 INTRM1, DRILLOUT CIRC P Fill pipe and surface test tools. (all good) Note: Mud pump #2 pop off tripped at 414psi (Set at 4600psi) Note: Mud pump #2 pop off tripped at 982psi (Set at 4300psi) 12-12-23 03:00 hrs. 2,900.0 2,900.0 12/25/2023 18:00 12/25/2023 22:30 4.50 INTRM1, DRILLOUT TRIP P Continue TIH with Intermediate 2 BHA from 2,900' MD to 11,284' MD. Fill pipe every 25 stands. 2,900.0 11,284.0 12/25/2023 22:30 12/25/2023 23:30 1.00 INTRM1, DRILLOUT CIRC P Break circulation at 11,284' MD. Choke drill with crews. SIMOPS: R/U HT60 rig tongs. Break over-torqued 5" double. 11,284.0 11,284.0 12/25/2023 23:30 12/26/2023 00:00 0.50 INTRM1, DRILLOUT OTHR P P/U 5" high torque double drill pipe. Break connection and L/D same. 150k to break connection. 11,284.0 11,284.0 12/26/2023 00:00 12/26/2023 07:00 7.00 INTRM1, DRILLOUT WASH P Wash and ream from 11,284' MD to 11,467' MD, tagged cement plugs. Drill out shoe track from 11,467' MD to top of shoe at 11,555' MD. Continue drilling shoe at 11,555' MD to 11,559' MD. Clean out 12-1/4" rat hole from 11,559' MD to 11,571' MD. Note: 4hrs to drill out shoe. GPM: 400 PSI: 2100 ECD: 12.5 ppg RPM: 80 10.0 k TQ off btm ROT: 229k PU: 290k SO: 195k 11,284.0 11,571.0 12/26/2023 07:00 12/26/2023 07:30 0.50 INTRM1, DRILLOUT DDRL P Drill 8-1/2" Hole from 11,571' MD to 11,590' MD. GPM: 650 PSI: 3690 ECD: 12.7 ppg WOB: 8-15k RPM: 85 10.0-12.0 k TQ off btm ROT: 229k PU: 290k SO: 195k SIMOPS: Attempt to preform LOT on 9- 5/8" X 13-3/8". Pressured up to 806psi (16.1ppg EMW). 11,571.0 11,590.0 12/26/2023 07:30 12/26/2023 09:00 1.50 INTRM1, DRILLOUT BKRM P BROOH from 11,590' MD tp 11,501' MD, while circulating btm's up. GPM: 600 PSI: 3695 ECD: 12.8ppg RPM: 85 12.0-14.0 k TQ off btm 11,590.0 11,501.0 12/26/2023 09:00 12/26/2023 10:00 1.00 INTRM1, DRILLOUT FIT P FIT at 11,501' MD / 7,492' TVD, (Shoe 11,559' MD 7,92' TVD) Mud weight 11.5ppg, Test pressure 978psi, EMW 14.0ppg. 11,501.0 11,501.0 12/26/2023 10:00 12/26/2023 11:00 1.00 INTRM2, DRILL MPDA P Pull trip nipple and install 5" RCD. 11,501.0 11,501.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 23/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/26/2023 11:00 12/26/2023 11:45 0.75 INTRM2, DRILL REAM P Wash and ream in hole from 11,501' MD to 11,590' MD. Down-link and establish drilling parameters. 11,501.0 11,590.0 12/26/2023 11:45 12/26/2023 17:30 5.75 INTRM2, DRILL DDRL P Drill 8-1/2" hole from 11,590' MD to 11,672' MD / 7,582' TVD. WOB: 20-30k GPM: 600 PSI: 3700 ECD: 12.9ppg RPM: 60-100 12.0-18.0 k TQ on btm 10.0 k TQ off btm FO: 45% ROT: 219k PU: 295k SO: 198k ADT: 2.5 hrs TBH: 2.9 hrs TJH: 84.2 hrs 11,590.0 11,672.0 12/26/2023 17:30 12/26/2023 19:00 1.50 INTRM2, DRILL CIRC P Take base parameters at 11,655' MD f/ underreamer. Drop 1.25" Torlon ball. Pump down string. Pump down at 250gpm for 1000stks and reduce rate to 100gpm 456psi. Ball landed 2020stks. Check parameters to confirm under- reamer open. Perform 10k ledge test. (Good test). Wash and ream in hole to 11,672' MD. Base parameters: 4332 Turbine RPM 600 GPM 3685 PSI Post parameters: 4000 Turbine RPM 600 GPM 3300 PSI 11,672.0 11,672.0 12/26/2023 19:00 12/27/2023 00:00 5.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 11,672' MD to 12,004' MD / 7,832' TVD. WOB: 20-30k GPM: 650 PSI: 3700 ECD: 12.9ppg RPM: 180 12.0-20.0 k TQ on btm 10.0 k TQ off btm FO: 45% ROT: 219k PU: 295k SO: 198k ADT: 4.0 hrs TBH: 6.9 hrs TJH: 88.2hrs Note: Squeezed 23.25bbls in 9-5/8" X 13-3/8" annulus. 11,672.0 12,004.0 12/27/2023 00:00 12/27/2023 00:30 0.50 INTRM2, DRILL SVRG P Circulate at 12,004' MD. Service #2 mud pump Pop off connection. Change gasket. 12,004.0 12,004.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 24/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/27/2023 00:30 12/27/2023 06:00 5.50 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 12,004' MD / 7,832' TVD to ~12,506' MD / 8,115' TVD. WOB: 32k GPM: 650 PSI: 3580 ECD: 12.9ppg RPM: 180 21.0 k TQ on btm 10.0 k TQ off btm FO: 42% ROT: 220k ADT: 4.0 hrs TBH: 10.9 hrs TJH: 92.2hrs 12,004.0 12,506.0 12/27/2023 06:00 12/27/2023 12:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 12,506' MD / 8,115' TVD to 12,995' MD / 8,291' TVD. WOB: 32k GPM: 650 PSI: 3680 ECD: 12.8ppg RPM: 180 23.0 k TQ on btm FO: 44% ROT: 220k ADT: 4.4 hrs TBH: 15.3 hrs TJH: 96.6hrs 12,506.0 12,995.0 12/27/2023 12:00 12/27/2023 14:00 2.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 12,995' MD / 8,291' TVD to 13,089' MD / 8,313' TVD. WOB: 32k GPM: 600 PSI: 3680 ECD: 12.8ppg RPM: 180 22.0 k TQ on btm FO: 44% ROT: 220k ADT: 1.8 hrs TBH: 17.1 hrs TJH: 98.4hrs 12,995.0 13,089.0 12/27/2023 14:00 12/27/2023 14:30 0.50 INTRM2, DRILL RGRP T Change out expansion joint on #2 mud pump. GPM: 350 PSI: 1500 RPM: 60 TRQ: 17k 13,089.0 13,089.0 12/27/2023 14:30 12/27/2023 16:00 1.50 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 13,089' MD / 8,313' TVD to 13,147' MD / 8,326' TVD. WOB: 3220k GPM: 600 PSI: 3300 ECD: 12.4ppg RPM: 180 21.0 k TQ on btm FO: 44% ROT: 220k ADT: 1.3 hrs TBH: 18.4 hrs TJH: 99.7hrs 13,089.0 13,147.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 25/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/27/2023 16:00 12/27/2023 17:30 1.50 INTRM2, TRIPCAS CIRC P Take final survey, Take base parameters at 13,147' MD f/ underreamer. Drop 1.625" closing ball. Pump down string. Pump down at 250gpm for 1200stks and reduce rate to 100gpm 750psi. Ball landed 2157stks. Check parameters to confirm under-reamer closed. Base parameters: 3882 Turbine RPM 560 GPM 2860 PSI Post parameters: 4065 Turbine RPM 560 GPM 3010 PSI 13,147.0 13,147.0 12/27/2023 17:30 12/27/2023 19:00 1.50 INTRM2, TRIPCAS CIRC P Circulate hole clean at 13,147' MD. GPM: 660 PSI: 3960 RPM: 120 TRQ: 17k ROT: 235k PU: 310k SO: 202k 13,147.0 13,147.0 12/27/2023 19:00 12/27/2023 21:00 2.00 INTRM2, TRIPCAS SMPD P SOOH from 13,147' MD to 11,740' MD. Over Pull at 12,921' MD quick pull 40k and dropped off. SO. Pull through with no over pull. Continue SOOH to 11,807' MD. 30k continuous pull. SIH to 11,740' MD. 13,147.0 11,740.0 12/27/2023 21:00 12/27/2023 23:00 2.00 INTRM2, TRIPCAS BKRM P BROOH from 11,740' MD to 11,550' MD. GPM: 660 PSI: 3700 RPM: 50/80 TRQ: 15k 11,740.0 11,550.0 12/27/2023 23:00 12/27/2023 23:30 0.50 INTRM2, TRIPCAS CIRC P Circulate Btms up at 11,550' MD, while BROOH to 11469' MD. Shakers clean on Btm's up. 11,550.0 11,469.0 12/27/2023 23:30 12/28/2023 00:00 0.50 INTRM2, TRIPCAS OWFF P OWFF (Static). Blow down surface equipment. 11,469.0 11,469.0 12/28/2023 00:00 12/28/2023 06:00 6.00 INTRM2, TRIPCAS STRP P SOOH from 11,469' MD to 5,170' MD at 50'/min with 550psi static and 670psi dynamic. 11,469.0 5,170.0 12/28/2023 06:00 12/28/2023 10:45 4.75 INTRM2, TRIPCAS STRP P SOOH from 5,170' MD to 642' MD at 50'/min with 550psi static and 670psi dynamic. 5,170.0 642.0 12/28/2023 10:45 12/28/2023 11:30 0.75 INTRM2, TRIPCAS OWFF P OWFF (Static). SIMOPS: Pull RCD and install trip nipple. 642.0 642.0 12/28/2023 11:30 12/28/2023 15:00 3.50 INTRM2, TRIPCAS BHAH P Lay down 5" HWT and Intermediate 2 BHA. 642.0 0.0 12/28/2023 15:00 12/28/2023 17:30 2.50 INTRM2, TRIPCAS OTHR P Clean and clear rig floor. Drain BOP stack. Change UPR to 7-5/8" fixed rams. 0.0 0.0 12/28/2023 17:30 12/28/2023 20:00 2.50 INTRM2, TRIPCAS PRTS P Pull wear ring and install 7-5/8" test joint. Work air from system. Pressure test with 7-5/8" rams/test joint to 250/2500psi 5/10min on annular and 250/3500psi 5/10min UPR. Instal 8.75" wear ring. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 26/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/28/2023 20:00 12/28/2023 21:00 1.00 INTRM2, CASING OTHR P P/U Baker cement head and M/U 15' pup joint and L/D in pipe shed. SIMOPS: Finish R/U 7-5/8" casing equipment. 0.0 0.0 12/28/2023 21:00 12/28/2023 22:45 1.75 INTRM2, CASING PUTB P M/U 7-5/8" 29.7ppf L-80 H523 shoe track. Backerlok joints 1-4. (Torque turn connections to 11,900ft/lbs). Check floats (all ok). 1- Joint 1- Landing collar 2- Joints 1- Float collar (Citadel 338 ultra mag DV) 1- joint 1 Shoe (Citadel 338 ultra mag DV) with wound tapered nose. 0.0 123.0 12/28/2023 22:45 12/29/2023 00:00 1.25 INTRM2, CASING PUTB P M/U 7-5/8" 29.7ppf Eagle SF-H (Torque turn connections to 20,000ft/lbs) from 123' MD to 617' MD. Filling every joint to keep casing from floating in elevators. Note: Running 7-5/8" X 10" Vulcan centralizers. 123.0 617.0 12/29/2023 00:00 12/29/2023 02:30 2.50 INTRM2, CASING PUTB P M/U 7-5/8" 29.7ppf Eagle SF-H (Torque turn connections to 20,000ft/lbs) from 617' MD to 1,737' MD. Filling every joint to keep casing from floating in elevators. Note: Running 7-5/8" X 10" Vulcan centralizers. 617.0 1,737.0 12/29/2023 02:30 12/29/2023 03:00 0.50 INTRM2, CASING PUTB P M/U 7-5/8" Eagle SF-H pin X H523 X/O joint. P/U Dril-Quip 7-5/8" Hanger. M/U 5' pup and X/O. 1,737.0 1,737.0 12/29/2023 03:00 12/29/2023 21:30 18.50 INTRM2, CASING OWFF T Dril-Quip plug set has wrong thread that was sent out with hanger assy. Trouble shoot same. Waiting on X/O being made in Anchorge. (ETA to rig 21:00hrs) New plug sets in route from Houston and landed in Seatle at 20:32hrs. ETA in Anchorge 01:30hrs 12-30-23. 1,737.0 1,737.0 12/29/2023 21:30 12/29/2023 22:30 1.00 INTRM2, CASING OTHR P X/O arrived on location. Inspect and check dimentsions. Sent in data to town and received approval to run crossover on plug set. Make up plug set and M/U hanger. RIH with stand of 5" drill pipe to 1,886' MD. 1,737.0 1,886.0 12/29/2023 22:30 12/30/2023 00:00 1.50 INTRM2, CASING RUNL P Circulate at 1,886' MD, stage pumps up to 6bpm 510psi. Circulate liner volume. Pull trip nipple and install 5" RCD. Take T&D at 1981' MD. PU: 116k SO: 88k ROT:101k RPM: 10 TRQ 3 RPM: 20 TRQ 3.5 1,886.0 1,981.0 12/30/2023 00:00 12/30/2023 06:00 6.00 INTRM2, CASING RUNL P Continue SIH with 7-5/8" Liner with 5" drill pipe at 30'/min from 1,981' MD to 7,800' MD. SO: 91k 1,981.0 7,800.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 27/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/30/2023 06:00 12/30/2023 09:30 3.50 INTRM2, CASING RUNL P Continue SIH with 7-5/8" Liner with 5" drill pipe at 30'/min from 7,800' MD to 11,491' MD. SO: 190k 7,800.0 11,491.0 12/30/2023 09:30 12/30/2023 10:00 0.50 INTRM2, CASING CIRC P Fill pipe at 11,491' MD. PU: 275k SO: 190k ROT: 228k TRQ: 13k 11,491.0 11,491.0 12/30/2023 10:00 12/30/2023 11:30 1.50 INTRM2, CASING RUNL P Continue SIH with 7-5/8" Liner with 5" drill pipe at 30'/min from 11,491' MD to 13,147' MD. Tagged bottom with 10K. L/D 2 singles. SO: 190k 11,491.0 13,137.0 12/30/2023 11:30 12/30/2023 13:00 1.50 INTRM2, CEMENT RURD P M/U Baker cement swivel. PU: 315k SO: 200k 13,137.0 13,137.0 12/30/2023 13:00 12/30/2023 17:00 4.00 INTRM2, CEMENT CIRC P Circulate and condition mud at 13,137' MD. Stage pumps up to 4bpm 370psi. 13,137.0 13,137.0 12/30/2023 17:00 12/30/2023 19:30 2.50 INTRM2, CEMENT CMNT P Rig pump 70bbls 8.9ppg KCL 5% deep clean spacer at 4bpm 780psi. Flood lines and test to 4600 PSI. Drop bottom dart. Swap to cementers. Pump 64.5 BBLS of 15.8ppg cement @ 4-4.5 BPM. SD and drop top dart. Pump 20 BBLS FW w/ cement unit. Swap to rig pumps and displace at 4 BPM 750psi. (BTM dart landed at 1263stks and sheared at 904psi. Top dart landed at 2006stks and sheared at 2169psi. BTM plug landed at 2126stks and sheared at 2960psi). Slow rate to 2 BPM and bump plug 2905stks (5.5bbls early). FCP - 450psi. Pressure up to 1250psi. Hold for 5 minutes and check floats. All Good. Full returns throughout job. No losses. Cement in place @ 18:55hrs, 12/30/23. TOL: 11,379' MD Landing collar 13,009' MD Float collar: 13,092' MD Shoe: 13,137' MD 13,137.0 13,137.0 12/30/2023 19:30 12/30/2023 21:00 1.50 INTRM2, CEMENT PRTS P Set Dril-Quip hanger. Pressure up to 5000psi (10min). Hanger/Packer set at 3759psi. Bleed off 5.5bbls pumped/returned. Pull test to 375k (60k over). L/D cement swivel and blow down cement line. P/U single and SO to 189k (30k down). Close bag with pipe open to atmosphere. Test hanger to 2000psi for 10min (all good). 4bbls pumped / returned. P/U string 19' noticed 7k drop - RT out of hanger assy. (Pumped 1bbl to seat Bozo plug) 13,137.0 13,137.0 12/30/2023 21:00 12/30/2023 23:00 2.00 INTRM2, CEMENT MPDA P OWFF (static). Pull RCD and Install trip nipple. Blow down surface equipment. 11,270.0 11,270.0 12/30/2023 23:00 12/31/2023 00:00 1.00 INTRM2, CEMENT TRIP P POOH from 11,270' MD to 10,100' MD. Culling 5" drill pipe and stand back in derrick to L/D off line. 11,270.0 10,100.0 12/31/2023 00:00 12/31/2023 07:30 7.50 INTRM2, CEMENT TRIP P Continue POOH from 10,100' MD to 81' MD. Cull pipe racking stands to be L/D off line (75 joints). 1,800.0 81.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 28/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/31/2023 07:30 12/31/2023 09:00 1.50 INTRM2, CEMENT BHAH P L/D Dril-Quip Liner hanger running tools. 81.0 0.0 12/31/2023 09:00 12/31/2023 09:30 0.50 INTRM2, CEMENT CLEN P Clean and clear rig floor from wet trip. 0.0 0.0 12/31/2023 09:30 12/31/2023 11:00 1.50 INTRM2, WHDBOP WWWH P Remove wear ring and wash stack. Blow down top drive and pump out BOP's. 0.0 0.0 12/31/2023 11:00 12/31/2023 14:00 3.00 INTRM2, WHDBOP BOPE P Close blind rams and change UPR to 2- 7/8" X 5" VBRs. SIMOPS: Inspect pressure switch on top drive. Seal up Joes box nad install PS- 21's. 0.0 0.0 12/31/2023 14:00 12/31/2023 15:00 1.00 INTRM2, WHDBOP PRTS P Install test plug. Rebuild 3" Demco valve and grease IBOP. 0.0 0.0 12/31/2023 15:00 12/31/2023 23:00 8.00 INTRM2, WHDBOP PRTS P BOPE Test All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5” Test jt: test annular/2 7/8" x 5" UPR/2 7/8" 5" LPR, W/ 4" Test jt: test annular/2 7/8" x 5" UPR/2 7/8" 5" LPR,Test choke valves 1-15. Manuals 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/Shear rams. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1400 psi, ACC = 1800 psi after all functions on bottles,14 sec for 200 psi. Build w/ 2 electric pumps, 81 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 23 sec. UPR = 18 sec, Blind / Shears = 16 sec, LPR = 16 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Brian Bixby waived witness BOP test at 10:53hrs 12-31-23. BLM Quinn M Sawyer waived witness BOP test at 08:21hrs 12-25-23. 