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Home My WebLink About222-116DA 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 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 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 , S O N I C , C A L I P E R No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 1/ 4 / 2 0 2 3 34 5 0 1 3 2 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ M T 7 - 0 8 _ T O C . l a s 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ M T 7 - 08 _ T O C _ 2 0 0 M D . P d f 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ M T 7 - 08 _ T O C _ 5 0 0 M D . P d f 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ T O C . d l i s 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ T O C _ 1 0 0 0 M D . P d f 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ T O C _ 4 0 0 0 M D . P d f 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ T O C _ 6 0 0 0 M D . P d f 37 4 1 5 ED Di g i t a l D a t a DF 1/ 4 / 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 - 0 8 _ T O C _ 8 0 0 0 M D . P d f 37 4 1 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 24 6 2 9 2 0 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ C O M P _ M E M . l a s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ R U N 0 4 _ M E M _ A P - L O G _ T I M E . l a s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ R U N 0 5 _ M E M _ A P - L O G _ T I M E . l a s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ R U N 0 4 _ M E M _V S S - L O G _ T I M E . l a s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ R U N 0 5 _ M E M _V S S - L O G _ T I M E . l a s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 22 0 2 9 2 0 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ V S S - D E P _ C O M P _ M E M . l a s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ R U N 04 _ M E M _ A P - L O G _ T I M E . a s c 37 4 4 4 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 1 o f 1 0 CP A I _ M T 7 - , 08_ C OMP _ 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 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ R U N 05 _ M E M _ A P - L O G _ T I M E . a s c 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ R U N 04 _ M E M _ V S S - L O G _ T I M E . a s c 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ R U N 05 _ M E M _ V S S - L O G _ T I M E . a s c 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 _ m e m _ L T K _ R 4 . d l i s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ L T K _ R 4 _ L M G _ 0 9 8 _ 0 2 4 0 s c l . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ L T K _ R 4 _ L M G _ 0 9 8 _ 0 2 4 0 s c l . P D F 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 _ m e m _ L T K _ R 5 . d l i s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ L T K _ R 5 _ L M G _ 0 9 8 _ 0 2 4 0 s c l . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ L T K _ R 5 _ L M G _ 0 9 8 _ 0 2 4 0 s c l . P D F 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 _ m e m _ S T K _ R 4 . d l i s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ 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 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ 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 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ S T K _ R 4 _ L M G _ 1 0 0 _ 0 4 8 s c l . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ S T K _ R 4 _ L M G _ 1 0 0 _ 0 4 8 s c l . P D F 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 _ m e m _ S T K _ R 5 . d l i s 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ 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 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ 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 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ S T K _ R 5 _ L M G _ 1 0 0 _ 0 4 8 s c l . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 _ m e m _ S T K _ R 5 _ L M G _ 1 0 0 _ 0 4 8 s c l . P D F 37 4 4 4 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 2 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 2 M D _ C O M P _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 2 T V D _ C O M P _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 5 M D _ C O M P _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 5 T V D _ C O M P _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ A P - TI M E _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ V S S - DE P _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ V S S - TI M E _ M E M . c g m 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 2 M D _ C O M P _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 2 T V D _ C O M P _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 5 M D _ C O M P _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ 5 T V D _ C O M P _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ A P - TI M E _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ V S S - DE P _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ V S S - TI M E _ M E M . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 M D _ I N C _ A Z I D e f i n i t i v e Su r v e y s . t x t 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 N A D 2 7 D e f i n i t i v e Su r v e y s . p d f 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 N A D 2 7 D e f i n i t i v e Su r v e y s . t x t 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 N A D 8 3 D e f i n i t i v e Su r v e y s . p d f 37 4 4 4 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 3 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 N A D 8 3 D e f i n i t i v e Su r v e y s . t x t 37 4 4 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 24 6 2 2 3 8 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ C O M P _ M E M . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 1 _ M E M _ A P - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 2 _ M E M _ A P - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 3 _ M E M _ A P - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 4 _ M E M _ A P - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 1 _ M E M _ V S S - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 2 _ M E M _ V S S - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 3 _ M E M _ V S S - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 P B 1 _ R U N 0 4 _ M E M _ V S S - L O G _ T I M E . l a s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 01 _ M E M _ A P - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 02 _ M E M _ A P - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 03 _ M E M _ A P - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 04 _ M E M _ A P - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 01 _ M E M _ V S S - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 02 _ M E M _ V S S - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 03 _ M E M _ V S S - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ R U N 04 _ M E M _ V S S - L O G _ T I M E . a s c 37 4 4 5 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 4 o f 1 0 CPA I _ M T 7 - , 08P B 1 _ 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 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 _ m e m _ L T K _ R 4 . d l i s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 P B 1 _ m e m _ L T K _ R 4 _ L M G _ 0 9 8 _ 0 2 4 0 s c l . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 P B 1 _ m e m _ L T K _ R 4 _ L M G _ 0 9 8 _ 0 2 4 0 s c l . P D F 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 _ m e m _ S T K _ R 4 . d l i s 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 P B 1 _ 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 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 P B 1 _ 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 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 P B 1 _ 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 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 08 P B 1 _ 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 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ A P - TI M E _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ V S S - DE P _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ V S S - TI M E _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 2 M D _ C O M P _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 2 T V D _ C O M P _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 5 M D _ C O M P _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 5 T V D _ C O M P _ M E M . c g m 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ A P - TI M E _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ V S S - DE P _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 P B 1 _ V S S - TI M E _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 2 M D _ C O M P _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 5 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 2 T V D _ C O M P _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 5 M D _ C O M P _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 P B 1 _ 5 T V D _ C O M P _ M E M . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 M D _ I N C _ A Z I De f i n i t i v e S u r v e y s . t x t 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 N A D 2 7 D e f i n i t i v e Su r v e y s . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 N A D 2 7 D e f i n i t i v e Su r v e y s . t x t 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 N A D 8 3 D e f i n i t i v e Su r v e y s . p d f 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 8 P B 1 N A D 8 3 D e f i n i t i v e Su r v e y s . t x t 37 4 4 5 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 6 1 6 0 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 08 D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 2 1 6 0 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 09 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 2 3 2 2 6 7 4 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 1 4 2 0 0 B W P D _ C o n C u _ R 0 1 _L 0 1 2 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 5 5 1 6 0 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 2D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 6 1 6 0 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 3U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 5 1 6 0 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 4D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 4 1 6 0 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 5U p . l a s 38 4 2 7 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 6 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 4 13 1 9 8 2 6 7 8 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 6 5 0 0 B W P D _ C o n C u _ R 0 1 _ L0 1 4 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 2 1 6 1 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 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 6D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 4 7 1 6 1 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 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 7U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 2 0 2 2 6 8 7 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ S I _ W a r m b a c k _ C o n C u _ R 0 1_ L 0 1 9 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 12 5 5 0 2 9 4 8 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : 13 8 1 5 _ B W P D _ U p _ 6 0 F P M _ R u n _ 1 _ _ L o g _ 1 6 _ U p _1 _ _ _ 2 8 S e p 2 3 _ 0 7 1 2 3 9 . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 92 2 1 1 2 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 08 D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 93 2 1 1 2 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 09 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 3 0 0 2 9 1 7 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 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 1 3 8 1 5 B W P D _ C o n C u _ R 0 1 _L 0 1 6 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 92 4 1 1 2 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 2D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 93 4 1 1 2 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 3U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 93 4 1 1 4 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 4D o w n . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 90 7 1 1 4 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 5U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 3 0 0 2 9 1 7 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 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 6 5 0 0 B W P D _ C o n C u _ R 0 1 _ L0 2 0 U p . l a s 38 4 2 7 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 7 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 4 92 2 1 1 2 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 7U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 13 3 0 0 2 9 1 7 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 - 08 _ I P R O F _ _ 0 2 O c t 2 3 _ S I _ W a r m b a c k _ C o n C u _ R 0 1_ L 0 2 3 U p . l a s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 08 D o w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 09 U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 1 4 2 0 0 B W P D _ C o n C u _ R 0 1 _L 0 1 2 U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 2D o w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 3U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 4D o w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 5U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 6D o w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 7U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ S I _ W a r m b a c k _ C o n C u _ R 0 1_ L 0 1 9 U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 1 7 A U G 2 3 _ F i e l d P r i n t . P d f 38 4 2 7 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 8 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 2 0 2 5 UI C Ye s DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 8 _ P S P - IL _ 1 4 A u g u s t 2 0 2 3 _ I P R O F _ I n t e r p _ R e p o r t _ A n I . p d f 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : 13 8 1 5 _ B W P D _ U p _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 1 6 U p _P F C S _ P I L S _ P B M S T _ S P P A C _ S P D R S _ S P C P S _S P H Y S . