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DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : GR , R E S , 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 6/ 7 / 2 0 2 4 13 6 1 9 4 1 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 - 91 _ C O M P _ M E M . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 13 6 1 9 4 1 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 - 91 _ C O M P _ M E M _ F u l l H e a d e r . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 1 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 2 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 3 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 4 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 5 _ C l e a n o u t . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 6 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 7 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ A P - L O G _ M E M _ R u n 8 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 13 5 1 9 4 1 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 91 _ V S S - D E P T H _ C O M P _ M E M . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 1 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 2 . l a s 38 8 7 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 1 o f 1 0 CP A I _ M T 7 - , 91_ CO MP _ M E M _ F u l l H e a d e r . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 3 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 4 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 5 _ C l e a n o u t . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 6 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 7 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ V S S - T I M E _ M E M _ R u n 8 . l a s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 1 _ 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 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 1 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 2 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 3 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 4 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 5 _ C l e a n o u t . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 6 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 7 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - L O G _ M E M _ Ru n 8 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 1 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 2 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 3 . a s c 38 8 7 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 2 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 4 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 5 _ C l e a n o u t . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 6 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 7 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M _ R u n 8 . a s c 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ P R O C E S S E D _ L T K _ I M A G E _ 1 _ 2 4 0 _ Ru n 7 . d l i s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ P R O C E S S E D _ L T K _ I M A G E _ 1 _ 2 4 0 _ Ru n 7 . m e t a 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ P R O C E S S E D _ L T K _ I M A G E _ 1 _ 2 4 0 _ Ru n 7 . P D F 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ P R O C E S S E D _ L T K _ I M A G E _ 1 _ 2 4 0 _ Ru n 8 . m e t a 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ P R O C E S S E D _ L T K _ I M A G E _ 1 _ 2 4 0 _ Ru n 8 . P D F 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ P R O C E S S E D _ L T K _ I M A G E _ R U N _ 8 . d l i s 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 2 M D _ C O M P _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 2 T V D _ C O M P _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ C O M P _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 T V D _ C O M P _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - TI M E _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 3 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 6/ 7 / 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 1 _ V S S - DE P T H _ C O M P _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M . c g m 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 2 M D _ C O M P _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 2 T V D _ C O M P _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 M D _ C O M P _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 - 91 _ 5 T V D _ C O M P _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ A P - TI M E _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - DE P T H _ C O M P _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 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 1 _ V S S - TI M E _ M E M . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 1 D e f i n i t i v e S u r v e y R e p o r t NA D 2 7 . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 1 D e f i n i t i v e S u r v e y R e p o r t NA D 2 7 . t x t 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 1 D e f i n i t i v e S u r v e y R e p o r t NA D 8 3 . p d f 38 8 7 8 ED Di g i t a l D a t a DF 6/ 7 / 2 0 2 4 E l e c t r o n i c F i l e : M T 7 - 9 1 D e f i n i t i v e S u r v e y R e p o r t NA D 8 3 . t x t 38 8 7 8 ED Di g i t a l D a t a DF 8/ 7 / 2 0 2 4 39 2 0 1 1 4 1 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 - 91 _ T O C _ L A S _ R M . l a s 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ 1 0 0 0 M D _ R M . p d f 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ 2 0 0 0 M D _ R M . p d f 39 3 6 2 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 4 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 8/ 7 / 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 - 91 _ T O C _ 2 0 0 M D _ R M . p d f 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ 4 0 0 0 M D _ R M . p d f 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ 4 0 0 0 M D _ R M _ L a b e l e d . p d f 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ 5 0 0 M D _ R M . p d f 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ 6 0 0 0 M D _ R M . p d f 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ D L I S _ R M . d l i s 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 - 91 _ T O C _ D L I S _ R M . h t m l 39 3 6 2 ED Di g i t a l D a t a DF 8/ 7 / 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 _ 9 1 _ S o n i c S c op e 4 7 5 _ R M _ T O C _ 1 0 3 0 0 f t _ 1 1 3 9 2 f t M D _ P P T . p p t x 39 3 6 2 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 6 9 2 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 0 8U p . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 6 9 2 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 0 9D o w n . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 8 9 2 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 2 Up . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 8 9 2 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 3 Do w n . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 11 3 2 8 1 9 3 7 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 4 2 4 0 B W P D _ 6 0 F P M _ C o n Cu _ R 0 1 _ L 0 1 3 U p . l a s 39 9 0 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 5 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 1/ 3 / 2 0 2 5 89 4 7 9 2 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 4 Up . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 7 9 2 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 5 Do w n . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 8 9 2 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 6 Up . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 89 4 8 9 2 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 7 Do w n . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 11 3 7 0 1 9 3 7 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 8 5 1 5 B W P D _ 6 0 F P M _ C o n Cu _ R 0 1 _ L 0 1 1 U p . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 11 3 5 8 1 9 3 7 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ S h u t - In _ 1 H r _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 1 5 U p . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 11 2 2 9 1 9 3 8 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ S h u t - In _ 8 H r _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 1 7 U p . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 11 3 5 8 1 9 3 5 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ T r a c t o r i n g _ 4 2 4 0 B W P D _ C on C u _ R 0 1 _ L 0 1 2 D o w n . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 91 2 6 1 9 3 6 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 - 91 _ I P R O F _ 2 9 D E C 2 4 _ T r a c t o r i n g _ 8 5 1 5 B W P D _ C on C u _ R 0 1 _ L 0 1 0 D o w n . l a s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 0 8U p . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 0 9D o w n . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 2 Up . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 3 Do w n . d l i s 39 9 0 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 6 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 4 2 4 0 B W P D _ 6 0 F P M _ C o n Cu _ R 0 1 _ L 0 1 3 U p . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 4 Up . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 5 Do w n . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 6 Up . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 7 Do w n . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ 8 5 1 5 B W P D _ 6 0 F P M _ C o n Cu _ R 0 1 _ L 0 1 1 U p . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ S h u t - In _ 1 H r _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 1 5 U p . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ S h u t - In _ 8 H r _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 1 7 U p . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ T r a c t o r i n g _ 4 2 4 0 B W P D _ C on C u _ R 0 1 _ L 0 1 2 D o w n . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ T r a c t o r i n g _ 8 5 1 5 B W P D _ C on C u _ R 0 1 _ L 0 1 0 D o w n . d l i s 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 / 2 0 2 5 E l e c t r o n i c F i l e : C P A I _ M T 7 - 91 _ I P R O F _ 2 9 D E C 2 4 _ F i e l d P r i n t . P d f 39 9 0 8 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 12 9 2 1 1 2 0 2 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 : M T 7 - 9 1 _ 2 5 - J a n - 25 _ M a i n U p P a s s . l a s 40 0 3 8 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 2 0 2 5 - 0 1 - 2 5 _ 2 1 1 8 9 _ G M T U _ M T 7 - 91 _ C o i l F l a g _ T r a n s m i t t a l . d o c x 40 0 3 8 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U _ M T 7 - 9 1 _ 2 5 - J a n - 25 _ C o i l F l a g . p d f 40 0 3 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 7 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U _ M T 7 - 9 1 _ 2 5 - J a n - 25 _ C o i l F l a g . t i f 40 0 3 8 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 11 1 1 6 1 4 3 8 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 : M T 7 - 91 _ M F C 4 0 _ 2 6 J a n 2 0 2 5 _ P r o c e s s e d D a t a . l a s 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 2 0 2 5 - 0 1 - 2 6 _ 2 2 6 3 7 _ G M T U _ M T 7 - 91 _ C a l i p e r S u r v e y _ L o g D a t a _ T r a n s m i t t a l . d o c x 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 91 _ M F C _ 2 6 J a n 2 0 2 5 _ I n t e g r i t y R e p o r t . p d f 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : a u t o r u n . c d d 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 0 _ 1 3 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 1 _ 9 7 8 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 3 _ 1 7 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 3 _ 9 7 8 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 7 _ 1 3 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 8 _ 1 7 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 1 9 _ 1 3 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 3 0 _ 1 3 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 3 1 _ 1 3 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 3 _ 1 6 4 4 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 4 _ 1 3 3 9 . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : g r e y _ p i l l . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : g r e y _ r o u n d e d . b t n 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : 6 3 0 B 0 9 4 0 . j p g 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : I R D i s s o l v e T r a n s i t i o n . t n s 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : I R S l i d e T r a n s i t i o n . t n s 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : I R W i p e T r a n s i t i o n s . t n s 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U _ M T 7 - 9 1 _ 2 5 - J a n - 25 _ C a l i p e r S u r v e y L o g . p d f 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : G M T U _ M T 7 - 9 1 _ 2 5 - J a n - 25 _ C a l i p e r S u r v e y L o g . t i f 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 9 1 2 0 2 5 - 0 1 - 2 6 4 . 5 ' ' T u b i n g an d L i n e r . I D X 40 0 3 9 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 8 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l 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 : 6 / 2 / 2 0 2 4 Re l e a s e D a t e : 3/ 2 8 / 2 0 2 4 DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 9 1 2 0 2 5 - 0 1 - 2 6 4 . 5 ' ' T u b i n g an d L i n e r . R G B 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 9 1 2 0 2 5 - 0 1 - 2 6 4 . 5 ' ' T u b i n g an d L i n e r . s r v 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : M T 7 - 9 1 2 0 2 5 - 0 1 - 2 6 4 . 5 ' ' T u b i n g an d L i n e r . U N W 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : P D S V i e w e r . i c o 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : S a m p l e D a t a . I D X 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : S a m p l e D a t a . r g b 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : S a m p l e D a t a . U N W 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : P D S 3 - D C a l i p e r D a t a V i e w e r He l p . d o c 40 0 3 9 ED Di g i t a l D a t a DF 1/ 3 0 / 2 0 2 5 E l e c t r o n i c F i l e : P D S 3 - D C a l i p e r D a t a V i e w e r He l p . p d f 40 0 3 9 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 9 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 8 1 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 9 1 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 6/ 2 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 2 0 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 19 4 1 8 TV D 84 5 4 Cu r r e n t S t a t u s WA G I N 1/ 2 1 / 2 0 2 6 UI C Ye s 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 : We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 1 0 o f 1 0 1/ 2 2 / 2 0 2 6 M. G u h l C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-26_22637_GMTU_MT7-91_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22637 GMTU MT7-91 50-103-20881-00 Caliper Survey w/ Log Data 26-Jan-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-020 T40039 1/30/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.30 15:16:06 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-25_21189_GMTU_MT7-91_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21189 GMTU MT7-91 50-103-20881-00 Coil Flag 25-Jan-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-020 T40038 1/30/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.30 09:48:02 -09'00' Originated: Delivered to:2-Jan-25 Alaska Oil & Gas Conservation Commiss 02Jan25-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24 1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24 1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39899 T39900 T39901 T39902 T39901 T39903 T39904 T39905 T39906 T39907T39908 T39909 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.03 08:13:20 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT7-91 GMTU MT7-91 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 MT7-91 50-103-20881-00-00 224-020-0 W SPT 8230 2240200 2058 0 0 0 0 225 230 230 230 INITAL P Kam StJohn 7/27/2024 Initial MITIA for new injector 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:GMTU MT7-91 Inspection Date: Tubing OA Packer Depth 860 2400 2340 2320IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240728120447 BBL Pumped:4 BBL Returned:3.9 Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 99 9 9 9 new injector James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 15:37:52 -08'00' t >>ED W/η ^ Zs/ KZ Z η&/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' K>KZ WZ/Ed^ ͲĞůŝǀĞƌLJ 1H-112PH1 50-029-23787-00-00 224-031 KUPARUK RIVER MEMORY Top of Cement PROCESSED 5-Jun-24 1 1H-120PH1 50-029-23794-00-00 224-080 KUPARUK RIVER MEMORY Top of Cement PROCESSED 14-Jul-24 1 GMTU MT7-91 50-103-20881-00-00 224-020 EATER MOOSES TOO MEMORY Top of Cement PROCESSED 11-May-24 1 GMTU MT7-15 50-103-20885-00-00 224-037 EATER MOOSES TOO MEMORY Top of Cement PROCESSED 2-Jul-24 1 3S-626PB1 50-103-20878-70-00 224-007 KUPARUK RIVER MWD/LWD/DD VISION Service FINAL FIELD 20-May-24 1 dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚ ͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ WƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞ WůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘ sdƵŽŶŐΛƐůď͘ĐŽŵ ^>ƵĚŝƚŽƌͲ dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĂŶĚƚŚĞĐŽŶƚĞŶƚƐŽĨƚŚĞƉĂĐŬĂŐĞ ŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐ ĐŽŶƚĞŶƚŽĨƚŚĞƐĂŶĚͬŽƌŚĂƌĚĐŽƉLJƉƌŝŶƚƐŵĂLJŽƌŵĂLJŶŽƚŚĂǀĞďĞĞŶ ǀĞƌŝĨŝĞĚĨŽƌĐŽƌƌĞĐƚŶĞƐƐŽƌƋƵĂůŝƚLJůĞǀĞůĂƚƚŚŝƐƉŽŝŶƚ͘ η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ T39360 T39361 T39362 T39363 T39364 GMTU MT7-91 50-103-20881-00-00 224-020 EATER MOOSES TOO MEMORY Top of Cement PROCESSED 11-May-24 1 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.07 08:39:15 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:4803' FSL, 1247' FEL S32 T10N R2E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 100.7 BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI:x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth:x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20"H-40 134' 13-3/8 L-80 3051' 9-5/8"T-95 7117' 7-5/8"P110 8266' 4 1/2"P110-S 8454' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27. Date First Production:Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 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: 67 ppg 15.8ppg Class G8.5"x9-7/8" TUBING RECORD 19418' Lead:71 bbl 13.0ppg Class G Tail: 115.1bbl 15.8ppg Class G 8230' 12-1/4" 6-1/2" 11255'4.5"11199'MD/8216'TVD 11249'MD/8230'TVD BOTTOM 16"Lead: 393bbl 11.0ppg Blend Tail: 70bbl 15.8 Class G CASING 50-103-20881-00-00 GMT MT7-91 4/17/2024 19418'MD/8454'TVD N/A 154.8 P.O.Box 100360, Anchorage, AK 99510-0360 290186 1101' FSL, 3175' FEL S32 T10N R2E 3085' FSL, 2979' FEL S4 T9N R2E 5/25/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 6/2/2024 224-020 998'MD/996'TVD SETTING DEPTH TVD 5912472 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER PACKER SET (MD/TVD) 11249' 42" 12.6 5915917 Greater Mooses Tooth/Rendezvous AA081800, AA081781, AA098885, AA092341 932535000, 932516000 0 33.7 0 9197' 3542' 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 292204 295579 CEMENTING RECORD 5919564 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner ( 5/29/2024): 11249'MD/8230'TVD - 19418'MD/8454'TVD Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A 0 0 Per 20 AAC 25.283 (i)(2) attach electronic information 47 11388' 0 6975' 94 68 80' 0 9360' SIZE DEPTH SET (MD) 10 Yards Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl:Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: Flow Tubing W d 1b 0 D p op and B om; Perf L s ((atta Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 3:26 pm, Jun 28, 2024 Completed 6/2/2024 JSB RBDMS JSB 070224 GDSR-7/9/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 998 996 C-30 1448 1437 2112 2045 3489 3017 K-2 4046 3364 Albian 97 4496 3643 Albian 96 4790 3827 HRZ 9274 7043 Kalubik 9573 7294 Kuparuk C 9916 7559 9922 7563 11558 8297 19418 8454 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. N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Weifeng Dai DN: O=ConocoPhillips, CN=Weifeng Dai, E=weifeng.dai@cop.com Reason: I am the author of this document Location: Date: 2024.06.28 13:10:04-08'00' Foxit PDF Editor Version: 13.0.0Weifeng Dai Page 1/54 MT7-91 Report Printed: 6/25/2024 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) 4/7/2024 00:00 4/7/2024 06:00 6.00 MIRU, MOVE MOB P PJSM. Continue cleaning rig floor drip pan, rotary table and flow line. Secure mousehole in derrick for transport. Remove all oily waste from rig floor. Continue cleaning mud pits and suction lines. SIMOPS: Fill cellar box with 40 bbls hot water to melt ice and pump out same. 0.0 0.0 4/7/2024 06:00 4/7/2024 10:00 4.00 MIRU, MOVE MOB P Blow down mud lines, mud manifold, MPD line, mud pumps, charge pump suctions, hole fill line and jet line. Continue cleaning mud pits and CPU tank. Assist Sure Point and Magtec disconnect and blow down transfer lines. 0.0 0.0 4/7/2024 10:00 4/7/2024 17:00 7.00 MIRU, MOVE MOB P Working on Rig Floor, BOP and Pump Room modules disconnecting inner connects (MPD line, HP mud line, cement line). Clean and inspect mud pumps suction and discharge manifolds. Assist Magtec R/D transfer lines and heat trace. Remove berming around Magtec equipment. Continue thawing ice out of cellar box. Blow down H2O lines to Drill Floor, Pipe Shed, Pits and CPU. Empty and clean out CPU. Remove Geronimo line. Lubricate rig floor skid rails. 0.0 0.0 4/7/2024 17:00 4/8/2024 00:00 7.00 MIRU, MOVE MOB P Start cold starts around rig. Unplugging modules. Prepare pipe shed to move. Patch leaking weld in cellar box floor plate. Removing berms around rig. Lift all stairs around rig. Disconnect steam, air and water lines in all interconnects. Move mats and equipment from around rig and prepare to stomp modules away. Move Site Control and Smoke shack trailer. R/D portable power from each. 0.0 0.0 4/8/2024 00:00 4/8/2024 02:00 2.00 MIRU, MOVE MOB P Prepare to move CPU, Power and Pump modules. R/D berming containment around exterior of rig. Take on water to hot well. 0.0 0.0 4/8/2024 02:00 4/8/2024 06:00 4.00 MIRU, MOVE MOB P Stomp CPU away from Pits, in position for truck. Stomp Power module away from Pits and pin tires. In position for truck. Stomp Pump module away from Pits and pin tires. In position for truck. Stomp Pits away from Sub. 0.0 0.0 4/8/2024 06:00 4/8/2024 07:00 1.00 MIRU, MOVE MOB P Move Motor module from Titan ice pad down ice road to T1 staging area (7 miles) close to gravel road. SIMOPS: PJSM, Stomp pipe shed away from Sub. 0.0 0.0 4/8/2024 07:00 4/8/2024 08:30 1.50 MIRU, MOVE MOB P PJSM. Skid rig floor to move position and secure. SIMOPS: Pick up herculite, clearing pad of debris. 0.0 0.0 4/8/2024 08:30 4/8/2024 11:00 2.50 MIRU, MOVE MOB P PJSM. Unpin BOP module from Sub. Raise out riggers and lower BOP module. Remove all lumber from cellar area and clear outside cellar of debris. 0.0 0.0 4/8/2024 11:00 4/8/2024 12:00 1.00 MIRU, MOVE MOB P PJSM. Prepare Sub to move. 0.0 0.0 4/8/2024 12:00 4/8/2024 15:30 3.50 MIRU, MOVE MOB P Hook up boiler room and cpu and stage on ice pad 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 2/54 MT7-91 Report Printed: 6/25/2024 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) 4/8/2024 15:30 4/8/2024 17:00 1.50 MIRU, MOVE MOB P Hook pits up and stage on ice pad 0.0 0.0 4/8/2024 17:00 4/8/2024 18:00 1.00 MIRU, MOVE MOB P Reposition the Sub-base module away from other modules 0.0 0.0 4/8/2024 18:00 4/8/2024 22:00 4.00 MIRU, MOVE MOB P Hook up pipe shed module and stage on ice pad 0.0 0.0 4/8/2024 22:00 4/9/2024 00:00 2.00 MIRU, MOVE MOB P Hook up BOP module and stage on ice pad, Position sub-base module to move 0.0 0.0 4/9/2024 00:00 4/9/2024 06:00 6.00 MIRU, MOVE MOB P Prepare Sub Module for move from Titan 1 to T1 Staging Pad. Simops: Continue Cleaning up around the Titan 1 Pad: Rig Mats and Herculite. Prepare and Secure Dunnage for transport. Prepare and band up miscellaneous equipment and subs around pad. 0.0 0.0 4/9/2024 06:00 4/9/2024 12:00 6.00 MIRU, MOVE MOB P Move Sub Module from Titan 1 to T1 Staging Pad. Simops: Continue loading out trucks with materials and equipment. 0.0 0.0 4/9/2024 12:00 4/9/2024 18:00 6.00 MIRU, MOVE MOB P Continue Moving Sub Module from Titan 1 to T1 Staging Pad. 0.0 0.0 4/9/2024 18:00 4/10/2024 00:00 6.00 MIRU, MOVE MOB X Prepare Rig Modules for Rig Move. Clean snow off stompers on all modules. Fuel Modules. Service moving equipment on rig. 0.0 0.0 4/10/2024 00:00 4/10/2024 06:00 6.00 MIRU, MOVE MOB X Transferred crews luggage to Doyon Camp 5. Cleaned & organized modules. Changed out pop off on #2 mud pump. Inspected hydraulic equipment on modules hourly. Fueled generators and heaters as needed. 0.0 0.0 4/10/2024 06:00 4/10/2024 12:00 6.00 MIRU, MOVE MOB X Cleaned & organized modules. Inspected hydraulic equipment on modules hourly. Fueled generators and heaters as needed. Assisted with cleaning out Doyon Camp 1. Loaded out equipment from Titan ice pad. 0.0 0.0 4/10/2024 12:00 4/10/2024 18:00 6.00 MIRU, MOVE MOB X Changed tire on Doyon Camp1. Cleaned & organized. Fueled generators & heaters. Performed maintenance on agitators in the pits. Sealed hatches on mud pumps. 0.0 0.0 4/10/2024 18:00 4/11/2024 00:00 6.00 MIRU, MOVE MOB X Changed tire on Doyon Camp1. Cleaned & organized. Fueled generators & heaters. Performed maintenance on agitators in the pits. Sealed hatches on mud pumps. 