0.0 0.0 12/31/2023 23:00 1/1/2024 00:00 1.00 INTRM2, WHDBOP RURD P Pull test plug and set wear ring. Blow down surface equipment. R/U to test casing. 0.0 0.0 1/1/2024 00:00 1/1/2024 01:00 1.00 INTRM2, DRILLOUT PRTS P Test 9-5/8" X 7-5/8" casing to 3500psi for 30 mins. 0.0 0.0 1/1/2024 01:00 1/1/2024 03:45 2.75 INTRM2, DRILLOUT BHAH P P/U Production BHA to 229' MD. 0.0 229.0 1/1/2024 03:45 1/1/2024 10:30 6.75 INTRM2, DRILLOUT TRIP P TIH with doubles from 229' MD to 7,940' MD. (Sonic tool turned on at 07:30hrs). Log free-ring pipe at 4,700' MD. 229.0 7,940.0 1/1/2024 10:30 1/1/2024 12:00 1.50 INTRM2, DRILLOUT DLOG P TIH with doubles from 7,940' MD to 9,400' MD. Log at 1800'/hr. 7,940.0 9,400.0 1/1/2024 12:00 1/1/2024 14:30 2.50 INTRM2, DRILLOUT DLOG P TIH with doubles from 9,400' MD to 11,398' MD. Log at 5000'/hr. Tagged DPOB with 7k. 9,400.0 11,398.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 29/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/1/2024 14:30 1/1/2024 17:30 3.00 INTRM2, DRILLOUT DRLG P Drill out DPOB from 11,398' MD. Clean out and wipe throught to 11,400' MD. GPM: 200 PSI: 1730 RPM: 40 TRQ: 8k 11,398.0 11,400.0 1/1/2024 17:30 1/1/2024 20:00 2.50 INTRM2, DRILLOUT DLOG P TIH with doubles from 11,400' MD to 12,665' MD. Log at 1800'/hr. Tagged up on CMT stringers at 12,665' MD. 11,400.0 12,665.0 1/1/2024 20:00 1/1/2024 22:00 2.00 INTRM2, DRILLOUT DLOG P Drill cement stringers from 12,665' MD to plug sets at 13,007' MD. 12,665.0 13,007.0 1/1/2024 22:00 1/2/2024 00:00 2.00 INTRM2, DRILLOUT DRLG P Drilling on plug set and landing collar from 13,007' MD to 13,009' MD. 13,007.0 13,009.0 1/2/2024 00:00 1/2/2024 06:30 6.50 INTRM2, DRILLOUT DRLG P Drill plug set and landing collar from 13,007' MD to 13,009' MD. GPM: 160-220 PSI: 1300-2300 WOB: 7-25k RPM: 10-100 TRQ: 7-16k SIMOPS: L/D culled 5" drill pipe from derrick. Phase 1 weather conditions at 06:20hrs. 13,009.0 13,009.0 1/2/2024 06:30 1/2/2024 08:00 1.50 INTRM2, DRILLOUT DRLG P Drill landing collar from 13,009' MD to 13,010' MD and cement to 13,035' MD. Work pipe to release pack off. GPM: 125-220 PSI: 1300-1800 WOB: 12-27k RPM: 25 TRQ: 15k SIMOPS: L/D culled 5" drill pipe from derrick. Phase 2 weather conditions at 07:11hrs. 13,009.0 13,035.0 1/2/2024 08:00 1/2/2024 12:30 4.50 INTRM2, DRILLOUT DISP P Drill cement from 13,035' MD to 13,098' MD while displacing to 8.8ppg FloPro. GPM: 200-225 PSI: 1500-2500 WOB: 28k RPM: 80 TRQ: 8-14k SIMOPS: L/D culled 5" drill pipe from derrick. 13,035.0 13,098.0 1/2/2024 12:30 1/2/2024 12:45 0.25 INTRM2, DRILLOUT OWFF P OWFF (Static). SIMOPS: Clean pits, shakers, trough and flow line. 13,098.0 13,098.0 1/2/2024 12:45 1/2/2024 14:30 1.75 INTRM2, DRILLOUT SLPC P Slip and cut 100' drill line. Service top drive and drawworks. SIMOPS: Clean pits, shakers, trough and flow line. 13,098.0 13,098.0 1/2/2024 14:30 1/2/2024 17:00 2.50 INTRM2, DRILLOUT OTHR P Clean pits, shakers, trough and flow line. Phase 3 weather conditions at 16:49hrs. 13,098.0 13,098.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 30/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/2/2024 17:00 1/2/2024 21:00 4.00 INTRM2, DRILLOUT CIRC T Waiting on weather, Circulate BTM's up at 13,098' MD. GPM: 200 PSI: 900 Phase 3 weather conditions 13,098.0 13,098.0 1/2/2024 21:00 1/3/2024 00:00 3.00 INTRM2, DRILLOUT WAIT T Blow down top drive. Waiting on weather. Phase 3 weather conditions. Temp: -5° Wind: N 31mph Gusts: 46mph Convoy couldn't make it pass MT6 pad. 13,098.0 13,098.0 1/3/2024 00:00 1/4/2024 00:00 24.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions Temp: -3° Wind: NNE 37mph Gusts: 53mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 180 PSI: 800 13,069.0 13,069.0 1/4/2024 00:00 1/4/2024 05:00 5.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions. Temp: -3° Wind: NNE 37mph Gusts: 53mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 180 PSI: 800 13,069.0 13,069.0 1/4/2024 05:00 1/4/2024 08:30 3.50 INTRM2, DRILLOUT WAIT T Circulate at 13,069' MD, Warm up mud prep to drill out. Wash down to 13,097' MD. GPM: 175 PSI: 580 RPM: 40 TRQ: 6k 13,069.0 13,097.0 1/4/2024 08:30 1/4/2024 10:00 1.50 INTRM2, DRILLOUT WAIT T Dril cement and float collar to 13,135' MD. GPM: 220 PSI: 970 RPM: 80 TRQ: 7k 13,097.0 13,135.0 1/4/2024 10:00 1/4/2024 17:00 7.00 INTRM2, DRILLOUT WAIT T Circulate and condition mud at 13,096' MD. GPM: 200 PSI: 945 RPM: 60 TRQ: 9k 13,135.0 13,096.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 31/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/4/2024 17:00 1/5/2024 00:00 7.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions. Temp: 1° Wind: NNE 38mph Gusts: 61mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803 13,096.0 13,096.0 1/5/2024 00:00 1/5/2024 06:00 6.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions Temp: 0° Wind: NNE 30mph Gusts: 61mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803 13,096.0 13,096.0 1/5/2024 06:00 1/5/2024 12:00 6.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions Temp: 1° Wind: NNE 33mph Gusts: mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803 13,096.0 13,096.0 1/5/2024 12:00 1/5/2024 18:00 6.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions Temp: -2° Wind: E 21mph Gusts: mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803 13,096.0 13,096.0 1/5/2024 18:00 1/6/2024 00:00 6.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions Temp: -8° Wind: E 14mph Gusts: mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803 13,096.0 13,096.0 1/6/2024 00:00 1/6/2024 06:00 6.00 INTRM2, DRILLOUT WAIT T Waiting on weather at 13,069' MD. Phase 3 weather conditions Temp: -8° Wind: E 14mph Gusts: mph Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803 13,096.0 13,096.0 1/6/2024 06:00 1/6/2024 15:00 9.00 INTRM2, DRILLOUT WAIT T Phase 3 lifted. Continue waiting for roads and pads to be cleared. Startup mud/water trucks and mobilize drivers. Service TD and pipe skate. LD 5" DP. 13,096.0 13,096.0 1/6/2024 15:00 1/6/2024 16:45 1.75 INTRM2, DRILLOUT DRLG P Wash ream f/ 13100' to 13135'. Drill out shoe and clean out rathole. Work through shoe x3. Drill 20' new formation to 13167' MD / 8330' TVD. 15k WOB 220 GPM 1150 PSI 60 RPM 14k TQ 9.1ppg ECD 208k PU 157k SO 185k ROT 13,096.0 13,167.0 1/6/2024 16:45 1/6/2024 19:00 2.25 INTRM2, DRILLOUT CIRC P Backream into shoe and circulate BU. 220 GPM 1150 PSI 60 RPM 14k TQ 13,167.0 13,167.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 32/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/6/2024 19:00 1/6/2024 21:00 2.00 INTRM2, DRILLOUT FIT P RU and perform FIT to 12.0ppg EMW. Good test. RD test equipment. 4.5 bbls pumped/4 bbls returned. FIT was witnessed by Quinn Sawyer of BLM. Perform weekly BOP function test and take SPRs. 13,167.0 13,167.0 1/6/2024 21:00 1/6/2024 22:30 1.50 PROD1, DRILL DDRL P Drill from 13167' MD to 13287' MD 8353' TVD. 25k WOB 220 GPM 1130 PSI 9.2ppg ECD 120 RPM 16k TQ 205k PU 170k SO 187k ROT 508 units max gas 13,167.0 13,287.0 1/6/2024 22:30 1/7/2024 00:00 1.50 PROD1, DRILL CIRC T Cement contaminated fluid at ball mill. Unable to offload due to Super Sucker truck down. PU and circulate while waiting on Super sucker truck to arrive. 13,287.0 13,287.0 1/7/2024 00:00 1/7/2024 07:00 7.00 PROD1, DRILL DDRL P Drill from 13287' MD to 14044' MD 8405' TVD. 22k WOB 220 GPM 1270 PSI 9.4ppg ECD 130 RPM 18k TQ 223k PU 149k SO 179k ROT 1770 units max gas 13,287.0 14,044.0 1/7/2024 07:00 1/7/2024 10:00 3.00 PROD1, DRILL CIRC T Phase 3 called. Circulate BU for trip to shoe. 220 GPm 1240 PSi 9.4ppg ECD 60 RPM 16kTQ 14,044.0 14,044.0 1/7/2024 10:00 1/7/2024 10:15 0.25 PROD1, DRILL BKRM T BROOH f/ 14044' to 13965'. 14,044.0 13,965.0 1/7/2024 10:15 1/7/2024 11:30 1.25 PROD1, DRILL TRIP T Blow down TD and POOH to 13095' inside shoe on elevators. 13,965.0 13,095.0 1/7/2024 11:30 1/8/2024 00:00 12.50 PROD1, DRILL WAIT T Waiting on weather at 13,095' MD. Phase 3 weather conditions. Temp: -1° Wind: E 21mph. Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803. Note: Phase 2 on roads at 22:54hrs 1.7.24. 13,095.0 13,095.0 1/8/2024 00:00 1/8/2024 06:30 6.50 PROD1, DRILL WAIT T Waiting on weather at 13,095' MD. Phase 2 weather conditions. Temp: -1° Wind: E 21mph. Break circulation and circulate drill pipe volume every 6hrs. GPM: 174 PSI: 803. Note: Phase 2 on roads at 22:54hrs 1.7.24. 14,044.0 14,044.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 33/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/8/2024 06:30 1/8/2024 07:00 0.50 PROD1, DRILL TRIP T RIH to 13950'. 14,044.0 14,044.0 1/8/2024 07:00 1/8/2024 07:45 0.75 PROD1, DRILL CIRC T Circulate and downlink to turn tools on. Wash down f/ 13950' to 14044'. 220 GPM 1230 PSI 80 RPM 13k TQ 14,044.0 14,044.0 1/8/2024 07:45 1/8/2024 09:45 2.00 PROD1, DRILL DDRL P Drill from 14044' MD to 14236' MD 8401' TVD. 27k WOB 220 GPM 1285 PSI 9.4ppg ECD 130 RPM 15k TQ 223k PU 149k SO 179k ROT 0 units max gas 14,044.0 14,236.0 1/8/2024 09:45 1/8/2024 10:45 1.00 PROD1, DRILL MPDA P Backream std. Retrieve trip nipple. Install RCD bearing assembly. 14,236.0 14,236.0 1/8/2024 10:45 1/8/2024 16:00 5.25 PROD1, DRILL DDRL P Drill from 14236' MD to 14804' MD 8388' TVD. 12k WOB 220 GPM 1320 PSI 9.5ppg ECD 150 RPM 13k TQ 222k PU 152k SO 185k ROT 136 units max gas 14,236.0 14,804.0 1/8/2024 16:00 1/8/2024 17:00 1.00 PROD1, DRILL MPDA T Backream std. Circulate OH volume. Flow check. Swap out RCD bearing assembly. 14,804.0 14,804.0 1/8/2024 17:00 1/9/2024 00:00 7.00 PROD1, DRILL DDRL P Drill from 14804' MD to 15652' MD 8354' TVD. 15k WOB 220 GPM 1380 PSI 9.5ppg ECD 150 RPM 13k TQ 223k PU 153k SO 185k ROT 136 units max gas 14,804.0 15,652.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 34/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/9/2024 00:00 1/9/2024 06:00 6.00 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/15,652'MD - T/16,355'MD 8,359' TVD 15 WOB 220 GPM 1,445 PSI 32% F/O 9.8 PPG ECD 535 Max Gas 130 RPM 12K TRQ 234 PUW 163 SOW 198 ROW-9K TQ 21.1 BIT Hrs, 4.3 ADT Closing Choke on Conn. 0 PSI Build Up 15,652.0 16,355.0 1/9/2024 06:00 1/9/2024 12:00 6.00 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/16,355'MD - T/17,087'MD 8,339' TVD. Observe Fault @ 17,010'. Returns Drop F/36%-22%. 100 BPH Losses 17k WOB 220 GPM 1,270 PSI 22% F/O 9.6 PPG ECD 535 Max Gas 130 RPM 14K TRQ 243 PUW 159 SOW 198 ROW 25.6 BIT Hrs, 4.5 ADT Closing Choke on Conn. 0 PSI Build Up 16,355.0 17,087.0 1/9/2024 12:00 1/9/2024 12:45 0.75 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/17087'MD to 17160'MD. Lost returns. Pump 42 bbls of 35 PPB LCM pill 17095'. Loss rate at 85 BPH. 17k WOB 220 GPM 1,270 PSI 22% F/O 9.6 PPG ECD 535 Max Gas 130 RPM 14K TRQ 243 PUW 159 SOW 198 ROW 25.6 BIT Hrs, 4.5 ADT Closing Choke on Conn. 0 PSI Build Up 17,087.0 17,160.0 1/9/2024 12:45 1/9/2024 13:30 0.75 PROD1, DRILL CIRC T Reduce rate to 150 GPM. 880 PSI 80 RPM 11k TQ to turn tools off and pump LCM pill through BHA. 17,160.0 17,160.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 35/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/9/2024 13:30 1/9/2024 15:00 1.50 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/17160' MD to 17348' MD 8326' TVD. Pump 86 BBLS of 35 PPB LCM pill @ 17260'. 18k WOB 220 GPM 1060 PSI 33% F/O 9.5 PPG ECD 182 Max Gas 130 RPM 13K TRQ 243 PUW 159 SOW 198 ROW BIT Hrs, ADT Closing Choke on Conn. 0 PSI Build Up 17,160.0 17,348.0 1/9/2024 15:00 1/9/2024 17:00 2.00 PROD1, DRILL CIRC T Reduce rate to 150 GPM. 880 PSI 80 RPM 11k TQ to turn tools off and pump LCM pill through BHA. SD and circulate across top of hole. 17,348.0 17,348.0 1/9/2024 17:00 1/10/2024 00:00 7.00 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/17348' MD to 18104' MD 8104' TVD. Adding background LCM. Losses at 80-90 BPH. 12k WOB 170 GPM 1100 PSI 18% F/O 9.7 PPG ECD 210 Max Gas 130 RPM 12K TQ 255 PUW 154 SOW 200 ROW 32.5BIT Hrs, Closing Choke on Conn. 0 PSI Build Up Note: 14A well was shut in at 22:00hrs 17,348.0 18,104.0 1/10/2024 00:00 1/10/2024 06:30 6.50 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/18104' MD to 18694' MD 8325' TVD. Adding background LCM. Losses at 80-90 BPH. #2 rib on rotary steerable not communicating. 13k WOB 170 GPM 1090 PSI 21% F/O 9.7 PPG ECD 360 Max Gas 130 RPM 12K TQ 260k PUW 150k SOW 204k ROW 37 BIT Hrs, Closing Choke on Conn. 0 PSI Build Up Note: 14A well was shut in at 22:00hrs 18,104.0 18,694.0 1/10/2024 06:30 1/10/2024 07:30 1.00 PROD1, DRILL OWFF T Pump across top of hole for static loss rate. 68 BPH. Approaching hardline in formation. Decision made to trip for BHA due to #2 rib on rotary steerable not functioning. 18,694.0 18,694.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 36/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/10/2024 07:30 1/10/2024 12:00 4.50 PROD1, DRILL CIRC T Circulate BU for TOOH. 220 GPM 1350 PSI 21% FO 9.7ppg ECD 120 RPM 10k TQ 18,694.0 18,694.0 1/10/2024 12:00 1/10/2024 13:00 1.00 PROD1, DRILL SMPD T SOOH f/ 18694' to 18100'. Observed 30k overpull at 18100'. work through twice still seeing overpull. 18,694.0 18,100.0 1/10/2024 13:00 1/10/2024 18:00 5.00 PROD1, DRILL BKRM T BROOH f/ 18100' to 16500'. 220 GPM 1240 PSi 80 RPM 8k TQ 18,100.0 16,500.0 1/10/2024 18:00 1/10/2024 19:00 1.00 PROD1, DRILL RURD T MU cement swivel. Break circulation and take dynamic loss rate. 87 BPH at 170 GPM. Close chokes and record injection rates. 2 BPM - 460 PSI 3 BPM - 830 PSI 4 BPM - 1325 PSI 16,500.0 16,500.0 1/10/2024 19:00 1/10/2024 22:00 3.00 PROD1, DRILL CMNT T PJSM w/ cementers. Swap over to cement unit. Flood lines and pressure test to 3500 PSI. Mix and pump 30 BBLS of 12.0ppg Mudpush at 4 BPM + 130 BBLS of 14.0ppg Thixotropic cement at 5 BPM + 20 BBLS of 12.0 PPG Mudpush at 3.0 BPM + 20 BBLS of FW at 3.0 BPM. closed chokes before pumping FW. Swap over to rig pumps and bullhead cement at 3 BPM into loss zone. 171 BBLS total displacement. Max IA pressure 597 PSI. ISIP - IA 450 PSI 2 minutes - 311 PSI 5 minutes- 128 PSI 10 minutes 45 PSI 16,500.0 16,500.0 1/10/2024 22:00 1/10/2024 22:30 0.50 PROD1, DRILL RURD T RD cement swivel and record static loss rate. Static loss rate 24 BPH. 16,500.0 16,500.0 1/10/2024 22:30 1/11/2024 00:00 1.50 PROD1, DRILL SMPD T SOOH f/ 16500' to 14837'. 