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 0 8 Do w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 1 2 0 F P M _ C o n C u _ R 0 1 _ L 0 0 9 Up . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 1 3 8 1 5 B W P D _ C o n C u _ R 0 1 _ L0 1 6 U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 2 Do w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 4 0 F P M _ C o n C u _ R 0 1 _ L 0 0 3 Up . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 4 Do w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 6 0 F P M _ C o n C u _ R 0 1 _ L 0 0 5 Up . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 6 5 0 0 B W P D _ C o n C u _ R 0 1 _ L 02 0 U p . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 6 Do w n . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ 8 0 F P M _ C o n C u _ R 0 1 _ L 0 0 7 Up . d l i s 38 4 2 7 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 08 _ I P R O F _ 2 O C T 2 3 _ S I _ W a r m b a c k _ C o n C u _ R 0 1 _L 0 2 3 U p . d l i s 38 4 2 7 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 9 o f 1 0 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 8 4 6 - 0 0 - 0 0 We l l N a m e / N o . GM T U M T 7 - 0 8 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 1/ 1 2 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 1 6 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 29 2 0 3 TV D 84 8 9 Cu r r e n t S t a t u s WA G I N 7/ 2 3 / 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 : 1/ 1 2 / 2 0 2 3 Re l e a s e D a t e : 10 / 2 8 / 2 0 2 2 DF 1/ 1 9 / 2 0 2 4 E l e c t r o n i c F i l e : CP A I _ _ M T 7 _ 0 8 _ I P R O F _ 0 2 O C T 2 3 _ F i e l d P r i n t . p d f 38 4 2 7 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 1 0 o f 1 0 M. G u h l 7/ 2 3 / 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. MT7-08 GMTU MT7-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 MT7-08 50-103-20846-00-00 222-116-0 W SPT 8265 2221160 2066 2054 2075 2045 2045 175 350 350 350 4YRTST P Sully Sullivan 7/15/2024 4 year MIT-IA tested to 2700 for 500 psi dp 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 MT7-08 Inspection Date: Tubing OA Packer Depth 1090 2785 2720 2700IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240717094132 BBL Pumped:5.5 BBL Returned:5.5 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:29:02 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Mooses Tooth DATE: 12/19/2023 Transmitted: North Slope, Mooses Tooth Unit Via hard drive data drop MT7-07 50-103-20841-00 222052_MT7-07_CBP_15Feb2023 222052_MT7-07_IPROF_14Aug23 222052_MT7-07_IPROF_14Mar23 222052_MT7-07_IPROF_25Nov22 222052_MT7-07_Patch_Setting_28Oct23 222052_MT7-07_PPROF_22Aug2022 222052_MT7-07_WFL_16Mar23 MT7-08 50-103-20846-00 222116_MT7-08_IPROF_17Aug23 222116_MT7-08_TTiX-IPROF_2Oct2023 MT7-09 50-103-20837-00 222011_MT7-09_PPROF_01Nov2022 222011_MT7-09_PPROF_03Jul2022 222011_MT7-09_TTiXPerf_04Oct23 MT7-94 50-103-20858-00 223049_MT7-94_MDT-XLROCK- GR_10Sep2023 MT7-95 50-103-20854-00 223035_MT7-95_TubingPuncher_12Jun2023 2of 3 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38426 T38427 T38428 T38429 T38430 2/29/2024 MT7-08 50-103-20846-00 222116_MT7-08_IPROF_17Aug23 222116_MT7-08_TTiX-IPROF_2Oct2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:00:23 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: __Convert Inj to Prod_ ConocoPhillips Alaska Inc Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 29,203 feet NA feet true vertical 8,489 feet NA feet Effective Depth measured 29189 feet 12838 feet true vertical 8489 feet 8192 feet Perforation depth Measured depth 13628-29145 feet True Vertical depth 8350-8491 feet Tubing (size, grade, measured and true vertical depth) 4.5" L80 13086' / 8260' Packers and SSSV (type, measured and true vertical depth) Halliburton TNT 12838' / 8192' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3458' 3025' Burst Collapse 2260 3810 7030 5020 6330 8160 measured TVD Intermediate 2 Liner 11002 2390 16100 Casing Structural 7368' 8297' 4.5" 11042' 13244' 29189' 8489' Plugs Junk measured NA Length 80 3418 120'Conductor Surface Intermediate 20" 13-3/8" NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: AA081800, AA081781, AA081736 Greater Mooses Tooth / Rendezvous STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-116 50-103-20846-00-00 Size 120' 265 5743438 1195 407285 406 9-5/8" 8430 7" PO Box 100360, Anchorage