0.0 0.0 4/11/2024 00:00 4/11/2024 12:00 12.00 MIRU, MOVE MOB X Moved material & misc equipment from Titan 1 ice pad to MT7. Cleaned walls in modules. Inspected hydraulic equipment hourly. Fueled generators & heaters as needed. Worked on MP2s. 0.0 0.0 4/11/2024 12:00 4/12/2024 00:00 12.00 MIRU, MOVE MOB X Blew down Doyon Camp 5 water system. Prepped camp for move. Cleaned up Herculite liner where camp was. Removed & sent all mud pump pop offs to rig shop for rebuild. Inspected hydraulic equipment hourly. Fueled generators & heaters as needed. Worked on MP2s. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 3/54 MT7-91 Report Printed: 6/25/2024 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) 4/12/2024 00:00 4/12/2024 12:00 12.00 MIRU, MOVE MOB X Inspected hydraulic equipment hourly. Fueled generators and air heaters as needed. Worked on MP2S. Changed out drillers & off drillers sided man rider winch cables. 0.0 0.0 4/12/2024 12:00 4/12/2024 19:45 7.75 MIRU, MOVE MOB X Installed pop off on mud pump #4. Worked on MP2s. Cleaned & organized around the modules. Mobilized trucks & hooked up to modules. Prepped to begin move. 0.0 0.0 4/12/2024 19:45 4/13/2024 00:00 4.25 MIRU, MOVE MOB P Moved 17 miles from T1 pad staging area to MT7 with the motor, pump, pits, CPU, & BOP modules. SIMOPS laid mats & Herculite for foot print over MT7- 91. 0.0 0.0 4/13/2024 00:00 4/13/2024 07:00 7.00 MIRU, MOVE MOB P Centered & leveled BOP module over MT7-91 conductor. Laid herculite and mats. 0.0 0.0 4/13/2024 07:00 4/13/2024 08:30 1.50 MIRU, MOVE MOB P Hooked up pipe shed to truck. Positioned pipe shed to move off of T1 ice staging pad. Prepped for move to MT7. 0.0 0.0 4/13/2024 08:30 4/13/2024 21:00 12.50 MIRU, MOVE MOB P Moved sub module & pipe shed from T1 ice staging pad 17 miles to MT7. 0.0 0.0 4/13/2024 21:00 4/13/2024 22:30 1.50 MIRU, MOVE MOB P Positioned sub to back up to BOP module. 0.0 0.0 4/13/2024 22:30 4/14/2024 00:00 1.50 MIRU, MOVE MOB P Aligned sub into pinning position with the BOP module. 0.0 0.0 4/14/2024 00:00 4/14/2024 03:00 3.00 MIRU, MOVE MOB P Positioned sub with the BOP module & shimmed to level both. 0.0 0.0 4/14/2024 03:00 4/14/2024 04:30 1.50 MIRU, MOVE MOB P Skidded rig floor over into drill position. Walked the pipe shed to mate up with the sub. 0.0 0.0 4/14/2024 04:30 4/14/2024 06:00 1.50 MIRU, MOVE MOB T Attempted to spot pits to the sub. Rig move truck blew the transmission. Unhooked the truck and towed it away. Hooked up another rig move truck that quit working. Mechanic mobilized and fixed truck. 0.0 0.0 4/14/2024 06:00 4/14/2024 12:00 6.00 MIRU, MOVE MOB P Positioned pits, pump module, CPU, & motor module into place. SIMOPS plug in electrical connections & started hooking up interconnects. 0.0 0.0 4/14/2024 12:00 4/15/2024 00:00 12.00 MIRU, MOVE MOB P Continued working on rig acceptance checklist. Finished hooking up interconnects. Energized steam, water & air throughout the rig. Finished with electrical connections & swapped to generator power at 15:30hrs. Mobilized Baker directional equipment to rig floor and assisted with rig up as needed. Changed out saver sub from 4-1/2" to 5- 7/8", along with grabber blocks & bell guide.Functioned auger in the pits & verified safety stops. SIMOPS moved shops and parts trailers from Titan 1 to MT7. Cleaned up Titan pad. Laid mats for shops & parts trailers. Spotted shops & trailers on MT7. Continue unloading equipment from trucks. Loaded 99 joints of 5-7/8" drill pipe into the pipe shed. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 4/54 MT7-91 Report Printed: 6/25/2024 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) 4/15/2024 00:00 4/15/2024 06:00 6.00 MIRU, MOVE MOB P Continued working on the rig acceptance check list. Mobilized Baker directional equipment & assisted with rig up as needed. Unloaded equipment from trucks. Mobilized riser to the rig floor. Staged FMC riser adapter in the cellar. 0.0 0.0 4/15/2024 06:00 4/15/2024 11:30 5.50 MIRU, MOVE MOB P Continued working on rig acceptance check list. Assisted with Baker directional rig up as needed. Pressure test surface lines & mud pump pop offs to 3500 psi. Unload equipment from trucks. 0.0 0.0 4/15/2024 11:30 4/15/2024 12:00 0.50 MIRU, MOVE NUND P Nippled up FMC riser adapter over landing ring. Tested to 1000 psi per FMC. Witnessed by CPAI Rep. SIMOPS unload equipment from trucks; changed out tugger lines in the BOP deck; assisted with Baker rig up; continued with MagTec rig up. 0.0 0.0 4/15/2024 12:00 4/16/2024 00:00 12.00 MIRU, MOVE MOB P Continued working on the rig acceptance check list. Assisted Baker with rig up as needed. Continued MagTec rig up. Unloaded equipment from trucks. Performed maintenance on mud pump pop offs. Prepped pits to take on mud. Installed Baker tee on stand pipe goose neck. Pressure tested all mud pump pop offs to 3000 psi. Worked on MP2s. SIMOPS Nippled up surface risers; welder modified upper riser section; aired up boots & secured surface riser. Rig accepted at 18:00 hrs. 0.0 0.0 4/16/2024 00:00 4/16/2024 03:30 3.50 MIRU, MOVE MOB P Loaded & processed 13-3/8" casing in the pipe shed. Prepped pits for bringing on spud mud. Prepped handling equipment for picking up BHA1. Inspected & serviced pits auger bearing. Serviced top drive. General housekeeping & serviced equipment. Unloaded trucks with rig equipment from previous locations. 0.0 0.0 4/16/2024 03:30 4/16/2024 04:30 1.00 MIRU, MOVE PULD P Picked up 6 joints of 5-7/8" drill pipe and tagged bottom of the conductor at 125' MD. Laid down 2 singles and racked back a stand. 0.0 0.0 4/16/2024 04:30 4/16/2024 06:00 1.50 MIRU, MOVE MOB P Loaded & processed 13-3/8" casing in the pipe shed. Prepped pits for bringing on spud mud. Prepped handling equipment for picking up BHA1. Inspected & serviced pits auger bearing. General housekeeping & serviced equipment. Unloaded trucks with rig equipment from previous locations. 0.0 0.0 4/16/2024 06:00 4/16/2024 12:00 6.00 MIRU, MOVE MOB P Loaded & processed 13-3/8" casing in the pipe shed. Took on spud mud to the pits. Continued with Baker directional rig up. Serviced & inspected rotary table. Mobilized centralizers to the rig floor. Mobilized BHA 1 components to the rig floor. Began between wells maintenance on BOPE. General housekeeping & serviced equipment. Unloaded trucks with rig equipment from previous locations. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 5/54 MT7-91 Report Printed: 6/25/2024 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) 4/16/2024 12:00 4/16/2024 18:00 6.00 MIRU, MOVE WAIT T Processed 13-3/8" casing in the pipe shed. Continued with Baker directional rig up. Continued with between wells maintenance on BOPE. Installed 9-5/8" solid body rams in upper ram bonnets. Assisted HVAC Rep with A/C systems as needed. Stocked pits with mud products. General housekeeping & serviced equipment. Unloaded trucks with rig equipment from previous locations. 0.0 0.0 4/16/2024 18:00 4/17/2024 00:00 6.00 MIRU, MOVE WAIT T Continued with Baker directional rig up. Calibrated drawworks encoder with Baker. Installed 9-5/8" solid body rams in upper ram bonnets. Pressure tested high pressure mud lines to 4500 psi. Stocked pits with mud products. General housekeeping & serviced equipment. Unloaded trucks with rig equipment from previous locations. 0.0 0.0 4/17/2024 00:00 4/17/2024 06:00 6.00 MIRU, MOVE WAIT T Waited on ice road to open. Tested MagTec cuttings lines & repaired for a leak. Continued processing casing. Installed new cables on BOP deck work platforms. Worked on steam system repairs. Continued to unload trucks & organize equipment on location. General housekeeping & serviced equipment. 0.0 0.0 4/17/2024 06:00 4/17/2024 11:00 5.00 MIRU, MOVE BHAH P Picked up 16" surface BHA 1 as per Baker DD to 123' MD. Plugged into MWD & Gyro, tested & verified working. 0.0 123.0 4/17/2024 11:00 4/17/2024 11:30 0.50 MIRU, MOVE SFTY P Conducted pre-spud meeting. 123.0 123.0 4/17/2024 11:30 4/17/2024 12:15 0.75 MIRU, MOVE SEQP P Flooded surface lines, conductor & riser, Pressure tested mud lines to 6000 psi, good. 123.0 123.0 4/17/2024 12:15 4/17/2024 12:30 0.25 MIRU, MOVE DRLG P Cleaned out conductor from 123'-134' MD at 450 gpm, 540 psi, 40 rpm, Tq 2K. 123.0 134.0 4/17/2024 12:30 4/17/2024 18:00 5.50 SURFAC, DRILL DDRL P Drilled 16" surface section from 134'- 806' MD, 804' TVD. 700 gpm; 1354 psi; FO 35% 60 rpm; Tq on 7-8K, off 4K WOB 6-18K ECD 12.1 PUW 117K, SOW 123K ADT 2.1, AST .5, JARS 1.9, BIT Hrs 2.1 134.0 806.0 4/17/2024 18:00 4/17/2024 20:30 2.50 SURFAC, DRILL DDRL P Drilled 16" surface section from 806'- 994' MD, 991' TVD. 700 gpm; 1474 psi; FO 35% 70 rpm; Tq on 8K, off 3K WOB 15-24K ECD 11.8 PUW 117K, SOW 123K ADT 1.3, AST .4, JARS 3.2, BIT Hrs 3.4 806.0 994.0 4/17/2024 20:30 4/17/2024 22:30 2.00 SURFAC, DRILL CIRC T Tried to down link to MWD for survey. Unable to communicate with MWD. Down link was established. 994.0 994.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 6/54 MT7-91 Report Printed: 6/25/2024 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) 4/17/2024 22:30 4/18/2024 00:00 1.50 SURFAC, DRILL DDRL P Drilled 16" surface section from 994'- 1215' MD, 1210' TVD. 800 gpm; 1720 psi; FO 35% 70 rpm; Tq on 9K, off 3K WOB 25-30K ECD 11.9 PUW 131K, SOW 135K ROT 131k ADT .8, AST .2, JARS 4.2, BIT Hrs 4.2 994.0 1,215.0 4/18/2024 00:00 4/18/2024 06:00 6.00 SURFAC, DRILL DDRL P Drilled 16" surface section from 1215'- 2014' MD, 1959' TVD. 900 gpm; 2084 psi; FO 30% 70 rpm; Tq on 9K, off 4K WOB 30K ECD 11.7 PUW 131K, SOW 135K ROT 131k ADT 3.5, AST 2, JARS 6.4, BIT Hrs 7.7 1,215.0 2,014.0 4/18/2024 06:00 4/18/2024 12:00 6.00 SURFAC, DRILL DDRL P Drilled 16" surface section from 2014'- 2754' MD, 2538' TVD. 900 gpm; 2090 psi; FO 30% 70 rpm; Tq on 10K, off 5K WOB 30K ECD 11.6 PUW 156K, SOW 144K ROT 139k ADT 3.6, AST 2, JARS 8.7, BIT Hrs 11.3 2,014.0 2,754.0 4/18/2024 12:00 4/18/2024 18:30 6.50 SURFAC, DRILL DDRL P Drilled 16" surface section from 2754'- 3548' MD, 3054' TVD. 900 gpm; 2643 psi; FO 38% 75 rpm; Tq on 18K, off 4K WOB 45K ECD 11.7 PUW 184K, SOW 152K ROT 163k ADT 4.3, AST 1, JARS 13.3, BIT Hrs 15.6 2,754.0 3,548.0 4/18/2024 18:30 4/18/2024 20:15 1.75 SURFAC, TRIPCAS BKRM P Back reamed out of the hole from 3548'- 3410' MD, circulating 1 bottoms up each stand. 900 gpm; 1862 psi; FO 32% 75 rpm; Tq 6K ECD 11.6 3,548.0 3,410.0 4/18/2024 20:15 4/18/2024 20:45 0.50 SURFAC, TRIPCAS OWFF P Monitored well, static. 3,410.0 3,410.0 4/18/2024 20:45 4/19/2024 00:00 3.25 SURFAC, TRIPCAS BKRM P Back reamed out of the hole from 3410'- 2650' MD, circulating 1 bottoms up each stand. 900 gpm; 1820 psi; FO 35% 75 rpm; Tq 5K ECD 11.9 3,410.0 2,650.0 4/19/2024 00:00 4/19/2024 01:45 1.75 SURFAC, TRIPCAS BKRM P Back reamed out of the hole from 2650'- 2128' MD. 900 gpm; 1832 psi; FO 30% 75 rpm; Tq 3K ROT 139K 2,650.0 2,128.0 4/19/2024 01:45 4/19/2024 03:15 1.50 SURFAC, TRIPCAS OTHR T Packed off rotary box & flow line with clay. Cleaned out both, establishing flow path. Staged pump rate up to 900 gpm, 1816 psi, 75 rpm, Tq 4K. Worked tool joint through the riser to verify clay removed. 2,128.0 2,128.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 7/54 MT7-91 Report Printed: 6/25/2024 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) 4/19/2024 03:15 4/19/2024 04:15 1.00 SURFAC, TRIPCAS BKRM P Back reamed out of the hole from 2128'- 2050' MD. 900 gpm; 1778 psi; FO 30% 75 rpm; Tq 3K ROT 139K 2,128.0 2,050.0 4/19/2024 04:15 4/19/2024 05:30 1.25 SURFAC, TRIPCAS OTHR T Packed off flow line with clay. Cleaned out, establishing flow path. Staged pump rate up to 900 gpm, 1778 psi, 75 rpm, Tq 3K. 2,050.0 2,050.0 4/19/2024 05:30 4/19/2024 10:00 4.50 SURFAC, TRIPCAS BKRM P Back reamed out of the hole from 2050'- 1002' MD. 900 gpm; 1778 psi; FO 30% 75 rpm; Tq 5K ROT 137K 2,050.0 1,002.0 4/19/2024 10:00 4/19/2024 12:00 2.00 SURFAC, TRIPCAS TRIP P Blew down top drive. Tripped out of the hole from 1002'-220' MD. PUW 152K. 1,002.0 220.0 4/19/2024 12:00 4/19/2024 14:00 2.00 SURFAC, TRIPCAS BHAH P Laid down BHA per Baker DD. Cleaned and inspected tools. SIMOPS prepped pits for cementing & mobilized casing equipment to the rig floor. 220.0 0.0 4/19/2024 14:00 4/19/2024 15:30 1.50 SURFAC, CASING RURD P Rigged up casing equipment. 0.0 0.0 4/19/2024 15:30 4/19/2024 18:00 2.50 SURFAC, CASING PUTB P Run 13-3/8", L80, 68#, H563 to 403' MD. Picked up shoe track, BakerLok on each connection to the pin end of pup joint. Torque to 29K, double bumped. Checked floats, good. Continued to run as per tally with BOL 2000 AG, torque to 25K double bumped. Installed centralizers on each joint to #12 and on every other after. SO 78K, 0.0 403.0 4/19/2024 18:00 4/19/2024 23:00 5.00 SURFAC, CASING PUTB P Run 13-3/8", L80, 68#, H563 from 403'- 3440' MD, as per tally with BOL 2000 AG, torque to 25K double bumped. Installed centralizers on every other after. Topped off every 10 joints. SO 175K. SIMOPS rigged up black water lines to the conductor. 403.0 3,440.0 4/19/2024 23:00 4/20/2024 00:00 1.00 SURFAC, CASING PUTB P Washed down from 3440'-3483' MD. Cleared rig floor. Removed spiders & installed bushing. Prepped to make up hanger. PUW 255K; SOW 216K. 3,440.0 3,483.0 4/20/2024 00:00 4/20/2024 01:00 1.00 SURFAC, CASING HOSO P Made up FMC hanger and landing joint. Washed down from 3483'-3541.78' at 1 bpm, 147 psi. Landed hanger on landing ring. 3,483.0 3,541.7 4/20/2024 01:00 4/20/2024 02:30 1.50 SURFAC, CEMENT CIRC P Circulated & conditioned mud for cementing. Staged up pump rate to 7 bpm, 470 psi. Reciprocated with 15' strokes. PUW 260K; SOW 214K. 3,541.7 3,541.7 4/20/2024 02:30 4/20/2024 02:45 0.25 SURFAC, CEMENT RURD P Blew down top drive. Rigged up cement line to CRT swivel 3,541.7 3,541.7 4/20/2024 02:45 4/20/2024 03:30 0.75 SURFAC, CEMENT CIRC P Circulated at 7 bpm, 475 psi, reciprocated with 15' strokes. PJSM with all critical personnel for cementing. 3,541.7 3,541.7 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 8/54 MT7-91 Report Printed: 6/25/2024 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) 4/20/2024 03:30 4/20/2024 07:30 4.00 SURFAC, CEMENT CMNT P Lined up to SLB cement unit & pumped 5 bbls of H2O. Tested lines to 3700 psi, good. Batched and pumped 101.5 bbls of 10.9 ppg MP II at 6.2 bpm, 260 psi. Dropped bottom plug. Batched and pumped 392.8 bbls of 11.0 ppg lead cement at 6 bpm, 330 psi. Batched & pumped 70 bbls of 15.8 ppg tail cement at 6 bpm, 394 psi. Dropped top plug. Pumped 20 bbls of fresh H2O at 6 bpm, 220 psi. Swapped to rig pump. Pumped 11.0 ppg KlaShield at 8 bpm, 250 - 688 psi. Bumped the plug with 503 bbls pumped (4,237 strokes). Pressured up to 900 psi & hold for 5 minutes. Checked floats, good. CIP 07:30 hrs. Had 136 bbls of cement returns to surface. 3,541.7 0.0 4/20/2024 07:30 4/20/2024 09:00 1.50 SURFAC, CEMENT RURD P Rigged down casing equipment. Laid down landing joint. Blew down cement line. Cleaned cement valves on mud manifold. Cleaned & cleared rig floor. 0.0 0.0 4/20/2024 09:00 4/20/2024 10:00 1.00 SURFAC, CEMENT WWWH P Made up a stand of 5-7/8" drill pipe & stack wash tool. Washed & flushed stack till shakers cleaned up. Laid down wash tool & racked back stand. 0.0 0.0 4/20/2024 10:00 4/20/2024 13:00 3.00 SURFAC, WHDBOP NUND P Nippled down surface riser sections & FMC slip ring lock. SIMOPS cleaned cement manifold valves; cleaned pits & cellar box; loaded 90 joints of 5-7/8" drill pipe in the shed. 0.0 0.0 4/20/2024 13:00 4/20/2024 15:30 2.50 SURFAC, WHDBOP NUND P Installed FMC wellhead & aligned. Installed lower high pressure riser above wellhead. Torque all bolts to spec. 0.0 0.0 4/20/2024 15:30 4/20/2024 16:00 0.50 SURFAC, WHDBOP PRTS P Pressure tested casing hanger neck seals to 1000 psi for 10 minutes, witnessed by CPAI Rep. SIMOPS prepped BOPE for nipple up. 0.0 0.0 4/20/2024 16:00 4/20/2024 19:30 3.50 SURFAC, WHDBOP NUND P Nippled up BOP stack & upper riser. Made up choke & kill lines to mud cross. Energized accumulator & inspected lines. Made up MPD lines. Secured stack with turn buckles. SIMOPS made up 5-7/8" test joint, pups & test plug; prepped testing equipment; set test plug per FMC Rep. 0.0 0.0 4/20/2024 19:30 4/20/2024 20:00 0.50 SURFAC, WHDBOP BOPE P Flooded BOPE, surface lines & choke manifold. Performed shell test to 3500 psi. 0.0 0.0 4/20/2024 20:00 4/21/2024 00:00 4.00 SURFAC, WHDBOP BOPE P Performed initial BOPE test with 5-7/8" test joint. Tested annular to 250 psi for 5 minutes & 3500 psi for 10 minutes. All other tests were to 250 psi for 5 minutes & 5000 psi for 10 minutes. #1 Annular #2 Upper 3-1/2" X 6-5/8" VBRs; CMVs 1,14, 15, 16, kill line valve #3 #3 CMVs 10,13, needle valve above #1; HCR kill; lower IBOP #4 CMVs 4, 9, 12; manual kill; upper IBOP #5 CMVs 6, 8, 11 Tested gas alarms, PVT gain/loss, & flow out. Test witnessed by AOGCC Guy Cook & BLM Quinn Sawyer. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 9/54 MT7-91 Report Printed: 6/25/2024 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) 4/21/2024 00:00 4/21/2024 07:30 7.50 SURFAC, WHDBOP BOPE P Continued initial BOPE test with 5-7/8" test joint. Tested all components to 250 psi for 5 minutes & 5000 psi for 10 minutes. #6 CMV 5, 7; 5-7/8" dart valve #7 CMV 2; 5-7/8" FOSV #8 HCR choke valve (FP "other" quick connect leaking) #9 Manual choke valve #10 Lower 3-1/2" X 6-5/8" VBRs #11 Blind shear rams; CMV 3, 4, 6 #12 Manual choke bleed down #13 Super choke bleed down Accumulator drawdown test. System pressure 3000 psi; manifold pressure 1500 psi; Pressure after closure 1600 psi; 200 psi attained in 15 seconds; full pressure attained in 100 seconds. Closing times: annular 20 seconds, UVBRs 15 seconds, blind/shears 24 seconds, LVBRs 15 seconds, choke HCR 2 seconds, kill HCR 2 seconds. 10 nitrogen bottles average 3900 psi. Test witnessed by AOGCC Guy Cook & BLM Quinn Sawyer. SIMOPS prepped for cut & slip; mobilized MPD test plug to the rig floor; mobilized BHA to rig floor. 0.0 0.0 4/21/2024 07:30 4/21/2024 09:30 2.00 SURFAC, WHDBOP SLPC P Cut & slipped 71' of drilling line. Torque dead man to spec. Removed block hanging line. Cleared rig floor & calibrated block height. SIMOPS finished rigging up MPD lines & equipment. 0.0 0.0 4/21/2024 09:30 4/21/2024 10:30 1.00 SURFAC, WHDBOP MPDA P Made up a stand of 5-7/8" drill pipe, Installed RCD test plug. Tested MPD system to 250 / 1250 psi for 5 minutes each test, charted. 0.0 0.0 4/21/2024 10:30 4/21/2024 11:15 0.75 SURFAC, WHDBOP MPDA P Removed RCD & FMC test plugs. Drained stack of fresh water. Blew down all lines. 0.0 0.0 4/21/2024 11:15 4/21/2024 12:30 1.25 SURFAC, WHDBOP RURD P Made up a stand of 5-7/8" drill pipe & FMC running tool. Set wear bushing as per FMC Rep. Laid down running tool & racked back the stand. SIMOPS prepped for casing test. 0.0 0.0 4/21/2024 12:30 4/21/2024 13:45 1.25 SURFAC, DRILLOUT PRTS T Flooded mud lines & stack with mud & prepped for casing test. Pumped 7 bbls of 11.0 ppg mud, pressuring up to 3554 psi. Shut in and observed pressure for 30 minutes from 3554 to 2929 psi. Bled back 6.4 bbls. Confer with town to perform another test. 0.0 0.0 4/21/2024 13:45 4/21/2024 14:45 1.00 SURFAC, DRILLOUT PRTS T Pumped 7.3 bbls of 11.0 ppg mud, pressuring up in 1000 psi increments, holding pressure for 5 minutes at each increment. Shut in pressure at 3527 psi & monitored for 20 minutes, with a final pressure of 2958 psi. Bled back 6.7 bbls. Decision made to test again. 0.0 0.0 4/21/2024 14:45 4/21/2024 15:30 0.75 SURFAC, DRILLOUT PRTS P Pumped 7.0 bbls of 11.0 ppg mud, pressuring up to 3594 psi. Shut in and monitored for 30 minutes, with a final pressure of 3499 psi. Bled back 7.0 bbls. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 10/54 MT7-91 Report Printed: 6/25/2024 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) 4/21/2024 15:30 4/21/2024 16:00 0.50 SURFAC, DRILLOUT RURD P Blew down kill line & lined up mud pumps. SIMOPS prepped floor to pickup BHA 2. 0.0 0.0 4/21/2024 16:00 4/21/2024 17:45 1.75 SURFAC, DRILLOUT BHAH P Picked up 12-1/4" intermediate 1, BHA 2 to 99' MD as per Baker DD & MWD. Tested tools at surface. SOW 92K. 0.0 99.0 4/21/2024 17:45 4/21/2024 19:45 2.00 SURFAC, DRILLOUT TRIP P Tripped in the hole from 99'-3250' MD. PUW 134K SOW 121K 99.0 3,250.0 4/21/2024 19:45 4/21/2024 20:00 0.25 SURFAC, DRILLOUT DHEQ P Filled pipe and shallow tested MWD tools at 750 gpm, 1040 psi, FO 35%. 3,250.0 3,250.0 4/21/2024 20:00 4/21/2024 20:45 0.75 SURFAC, DRILLOUT REAM P Reamed down from 3250'-3450' MD to tag float collar. 750 gpm; 1046 psi; FO 35% 40 rpm; Tq 7K ECD 11.1 PUW 181K SOW 146K ROT 159K 3,250.0 3,450.0 4/21/2024 20:45 4/22/2024 00:00 3.25 SURFAC, DRILLOUT DRLG P Drilled shoe track & rat hole from 3450'- 3548' MD as per Baker DD. Drilled float collar at 700 gpm, 1043 psi, FO 35%, 40 rpm, Tq 7-10K; reamed collar 3 times. Drilled cement at 800 gpm, 1163 psi, FO 38%, 80 rpm, Tq 11-14K. Drilled float shoe at 750 gpm, 1055 psi, FO 30%, 40 rpm, Tq 7K, WOB 15-20K. Drilled out rat hole at 750 gpm, 1055 psi, FO 30%, 80 rpm, Tq 7K, WOB 15- 25 3,450.0 3,548.0 4/22/2024 00:00 4/22/2024 01:15 1.25 SURFAC, DRILLOUT DDRL P Directional drilled 12-1/4" intermediate 1 section from 3548'-3568' MD, 3066' TVD. Displaced well on the fly to 11.0 ppg FWP system. Reamed the shoe 3 times & drifted once. 800 gpm, 1030 psi, FO 30% 80 rpm, Tq 7-12K WOB 4K ECD 11.3 PUW 181K SOW 146K RW 159K ADT .2; BIT .2; JARS 13.5 hrs. 3,548.0 3,568.0 4/22/2024 01:15 4/22/2024 01:30 0.25 SURFAC, DRILLOUT RURD P Mouse Holed a stand of drill pipe & rigged up to perform FIT. 3,568.0 3,526.0 4/22/2024 01:30 4/22/2024 02:00 0.50 SURFAC, DRILLOUT FIT P Performed FIT to an EMW of 18.5 ppg at 3050' TVD. Pumped 3.6 bbls of 11.0 ppg mud at .6 bpm pressuring up to 1189 psi. Shut in and monitored pressure for 10 minutes with a final pressure of 993 psi. Bled back 3.5 bbls. 3,526.0 3,526.0 4/22/2024 02:00 4/22/2024 02:30 0.50 INTRM1, DRILL RURD P Rigged down testing equipment & blew down kill line. Washed and reamed back to bottom at full drilling rates. 3,526.0 3,568.0 4/22/2024 02:30 4/22/2024 06:00 3.50 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 3568'-3820' MD, 3224' TVD. Obtained torque & drag every 3 stands. 1200 gpm, 2040 psi, FO 36% 130 rpm, Tq on 11K; off 3K WOB 9-11K ECD 11.5 PUW 178K SOW 153K RW 167K ADT 2.1; BIT 2.3; JARS 15.8 hrs. 3,568.0 3,820.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 11/54 MT7-91 Report Printed: 6/25/2024 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) 4/22/2024 06:00 4/22/2024 12:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 3820'-4518' MD, 3656' TVD. Obtained torque & drag every 3 stands. 1290 gpm, 2500 psi, FO 40% 160 rpm, Tq on 12K; off 3K WOB 16K ECD 11.7 PUW 186K SOW 161K RW 168K ADT 3.8; BIT 6.1; JARS 19.4 hrs. 3,820.0 4,518.0 4/22/2024 12:00 4/22/2024 18:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 4518'-5256' MD, 4119' TVD. Obtained torque & drag every 3 stands. 1289 gpm, 2650 psi, FO 38% 160 rpm, Tq on 12K; off 3K WOB 15-20K ECD 11.8 PUW 196K SOW 174K RW 182K ADT 4.1; BIT 10.2; JARS 23.5 hrs. 4,518.0 5,256.0 4/22/2024 18:00 4/23/2024 00:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 5256'-6032' MD, 4608' TVD. Obtained torque & drag every 3 stands. 1290 gpm, 2870 psi, FO 42% 160 rpm, Tq on 15K; off 4K WOB 15-20K ECD 11.9 PUW 216K SOW 184K RW 190K ADT 4.1; BIT 14.3; JARS 27.6 hrs. 5,256.0 6,032.0 4/23/2024 00:00 4/23/2024 06:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 6032'-6776' MD, 5075' TVD. Obtained torque & drag every 3 stands. 1290 gpm, 3083 psi, FO 40% 160 rpm, Tq on 16K; off 4K WOB 21K ECD 12.2 PUW 226K SOW 193K RW 200K ADT 4.1; BIT 18.4; JARS 31.7 hrs. 6,032.0 6,776.0 4/23/2024 06:00 4/23/2024 12:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 6776'-7527' MD, 5361' TVD. Obtained torque & drag every 3 stands. 1290 gpm, 3176 psi, FO 43% 170 rpm, Tq on 19K; off 6K WOB 25K ECD 12.2 PUW 246K SOW 195K RW 209K ADT 3.9; BIT 22.3; JARS 35.6 hrs. 6,776.0 7,527.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 12/54 MT7-91 Report Printed: 6/25/2024 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) 4/23/2024 12:00 4/23/2024 18:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 7527'-8261' MD, 6150' TVD. Obtained torque & drag every 3 stands. 1290 gpm, 3350 psi, FO 42% 170 rpm, Tq on 21K; off 7K WOB 20K ECD 12.1 PUW 270K SOW 207K RW 228K ADT 3.9; BIT 26.2; JARS 39.5 hrs. 7,527.0 8,261.0 4/23/2024 18:00 4/24/2024 00:00 6.00 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 8261'-9003' MD, 6805' TVD. Obtained torque & drag every 3 stands. 1290 gpm, 35230 psi, FO 43% 170 rpm, Tq on 16K; off 8K WOB 20-28K ECD 12.2 PUW 284K SOW 216K RW 245K ADT 4.3; BIT 30.5; JARS 43.8 hrs. 8,261.0 9,003.0 4/24/2024 00:00 4/24/2024 03:30 3.50 INTRM1, DRILL DDRL P Directional drilled 12-1/4" intermediate 1 section from 9003'-9365' MD, 7121' TVD. Obtained final survey at TD. 1290 gpm, 3351 psi, FO 43% 170 rpm, Tq on 19K; off 8K WOB 6K ECD 12.0 PUW 284K SOW 216K RW 245K ADT 2.9; BIT 33.4; JARS 46.7 hrs. 9,003.0 9,365.0 4/24/2024 03:30 4/24/2024 05:00 1.50 INTRM1, TRIPCAS BKRM P BROOH form 9365' MD to 9250' MD. 800 GPM, 1631 psi, FO 30% 20 rpm Tq 11K, B/O Tq 10K. PUW 305K SOW 230K RW 249K Collect SCR's @ 9250' MD 7121' TVD MW 11 ppg, time 04:45 #1 MP @ 20 SPM = 230 psi, 30 SPM = 265 psi #2 MP @ 20 SPM = 229 psi, 30 SPM = 268 psi 9,365.0 9,250.0 4/24/2024 05:00 4/24/2024 07:45 2.75 INTRM1, TRIPCAS BKRM P BROOH form 9250' MD to 9152' MD. pumping 1 bottoms up per stand racked back. 1290 GPM, 3287 psi, FO 54% 20 rpm Tq 17K, ECD 11.8 ppg Monitor hole via active system. 9,250.0 9,152.0 4/24/2024 07:45 4/24/2024 08:15 0.50 INTRM1, TRIPCAS OWFF P Perform 30 minute flow check, well static. 9,152.0 9,152.0 4/24/2024 08:15 4/24/2024 12:00 3.75 INTRM1, TRIPCAS BKRM P BROOH form 9152' MD to 7732' MD. 1290 GPM, 3300 psi, FO 30% 140 rpm Tq 20K, ECD 11.8 ppg RTW 209K Monitor hole via active system. 9,152.0 7,732.0 4/24/2024 12:00 4/24/2024 16:00 4.00 INTRM1, TRIPCAS BKRM P BROOH form 7732' MD to 6677' MD. 1290 GPM, 3097 psi, FO 45% 140 rpm Tq 15K, ECD 12.1 ppg Monitor hole via active system. 7,732.0 6,677.