16,500.0 14,837.0 1/11/2024 00:00 1/11/2024 00:45 0.75 PROD1, DRILL SMPD T SOOH f/ 14837' to 14160'. 14,837.0 14,160.0 1/11/2024 00:45 1/11/2024 02:15 1.50 PROD1, DRILL MPDA T Retrieve RCD bearing assembly and install trip nipple. 14,160.0 14,160.0 1/11/2024 02:15 1/11/2024 03:45 1.50 PROD1, DRILL TRIP T POOH f/ 14160 to 13097'. 14,160.0 13,097.0 1/11/2024 03:45 1/11/2024 07:45 4.00 PROD1, DRILL CIRC T Break circulation and pump @ 126 GPM f/ 10 minutes staying below rate tools turn on. Pump sugarwater sweep and circulate surface to surface at 200 GPM. 200 GPM 880 PSI 30 RPM 5k TQ 13,097.0 13,097.0 1/11/2024 07:45 1/11/2024 08:15 0.50 PROD1, DRILL OWFF T SD and record static loss rate. 30 BPH. 13,097.0 13,097.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 37/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2024 08:15 1/11/2024 14:00 5.75 PROD1, DRILL TRIP T POOH f/ 13097' to 230'. 13,097.0 230.0 1/11/2024 14:00 1/11/2024 16:30 2.50 PROD1, DRILL BHAH T PJSM. LD BHA #4. 230.0 0.0 1/11/2024 16:30 1/11/2024 17:00 0.50 PROD1, DRILL CLEN T Clean and clear rig floor. 0.0 0.0 1/11/2024 17:00 1/11/2024 20:30 3.50 PROD1, DRILL BHAH T MU and RIH w/ 6 3/4" production BHA. 0.0 330.0 1/11/2024 20:30 1/11/2024 21:30 1.00 PROD1, DRILL TRIP T RIH f/ 330' to 2556'. 330.0 2,556.0 1/11/2024 21:30 1/11/2024 22:00 0.50 PROD1, DRILL CIRC T Shallow test MWD. Good test. 2,556.0 2,556.0 1/11/2024 22:00 1/12/2024 00:00 2.00 PROD1, DRILL TRIP T RIH f/ 2556' to 6281'. 2,556.0 6,281.0 1/12/2024 00:00 1/12/2024 04:00 4.00 PROD1, DRILL TRIP T RIH out of derrick f/6,281' to 13,155' W/4" DP X K SOW, Fill pipe every 25 STD's, 6,281.0 13,155.0 1/12/2024 04:00 1/12/2024 05:15 1.25 PROD1, DRILL SLPC T Slip N Cut Drill Line 36 Wraps (282') Calibrate Block Height 13,155.0 13,155.0 1/12/2024 05:15 1/12/2024 06:00 0.75 PROD1, DRILL CIRC T Fill Pipe, B/D Top Drive Monitor Well on Trip Tank. Discuss with office plan forward. 13,155.0 13,155.0 1/12/2024 06:00 1/12/2024 12:00 6.00 PROD1, DRILL CIRC T Waiting On Weather, Monitor Well on Trip Tank, 30 BPH Loss Rate, Service Top Drive. Phase 2 conditions called @ 06:52hrs1/12/24. Phase 3 weather conditions called @ 08:29hrs 1/12/24. 13,155.0 13,155.0 1/12/2024 12:00 1/12/2024 18:00 6.00 PROD1, DRILL CIRC T Waiting on Weather, Monitor Well on Trip Tank, 24BPH Loss Rate. Circulate string volume every 6 hrs. 13,155.0 13,155.0 1/12/2024 18:00 1/13/2024 00:00 6.00 PROD1, DRILL CIRC T Waiting on Weather, Monitor Well on Trip Tank, 22BPH Loss Rate. Circulate string volume every 6 hrs. 13,155.0 13,155.0 1/13/2024 00:00 1/13/2024 06:00 6.00 PROD1, DRILL CIRC T Waiting on Weather, Monitor Well on Trip Tank, 18 BPH Loss Rate. Circulate string volume every 6 hrs. 13,155.0 13,155.0 1/13/2024 06:00 1/13/2024 12:00 6.00 PROD1, DRILL CIRC T Waiting on Weather, Monitor Well on Trip Tank, 20 BPH Loss Rate. Circulate string volume every 6 hrs. 13,155.0 13,155.0 1/13/2024 12:00 1/13/2024 23:00 11.00 PROD1, DRILL CIRC T Waiting on Weather, Monitor Well on Trip Tank, 20 BPH Loss Rate. Circulate string volume every 6 hrs. 13,155.0 13,155.0 1/13/2024 23:00 1/14/2024 00:00 1.00 PROD1, DRILL TRIP T PJSM. RIH w/ 6 3/4" production BHA f/ 13155' to 14101'. 13,155.0 14,101.0 1/14/2024 00:00 1/14/2024 05:00 5.00 PROD1, DRILL BKRM T Observe 30k overpull. Attempt to circulate, Packed off no returns. 60-80 GPM/ 760-910 PSI/ 60-100 RPM / 8-19k TQ. Backreamed out to 13872' observed over pull and taking down weight. 14,101.0 13,872.0 1/14/2024 05:00 1/14/2024 05:45 0.75 PROD1, DRILL REAM T Ream/wash std back down to 13942'. 5- 15k WOB / 60-80 GPM / 760-910 PSI / 60-100 RPM / 8-19k TQ. Discuss with office. Decision made to stage up rates and attempt to BROOH. 13,872.0 13,942.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 38/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/14/2024 05:45 1/14/2024 11:00 5.25 PROD1, DRILL BKRM T BROOH f/ 13942' to 13154'. Staged up rates and observed tools turn on and turn off. Observed trickle of returns and improving to full returns. BROOH to shoe. Pull into shoe w/ no rotary. No overpull observed, 200 GPM 1260 PSI 110 RPM 8k TQ 185k ROT 13,942.0 13,154.0 1/14/2024 11:00 1/14/2024 11:30 0.50 PROD1, DRILL CIRC T Troubleshoot tools. No communication. 13,154.0 13,154.0 1/14/2024 11:30 1/14/2024 14:00 2.50 PROD1, DRILL CIRC T Circulate BU. Observed shakers loading up with sand/fines at BU. 220 GPM 870 PSI 80 RPM 7k TQ 13,154.0 13,154.0 1/14/2024 14:00 1/14/2024 14:30 0.50 PROD1, DRILL CIRC T Rack back std. Pump slug. Blow down topdrive. 13,154.0 13,056.0 1/14/2024 14:30 1/14/2024 20:15 5.75 PROD1, DRILL TRIP T POOH to BHA. 13,056.0 190.0 1/14/2024 20:15 1/14/2024 23:30 3.25 PROD1, DRILL BHAH T Flow check.slight loss. PJSM for BHA. LD BHA. Troubleshoot tools. 190.0 0.0 1/14/2024 23:30 1/15/2024 00:00 0.50 PROD1, DRILL CLEN T Clean and clear rig floor. 0.0 0.0 1/15/2024 00:00 1/15/2024 01:30 1.50 PROD1, DRILL SVRG T Service rig. Monitor hole on TT. 0.0 0.0 1/15/2024 01:30 1/15/2024 05:00 3.50 PROD1, DRILL BHAH T MU shorter BHA components and lay down. 0.0 0.0 1/15/2024 05:00 1/15/2024 06:00 1.00 PROD1, DRILL BHAH T MU bit and bit sub f/ kill string. Received ok to test BOPE. Lay down bit and bit sub. 0.0 0.0 1/15/2024 06:00 1/15/2024 07:00 1.00 PROD1, DRILL WWWH P Retrieve wear bushing. MU jetting tool and jet BOP and wellhead. 0.0 0.0 1/15/2024 07:00 1/15/2024 08:00 1.00 PROD1, DRILL RURD P Set test plug. RU test equipment. LIne up injection line on IA for continuous hole fill. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 39/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2024 08:00 1/15/2024 15:30 7.50 PROD1, DRILL BOPE P BOPE Test All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5” Test jt: test annular/2 7/8" x 5" UPR/2 7/8" 5" LPR, W/ 4" Test jt: test annular/2 7/8" x 5" UPR/2 7/8" 5" LPR,Test choke valves 1-15. Manuals 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/Shear rams. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1500 psi, ACC = 1850 psi after all functions on bottles,16 sec for 200 psi. Build w/ 2 electric pumps, 81 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 26 sec. UPR = 14 sec, Blind / Shears = 15 sec, LPR = 13 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. AOGCC Adam Earl waived witness BOP test at 05:14hrs 1/15/24. BLM Quinn M Sawyer waived witness BOP test at 23:00hrs 1/14/24. 0.0 0.0 1/15/2024 15:30 1/15/2024 16:30 1.00 PROD1, DRILL RURD P RD test equipment. Retrieve test plug. Install wear bushing. 0.0 0.0 1/15/2024 16:30 1/15/2024 19:00 2.50 PROD1, DRILL BHAH T MU and RIH w/ 6 3/4" production BHA #6 to 190'. Plug in and program tools. 0.0 190.0 1/15/2024 19:00 1/15/2024 20:15 1.25 PROD1, DRILL TRIP T RIH w/ 6 3/4" Production BHA f/ 190' to 2558' 190.0 2,558.0 1/15/2024 20:15 1/15/2024 21:00 0.75 PROD1, DRILL CIRC T Shallow test MWD. Good test. 2,558.0 2,558.0 1/15/2024 21:00 1/16/2024 00:00 3.00 PROD1, DRILL TRIP T RIH w/ 6 3/4" Production BHA f/ 2558' to 8710'. Filling pipe every 25 stds. 2,558.0 8,710.0 1/16/2024 00:00 1/16/2024 02:45 2.75 PROD1, DRILL TRIP T RIH w/ 6 3/4" Production BHA f/ 8710' to 12969''. Filling pipe every 25 stds. 8,710.0 12,969.0 1/16/2024 02:45 1/16/2024 03:45 1.00 PROD1, DRILL SLPC T Slip/Cut drill line. 12,969.0 12,969.0 1/16/2024 03:45 1/16/2024 07:00 3.25 PROD1, DRILL WASH T Wash down f/ 12969' to 13832'. 200 GPM 900 PSI 12,969.0 13,832.0 1/16/2024 07:00 1/16/2024 12:00 5.00 PROD1, DRILL REAM T Wash/Ream f/ 13832' to 15812'. 200 GPM 970 PSI 80 RPM 13k TQ 13,832.0 15,812.0 1/16/2024 12:00 1/16/2024 18:00 6.00 PROD1, DRILL REAM T Wash/Ream f/ 15812' to 17120'. 200 GPM 1040 PSI 80-130 RPM 18-22k TQ 15,812.0 17,120.0 1/16/2024 18:00 1/16/2024 19:00 1.00 PROD1, DRILL CIRC T Circulate and troubleshoot tools. Pulser stopped pulsing. Recycle pumps. Increase flow rate. Pump 20bbls FW sweep. Pulser came back on before FW passed BHA. 17,120.0 17,120.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 40/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/16/2024 19:00 1/17/2024 00:00 5.00 PROD1, DRILL REAM T Wash/Ream f/ 17120' to 18300'. 200 GPM 1340 PSI 120 RPM 22-25k TQ 17,120.0 18,300.0 1/17/2024 00:00 1/17/2024 00:30 0.50 PROD1, DRILL REAM T Wash/Ream f/ 18300' to 18446'. 200 GPM 1340 PSI 120 RPM 22-25k TQ 18,300.0 18,446.0 1/17/2024 00:30 1/17/2024 01:00 0.50 PROD1, DRILL MPDA T Retrieve trip nipple. Install RCD bearing assembly. 18,446.0 18,446.0 1/17/2024 01:00 1/17/2024 01:30 0.50 PROD1, DRILL REAM T Wash/Ream f/ 18446' to 18634'. 200 GPM 1340 PSI 120 RPM 22-25k TQ 18,446.0 18,634.0 1/17/2024 01:30 1/17/2024 02:45 1.25 PROD1, DRILL REAM T Attempt to trough through dogleg . Hi torque 27k stalling out rotary. PU and mousehole std. 18,446.0 18,634.0 1/17/2024 02:45 1/17/2024 05:00 2.25 PROD1, DRILL CIRC T Perform a 400 bbl dilution increase lube up to 2 %. 220 GPM 1340 PSI 120 RPM 26k TQ 9.5ppg ECD 18,634.0 18,634.0 1/17/2024 05:00 1/17/2024 07:30 2.50 PROD1, DRILL REAM T Trough 18630' to 18694'. at 50 FPH. 220 GPM 1340 PSi 120 RPM 26k TQ 9.5ppg ECD 18,634.0 18,694.0 1/17/2024 07:30 1/17/2024 18:00 10.50 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/ 18694' MD to 19716' MD 8327' TVD. 15k WOB 220 GPM 1290 PSI 22% F/O 9.6 PPG ECD 2010 Max Gas 120 RPM 23K TQ 278k PUW 143k SOW 202k ROW 7.8 BIT Hrs, Closing Choke on Conn. 0 PSI Build Up 18,694.0 19,716.0 1/17/2024 18:00 1/18/2024 00:00 6.00 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/ 19716' MD to 20324' MD 8326' TVD. 16k WOB 230 GPM 1420 PSI 29% F/O 9.7 PPG ECD 920 Max Gas 120 RPM 25K TQ 283k PUW 126k SOW 207k ROW 11.9 BIT Hrs, Closing Choke on Conn. 0 PSI Build Up 19,716.0 20,324.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 41/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/18/2024 00:00 1/18/2024 03:30 3.50 PROD1, DRILL DDRL P Drill 6-3/4" Prod F/ 20324' MD to 20721' MD 8320' TVD. Lost returns at 20530'. Pump 100bbls of 35 PPB LCM pill. Observed 2nd fault at 20650'. Pump across top of hole at 1-4 BPM to keep hole full. Losses at 250-300 BPH 18k WOB 180 GPM 800 PSI 0% F/O 8.9 PPG ECD 1400 Max Gas 120 RPM 23K TQ 283k PUW 143k SOW 204k ROW 11.9 BIT Hrs, Closing Choke on Conn. 0 PSI Build Up 20,324.0 20,701.0 1/18/2024 03:30 1/18/2024 05:00 1.50 PROD1, DRILL CIRC T PU off bottom. Decrease pump rate to turn tools off as LCM pill passed through BHA. Continue pumping across top of hole to keep hole full. 20,701.0 20,701.0 1/18/2024 05:00 1/18/2024 05:30 0.50 PROD1, DRILL DDRL T Drill 6-3/4" Prod F/ 20721' MD to 20795' MD 8319' TVD. Still on full losses. Observed 3rd fault at 20760'. Drill std down. Pumping 1-4 BPM across top of hole to keep hole full. Losses at 300-325 BPH. 18k WOB 180 GPM 800 PSI 0% F/O 8.9 PPG ECD 1400 Max Gas 120 RPM 23K TQ 283k PUW 143k SOW 204k ROW 11.9 BIT Hrs, Closing Choke on Conn. 0 PSI Build Up 20,701.0 20,795.0 1/18/2024 05:30 1/18/2024 13:00 7.50 PROD1, TRIPCAS BKRM T BROOH f/ 20795' to 18508'. 180 GPM 810 PSI 8.9ppg ECD 120 RPM 13k TQ 20,795.0 18,508.0 1/18/2024 13:00 1/18/2024 14:00 1.00 PROD1, TRIPCAS RURD T MU cement swivel. Close chokes and record injection pressures. PJSM for cement job. 2 BPM - 205 3 BPM - 350 PSI 4 BPM - 575 PSI 18,508.0 18,508.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 42/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/18/2024 14:00 1/18/2024 17:30 3.50 PROD1, TRIPCAS CMNT T Flood lines and pressure test to 3500 PSI. Pump 30 bbls 12.0ppg mud push 3BPM/190 PSI + Mix and pump 129 bbls of 14.0ppg Thixotropic cement 3 BPM/38 PSI + 20 bbls 12.0ppg mud push 3 BPM/21 PSI + 20 bbls FW. Swap over to rig and displace w/ mud. Close chokes 290stks into displacement and squeeze cement into loss zone at 3 BPM. Annular pressure slowly increased 168 PSI at end of squeeze. Shut down and Annular pressure decreased to 0 PSI in 3 minutes. Cement wet @ 15:00hrs 1/18/24 Cement in place @ 17:18hrs 1/18/24 18,508.0 18,508.0 1/18/2024 17:30 1/18/2024 18:00 0.50 PROD1, TRIPCAS RURD T Open chokes and LD cement swivel. Static losses 87 BPH. 18,508.0 18,508.0 1/18/2024 18:00 1/18/2024 19:30 1.50 PROD1, TRIPCAS SMPD T SOOH f/ 18508' to 17000'. 18,508.0 17,000.0 1/18/2024 19:30 1/18/2024 21:00 1.50 PROD1, TRIPCAS CIRC T Circulate at below tool rate for 10 minutes. Pump 20 BBLs FW and stage pumps up to 200 GPM. Tools on and all working. Pump FW through BHA. Dynamic loss rate 150 BPH. 190 GPM 850 PSI 8.8ppg ECD 20 RPM 13k TQ 17,000.0 17,000.0 1/18/2024 21:00 1/19/2024 00:00 3.00 PROD1, TRIPCAS SMPD T SOOH f/ 17000' to 14298'. 17,000.0 14,298.0 1/19/2024 00:00 1/19/2024 01:00 1.00 PROD1, TRIPCAS SMPD T SOOH to 14107'. Retrieve RCD bearing assembly and install trip nipple. 14,298.0 14,107.0 1/19/2024 01:00 1/19/2024 02:30 1.50 PROD1, TRIPCAS TRIP T POOH f/ 14107 to inside shoe @ 13061'. No issues pulling into shoe. 14,107.0 13,061.0 1/19/2024 02:30 1/19/2024 03:00 0.50 PROD1, TRIPCAS CIRC T Pump 20 bbls FW and circulate through BHA. Dynamic loss rate - 138 BPH. 220 GPM 912 PSI 13,061.0 13,061.0 1/19/2024 03:00 1/19/2024 07:00 4.00 PROD1, TRIPCAS WOC T Wait on cement. Monitor well on TT. Static losses - 96 BPH. perform derrick inspection. Service crown/Top Drive/Blocks. 13,061.0 13,061.0 1/19/2024 07:00 1/19/2024 18:00 11.00 PROD1, TRIPCAS WASH T Wash down f/ 13061' to 18500'. Run hole fill to keep annulus full. 100 GPM 330 PSI 13,061.0 18,500.0 1/19/2024 18:00 1/20/2024 00:00 6.00 PROD1, TRIPCAS REAM T Wash/Ream f/ 18500' to 20300'. Dynamic loss rate-155-170 BPH 160-180 GPM 710-810 PSI 80 RPM 22k TQ 9.1ppg ECD 18,500.0 20,300.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 43/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/20/2024 00:00 1/20/2024 01:30 1.50 PROD1, TRIPCAS REAM T Wash/Ream f/ 20300' to 20794'. Dynamic loss rate-155-170 BPH 160-180 GPM 710-810 PSI 80 RPM 22k TQ 9.1ppg ECD 20,300.0 20,794.0 1/20/2024 01:30 1/20/2024 03:00 1.50 PROD1, TRIPCAS CIRC T Circulate and establish loss rates. Dynamic loss rate - 160 BPH. Static loss rate - 48 BPH. Discuss plan forward with office. 230 GPM 860 PSI 20,794.0 20,794.0 1/20/2024 03:00 1/20/2024 04:30 1.50 PROD1, TRIPCAS BKRM T BROOH f/ 20794' to 20325'. 