AK 995103. Address: GMT MT7-99 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1067 Gas-Mcf MD 578 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Sr Pet Eng: 7500 Sr Pet Geo: Sr Res Eng: WINJ WAG 3641 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Greater Mooses Tooth / Rendezvous Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Staff Production Engineer Dana Glessner glessd@conocophillips.com 907-265-6478 By Samantha Carlisle at 12:30 pm, Feb 28, 2023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 28 February 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well GMTU MT7-08 (PTD 222-116) to convert the well from injection to production. GMTU MT7-08 was originally permitted as an injector and planned to preproduce for less than 30 days. However due to status changes with other wells on the pad it was decided to extend the preproduction period on MT7-08 for more than 30 days. The well was first placed on production post drilling and completion on 01/26/2023 and CPAI intends to continue production through March 2023 now. Please contact me at 265-6478 if you have any questions. Sincerely, Dana Glessner Staff Production Engineer ConocoPhillips Alaska, Inc. Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLVs, pull B&R & RHC post rig MT7-08 1/18/2023 rmoore22 General Notes: Last 3 entries Com Date Last Mod By No BPV in wellhead 1/12/2023 d25cm Liner Top Packer @ 13,083' not tested due to damaged seal in running tool. Cannot be used as barrier for future work. 1/12/2023 d25cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 19.12 40.0 80.0 80.0 94.00 L80 Welded Surface 13 3/8 12.42 38.1 3,458.6 3,025.0 68.00 L-80 H563 Intermediate 1 9 5/8 8.76 -0.8 11,041.0 7,367.5 43.50 L80 Hyd563 Intermediate 2 7 6.28 10,855.9 13,245.0 8,298.1 26.00 L-80 TSH 563 Liner 4 1/2 3.96 13,083.2 29,193.0 8,489.3 12.60 L-80 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.1 Set Depth 13,089.8 Set Depth 8,261.3 String Ma 4 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 34.1 34.1 0.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril HYD 563 FMC TC-EMS 3.958 1,854.7 1,818.5 21.34 Nipple - DB, XN, DS, D 4.500 NIPPLE,LANDING,4 1/2","X",3.813", H563 HES X Nipple 3.813 4,252.3 3,473.2 55.25 Mandrel 4.500 4-1/2" x 1" KBG 4-5 GLM,12.6# H563 Camco KBG4-5 3.865 8,628.2 5,983.5 55.07 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.860 12,632.3 8,125.6 69.77 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.860 12,739.4 8,161.5 70.98 Gauge / Pump Sensor 4.500 Halliburton Opsis Mandrel w/ Downhole gauge HES DHG 3.920 13,059.3 8,253.8 75.67 Nipple - DB, XN, DS, D 4.500 NIPPLE,LANDING,4 1/2",DB,3.75", H563 SLB OSDB-6 3.750 13,080.9 8,259.1 75.78 No-go Nipple 4.940 No-Go locator sub- 5.76" OD Baker 3.910 13,086.6 8,260.5 75.80 Mule Shoe 4.500 HES Self indexing Mule Shoe HES Self orienting 3.958 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,252.3 3,473.2 55.25 1 GAS LIFT OV BK 1 1/17/2023 0.438 8,628.2 5,983.5 55.07 2 GAS LIFT OV BK 1 1/18/2023 0.438 12,632.3 8,125.6 69.77 3 GAS LIFT OV BK 1 1/18/2023 0.438 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,628.3 8,350.4 85.35 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 13,991.9 8,379.8 85.80 Swell Packer 4.500 Baker Rapidswell 906 3.910 14,415.1 8,390.9 89.58 Swell Packer 4.500 Baker Rapidswell 906 3.910 14,758.7 8,393.3 89.59 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 15,085.5 8,397.5 89.12 Swell Packer 4.500 Baker Rapidswell 906 3.910 15,430.8 8,404.5 88.60 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 15,758.5 8,412.6 88.63 Swell Packer 4.500 Baker Rapidswell 906 3.910 16,100.2 8,420.1 89.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 16,462.1 8,420.9 90.09 Swell Packer 4.500 Baker Rapidswell 906 3.910 16,761.5 8,421.5 89.60 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 17,123.2 8,424.0 89.61 Swell Packer 4.500 Baker Rapidswell 906 3.910 17,505.9 8,425.3 90.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 17,912.1 8,424.8 90.08 Swell Packer 4.500 Baker Rapidswell 906 3.910 18,696.6 8,435.6 88.10 Swell Packer 4.500 Baker Rapidswell 922 3.910 19,082.2 8,451.4 87.55 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 HORIZONTAL, MT7-08, 1/18/2023 10:10:31 AM Vertical schematic (actual) Liner; 13,083.2-29,193.0 Shoe; 29,188.2-29,193.0 FRAC Sleeve/Port; 29,145.6- 29,147.7 Swell Packer; 28,757.7-28,777.7 FRAC Sleeve/Port; 28,425.8- 28,427.9 Swell Packer; 28,035.8-28,055.9 FRAC Sleeve/Port; 27,667.8- 27,669.8 Swell Packer; 27,330.3-27,350.3 FRAC Sleeve/Port; 27,005.0- 27,007.1 Swell Packer; 26,621.0-26,641.0 FRAC Sleeve/Port; 26,295.1- 26,297.2 Swell Packer; 25,913.2-25,933.3 FRAC Sleeve/Port; 25,550.6- 25,552.6 