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 13/54 MT7-91 Report Printed: 6/25/2024 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) 4/24/2024 16:00 4/24/2024 20:00 4.00 INTRM1, TRIPCAS CIRC T Continue BROOH from 6677' and observe 250 psi pressure spike and losses at 6712' MD. Run back in hole one stand and to 6773' and reduce rate to 300 gpm to regain returns, slowly work pump rates back up to 1100 gpm and work rotary up to 120 rpm while monitoring loses, 1100 gpm, 2235 psi. 120 rpm, Tq 10k ECD 11.6 ppg 6,677.0 6,677.0 4/24/2024 20:00 4/25/2024 00:00 4.00 INTRM1, TRIPCAS BKRM P BROOH from 6677' MD to 5960' MD. 1290 GPM, 2145 psi, FO 45% 120 rpm Tq 11K, ECD 11.7 ppg RTW 191k Monitor hole via active system. 6,677.0 5,960.0 4/25/2024 00:00 4/25/2024 06:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 5960' MD to 4886' MD. 1060 GPM, 1960 psi, FO 35% 120 rpm Tq 12K, ECD 11.5 ppg RTW 165k Monitor hole via active system. 5,960.0 4,886.0 4/25/2024 06:00 4/25/2024 11:45 5.75 INTRM1, TRIPCAS BKRM P BROOH from 4886' MD to 3526' MD (inside 13-3/8" casing shoe) 1060 GPM, 1875 psi, FO 35% 120 rpm Tq 10K, ECD 11.6 ppg RTW 159k Monitor hole via active system. 4,886.0 3,526.0 4/25/2024 11:45 4/25/2024 14:00 2.25 INTRM1, TRIPCAS CIRC P Stage up flow rate to 1290 GPM, 2500 psi, FO 42%. Circulate and reciprocate from 3527' MD to 3430' MD to clean up casing. Pump 2 nutplug sweeps and observe shakers unloading. Continue circulation until shakers clean up. 8 total bottoms up pumped. ECD 11.5 RTW 150k 3,526.0 3,526.0 4/25/2024 14:00 4/25/2024 14:30 0.50 INTRM1, TRIPCAS OWFF P Perform 15 minute flow check and blow down top drive. Prepare to pull out of hole on elevators. 3,526.0 3,526.0 4/25/2024 14:30 4/25/2024 16:00 1.50 INTRM1, TRIPCAS TRIP P POOH from 3526' MD to 1368' PUW 150K Noted 25K overpull @ 1368'. Monitor hole fill via trip tank. 3,526.0 1,368.0 4/25/2024 16:00 4/25/2024 16:45 0.75 INTRM1, TRIPCAS BKRM T RIH to 1403' establish circulation @ 1290 GPM, 2150 psi, 120 rpm, TQ 3K. BROOH from 1403' to 1311' MD. 1,368.0 1,311.0 4/25/2024 16:45 4/25/2024 18:15 1.50 INTRM1, TRIPCAS TRIP P POOH on elevators from 1368' to 192' MD. Monitor hole fill via trip tank. 1,311.0 192.0 4/25/2024 18:15 4/25/2024 18:30 0.25 INTRM1, TRIPCAS OWFF P Perform 15 minute flow check. 192.0 192.0 4/25/2024 18:30 4/25/2024 19:00 0.50 INTRM1, TRIPCAS TRIP P POOH from 192' to 104' MD and observe overpull. 192.0 104.0 4/25/2024 19:00 4/26/2024 00:00 5.00 INTRM1, TRIPCAS BHAH T Work tight area and troubleshoot cause of obstruction, continue to work area with no success, make several attempts dropping down and making quarter turns , attempted with and without pumps on. With and without rotation. Worked up to bit depth of 60'. 104.0 60.0 4/26/2024 00:00 4/26/2024 06:00 6.00 INTRM1, TRIPCAS BHAH T Continue to work BHA through wellhead area - unable to pull AutoTrak and bit through wellhead. Attempt with varying parameters and rates. 60.0 60.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 14/54 MT7-91 Report Printed: 6/25/2024 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) 4/26/2024 06:00 4/26/2024 14:00 8.00 INTRM1, TRIPCAS BHAH T Continue to work BHA through wellhead area - unable to pull AutoTrak and bit through wellhead. Attempt with varying parameters and rates. 60.0 60.0 4/26/2024 14:00 4/26/2024 18:00 4.00 INTRM1, TRIPCAS TRIP T Unable to make progress getting BHA through wellhead. Run back in hole from 60' to 3437' MD. Monitor hole displacement via trip tank. 60.0 3,437.0 4/26/2024 18:00 4/26/2024 18:45 0.75 INTRM1, TRIPCAS CIRC T Fill pipe and collect base line parameters. PUW 165K SOW 156K RTW 163K 3k TQ @ 20 RPM 1100 gpm, 1732 psi, 11.2 ECD. 3,437.0 3,437.0 4/26/2024 18:45 4/26/2024 19:30 0.75 INTRM1, TRIPCAS REAM T Wash and ream from 3437' to 3620' MD passing up and down through shoe several times. 1290 gpm, 2372 psi, FO 40% 80 rpm, Tq 6k ECD 11.2 RW 155K 3,437.0 3,620.0 4/26/2024 19:30 4/26/2024 21:30 2.00 INTRM1, TRIPCAS REAM T Downlink and open AutoTrak. Work pipe from 3560' to 3610' MD varying RPM's to clear debris. 1290 gpm, 2470 psi, FO 40% 120 rpm, Tq 6.4k ECD 11.2 RW 155K 3,620.0 3,620.0 4/26/2024 21:30 4/26/2024 22:15 0.75 INTRM1, TRIPCAS REAM T Downlink and close Autotrak and pull back into shoe and work BHA through shoe several times. 3,620.0 3,530.0 4/26/2024 22:15 4/26/2024 22:30 0.25 INTRM1, TRIPCAS OWFF T Perform flow check and blow down top drive for tripping. 3,530.0 3,530.0 4/26/2024 22:30 4/27/2024 00:00 1.50 INTRM1, TRIPCAS TRIP T POOH from 3530' MD to 1200' MD racking back stands in derrick watching for signs of excess drag and monitoring hole fill via trip tank. 3,530.0 1,200.0 4/27/2024 00:00 4/27/2024 01:45 1.75 INTRM1, TRIPCAS TRIP T POOH from 1200' MD to surface racking back stands in derrick watching for signs of excess drag and monitoring hole fill via trip tank. 1,200.0 0.0 4/27/2024 01:45 4/27/2024 02:00 0.25 INTRM1, TRIPCAS BHAH P Clean and inspect BHA for damage, document with pictures. 0.0 0.0 4/27/2024 02:00 4/27/2024 03:30 1.50 INTRM1, TRIPCAS BHAH P Break off bit and L/D BHA. 0.0 0.0 4/27/2024 03:30 4/27/2024 04:00 0.50 INTRM1, TRIPCAS RURD P Change out elevators and P/U double of 5-7/8" drillpipe and M/U stack washer. 0.0 0.0 4/27/2024 04:00 4/27/2024 04:30 0.50 INTRM1, TRIPCAS WWWH P Wash BOP stack at 1200 gpm, 180 psi. 0.0 0.0 4/27/2024 04:30 4/27/2024 05:00 0.50 INTRM1, TRIPCAS RURD P L/D stack washer. Drain BOP stack for upper ram change. 0.0 0.0 4/27/2024 05:00 4/27/2024 06:00 1.00 INTRM1, TRIPCAS RURD P Change upper pipe rams to 9-5/8" SBR's. 0.0 0.0 4/27/2024 06:00 4/27/2024 06:45 0.75 INTRM1, TRIPCAS RURD P M/U up wear ring running tool to 5-7/8" double and pull wear ring. Remove wear ring from puller and rack back stand. 0.0 0.0 4/27/2024 06:45 4/27/2024 08:00 1.25 INTRM1, TRIPCAS RURD P Change out elevators. M/U 9-5/8" test joint to X/O and test plug. Set BOP test plug as per FMC rep. 0.0 0.0 4/27/2024 08:00 4/27/2024 08:45 0.75 INTRM1, TRIPCAS RURD P Fill stack with water and rig up test lines. Purge air from system. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 15/54 MT7-91 Report Printed: 6/25/2024 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) 4/27/2024 08:45 4/27/2024 09:15 0.50 INTRM1, TRIPCAS BOPE P Test 9-5/8" upper rams to 250 low psi for 5 minutes and 3500 high psi for 10 minutes. 0.0 0.0 4/27/2024 09:15 4/27/2024 10:15 1.00 INTRM1, TRIPCAS RURD P Rig down test equipment. Pull test joint and L/D test plug and X/O's. Drain stack of water. 0.0 0.0 4/27/2024 10:15 4/27/2024 12:00 1.75 INTRM1, CASING RURD P Rig up 9-5/8" casing running equipment. 0.0 0.0 4/27/2024 12:00 4/27/2024 18:00 6.00 INTRM1, CASING PUTB P RIH with 9-5/8" HYD 563 casing as per casing tally from 0' to 2593' MD. BOL artic grade 2000 pipe dope, and filling every joint topping off every 10 joints. Bakerlock shoe track and torque to 19000 FT/LBS. Torque reaming to 16000 FT/LBS double bump connections and check all connection hash marks. Install Centek 12.25" centralizers on joints #4-60. 0.0 2,593.0 4/27/2024 18:00 4/27/2024 19:30 1.50 INTRM1, CASING PUTB P RIH with 9-5/8" HYD 563 casing as per casing tally from 2593' to 3540' MD. BOL artic grade 2000 pipe dope, and filling every joint topping off every 10 joints. Bakerlock shoe track and torque to 19000 FT/LBS. Torque reaming to 16000 FT/LBS double bump connections and check all connection hash marks. Install Centek 12.25" centralizers on joints #4-60. 2,593.0 3,540.0 4/27/2024 19:30 4/27/2024 20:30 1.00 INTRM1, CASING CIRC P Circulate and reciprocate from 3540' to 3511' slowly working pump rate up to 6 BPM. 252 gpm, 162 psi, FO 14% 3,540.0 3,540.0 4/27/2024 20:30 4/28/2024 00:00 3.50 INTRM1, CASING PUTB P RIH with 9-5/8" HYD 563 casing as per casing tally. from 3540' to 6300' MD. BOL artic grade 2000 pipe dope, and filling every joint topping off every 10 joints. Bakerlock shoe track and torque to 19000 FT/LBS. Torque reaming to 16000 FT/LBS double bump connections and check all connection hash marks. Install Centek 12.25" centralizers on joints #4-60. Install Centek 12.25" on every third joint starting at joint #140. 3,540.0 6,300.0 4/28/2024 00:00 4/28/2024 00:15 0.25 INTRM1, CASING PUTB P RIH with 9-5/8" HYD 563 casing as per casing tally from 6300' to 6518' MD. BOL artic grade 2000 pipe dope, and filling every joint topping off every 10 joints. Bakerlock shoe track and torque to 19000 FT/LBS. Torque reaming to 16000 FT/LBS double bump connections and check all connection hash marks. Install Centek 12.25" centralizers on joints #4-60. Install Centek 12.25" on every third joint starting at joint #140. SOW 128K PUW 304K 6,300.0 6,518.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 16/54 MT7-91 Report Printed: 6/25/2024 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) 4/28/2024 00:15 4/28/2024 02:00 1.75 INTRM1, CASING CIRC P Circulate to reduce drag. Stage up pumps slowly in 1/2 bbl increments to 6 BPM. 263 psi. SOW 128k PUW 304K 6,518.0 6,518.0 4/28/2024 02:00 4/28/2024 07:15 5.25 INTRM1, CASING PUTB P RIH with 9-5/8" HYD 563 casing as per casing tally. from 6518' to 9294' MD. BOL artic grade 2000 pipe dope, and filling every joint topping off every 10 joints. Bakerlock shoe track and torque to 19000 FT/LBS. Torque reaming to 16000 FT/LBS double bump connections and check all connection hash marks. Install Centek 12.25" centralizers on joints #4-60. Install Centek 12.25" on every third joint starting at joint #140. SOW 250K PUW 425K 6,518.0 9,294.0 4/28/2024 07:15 4/28/2024 07:45 0.50 INTRM1, CASING PUTB P Lost slack off weight to 140K work pipe down from 9294' MD to 9306' MD. 9,294.0 9,306.0 4/28/2024 07:45 4/28/2024 08:00 0.25 INTRM1, CASING THGR P M/U hanger and landing joint as per FMC rep. 9,306.0 9,306.0 4/28/2024 08:00 4/28/2024 10:30 2.50 INTRM1, CASING THGR P Work casing down with hanger and landing joint made up from 9306' MD to 9360' MD. 9,306.0 9,360.0 4/28/2024 10:30 4/28/2024 12:00 1.50 INTRM1, CASING CIRC P Reciprocate casing from 9358' MD to 9352' MD while establishing circulation at .5 BPM on down stroke and 1 BPM on up stroke. 500 psi up stroke. SOW 250K, PUW 420K. 9,360.0 9,360.0 4/28/2024 12:00 4/28/2024 13:15 1.25 INTRM1, CASING CIRC P Continue to circulate while reciprocating from 9357' MD to 9353' MD. Increase pump rate in 1/2 bbl increments to 3.5 BPM 555 psi. 9,360.0 9,360.0 4/28/2024 13:15 4/28/2024 15:15 2.00 INTRM1, CASING THGR P Land hanger at 9360' MD work pump rate up to 6 BPM at 520 psi, 10% FO. Circulate until even in/out mud weights. 9,360.0 0.0 4/28/2024 15:15 4/28/2024 16:00 0.75 INTRM1, CEMENT RURD P Replace cup seal on Volant, prime MP#1 & #4 with LVT. Blow down top drive and rig up cement line to Volant. 0.0 0.0 4/28/2024 16:00 4/28/2024 16:45 0.75 INTRM1, CEMENT CIRC P Establish circulation through cement hose @ 6 BPM with 630 psi, 10% FO. Prepare mud pits for cement job. PJSM with all crew members. 0.0 0.0 4/28/2024 16:45 4/28/2024 17:00 0.25 INTRM1, CEMENT SEQP P Flood surface lines with water from cementers and pressure test lines to 500 psi low and 3500 psi high. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 17/54 MT7-91 Report Printed: 6/25/2024 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) 4/28/2024 17:00 4/28/2024 21:15 4.25 INTRM1, CEMENT CMNT P Pump 60 bbl 12.5 ppg mud push @ 4 BPM, 420 psi. Cement wet at 17:22. Drop bottom plug at 17:57. Pump 71 bbls 13 ppg lead cement at 4.5 BPM average, 442 psi. Lead cement was wet at 17:57. Follow with 116 bbls of 15.8 ppg tail cement at 4.5 BPM average, 700 psi. Tail cement was wet at 18:24. Drop top plug at 19:04 and pump 10 bbls of fresh water from cement unit to flush lines. Chase with 679 bbls of 11.5 ppg Versa- Clean NAF from rig at 6 BPM average, 750 psi. Slow pumps to 3 BPM at 5560 strokes, bump floats at 5720 strokes FCP = 775 psi. Continue pumping to 5726 strokes 1275 psi for 500 psi over FCP. 0.0 0.0 4/28/2024 21:15 4/28/2024 22:15 1.00 INTRM1, CEMENT DHEQ P Pressure up floats to 1275 psi and hold for 5 minutes. Bleed back off pressure and record 6.4 bbls bled back. Check floats - minor flow at surface from compressibility. Vis-cup indacate 1 BPH and reducing. Shut in and record 20 psi gain over 10 minutes. Floats deemed holding. 0.0 0.0 4/28/2024 22:15 4/28/2024 22:45 0.50 INTRM1, CEMENT RURD P Blow down cement hose and rig up for casing test. 0.0 0.0 4/28/2024 22:45 4/29/2024 00:00 1.25 INTRM1, WHDBOP PRTS P Conduct casing test to 3500 PSI for 30 minutes. Pumped 75 strokes with indications that stokes are inaccurate with actual volume. Stop pumps, shut in casing and monitor casing test pressure for 4 minutes - casing pressure steady at 1449 psi. Continue with test. Pump 215 strokes to 3523 psi. Pit volume indicates 9 bbls pumped. Shut in and monitor pressure for 30 minutes. Pressure increases from 3544 psi to 3558 psi over 30 minutes. Bled back test pressure to pit #2 and record 9 bbls bled back. 0.0 0.0 4/29/2024 00:00 4/29/2024 00:45 0.75 INTRM1, WHDBOP RURD P Rig down casing pressure test equipment . Drain BOP stack for ram change. 0.0 0.0 4/29/2024 00:45 4/29/2024 01:30 0.75 INTRM1, WHDBOP RURD P L/D landing joint and pup, clean remaining pits of water based. 0.0 0.0 4/29/2024 01:30 4/29/2024 02:30 1.00 INTRM1, WHDBOP RURD P Clean and rig down casing running equipment. SIMOPS: Clean pits. 0.0 0.0 4/29/2024 02:30 4/29/2024 04:30 2.00 INTRM1, WHDBOP WWSP P P/U stand of 5-7/8" drill pipe install pack off as per FMC rep and pressure test seals to 5K for 10 minutes. L/D pack off running tool and stand back. 0.0 0.0 4/29/2024 04:30 4/29/2024 05:30 1.00 INTRM1, WHDBOP RURD P Change upper pipe rams to 5-7/8" x 7- 5/8" VBR. SIMOPS clean pits. 0.0 0.0 4/29/2024 05:30 4/29/2024 07:30 2.00 INTRM1, WHDBOP RURD P Mobilize test plug and BHA components to rig floor. C/O kill line HCR. SIMOPS continue cleaning pits. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 18/54 MT7-91 Report Printed: 6/25/2024 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) 4/29/2024 07:30 4/29/2024 09:00 1.50 INTRM1, WHDBOP RURD P M/U 5-7/8" test joint and test plug. Set test plug, fill stack and purge lines of air. SIMOPS cleaning pits. 0.0 0.0 4/29/2024 09:00 4/29/2024 10:00 1.00 INTRM1, WHDBOP BOPE P Pressure test upper pipe rams and HCR valve with 5-7/8" test joint . 250 low psi for 5 minutes. 3500 psi high for 10 minutes. 0.0 0.0 4/29/2024 10:00 4/29/2024 10:45 0.75 INTRM1, WHDBOP RURD P Pull 5-7/8" test joint , install 7-5/8" test joint . SIMOPS cleaning pits. 0.0 0.0 4/29/2024 10:45 4/29/2024 11:15 0.50 INTRM1, WHDBOP RURD P Rebuild Kill valve #3. 0.0 0.0 4/29/2024 11:15 4/29/2024 12:00 0.75 INTRM1, WHDBOP BOPE P Test upper pipe rams and Kill valve #3 with 7-5/8" test joint with 250 psi low pressure for 5 minutes and 3500 psi high pressure for 10 minutes. 0.0 0.0 4/29/2024 12:00 4/29/2024 13:00 1.00 INTRM1, WHDBOP RURD P Pull BOP test plug as per FMC rep, drain stack and blow down mud line and kill line. Set wear ring as per FMC, ID = 8.5" OD = 13.5" Length = 10.58". L/D 7-5/8" test joint and pups. 0.0 0.0 4/29/2024 13:00 4/29/2024 13:45 0.75 INTRM1, DRILLOUT BHAH P Clean and clear rig floor and conduct PJSM for BHA. 0.0 0.0 4/29/2024 13:45 4/29/2024 15:45 2.00 INTRM1, DRILLOUT BHAH P M/u BHA #3 as per Baker DD from 0 to 148' MD . Plug in and test tools on surface. 0.0 148.0 4/29/2024 15:45 4/29/2024 16:15 0.50 INTRM1, DRILLOUT TRIP P Run in hole with HWDP from 148' MD to 797' MD SOW 117K Monitor displacement via trip tank. 148.0 797.0 4/29/2024 16:15 4/29/2024 17:15 1.00 INTRM1, DRILLOUT TRIP P Run in hole from 797' MD to 3110' MD SOW 122K Monitor displacement via trip tank. 797.0 3,110.0 4/29/2024 17:15 4/29/2024 18:15 1.00 INTRM1, DRILLOUT DHEQ P At 3110' MD fill pipe and shallow test tools @ 600 gpm, 2015 psi. 25% FO. Blow down top drive. PUW 156K SOW 150K 3,110.0 3,110.0 4/29/2024 18:15 4/29/2024 21:45 3.50 INTRM1, DRILLOUT TRIP P Run in hole from 3110' MD to 9148' MD SOW 187K Monitor displacement via trip tank. 3,110.0 9,146.0 4/29/2024 21:45 4/29/2024 22:15 0.50 INTRM1, DRILLOUT REAM P Wash and ream from 9148' MD to 9263' MD 600 gpm, 3112 psi, FO 26% 30 rpm, Tq on 7K; WOB 6K ECD 13.0 PUW 272K SOW 220K RW 239K 9,146.0 9,263.0 4/29/2024 22:15 4/29/2024 23:30 1.25 INTRM1, DRILLOUT DRLG P Tag float at 9263' and drill float collar 9270' MD 600 gpm, 2854 psi, FO 24% 40 rpm, Tq on 11K; WOB 6K ECD 13.0 9,263.0 9,270.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 19/54 MT7-91 Report Printed: 6/25/2024 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) 4/29/2024 23:30 4/30/2024 00:00 0.50 INTRM1, DRILLOUT DRLG P Ream cement from 9270' to 9313' 600 gpm, 2942 psi, FO 26% 60 rpm, Tq on 9K; WOB 6K ECD 13.0 PUW 272K SOW 220K RW 239K 9,270.0 9,313.0 4/30/2024 00:00 4/30/2024 02:00 2.00 INTRM1, DRILLOUT DRLG P Ream cement from 9313' to 9354' 600 gpm, 2942 psi, FO 27% 60 rpm, Tq on 9K; WOB 6K ECD 13.5 PUW 242K SOW 198K RW 223K 9,313.0 9,354.0 4/30/2024 02:00 4/30/2024 07:15 5.25 INTRM1, DRILLOUT DRLG P Drill casing shoe from 9354' MD to 9358' MD 600 gpm, 1700 to 2800 psi, FO 26% 30-80 rpm, Tq on 7-20K; WOB 20K ECD 13.1 PUW 250K SOW 200K RW 225K SIMOPS: Freeze protect OA with 71 BBLS diesel @ max rate of 2 BPM . Break over max psi 825, ICP=381, FCP=536 psi at 2 BPM. 9,354.0 9,358.0 4/30/2024 07:15 4/30/2024 07:30 0.25 INTRM1, DRILLOUT REAM P Wash and ream down to 9365' MD 550 gpm, 2370 psi, FO 26% 80 rpm, Tq on 13K; WOB 1K ECD 13.3 9,358.0 9,365.0 4/30/2024 07:30 4/30/2024 08:30 1.00 INTRM1, DRILLOUT REAM P Wash and ream through shoe 3 times from 9365' to 9331' MD, 550 gpm, 2370 psi, FO 26% 80 rpm, Tq on 13K; ECD 13.3 9,365.0 9,365.0 4/30/2024 08:30 4/30/2024 09:15 0.75 INTRM1, DRILLOUT DDRL P Drill 20' of new formation for FIT test 550 gpm, 2340 psi, FO 26% 18K WOB 80 rpm, Tq on 13K; ECD 13.3 9,365.0 9,385.0 4/30/2024 09:15 4/30/2024 10:00 0.75 INTRM1, DRILLOUT CIRC P Circulate bottoms up while rotate and reciprocate from 9385' to 9236' MD. Begin dropping mud weight to 11.0 ppg from 11.5 ppg 525 gpm, 2120 psi, FO 26% 60 rpm, Tq 13K; ECD 13.1 ADT:.6 / Bit hrs .6 / Jar hrs 47.3 9,385.0 9,385.0 4/30/2024 10:00 4/30/2024 11:00 1.00 INTRM1, DRILLOUT MPDA P Drain BOP stack to annular and install RCD as per MPD rep. Fill and pressure test lines. 9,385.0 9,385.0 4/30/2024 11:00 4/30/2024 12:00 1.00 INTRM1, DRILLOUT FIT P Perform FIT test to 14 ppg eqv at 17 spm, 39 strokes total pumped, pressure 925 psi, shut in and hold pressure for 10 minutes. Bled back 4.8 bbls to trip tank. Pump up test data from MWD tools. 550 GPM 2400 psi. 9,385.0 9,385.0 4/30/2024 12:00 4/30/2024 12:45 0.75 INTRM2, DRILL CIRC P Circulate while reciprocate from 9290' MD to 9385' 520 gpm, 1962 psi, FO 26% 80 rpm, Tq 15K; ECD 13.2 9,385.0 9,385.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 20/54 MT7-91 Report Printed: 6/25/2024 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) 4/30/2024 12:45 4/30/2024 15:15 2.50 INTRM2, DRILL DDRL P Drill formation from 9385' MD to 9465' MD 600 gpm, 2400 psi, FO 27% 100 rpm, Tq on 16K; WOB 19K ECD 13.2 Utilizing MPD to maintain ECD/ESD. ADT:1.8 / Bit hrs 2.4 / Jar hrs 49.1 9,385.0 9,465.0 4/30/2024 15:15 4/30/2024 19:00 3.75 INTRM2, DRILL CIRC T Obtain base line parameters with reamer closed. prior to dropping activation 1.25" ball. PUW 280K, SOW 180K 600 gpm, 2400 psi. TRPM 4059. Pump down 1.25' ball at 250 gpm, 860 psi, 20 rpm. 900 strokes. Drop pump rate to 100 gpm, 624 psi, 20 rpm. No indication of ball seat is noted. Attempt various flow rates and rpm to open reamer. Pump 30 bbl HiVis sweep to move potential stuck ball. Discuss with specialist options to open reamer. Pull into shoe several time to verify reamer has not opened no overpull noted. 9,465.0 9,465.0 4/30/2024 19:00 4/30/2024 19:15 0.25 INTRM2, DRILL DDRL T Drill formation from 9465' MD to 9475' MD 600 gpm, 2360 psi, FO 27% 100 rpm, Tq on 15K; WOB 14K ECD 13.2 Utilizing MPD to maintain ECD/ESD. ADT:2 / Bit hrs 2.6 / Jar hrs 49.3 9,465.0 9,475.0 4/30/2024 19:15 4/30/2024 19:45 0.50 INTRM2, DRILL CIRC T Continue to try and ope reamer with variying rates, consult with engineers on plan forward. 9,475.0 9,475.0 4/30/2024 19:45 4/30/2024 20:15 0.50 INTRM2, DRILL BKRM T Backream out of hole from 9475' to 9328' 600 gpm, 2250 psi, FO 26% ECD 12.8 ppg Utilizing MPD to mantain desired ECD/ESD 9,475.0 9,328.0 4/30/2024 20:15 4/30/2024 21:00 0.75 INTRM2, DRILL OWFF T Relieve all MPD pressure and conduct open well flow check 9,328.0 9,328.0 4/30/2024 21:00 5/1/2024 00:00 3.00 INTRM2, DRILL SMPD T Drop 3.5" hollow drift with 100' tail. Strip out of hole utilizing MPD to offset swab from 9328' to 7124' MD. Monitor hole displacment via pit#1. 9,328.0 7,124.0 5/1/2024 00:00 5/1/2024 06:15 6.25 INTRM2, DRILL SMPD T Strip out of hole utilizing MPD to offset swab from 7124' to 819' MD. Monitor hole displacment via pit#1. 7,124.0 819.0 5/1/2024 06:15 5/1/2024 08:00 1.75 INTRM2, DRILL OWFF T Pull wear bushing and stripping rubber, drain stand of drill pipe. Drain riser through 2" RCD line. Monitor well for 15 minutes well static. 819.0 819.0 5/1/2024 08:00 5/1/2024 08:30 0.50 INTRM2, DRILL MPDA T Unclamp RCD bearing and pull RCD to rig floor and rack back in derrick on #1 stand of drillpipe. 819.0 730.0 5/1/2024 08:30 5/1/2024 09:00 0.50 INTRM2, DRILL TRIP T Pull out of hole racking back stands of HWDP and jars. 730' to 581'. puw 110k 730.0 581.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 21/54 MT7-91 Report Printed: 6/25/2024 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) 5/1/2024 09:00 5/1/2024 09:15 0.25 INTRM2, DRILL TRIP T At 581' MD encounter 10 to 20K overpull, slack off to 594' MD and attempt to pull over pull encountered again attempt slack off again and stack out weight. Make up top drive and turn string 1/4" turn with 7K torque and pull free. 581.0 594.0 5/1/2024 09:15 5/1/2024 10:00 0.75 INTRM2, DRILL TRIP T Pull out of hole racking back stands of HWDP. 594' to 146'. puw 85k 594.0 146.0 5/1/2024 10:00 5/1/2024 11:00 1.00 INTRM2, DRILL BHAH T L/D BHA from 146' MD to 86' MD inspecting all components looking for 1.25" reamer ball. 146.0 86.0 5/1/2024 11:00 5/1/2024 11:45 0.75 INTRM2, DRILL BHAH T Continue L/D BHA from 86' MD to surface MD inspecting all components looking for 1.25" reamer ball. Baker rep plug into tools and download data. Break and inspect filter sub. 1.25" reamer ball not located , Rhino reamer and well commander being sent to SLB shop for tear down to locate ball. 86.0 0.0 5/1/2024 11:45 5/1/2024 12:00 0.25 INTRM2, DRILL BHAH T RIH from 44' to 86' to break apart and inspect filter sub 0.0 86.0 5/1/2024 12:00 5/1/2024 12:45 0.75 INTRM2, DRILL BHAH T Continue to M/U BHA, #4 as per DD at reamer drop 1.25" stell ball, install float and M/U collar Stab and XO. 86.0 86.0 5/1/2024 12:45 5/1/2024 13:15 0.50 INTRM2, DRILL BHAH T Screw into XO and pressure up to 1129 PSI with reamer just below the rotary table, observe pressure drop and witness reamer function open and close with pumps off. Visually inspect on surface. 86.0 86.0 5/1/2024 13:15 5/1/2024 13:30 0.25 INTRM2, DRILL BHAH T Continue to P/U BHA and RIH as per DD from 85' to 145'. Monitor displacement via trip tank. Blow down top drive and change elevators. 86.0 145.0 5/1/2024 13:30 5/1/2024 14:15 0.75 INTRM2, DRILL BHAH T RIH with HWDP from derrick from 145' to 795' MD SOW 113K Monitor displacement via trip tank. 145.0 795.0 5/1/2024 14:15 5/1/2024 14:30 0.25 INTRM2, DRILL MPDA T PJSM and install RCD bearing as per MPD advisor. 795.0 795.0 5/1/2024 14:30 5/1/2024 18:00 3.50 INTRM2, DRILL STRP T Strip in hole utilizing MPD to offset surge holding constant 12 ppg eqv at the casing shoe from 795' MD to 5070' MD. SOW 141K 795.0 5,070.0 5/1/2024 18:00 5/1/2024 21:15 3.25 INTRM2, DRILL STRP T Strip in hole utilizing MPD to offset surge holding constant 12 ppg eqv at the casing shoe from 5070' MD to 9333' MD. SOW 141K 5,070.0 9,333.0 5/1/2024 21:15 5/1/2024 21:45 0.50 INTRM2, DRILL REAM P Wsh and ream from 9333' MD to 9455' MD with 100 GPM 796 psi 12% FO. SOW 199K 9,333.0 9,455.0 5/1/2024 21:45 5/1/2024 22:00 0.25 INTRM2, DRILL CIRC P Obtain parameters with reamer open 600 gpm 2745 psi 32% FO Perform 15k pull test with rotation off against 9-5/8" casing shoe. 9,455.0 9,455.0 5/1/2024 22:00 5/1/2024 22:30 0.50 INTRM2, DRILL REAM P Wash and ream in hole from 9455' to 9475' MD 605 GPM, 2470 psi, 50 rpm, 17K TQ. 9,455.0 9,475.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 22/54 MT7-91 Report Printed: 6/25/2024 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) 5/1/2024 22:30 5/1/2024 23:15 0.75 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-7/8" intermediate 2 hole section from 9475' to 9515' MD. 650 gpm, 2745 psi, 32% FO. 140 rpm, 19k TQ, 20K WOB, 13.5 ECD ADT .8 / Bit hrs. 3.4 / 50.1 Jar hours. 9,475.0 9,515.0 5/1/2024 23:15 5/2/2024 00:00 0.75 INTRM2, DRILL CIRC P Circulate and reciprocate to work suspected junk. 9,515.0 9,515.0 5/2/2024 00:00 5/2/2024 06:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-7/8" intermediate 2 hole section from 9515' to 9872' MD, 7526 TVD. 650 gpm, 2600 psi, 37% FO. 140 rpm, 21k TQ on , 17k TQ off, 25K WOB, 13.1 ECD RTW 240K ADT 2.2 / Bit hrs. 5.6 / 52.3 Jar hours. 9,515.0 9,872.0 5/2/2024 06:00 5/2/2024 12:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-7/8" intermediate 2 hole section from 9872' to 10261' MD, 7526 TVD. 575 gpm, 2200 psi, 30% FO. 140 rpm, 23k TQ on 18k TQ off, 25K WOB, 13.1 ECD RTW 240K ADT 4.3 / Bit hrs. 9.9 / 56.6 Jar hours. 9,872.0 10,261.0 5/2/2024 12:00 5/2/2024 18:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-7/8" intermediate 2 hole section from 10261' to 10716' MD, 8039' TVD. 575 gpm, 2208 psi, 36% FO. 130 rpm, 24k TQ on 13K TQ off, 19K WOB, 12.8 ECD RTW 240K, Max gas 2 units ADT 4.9 / Bit hrs. 14.8 / 61.5 Jar hours. 10,261.0 10,716.0 5/2/2024 18:00 5/3/2024 00:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-7/8" intermediate 2 hole section from 10716' to 11115' MD, 8185' TVD. 575 gpm, 2204 psi, 32% FO. 130 rpm, 23k TQ on 13K TQ off, 14K WOB, 12.7 ECD RTW 242K, Max gas 2 units ADT 4.9 / Bit hrs. 14.8 / 61.5 Jar hours. 