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223-002
DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 0 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 1 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 4/ 2 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 0 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 23 1 0 4 TV D 82 3 1 Cu r r e n t S t a t u s WA G I N 9/ 4 / 2 0 2 5 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 , N B I 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 5/ 1 / 2 0 2 3 20 0 2 3 1 0 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ C O M P _ M E M . L A S 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 20 0 2 3 1 0 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ C O M P _ M E M _ F u l l H e a d e r . L A S 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 36 0 0 0 2 8 9 8 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 - 11 _ R U N 0 1 _ M E M _ A P - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 2 _ M E M _ A P - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 3 _ M E M _ A P - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 4 _ M E M _ A P - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 5 _ M E M _ A P - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 6 _ M E M _ A P - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 36 0 0 0 2 8 9 8 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 - 11 _ R U N 0 1 _ M E M _V S S - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 2 _ M E M _V S S - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 3 _ M E M _V S S - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 4 _ M E M _V S S - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 5 _ M E M _V S S - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a Th u r s d a y , S e p t e m b e r 4 , 2 0 2 5 AO G C C P a g e 1 o f 6 CP A I _ M T 7 - , 11 _ CO MP _ M E M . L A S DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 0 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 1 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 4/ 2 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 0 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 23 1 0 4 TV D 82 3 1 Cu r r e n t S t a t u s WA G I N 9/ 4 / 2 0 2 5 UI C Ye s DF 5/ 1 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ R U N 0 6 _ M E M _V S S - L O G _ T I M E . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 20 0 2 3 1 0 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 11 _ V S S - D E P T H _ C O M P _ M E M . l a s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 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 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 01 _ M E M _ A P - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 02 _ M E M _ A P - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 03 _ M E M _ A P - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 04 _ M E M _ A P - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 05 _ M E M _ A P - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 06 _ M E M _ A P - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 01 _ M E M _ V S S - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 02 _ M E M _ V S S - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 03 _ M E M _ V S S - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 04 _ M E M _ V S S - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 05 _ M E M _ V S S - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ R U N 06 _ M E M _ V S S - L O G _ T I M E . a s c 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ m e m _ L T K _ R 4 . d l i s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ m e m _ L T K _ R 5 . d l i s 37 6 2 1 ED Di g i t a l D a t a Th u r s d a y , S e p t e m b e r 4 , 2 0 2 5 AO G C C P a g e 2 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 0 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 1 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 4/ 2 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 0 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 23 1 0 4 TV D 82 3 1 Cu r r e n t S t a t u s WA G I N 9/ 4 / 2 0 2 5 UI C Ye s DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ L T K _ R 5 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ L T K _ R 5 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ m e m _ L T K _ R 6 . d l i s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ L T K _ R 6 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ L T K _ R 6 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ m e m _ S T K _ R 4 . d l i s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 0 4 8 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 0 4 8 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ m e m _ S T K _ R 5 . d l i s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 5 _ L M G 1 0 0 _ 0 0 4 8 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 5 _ L M G 1 0 0 _ 0 0 4 8 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 5 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 5 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ m e m _ S T K _ R 6 . d l i s 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 6 _ L M G 1 0 0 _ 0 0 4 8 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 6 _ L M G 1 0 0 _ 0 0 4 8 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 6 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 37 6 2 1 ED Di g i t a l D a t a Th u r s d a y , S e p t e m b e r 4 , 2 0 2 5 AO G C C P a g e 3 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 0 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 1 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 4/ 2 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 0 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 23 1 0 4 TV D 82 3 1 Cu r r e n t S t a t u s WA G I N 9/ 4 / 2 0 2 5 UI C Ye s DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ m e m _ S T K _ R 6 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 2 M D _ C O M P _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 2 T V D _ C O M P _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 5 M D _ C O M P _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 5 T V D _ C O M P _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ A P - TI M E _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ V S S - DE P T H _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ V S S - TI M E _ M E M . c g m 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 2 M D _ C O M P _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 2 T V D _ C O M P _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 5 M D _ C O M P _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 11 _ 5 T V D _ C O M P _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ A P - TI M E _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ V S S - DE P T H _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 1 1 _ V S S - TI M E _ M E M . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 N A D 2 7 _ B H I E O W De f i n i t i v e S u r v e y s . t x t 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 N A D 2 7 _ C a n v a s De f i n i t i v e S u r v e y s . t x t 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ N A D 8 3 _ C a n v a s De f i n i t i v e S u r v e y s . t x t 37 6 2 1 ED Di g i t a l D a t a Th u r s d a y , S e p t e m b e r 4 , 2 0 2 5 AO G C C P a g e 4 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 0 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 1 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 4/ 2 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 0 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 23 1 0 4 TV D 82 3 1 Cu r r e n t S t a t u s WA G I N 9/ 4 / 2 0 2 5 UI C Ye s DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ N A D 8 3 _ P e t r e l De f i n i t i v e S u r v e y s . t x t 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ N A D 2 7 _ C o m p a s s De f i n i t i v e S u r v e y s . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 11 _ N A D 2 7 _ P e t r e l _ D e f i n i t i v e S u r v e y s . t x t 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ N A D 8 3 _ B H I E O W De f i n i t i v e S u r v e y s . t x t 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 1 1 _ N A D 8 3 _ C o m p a s s De f i n i t i v e S u r v e y s . p d f 37 6 2 1 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 61 2 1 7 3 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 : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ L A S _ R M . l a s 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ R M _ T O C _ 4 2 0 0 f t _ 1 4 6 2 0 f t _ P P T . pp t . p p t x 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 1 0 0 0 M D _ R M . P d f 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 2 0 0 M D _ R M . P d f 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 4 0 0 0 M D _ R M . p d f 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 4 0 0 0 M D _ R M _ L a b e l e d . p d f 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 5 0 0 M D _ R M . P d f 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 6 0 0 0 M D _ R M . p d f 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ 8 0 0 0 M D _ R M . p d f 37 6 4 5 ED Di g i t a l D a t a Th u r s d a y , S e p t e m b e r 4 , 2 0 2 5 AO G C C P a g e 5 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 5 0 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 1 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 4/ 2 1 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 0 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 23 1 0 4 TV D 82 3 1 Cu r r e n t S t a t u s WA G I N 9/ 4 / 2 0 2 5 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 Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 4/ 2 1 / 2 0 2 3 Re l e a s e D a t e : 2/ 2 2 / 2 0 2 3 DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ D L I S _ R M . d l i s 37 6 4 5 ED Di g i t a l D a t a DF 5/ 1 6 / 2 0 2 3 E l e c t r o n i c F i l e : GM T U _ M T 7 _ 1 1 _ R 1 _ 9 . 6 2 5 i n _ a n d _ 7 i n _ C a s i n g s _ So n i c S c o p e 4 7 5 _ T O C _ D L I S _ R M . h t m l 37 6 4 5 ED Di g i t a l D a t a Th u r s d a y , S e p t e m b e r 4 , 2 0 2 5 AO G C C P a g e 6 o f 6 M. G u h l 9/ 5 / 2 0 2 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT7-11 GMTU MT7-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 MT7-11 50-103-20850-00-00 223-002-0 G SPT 8229 2230020 2057 3575 3513 3514 3512 100 105 105 105 4YRTST P Sully Sullivan 7/15/2024 4 year MIT-IA no issues 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 MT7-11 Inspection Date: Tubing OA Packer Depth 910 2390 2340 2340IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240717094446 BBL Pumped:5.3 BBL Returned:5.2 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:30:59 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT7-11 GMTU MT7-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 MT7-11 50-103-20850-00-00 223-002-0 G SPT 8229 2230020 2057 3046 3049 3047 3046 110 110 110 110 INITAL P Sully Sullivan 6/11/2023 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 MT7-11 Inspection Date: Tubing OA Packer Depth 1185 2390 2360 2350IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230612103202 BBL Pumped:3.9 BBL Returned:3.8 Thursday, July 27, 2023 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: GMTU MT7-11 (PTD#223-002-0) Courtesy Notification Date:Wednesday, May 31, 2023 10:48:57 AM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, May 31, 2023 10:28 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Elganzoory, Mutasim H <melganzoory@blm.gov>; Earhart, Will C <William.C.Earhart@conocophillips.com>; NSK DHD Field Supervisor <n2238@conocophillips.com> Subject: GMTU MT7-11 (PTD#223-002-0) Courtesy Notification Good Morning, This is a courtesy notification associated with MT7-11 initial state witnessed MIT-IA. CPAI is using step rate technique to increase injection pressure as this well comes online. CPAI anticipates the well to reach planned injection pressure by June 10th. Once the well stabilizes, CPAI will provide (72hr) notice and coordinate initial state witnessed MITIA. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com t >>ED W/η^ Zs/ KZ Zη&/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' K>KZWZ/Ed^ ƐGMTU MT7-97 50-103-20849-00-00 222-150 GMTU MEMORY SonicScope TOC FINAL FIELD 1GMTU MT7-11 50-103-20850-00-00 223-002 GMTU MEMORY SonicScope TOC FINAL FIELD 1dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺWƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞWůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘sdƵŽŶŐΛƐůď͘ĐŽŵ^>ƵĚŝƚŽƌͲdƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĂŶĚƚŚĞĐŽŶƚĞŶƚƐŽĨƚŚĞƉĂĐŬĂŐĞŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐĐŽŶƚĞŶƚŽĨƚŚĞƐĂŶĚͬŽƌŚĂƌĚĐŽƉLJƉƌŝŶƚƐŵĂLJŽƌŵĂLJŶŽƚŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚĨŽƌĐŽƌƌĞĐƚŶĞƐƐŽƌƋƵĂůŝƚLJůĞǀĞůĂƚƚŚŝƐƉŽŝŶƚ͘η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞPTD: 222-150 T37644 PTD: 223-002 T37645MT7-97MT7-11GMTU MT7-1150-103-20850-00-00223-002GMTUMEMORYSonicScope TOCFINAL FIELDKayla JunkeDigitally signed by Kayla Junke Date: 2023.05.16 09:58:45 -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:4741' FSL, 4026' FWL S12 T9N R1E 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"L-80 80'10yards 13 3/8"L-80 3009' 9 5/8"L-80 7350' 7"L-80 8258' 4 1/2"L-80 8232' 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, 82bbls 15.8ppg Class G9 7/8" TUBING RECORD 23095' Lead: 191bbl 13ppg Class G Tail: 152bbl 15.8ppg Class G 8230' 12 1/4" 6 1/8" 14564'4.5 14431'MD/8199'TVD 14561'MD/8230'TVD BOTTOM 16"Lead: 432bbl 11ppg DeepCrete Tail: 73bbl 15.8ppg Class G CASING 50-103-20850-00-00 GMT MT7-11 3/4/2023 23104'MD/8231'TVD N/A 140.2 P.O.Box 100360, Anchorage, AK 99510-0360 289848 920' FSL, 1772' FWL S32 T10N R2E 1398' FSL, 69' FWL S36 T10N R1E 4/14/2023 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 4/21/2023 223-002 SETTING DEPTH TVD 5916569 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER, NBI 14562' 42" 12.6 5915745 Greater Mooses Tooth/Rendevous Pool AA081800, AA081781, AA081803 932535000, 932516000, 932519000, 932538000 0' 29 0' 12254' 3747' 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 281489 277740 CEMENTING RECORD 5909240 981'MD/981'TVD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner: 14562'MD/8230' TVD - 23095'MD/8232'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 43.5 14707' 39' 7264' 94 68 80' 39'12424' SIZE DEPTH SET (MD)PACKER SET (MD/TVD) 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 G d 1b 0 D p p and B om; Perf L s (((atta Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:06 am, May 08, 2023 Completed 4/21/2023 JSB RBDMS JSB 051623 G DSR-5/22/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 981 981 C-30 1422 1422 2059 2059 3685 3685 K-2 4373 3322 Albian 97 4905 4905 Albian 96 5310 5310 HRZ 12452 7364 Kalubik 12708 7494 Kuparuk C 12935 7607 12941 7610 14839 8279 23104 8231 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: Joe Longo Digital Signature with Date: Contact Phone:907-265-6824 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. 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: joseph.j.longo@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 Page 1 of 1 5/4/2023file:///C:/Users/jennalt/Downloads/MT7-11%20Final%20Schematic.vsd Page 1/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/1/2023 10:00 3/1/2023 12:00 2.00 MIRU, MOVE MOB P Pull 25' Drill line. Blow down Steam in pits, BOP deck and rig floor. Remove cattle shute covers and hook up hydralic lines. 0.0 0.0 3/1/2023 12:00 3/1/2023 15:00 3.00 MIRU, MOVE MOB P Lower cattle shute and secure, Raise C section and pin in place. Lower and pin derrick rams. SIMOPS: Unplugging Modules and stomp motor complexaway from pump module. Set Motor module on suspension. 0.0 0.0 3/1/2023 15:00 3/1/2023 16:00 1.00 MIRU, MOVE MOB P Skid rig floor to MOB position, Secure roof and hand rails. SIMOPS: Stomp pump and pit modules and place on suspension. 0.0 0.0 3/1/2023 16:00 3/1/2023 18:00 2.00 MIRU, MOVE MOB P PJSM, Lower derrick and set on rack. Secure cables in derrick. SIMOPS: Stomp casing module away from pipe module and place on suspension. 0.0 0.0 3/1/2023 18:00 3/1/2023 21:00 3.00 MIRU, MOVE MOB P Raise well house, Unpin pipe shed from sub and stomp pipe module away from sub. 0.0 0.0 3/1/2023 21:00 3/2/2023 00:00 3.00 MIRU, MOVE MOB P Stomp sub off MT7-97 well and stomp towards MT7-11 well. 0.0 0.0 3/2/2023 00:00 3/2/2023 02:30 2.50 MIRU, MOVE MOB P Stomp sub off MT7-97 well and turn to position for trucks. 0.0 0.0 3/2/2023 02:30 3/2/2023 03:00 0.50 MIRU, MOVE MOB P Install Jeep onto sub and hook up truck. 0.0 0.0 3/2/2023 03:00 3/2/2023 07:30 4.50 MIRU, MOVE MOB P Move sub with trucks and align with MT7-11 well. SIMOPS: Stomp pipe shed and turn for trucks Change pump liners on #2 pump to 6.5" 0.0 0.0 3/2/2023 07:30 3/2/2023 09:30 2.00 MIRU, MOVE MOB P Lay mats on MT7-11 well, Pull sub on mats and remove trucks and Jeep from sub. 0.0 0.0 3/2/2023 09:30 3/2/2023 11:00 1.50 MIRU, MOVE MOB P Stomp sub, center and level on MT7-11 well. 0.0 0.0 3/2/2023 11:00 3/2/2023 16:00 5.00 MIRU, MOVE MOB P Lay mats for pipe shed, Lay herculite for well house. Hook up trucks to pipe shed and move into position. Remove truck and stomp pipe shed to align with sub. 0.0 0.0 3/2/2023 16:00 3/2/2023 18:00 2.00 MIRU, MOVE MOB P Lay mats for pit and pump modules. Hook up trucks to pits and pump modules and move toward sub. Remove off suspension and onto stompers. 0.0 0.0 3/2/2023 18:00 3/3/2023 00:00 6.00 MIRU, MOVE MOB P Stomp pipe shed module under sub. Trouble pinning pipe shed, re shim sub and pipe shed to pin pipe shed due to un level pad. SIMOPS: place mats for motor and casing modules. 0.0 0.0 3/3/2023 00:00 3/3/2023 01:30 1.50 MIRU, MOVE MOB P Stomp pits into place with sub, Hook trucks on casing module and move into position, release truck and remove off suspention and onto stompers. 0.0 0.0 3/3/2023 01:30 3/3/2023 03:00 1.50 MIRU, MOVE MOB P Stomp casing and pump module, shim pump module into position. Plug in electric for pits and pump modules. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 2/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/3/2023 03:00 3/3/2023 06:00 3.00 MIRU, MOVE MOB P Couldn't move casing module with stompers, Heat up worm drives to turn stompers due to cold weather while hooking up pump interconnect and move motor module with SOW. 0.0 0.0 3/3/2023 06:00 3/3/2023 07:00 1.00 MIRU, MOVE MOB P Heat up worm drives to turn stompers due to cold weather on motor module. 0.0 0.0 3/3/2023 07:00 3/3/2023 08:30 1.50 MIRU, MOVE MOB P Continue hook up interconnections, PJSM, raise and pin derrick. Retract raising cylinders SIMOPS: continue heating worm drives on motor modules. 0.0 0.0 3/3/2023 08:30 3/3/2023 09:30 1.00 MIRU, MOVE MOB P Continue hook up interconnections, PJSM, skid rig floor and install hand rails and walkways. 0.0 0.0 3/3/2023 09:30 3/3/2023 11:00 1.50 MIRU, MOVE MOB P Continue hook up interconnections, Lower cellar walls and Lower C section SIMOPS: Set motor module in place. 0.0 0.0 3/3/2023 11:00 3/3/2023 15:00 4.00 MIRU, MOVE RURD P Prep and raise cattle shute. install cattle shute roof covers. Remove straps on top drive and energy track. SIMOPS: Continue hook up interconnections 0.0 0.0 3/3/2023 15:00 3/3/2023 18:00 3.00 MIRU, MOVE RURD P Change hydralic fitting on hydralic pump, Swap rig to Gen power, Trouble shoot amphion, Spool up drill line on drum, install bridle lines. 0.0 0.0 3/3/2023 18:00 3/3/2023 22:00 4.00 MIRU, MOVE RURD P PJSM, Scope up derrick and secure. R/D bridle lines, Power up derrick lights, M/U kelly hose, Prep pits to take on fluid, Chink cellar wind walls, Install 4" valves in cellar, Install 2" valve in cellar, Note Accept rig at 2200 hrs 3-3-23 0.0 0.0 3/3/2023 22:00 3/4/2023 00:00 2.00 MIRU, MOVE NUND P N/U surface riser, Install air boot flange on surface annular, Take on mud to pits. SIMOPS: change pump #1 liners to 6.5" 0.0 0.0 3/4/2023 00:00 3/4/2023 04:00 4.00 MIRU, MOVE RURD P Continue N/U surface riser, Install air boot flange on surface annular, Take on mud to pits. SIMOPS: change pump #1 liners to 6.5" 0.0 0.0 3/4/2023 04:00 3/4/2023 05:30 1.50 MIRU, MOVE RURD P R/D 50' slings, Install master bushings, Install 90' mouse hole, Transfer BHA tools to rig floor. SIMOPS: taking on fluid and dress shakers 0.0 0.0 3/4/2023 05:30 3/4/2023 07:30 2.00 MIRU, MOVE BHAH P P/U and rack back 5" HWT drill pipe and jars. 0.0 0.0 3/4/2023 07:30 3/4/2023 10:00 2.50 MIRU, MOVE BHAH P PJSM. P/U 16" surface BHA #1. SIMOPS: Prime mud pumps and surface lines, Fill conductor and check for leaks (All Good) 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 3/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/4/2023 10:00 3/4/2023 10:30 0.50 MIRU, MOVE CIRC P Circulate and pressure test surface lines to 3500psi (good test) Wash in hole and tagged at 90' MD, wash in hole and clean out conductor to 120' MD. GPM: 575 PSI: 820 RPM: 40 0.0 120.0 3/4/2023 10:30 3/4/2023 12:00 1.50 SURFAC, DRILL DDRL P Drill 16" hole from 120' MD to 244' MD. WOB: 5k GPM: 575 PSI: 840 RPM: 40 TQ on: 5k ft/lbs TQ off: 4k ft/lbs F/O: 52% MW: 11.0 ppg PU: 48k SO: 55k ROT: 50k AST: 0.0hrs ART: 1.2hrs ADT: 1.2hrs 120.0 244.0 3/4/2023 12:00 3/4/2023 13:00 1.00 SURFAC, DRILL DDRL P Drill 16" hole from 244' MD to 276' MD. WOB: 6k GPM: 575 PSI: 780 RPM: 40 TQ on: 5k ft/lbs TQ off: 4k ft/lbs F/O: 52% MW: 11.0 ppg PU: 48k SO: 55k ROT: 50k 244.0 276.0 3/4/2023 13:00 3/4/2023 13:30 0.50 SURFAC, DRILL BKRM P BROOH from 276' MD to 55' MD GPM: 575 PSI: 670 RPM: 40 276.0 55.0 3/4/2023 13:30 3/4/2023 16:30 3.00 SURFAC, DRILL BHAH P P/U 16" surface BHA from 55' MD to 242' MD. 55.0 242.0 3/4/2023 16:30 3/4/2023 17:00 0.50 SURFAC, DRILL WASH P Wash in hole from 242' MD to 276' MD 242.0 276.0 3/4/2023 17:00 3/4/2023 18:00 1.00 SURFAC, DRILL DDRL P Drill 16" hole from 276' MD to 331' MD. WOB: 7k GPM: 690 PSI: 1290 RPM: 50 TQ on: 5k ft/lbs TQ off: 5k ft/lbs F/O: 56% MW: 11.0 ppg AST: 0.0hrs ART: 0.8hrs ADT: 2.0hrs 276.0 331.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 4/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/4/2023 18:00 3/5/2023 00:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole from 331' MD to 921' MD 920' TVD WOB: 8k GPM: 700 PSI: 1530 RPM: 60 TQ on: 5k ft/lbs TQ off: 5k ft/lbs F/O: 60% MW: 11.0 ppg AST: 0.9hrs ART: 3.4hrs ADT: 6.3hrs 331.0 921.0 3/5/2023 00:00 3/5/2023 03:30 3.50 SURFAC, DRILL DDRL P Drill 16" hole from 921' MD 920' TVD to 1,273' MD 1,268' TVD WOB: 7k GPM: 860 PSI: 1965 ECD: 11.5ppg RPM: 60 TQ on: 5k ft/lbs TQ off: 1.5k ft/lbs F/O: 66% MW: 11.0 ppg PU: 83k SO: 98k ROT: 87k AST: 0.7hrs ART: 1.6hrs ADT: 2.3hrs TBH: 8.6 TJH: 76.3 921.0 1,273.0 3/5/2023 03:30 3/5/2023 05:00 1.50 SURFAC, DRILL CIRC P Ball mill at max capacity, waiting on trucks off load in uprights and from disposal. Circulate at 575gpm 1023psi. Two trucks down 1- Water truck 1- Dirty mud truck 1,273.0 1,273.0 3/5/2023 05:00 3/5/2023 12:00 7.00 SURFAC, DRILL DDRL P Drill 16" hole from 1,273' MD 1,268' TVD to 1,973' MD 1,917' TVD WOB: 9k GPM: 900 PSI: 2200 ECD: 11.7ppg RPM: 60 TQ on: 7k ft/lbs TQ off: 1.5k ft/lbs F/O: 70% MW: 11.0 ppg PU: 95k SO: 95k ROT: 95k AST: 3.7hrs ART: 2.5hrs ADT: 6.2hrs TBH: 13.5 TJH: 81.2 1,273.0 1,973.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 5/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/5/2023 12:00 3/5/2023 18:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole from 1,973' MD 1,917' TVD to 2,610' MD 2401' TVD WOB: 14k GPM: 900 PSI: 2620 ECD: 11.7ppg RPM: 60 TQ on: 8k ft/lbs TQ off: 4k ft/lbs F/O: 70% MW: 11.0 ppg PU: 100k SO: 105k ROT: 105k AST: 2.2hrs ART: 2.2hrs ADT: 4.4hrs TBH: 17.9 TJH: 85.6 1,973.0 2,610.0 3/5/2023 18:00 3/6/2023 00:00 6.00 SURFAC, DRILL DDRL P Drill 16" hole from 2,610' MD 2,401' TVD to 3,339' MD 2,824' TVD WOB: 22k GPM: 900 PSI: 2850 ECD: 11.6ppg RPM: 60 TQ on: 10k ft/lbs TQ off: 4k ft/lbs F/O: 70% MW: 11.0 ppg PU: 119k SO: 106k ROT: 104k AST: 1.9hrs ART:2.4hrs ADT: 4.3hrs TBH: 22.2 TJH: 89.9 2,610.0 3,339.0 3/6/2023 00:00 3/6/2023 02:00 2.00 SURFAC, DRILL DDRL P Drill 16" hole from 3,339' MD 2,824' TVD to 3,620' MD 2,948' TVD. WOB: 23k GPM: 900 PSI: 3000 ECD: 11.6ppg RPM: 60 TQ on: 11k ft/lbs TQ off: 4k ft/lbs F/O: 70% MW: 11.0 ppg PU: 119k SO: 106k ROT: 104k AST: 0.3hrs ART: 1.3hrs ADT: 2.6hrs TBH: 23.8 TJH: 91.5 3,339.0 3,620.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 6/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/6/2023 02:00 3/6/2023 03:00 1.00 SURFAC, DRILL CIRC T While drilling, ECD rapid increased from 11.8ppg to 13.3ppg, Circulate BTM's up, Flow line packed off at 4200stks, clear flow line and stage pumps to full rate. GPM : 42-900 PSI: 90-2650 RPM: 5-60 ECD: 11.6-13.3ppg 3,620.0 3,620.0 3/6/2023 03:00 3/6/2023 04:30 1.50 SURFAC, DRILL DDRL P Drilling and TD 16" surface section from 3,620' MD to 3,757' MD 3,013' TVD. WOB: 23k GPM: 900 PSI: 3000 ECD: 11.6ppg RPM: 60 TQ on: 11k ft/lbs TQ off: 4k ft/lbs F/O: 70% MW: 11.0 ppg PU: 116k SO: 107k ROT: 112k AST: 0.0hrs ART: 0.8hrs ADT: 0.8hrs TBH: 24.6 TJH: 92.3 3,620.0 3,757.0 3/6/2023 04:30 3/6/2023 07:00 2.50 SURFAC, TRIPCAS CIRC T At TD of hole section, ECD rapid increased from 11.8ppg to 14.3ppg, Circulate BTM's up, Flow line packed off at 4600stks, clear flow line. Issues with cuttings auger. GPM : 42-900 PSI: 90-2650 RPM: 5-60 ECD: 11.8-14.3ppg 3,757.0 3,757.0 3/6/2023 07:00 3/6/2023 11:00 4.00 SURFAC, TRIPCAS RGRP T Circulate while changing out cuttings auger motor and gear box. 3,757.0 3,736.0 3/6/2023 11:00 3/6/2023 13:30 2.50 SURFAC, TRIPCAS CIRC P Continue Circulating and stage pump to 900gpm 2800psi, Take final survey and pump 45bbls nut plug sweep around. (not alot of return cutting on sweep return) Blow down Top Drive. 3,736.0 3,706.0 3/6/2023 13:30 3/6/2023 16:30 3.00 SURFAC, TRIPCAS BKRM P BROOH from 3,706' MD to 3,055' MD. Noticed torque increased. GPM: 900 PSI: 2530 ECD: 11.6ppg RPM: 60 TQ off: 6k ft/lbs PU: 104k 3,706.0 3,055.0 3/6/2023 16:30 3/6/2023 17:00 0.50 SURFAC, TRIPCAS CIRC P Pump and circulate out 44bbls nut plug sweep. Slight cuttings increased. GPM: 900 PSI: 2480 3,055.0 3,055.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 7/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/6/2023 17:00 3/6/2023 19:00 2.00 SURFAC, TRIPCAS BKRM P BROOH from 3,055' MD to 2,491' MD. Noticed ECD increased. GPM: 900 PSI: 2530 ECD: 11.6ppg RPM: 60 TQ off: 6k ft/lbs PU: 101k 3,055.0 2,491.0 3/6/2023 19:00 3/6/2023 19:30 0.50 SURFAC, TRIPCAS CIRC P Circulate BTM's up slight cuttings increase on BTM's up. GPM: 900 PSI: 2530 2,491.0 2,491.0 3/6/2023 19:30 3/7/2023 00:00 4.50 SURFAC, TRIPCAS BKRM P BROOH from 2,491' MD to 1,271' MD. GPM: 900 PSI: 2290 ECD: 11.8ppg RPM: 60 TQ off: 5k ft/lbs PU: 93k 2,491.0 1,271.0 3/7/2023 00:00 3/7/2023 03:00 3.00 SURFAC, TRIPCAS BKRM P BROOH from 1,271' MD to 545' MD At 600' MD ECD still at 12.2ppg with clean shakers. Continue BROOH for safety. GPM: 750-900 PSI: 1550-2221 ECD: 11.8-12.3ppg RPM: 60 TQ off: 3k ft/lbs PU: 87k 1,271.0 545.0 3/7/2023 03:00 3/7/2023 04:00 1.00 SURFAC, TRIPCAS PMPO P Pump out hole from 545' MD to 265' MD. GPM: 550 PSI: 800 PU: 65k 545.0 265.0 3/7/2023 04:00 3/7/2023 07:30 3.50 SURFAC, TRIPCAS BHAH P Monitor well (static) Blow down top drive, PJSM, POOH L/D BHA #1 244.0 0.0 3/7/2023 07:30 3/7/2023 08:00 0.50 SURFAC, TRIPCAS CLEN P Clean and clear rig floor. 