230 GPM 1180 PSI 80 RPM 22k TQ SimOps-Building gel pill and HI-Vis pill. 20,794.0 20,325.0 1/20/2024 04:30 1/20/2024 05:30 1.00 PROD1, TRIPCAS MPDA T Retrieve trip nipple and install RCD bearing assembly. SimOps-Building gel pill and HI-Vis pill. 20,325.0 20,325.0 1/20/2024 05:30 1/20/2024 06:30 1.00 PROD1, TRIPCAS CIRC T Circulate and reciprocate drill string while building gel pill 20,325.0 20,325.0 1/20/2024 06:30 1/20/2024 10:30 4.00 PROD1, TRIPCAS CIRC T Pump 20 bbls HiVis spacer + 85 bbls gel pill + 38 bbls HiVis spacer. Close chokes as spacer exits bit. Squeeze into loss zone. Observed pressure increases while squeezing slow rate Max pressure observed 1055psi DP/255psi IA. 20,325.0 20,325.0 1/20/2024 10:30 1/20/2024 12:00 1.50 PROD1, TRIPCAS OWFF T SD and monitor well w/ chokes closed. 20,325.0 20,325.0 1/20/2024 12:00 1/20/2024 13:00 1.00 PROD1, TRIPCAS OWFF T Circulate across top of hole and monitor well f/ losses. 40-50 BPH. 20,325.0 20,325.0 1/20/2024 13:00 1/20/2024 15:00 2.00 PROD1, TRIPCAS REAM T Ream to bottom. 200 GPM 1010 PSI 60-150 RPM 15-18k TQ 20,325.0 20,325.0 1/20/2024 15:00 1/20/2024 18:30 3.50 PROD1, TRIPCAS CIRC T Circulate and clean hole. Dynamic losses 60-90 BPH 230 GPM 1200 PSI 150 RPM 18k TQ 20,325.0 20,325.0 1/20/2024 18:30 1/21/2024 00:00 5.50 PROD1, TRIPCAS BKRM P BROOH f/ 20794' to 19200'. 250 GPM 1330 PSI 80 -100 RPM 18k TQ 270k PU 161k SO 203k ROT 20,325.0 19,200.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 44/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/21/2024 00:00 1/21/2024 12:00 12.00 PROD1, TRIPCAS BKRM P BROOH f/ 19200' to 15241'. 250 GPM 1330 PSI 80 -100 RPM 18k TQ Torque and Drag 18729' - 260k PU/167k/ SO/200k ROT 17692' - 253k PU/ 170k SO/ 200k ROT 16653' - 244k PU/ 170k SO/ 195k ROT 15617' - 234k PU /166k SO/ 200k ROT 19,200.0 15,241.0 1/21/2024 12:00 1/21/2024 15:00 3.00 PROD1, TRIPCAS BKRM P BROOH f/ 15241' to 14109'. 250 GPM 1250 PSI 110 RPM 10k TQ Torque and Drag 14581' - 223k PU/162k/ SO/181k ROT 15,241.0 14,109.0 1/21/2024 15:00 1/21/2024 16:30 1.50 PROD1, TRIPCAS MPDA P Retrieve RCD bearing assembly and install trip nipple. 14,109.0 14,109.0 1/21/2024 16:30 1/21/2024 20:00 3.50 PROD1, TRIPCAS BKRM P BROOH f/ 14109' to 13064'. Loss rate 96 BPH 250 GPM 1193 PSI 110 RPM 8k TQ Torque and Drag 143538' - 211k PU/166k/ SO/178k ROT 14,109.0 13,064.0 1/21/2024 20:00 1/21/2024 21:00 1.00 PROD1, TRIPCAS CIRC P Circulate 3x liner volume. Drop 1.75" WC opening ball. Blow down TD. Dynamic Loss rate 70-75BPH. 250 GPM 1150 PSI 80 RPM 7k TQ 13,064.0 13,064.0 1/21/2024 21:00 1/21/2024 22:30 1.50 PROD1, TRIPCAS TRIP P POOH 13064' to 11458'. 13,064.0 11,458.0 1/21/2024 22:30 1/22/2024 00:00 1.50 PROD1, TRIPCAS CIRC P Open WC. Sheared @ 2760 PSI. Wash through TOL. Rack back std and continue circulating hole clean. 400 GPM 900 PSI 40 RPM 5k TQ 11,458.0 11,360.0 1/22/2024 00:00 1/22/2024 01:30 1.50 PROD1, TRIPCAS CIRC P Circulate 2 x BU. Shakers clean. 400 GPM 870 PSI 40 RPM 5k TQ 11,360.0 11,360.0 1/22/2024 01:30 1/22/2024 03:00 1.50 PROD1, TRIPCAS TRIP P POOH f/ 11360' to 8444'. 11,360.0 8,444.0 1/22/2024 03:00 1/22/2024 03:30 0.50 PROD1, TRIPCAS CIRC P Pressure and shift WC closed. Shifted @ 1794 PSI. Blow down TD and line up hole fill. 8,444.0 8,444.0 1/22/2024 03:30 1/22/2024 08:00 4.50 PROD1, TRIPCAS TRIP P POOH f/ 8444' to 287'. 8,444.0 287.0 1/22/2024 08:00 1/22/2024 10:30 2.50 PROD1, TRIPCAS BHAH P Perform weekly function test on BOP. Flow check. LD 6 3/4" BHA. 287.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 45/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/22/2024 10:30 1/22/2024 11:00 0.50 COMPZN, CASING CLEN P Clean and clear rig floor. 0.0 0.0 1/22/2024 11:00 1/22/2024 12:00 1.00 COMPZN, CASING SLPC P Slip/Cut drill line. 0.0 0.0 1/22/2024 12:00 1/22/2024 15:00 3.00 COMPZN, CASING RURD P RU to run lower completion. 0.0 0.0 1/22/2024 15:00 1/23/2024 00:00 9.00 COMPZN, CASING PUTB P MU and RIH w/ 4 1/2" lower completion as per tally to 4471'. 0.0 4,471.0 1/23/2024 00:00 1/23/2024 04:00 4.00 COMPZN, CASING PUTB P MU and RIH w/ 4 1/2" 12.6# P110 HYD 563 lower completion as per tally 4471' to 7530'. . 4,471.0 7,530.0 1/23/2024 04:00 1/23/2024 09:00 5.00 COMPZN, CASING WAIT T Wait on weather. Phase 3. 7,530.0 7,530.0 1/23/2024 09:00 1/23/2024 10:00 1.00 COMPZN, CASING PUTB P MU DB nipple and PU liner hanger. Fill w/ ZanPlex and RIH. 7,530.0 7,590.0 1/23/2024 10:00 1/23/2024 10:30 0.50 COMPZN, CASING CIRC P Swap handling tools. RIH w/ 1 std of 4" DP. Circulate through liner. 20 RPM 3k TQ 30 RPM 3k TQ 110k PU 108k SP 102k ROT 7,590.0 7,794.0 1/23/2024 10:30 1/23/2024 12:00 1.50 COMPZN, CASING RUNL P RIH w/ 4 1/2"liner on 4" DP f/ 7794' to 9502'. 7,794.0 9,502.0 1/23/2024 12:00 1/23/2024 16:00 4.00 COMPZN, CASING RUNL P RIH w/ liner singling in 5" DP f/ 9502' to 11900'. Torque and Drag: 11300' - 190k PU/161k SO/174k ROT/6k 20 RPM/7k 30 RPM 9,502.0 11,900.0 1/23/2024 16:00 1/24/2024 00:00 8.00 COMPZN, CASING RUNL P RIH w/ liner singling in 5" DP f/ 11900' to 17511'. Torque and Drag: 13086' - 228k PU/178k SO/200k ROT/8k 20 RPM/9k 30 RPM 13746' - 235k PU/175k SO/195k ROT/8k 20 RPM/9k 30 RPM 14687' - 244k PU/172k SO/200k ROT/11k 20 RPM/11k 30 RPM 15631' - 254k PU/170k SO/200k ROT/11k 20 RPM/11k 30 RPM 16571' - 266k PU/165k SO/211k ROT/11k 20 RPM/12k 30 RPM 17511' - 274k PU/164k SO/215k ROT/14k 20 RPM/13k 30 RPM 11,900.0 17,511.0 1/24/2024 00:00 1/24/2024 04:30 4.50 COMPZN, CASING RUNL P RIH w/ liner singling in 5" DP f/ 17511' to 20574'. Torque and Drag: 18543' - 290k PU/172k SO/225k ROT/14k 20 RPM/14k 30 RPM 19393' - 303k PU/178k SO/132k ROT/16k 20 RPM/16k 30 RPM 20574' - 333k PU/172k SO/185k 17,511.0 20,574.0 1/24/2024 04:30 1/24/2024 05:00 0.50 COMPZN, CASING RURD P RU to circulate through cement line. Pull mousehole 20,574.0 20,574.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 46/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/24/2024 05:00 1/24/2024 10:00 5.00 COMPZN, CASING CIRC P Circulate 2 x BU. Dynamic loss rate - 100BPH 330 GPM 1040 PSI SimOps: RU hardlines and spot acid trucks for acid job. 20,574.0 20,574.0 1/24/2024 10:00 1/24/2024 12:30 2.50 COMPZN, CASING CIRC P PJSM. Flood lines and test to 2500 PSI. Good test. Pump 175bbls 9% formic acid blend. Chase with 30 bbls 8.8ppg clear brine. Swap over to rig and close annular. Bullhead acid w/ 296bbls of 8.8 ppg clear brine at 8-9.5 BPM/1500-1820 psi. FCP - 9.5 BPM/1630 psi. Max IA 450 psi/Final IA 192 psi. SD and pressure fell to 0psi in 3 minutes. 20,574.0 20,574.0 1/24/2024 12:30 1/24/2024 16:30 4.00 COMPZN, CASING OWFF P Line up and monitor well keeping hole full. 8.8ppg Vis brine on annulus and 8.8ppg clear brine on drillstring. Lost 521bbls in 4 hrs. SimOps- RD hardlines. 20,574.0 20,574.0 1/24/2024 16:30 1/24/2024 18:30 2.00 COMPZN, CASING CIRC P LIne up and circulate 1000 bbls 8.8ppg brine. Loss rate 130 +/- BPH 10 BPM 1480 PSI 20,574.0 20,574.0 1/24/2024 18:30 1/24/2024 20:00 1.50 COMPZN, CASING PACK P Drop 1 5/16" ball and rod. Chase w/ 8.8ppg brine. land and pressure up to 2500 psi. Hold f/ 5 min. SO 250k to confirm hanger set. Increase pressure to 3300 psi. Hold 5 min. Bleed off pressure. PU 5' and expose dog sub. Rotate 20 rpm 10/14k TQ. Set down 80k to set packer. Test packer to 3500 psi f/ 5 min. Good test. Flow check. PU and release f/ seal assembly. Shoe at 20,574' TOL aat 12,979' 20,574.0 12,955.0 1/24/2024 20:00 1/24/2024 22:45 2.75 COMPZN, CASING CIRC P Circulate and displace to 8.8ppg CI brine. 8 BPM 560 PSI 12,955.0 12,955.0 1/24/2024 22:45 1/24/2024 23:00 0.25 COMPZN, CASING OWFF P Flow check. Static 12,955.0 12,955.0 1/24/2024 23:00 1/25/2024 00:00 1.00 COMPZN, CASING PULD P POOH LD drill pipe f/ 12955' to 12180'. 12,955.0 12,180.0 1/25/2024 00:00 1/25/2024 09:15 9.25 COMPZN, CASING PULD P POOH LD DP. Using tongs and steam on tight connections. 12,180.0 5,480.0 1/25/2024 09:15 1/25/2024 09:45 0.50 COMPZN, CASING SVRG P Service rig 5,480.0 5,480.0 1/25/2024 09:45 1/25/2024 20:00 10.25 COMPZN, CASING PULD P POOH LD DP to running tool. Using tongs and steam on tight connections. 5,480.0 50.0 1/25/2024 20:00 1/25/2024 21:00 1.00 COMPZN, CASING PULD P LD running tool. 50.0 0.0 1/25/2024 21:00 1/26/2024 00:00 3.00 COMPZN, WELLPR TRIP P MU jetting sub. RIH w/ excess 4" DP out of derrick to 5125'. 0.0 5,125.0 1/26/2024 00:00 1/26/2024 03:30 3.50 COMPZN, WELLPR TRIP P RIH w/ excess 4" DP out of derrick to 11081'. 5,125.0 11,081.0 1/26/2024 03:30 1/26/2024 12:00 8.50 COMPZN, WELLPR PULD P POOH LD 4" DP to 7500'. 11,081.0 7,500.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 47/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/26/2024 12:00 1/27/2024 00:00 12.00 COMPZN, WELLPR PULD P POOH LD 4" DP to surface. 7,500.0 0.0 1/27/2024 00:00 1/27/2024 01:00 1.00 COMPZN, WELLPR CIRC P Retrieve wear bushing. MU jetting tool. Wash BOPE and well head area. 0.0 0.0 1/27/2024 01:00 1/27/2024 01:45 0.75 COMPZN, RPCOMP RURD P RU to run upper completion. 0.0 0.0 1/27/2024 01:45 1/27/2024 02:30 0.75 COMPZN, RPCOMP PUTB P PJSM. MU and RIH w/ mule shoe to gauge mandrel 150'. 0.0 150.0 1/27/2024 02:30 1/27/2024 03:15 0.75 COMPZN, RPCOMP PUTB P Connect TEC line to gauge mandrel and test. Good test. 150.0 150.0 1/27/2024 03:15 1/27/2024 07:00 3.75 COMPZN, RPCOMP PUTB P RIH w/ 4-1/2" upper completion to 3260' MD. Observed fluid U-tubing back up tbg string while RIH. 150.0 3,260.0 1/27/2024 07:00 1/27/2024 08:30 1.50 COMPZN, RPCOMP CIRC P Circulate and clean hole. 135 GPM 80-120 PSI 3,260.0 3,260.0 1/27/2024 08:30 1/27/2024 10:15 1.75 COMPZN, RPCOMP PUTB P RIH f/ 3260' to 4142' MD. 3,260.0 4,142.0 1/27/2024 10:15 1/27/2024 11:15 1.00 COMPZN, RPCOMP CIRC P Circulate. 167 GPM 230 PSI 4,142.0 4,142.0 1/27/2024 11:15 1/27/2024 12:30 1.25 COMPZN, RPCOMP PUTB P RIH 4-1/2" upper completion f/ 4142' to 4704' MD. Observed fluid U-tubing up tbg. 4,142.0 4,704.0 1/27/2024 12:30 1/27/2024 13:00 0.50 COMPZN, RPCOMP CIRC P Circulate stage up to 5 BPM. 5 BPM 216 PSI 4,704.0 4,704.0 1/27/2024 13:00 1/27/2024 14:00 1.00 COMPZN, RPCOMP PUTB P RIH w/ 4-1/2" upper completion f/ 4704' to 4953' MD. 4,704.0 4,953.0 1/27/2024 14:00 1/27/2024 15:30 1.50 COMPZN, RPCOMP CIRC P Circulate BU. Reciprocate string slowly. 4 BPM 140 PSI 4,953.0 4,953.0 1/27/2024 15:30 1/27/2024 16:00 0.50 COMPZN, RPCOMP PUTB P RIH w/ 4-1/2" upper completion f/ 4953' to 5077' MD. Observed fluid U-tubing up string. 4,953.0 5,077.0 1/27/2024 16:00 1/28/2024 00:00 8.00 COMPZN, RPCOMP WASH P Wash down 4-1/2" upper completion f/ 5077' to 6770' MD. Loaded string with 90bbls of 8.8 ppg DeepClean/citric pill at 6600' MD. 1 BPM 50 PSI 5,077.0 6,770.0 1/28/2024 00:00 1/28/2024 02:00 2.00 COMPZN, RPCOMP WASH P Wash down 4-1/2" upper completion f/ 6770' to 7423' MD. Load string with 90bbls of DeepClean/citric pill at 6600' MD. 1 BPM, 50 PSI. 6,770.0 7,423.0 1/28/2024 02:00 1/28/2024 09:30 7.50 COMPZN, RPCOMP PUTB P RIH on elevators w/ 4-1/2" 12.6# HYD 563 upper completion f/ 7423' to 12832' MD. 7,423.0 12,832.0 1/28/2024 09:30 1/28/2024 11:00 1.50 COMPZN, RPCOMP PUTB P RIH on elevators w/ 4-1/2" 12.6# HYD 563 upper completion f/ 12832' to 12984' MD. Observe shear screws w/ 10k down. LD jts 309-311. MU space out pup joints - 9.78' + 9.71' + 5.8' + jt 309 + tbg hanger + landing joint. 12,832.0 12,982.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 48/48 MT7-93 Report Printed: 2/20/2024 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/28/2024 11:00 1/28/2024 12:30 1.50 COMPZN, RPCOMP CIRC P Circulate out DeepClean/citric pill to surface. 3 BPM 125 PSI 12,982.0 1,292.0 1/28/2024 12:30 1/28/2024 13:30 1.00 COMPZN, RPCOMP PUTB P Drain stack. Land hanger. Run in LDS. 12,982.0 12,982.0 1/28/2024 13:30 1/28/2024 15:00 1.50 COMPZN, RPCOMP PRTS P RU test equipment. Test hanger seals to 3000 PSI f/ 5 min. Good test. 0.0 0.0 1/28/2024 15:00 1/28/2024 17:00 2.00 COMPZN, RPCOMP CIRC P Load 1.875" ball and rod. Pump down. Stage up pressure to 500 PSI f/ 5 min and then to 4200 PSI f/ 30 minutes - good test. Packer set. Bleed tubing to 2000 PSI. IA at 3000 PSI. Hold 30 Minutes. Good test. Bleed tubing to 0 PSI. Shear SOV. Circulate at .5 BPM, 75 PSI to confirm shear. 0.0 0.0 1/28/2024 17:00 1/28/2024 18:30 1.50 COMPZN, RPCOMP OWFF P Flow check. Static. SimOps- Drain stack. Blow down choke and kill lines. LD landing joint. 0.0 0.0 1/28/2024 18:30 1/28/2024 19:00 0.50 COMPZN, WHDBOP PRTS P Install BPV and test to 3000 PSI f/ 5 minutes. God test. 0.0 0.0 1/28/2024 19:00 1/28/2024 21:00 2.00 COMPZN, WHDBOP CLEN P Clean Joes box/rig floor. Blow down pumps. 0.0 0.0 1/28/2024 21:00 1/29/2024 00:00 3.00 COMPZN, WHDBOP NUND P ND BOPE and risers. SimOps- Cleaning pits. 0.0 0.0 1/29/2024 00:00 1/29/2024 00:30 0.50 COMPZN, WHDBOP NUND P ND risers. 0.0 0.0 1/29/2024 00:30 1/29/2024 01:00 0.50 COMPZN, WHDBOP NUND P Terminate TEC line through wellhead. Confirm working. 0.0 0.0 1/29/2024 01:00 1/29/2024 02:00 1.00 COMPZN, WHDBOP RGRP T Lost power on rig. Switch over to generators. 0.0 0.0 1/29/2024 02:00 1/29/2024 04:00 2.00 COMPZN, WHDBOP NUND P NU adapter flange and 5k tree. Test void to 5000 psi. Good test. Witnessed by COP. 0.0 0.0 1/29/2024 04:00 1/29/2024 06:30 2.50 COMPZN, WHDBOP PRTS P Fill tree with diesel and test to 250 psi low/ 5000 psi high f/ 5/10 min each. Good test. Witnessed by COP. 0.0 0.0 1/29/2024 06:30 1/29/2024 08:00 1.50 DEMOB, MOVE RURD P RU manifold and lines for freeze protect. 0.0 0.0 1/29/2024 08:00 1/29/2024 11:15 3.25 DEMOB, MOVE FRZP P Test lines to 250/3500 psi. Good test. Pump 85 bbls diesel down IA and take returns up tbg. SD and alllow u-tubing. Final pressure. IA-190 PSI OA- 0 PSI 0.0 0.0 1/29/2024 11:15 1/29/2024 12:00 0.75 DEMOB, MOVE SISW P Blow down lines. Secure well. Release rig at 12:00hrs 1/29/24. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/29/2024 Page 1/1 MT7-93 Report Printed: 2/20/2024 Cement Cement Details Description Surface String Cement Cementing Start Date 12/16/2023 01:45 Cementing End Date 12/16/2023 05:48 Wellbore Name MT7-93 Comment Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 6 bbls/min, 230 psi, Dropped bottom plug, Add two gallions dye. Start batching lead (Cemet wet @02:10hrs). Pump 470 bbls of 11.0 ppg DeepCRETE cement at 6 bbls/min, 277 psi ICP. Batch tail cement (Cement wet @ 03:53hrs) and pump 70 bbls of G Blend Tail 15.8 ppg cement @ 6.0 bbls/min, 312 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 351 psi ICP, 508 psi FCP. Slow pumps 18 bbls prior to calculated bump to 3 bbls/min, 315 psi ICP, Bump plug with 840 psi (595.5 bbls + 20 bbls). 