10,716.0 11,115.0 5/3/2024 00:00 5/3/2024 06:15 6.25 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-7/8" intermediate 2 hole section from 11115' to 11395' MD, 8185' TVD. 575 gpm, 2154 psi, 36% FO. 130 rpm, 24k TQ on 13K TQ off, 19K WOB, 12.6 ECD RTW 247K, Max gas 2 units ADT 5.4 / Bit hrs. 24.8 / 71.5 Jar hours. 11,115.0 11,395.0 5/3/2024 06:15 5/3/2024 07:15 1.00 INTRM2, TRIPCAS CIRC P Obtain final survey and rack one stand back to change out grabber dies. 11,395.0 11,372.0 5/3/2024 07:15 5/3/2024 08:00 0.75 INTRM2, TRIPCAS SVRG P Change top drive grabber dies, observe static losses ~ 50 BPH. Lower surface back pressure to 12 EQV to mitigate. Total loss 55 bbls 11,372.0 11,372.0 5/3/2024 08:00 5/3/2024 09:15 1.25 INTRM2, TRIPCAS CIRC P M/U up working single of 5-7/8" DP and pump 40 Bbl LCM pill while reciprocating pipe from 11,372' MD to 11,310' MD 270 gpm, 693 psi 20 rpm, 11k TQ. 11,372.0 11,372.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 23/54 MT7-91 Report Printed: 6/25/2024 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) 5/3/2024 09:15 5/3/2024 11:00 1.75 INTRM2, TRIPCAS CIRC P Drop 1.625" closing ball to function reamer closed. Pump down at 287 gpm 646 psi. Slow to 96 gpm and 472 psi at 580 strokes in. Ball on seat with 1715 psi at 2133 strokes pumped. Stage pressure up and reamer closed at 2392 psi. 11,372.0 11,372.0 5/3/2024 11:00 5/3/2024 11:30 0.50 INTRM2, TRIPCAS CIRC P Circulate while rotate and reciprocate from 11309' MD to 11228' MD. 575 gpm, 2270 psi. 31 rpm, 11kTQ. 11,372.0 11,372.0 5/3/2024 11:30 5/3/2024 11:45 0.25 INTRM2, TRIPCAS PULD P L/D working single and blow down top drive. 11,372.0 11,278.0 5/3/2024 11:45 5/3/2024 12:00 0.25 INTRM2, TRIPCAS OWFF P Drain RCD and perform 10 minute flowcheck. 11,278.0 11,278.0 5/3/2024 12:00 5/3/2024 15:30 3.50 INTRM2, TRIPCAS SMPD P SOOH utilizing MPD to offset swab. MPD dynamic 560 psi, static 430 psi. Pulling speed 17 FPM. 11,278.0 9,330.0 5/3/2024 15:30 5/3/2024 16:00 0.50 INTRM2, TRIPCAS COND P Prepare pits for 11.5 ppg weight up. Service top drive. 9,330.0 9,330.0 5/3/2024 16:00 5/3/2024 17:15 1.25 INTRM2, TRIPCAS CIRC P Circulate while reciprocate from 9330' MD to 9270' MD While weight up wellbore to 11.5 ppg. 450 gpm, 1543 psi. 80 rpm, 12k TQ. ECD 12.7 660 strokes total to 11.5 ppg. 9,330.0 9,330.0 5/3/2024 17:15 5/3/2024 18:30 1.25 INTRM2, TRIPCAS OWFF P Perform flow check. 9,330.0 9,330.0 5/3/2024 18:30 5/4/2024 00:00 5.50 INTRM2, TRIPCAS SMPD P Strip out of hole from 9930' MD to 4670' MD utilizing MPD to maintain 12.0 ppg ESD at TD and offset swab. PUW 192K 9,330.0 4,670.0 5/4/2024 00:00 5/4/2024 04:15 4.25 INTRM2, TRIPCAS SMPD P Strip out of hole from 4670' MD to 830' MD utilizing MPD to maintain 12.0 ppg ESD at TD and offset swab. PUW 192K 4,670.0 830.0 5/4/2024 04:15 5/4/2024 05:30 1.25 INTRM2, TRIPCAS OWFF P Drain double on stand #1 , pull master bushings and stripping rubbers, drain RCD and monitor well for static conditions. 830.0 830.0 5/4/2024 05:30 5/4/2024 06:15 0.75 INTRM2, TRIPCAS MPDA P Pull RCD bearing as per MPD advisor. 830.0 830.0 5/4/2024 06:15 5/4/2024 06:45 0.50 INTRM2, TRIPCAS BHAH P L/D 2 joints of HWDP and Jars. 830.0 699.0 5/4/2024 06:45 5/4/2024 07:30 0.75 INTRM2, TRIPCAS BHAH P POOH from 699' MD to 146' MD Racking back stands of HWDP. 699.0 146.0 5/4/2024 07:30 5/4/2024 09:30 2.00 INTRM2, TRIPCAS BHAH P C/O elevators and L/D BHA from 146' MD to 0' 146.0 0.0 5/4/2024 09:30 5/4/2024 10:15 0.75 INTRM2, TRIPCAS BHAH P Clean and clear rig floor 0.0 0.0 5/4/2024 10:15 5/4/2024 11:30 1.25 INTRM2, CASING RURD P Mobilize casing running equipment to rig floor and rig up. R/U Volant, install bail extensions and elevators and casing tongs. 0.0 0.0 5/4/2024 11:30 5/4/2024 12:00 0.50 INTRM2, CASING PUTB P PJSM, M/U and RIH with 7-5/8" 29.7# L- 80 Shoe track from surface to 164' MD. Baker lock first 5 pins and torque to 11,900 FT/Lbs. 0.0 164.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 24/54 MT7-91 Report Printed: 6/25/2024 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) 5/4/2024 12:00 5/4/2024 18:30 6.50 INTRM2, CASING PUTB P RIH with 7-5/8" 33.7# P-110 from 164' MD to 2171' MD as per tally. Install 9-1/2" centek centralizers on joints #4 - #18. Torque all connections to 11,900 Ft/lbs with BOL 2000 dope. SOW - 119K, PUW - 129K. Fill pipe every joint and top off every 20 joints. Monitor displacement via pit #5. 164.0 2,171.0 5/4/2024 18:30 5/4/2024 19:30 1.00 INTRM2, CASING RURD P Rig down casing running equipment and clean and clear rig floor. 2,171.0 2,171.0 5/4/2024 19:30 5/4/2024 21:00 1.50 INTRM2, CASING OTHR P PJSM , R/U skud launcher , and P/U TIW 7-5/8" Liner hanger as per DrilQuip rep. 2,171.0 2,171.0 5/4/2024 21:00 5/4/2024 21:45 0.75 INTRM2, CASING CIRC P With liner hanger in string Pick up one stand of drill pipe and break circulation starting at 1/2 BPM and slowly increase rate to 6 BPM in 1/2 BPM increments. final circulating pressure at 6 BPM 548 psi. 2,171.0 2,314.0 5/4/2024 21:45 5/4/2024 22:30 0.75 INTRM2, CASING SMPD P PJSM and install RCD as per per procedure. 2,314.0 2,312.0 5/4/2024 22:30 5/5/2024 00:00 1.50 INTRM2, CASING SMPD P Strip in hole utilizing MPD to offset surge pressure's from 2412' MD to 3639' MD. holding 12.0 ppg EQV at TD. 2,312.0 3,639.0 5/5/2024 00:00 5/5/2024 06:00 6.00 INTRM2, CASING SMPD P Strip in hole utilizing MPD to offset surge pressure's from 3639' MD to 8500' MD. holding 12.0 ppg EQV at TD. Filling pipe every 25 stands, monitor displacement VIA pit #5 3,639.0 8,500.0 5/5/2024 06:00 5/5/2024 06:45 0.75 INTRM2, CASING SMPD P Strip in hole utilizing MPD to offset surge pressure's from 8500' MD to 9200' MD. holding 12.0 ppg EQV at TD. SOW 180K Filling pipe every 25 stands, monitor displacement VIA pit #5 8,500.0 9,200.0 5/5/2024 06:45 5/5/2024 08:15 1.50 INTRM2, CASING REAM P Fill pipe and wash in hole from 9200' MD to 9278' MD and circulate at 545 GPM 425 psi. Obtain T&D parameters at 1 BPM on up stroke and 1/2 BPM on down stroke at 30 FPM. PUW 272K SOW 210K RTW 230K TQ 5-7K 9,200.0 9,278.0 5/5/2024 08:15 5/5/2024 10:30 2.25 INTRM2, CASING SMPD P Strip in hole utilizing MPD to offset surge pressure's from 9278' MD to 11325' MD. holding 12.0 ppg EQV at TD. SOW 240K Filling pipe every 25 stands, monitor displacement VIA pit #5 9,278.0 11,325.0 5/5/2024 10:30 5/5/2024 11:00 0.50 INTRM2, CASING REAM P Fill pipe and circulate down from 11325' MD to 11392' MD At 1/2" BPM, 378 psi, SOW 220K, PUW 310K. Tag bottom at 11392' MD with 30K 11,325.0 11,392.0 5/5/2024 11:00 5/5/2024 12:30 1.50 INTRM2, CASING CIRC P Stage pumps up to 1.5 BPM 450 psi. Reciprocate pipe from 11,392' 10' to 20' foot strokes. PUW 310K SOW 220K. 11,392.0 11,392.0 5/5/2024 12:30 5/5/2024 13:00 0.50 INTRM2, CASING PULD P L/D top single on stand #99 Blow down top drive and P/U 9.88' pup joint. 11,392.0 11,392.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 25/54 MT7-91 Report Printed: 6/25/2024 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) 5/5/2024 13:00 5/5/2024 14:00 1.00 INTRM2, CEMENT RURD P P/U and rig up Citadel cement head. as per SOP rig up hose and pressure test to 6500 psi. 11,392.0 11,392.0 5/5/2024 14:00 5/5/2024 14:30 0.50 INTRM2, CEMENT SFTY P PJSM , with all crews members for cement job obtain final string weights, clean suction screens, line up pits for cement job. PUW 315K SOW 235K 11,392.0 11,388.0 5/5/2024 14:30 5/5/2024 19:45 5.25 INTRM2, CEMENT CMNT P Pump 70 bbl KCL deep clean spacer @ 2 BPM 750 psi. Flood lines 2.8 bbl H2O, pressure test to 5000 psi. Drop bottom dart at 15;30 hours. Pump 67 BBL 15.8 ppg cement at 2 BPM 680 to 83 psi cement wet at 15:33 hrs. Drop top dart at 16:23 hrs. Chase with 10 bbl H2O. @16:31 Chase with OBM from rig at 2 BPM, ICP 217 psi. Drop BOZO at 711 strokes. Pick up bottom wiper plug at 1259 strokes. 380 PSI Pick up top wiper plug at 1810 strokes 1792 psi. Bottom wiper plug at LC at 2009 strokes 2816 psi to shear. top plug at LC 2628 strokes, 600 PSI FCP, pressure up 500 over to 1163 psi and hold for 5 minutes. Losses throughout 264 bbls. 11,388.0 11,388.0 5/5/2024 19:45 5/5/2024 20:15 0.50 INTRM2, CEMENT OTHR P Shear ring on liner hanger at 3924 psi, increase pressure to 5000 psi and hold for 10 minutes to expand hanger, bled down pressure to 500 psi and pick up to 300K bleed pressure to 0 psi. Pick up on string to 380K for a 65K pull test verifying hanger is set. at 11,388' MD. 11,388.0 11,388.0 5/5/2024 20:15 5/5/2024 21:15 1.00 INTRM2, CEMENT RURD P Blow down cement line and rig down cement head, pick up single and slack off to 205K. 11,388.0 11,388.0 5/5/2024 21:15 5/5/2024 21:30 0.25 INTRM2, CEMENT PRTS P Test annulus and liner top to 2000 psi for 10 minutes charted on Totco IA sensor. 11,388.0 11,388.0 5/5/2024 21:30 5/5/2024 22:00 0.50 INTRM2, CEMENT OTHR P Hoist string 17' feet to remove from liner top and additional 33' to clear liner top for BOZO shear. Pump 146 strokes to shear and observe 6453 psi to shear. 11,388.0 9,150.0 5/5/2024 22:00 5/5/2024 23:15 1.25 INTRM2, CEMENT CIRC P L/D pup joint and insert foam balls into string, circulate at 630 gpm at 2400 psi, circulate until shakers clean. 9,150.0 9,150.0 5/5/2024 23:15 5/6/2024 00:00 0.75 INTRM2, CEMENT OWFF P Blow down top drive and perform 30 minute flow check. 9,150.0 9,150.0 5/6/2024 00:00 5/6/2024 00:30 0.50 INTRM2, CEMENT SMPD P Remove RCD bearing. 9,150.0 9,150.0 5/6/2024 00:30 5/6/2024 05:15 4.75 INTRM2, CEMENT PULD P Break down 5-7/8" HWDP and 5-7/8" drillpipe from derrick. 9,150.0 9,150.0 5/6/2024 05:15 5/6/2024 09:45 4.50 INTRM2, CEMENT TRIP P Trip out of hole racking back stands of 5 -7/8" drillpipe and racking back in derrick. 9,150.0 0.0 5/6/2024 09:45 5/6/2024 11:30 1.75 INTRM2, CEMENT OTHR P Clean and lay down Drill Quip liner running tool. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 26/54 MT7-91 Report Printed: 6/25/2024 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) 5/6/2024 11:30 5/6/2024 13:00 1.50 INTRM2, WHDBOP WWWH P M/U stack washer and wash BOP stack with deep clean pill. 0.0 0.0 5/6/2024 13:00 5/6/2024 14:30 1.50 INTRM2, WHDBOP RURD P Drain BOP stack close blind rams Power down Koomey and change upper VBR's to 3-1/2" x 6-5/8" VBR's. SIMOPs make up test joints. 0.0 0.0 5/6/2024 14:30 5/6/2024 15:30 1.00 INTRM2, WHDBOP RURD P Pull wear ring and set test plug with 4- 1/2" test joints as per FMC rep. Flood surface lines and fill BOP stack with water. Conduct shell test to 2500 psi. 0.0 0.0 5/6/2024 15:30 5/6/2024 21:00 5.50 INTRM2, WHDBOP BOPE P Perform BOPE test with 4-1/2" & 5-7/8" test jts. Annular to 250 psi low for 5 minutes and 2500 psi high for 10 minutes. Remaining tests to 250 psi low for 5 minutes and 3500 psi high for 10 minutes. #1 Annular with 4-1/2" test joint #2 Upper 3-1/2" x 6-5/8" VBR's with 4- 1/2" test joint, CMV 1,14,15,16.& Kill #3 #3 CMV #10, 13, needle valve above #1, HCR Kill, Upper IBOP. #4 CMV #4, 9, 12, Manual Kill & Lower IBOP. #5 CMV #6, 8, 11 #6 CMV #5, 7 & 5-7/8" Dart. #7 CMV #2 & 5-7/8" TIW #8 HCR Choke #9 Manual Choke #10 Lower 3-1/2" x 6-5/8" VBR's with 4- 1/2" test joint. #11 Blind shear rams & CMV #3, 4, 6 #12 Manual & Super choke to 1500 psi. #13 Upper 3-1/2" x 6-5/8" VBR's with 5- 7/8" test joints and 4-1/2" Dart #14 Lower 3-1/2" x 6-5/8" VBR's with 5- 7/8" test joints & 4-1/2" TIW. Conduct Koomey draw down test, ACC = 3050 psi, Manifold = 1550 psi, ACC 1700 psi after all functions on bottles, 14 seconds for 200 psi build up with 2 electric pumps, 83 seconds to full system pressure with 2 electric pups and air pumps, closing times: ANN = 13 seconds, UPR = 13 seconds Blind shear = 14 seconds, LPR = 12 seconds. Choke HCR = 1 second, Kill HCR 1 second, Test PVT gain/loss and flow out alarms, 10 bottles nitrogen backup average 3900 psi. test LEL and H2S alarms. Witness waived by AOGCC Brian Bixby and BLM Sawyer Quinn 0.0 0.0 5/6/2024 21:00 5/6/2024 21:45 0.75 INTRM2, WHDBOP RURD P Pull test plug and set wear bushing , blow down choke manifold, Kill line and choke line, drain BOP stack and set wear bushing. L/D test joints and pups, clean and clear rig floor. Mobilize BHA to rig floor. 0.0 0.0 5/6/2024 21:45 5/6/2024 23:15 1.50 INTRM2, CEMENT BHAH P PJSM and P/U 6-1/2" x 6-5/8" BHA as per DD from 0' MD to 172'. Sonic Picked up at 22:30. 0.0 172.0 5/6/2024 23:15 5/7/2024 00:00 0.75 INTRM2, CEMENT PULD P RIH with 4.5" singles from pipeshed from 172' MD to 644' MD 172.0 644.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 27/54 MT7-91 Report Printed: 6/25/2024 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) 5/7/2024 00:00 5/7/2024 04:00 4.00 INTRM2, CEMENT PULD P Run in hole with 4-1/2" singles from pipeshed, from 644' MD to 3942' MD. SOW 116K Monitor displacement via trip tank fill pipe every 25 stands. 644.0 3,942.0 5/7/2024 04:00 5/7/2024 04:30 0.50 INTRM2, CEMENT DLOG P Run in hole at reduced speed to 1800 FPH for sonic logging free ringing pipe from 3942' MD to 4230' MD as per SLB rep. 3,942.0 4,230.0 5/7/2024 04:30 5/7/2024 06:00 1.50 INTRM2, CEMENT PULD P Run in hole with 4-1/2" singles from pipeshed, from 4230' MD to 4824' MD. SOW 116K Monitor displacement via trip tank fill pipe every 25 stands. 4,230.0 4,824.0 5/7/2024 06:00 5/7/2024 06:30 0.50 INTRM2, CEMENT SVRG P Service blocks and top drive. 4,824.0 4,824.0 5/7/2024 06:30 5/7/2024 06:45 0.25 INTRM2, CEMENT PULD P Run in hole with 4-1/2" singles from pipeshed, from 4824' MD to 4948' MD. SOW 132K Monitor displacement via trip tank fill pipe every 25 stands. 4,824.0 4,948.0 5/7/2024 06:45 5/7/2024 13:15 6.50 INTRM2, CEMENT DLOG P Run in hole at reduced speed to 1800 FPH for sonic logging free ringing pipe from 4948' MD to 9195' MD as per SLB rep. SOW 160K Monitor displacement via trip tank fill pipe every 25 stands. 4,948.0 9,195.0 5/7/2024 13:15 5/7/2024 15:45 2.50 INTRM2, CEMENT DRLG P Wash in hole from 9195' MD to DPOB tagged at 9217' MD drill DPOB as per DD, work to 9322' MD Work mill to DPOB depth and work through three times to clean. gpm 250. psi 1100, rpm 50, TQ 6K, WOB 5-6K, FO 11% 9,195.0 9,322.0 5/7/2024 15:45 5/7/2024 18:30 2.75 INTRM2, CEMENT DLOG P Run in hole at reduced speed to 1800 FPH for sonic logging free ringing pipe from 9322' MD to 10925' MD as per SLB rep. SOW 165K Monitor displacement via trip tank fill pipe every 25 stands. 9,322.0 10,925.0 5/7/2024 18:30 5/7/2024 19:45 1.25 INTRM2, CEMENT CIRC P Circulate and reciprocate from 10925' MD to 10900 MD to get even in even out mud weight. gpm 250, psi 1165, rpm 40, TQ 6k FO 6%. 4100 strokes pumped for 11.1+ in and out MDWT. 10,925.0 10,925.0 5/7/2024 19:45 5/7/2024 21:00 1.25 INTRM2, CEMENT PRTS P Conduct casing test with pipe rams closed. Flood surface lines and pump 57 strokes at 1/2 BPM, pressure up to 2065 psi and note rapid pressure decrease. Verify all surface equipment is intact, isolate well bore and monitor pressure , note pressure is dropping. Isolate surface equipment and pressure up to 3000 psi and monitor, no pressure loss recorded on surface equipment. Bleed off pressure and restart test, pump 45 strokes and 1303 psi and note pressure not increase as predicted, Stop pumps and isolate wellbore, record pressure dropping from 1288 to 725 psi in 5 minutes. 10,925.0 10,925.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 28/54 MT7-91 Report Printed: 6/25/2024 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) 5/7/2024 21:00 5/7/2024 21:30 0.50 INTRM2, CEMENT OWFF P Perform 30 minute flow check 10,925.0 10,925.0 5/7/2024 21:30 5/7/2024 22:00 0.50 INTRM2, CEMENT RURD P Rack back stand #115 and install stripping rubbers and prepare floor for tripping operations. Pump 30 bbl dry job of 13.2 ppg slug, blow down top drive. 10,925.0 10,831.0 5/7/2024 22:00 5/8/2024 00:00 2.00 INTRM2, CEMENT TRIP P Pull out of hole from 10831' to 5874'. 10,831.0 5,874.0 5/8/2024 00:00 5/8/2024 02:45 2.75 INTRM2, CEMENT TRIP P Tripped out of the hole from 5874'-187' MD. PUW 78K 5,874.0 187.0 5/8/2024 02:45 5/8/2024 03:00 0.25 INTRM2, CEMENT OWFF P Monitored, well static for 10 minutes. SIMOPS removed stripping rubbers. 187.0 187.0 5/8/2024 03:00 5/8/2024 04:00 1.00 INTRM2, CEMENT BHAH P Laid down clean out BHA as per Baker DD. 187.0 0.0 5/8/2024 04:00 5/8/2024 04:45 0.75 INTRM2, CEMENT BHAH P Cleaned & cleared rig floor. 0.0 0.0 5/8/2024 04:45 5/8/2024 08:00 3.25 INTRM2, CEMENT SLPC P Cut and slipped 113' of drilling line. Inspected brakes. Adjusted brake #1 & 3. Calibrated block height to Amphion. 0.0 0.0 5/8/2024 08:00 5/8/2024 09:45 1.75 INTRM2, CEMENT PRTS P Closed blind rams & performed casing pressure test to 3600 psi. Pumped 12.7 bbls of 11.1 ppg OBM at .6 bpm, pressuring up to 3603 psi. Shut in and observed pressure for 30 minutes, final shut in pressure 3554 psi. Bled back 11.3 bbls. 0.0 0.0 5/8/2024 09:45 5/8/2024 10:45 1.00 INTRM2, DRILLOUT BHAH P Mobilized BHA to the rig floor. Prepped BHA in the pipe shed to pick up. 0.0 0.0 5/8/2024 10:45 5/8/2024 14:15 3.50 INTRM2, DRILLOUT BHAH P Made up 6-1/2" production drilling BHA as per Baker DD to 222' MD. 0.0 222.0 5/8/2024 14:15 5/8/2024 15:15 1.00 INTRM2, DRILLOUT TRIP P Tripped in the hole from 222'-2581' MD. SOW 103K 222.0 2,581.0 5/8/2024 15:15 5/8/2024 15:45 0.50 INTRM2, DRILLOUT DHEQ P Filled drill pipe & tested tools at 225 gpm, 1125 psi, FO 9%. 2,581.0 2,581.0 5/8/2024 15:45 5/8/2024 18:00 2.25 INTRM2, DRILLOUT TRIP P Tripped in the hole from 2581'-6927' MD. SOW 136K 2,581.0 6,927.0 5/8/2024 18:00 5/8/2024 19:45 1.75 INTRM2, DRILLOUT TRIP P Tripped in the hole from 6927'-10,140' MD. SOW 162K 6,927.0 10,140.0 5/8/2024 19:45 5/8/2024 20:45 1.00 INTRM2, DRILLOUT QEVL P Tripped in the hole performing MAD pass at 1800 fph from 10,140'-10,976' MD. SOW 163K 10,140.0 10,976.0 5/8/2024 20:45 5/8/2024 21:45 1.00 INTRM2, DRILLOUT REAM P Reamed down from 10,976'-11,220' MD to tag plugs on float collar. 205 gpm, 1579 psi, FO 7% 40 rpm, Tq 7K ECD 11.9 PUW 223K SOW 172K RW 192K 10,976.0 11,220.0 5/8/2024 21:45 5/9/2024 00:00 2.25 INTRM2, DRILLOUT DRLG P Drilled on plugs & landing collar 11,220' MD with varying parameters. 175-205 gpm, 944 psi, FO 6% 40-80 rpm, Tq 7K ECD 11.8 WOB 10-20K 11,220.0 11,220.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 29/54 MT7-91 Report Printed: 6/25/2024 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) 5/9/2024 00:00 5/9/2024 04:15 4.25 INTRM2, DRILLOUT DRLG P Drilled on plugs & landing collar from 11,220'-11,224' MD with varying parameters. Reamed landing collar twice. 162-205 gpm, 944-1450 psi, FO 3-6% 20-80 rpm, Tq 4-12K ECD 11.6 WOB 15-30K PUW 225K SOW 180K RW 202K 11,220.0 11,224.0 5/9/2024 04:15 5/9/2024 06:00 1.75 INTRM2, DRILLOUT DRLG P Drilled cement from 11,224'-11,299' MD. 203 gpm, 1445 psi, FO 6% 80 rpm, Tq 9K ECD 11.7 WOB 1-2K PUW 225K SOW 180K RW 202K 11,224.0 11,299.0 5/9/2024 06:00 5/9/2024 07:00 1.00 INTRM2, DRILLOUT DRLG P Drilled float collar from 11,299'-11,302' MD. Reamed collar 3 times. 203 gpm, 1377 psi, FO 6% 61 rpm, Tq 7-10K ECD 11.7 WOB 20K PUW 225K SOW 180K RW 202K 11,299.0 11,302.0 5/9/2024 07:00 5/9/2024 08:15 1.25 INTRM2, DRILLOUT DRLG P Drilled cement from 11,302'-11,383' MD. 203 gpm, 1394 psi, FO 6% 61 rpm, Tq 9K ECD 11.7 WOB 1-2K PUW 225K SOW 180K RW 202K 11,302.0 11,383.0 5/9/2024 08:15 5/9/2024 12:00 3.75 INTRM2, DRILLOUT DISP P Displace well from 11.3 ppg NAF to 8.8 ppg FloPro mud system as per Mud Engineer plan. Pumped 20 bbls LVT, 100 bbls of weighted vis. spacer, 100 bbls of cleaning spacer, & 35 bbls of hi vis spacer. Pumped 710 bbls of 8.8 ppg FloPro back to surface. 250 gpm, 1910 psi 60 rpm, Tq 8K. 11,383.0 11,383.0 5/9/2024 12:00 5/9/2024 13:30 1.50 INTRM2, DRILLOUT CLEN P Flushed all surface equipment with cleaning pill. Cleaned drip pan. Blew down kill & choke lines. Flushed Baker skid & MPD equipment. Cleaned pits and offloaded mud from pits. 11,383.0 11,383.0 5/9/2024 13:30 5/9/2024 19:45 6.25 INTRM2, DRILLOUT DRLG P Reamed remaining cement and shoe from 11,383'-11,388' MD at varying parameters. 175-225 gpm, 720-925 psi 40-80 rpm, Tq 4-8K WOB 15-30K 11,383.0 11,388.0 5/9/2024 19:45 5/9/2024 20:15 0.50 INTRM2, DRILLOUT DRLG P Drilled cement in the rat hole from 11,388'-11,395' MD. Reamed through the shoe 5 times. 225 gpm, 910 psi 80 rpm, Tq 4K WOB 15-30K 11,388.0 11,395.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 30/54 MT7-91 Report Printed: 6/25/2024 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) 5/9/2024 20:15 5/9/2024 20:45 0.50 INTRM2, DRILLOUT FIT P Conducted a FIT to an EMW of 12.0 ppg with 8.8 ppg mud with the shoe at 8266' TVD. Pressured up 4.2 bbls, pumping at 1/2 bpm to 1391psi and shut in. Monitored pressure for 10 minutes with a final pressure of 1261 psi. bled back 4.0 bbls. 11,395.0 11,395.0 5/9/2024 20:45 5/9/2024 21:15 0.50 INTRM2, DRILLOUT CIRC P Circulated MWD data up at 250 gpm, 1054 psi. 11,395.0 11,395.0 5/9/2024 21:15 5/9/2024 21:45 0.50 INTRM2, DRILLOUT DDRL P Directional drilled 6-1/2 production section from 11,395'-11,415' MD, 8272' TVD. 250 gpm, 1035 psi, FO 6% 80 rpm, Tq on 6K, off 2K WOB 10K ECD 9.12 PUW 216K SOW 191K RW 202K ADT.59, BIT .59 11,395.0 11,415.0 5/9/2024 21:45 5/9/2024 23:30 1.75 INTRM2, DRILLOUT CIRC P Circulated bottoms up reciprocating. 245 gpm, 1074 psi, FO 4% 80 rpm, Tq 4K ECD 9.1 11,415.0 11,356.0 5/9/2024 23:30 5/10/2024 00:00 0.50 INTRM2, DRILLOUT FIT P Conducted a FIT to an EMW of 11.9 ppg with 8.8 ppg mud with the shoe at 8266' TVD. Pressured up 4.3 bbls, pumping at 1/2 bpm to 1344 psi and shut in. Monitored pressure for 10 minutes with a final pressure of 1253 psi. bled back 4.0 bbls. Decision made to retest to 12.0 ppg due to discrepancy in shut in pressure. 11,356.0 11,356.0 5/10/2024 00:00 5/10/2024 00:30 0.50 INTRM2, DRILLOUT FIT P Conducted a FIT to an EMW of 12.0 ppg with 8.8 ppg mud with the shoe at 8266' TVD. Pressured up 5.0 bbls, pumping at 1/2 bpm to 1383 psi and shut in. Monitored pressure for 10 minutes with a final pressure of 1280 psi. bled back 4.6 bbls. 11,356.0 11,356.0 5/10/2024 00:30 5/10/2024 01:30 1.00 PROD1, DRILL OWFF T Monitored well, with slight flow observed. 11,356.0 11,356.0 5/10/2024 01:30 5/10/2024 03:00 1.50 PROD1, DRILL CIRC T Circulated bottoms up, reciprocating at 250 gpm, 1092 psi, 40 rpm, Tq 4K. Observed signs mud was aired up. 11,356.0 11,356.0 5/10/2024 03:00 5/10/2024 03:15 0.25 PROD1, DRILL OWFF T Monitored well, with slight flow observed. 11,356.0 11,356.0 5/10/2024 03:15 5/10/2024 03:45 0.50 PROD1, DRILL CIRC T Circulated ~180 bbls reciprocating at 250 gpm, 1100 psi, 40 rpm, Tq 4K. 11,356.0 11,356.0 5/10/2024 03:45 5/10/2024 04:45 1.00 PROD1, DRILL OWFF T Monitored well, with slight flow observed. 11,356.0 11,356.0 5/10/2024 04:45 5/10/2024 05:15 0.50 PROD1, DRILL CIRC T Circulated ~180 bbls reciprocating at 250 gpm, 1085 psi, 40 rpm, Tq 4K. 11,356.0 11,356.0 5/10/2024 05:15 5/10/2024 07:45 2.50 PROD1, DRILL OWFF T Monitored well, with slight flow observed. Lined up to observe flow at BOP deck, measuring flow with vis cup. Established decreasing flow rate trend from 85 seconds to 111 seconds over 1.3 hours. 11,356.0 11,356.0 5/10/2024 07:45 5/10/2024 09:00 1.25 PROD1, DRILL MPDA T Blew down top drive. Prepped floor for installation. Installed 4-1/2" bearing per MPD Advisor. Tested MPD system with MP #3. 11,356.0 11,356.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 31/54 MT7-91 Report Printed: 6/25/2024 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) 5/10/2024 09:00 5/10/2024 10:45 1.75 PROD1, DRILL SMPD T Stripped out of the hole from 11,356'- 10,175' MD holding an 8.8 EMW at the shoe, pulling 50 fpm. PUW 219K. Encountered 20-30K over pull at 11,262', 10,197', 10,175' MD. 11,356.0 10,175.0 5/10/2024 10:45 5/10/2024 11:30 0.75 PROD1, DRILL BKRM T Ran back in the hole to 10,219' MD. Backreamed up to 10,124' MD. 250 gpm, 1065 psi 40 rpm, Tq 3-4K PUW 197K SOW 180K RW 197K 10,175.0 10,124.0 5/10/2024 11:30 5/10/2024 12:30 1.00 PROD1, DRILL SMPD T Stripped out of the hole from 10,124- 9368' MD holding an 8.8 EMW at the shoe, pulling 50 fpm. PUW 208K, SOW 178K. 10,124.0 9,368.0 5/10/2024 12:30 5/10/2024 13:00 0.50 PROD1, DRILL CIRC T Dropped 1.75" stainless steel ball to open Well Commander. Circulated ball down at 84 gpm, 234 psi, 17 rpm, Tq 3K. Ball on seat with 33.6 bbls pumped. Held 1300 psi for 30 seconds. Increased to 1713 psi to function open. 9,368.0 9,368.0 5/10/2024 13:00 5/10/2024 14:00 1.00 PROD1, DRILL CIRC T Pumped 40 bbls of high vis sweep while pulling from 9368'-9321' MD to position Well Commander ports at 7-5/8" liner top. Staged up pump rate as ports exited the liner top. 260-650 gpm, 460-1290 psi, FO 16% 10 rpm, Tq 3K PUW 208K SOW 178K RW 180K 9,368.0 9,321.0 5/10/2024 14:00 5/10/2024 14:45 0.75 PROD1, DRILL CIRC T Dropped 1.75" stainless steel ball. Attempted to strip & observed floats leaking by. Made up top drive to the string and pumped ball down on seat with 26.7 bbls at 84 gpm, 168 psi. Ball on seat with 1050 psi. Pressured up to 1899 psi to close Well Commander. 9,321.0 9,321.0 5/10/2024 14:45 5/10/2024 18:00 3.25 PROD1, DRILL SMPD T Stripped out of the hole from 9321'- 6069' MD holding an 8.8 EMW at the shoe, pulling 50 fpm. PUW 155K 9,321.0 6,069.0 5/10/2024 18:00 5/10/2024 23:00 5.00 PROD1, DRILL SMPD T Stripped out of the hole from 6069'-316' MD holding an 8.8 EMW at the shoe, pulling 50 fpm. PUW 83K 6,069.0 316.0 5/10/2024 23:00 5/11/2024 00:00 1.00 PROD1, DRILL OWFF T Shut down backside pump. Drained MPD equipment. Lined up & began establishing trend for decreasing flow. 316.0 316.0 5/11/2024 00:00 5/11/2024 00:15 0.25 PROD1, DRILL OWFF T Monitored well, establishing decreasing flow rate trend. 316.0 316.0 5/11/2024 00:15 5/11/2024 00:45 0.50 PROD1, DRILL MPDA T Removed MPD bearing as per Advisor, racking it back on a stand of drill pipe from 316'-220' MD. 316.0 220.0 5/11/2024 00:45 5/11/2024 04:00 3.25 PROD1, DRILL BHAH T Laid down Sonic tool, string stab. Changed out the Well Commander & bit. Inspected all tools & plugged into MWD to check tools. 