0.0 0.0 3/7/2023 08:00 3/7/2023 09:00 1.00 SURFAC, CASING RURD P R/U 13-3/8" casing running equipment w/ casing swedge and safety valve and volant. 0.0 0.0 3/7/2023 09:00 3/7/2023 10:00 1.00 SURFAC, CASING PUTB P P/U 13-3/8" 68ppf L-80 H563 shoe track thread lock same. Circulate shoe track (all good) 0.0 88.0 3/7/2023 10:00 3/7/2023 10:30 0.50 SURFAC, CASING SVRG P Service top drive 88.0 88.0 3/7/2023 10:30 3/7/2023 12:00 1.50 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 88' MD to 295' MD. 88.0 295.0 3/7/2023 12:00 3/7/2023 14:00 2.00 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 295' MD to 1,096' MD. 295.0 1,096.0 3/7/2023 14:00 3/7/2023 14:30 0.50 SURFAC, CASING CIRC P Circulate BTM's up at 1,096' MD GPM: 340 PSI: 86 1,096.0 1,096.0 3/7/2023 14:30 3/7/2023 18:00 3.50 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 1,096' MD to 2,324' MD. Tagged with 25k SO: 145k 1,096.0 2,324.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 8/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/7/2023 18:00 3/7/2023 18:30 0.50 SURFAC, CASING RURD T Reset low pressure riser on drilling nipple. 2,324.0 2,324.0 3/7/2023 18:30 3/7/2023 20:00 1.50 SURFAC, CASING RURD P P/U 13-3/8" casing and wash from 2,324' MD to 2,488' MD, Worked through tight spot with 20-30k and 100- 120psi differential pressure. GPM: 200 PSI: 80 FPH: 500 PU: 171k SO: 153k 2,324.0 2,488.0 3/7/2023 20:00 3/7/2023 21:00 1.00 SURFAC, CASING PUTB P Continue P/U and run 13-3/8" 68ppf L- 80 H563 casing from 2,488' MD to 2,788' MD. Tagged with 35k SO: 145k 2,488.0 2,788.0 3/7/2023 21:00 3/8/2023 00:00 3.00 SURFAC, CASING RURD P P/U 13-3/8" casing and wash from 2,488' MD to 3,326' MD, At 3,253' MD lowerd pump to 84gpm and increased run speed to 700'/hr. GPM: 200 PSI: 125 FPH: 500 PU: 171k SO: 168k 2,788.0 3,326.0 3/8/2023 00:00 3/8/2023 01:30 1.50 SURFAC, CASING PUTB P P/U 13-3/8" casing and wash from 3,326' MD to 3,708' MD, At 3,253' MD lowerd pump to 84gpm and increased run speed to 700'/hr. GPM: 200 PSI: 125 FPH: 500 PU: 171k SO: 168k 3,326.0 3,708.0 3/8/2023 01:30 3/8/2023 02:00 0.50 SURFAC, CASING OTHR P R/U pump T and valves on Volant, M/U hanger and landing joint. Wash in hole at 2bpm and land hanger. 3,708.0 3,747.0 3/8/2023 02:00 3/8/2023 03:30 1.50 SURFAC, CEMENT CIRC P Circulate and condition mud stage pumps from 2bpm to 8bpm. reciprocate pipe 15'. GPM: 336 PSI: 180 3,747.0 3,747.0 3/8/2023 03:30 3/8/2023 07:30 4.00 SURFAC, CEMENT CMNT P Blow down top drive, test lines to 4500psi (all ok) Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4.0 bbls/min, 352 psi, Dropped bottom plug. Start batching lead. Pump 423 bbls of 11.0 ppg DeepCRETE cement at 5.5 bbls/min, 435 psi ICP. Batch and pump 73 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 280 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 280 psi ICP, 610 psi FCP. Slow pumps 20 bbls prior to calculated bump to 3 bbls/min, 370 psi ICP, 388 psi FCP, Bump plug with 925 psi (527 bbls + 20 bbls). 4454 strokes, final circ. PSI 388 Pressure up to 925 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 60 bbls cement to surface. Cement in place @ 07:27hrs 3/8/23 full returns. Check floats (all good) 3,747.0 3,747.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 9/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/8/2023 07:30 3/8/2023 08:30 1.00 SURFAC, CEMENT PRTS P Drain and flush riser and flow line. Test casing to 3500psi 30min (good test) pumped 9.5bbls and returned 8.5bbls. 3,747.0 3,747.0 3/8/2023 08:30 3/8/2023 12:45 4.25 SURFAC, CEMENT NUND P Back out landing joint, clean surface equipment, ND riser/lines.ND surface bag and set back. Pull 90' MH. RD surface diverter and Tee. SIMOPS: Cleanning mud pits. 3,747.0 3,747.0 3/8/2023 12:45 3/8/2023 14:30 1.75 SURFAC, WHDBOP NUND P NU and orientate WH. Test seals to 1000psi (CPAI witnessed) 0.0 0.0 3/8/2023 14:30 3/8/2023 23:00 8.50 SURFAC, WHDBOP NUND P Nipple up drilling riser & BOPE SIMOPS- Clean pits, slide Joe's box, install flow line, choke & kill lines, N/U MPD equipment. 0.0 0.0 3/8/2023 23:00 3/9/2023 00:00 1.00 SURFAC, WHDBOP PRTS P Set test plug and install MPD test cap, test to 250/1250psi 5/10min. 0.0 0.0 3/9/2023 00:00 3/9/2023 01:00 1.00 SURFAC, WHDBOP MPDA P Continue test MPD, Pull test cap. 0030-0200: Install 5" test joing and service lines. Bonnet ntest BOP's. 0200-0215: Test BOP's 0215-0330: Trouble shoot, repair BOP test pump. 0330-0600: Test BOP's 0.0 0.0 3/9/2023 01:00 3/9/2023 01:30 0.50 SURFAC, WHDBOP SVRG T Inspect and rebuild test pump. 0.0 0.0 3/9/2023 01:30 3/9/2023 08:00 6.50 SURFAC, WHDBOP BOPE P Test BOPE all test T/ 250 low for 5 min and 5,000 high for 10 min charted. W/ exception of annular T/ 250 low for 5 min and 3,500 high for 10 min. Manual operated & super choke tested T/2,000 psi charted, W/ 5" test JT test annular, 2 7/8" X 5 1/2" UPR, 2 7/8" X 5 1/2" LPR,Test choke valves 1-15, manual operated & super choke, Choke & kill manuals, HCR's, 4" valves on kill line, 5" FOSV, 5" Dart valve, Upper and lower IBOP on TD; Blind/shear rams; Perform KOOMEY drawdown, ACC = 2950 PSI. MANIF. = 1500 PSI. ACC = 1575 PSI After all functions on bottles, 18 sec for 200 psi. Build W/ 2 Elec. pumps, 107 sec T/ Build full system. Pressure W/ 2 Elec. & 2 Air pumps, Closing times, Annular = 19 sec. UPR = 16 sec. Blind / Shears = 14 sec. LPR = 16 sec. Choke HCR = 2 Ssec. Kill HCR = 2 sec; Test PVT G/L and flow out alarms, Test LEL and H2S alarms. Witness by AOGCC Bob Noble. Witness by BLM Quinn Sawyer 0.0 0.0 3/9/2023 08:00 3/9/2023 08:30 0.50 SURFAC, WHDBOP RGRP T Complete BOP test, 1/2 Hour down time after contract 15hr grace to N/U and Test BOPs. 0.0 0.0 3/9/2023 08:30 3/9/2023 09:15 0.75 SURFAC, WHDBOP OTHR P Remove test plug and install wear ring. 0.0 0.0 3/9/2023 09:15 3/9/2023 10:45 1.50 SURFAC, DRILLOUT SLPC P Cut and slip 100' drill line. Calibrate block 0.0 0.0 3/9/2023 10:45 3/9/2023 13:30 2.75 SURFAC, DRILLOUT BHAH P PJSM, P/U Baker 12-1/4" BHA #2 0.0 242.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 10/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/9/2023 13:30 3/9/2023 15:00 1.50 SURFAC, DRILLOUT TRIP P TIH with 12-1/4" BHA from 242' MD to 2,441' MD. 242.0 2,441.0 3/9/2023 15:00 3/9/2023 15:30 0.50 SURFAC, DRILLOUT OTHR P Fill pipe at 2,441' MD. Shallow test tools 700gpm 1450psi. Blow down top drive. 2,441.0 2,441.0 3/9/2023 15:30 3/9/2023 16:30 1.00 SURFAC, DRILLOUT TRIP P TIH with 12-1/4" BHA from 2441' MD to 3,471' MD. 2,441.0 3,471.0 3/9/2023 16:30 3/9/2023 17:30 1.00 SURFAC, DRILLOUT OTHR P Preform well control drill CRT: 91 Sec. Preform choke drill with crew 3,471.0 3,471.0 3/9/2023 17:30 3/9/2023 18:30 1.00 SURFAC, DRILLOUT WASH P Wash in hole and tagged cement at 3,650' MD. GPM: 650 PSI: 1250 3,471.0 3,650.0 3/9/2023 18:30 3/9/2023 20:00 1.50 SURFAC, DRILLOUT DRLG P Dilling cement, plugs and float collar from 3,650' MD to 3,660' MD, Continue drilling shoe track to 3,747' MD. Wash out rat hole to 3,757' MD. 3,650.0 3,757.0 3/9/2023 20:00 3/9/2023 21:00 1.00 SURFAC, DRILLOUT DDRL P Drill new formation from 3,757' MD to 3,778' MD 3,050' TVD. WOB: 10/15k GPM: 850 PSI: 1960 RPM: 80 TQ on: 10k ft/lbs TQ off: 5k ft/lbs ART: 0.2hrs ADT: 0.2hrs TBH: 0.2 TJH: 92.5 3,757.0 3,778.0 3/9/2023 21:00 3/9/2023 21:30 0.50 SURFAC, DRILLOUT CIRC P Circulate BTM's up at 3,778' MD. BROOH to shoe 3,747' MD 3,778.0 3,747.0 3/9/2023 21:30 3/9/2023 23:00 1.50 SURFAC, DRILLOUT LOT P R/U safety valve and pump lines. Preform LOT at 3,747' MD 3007' TVD with 10.9ppg mud. at 1/2bpm leak off at 800psi EMW 16.0ppg. 3,747.0 3,747.0 3/9/2023 23:00 3/9/2023 23:30 0.50 INTRM1, DRILL REAM P Wash and ream in hole from 3,747' MD to 3,778' MD while pump 40bbls Hi Vis spacer and displace to 10.9ppg FWP mud. 3,747.0 3,778.0 3/9/2023 23:30 3/10/2023 00:00 0.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 3,778' MD to 3,810' MD 3,035' TVD, While finish displaceing to 11.0ppg FWP mud. WOB: 15k GPM: 850 PSI: 1960 RPM: 80 TQ on: 11k ft/lbs MW: 10.9 ppg PU: 125k SO: 101k ROT: 111k ART: 0.3hrs ADT: 0.3hrs TBH: 0.5 TJH: 92.8 3,778.0 3,810.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 11/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/10/2023 00:00 3/10/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 3,810' MD 3,035' TVD to 4,703' MD 3,345' TVD. WOB: 17k GPM: 1033 PSI: 2670 ECD: 11.9ppg RPM: 170 TQ on: 9k ft/lbs TQ off: 4k ft/lbs F/O: 55% MW: 11.0 ppg PU: 119k SO: 122k ROT: 122k ADT: 4.3hrs TBH: 4.8 TJH: 97.1 3,810.0 4,703.0 3/10/2023 06:00 3/10/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4,703' MD 3,345' TVD to 5,175' MD 3,724' TVD. WOB: 17k GPM: 1033 PSI: 2800 ECD: 11.8ppg RPM: 170 TQ on: 9k ft/lbs TQ off: 5k ft/lbs F/O: 55% MW: 11.0 ppg PU: 130k SO: 124k ROT: 122k ADT: 4.6hrs TBH: 9.4 TJH: 101.7 4,703.0 5,175.0 3/10/2023 12:00 3/10/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5,175' MD 3,724' TVD to 5,929' MD 4,100' TVD. WOB: 17k GPM: 1033 PSI: 3060 ECD: 11.8ppg RPM: 180 TQ on: 13k ft/lbs TQ off: 4k ft/lbs F/O: 56% MW: 11.0 ppg PU: 130k SO: 124k ROT: 122k ADT: 4.6hrs TBH: 14 TJH: 106.3 5,175.0 5,929.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 12/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/10/2023 18:00 3/11/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5,929' MD 3,724' TVD to 6,610' MD 4,441' TVD. WOB: 20k GPM: 1033 PSI: 3200 ECD: 11.8ppg RPM: 180 TQ on: 13k ft/lbs TQ off: 4.5k ft/lbs F/O: 56% MW: 11.0 ppg PU: 147k SO: 133k ROT: 138k ADT: 4.2hrs TBH: 18.2 TJH: 110.5 5,929.0 6,610.0 3/11/2023 00:00 3/11/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 6,610' MD 4,441' TVD to 7,342 MD 4,807' TVD. WOB: 23k GPM: 1033 PSI: 3470 ECD: 12.0ppg RPM: 180 TQ on: 13k ft/lbs TQ off: 6k ft/lbs F/O: 58% MW: 11.0 ppg PU: 162k SO: 143k ROT: 143k ADT: 4.3hrs TBH: 22.5 TJH: 114.8 6,610.0 7,342.0 3/11/2023 06:00 3/11/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 7,342' MD 4,807' TVD to 8,004' MD 5,116' TVD. WOB: 22k GPM: 1033 PSI: 3651 ECD: 11.8ppg RPM: 180 TQ on: 14k ft/lbs TQ off: 7k ft/lbs F/O: 58% MW: 11.0 ppg PU: 165k SO: 142k ROT: 146k ADT: 4.4hrs TBH: 26.5 TJH: 119.2 7,342.0 8,004.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 13/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/11/2023 12:00 3/11/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8,004' MD 5,116' TVD to 8,645' MD 5,458' TVD. Pack off at 8,481' MD ECD increased from 12.3ppg to 13.7ppg. WOB: 26k GPM: 1033 PSI: 3680 ECD: 12.0ppg RPM: 180 TQ on: 16k ft/lbs TQ off: 10k ft/lbs F/O: 58% MW: 11.1 ppg PU: 187k SO: 146k ROT: 157k ADT: 4.2hrs TBH: 31.1 TJH: 123.4 8,004.0 8,645.0 3/11/2023 18:00 3/12/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5,929' MD 3,724' TVD to 9,318' MD 5,794' TVD. max gas at 9,155' MD 433 units WOB: 35k GPM: 993 PSI: 3528 ECD: 12.2ppg RPM: 180 TQ on: 19k ft/lbs TQ off: 15k ft/lbs F/O: 55% MW: 11.2 ppg PU: 200k SO: 144k ROT: 167k ADT: 4.8hrs TBH: 35.9 TJH: 128.2 8,645.0 9,318.0 3/12/2023 00:00 3/12/2023 02:00 2.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,318' MD 5,794' TVD to 9,552' MD 5,911' TVD. WOB: 24k GPM: 990 PSI: 3750 ECD: 12.3ppg RPM: 180 TQ on: 21k ft/lbs TQ off: 15k ft/lbs F/O: 55% MW: 11.2 ppg PU: 203k SO: 145k ROT: 163k ADT: 1.3hrs TBH: 37.5 TJH: 129.8 9,318.0 9,552.0 3/12/2023 02:00 3/12/2023 03:00 1.00 INTRM1, DRILL OTHR P Daylight Savings time 9,552.0 9,552.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 14/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/12/2023 03:00 3/12/2023 06:00 3.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,552' MD 5,911' TVD to 9,811' MD 6,075' TVD. WOB: 21k GPM: 1000 PSI: 3730 ECD: 12.2ppg RPM: 180 TQ on: 21k ft/lbs TQ off: 15k ft/lbs F/O: 55% MW: 11.2 ppg PU: 206k SO: 147k ROT: 169k ADT: 2.5hrs TBH: 40.0 TJH: 129.8 9,552.0 9,881.0 3/12/2023 06:00 3/12/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9,811' MD 6,075' TVD to 10,449' MD 6,358' TVD. WOB: 27k GPM: 940 PSI: 3770 ECD: 12.7ppg RPM: 180 TQ on: 23k ft/lbs TQ off: 17k ft/lbs F/O: 54% MW: 11.9 ppg PU: 225k SO: 152k ROT: 172k ADT: 4.7hrs TBH: 44.7 TJH: 137 9,881.0 10,449.0 3/12/2023 12:00 3/12/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 10,449' MD 6,358' TVD to 11,118' MD 6,696' TVD. WOB: 25k GPM: 913 PSI: 3850 ECD: 12.8ppg RPM: 180 TQ on: 23k ft/lbs TQ off: 16k ft/lbs F/O: 50% MW: 11.9 ppg PU: 220k SO: 152k ROT: 178k ADT: 4.9hrs TBH: 49.6 TJH: 141.9 10,449.0 11,118.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 15/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/12/2023 18:00 3/12/2023 21:00 3.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 11,118' MD 6,696' TVD to 11,453' MD 6,862' TVD. WOB: 26k GPM: 892 PSI: 3830 ECD: 12.7ppg RPM: 180 TQ on: 23k ft/lbs TQ off: 19k ft/lbs F/O: 62% MW: 11.9 ppg PU: 240k SO: 147k ROT: 179k ADT: 2.4hrs TBH: 52 TJH: 144.3 11,118.0 11,453.0 3/12/2023 21:00 3/12/2023 21:30 0.50 INTRM1, DRILL SVRG P Service #1 mud pump, change swab. Continue circulate #2 pump GPM: 478 PSI: 1355 11,453.0 11,453.0 3/12/2023 21:30 3/13/2023 00:00 2.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 11,453' MD 6,862' TVD to 11,730' MD 7,001' TVD. WOB: 21k GPM: 892 PSI: 3860 ECD: 12.7ppg RPM: 180 TQ on: 23k ft/lbs TQ off: 19k ft/lbs F/O: 64% MW: 11.9 ppg PU: 244k SO: 152k ROT: 181k ADT: 2.0hrs TBH: 54 TJH: 146.3 11,453.0 11,730.0 3/13/2023 00:00 3/13/2023 06:30 6.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 11,730' MD 7,001' TVD to 12,434' MD 7,355' TVD. WOB: 23k GPM: 862 PSI: 3842 ECD: 12.7ppg RPM: 180 TQ on: 23k ft/lbs TQ off: 18k ft/lbs F/O: 50% MW: 12.0 ppg PU: 259k SO: 163k ROT: 195k ADT: 5.2hrs TBH: 59.2 TJH: 151.5 11,730.0 12,434.0 3/13/2023 06:30 3/13/2023 11:30 5.00 INTRM1, TRIPCAS BKRM P BROOH from 12,434' MD to 12,253' MD, racking back 1 stand/BTM's up, Pumped 400bbl dilution. 12,434.0 12,253.0 3/13/2023 11:30 3/13/2023 12:00 0.50 INTRM1, TRIPCAS OWFF P OWFF (Static) 12,253.0 12,253.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 16/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/13/2023 12:00 3/13/2023 18:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 12,253' MD to 10,824' MD. Well unloading cuttings at 10,830' MD. GPM: 862 PSI: 3360 ECD: 12.7ppg RPM: 120 TQ: 15k ft/lbs F/O: 64% 12,253.0 10,824.0 3/13/2023 18:00 3/14/2023 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 10,824' MD to 9,160' MD. At 9,220' MD, slight packoff ECD 12.9ppg, high torque 23k. Shakers unloading, Pump 32bbls NP sweep and continue BROOH slow. GPM: 953 PSI: 3475 PU: 150k ECD: 12.7ppg RPM: 130 TQ: 16k ft/lbs F/O: 64% 10,824.0 9,160.0 3/14/2023 00:00 3/14/2023 05:00 5.00 INTRM1, TRIPCAS BKRM P BROOH from 9,160' MD to 7,725' MD. At 9,220' MD, slight packoff ECD 12.9ppg, high torque 23k. Shakers unloading, Pump 32bbls NP sweep and continue BROOH slow. GPM: 953 PSI: 3475 PU: 150k ECD: 12.7ppg RPM: 130 TQ: 16k ft/lbs F/O: 64% 9,160.0 7,725.0 3/14/2023 05:00 3/14/2023 05:30 0.50 INTRM1, TRIPCAS SVRG P Service #2 mud pump, change swab. Continue circulate with #1 pump GPM: 501 PSI: 1060 7,725.0 7,725.0 3/14/2023 05:30 3/14/2023 12:00 6.50 INTRM1, TRIPCAS BKRM P BROOH from 7,725' MD to 6,604' MD. At 7,388' MD, slight packoff ECD 12.9ppg, with 700psi spike, high torque 23k. Shakers unloading, Pump 30bbls NP sweep and continue BROOH slow. GPM: 1000 PSI: 3450 ROT: 125k ECD: 12.6ppg RPM: 120 TQ: 15k ft/lbs F/O: 55% 7,725.0 6,604.0 3/14/2023 12:00 3/14/2023 18:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 6,604' MD to 5,533' MD. GPM: 1000 PSI: 3450 ROT: 124k ECD: 12.6ppg RPM: 120 TQ: 12-17k ft/lbs F/O: 55% 6,604.0 5,533.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 17/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/14/2023 18:00 3/15/2023 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH from 7,725' MD to 6,604' MD. At 5,630' and 4,410' MD, Pump 30bbls NP sweep and continue BROOH slow, sweep returned on time with slight increase in cuttings. High torque from 5,730' to 5,648' MD. GPM: 1000 PSI: 3450 ROT: 125k ECD: 12.6ppg RPM: 120 TQ: 10-15k ft/lbs F/O: 55% 5,533.0 4,229.0 3/15/2023 00:00 3/15/2023 04:00 4.00 INTRM1, TRIPCAS BKRM P Continue BROOH @ 3,966' high torque 23k, continue work string out hole. @ 3,886' MD high torque continue 17-22k at 75-125'/Hr back reaming. After back reaming normal torque 5.7-6.2k. Pump 30bbl Nutplug sweep at 3,886' MD. No change in cuttings returned. At 3,834' MD while BROOH torque returned to normal, from 16 to 6.2k. 4,229.0 3,747.0 3/15/2023 04:00 3/15/2023 05:00 1.00 INTRM1, TRIPCAS CIRC P Pump 2 Nutplug sweeps and circulate SS. GPM: 1033 PSI: 2550 ECD: 12.2ppg 3,747.0 3,747.0 3/15/2023 05:00 3/15/2023 05:30 0.50 INTRM1, TRIPCAS OWFF P OWFF (static) Blow down top drive. line up hole fill. 3,747.0 3,747.0 3/15/2023 05:30 3/15/2023 07:15 1.75 INTRM1, TRIPCAS TRIP P Trip out hole on elevators from 3,747' MD to 562' MD. 3,747.0 562.0 3/15/2023 07:15 3/15/2023 07:30 0.25 INTRM1, TRIPCAS OWFF P OWFF (static) 562.0 562.0 3/15/2023 07:30 3/15/2023 10:00 2.50 INTRM1, TRIPCAS BHAH P Rack back HWT and collars, L/D Intermediate 1 BHA. 562.0 0.0 3/15/2023 10:00 3/15/2023 11:30 1.50 INTRM1, TRIPCAS WWWH P Pull wear ring and wash BOP stack. 0.0 0.0 3/15/2023 11:30 3/15/2023 12:30 1.00 INTRM1, TRIPCAS OTHR P Close Blind rams and chang out top rams to 9-5/8" casing rams. 0.0 0.0 3/15/2023 12:30 3/15/2023 14:00 1.50 INTRM1, TRIPCAS PRTS P R/U 9-5/8" test joing and test annular 250/3500 5/10 min. R/D test equipment. AOGCC. Kam StJohn waived witness 3- 14-23 @ 05:46hrs. 0.0 0.0 3/15/2023 14:00 3/15/2023 16:00 2.00 INTRM1, CASING RURD P R/U 9-5/8" casing equipment. AOGCC, Kam StJohn waived witness 3- 14-23 @ 0546hrs. BLM, Mutasim Elganzoory Notification recieved 3-14-23 @ 1001hrs. 0.0 0.0 3/15/2023 16:00 3/15/2023 22:30 6.50 INTRM1, CASING PUTB P PJSM, P/U 9-5/8" shoe track, sheck floats (all good) Continue running 9-5/8" 47# H563 casing to 3,747' MD. 0.0 3,747.0 3/15/2023 22:30 3/15/2023 23:30 1.00 INTRM1, CASING CIRC P Fill pipe, break circulation and stage pumps up to 336gpm 250psi. Full returns with no change in cutting on BTM's up. GPM: 336 PSI: 250 PU: 158k SO: 150k 3,747.0 3,747.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 18/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/15/2023 23:30 3/16/2023 00:00 0.50 INTRM1, CASING PUTB P Continue running 9-5/8" 47# H563 casing from 3,747' MD to 4,139' MD. PU: 158k SO: 150k 3,747.0 4,139.0 3/16/2023 00:00 3/16/2023 06:00 6.00 INTRM1, CASING PUTB P Continue running 9-5/8" 47# H563 casing on elevators from 4,139' MD to 8,338' MD. 4,139.0 8,338.0 3/16/2023 06:00 3/16/2023 09:30 3.50 INTRM1, CASING PUTB P Continue running 9-5/8" 47# H563 casing on elevators from 8,338' MD to 10,740' MD. Set down at 10,740' MD, P/U break over at 390k. 8,338.0 10,740.0 3/16/2023 09:30 3/16/2023 11:30 2.00 INTRM1, CASING WASH P Stage pumps up to 4bpm 463psi, Wash in hole with reduce pump rate 2bpm from 10,740' MD to 10, 851' MD. Stage pump up to 6bpm 511psi. No overpull or packoff observed. 10,740.0 10,851.0 3/16/2023 11:30 3/16/2023 12:00 0.50 INTRM1, CASING PUTB P Continue running 9-5/8" 47# H563 casing on elevators from 10,851' MD to 11,071' MD. 10,851.0 11,071.0 3/16/2023 12:00 3/16/2023 16:00 4.00 INTRM1, CASING WASH P Wash in hole from 11,114' MD to 12,424' MD. working casing to bottom. GPM: 84 PSI: 450-525 PU:360k SO: 145k 11,071.0 12,424.0 3/16/2023 16:00 3/16/2023 17:00 1.00 INTRM1, CEMENT HOSO P Pump out hole from 12,424' MD to 12,383' MD, M/U hanger and landing joint. Wash in hole at 2bpm 480psi and land hanger with 230k. PU: 350k 12,424.0 12,424.0 3/16/2023 17:00 3/16/2023 19:00 2.00 INTRM1, CEMENT CIRC P Circulate and condition mud at 12,424' MD stage pumps up to 8bpm 440psi. Mud 12.1ppg in/out 12,424.0 12,424.0 3/16/2023 19:00 3/16/2023 20:30 1.50 INTRM1, CEMENT CIRC P Blow down top drive and R/U cement hose. establish circulation through cement hose 7bpm 575psi. While restaging trucks. (water truck broke down before job, second water truck busted line during job) SIMOPS: PJSM, cement crews 12,424.0 12,424.0 3/16/2023 20:30 3/17/2023 00:00 3.50 INTRM1, CEMENT CMNT P Line up cement unit. flush w/ 2 bbls FW. Test lines to 3500psi. Good test. Mix and pump 60bbls 12.5ppg mud push II at 4 bpm. SD and drop bottom plug. Mix and pump 191bbls 13.0 ppg G lead cement at 5.2bpm, Mix and pump 152bbls 15.8 ppg G Tail cement at 4.5 bpm. SD and drop top plug. Pump 20 bbls FW w/ cement unit. Swap over to rig pumps and begin displace cement at 8bpm to catch cement (20bbls) lower rate to 6BPM and continue displacing cement and reduce rate as needed for ballmill/trucks. slow pump rate to 3bpm 26bbls early. bumped plug at 905bbls (1bbl early) FCP 887psi, pressure up to 1400psi, hold 5 min, bled off (floats holding) cement in place 3-17-23 @ 0128hrs. 12,424.0 12,424.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 19/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/17/2023 00:00 3/17/2023 01:30 1.50 INTRM1, CEMENT CMNT P Finish displacing cement, Swap over to rig pumps and begin displace cement at 8bpm to catch cement (20bbls) lower rate to 6BPM and continue displacing cement and reduce rate as needed for ballmill/trucks. slow pump rate to 3bpm 26bbls early. bumped plug at 905bbls (1bbl early) FCP 887psi, pressure up to 1400psi, hold 5 min, bled off (floats holding) cement in place 3-17-23 @ 0128hrs. 12,424.0 12,424.0 3/17/2023 01:30 3/17/2023 02:00 0.50 INTRM1, CEMENT OWFF P Check floats (all good) 12,424.0 12,424.0 3/17/2023 02:00 3/17/2023 03:00 1.00 INTRM1, CEMENT PRTS P R/U to test casing, trouble priming mud pump. swap pumps and pressure up casing to 3600psi pumped 13bbls, slight leak, attempt to trouble shoot leak. Hose to test chart released off quick connect. Bled off pressure to 0psi (one hour into testing, abort pressure test) 12,424.0 12,424.0 3/17/2023 03:00 3/17/2023 05:00 2.00 INTRM1, WHDBOP WWSP P R/D service lines and volant. Pull and L/D landing joint. Run packoff and test 0.0 0.0 3/17/2023 05:00 3/17/2023 08:30 3.50 INTRM1, WHDBOP PRTS P Set test plug and purge equipment. Test UPR and Annular with 5" test joints 250/3500psi 5/10min. Weekly BOP function test, 0.0 0.0 3/17/2023 08:30 3/17/2023 09:30 1.00 INTRM1, DRILLOUT OTHR P R/D test equipment and pull test joint. Install wear ring 0.0 0.0 3/17/2023 09:30 3/17/2023 10:30 1.00 INTRM1, DRILLOUT BHAH P Move BHA components to rig floor. Service rig 0.0 0.0 3/17/2023 10:30 3/17/2023 12:30 2.00 INTRM1, DRILLOUT SLPC P Hang block and Slip and cut 64' Drill line. Calibrate AMPHION and Pason. Check COM (all good) Clear rig floor. SIMOPS: Changing liners in pumps to 5.5", finish cleanning pits and dress shakers. 0.0 0.0 3/17/2023 12:30 3/17/2023 16:30 4.00 INTRM1, DRILLOUT BHAH P P/U 8-1/2" X 9-7/8" Intermedate #2 BHA to 549' MD. 0.0 549.0 3/17/2023 16:30 3/17/2023 18:00 1.50 INTRM1, DRILLOUT TRIP P TIH from 549' MD to 2914' MD. Shallow test (all good) PU: 88k SO: 94k 549.0 2,914.0 3/17/2023 18:00 3/18/2023 00:00 6.00 INTRM1, DRILLOUT TRIP P TIH from 2,914' MD to 11,004' MD. Fill pipe every 25 stands. PU: 88k SO: 94k 2,914.0 11,004.0 3/18/2023 00:00 3/18/2023 01:00 1.00 INTRM1, DRILLOUT TRIP P Continue TIH from 11,004' MD to 12,034' MD. PU: 212k SO: 134k 11,004.0 12,034.0 3/18/2023 01:00 3/18/2023 02:00 1.00 INTRM1, DRILLOUT WASH P Break circulation, wash down and tag CMT at 12,321' MD with 10k. GPM: 500 PSI: 3000 ECD: 12.5ppg PU: 218k SO: 146k 12,034.0 12,321.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 20/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2023 02:00 3/18/2023 03:00 1.00 INTRM1, DRILLOUT CIRC P Circulate and condition mud at 12,307' MD. GPM: 600 PSI: 3,771 ECD: 12.7ppg SIMOPS: Install bail extensions. 12,321.0 12,307.0 3/18/2023 03:00 3/18/2023 05:30 2.50 INTRM1, DRILLOUT PRTS P R/U safety valve and head pin, preform Choke drill with crew. Test casing to 3540psi. 30min, pumped 12.7bbls returned 12.5bbls. R/D service equipment and blow down choke and kill lines. 12,307.0 12,307.0 3/18/2023 05:30 3/18/2023 06:30 1.00 INTRM1, DRILLOUT DRLG P Drill shoe track from 12,321' MD to 12,376' MD. GPM: 500 PSI: 2,750 ECD: 12.5ppg PU: 224k SO: 150k RPM: 80 TRQ: 7k 12,321.0 12,376.0 3/18/2023 06:30 3/18/2023 07:30 1.00 INTRM1, DRILLOUT OTHR T Lost Hi Line power, Swap to generator power. 12,376.0 12,376.0 3/18/2023 07:30 3/18/2023 09:15 1.75 INTRM1, DRILLOUT DRLG P Drill shoe track and clean out rat hole from 12,376' MD to 12,434' MD. GPM: 550 PSI: 3,250 ECD: 12.9ppg PU: 224k SO: 150k ROT: 180 RPM: 120 TRQ: 12k 12,376.0 12,434.0 3/18/2023 09:15 3/18/2023 10:00 0.75 INTRM1, DRILLOUT DDRL P Drill 8 1/2" Interm 2 hole from 12,434' MD to 12,454' MD 7,365' TVD. WOB: 21k GPM: 550 PSI: 3,250 ECD: 12.9ppg RPM: 120 TQ on: 12k ft/lbs TQ off: 9k ft/lbs F/O: 32% MW: 11.5 ppg PU: 224k SO: 150k ROT: 180k ADT: 0.7rs TBH: 0.7 TJH: 152.2 12,434.0 12,454.0 3/18/2023 10:00 3/18/2023 10:30 0.50 INTRM1, DRILLOUT BKRM P Back ream from 12,454' MD to 12,403' MD 12,454.0 12,403.0 3/18/2023 10:30 3/18/2023 11:30 1.00 INTRM1, DRILLOUT CIRC P Circulate and condition mud at 12,403' MD. GPM: 640 PSI: 4,040 ECD: 12.9ppg RPM: 40 TRQ: 9k ROT: 180k 12,403.0 12,403.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 21/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2023 11:30 3/18/2023 12:00 0.50 INTRM1, DRILLOUT RURD P R/U bail extensions safety valve and head pin. 12,403.0 12,403.0 3/18/2023 12:00 3/18/2023 13:30 1.50 INTRM1, DRILLOUT FIT P Purge air from system with 11.5ppg mud, Pump 0.5bpm to 980psi , hold 10min and bled off 3.5bbls pumped 3.1bbls returned. EMW 14.1ppg 12,403.0 12,403.0 3/18/2023 13:30 3/18/2023 14:30 1.00 INTRM1, DRILLOUT OTHR T Attempt to swap generator power to Hi Line, Continue trouble shoot same. 12,403.0 12,403.0 3/18/2023 14:30 3/18/2023 16:00 1.50 INTRM1, DRILLOUT MPDA P PJSM, Blow down fill line, Remove trip nipple and install RCD, Flood lines and circulate through MPD equipment. 12,403.0 12,408.0 3/18/2023 16:00 3/18/2023 16:30 0.50 INTRM1, DRILLOUT REAM P Wash and ream shoe track and rat hole from 12,408' MD to 12,454' MD. DownLink directional tools. GPM: 500 PSI: 3,250 RPM: 60 TRQ: 12k 12,408.0 12,454.0 3/18/2023 16:30 3/18/2023 18:00 1.50 INTRM2, DRILL DDRL P Drill 8 1/2" Interm 2 hole from 12,454' MD to 12,499' MD 7,388' TVD. WOB: 10k GPM: 600 PSI: 3,840 ECD: 13.1ppg RPM: 120 TQ on: 13k ft/lbs TQ off: 9k ft/lbs F/O: 30% MW: 11.5 ppg PU: 214k SO: 171k ROT: 178k 12,454.0 12,499.0 3/18/2023 18:00 3/18/2023 18:30 0.50 INTRM2, DRILL OTHR P Swap generator power to Hi Line. 12,499.0 12,499.0 3/18/2023 18:30 3/18/2023 19:30 1.00 INTRM2, DRILL DDRL P Drill 8 1/2" Interm 2 hole from 12,499' MD to 12,537' MD 7,406' TVD. WOB: 10k GPM: 600 PSI: 3,840 ECD: 13.1ppg RPM: 120 TQ on: 13k ft/lbs TQ off: 9k ft/lbs F/O: 30% MW: 11.5 ppg PU: 214k SO: 171k ROT: 178k 12,499.0 12,537.