5039 strokes, final circ. PSI 315 Pressure up to 840 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 148 bbls cement to surface. Cement in place @ 05:48hrs 12/16/23 Lead: 11ppg D047: 0.5 gal/sk Antifoam D185: 0.09 gal/sk Dispersant D167: 0.450% BWOB Fluid Loss D177: 0.02 gal/sk Retarder Tail: 15.8ppg D047: 0.2 gal/sk Antifoam D065: 0.65 % BWOC Dispersant D225: 0.3% BWOB Fluid Loss D186: 0.5 gal/sk Accelerator Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 39.8 Bottom Depth (ftKB) 4,216.0 Full Return? No Vol Cement … 148.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 315.0 P Plug Bump (psi) 840.0 Recip? Yes Stroke (ft) 6.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 4,125.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 12 1/4 Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 39.8 Est Btm (ftKB) 3,716.0 Amount (sacks) 1,476 Class Blend Volume Pumped (bbl) 502.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 6.66 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 223.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 3,716.0 Est Btm (ftKB) 4,216.0 Amount (sacks) 334 Class G Volume Pumped (bbl) 70.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 5.00 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 189.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 MT7-93 Report Printed: 2/20/2024 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 12/24/2023 18:50 Cementing End Date 12/24/2023 22:10 Wellbore Name MT7-93 Comment Mix and pump 64 bbls of 12.5 ppg Mud Push II @ 5 bbls/min, 385 psi, Dropped bottom plug. Start batching lead. Pump 69 bbls of 13.0 ppg G-Blend cement at 4.5 bbls/min, 365 psi ICP. Batch and pump 10 bbls of G Blend Tail 15.8 ppg cement @ 4.9 bbls/min, 173 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 5/6 bbls/min, 255 psi ICP, 851 psi FCP. Slow pumps 30 bbls prior to calculated bump to 3 bbls/min, 851 psi ICP, Bump plug with 1410 psi (822 bbls + 20 bbls). 6955 strokes, final circ. PSI 851 Pressure up to 1410 psi & hold for 5 minutes. Bleed off pressure. Cement in place @ 22:10hrs 12/24/23 (No losses) Cement Stages Stage # 2 Description Primary – Full Bore Objective Lead Cement 13.0ppg Top Depth (ftKB) 9,163.0 Bottom Depth (ftKB) 10,059.0 Full Return? Yes Vol Cement …Top Plug? No Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 5 Q Pump Avg (bbl/… 5 P Pump Final (psi) 361.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 11,467.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 8 1/2 Comment Pumped 69 bbls lead cement Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 9,163.0 Est Btm (ftKB) 10,059.0 Amount (sacks) 175 Class G Volume Pumped (bbl) 64.0 Yield (ft³/sack) 1.89 Mix H20 Ratio (gal/sack) 10.31 Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 3 Description Primary – Full Bore Objective Tail Cement 15.8ppg Top Depth (ftKB) 10,059.0 Bottom Depth (ftKB) 11,559.3 Full Return? Yes Vol Cement …Top Plug? Yes Btm Plug? No Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 5 Q Pump Avg (bbl/… 5 P Pump Final (psi) 72.0 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 Pumped 120 bbls tail cement Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 10,059.0 Est Btm (ftKB) 11,559.3 Amount (sacks) 581 Class G Volume Pumped (bbl) 120.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 4.99 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 1 Cement Page 1/1 MT7-93 Report Printed: 2/20/2024 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 12/30/2023 16:30 Cementing End Date 12/30/2023 18:55 Wellbore Name MT7-93 Comment Rig pump 70bbls 8.9ppg KCL 5% deep clean spacer at 4bpm 780psi, Flood lines and test to 4600 PSI. Drop bottom dart. Swap to cementers. Pump 64.5 BBLS of 15.8ppg cement @ 4-4.5 BPM. SD and drop top dart. Pump 20 BBLS FW w/ cement unit. Swap to rig pumps and displace at 4 BPM 750psi. (BTM dart landed at 1263stks and sheared at 904psi, Top dart landed at 2006stks and sheared t 2169psi, BTM plug landed at 2126stks and sheared at 2960psi) Slow rate to 2 BPM and bump plug 2905stks (5.5bbls early). Pressure up to 1250psi, FCP to 450psi. Hold for 5 minutes and check floats. All Good. Full returns throughout job. No losses. Cement in place @ 18:55hrs 12/30/23 Cement Stages Stage # 1 Description Liner Cement Objective Top Depth (ftKB) 12,385.0 Bottom Depth (ftKB) 13,137.0 Full Return? No Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 3 P Pump Final (psi) 450.0 P Plug Bump (psi) 1,250.0 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 Rig pump 70bbls 8.9ppg KCL 5% deep clean spacer at 4bpm 780psi. Flood lines and test to 4600 PSI. Drop bottom dart. Swap to cementers. Pump 64.5 BBLS of 15.8ppg cement @ 4-4.5 BPM. SD and drop top dart. Pump 20 BBLS FW w/ cement unit. Swap to rig pumps and displace at 4 BPM 750psi. (BTM dart landed at 1263stks and sheared at 904psi. Top dart landed at 2006stks and sheared at 2169psi. BTM plug landed at 2126stks and sheared at 2960psi). Slow rate to 2 BPM and bump plug 2905stks (5.5bbls early). FCP - 450psi. Pressure up to 1250psi. Hold for 5 minutes and check floats. All Good. Full returns throughout job. No losses. Cement in place @ 18:55hrs, 12/30/23. TOL: 11,379' MD Landing collar 13,009' MD Float collar: 13,092' MD Shoe: 13,137' MD Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 12,385.0 Est Btm (ftKB) 13,137.0 Amount (sacks) 309 Class G Volume Pumped (bbl) 64.5 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 4.74 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 ! " # " !$%&' ( ) * ) +%" ) !, ) ) ) - ) !" !" ") ## $ %&'())*+,-"!*./01(2)*2) '3 4 .) !" - )5( 6 )$ %&'())*+,-"!*./01(2)*2) '3 4 ) !" *) *) ( / ) * *)7 (! '58 $ 0 (! '3370 9 6 97 6 :)2 , 7 4 $ 7 44 $ $ $ +." ) +" ) 0 .) .) 102% 1 2% 3 "+ ) !" )*)) )*)) ;9!(;9.!!*;" !)9(;)*+( ())*+) "0 ) )*)) )<()=2*+)! (;(<2(=(*; ; - 456 7 " . 4!6 * . 456 !" " * . &)" (>((>)" ("* ! .)*"2 ; 9)."*2! ), ) " ) . !" (*) 7, , ) 7*4!, 6 4 6 1 2% 4 6 456 102% 4 6 ! 8 )"!*.) 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Rig 25 Cc:Regg, James B (OGC) Subject:RE: D25 BOP test 12/31/23 Date:Thursday, February 1, 2024 10:25:03 AM Attachments:Doyon 25 12-31-23.xlsx Zak, I changed the Misc. Inspections/Misc. field to “NA”. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rig 25 <rig25@doyondrilling.com> Sent: Monday, January 1, 2024 1:37 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25 <Doyon25.OperationsEngineer@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Bill Walter <bwalter@doyondrilling.com>; Samuel Dye <sdye@doyondrilling.com>; Ben Wedin <bwedin@doyondrilling.com> Subject: D25 BOP test 12/31/23 Zak Coleman Rig 25 Tourpusher rig25@doyondrilling.com 907-670-4971 *UHDWHU0RRVHV7RRWK8QLW07 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:25 DATE: 12/31/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22230990 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Other: X Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3446 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 4P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators PP #1 Rams 1 2-7/8"x5"P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 1 2-7/8"x5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result HCR Valves 2 3-1/8"x5000psi P System Pressure (psi)2950 P Kill Line Valves 2 3-1/8"x5000psi P Pressure After Closure (psi)1800 P Check Valve 0NA200 psi Attained (sec)14 P BOP Misc 0NAFull Pressure Attained (sec)105 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6/1938 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 30 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/31/23 10:53AM Waived By Test Start Date/Time:12/31/2023 16:00 (date) (time)Witness Test Finish Date/Time:12/31/2023 23:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Doyon Test Annular 250/3500psi f/ 5/10 min. w/ 4" & 5" test joint. Test Ram #1 & 3 w/ 4" and 5" test joints 250/3500psi f/ 5/10min. Test ram #2 250/3500psi f/ 5/10 min. Test 2 each 5" and 4" FOSV and 1 each 5" and 4" dart valve. Function primary and remote BOPE control stations. Test LEL and H2S gas alarms. BLM Rep Quinn Sawyer waived witness 12/25/23 @ 8:21PM R. Fritts / Z. Coleman CPAI J. Benedict / P. Angelle GMTU MT7-93 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022) 2023-1231_BOP_Doyon25_GMTU7-93 9 9 9 9 9 9 9 9 9 9 -5HJJ %23(7HVW'R\RQ *07807 37' #01&5FTU%PZPO (.56.5 15% DOYON RIG 25 ACCUMULATOR DRAW DOWN WORKSHEET WELL: MT7-93 DATE: 12/31/23 ACCUMULATOR PSI 2950 MANIFOLD PSI 1425 FUNCTION RAMS/ANNULAR/ HCR'S, DON'T FUNCTION BLINDS! FUNCTION ONE RAM TWICE LET PRSSURE STABILIZE AND RECORD BACK UP NITROGEN BOTTLE'S ACCUMULATOR PSI 1800 NITROGEN BOTTLE'S PSI BOTTLE # 1 1925 BOTTLE # 2 1850 BOTTLE # 3 2000 BOTTLE # 4 1975 BOTTLE # 5 1975 BOTTLE # 6 1900 AVG FOR 6 BOTTLE'S = 1938 TURN ON ELEC. PUMP, SEC FOR 200 PSI =14 TURN ON AIR PUMP'S TIME FOR FULL CHARGE =105 MT7-93 12/31/2023 Tested to 250PSI/5MIN, 3500PSI/10MIN 4” Test Jt – Chart #1 1. Annular Preventer, Valves: 1, 13, 14, 15, 4” Kill Line Valve, 4” Dart Valve 2. Upper Pipe Rams (2.87” x 5” ), Valves: 2, 10, 12, HCR KILL & 4” FOSV #1 3. Valves: 6, 9 ,11, Manual Kill, 4” FOSV #2 4. Valves 5, 7, 8 & Auto IBOP 5. Valves 3 & 5” MAN IBOP 6. Lower Pipe Rams (2.87” x 5” VBR’S) 7. Blind Shear Rams, Valves: 4 8. Manually Operated & Super Choke ( 8B = SUPER Choke – 8A = MANUAL Choke) 5” Test Jt – Chart #2 9. Annular Preventer, HCR Choke 10. Upper Pipe Rams (2.87” x 5” VBR’S) & Manual Choke 11. Lower Pipe Rams (2.87” x 5” VBR’S) T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Jan 26, 2024 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-93 Greater Mooses Tooth API #: 50-103-20866-00 Permit No: 223-099 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. MT7-93 is located in a federal oil and gas unit. Only with respect to the MT7-93 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: 223-099 T38446 1/29/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.29 15:20:19 -09'00' 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:Rig 25 To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; WSC Rig Advisor; Bill Walter; Samuel Dye; Ben Wedin Subject:Revised D25 BOP test 1/15/24 Date:Monday, January 15, 2024 4:34:35 PM Attachments:Doyon 25 1-15-24.xlsx Some people who received this message don't often get email from rig25@doyondrilling.com. Learn why this is important Everett Potter Rig 25 Toolpusher rig25@doyondrilling.com 907-670-4971 *UHDWHU0RRVHV7RRWK8QLW07 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:25 DATE: 1/15/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2230990 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Other: X Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3446 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.P Ball Type 4P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators PP #1 Rams 1 2-7/8"x5"P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 1 2-7/8"x5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result HCR Valves 2 3-1/8"x5000psi P System Pressure (psi)2950 P Kill Line Valves 2 3-1/8"x5000psi P Pressure After Closure (psi)1850 P Check Valve 0NA200 psi Attained (sec)16 P BOP Misc 0NAFull Pressure Attained (sec)96 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6/1983 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 26 P #1 Rams 14 P Coiled Tubing Only:#2 Rams 15 P Inside Reel valves 0NA #3 Rams 13 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/15/24 5:14AM Waived By Test Start Date/Time:1/15/2024 8:00 (date) (time)Witness Test Finish Date/Time:1/15/2024 15:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Doyon Test Annular 250/3500psi f/ 5/10 min. w/ 4" & 5" test joint. Test Ram #1 & 3 w/ 4" and 5" test joints 250/3500psi f/ 5/10min. Test ram #2 250/3500psi f/ 5/10 min. Test 2 each 5" and 4" FOSV and 1 each 5" and 4" dart valve. Function primary and remote BOPE control stations. Test LEL and H2S gas alarms. BLM Rep Quinn Sawyer waived witness 1/14/24 @ 23:00. E. Potter/ C. Bali CPAI R. Reinhardt/ L. Shirley GMTU MT7-93 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022) 2024-0115_BOP_Doyon25_GMTU_MT7-93 9 9 9 9 9 9 9 9 9 9 9 -5HJJ MT7-93 1/15/24 Tested to 250PSI/5MIN, 3500PSI/10MIN 5” Test Joint #1 – ANNULAR PREVENTER, UPPER IBOP CMV’S # 13, 14, 15, 1 & 4”KILL LINE VALVE “RIG FLOOR” #2- UPPER PIPE RAMS, LOWER IBOP, HCR KILL, CMV’S # 10, 12, and 2 #3 – CMV’S # 9, 6, 11, 5” DART VALVE, MANUAL KILL #4 – CMV’S # 7, 8, 5, 5” FOSV #1 #5 – CMV. # 3, 5” FOSV # 2 #6 – LOWER PIPE RAMS, 4” DART * KOOMEY TEST AT THIS TIME #7 – BLIND RAMS & CMV # 4, 4” FOSV #1 #8A & 8B HYD & MANUAL CHOKES 4” TEST JOINT #9- ANNULAR, HCR CHOKE, 4” FOSV #2 #10 – UPPER PIPE RAMS, MANUAL CHOKE #11- LOWER PIPE RAMS 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:Rig 25 To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; WSC Rig Advisor; Bill Walter; Samuel Dye; Ben Wedin Subject:MT7-93 7 5/8" Date:Friday, December 29, 2023 12:22:11 AM Attachments:Doyon 25 12-28-23.xlsx Test Sequence 12-28-23.docx MT7 93 7.625in ram test chart.pdf Zak Coleman Rig 25 Tourpusher rig25@doyondrilling.com 907-670-4971 *UHDWHU0RRVHV7RRWK8QLW07 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:25 DATE: 12/28/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2230990 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Other: X Rams:250/3500 Annular:250/2500 Valves: MASP:3446 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping NA Well Sign NA Upper Kelly 0NA Permit On Location NA Hazard Sec.NA Lower Kelly 0NA Standing Order Posted NA Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 0 13-5/8"x5000psi P Pit Level Indicators NA NA #1 Rams 1 7 5/8"P Flow Indicator NA NA #2 Rams 0 Blind NA Meth Gas Detector NA NA #3 Rams 0 2-7/8"x5-1/2" VBR NA H2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 0 3-1/8"x5000psi NA Time/Pressure Test Result HCR Valves 1 3-1/8"x5000psi NA System Pressure (psi)NA Kill Line Valves 0 3-1/8"x5000psi NA Pressure After Closure (psi)NA Check Valve 0NA200 psi Attained (sec)NA BOP Misc 0NAFull Pressure Attained (sec)NA Blind Switch Covers: All stations NA CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 0NA ACC Misc 0NA Manual Chokes 0NA Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 0 NA Coiled Tubing Only:#2 Rams 0 NA Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:1.