220.0 0.0 5/11/2024 04:00 5/11/2024 06:45 2.75 PROD1, DRILL BHAH T Made up new 6-1/2" PDC bit & Well Commander. Picked up remaining BHA to 183' MD. 0.0 183.0 5/11/2024 06:45 5/11/2024 08:00 1.25 PROD1, DRILL TRIP T Tripped in the hole from 183'-2540' MD. SOW 107K 183.0 2,540.0 5/11/2024 08:00 5/11/2024 09:00 1.00 PROD1, DRILL DHEQ T Shallow hole tested tools at 200 gpm, 530 psi. Good test. 2,540.0 2,540.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 32/54 MT7-91 Report Printed: 6/25/2024 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) 5/11/2024 09:00 5/11/2024 12:00 3.00 PROD1, DRILL TRIP T Tripped in the hole from 2540'-6800' MD. Filled pipe every 25 stands. PUW 156K, SOW 144K. 2,540.0 6,800.0 5/11/2024 12:00 5/11/2024 15:30 3.50 PROD1, DRILL TRIP T Tripped in the hole from 6800'-10,880' MD. Filled pipe every 25 stands. PUW 215K, SOW 181K. 6,800.0 10,880.0 5/11/2024 15:30 5/11/2024 17:30 2.00 PROD1, DRILL REAM T Ran into debris at 10,880' MD, with 30K WOB. Worked pipe down from 10,880'- 10,926' MD, with 5-30K WOB. Pulled back up to 10,907' MD. Made up XO to top drive and washed down to 11,018' MD to see 26K WOB. Reamed down to 11,028' MD. 200 gpm, 800 psi 20 rpm, Tq 4K PUW 220K SOW 186K RW 205K 10,880.0 11,028.0 5/11/2024 17:30 5/11/2024 18:45 1.25 PROD1, DRILL WASH T Washed down from 11,028'-11,312' MD at 200 gpm, 754 psi. PUW 220K, SOW 186K 11,028.0 11,312.0 5/11/2024 18:45 5/11/2024 19:45 1.00 PROD1, DRILL MPDA T Made up bearing stand & installed RCD as per Advisor. Tested MPD equipment as per Advisor. 11,312.0 11,312.0 5/11/2024 19:45 5/11/2024 20:15 0.50 PROD1, DRILL REAM T Washed down from 11,312'-11,415' MD 200 gpm, 754 psi. FO 4-7% ECD 9.1 PUW 220K, SOW 186K 11,312.0 11,415.0 5/11/2024 20:15 5/11/2024 22:30 2.25 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 11,415'-11,511' MD, 8289' TVD 200 gpm, 825 psi, FO 3-7 80 rpm, Tq on 7K, off 5K WOB 17K 9.2 ECD Gas 0 PUW 224K SOW 190K RW 209K ADT 1.72. BIT 1.72 11,415.0 11,511.0 5/11/2024 22:30 5/12/2024 00:00 1.50 PROD1, DRILL DHEQ T Troubleshoot MWD. MWD was pulsing intermittently. Started to pull back inside the shoe to troubleshoot. A hard reboot was done while pumps were off for 10 minutes. MWD working correctly after. 200 gpm, 800 psi, 20 rpm, Tq 4K 11,511.0 11,404.0 5/12/2024 00:00 5/12/2024 01:00 1.00 PROD1, DRILL REAM T Reamed from 11,404'-11,515' MD 220 gpm, 750 psi, FO 7 20 rpm, Tq 4K ECD 9.1 PUW 220K SOW 186K 11,404.0 11,515.0 5/12/2024 01:00 5/12/2024 06:00 5.00 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 11,511'-12,010' MD, 8330' TVD 200 gpm, 1081 psi, FO 9 220 rpm, Tq on 6K, off 3K WOB 14K 9.5 ECD Max Gas 53 PUW 226K SOW 180K RW 203K ADT 3.3. BIT 5.0 11,515.0 12,010.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 33/54 MT7-91 Report Printed: 6/25/2024 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) 5/12/2024 06:00 5/12/2024 08:45 2.75 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 12,010'-12,320' MD, 8351' TVD. Losses observed ~12,250' MD about 60 bph. 200 gpm, 1401 psi, FO 7 150 rpm, Tq on 8K, off 5K WOB 18K 9.4 ECD PUW 231K SOW 180K RW 203K ADT 1.7. BIT 6.7 12,010.0 12,320.0 5/12/2024 08:45 5/12/2024 09:15 0.50 PROD1, DRILL CIRC P Pumped 50 bbls of 35 ppb LCM pill. Reduced flow rate to 140 gpm, 609 psi as pill went through the BHA. 12,320.0 12,320.0 5/12/2024 09:15 5/12/2024 12:00 2.75 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 12,320'-12,539' MD, 8359' TVD. 220 gpm, 1177 psi, FO 8 150 rpm, Tq on 10K, off 6K WOB 18K 9.7 ECD PUW 238K SOW 175K RW 200K ADT 1.7. BIT 8.4 12,320.0 12,539.0 5/12/2024 12:00 5/12/2024 14:15 2.25 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 12,539'-12,823 MD, 8358' TVD. 220 gpm, 1288 psi, FO 11 150 rpm, Tq on 10K, off 6K WOB 18-22K 9.9 ECD PUW 238K SOW 175K RW 202K ADT 1.4. BIT 9.8 12,539.0 12,823.0 5/12/2024 14:15 5/12/2024 17:00 2.75 PROD1, DRILL DHEQ T Troubleshot MWD tools that quit pulsing. Pumped 25 bbls of H2O at 140 gpm across the tools with no success. Pumped 25 bbls of H2O at 250 gpm across the tools with no success. Tried reboot with pumps off for 10 minutes with no success. Decision made to trip out of the hole for tools. 12,823.0 12,823.0 5/12/2024 17:00 5/12/2024 18:30 1.50 PROD1, DRILL SMPD T Stripped out of the hole from 12,823'- 12,445' MD. Observed 30K over pull at 12,370' MD. Attempted 2 times to pull past. Worked back down to 12,445' MD. PUW 230K SOW 176K 12,823.0 12,445.0 5/12/2024 18:30 5/12/2024 23:30 5.00 PROD1, DRILL BKRM T Backreamed out of the hole from 12,445'-11,522' MD. Indications showed pulling debris up the hole with the string. Tried varying parameters to get past it. Observed pressure increase at 11,564' MD & MWD turned on. Verified tools working, no issues. 41-200 gpm, 220-909 psi 5-120 rpm, Tq 5-15K PUW 215K SOW 178K RW 197K 12,445.0 11,522.0 5/12/2024 23:30 5/13/2024 00:00 0.50 PROD1, DRILL TRIP T Tripped in the hole from 11,522'-11,739' MD. SOW 181K. 11,522.0 11,739.0 5/13/2024 00:00 5/13/2024 01:45 1.75 PROD1, DRILL TRIP T Tripped in the hole from 11,739'-12,729' MD. SOW 177K. 11,739.0 12,729.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 34/54 MT7-91 Report Printed: 6/25/2024 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) 5/13/2024 01:45 5/13/2024 02:15 0.50 PROD1, DRILL REAM T Reamed from 12,729'-12,823' MD. 220 gpm, 1221 psi 150 rpm, Tq 10K PUW 230K SOW 175K RW 201K 12,729.0 12,823.0 5/13/2024 02:15 5/13/2024 06:30 4.25 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 12,823'-13,229' MD, 8354' TVD. Losses encountered at 13,101' MD. 220 gpm, 1258 psi, FO 7 150 rpm, Tq on 10K, off 4K WOB 19K 9.9 ECD PUW 230K SOW 175K RW 201K ADT 2.6. BIT 12.4 12,823.0 13,229.0 5/13/2024 06:30 5/13/2024 08:30 2.00 PROD1, DRILL CIRC T Circulated to clean open hole & monitor losses. Pumped 140 bbls of 35 ppb LCM pill at 130 gpm, 480 psi, 60 rpm, Tq 7K 13,229.0 13,229.0 5/13/2024 08:30 5/13/2024 09:45 1.25 PROD1, DRILL CIRC T Troubleshot MWD 100 gpm, 426 psi, 60 rpm, Tq 7K. Pumped 30 bbls of H2O to flush MWD & functioned downlink. Tried varying parameters.Tools on. 13,229.0 13,229.0 5/13/2024 09:45 5/13/2024 11:15 1.50 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 13,229'-13,388' MD, 8355' TVD. 182 gpm, 916 psi, FO 1 150 rpm, Tq on 10K, off 7K WOB 15K 9.4 ECD PUW 230K SOW 178K RW 199K ADT 1.1. BIT 13.5 13,229.0 13,388.0 5/13/2024 11:15 5/13/2024 13:30 2.25 PROD1, DRILL MPDA P Pulled 4-1/2" MPD bearing on a stand of drill pipe and racked back in the derrick. Installed 5-7/8" MPD bearing as per advisor. Static losses at 24 bph. 13,388.0 13,388.0 5/13/2024 13:30 5/13/2024 15:15 1.75 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 13,388'-13,571' MD, 8358' TVD. 180 gpm, 920 psi, FO 1 150 rpm, Tq on 10K, off 7K WOB 20K 9.5 ECD PUW 230K SOW 174K RW 205K ADT .9. BIT 14.4 13,388.0 13,571.0 5/13/2024 15:15 5/13/2024 15:45 0.50 PROD1, DRILL CIRC T Troubleshot MWD with varying parameters. 200-260 gpm, 830-1140 psi 13,571.0 13,571.0 5/13/2024 15:45 5/13/2024 16:30 0.75 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 13,571'-13,665' MD, 8359' TVD. Losses ~120 bph while drilling. 180 gpm, 920 psi, FO 1 150 rpm, Tq on 10K, off 7K WOB 10-20K 9.5 ECD PUW 232K SOW 174K RW 207K ADT .6. BIT 15.0 13,571.0 13,665.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 35/54 MT7-91 Report Printed: 6/25/2024 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) 5/13/2024 16:30 5/13/2024 18:45 2.25 PROD1, DRILL CIRC T Pumped 80 bbls of 35 ppb LCM with 15 bbls of H2O ahead & behind pill. Slowed rate to 120 gpm as pill crossed the BHA. Dynamic losses ~65-75 bph, no losses static. 180 gpm, 880 psi 80 rpm, Tq 8K ECD 9.4 13,665.0 13,665.0 5/13/2024 18:45 5/13/2024 19:30 0.75 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 13,665'-13,759' MD, 8360' TVD. Losses ~120 bph while drilling. 180 gpm, 855 psi, FO 1 150 rpm, Tq on 10K, off 7K WOB 13K 9.5 ECD PUW 232K SOW 174K RW 207K ADT .5. BIT 15.5 13,665.0 13,759.0 5/13/2024 19:30 5/13/2024 20:30 1.00 PROD1, DRILL CIRC T Established dynamic loss rate at 210 bph & static at 50-60 bph. Decision made to trip to the shoe to pump Thixotropic cement. 13,759.0 13,759.0 5/13/2024 20:30 5/13/2024 21:00 0.50 PROD1, DRILL SMPD T Stripped out of the hole from 13,759'- 13,481' MD. MPD choke open. Observed loss rate increase to 130 bph. 13,759.0 13,481.0 5/13/2024 21:00 5/13/2024 23:45 2.75 PROD1, DRILL CIRC T Pumped 70 bbls of 35 ppb LCM with 15 bbls of H2O ahead & behind pill. Dynamic losses 78 bph, static losses 42 bph. 103 gpm, 418 psi 20 rpm, Tq 5K 13,481.0 13,481.0 5/13/2024 23:45 5/14/2024 00:00 0.25 PROD1, DRILL SMPD T Stripped out of the hole from 13,481'- 13,319' MD. MPD choke open. Prepared for bearing swap. PUW 240K. 13,481.0 13,319.0 5/14/2024 00:00 5/14/2024 01:45 1.75 PROD1, DRILL MPDA T Changed out MPD bearing from 5-7/8" to 4-1/2". Racked back 5-7/8" bearing on last stand of drill pipe. Blew down top drive. 13,319.0 13,294.0 5/14/2024 01:45 5/14/2024 05:45 4.00 PROD1, DRILL SMPD T Stripped out of the hole from 13,294'- 11,374' MD. Circulated across the top with back pressure pump & MPD choke open. Loss rate 40-60 bph. Observed 30K over pull at 11,626' & 11,448' MD; dropped down and pulled past with no weight increase both times. PUW 227K SOW 184K. Laid down top single from stand for cementing. 13,294.0 11,374.0 5/14/2024 05:45 5/14/2024 06:15 0.50 PROD1, DRILL CIRC T Pumped 235 gpm, 1065 psi to function Baker steering off. Blew down top drive. SIMOPs blew air through cement line to SLB; greased wash pipe; changed elevators; closed lower IBOP. 11,374.0 11,374.0 5/14/2024 06:15 5/14/2024 08:15 2.00 PROD1, DRILL RURD T Made up cement swivel to top drive. Rigged up cement hose to swivel. Circulated cement line on the rig to the bleeder & pressure tested to 4500 psi. SIMOPS observed 30 minutes static loss rate at 37 bph. 11,374.0 11,374.0 5/14/2024 08:15 5/14/2024 08:45 0.50 PROD1, DRILL CIRC T Performed injection test with MPD choke closed. 2 bpm = 285 psi; IA 175 psi 3 bpm = 470 psi; IA 250 psi 4 bpm = 700 psi; IA 245 psi 11,374.0 11,374.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 36/54 MT7-91 Report Printed: 6/25/2024 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) 5/14/2024 08:45 5/14/2024 13:15 4.50 PROD1, DRILL CMNT T Lined up to SLB cement unit. Fluid packed lines. Pressure tested lines to cement swivel on top drive to 4500 psi. Mixed and pumped 30 bbls of 12.0 ppg mud push at 3 bpm, 260-0 psi. Pumped 152.2 bbls of 14 ppg thixotropic cement at 3 bpm, 300 psi. Closed MPD choke with 110 bbls of cement pumped. Began bullheading cement at 3 bpm, 295 psi, IA 207 psi, 5 rpm, Tq 6K. Bullheaded 22.7 bbls of 12.0 ppg mud push at 3 bpm, 310 psi, IA 260 psi. Swapped to the rig pump & bullheaded 207 bbls of 8.8 ppg mud at 3 bpm, 59-716 psi, IA 405-351 psi, peak IA pressure 537 psi. Monitored IA pressure decrease from 261-70 psi in 12 minutes. Bled off pressure. No static losses observed while rigging down cement hose. 11,374.0 11,374.0 5/14/2024 13:15 5/14/2024 13:30 0.25 PROD1, DRILL CIRC T Circulated at 140 gpm, 477 psi, ~18 bph losses. 11,374.0 11,374.0 5/14/2024 13:30 5/14/2024 14:15 0.75 PROD1, DRILL RURD T Rigged down cement swivel & cementing equipment. Changed out elevators. Picked up a single of 4-1/2" drill pipe from the shed. 11,374.0 11,374.0 5/14/2024 14:15 5/14/2024 15:00 0.75 PROD1, DRILL MPDA T Began to strip out of the hole & drill pipe floats were leaking. Pulled MPD bearing and racked it back on stand of drill pipe. 11,374'-11,217' MD. 11,374.0 11,217.0 5/14/2024 15:00 5/14/2024 17:00 2.00 PROD1, DRILL TRIP T Tripped out of the hole from 11,217'- 10,271' MD, PUW 211K. Calculated fill 6.5; actual 15.0 bbls. 11,217.0 10,271.0 5/14/2024 17:00 5/14/2024 20:30 3.50 PROD1, DRILL CIRC T Circulated 40 bbls sugar water pill surface to surface at 180 gpm, 502 psi. Blew down top drive & installed stripping rubbers. 10,271.0 10,271.0 5/14/2024 20:30 5/15/2024 00:00 3.50 PROD1, DRILL TRIP T Tripped out of the hole from 10,271'- 7343' MD, PUW 170K. Calculated fill 19.4; actual 38.0 bbls. 10,271.0 7,343.0 5/15/2024 00:00 5/15/2024 06:00 6.00 PROD1, DRILL TRIP T Tripped out of the hole from 7343'-183' MD, PUW 90K. Calculated fill 50.2; actual 79.4 bbls. 7,343.0 183.0 5/15/2024 06:00 5/15/2024 06:15 0.25 PROD1, DRILL OWFF T Monitored well to establish static loss rate of ~4 bph. SIMOPS laid down extra stand of 4-1/2" drill pipe. 183.0 183.0 5/15/2024 06:15 5/15/2024 08:30 2.25 PROD1, DRILL BHAH T Pulled BHA 7 to surface. Unloaded the source & downloaded data. Broke off the bit. Laid down the AutoTrack & BCPM. 183.0 0.0 5/15/2024 08:30 5/15/2024 12:00 3.50 PROD1, DRILL BHAH T Pick up the fresh AutoTrak & BCPM. Made up same 6-1/2" PDC bit. Uploaded data to the MWD & verify connectivity. Checked the filter sub. Loaded the source. SOW 88K 0.0 183.0 5/15/2024 12:00 5/15/2024 13:15 1.25 PROD1, DRILL TRIP T Tripped in the hole from 183'-2250' MD, SOW 110K. 183.0 2,250.0 5/15/2024 13:15 5/15/2024 14:00 0.75 PROD1, DRILL DHEQ T Filled drill pipe & tested MWD tools. MWD tested good, 200 gpm, 560 psi. 2,250.0 2,250.0 5/15/2024 14:00 5/15/2024 14:15 0.25 PROD1, DRILL TRIP T Tripped in the hole from 2250'-3024' MD, SOW 113K. Made up connections with chain tongs & rig tongs due to swivel fitting failure on the ST-120. 2,250.0 3,024.0 5/15/2024 14:15 5/15/2024 14:45 0.50 PROD1, DRILL SVRG T Serviced top drive & blocks. SIMOPS repair ST-120. Static loss rate ~5 bph. 3,024.0 3,024.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 37/54 MT7-91 Report Printed: 6/25/2024 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) 5/15/2024 14:45 5/15/2024 15:45 1.00 PROD1, DRILL RGRP T Changed out hydraulic swivel on ST- 120. Static loss rate ~5 bph. 3,024.0 3,024.0 5/15/2024 15:45 5/15/2024 16:45 1.00 PROD1, DRILL TRIP T Tripped in the hole from 3024'-4899' MD, SOW 128K. 3,024.0 4,899.0 5/15/2024 16:45 5/15/2024 17:15 0.50 PROD1, DRILL DHEQ T Filled drill pipe & down linked to MWD tools, 200 gpm, 645 psi. 4,899.0 4,899.0 5/15/2024 17:15 5/15/2024 18:15 1.00 PROD1, DRILL TRIP T Tripped in the hole from 4899'-7259' MD, SOW 146K. 4,899.0 7,259.0 5/15/2024 18:15 5/15/2024 18:45 0.50 PROD1, DRILL DHEQ T Filled drill pipe & checked pulse on MWD tools, 200 gpm, 647 psi. 7,259.0 7,259.0 5/15/2024 18:45 5/15/2024 20:00 1.25 PROD1, DRILL TRIP T Tripped in the hole from 7259'-9617' MD, SOW 172K. 7,259.0 9,617.0 5/15/2024 20:00 5/15/2024 20:30 0.50 PROD1, DRILL DHEQ T Filled drill pipe & checked pulse on MWD tools, 200 gpm, 650 psi. 9,617.0 9,617.0 5/15/2024 20:30 5/15/2024 21:15 0.75 PROD1, DRILL TRIP T Tripped in the hole from 9617'-11,229' MD, SOW 185K. 9,617.0 11,229.0 5/15/2024 21:15 5/15/2024 21:45 0.50 PROD1, DRILL TRIP T Filled drill pipe & checked pulse on MWD tools, 200 gpm,710 psi. 11,229.0 11,229.0 5/15/2024 21:45 5/16/2024 00:00 2.25 PROD1, DRILL SLPC T Picked up working single of 5-7/8" of drill pipe & hung blocks. Cut & slipped drill line. Static losses ~4 bph. 11,229.0 11,229.0 5/16/2024 00:00 5/16/2024 02:00 2.00 PROD1, DRILL SLPC T Finished cut & slip. Laid down the 5-7/8" working single. Changed out elevators. Calibrated block height. 11,229.0 11,229.0 5/16/2024 02:00 5/16/2024 03:00 1.00 PROD1, DRILL WASH T Washed down from 11,229'-11,500' MD; 180 gpm, 600 psi, SOW 188K. 11,229.0 11,500.0 5/16/2024 03:00 5/16/2024 06:00 3.00 PROD1, DRILL REAM T Reamed from 11,500'-12,276' MD. Offloaded contaminated mud & brought on new Flo-Pro 8.8 ppg. 180 gpm, 870 psi, FO 3% 80 rpm, Tq 6-7K PUW 224K SOW 190K RW 206K 11,500.0 12,276.0 5/16/2024 06:00 5/16/2024 12:00 6.00 PROD1, DRILL REAM T Reamed from 12,276'-13,293' MD. Offloaded contaminated mud & brought on new Flo-Pro 8.8 ppg. 190 gpm, 1030 psi, FO 3% 80 rpm, Tq 6-7K PUW 224K SOW 190K RW 206K 12,276.0 13,293.0 5/16/2024 12:00 5/16/2024 17:45 5.75 PROD1, DRILL REAM T Reamed from 13,293'-13,758' MD. 190 gpm, 960 psi, FO 2-7% 80 rpm, Tq 16K PUW 245K SOW 174K RW 206K 13,293.0 13,758.0 5/16/2024 17:45 5/17/2024 00:00 6.25 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 13,759'-14,405' MD, 8371' TVD. Losses ~65 bph while drilling. 190 gpm, 1020 psi, FO 2-7% 125-150 rpm, Tq on 22K, off 18K WOB 6-15K 9.5 ECD Max Gas 170 PUW 276K SOW 164K RW 207K ADT 4.4. BIT 20.1 13,758.0 14,405.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 38/54 MT7-91 Report Printed: 6/25/2024 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) 5/17/2024 00:00 5/17/2024 06:00 6.00 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 14,405'-14,963' MD, 8382' TVD. Losses ~50 bph while drilling. 190 gpm, 975 psi, FO 2% 125 rpm, Tq on 21K, off 19K WOB 9-15K 9.4 ECD Max Gas 417 PUW 265K SOW 169K RW 212K ADT 4.2. BIT 24.3 14,405.0 14,963.0 5/17/2024 06:00 5/17/2024 12:00 6.00 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 14,963'-15,520' MD, 8400' TVD. 190-210 gpm, 1100 psi, FO 1-3% 125-150 rpm, Tq on 19-23K, off 7K WOB 9K 9.6 ECD Max Gas 463 PUW 265K SOW 170K RW 214K ADT 3.1. BIT 27.4 14,963.0 15,520.0 5/17/2024 12:00 5/17/2024 17:00 5.00 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 15,520'-16,060' MD, 8401' TVD. Observed complete losses. 190-200 gpm, 1208 psi, FO 7% 125 rpm, Tq on 20K, off 16K WOB 13K 9.5 ECD Max Gas 319 PUW 285K SOW 165K RW 220K ADT 2.9. BIT 30.3 15,520.0 16,060.0 5/17/2024 17:00 5/17/2024 21:15 4.25 PROD1, DRILL CIRC T Pumped 95 bbls of 35 ppb LCM pill with 15 bbls of H2O ahead & behind. Pumped it down at 200 gpm with 336 gpm on the back side to fill the hole. Reduced pump rate to 115 gpm before pill got to the BHA. Began to get some returns & pump pressure when pill went to formation. Pumping at 180 gpm & 126 gpm on the backside dynamic losses at 281 bph. Pumped another 100 bbls LCM pill with same parameters. Dynamic loss rate at 248 bph & static losses at 152 bph. Decision made to drill ahead to see if any more loss zones before tripping to the shoe to pump thixotropic cement. 16,060.0 16,060.0 5/17/2024 21:15 5/17/2024 22:00 0.75 PROD1, DRILL DDRL T Directional drilled 6-1/2" production section from 16,060'-16,172' MD, 8401' TVD. Losses at 255 bph. Pumped another 100 bbls of 35 ppb LCM pill. 180 gpm, 1723 psi, FO 0% 125 rpm, Tq on 21K, off 16K WOB 8K 8.83 ECD Max Gas 0 PUW 285K SOW 165K RW 220K 16,060.0 16,172.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 39/54 MT7-91 Report Printed: 6/25/2024 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) 5/17/2024 22:00 5/17/2024 23:30 1.50 PROD1, DRILL CIRC T Circulated LCM pill out of the pipe at 180-115 gpm, 741-260 psi, 80 rpm, Tq 19K. Dynamic losses at 255 bph & static losses at 147 bph. Decision made to drill 1 more stand before tripping to pump cement. 16,172.0 16,172.0 5/17/2024 23:30 5/18/2024 00:00 0.50 PROD1, DRILL DDRL T Directional drilled 6-1/2" production section from 16,172'16,265' MD, 8401' TVD. Losses at 277 bph. 180 gpm, 1723 psi, FO 0% 125 rpm, Tq on 19K, off 15K WOB 9K 8.73 ECD Max Gas 0 PUW 285K SOW 165K RW 220K 16,172.0 16,265.0 5/18/2024 00:00 5/18/2024 03:45 3.75 PROD1, DRILL SMPD T Tripped out of the hole from 16,245'- 15,398' MD, with MPD choke open & filled the back side with MPD pump to manage & monitor losses. Observed 30K over pull at 15,363' & 15,541' MD. Was able to ream past with minimum torque & no pressure increase. Indications of junk in the hole. PUW 290K SOW 180K RW 228K 16,245.0 15,398.0 5/18/2024 03:45 5/18/2024 05:00 1.25 PROD1, DRILL BKRM T Backreamed out of the hole from 15,398'-15,224' MD. Filled the annulus with MPD pump to manage & monitor losses. 100 gpm, 130 psi, 60 rpm, Tq 9K. 15,398.0 15,224.0 5/18/2024 05:00 5/18/2024 05:15 0.25 PROD1, DRILL SVRG T Changed out top drive grabber dies. 15,224.0 15,224.0 5/18/2024 05:15 5/18/2024 09:00 3.75 PROD1, DRILL SMPD T Tripped out of the hole from 15,224'- 13,293' MD. Filled the annulus with MPD pump to manage & monitor losses. PUW 250K, SOW 180K 15,224.0 13,293.0 5/18/2024 09:00 5/18/2024 09:45 0.75 PROD1, DRILL MPDA T Removed MPD bearing on last stand of 5-7/8" drill pipe & racked back in the derrick. Installed 4-1/2" bearing that was racked back on a stand of 4-1/2" drill pipe. 13,293.0 13,293.0 5/18/2024 09:45 5/18/2024 11:00 1.25 PROD1, DRILL SMPD T Tripped out of the hole from 13,293'- 13,200' MD. Filled the annulus with MPD pump to manage & monitor losses. Attempted to pull past debris in the hole. PUW 233K, SOW 180K. 13,293.0 13,200.0 5/18/2024 11:00 5/18/2024 11:30 0.50 PROD1, DRILL SVRG T Changed out top drive grabber dies. 13,200.0 13,200.0 5/18/2024 11:30 5/18/2024 15:00 3.50 PROD1, DRILL SMPD T Backreamed out of the hole from 13,200'-11,378' MD. Filled the annulus with MPD pump to manage & monitor losses. 50 gpm, 55 psi 40 rpm, Tq 6-10K PUW 233K SOW 180K RW 207K 13,200.0 11,378.0 5/18/2024 15:00 5/18/2024 16:00 1.00 PROD1, DRILL RURD T Laid down top single of 4-1/2" drill pipe. Made up cement swivel & rigged up cement lines. Prepped for cement job. 11,378.0 11,378.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 40/54 MT7-91 Report Printed: 6/25/2024 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) 5/18/2024 16:00 5/18/2024 20:00 4.00 PROD1, DRILL CMNT T Lined up to cementers and pumped 5 bbls of H2O. Pressure tested lines to 3500 psi. Back side pump was kept running from 4 bpm to 1/2 bpm to keep the annulus full while pumping the job. Pumped 34 bbls of 12.0 ppg mud push at 3 bpm, 130-174 psi, IA 0. Pumped 158 bbls of 14 ppg thixotropic cement at 3 bpm, 216-206 psi, IA 0. Pumped 27.5 bbls of 12.0 ppg mud push at 3 bpm, 153-0 psi, IA 0. Pumped 20 bbls of H2O at 3 bpm, 0 psi, IA 0. Swapped to rig and displaced with 8.5 ppg Flo-Pro mud at 3 bpm, 90-487 psi, IA 0-97 psi, pumped 280 bbls total. Observed pump pressure increase with 107 bbls pumped. Observed IA pressure increase with 207 bbls pumped. Max IA pressure noted 111 psi. Static losses after job ~147 bph. CIP 19:32 hrs. 11,378.0 11,378.0 5/18/2024 20:00 5/18/2024 20:30 0.50 PROD1, DRILL RURD T Rigged down cement swivel & cementing equipment. 11,378.0 11,378.0 5/18/2024 20:30 5/18/2024 20:45 0.25 PROD1, DRILL CIRC T Circulated to clear BHA of any residual cement at 140 gpm, 326 psi. Dynamic losses ~200 bph. 11,378.0 11,378.0 5/18/2024 20:45 5/19/2024 00:00 3.25 PROD1, DRILL WOC T Evaluated losses while waiting on cement. Starting losses ~156 bph; ending losses ~211 bph. SIMOPS cleaned cementing valves & rig floor, transfer mud into pits. 11,378.0 11,378.0 5/19/2024 00:00 5/19/2024 07:00 7.00 PROD1, DRILL WOC T Waited on cement monitoring static loss rate. Start ~211 bph; end ~204 bph. SIMOPS changed out dies on ST-120; cleaning around the rig; derrick inspection. 11,378.0 11,378.0 5/19/2024 07:00 5/19/2024 08:15 1.25 PROD1, DRILL CIRC T Pumped 50 bbls of 35 ppb LCM with 15 bbls of H2O ahead and behind, with 170 bbls of 8.5 ppg FloPro. Blew down top drive. 120 gpm, 228 psi 10 rpm, Tq 7K 11,378.0 11,378.0 5/19/2024 08:15 5/19/2024 11:15 3.00 PROD1, DRILL WOC T Waited on cement monitoring static loss rate. At 10:00 hrs loss rate at 188 bph. SIMOPS changed out saver sub on top drive. 11,378.0 11,378.0 5/19/2024 11:15 5/19/2024 13:00 1.75 PROD1, DRILL REAM T Picked up top single from the pipe shed. Reamed from 11,378'-11,975' MD. Pumped across the top with MPD pump at 1 bpm to monitor losses & returns. 190 gpm, 706 psi 80 rpm, Tq 14K 11,378.0 11,975.0 5/19/2024 13:00 5/19/2024 14:30 1.50 PROD1, DRILL CIRC T Pumped 100 bbls of 35 ppb LCM with 10 bbls of H2O ahead and behind. 220 gpm, 830 psi 50 rpm, Tq 13K 11,975.0 11,975.0 5/19/2024 14:30 5/19/2024 18:00 3.50 PROD1, DRILL REAM T Reamed from 11,975'-13,393' MD. Pumped across the top with MPD pump at 1 bpm to monitor losses & returns. 150 gpm, 560 psi 80 rpm, Tq 16K PUW 250K SOW 170K RW 210K 11,975.0 13,393.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 41/54 MT7-91 Report Printed: 6/25/2024 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) 5/19/2024 18:00 5/19/2024 19:30 1.50 PROD1, DRILL MPDA T Removed 4-1/2" MPD bearing racking it back on a stand. Installed 5-7/8" MPD bearing as per MPD Advisor. 13,393.0 13,393.0 5/19/2024 19:30 5/20/2024 00:00 4.50 PROD1, DRILL REAM T Reamed from 13,393'-14,982' MD. Pumped across the top with MPD pump at 1 bpm to monitor losses & returns. Dynamic loss rate at 24:00 hrs ~180 bph. 150 gpm, 599 psi 80 rpm, Tq 20K PUW 250K SOW 170K RW 218K 13,393.0 14,982.0 5/20/2024 00:00 5/20/2024 05:00 5.00 PROD1, DRILL REAM T Reamed in the hole from 14,982'- 16,260' MD. Monitored losses with MPD pump at 1 bpm across the top. Loss rate at 04:30 ~170 bph @ 150 gpm. 150 gpm, 599 psi 80 rpm, Tq 20K PUW 290K SOW 180K RW 222K 14,982.0 16,260.0 5/20/2024 05:00 5/20/2024 07:00 2.00 PROD1, DRILL TRIP T Tripped out of the hole from 16,265'- 15,890' MD. Losses monitored & managed with MPD pump across the top at 4 bpm. PUW 290K 16,260.0 15,890.0 5/20/2024 07:00 5/20/2024 08:30 1.50 PROD1, DRILL CIRC T Dropped 1.75" stainless steel opening ball & pumped at 84 gpm, 166 psi. Observed shift open 34 bbls pumped, pressuring up to 1602 psi. Dropped 1.698 BHA isolation ball & pumped at 84 gpm, 166 psi. Increase rate to 210 gpm to verify tools isolated. Rotated at 10 rpm, Tq 18K. 15,890.0 15,890.0 5/20/2024 08:30 5/20/2024 09:15 0.75 PROD1, DRILL CIRC T Circulated at 87 gpm, 106 psi, 10 rpm, Tq 18K. 15,890.0 15,890.0 5/20/2024 09:15 5/20/2024 10:45 1.50 PROD1, DRILL CIRC T Pumped 40 bbls of Form-A-Blok hybrid pill ( 40 ppb FAB; 10 ppb nut plug med; 10 ppb SafeCarb 500) & chased with 256 bbls of 8.5 ppg FloPro mud at 201 gpm, 497 psi. 15,890.0 15,890.0 5/20/2024 10:45 5/20/2024 11:15 0.50 PROD1, DRILL TRIP T Tripped out of the hole from 15,890'- 15,423' MD, calculated top of pill. Losses monitored & managed with MPD pump across the top at 4 bpm. PUW 330K 15,890.0 15,423.0 5/20/2024 11:15 5/20/2024 12:00 0.75 PROD1, DRILL SQEZ T Performed hesitation squeeze at 1 bpm, 20 rpm, Tq 18K 1. Pumped down drill pipe at 1 bpm, 7 bbls total to ensure pipe clear. Monitored 109-51 psi. 2. Pumped down annulus at 1 bpm to 100 psi. Monitored 15 minutes to -5 psi. 3. Pumped down annulus at 1 bpm to 100 psi. Monitored 5 minutes to 0 psi. 15,423.0 15,423.0 5/20/2024 12:00 5/20/2024 13:00 1.00 PROD1, DRILL TRIP T Tripped in of the hole from 15,423'- 15,893' MD. Monitored losses pumping across the top with MPD pump. 15,423.0 15,893.0 5/20/2024 13:00 5/20/2024 15:00 2.00 PROD1, DRILL CIRC T Obtained loss rates; dynamic at 165 gpm, 150 bph; static 72 bph. Pumped 60 bbls of Form-A-Blok hybrid pill ( 40 ppb FAB; 10 ppb nut plug med; 10 ppb SafeCarb 500) & chased with 255 bbls of 8.5 ppg FloPro mud at 208 gpm, 507 psi, 10 rpm, Tq 12K. 15,893.0 15,893.