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 22/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2023 19:30 3/18/2023 21:30 2.00 INTRM2, DRILL OTHR P Take base parameters f/ underreamer. Drop 1.25" Torlon ball. Pump down string. Pump down at 250 GPM for 1200stks and reduce rate to 100 GPM. Ball landed at 2280stks. under reamer shift open at 1130psi. Check parameters to confirm under reamer open. Perform ledge test. Good test Base parameters: 4509 Turbine RPM 600 GPM 3750 PSI Post parameters: 3888 Turbine RPM 600 GPM 3350 PSI 12,537.0 12,522.0 3/18/2023 21:30 3/19/2023 00:00 2.50 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 12,454' MD to 12,630' MD 7,454' TVD. WOB: 26k GPM: 650 PSI: 3,845 ECD: 13.3ppg RPM: 140 TQ on: 14k ft/lbs TQ off: 9k ft/lbs F/O: 32% MW: 11.5 ppg PU: 212k SO: 171k ROT: 178k ADT: 4.8rs TBH: 4.8 TJH: 157 12,522.0 12,630.0 3/19/2023 00:00 3/19/2023 06:00 6.00 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 12,630' MD to 13,093' MD 7,685' TVD. WOB: 28k GPM: 650 PSI: 3,840 ECD: 13.3ppg, Holding on connections RPM: 150 TQ on: 20k ft/lbs TQ off: 14k ft/lbs F/O: 36% MW: 11.5 ppg PU: 214k SO: 142k ROT: 178k ADT: 3.9rs TBH: 9.4 TJH: 160.9 12,630.0 13,093.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 23/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/19/2023 06:00 3/19/2023 08:00 2.00 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 13,093' MD to 13,283' MD 7,865' TVD. WOB: 27k GPM: 675 PSI: 4,080 ECD: 13.3ppg, Holding on connections RPM: 150 TQ on: 20k ft/lbs TQ off: 14k ft/lbs F/O: 36% MW: 11.5 ppg PU: 215k SO: 150k ROT: 180k ADT: 1.5rs TBH: 10.9 TJH: 162.4 13,093.0 13,283.0 3/19/2023 08:00 3/19/2023 08:30 0.50 INTRM2, DRILL OTHR T While drilling at 13,283' MD, string torque and stalled with 24k, (no increase of pump pressure) P/U string to 375k and wouldn't break over, S/O to neutral weight 180k and release torque, Pull up to 400k with no break over, Downlink retract steering head ribs. Attempt to set jars off with 400k, S/O to neutral weight and attempt to rotate (stalled with 30k) Release torque and pulled to 425k and broke free. 13,283.0 13,283.0 3/19/2023 08:30 3/19/2023 09:30 1.00 INTRM2, DRILL CIRC T Circulate BTM's up at 13,283' MD GPM: 660 PSI: 3800 ECD: 13.1ppg RPM: 80 TRQ: 14k PU: 215k SO: 150k ROT: 183k 13,283.0 13,283.0 3/19/2023 09:30 3/19/2023 12:00 2.50 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 13,283' MD to 13,482' MD 7,865' TVD. WOB: 26k GPM: 675 PSI: 4,050 ECD: 13.2ppg, Holding on connections RPM: 150 TQ on: 20k ft/lbs TQ off: 14k ft/lbs F/O: 34% MW: 11.5 ppg PU: 217k SO: 150k ROT: 180k ADT: 1.7rs TBH: 12.6 TJH: 164.1 13,283.0 13,482.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 24/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/19/2023 12:00 3/19/2023 18:00 6.00 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 13,482' MD to 14,102' MD 8,104' TVD. WOB: 21k GPM: 675 PSI: 4,045 ECD: 13.2ppg, Holding on connections RPM: 150 TQ on: 22k ft/lbs TQ off: 16k ft/lbs F/O: 35% MW: 11.5 ppg PU: 225k SO: 147k ROT: 175k ADT: 4.8rs TBH: 17.4 TJH: 168.9 13,482.0 14,102.0 3/19/2023 18:00 3/20/2023 00:00 6.00 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 14.102' MD to 14,565' MD 8,230' TVD. High torque increased, adding 776 lub and controll P-Rate. WOB: 18k GPM: 675 PSI: 4,045 ECD: 13.1ppg, Holding on connections RPM: 150 TQ on: 23k ft/lbs TQ off: 18k ft/lbs F/O: 35% MW: 11.5 ppg PU: 235k SO: 138k ROT: 175k ADT: 4.4rs TBH: 21.8 TJH: 173.3 14,102.0 14,565.0 3/20/2023 00:00 3/20/2023 04:00 4.00 INTRM2, DRILL DDRL P Drill 8 1/2" X 9 7/8" Interm 2 hole from 14,565' MD to 14,712' MD 8,258' TVD. High torque increased, Slowed ROP down to 30'/hr after confirming TD was going to be called early. WOB: 20k GPM: 675 PSI: 3,965 ECD: 12.9ppg, Holding on connections RPM: 150 TQ on: 18k ft/lbs TQ off: 16k ft/lbs F/O: 34% MW: 11.5 ppg PU: 260k ROT: 182k ADT: 3.1rs TBH: 25 TJH: 176.5 14,565.0 14,712.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 25/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/20/2023 04:00 3/20/2023 06:00 2.00 INTRM2, TRIPCAS CIRC P Take base parameters f/ underreamer. Drop 1.625" Torlon ball. Pump down string. Pump down at 250 GPM 954psi (192psi BP) for 1200stks and reduce rate to 100 GPM 750psi (370psi BP). Ball landed at 2,495stks. under reamer shift close at 2,057psi. Check parameters to confirm under reamer closed. Base parameters: open 3888 Turbine RPM 600 GPM 3313 PSI Post parameters: closed 4473 Turbine RPM 600 GPM 3455 PSI 14,712.0 14,699.0 3/20/2023 06:00 3/20/2023 08:30 2.50 INTRM2, TRIPCAS CIRC P Circulate and condition mud at 14,699' MD. GPM: 600 PSI: 3932 ECD: 12.8ppg RPM: 120 TRQ: 14k ROT: 188k 14,699.0 14,699.0 3/20/2023 08:30 3/20/2023 09:00 0.50 INTRM2, TRIPCAS CIRC P Relax MPD pressure to 0psi, OWFF 10min (static) Blow down top drive and line up for stripping. Take SPR's 14,699.0 14,672.0 3/20/2023 09:00 3/20/2023 11:30 2.50 INTRM2, TRIPCAS SMPD P SOOH from 14672' MD to 12,590' MD. holding 580psi in slips and 650psi out. 14,672.0 12,590.0 3/20/2023 11:30 3/20/2023 14:30 3.00 INTRM2, TRIPCAS BKRM T Pulled tight at 12,590' MD, Establish circulation 475gpm 2,200psi, rotate at 20rmp, BROOH from 12,590' MD to 12,430' MD, Stall out and pack off at 12,430' MD, work string down to 12,465' MD, continue BROOH working string unto shoe. Continue BROOH in shoe to 12,405' MD. 12,590.0 12,405.0 3/20/2023 14:30 3/20/2023 17:00 2.50 INTRM2, TRIPCAS CIRC P Circulate and condition mud at 12,310' MD GPM: 660 PSI: 3640 RPM: 60 TRQ: 13k ECD: 12.8ppg ROT: 178k 12,405.0 12,310.0 3/20/2023 17:00 3/20/2023 17:30 0.50 INTRM2, TRIPCAS OWFF P OWFF, (static) Blow down top drive and line up to strip out hole. Drop 2.44" hallow drift. 12,310.0 12,310.0 3/20/2023 17:30 3/21/2023 00:00 6.50 INTRM2, TRIPCAS STRP P SOOH from 12,310' MD to 5,352' MD. holding 580psi in slips and 690psi out. PU: 127k SO: 112k 12,310.0 5,352.0 3/21/2023 00:00 3/21/2023 04:00 4.00 INTRM2, TRIPCAS STRP P SOOH from 5,352' MD to 732' MD. 50'/min MPD 620 off 580 on slips. 5,352.0 732.0 3/21/2023 04:00 3/21/2023 04:30 0.50 INTRM2, TRIPCAS OWFF P Bled off MPD back pressure to 0psi, OWFF (Static) 732.0 732.0 3/21/2023 04:30 3/21/2023 05:00 0.50 INTRM2, TRIPCAS MPDA P Pull RCD and install trip nipple, 732.0 720.0 3/21/2023 05:00 3/21/2023 08:00 3.00 INTRM2, TRIPCAS BHAH P L/D 8-1/2" x 9-7/8" Intermedate #2 BHA. No noted damages on tools. 720.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 26/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/21/2023 08:00 3/21/2023 09:00 1.00 INTRM2, TRIPCAS BHAH P Clean and clear rig floor, L/D tools and equipment out beaver slide. 0.0 0.0 3/21/2023 09:00 3/21/2023 10:00 1.00 INTRM2, CASING RURD P R/U 7" casing equipment, Function safety valve with X/O on floor. 0.0 0.0 3/21/2023 10:00 3/21/2023 12:00 2.00 INTRM2, CASING PUTB P PJSM, P/U and run shoe track (check floats all ok) continue RIH with 7" 29ppf L80 H563 liner to 857' MD. MU: 10,100ft/lbs PU: 57k SO: 64k NOTE: PU and SO readings seems backwards but thats the correct readings. 0.0 857.0 3/21/2023 12:00 3/21/2023 13:30 1.50 INTRM2, CASING OTHR P Continue P/U and RIH with 7" 29ppf L80 H563 liner from 857' MD to 2419' MD. MU: 10,100ft/lbs PU: 94k SO: 98k 857.0 2,419.0 3/21/2023 13:30 3/21/2023 15:00 1.50 INTRM2, CASING PULD P PU and RIH with 7" liner hanger HRD-E running tools per Baker. Fill hanger w/ Zanplex. Fill liner and break circulation 2bpm 110psi. PU: 94k SO:98k 2,419.0 2,462.0 3/21/2023 15:00 3/21/2023 16:00 1.00 INTRM2, CASING MPDA P Pull trip nipple and install RCD and lines. 2,462.0 2,462.0 3/21/2023 16:00 3/21/2023 18:00 2.00 INTRM2, CASING SMPD P SIH with 7" 29ppf L80 H563 liner on 5" drill pipe from 2,462' MD to 4812' MD. SO: 96k 2,462.0 4,812.0 3/21/2023 18:00 3/22/2023 00:00 6.00 INTRM2, CASING SMPD P SIH with 7" 29ppf L80 H563 liner on 5" drill pipe from 4,812' MD to 10,560' MD. Holding 410psi on and 580psi off slips. SO: 128k 4,812.0 10,560.0 3/22/2023 00:00 3/22/2023 02:00 2.00 INTRM2, CASING SMPD P SIH with 7" 29ppf L80 H563 liner on 5" drill pipe from 10,560' MD to 12,348' MD. Holding 410psi on and 580psi off slips. PU: 212k SO: 140k 10,560.0 12,348.0 3/22/2023 02:00 3/22/2023 05:00 3.00 INTRM2, CASING CIRC P Stage up pump to 6bpm 817psi, attempt to rotate, 11k torque unable to rotate. Circulate BU, PU: 196k SO: 150k still unable to rotate at 11k. Blow down top drive. MU: 10,100ft/lbs Final PU/SO PU: 196k SO: 150k 12,348.0 12,348.0 3/22/2023 05:00 3/22/2023 07:00 2.00 INTRM2, CASING SMPD P SIH with 7" 29ppf TN 100SS H563 liner on 5" drill pipe from 12,348' MD to 14,618' MD. Holding 410psi on and 580psi off slips. PU: 212k SO: 155k 12,348.0 14,618.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 27/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/22/2023 07:00 3/22/2023 10:00 3.00 INTRM2, CASING WASH P Wash in hole from 14,618' MD to 14,707' MD. Stage up to 2bpm 452psi, work through 8.5" hole section with string packing off, Adjust MPD pressure to circulate at 1/2bpm. Increase rotary torque, string rotating at 18k, continue work string down to 14,707' MD. 14,618.0 14,707.0 3/22/2023 10:00 3/22/2023 10:30 0.50 INTRM2, CEMENT RURD P Blow down top drive, P/U cement swivel and cement hose. 14,707.0 14,707.0 3/22/2023 10:30 3/22/2023 12:00 1.50 INTRM2, CEMENT CIRC P Break circulation and stage pump up from 1/4bpm to 2bpm 560psi. while holding 350psi on MPD. 14,707.0 14,707.0 3/22/2023 12:00 3/22/2023 17:30 5.50 INTRM2, CEMENT CIRC P Circulate and work pipe free at 14,707' MD PU: 275k SO: 147k, stage pump rate from 1/4bpm to 2bpm 430psi, 0psi on MPD. FCP at 2bpm 430psi. 14,707.0 14,707.0 3/22/2023 17:30 3/22/2023 23:00 5.50 INTRM2, CEMENT CMNT P Pressure test line to 4600psi. Pump 70bbls KCL w/ rig. Drop bottom dart. Swap to cementers.Mix and pump 82bbls 15.8ppg cement @ 2BPM. SD and drop top dart.Pump 10bbl FW w/ cementers. Swap over to rig pumps and displace cement w/ 285.3bls 11.5ppg NAF. 3372stks pumped. FCP 670 PSI. Pressure up to 1230 PSI and hold f/ 5 min. Bleed off and check floats. Good. Cement in place. @ 22:58hrs 3-22-23 Note: Bottom dart lands and shears bottom plug at 1345stks 1720psi while pumping at 2bpm 200psi. Surge of plug released, lost returns form well, (fluid still at flow line), Work string PU:275k SO: 97k without returns, work pipe free with 342k and regained returns (-17bbls lost and regained volume after establishing circulation) Staged up pumps to 2bpm 410psi. Top dart lands 2330stks and shears at 1730psi, Bottom plug land and shear at 480psi, Drop rate to 1bpm 290psi (full returns) Increase rate to 1.5bpm for 3min and packed off, P/U string and broke free and regained circulation with 290k, set string back on depth pumping at 1bpm, bump plug at 3372stks 3.7bbls early. 0bbls lost after cement turned the shoe. TOL @ 12,253'. FS @ 14,707'. 14,707.0 14,707.0 3/22/2023 23:00 3/23/2023 00:00 1.00 INTRM2, CEMENT OTHR P Set Baker hanger, Pressure up to 2400psi, SO 50k verify set, Pressure up to 3700psi and release HRD running tool, Free weight 210k, Expose dog sub, Slack off string and packer set at 130k, PU rotate and set back down to 150k 20rpm 9k torque for 3min. 14,707.0 14,707.0 3/23/2023 00:00 3/23/2023 00:00 INTRM2, CEMENT 14,707.0 3/23/2023 00:00 3/23/2023 00:30 0.50 INTRM2, CEMENT PRTS P Drill pipe open to atmosphere, pressure test 7" liner top to 1000psi 10min (good test) 3.2bbls pumped and returned. 14,707.0 14,707.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 28/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/23/2023 00:30 3/23/2023 02:00 1.50 INTRM2, CEMENT RURD P R/D Baker cement swivel, Pressure up to 500psi on string, Unseat from liner and observed pressure drop, Increase pump rate to 500gpm 1830psi. (pump 7" nerf wipper ball) 14,707.0 14,707.0 3/23/2023 02:00 3/23/2023 03:00 1.00 INTRM2, CEMENT MPDA P OWFF (static) Pull RCD and install trip nipple and lines. 14,707.0 12,041.0 3/23/2023 03:00 3/23/2023 03:30 0.50 INTRM2, CEMENT CIRC P Pump dry job and blow down top drive. 12,041.0 12,041.0 3/23/2023 03:30 3/23/2023 09:00 5.50 INTRM2, CEMENT TRIP P POOH from 12,041' MD to 2,114' MD. 12,041.0 2,114.0 3/23/2023 09:00 3/23/2023 11:00 2.00 INTRM2, CEMENT TRIP P Continue POOH L/D 5" singles for pipe management. 2,114.0 0.0 3/23/2023 11:00 3/23/2023 11:30 0.50 INTRM2, CEMENT BHAH P L/D Baker liner running tools. 0.0 0.0 3/23/2023 11:30 3/23/2023 12:30 1.00 INTRM2, WHDBOP OTHR P Change out upper rams from 4-1/2" X 7" to 2-7/8" X 5-1/2". 0.0 0.0 3/23/2023 12:30 3/23/2023 13:30 1.00 INTRM2, WHDBOP OTHR P R/U and pull wear ring and install test plug. 0.0 0.0 3/23/2023 13:30 3/23/2023 15:00 1.50 INTRM2, WHDBOP BOPE P R/U test equipment and purge air from system. 0.0 0.0 3/23/2023 15:00 3/23/2023 22:00 7.00 INTRM2, WHDBOP BOPE P BOPE Test: All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 2500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5” Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR, W/ 4" Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR,Test choke valves 1-15. Manual operated and super choke. Choke manuals and HCR valves. 4" kill line valve. Test 2x 4" FO safety valves. 4" dart valve. 2x 5" FO safety valves. 5" dart valve. Test upper and lower IBOP. Blind ram. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1400 psi, ACC = 1675 psi after all functions on bottles,16 sec for 200 psi. Build w/ 2 electric pumps, 104 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 17 sec. UPR = 14 sec, Blind ram = 14 sec, LPR = 15 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms AOGCC Austin McLeod waived witness at 19:10pm 3-22-23. BLM Quinn M Sawyer waived witness 16:57pm 3-20-23. 0.0 0.0 3/23/2023 22:00 3/23/2023 23:00 1.00 INTRM2, WHDBOP OTHR P Drain water from BOP, pull test plug and install wear ring. 0.0 0.0 3/23/2023 23:00 3/24/2023 00:00 1.00 INTRM2, DRILLOUT PRTS P Fill BOP's with 11.5ppg mud, Purge air from system, Pressure test 9-5/8" X 7" liner to 3500psi 30 MIn. Pumped 15.2bbls returned 15.0bbls (good test) 0.0 0.0 3/24/2023 00:00 3/24/2023 00:30 0.50 INTRM2, DRILLOUT PRTS P Finish pressure test casing, Pressure test 9-5/8" X 7" liner to 3500psi 30 MIn. Pumped 15.2bbls returned 15.0bbls (good test) 0.0 0.0 3/24/2023 00:30 3/24/2023 01:00 0.50 INTRM2, DRILLOUT RURD P R/D test equipment and Blow down, Finish Prep for production BHA #4. SIMOPS: change out flow box air boot. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 29/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/24/2023 01:00 3/24/2023 05:00 4.00 INTRM2, DRILLOUT BHAH P P/U BAker 6-1/8" production BHA #4. RIH to 244' MD. 0.0 244.0 3/24/2023 05:00 3/24/2023 12:00 7.00 INTRM2, DRILLOUT TRIP P Change out PS-121's inserts to 4", Single in 4" drill pipe to 5,455' MD. Fill pipe every 25stds. Log ring pipe at 4,200' MD, Log with sonic at 1800'/hr from 5,400' MD. 244.0 5,455.0 3/24/2023 12:00 3/24/2023 18:00 6.00 INTRM2, DRILLOUT TRIP P Single in 4" drill pipe from 5,455' MD to 9,244' MD, Log with sonic at 1800'/hr, Fill pipe every 25stds. 5,455.0 9,244.0 3/24/2023 18:00 3/25/2023 00:00 6.00 INTRM2, DRILLOUT TRIP P Single in 4" drill pipe from 9,244' MD to 12,571' MD, Log with sonic at 1800'/hr, Fill pipe every 25stds. 9,244.0 12,571.0 3/25/2023 00:00 3/25/2023 03:00 3.00 INTRM2, DRILLOUT TRIP P Single in 4" drill pipe from 12,571' MD to 14,459' MD, Log with sonic at 1800'/hr, Fill pipe every 25stds. 12,571.0 14,459.0 3/25/2023 03:00 3/25/2023 04:00 1.00 INTRM2, DRILLOUT COCF P Break circulation and wash/ream from 14,459' MD , tagged at 14,610' MD. GPM: 180-240 PSI: 3060 RPM: 50 TRQ: 9-10k ROT: 148k 14,459.0 14,610.0 3/25/2023 04:00 3/25/2023 08:00 4.00 INTRM2, DRILLOUT DRLG P Drill cement, LC, FC from 14,610' MD to 14,704' MD. GPM: 180-240 PSI: 3060 WOB: 10-18k RPM: 50 TRQ: 9-12k PU: 186k SO: 125k ROT: 148k 14,610.0 14,704.0 3/25/2023 08:00 3/25/2023 10:00 2.00 INTRM2, DRILLOUT CIRC P Displace well at 14,704' MD, 40bbls LVT 100bbls Transition spacer GPM: 230 PSI: 2300 RPM: 30 TRQ: 10k ROT: 148k 14,704.0 14,704.0 3/25/2023 10:00 3/25/2023 10:30 0.50 INTRM2, DRILLOUT OTHR T Replace packed off transfer hose to trucks. 14,704.0 14,704.0 3/25/2023 10:30 3/25/2023 14:00 3.50 INTRM2, DRILLOUT CIRC P Finish displacing well at 14,704' MD, 100bbls clean spacer 50bbls HI-Vis FPNT spacer GPM: 230 PSI: 2300... FCP 1330psi. RPM: 30 TRQ: 10k ROT: 148k 14,704.0 14,704.0 3/25/2023 14:00 3/25/2023 17:00 3.00 INTRM2, DRILLOUT CLEN P Clean pits and surface equipment, prep for FloPro fluid. SIMOPS: Cut and slip 118' drill line. SIMOPS: Pull trip nipple and install RCD 14,704.0 14,704.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 30/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2023 17:00 3/25/2023 17:30 0.50 INTRM2, DRILLOUT DRLG P Establish circulation through MPD system, Gather drilling parameters. Drill remainding cement and shoe from 14,704' MD to 14,712' MD. 14,704.0 14,712.0 3/25/2023 17:30 3/25/2023 18:30 1.00 INTRM2, DRILLOUT DDRL P Drill 6-1/8" production hole from 14,712' MD to 14,732' MD. WOB: 12k GPM: 225 PSI: 1300 ECD: 9.3ppg RPM: 50 TQ on: 8k ft/lbs TQ off: 6k ft/lbs F/O: 13% MW: 8.8 ppg PU: 171k SO: 136k ROT: 155k ADT: 0.7hrs TBH: 0.7 hrs 14,712.0 14,732.0 3/25/2023 18:30 3/25/2023 19:00 0.50 INTRM2, DRILLOUT CIRC P Pull into shoe from 14,732' MD to 14,645' MD. Blow down top drive, R/U safety valve and circulating hose. Circulate at 225gpm 1300psi Mud 8.7+ in/out. 14,732.0 14,645.0 3/25/2023 19:00 3/25/2023 20:30 1.50 INTRM2, DRILLOUT FIT P Line up BOP equipment and purge air from system. Perform FIT @ 14,707' MD 8,258' TVD with 8.7+ mud pump at 0.5bpm to 1430psi, held for 10min final pressure 1429psi, Pumped 4.6bbls returned 4.2bbls 12.1ppg EMW. 14,645.0 14,645.0 3/25/2023 20:30 3/25/2023 21:00 0.50 INTRM2, DRILLOUT OTHR P Establish circulation at 14,645' MD, Set up Novos. Gather perameters in casing with Novos. Wash in hole to 14,732' MD. GPM: 70 PSI: 364 RPM: 20 TQ off: 4.7k ft/lbs FT/Min: 30 MW: 8.8 ppg PU: 172k SO: 139k ROT: 163k 14,645.0 14,732.0 3/25/2023 21:00 3/26/2023 00:00 3.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 14,732' MD to 14,835' MD 8,278' TVD. Close MPD on connections 0psi. WOB: 18k GPM: 225 PSI: 1300 ECD: 9.2ppg RPM: 50 TQ on: 8k ft/lbs TQ off: 5k ft/lbs F/O: 11% MW: 8.8 ppg PU: 172k SO: 139k ROT: 154k ADT: 2.5hrs TBH: 3.2hrs 14,732.0 14,835.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 31/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/26/2023 00:00 3/26/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 14,835' MD to 15,329' MD 8,337' TVD. Close MPD on connections 0psi. WOB: 20k GPM: 241 PSI: 1540 ECD: 9.5ppg RPM: 130 TQ on: 9k ft/lbs TQ off: 5k ft/lbs F/O: 13% MW: 8.8 ppg PU: 180k SO: 134k ROT: 158k ADT: 4.6hrs TBH: 7.8hrs 14,835.0 15,329.0 3/26/2023 06:00 3/26/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 15,329' MD to 15,878' MD 8,377' TVD. Close MPD on connections 0psi. WOB: 10-18k GPM: 241 PSI: 1583 ECD: 9.5ppg RPM: 130 TQ on: 7k ft/lbs TQ off: 5k ft/lbs F/O: 15% MW: 8.8 ppg PU: 180k SO: 131k ROT: 154k ADT: 5.0hrs TBH: 12.8hrs 15,329.0 15,878.0 3/26/2023 12:00 3/26/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 15,878' MD to 16418' MD 8,367' TVD. Close MPD on connections 0psi. WOB: 10-18k GPM: 241 PSI: 1583 ECD: 9.5ppg RPM: 130 TQ on: 7k ft/lbs TQ off: 5k ft/lbs F/O: 15% MW: 8.8 ppg PU: 180k SO: 131k ROT: 154k ADT: 5.0hrs TBH: 12.8hrs 15,878.0 16,418.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 32/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/26/2023 18:00 3/27/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 16,418' MD to 16,832' MD 8,353' TVD. Close MPD on connections 0psi. WOB: 15k GPM: 241 PSI: 1780 ECD: 9.6ppg RPM: 130 TQ on: 9k ft/lbs TQ off: 6k ft/lbs F/O: 15% MW: 8.8 ppg PU: 182k SO: 128k ROT: 156k ADT: 4.8hrs TBH: 22.0hrs 16,418.0 16,832.0 3/27/2023 00:00 3/27/2023 02:00 2.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 16,832' MD to 17,022' MD 8,347' TVD. Close MPD on connections 0psi. Losses at 16,593' MD +30bph, adding back ground LCM to system. Losses decreased to 20bph. Losses at 16,953' MD from 20bph to 80bph, AT 17,010' MD Pump 20bbls 35ppb LCM down string. After starting to chase pill , lost 100% of returns. WOB: 15k GPM: 240 PSI: 1780 ECD: 9.7ppg RPM: 130 TQ on: 9k ft/lbs TQ off: 6k ft/lbs F/O: 15% MW: 8.8 ppg PU: 182k SO: 128k ROT: 156k ADT: 1.8hrs TBH: 23.8hrs 16,832.0 17,022.0 3/27/2023 02:00 3/27/2023 08:00 6.00 PROD1, DRILL CIRC T Continue pumping 20bbls 35ppb LCM pill at 17,016' MD, reduce rotary rpm to 20rpm, fill backside with 41bbls and regained slight returns, Lost 100% returns again and slowed pump rate down to 0.5bpm and regained slight returns. Fill backside with 93bbls 8.7ppg with intermitting returns. Rack back stand while continue keeping intermitting returns on back side while prepping for second pill. Total 332bbls pumped on backside. Pill 5ppb MIX II Med 10ppb WN plug fine 10ppb WN plug Med 10ppb Cal CarbD50 17,022.0 17,022.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 33/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2023 08:00 3/27/2023 13:30 5.50 PROD1, DRILL CIRC T Attempt to regain circulation, Pump 1bpm down string and 3bpm on backside. Drop well commander opening ball and pump down 800stks, drop isolation ball and continue pumping. Ball landed at 994stks. pressure up to 1400psi to shift open, Pump out of hole from 17,016' MD to 16,825' MD. Pump 100bbls 60ppb LCM at 3bpm and chase with 8.6ppb at 5bpm. Allow pill to soak keeping backside full pumping at 70gpm for 10min with no changes. Pump second 100bbl 60ppb LCM at 3bpm and chase at 3bpm spot out WC, Apply back pressure with MPD staging up to 300psi while pumping down the backside at 5bpm (squeezed 85bbls away). With minimum returns recovered. Drop closing ball and pump down at 2bpm, ball landed at 1023stks and shift closed at 1980psi. Increase rate to 170gpm to observe directional tools pulse. Pill's 5ppb MIX II Med 10ppb WN plug fine 30ppb WN plug Med 15ppb Cal CarbD50 17,022.0 16,825.0 3/27/2023 13:30 3/27/2023 16:00 2.50 PROD1, DRILL TRIP T Attempt to TIH from 16,838' MD, tagged at 16,838' MD, wash and ream down to 17,022' MD at 84gpm 570psi 10rpm keeping hole full on backside. 16,825.0 17,022.0 3/27/2023 16:00 3/27/2023 18:00 2.00 PROD1, DRILL DDRL T Drill 6-1/8" production hole from 17,022' MD to 17,300' MD 8,340' TVD. Close MPD on connections 0psi. WOB: 16k GPM: 170 PSI: 985 ECD: 9.2ppg RPM: 130 TQ on: 12k ft/lbs TQ off: 7k ft/lbs F/O: 0% MW: 8.7 ppg PU: 190k SO: 130k ROT: 140k ADT: 2.0hrs TBH: 25.9hrs 17,022.0 17,300.0 3/27/2023 18:00 3/27/2023 19:00 1.00 PROD1, DRILL STRP T SOOH from 17,300' MD to 16,827' MD. Keeping back side full. PU: 190k SO: 128k 17,300.0 16,827.0 3/27/2023 19:00 3/27/2023 20:00 1.00 PROD1, DRILL CIRC T Pump down 1.75" well commander openning ball at 2bpm 370psi, ball on seat at 921stks, pressure up to 1400psi, 1800psi, shift at 2000psi. Pump down 1.693" !solation ball. 16,827.0 16,827.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 34/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2023 20:00 3/28/2023 00:00 4.00 PROD1, DRILL CIRC T Pump 95bbls Procore Level 1 pill at 126gpm 390psi with 20gpm returns. Spot pill with 2030stks FCP 126gpm 440psi with 40-50gpm returns. Set for 10min, turn on hole fill pump with open choke continue filling back side 30bbls with, 15min, Pump at 2bpm 10bbls every 15min till 95bbls of pill was displaced. (no returns to surface) Pill, Mixed with Schlumberger 5ppb Pro Tightceal Med 5ppb SB Superceal 40ppb Pro V+ 16,827.0 16,827.0 3/28/2023 00:00 3/28/2023 00:30 0.50 PROD1, DRILL OWFF T Monitor losses while prep for next LCM pill. Continuous fill backside 46bbls. (92bpmh losses) 16,827.0 16,827.0 3/28/2023 00:30 3/28/2023 03:00 2.50 PROD1, DRILL CIRC T Pump 100bbls 100ppb LCM pill at 126gpm 430psi 0 returns ROT 5rpm 7k torque, Pill in pipe and start casing pill regained returns. FCP spotting pill 119gpm 440psi 42gpm returns. Let pill set 10min. Squeeze pill in place BP set at 50psi pump at 42gpm 0 returns. Increase rate 60gpm 50psi 21gpm returns Increase BP to 70psi (10bbls pumped away) increase rate 80gpm 70psi 35gpm returns. increase BP to 80psi 40gpm return (32bbls pumped away) increase to 100psi 40gpm returns increased to 120psi 40gpm returns (50bbls pumped away) increased to 140psi 40gpm returns (60bbls pumped away) same at 80bbls pumped away Reduce rate to 1bpm 78psi back pressure (90bbls pumped away) Pill 10ppb WN fine 65ppb WN Med 5ppb MIX II Med 15ppb Safe Carb XC 16,827.0 16,827.0 3/28/2023 03:00 3/28/2023 06:30 3.50 PROD1, DRILL OWFF T Circulate across top at 2bpm 40/60bph losses. While fluid management and building Hybrid LCM pill. 16,827.0 16,827.0 3/28/2023 06:30 3/28/2023 09:00 2.50 PROD1, DRILL WASH T Wash in hole through well commander (BHA isolated) from 16,827' MD to 17,297' MD GPM: 122 PSI: 400 RPM: 10 TRQ: 7-10 FO: 1% 16,827.0 17,297.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 35/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/28/2023 09:00 3/28/2023 10:30 1.50 PROD1, DRILL CIRC T Circulate at 17,297' MD (through well commander) Monitor static loss rate @ 100bph GPM: 122 PSI: 400-440 RPM: 5 TRQ: 7 FO: 1% 17,297.0 17,297.0 3/28/2023 10:30 3/28/2023 12:30 2.00 PROD1, DRILL CIRC T Pump 50bbls Hybrid LCM pill at 1bpm 60psi rotating at 5rpm 7k torque. Chase pill at 3bpm 400psi and spot at well commander. Hybrid Pill - Mixed with batch tank 100bbls 40ppb Form-A-Blok 50ppb WN Med. 17,297.0 17,297.0 3/28/2023 12:30 3/28/2023 13:00 0.50 PROD1, DRILL PMPO T Pump out while spotting Hybrid LCM pill from 17,297' MD to 17,110' MD. GPM: 54 PSI: 210 RPM: 10 TRQ: 7 FO: 1% 17,297.0 17,110.0 3/28/2023 13:00 3/28/2023 14:30 1.50 PROD1, DRILL OTHR T Encountered pack off at 17,110' MD. Troubleshoot surface equipment. Verified packoff at well commander. Attempt to work packoff free, attempt to reverse and pressure up on string in stages up to 1500psi and dumping pressure without sucess. Blow down top drive and kill line. Line up MPD for tripping. 17,110.0 17,110.0 3/28/2023 14:30 3/28/2023 18:00 3.50 PROD1, DRILL STRP T Strip out hole from 17,110' MD to 13,366' MD. GPM: 180 FO: 5% PU: 187k SO: 134k Losses: 120bph 17,110.0 13,366.0 3/28/2023 18:00 3/28/2023 20:00 2.00 PROD1, DRILL STRP T Continue strip out hole from 13,366' MD to 12,088' MD. GPM: 110 FO: 2% PU: 184k SO: 120k Losses: 120bph 13,366.0 12,088.0 3/28/2023 20:00 3/28/2023 21:00 1.00 PROD1, DRILL MPDA T OWFF (still losses). Pull RCD and install trip nipple and service lines. Losses: 120bph 12,088.0 12,088.0 3/28/2023 21:00 3/29/2023 00:00 3.00 PROD1, DRILL TRIP T Trip out hole from 12,088' MD to 5,549' MD. Dropped 2.40" hallow drift with tail at 8,011' MD. GPM: 110 FO: 2% PU: 117k Losses: 120bph 12,088.0 5,549.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 36/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/29/2023 00:00 3/29/2023 01:30 1.50 PROD1, DRILL TRIP T Trip out hole from 5549' MD to 3900' MD. GPM: 110 FO: 2% PU: 95k Losses: 120bph 5,549.0 3,900.0 3/29/2023 01:30 3/29/2023 03:00 1.50 PROD1, DRILL TRIP T MU 3/4" grout line to wash out LCM pill from drillpipe. 