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/24/23 4:21pm Waived By Test Start Date/Time:12/28/2023 18:30 (date) (time)Witness Test Finish Date/Time:12/28/2023 19:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Doyon Change #1 Ram to 7 5/8". Test annular to 250/2500psi f/ 5/10 min. Test #1 Ram to 250/3500psi f/ 5/10 min. BLM Rep. Quinn Sawyer waived witness of test. R. Frittis / Z. Coleman CPAI J. Benedict / P. Angelle GMTU MT7-93 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022) 2023-1228_BOP_Doyon25_ram_GMTU_MT7-93 9 9 9 9 99917 9 9 9 9 9 -5HJJ #01&%PZPO $TH3BNT(.56.5 15% Rig 25 BOP test, 12/28/23 7 5/8” test joint Chart #1 1.Annular 250/2500 2.UPR 7 5/8” 250/3500 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:Rig 25 To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; Bill Walter; Samuel Dye; Ben Wedin; WSC Rig Advisor Subject:Upper Ram & HCR Choke Test Date:Monday, December 25, 2023 12:19:53 PM Attachments:Doyon 25 12-25-23.xlsx HCR Choke Test chart 12-25-23.pdf UPR Test chart 12-25-23.pdf Merry Christmas Zak Coleman Rig 25 Tourpusher rig25@doyondrilling.com 907-670-4971 *UHDWHU0RRVHV7RRWK8QLW07 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:25 DATE: 12/25/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2230990 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Other: X Rams:250/3500 Annular: Valves:250/5000 MASP:3446 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping NA Well Sign NA Upper Kelly 0NA Permit On Location NA Hazard Sec.NA Lower Kelly 0NA Standing Order Posted NA Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 0 13-5/8"x5000psi NA Pit Level Indicators NA NA #1 Rams 1 2 7/8'x5 1/2" VBR P Flow Indicator NA NA #2 Rams 0 Blind NA Meth Gas Detector NA NA #3 Rams 0 2-7/8"x5-1/2" VBR NA H2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 0 3-1/8"x5000psi NA Time/Pressure Test Result HCR Valves 1 3-1/8"x5000psi P System Pressure (psi)NA Kill Line Valves 0 3-1/8"x5000psi NA Pressure After Closure (psi)NA Check Valve 0NA200 psi Attained (sec)NA BOP Misc 0NAFull Pressure Attained (sec)NA Blind Switch Covers: All stations NA CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 0NA ACC Misc 0NA Manual Chokes 0NA Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 0 NA Coiled Tubing Only:#2 Rams 0 NA Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/21/23 12:14pm Waived By Test Start Date/Time:12/25/2023 5:00 (date) (time)Witness Test Finish Date/Time:12/25/2023 7:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Change #1 Ram to 2 7/8" x 5 1/2" VBR. Test #1 Ram to 250/3500psi f/ 5/10 min. While function HCR choke after test observed HCR Choke hydrualic leak. Change HCR Choke and test 250/5000psi f/ 5/10 min against #1 Ram. BLM waived witness of test. Z. Coleman / C.Bali CPAI J. Benedict / P. Angelle GMTU MT7-93 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022) 2023-1225_BOP_Doyon25_ram_GMTU_MT7-93 9 9 9 9917 9 9 9 -5HJJ #01%PZPO 7#3 (.56.5 15% #01%PZPO )$3$IPLF (.56.5 15% 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:Rig 25 To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; Bill Walter; Ben Wedin Subject:D25 BOP test 12/17/2023 Date:Sunday, December 17, 2023 9:38:51 AM Attachments:Test Sequence 12-17-23.docx Doyon 25 12-17-23.xlsx Test Chart #1 Choke test 12.16.23.pdf Test Chart #2 - 2 test joints 12.16.23.pdf Everett Potter Rig 25 Toolpusher rig25@doyondrilling.com 907-670-4971 *UHDWHU0RRVHV7RRWK8QLW07 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:25 DATE: 12/17/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2230990 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:3446 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators PP #1 Rams 1 9 5/8 P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 1 2-7/8"x5-1/2" VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result HCR Valves 2 3-1/8"x5000psi P System Pressure (psi)3025 P Kill Line Valves 2 3-1/8"x5000psi P Pressure After Closure (psi)1800 P Check Valve 0NA200 psi Attained (sec)13 P BOP Misc 0NAFull Pressure Attained (sec)74 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 / 1875 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 26 P #1 Rams 14 P Coiled Tubing Only:#2 Rams 15 P Inside Reel valves 0NA #3 Rams 13 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/12/23 4:23pm Waived By Test Start Date/Time:12/16/2023 23:30 (date) (time)Witness Test Finish Date/Time:12/17/2023 4:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Doyon Test Annular to 250/3500psi & ram #1 to 250/5000psi w/9 5/8" test joint. Test ram #2 to 250/5000 psi. Test Annular to 250/3500 psi & ram #3 to 250/5000psi w/ 5" test joint. Test 2 ea 5" FOSV and 1 ea 5" & Dart Valve. All tests for 5/10 mins. Function primary & remote BOPE control stations. Test LEL & H2S alarms. Choke manifold valves tested offline.BLM Rep. Quinn Sawyer waved witness of test. E. Potter / C.Bali CPAI J. Benedict / P. Angelle GMTU MT7-93 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022) 2023-1217_BOP_Doyon25_GMTU_MT7-93 9 9 9 9 9 9 9 9 9 9 9 -5HJJ Rig 25 BOP test, 12/17/23 9 5/8 and 5” test joint 250 low, 5000 Psi high Chart #1 1.Valves: # 1, 13, 14, 15. 2.Valves: # 2, 10, 12. 3.Valves: # 6, 9 ,11. 4.Valves: # 5, 7, 8. 5.Valve: 3. 6.Valve: 4. 7.Super choke and manual choke Chart #2 1. 9 5/8 test joint: Annular Preventer ( 250 low / 3500 high)h). Choke hose. 2. Upper rams (9 5/8), 4” Kill Valve on mud manifold, 5” Dart, Choke hose connections. 3. HCR Kill, 5” FOSV # 1, HCR choke. 4. Manual Kill, Manual choke, 5” FOSV # 2. 5. Blinds, Upper IBOP 6. Annular 3500 psi. (5” test joint) 7. 5” lower rams, Lower IBOP (5” test joint) Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Greater Mooses Tooth Field, Rendezvous Oil Pool, GMTU MT7-93 Conoco Phillips Alaska, Inc. Permit to Drill Number: 223-099 Surface Location: 1083' FSL, 2071' FWL, SESW S32 T10N R2E, UM Bottomhole Location: 2213' FSL, 3854' FWL, SESE S30 T10N R2E, UM Dear Mr.Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCCreserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, *UHJRU\:LOVRQ Commissioner DATED this ___ day of October2023. . Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.10.31 14:02:43 -08'00' 31 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: 25,376 TVD:8,204 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number:13. Approximate Spud Date: 11/1/2023 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 1264.5' to AA092341 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-290151 y- 5915644 Zone-4 100.8 to Same Pool:1,087' to MT7-14A 16. Deviated wells:Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42 20 94 H-40 Welded 80 40 40 120 120 16 13-3/8" 68 L-80 Hyd563 4158 40 40 4198 3046 12-1/4" 9-5/8" 47.00 T-95 Hyd563 11635 40 40 11675 7544 8.5" x 9-7/8"7.625" 29.00 L-80/P-110 Hyd563 1625 11525 7429 13150 8318 6-3/4" 4.5" 12.60 P-110 Hyd563 12376 13000 8282 25376 8204 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. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 128 sx 15.8 ppg Class G Uncemented liner Effect. Depth MD (ft):Effect. Depth TVD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Conductor/Structural LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry 1515 sx 11.0 ppg DC + 238 sx 15.8 ppg Class G 3782, 5723 18. Casing Program:Top - Setting Depth - BottomSpecifications 4266 Total Depth MD (ft):Total Depth TVD (ft): 59-52-180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 125 sx 15.8 ppg Class G 3446 1911' FSL, 4241' FWL , SESW S5 T09N R2E, UM 2213' FSL, 3854' FWL, SESE S30 T10N R2E, UM 932535000, 932516000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips 1083' FSL, 2071' FWL, SESW S32 T10N R2E, UM AA081800,AA081781 Greater Mooses Tooth Rendezvous Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. q''d: Yes ype of W L l R L 1b S Class: os N q''d: Yesq No s N No Drilli s s s T Drilli D o shahales: well is p G S S S S S q''d: Yes q Nos No S G y E S q''d: Yes q No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 12:45 pm, Oct 19, 2023 Diverter variance granted per 20 AAC 25.035(h)(2). No evidence of shallow gas or gas hydrates in recent wells. -A.Dewhurst VTL 10/31/2023 5915899.5 Alaska, Inc 50-103-20866-00-00 290150.6 A.Dewhurst 20OCT23 GMTU MT7-93 X DSR-10/19/23 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Waiver for CPAI Rotary 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. 223-099 Oil Pool &': Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.10.31 14:34:55 -08'00'10/31/23 10/31/23 RBDMS JSB 110223 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' 'DdDdϳͲϵϯ 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. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 17, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-93 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand producer well from the MT7 drilling pad. The intended spud date for this well is 11/1/2023. It is intended that Doyon 25 be used to drill the well. MT7-93 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 7.625” 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 6-3/4" 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 ICDs, 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 Weifeng Dai at 907-265-6936 (Weifeng.Dai@conocophillips.com) or Greg Hobbs at 907-263-4794 (greg.s.hobbs@conocophillips.com). Sincerely, cc: MT7-93 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1552 Weifeng Dai Chris Brillon ATO 1548 Staff Drilling Engineer Andy Mack Kuukpik Corp MT7-93 Saved: 17-Oct-23 MT7-93 Page 1 of 14 Printed: 17-Oct-23 MT7-93 Well Plan Application for Permit to Drill Table of Contents 1.Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3.Proposed Drilling Program ...................................................................................... 5 4.Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) .................. 6 5.MASP Calculations ................................................................................................... 6 6.Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 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 MT7-93 Saved: 17-Oct-23 MT7-93 Page 2 of 14 Printed: 17-Oct-23 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-93 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1083' FSL, 2071' FWL, SESW S32 T10N R2E, UM NAD27 Northings: 5915900 Eastings: 290151 RKB Elevation 38.7’ AMSL Pad Elevation 100.8’ AMSL Top of Productive Horizon (Heel) 1911' FSL, 4241' FWL , SESW S5 T09N R2E, UM NAD27 Northings:5911389 Eastings: 292211 Measured Depth, RKB: 13,176’ Total Vertical Depth, RKB: 8,323’ Total Vertical Depth, SS: 8,183’ Total Depth (Toe) 106' FSL, 4931' FWL, SESE S30 T10N R2E, UM NAD27 Northings: 5922401 Eastings: 286976 Measured Depth, RKB: 25,376’ Total Vertical Depth, RKB: 8,204’ Total Vertical Depth, SS: 8,064’ Please see attached well stick diagram for the current planned development of the pad. MT7-93 Saved: 17-Oct-23 MT7-93 Page 3 of 14 Printed: 17-Oct-23 Pad Layout Well Stick Diagram MT7-93 Saved: 17-Oct-23 MT7-93 Page 4 of 14 Printed: 17-Oct-23 MT7-93 Saved: 17-Oct-23 MT7-93 Page 5 of 14 Printed: 17-Oct-23 3.Proposed Drilling Program 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” fix 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 11.0 ppg Fresh water polymer WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and trip out of hole. 14. 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” fixed casing ram to 5” x 7-5/8” VBRs. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 18. Pick up and run in hole with 8-1/2” x 9-7/8” drilling BHA to drill intermediate 2. Simops – perform 9.625” annulus 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. MT7-93 Saved: 17-Oct-23 MT7-93 Page 6 of 14 Printed: 17-Oct-23 5. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparation for cementing. 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 and trip OOH. 24. Pick up and run in hole with the 7.625” liner on 5” DP to section TD. 25. Circulate and condition mud in preparation for cementing. 26. Cement 7.625” 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 13.0 ppg EMW. 32. Drill 6-3/4” 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 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 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 4,198 / 3,046 14.5 1364 1059 9.625 11,675 / 7,544 16.5 3406 1992 MT7-93 Saved: 17-Oct-23 MT7-93 Page 7 of 14 Printed: 17-Oct-23 7.00 13,150 / 8,318 12.5 3755 2923 4.5 25,376 / 8,204 12.5 4266 3446 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 3046’) = 1059 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 3046’ = 1992 psi OR ASP = FPP – (0.1 x D) = 3406 – (0.1 x 7544) = 2652 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 7544 = 5679 psi OR ASP = FPP – (0.1 x D) = 3755 – (0.1 x 8318’) = 2923 psi Minimum MW needed = 8.7 ppg 4.Drilling below 7” production liner ASP = [(FG x 0.052) – 0.1] D 4266 MT7-93 Saved: 17-Oct-23 MT7-93 Page 8 of 14 Printed: 17-Oct-23 = [(12.5 x 0.052) – 0.1] x 8204 = 4512 psi OR ASP = FPP – (0.1 x D) = 4266 – (0.1 x 8204) = 3446 psi Minimum MW needed = 8.8 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 47 T-95 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7.625 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 4,198’ MD /3,046’ TVD Cement Plan: Cement from 4,198’ MD to 3,698' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,698' 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 3,698’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 2,620 ft3 => 1,515 sx of 11.0 ppg Deepcrete + Add's @ 1.73 ft 3 /sk Tail slurry from 4,198’ MD to 3,698’ MD with 15.8 ppg Deepcrete + Add's Total Volume = 316 ft3 => 238 sx of 15.8 ppg Class G + Adds @ 1.33 ft3/sk Deepcrete + Add's f 15.8 ppg Class G + Adds Deepcrete + Add's Arctic Lite Crete MT7-93 Saved: 17-Oct-23 MT7-93 Page 9 of 14 Printed: 17-Oct-23 9.625” Intermediate Casing run to 11,675’ MD / 7,544’ TVD Cement Plan: Primary cement job consists of 500 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 11,175’ MD, which is 500’MD or 250’ TVD above the prognosis hydrocarbon bearing zone. 