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 42/54 MT7-91 Report Printed: 6/25/2024 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) 5/20/2024 15:00 5/20/2024 16:00 1.00 PROD1, DRILL TRIP T Tripped out of the hole from 15,893'- 15,056' MD. PUW 335K 15,893.0 15,056.0 5/20/2024 16:00 5/20/2024 18:00 2.00 PROD1, DRILL SQEZ T Performed hesitation squeeze pressuring up at .5-1 bpm, 20 rpm, Tq 17K. Performed 8 squeeze stations pressuring up to 80 psi & bleeding down to 0. Total squeezed 38 bbls. 15,056.0 15,056.0 5/20/2024 18:00 5/20/2024 19:15 1.25 PROD1, DRILL TRIP T Tripped in the hole from 15,056'-15,897' MD. SOW 172K 15,056.0 15,897.0 5/20/2024 19:15 5/20/2024 22:30 3.25 PROD1, DRILL WAIT T Waited on 80 bbls of hybrid Form-A-Blok pill to be built. Circulated across the top to monitor losses. Rotated 10 rpm, Tq 18K. 15,897.0 15,897.0 5/20/2024 22:30 5/21/2024 00:00 1.50 PROD1, DRILL CIRC T Established loss rates dynamic at 165 gpm 76 bph & static 18 bph. Attempted to pump hybrid Form-A-Block pill. Lost prime on the mud pump several times trying to pump pill. Drill string loaded with 14 bbls of pill. Continued circulating down the drill string with mud at 140 gpm, 280 psi while thinning back pill with 10 bbls of H2O. 15,897.0 15,897.0 5/21/2024 00:00 5/21/2024 01:30 1.50 PROD1, DRILL CIRC T Pumped 81 bbls of Form-A-Blok hybrid pill ( 40 ppb FAB; 10 ppb nut plug med; 10 ppb SafeCarb 500) & chased with 256 bbls of 8.5 ppg FloPro mud at 210 gpm, 372 psi. 15,897.0 15,897.0 5/21/2024 01:30 5/21/2024 03:30 2.00 PROD1, DRILL TRIP T Tripped out of the hole from 15,897'- 14,410' MD. PUW 330K 15,897.0 14,410.0 5/21/2024 03:30 5/21/2024 05:45 2.25 PROD1, DRILL SQEZ T Performed hesitation squeeze utilizing MPD system. Pressured up to 40 psi 6 times & monitored pressure for 15 minutes. Each time pressure dropped to -7 or -10 psi on MPD RCD sensor. Squeezed a total of 28 bbls. 14,410.0 14,410.0 5/21/2024 05:45 5/21/2024 09:00 3.25 PROD1, DRILL SQEZ T Performed dynamic squeeze with MPD system; 20 rpm, Tq 16K, RW 219K. Held down hole pressure at 45-55 psi for 1:10 hours, squeezing 26.8 bbls. Held down hole pressure at 74 psi for 15 minutes, squeezing 4.2 bbls. Held down hole pressure at 100 psi for 30 minutes, squeezing 9.4 bbls. Shut down and trapped 60 psi on the annulus. After 5 minutes decreased to 37 psi on MPD sensor. Opened choke and circulated across the top to observe static losses at 0 bph. 14,410.0 14,410.0 5/21/2024 09:00 5/21/2024 10:30 1.50 PROD1, DRILL CIRC T Dropped 1.75" stainless steel ball & pumped down at 84 gpm, 251 psi. Ball on seat with 79.8 bbls pumped. Observed pressure increase to 1498 psi to shift Well Commander closed & open to the BHA. Flushed tools at 120 gpm, 450 psi. Pumped up tools at 210 gpm, 875 psi, checked good. 14,410.0 14,410.0 5/21/2024 10:30 5/21/2024 11:00 0.50 PROD1, DRILL BKRM T Backreamed from 14,410'-14,226' MD 150 gpm, 535psi 20 rpm, Tq 14K RW 212K 14,410.0 14,226.0 5/21/2024 11:00 5/21/2024 20:30 9.50 PROD1, DRILL CIRC T Circulated & reciprocated waiting for mud volume to be built & transported to location. 120 gpm, 430 psi 20 rpm, Tq 12K RW 212K 14,226.0 14,226.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 43/54 MT7-91 Report Printed: 6/25/2024 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) 5/21/2024 20:30 5/21/2024 22:45 2.25 PROD1, DRILL TRIP T Tripped in the hole from 14,226'-15,700' MD, SOW 178K. 14,226.0 15,700.0 5/21/2024 22:45 5/22/2024 00:00 1.25 PROD1, DRILL REAM T Reamed in the hole from 15,700'- 15,982' MD. Dynamic loss rate 50 bph. 160 gpm, 691 psi 80 rpm, Tq 13K RW 219K 15,700.0 15,982.0 5/22/2024 00:00 5/22/2024 01:45 1.75 PROD1, DRILL DLOG T Fill pipe and MAD pass from 15982' to 16265' MD Dynamic loss rate 50 BPH 160 gpm, 691 psi 30 rpm, Tq 7K RW 219K 15,982.0 16,265.0 5/22/2024 01:45 5/22/2024 06:00 4.25 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 16,260'-16,631' MD, 8406' TVD. 190 gpm, 900psi, FO 1% 120 rpm, Tq on 23K, off 21K WOB 13K 9.1 ECD Max Gas 0 PUW 263K SOW 189K RW 228K Record SCR's at 16260' MD on MP #1 & #2 Encountered losses equaling 184 BPH at 16538' MD pump 50 bbls 35 PPB LCM pill with 15 bbls lead and follow water. . Reduced flow rate to 120 GPM while pumping LCM through MWD tools. Flush 13.5 bbls 8.5 ppg flow pro through tools and bring pumps back up to 180 GPM and resume drilling. 16,265.0 16,631.0 5/22/2024 06:00 5/22/2024 12:00 6.00 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 16,631'-16,940' MD, 8411' TVD. 190 gpm, 1000psi, FO 1% 120 rpm, Tq on 13K, off 8K WOB 13K 9.1 ECD Max Gas 5 PUW 263K SOW 189K RW 228K Dynamic loss rate 180 BPH Pump 2 x 50 bbls 35 PPB LCM pill with 15 bbls lead and follow water. . Reduced flow rate to 120 GPM while pumping LCM through MWD tools. Flush 13.5 bbls 8.5 ppg flow pro through tools and bring pumps back up to 180 GPM and resume drilling. 16,631.0 16,940.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 44/54 MT7-91 Report Printed: 6/25/2024 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) 5/22/2024 12:00 5/22/2024 16:45 4.75 PROD1, DRILL DDRL P Directional drilled 6-1/2" production section from 16,940'-17,283' MD, 8397' TVD. 190 gpm, 955psi, FO 1% 120 rpm, Tq on 17K, off12K WOB 13K 9.23 ECD Max Gas PUW 268K SOW 183K RW 228K Dynamic loss rate 145 BPH Pump 1 x 50 bbls 35 PPB LCM pill with 15 bbls lead and follow water. . Reduced flow rate to 120 GPM while pumping LCM through MWD tools. Flush 13.5 bbls 8.5 ppg flow pro through tools and bring pumps back up to 180 GPM and resume drilling. 16,940.0 17,283.0 5/22/2024 16:45 5/22/2024 17:15 0.50 PROD1, DRILL BKRM T BROOH from 17,283 to 17,096' 190 gpm, 955psi, FO 2% 30 rpm, Tq 11K, 9.11 ECD Max Gas 5 PUW 258K RW 235K Dynamic loss rate 145 BPH 17,283.0 17,096.0 5/22/2024 17:15 5/22/2024 19:15 2.00 PROD1, DRILL CIRC T Dropped 1.75" stainless steel opening ball & pumped at 84 gpm, 251 psi. Observed shift open 121 bbls pumped, pressuring up to 1600 psi. Dropped 1.698 BHA isolation ball & pumped at 84 gpm, 166 psi. Increase rate to 210 gpm to verify tools isolated. Rotated at 10 rpm, Tq 18K. Dynamic loss rate 145 BPH 17,096.0 17,096.0 5/22/2024 19:15 5/22/2024 20:45 1.50 PROD1, DRILL CIRC T Pumped 92 bbls of Form-A-Blok hybrid pill 40 ppb FAB; 10 ppb nut plug med; 10 ppb SafeCarb 500 at 84 GPM, 87 psi & chased with 282 bbls of 8.5 ppg FloPro mud at 210 gpm, 430 psi. 17,096.0 17,096.0 5/22/2024 20:45 5/22/2024 23:00 2.25 PROD1, DRILL BKRM T BROOH from 17096 to 15979' MD to get BHA above loss zone. 150 gpm, 535 psi. 20 rpm 14k tq. RTW 212k. 17,096.0 15,979.0 5/22/2024 23:00 5/22/2024 23:30 0.50 PROD1, DRILL SQEZ T Performed dynamic squeeze with MPD system; 20 rpm, Tq 14K, RW 224K. Held down hole pressure starting at 20 psi and slowly increasing to 100 psi , held 100 psi for 15 minutes, squeezing 22.3 bbls. slowly opened choke and circulated across the top to observe static losses at 30 bph. 15,979.0 15,979.0 5/22/2024 23:30 5/23/2024 00:00 0.50 PROD1, DRILL CIRC T Drop 1.75" stainless steel ball to function well commander closed. Pump at 84 GPM 251 psi. 15,979.0 15,979.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 45/54 MT7-91 Report Printed: 6/25/2024 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) 5/23/2024 00:00 5/23/2024 01:15 1.25 PROD1, DRILL CIRC T Drop 1.75" well commander ball closing ball (ball #6), pump down at 84 GPM 262 PSI, ball on seat @ 926 STKS, stage up pressure in 500 PSI increments close well commander @ 1569 PSI, pump 120 GPM 475 PSI to flush MWD tools Pump 180 GPM 830 PSI confirm MWD tools function Rotate 10 RPM 5.5K TQ 15,979.0 15,979.0 5/23/2024 01:15 5/23/2024 03:00 1.75 PROD1, DRILL DLOG T Wash and ream F/15,979' T/16,261' 160 GPM 800 PSI, 60 RPM 8-9K TQ MAD pass @ 300 FPH 15,979.0 16,261.0 5/23/2024 03:00 5/23/2024 07:45 4.75 PROD1, DRILL REAM T Wash and ream F/16,261' T/17,095' 160 GPM 790 PSI, 60 RPM 8K TQ At 17,006' pump 75 BBL 35 PPB nut plug fine LCM pill, chase with 15 BBLS water to flush MWD, Slow pump down to 3 BPM while pill going thru BHA Bring up pump rate to 190 GPM 911 PSI after pill clear of drill string Loss rate while pumping LCM pill down 138 BPH, loss rate after pill out 90 BPH pumping 3 BPM, loss rate while pumping 190 GPM = 96 BPH 16,261.0 17,095.0 5/23/2024 07:45 5/23/2024 10:15 2.50 PROD1, DRILL CIRC T Drop 1.75" opening ball (ball #7) pump down at 2 BPM 373 PSI, 30 RPM 8.6K TQ Ball on seat @ 1055 STKS, pressure up to 1480 open well commander Drop 1.698" BHA shut off ball (ball#8), loss rate while pumping at 2 BPM 93 BPH Pump 100 BBLS of 88 PPB LCM pill, pump pill at 3.5 BPM 360 PSI, 30 RPM 8K TQ, chase at 4.9 BPM 450 PSI 17,095.0 17,095.0 5/23/2024 10:15 5/23/2024 11:30 1.25 PROD1, DRILL CIRC T Performed dynamic squeeze with MPD system when LCM pill out of drill string Pump @ 4.9 BPM 600 PSI, 30 RPM 7.7K TQ Hold 20 PSI and slowly increasing in 10 psi increments to 100 psi and holding for 10 minutes each.Total 53.3 BBLS squeezed. Slowly opened choke to zero psi and circulated across the top to observe static losses at 0 BPH Dynamic losses at 60BPH while at 210gpm 60rpm rotary w/9.4ppg ECD 17,095.0 17,095.0 5/23/2024 11:30 5/23/2024 13:15 1.75 PROD1, DRILL CIRC T Circulate at 4.5 BPM 334 PSI, 30 RPM 8K TQ Drop 1.75" closing ball (ball #9) RTW 225 K, SOW 185K, PUW 260K. Ball on seat and shear close at 1656 PSI 17,095.0 17,095.0 5/23/2024 13:15 5/23/2024 14:00 0.75 PROD1, DRILL REAM T Wash and ream F/17,099' T/17,284' 205 GPM, 930 PSI, 80 RPM, 12K TQ. 17,095.0 17,284.0 5/23/2024 14:00 5/23/2024 14:15 0.25 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 17284' to 17375' 190 GPM 945 PSI, 30 RPM, 12K TQ. Observed total losses at 17332' MD. drill down remainder of stand while prepare LCM pill. 17,284.0 17,375.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 46/54 MT7-91 Report Printed: 6/25/2024 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) 5/23/2024 14:15 5/23/2024 16:15 2.00 PROD1, DRILL CIRC T Pump 70 bbls 35 PPB with 15 bbls lead and tail fresh water to flush BHA. Pump at 190 GPM 945 PSI and reduce to 120 GPM while going through tools. 17,375.0 17,375.0 5/23/2024 16:15 5/23/2024 17:45 1.50 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 17375' to 17561' TVD 8397' 190 GPM 920 PSI, 120 RPM, 20K TQ. Dynamic losses averaging 220 BPH. Static losses 90 BPH. 17,375.0 17,561.0 5/23/2024 17:45 5/23/2024 19:00 1.25 PROD1, DRILL CIRC T Pump 70 bbls 35 PPB with 15 bbls lead and tail fresh water to flush BHA. Pump at 150 GPM 920 PSI and reduce to 120 GPM while going through tools. RTW 224K Dynamic loss rate 112 BPH. Static Loss rate 60BPH 17,561.0 17,561.0 5/23/2024 19:00 5/24/2024 00:00 5.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 17561' to 18026' TVD 8397' 190 GPM 920 PSI, 120 RPM, 20K TQ. 18K WOB PUW 301K, SOW 290K RTW 178K Dynamic losses averaging 161 BPH. Static losses 25 BPH. 17,561.0 18,026.0 5/24/2024 00:00 5/24/2024 05:15 5.25 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 18,026' to 18,489' 190 GPM 1135 PSI, 120 RPM, 20K TQ. 18K WOB PUW 295K, SOW 178K RTW 233K Note: At 18,335' pump 70 BBL LCM pill at 35 PPB, slowing to 120 GPM when LCM going thru BHA, continue drilling to see if loss rate improved Dynamic losses averaging 200 -230 BPH. Static losses 80 BPH. 18,026.0 18,489.0 5/24/2024 05:15 5/24/2024 06:15 1.00 PROD1, DRILL CIRC T Drop 1.75" opening ball for well commander (ball #10) Pump down at 5 BPM 1104 PSI, slow to 2 BPM 350 PSI, 30 RPM 9.9K TQ Ball on seat @ 1215 STKS, pressure up to 1584 PSI shift well commander open Loss rate while pumping ball down ~150 BPH @ 2 BPM Drop 1.698" BHA shut off ball (ball#11), pump down at 2 BPM 213 PSI 30 RPM 9.9K TQ Pump 100 BBLS of 88 PPB LCM pill 18,489.0 18,489.0 5/24/2024 06:15 5/24/2024 09:45 3.50 PROD1, DRILL CIRC T Performed dynamic squeeze with MPD system when LCM pill out of drill string Pump @ 5.2 BPM 690 PSI, 30 RPM 10K TQ Hold 20 PSI and slowly increase to 35 psi.Total 73 BBLS squeezed. Slowly opened choke to zero psi and circulated across the top to observe static losses at 0 BPH Dynamic losses at 190 BPH while at 210gpm 30 rpm rotary w/9.4ppg ECD 18,489.0 18,489.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 47/54 MT7-91 Report Printed: 6/25/2024 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) 5/24/2024 09:45 5/24/2024 12:00 2.25 PROD1, DRILL CIRC T Drop 1.75" closing ball (ball #12) pump down at 2 BPM 370 PSI Ball on seat at 1,482 strokes. Pressure up to close well commander to 1677 PSI Flush though MWD tools with 125 GPM / 535 psi. Pump @ 210 GPM 1175 PSI to function MWD tools. 18,489.0 18,489.0 5/24/2024 12:00 5/24/2024 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 18,489' to 19,023' 8397' TVD 200 GPM 1145 PSI, 120 RPM, 20K TQ. 18K WOB PUW 295K, SOW 178K RTW 233K Dynamic losses averaging 190 BPH - 200 BPH . Static losses 10 BPH. 18,489.0 19,025.0 5/24/2024 18:00 5/25/2024 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 19,023' to 19,394' 230 GPM 1230 PSI, 120 RPM, 21K TQ. 19K WOB PUW 295K, SOW 178K RTW 238K Dynamic losses averaging 190 BPH - 200 BPH . Static losses 10 BPH. 19,025.0 19,394.0 5/25/2024 00:00 5/25/2024 00:45 0.75 PROD1, TRIPCAS DDRL P Drill 6-1/2" production hole section from 19,394' to 19,418' 8,453' TVD - section TD 230 GPM 1230 PSI, 120 RPM, 21K TQ. 15K WOB PUW 308K, SOW 178K RTW 238K Dynamic losses averaging 190 BPH - 200 BPH . Static losses 120 BPH. 19,394.0 19,418.0 5/25/2024 00:45 5/25/2024 01:00 0.25 PROD1, TRIPCAS OWFF P Perform fingerprint and static loss rate with MPD Static loss rate = 90 - 120 BPH 19,418.0 19,418.0 5/25/2024 01:00 5/25/2024 05:00 4.00 PROD1, TRIPCAS BKRM P Pump 100 BBLS of 35 PPB LCM pill, followed by 15 BBLS water while back ream stand. Slow to 120 GPM while pill going thru BHA Pump at 200 GPM 1015 PSI, 50 RPM 15.2K TQ Dynamic loss rate at 120 GPM ~150 BPH Dynamic loss rate at 200 GPM ~180 BPH 19,418.0 19,327.0 5/25/2024 05:00 5/25/2024 12:00 7.00 PROD1, TRIPCAS BKRM P Backream out of hole racking back one stand per bottoms up from 19,327' to 19,048' MD total of 3 bottoms up pumped. 200 Gpm, 1000 Psi. 120 Rpm, 19K TQ Dynamic loss rate 180 BPH. 19,327.0 19,048.0 5/25/2024 12:00 5/25/2024 13:30 1.50 PROD1, TRIPCAS TRIP P Trip in hole from 19,048' to 19,326' MD with drill pipe from derrick. SOW 195K Monitor displacement via trip tank. 19,048.0 19,327.0 5/25/2024 13:30 5/25/2024 14:30 1.00 PROD1, TRIPCAS SMPD P Trip out of hole utilizing MPD to offset swab, Encounter over pull at 18,909' MD 20K over pull. drop back down to 18,924'. 19,327.0 18,924.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 48/54 MT7-91 Report Printed: 6/25/2024 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) 5/25/2024 14:30 5/26/2024 00:00 9.50 PROD1, TRIPCAS BKRM P Backream out of hole from 18,924' to 16,719' MD Utilizing MPD to offset swab racking back stands in derrick. 190 GPM 830 psi. 120 rpm, 10k Tq. RTW 223k Max gas 56 units. Pump 45 bbl 35 PPB LCM sweep with 15 bbl fresh water tail. reduce rate to 140 GPM while pumping sweep. Flush 13.5 bbl 8.5 flopro through BHA before resume full rate. Dynamic losses 180-240 BPH. 18,924.0 16,719.0 5/26/2024 00:00 5/26/2024 03:30 3.50 PROD1, TRIPCAS BKRM P Backream out of hole from 16,719' to 16,161' MD Utilizing MPD to offset swab racking back stands in derrick. 190 GPM 830 psi. 120 rpm, 10k Tq. RTW 223k Dynamic losses 180-240 BPH. 16,719.0 16,161.0 5/26/2024 03:30 5/26/2024 04:00 0.50 PROD1, TRIPCAS SVRG P Service rig 16,161.0 16,161.0 5/26/2024 04:00 5/26/2024 12:00 8.00 PROD1, TRIPCAS BKRM P Backream out of hole from 16,161' to 13,389' MD Utilizing MPD to offset swab racking back stands in derrick. 190 GPM 580 psi. 120 rpm, 8.5k Tq. RTW 212k PUW 233K Dynamic losses 180-240 BPH. 16,161.0 13,389.0 5/26/2024 12:00 5/26/2024 13:00 1.00 PROD1, TRIPCAS MPDA P PJSM Pull 5 7/8" MPD bearing, install 4 1/2" MPD bearing 13,389.0 13,293.0 5/26/2024 13:00 5/26/2024 20:15 7.25 PROD1, TRIPCAS BKRM P Backream out of hole from 13,293' to 11,310' MD Utilizing MPD to offset swab racking back stands in derrick. 190 GPM 694 psi. 120 rpm, 8k Tq. RTW 199k Dynamic losses 180-240 BPH. 13,293.0 11,310.0 5/26/2024 20:15 5/26/2024 22:15 2.00 PROD1, TRIPCAS CIRC P Rotate and reciprocate inside 7-5/8" casing shoe to clean up well. 220 GPM 860 PSI 120 RPM 6.5k TQ RTW 201k. 11,310.0 11,310.0 5/26/2024 22:15 5/26/2024 22:45 0.50 PROD1, TRIPCAS OWFF P Perform flow check Static loss rate 88 BPH 11,310.0 11,310.0 5/26/2024 22:45 5/27/2024 00:00 1.25 PROD1, TRIPCAS SMPD P Blow down top drive. Strip out of hole from 11,310' to 10,178' utilizing MPD to offset swab pressures. PUW 222K Monitor displacement via pit #5 11,310.0 10,178.0 5/27/2024 00:00 5/27/2024 01:00 1.00 PROD1, TRIPCAS SMPD P SOOH F/10,178' T/9,138' utilizing MPD to offset swab pressures. PUW 206K Monitor displacement via pit #5 10,178.0 9,138.0 5/27/2024 01:00 5/27/2024 03:45 2.75 PROD1, TRIPCAS CIRC P Circulate condition mud for liner run 220 GPM 770 PSI, 80 RPM 4K TQ Blow down top drive 9,138.0 9,138.0 5/27/2024 03:45 5/27/2024 11:00 7.25 PROD1, TRIPCAS SMPD P SOOH F/9,138' T/183' utilizing MPD to offset swab pressures. Monitor displacement via pit #5 9,138.0 183.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 49/54 MT7-91 Report Printed: 6/25/2024 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) 5/27/2024 11:00 5/27/2024 12:00 1.00 PROD1, TRIPCAS MPDA P Pull 4 1/2" MPD bearing Stand back stand T/183' 183.0 183.0 5/27/2024 12:00 5/27/2024 15:00 3.00 PROD1, TRIPCAS BHAH P PJSM on L/D BHA Lay down 3 JTS 4 1/2" HWDP L/D BHA #8 as per Baker DD 183.0 0.0 5/27/2024 15:00 5/27/2024 18:00 3.00 PROD1, WHDBOP RURD P M/U 4-1/2' test joint and M/U wear bushing puller and pull wear bushing as per FMC rep. M/U BOP test plug and set test plug . Flood lines and BOP stack with fresh water. Rig up hole fill line to IA to continually fill well through IA while BOP testing. Static losses 180 to 200 BPH 0.0 0.0 5/27/2024 18:00 5/28/2024 00:00 6.00 PROD1, WHDBOP BOPE P Perform BOPE test with 4-1/2" & 5-7/8" test jts. Annular to 250 psi low for 5 minutes and 2500 psi high for 10 minutes. Remaining tests to 250 psi low for 5 minutes and 3500 psi high for 10 minutes. #1 Annular with 4-1/2" test joint #2 Upper 3-1/2" x 6-5/8" VBR's with 4- 1/2" test joint, CMV 1,14,15,16.& Kill #3 Upper IBOP #3 CMV #10, 13, needle valve above #1, HCR Kill, Lower IBOP #4 CMV #4, 9, 12, Manual Kill & 5-7/8" TIW #5 CMV #6, 8, 11 & 5-7/8" Dart. #6 CMV #5, 7" & 4-1/2" TIW #7 CMV #2 & 4-1/2" Dart #8 HCR Choke #9 Manual Choke & Kill #10 Lower 3-1/2" x 6-5/8" VBR's with 4- 1/2" test joint. #11 Blind shear rams & CMV #3, 4, 6 Conduct Koomey draw down test, ACC = 3000 psi, Manifold = 1500 psi, ACC 1650 psi after all functions on bottles, 15 seconds for 200 psi build up with 2 electric pumps, 90 seconds to full system pressure with 2 electric pups and air pumps, closing times: ANN = 20 seconds, UPR = 12 seconds Blind shear = 12 seconds, LPR = 12 seconds. Choke HCR = 2 second, Kill HCR = 2 second, Test PVT gain/loss and flow out alarms, 10 bottles nitrogen backup average 4000 psi. test LEL and H2S alarms. Witness by AOGCC Brian Bixby. Static losses during BOP test, 720 bbls , 180 BPH. 0.0 0.0 5/28/2024 00:00 5/28/2024 01:30 1.50 PROD1, WHDBOP BOPE P Test BOP with 5 7/8" test joint, all test 250 PSI for 5 min and 3500 PSI for 10 min Test 3 1/2" x 6 5/8" LVBR Test 3 1/2" x 6 5/8" UVBR Test manual and super choke's to 2000 PSI Witness by AOGCC Brian Bixby 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 50/54 MT7-91 Report Printed: 6/25/2024 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) 5/28/2024 01:30 5/28/2024 02:30 1.00 PROD1, WHDBOP RURD P Pull test plug, install wear ring Lay down 5 7/8" test joint, blow down lines Blow down and rig down fill up line going to IA 0.0 0.0 5/28/2024 02:30 5/28/2024 03:30 1.00 COMPZN, CASING RURD P Rig up power tongs, elevators and floor valve to run 4 1/2" liner Confirm joint count and running order in pipe shed 0.0 0.0 5/28/2024 03:30 5/28/2024 06:00 2.50 COMPZN, CASING PUTB P RIH with floated 4 1/2" HYD 563 liner as per detail from surface to 904' MD SOW 87K Use Best O Life AG 2000 pipe dope Make up TQ = 5600 FT/LBS 0.0 904.0 5/28/2024 06:00 5/28/2024 12:00 6.00 COMPZN, CASING PUTB P RIH with floated 4 1/2" HYD 563 liner as per detail from 904' MD to 6450' SOW 87K Use Best O Life AG 2000 pipe dope Make up TQ = 5600 FT/LBS 904.0 6,450.0 5/28/2024 12:00 5/28/2024 14:45 2.75 COMPZN, CASING PUTB P RIH with floated 4 1/2" HYD 563 liner as per detail from 6450' MD to 8,129' MD SOW 102K Use Best O Life AG 2000 pipe dope Make up TQ = 5600 FT/LBS 6,450.0 8,129.0 5/28/2024 14:45 5/28/2024 15:30 0.75 COMPZN, CASING OTHR P Pick up Baker SLZXP, make up ITTS shear out sub on bottom of running tool, make up SLZXP to string, install Xanplex mix in liner tie back sleeve RIH T/8,129' to 8,182' 8,129.0 8,182.0 5/28/2024 15:30 5/28/2024 18:00 2.50 COMPZN, CASING RUNL P RIH F/8,182' T/11,295' MD 5 7/8" DP from derrick Obtain TQ and drag readings on first stand of drill pipe PUW 115K, SOW 111K, RTW @ 20 RPM 112K TQ 2K 8,182.0 11,295.0 5/28/2024 18:00 5/28/2024 19:00 1.00 COMPZN, CASING MPDA P Install 5-7/8" RCD bearing, line up on MPD system to fill hole. 11,295.0 11,295.0 5/28/2024 19:00 5/29/2024 00:00 5.00 COMPZN, CASING RUNL P Continue running liner on drill pipe as per program from 11,295' MD to 14,730' MD. Monitor hole fill and losses via pit #5 and flow meter. Obtain torque and drag before entering open hole. PUW 164K, SOW 139K, RTW @ 20 RPM 148K TQ 2K 11,295.0 14,730.0 5/29/2024 00:00 5/29/2024 07:30 7.50 COMPZN, CASING RUNL P Continue running liner on drill pipe F/14,730' T/19,418', tag bottom with 15K DN, pick up tag again same spot with 15K DN Monitor hole fill and losses via pit #5 and flow meter. 297K UP 218K DN Loss rate at ~50 - 60 BPH 14,730.0 19,418.0 5/29/2024 07:30 5/29/2024 08:30 1.00 COMPZN, CASING RURD P Pick up T/19,396' Lay down top double off stand 121 and make up pup joints, side entry sub, rig up hoses and valves for bursting Arsenal Flotation 19,418.0 19,396.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 51/54 MT7-91 Report Printed: 6/25/2024 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) 5/29/2024 08:30 5/29/2024 10:30 2.00 COMPZN, CASING CIRC P Set shoe at 19412' MD Pump at 2 BPM and pressure up to T/1320, burst Arsenal Flotation sub with 6 bbls pumped. Pump @ 5 BPM 40 PSI, catch pump pressure @ 122 BBLS pumped circulate 60 bbl tubing volume at 5 BPM 665 psi to clear debris from the WIV. Total loss with filling pipe = 177 BBLS 19,396.0 19,412.0 5/29/2024 10:30 5/29/2024 13:00 2.50 COMPZN, CASING CIRC P Break out of top drive, drop 1 1/8" ball, make up top drive Park liner in tension at set depth 19,412' MD Circulate at 5 BPM 520 PSI Pump 20 BBLS Hi Vis 8.5 PPG brine pill Chase with 495 BBLS 8.5 PPG brine Ball on seat @ 4178 STKS 305K SOW 218K PUW 19,412.0 19,412.0 5/29/2024 13:00 5/29/2024 14:00 1.00 COMPZN, CASING PACK P Pump at .5 BPM to pressure up to 1600 psi to shift WIV at 4178 strokes. Continue pumping at .5 BPM to 2000 psi hold to set hanger, increase to 3000 psi. Slack off to check if hanger has set, Hanger has not set. 4189 strokes pumped. Continue pumping at .5 BPM pressuring up to 3600 psi and slack off to check if hanger set. Hanger has not set hold, pressure, strokes pumped 4195. Pump at .5 BPM pressuring up to 4017 psi and slack off to check if hanger is set. Hanger has not set hold, pressure, strokes pumped 4199. Bleed off pressure and let sit for 2 minutes. Pump at .5 BPM to pressure up to 4000 psi and slack off to check if packer has set. Hanger has not set, hold pressure, strokes pumped 4247. Pump at .5 BPM to pressure up to 4500 psi and slack off to check if hanger has set. Packer and hanger assembly has set at 19,418' verify with 50K down weight. Pick up free from hanger to neutral weight confirm release and rotate at 15 RPM, 6K TQ. PUW 274K, SOW 248K. 19,412.0 19,418.0 5/29/2024 14:00 5/29/2024 15:00 1.00 COMPZN, CASING PRTS P R/U and test SLZXP liner top , flood surface lines with water. Close upper pipe rams and pressure up annular at .5 BPM test to 3500 PSI for 5 minutes charted. 90 strokes/10 bbls pumped. 19,418.0 19,402.0 5/29/2024 15:00 5/29/2024 15:30 0.50 COMPZN, WELLPR OWFF P Perform 30 minute flowcheck. Well static. 19,402.0 19,402.0 5/29/2024 15:30 5/29/2024 19:00 3.50 COMPZN, WELLPR DISP P Displace well from 8.5 ppg Flo-Pro to 9.0 ppg corrosion inhibited brine. Pump 20 bbl of HiVis spacer, followed by 700 bbls of 9.0 bbls corrosion inhibited brine at 5 BPM. Total strokes pumped 7,062 , 837 bbls. 19,402.0 19,402.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 52/54 MT7-91 Report Printed: 6/25/2024 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) 5/29/2024 19:00 5/29/2024 19:30 0.50 COMPZN, WELLPR OWFF P Perform 30 minute flowcheck. Well static. 19,402.0 19,402.0 5/29/2024 19:30 5/29/2024 21:30 2.00 COMPZN, WELLPR MPDA P Break down bleed and purge manifold and L/D. Pull 5-7/8" RCD bearing as per MPD advisor. 19,402.0 10,990.0 5/29/2024 21:30 5/30/2024 00:00 2.50 COMPZN, WELLPR PULD P Pull out of hole laying down singles of 5- 7/8" and 4-1/2" drill pipe to pipeshed. Monitor hole fill via trip tank. 10,990.0 9,448.0 5/30/2024 00:00 5/30/2024 03:00 3.00 COMPZN, WELLPR PULD P POOH laying down 5-7/8" singles to pipeshed from 9448' to 7085' Monitor hole fill via trip tank. 9,448.0 7,085.0 5/30/2024 03:00 5/30/2024 03:30 0.50 COMPZN, WELLPR SVRG P Perform rig service repair pin in pipe skate pipe roller. 7,085.0 7,085.0 5/30/2024 03:30 5/30/2024 04:00 0.50 COMPZN, WELLPR PULD T Repair pin in pipe skate pipe roller. 