3,900.0 3,900.0 3/29/2023 03:00 3/29/2023 12:00 9.00 PROD1, DRILL TRIP T Trip out of hole from 3900' to 1250'. LD 4" DP in doubles to pipe tubs in shed. Wash each double w/ grout line and drift same. 120 BPH loss rate. 3,900.0 1,250.0 3/29/2023 12:00 3/29/2023 17:00 5.00 PROD1, DRILL TRIP T Trip out of hole from 1250' to 241'. LD 4" DP in doubles to pipe tubs in shed. Wash each double w/ grout line and drift same. 120 BPH loss rate. 3,900.0 241.0 3/29/2023 17:00 3/29/2023 18:30 1.50 PROD1, DRILL BHAH T Flush and wash out HWDP, reamer and float sub. Inspect well commander. Ports plugged w/ LCM. Clean out well commander ports. 241.0 241.0 3/29/2023 18:30 3/29/2023 21:30 3.00 PROD1, DRILL BHAH T Retrieve source from MWD tools. LD Well commander and SonicScope. Plug in to BHA and turn off tools. Plug in and download data from tools. SimOps: Flush and clean mud pits. 241.0 0.0 3/29/2023 21:30 3/29/2023 23:30 2.00 PROD1, DRILL BHAH T Visually inspect BHA. Good. Plug in to tools and initialize. RIH single and circulate at 120 gpm for 5 minutes. Bring up rate to 220 gpm and shallow testr tools. Good test. 0.0 0.0 3/29/2023 23:30 3/30/2023 00:00 0.50 PROD1, DRILL BHAH T MU BHA and RIH. 0.0 3/30/2023 00:00 3/30/2023 01:30 1.50 PROD1, DRILL BHAH T MU BHA and RIH to 208'. Drop opening ball and open well commander. Shifted @ 1350psi. Drop BHA isolation ball. 0.0 208.0 3/30/2023 01:30 3/30/2023 03:30 2.00 PROD1, DRILL CLEN T Clean out LCM fromflow box and drainpans under rotary. 208.0 208.0 3/30/2023 03:30 3/30/2023 07:30 4.00 PROD1, DRILL TRIP T RIH w/ 4" DP doubles from pipe shed to 5512'. 208.0 5,512.0 3/30/2023 07:30 3/30/2023 12:00 4.50 PROD1, DRILL TRIP T RIH w/ 4" DP out of derrick f/ 5512' to 12100'. 5,512.0 12,100.0 3/30/2023 12:00 3/30/2023 13:00 1.00 PROD1, DRILL MPDA T Retrieve trip nipple and install MPD bearing assembly. 12,100.0 12,100.0 3/30/2023 13:00 3/30/2023 14:00 1.00 PROD1, DRILL SLPC T Slip/Cut drill line. SimOps: Pump DS volume to ensure clear. 12,100.0 12,100.0 3/30/2023 14:00 3/30/2023 18:30 4.50 PROD1, DRILL SMPD T SIH f/ 12100' to 17270'. Observed obstruction @ 15760'. Rotate through it @ 10 RPM /9k TQ/3 BPM/440PSI. 12,100.0 17,270.0 3/30/2023 18:30 3/30/2023 20:30 2.00 PROD1, DRILL SMPD T SOOH f/ 17270' to 15658'. 17,270.0 15,658.0 3/30/2023 20:30 3/30/2023 22:30 2.00 PROD1, DRILL CIRC T Establish static loss rate=43 BPH Break circulation and establish dynamic loss ate 3 BPM/400 PSI=132 BPH Pump 72bbls of 90PPB ProCor LCM pill. Chase pill to well commander @ 3BPM/368 PSI. Slow rate to 2 BPM and close choke on MPD as pill exits well commander. Pump @ 2 BPM 440PSI with choke closed until pill cleared drill string + 10 BBLS. MPD pressure @ 175 PSI. 15,658.0 15,658.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 37/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/30/2023 22:30 3/30/2023 23:00 0.50 PROD1, DRILL OTHR T SD pumps. Holding 175PSI with MPD. Blow down top drive. Rack back 1 std to be above LCM pill. Let pill soak. MPD pressure bled to 0 PSI in 15 minutes. 15,658.0 15,553.0 3/30/2023 23:00 3/31/2023 00:00 1.00 PROD1, DRILL OTHR T 1st squeeze: Fill Annulus = 12 BBLS. Close choke and squeeze 5 BBLS @ 1/2 BPM 140 PSI. MPD pressure 30 PSI. SD and pressure fell to 0 PSI. Total pumped 17 BBLS. Monitor for 30 minutes. 2nd squeeze: Fill annulus=22 BBLS. Close choke and squeeze 5 BBLS @ 1/2 BPM 140 PSI. MPD pressure= 30 PSI. SD and pressure fell to 0 PSI Monitor for 30 minutes. 15,553.0 15,553.0 3/31/2023 00:00 3/31/2023 01:00 1.00 PROD1, DRILL CIRC T Circulate across top of hole. RIH 1 std to 15658'. Static loss rate = 49 BPH 15,553.0 15,658.0 3/31/2023 01:00 3/31/2023 02:30 1.50 PROD1, DRILL CIRC T 2nd Procor LCM pill: Pump 70bbls of 90PPB ProCor LCM pill. Chase pill to well commander @ 3BPM/620 PSI. Slow rate to 2 BPM and close choke on MPD as pill exits well commander. Pump @ 2 BPM 588PSI with choke closed until pill cleared drill string + 10 BBLS. MPD pressure @ 250PSI. 15,658.0 15,658.0 3/31/2023 02:30 3/31/2023 03:00 0.50 PROD1, DRILL CIRC T SD pumps. Holding 224PSI with MPD. Blow down top drive. Rack back 1 std to be above LCM pill. Let pill soak. MPD pressure bled to 0 PSI in 20 minutes. Open choke and fill annulus. 1 BBL to fill. Circulate across top and establish static loss rate = 18 BPH. 15,658.0 15,553.0 3/31/2023 03:00 3/31/2023 05:00 2.00 PROD1, DRILL CIRC T 1st squeeze: Close choke and squeeze 5 BBLS @ 1/2 BPM 140 PSI. MPD pressure 45 PSI. SD and pressure fell to 0 PSI. Monitor for 30 minutes. Open choke and fill annulus = 8 BBLS. Circulate across top of hole for 30 minutes. Loss rate = 50 BPH Close choke and squeeze 5 BBLs @ 1/2 BPM 140 PSi. MPD pressure 41 PSI. SD and pressure fell to 0 PSi. Monitor for 30 minutes. Open choke and fill annulus = 13 BBLS. 15,553.0 15,553.0 3/31/2023 05:00 3/31/2023 05:30 0.50 PROD1, DRILL CIRC T Circulate across top of hole. RIH 1 std to 15658'. Static loss rate = 45 BPH 15,553.0 15,658.0 3/31/2023 05:30 3/31/2023 07:30 2.00 PROD1, DRILL CIRC T 3rd Procor LCM pill: Pump 70bbls of 90PPB ProCor LCM pill. Chase pill to well commander @ 3BPM/328 PSI. Slow rate to 2 BPM and close choke on MPD as pill exits well commander. Pump @ 2 BPM 488PSI with choke closed until pill cleared drill string + 10 BBLS. MPD pressure @ 225PSI. 15,658.0 15,658.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 38/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/31/2023 07:30 3/31/2023 10:00 2.50 PROD1, DRILL CIRC T Monitor f/ 1 hr. Fill Annulus = 10 BBLS to fill. Monitor 1 hr. Fill annulus = 40 BBLS to fill annulus. 15,658.0 15,658.0 3/31/2023 10:00 3/31/2023 11:30 1.50 PROD1, DRILL TRIP T RIH f/ 15658' to 17265'. 15,658.0 17,265.0 3/31/2023 11:30 3/31/2023 13:00 1.50 PROD1, DRILL CIRC T Establish static loss rate = 25 BPH. Attempt to pump down string and pressure up to 1300 PSI. Bleed off rotate and work drill string in attempt to regain circulation. 17,265.0 17,265.0 3/31/2023 13:00 3/31/2023 14:00 1.00 PROD1, DRILL TRIP T POOH f/ 17265' to 16511'. 17,265.0 16,511.0 3/31/2023 14:00 3/31/2023 15:00 1.00 PROD1, DRILL CIRC T Attempt to regain circulation. Pressure up to 1800 PSI. No success. 16,511.0 16,511.0 3/31/2023 15:00 3/31/2023 16:30 1.50 PROD1, DRILL TRIP T POOH f/ 16511' to 15194'. 16,511.0 15,194.0 3/31/2023 16:30 3/31/2023 18:00 1.50 PROD1, DRILL CIRC T Attempt to regain circulation. Pressure up to 2800 PSI. Observed pressure loss and returns at shakers. Stage up pumps. Well commander closed pumping through BHA. Circulate at low rate to flush BHA. Stage up rate. All tools came on. 20 RPM 12k TQ 165 GPM 1780 PSI. 15,194.0 15,194.0 3/31/2023 18:00 3/31/2023 21:00 3.00 PROD1, DRILL TRIP T RIH f/ 16511' to 17265'. Wash down last 2 stds. 30 RPM 14k TQ 165 GPM 1525 PSI 15,194.0 17,265.0 3/31/2023 21:00 3/31/2023 22:00 1.00 PROD1, DRILL CIRC T Circulate and establish loss rate. Initial 54 BPH loss rate. 30 RPM 14k TQ 190 GPM 1890 PSI 17,265.0 17,265.0 3/31/2023 22:00 3/31/2023 22:30 0.50 PROD1, DRILL CIRC T MU std of DP. Wash down and relog last 30' to 17299' MD. 130 RPM 16k TQ 198 GPM 1960 PSI 17,265.0 17,299.0 3/31/2023 22:30 4/1/2023 00:00 1.50 PROD1, DRILL DDRL P Drill 17299' to 17405' MD / 8338' TVD 9k WOB 195 GPM 1930 PSI on bttm 1900 PSI off bttm 130 RPM 18k TQ on bttm 17k TQ off bttm 9.3ppg ECD 26.9 Bit hrs Loss rate= 70-100 BPH 17,265.0 17,405.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 39/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2023 00:00 4/1/2023 03:00 3.00 PROD1, DRILL DDRL T Drill 17405' to 17632' MD / 8337' TVD 16k WOB 180 GPM 1750 PSI on bttm 130 RPM 20k TQ on bttm 16k TQ off bttm 9.3ppg ECD 28.7 Bit hrs Loss rate= 80-120 BPH 17,405.0 17,632.0 4/1/2023 03:00 4/1/2023 04:00 1.00 PROD1, DRILL TRIP T SOOH f/ 17632' to 17455'. 17,632.0 17,455.0 4/1/2023 04:00 4/1/2023 05:30 1.50 PROD1, DRILL CIRC T Obtain parameters. Drop WC opening ball. Pump down @ 2 BPM. Ball landed and shifted WC open with 2200 PSI. Check parameters and confirm WC open.Drop BHA isolation bal and pump down to WC at 2 BPM. 17,455.0 17,455.0 4/1/2023 05:30 4/1/2023 07:30 2.00 PROD1, DRILL CIRC T Pump 40 BBL FormABloc pill and chase with 199 bbls of 8.8ppg Flo Pro at 3 BPM 483 PSI. 17,455.0 17,400.0 4/1/2023 07:30 4/1/2023 09:30 2.00 PROD1, DRILL TRIP T SOOH f/ 17400' to 16035'. SimOps: Building 3rd FormaBloc LCM pill. 17,400.0 16,035.0 4/1/2023 09:30 4/1/2023 10:30 1.00 PROD1, DRILL CIRC T Establish loss rates.Static- 42 BPH 16,035.0 16,035.0 4/1/2023 10:30 4/1/2023 12:30 2.00 PROD1, DRILL CIRC T Pump 2nd FormABloc LCM pill - 60 BBls Pump 60bbl os 40ppb pill. Displace w/ 8.8ppg FloPro @ 4 BPM 500 PSI. 16,035.0 16,035.0 4/1/2023 12:30 4/1/2023 14:00 1.50 PROD1, DRILL TRIP T SOOH f/ 16035' to 14995'. 16,035.0 14,995.0 4/1/2023 14:00 4/1/2023 18:00 4.00 PROD1, DRILL OTHR T Monitor well. 13:51hrs - Annulus full. SD holefill on backside. 14:51hrs - 32 BBLS to fill annulus 15:51hrs - 28 BBLS to fill annulus 16:51hrs - 26 BBLS to fill annulus 17:51hrs - 26 BBLS to fill annulus 14,995.0 14,995.0 4/1/2023 18:00 4/1/2023 19:30 1.50 PROD1, DRILL TRIP T RIH to 16035' MD. 14,995.0 16,035.0 4/1/2023 19:30 4/1/2023 21:00 1.50 PROD1, DRILL CIRC T Pump 3rd FormABloc pill. 51bbls pill @ 4 BPM 531 PSI Displace with 184 BBLS of 8.8ppg FloPro. at 4 BPM 539 PSI Slow to 3 BPM 443 PSi when pill exits well commander. 16,035.0 16,035.0 4/1/2023 21:00 4/1/2023 23:00 2.00 PROD1, DRILL TRIP T POOH f/ 16035' to 14500' at 5 min per std. 16,035.0 14,500.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 40/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2023 23:00 4/2/2023 00:00 1.00 PROD1, DRILL TRIP T Break circulation to confirm DS clear. 1st squeeze- 1BBL - 37PSI. Monitor 30 minutes 14,500.0 14,500.0 4/2/2023 00:00 4/2/2023 02:30 2.50 PROD1, DRILL CIRC T Fill annulus 12 bbls 2nd squeeze - 1 bbl - 30psi. fell to 0psi immediately. Monitor 30 minutes Fill annulus - 12 bbls 3rd squeeze- 1 bbl - 32psi - fell to 0psi immediately. Monitor 30 minutes Fill annulus - 12 bbls Squeeze 1 bbl - 30ps- fell to 0psi immediately. Monitor for 30 minutes. Fill annulus - 13 bbls Squeeze 1 bbl - 29psi - fell to 0psi immediately. Monitor for 30 minues. Fill annulus - 14 bbls. Note: Dropped WC closing ball and let fall while performing squeeze. 14,500.0 14,500.0 4/2/2023 02:30 4/2/2023 03:00 0.50 PROD1, DRILL CIRC T Close well commander. Shifted @ 2090 PSI. Confirm parameters and tools are working. BD top drive. 14,500.0 14,500.0 4/2/2023 03:00 4/2/2023 06:00 3.00 PROD1, DRILL TRIP T RIH to 16500'. Wash down from 16500' for safety at 1-2bpm to bottom. 14,500.0 17,632.0 4/2/2023 06:00 4/2/2023 12:00 6.00 PROD1, DRILL CIRC T Circulate BU while establishing loss rates. 165 GPM 1600 PSI 30 RPM 15k TQ 9.3ppg ECD Loss rate: 55-70 BPH 17,632.0 17,632.0 4/2/2023 12:00 4/2/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 17632' MD to 18216' MD / 8326' TVD. Losses increased @ 18164' and then came back 11k WOB 175 GPM 1780 PSI on bttm 1720 PSI off bttm 130 RPM 19k TQ on bttm 17k TQ off bttm 9.5ppg ECD 226k PU 105k SO 152k ROT 33.2 Bit hrs Loss rate= 65-120 BPH 17,632.0 18,216.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 41/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/2/2023 18:00 4/2/2023 22:00 4.00 PROD1, DRILL DDRL P Drill 18216' MD to 18469' MD / 8326' TVD. Pump 50 BBLS of 35PPB LCM pill @ 18415'. Went on full losses before pill exited DS @ 18440'. Keep hole full with pump on annulus. Slow rate and pump pill out of drill string. Observed returns increase when pill exited bit. Drill to 18469' and lost returns again. 11k WOB 175 GPM 1780 PSI on bttm 1720 PSI off bttm 130 RPM 19k TQ on bttm 17k TQ off bttm 9.5ppg ECD 226k PU 105k SO 152k ROT 33.2 Bit hrs 17,632.0 18,216.0 4/2/2023 22:00 4/2/2023 23:30 1.50 PROD1, DRILL TRIP T POOH to 18100' MD. SimOps Building 105PPB LCM pill. 18,216.0 18,443.0 4/2/2023 23:30 4/3/2023 00:00 0.50 PROD1, DRILL CIRC T Drop well commander opening ball and pump down @ 2 BPM 600 PSI. 20 RPM/18.4k TQ 18,443.0 18,443.0 4/3/2023 00:00 4/3/2023 01:00 1.00 PROD1, DRILL CIRC T Finish pumping down well commander opening ball. Shifted open @ 2090 PSI. Drop BHA isolation ball and pump down to isolate BHA. 18,443.0 18,443.0 4/3/2023 01:00 4/3/2023 02:00 1.00 PROD1, DRILL TRIP T POOH to 17500'. 18,443.0 17,500.0 4/3/2023 02:00 4/3/2023 04:00 2.00 PROD1, DRILL CIRC T Pump 50 BBLS of 105 PPB LCM pill. Displace with 8.8 PPG. flopro mud @ 3 BPM. Slow to 2 BPM as pill exits well commander and close choke. Bullhead pill below BHA. Max annulus pressure 61 PSI. 17,500.0 17,500.0 4/3/2023 04:00 4/3/2023 05:00 1.00 PROD1, DRILL CIRC T Rack back one std to 17455'. Establish static loss rates. 60 BPH. Pump across top of hole and let pill soak into loss zone. 17,500.0 17,455.0 4/3/2023 05:00 4/3/2023 06:30 1.50 PROD1, DRILL CIRC T Pump 2nd 50 BBL/ 90 PPB LCM pill. Dispalce w/ 8.8ppg flopro mud @ 3 BPM. Slow to 2 BPM and close choke when pill exits well commander. Bullhead pill below BHA. Max annulus pressure 150 PSI. 17,455.0 17,455.0 4/3/2023 06:30 4/3/2023 08:30 2.00 PROD1, DRILL CIRC T Establish loss rates. 60 BPH static. 120 BPH dynamic. 17,455.0 17,455.0 4/3/2023 08:30 4/3/2023 10:30 2.00 PROD1, DRILL CIRC T Pump 100 BBL LCM pill at 3 BPM. Displace w/ 8.8ppg flopro mud. 17,455.0 17,455.0 4/3/2023 10:30 4/3/2023 12:00 1.50 PROD1, DRILL TRIP T POOH above LCM pill to 16038'. 17,455.0 16,038.0 4/3/2023 12:00 4/3/2023 13:00 1.00 PROD1, DRILL CIRC T Establish loss rate: Static-84 BPH Dynamic - 120 BPH 16,038.0 16,038.0 4/3/2023 13:00 4/3/2023 15:00 2.00 PROD1, DRILL TRIP T RIH to 17455'. 16,038.0 17,455.0 4/3/2023 15:00 4/3/2023 16:00 1.00 PROD1, DRILL CIRC T Circulate @ 170 GPM/650 PSI. 20 RPM/10k TQ. 17,455.0 17,455.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 42/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/3/2023 16:00 4/3/2023 18:00 2.00 PROD1, DRILL CIRC T Pump 108 BBL of 115 PPB LCM pill. Displace out of drill string w/ 8.8 PPG flopro mud. 17,455.0 17,455.0 4/3/2023 18:00 4/3/2023 20:00 2.00 PROD1, DRILL TRIP T POOH to 16038'. 17,455.0 16,038.0 4/3/2023 20:00 4/4/2023 00:00 4.00 PROD1, DRILL CIRC T Fill annulus 15 BBLS Pump down DS to confirm clear. Circulate across top of hole to establish static loss rate-20-24 BPH Squeeze 1BBL at 1/2 BPM into looss zone- Built 50 PSI but bled off when SD pumps. Monitor 30 minutes. Static losses 18 BPH Squeeze 1 BBL into loss zone. Built 50 PSI but bled off when SD pumps. Monitor 30 ninutes. Static losses- 25 BPH Squeeze 5 BBLS @ 1/2 BPM. Built 50 PSI but bled off when SD pumps. Monitor 30 minutes. Static losses 25 BPH. Monitor 30 minutes Static losses 25 BPH. Circulate down string: 3 BPM-96 BPH loss rate 4 BPM- 84 BPH loss rate 5 BPM - 72 BPH loss rate. 16,038.0 16,038.0 4/4/2023 00:00 4/4/2023 01:00 1.00 PROD1, DRILL CIRC T Drop closing ball and pump down @ 2 BPM to close well commander. Circulate below rate for tools to come and flush BHA. Bring up rate and confirm tools are working. 16,038.0 16,038.0 4/4/2023 01:00 4/4/2023 04:00 3.00 PROD1, DRILL WASH T RIH to 17450'. Observed 15k weight @ 17450'. Wash down f/ 17440' to 18469'. 16,038.0 18,469.0 4/4/2023 04:00 4/4/2023 06:30 2.50 PROD1, DRILL DDRL P Drill 18469' MD to 18605' MD / 8312' TVD. 10k WOB 175 GPM 1800 PSI on bttm 1720 PSI off bttm 130 RPM 15k TQ on bttm 14k TQ off bttm 9.6ppg ECD 199k PU 120k SO 152k ROT 36.7 Bit hrs Loss rate= 65-120 BPH 18,469.0 18,605.0 4/4/2023 06:30 4/4/2023 07:30 1.00 PROD1, DRILL CIRC T Observe losses increasing PU and evaluate losses. 180-220 BPH losses and then started coming down to manageable level 100- 120 BPH. 18,605.0 18,605.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 43/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/4/2023 07:30 4/4/2023 12:00 4.50 PROD1, DRILL DDRL P Drill 18605' MD to 18977' MD / 8300' TVD. 10k WOB 175 GPM 1800 PSI on bttm 1720 PSI off bttm 130 RPM 15k TQ on bttm 14k TQ off bttm 9.6ppg ECD 199k PU 120k SO 152k ROT 40.3 Bit hrs Loss rate= 100-200 BPH 18,469.0 18,605.0 4/4/2023 12:00 4/4/2023 13:30 1.50 PROD1, DRILL CIRC T Circulate 3 x OH volume + liner volume. 190 GPM 1680 PSI 90 RPM 16k TQ 19,500.0 19,500.0 4/4/2023 13:30 4/4/2023 19:30 6.00 PROD1, DRILL DDRL P Drill 18977' MD to 19500' MD / 8300' TVD. Downlink and take survey. 10k WOB 175 GPM 1800 PSI on bttm 1720 PSI off bttm 130 RPM 15k TQ on bttm 14k TQ off bttm 9.6ppg ECD 199k PU 120k SO 152k ROT 40.3 Bit hrs Loss rate= 100-150 BPH 18,605.0 19,500.0 4/4/2023 19:30 4/4/2023 21:00 1.50 PROD1, DRILL CIRC T Drop WC closing ball and pump down. Shifted @ 1440 PSI. Confirm cosed and drop BHA isolation ball and pump down. 19,500.0 19,500.0 4/4/2023 21:00 4/4/2023 23:30 2.50 PROD1, DRILL CIRC T Pump 100 BBLS of 35 PPB LCM pill and 100 BBLS of 105 PPB LCM pill. Displace out well commander with 8.8ppg flopro fluid. 19,500.0 19,500.0 4/4/2023 23:30 4/5/2023 00:00 0.50 PROD1, DRILL TRIP T POOH f/ 19500' to 19250'. 19,500.0 19,250.0 4/5/2023 00:00 4/5/2023 05:30 5.50 PROD1, DRILL TRIP T POOH to inside shoe 14700'. 19,250.0 14,700.0 4/5/2023 05:30 4/5/2023 06:00 0.50 PROD1, DRILL CIRC T Circulate 2x liner volume. Loss rate 120 +/- BPH 208 GPM 640 PSI 10 RPM 5k TQ 14,700.0 14,700.0 4/5/2023 06:00 4/5/2023 08:00 2.00 PROD1, DRILL TRIP T POOH to TOL @ 12240'. 14,700.0 12,240.0 4/5/2023 08:00 4/5/2023 10:30 2.50 PROD1, DRILL CIRC T Circulate BU. 208 GPM 530 PSI 10 RPM 2k TQ 12,240.0 12,240.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 44/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/5/2023 10:30 4/5/2023 11:00 0.50 PROD1, DRILL MPDA T Drop well commander closing ball. Retrieve MPD bearing assembly. Install trip nipple. 12,240.0 12,240.0 4/5/2023 11:00 4/5/2023 11:30 0.50 PROD1, DRILL CIRC T Close well commander.Shifted close @ 3700 PSI. Pump slug. 12,240.0 12,240.0 4/5/2023 11:30 4/5/2023 16:30 5.00 PROD1, DRILL TRIP T POOH f/ 12240' to 6268' racking stds in derrick. 12,240.0 6,268.0 4/5/2023 16:30 4/5/2023 22:00 5.50 PROD1, DRILL TRIP T POOH f/ 6268' to 208' laying down doubles to pipe shed. 6,268.0 208.0 4/5/2023 22:00 4/6/2023 00:00 2.00 PROD1, DRILL BHAH T PJSM and LD BHA. Visually looks good. 2 jets plugged on bit. 208.0 43.0 4/6/2023 00:00 4/6/2023 00:30 0.50 PROD1, DRILL BHAH T Finish LD BHA. Bit had 2 jets plugged. 43.0 0.0 4/6/2023 00:30 4/6/2023 01:00 0.50 PROD1, DRILL CLEN T Clean and clear rig floor. 0.0 0.0 4/6/2023 01:00 4/6/2023 03:00 2.00 PROD1, DRILL SLPC T Slip/Cut drill line. 0.0 0.0 4/6/2023 03:00 4/6/2023 03:30 0.50 PROD1, DRILL BHAH T MU cementing BHA and RIH. 0.0 48.0 4/6/2023 03:30 4/6/2023 08:30 5.00 PROD1, DRILL TRIP T RIH w/ cementing BHA w/ 4" DP to 6110'. PU doubles f/ pipe shed. 48.0 6,110.0 4/6/2023 08:30 4/6/2023 14:00 5.50 PROD1, DRILL TRIP T RIH w/ cementing BHA w/ 4" DP out of derrick f/ 6110' to 14641'. 6,110.0 14,641.0 4/6/2023 14:00 4/6/2023 14:30 0.50 PROD1, DRILL SVRG T Rig service. 14,641.0 14,641.0 4/6/2023 14:30 4/6/2023 19:30 5.00 PROD1, DRILL TRIP T RIH w/ cementing BHA w/ 4" DP out of derrick f/ 14641' to 19500'. 14,641.0 19,500.0 4/6/2023 19:30 4/7/2023 00:00 4.50 PROD1, DRILL TRIP T POOH f/ 19500' to 16900'. Observed trying to swab @ 17650' Pumped out to 16900'. 2 BPM/340 PSI. 19,500.0 16,900.0 4/7/2023 00:00 4/7/2023 05:30 5.50 PROD1, DRILL PMPO T Pump out of hole f/ 16900' to 14645'. Observed 4-5k loss when bit came through shoe. 16,900.0 14,645.0 4/7/2023 05:30 4/7/2023 07:00 1.50 PROD1, DRILL RURD T BD top drive. RU cement swivel. Perform practice run of LD cement swivel. 14,645.0 14,645.0 4/7/2023 07:00 4/7/2023 07:30 0.50 PROD1, DRILL CIRC T Establish loss rates. Static - 20 BPH Circulate DS volume. Dynamic loss rate 150 BPH and decreased to 60 BPH over circulation. 14,645.0 14,645.0 4/7/2023 07:30 4/7/2023 09:30 2.00 PROD1, DRILL CIRC T Close annular and establish injection rates. 2 BPM- Anullar pressure slowly increased to 200psi. SD and monitor. Discuss plan forward with town. After discussion stage to 2 BPM and watch pressure slowly build to 332psi. SD and monior. Slowwly bled off to 0 psi (25 minutes). Decision made to RIH to bottom and circulate. 14,645.0 14,645.0 4/7/2023 09:30 4/7/2023 10:00 0.50 PROD1, DRILL RURD T BD cement line.. LD cement swivel 14,645.0 14,645.0 4/7/2023 10:00 4/7/2023 16:00 6.00 PROD1, DRILL CIRC T RIH f/ 14645' to 19500'. 14,645.0 19,500.0 4/7/2023 16:00 4/7/2023 17:00 1.00 PROD1, DRILL CIRC T Circulate and establish loss rates. Static- 12 BPH Dynamic Stage rate to 252 gpm- 132 BPH. 19,500.0 19,500.0 4/7/2023 17:00 4/7/2023 23:00 6.00 PROD1, DRILL TRIP T POOH f/ 19500' to 14645' 19,500.0 14,645.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 45/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/7/2023 23:00 4/8/2023 00:00 1.00 PROD1, DRILL OTHR T RU cement swivel. Perform practice run of LD cement swivel with new crew. 14,645.0 14,645.0 4/8/2023 00:00 4/8/2023 01:30 1.50 PROD1, DRILL CIRC T Establish loss rates: Static - 34 BPH Dynamic - 48 BPH at 195 GPM Close annular and Establish injection rates: 2 BPM- 182 PSI 3 BPM - 343 PSI 4 BPM - 470 PSI 14,645.0 14,645.0 4/8/2023 01:30 4/8/2023 04:00 2.50 PROD1, DRILL CMNT T PJSM. Flood lines and test to 4500 PSI. Mix and pump 37 BBLS of 12.0 PPG mud push. Mix and pump 133 BBLS of 14.0 PPG cement. Closed annular 75 BBLS into cement as spacer exited bit. Pump 10 BBLS of 12.0 PPG mud push behind cement. Drop Foam ball on the fly. Pump 10 BBLS FW to clear surface lines. Swap over to rig pumps. Stage pumps to 8 BPM to catch cement. Slow rate to 5 BPM after catching pressure. Bullhead cemeent into loss zones w/ 210 BBLS of 8.7 PPG mud. Calculated TOC at 16500'. Max bullhead 769 PSI. Final pressure 657 PSI. Cement in place @ 04:oo hrs 4/8/23 14,645.0 14,645.0 4/8/2023 04:00 4/8/2023 05:00 1.00 PROD1, DRILL RURD T Monitor pressure for 5 minutes. Bled off to 541 PSI. Bleed off pressure slowly through choke. Open annular. Still flowing back. Close annular and LD cement swivel. Built 90 PSI. 14,645.0 14,645.0 4/8/2023 05:00 4/8/2023 06:30 1.50 PROD1, DRILL CIRC T Insert foam ball into drill string. Circulate drill string volume through choke. 126 GPM 512 PSI 14,645.0 14,645.0 4/8/2023 06:30 4/8/2023 07:00 0.50 PROD1, DRILL CIRC T Shut in well and monitor for 30 minutes. 0 PSI. 14,645.0 14,645.0 4/8/2023 07:00 4/8/2023 14:00 7.00 PROD1, DRILL WOC T Open Annular. Well static. Monitor well while WOC. Work pipe 20' every 30 minutes. SimOPs: Service rig. Complete work orders. 14,645.0 14,645.0 4/8/2023 14:00 4/8/2023 15:30 1.50 PROD1, DRILL CIRC T Establish dynamic loss rate: 36 BPH 252 GPM 252 PSI Note: Static 10BPH 1BPM 36BPH 2BPM 36BPH 3BPM 30BPH 4BPM 27BPH 5BPM 30BPH 6BPM 36BPH 1,465.0 1,465.0 4/8/2023 15:30 4/8/2023 16:30 1.00 PROD1, DRILL TRIP T RIH f/ 14645' to 15200'. 14,645.0 14,645.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 46/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/8/2023 16:30 4/9/2023 00:00 7.50 PROD1, DRILL WASH T Wash down f/ 15200' to 17390' 2-4 BPM/ 440 - 700 PSI. 0-120 RPM 15326' - 20k down. PU and wash/ream through did not see it. 15507' - 20k down. PU and wash/ream through did not see it. 16625' - 20k down. PU and wash/ream through did not see it. 16812' - 20k down. PU and wash/ream through did not see it. Observed trace cement at shakers f/ 15200' calculated BU. Good cement f/ calculated BU @ 16600'. Loss rate - 4-5 BPH. 14,645.0 17,390.0 4/9/2023 00:00 4/9/2023 09:00 9.00 PROD1, DRILL WASH T Wash/ream f/ 17390' to 19481'. 169 GPM 800 PSI 120 RPM 20k TQ 17700' - Set down 20k. PU and wash/ream down with no issue. 17,390.0 19,481.0 4/9/2023 09:00 4/9/2023 13:00 4.00 PROD1, DRILL CIRC T Circulate and condition mud 165-250 GPM 770-1008 PSI 80 RPM 22k TQ. 17,390.0 19,481.0 4/9/2023 13:00 4/9/2023 14:00 1.00 PROD1, DRILL CIRC T Establish dynamic loss rates - 36 BPH 252 GPM 1020 PSI 17,390.0 19,481.0 4/9/2023 14:00 4/9/2023 15:00 1.00 PROD1, DRILL MPDA T Retrieve trip nipple and install MPD bearing assembly. SimOps: monitor well and establish static loss rates - Static. 19,481.0 19,481.0 4/9/2023 15:00 4/9/2023 18:00 3.00 PROD1, DRILL SMPD T SOOH f/ 19481' to 16920'. 19,481.0 16,920.0 4/9/2023 18:00 4/9/2023 19:00 1.00 PROD1, DRILL CIRC T Circulate and establish dynamic loss rates. 126 GPM - 12 BPH. 16,920.0 16,920.0 4/9/2023 19:00 4/9/2023 22:00 3.00 PROD1, DRILL CIRC T Circulate across top of hole and monitor losses while building LCM pill. 16,920.0 16,920.0 4/9/2023 22:00 4/9/2023 23:00 1.00 PROD1, DRILL CIRC T Pump 75 BBLS of 125 PPB conventional LCM pill. Displace w/ 186 BBLS 8.8 mud (10bbls over DS volume). 16,920.0 16,920.0 4/9/2023 23:00 4/10/2023 00:00 1.00 PROD1, DRILL CIRC T SOOH to 16539' monitoring hole fill. Adjust MPD back pressure as needed to keep hole f/ swabbing. 16,920.0 16,539.0 4/10/2023 00:00 4/10/2023 05:30 5.50 PROD1, DRILL SMPD T SOOH f/ 16539' to 12200'. 6 BPH loss rate. 16,920.0 12,200.0 4/10/2023 05:30 4/10/2023 07:00 1.50 PROD1, DRILL MPDA T Retrieve MPD bearing assembly. Instasll trip nipple. Static loss rate 6 BPH. Pump slug. Blow down top drive. 16,920.0 12,200.0 4/10/2023 07:00 4/10/2023 11:00 4.00 PROD1, DRILL TRIP T POOH f/ 12200' to 6203'. Racking back pipe in derrick. 16,920.0 6,203.0 4/10/2023 11:00 4/10/2023 13:00 2.00 PROD1, DRILL PULD T POOH f/6203' to 3459' LD doubles to pipe shed. 6,203.0 3,459.0 4/10/2023 13:00 4/10/2023 17:00 4.00 PROD1, DRILL PULD T POOH f/ 3259' to BHA LD singles to pipe shed. 6,203.0 45.0 4/10/2023 17:00 4/10/2023 17:30 0.50 PROD1, DRILL PULD T LD BHA. 45.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 47/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/10/2023 17:30 4/10/2023 19:00 1.50 PROD1, DRILL CIRC T Retrieve wear bushing. MU jetting tool and clean wellhead and BOP. 0.0 0.0 4/10/2023 19:00 4/10/2023 20:00 1.00 PROD1, DRILL BOPE T RU test equipment. Flood lines and purge air out of system. 0.0 0.0 4/10/2023 20:00 4/11/2023 00:00 4.00 PROD1, DRILL BOPE T BOPE Test: All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5” Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR, W/ 4" Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR,Test choke valves 1-15. Manual operated and super choke. Choke manuals and HCR valves. 4" kill line valve. Test 2x 4" FO safety valves. 4" dart valve. 2x 5" FO safety valves. 5" dart valve. Test upper and lower IBOP. Blind ram. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1400 psi, ACC = 1675 psi after all functions on bottles,16 sec for 200 psi. Build w/ 2 electric pumps, 104 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 17 sec. UPR = 14 sec, Blind ram = 14 sec, LPR = 15 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms AOGCC waived witness per Brian Bixby email 4/10/23 16:43 hrs BLM waived witness per Quinn Sawyer email 4/5/23 14:43 hrs 0.0 0.0 4/11/2023 00:00 4/11/2023 03:00 3.00 PROD1, DRILL BOPE T BOPE Test: All tests to 250psi/5min 3500psi/10min Annular 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5” Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR, W/ 4" Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR,Test choke valves 1-15. Manual operated and super choke. Choke manuals and HCR valves. 4" kill line valve. Test 2x 4" FO safety valves. 4" dart valve. 2x 5" FO safety valves. 5" dart valve. Test upper and lower IBOP. Blind ram. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1400 psi, ACC = 1700 psi after all functions on bottles,18 sec for 200 psi. Build w/ 2 electric pumps, 94 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 17 sec. UPR = 14 sec, Blind ram = 14 sec, LPR = 15 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms AOGCC waived witness per Brian Bixby email 4/10/23 16:43 hrs BLM waived witness per Quinn Sawyer email 4/5/23 14:43 hrs 0.0 0.0 4/11/2023 03:00 4/11/2023 04:00 1.00 PROD1, DRILL BOPE T RD test equipment. Line up for drilling. Retrieve test plug. Install wear bushing. 0.0 0.0 4/11/2023 04:00 4/11/2023 05:00 1.00 PROD1, DRILL SVRG T Service rig. Stage BHA to rig floor. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 48/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/11/2023 05:00 4/11/2023 07:30 2.50 PROD1, DRILL BHAH T MU and RIH w/ BHA #8 to 208'. 0.0 208.0 4/11/2023 07:30 4/11/2023 10:00 2.50 PROD1, DRILL TRIP T RIH w/ BHA #8 with doubles f/ pipe shed to 2853'. 208.0 2,853.0 4/11/2023 10:00 4/11/2023 12:30 2.50 PROD1, DRILL CIRC T Shallow test smart tools. Ok. 194 GPM 530 PSI 208.0 2,853.0 4/11/2023 12:30 4/11/2023 18:00 5.50 PROD1, DRILL TRIP T RIH f/ 2853' to 14610'. Slow running speed at TOL. 2,853.0 14,610.0 4/11/2023 18:00 4/11/2023 19:30 1.50 PROD1, DRILL SLPC T Slip/Cut drill line at shoe. 2,853.0 14,610.0 4/11/2023 19:30 4/12/2023 00:00 4.50 PROD1, DRILL TRIP T RIH f/ 14610'' to 16226' (169 stds 4" DP). Swap over to 5" DP. RIH f/ 16226' to 16836'. 14,610.0 16,836.0 4/12/2023 00:00 4/12/2023 09:00 9.00 PROD1, DRILL WASH T Set down 20k @ 16700' PU and wash/ream through spot and did not observe anything. Continue washing in hole to condition mud to 19340' 160-170 GPM 14,610.0 19,340.0 4/12/2023 09:00 4/12/2023 09:30 0.50 PROD1, DRILL MPDA T Retrieve trip nipple. Install MPD bearing assembly. 19,340.0 19,340.0 4/12/2023 09:30 4/12/2023 10:30 1.00 PROD1, DRILL REAM T Wash/ream to 19500'. 190 GPM 1098 PSi 80 RPM 22k TQ 170k ROT 19,340.0 19,340.0 4/12/2023 10:30 4/12/2023 18:00 7.50 PROD1, DRILL DDRL P Drill 19500' MD to 19810' MD / 8287' TVD. Varying parameters to reduce vibrations and TQ. 5-15k WOB 200 GPM 1160 PSI on bttm 1150 PSI off bttm 80-90 RPM 25-27k TQ on bttm 25k TQ off bttm 9.3ppg ECD 260k PU 117k SO 170k ROT 4.6 Bit hrs 19,340.0 19,810.0 4/12/2023 18:00 4/13/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 19810' MD to 20290' MD / 8285' TVD. 9k WOB 200 GPM 1210 PSI on bttm 110 RPM 19k TQ on bttm 18k TQ off bttm 9.4ppg ECD 250k PU 115k SO 170k ROT 9 Bit hrs 19,810.0 20,290.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 49/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/13/2023 00:00 4/13/2023 04:30 4.50 PROD1, DRILL DDRL P Drill 20290' MD to 20659' MD / 8268' TVD. 10k WOB 200 GPM 1210 PSI on bttm 100 RPM 19k TQ on bttm 14k TQ off bttm 9.4ppg ECD 223k PU 130k SO 167k ROT 12.4 Bit hrs 20,290.0 20,659.0 4/13/2023 04:30 4/13/2023 05:30 1.00 PROD1, DRILL MPDA T Flow Check. Change out MPD bearing assembly. 20,659.0 20,659.0 4/13/2023 05:30 4/13/2023 12:00 6.50 PROD1, DRILL DDRL P Drill 20659' MD to 21178' MD / 8254' TVD. 10k WOB 200 GPM 1275 PSI on bttm 100 RPM 19k TQ on bttm 14k TQ off bttm 9.5ppg ECD 217k PU 136k SO 176k ROT 12.4 Bit hrs 20,659.0 21,178.0 4/13/2023 12:00 4/13/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 21178' MD to 21674' MD / 8246' TVD. 10k WOB 200 GPM 1315 PSI on bttm 90 RPM 14k TQ on bttm 12k TQ off bttm 9.6ppg ECD 230k PU 98 k SO 173k ROT 21 Bit hrs 21,178.0 21,674.0 4/13/2023 18:00 4/14/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 21674' MD to 22257' MD / 8241' TVD. 8k WOB 200 GPM 1370 PSI on bttm 90 RPM 17k TQ on bttm 12k TQ off bttm 9.6ppg ECD 230k PU k SO 173k ROT 25.6 Bit hrs 21,674.0 22,257.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 50/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/14/2023 00:00 4/14/2023 08:30 8.50 PROD1, DRILL DDRL P Drill 22,257' MD to 23104' MD / 8235' TVD. 11k WOB 200 GPM 1415 PSI on bttm 120 RPM 17k TQ on bttm 10k TQ off bttm 9.7ppg ECD 234k PU 110k SO 174k ROT 31.9 Bit hrs 22,257.0 23,104.0 4/14/2023 08:30 4/14/2023 13:30 5.00 PROD1, TRIPCAS CIRC P Take final survey. Downlink tools. Circulate and reciprocate cleaning hole. 200 GPM 1392 PSI 80-110 RPM 173k ROT 23,104.0 23,104.0 4/14/2023 13:30 4/14/2023 14:00 0.50 PROD1, TRIPCAS OWFF P Fingerprint well. Start: 10psi 3min- 22psi Open choke 3 min- 10psi Close choke 3 min- 9psi Open choke 3 min- 7psi Close choke 3 min - 4 psi Open choke 3 min - 2psi Close choke 3min 1psi Open choke Flow check- No flow 28.5 bbls to fill- 53 BPH loss rae 23,104.0 23,104.0 4/14/2023 14:00 4/14/2023 18:00 4.00 PROD1, TRIPCAS CIRC P Circulate and pump 2- 50 BBL of 35 PPB LCM pills. Did not observe any gas at BU from fingerprinting well. 23,104.0 23,104.0 4/14/2023 18:00 4/15/2023 00:00 6.00 PROD1, TRIPCAS CIRC P Circulate and condition hole. Racking back 1 std after each BU. 3 BU 23,104.0 23,012.0 4/15/2023 00:00 4/15/2023 04:30 4.50 PROD1, TRIPCAS CIRC P Circulate and condition hole. Racking back 1 std after each BU. 23,104.0 22,731.0 4/15/2023 04:30 4/15/2023 05:30 1.00 PROD1, TRIPCAS WASH P Wash bcak to TD at 23104'. Continue circulating while taking on brine and lining up for displacement. 22,731.0 23,104.0 4/15/2023 05:30 4/15/2023 10:30 5.00 PROD1, TRIPCAS DISP P Pump spacer and displace hole to 8.9ppg Vis Brine. Lost 165 BBLS during displacement. 22 BBLS interface. 200 GPM 1330 PSI 80 RPM 18k TQ 9.2ppg ECD 23,104.0 23,104.0 4/15/2023 10:30 4/15/2023 11:00 0.50 PROD1, TRIPCAS OWFF P Establish staic loss rate. 70 BPH. Blow down top drive. 23,104.0 23,104.0 4/15/2023 11:00 4/15/2023 19:00 8.00 PROD1, TRIPCAS SMPD P SOOH f/ 23104' to 16226' racking back 5" DP. Worked back through spot observed on TIH @ 16800'. Did not observe any drag. 23,104.0 16,226.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 51/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/15/2023 19:00 4/15/2023 20:00 1.00 PROD1, TRIPCAS MPDA P Flow check. Still on losses. Retrieve 5" MPD bearing assembly. Install 4" bearing assembly. 16,226.0 16,226.0 4/15/2023 20:00 4/15/2023 21:30 1.50 PROD1, TRIPCAS SMPD P SOOH f/ 16226' to 14703'. Note: Dropped well commander ball 5 stds f/ shoe. 16,226.0 14,703.0 4/15/2023 21:30 4/15/2023 22:30 1.00 PROD1, TRIPCAS CIRC P Open well commander. Shifted at 1400 PSI. Circulate 2 x liner volume 200 GPM 380 PSI 14,703.0 14,703.0 4/15/2023 22:30 4/15/2023 23:30 1.00 PROD1, TRIPCAS SMPD P SOOH f/ 14703' to 13855' racking back 4" DP. 14,703.0 13,855.0 4/15/2023 23:30 4/16/2023 00:00 0.50 PROD1, TRIPCAS PULD P SOOH LD 4" DP f/ 13855' to 13611'. 13,855.0 13,611.0 4/16/2023 00:00 4/16/2023 02:30 2.50 PROD1, TRIPCAS PULD P SOOH LD 4" DP f/ 13611' to 12368' bit depth. Well commander depth 12260'. 13,855.0 12,368.0 4/16/2023 02:30 4/16/2023 05:30 3.00 PROD1, TRIPCAS CIRC P Circulate 3 x BU. Stage rate to 600 GPM / 1640 PSI with no changes in loss rates. 60 BPH loss rate. Observed Increase in LCM over shakers halfway through 1st BU. Cleaned up after 3rd BU. 40 RPM 5k TQ 600 GPM 1640 PSI 12,368.0 12,368.0 4/16/2023 05:30 4/16/2023 06:30 1.00 PROD1, TRIPCAS MPDA P Retrieve MPD bearing assembly. Install trip nipple. 12,368.0 12,368.0 4/16/2023 06:30 4/16/2023 09:00 2.50 PROD1, TRIPCAS TRIP P POOH f/ 12368' to 11036' LD singles 4" DP. Note: dropped WC closing ball and let fall while POOH. 12,368.0 11,036.0 4/16/2023 09:00 4/16/2023 09:30 0.50 PROD1, TRIPCAS CIRC P Pressure up and close well commander. Shifted close @ 1480 PSI. 11,036.0 11,036.0 4/16/2023 09:30 4/16/2023 21:00 11.50 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 11036' to BHA. 11,036.0 207.0 4/16/2023 21:00 4/17/2023 00:00 3.00 PROD1, TRIPCAS BHAH P Flow check. PJSM f/ LD BHA. LD BHA. 207.0 0.0 4/17/2023 00:00 4/17/2023 01:30 1.50 COMPZN, CASING BHAH P Change pipe handling equpiment, Jet stack. Blow down top drive. L/D directional tools Per Baker DD. Clean and clear rig floor. 0.0 0.0 4/17/2023 01:30 4/17/2023 02:00 0.50 COMPZN, CASING PUTB P Rig up pipe handling equipment to run lower completion. 0.0 0.0 4/17/2023 02:00 4/17/2023 06:00 4.00 COMPZN, CASING PUTB P Run in the hole picking up 4 1/2" 12.6# Hydril 563 lower completion from the pipe shed from surface to 2,363'. Floating liner. Monitoring displacement on the trip tank. PUWT: 67K SOWT: 55K 0.0 2,363.0 4/17/2023 06:00 4/17/2023 12:00 6.00 COMPZN, CASING PUTB P Continue running in the hole with 4 1/2" 12.6# Hydril 563 liner from 2,363' to 7,445'. Floating liner. Monitor displacement on the trip tank. SOWT: 71K 2,363.0 7,445.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 52/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/17/2023 12:00 4/17/2023 14:00 2.00 COMPZN, CASING PUTB P Continue running in the hole with 4 1/2" 12.6# HYD 563 liner from 7,445' to 8,541'. Floating liner. Monitor displacement on the tirp tank. SOWT: 74K 7,445.0 8,541.0 4/17/2023 14:00 4/17/2023 14:30 0.50 COMPZN, CASING PUTB P Pick up BHI liner hanger. inspect liner hanger. Pull cap and insall Xanplex D. Change out handling equipment. 8,541.0 8,541.0 4/17/2023 14:30 4/17/2023 17:00 2.50 COMPZN, CASING RUNL P Run in the hole with liner on 4" drill pipe from 8,541' to 10,912'. Obtain parameters after making up first stand of drill pipe. PUWT: 75 K SOWT: 76 K ROTWT: 77 K TQ: 2.2 K @ 10 / 20 RPM 8,541.0 10,912.0 4/17/2023 17:00 4/17/2023 18:00 1.00 COMPZN, CASING MPDA P OWFF, B/D jet pump line. Remove trip nipple, and install 5" RCD bearing as per Beyond rep. Line up #1 MP on the annulus, Static loss rate: 32 BBL/ hr. 10,912.0 10,912.0 4/17/2023 18:00 4/18/2023 00:00 6.00 COMPZN, CASING RUNL P Continue to run in the hole with liner on 5" drill pipe from 10,912' to 16,091'. Obtain parameters @ 14,682' prior to exiting the shoe. PUWT: 154 K @ 30 ft/min. SOWT: 127 K @ 30 ft/min. ROTWT @ 10 RPM: 143K @ 5K TQ ROTWT @ 20 RPM: 141k @ 5K TQ 10,912.0 16,091.0 4/18/2023 00:00 4/18/2023 02:00 2.00 COMPZN, CASING RUNL P RIH from 16,091' to 17,802' with 4.5" 12.5 # 563 Hydrill liner on drill pipe. Floating liner. SOWT: 138K 16,091.0 17,802.0 4/18/2023 02:00 4/18/2023 02:45 0.75 COMPZN, CASING RUNL T High line supply to the rig cut out. Difficulty getting switched over rig gens due to fluctuations in high line power supplied to the rig. Rig crew continued to trouble shoot and was able to get rig back on high line power after supply fluctuations stopped. 17,802.0 17,802.0 4/18/2023 02:45 4/18/2023 06:00 3.25 COMPZN, CASING RUNL P Continue to RIH F/ 17,802' to 20,778' with 4.5" 12.6# HYydril 563 liner on drill pipe. Floating liner. SOWT: 150K 17,802.0 20,778.0 4/18/2023 06:00 4/18/2023 09:00 3.00 COMPZN, CASING RUNL P Continue to RIH F/ 20,778' to 23,064' with 4.5" 12.6# Hydrill 563 liner on drill pipe. Floating liner. SOWT: 155k 20,778.0 23,064.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 53/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/18/2023 09:00 4/18/2023 10:30 1.50 COMPZN, CASING PACK P Obtain Parameters. RIH and tag bottom @ 23,108'. Set down 15 K to confirm tag. Pick up and space out shoe @ 23,095' SOWT: 155 K PUWT: 224 K Pressure up on liner 8 times attempting to rupture floatation sub glass disk. Attempt 1: 1600 PSI hold 5 min Attempt 2: 1600 PSI hold 10 min Attempt 3: 1660 PSI hold 5 min Attempt 4: 1700 PSI, hold 5 min Attempt 5: 1850 PSI, hold 5 min. Attempt 6: 1887 PSI, Hold 5 min. Attempt 7: 1881 PSI. hold 5 min. Attempt 8: 1964 PSI liner hanger shear observed. Glass disk ruptured. 23,064.0 23,095.0 4/18/2023 10:30 4/18/2023 14:30 4.00 COMPZN, CASING CIRC P Fill liner @ 336 GPM, once pressure observed slow down flow rate to 120 GPM. 120 BBLs to fill liner, 36 BBLs to fill annulus. Circulate out air through MPD choke @ 208 GPM, 780 PSI. 23,095.0 23,095.0 4/18/2023 14:30 4/18/2023 16:30 2.00 COMPZN, CASING PACK P Drop 1.125" Ball. Pump ball down @ 210 GPM, @ 654 PSI. Ball landed on seat @ 4000 STKS. Pressure up to 1300 PSI. Slack off to 80 K. Increase pressure to 2300 PSI and then to 3600 PSI P/U to 216 K HKLD to verify hanger set. Slack off to 124 K, and rotate @ 10 RPM @ 8.5 K TQ. S/O to 113 K HKLD continuing to rotate, observe shear. Continue to rotate for 2 min after shear. P/U 10' to pull pack off out of Liner hanger seal bore and space out for liner top packer test. TOL: 14,561 NOTE: when pressuring up to 3600 PSI held pressure over 5 min to ensure open hole packers were set. 23,095.0 14,550.0 4/18/2023 16:30 4/18/2023 17:00 0.50 COMPZN, CASING PRTS P Line up and purge lines. Close upper pipe rams, and line up to test 4 1/2" liner top packer to 3500 PSI for 5 min: Good test. Bleed off pressure (9 BBL'S pumped, 9 BBL'S bled back). Open upper pipe rams, blow down kill line. 14,550.0 14,550.0 4/18/2023 17:00 4/18/2023 20:00 3.00 COMPZN, CASING CIRC P Displace well to 8.9 PPG corrosion inhibited brine. ( from 15,550'). Pumping 420 GPM @ 1025 PSI. 14,550.0 14,550.0 4/18/2023 20:00 4/18/2023 20:30 0.50 COMPZN, CASING OWFF P Line up on the trip tank, and flow check the well for 30 min: Static. 14,550.0 14,550.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 54/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/18/2023 20:30 4/18/2023 21:30 1.00 COMPZN, CASING PULD P POOH L/D singles of 5" drill pipe from 15,550' to 14,078'. PUWT: 227 K. 14,550.0 14,078.0 4/18/2023 21:30 4/18/2023 22:00 0.50 COMPZN, CASING MPDA P Flow check 10 min. Conduct PJSM while flow checking. Remove RCD bearing, and install trip nipple. 14,078.0 14,078.0 4/18/2023 22:00 4/19/2023 00:00 2.00 COMPZN, CASING PULD P POOH L/D singles of 5" DP f/ 14078' to 12346'. 14,078.0 40.0 4/19/2023 00:00 4/19/2023 15:00 15.00 COMPZN, CASING PULD P POOH L/D singles of 5" DP and 4" DP f/ 12346' to running tool. 14,078.0 40.0 4/19/2023 15:00 4/19/2023 16:00 1.00 COMPZN, CASING PULD P LD and inspect running tool. Tool in good condition, no visible damage. 40.0 0.0 4/19/2023 16:00 4/19/2023 16:30 0.50 COMPZN, WELLPR WWWH P M/U two joints of 5" drill pipe, and wear bushing tool. Retrieve wear bushing from well head. 0.0 0.0 4/19/2023 16:30 4/19/2023 17:30 1.00 COMPZN, WELLPR WWWH P M/U Stack washer to drill pipe. Wash BOP stack, and well head. B/O stack washer, and L/D DP. **L/D drill pipe handling equipment, bring master bushings to the rig floor while washing stack / well head. 0.0 0.0 4/19/2023 17:30 4/19/2023 19:00 1.50 COMPZN, RPCOMP RURD P R/U to run upper completion. Bring up and R/U HES TEC wire spooler and Doyon Casing equipment. 0.0 0.0 4/19/2023 19:00 4/20/2023 00:00 5.00 COMPZN, RPCOMP PUTB P RIH W/ 4 1/2" 12.6# L80 upper completion from surface to 2,534'. Putting clamps on every joint for TEC wire after Gauge mandrel picked up and Opsis gauge installed. **HAL test TEC wire/ gauge conncection to 10,000 PSI for 10 MIN after installing on gauge mandrel: GOOD. 0.0 2,534.0 4/20/2023 00:00 4/20/2023 14:30 14.50 COMPZN, RPCOMP PUTB P RIH w/ 4.5" 12.6# L80 upper completion from 2,534' to 14,568'. Test TEC wire every 1000'. Install TEC wire clamps on every joint. PUWT: 160 K SOWT: 115 K 2,534.0 14,568.0 4/20/2023 14:30 4/20/2023 15:00 0.50 COMPZN, RPCOMP PUTB P Tag NO GO @ 14,570'. Observe shear on NO GO @ 13 K down. P/U and L/D 3 Jts of tubing. 14,568.0 14,570.0 4/20/2023 15:00 4/20/2023 17:00 2.00 COMPZN, RPCOMP THGR P P/U and M/U 9.71', 5.81', and 1.77' Pups, and one full joint of tubing. P/U and Make up hanger per FMC rep. HES strip TEC wire, and feed though hanger penetrations. Test, ports, and TEC wire. M/U Landing joint to hanger, and land, RILDS. 14,570.0 14,564.4 4/20/2023 17:00 4/20/2023 18:30 1.50 COMPZN, RPCOMP PRTS P Flood BOP stack, close annular, and line up to test hanger neck seals from above. Test to 3,000 PSI: GOOD TEST. R/D testing equipment. 14,570.0 14,570.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 55/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/20/2023 18:30 4/20/2023 21:00 2.50 COMPZN, RPCOMP PRTS P Install 1502 head pin on landing joint. R/U lines. Line up on tubing. Test DFCV 500 PSI 5 min: GOOD TEST Set Packer and test tubing 4200 PSI 30 min: GOOD TEST. (No shear observed when packer set) Bleed Tubing to 3000 PSI, and Hold. Line up on IA. test Packer 3500 PSI 30 MIN: GOOD TEST. leave pressure on IA after test. Line up on tubing and bleed tubing. Observe shear @ 1540 PSI, Tubing and IA equalize. Bleed both to 0 PSI. 14,570.0 14,570.0 4/20/2023 21:00 4/20/2023 21:30 0.50 COMPZN, RPCOMP OWFF P OWFF 30 min: Static Offline: Break down lines from testing, Build T-Bar for BPV. 14,570.0 14,570.0 4/20/2023 21:30 4/20/2023 23:00 1.50 COMPZN, RPCOMP RURD P PJSM. L/D landing jt. Suck out stack. Blow down choke and kill lines. 14,570.0 14,570.0 4/20/2023 23:00 4/21/2023 00:00 1.00 COMPZN, RPCOMP MPSP P Install BPV in hanger neck using T-bar per FMC rep. Line up on the IA and test BPV from below 3000 PSI for 10 min: GOOD TEST. 14,570.0 14,570.0 4/21/2023 00:00 4/21/2023 04:00 4.00 COMPZN, WHDBOP NUND P PJSM. Pull master bushings. Clean joes box. Pull trip nipple. ND BOP and risers. Stage tree. Clean and prep wellhead. SimOps: Cleaning pits. 0.0 0.0 4/21/2023 04:00 4/21/2023 05:00 1.00 COMPZN, WHDBOP NUND P FMC/ HES terminate TEC wire through well head. 0.0 0.0 4/21/2023 05:00 4/21/2023 06:30 1.50 COMPZN, WHDBOP NUND P Set adaptor flange, and tree on top of tubing spool. N/U adapter flange, per FMC rep. FMC rep test hanger neck seals and hanger neck/adaptor flange void to 5000 PSI for 5 min: GOOD TEST. 0.0 0.0 4/21/2023 06:30 4/21/2023 10:00 3.50 COMPZN, WHDBOP NUND P HES test, and terminate TEC wire: GOOD. Torque tree to adaptor flange. Fill with diesel, and test to 250 PSI low/ 5 min, and 5000 PSI high for 5 min: GOOD TEST. 0.0 0.0 4/21/2023 10:00 4/21/2023 12:00 2.00 COMPZN, WHDBOP MPSP P Rig up lubricator, and pull BPV. Rig up lines to freeze protect well. 0.0 0.0 4/21/2023 12:00 4/21/2023 13:00 1.00 COMPZN, WHDBOP CIRC P LRS pump 82 bbls of diesel into annulus. taking returns out of the tubing. Pumping 1.5- 2 BBL/min @ 1100 PSI. 0.0 0.0 4/21/2023 13:00 4/21/2023 14:00 1.00 COMPZN, WHDBOP CIRC P Line up tubing to annulus, and allow well to U-Tube for 1 hour. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 56/56 MT7-11 Report Printed: 5/2/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/21/2023 14:00 4/21/2023 16:00 2.00 COMPZN, WHDBOP RURD P R/D hoses, and hard line from Tree/ annulus. P/U lubricator, and install BPV. Install gauge flanges on annulus. Install tubing cap. Rig Released at 16:00 Hrs. Final Pressures OA/IA/TBG = 0 psi. Sim Ops: Prepare to scope mast. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/21/2023 Page 1/1 MT7-11 Report Printed: 5/2/2023 Cement Cement Details Description Surface String Cement Cementing Start Date 3/8/2023 03:30 Cementing End Date 3/8/2023 07:27 Wellbore Name MT7-11 Comment Blow down top drive, test lines to 4500psi (all ok) Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4.0 bbls/min, 352 psi, Dropped bottom plug. Start batching lead. Pump 423 bbls of 11.0 ppg DeepCRETE cement at 5.5 bbls/min, 435 psi ICP. Batch and pump 73 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 280 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 280 psi ICP, 610 psi FCP. Slow pumps 20 bbls prior to calculated bump to 3 bbls/min, 370 psi ICP, 388 psi FCP, Bump plug with 925 psi (527 bbls + 20 bbls). 4454 strokes, final circ. PSI 388 Pressure up to 925 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 60 bbls cement to surface. Cement in place @ 07:27hrs 3/8/23 full returns. Check floats (all good) Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 39.7 Bottom Depth (ftKB) 3,747.1 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 6 P Pump Final (psi) 388.0 P Plug Bump (psi) 925.0 Recip? Yes Stroke (ft) 15.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Blow down top drive, test lines to 4500psi (all ok) Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4.0 bbls/min, 352 psi, Dropped bottom plug. Start batching lead. Pump 423 bbls of 11.0 ppg DeepCRETE cement at 5.5 bbls/min, 435 psi ICP. Batch and pump 73 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 280 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 280 psi ICP, 610 psi FCP. Slow pumps 20 bbls prior to calculated bump to 3 bbls/min, 370 psi ICP, 388 psi FCP, Bump plug with 925 psi (527 bbls + 20 bbls). 4454 strokes, final circ. PSI 388 Pressure up to 925 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 60 bbls cement to surface. Cement in place @ 07:27hrs 3/8/23 full returns. Check floats (all good) Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 39.7 Est Btm (ftKB) 3,247.0 Amount (sacks) 1,230 Class Blend Volume Pumped (bbl) 432.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 6.69 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 143.0 Thickening Time (hr) 6.30 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 3,247.0 Est Btm (ftKB) 3,747.1 Amount (sacks) 334 Class G Volume Pumped (bbl) 73.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 5.00 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 80.0 Thickening Time (hr) 4.20 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 MT7-11 Report Printed: 5/2/2023 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 3/16/2023 20:30 Cementing End Date 3/17/2023 01:28 Wellbore Name MT7-11 Comment Blow down top drive, test lines to 3500psi (all ok) Mix and pump 60 bbls of 12.5 ppg Mud Push II @ 4.0 bbls/min, 408 psi, Dropped bottom plug. Start batching lead. Pump 191 bbls of 13.0 ppg Extended class G cement at 5.2 bbls/min, 490 psi ICP. Batch and pump 152 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 220 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 6 bbls/min, 280 psi ICP, 982 psi FCP. Slow pumps 26 bbls prior to calculated bump to 3 bbls/min, 861 psi ICP, 887 psi FCP, Bump plug with 1400 psi (905 bbls + 20 bbls). 7657 strokes, final circ. PSI 887 Pressure up to 1400 psi & hold for 5 minutes. Bleed off pressure, Check floats good. Full returns. Cement in place @ 01:28hrs 3/17/23 full. Check floats (all good) Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 7,794.0 Bottom Depth (ftKB) 12,424.0 Full Return? Yes Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 887.0 P Plug Bump (psi) 1,400.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 12,321.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) 12,424.0 Drill Out Diameter (in) 8 1/2 Comment Blow down top drive, test lines to 3500psi (all ok) Mix and pump 60 bbls of 12.5 ppg Mud Push II @ 4.0 bbls/min, 408 psi, Dropped bottom plug. Start batching lead. Pump 191 bbls of 13.0 ppg Extended class G cement at 5.2 bbls/min, 490 psi ICP. Batch and pump 152 bbls of G Blend Tail 15.8 ppg cement @ 4.5 bbls/min, 220 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 6 bbls/min, 280 psi ICP, 982 psi FCP. Slow pumps 26 bbls prior to calculated bump to 3 bbls/min, 861 psi ICP, 887 psi FCP, Bump plug with 1400 psi (905 bbls + 20 bbls). 7657 strokes, final circ. PSI 887 Pressure up to 1400 psi & hold for 5 minutes. Bleed off pressure, Check floats good. Full returns. Cement in place @ 01:28hrs 3/17/23 full. Check floats (all good) Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 7,794.0 Est Btm (ftKB) 10,423.0 Amount (sacks) 566 Class G Volume Pumped (bbl) 191.0 Yield (ft³/sack) 1.89 Mix H20 Ratio (gal/sack) 10.33 Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 10,423.0 Est Btm (ftKB) 12,424.0 Amount (sacks) 735 Class G Volume Pumped (bbl) 152.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 5.05 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 1 Cement Page 1/1 MT7-11 Report Printed: 5/2/2023 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 3/22/2023 17:53 Cementing End Date 3/22/2023 22:55 Wellbore Name MT7-11 Comment Pressure test line to 4600psi. Pump70bbls KCL w/ rig. Drop bottom dart. Swap to cementers.Mix and pump 82bbls 15.8ppg cement @ 2BPM. Sd and drop top dart.Pump 10bbl FW w/ cementers. Swap over to rig pumps and displace cement w/ 285.3bls 11.5ppg NAF. 3372stks pumped. FCP 670 PSI. Pressure up to 1230 PSI and hold f/ 5 min. Bleed off and check floats. Good. Cement in place. @ 22:88hrs 3-22-23 Note: Bottom dart lands and shears bottom plug at 1345stks 1720psi while pumping at 2bpm 200psi. Surge of plug released, lost returns form well, (fluid still at flow line) ,Work string PU:275k SO: 97k without returns, work pipe free with 342k and regained returns (-17bbls lost and regained volume after establishing circulation) Staged up pumps to 2bpm 410psi. Top dart lands 2330stks and shears at 1730psi, Bottom plug land and shear at 480psi, Drop rate to 1bpm 290psi (full returns) Increase rate to 1.5bpm for 3min and packed off, P/U string and broke free and regained circulation with 290k, set string back on depth pumping at 1bpm, bump plug at 3372stks 3.7bbls early. 0bbls lost after cement turned the shoe. TOL @ 12,253'. FS @ 14,707'. Cement Stages Stage # 1 Description Intermediate String 2 Cement Objective Top Depth (ftKB) 13,776.0 Bottom Depth (ftKB) 14,707.0 Full Return? Yes Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 1 Q Pump Avg (bbl/… 2 P Pump Final (psi) 670.0 P Plug Bump (psi) 1,230.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 14,610.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 6 1/8 Comment Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 13,776.0 Est Btm (ftKB) 14,707.0 Amount (sacks) 299 Class G Volume Pumped (bbl) 82.