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. Tail slurry from 11,675’ MD to 11,175’ MD with 15.8 ppg Class G + Add's Total Volume = 203 ft3 => 125 sx of 15.8 ppg Class G + Adds @ 1.63 ft3/sk 7.625” Intermediate Casing run to 13,150’ MD / 8,318’ TVD Cement Plan: Top of slurry is designed to be at 12,457’ MD, which is 500’MD or 250’ TVD above Alpine D. Assume 40% excess annular volume. Tail slurry from 13,150’ MD to 12,457’ MD with 15.8 ppg Class G + Adds Total Volume = 208 ft 3 => 128 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 7.625 4.5 Density PPG 9.0 – 10.0 11.0 – 12.0 10.0 – 13.0 8.8 – 9.0 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. 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 f 13.0 ppg lead slurry MT7-93 Saved: 17-Oct-23 MT7-93 Page 10 of 14 Printed: 17-Oct-23 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 MT7-93 will be injected into a permitted annulus on the MT7 pad, or hauled to the Class 1 disposal well on CD1. The MT7-93 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 MT7-93 has been drilled and completed, consideration may be given to permit this well for annular injection. 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. MT7-93 Saved: 17-Oct-23 MT7-93 Page 11 of 14 Printed: 17-Oct-23 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) * (3046’) + 1,500 psi = 3401 psi Pore Pressure = 1,381 psi Therefore Differential = 3401 – 1,381 = 2020 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 MT7-93 Saved: 17-Oct-23 MT7-93 Page 12 of 14 Printed: 17-Oct-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 / 7.625” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well MT7-93 Saved: 17-Oct-23 MT7-93 Page 13 of 14 Printed: 17-Oct-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. MT7-93 Saved: 17-Oct-23 MT7-93 Page 14 of 14 Printed: 17-Oct-23 15. Proposed Completion Schematic Attachment 1 – MT7-93 Area of Review (AOR) An Area of Review plot is show below of the MT7-93 planned wellpath and offset wells. MT7-14A and MT7-95 are the offset wells from the planned MT7-93 producer. MT7-95 is injector currently shut in for trial of seawater and production water. MT7-14A is also injector and currently on pre-production. Well Name Status Top of Alpine Pool (MD/TVD) TOC (MD/TVD) TOC – Determined By Reservoir Status Zonal Isolation Cement Operations Summary MT7-95 Shut in 11,264’ / 8,226’ 9,650’ / 7,000’ SonicScope Liner TOC and production Packer 62 bbls of 15.8 ppg Class G MT7-14 Abandoned 13,393’ / 8,267’ 12,470’ / 8,138’ SonicScope Liner TOC, P&A plugs 128 bbls of 15.8 ppg Class G MT7- 14A Pre- producing 11,905’ / 8,257’ 10,380’ / 7,501’ SonicScope Liner TOC and production Packer 70.5 bbls of 15.8 ppg Class G MT7-95 9-7/8” intermediate section was drilled to from 9,707’ to 11,040’ MD and 7” casing run to bottom at 11,032’ MD. Cement job went successfully. Total pumped 62bbls 15.8ppg class G cement and cement placement was measured with Sonicscope in production BHA and apparent TOC is identified at a depth of 9806’. A horizontal production section was drilled in Alpine C to 24,803’ MD with 4-1/2” liner set ~1000 ft off bottom due to tight hole. The Alpine C zone was penetrated at 11,264’ MD. MT7-14 9-7/8” intermediate section was drilled to from 10,407’ to 13,044’ MD and 7” casing run tight and had to work pipe down to 12,366’. Was not able to build up circulation. Performed injectivity test and injected total 128bbls 15.8ppg class G cement and cement placement was measured with Sonicscope in production BHA and apparent TOC is identified at a depth of 12,470’. A horizontal production section was drilled in Alpine C to 22,795’ MD, after ream BHA back into the 7” shoe, it appears the hole collapsed and lost ability to re-enter the open hole. Decision was made to P&A the existing hole. MT7-14A 9-7/8” intermediate section was drilled to from 10,220’ to 11,890’ MD and 7” casing run to bottom at 11,885’ MD. Cement job went successfully. Total pumped 70.5 bbls 15.8ppg class G cement and cement placement was measured with Sonicscope in production BHA and apparent TOC is identified at a depth of 10,380’ MD. A horizontal production section was drilled in Alpine C to 21,015’ MD with 4- 1/2” liner run to bottom successfully. The Alpine C zone was penetrated at 11,905’ MD. 39 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 3500 3500 8000 8000 15000 15000 23510 MT7-93_wp13 Plan Summary MT7-93_wp13MT7-01MT7-01PB1 MT7-02 MT7-03 MT7-04 MT7-05 MT7-06 MT7-06A MT7-06PB1 MT7-07 MT7-08 MT7-08PB1 MT7-09 MT7-11 MT7-14MT7-14A MT7-94 MT7-95 MT7-96 MT7-97 MT7-98 MT7-99 MT7-10_wp04 MT7-94_wp03 0 4 Do g l e g S e v e r i t y 0 4000 8000 12000 16000 20000 24000 Measured Depth 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Liner 4-1/2" Production Liner 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] MT7-94 MT7-95 MT7-96 MT7-97 MT7-98 MT7-94_wp03 0 5000 Tr u e V e r t i c a l D e p t h -6000 -4000 -2000 0 2000 4000 6000 Vertical Section at 332.38° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Liner 4-1/2" Production Liner 0 55 110 Ce n t r e t o C e n t r e S e p a r a t i o n 0 4500 9000 13500 18000 22500 27000 31500 Measured Depth Equivalent Magnetic Distance DDI 7.223 SURVEY PROGRAM Date: 2023-01-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.00 1000.00 MT7-93_wp13 (MT7-93) SDI_Keeper_ADK 1000.00 4198.00 MT7-93_wp13 (MT7-93) MWD+IFR2+SAG+MS 4198.00 11675.00 MT7-93_wp13 (MT7-93) MWD+IFR2+SAG+MS 11675.00 13150.00 MT7-93_wp13 (MT7-93) MWD+IFR2+SAG+MS 13150.00 25376.00 MT7-93_wp13 (MT7-93) MWD+IFR2+SAG+MS Surface Location North / 5915643.66 East / 1430186.73Ground / 100.50 CASING DETAILS TVD MD Name 3046.20 4198.00 13-3/8" Surface Casing 7544.45 11675.00 9-5/8" Intermediate Casing 8317.55 13150.00 7" Intermediate Liner 8203.80 25376.00 4-1/2" Production Liner Mag Model & Date: BGGM2023 20-Oct-23 Magnetic North is 13.85° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.35° 57086.91nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2500.000.00 0.00500.00 0.00 0.000.00 0.00 0.00Start Build 1.50 3 700.00 3.00 160.00 699.91 -4.92 1.79 1.50 160.00 -5.19 Start Build 2.00 4 1000.00 9.00 160.00 998.13 -34.37 12.51 2.00 0.00 -36.26 Start DLS 2.50 TFO -7.40 5 3442.78 70.00 153.11 2795.72 -1366.08 659.39 2.50 -7.40 -1516.10 Start 557.22 hold at 3442.78 MD 6 4000.00 70.00 153.11 2986.30 -1833.08 896.21 0.00 0.00 -2039.68 Start DLS 3.00 TFO 0.11 7 4110.24 73.31 153.12 3020.99 -1926.39 943.52 3.00 0.11 -2144.28 Start 3066.09 hold at 4110.24 MD 8 7176.32 73.31 153.12 3901.70 -4545.88 2271.49 0.00 0.00 -5080.92 Start DLS 2.50 TFO 179.53 9 11624.89 37.91 332.41 7504.92 -5583.06 2768.85 2.50 179.53 -6230.49 Start 100.00 hold at 11624.89 MD 10 11724.89 37.91 332.41 7583.81 -5528.61 2740.39 0.00 0.00 -6169.04 Start DLS 2.86 TFO 0.71 11 13107.44 77.46 332.88 8308.31 -4510.87 2215.00 2.86 0.71 -5023.71 Start 128.11 hold at 13107.44 MD 12 13235.55 77.46 332.88 8336.13 -4399.57 2157.99 0.00 0.00 -4898.66 Start DLS 2.60 TFO 0.51 13 13752.21 90.91 332.99 8388.35 -3942.90 1924.66 2.60 0.51 -4385.86 Start DLS 0.00 TFO -101.12 14 23876.00 90.91 332.98 8227.58 5075.29 -2672.91 0.00 -101.12 5736.09 Start 1500.00 hold at 23876.00 MD 15 25376.00 90.91 332.98 8203.80 6411.38 -3354.29 0.00 0.00 7235.82 TD at 25376.00 FORMATION TOP DETAILS TVDPath Formation 979.34 Perma_Frost 1088.52 C40 1420.87 C30 1647.25 C20 2003.81 C10 3031.94 K3 3046.20 SCP 3668.83 Albian_97 3893.18 Albian_96 4055.87 Albian_95 4882.66 Albian_94 5448.39 Albian_93 6298.04 Albian_92 6397.10 Albian_91 7504.74 HRZ 7543.83 INT1 CP 7650.00 LCU 8314.73 Alpine_D 8320.52 INT2 CP By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan KB (100.5 GL + 39.0 DF) @ 139.50usft (Original Well Elev) Pl a n V i e w Pr o j e c t : W e s t e r n N o r t h S l o p e Si t e : GM T 2 R e n d e z v o u s P a d We l l : M T 7 - 9 3 We l l b o r e : M T 7 - 9 3 De s i g n : M T 7 - 9 3 _ w p 1 3 -2 4 0 0 0 -1 2 0 0 0 0 12 0 0 0 South(-)/North(+) (6000 usft/in) -3 6 0 0 0 - 2 4 0 0 0 - 1 2 0 0 0 0 1 2 0 0 0 We s t ( - ) / E a s t ( + ) ( 6 0 0 0 u s f t / i n ) MT 7 - 9 3 T1 - 1 3 2 0 f t MT 7 - 9 3 T 2 - 1 3 2 0 f t M T 7 - 1 4 A M T 7 - 1 4 M T 7 - 0 8 P B 1 M T 7 - 0 8 M T 7 - 0 7 M T 7 -0 1P B 1 M T 7 - 0 2 M T 7 - 0 9 M T 7 - 9 4 _ w p 0 3 MT 7 -94 M T 7 - 0 4 M T 7 - 0 3 M T 7 - 0 6 A M T 7 - 0 6 P B 1 M T 7 - 9 5 M T 7 - 9 9 M T 7 - 1 0 _ w p 0 4 M T 7 - 1 1 M T 7 - 0 1 M T 7 - 9 8 M T 7 - 9 6 M T 7 - 0 5 M T 7 - 9 7 M T 7 - 0 6 13 - 3 / 8 " S u r f a c e C a s i n g 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 7" I n t e r m e d i a t e L i n e r 4- 1 / 2 " P r o d u c t i o n L i n e r 1 0 0 0 2 0 0 0 3 0 0 0 4 0 0 0 6 0 0 0 7 0 0 0 8 0 0 0 8 2 0 4 MT 7 - 9 3 _ w p 1 3 0 30 0 0 60 0 0 90 0 0 True Vertical Depth (1500 usft/in) -6 0 0 0 - 3 0 0 0 0 3 0 0 0 6 0 0 0 Ve r t i c a l S e c t i o n a t 3 3 2 . 3 8 ° ( 1 5 0 0 u s f t / i n ) 13 - 3 / 8 " S u r f a c e C a s i n g 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 7" I n t e r m e d i a t e L i n e r 4- 1 / 2 " P r o d u c t i o n L i n e r 10 00 200 0 30 0 0 4 0 00 5000 6 0 0 0 7 00 0 80 0 0 90 0 0 10000 1 1 0 0 0 1 2 0 0 0 13000 14 000 15 000 16000 17000 18000 19000 20000 21000 22000 23000 24000 25000 MT7-93/MT7-93_wp13 St a r t B u i l d 1 . 5 0 St a r t B u i l d 2 . 0 0 St a r t D L S 2 . 5 0 T F O - 7 . 4 0 St a r t D L S 2 . 5 0 T F O - 7 . 4 0 St a r t 5 5 7 . 2 2 h o l d a t 3 4 4 2 . 7 8 M D St a r t D L S 3 . 0 0 T F O 0 . 1 1 St a r t 3 0 6 6 . 0 9 h o l d a t 4 1 1 0 . 2 4 M D St a r t D L S 2 . 5 0 T F O 1 7 9 . 5 3 St a r t 1 0 0 . 0 0 h o l d a t 1 1 6 2 4 . 8 9 M D St a r t D L S 2 . 8 6 T F O 0 . 7 1 St a r t 1 2 8 . 1 1 h o l d a t 1 3 1 0 7 . 4 4 M D St a r t D L S 2 . 6 0 T F O 0 . 5 1 St a r t D L S 0 . 0 0 T F O - 1 0 1 . 1 2 St a r t 1 5 0 0 . 0 0 h o l d a t 2 3 8 7 6 . 0 0 M D TD a t 2 5 3 7 6 . 0 0 Se c t i o n V i e w Pr o j e c t : W e s t e r n N o r t h S l o p e Si t e : GM T 2 R e n d e z v o u s P a d We l l : M T 7 - 9 3 We l l b o r e : M T 7 - 9 3 De s i g n : M T 7 - 9 3 _ w p 1 3 ! ! " #$ %& % & ' () * ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 / ' -* 0 2 / -*7 8 2 /5*.'58 2 / 92 / 97* : ; ", 7 *+ (. * 7 *++ *. . (. ! !! 3 ! +!* + 1!* !! 4 !/ & !1 5 !1 '! )1 !3 4, ' < !* 3 * 9 9 8 ' ( 9; 9 =3 ' ( ' ( < >33 =;2 <;>= % % !! + 1!* +!* 5 !1 & !1 657% 6&7 !! 4 !/' *+) 9 9=; ==' ( 9; 98= ' ( ' (% 5 )! ' ( < >3 ;2 <;>3 = = ' ( 33 3' ( % - !! 89: 3! 1 8: - -! "1 89: &1! !!3 3 ?3 ?3 3 8 8 9 8= 3 . ! "*!& - !116 "2 .! ! - 3 8.-: 8* ,: 6&7 8* ,: -! ! 89: 657% 8* ,: !;- 3 8 - 3 8* ,: *)/ 1 # &*)/8% : - 8* ,: -??3 3 01 1 0 *' 16 % 9 #0$ 3#!# )!#0$ 3#+# 16 %9 ;98 3 #0$ 3#!# )!#0$ 3#+# 16 %;98 9= #0$ 3#!# )!#0$ 3#+# 16 %9= 9 ; #0$ 3#!# )!#0$ 3#+# 16 %9 3 9= ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 $ !! 89: "(!* 89: 657% 8* ,: 3; 89: 6&7 8* ,: * - 8* ,: .! - 8* ,: - 1 1 897* ,: <*! 897* ,: * 897* ,: ! 1 = ; 3= = 3 3 3 ; 8 = 9 ; 383 3 = 9== 839 3 9;;3 8 8= 398 8398= ;9 ; 393= 9 3 3 ;9 3; 393 ;;9 ; 889 3 9= 3 ; 8 3 39=8 8 9 8 9 ; 33 ; 9=3; 8 39; 9 38 =9 8 83 ; 93; 8 3 8=3 8=393 ;9 889 8 3 88 ;=9 ;; 39 ;9 89= 3 88 ;=93 33 = 3 = 93; ==9;3 8988 3 9 3 3A ,; 3 39=3 9 38933 83 8 398= ,; 9 ; 3=9; 8893 8 3 8 3 9= ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: 3 3 ; ; <*! => = = 3 ; = = ; 3 <*! = 8 = == 3 3 ; ; 8 3 = 8 33 ;= 3 3 3 8 8 =3 = ; 3 =; 3 3 9 = 8 = 3= 3 ; 3 3 -+=>3;=? 9 8 38 8 ; 9 88 3 3 3 ; ;8 8 3= 3 ;8 = ? 9 ;8 8 8 9 = 3 8 8 8 3 ; 3 93 ; 9; = 8; 3 8 3 8 3 ; 9 = ; = = 93 3 3 ;= 3 ; ; 9; 8 = = 98 8 3 = 3 3 ; =8 3 ; 9; 8 88 9;3 8 ;; 3 ; =8 ; 3 3 ;= 9 3 ;= = 9; =; == 8; 3 ; = 8 3 ; 9= 3 3 9 88 3 8 3 8= 3 ; 9=8 = 3= 9=; 3 3; ;= 3 33 8 ; = 3 38 9 3= ; 9==3 = 3; 3 338 =; = 3 3= 98 38 ; 8 9 8 3; ; 3 3 3 ;8 3 3 9 ; ; 8 98 ;; 3 = 8 8 3 3 39 ; ; ; 93 ;= 8 = 3 =; =3 3 3 39 = ;; ; 3 39 8 ; = = 3 ;= 8 8 33 3 39 = ;= ; 3 39 8 ; = =3 3 ; 3 8 ;3 3 ; 393 8 ; ; 3 39 83 3= 3 ; 3 8; 3 39 ; ;; ; 39 8 = 8 = 3 3 3;3 3 3 39; ; ; 8 3933 =; ; 3 8 3 8= 3 39 ;= ;; 39 3 == 3 ; 3 = ; 3 39= ;8 ; 39= ; 3 3 8 8 3 39 ;; = 39;; 8 = 3 8 =; = ; 3 398 39;; = = 3 8= 8 ; 3 8 39 = ; ;= 39 9 3 ; 3 ; ;; 3 9 8 39= = 9 3 3 9 8 ; 8 3 9 = ; 3 39= ; 88 93 8 3 9 8 ; 8 = 3 93 = 3 39 933 8 3 9== 8 8 = 3 = 9 == ; 39;3 ; 98 3 93; 8 3 3 = 9; =8 398 9;= 3 9 =; 38 3 = 9;;3 8 39 3 9 = 3 9== 8 = 3 = >>= ??=@- 9 398 3 9 = 8 9;; ; =8 ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: 9= 398; ; 9== 8 9; 8 3= 3 9 3988 = 9 9 8 = =8 98 39 8 98 9== ;= 8 3 9 39 3 9; 9; 3 8 ;9 398= 39 =8 98 8 8= 3 -+=3;= ;9 3 9 8 3 39; ; 9 = ;9 3; 3 9 3 39;; 38 93= ; 3 AA= ?=?- ;9;8 = 3 9 ; 398 8 9 8 = = B ;98 3 9 ;= 3 39338 ; 39 8 7@C*, !1 ;93 3 9 ;= 393 3= 39 8 83 ; ;9 3 9 393= ; 39 88 9 3 ;9; 3 9 ; 33 39;3 83 39 9 = 3 ;9 3 93 39 393 8 93 ;9= 3 9= = 39= 39;; 83 9 =; ;9 3 9 39 39; 3 98 = ;98 3 93 3 398 ; 39 = 93;3 3 ;9 3 93; 8; 39 39= 3 938 8 9 3 93= 39= ;8 39=8= 938 8 9 3 9 3 9 3 3= 39 93 3 93 3 9; 3 988 ; 398 ;3 9; 9 3 9=3 ; 938 83 39;3 8= 9; 8 83 9; 3 9 ;= 9 9 38 3 9 3 ; 9 3 9;3 9; 9 9 ; ; 9= 3 9;;8 9 9 = 9 88 = 9 3 9; =; 9=== 938; 9=3 98 3 9 = = 9=3 9 9= 8 9 3 9 98 8 ;8 9; ;= 98 = =9 3 9 = 8 9 ; 3= 9 ; 9=3 =9 3 9 3 ;9 ; 9=3= 98 3 =93 3 9=3 3= ;9; 83 9 98;8 = =9 3 9=; 8 ;93; = 9 3 98 ; =9= = 3 9==8 8 ;9 ; ;; 98 3= 93 = " ! =9; 3 9=8 ;9 9883 =; 9 3 =9 3 9 ; ;9; 9=8 98 = =9= 3 9= = ;9 38 ;9 39 3 88 =9 3 9=; 88 ;9=3; ;98 ; 39 = =98 3 9 = ;93 ; ;933; 39 8 =9 3 9833 ;98= 3= ;9 8 39 8 9 3 98 ;93 ; ;9 3; 39 3 9 3 98 8 9 83 ;9;8 =8 3938 ; 9;= == 3 98 8 9 3 ;9 3 ; 393 8 =; " ! A 9= 3 3 9 9 8 3 ;9 ; 88 393 ; -+=>3;=> 93 3 3 3 9 8 =3 9 = 3 ;9 == 8 3938 3 3 9 33 ; 9; ; 98 = 3 ;9= = 393; 3 3 ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: 9; = 3 9= 3 93 =8 3 ;9 3 39== 3 3 3 9 = 33 ;9 = 33 98 3 ;98 39; 8 3 3 9 =3 3 ;9 8 9;=; 3 3 ;9888 39;;; 8 3 3 " ! > 9= =3 3 3 ;9 = 9; 8 3 ;98 39;;8 3 3 9 = 33 3; ;9 8 9 = 3 3 ;9; = 39;88 3 98 3 3 ;9 ; 9=;= = 3 9 8 39 3= 3 9 33 3 ;93; = 9 3 93 39 =; 3 3 89 3 3 3 ;93 ; 98 88 3 9 = 39= 3 89 33 ;9 8 988 8 3 93= ;= 39= = 3 893 ; 3 ;9; ; 9=; 3 9; 88 39== ; 3 89 ; 33 ; ;9; =9 = 8 3 9 39 88 3 ; 89; ;3 3 ; ;9 ;3 3 =9 = 8 3 9;= 8 393 3 3 ; 89 ; 33 ;9= 3 =93 8 3 9 3 39=3 ; 3 ; 89= 3 = ;9=; ; =93 ; 3 9 ; 39 3 89 33 =3 ;9 =93; 8 3 9= 398= 3 = 898 3 3 =8 ;98 8 38 =9 3 3 9=8 = 398; 3 = 89838 8= 3 ;9883 == =9== = 3 9=; ;8 398;8 8 3 " ! ? 