7,085.0 7,085.0 5/30/2024 04:00 5/30/2024 07:45 3.75 COMPZN, WELLPR PULD P POOH laying down 5-7/8" singles to pipeshed from 7085' to 3163' Monitor hole fill via trip tank. 7,085.0 3,163.0 5/30/2024 07:45 5/30/2024 11:30 3.75 COMPZN, WELLPR PULD P Change pipe handling equipment to 4- 1/2" POOH laying down 5-7/8" singles to pipeshed from 3163' to 50' Monitor hole fill via trip tank. 3,163.0 50.0 5/30/2024 11:30 5/30/2024 12:00 0.50 COMPZN, WELLPR BHAH P L/D liner running tools as per Baker rep. 50.0 0.0 5/30/2024 12:00 5/30/2024 17:30 5.50 COMPZN, WELLPR RURD P Make up stack washer and wash BOP stack at full rate. L/D stack washer and make up wear ring puller and pull wear ring as per FMC. Flush MPD equipment and clean and clear rig floor. 0.0 0.0 5/30/2024 17:30 5/30/2024 18:00 0.50 COMPZN, RPCOMP BHAH P PJSM with all parties , running 4-1/2" L80 H563 upper completions as per tally. P/U and M/U Haliburton self indexing mule shoe and remanding BHA to Opsis down hole gauge, torque all connections to 3800 FT/LB with BOL artic grade 2000, pipe dope. 0.0 245.0 5/30/2024 18:00 5/30/2024 18:45 0.75 COMPZN, RPCOMP RURD P M/U Haliburton TEC wire to Opsis mandrel gauge and test as per Haliburton tech. Pressure test to 10K and hold for 10 minutes. 245.0 245.0 5/30/2024 18:45 5/31/2024 00:00 5.25 COMPZN, RPCOMP PUTB P Continue run 4-1/2" L80 H563 upper completions as per tally with HES TEC wire. From 245' to 3246' torque all connections o 3800 LB/FT and dope wit BOL artic grade 2000 pipe dope. 245.0 3,246.0 5/31/2024 00:00 5/31/2024 06:00 6.00 COMPZN, RPCOMP PUTB P Continue run 4-1/2" L80 H563 upper completions as per tally with HES TEC wire. From 3246' to 7805' torque all connections o 3800 LB/FT and dope wit BOL artic grade 2000 pipe dope. Monitoring hole fill via trip tank. SOW 128K 3,246.0 7,805.0 5/31/2024 06:00 5/31/2024 11:15 5.25 COMPZN, RPCOMP PUTB P Continue run 4-1/2" L80 H563 upper completions as per tally with HES TEC wire. From 7805' to 11259' torque all connections o 3800 LB/FT and dope wit BOL artic grade 2000 pipe dope. Monitoring hole fill via trip tank. SOW 138K 7,805.0 11,259.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 53/54 MT7-91 Report Printed: 6/25/2024 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) 5/31/2024 11:15 5/31/2024 11:45 0.50 COMPZN, RPCOMP HOSO P Tag liner hanger No Go at 11,259' Performed space out calculations. Pick up and tag again to verify depth. slack off to 102K. PUW 158K Sow 138K 11,259.0 11,259.0 5/31/2024 11:45 5/31/2024 12:00 0.25 COMPZN, RPCOMP HOSO P Pick up and install space out pups between joints #168 and #169 with 25.3' of pup joints. Pick up tubing hanger. 11,259.0 11,230.0 5/31/2024 12:00 5/31/2024 13:45 1.75 COMPZN, RPCOMP THGR P Terminate TEC wire while keeping hole full losses encountered through AU sleeves at 96 BPH. Monitor losses Via trip tank pressure test TEC wire through tubing to 5K for 10 minute per FMC. Strip and cut TEC wire connect ETC cord from XPIO to TEC pig tail. 11,230.0 11,230.0 5/31/2024 13:45 5/31/2024 14:30 0.75 COMPZN, RPCOMP THGR P RIH with tubing hanger and land hanger as per FMC run in LDS. Monitor hole via trip tank 100 BPH losses. 11,230.0 11,254.9 5/31/2024 14:30 5/31/2024 15:00 0.50 COMPZN, RPCOMP PRTS P Close annular and pressure test hanger seals through kill line to 3000 psi for 5 minutes. 11,254.9 11,254.9 5/31/2024 15:00 5/31/2024 15:30 0.50 COMPZN, RPCOMP RURD P Drop ball and rod and rig up TIW, headpin,valve, and hose. 11,254.9 11,254.9 5/31/2024 15:30 5/31/2024 16:45 1.25 COMPZN, RPCOMP PRTS P Pump down tubing and pressure up to 500 psi, unable to hold pressure, eliminate possibility of surface equipment leak . keep pumping to keep pressure between 500-700 psi while consult with town. Continue hole fill on IA 100 BPH losses monitor via trip tank. 11,254.9 11,254.9 5/31/2024 16:45 5/31/2024 17:30 0.75 COMPZN, RPCOMP PRTS P Pressure up tubing to 1280 psi twice and dump pressure to help seat ball, then increase pressure up to 4270 psi and hold for 30 minutes. Losses 0. 11,254.9 11,254.9 5/31/2024 17:30 5/31/2024 18:15 0.75 COMPZN, RPCOMP PRTS P Bleed off tubing to 3000 psi and pressure up IA to 3000 psi and hold for 30 minutes to pressure test IA. 11,254.9 11,254.9 5/31/2024 18:15 5/31/2024 18:30 0.25 COMPZN, RPCOMP DHEQ P Bleed off tubing and observe SOV shear. IA stabilized at 60 PSI due to mud imbalance. 11,254.9 11,254.9 5/31/2024 18:30 5/31/2024 19:15 0.75 COMPZN, RPCOMP OWFF P Rig down TIW, valve and hoses and monitor tubing level for 30 minutes static. IA 60 psi due to mud imbalance. 11,254.9 11,254.9 5/31/2024 19:15 5/31/2024 19:30 0.25 COMPZN, RPCOMP RURD P Pull landing joint and L/D. 11,254.9 0.0 5/31/2024 19:30 5/31/2024 21:30 2.00 COMPZN, RPCOMP OWFF T Open IA and allow to U-tube prior to nipple down, U-tube due to light mud in the IA. pressure stabilized at 25 psi (Hydrostatic psi on sensor.) 0.0 0.0 5/31/2024 21:30 5/31/2024 22:00 0.50 COMPZN, RPCOMP THGR P Remove U-tube line and attempt to install HPBV. unable to get installed. Rig up landing joint and blow down BOP stack. L/D landing joint and run back in with HPBV and install successful. 0.0 0.0 5/31/2024 22:00 5/31/2024 23:00 1.00 COMPZN, RPCOMP DHEQ P Pressure test IA x OA and HPBV to 3000 psi for 10 minutes. Bleed off pressure. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 Page 54/54 MT7-91 Report Printed: 6/25/2024 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) 5/31/2024 23:00 6/1/2024 00:00 1.00 COMPZN, RPCOMP OWFF P Perform flow check verify well static. SIMOPS Flush mud pumps with deep clean. 0.0 0.0 6/1/2024 00:00 6/1/2024 04:45 4.75 COMPZN, WHDBOP RURD P Flush all surface line, choke manifold and MPD manifold, kill line MPD line and BOP with DeepClean. Drain BOP stack, blow down choke manifold and surface lines. L/D landing joint and pup. Remove upper riser clean and clear rig floor prepare for nipple down. Rig down MPD hoses, power down Koomey, Nipple down BOP, rack back on stump and secure. Simops break down stands of 4-1/2" drill pipe from derrick and lay singles to pipe shed. 0.0 0.0 6/1/2024 04:45 6/1/2024 07:00 2.25 COMPZN, WHDBOP NUND P Nipple down high pressure riser and secure on cart. SIMOPS: L/D stands 4-1/2" drill pipe from derrick. 0.0 0.0 6/1/2024 07:00 6/1/2024 10:15 3.25 COMPZN, WHDBOP NUND P Nipple up tree adapter and torque studs to 1670 Ft/lbs. Test void to 5K for 10 minutes. SIMOPS L/D stands 4-1/2" drill pipe from derrick. 0.0 0.0 6/1/2024 10:15 6/1/2024 12:00 1.75 COMPZN, WHDBOP NUND P Nipple up 5K FMC as per FMC, torque all studs to spec . Fill with diesel and prepare for pressure test. 0.0 0.0 6/1/2024 12:00 6/1/2024 14:30 2.50 COMPZN, WHDBOP PRTS P Pressure test 5K FMC production tree to 250 psi low and 5000 psi high for 10 minutes each test. SIMOPS: L/D 4-1/2" drillpipe stands from derrick. Cleaning mud pits. 0.0 0.0 6/1/2024 14:30 6/1/2024 16:00 1.50 COMPZN, WHDBOP RURD P Rig up LRS pumping unit and piping to freeze protect. SIMOPS: Continue cleaning pits and blow down mud lines and mud pumps. Rig off high line at 15:15 hours. 0.0 0.0 6/1/2024 16:00 6/1/2024 17:00 1.00 COMPZN, WHDBOP FRZP P Perform IA x tubing freeze protect to 1207' MD as per COP SOP, pump 83 bbls LEPD diesel down the IA, 1.5 BPM at 807 psi. Slow rate to 1.25 BPM after 35 bbls pumped 850 psi. SIMOPS:Continue cleaning pits, L/D 4- 1/2" drillpipe stands from derrick. 0.0 0.0 6/1/2024 17:00 6/1/2024 20:00 3.00 COMPZN, WHDBOP FRZP P U-tube IA x tubing starting psi IA = 190 psi Tubing = 196 psi. Open U-tube line and allow to U-tube for 3 hours. Final psi IA = 100, Tubing = 100. SIMOPS:Continue cleaning pits, L/D 4- 1/2" drillpipe stands from derrick. 0.0 0.0 6/1/2024 20:00 6/1/2024 21:00 1.00 COMPZN, WHDBOP RURD P R/D U-tube lines install gauges and secure well. SIMOPS:Continue cleaning pits L/D 4- 1/2" drillpipe stands from derrick. 0.0 0.0 6/1/2024 21:00 6/2/2024 00:00 3.00 DEMOB, MOVE RURD P Finish L/D 4-1/2" drillpipe stands from derrick C/O elevators and L/D 10 stands 5-7/8" drill pipe. Clean and clear rig floor, Secure BOP stack to stump for move. Release rig at 24:00. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 6/2/2024 !" # $ # "%&' ( ) * ) +&# ) ", ) ) ) - ) !" !" #) ## $ %&'"(() *+,)""-./"+,)0" ' 1. .) !" - )2" 3 )$ %&'"(() *+,)""-./"+,)0" ' 1. ) !" *) ! *) ( / ) * *)4 "! '25 $ . "! '664. 7 3 74 3 8(, 9 4 : $ 4 :: $ $ $ +.# ) +# ) 0 .) .) 102& 1 2& 3 !#+ ) !" ()(( ()(( +7!"+7!" )1; !(7"01); "(() ( #0 )()(( ()(( (<"(=,) ! "+"<,"=()+++ - 456 7 # . 4"6 * . 456 !" # * . &(; ">1>(, ";) ; 0();, + 7( !)+ &(, +>0>(, ";)+1 0();; + 7(11)"" ), ) # ) . !" ")( 49 , ) 7*4", 6 4 6 1 2& 4 6 456 102& 4 6 " 8 )+,)"" "()!!()((()((+,)"" 7* 4 6 .* " * 4 - 6 " 4 6 +>;">(, )+?@4" ?4 ": '? +.";+)++ 000) ! 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";7( ,);0 !()00 "+")!+ 07;+,)0 7;+()1 7+!0)+007"!!), +7!"07"!,)0" !70,0)!, ();, "7(" )0; *?-**'1. ";7"1!);, 0!),( "+)(( 07;+,)(+ 711),; 71,;)(07"!!), +7!"07"(!) ! !70!") ")+1 "7(!!); *?-**'1. ";71)!( 0!);, "+;)01 07;++)(0 7"0;)"; 710+) 07(() +7!"07(+);, !7!;"),1 ")!! "7" 0)1" *?-**'1. ";7;+!)" 0!);0 "+;) 07;+1)"+ 7(!1)!; 7 0)1;07(");, +7!" 7!; )!! !7! ")!" ()1" "7+!) ; *?-**'1. ";7,+")+; 0!), "+;); 07;+ )(0 7(",),; 7 ()";07() +7!" 70+,); !;7("")"" ()"" "7;; ) 0 *?-**'1. ";7+,+)0 0!)+; "+,)(; 07;+ )!( "7!!)! 70"")!,07(;)(! +7!" 7 10) + !;7(+()++ () 1 "7," )"; *?-**'1. ";71; ) 0!);, "+;)1 07;+0)0( "70, )0+ 70+)007(;)!! +7!" 710+)+! !;7(00)1( (),! "7,!;)! *?-**'1. ";7 0)!! 0!)," "+)! 07;+!)0( "7 1+)!, 70!;)+;07(,)!! +7!" 71()+ !;7" )+1 () "7+ ")+( *?-**' . ";70")1 0!);+ "+)!; 07;1()0" "710;), 7!;+)1!07(1)(( +7!" 7+"0)! !;7"1 )," ()( "71+()"( *?-**' . ";7!",)"1 00)0 "+)0 07;1)0 "71(")"( 7! )0,07( ), +7!" 7,;+),1 !;7( )1 ()+0 "7 0)1, *?-**' . ",7(( )!+ 00)! 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"+)+, 07,(1)"+ !+) ,7(")1(07+");, +7!"+7((1)( !,7;1,)(, (),1 ,7(""),1 *?-**' . "171!0)0 00)0! "+;)"" 07,( )! 0 ),; ,7,;) 007+;)"" +7!",7!)!" !,7,(;)!; ()1 ,7(0!)! *?-**' . "17 !()!+ 0!),0 "+;);; 07,(!), !1()"1 ,70+)+;07+,),; +7!",70;!)(1 !,7,,;); ()10 ,7"10);( *?-**' . "1700)" 0!)," "+)!0 07,"()" "7(,")+, ,7;1) 07++);" +7!",7 +1)+ !,7,0)0 ();! ,7,+)+" *?-**' . "17! +); !"); "+,)+0 07,(!)1( "7"+)"+ ,7;1 )!(07+,) ! +7!",71 ")01 !,7+")" )1( ,7;;)0+ *?-**' . " 7(10)"0 0!)+( "+)1+ 07,(!)(" "7(0) ,7,(!)",07+,)( +7!",7+0 )1; !,7+1()(, ) ! ,7,()(( *?-**' . " 7"1)"" 0!)," "+) + 07,(!)!( "7!") , ,7,+)07++)(! +7!",7+(;)(( !,71(() 0 ()", ,7,0")!( *?-**' . " 7+;);; 0!)+, "+);! 07,"() , "7; ) ( ,7,!,);07++)!; +7!",7,()!" !,71,()+, (), ,7++!)1( *?-**' . " 7;,1)+! 0!)! "+)0 07,"")", "7,++)+ ,7+; )""07+1);; +7!",7;;1)!; !,710")"( ()1! ,71;!)(( *?-**' . " 7,,(), 0!);, "+)1( 07,"") ( "7+;0) ,7+0()("07+1)0! +7!",7+)+, !,7 ")10 () ; ,7 "0)1; *?-**' . " 7+;), 0!)+, "+)0+ 07,")1( "71()1! ,71)+07+ ) ! +7!",7"1!),0 !,7 1")1 ();+ ,7 ! )( *?-**' . " 71+), 0!)+, "+;)(+ 07,";);+ "7 (;)+1 ,711,)+ 07+0)+, +7!",7(0+), !,70(")1 ()" ,70 +)!1 *?-**' . " 7 "0)(; 0!)+" "+) ; 07,",)" "7 0+)!+ ,7 (1) ,07+!);" +7!",7((")!+ !,70,")+( ();+ ,7!+,)+; *?-**' . " 70""),, 0!)+, "+)!" 07,",)0! "701!)(, ,7 ,!),"071()(0 +7!";7!" ) " !,700")0, ()( +7(;;)0! *?-**' . " 7!(;)0 0!)(" "+)10 07,"1)(1 "7!+"), ,7 !")1 071")+ +7!";70;,); !,7!")0( ()1; +7""),; *?-**' . " 7!!1)++ 00)!+ "+) ( 07," ) " 7(;;)+0 ,70;,)"0071)!( +7!";7 +()0! !,7!1)(" ()( +7"!") *?-**' . "07(!()! 0!)( "+)+( 07,"!); 7""1) ! ,70 );"071,)+1 +7!";7111)+ !+7(()0 (); +7 ")(0 *?-**' . "07"0);1 0!)(0 "+")0; 07,()!( 7"!0)"! ,7!();(0711)(! +7!";7+0;)!1 !+7(,;)+; () ; +7;,!)0, *?-**' . "07 +)1" 00),+ "+")0+ 07,)!" 70();0 ,7!1,)!0710)"( +7!";7+(()+! !+7(0+); ()10 +7,!)0 *?-**' . "07;10) , 00)0 "+()!( 07,+)+1 7;1)"( +7((0)0!07 () + +7!";7," )1 !+7" )+, ")(, +7+"()" *?-**' . "07,1"),+ 0 )!; ",1)0; 07,0)1; 7,,");! +7(+1) !07 ;)0 +7!";7;; )(0 !+7" ;) ,),( +7+!)(1 *?-**' . "07++;),! 00),1 "+()(, 07,;")+; 7+"!) +7"(,)!,07 1) +7!";7+ )," !+7"!)" ;)+; +71 ;)1! *?-**' . "071,1)(( 00),1 "+(),; 07,;,)( 71(()(+ +7"+()0+07 !)" +7!";7" +)0! !+71)0, (), +7 +,); *?-**' . "07 ;0),, 0 ); "+;)(; 07,; ),! 710");! +7"!,)1(070)10 +7!";7(!;); !+7;(,);" ;)"" +70;;) + *?-**' . "070;") 0 );( "+;);( 07,,")! 7 1,)(0 +7;1),;070 )"" +7!";7((!)++ !+7;,;)0; ();( +7!")"! *?-**' . "07!,)( 01)+0 "+,),, 07,,1)0 70, )0 +7 ),07!)(1 +7!"7!+)1 !+7;0); "),+ +7!!()(" *?-**' . "!7("1)01 01)1+ "+,) , 07,+);1 7!;()!! +7;" )("07! )++ +7!"70,(),0 !+7,"!) + ();; 17(1 )( *?-**' . "!7"(!) 0 )+" "++)!" 07,+ )(! ;7("+);( +7;++) +07;()0 +7!"7 ++)"; !+7,+1)"; ")+1 17",;)0" *?-**' . ( ) * ) +&# ) ", ) ) ) - ) !" !" #) ## $ %&'"(() *+,)""-./"+,)0" ' 1. .) !" - )2" 3 )$ %&'"(() *+,)""-./"+,)0" ' 1. ) !" 4 6 9 456 $ 456 102& 4 6 1 2& 4 6 ", 4 6 ", 4 6 . 4 6 0 . 4 6 , 4 6 + 452 :6 " * "!7()0; 0!)+0 "+;) 07,+!),+ ;7(!!),0 +7;!+);;07;(,)1, +7!"711!)0! !+7,!;);1 ;), 17")(! *?-**' . "!7!+)1 !"); "+,)0( 07,+0) ;7"0;)(1 +7,;+)1;07;(;)!" +7!"7+0+), !+7+;"); )" 17!0)1+ *?-**' . "!7;0!)1+ !) 1 "+1)"; 07,++);0 ;710)+; +7, ,)1,07;(()+ +7!"7,!0) " !+7+1 )!+ )(0 17; 1)"" *?-**' . "!7,"0)(( !) 1 "+1)"; 07,+,)(" ;7!,),; +7,01)"(07!!)( +7!"7, )+" !+7+ 0)1! ()(( 17;!!) 6C22 Page 1/1 MT7-91 Report Printed: 6/25/2024 Cement Cement Details Description Conductor String Cement Cementing Start Date 3/26/2024 18:00 Cementing End Date 3/26/2024 10:00 Wellbore Name MT7-91 Comment Cement Stages Stage # 1 Description Conductor String Cement Objective Top Depth (ftKB) 58.0 Bottom Depth (ftKB) 134.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Conductor String Cement Page 1/1 MT7-91 Report Printed: 6/25/2024 Cement Cement Details Description Surface String Cement Cementing Start Date 4/20/2024 03:30 Cementing End Date 4/20/2024 07:30 Wellbore Name MT7-91 Comment Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 58.0 Bottom Depth (ftKB) 3,548.0 Full Return? Yes Vol Cement … 136.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 5 Q Pump Avg (bbl/… 6 P Pump Final (psi) 380.0 P Plug Bump (psi) 900.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Surface Cement Fluid Description Estimated Top (ftKB) 54.4 Est Btm (ftKB) 3,042.0 Amount (sacks) 1,155 Class Blend Volume Pumped (bbl) 393.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 6.82 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 244.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 3,042.0 Est Btm (ftKB) 3,548.0 Amount (sacks) 358 Class G Volume Pumped (bbl) 70.1 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 5.10 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 MT7-91 Report Printed: 6/25/2024 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 4/28/2024 17:00 Cementing End Date 4/28/2024 22:15 Wellbore Name MT7-91 Comment Pump 60 bbl 12.5 ppg mud push @ 4 BPM, 420 psi. Cement wet at 17:22. Drop bottom plug at 17:57. Pump 71 bbls 13 ppg lead cement at 4.5 BPM average, 442 psi. Lead cement was wet at 17:57. Follow with 116 bbls of 15.8 ppg tail cement at 4.5 BPM average, 700 psi. Tail cement was wet at 18:24. Drop top plug at 19:04 and pump 10 bbls of fresh water from cement unit to flush lines. Chase with 679 bbls of 11.5 ppg Versa-Clean NAF from rig at 6 BPM average, 750 psi. Slow pumps to 3 BPM at 5560 strokes, bump floats at 5720 strokes FCP = 775 psi. Continue pumping to 5726 strokes 1275 psi for 500 psi over FCP. Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 6,220.0 Bottom Depth (ftKB) 9,360.4 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 5 P Pump Final (psi) 775.0 P Plug Bump (psi) 1,275.0 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 Pump 60 bbl 12.5 ppg mud push @ 4 BPM, 420 psi. Cement wet at 17:22. Drop bottom plug at 17:57. Pump 71 bbls 13 ppg lead cement at 4.5 BPM average, 442 psi. Lead cement was wet at 17:57. Follow with 116 bbls of 15.8 ppg tail cement at 4.5 BPM average, 700 psi. Tail cement was wet at 18:24. Drop top plug at 19:04 and pump 10 bbls of fresh water from cement unit to flush lines. Chase with 679 bbls of 11.5 ppg Versa-Clean NAF from rig at 6 BPM average, 750 psi. Slow pumps to 3 BPM at 5560 strokes, bump floats at 5720 strokes FCP = 775 psi. Continue pumping to 5726 strokes 1275 psi for 500 psi over FCP. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 1 Cement Page 1/1 MT7-91 Report Printed: 6/25/2024 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 5/5/2024 14:30 Cementing End Date 5/5/2024 19:45 Wellbore Name MT7-91 Comment Pump 70 bbl KCL deep clean spacer @ 2 BPM 750 psi. Flood lines 2.8 bbl H2O, pressure test to 5000 psi. Drop bottom dart at 15;30 hours. Pump 67 BBL 15.8 ppg cement at 2 BPM 680 to 83 psi cement wet at 15:33 hrs. Drop top dart at 16:23 hrs. Chase with 10 bbl H2O. @16:31 Chase with OBM from rig at 2 BPM, ICP 217 psi. Drop BOZO at 711 strokes. Pick up bottom wiper plug at 1259 strokes. 380 PSI Pick up top wiper plug at 1810 strokes 1792 psi. Bottom wiper plug at LC at 2009 strokes 2816 psi to shear. top plug at LC 2628 strokes, 600 PSI FCP, pressure up 500 over to 1163 psi and hold for 5 minutes. Losses throughout 264 bbls. Lost approximately 36 bbls cement once cement came out shoe Cement Stages Stage # 1 Description Intermediate String 2 Cement Objective Top Depth (ftKB) 10,990.0 Bottom Depth (ftKB) 11,388.0 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 2 P Pump Final (psi) 600.0 P Plug Bump (psi) 1,163.0 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 Pump 70 bbl KCL deep clean spacer @ 2 BPM 750 psi. Flood lines 2.8 bbl H2O, pressure test to 5000 psi. Drop bottom dart at 15;30 hours. Pump 67 BBL 15.8 ppg cement at 2 BPM 680 to 83 psi cement wet at 15:33 hrs. Drop top dart at 16:23 hrs. Chase with 10 bbl H2O. @16:31 Chase with OBM from rig at 2 BPM, ICP 217 psi. Drop BOZO at 711 strokes. Pick up bottom wiper plug at 1259 strokes. 380 PSI Pick up top wiper plug at 1810 strokes 1792 psi. Bottom wiper plug at LC at 2009 strokes 2816 psi to shear. top plug at LC 2628 strokes, 600 PSI FCP, pressure up 500 over to 1163 psi and hold for 5 minutes. Losses throughout 264 bbls. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 2 Cement T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Jun 07, 2024 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-91 Greater Mooses Tooth API #: 50-103-20881-00 Permit No: 224-020 Rig: Doyon 26 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-91 is located in a federal oil and gas unit. Only with respect to the MT7-91 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 224-020 T38878 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.07 08:40:44 -08'00' 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. Some people who received this message don't often get email from rig26@doyondrilling.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Rig 26 Cc:Regg, James B (OGC) Subject:RE: Doyon 26 BOP Form Date:Tuesday, June 4, 2024 2:36:32 PM Attachments:Doyon 26 05-06-24 Revised.xlsx Johnny, Attached is a revised report changing the test type to Other. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rig 26 <rig26@doyondrilling.com> Sent: Tuesday, May 7, 2024 5:26 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Doyon 26 Driling Supervisor <d26cm@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Samuel Dye <sdye@doyondrilling.com>; Ben Wedin <bwedin@doyondrilling.com>; BLM_AK_AKSO_EnergySection_Notifications <BLM_AK_AKSO_EnergySection_Notifications@blm.gov>; WSC Rig Advisor (wscrigadvisor@conocophillips.com) <wscrigadvisor@conocophillips.com>; Operations Engineer, Doyon 26 <Doyon26.OperationsEngineer@conocophillips.com> Subject: Doyon 26 BOP Form All, attached is info for our BOP test date 5-6-24 Johnny Newman Rig 26 Toolpusher Rig26@doyondrilling.com Rig Cell 907-301-1502 Office 907-670-4187 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Subm it to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:26 DATE: 5/6/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2240200 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Other: X Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2995 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 2 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 18-3/4"x5000psi P Pit Level Indicators P P #1 Rams 1 3-1/2"x 6-5/8"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 3-1/2"x6-5/8"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result HCR Valves 2 3-1/16" & 3-1/8"P System Pressure (psi)3050 P Kill Line Valves 2 3" & 3-1/16"P Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)14 P BOP Misc 0 P Full Pressure Attained (sec)85 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 3900 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 15 P #1 Rams 13 P Coiled Tubing Only:#2 Rams 14 P Inside Reel valves 0 NA #3 Rams 12 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5/3/24 @ 16:00 Waived By Test Start Date/Time:5/6/2024 15:30 (date) (time)Witness Test Finish Date/Time:5/6/2024 21:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Doyon Test Annular W/ 4-1/2" Test Joint to 250/2500psi Low/High F/ 5min Low, 10min high. Test #1 & #3 Rams W/ 4 1/2" & 5-7/8" TJ, Blind Rams, Auto & Manual IBOP's, Choke Manifold Valves #1-16, Kill lines and Choke line HCR's & Manual Valves, 4 1/2" Delta 425 & 5 7/8" VX57 FOSV & Dart valves all tested to 250/3500psi Low/High F/ 5min low, 10min high. Tested Gas Alarms. Tested Manual & Remote Manifold Chokes to 1,800psi. J. Newman / E. Fleagle ConocoPhillips K. Harding / K. Hinrichs GMTU MT7-91 Test Pressure (psi): rig26@doyondrilling.com d26cm@conocophillips.com Form 10-424 (Revised 08/2022) 2024-0506_BOP_Doyon26_GMTU_MT7-91 DOYON RIG 26 ACCUMULATOR DRAW DOWN WORKSHEET WELL: MT7-91 DATE: 5-6-24 ACCUMULATOR PSI 3050 MANIFOLD PSI 1550 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 1700 Accumulator bottle pre-charge 1000 NITROGEN BOTTLE'S 10ea 3900psi Avg. TURN ON ELEC. PUMP, SEC FOR 200 PSI = 14 * Tested with both electric pumps TURN ON AIR PUMP'S TIME FOR FULL CHARGE = 85 Doyon 26 MT7-91 5-6-24 Test Sequence 4-1/2” Test Joint #1. Annular #2. UPR/ Valves 1,14,15,16/ kill valve 3 #3. Valves 10, 13/ HCR kill/ upper IBOP #4. Valves 4, 9, 12/ manual kill/ lower IBOP #5. Valves 6, 8, 11 #6. Valve 5,7/ 5-7/8 dart #7. Valve 2/ 5-7/8 FOSV #8. HCR choke #9. Manual choke #10. LPR #11. Blind shears, valves 3, 4 #12. Choke A , choke B 5-7/8” Test Joint #13. UPR/ 4-1/2 Dart #14. LPR / 4-1/2 FOSV STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-91 JBR 07/05/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tested with 4 1/2" and 5 7/8" Test Joints. Precatghe Bottles = 11 each @ 950 psi and 25 each @ 1000psi. Good. Test Results TEST DATA Rig Rep:J. Newman/A/ AgnesOperator:ConocoPhillips Alaska, Inc.Operator Rep:R. Bjorhus/K. Hinrichs Rig Owner/Rig No.:Doyon 26 PTD#:2240200 DATE:5/28/2024 Type Operation:DRILL Annular: 250/2500Type Test:OTH Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB240529102731 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7.5 MASP: 2995 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 18 3/4"P #1 Rams 1 3 1/2"x 6 5/8"P #2 Rams 1 Blind/Shear P #3 Rams 1 3 1/2"x 6 5/8"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 2 1/16,3 1/8 P Kill Line Valves 2 3", 3 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1650 200 PSI Attained P15 Full Pressure Attained P90 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P10@4000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P12 #2 Rams P12 #3 Rams P12 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9999 9 3UHFKDUJH MEU %23(7HVW'R\RQ *07807 37' $2*&&,QVS5SWERS%'% %23(7HVW'R\RQ *07807 37' $2*&&,QVS5SWERS%'% %23(7HVW'R\RQ *07807 37' $2*&&,QVS5SWERS%'% DOYON RIG 26 ACCUMULATOR DRAW DOWN WORKSHEET WELL: MT7-91 DATE: 5-28-24 ACCUMULATOR PSI 3000 MANIFOLD PSI 1500 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 1650 Accumulator bottle pre-charge 1000 NITROGEN BOTTLE'S 10ea 4000psi Avg. TURN ON ELEC. PUMP, SEC FOR 200 PSI = 15 * Tested with both electric pumps TURN ON AIR PUMP'S TIME FOR FULL CHARGE = 90 %23(7HVW'R\RQ *07807 37' $2*&&,QVS5SW ERS%'% STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-91 JBR 06/07/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 A 5 7/8" test joint was used for testing. During test #8 the speed head on the BOPs began to leak. They bled off and tightened the head and went back to a high for a fail. The head was then retorqued and tested for a pass. This is captured in BOP Misc. Test Results TEST DATA Rig Rep:A. Agnes/R. PackratzOperator:ConocoPhillips Alaska, Inc.Operator Rep:R. Bjorus/ Rig Owner/Rig No.:Doyon 26 PTD#:2240200 DATE:4/21/2024 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC240420123031 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 11.5 MASP: 2995 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 18 3/4" 5000 P #1 Rams 1 3.5X6 5/8" V P #2 Rams 1 Blind/Shear P #3 Rams 1 3.5X6 5/8" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/16" & 3 1/P Kill Line Valves 2 3 1/16" & 3"P Check Valve 0 NA BOP Misc 1 Speed Head FP System Pressure P3000 Pressure After Closure P1600 200 PSI Attained P15 Full Pressure Attained P100 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@3900 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P15 #2 Rams P24 #3 Rams P15 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 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 MT7-91 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-020 Surface Location: 1102' FSL, 2105' FWL, SESW S32 T10N R2E, UM Bottomhole Location: 867' FSL, 3414' FWL, SESE S4 T9N R2E, UM Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this day of March 2024. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.28 15:46:40 -05'00' 28 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: CRU Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): Colville River Unit MD: 21,899 TVD: 8,454 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: 4/15/2024 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1866' to AA081780 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 155.3 15. Distance to Nearest Well Open Surface: x-290186 y- 5915918 Zone- 4 100.7 to Same Pool: 2380' to MT7-14A 16. Deviated wells:Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42 20 94 H-40 Welded 80 40 40 120 120 16 13-3/8" 68 L-80 Hyd563 3492 40 40 3532 3027 12-1/4" 9-5/8" 47.00 L-80 Hyd563 9491 40 40 9531 7248 8.5" x 9-7/8"7.625" 33.70 P-110S Hyd523 1907 9381 7556 11288 8248 6-1/2" 4.5" 12.60 L-80 Hyd563 10761 11138 8305 21899 8454 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 1273 sx 11.0 ppg CG + 238 sx 15.8 ppg CG MT7-91 Greater Mooses Tooth Rendezvous Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 4765' FSL, 4049' FWL , SESW S32 T10N R2E, UM 867' FSL, 3414' FWL, SESE S4 T9N R2E, UM 932535000, 932516000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry 603 sx 13.0 ppg CG + 125 sx 15.8 ppg CG Total Depth MD (ft):Total Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 18. Casing Program:Top - Setting Depth - BottomSpecifications 3840 2995 ConocoPhillips Alaska. Inc. 1102' FSL, 2105' FWL, SESW S32 T10N R2E, UM AA081800,AA081781 3782, 5723 59-52-180 LengthCasing Authorized Title: Authorized Signature: Authorized Name: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 104 sx 15.8 ppg CG Uncemented liner w/frac sleeves & swell packers Effect. Depth MD (ft):Effect. Depth TVD (ft): d:: Y: Y YYYYYYYYYYYYYYYYYYYYYYYeeees ype of W l 1b S Class: os N d:::Yeeees NNNNo s N NNNNo Dril s s s T Dril 0 o haaaaleslesssleeeeeeeeeeeeeeeeeeeeee: well is G S S 2 SS S d:::Yeeees NNNNo s No S G y E S d:::Yeeees NNNNo s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 1:29 pm, Mar 01, 2024 X 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. AA098885, AA092341 A.Dewhurst 12MAR24 50-103-20881-00-00 GMTU 224-020 DSR-3/4/24 Diverter variance granted per 20 AAC 25.035(h)(2) VTL 3/27/2024 *&:JLC 3/27/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.03.28 15:47:29 -05'00' 03/28/24 03/28/24 'DdDdϳͲϵϭ 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. 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' ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 27, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-91 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand injector well from the MT7 drilling pad. The intended spud date for this well is 4/15/2024. It is intended that Doyon 26 be used to drill the well. MT7-91 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 7-5/8” liner string will be set and cemented from TD to seccure the shoe and cover 500’ MD or 250’ TVD above any hydrocarbon bearing zone. The production interval will be comprised of a 6-1/2" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as a injector with 4.5” liner with sleeves and swell packers. The upper completion will include a production packer with GLM’s and tied back to surface. It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. 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: MT7-91 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1552 Weifeng Dai Chris Brillon ATO 1548 Staff Drilling Engineer Andy Mack Kuukpik Corp It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted Recommend granting diverter variance. -A.Dewhurst 12MAR24 MT7-91 Saved: 27-Feb-24 MT7-91 Page 1 of 14 Printed: 27-Feb-24 MT7-91 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 MT7-91 Saved: 27-Feb-24 MT7-91 Page 2 of 14 Printed: 27-Feb-24 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-91 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1102' FSL, 2105' FWL, SESW S32 T10N R2E, UM NAD27 Northings: 5915918 Eastings: 290186 RKB Elevation 54.6’ AMSL Pad Elevation 100.7’ AMSL Top of Productive Horizon (Heel) 4765' FSL, 4049' FWL , SESW S32 T10N R2E, UM NAD27 Northings:5919526 Eastings: 292219 Measured Depth, RKB: 11,600’ Total Vertical Depth, RKB: 8,309’ Total Vertical Depth, SS: 8,153’ Total Depth (Toe) 867' FSL, 3414' FWL, SESE S4 T9N R2E, UM NAD27 Northings: 5910225 Eastings: 296637 Measured Depth, RKB: 21,899’ Total Vertical Depth, RKB: 8,454’ Total Vertical Depth, SS: 8,298’ Please see attached well stick diagram for the current planned development of the pad. MT7-91 Saved: 27-Feb-24 MT7-91 Page 3 of 14 Printed: 27-Feb-24 Pad Layout Well Stick Diagram MT7-91 Saved: 27-Feb-24 MT7-91 Page 4 of 14 Printed: 27-Feb-24 MT7-91 Saved: 27-Feb-24 MT7-91 Page 5 of 14 Printed: 27-Feb-24 3. Proposed Drilling Program 1. MIRU rig Doyon 26 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 3-1/2” x 6-5/8” VBR. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4” drilling BHA to drill intermediate #1. (LWD Program: GR/RES). 8. Chart casing pressure test to 3,500 psi for 30 minutes. 9. Drill out shoe track and 20’ of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. 1. Send results to AOGCC as soon as available. 11. Displace well to 11.0 ppg Fresh water polymer WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and trip out of hole. 14. 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 3-1/2” x 6-5/8” 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. Send OH logs to AOGCC to review shallow hydrocarbon bearing sands MT7-91 Saved: 27-Feb-24 MT7-91 Page 6 of 14 Printed: 27-Feb-24 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 drill pipe. 7. Continue to Step 24 below 23. Circulate wellbore clean and trip OOH. 24. Change upper ram to 7-5/8” fix casing ram and test the same. 25. Pick up and run in hole with the 7-5/8” liner to section TD. 26. Circulate and condition mud in preparation for cementing. 27. Cement 7-5/8” liner to required TOC. Set liner top packer. Circulate excess cement from top of liner. POOH laying down drill pipe. Submit results to AOGCC as soon as possible. 28. Change out upper rams to 3-1/4” x 6-5/8” VBR. 29. Pick up DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 30. Pick up and RIH with 6-1/2” drilling assembly. (LWD Program: GR/Azimuthal RES, Neu/Den). 31. Chart casing pressure test to 3,500 psi for 30 minutes and record results. 32. Drill out and perform FIT to 13.5 ppg EMW. 33. Drill 6-1/2” horizontal hole to TD. 34. Circulate the hole clean, displace to vis brine, POOH. 35. Run 4-1/2” liner on DP, set liner hanger and top packer. Test to confirm packer set. Release from hanger and displace well to CI brine. POOH and laying down DP. 36. Run 4-1/2” tubing with production packer, DHG, GLMs and landing nipples. Locate and space out tubing. Terminate TEC wire and land tubing hanger. 37. Test tubing hanger seals from above to 2,500 psi for 15 mins. 38. Drop ball and rod. Pressure up to set production packer. 39. Pressure test tubing to 4,200 psi for 30 mins. Test IA to 3,500 psi for 30 mins. Shear SOV. 40. Install BPV, test same and tubing hanger seals from below to 2,500 psi. 41. Nipple down BOP, terminate TEC wire. 42. Install tubing head adaptor. Pressure test adaptor to 5,000 psi. 43. Install tree and test. 44. Pull BPV, freeze protect IA and tubing. 45. Secure well. Rig down and move out. 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP and diverter schematics on file for Doyon 26. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD (ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 115 / 115 10.9 52 54 MT7-91 Saved: 27-Feb-24 MT7-91 Page 7 of 14 Printed: 27-Feb-24 13.375 3,532 / 3,027 14.5 1364 1077 9.625 9,531 / 7,248 16.5 3406 1980 7.00 11,228 / 8,248 12.5 3755 2930 4.5 21,899 / 8,454 12.5 3840 2995 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) = 1380 – (0.1 x 3027’) = 1077 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 3027’ = 1980 psi OR ASP = FPP – (0.1 x D) = 3406 – (0.1 x 7248) = 2681 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 7248 = 5494 psi OR ASP = FPP – (0.1 x D) = 3755– (0.1 x 8248’) = 2930 psi Minimum MW needed = 8.7 ppg 4. Drilling below 7” production liner MT7-91 Saved: 27-Feb-24 MT7-91 Page 8 of 14 Printed: 27-Feb-24 ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8454 = 4650 psi OR ASP = FPP – (0.1 x D) = 3840 – (0.1 x 8454) = 2995 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 L-80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7.625 8.5 x 9.875 33.7 P-110 Hyd523 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 4.5 6.125 12.6 L-80 Hyd563 Uncemeneted open hole liner with frac ports and swell packers 13.375” Surface Casing run to 3,532’ MD /3,027’ TVD Cement Plan: Cement from 3,532’ MD to 3,032' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,032' 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 3,032’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 2,201 ft3 => 1,273 sx of 11.0 ppg Deepcrete + Add's @ 1.73 ft3 /sk Tail slurry from 3,532’ MD to 3,032’ 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 MT7-91 Saved: 27-Feb-24 MT7-91 Page 9 of 14 Printed: 27-Feb-24 9.625” Intermediate Casing run to 9,531’ MD / 7,248’ 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 6,539’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Albian Sub 93. If a shallower hydrocarbon zone of producible volumes is encountered while drilling, a 2nd stage cement job will be performed to isolate this zone. Assume 30% excess annular volume. Lead slurry from 9031’ MD to 6,539’ MD with 13.0 ppg Class G + Add’s Total Volume = 1015 ft3 => 603 sx of 13.0 ppg Class G + Add's @ 1.68 ft 3 /sk Tail slurry from 9,531’ MD to 9,031’ 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 7-5/8” Intermediate Casing run to 11,288’ MD /8,248’ TVD Cement Plan: Top of slurry is designed to be at 10,727’ MD, which is 500’MD or 250’ TVD above Alpine D. Assume 40% excess annular volume. Tail slurry from 11,288’ MD to 10,727’ MD with 15.8 ppg Class G + Adds Total Volume = 169 ft3 => 104 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 – 9.5 PV cP 13 10 40 15 YP lb./100 ft2 35-50 20 - 28 20 - 35 15 - 20 Funnel Viscosity s/qt. 200 40 - 50 70 - 90 60 - 80 Initial Gels lb./100 ft2 50 10 14 10 10 Minute Gels lb./100 ft2 60 15 42 15 API Fluid Loss cc/30 min. N.C. – 15.0 10 N/A 4 HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 5.0 10.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A fresh water drilling fluid (KSI) will be used for the surface interval. Keep flow line viscosity at r 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 10.0 ppg by use of solids control system and dilutions where necessary. 6,539’ MD,y j ppg y p ppg y g which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Albian Sub 93 MT7-91 Saved: 27-Feb-24 MT7-91 Page 10 of 14 Printed: 27-Feb-24 Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-12.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: The intermediate 2-hole section will be drilled with OBM weighted to 11.5 ppg. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight will be 11.5 targeting 13.0 EMW using MPD. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with water-based mud drill-in fluid weighted to 8.8-9.5 ppg. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 26 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT7-91 will be injected into a permitted annulus on the MT7 pad, or hauled to the Class 1 disposal well on CD1. The MT7-91 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 MT7-91 has been drilled and completed, consideration may be given to permit this well for annular injection. MT7-91 Saved: 27-Feb-24 MT7-91 Page 11 of 14 Printed: 27-Feb-24 An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the C10 formation, above the K3. These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig’s specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3027’) + 1,500 psi = 3,389 psi Pore Pressure = 1,381 psi Therefore Differential = 3389 – 1,381 = 2008 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” 47 L-80 3 Hyd563 3810 psi 3238 psi 6330 psi 5380 psi MT7-91 Saved: 27-Feb-24 MT7-91 Page 12 of 14 Printed: 27-Feb-24 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 MT7-91 Saved: 27-Feb-24 MT7-91 Page 13 of 14 Printed: 27-Feb-24 control practices, mud scavengers 6.5” Hole / 4.5” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in 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. Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG 4-5 (3x) 3) HES Opsis Downhole Gauge 4) Baker Premier Production Packer 5) 4-½” DB Landing Nipple (3.75" ID) 6) Baker Liner Top Packer / Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner w/ swell packers and AU sleeve MW: 9.1 Visc Brine 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-1/2” Production Hole TD at 21,899' MD / 8,454' TVD Tubing 4-1/2" 12.6# L-80 Hyd563 MT7-91wp06 Proposed X GLGL GLGL 1/29/2024 Production Packer DQ Xpak LH & Packer Downhole Gauge 16" Surface Hole Surface Casing 13-3/8" 68# L-80 Hyd563 Set at 3,532' MD / 3,027' TVD 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7-5/8" 33.7# P110S HYD523 Liner top at +/- 9,381' MD / 7,211' TVD Shoe set @ 11,287' MD / 8,248' TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8" 47# L-80 HYD563 Set @ 9,531' MD / 7,248' TVD Top HRZ 9,513' MD / 7,233' TVD 4-String Injector Schematic Top Alpine D 11,227' MD / 8,233 TVD Plan Int1 TOC 6,531' MD / 4,911' TVD Top Alpine C 11,600' MD / 8,309' TVD 11,137' MD / 8,210' TVD MT7-91 Saved: 27-Feb-24 MT7-91 Page 14 of 14 Printed: 27-Feb-24 15. Proposed Completion Schematic Superseded by updated wellbore schematic. -A.Dewhurst 07MAR24 55 500 500 1000 1000 1500 1500 2000 2000 3000 3000 5000 5000 8000 8000 12000 12000 18000 18000 21899 MT7-91_wp06 Plan Summary MT7-91_wp06 MT7-92 wp07 (88+89 S2N) MT7-14AMT7-14 MT7-08PB1 MT7-07 MT7-03A RWO Redrill MT7-03 MT7-11 MT7-02 MT7-09 MT7-94 MT7-04 MT7-06MT7-06AMT7-06PB1 MT7-93 MT7-95 MT7-99 MT7-01PB1 MT7-01 MT7-98MT7-96MT7-05 MT7-97 0 4 Do g l e g S e v e r i t y 0 3500 7000 10500 14000 17500 21000 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] MT7-92 wp07 (88+89 S2N) MT7-94 MT7-93 MT7-95 MT7-96 0 5000 Tr u e V e r t i c a l D e p t h -2000 0 2000 4000 6000 8000 Vertical Section at 129.84° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Liner 4-1/2" Production Liner 0 500 1000 Ce n t r e t o C e n t r e S e p a r a t i o n 0 3000 6000 9000 12000 15000 18000 21000 Measured Depth Equivalent Magnetic Distance DDI 6.990 SURVEY PROGRAM Date: 2023-03-27T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.60 1450.00 MT7-91_wp06 (MT7-91)r.5 SDI_URSA1 1450.00 3532.00 MT7-91_wp06 (MT7-91) MWD+IFR2+SAG+MS 3532.00 9531.00 MT7-91_wp06 (MT7-91) MWD+IFR2+SAG+MS 9531.00 11288.00 MT7-91_wp06 (MT7-91) MWD+IFR2+SAG+MS 11288.00 21899.31 MT7-91_wp06 (MT7-91) MWD+IFR2+SAG+MS Surface Location North / 5915661.76 East / 1430222.44Ground / 100.70 CASING DETAILS TVD MD Name 3027.36 3532.40 13-3/8" Surface Casing 7248.26 9531.31 9-5/8" Intermediate Casing 8247.69 11287.98 7" Intermediate Liner 8453.73 21899.31 4-1/2" Production Liner Mag Model & Date: BGGM2023 01-May-24 Magnetic North is 13.62° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.33° 57068.72nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 54.60 0.00 0.00 54.60 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 300.00 699.91 2.62 -4.53 1.50 300.00 -5.16 Start Build 2.00 4 1000.00 9.00 300.00 998.13 18.29 -31.68 2.00 0.00 -36.04 Start DLS 2.50 TFO 70.74 5 2896.34 50.92 3.55 2626.37 876.59 -119.65 2.50 70.74 -653.42 Start 4325.74 hold at 2896.34 MD 6 7222.08 50.92 3.55 5353.48 4227.95 88.21 0.00 0.00 -2640.72 Start DLS 3.00 TFO 143.35 7 9505.25 35.85 112.07 7227.14 4949.17 856.40 3.00 143.35 -2512.88 Start 94.58 hold at 9505.25 MD 8 9599.83 35.85 112.07 7303.80 4928.36 907.73 0.00 0.00 -2460.13 Start DLS 3.10 TFO 54.80 9 11244.17 75.61 153.00 8236.80 3974.11 1773.32 3.10 54.80 -1184.17 Start 100.62 hold at 11244.17 MD 10 11344.78 75.61 153.00 8261.80 3887.27 1817.57 0.00 0.00 -1094.57 Start DLS 3.00 TFO 0.00 11 11799.35 89.25 153.00 8321.53 3486.73 2021.66 3.00 0.00 -681.26 Start 10099.96 hold at 11799.35 MD 12 21899.31 89.25 153.00 8453.73 -5511.64 6606.55 0.00 0.00 8603.76 TD at 21899.31 FORMATION TOP DETAILS TVDPath Formation 995.95 Permafrost_Base 1101.50 C40 1434.34 C30 1664.20 C20 2016.39 C10 3012.68 K3 3631.19 Albian 97 3829.33 Albian 96 4038.86 Albian 95 4732.77 Albian 94 5238.35 Albian 93 6370.28 Albian 92 6372.10 Albian 91 7233.28 HRZ 7581.26 LCU 8232.57 Alpine D ERS Rende Spark 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 (100.7 GL + 54.6 DF) @ 155.30usft 0 3000 6000 9000 Tr u e V e r t i c a l D e p t h ( 1 5 0 0 u s f t / i n ) -3000 0 3000 6000 9000 Vertical Section at 129.84° (1500 usft/in) 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Liner 4-1/2" Production Liner 1000 2000 30 0 0 4000 50 00 60 0 0 70 0 0 8000 90 0 0 1 000 0 1100 0 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 MT 7-9 1/MT7 -9 1_wp 06 Start Build 1.50 Start Build 2.00 Start DLS 2.50 TFO 70.74 Start 4325.74 hold at 2896.34 MD Start DLS 3.00 TFO 143.35 Start 94.58 hold at 9505.25 MD Start DLS 3.10 TFO 54.80 Start 100.62 hold at 11244.17 MD Start DLS 3.00 TFO 0.00 Start 10099.96 hold at 11799.35 MD TD at 21899.31 Section View Project: Western North Slope Site:GMT2 Rendezvous Pad Well: MT7-91 Wellbore: MT7-91 Design: MT7-91_wp06 Plan View Project: Western North Slope Site:GMT2 Rendezvous Pad Well: MT7-91 Wellbore: MT7-91 Design: MT7-91_wp06 -24000 -12000 0 12000 So u t h ( - ) / N o r t h ( + ) ( 6 0 0 0 u s f t / i n ) -24000 -12000 0 12000 24000 West(-)/East(+) (6000 usft/in) Target 2 1320ft Target 1 1320ft M T 7-9 2 w p07 (8 8 +8 9 S 2 N ) MT 7-14A MT 7-14 MT7 -0 8 P B1 M T 7-0 8 M T 7-0 7 M T7-03A R W O R e d rill M T7-03 M T 7 -10_w p 04 MT 7 -11 MT 7-0 2 M T7-09 MT 7 -94 MT7-0 4 MT7-0 6MT7-0 6 A MT 7-06 P B 1 MT 7 -93 M T 7 -95 M T 7-9 9 M T7-01PB 1 MT7-0 1 MT 7-9 8 MT 7-9 6 M T7 -05 MT 7 -9 7 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7" Intermediate Liner 4-1/2" Production Liner 50020002500 3000 3500 4000 4500 5000 6000 7000 750 0 800 0 84 5 4 M T7-9 1 _w p06 ! 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ttachment 1 – MT7-91 Area of Review (AOR) An Area of Review plot is show below of the MT7-91 planned wellpath and offset wells. MT7-92 is the offset well from the planned MT7-91 injector. MT7-92 has successfully cemented int 1 9-5/8” casing at this point. Plan forward is to drill int 2 section and cement 7-5/8” liner per plan, please refer to MT7-92 PTD for details. 1 Dewhurst, Andrew D (OGC) From:Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent:Tuesday, March 12, 2024 12:41 To:Dewhurst, Andrew D (OGC) Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Loepp, Victoria T (OGC); Hobbs, Greg S Subject:RE: [EXTERNAL]RE: GMTU MT7-91 (PTD 224-020): Questions Andy, yes, that is what our experience has been during the development of this Ʊeld. Weifeng Dai ConocoPhillips Alaska StaƯ Drilling Engineer Cell: 907-346-0324 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, March 12, 2024 10:47 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: GMTU MT7-91 (PTD 224-020): Questions Weifeng, OK, so just to conĮrm, you are saying that there is not potenƟal for these overpressured zones to Ňow and impart surface pressures higher than the 2,995 psi provided. Andy From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Monday, March 11, 2024 11:11 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com > Subject: RE: [EXTERNAL]RE: GMTU MT7-91 (PTD 224-020): Questions Morning Andy, apologies for the delay in my response due to my absence last Friday. I appreciate your perspective, and I concur with you assessment when over-pressured formation exists that is permeable. In our field, the high pressure, for example 12.2 ppg in Miluveach, is predominantly present in the shale and remains immobile. Consequently, our mud weight consistently remained lower than the pore pressure within the shale, and well flow is not observed. Specifically, for MT7-04, we used a mud weight of 10.6 ppg (for shale stability purpose), and with the existence of the sands you note, flow was still not observed as the section was drilled suggesting the sands are not pressured the same as the shales. Given these considerations, utilizing the highest pore pressure within the entire section to calculate MASP in this field appears to be a conservative approach, CPAI approach is to use 8.8 ppg at the next casing point, which is the high end of normal pore pressure gradient in MASP calculation. You don't often get email from weifeng.dai@conocophillips.com. Learn why this is important You don't often get email from weifeng.dai@conocophillips.com. Learn why this is important 2 Weifeng Dai ConocoPhillips Alaska StaƯ Drilling Engineer Cell: 907-346-0324 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Thursday, March 7, 2024 4:52 PM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE: GMTU MT7-91 (PTD 224-020): Questions Weifeng, Thank you for this table. Would you please explain why you are using pore pressures only at each casing point, rather than the maximum pressures within the enƟre hole secƟon for the MASP calculaƟon, speciĮcally where there are silts and sands? For example, at MT7-04, there do appear to be some sandy intervals in the upper part of the Miluveach. Andy From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Thursday, March 7, 2024 14:15 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]GMTU MT7-91 (PTD 224-020): Questions Afternoon Andy, Please see my comments below in green, let me know if you have any questions. Weifeng Dai ConocoPhillips Alaska StaƯ Drilling Engineer Cell: 907-346-0324 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, March 6, 2024 4:19 PM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]GMTU MT7-91 (PTD 224-020): Questions 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. You don't often get email from weifeng.dai@conocophillips.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Weifeng, I am reviewing the GMTU MT7-91 PTD and have a few quesƟons: x The prognosed depths on the direcƟonal plan to not enƟrely agree with those listed on the wellbore schemaƟc. Would you please clarify? The depths on the direcƟonal plan are the correct one, updated schemaƟc enclosed. x Would you please conĮrm that both AA098885 and AA092341 should be added to the 10-401 box 7: Property DesignaƟon? Yes, we should add those two leases in the box 7, updated 10-401 enclosed. x Are you planning to pre-produce this well? If so, for how long? Yes, currently planning to pre-produce for 4 months. x Regarding the predicted pore pressures for the well, I understand from previous communica Ɵon regarding MT7- 92 that there were porƟons of that wellbore that had anƟcipated pore pressures of at least 11.4 ppg EMW. Some of these overpressured zones are in shales that were not expected to be permeable. Would you please provide addiƟonal detail around the anƟcipated maximum pore pressures for each secƟon of this well (not just at each casing point)? Correct, there are some impermeable shales with higher PP. Please refer to the list below. Sections High PP Formation Lithology Max PP (ppg) Surface C10 Sand, silt and clay 9.3 Int 1 HRZ Sand and shale 11.2 Int 2 Miluveach Shale 12.2 Production Alpine D Sand, silt and clay 10.5 Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 224-020 X GRTR MOOSES TOOTH RENDEZVOUS OIL POOL GMTU MT7-91 WELL PERMIT CHECKLIST Company ConocoPhillips Alaska, Inc. Well Name:GMTU MT7-91 Initial Class/Type SER / PEND GeoArea 890 Unit 10750 On/Off Shore On Program SERField & Pool Well bore seg Annular DisposalPTD#:2240200 GRTR MOOSES TOOTH, RENDEZV OIL - 2822 NA1Permit fee attached Yes AA081800, AA081781 , AA098885, AA0923412Lease number appropriate Yes3Unique well name and number Yes GRTR MOOSES TOOTH, RENDEZV OIL - 282200 - governed by 7934Well located in a defined pool Yes5Well located proper distance from drilling unit boundary NA6Well located proper distance from other wells Yes7Sufficient acreage available in drilling unit Yes8If deviated, is wellbore plat included Yes9Operator only affected party Yes10Operator has appropriate bond in force Yes11Permit can be issued without conservation order Yes12Permit can be issued without administrative approval Yes13Can permit be approved before 15-day wait Yes Area Injection Order No. 4314Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes15All wells within 1/4 mile area of review identified (For service well only) Yes Planning 4 months of pre-production16Pre-produced injector: duration of pre-production less than 3 months (For service well only) NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) Yes MPSP18Conductor string provided Yes SC set at 3532' MD19Surface casing protects all known USDWs Yes 67% excess cement planned20CMT vol adequate to circulate on conductor & surf csg No21CMT vol adequate to tie-in long string to surf csg No uncemented liner with frac sleeves and swell packers22CMT will cover all known productive horizons Yes23Casing designs adequate for C, T, B & permafrost Yes24Adequate tankage or reserve pit NA25If a re-drill, has a 10-403 for abandonment been approved Yes26Adequate wellbore separation proposed Yes Diverter variance granted per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulations Yes Max reservoir pressure is 3840 psig(8.8 ppg EMW); will drill w/ 8.8 to 9.5 thru prod section28Drilling fluid program schematic & equip list adequate Yes29BOPEs, do they meet regulation Yes MPSP is 2995 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments) Yes31Choke manifold complies w/API RP-53 (May 84) Yes32Work will occur without operation shutdown No33Is presence of H2S gas probable Yes34Mechanical condition of wells within AOR verified (For service well only) Yes H2S not expected; rig has sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measures Yes Max pore pressure anticipated to be 11.4 ppg EMW in shales of Alpine D. Expecting 8.7 ppg in reservoir.36 Data presented on potential overpressure zones NA37Seismic analysis of shallow gas zones NA38Seabed condition survey (if off-shore) NA39Contact name/phone for weekly progress reports [exploratory only] Appr ADD Date 3/7/2024 Appr VTL Date 3/27/2024 Appr ADD Date 3/12/2024 Administration Engineering Geology Geologic Commissioner:Date:Engineering Commissioner:Date Public Commissioner Date INT2 section has overpressured shale zones that CPAI state are not capable of flowing. MPD used to control wellbore stability. *&:JLC 3/27/2024