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 4.71 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 2 Cement ConocoPhillips Definitive Survey Report 27 April, 2023 NADConversion Western North Slope GMT2 Rendezvous Pad MT7-11 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Western North Slope, North Slope Alaska, United States Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MT7-11 usft usft 0.00 0.00 5,915,745.06 289,847.70 100.70Wellhead Elevation:0.00 usft0.00 70° 10' 23.008 N 151° 41' 30.225 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MT7-11 Model NameMagnetics BGGM2022 3/1/2023 14.17 80.35 57,101.81 Phase:Version: Audit Notes: Design MT7-11 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:39.50 333.000.000.0039.50 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 4/25/2023 Survey Date SDI_Keeper_ADK SDI Keeper All-Attitude Drop Keeper V 1.1133.56 887.37 Survey #1 (MT7-11)3/6/2023 12:16 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Co912.20 3,684.98 Survey #2 (MT7-11)3/6/2023 12:18 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Co3,779.64 12,393.86 Survey #3 (MT7-11)3/6/2023 12:18 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Co12,475.66 14,688.35 Survey #4 (MT7-11)3/6/2023 12:18 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Co14,707.00 23,104.00 Survey #5 (MT7-11)3/6/2023 12:18 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 39.50 0.00 0.00 39.50 0.00 0.00-100.70 5,915,745.06 289,847.70 0.00 0.00 UNDEFINED 133.56 0.18 351.91 133.56 0.15 -0.02-6.64 5,915,745.21 289,847.68 0.19 0.14 SDI_Keeper_ADK (1) 235.75 0.35 1.41 235.75 0.62 -0.0495.55 5,915,745.68 289,847.68 0.17 0.57 SDI_Keeper_ADK (1) 326.34 0.53 0.35 326.34 1.31 -0.03186.14 5,915,746.37 289,847.71 0.20 1.18 SDI_Keeper_ADK (1) 414.99 0.53 356.48 414.98 2.13 -0.05274.78 5,915,747.19 289,847.71 0.04 1.92 SDI_Keeper_ADK (1) 510.85 0.18 239.06 510.84 2.50 -0.21370.64 5,915,747.56 289,847.56 0.66 2.32 SDI_Keeper_ADK (1) 605.24 1.76 189.84 605.21 0.99 -0.58465.01 5,915,746.07 289,847.15 1.75 1.15 SDI_Keeper_ADK (1) 700.01 3.96 184.22 699.86 -3.71 -1.07559.66 5,915,741.39 289,846.53 2.34 -2.82 SDI_Keeper_ADK (1) 793.40 6.79 185.98 792.83 -12.41 -1.88652.63 5,915,732.71 289,845.47 3.04 -10.21 SDI_Keeper_ADK (1) 887.37 8.09 187.38 886.01 -24.50 -3.31745.81 5,915,720.67 289,843.71 1.40 -20.32 SDI_Keeper_ADK (1) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 912.20 8.17 188.15 910.59 -27.98 -3.79770.39 5,915,717.20 289,843.14 0.54 -23.21 MWD+IFR2+SAG+MS (2) 1,006.04 7.47 197.43 1,003.56 -40.40 -6.56863.36 5,915,704.86 289,840.02 1.54 -33.02 MWD+IFR2+SAG+MS (2) 1,101.28 8.20 214.04 1,097.92 -51.93 -12.21957.72 5,915,693.49 289,834.05 2.49 -40.73 MWD+IFR2+SAG+MS (2) 1,194.78 9.89 220.49 1,190.26 -63.57 -21.161,050.06 5,915,682.11 289,824.78 2.11 -47.03 MWD+IFR2+SAG+MS (2) 1,290.03 11.76 220.56 1,283.81 -77.16 -32.791,143.61 5,915,668.84 289,812.78 1.96 -53.87 MWD+IFR2+SAG+MS (2) 1,383.85 13.83 215.05 1,375.30 -93.61 -45.441,235.10 5,915,652.76 289,799.67 2.56 -62.77 MWD+IFR2+SAG+MS (2) 1,478.43 16.24 213.45 1,466.63 -113.90 -59.231,326.43 5,915,632.86 289,785.33 2.59 -74.60 MWD+IFR2+SAG+MS (2) 1,573.07 19.26 211.73 1,556.76 -138.22 -74.741,416.56 5,915,608.97 289,769.16 3.24 -89.23 MWD+IFR2+SAG+MS (2) 1,666.72 22.29 213.04 1,644.31 -166.26 -92.551,504.11 5,915,581.45 289,750.58 3.27 -106.12 MWD+IFR2+SAG+MS (2) 1,761.21 25.53 211.68 1,730.68 -198.61 -113.021,590.48 5,915,549.67 289,729.22 3.48 -125.66 MWD+IFR2+SAG+MS (2) 1,854.57 28.08 211.29 1,814.00 -234.52 -135.001,673.80 5,915,514.40 289,706.25 2.74 -147.67 MWD+IFR2+SAG+MS (2) 1,949.04 30.87 211.19 1,896.24 -274.26 -159.101,756.04 5,915,475.34 289,681.05 2.95 -172.14 MWD+IFR2+SAG+MS (2) 2,043.17 33.32 211.07 1,975.97 -317.07 -184.951,835.77 5,915,433.27 289,654.02 2.60 -198.54 MWD+IFR2+SAG+MS (2) 2,135.72 35.88 212.83 2,052.15 -361.64 -212.781,911.95 5,915,389.49 289,624.97 2.97 -225.62 MWD+IFR2+SAG+MS (2) 2,230.55 38.20 215.83 2,127.85 -408.77 -245.021,987.65 5,915,343.27 289,591.44 3.10 -252.98 MWD+IFR2+SAG+MS (2) 2,325.27 41.24 217.97 2,200.70 -457.14 -281.382,060.50 5,915,295.93 289,553.74 3.52 -279.57 MWD+IFR2+SAG+MS (2) 2,416.31 44.08 218.16 2,267.64 -505.71 -319.422,127.44 5,915,248.44 289,514.38 3.12 -305.58 MWD+IFR2+SAG+MS (2) 2,511.64 46.36 218.33 2,334.79 -558.85 -361.302,194.59 5,915,196.49 289,471.03 2.40 -333.91 MWD+IFR2+SAG+MS (2) 2,605.68 47.92 219.95 2,398.75 -612.30 -404.822,258.55 5,915,144.27 289,426.05 2.08 -361.78 MWD+IFR2+SAG+MS (2) 2,699.81 49.70 219.41 2,460.74 -666.82 -450.042,320.54 5,915,091.03 289,379.33 1.94 -389.82 MWD+IFR2+SAG+MS (2) 2,794.50 51.03 219.52 2,521.14 -723.11 -496.392,380.94 5,915,036.05 289,331.44 1.41 -418.94 MWD+IFR2+SAG+MS (2) 2,887.50 52.85 220.75 2,578.47 -779.08 -543.602,438.27 5,914,981.41 289,282.70 2.22 -447.38 MWD+IFR2+SAG+MS (2) 2,983.61 54.63 220.32 2,635.32 -837.98 -593.962,495.12 5,914,923.94 289,230.73 1.89 -477.00 MWD+IFR2+SAG+MS (2) 3,077.58 56.47 219.60 2,688.47 -897.38 -643.722,548.27 5,914,865.95 289,179.34 2.06 -507.33 MWD+IFR2+SAG+MS (2) 3,171.44 58.05 220.39 2,739.23 -957.85 -694.462,599.03 5,914,806.91 289,126.94 1.83 -538.18 MWD+IFR2+SAG+MS (2) 3,265.63 60.28 220.46 2,787.51 -1,019.42 -746.902,647.31 5,914,746.83 289,072.81 2.37 -569.22 MWD+IFR2+SAG+MS (2) 3,359.05 62.39 219.65 2,832.32 -1,082.16 -799.652,692.12 5,914,685.58 289,018.35 2.38 -601.18 MWD+IFR2+SAG+MS (2) 3,453.49 63.36 219.91 2,875.38 -1,146.75 -853.432,735.18 5,914,622.51 288,962.80 1.06 -634.32 MWD+IFR2+SAG+MS (2) 3,546.71 63.03 219.42 2,917.41 -1,210.80 -906.542,777.21 5,914,559.96 288,907.93 0.59 -667.27 MWD+IFR2+SAG+MS (2) 3,641.46 63.06 219.43 2,960.36 -1,276.04 -960.172,820.16 5,914,496.24 288,852.51 0.03 -701.05 MWD+IFR2+SAG+MS (2) 3,684.98 63.31 219.69 2,980.00 -1,305.98 -984.912,839.80 5,914,467.00 288,826.95 0.78 -716.50 MWD+IFR2+SAG+MS (2) 3,757.00 62.11 220.07 3,013.02 -1,355.10 -1,025.942,872.82 5,914,419.04 288,784.57 1.73 -741.63 MWD+IFR2+SAG+MS (3) 13-3/8" Surface Casing 3,779.64 61.73 220.19 3,023.68 -1,370.37 -1,038.822,883.48 5,914,404.14 288,771.28 1.73 -749.40 MWD+IFR2+SAG+MS (3) 3,812.82 61.52 220.43 3,039.44 -1,392.63 -1,057.702,899.24 5,914,382.41 288,751.78 0.90 -760.66 MWD+IFR2+SAG+MS (3) 3,907.64 59.83 222.52 3,085.89 -1,454.58 -1,112.442,945.69 5,914,322.02 288,695.35 2.62 -791.00 MWD+IFR2+SAG+MS (3) 4,002.24 59.59 221.45 3,133.60 -1,515.29 -1,167.082,993.40 5,914,262.84 288,639.04 1.01 -820.29 MWD+IFR2+SAG+MS (3) 4,096.83 59.40 222.42 3,181.62 -1,575.92 -1,221.543,041.42 5,914,203.76 288,582.92 0.91 -849.58 MWD+IFR2+SAG+MS (3) 4,190.83 59.49 223.73 3,229.40 -1,635.04 -1,276.823,089.20 5,914,146.19 288,526.02 1.20 -877.17 MWD+IFR2+SAG+MS (3) 4,285.04 59.50 224.01 3,277.23 -1,693.56 -1,333.083,137.03 5,914,089.26 288,468.17 0.26 -903.77 MWD+IFR2+SAG+MS (3) 4,378.72 59.52 223.34 3,324.76 -1,751.95 -1,388.823,184.56 5,914,032.45 288,410.83 0.62 -930.48 MWD+IFR2+SAG+MS (3) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,473.55 59.49 223.97 3,372.88 -1,811.07 -1,445.233,232.68 5,913,974.92 288,352.80 0.57 -957.55 MWD+IFR2+SAG+MS (3) 4,568.29 59.52 223.50 3,420.96 -1,870.05 -1,501.673,280.76 5,913,917.53 288,294.75 0.43 -984.48 MWD+IFR2+SAG+MS (3) 4,663.08 60.03 224.33 3,468.68 -1,929.05 -1,558.473,328.48 5,913,860.14 288,236.33 0.93 -1,011.26 MWD+IFR2+SAG+MS (3) 4,758.27 60.02 223.30 3,516.24 -1,988.55 -1,615.563,376.04 5,913,802.25 288,177.62 0.94 -1,038.36 MWD+IFR2+SAG+MS (3) 4,852.31 60.06 223.59 3,563.20 -2,047.70 -1,671.593,423.00 5,913,744.68 288,119.97 0.27 -1,065.63 MWD+IFR2+SAG+MS (3) 4,946.24 60.07 223.99 3,610.07 -2,106.46 -1,727.923,469.87 5,913,687.51 288,062.03 0.37 -1,092.41 MWD+IFR2+SAG+MS (3) 5,041.03 60.03 222.71 3,657.40 -2,166.18 -1,784.293,517.20 5,913,629.38 288,004.02 1.17 -1,120.03 MWD+IFR2+SAG+MS (3) 5,134.89 60.04 223.28 3,704.28 -2,225.66 -1,839.743,564.08 5,913,571.47 287,946.94 0.53 -1,147.85 MWD+IFR2+SAG+MS (3) 5,228.78 60.05 221.96 3,751.16 -2,285.52 -1,894.833,610.96 5,913,513.17 287,890.22 1.22 -1,176.18 MWD+IFR2+SAG+MS (3) 5,322.15 59.97 222.63 3,797.83 -2,345.33 -1,949.253,657.63 5,913,454.89 287,834.17 0.63 -1,204.77 MWD+IFR2+SAG+MS (3) 5,417.34 60.07 221.90 3,845.40 -2,406.35 -2,004.703,705.20 5,913,395.43 287,777.04 0.67 -1,233.96 MWD+IFR2+SAG+MS (3) 5,511.84 59.95 221.26 3,892.64 -2,467.58 -2,059.023,752.44 5,913,335.75 287,721.05 0.60 -1,263.85 MWD+IFR2+SAG+MS (3) 5,605.08 60.06 220.99 3,939.25 -2,528.40 -2,112.133,799.05 5,913,276.42 287,666.27 0.28 -1,293.94 MWD+IFR2+SAG+MS (3) 5,700.85 59.99 221.08 3,987.10 -2,590.98 -2,166.603,846.90 5,913,215.38 287,610.09 0.11 -1,324.97 MWD+IFR2+SAG+MS (3) 5,795.21 60.08 221.05 4,034.23 -2,652.62 -2,220.303,894.03 5,913,155.26 287,554.70 0.10 -1,355.50 MWD+IFR2+SAG+MS (3) 5,887.96 60.06 221.29 4,080.50 -2,713.12 -2,273.213,940.30 5,913,096.25 287,500.13 0.23 -1,385.39 MWD+IFR2+SAG+MS (3) 5,983.60 59.96 221.98 4,128.31 -2,775.03 -2,328.243,988.11 5,913,035.90 287,443.40 0.63 -1,415.57 MWD+IFR2+SAG+MS (3) 6,078.15 60.06 222.47 4,175.57 -2,835.67 -2,383.284,035.37 5,912,976.81 287,386.71 0.46 -1,444.62 MWD+IFR2+SAG+MS (3) 6,172.58 60.02 222.92 4,222.73 -2,895.80 -2,438.754,082.53 5,912,918.25 287,329.58 0.42 -1,473.01 MWD+IFR2+SAG+MS (3) 6,268.06 60.09 222.77 4,270.39 -2,956.46 -2,495.014,130.19 5,912,859.18 287,271.66 0.15 -1,501.51 MWD+IFR2+SAG+MS (3) 6,361.30 60.01 223.35 4,316.94 -3,015.49 -2,550.174,176.74 5,912,801.71 287,214.89 0.55 -1,529.07 MWD+IFR2+SAG+MS (3) 6,454.48 60.03 223.51 4,363.50 -3,074.10 -2,605.664,223.30 5,912,744.66 287,157.80 0.15 -1,556.10 MWD+IFR2+SAG+MS (3) 6,550.86 60.07 225.84 4,411.62 -3,133.48 -2,664.374,271.42 5,912,686.94 287,097.47 2.10 -1,582.35 MWD+IFR2+SAG+MS (3) 6,643.80 59.99 227.13 4,458.05 -3,188.92 -2,722.754,317.85 5,912,633.15 287,037.57 1.21 -1,605.24 MWD+IFR2+SAG+MS (3) 6,737.95 60.06 226.44 4,505.09 -3,244.76 -2,782.194,364.89 5,912,578.98 286,976.60 0.64 -1,628.02 MWD+IFR2+SAG+MS (3) 6,833.63 59.99 225.16 4,552.90 -3,302.54 -2,841.614,412.70 5,912,522.88 286,915.61 1.16 -1,652.52 MWD+IFR2+SAG+MS (3) 6,926.16 60.05 223.79 4,599.14 -3,359.73 -2,897.764,458.94 5,912,467.27 286,857.89 1.28 -1,677.99 MWD+IFR2+SAG+MS (3) 7,020.34 59.98 223.48 4,646.21 -3,418.77 -2,954.054,506.01 5,912,409.82 286,799.99 0.29 -1,705.04 MWD+IFR2+SAG+MS (3) 7,114.92 60.00 222.95 4,693.51 -3,478.46 -3,010.134,553.31 5,912,351.72 286,742.27 0.49 -1,732.76 MWD+IFR2+SAG+MS (3) 7,208.64 60.02 222.24 4,740.36 -3,538.21 -3,065.074,600.16 5,912,293.51 286,685.70 0.66 -1,761.06 MWD+IFR2+SAG+MS (3) 7,302.47 60.05 222.13 4,787.22 -3,598.45 -3,119.664,647.02 5,912,234.82 286,629.47 0.11 -1,789.95 MWD+IFR2+SAG+MS (3) 7,397.04 59.99 221.80 4,834.48 -3,659.36 -3,174.434,694.28 5,912,175.46 286,573.02 0.31 -1,819.35 MWD+IFR2+SAG+MS (3) 7,492.19 59.93 221.88 4,882.11 -3,720.72 -3,229.384,741.91 5,912,115.65 286,516.40 0.10 -1,849.08 MWD+IFR2+SAG+MS (3) 7,584.58 59.98 221.72 4,928.37 -3,780.34 -3,282.684,788.17 5,912,057.53 286,461.46 0.16 -1,878.00 MWD+IFR2+SAG+MS (3) 7,678.03 60.05 221.81 4,975.07 -3,840.72 -3,336.604,834.87 5,911,998.68 286,405.89 0.11 -1,907.32 MWD+IFR2+SAG+MS (3) 7,773.13 59.97 222.40 5,022.61 -3,901.82 -3,391.824,882.41 5,911,939.14 286,348.99 0.54 -1,936.70 MWD+IFR2+SAG+MS (3) 7,866.80 60.04 221.67 5,069.44 -3,962.08 -3,446.144,929.24 5,911,880.42 286,293.02 0.68 -1,965.72 MWD+IFR2+SAG+MS (3) 7,961.18 59.96 221.39 5,116.63 -4,023.27 -3,500.334,976.43 5,911,820.76 286,237.16 0.27 -1,995.64 MWD+IFR2+SAG+MS (3) 8,055.50 59.98 221.02 5,163.83 -4,084.70 -3,554.135,023.63 5,911,760.85 286,181.68 0.34 -2,025.96 MWD+IFR2+SAG+MS (3) 8,149.20 60.00 219.04 5,210.70 -4,146.83 -3,606.315,070.50 5,911,700.20 286,127.79 1.83 -2,057.62 MWD+IFR2+SAG+MS (3) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,243.48 60.09 218.86 5,257.77 -4,210.35 -3,657.665,117.57 5,911,638.12 286,074.70 0.19 -2,090.91 MWD+IFR2+SAG+MS (3) 8,338.65 60.06 218.97 5,305.25 -4,274.53 -3,709.475,165.05 5,911,575.41 286,021.13 0.11 -2,124.57 MWD+IFR2+SAG+MS (3) 8,430.88 59.99 219.22 5,351.33 -4,336.54 -3,759.855,211.13 5,911,514.84 285,969.05 0.25 -2,156.94 MWD+IFR2+SAG+MS (3) 8,524.64 60.06 219.89 5,398.18 -4,399.16 -3,811.585,257.98 5,911,453.68 285,915.61 0.62 -2,189.26 MWD+IFR2+SAG+MS (3) 8,618.79 59.98 219.58 5,445.22 -4,461.87 -3,863.715,305.02 5,911,392.44 285,861.76 0.30 -2,221.47 MWD+IFR2+SAG+MS (3) 8,713.43 60.09 219.22 5,492.49 -4,525.23 -3,915.755,352.29 5,911,330.56 285,807.98 0.35 -2,254.29 MWD+IFR2+SAG+MS (3) 8,806.97 60.07 219.74 5,539.15 -4,587.80 -3,967.295,398.95 5,911,269.44 285,754.72 0.48 -2,286.65 MWD+IFR2+SAG+MS (3) 8,901.50 60.04 220.44 5,586.34 -4,650.47 -4,020.045,446.14 5,911,208.27 285,700.25 0.64 -2,318.53 MWD+IFR2+SAG+MS (3) 8,995.33 60.02 220.85 5,633.21 -4,712.14 -4,072.995,493.01 5,911,148.09 285,645.62 0.38 -2,349.45 MWD+IFR2+SAG+MS (3) 9,090.25 59.95 221.58 5,680.69 -4,773.97 -4,127.145,540.49 5,911,087.79 285,589.77 0.67 -2,379.95 MWD+IFR2+SAG+MS (3) 9,184.37 59.98 222.86 5,727.80 -4,834.31 -4,181.905,587.60 5,911,029.00 285,533.37 1.18 -2,408.86 MWD+IFR2+SAG+MS (3) 9,277.34 60.03 223.92 5,774.28 -4,892.82 -4,237.215,634.08 5,910,972.05 285,476.45 0.99 -2,435.88 MWD+IFR2+SAG+MS (3) 9,371.68 60.00 224.08 5,821.43 -4,951.60 -4,293.975,681.23 5,910,914.87 285,418.08 0.15 -2,462.49 MWD+IFR2+SAG+MS (3) 9,466.27 60.00 224.08 5,868.72 -5,010.45 -4,350.965,728.52 5,910,857.63 285,359.49 0.00 -2,489.05 MWD+IFR2+SAG+MS (3) 9,560.73 60.09 223.44 5,915.89 -5,069.56 -4,407.565,775.69 5,910,800.12 285,301.26 0.59 -2,516.02 MWD+IFR2+SAG+MS (3) 9,653.04 60.05 223.25 5,961.95 -5,127.73 -4,462.475,821.75 5,910,743.50 285,244.76 0.18 -2,542.92 MWD+IFR2+SAG+MS (3) 9,746.24 60.07 224.29 6,008.46 -5,186.05 -4,518.345,868.26 5,910,686.75 285,187.30 0.97 -2,569.52 MWD+IFR2+SAG+MS (3) 9,841.13 60.03 224.67 6,055.84 -5,244.72 -4,575.955,915.64 5,910,629.72 285,128.09 0.35 -2,595.64 MWD+IFR2+SAG+MS (3) 9,934.96 60.06 224.68 6,102.69 -5,302.53 -4,633.105,962.49 5,910,573.52 285,069.35 0.03 -2,621.20 MWD+IFR2+SAG+MS (3) 10,029.97 60.04 224.25 6,150.12 -5,361.28 -4,690.776,009.92 5,910,516.39 285,010.08 0.39 -2,647.37 MWD+IFR2+SAG+MS (3) 10,124.13 59.95 224.44 6,197.21 -5,419.59 -4,747.766,057.01 5,910,459.69 284,951.49 0.20 -2,673.45 MWD+IFR2+SAG+MS (3) 10,218.01 60.03 223.42 6,244.16 -5,478.14 -4,804.166,103.96 5,910,402.73 284,893.49 0.94 -2,700.01 MWD+IFR2+SAG+MS (3) 10,312.49 59.96 221.96 6,291.41 -5,538.27 -4,859.646,151.21 5,910,344.17 284,836.37 1.34 -2,728.41 MWD+IFR2+SAG+MS (3) 10,406.64 60.04 220.96 6,338.49 -5,599.38 -4,913.626,198.29 5,910,284.59 284,780.71 0.92 -2,758.34 MWD+IFR2+SAG+MS (3) 10,500.70 59.94 220.71 6,385.53 -5,661.00 -4,966.886,245.33 5,910,224.47 284,725.76 0.25 -2,789.07 MWD+IFR2+SAG+MS (3) 10,595.37 59.97 221.23 6,432.93 -5,722.88 -5,020.616,292.73 5,910,164.11 284,670.34 0.48 -2,819.81 MWD+IFR2+SAG+MS (3) 10,687.64 60.05 220.35 6,479.05 -5,783.38 -5,072.826,338.85 5,910,105.08 284,616.47 0.83 -2,850.02 MWD+IFR2+SAG+MS (3) 10,781.64 59.93 219.83 6,526.07 -5,845.65 -5,125.246,385.87 5,910,044.30 284,562.35 0.50 -2,881.71 MWD+IFR2+SAG+MS (3) 10,875.88 59.99 219.38 6,573.25 -5,908.51 -5,177.246,433.05 5,909,982.91 284,508.62 0.42 -2,914.10 MWD+IFR2+SAG+MS (3) 10,970.00 60.05 219.49 6,620.28 -5,971.47 -5,229.036,480.08 5,909,921.41 284,455.11 0.12 -2,946.69 MWD+IFR2+SAG+MS (3) 11,064.37 60.04 220.63 6,667.40 -6,034.05 -5,281.656,527.20 5,909,860.32 284,400.77 1.05 -2,978.56 MWD+IFR2+SAG+MS (3) 11,157.92 59.99 221.56 6,714.15 -6,095.12 -5,334.916,573.95 5,909,800.76 284,345.84 0.86 -3,008.79 MWD+IFR2+SAG+MS (3) 11,251.64 59.99 221.53 6,761.03 -6,155.86 -5,388.736,620.83 5,909,741.54 284,290.35 0.03 -3,038.47 MWD+IFR2+SAG+MS (3) 11,345.88 60.02 221.83 6,808.14 -6,216.82 -5,443.016,667.94 5,909,682.12 284,234.41 0.28 -3,068.15 MWD+IFR2+SAG+MS (3) 11,440.48 60.00 222.10 6,855.43 -6,277.74 -5,497.796,715.23 5,909,622.75 284,177.95 0.25 -3,097.56 MWD+IFR2+SAG+MS (3) 11,534.79 59.98 222.18 6,902.60 -6,338.29 -5,552.596,762.40 5,909,563.74 284,121.50 0.08 -3,126.64 MWD+IFR2+SAG+MS (3) 11,629.00 59.92 222.41 6,949.77 -6,398.61 -5,607.476,809.57 5,909,504.97 284,064.97 0.22 -3,155.47 MWD+IFR2+SAG+MS (3) 11,723.27 60.17 221.70 6,996.84 -6,459.26 -5,662.186,856.64 5,909,445.87 284,008.60 0.70 -3,184.67 MWD+IFR2+SAG+MS (3) 11,818.63 60.00 222.67 7,044.40 -6,520.50 -5,717.686,904.20 5,909,386.19 283,951.42 0.90 -3,214.04 MWD+IFR2+SAG+MS (3) 11,911.14 60.12 224.60 7,090.58 -6,578.52 -5,772.996,950.38 5,909,329.74 283,894.52 1.81 -3,240.62 MWD+IFR2+SAG+MS (3) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 12,005.16 59.77 227.47 7,137.67 -6,635.01 -5,831.566,997.47 5,909,274.90 283,834.41 2.67 -3,264.36 MWD+IFR2+SAG+MS (3) 12,096.78 59.70 230.03 7,183.85 -6,687.18 -5,891.047,043.65 5,909,224.41 283,773.50 2.41 -3,283.84 MWD+IFR2+SAG+MS (3) 12,190.75 59.64 232.95 7,231.31 -6,737.67 -5,954.507,091.11 5,909,175.70 283,708.67 2.68 -3,300.02 MWD+IFR2+SAG+MS (3) 12,285.08 59.63 235.01 7,279.00 -6,785.53 -6,020.327,138.80 5,909,129.69 283,641.55 1.88 -3,312.78 MWD+IFR2+SAG+MS (3) 12,379.33 59.20 235.60 7,326.96 -6,831.71 -6,087.037,186.76 5,909,085.38 283,573.58 0.71 -3,323.65 MWD+IFR2+SAG+MS (3) 12,393.86 59.17 235.47 7,334.40 -6,838.78 -6,097.327,194.20 5,909,078.60 283,563.10 0.80 -3,325.27 MWD+IFR2+SAG+MS (3) 12,434.00 59.31 235.89 7,354.93 -6,858.22 -6,125.817,214.73 5,909,059.95 283,534.09 0.96 -3,329.66 MWD+IFR2+SAG+MS (4) 9-5/8" Intermediate Casing 12,475.66 59.46 236.32 7,376.15 -6,878.22 -6,155.577,235.95 5,909,040.79 283,503.79 0.96 -3,333.97 MWD+IFR2+SAG+MS (4) 12,568.66 59.58 239.15 7,423.33 -6,921.00 -6,223.337,283.13 5,908,999.92 283,434.87 2.63 -3,341.32 MWD+IFR2+SAG+MS (4) 12,662.66 59.62 241.92 7,470.90 -6,960.87 -6,293.917,330.70 5,908,962.02 283,363.21 2.54 -3,344.81 MWD+IFR2+SAG+MS (4) 12,757.56 59.87 244.45 7,518.72 -6,997.84 -6,367.067,378.52 5,908,927.09 283,289.06 2.32 -3,344.54 MWD+IFR2+SAG+MS (4) 12,851.79 60.14 248.23 7,565.84 -7,030.58 -6,441.797,425.64 5,908,896.45 283,213.46 3.49 -3,339.78 MWD+IFR2+SAG+MS (4) 12,946.23 60.33 250.66 7,612.73 -7,059.36 -6,518.557,472.53 5,908,869.81 283,135.94 2.24 -3,330.58 MWD+IFR2+SAG+MS (4) 13,040.52 60.57 253.07 7,659.24 -7,084.89 -6,596.497,519.04 5,908,846.46 283,057.32 2.24 -3,317.94 MWD+IFR2+SAG+MS (4) 13,134.08 61.15 256.39 7,704.81 -7,106.40 -6,675.317,564.61 5,908,827.15 282,977.94 3.16 -3,301.32 MWD+IFR2+SAG+MS (4) 13,229.41 61.93 259.35 7,750.24 -7,124.00 -6,757.237,610.04 5,908,811.83 282,895.56 2.85 -3,279.81 MWD+IFR2+SAG+MS (4) 13,323.34 62.42 262.77 7,794.10 -7,136.90 -6,839.287,653.90 5,908,801.21 282,813.19 3.26 -3,254.06 MWD+IFR2+SAG+MS (4) 13,417.77 63.46 266.40 7,837.07 -7,144.82 -6,922.977,696.87 5,908,795.62 282,729.31 3.60 -3,223.12 MWD+IFR2+SAG+MS (4) 13,510.30 64.41 270.14 7,877.74 -7,147.32 -7,006.037,737.54 5,908,795.43 282,646.22 3.77 -3,187.63 MWD+IFR2+SAG+MS (4) 13,604.69 65.22 272.47 7,917.91 -7,145.37 -7,091.427,777.71 5,908,799.75 282,560.92 2.39 -3,147.13 MWD+IFR2+SAG+MS (4) 13,700.07 66.33 275.88 7,957.05 -7,139.03 -7,178.157,816.85 5,908,808.50 282,474.41 3.46 -3,102.11 MWD+IFR2+SAG+MS (4) 13,794.76 67.35 278.45 7,994.30 -7,128.16 -7,264.527,854.10 5,908,821.76 282,388.38 2.72 -3,053.22 MWD+IFR2+SAG+MS (4) 13,887.54 68.23 281.07 8,029.37 -7,113.60 -7,349.167,889.17 5,908,838.67 282,304.18 2.78 -3,001.81 MWD+IFR2+SAG+MS (4) 13,982.32 69.51 284.42 8,063.55 -7,094.08 -7,435.377,923.35 5,908,860.57 282,218.55 3.56 -2,945.29 MWD+IFR2+SAG+MS (4) 14,077.13 70.75 286.59 8,095.78 -7,070.24 -7,521.287,955.58 5,908,886.78 282,133.34 2.52 -2,885.04 MWD+IFR2+SAG+MS (4) 14,171.05 71.99 289.30 8,125.78 -7,042.82 -7,605.947,985.58 5,908,916.55 282,049.48 3.04 -2,822.18 MWD+IFR2+SAG+MS (4) 14,266.00 73.20 292.20 8,154.19 -7,010.72 -7,690.658,013.99 5,908,950.99 281,965.70 3.18 -2,755.11 MWD+IFR2+SAG+MS (4) 14,361.28 74.60 294.73 8,180.62 -6,974.26 -7,774.618,040.42 5,908,989.76 281,882.79 2.94 -2,684.52 MWD+IFR2+SAG+MS (4) 14,455.17 75.89 296.76 8,204.53 -6,934.83 -7,856.388,064.33 5,909,031.45 281,802.14 2.50 -2,612.25 MWD+IFR2+SAG+MS (4) 14,550.40 77.34 299.44 8,226.58 -6,891.19 -7,938.098,086.38 5,909,077.33 281,721.68 3.13 -2,536.28 MWD+IFR2+SAG+MS (4) 14,620.00 78.46 301.45 8,241.17 -6,856.70 -7,996.758,100.97 5,909,113.43 281,664.00 3.26 -2,478.92 MWD+IFR2+SAG+MS (4) 7" Intermediate Liner 14,644.87 78.87 302.17 8,246.05 -6,843.85 -8,017.478,105.85 5,909,126.86 281,643.65 3.26 -2,458.06 MWD+IFR2+SAG+MS (4) 14,688.35 79.73 302.92 8,254.13 -6,820.87 -8,053.498,113.93 5,909,150.83 281,608.29 2.60 -2,421.23 MWD+IFR2+SAG+MS (4) 14,712.00 79.61 302.97 8,258.37 -6,808.21 -8,073.018,118.17 5,909,164.02 281,589.12 0.55 -2,401.09 MWD+IFR2+SAG+MS (5) 4-1/2" Production Liner 14,808.35 81.19 307.45 8,274.44 -6,753.45 -8,150.618,134.24 5,909,220.92 281,513.08 4.87 -2,317.07 MWD+IFR2+SAG+MS (5) 14,902.86 82.09 310.55 8,288.19 -6,694.61 -8,223.268,147.99 5,909,281.75 281,442.09 3.38 -2,231.66 MWD+IFR2+SAG+MS (5) 14,997.59 82.68 313.42 8,300.74 -6,631.80 -8,293.058,160.54 5,909,346.47 281,374.08 3.07 -2,144.02 MWD+IFR2+SAG+MS (5) 15,092.05 83.18 316.93 8,312.37 -6,565.33 -8,359.128,172.17 5,909,414.75 281,309.89 3.73 -2,054.79 MWD+IFR2+SAG+MS (5) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 15,186.63 83.83 318.95 8,323.07 -6,495.56 -8,422.078,182.87 5,909,486.23 281,248.90 2.23 -1,964.05 MWD+IFR2+SAG+MS (5) 15,281.86 84.38 321.00 8,332.85 -6,423.03 -8,482.988,192.65 5,909,560.43 281,190.03 2.22 -1,871.76 MWD+IFR2+SAG+MS (5) 15,375.31 84.97 324.16 8,341.53 -6,349.14 -8,539.518,201.33 5,909,635.85 281,135.57 3.43 -1,780.26 MWD+IFR2+SAG+MS (5) 15,470.89 85.46 325.04 8,349.50 -6,271.50 -8,594.698,209.30 5,909,714.99 281,082.58 1.05 -1,686.04 MWD+IFR2+SAG+MS (5) 15,565.16 86.01 325.49 8,356.51 -6,194.24 -8,648.258,216.31 5,909,793.70 281,031.19 0.75 -1,592.89 MWD+IFR2+SAG+MS (5) 15,658.86 86.32 325.40 8,362.78 -6,117.25 -8,701.288,222.58 5,909,872.14 280,980.32 0.34 -1,500.21 MWD+IFR2+SAG+MS (5) 15,753.90 86.05 324.97 8,369.10 -6,039.39 -8,755.428,228.90 5,909,951.46 280,928.36 0.53 -1,406.26 MWD+IFR2+SAG+MS (5) 15,850.89 86.14 325.42 8,375.71 -5,959.94 -8,810.658,235.51 5,910,032.41 280,875.36 0.47 -1,310.39 MWD+IFR2+SAG+MS (5) 15,943.85 88.71 328.37 8,379.89 -5,882.16 -8,861.368,239.69 5,910,111.56 280,826.84 4.21 -1,218.07 MWD+IFR2+SAG+MS (5) 16,038.88 90.71 330.13 8,380.37 -5,800.50 -8,909.948,240.17 5,910,194.54 280,780.54 2.80 -1,123.25 MWD+IFR2+SAG+MS (5) 16,133.41 92.16 332.01 8,378.00 -5,717.80 -8,955.658,237.80 5,910,278.47 280,737.15 2.51 -1,028.81 MWD+IFR2+SAG+MS (5) 16,227.44 92.16 331.53 8,374.46 -5,635.01 -9,000.108,234.26 5,910,362.46 280,695.02 0.51 -934.87 MWD+IFR2+SAG+MS (5) 16,322.25 92.10 331.80 8,370.93 -5,551.62 -9,045.078,230.73 5,910,447.07 280,652.39 0.29 -840.15 MWD+IFR2+SAG+MS (5) 16,417.42 93.02 332.25 8,366.68 -5,467.65 -9,089.678,226.48 5,910,532.23 280,610.14 1.08 -745.09 MWD+IFR2+SAG+MS (5) 16,511.84 92.32 331.60 8,362.28 -5,384.44 -9,134.058,222.08 5,910,616.65 280,568.08 1.01 -650.79 MWD+IFR2+SAG+MS (5) 16,607.32 91.16 329.42 8,359.38 -5,301.37 -9,181.038,219.18 5,910,700.98 280,523.43 2.59 -555.46 MWD+IFR2+SAG+MS (5) 16,703.16 91.82 332.12 8,356.89 -5,217.77 -9,227.818,216.69 5,910,785.84 280,479.00 2.90 -459.73 MWD+IFR2+SAG+MS (5) 16,798.06 91.73 332.88 8,353.95 -5,133.63 -9,271.618,213.75 5,910,871.16 280,437.55 0.81 -364.88 MWD+IFR2+SAG+MS (5) 16,892.56 91.57 333.03 8,351.23 -5,049.50 -9,314.568,211.03 5,910,956.45 280,396.96 0.23 -270.42 MWD+IFR2+SAG+MS (5) 16,987.37 91.85 331.26 8,348.40 -4,965.72 -9,358.848,208.20 5,911,041.42 280,355.03 1.89 -175.67 MWD+IFR2+SAG+MS (5) 17,082.62 91.37 332.66 8,345.72 -4,881.69 -9,403.598,205.52 5,911,126.66 280,312.62 1.55 -80.47 MWD+IFR2+SAG+MS (5) 17,178.73 91.33 332.55 8,343.46 -4,796.38 -9,447.808,203.26 5,911,213.16 280,270.80 0.12 15.61 MWD+IFR2+SAG+MS (5) 17,240.27 91.33 332.98 8,342.03 -4,741.67 -9,475.968,201.83 5,911,268.62 280,244.18 0.70 77.13 MWD+IFR2+SAG+MS (5) 17,335.05 91.33 332.12 8,339.83 -4,657.59 -9,519.648,199.63 5,911,353.89 280,202.85 0.91 171.88 MWD+IFR2+SAG+MS (5) 17,430.78 91.36 332.09 8,337.58 -4,573.01 -9,564.418,197.38 5,911,439.68 280,160.45 0.04 267.58 MWD+IFR2+SAG+MS (5) 17,525.86 90.48 332.40 8,336.06 -4,488.88 -9,608.698,195.86 5,911,525.00 280,118.53 0.98 362.63 MWD+IFR2+SAG+MS (5) 17,619.63 90.41 331.45 8,335.33 -4,406.14 -9,652.818,195.13 5,911,608.92 280,076.72 1.02 456.38 MWD+IFR2+SAG+MS (5) 17,714.87 90.41 333.93 8,334.65 -4,321.53 -9,696.518,194.45 5,911,694.71 280,035.40 2.60 551.61 MWD+IFR2+SAG+MS (5) 17,809.56 91.05 334.12 8,333.44 -4,236.41 -9,737.988,193.24 5,911,780.94 279,996.31 0.71 646.28 MWD+IFR2+SAG+MS (5) 17,905.02 90.99 333.25 8,331.74 -4,150.86 -9,780.298,191.54 5,911,867.63 279,956.39 0.91 741.72 MWD+IFR2+SAG+MS (5) 17,999.06 91.11 332.77 8,330.02 -4,067.07 -9,822.968,189.82 5,911,952.57 279,916.07 0.53 835.74 MWD+IFR2+SAG+MS (5) 18,093.85 91.05 333.83 8,328.23 -3,982.41 -9,865.548,188.03 5,912,038.38 279,875.86 1.12 930.51 MWD+IFR2+SAG+MS (5) 18,188.16 90.99 333.76 8,326.55 -3,897.80 -9,907.188,186.35 5,912,124.10 279,836.58 0.10 1,024.80 MWD+IFR2+SAG+MS (5) 18,284.02 91.33 333.65 8,324.61 -3,811.88 -9,949.648,184.41 5,912,211.17 279,796.53 0.37 1,120.63 MWD+IFR2+SAG+MS (5) 18,378.43 91.70 334.09 8,322.12 -3,727.15 -9,991.208,181.92 5,912,297.01 279,757.34 0.61 1,214.99 MWD+IFR2+SAG+MS (5) 18,474.63 92.62 333.35 8,318.49 -3,640.96 -10,033.768,178.29 5,912,384.35 279,717.19 1.23 1,311.12 MWD+IFR2+SAG+MS (5) 18,569.34 93.17 333.22 8,313.71 -3,556.46 -10,076.298,173.51 5,912,469.99 279,677.03 0.60 1,405.70 MWD+IFR2+SAG+MS (5) 18,664.48 92.75 333.36 8,308.79 -3,471.59 -10,118.998,168.59 5,912,556.01 279,636.70 0.47 1,500.72 MWD+IFR2+SAG+MS (5) 18,759.48 91.46 333.62 8,305.31 -3,386.64 -10,161.378,165.11 5,912,642.10 279,596.71 1.39 1,595.65 MWD+IFR2+SAG+MS (5) 18,854.48 91.33 334.69 8,302.99 -3,301.17 -10,202.778,162.79 5,912,728.69 279,557.70 1.13 1,690.60 MWD+IFR2+SAG+MS (5) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18,948.92 91.39 333.77 8,300.75 -3,216.14 -10,243.818,160.55 5,912,814.81 279,519.03 0.98 1,784.99 MWD+IFR2+SAG+MS (5) 19,043.02 90.97 333.44 8,298.81 -3,131.87 -10,285.648,158.61 5,912,900.21 279,479.56 0.57 1,879.06 MWD+IFR2+SAG+MS (5) 19,138.56 91.48 334.06 8,296.77 -3,046.21 -10,327.888,156.57 5,912,987.01 279,439.71 0.84 1,974.57 MWD+IFR2+SAG+MS (5) 19,233.32 90.69 333.31 8,294.98 -2,961.28 -10,369.888,154.78 5,913,073.07 279,400.09 1.15 2,069.31 MWD+IFR2+SAG+MS (5) 19,327.24 90.56 333.54 8,293.95 -2,877.29 -10,411.908,153.75 5,913,158.19 279,360.43 0.28 2,163.22 MWD+IFR2+SAG+MS (5) 19,422.21 90.68 332.67 8,292.92 -2,792.60 -10,454.858,152.72 5,913,244.04 279,319.84 0.92 2,258.18 MWD+IFR2+SAG+MS (5) 19,469.17 90.72 332.45 8,292.35 -2,750.92 -10,476.498,152.15 5,913,286.29 279,299.37 0.48 2,305.14 MWD+IFR2+SAG+MS (5) 19,499.44 90.63 333.14 8,291.99 -2,724.00 -10,490.338,151.79 5,913,313.59 279,286.29 2.30 2,335.40 MWD+IFR2+SAG+MS (5) 19,594.13 90.68 335.66 8,290.91 -2,638.62 -10,531.248,150.71 5,913,400.07 279,247.77 2.66 2,430.05 MWD+IFR2+SAG+MS (5) 19,688.27 91.18 333.50 8,289.38 -2,553.61 -10,571.648,149.18 5,913,486.16 279,209.74 2.35 2,524.14 MWD+IFR2+SAG+MS (5) 19,781.49 91.11 333.61 8,287.52 -2,470.16 -10,613.158,147.32 5,913,570.73 279,170.57 0.14 2,617.34 MWD+IFR2+SAG+MS (5) 19,875.43 91.05 333.88 8,285.75 -2,385.93 -10,654.708,145.55 5,913,656.08 279,131.38 0.29 2,711.25 MWD+IFR2+SAG+MS (5) 19,970.14 91.15 333.66 8,283.93 -2,300.99 -10,696.558,143.73 5,913,742.14 279,091.91 0.26 2,805.93 MWD+IFR2+SAG+MS (5) 20,064.26 91.42 333.26 8,281.82 -2,216.81 -10,738.598,141.62 5,913,827.46 279,052.22 0.51 2,900.03 MWD+IFR2+SAG+MS (5) 20,158.79 91.33 332.86 8,279.55 -2,132.56 -10,781.418,139.35 5,913,912.86 279,011.76 0.43 2,994.53 MWD+IFR2+SAG+MS (5) 20,253.34 91.36 332.85 8,277.33 -2,048.45 -10,824.538,137.13 5,913,998.13 278,970.99 0.03 3,089.05 MWD+IFR2+SAG+MS (5) 20,348.01 91.33 331.45 8,275.11 -1,964.77 -10,868.748,134.91 5,914,083.00 278,929.12 1.48 3,183.69 MWD+IFR2+SAG+MS (5) 20,442.17 91.30 332.94 8,272.95 -1,881.50 -10,912.658,132.75 5,914,167.45 278,887.54 1.58 3,277.81 MWD+IFR2+SAG+MS (5) 20,536.55 91.30 333.25 8,270.81 -1,797.36 -10,955.358,130.61 5,914,252.74 278,847.20 0.33 3,372.16 MWD+IFR2+SAG+MS (5) 20,632.23 90.85 333.05 8,269.01 -1,712.01 -10,998.568,128.81 5,914,339.25 278,806.39 0.51 3,467.83 MWD+IFR2+SAG+MS (5) 20,724.61 90.87 333.01 8,267.63 -1,629.69 -11,040.458,127.43 5,914,422.70 278,766.80 0.05 3,560.20 MWD+IFR2+SAG+MS (5) 20,817.01 91.82 333.00 8,265.46 -1,547.38 -11,082.388,125.26 5,914,506.14 278,727.17 1.03 3,652.57 MWD+IFR2+SAG+MS (5) 20,912.51 91.85 332.06 8,262.40 -1,462.69 -11,126.418,122.20 5,914,592.01 278,685.51 0.98 3,748.02 MWD+IFR2+SAG+MS (5) 21,006.61 91.82 332.66 8,259.39 -1,379.37 -11,170.048,119.19 5,914,676.51 278,644.22 0.64 3,842.06 MWD+IFR2+SAG+MS (5) 21,101.01 91.85 334.12 8,256.36 -1,295.02 -11,212.308,116.16 5,914,762.00 278,604.32 1.55 3,936.41 MWD+IFR2+SAG+MS (5) 21,196.27 91.79 334.31 8,253.34 -1,209.29 -11,253.728,113.14 5,914,848.85 278,565.30 0.21 4,031.60 MWD+IFR2+SAG+MS (5) 21,289.21 90.85 334.22 8,251.20 -1,125.59 -11,294.068,111.00 5,914,933.63 278,527.30 1.02 4,124.49 MWD+IFR2+SAG+MS (5) 21,382.74 90.84 333.04 8,249.82 -1,041.80 -11,335.608,109.62 5,915,018.53 278,488.10 1.26 4,218.00 MWD+IFR2+SAG+MS (5) 21,477.51 90.75 333.20 8,248.50 -957.28 -11,378.448,108.30 5,915,104.21 278,447.63 0.19 4,312.76 MWD+IFR2+SAG+MS (5) 21,572.01 90.78 333.15 8,247.24 -872.96 -11,421.088,107.04 5,915,189.68 278,407.35 0.06 4,407.25 MWD+IFR2+SAG+MS (5) 21,662.51 90.30 332.98 8,246.39 -792.28 -11,462.088,106.19 5,915,271.46 278,368.61 0.56 4,497.75 MWD+IFR2+SAG+MS (5) 21,760.06 90.32 332.97 8,245.86 -705.38 -11,506.408,105.66 5,915,359.55 278,326.72 0.02 4,595.30 MWD+IFR2+SAG+MS (5) 21,853.78 90.35 332.92 8,245.31 -621.92 -11,549.038,105.11 5,915,444.16 278,286.43 0.06 4,689.02 MWD+IFR2+SAG+MS (5) 21,947.71 90.99 332.82 8,244.21 -538.33 -11,591.868,104.01 5,915,528.90 278,245.94 0.69 4,782.94 MWD+IFR2+SAG+MS (5) 22,041.01 91.08 331.98 8,242.53 -455.66 -11,635.088,102.33 5,915,612.74 278,205.04 0.91 4,876.22 MWD+IFR2+SAG+MS (5) 22,135.51 90.45 331.54 8,241.27 -372.42 -11,679.798,101.07 5,915,697.19 278,162.66 0.81 4,970.69 MWD+IFR2+SAG+MS (5) 22,229.42 90.44 332.20 8,240.54 -289.60 -11,724.068,100.34 5,915,781.19 278,120.70 0.70 5,064.58 MWD+IFR2+SAG+MS (5) 22,323.09 90.41 332.63 8,239.84 -206.58 -11,767.438,099.64 5,915,865.38 278,079.65 0.46 5,158.24 MWD+IFR2+SAG+MS (5) 22,418.34 90.41 331.72 8,239.16 -122.35 -11,811.898,098.96 5,915,950.81 278,037.55 0.96 5,253.48 MWD+IFR2+SAG+MS (5) 22,511.96 90.47 332.84 8,238.44 -39.48 -11,855.448,098.24 5,916,034.86 277,996.33 1.20 5,347.08 MWD+IFR2+SAG+MS (5) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope GMT2 Rendezvous Pad ConocoPhillips Definitive Survey Report Well: Wellbore: MT7-11 MT7-11 Survey Calculation Method:Minimum Curvature Doyon 25 Actual KB @ 140.20usft Design:MT7-11 Database:EDT 17 Alaska Prod MD Reference:Doyon 25 Actual KB @ 140.20usft North Reference: Well MT7-11 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 22,605.74 90.44 332.60 8,237.70 43.87 -11,898.428,097.50 5,916,119.36 277,955.68 0.26 5,440.86 MWD+IFR2+SAG+MS (5) 22,700.11 90.44 332.58 8,236.97 127.64 -11,941.868,096.77 5,916,204.31 277,914.58 0.02 5,535.22 MWD+IFR2+SAG+MS (5) 22,792.37 90.44 332.46 8,236.26 209.49 -11,984.438,096.06 5,916,287.30 277,874.30 0.13 5,627.48 MWD+IFR2+SAG+MS (5) 22,888.84 90.38 333.85 8,235.57 295.56 -12,028.008,095.37 5,916,374.54 277,833.15 1.44 5,723.94 MWD+IFR2+SAG+MS (5) 22,982.51 91.57 333.04 8,233.98 379.34 -12,069.868,093.78 5,916,459.44 277,793.63 1.54 5,817.59 MWD+IFR2+SAG+MS (5) 23,077.65 91.54 332.25 8,231.40 463.80 -12,113.568,091.20 5,916,545.09 277,752.29 0.83 5,912.70 MWD+IFR2+SAG+MS (5) 23,104.00 91.54 332.25 8,230.69 487.12 -12,125.838,090.49 5,916,568.73 277,740.68 0.00 5,939.03 MWD+IFR2+SAG+MS (5) 4/27/2023 3:26:34PM COMPASS 5000.17 Build Page 9 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA May 01, 2023 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-11 Greater Mooses Tooth API #: 50-103-20850-00 Permit No: 223-002 Rig: Doyon 25 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-11 is located in a federal oil and gas unit. Only with respect to the MT7-11 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: Please return transmittal letter to: Garrett Brown Garrett.Brown@conocophillips.com Luis Arismendi Luis.arismendi@bakerhughes.com PTD: 223-002 T37621 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.01 13:59:52 -08'00' 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Friday, March 24, 2023 7:31 AM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; WSC Rig Advisor; Operations Engineer, Doyon 25; Greg.S.Hobbs@conocophillips.com; Ben Wedin; Bill Walter Subject:Doyon 25 3-23-23 Attachments:Doyon 25 3-23-23.xlsx; Doyon 25 3-23-23 Test Chart.pdf; Doyon 25 3-23-23 Test sequence.docx BOPE test report attached Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907‐670‐4971 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. Greater Mooses Tooth Unit MT7-11PTD 2230020 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:25 DATE:3/23/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2230020 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250 / 3500 Annular:250 / 2500 Valves:250 / 3500 MASP:2923 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 4 P Test Fluid Water Inside BOP 2 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators P P #1 Rams 1 2-7/8 x 5-1/2 VBR P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2-7/8 x 5-1/2 VBR 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" x 5000 psi P Time/Pressure Test Result HCR Valves 2 3 1/8" x 5000 psi P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" x 5000 psi P Pressure After Closure (psi)1675 P Check Valve 0 NA 200 psi Attained (sec)16 P BOP Misc 0 NA Full Pressure Attained (sec)104 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6/ 1958 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 17 P #1 Rams 14 P Coiled Tubing Only:#2 Rams 14 P Inside Reel valves 0 NA #3 Rams 15 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/22/23 13:48 Waived By Test Start Date/Time:3/23/2023 14:30 (date)(time)Witness Test Finish Date/Time:3/23/2023 22:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Test annular 250/3500 w/ 5" and 4" test joint, Ram #1 and #3 w/ 5" and 4" test joint to 250/3500 psi f/ 5/10 min. Test ram #2 to 250/3500 psi for 5/10 min. Test 2 ea 5" and 4" FOSV and 1 ea 5" and 4" dart valve. Function primary and remote BOPE control stations. Test LEL and H2S gas alarms. BLM Quinn Sawyer waived witness. R.Fritts/ Z.Coleman CPAI R.Reinhardt/ P.Angelle GMTU MT7-11 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0323_BOP_Doyon25_GMTU_MT7-11 J. Regg BOPE Test - Doyon 25 GMTU MT7-11 PTD 2230020 3/23/2023 jbr BOPE Test - Doyon 25 GMTU MT7-11 PTD 2230020 3/23/2023 jbr MT7-11 3/23/2023 Tested to 250PSI / 5 MIN, 35OOPSI / 10MIN 5” Test Jt 1.Annular Preventer, Valves: 1, 13, 14, 15, 4” Kill Line Valve, UIBOP 2.Upper Pipe Rams (2.87” x 5.5” ), Valves: 2, 10, 12, HCR KILL & LIBOP 3.Valves: 6, 9 ,11, Manual Kill, 5” Dart Valve 4.Valves 5, 7, 8 & 5” FOSV # 1 5.Valves 3 & 5” FOSV # 2 6.Lower Pipe Rams (2.87” x 5.5” VBR’S) 7.Blind Shear Rams, Valves: 4 & 5” Dart Valve 8.Manually Operated & Super Choke ( 8A = Manual Choke – 8B = Super Choke) 4” Test Jt 9.Annular Preventer, HCR Choke , 5” FOSV # 1 10.Upper Pipe Rams (2.87” x 5.5” VBR’S) & Manual Choke, 5” FOSV # 2 11.Lower Pipe Rams (2.87” x 5.5” VBR’S) BOPE Test - Doyon 25 GMTU MT7-11 PTD 2230020 3/23/2023 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Sunday, March 19, 2023 9:06 AM To:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC) Cc:Drilling Supervisor, Doyon 25; WSC Rig Advisor; Greg.S.Hobbs@conocophillips.com Subject:Doyon 25 3-17-23 Attachments:Doyon 25 3-17-23.xlsx; Doyon 25 3-17-23 Test Sequence.docx; Doyon 25 3-17-23 Test Chart.pdf 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. Test report for 3‐17‐23 ram change Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907‐670‐4971 Greater Mooses Tooth Unit MT7-11PTD 2230020 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:25 DATE:3/17/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2230020 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250 / 3500 Annular:250 / 3500 Valves:MASP:2923 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping NA Well Sign NA Upper Kelly NA Permit On Location NA Hazard Sec.NA Lower Kelly NA Standing Order Posted NA Misc.NA Ball Type NA Test Fluid Water Inside BOP NA FSV Misc NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper NA Trip Tank NA Annular Preventer 1 13-5/8 P Pit Level Indicators NA #1 Rams 1 4.5 x 7 P Flow Indicator NA #2 Rams NA Meth Gas Detector NA #3 Rams NA H2S Gas Detector NA #4 Rams NA MS Misc NA #5 Rams NA #6 Rams NA ACCUMULATOR SYSTEM: Choke Ln. Valves NA Time/Pressure Test Result HCR Valves NA System Pressure (psi)NA Kill Line Valves NA Pressure After Closure (psi)NA Check Valve NA 200 psi Attained (sec)NA BOP Misc NA Full Pressure Attained (sec)NA Blind Switch Covers:All stations NA CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves NA ACC Misc 0 NA Manual Chokes NA Hydraulic Chokes NA Control System Response Time:Time (sec)Test Result CH Misc NA Annular Preventer 17 P #1 Rams 15 P Coiled Tubing Only:#2 Rams 0 NA Inside Reel valves NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.5 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/14/23 05:45 Waived By Test Start Date/Time:3/17/2023 5:00 (date)(time)Witness Test Finish Date/Time:3/17/2023 8:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Doyon Changed Ram #1 to 4.5" x 7". Test Annular 250/2500 f/ 5/10 min w/ 5" and 250/3500 f/ 5/10 min w/ 7" test joint. Test Ram #1 w/ 5" and 7" test joint.250/3500 psi f/ 5/10 min. BLM Rep. waived witness R. Fritts / C. Bali CPAI J. Benedict/ Percy Angelle GMTU MT7-11 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0317_BOP_Doyon25_ram-change_GMTU_MT7-11 J. Regg PTD 2230020 MT7-11 3/17/23 5” Test Joint 1.Annular Preventer - 250 Low, 2500 High 5/10min. 2.Upper Pipe Rams - (4.5” x 7” VBR’S) -250 Low, 3,500 High 5/10min. 7” Test Joint 3.Annular Preventer - 250 Low, 3,500 High 5/10min. 4.Upper Pipe Rams - (4.5” x 7” VBR’S) -250 Low, 3,500 High 5/10min PTD 2230020 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 Manager ConocoPhillips Alaska, LLC PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Rendezvous Pool, MT7-11 ConocoPhillips Alaska, LLC Permit to Drill Number: 223-002 Surface Location: 919' FSL, 1771' FWL, SESW, Sec. 32, T10N, R2E, UM Bottomhole Location: 3899.7 FSL, 1368.7 FWL, SWNW S26 T10N R1E, 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, 2023. 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 From:Gorham, Brad To:Davies, Stephen F (OGC) Cc:Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL]GMTU MT7-11 (Revised); PTD 223-002) - Request Date:Thursday, March 16, 2023 7:10:59 AM Attachments:4. MT7-11 Area of Review.pdf Steve, See the attached for the area of review that was submitted with the original permit package. MT7- 11 will not be pre-produced for longer then 30 days. Let me know if you have any other questions or if there is anything else missing. Thanks, Brad From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, March 15, 2023 5:07 PM To: Gorham, Brad <Brad.Gorham@conocophillips.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]GMTU MT7-11 (Revised); PTD 223-002) - Request Brad, Does MT7-09 or any other well lie within ¼ mile Area of Review for the planned MT7-11 injector? If so, the revised Permit to Drill application lacks an Area of Review discussion for MT7-09 including demonstration of cement-isolation for all significant hydrocarbon zones. Will MT7-11 be pre-produced for longer than 30 days? Thanks and stay safe, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Gorham, Brad <Brad.Gorham@conocophillips.com> Sent: Wednesday, March 15, 2023 2:20 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]GMTU MT7-11 (Revised); PTD 223-002) - Request the content is safe. Steve, My apologies, I attached the wrong file in my original email. See attached. Let me know if you need anything else. Thanks, Brad From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, March 15, 2023 2:16 PM To: Gorham, Brad <Brad.Gorham@conocophillips.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL]GMTU MT7-11 (Revised); PTD 223-002) - Request 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. Brad, Could ConocoPhillips please provide a copy of the planned directional survey data for this revised, extended wellbore in spreadsheet or ASCII table format? That data in digital form will greatly simplify my portion of the review for this application. I only need MD, inclination and azimuth information. Thanks and stay safe, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Attachment 1 MT7-11 Area of Review (AOR) An Area of Review plot is show below of the MT7-11 Injector planned wellpath and offset wells. MT7-09 is the only offset well from the planned MT7-11 injector. Well Name Status Top of Alpine Pool (MD/TVD) TOC (MD/TVD) TOC Determined By Reservoir Status Zonal Isolation Cement Operations Summary MT7-09 Producing 13,979 / 8,269 12,474 / 7,756 Sonic Log Liner TOC and Packer 88 bbls of 15.8 ppg Class G MT7-09 14,121 The Alpine C zone was penetrated at 14,155 The intermediate liner was cemented to isolate the Alpine pool with 88 bbls of Class G cement (plugs bumped and floats held) and top of cement was measured with a Sonic LWD at 14,474 21,697 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-11Initial Class/TypeSER / WAGINGeoArea890Unit10750On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230020GRTR MOOSES TOOTH, RENDEZV OIL - 282200NA1 Permit fee attachedYes Surface Location lies within AA081800; Portion of Well Passes Thru AA081781;2 Lease number appropriateYes Top Productive Interval lies in AA081784; TD lies in AA081803.3 Unique well name and numberYes Greater Mooses Tooth, Rendezvous Oil Pool 2822004 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes AIO 43 applies.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYes MT7-0915 All wells within 1/4 mile area of review identified (For service well only)No MT7-11 will not be pre-produced.16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 80' conductor18 Conductor string providedYes 3777' MD SC shoe19 Surface casing protects all known USDWsYes 73% excess20 CMT vol adequate to circulate on conductor & surf csgNo21 CMT vol adequate to tie-in long string to surf csgNo uncemented liner with swell packers and frac sleeves22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes rig has steel tanks; all waste to approved disposal wells24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes Anti collision analysis complete; no major risk failures26 Adequate wellbore separation proposedYes Diverter variance granted per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulationsYes Max formation pressure is 3752 psig(8.8 ppg EMW); will drill w/ 8.8 - 13.0 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 2923 psig; will test BOPs to 3500 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableYes MT7-09 good cement34 Mechanical 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 measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate3/16/2023ApprVTLDate2/15/2023ApprSFDDate3/15/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Wednesday, March 15, 2023 3:23 PM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC); BLM_AK_AKSO_EnergySection_Notifications@blm.gov Cc:Drilling Supervisor, Doyon 25; WSC Rig Advisor; Greg.S.Hobbs@conocophillips.com; Ben Wedin; Bill Walter; Samuel Dye Subject:Revised test report Attachments:Doyon 25 Test Report 3-15-23.xlsx Please disregard previous report. Everett Potter Rig 25 Toolpusher rig25@doyondrilling.com 907-670-4971 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. Greater Mooses Tooth Unit MT7-11PTD 2230020 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:25 DATE:3/15/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2230020 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250 / 3500 Annular:250 / 3500 Valves:NT MASP:2923 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping NA Well Sign NA Upper Kelly NA Permit On Location NA Hazard Sec.NA Lower Kelly NA Standing Order Posted NA Misc.NA Ball Type NA Test Fluid Water Inside BOP NA FSV Misc NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper NA Trip Tank NA Annular Preventer 1 13-5/8 P Pit Level Indicators NA #1 Rams 1 9 5/8 P Flow Indicator NA #2 Rams NA Meth Gas Detector NA #3 Rams NA H2S Gas Detector NA #4 Rams NA MS Misc NA #5 Rams NA #6 Rams NA ACCUMULATOR SYSTEM: Choke Ln. Valves NA Time/Pressure Test Result HCR Valves NA System Pressure (psi)NA Kill Line Valves NA Pressure After Closure (psi)NA Check Valve NA 200 psi Attained (sec)NA BOP Misc NA Full Pressure Attained (sec)NA Blind Switch Covers:All stations NA CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves NA ACC Misc 0 NA Manual Chokes NA Hydraulic Chokes NA Control System Response Time:Time (sec)Test Result CH Misc NA Annular Preventer 17 P #1 Rams 15 P Coiled Tubing Only:#2 Rams 0 NA Inside Reel valves NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:1.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/11/23 07:15 Waived By Test Start Date/Time:3/15/2023 13:30 (date)(time)Witness Test Finish Date/Time:3/15/2023 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Doyon Changed Ram #1 to 9-5/8". Test Annular 250/3500 f/ 5/10 min w/ 9-5/8" test joint. Test Ram #1 w/ 9 5/8 test joint 250/3500 psi f/ 5/10 min. BLM Rep. waved witness E. Potter / C. Bali CPAI J.Benedict/ Percy Angelle GMTU MT7-11 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0315_BOP_Doyon25_ram-change_GMTU_MT7-11 J. Regg; 6/14/2023 MT7-11 3/15/2023 250 Low for 5 min – 3500 High for 10 min 9 5/8” Test Jt 1. Annular Preventer ( 250 low / 3500 high) 2. Upper rams 9 5/8” STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-11 JBR 04/06/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Issues with one H2S alarm. Had to reboot system to get it to work corectly. Good test. Test Results TEST DATA Rig Rep:evert PotterOperator:ConocoPhillips Alaska, Inc.Operator Rep:J Benedict Rig Owner/Rig No.:Doyon 25 PTD#:2230020 DATE:3/9/2023 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopRCN230310121304 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 2923 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 P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8" x 5 1/2 P #2 Rams 1 blinds P #3 Rams 1 2 7/8" x 5 1/2 P #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"P Check Valve 0 none NA BOP Misc 0 none NA System Pressure P2950 Pressure After Closure P1575 200 PSI Attained P18 Full Pressure Attained P107 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6 @ 1917 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P FPH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P19 #1 Rams P16 #2 Rams P14 #3 Rams P14 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9999 9 9 Issues with one H2S alarm. MT7-11 3/9/2023 250 Low for 5 min – 5000 High for 10 min 5” Test Jt 1.Annular Preventer ( 250 low / 3500 high) 2.Upper 2 7/8” x 5 ½ VRB’s, Valves: # 1, 13, 14, 15, 4” Kill Valve, 5” Dart 3.Valves: # 2, 10, 12, HCR Kill, 5” FOSV # 1 4.Valves: # 6, 9 ,11, Manual Kill, 5” FOSV # 2 5.Valves: # 5, 7, 8 6.Valve:3 and UIBOP 7.HCR choke, LIBOP 8.Manual Choke 9.Lower Pipe Rams 2 7/8” x 5 ½” VRB’s 10.Blind Rams, Valve: #4 11.Manual and super chokes 'R\RQ%23(WHVW %PZPO#01&5FTU (.56.5 15% "0($$*OTQ3QUCPQ3$/ %PZPO#01&5FTU (.56.5 15% "0($$*OTQ3QUCPQ3$/ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Manager ConocoPhillips Alaska, LLC PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Rendezvous Pool, MT7-11 ConocoPhillips Alaska, LLC Permit to Drill Number: 223-002 Surface Location: 919' FSL, 1771' FWL, SESW, Sec. 32, T10N, R2E, UM Bottomhole Location: 701' FSL, 4590' FWL, SWNW, Sec. 35, T10N, R1E, 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 February, 2023. 23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.22 15:24:46 -09'00' 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 24,480 TVD: 8224 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: 2/16/2023 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 9994' to AA081804 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 139.5 15. Distance to Nearest Well Open Surface: x- 289848 y- 5915745 Zone- 4 100.7 to Same Pool: 1149' to MT7-09 16. Deviated wells:Kickoff depth: 600 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42 20 94 H-40 Welded 80 40 40 120 120 16 13-3/8" 68 L-80 Hyd563 3777 40 40 3777 3032 12-1/4" 9-5/8" 43.5 / 47.0 L-80 Hyd563 12446 40 40 12446 7371 8.5" x 9-7/8"7" 26.00 L-80 Hyd563 2598 12296 7295 14894 8291 6-1/8" 4.5" 12.60 L-80 Hyd563 9736 14744 8269 24480 8224 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:Brad Gorham Chris Brillon Contact Email:Brad.Gorham@conocophillips.com Wells Engineering Manager Contact Phone:907-265-6487 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 418 sx 15.8 ppg Class G Uncemented liner w/frac sleeves & swell packers Effect. Depth MD (ft):Effect. Depth TVD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Conductor/Structural LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) Cement to surface with 10 yds slurry 1231 sx 11.0 ppg Deepcrete + 330 sx 15.8 ppg Class G 3776, 5720, 5756, 5756 18. Casing Program:Top - Setting Depth - BottomSpecifications 3752 Total Depth MD (ft):Total Depth TVD (ft): 59-52-180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 577 sx 13.0 ppg Ext Class G + 730 sx 15.8 ppg Class G 2923 3604' FSL, 5109' FWL , SWNW S12 T9N R1E, UM 701' FSL, 4590' FWL, SWNW S35 T10N R1E, UM 932535000, 932516000, 932519000, 932538000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips 919' FSL, 1771' FWL, SESW S32 T10N R2E, UM AA081800, AA081781, AA081784, AA081803 MT7-11 Greater Mooses Tooth Rendezvous Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. s N ype of W L l R L 1b S Class: os N s No s N o D s s s D 0 o well is p G S S 20 S S S s No s No S G y E S s No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Meredith Guhl at 2:51 pm, Jan 11, 2023 223-002 50-103-20850-00-00 X VTL 02/16/2023 X X DSR-1/12/23 X X XInitial BOP test to 5000 psig Subsequent BOP test to 3500 psig Annular preventer test to 2500 psig BOP test to 3000 psig approved while drilling the Int I section The alternate BOP configuration(Section 16, this PTD) while drilling the Int 1 is approved. Diverter variance granted per 20 AAC 25.035(h)(2) Waiiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 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. DLB 01/25/2023 X 2/28/2023 X X DLB GCW 02/22/23 JLC 2/22/2023 2/22/23 2/22/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.02.22 15:25:15 -09'00' GMT MT7-11 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 -DQXDU\ &(57,),('0$,/± 5(78515(&(,375(48(67(' 0U/XNH/DZUHQFH :HOOV0DQDJHU &RQRFR3KLOOLSV$ODVND *6WUHHW $QFKRUDJH$. 5H 'RFNHW1XPEHU 27+ $SSOLFDWLRQIRU:DLYHURQ&3$,5RWDU\ 5LJ%23(7HVW)UHTXHQF\ 'HDU0U/DZUHQFH %\OHWWHUGDWHG0D\&RQRFR3KLOOLSV$ODVND,QF &3$, UHTXHVWHGDZDLYHUIURPWKH $ODVND 2LO DQG *DV &RQVHUYDWLRQ &RPPLVVLRQ¶V $2*&& UHJXODWRU\ UHTXLUHG EORZRXW SUHYHQWLRQHTXLSPHQW %23( WHVWIUHTXHQF\IRUDOO&3$,URWDU\GULOOLQJULJVSHWLWLRQLQJWRWHVW WKHEORZRXWSUHYHQWLRQHTXLSPHQW %23( RQDGD\WHVWVFKHGXOH$2*&&JUDQWVDSSURYDO IRUOLPLWHGGXUDWLRQDQGVFRSH &3$,PHWZLWK$2*&&RQ$SULOVXPPDUL]HGLWVREMHFWLYHLQUHTXHVWLQJDSSURYDORID GD\%23(WHVWVFKHGXOH LPSURYH&3$,¶VDELOLW\WRFRPSHWHIRUFRUSRUDWH FDSLWDOLQYHVWPHQWV H[SODLQHGDOLJQPHQWZLWKLQGXVWU\VWDQGDUG%23(WHVWFULWHULD DQG&RQRFR3KLOOLSVJOREDOZHOO FRQWUROSROLF\DQGSURYLGHGDQRYHUYLHZRIQHZGULOOLQJWDUJHWVSODQQHGXVLQJD³KLJKVSHF H[WHQGHGUHDFKGULOOLQJULJ´&3$,DOVRSURYLGHGGHWDLOVDERXWWKHVFRSHDQG%23(SHUIRUPDQFH DFKLHYHPHQWV XQGHU LWV %HWZHHQ :HOO 0DLQWHQDQFH 3URJUDP %:0 IRU URWDU\ GULOOLQJ DQG ZRUNRYHUULJV $VZLWKSUHYLRXVUHTXHVWVWRH[WHQGWKH%23(WHVWLQWHUYDO&3$,UHIHUHQFHVQXPHURXVUHJXODWRU\ MXULVGLFWLRQVDVZHOODVVXJJHVWHGLQGXVWU\SUDFWLFHIURPWKH$PHULFDQ3HWUROHXP,QVWLWXWHUHODWLQJ WR WHVW IUHTXHQF\ HDFK SURYLGLQJIRU %23( WHVWLQJ DW LQWHUYDOV EH\RQG GD\V &3$, DOVR UHIHUHQFHVLWVLQWHUQDOZHOOFRQWUROPDQXDOZKLFKDOORZVIRUWHVWLQJDWLQWHUYDOVEH\RQGGD\V ϭW/^ƚĂŶĚĂƌĚϱϯ͕͞tĞůůŽŶƚƌŽů ƋƵŝƉŵĞŶƚ^LJƐƚĞŵƐĨŽƌƌŝůůŝŶŐtĞůůƐ͕͟ϱƚŚ ĚŝƚŝŽŶ;ĞĐĞŵďĞƌϮϬϭϴͿ ϮK'ĂƉƉƌŽǀĂůŽĨƚŚĞtDƉƌŽŐƌĂŵŚĂƐĞŶĂďůĞĚW/ǁŽƌŬŽǀĞƌƌŝŐƐƚŽĞdžƚĞŶĚƚŚĞŝŶƚĞƌǀĂůďĞƚǁĞĞŶKW ƚĞƐƚƐ ĨƌŽŵĞǀĞƌLJϳĚĂLJƐƚŽŶŽƚĞdžĐĞĞĚŝŶŐϭϰĚĂLJƐ͘W/ĚĂƚĂƐŚŽǁƐƚŚĞtDŚĂƐƌĞĚƵĐĞĚƚŚĞŶƵŵďĞƌŽĨĐŽŵƉŽŶĞŶƚ ĨĂŝůƵƌĞƐĚƵƌŝŶŐKW ƚĞƐƚŝŶŐďLJƌĞƉůĂĐŝŶŐĐŽŵƉŽŶĞŶƚƐƚŚĂƚŝŶĚŝĐĂƚĞƐƵƐƉĞĐƚŝŶƚĞŐƌŝƚLJďĞĨŽƌĞƚŚŽƐĞĐŽŵƉŽŶĞŶƚƐĨĂŝů ĚƵƌŝŶŐƚĞƐƚŝŶŐ͘ 'RFNHW1XPEHU 27+ &3$,±GD\%23(7HVW,QWHUYDO -DQXDU\ ,PSURYHPHQW LQ %23( SHUIRUPDQFH WHVWLQJ UHVXOWV DWWULEXWHG WR &3$,¶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¶VUHTXHVWIRUD YDULDQFHIURPUHJXODWRU\UHTXLUHPHQWV RI$$& H $ LV DSSURYHGIRUGULOOLQJULJV'R\RQDQG'R\RQDVDSLORWSURMHFWZLWKWKHIROORZLQJFRQGLWLRQV 7KHSLORWWHVWGXUDWLRQLVIRU21( \HDU IURPWKHDSSURYDOGDWHRIWKLVOHWWHUVXEMHFWWR SRWHQWLDOH[WHQVLRQDQG H[SDQVLRQWRLQFOXGHRWKHU&3$,RSHUDWHGULJVZLWK DWOHDVW PRQWKVRIFRQWLQXRXVULJZRUNDQG$2*&&UHYLHZRIDULJ¶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eremy Price Digitally signed by Jeremy Price Date: 2022.01.25 13:00:50 -09'00' ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 9, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-11 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 02/25/2023. It is intended that Doyon 25 be used to drill the well. MT7-11 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 inerval. The 8-1/2" x 9-7/8" intermediate 2 section will be drilled and landed in the Alpine D. A 7” liner string will be set and cemented from TD to seccure the shoe and cover 500’ MD or 250’ TVD above any hydrocarbon bearing zone. The production interval will be comprised of a 6-1/8" x 6-5/16" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as an injector with 4.5” liner with frac sleeves and swell packers. The upper completion will include a production packer with GLM’s and tied back to surface. It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) 7. Area of Review Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Brad Gorham at 907-265-6487 (Brad.Gorham@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com). Sincerely, cc: MT7-11 Well File / Jenna Taylor ATO 1732 Dave Lee ATO 1552 Brad Gorham Chris Brillon ATO 1548 Drilling Engineer Andy Mack Kuukpik Corp Concur DLB It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there hasqq()() g not been a significant indication of shallow gas or gas hydrates through the surface hole interval. MT7-11 Saved: 10-Jan-23 MT7-11 Page 1 of 18 Printed: 10-Jan-23 MT7-11 Well Plan Application for Permit to Drill Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................ 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ..................................................................... 2 3. Proposed Drilling Program .................................................................................................................. 4 5. MASP Calculations ............................................................................................................................... 7 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ....... 8 7. Casing and Cementing Program ......................................................................................................... 9 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .............................................................. 10 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ..................... 11 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .................................................................... 11 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................................... 11 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................. 11 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ................................................. 11 (Requirements of 20 AAC 25.005 (c)(14)) ......................................................................................................... 