89 33 ;9; =9; 3 3 93 ; 398=; 8 3 9 3 3 8 9 =9; 3 3 9 88 3988= 3; 3 8 9 3 33 93 = =9; 8 3 98 8 39 8= 3 93 33 3 ; 93 =9 = ;8 3 98; ; 393 =8 3 3 9 3 33 ; 9 ; =9 = 3 988 3 39 = 3 9; 3 ; 8 9 =9= ; 3 9 = 39 = 3 9; = ;; ; 9;;8 =9=3 ; 3 93 39= 3 3 3 " ! 9 33 ; =3 9; ;; =9= 8 3 9 3 39= = 3 3= 9= 3 3 ; = 9 3 ; =9= 3 9 ; 39= 3 3 ; 9 33 ;= 9= ; =9= 8= 3 9 398; = 3 98 = 3 98 3 =9= ; 3 98 3 39 3 83 9 3 8= 9888 =9 ; =8 3 9 39 ;3 3 ; 9 3 =3 988 ; =9 3 =9 = 3 39 8 3 ;8 ; ; 9 3 =9 88 3 =9; 3 =9 8 8; 398 3 3= ; 93 3 3 ; =988 3 =93 3 3 =9 39= 83 8 ; =; 9 ; 8 3 = =9388 =9 = ; 3 =9 3 ; 39 3 ;8 9 = 3 =938 ; =9 3 3 =9 3 393 8 3 ; 3 =; " ! 9; 3 =98 =9= =3 3 9 ; 398 8= 3 ; ; 9; =8 ; 3 = =9 =9=; 8 3 93 398 3 3 " ! 9 8 ; =9;8= 8 =9=8 8 3 98 = 398 ; 3 8 9= 3 3 =9 8; 3 =9== = 3 9= 8= 39 = 3 ; 9 ; 3 =9=8 =9=8 33 3 9; 39 3 = 98 3 =9 8 =9= 3 9 8 39;= ; 3 3= 9 ; =983 = =9 8 8 3 98 39 ;; 3 9 33 3 8 =9= = =9 ;3 3 98 ;= 39; ; 3 9 3; 3 3 9 = =9 3 3 983; 3 398 3 3 93 3 3 3 3 9; ; =9; 3 98 ; 398 3 9 3 3 3 93 3 =9; 3 9; 398 3 8 3 9; 3 3 3 38 93 =9 3 9= = 39838 8 3 ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: 9 ; 3 ; 9; ; ; =9 ; 3 9=;8 =; 398 = 3 = 9= 3 3 ; 9;8 =93; = 3 9 = 39 88 3 = 9=3; = 3 ; 9 ; ; =93 =3 3 9 8 39=8 3 D 2 9=3; 8 3 ; 9 ; 3 =93 ; 3 9 8 39=8 8 3 = A?=@- 9=; 33 3 ; 9 ; 8 =93 8 9 = 3 39 ; 8 $& 9= 3 ; 9 ;; ; =9 9 8 39 ; >7@C$! !1 9 3 ; 9 =; =98; ; 9 ;3 39; ; 93; 8 3 ; 9 8 8 =9= ; 9 38 = 39; -+=@A3;= 98 ; = 3 ; 9=;3 =93 8 3 8= 9;8= 398 3 3 8= = 98 33 ; 3 ;= 9= =9 3 3 8= 9;8 88 39 ; 3 8= + 4 9 ;3 3 3 9 =9 = 3 8= 9;3 8 39=8 3 8= 39 ; 8 3 988 = 98 == 3 8= 9= 39= == 3 8= ; 39 ;8 =; 3 98 = 3 93 38 3 8= 9 8 39=3 8= 3 8= ; 393 3 =3 93 98 = 3 8= 933 39 8= 8 3 8= ; 39 ; = 3 == 98 9 8 3 8= 9= 39 ; 3 3 8= 39; 33 3 = 89 8 9= ; 3 8= 9 88 ;; 39 = 3 8= 39 = 8 3 3 89 8 3 9 8 ; 3 8= 9 3 = 39;3 8 3 8= 39= =3 ; 3 89= 8 9; 8= 3 8=;9; ;; 39;3 ; 3 8= 39 = 8 3 8 898 ; 9; 3 8=;98 ; 38 39 38 3 8= 398 =8 == 3 8 8938 8 9 3 8=;93 38 39; 3 3 8= 39 3 8 893 3 8 933 3 8=;9=88 = 39 = 3 8= 3 9 ; 3 8 89383 8 93 3 8=;9= = 393=3 3 8= 3 9 3 3 8 89 = =8 9 3 8=;9 3938 3 8= 3 9 ;; ;= 3 88 89 8 9 3 3 8=;9 8 393 3 8= 3 @= =??- 9 ;= 3 88 89; ;9; 8 ;9;8 8 393 8; " ! - 9 ;= 3 88 89 ;983 = ;9; 8 39= = C$!+! 9= = ;= 3 88 893 3 ;9=8 83 ;9;=3 3 398 $& 93 ;= 3 88 8938 ; ;9 = ;9; ; 39 8 93 ;= 3 88 89= ;988 == ;9 39 -+=A3;=> 9 ; 3 8 89; 3 ;98 3 = ;9; ; 393 33 3 = 3 9; 8 ; 3 89= 8 ;9= 3 = ;93 =3 39 8; 3 = 3 9 8; ; 3 ; 89 3 ;9= 3 = ;9= 3; 39 3 = 3 9= 8= 3 = 898 ;9 8 3 = ;9 8 ;; 9 3 = 3 9 8 3 8 8988 = ;9;8 3 = 98 ; 9;8 3 = 3 9 3 3 3 8988 ;98 8 3 = 9;3 93; == 3 = 3 -+=3;= 98 3 898 ;98 8 9 9 3 = 9 3 898= ;938 98 3; 98 = ;9 3 898; ; ;98 3 933 = 983 = ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: ;9 3 8983 83 ;9 8 9= 9== ;93 3 898 3 98 9 ; 93 ;9 3 89 =; 988 9; ; 9= ;9; 3 898 98 9= 83 9= ;9 3 89= ;= 9=8 3 93= 9 8 ; ;9= 3 89; 8 9 8 3 98 = 9 ; ;9 3 89 38 9;8 3; 9 8 9;; ; ;98 3 89 = 98 3= 9 ;8 9;;8 ;9 3 89 938 38 393 ; 9; 9 3 89=8 98 398 9 8 3 9 3 89== 3 9 8 3 39;3 3 93 3 93 3 89= 398 ; 39= 93= 9 3 89= ; 3988 39 =; = 933 9; 3 89=3 398 39;; 8 9= 9 3 89= = 39=8 398 9 9= 3 89 8 39 8 ; 393= 8 9 8 = 9 3 89 8 39;8 ; 393 9 ; 3 98 3 89 398 ; 398 = ; 88 9 3 89 ; 3 3938 ;= 39 3 = ; ; =9 3 89 3 = 398 ;8 9; ;8 ; =9 3 89 3 39 8 98 ; 8 8 == =93 3 89; ; 98 3 9=3 3 8 3 =9 3 89; 8; 988 ; 9= 3; = 8; =9; 3 89;= 3 98 = 9 8; 33 ;; =9 3 89;; == 9=8 9; = =9= 3 89; 9 8 9; = =3 =9 3 89; ;8 9;8 = 9= 8= 3 =98 3 89 8 98 = 933 8 ; 8 =9 3 898 938 = 98 ; ; ; 9 3 89= 3 98 = 9 ; == ;; 9 3 89 9 8 =8 = 8 ; ; 8 93 3 89 ; 8 8 9 3 89 88 3 83 ;3 = 9; 3 89 = 8 ; = ; 3=8 9 3 8938 =8 = = ; 3= 333 ; 9= 3 893 8 8 8 9 3 893 ;8 ;3= 3 3 98 3 893; 8 8 3 8= 9 3 8933 ;3 38 8 3; ; ; 3 89 3 893 8 8 8 8 8= ; 3 89 3 89 3; 8 8 = 8 ; 893 3 89 = = 3 ; ; 89 3 89= = = 8 8 ; 89; 3 89; ;8 3= 8 ;= 8 89 3 893 8 = = 38= ; 3 8 89= 3 89 ;= ; =3 3= 89 3 89 = ;=; 33 898 3 89 8 3 == 8 = ;3 89 3 89 = = =;3 8= ;3 8 9 3 89 ; 8= ; ; 8 3; 9 3 89 = = 83 3 == 93 3 89 9 = ; ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: 9 3 89 8 9= 3 8 ; ; 9; 3 8938 = 93= 9 88 3 = 9 3 893 9= 88 9 =8 3 9= 3 893 ;3 9;= 8= 93== ; 9 3 893 8 9 = 8; 9 ; = 98 3 8933 3; 9== 8 9;;; 83 = 9 3 893 == 9= 8 9 =; 8== 8 3 9 3 8938 98= 9=33 3 3 ; 3 9 3 8938 ;8 9= 9 8 8 3 93 3 8 8938 39 = 98 88 9 3 3 9 3 8 8938; 39= 988 = 9 ;8 = 3 9; 3 8 89383 3 393= 3 9 9 ; = 3 9 3 8 8938 39= 39 =8 9 ;8 3 9= 3 8 893 39;= =8 39 98; 3 9 3 8 893 = 39 = == 393;= 3= 93 3 98 3 8 893= 39== =; 39 ; 93 3 9 3 8 893; 39= = 39;3; ;3 93 39 3 8 893 3 398= = 39 ; 9== 39 3 8 893 = 39= 39= 3 9; 393 3 8 893 3 9 = 39= = 9; ; 39 3 8 893=8 ;; 9= 398 3 9 3 8 39; 3 8 893== 8 93= ; 398= 8 9 ;8 3 39 3 8 893= 3= 9= 3 39 8 88 9 = 39= 3 8 893= =8 9;= 9 ; 9= 39 3 8 893=3 9 = ;8 9 9=8; 398 3 8 893= 9== ;= 933= 93 39 3 8 893 8 3 9= ; 9 8 9 339 3 8 893 98= ; 9; ; 3 983 339 3 8 893 9= ; 9; 98== 3393 3 8 893 ; = ;9 = 9 83 ; 9 = 339 3 8 893 3 ;9= 9= ;8 9 339; 3 8 893 ;93= 9= 39 3 ; 339 3 8 893; ; ;9= ; 98; = 39 ; 88 339= 3 8 893; 8 ;9;= 3 98 39 339 3 8 893;= 3 ;9 = ;9 3 8 398 3 3398 3 8 893;; =; ;9== 38 ;9= 8 398; ; 339 3 8 893; = ;9= 3= ;93 3933 39 3 8 893; ; ;98= 3 ;93 393; 39 3 8 893 88 ;9= 3 ;98; 8 393 ; 393 3 8 8938 9 = 3 ;9; 39= 8; 39 3 8 893= 9= ;9 =3 33 39; 3= 39; 3 8 893 93= ;9= 39; = =8 39 3 8 893 ; 9= = ;9; 39 3 39= 3 8 893 = 9;= ; ;983 ;; 39 ; 39 3 8 893 9 = 3 ;98 3 39 3 = 398 3 8 89338 9== 9 39=8 8 398= 3 8 8933 8 9= 9 3 39=3 >= @A=- 39 3 8 8933 3 9= 8 9 = == 39=8 8 3;9 3 8 8933 = 98= 98 ; 393 3 3;9 3 8 8933; 9= 93; 8 39; == 3;93 3 8 89333 ;; =9 = 9= 88 3983 8 ! ! + ! , - !"# $%& ' ( )*+* ,% .- , - . /* * 0.12 / !"# $%& ' ( )*+* ,% - , 2 / 0 '& , !3 4, ' ! **5'5-','*)/ * ! % % 16 - !1 * - 8* ,: $ !! 89: "(!* 89: 657% 8* ,: .! ! 8* ,: - 1 1 897* ,: 6&7 8* ,: <*! 897* ,: * 897* ,: *)/ .! - 8* ,: 3;9 3 8 8933 8= =9= 9; 3 = 398= 3;9; 3 8 893 3 =93 9 ;3 39 ; 3;9 3 8 893 = =9 8 9= 39 = = 3;9= 3 8 893= =9; = 93 8 9 3;9 3 8 893; 3 =9 ; 98 3 9 ; 3 3;98 3 8 8933 =9= 3 988 3 9 3 =; 3;9 3 8 893 =9 98 ; 98 = 3 9 3 8 893 = =98 8 =9 = ; 98 ; 3 9 3 8 893 8 =9 8 =9= ; 9338 3 93 3 8 893 = 9 8 =93 ; = 93; ; 3 9 3 8 893 9 8 =9; = 9 = 3 9= 3 8 893 8 93 83 =9; 8 9 ; 3 ->A=?7C * ! +! 1& !7! 1 .- 8* ,: & !1 8* ,: 5 !1 8* ,: 6&7 8* ,: 657% 8* ,: - !11 + 1!*+!* -! 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, -%&%% /1 - 3 '# %-, - 2 4&%% 1 1 -%&%% / , / -2+ $ 5 0// + , /3- 7$2,,$./, - % 4'% '%% '% $%%% % B%% $4%% $A%% 4=%% %%% B%% 5 + ) 55 $=@ $=@ $= >% $=@ $=@ $= >% %A@ %A"$@ %A"$ >% %A@ %A@ %A >% %@ %@ % >% %$@ %$"$@ %$"$ >% %4@ %4@ %4 >% %@ %@ % >% =@ =@ = 7% >% =@ =@ = >% %=@ (4 %=@ %= >% %@ %@ % >% %B@ %B@ %B >% %B@ %B"$@ %B"$ >% '@ '@ ' >% @ @ >% $%@ $%@ $% 7%= >% $$@ $$@ $$ >% %$@ %$@ %$ >% A@ A@ A >% B@ B@ B >% %'@ %'@ %' >% @ @ >% %B@ %B@ %B >% ) 2 ( 2 + 5 3 9 5 : $A@ C = (5 31 / 9 $&'D 5 $'%D %E %&%%% 0// + 3 0// + / + 3 !" #$%%&' () * &% +,- . $ 5 31 @ , / @ 2 +) %, - - !" #$%%&' () * &% +,- . $&'% / #01 23- $./, - 0- !" #$%%&' () * &% +,- . $&'% / #01 23- #/, -(4 563 5, - ! , -%&%% /1 - 3 '# %-, - 2 4&%% 1 1 -%&%% / , / -2+ $ 5 0// + , /3- 7$2,,$./, - %&%% &%% B&%% &%% , % B'% $%% $'% 4B%% 4'% 5 + 0 +1 5 0 , $=@ $=@ $= >% $=@ $=@ $= >% %A@ %A"$@ %A"$ >% %A@ %A@ %A >% %@ %@ % >% %$@ %$"$@ %$"$ >% %4@ %4@ %4 >% %@ %@ % >% =@ =@ = 7% >% =@ =@ = >% %=@ (4 %=@ %= >% %@ %@ % >% %B@ %B@ %B >% %B@ %B"$@ %B"$ >% '@ '@ ' >% @ @ >% $%@ $%@ $% 7%= >% $$@ $$@ $$ >% %$@ %$@ %$ >% A@ A@ A >% B@ B@ B >% %'@ %'@ %' >% @ @ >% %B@ %B@ %B >% ) 2 ( 2 + 5 3 9 5 : $A@ C = (5 31 / 9 $&'D 5 $'%D %E %&%%% 0// + 3 0// + / + 3 !" #$%%&' () * &% +,- . $ 5 31 @ , / @ 2 1 Dewhurst, Andrew D (OGC) From:Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent:Friday, October 20, 2023 10:00 To:Dewhurst, Andrew D (OGC) Cc:Hobbs, Greg S; Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMTU MT7-93 (PTD 223-099): Question MorningAndy, 10.0ppgisthecurrentboƩompressureofoīsetinjector,subsurfaceteamdon’tbelievewewillseethispressurein MT7Ͳ93unlessthereisadirectconduitwhichtheythinkitisunlikelybutdon’twanttoruleitoutduetothecomplexity ofGMT2.Inanotherword,10.0ppgisunlikelybutcanbemaxabsolutePP.Themainreason10.0ppginthepermitisto calculatethemaxpredictablesurfacepressuretoensureallthesurfaceequipmentratedfortheworstͲcasescenario. ManagedPressureDrilling(MPD)isdeployedwhendrillingproducƟonsecƟon,weplantostartwiththemudproposed inthepermitandadjustbasedonwhatwesee. Ihopethisclarifythings,pleasefeelfreetocontactmeiffurtherdiscussionisneeded.Thanksandhaveagreat weekend. WeifengDai ConocoPhillipsAlaska StaīDrillingEngineer Desk:907Ͳ265Ͳ6936 Cell:907Ͳ346Ͳ0324 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Friday,October20,20238:34AM To:Dai,Weifeng<Weifeng.Dai@conocophillips.com> Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:[EXTERNAL]GMTUMT7Ͳ93(PTD223Ͳ099):Question Weifeng, IalsohaveoneotherquesƟonregardingtheexpectedporepressures. Onpage9,theexpectedporepressureatTDisreportedtobe4266psi.Thisequatestoa0.520psi/Ōgradientand ~10ppgEMW.ThatishigherthanothernearbywellsandthemudweightsproposedfortheproducƟonhole(9.0Ͳ9.5ppg EMW). WouldyoupleaseconĮrmthisvalueandyourproposedmudweights? Thanks, Andy 1 Dewhurst, Andrew D (OGC) From:Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent:Friday, October 20, 2023 13:45 To:Dewhurst, Andrew D (OGC) Cc:Hobbs, Greg S; Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMTU MT7-93 (PTD223-099): Question Attachments:MT7-93_wp13 NAD27.txt; MT7-93_wp13 MIA NAD27.txt; MT7-93 wp13 SPR Geo NAD27.pdf Andy, PleaseĮndaƩachedMT7Ͳ93wp13inNAD27,letmeknowifthisiswhatyouarelookingfor.AnyquesƟons,pleasereach out.Thankyouandhaveagreatweekend. WeifengDai ConocoPhillipsAlaska StaīDrillingEngineer Desk:907Ͳ265Ͳ6936 Cell:907Ͳ346Ͳ0324 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Thursday,October19,20234:25PM To:Dai,Weifeng<Weifeng.Dai@conocophillips.com> Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:[EXTERNAL]GMTUMT7Ͳ93(PTD223Ͳ099):Question Weifeng, ThedirecƟonalplanwasreceived. I’mgeƫngadiscrepancybetweenthegovernmentalsecƟonsandthereportedeasƟngandnorthingfortheSHL. x WouldyoupleasereͲsend(1)theeasƟngandnorthingand(2)lat/longfortheSHLinNAD27AKStatePlane? ItlookslikethedirecƟonalplan(p.22anon)isusingNAD83datum.Itwouldbehelpful,butnotnecessarytoalsoseethe direcƟonalplaninNAD27. Thanks, Andy From:Dai,Weifeng<Weifeng.Dai@conocophillips.com> Sent:Thursday,October19,202315:03 To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:RE:[EXTERNAL]GMTUMT7Ͳ93:DirectionalPlan GoodaŌernoonAndy, PleaseĮndtheaƩached. WeifengDai 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 ConocoPhillipsAlaska StaīDrillingEngineer Desk:907Ͳ265Ͳ6936 Cell:907Ͳ346Ͳ0324 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Thursday,October19,20233:01PM To:Dai,Weifeng<Weifeng.Dai@conocophillips.com> Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:[EXTERNAL]GMTUMT7Ͳ93:DirectionalPlan 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. Weifeng, WouldyoupleasesendoveracopyofthedirecƟonalplanforGMTUMT7Ͳ93(wp13)inExcelortextformat?Minimum dataneededisMD,InclinaƟon,andAzimuth. Thankyou, Andy AndrewDewhurst SeniorPetroleumGeologist AlaskaOilandGasConservaƟonCommission 333W.7thAve,Anchorage,AK99501 andrew.dewhurst@alaska.gov Direct:(907)793Ͳ1254 Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. X GMTU MT7-93 GRTR MOOSES TOOTH 223-099 RENDEZVOUS OIL POOL W E L L P E R M I T C H E C K L I S T Co m p a n y Co n o c o P h i l l i p s A l a s k a , I n c . 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A ) , ( j . 2 . A - D ) Ye s 80 ' c o n d u c t o r d r i v e n 18 Co n d u c t o r s t r i n g p r o v i d e d Ye s SC s e t a t 4 1 9 8 ' M D 19 Su r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s 64 % e x c e s s p l a n n e d 20 CM T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g No 21 CM T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s Pr o d u c t i v e i n t e r v a l w i l l b e c o m p l e t e d w i t h u n c e m e n t e d l i n e r 22 CM T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 23 Ca s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s Ri g h a s s t e e l t a n k s ; a l l w a s t e t o a p p r o v e d d i s p o s a l w e l l s 24 Ad e q u a t e t a n k a g e o r r e s e r v e p i t NA 25 If a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s An t i - c o l l i s i o n a n a l y s i s c o m p l e t e ; n o m a j o r r i s k f a i l u r e s 26 Ad e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d Ye s Di v e r t e r v a r i a n c e a p p r o v e d p e r 2 0 A A C 2 5 . 0 3 5 ( h ) ( 2 ) 27 If d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s Ma x r e s e r v o i r p r e s s u r e i s 4 2 6 6 p s i g ( 9 . 9 p p g E M W ) ; w i l l d r i l l w / 8 . 8 t o 1 3 p p g E M W u t i l i z i n g M P D 28 Dr i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s 29 BO P E s , d o t h e y m e e t r e g u l a t i o n Ye s MP S P i s 3 4 4 6 p s i g ; w i l l t e s t B O P s t o 5 0 0 0 p s i g i n i t i a l l y a n d 3 5 0 0 p s i g s u b s e q u e n t l y 30 BO P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s 31 Ch o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 Wo r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n No 33 Is p r e s e n c e o f H 2 S g a s p r o b a b l e NA 34 Me c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) Ye s H2 S n o t e x p e c t e d 35 Pe r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s Ma x a n t i c i p a t e d p o r e p r e s s u r e i s 1 0 p p g E M W d u e t o o f f s e t i n j e c t i o n i n t a r g e t r e s e r v o i r . M P D t o b e e m p l o y e d . 36 Da t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 Se i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 Se a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 Co n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 10 / 2 0 / 2 0 2 3 Ap p r VT L Da t e 10 / 3 0 / 2 0 2 3 Ap p r AD D Da t e 10 / 2 0 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *& :