11 14. Drilling Hazards Summary ................................................................................................................. 13 15. Proposed Completion Schematic ...................................................................................................... 15 16. MT7-11 Intermediate 1 MPSP Review & Ram Configuration .......................................................... 16 MT7-11 Saved: 10-Jan-23 MT7-11 Page 2 of 18 Printed: 10-Jan-23 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-11 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 919' FSL, 1771' FWL, SESW S32 T10N R2E, UM NAD27 Northings: 5915745.06 Eastings: 289847.70 RKB Elevation 38.8’ AMSL Pad Elevation 100.7’ AMSL Top of Productive Horizon (Heel) 3604' FSL, 5109' FWL , SWNW S12 T9N R1E, UM NAD27 Northings: 5908073.33 Eastings: 282539.00 Measured Depth, RKB: 14,843’ Total Vertical Depth, RKB: 8,284.4’ Total Vertical Depth, SS: 8,144.9’ Total Depth (Toe) 820' FSL, 2941' FWL, SWNW S26 T10N R1E, UM NAD27 Northings: 59121339.42 Eastings: 275468.98 Measured Depth, RKB: 28,379’ Total Vertical Depth, RKB: 8,162.1’ Total Vertical Depth, SS: 8,022.6’ Please see attached well stick diagram for the current planned development of the pad. MT7-11 Saved: 10-Jan-23 MT7-11 Page 3 of 18 Printed: 10-Jan-23 Pad Layout Well Stick Diagram MT7-11 Saved: 10-Jan-23 MT7-11 Page 4 of 18 Printed: 10-Jan-23 MT7-11 Saved: 10-Jan-23 MT7-11 Page 5 of 18 Printed: 10-Jan-23 3. Proposed Drilling Program 1. MIRU Doyon 25 onto well over pre-installed 20” insulated conductor. Install diverter and function test. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan, with KSI WBM. (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” FBR’s, blind ram and 2-7/8” x 5-1/2” VBR’s. x See section 16 for ram configuration justification. 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. 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. Minimum LOT required to drill ahead is 11.5 ppg EMW. 11. Displace well to 12 PPG WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and POOH. 14. Run 9-5/8” intermediate 1 casing to TD. 15. Pump single stage cement job to isolate the casing shoe or 500’ MD above uppermost hydro-carbon bearing zone. Note that a shallower hydrocarbon bearing sand may be encountered, and a 2nd stage cement job will be completed if the one is detected while drilling. Results of the cement operation will be submitted as soon as possible. a. 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. 16. Change upper 9-5/8” solid body rams to 2-7/8” x 5-1/2” VBR’s. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 17. Pick up and run in hole with 8-1/2" x 9-7/8” drilling BHA to drill intermediate hole. SimOps, perform 9-5/8 ” annulus LOT with Ball mill and freeze protect. 18. Chart casing pressure test to 3,500 psi for 30 minutes. 19. Drill out shoe track and 20’ of new hole. 20. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 11.0 ppg EMW. 21. Drill 8-1/2" x 9-7/8” hole to section TD. a. As an identified contingency plan: If Casing Drilling is required due to Geologic Instability in Intrm 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). MT7-11 Saved: 10-Jan-23 MT7-11 Page 6 of 18 Printed: 10-Jan-23 4. Land 7” liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. 5. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparations for cementing. 6. Cement 7” liner to top of liner. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5” drill pipe. 7. Continue to Step 28 below. 22. Circulate wellbore clean and POOH. 23. Change out upper rams to 4” x 7” VBRs. Test same to 250 psi low / 3,500 psi high. 24. Pick up and run in hole with the 7” liner on 5” DP to section TD 25. Circulate and condition mud in preparations for cementing. 26. Cement 7” liner to required TOC. Set liner top packer. POOH laying down 5” drill pipe. Results of the cement operation will be submitted as soon as possible. 27. Change out upper rams to 2-7/8” x 5-1/2” VBRs. Test same to 250 psi low / 3,500 psi high. 28. Pick up 4” DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 29. Pick up and RIH with 6-1/8” drilling assembly. (LWD Program: GR/Azimuthal RES). 30. Displace well to Flopro WBM. Chart casing pressure test to 3,500 psi for 30 minutes and record results. 31. Drill out and perform FIT to 13.5 PPG EMW maximum. Minimum acceptable leak-off for drilling ahead is 10.30 ppg EMW. 32. Drill 6-1/8" horizontal hole to section TD (LWD Program: GR/Azimuthal RES/Den/Neu) 33. Circulate the hole clean and POOH. 34. Run 4.5” liner on 4” DP, set liner hanger and packer. Chart casing pressure test 3,5000 psi. POOH LD DP. 35. Run 4-1/2” tubing with production packer, DHG, GLMs and 2x landing nipples. Locate and space out tubing. Terminate TEC wire and land tubing hanger. 36. Pressure test hanger seals to 2500 psi. 37. Drop ball & rod, pressure up and set production packer. 38. Pressure test tubing and IA and shear SOV. 39. Install BPV. ND BOPE and install tubing head adapter. Pressure test adapter to 5000 psi. 40. Install 10k frac tree and test. 41. Remove BPV and freeze protect well. 42. Secure well and RDMO. 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP and diverter schematics on file for Doyon 25 MT7-11 Saved: 10-Jan-23 MT7-11 Page 7 of 18 Printed: 10-Jan-23 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Depth Fracture Gradient Pore Pressure ASP Drilling MD TVD ppg psi psi 20 120 120 10.9 54 56 13.375 3777 3032 14.5 1372 1983 9.625 12446 7371 16.5 3335 2923 7 14894 8291 12.5 3752 2877 4.5 28379 8162 12.5 3693 n/a 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: 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 ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 120 = 56 psi OR ASP = FPP – (0.1 x D) = 1372 – (0.1 x 3032’) = 1069 psi MT7-11 Saved: 10-Jan-23 MT7-11 Page 8 of 18 Printed: 10-Jan-23 Minimum MW needed = 8.7 PPG Drilling below 13.375” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3032’ = 1983 psi OR ASP = FPP – (0.1 x D) = 3335 – (0.1 x 7371) = 2598 psi Minimum MW needed = 8.8 PPG Drilling below 9.625" intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 7371 = 5587 psi OR ASP = FPP – (0.1 x D) = 3752 – (0.1 x 8291’) = 2923 psi Minimum MW needed = 8.7 PPG Drilling below 7” production liner ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8224 = 4560 psi OR ASP = FPP – (0.1 x D) = 3693 – (0.1 x 8162) = 2877 psi Minimum MW needed = 8.8 PPG (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (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. Minimum MW needed = 8.8 PPG Minimum MW needed = 8.8 PPG Minimum MW needed = 8.7 PPG DLB Minimum MW needed = 8.7 PPG MT7-11 Saved: 10-Jan-23 MT7-11 Page 9 of 18 Printed: 10-Jan-23 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 16 68 L-80 Hyd563 Cement to Surface 9.625 12.25 43.5/47 L-80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7 8.5 x 9.875 26 L-80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 4.5 6.125 12.6 L-80 Hyd563 Uncemeneted open hole liner with frac ports and swell packers 13.375” Surface Casing run to 3,777’ MD / 3,032’ TVD Cement Plan: Cement from 3,777’ MD to 3,277’ (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3,277' 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. Tail slurry from 3777'MD to 3277 with Class G @ 15.8 ppg Total Volume = 383 ft3 => 330 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk Lead slurry from 3277' MD to surface with DeepCRETE @ 11 ppg Total Volume = 915 ft3 => 1231 sx of 11 ppg DeepCRETE + Add's @ 1.92 ft3/sk 9.625” Intermediate Casing run to 12,446’ MD / 1’ TVD Cement Plan: Primary cement job consists of 2000 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 7,752’ 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 10446' MD to 7752' MD with Extended Class G @ 13.0 ppg Total Volume = 1097 ft3 => 577 sx of 13.0 ppg Extended Class G + Add's @ 1.9 ft3/sk Tail slurry from 12446' MD to 10446' MD with Class G @ 15.8 ppg Total Volume = 847 ft3 => 730 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 7” Intermediate Liner run to 14,894’ MD / 8,291’ TVD Cement Plan: Top of slurry is designed to be at 13,880’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Alpine D. Assume 40% excess annular volume. MT7-11 Saved: 10-Jan-23 MT7-11 Page 10 of 18 Printed: 10-Jan-23 Tail slurry from 14894' MD to 13880' MD with Class G @ 15.8 ppg Total Volume = 485 ft3 => 418 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Intermediate #2 Production Hole Size in. 16 12.25 8.5 x 9.875 6.125 Casing Size in. 13.375 9.625 7 4.5 Density PPG 10.5 – 11.5 10.0 – 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 N/A N/A 4 HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 5.0 10.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A fresh water drilling fluid (KSI) will be used for the surface interval. Keep flow line viscosity at r 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 10-12.0 ppg and be prepared to add loss circulations materials as needed. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as needed) will all be important in maintaining wellbore stability. Intermediate #2: Versapro OBM will continue be used in this section for shale stability purpose. 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 from 10.0-12.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up before pulling out of the hole. 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. DLB Drilling Fluid Program Density PPG 10.5 – 11.5 10.0 – 12.0 10.0 – 13.0 8.8 – 9.5 MT7-11 Saved: 10-Jan-23 MT7-11 Page 11 of 18 Printed: 10-Jan-23 Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT7-11 will be injected into a permitted annulus on the MT7 pad, or hauled to the Class 1 disposal well on CD1. The MT7-11 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 MT7-11 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. 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) * (3032’) + 1,500 psi = 3391 psi Pore Pressure = 1,372 psi Therefore Differential = 3391– 1,372 = 2019 psi. MT7-11 Saved: 10-Jan-23 MT7-11 Page 12 of 18 Printed: 10-Jan-23 The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 13.375” 68 L-80 3 Hyd563 2260 psi 1921 psi 5020 psi 4267 psi 9.625” 43.5 / 47 L-80 3 Hyd563 3810 psi 3238 psi 6330 psi 5380 psi MT7-11 Saved: 10-Jan-23 MT7-11 Page 13 of 18 Printed: 10-Jan-23 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Surface Formations Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running speeds 12.25” Hole / 9.625” Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8.5x9.875” Hole / 7” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT7-11 Saved: 10-Jan-23 MT7-11 Page 14 of 18 Printed: 10-Jan-23 6.125” Hole / 4.5” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT7-11 Saved: 10-Jan-23 MT7-11 Page 15 of 18 Printed: 10-Jan-23 15. Proposed Completion Schematic MT7-11 Saved: 10-Jan-23 MT7-11 Page 16 of 18 Printed: 10-Jan-23 16. MT7-11 Intermediate 1 MPSP Review & Ram Configuration Proposal Requesting approval to use a BOPE stack equipped with an annular preventer, fixed 9-5/8” solid body rams, blind/shear rams and, variable rams (2-7/8” x 5-1/2”) while drilling and running casing in the Intermediate 1 section of MT7-11. The Maximum Potential Surface Pressure (MPSP) is expected to be 1,983 psi while drilling the 12-1/4” Intermediate 1 hole section with 5” drill pipe, satisfying 20 AAC 25.035.e.1.A. Please find the review below for more detail. 20 AAC 25.035.e.1.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sixed to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Proposed Configuration: x Annular Preventer (iii) x 9-5/8” Solid Body Rams x Blind/Shear Rams (ii) x 2-7/8” x 5-1/2” VBR’s (i) MT7-11 Saved: 10-Jan-23 MT7-11 Page 17 of 18 Printed: 10-Jan-23 Pore Pressure Assessment A Normal Compaction Trend (NCT) is defined using the Bowers Method on a calibration well with little/no erosion and global constants as a starting point. Both source rock and non-source rock NCTs are then defined. For a given unit/zone, deviations slower than NCT indicate overpressure and allow calculation of its magnitude. The NCT for individual wells is defined by modifying Bowers parameters to account for specific erosion amounts. The maximum estimated reservoir pressure in the Intermediate 1 section is 9.4 ppg Interval TVD Top TVD Base Max PPG Note Surface to Permafrost_Base 0 977 8.3 Hydrostatic Permafrost_Base to C40 977 1079 9.1 Hydrostatic C40 to C30 1079 1405 9.2 Rendezvous-2 DT Estimate C30 to C20 1405 1642 8.45 Hydrostatic C20 to C10 1642 1986 8.475 Hydrostatic C10 to K3 1986 2999 9.3 Rendezvous-2 DT Estimate K3 to Albian_97 2999 3607 8.55 Hydrostatic Albian_97 to Albian_96 3607 3788 8.56 Hydrostatic Albian_96 to Albian_95 3788 3972 8.56 Hydrostatic Albian_95 to Albian_94 (Tusk Sand if present) 3972 4240 8.56 Hydrostatic Albian_94 to Albian_93 4240 4895 8.57 Hydrostatic Albian_93 to Albian_92 4895 6061 8.6 Hydrostatic Albian_92 to Albian_91 6061 6121 8.6 Hydrostatic Albian_91 to HRZ (Susitna Sand if present) 6121 7396 9.4 Offset Well DT/ Res Estimates HRZ to LCU 7396 7591 11.6 Offset Well DT/ Res Estimates LCU to Alpine_D 7591 8237 11.75 Offset Well DT/ Res Estimates Alpine_D to Alpine_C 8237 8263 11.4 MT7-04 Res Est. Alpine_C to UJU 8263 8359 8.8 Offset MDT’s MT7-11 Saved: 10-Jan-23 MT7-11 Page 18 of 18 Printed: 10-Jan-23 Maximum Potential Surface Pressure Surface Casing Point:3777' MD/ 3032' TVD Intermediate 1 Casing Point:12446' MD/ 7371' TVD Max Anticipated Pore Pressure:9.4 ppg | Albian 91 > HRZ Surface Casing Shoe FG:14.5 ppg EMW | K3 Maximum Potential Surface Pressure (MPSP) is determined as the lesser of 1.) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2.) formation pore pressure at the next casing point less a gas gradient to the surface as follows: Method 1 Method 2 Where: FG – Fracture gradient at the casing seat in lb/gal 0.052 –Conversionfromlb/galtopsi/ft Gas Gradient –0.1 psi/ft TVD – True Vertical Depth of casing seat in ft RKB Where: FPP –Formation Pore Pressure at the next casing point MPSP CALCULATIONS: Method 1: MPSP = [(FG x 0.052) – Gas Gradient] x TVD MPSP = [(14.5 ppg EMW x 0.052) - 0.1] x 3032’ MPSP =1983psi Method 2: MPSP = FP – (Gas Gradient) x TVD MPSP =(9.4 ppg x 0.052 x 73741’ ) – (0.1 x 7371’ ) MPSP = 2865 psi Attachment 1 – MT7-11 Area of Review (AOR) An Area of Review plot is show below of the MT7-11 Injector planned wellpath and offset wells. MT7-09 is the only offset well from the planned MT7-11 injector. Well Name Status Top of Alpine Pool (MD/TVD) TOC (MD/TVD) TOC – Determined By Reservoir Status Zonal Isolation Cement Operations Summary MT7-09 Producing 13,979’ / 8,269’ 12,474’ / 7,756’ Sonic Log Liner TOC and Packer 88 bbls of 15.8 ppg Class G MT7-09 intermediate 2 section was drilled and cased with 7” liner down to 14,121’ MD in the Alpine D. The Alpine C zone was penetrated at 14,155’ MD. The intermediate liner was cemented to isolate the Alpine pool with 88 bbls of Class G cement (plugs bumped and floats held) and top of cement was measured with a Sonic LWD at 14,474’. A horizontal production section was drilled in the Alpine C to 21,697’ MD and completed with a liner. 39 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3800 3800 28379 MT7-11_wp04 Plan Summary MT7-11_wp04 MT7-01 MT7-01PB1 MT7-02 MT7-03 MT7-04 MT7-05 MT7-06 MT7-06AMT7-06PB1 MT7-07 MT7-08PB1 MT7-09 MT7-96 MT7-98 MT7-99 MT7-97_wp03 0 4 Dogleg Severity0 4000 8000 12000 16000 20000 24000 28000 Measured Depth Surface INT1 INT2 PROD 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 5987959911182 MT7-05 39199399598 793 MT7-06 39199399598 793 MT7-06A 39199399598 793 MT7-06PB1 39199399598796995118913821573 MT7-07 39200 400 597 790 MT7-08 39200 400 597 790 MT7-08PB1 39 198398598 79699511911386 15811774 19672159 MT7-09 0 4500 True Vertical Depth-2000 0 2000 4000 6000 8000 10000 Vertical Section at 333.00° Surface INT1 INT2 PROD 0 50 100 Centre to Centre Separation0 3250 6500 9750 13000 16250 19500 22750 Measured Depth MT7-06 MT7-06A MT7-06PB1 MT7-07 MT7-08 MT7-09 Equivalent Magnetic Distance DDI 7.377 SURVEY PROGRAM Date: 2022-11-01T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 38.80 1000.00 MT7-11_wp04 (MT7-11) SDI_Keeper_ADK 1000.00 2000.00 MT7-11_wp04 (MT7-11) MWD OWSG 2000.00 3776.00 MT7-11_wp04 (MT7-11) MWD+IFR2+SAG+MS 3776.00 4077.00 MT7-11_wp04 (MT7-11) MWD-INC_ONLY (INC>10°) 4077.00 5077.00 MT7-11_wp04 (MT7-11) MWD OWSG 5077.00 12446.00 MT7-11_wp04 (MT7-11) MWD+IFR2+SAG+MS 12446.00 12746.00 MT7-11_wp04 (MT7-11) MWD-INC_ONLY (INC>10°) 12746.00 13746.00 MT7-11_wp04 (MT7-11) MWD OWSG 13746.00 14894.00 MT7-11_wp04 (MT7-11) MWD+IFR2+SAG+MS 14894.00 15020.00 MT7-11_wp04 (MT7-11) MWD-INC_ONLY (INC>10°) 15020.00 16020.00 MT7-11_wp04 (MT7-11) MWD OWSG 16020.00 28378.99 MT7-11_wp04 (MT7-11) MWD+IFR2+SAG+MS Surface Location North / 5915489.18 East / 1429883.83Ground / 100.70 CASING DETAILS TVD MD Name 3031.69 3776.00 Surface 7371.72 12446.00 INT1 8291.76 14894.00 INT2 8162.10 28379.29 PROD Mag Model & Date: BGGM2022 01-Mar-23 Magnetic North is 14.17° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.35° 57100.35nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 38.80 0.00 0.00 38.80 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 3 700.00 3.00 182.00 699.91 -5.23 -0.18 1.50 182.00 -4.58 4 1000.00 9.00 182.00 998.13 -36.56 -1.28 2.00 0.00 -31.99 5 3133.09 60.00 222.25 2710.23 -954.23 -677.68 2.50 44.24 -542.56 6 11913.09 60.00 222.25 7100.23 -6582.63 -5790.16 0.00 0.00 -3236.49 7 12395.68 59.06 236.21 7345.85 -6853.40 -6103.83 2.50 98.00 -3335.34 8 12445.68 59.06 236.21 7371.56 -6877.24 -6139.48 0.00 0.00 -3340.41 9 12495.68 59.06 236.21 7397.26 -6901.09 -6175.12 0.00 0.00 -3345.47 10 14843.54 81.72 308.32 8284.50 -6716.94 -8182.90 3.00 88.00 -2269.88 11 14893.54 81.72 308.32 8291.70 -6686.26 -8221.72 0.00 0.00 -2224.92 12 14943.54 81.72 308.32 8298.90 -6655.58 -8260.54 0.00 0.00 -2179.96 13 15522.80 87.84 324.66 8351.94 -6238.58 -8655.86 3.00 70.30 -1628.94 14 15657.11 87.84 324.66 8357.01 -6129.11 -8733.49 0.00 0.00 -1496.15 15 15980.29 90.92 333.00 8360.53 -5852.87 -8900.58 2.75 69.80 -1174.17 16 24480.29 90.92 333.00 8224.50 1719.58 -12759.27 0.00 0.00 7324.74 17 28379.29 90.92 333.00 8162.10 5193.11 -14529.27 0.00 0.00 11223.25 FORMATION TOP DETAILS TVDPath Formation 979.50 Perma_Frost 1074.50 C40 1410.50 C30 1645.50 C20 1990.50 C10 3006.50 K3 3031.50 SCP 3607.50 Albian_97 3792.50 Albian_96 3967.50 Albian_95 4372.50 Albian_94 4832.50 Albian_93 5270.50 Sub_93 6148.50 Albian_92 6312.50 Albian_91 6461.50 Susitna 7345.50 HRZ 7371.50 INT1 7640.50 LCU 8284.50 Alpine_D 8291.50 INT2 8321.50 Alpine_C By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Doyon25 Plan KB @ 139.50usft Plan View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-11Wellbore: MT7-11Design: MT7-11_wp04-20000-10000010000South(-)/North(+) (5000 usft/in)-20000 -10000 0 10000 20000West(-)/East(+) (5000 usft/in)MT7-11 Heel - 1320ftMT7-11 Toe - 1320ftMT7-01MT7-01PB1MT7-02MT7-03MT7-04MT7-05MT7-06MT7-06AMT7-06PB1MT7-07MT7-08MT7-08PB1MT7-09MT7-96MT7-98MT7-99MT7-97_wp03SurfaceINT1INT2PRODMT7-11_wp04 040008000True Vertical Depth (2000 usft/in)-4000 0 4000 8000 12000Vertical Section at 333.00° (2000 usft/in)SurfaceINT1INT2PROD10002000300040005000600070008000900010000110001200013000140001500016000 17 00 0 18000 19000 20000 21000 22000 23000 24000 25000 26000 27000 28000MT7-11/MT7-11_wp04Start Build 1.50Start DLS 2.00 TFO 0.00Start DLS 2.50 TFO 44.24Start 8780.00 hold at 3133.09 MDStart DLS 2.50 TFO 98.00Start DLS 3.00 TFO 88.00Start DLS 3.00 TFO 70.30Start 134.30 hold at 15522.80 MDStart DLS 2.75 TFO 69.80Start 8500.00 hold at 15980.29 MDStart 3899.00 hold at 24480.29 MDSection View Project: Western North SlopeSite:GMT2 Rendezvous PadWell: MT7-11Wellbore: MT7-11Design: MT7-11_wp04 ! 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('881%'81 ('%& '& 4'( !'%! 4'% @A @ +@ = > 51(('(( &('& %%%'(( 45 !'& 1%'4! ('1 %1'%& ('881%'&1 ('%& '& 44'&1!'4( &'&% @A @ +@ = > 5!(('(( &('& %%%'(( 45 !8'& 11'! ('1 %8'(1 ('8811' 1 ('%& '& &('&4! '% %'(4 @A @ +@ = > 58(('(( &('& %%%'(( 45 !1'!& 11'1! ('1 %'8& ('8811'!1 ('%& '& &%'1! '48 % '& @A @ +@ = > 5(('(( &('& %%%'(( 45 ! '&& 11'! ('1 %&'%! ('8811'41 ('%& '& &!'1!%'14 %%' % @A @ +@ = > 54(('(( &('& %%%'(( 45 !'%& 1!'(8 ('1 1'( ('881!'! ('%& '& &'8!1' %1' @A @ +@ = > 5&(('(( &('& %%%'(( 45 1&'& 1!'% ('1 1 '84 ('881!'18 ('%& '& (('4!1'& %!'1 @A @ +@ = > %5((('(( &('& %%%'(( 45 14'& 1!'84 ('1 11'%8 ('881!' ('%& '& ( '8 !!'! %8'(( @A @ +@ = > %5(('(( &('& %%%'(( 45 18'!& 18'(( ('1 18'(1 ('8818'(& ('%& '& (!'(8!8'8! %8'& @A @ +@ = > %5 (('(( &('& %%%'(( 45 11'&& 18'% ('1 1' ('8818'1 ('%& '& ('18!'8 %'! @A @ +@ = > %5%(('(( &('& %%%'(( 45 1%'%& 18'81 ('1 1&'1( ('8818'% ('%& '& (&'4(!4'8! %4' @A @ +@ = > %51(('(( &('& %%%'(( 45 1'& 18'&8 ('1 !'(& ('881'(! ('%& '& '(1!&'! %4' @A @ +@ = > %5!(('(( &('& %%%'(( 45 1('& 1' 4 ('1 ! '& ('881'% ('%& '& 1'8('& %&'% @A @ +@ = > %58(('(( &('& %%%'(( 45 %4'!& 1'8 ('1 !1'14 ('881'( ('%& '& 8'48 '1 %&'& @A @ +@ = > %5(('(( &('& %%%'(( 45 %8'&& 1'&1 ('1 !8'& ('8814'( ('%& '& 4'(88%'1 1(' % @A @ +@ = > %54(('(( &('& %%%'(( 45 %!'%& 14' ('1 !'4& ('8814'%! ('%& '& &'4(81'% 1('8% @A @ +@ = > %5&(('(( &('& %%%'(( 45 %%'& 14'8( ('1 !&'8( ('8814'8& ('%& '& '1 88'(& 1('&4 @A @ +@ = > 15((('(( &('& %%%'(( 45 % '& 14'&% ('1 8'% ('881&'( ('%& '& '&8'1& 1'% @A @ +@ = > 15(('(( &('& %%%'(( 45 %('!& 1&' ('1 8%'( ('881&'%8 ('%& '& 1' &84'& 1'8( @A @ +@ = > 15 (('(( &('& %%%'(( 45 4'&& 1&'8 ('1 81'1 ('881&'8& ('%& '& !'!!('%& 1'48 @A @ +@ = > 15%(('(( &('& %%%'(( 45 '%& 1&'&! ('1 88'18 ('88!('(% ('%& '& 8' '44 1 ' @A @ +@ = > 151(('(( &('& %%%'(( 45 !'& !(' & ('1 84'& ('88!('% ('%& '& '4(%'%& 1 '%% @A @ +@ = > 1514(' & &('& %%%'(( 45 1'!( !('!8 ('1 8&'! ('88!('8! ('%& '& 4'8(1'8 1 '1& @A @ +@ = > 15!(('(( &('& %%%'(( 45 1'4 !('8% ('1 8&'& ('88!(' ('%& '& 4'&1'&% 1 '!% @A @ +@ = > 158(('(( &('& %%%'(( 45 '!4 !('&4 ('1 '81 ('88!'(8 ('%& '& &'8'14 1 ' @A @ +@ = > 15(('(( &('& %%%'(( 45 ('&4 !'% ('1 %'% ('88!'1 ('%& '& %('!84'(! 1 '4& @A @ +@ = > 154(('(( &('& %%%'(( 45 &'%4 !'8 ('1 !' ('88!'8 ('%& '& %'%1&'81 1%'(! @A @ +@ = > 15&(('(( &('& %%%'(( 45 '4 ! '( ('1 8'41 ('88! ' ('%& '& % '(4' 1 1%' ( @A @ +@ = > !5((('(( &('& %%%'(( 45 8'4 ! '% ('1 4'!4 ('88! '18 ('%& '& % '!4 '4! 1%'%1 @A @ +@ = > !5(('(( &('& %%%'(( 45 1'!4 ! '% ('1 4('% ('88! '4 ('%& '& %%'%441'14 1%'1 @A @ +@ = > !5 (('(( &('& %%%'(( 45 '&4 !%'(4 ('1 4 '( ('88!%' ('%& '& %%'&48' 1%'!& @A @ +@ = > !5%(('(( &('& %%%'(( 45 '%4 !%'11 ('1 4%'4 ('88!%'! ('%& '& %1'!%4'8 1%' @A @ +@ = > !51(('(( &('& %%%'(( 45 (&'4 !%'& ('1 4!'!8 ('88!%'44 ('%& '& %!'(14&'1 1%'4 @A @ +@ = > !5!(('(( &('& %%%'(( 45 (4'4 !1'! ('1 4'% ('88!1' 1 ('%& '& %!'!%&'( 1%'& @A @ +@ = > !58(('(( &('& %%%'(( 45 (8'!4 !1'! ('1 4&'(8 ('88!1'8( ('%& '& %!'&4& '1 11'( @A @ +@ = > !5(('(( &('& %%%'(( 45 (1'&4 !1'44 ('1 &('4 ('88!1'&8 ('%& '& %8'1&1'1 11' @A @ +@ = > !54(('(( &('& %%%'(( 45 (%'%4 !!' 1 ('1 & '! ('88!!'% ('%& '& %8'4 &8'( 11' ( @A @ +@ = > !5&(('(( &('& %%%'(( 45 ('4 !!'8( ('1 &1'%% ('88!!'8& ('%& '& %' (&'& 11' & @A @ +@ = > 85((('(( &('& %%%'(( 45 (('4 !!'& ('1 &8'(& ('88!8'(! ('%& '& %'!8&&'1& 11'% @A @ +@ = > 85(('(( &('& %%%'(( 45&4'!4 !8'%1 ('1 &'4! ('88!8'1 ('%& '& %'& ('& 11'1! @A @ +@ = > 85 (('(( &('& %%%'(( 45&8'&4 !8' ('1 &&'8 ('88!8'& ('%& '& %4' % ( '4& 11'!% @A @ +@ = > 85%(('(( &('& %%%'(( 45&!'%4 !'(4 ('1 ('%4 ('88!'8 ('%& '& %4'!1 (1'8( 11'8( @A @ +@ = > 851(('(( &('& %%%'(( 45&%'4 !'1! ('1 (%'! ('88!'!% ('%& '& %4'41 (8'% 11'8 @A @ +@ = > 85!(('(( &('& %%%'(( 45& '4 !'4 ('1 (1'& ('88!'&( ('%& '& %&' (4'(% 11'1 @A @ +@ = > /(%0, 1 , !"#$%&'!()* $230, 4, !"#$%&'!()* #30,+ , -.),, ) !0, , /)/). ) #%, 5, 0(136,7 '((2/ 35, , @6%#% 3 =0? =0? A =0? &1 =>? =>? / =0? A =0? 2 =0? A =0? #6% 0A =0? 1(11(14 =0? =0? &1 =>? $ %5 2 3 =0? 858(('(( &('& %%%'(( 45&('!4 !4'& ('1 (8'8& ('88!4' 4 ('%& '& %&'%4 (&'! 11'4 @A @ +@ = > 85(('(( &('& %%%'(( 4544'&4 !4'! ('1 (4'18 ('88!4'8! 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' !( 45 &'8154&1'(('((( 4'!(( ? 458 '( 45%&' &1'!(( 8' ! /(%0, 1 , !"#$%&'!()* $230, 4, !"#$%&'!()* #30,+ , -.),, ) !0, , /)/). ) #%, 5, 0(136,7 '((2/ 35, , #% 3 =0? 2 3 =0? 3 3 =>?!1 /6 3 =>? 91 &4'! /A / &&'!( 5('1& 1( / 5(1'!( 51 1'%4 %( / 51('!( 588'1 ( / 581!'!( 5(' ( / 5&&('!( %5 !'8% "% / %5((8'!( %5!'8% / %5(%'!( 15& '8% E& / %58('!( !5 &'8% E&8 / %5& '!( !581'8% E&! / %5&8'!( 851!'8% E&1 / 15% '!( 5%'8% E&% / 154% '!( 45 !%'8% )E&% / !5 ('!( (5((&'8% E& / 8514'!( (5%%'8% E& / 85% '!( (58%!'8% ) / 8518'!( 5%&!'(( D 6 / 5%1!'!( 511!'! / 5%'!( 5&'% 73 / 581('!( 1541%'!1 / 45 41'!( 154& ' / 45 &'!( !5&'!& / 45% '!( #% 3 =0? 2 3 =0? ; <( =0? ;!<( =0? /% 11 !(('(( !(('(( ('(( ('(( #),'!( (('(( 8&&'& !' % ('4 7 '((A?('(( 5((('(( &&4'% %8'!8 ' 4 7 '!(A?11' 1 %5%%'(& 5(' % &!1' % 8'84 44('((, %%%'(& 5&%'(& 5((' % 85!4 '8% !5&('8 7 '!(A?&4'(( 5%&!'84 5%1!'4! 854!%'1( 85(%'4% !('((, %&!'84 511!'84 5%'!8 854' 1 85%&'14 !('((, 11!'84 51&!'84 5%&' 8 85&('(& 85!' 7 %'((A?44'(( 1541%'!1 45 41'!( 858'&1 454 '&( !('((, 141%'!1 154&%'!1 45 &'( 85848' 8 45 ' !('((, 14&%'!1 15&1%'!1 45 &4'&( 858!!'!4 45 8('!1 7 %'((A?('%( !5! '4( 45%!'&1 85 %4'!4 458!!'48 %1'%(, !! '4( !58!' 45%!'( 85 &' 45%%'1& 7 '!A?8&'4( !5&4(' & 45%8('!% !54! '4 45&(('!4 4!(('((, !&4(' & 1514(' & 45 1'!( 5&'!4 5!&' %4&&'((, 114(' & 45%&' & 458 '( !5&%' 15! &' 4%&' & . ,# F ,# F F Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. X X 223-002 Rendezvous X GMTU MT7-11 GMTU2 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-11Initial Class/TypeSER / PENDGeoArea890Unit10750On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230020GRTR MOOSES TOOTH, RENDEZV OIL - 282200NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes AIO 43 applies.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYes15 All wells within 1/4 mile area of review identified (For service well only)No MT7-11 will not be pre-produced.16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 80' conductor18 Conductor string providedYes 3777' MD SC shoe19 Surface casing protects all known USDWsYes 73% excess20 CMT vol adequate to circulate on conductor & surf csgNo21 CMT vol adequate to tie-in long string to surf csgNo uncemented liner with swell packers and frac sleeves22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes rig has steel tanks; all waste to approved disposal wells24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes Anti collision analysis complete; no major risk failures26 Adequate wellbore separation proposedYes Diverter variance granted per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulationsYes Max formation pressure is 3752 psig(8.8 ppg EMW); will drill w/ 8.8 - 13.0 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 2923 psig; will test BOPs to 3500 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableYes MT7-09 good cement34 Mechanical 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 measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate1/25/2023ApprVTLDate2/15/2023ApprDLBDate1/23/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateGCW 02/22/23JLC 2/22/2023