Swell Packer; 25,166.1-25,186.2 FRAC Sleeve/Port; 24,843.1- 24,845.1 Swell Packer; 24,460.6-24,480.7 FRAC Sleeve/Port; 24,095.4- 24,097.5 Swell Packer; 23,472.6-23,492.7 FRAC Sleeve/Port; 23,151.0- 23,153.1 Swell Packer; 22,806.3-22,826.4 FRAC Sleeve/Port; 22,513.7- 22,515.8 Swell Packer; 22,167.9-22,187.9 Swell Packer; 21,861.9-21,881.9 FRAC Sleeve/Port; 21,497.2- 21,499.3 Swell Packer; 21,066.8-21,086.9 FRAC Sleeve/Port; 20,695.8- 20,697.9 Swell Packer; 20,274.4-20,294.5 FRAC Sleeve/Port; 19,868.7- 19,870.8 Swell Packer; 19,486.8-19,506.9 FRAC Sleeve/Port; 19,082.2- 19,084.2 Swell Packer; 18,696.6-18,716.6 Swell Packer; 17,912.0-17,932.1 FRAC Sleeve/Port; 17,505.9- 17,507.9 Swell Packer; 17,123.2-17,143.3 FRAC Sleeve/Port; 16,761.5- 16,763.5 Swell Packer; 16,462.1-16,482.1 FRAC Sleeve/Port; 16,100.2- 16,102.3 Swell Packer; 15,758.5-15,778.6 FRAC Sleeve/Port; 15,430.8- 15,432.9 Swell Packer; 15,085.5-15,105.6 FRAC Sleeve/Port; 14,758.7- 14,760.7 Swell Packer; 14,415.1-14,435.2 Swell Packer; 13,991.9-14,011.9 FRAC Sleeve/Port; 13,628.2- 13,630.3 Intermediate 2; 10,855.9- 13,245.0 Float Shoe; 13,242.1-13,245.0 Collar - Float; 13,195.8-13,197.2 Landing Collar; 13,157.8- 13,161.1 Hanger; 13,099.5-13,108.8 Packer (Liner Top); 13,083.2- 13,099.5 Packer (Tubing); 12,838.1 Gauge / Pump Sensor; 12,739.4 Mandrel; 12,632.3 Intermediate String 2 Cement; 11,560.0 ftKB Intermediate 1; -0.8-11,041.0 9-5/8" Davis Lynch Float Shoe, H563. Aluminium nose; 11,037.9 -11,041.0 Collar - Float; 10,950.1-10,952.8 Hanger; 10,880.3-10,889.9 Nipple; 10,877.5-10,880.3 Packer; 10,855.9-10,877.5 Intermediate String 1 Cement; 6,856.0 ftKB Mandrel; 8,628.2 Mandrel; 4,252.3 Surface; 38.1-3,458.6 Float Shoe; 3,456.4-3,458.6 Surface String Cement; 38.2 ftKB Conductor; 40.0-80.0 Casing Hanger; 38.1-39.4 Hanger; 34.1 Casing Hanger; -0.8-37.1 WNS SVC KB-Grd (ft) 39.00 RR Date Other Elev MT7-08 ... TD Act Btm (ftKB) 29,203.0 Well Attributes Field Name RENDE Wellbore API/UWI 501032084600 Wellbore Status SVC Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBOREMT7-08 Annotation End DateH2S (ppm) DateComment Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 19,486.8 8,465.5 88.75 Swell Packer 4.500 Baker Rapidswell 922 3.910 19,868.8 8,467.0 90.11 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 20,274.5 8,465.4 90.59 Swell Packer 4.500 Baker Rapidswell 922 3.910 20,695.9 8,457.8 91.57 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 21,066.8 8,455.6 89.50 Swell Packer 4.500 Baker Rapidswell 922 3.910 21,497.2 8,462.0 89.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 21,861.9 8,463.3 90.09 Swell Packer 4.500 Baker Rapidswell 922 3.910 22,167.9 8,467.5 87.86 Swell Packer 4.500 Baker Rapidswell 922 3.910 22,513.7 8,478.2 88.55 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 22,806.3 8,483.8 89.10 Swell Packer 4.500 Baker Rapidswell 922 3.910 23,151.0 8,489.4 88.95 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 23,472.6 8,499.7 87.88 Swell Packer 4.500 Baker Rapidswell 922 3.910 24,095.4 8,492.9 91.97 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 24,460.6 8,485.9 89.97 Swell Packer 4.500 Baker Rapidswell 922 3.910 24,843.1 8,483.8 89.98 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 25,166.1 8,485.2 90.00 Swell Packer 4.500 Baker Rapidswell 922 3.910 25,550.6 8,484.9 89.46 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 25,913.3 8,485.5 89.97 Swell Packer 4.500 Baker Rapidswell 922 3.910 26,295.1 8,481.2 89.75 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 26,621.0 8,491.9 87.93 Swell Packer 4.500 Baker Rapidswell 922 3.910 27,005.0 8,500.9 88.95 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 27,330.3 8,506.8 88.96 Swell Packer 4.500 Baker Rapidswell 922 3.910 27,667.8 8,512.6 89.88 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 28,035.8 8,503.9 91.12 Swell Packer 4.500 Baker Rapidswell 922 3.910 28,425.8 8,503.3 89.56 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 28,757.7 8,501.7 90.92 Swell Packer 4.500 Baker Rapidswell 922 3.910 29,145.6 8,490.9 91.97 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 HORIZONTAL, MT7-08, 1/18/2023 10:10:32 AM Vertical schematic (actual) Liner; 13,083.2-29,193.0 Shoe; 29,188.2-29,193.0 FRAC Sleeve/Port; 29,145.6- 29,147.7 Swell Packer; 28,757.7-28,777.7 FRAC Sleeve/Port; 28,425.8- 28,427.9 Swell Packer; 28,035.8-28,055.9 FRAC Sleeve/Port; 27,667.8- 27,669.8 Swell Packer; 27,330.3-27,350.3 FRAC Sleeve/Port; 27,005.0- 27,007.1 Swell Packer; 26,621.0-26,641.0 FRAC Sleeve/Port; 26,295.1- 26,297.2 Swell Packer; 25,913.2-25,933.3 FRAC Sleeve/Port; 25,550.6- 25,552.6 Swell Packer; 25,166.1-25,186.2 FRAC Sleeve/Port; 24,843.1- 24,845.1 Swell Packer; 24,460.6-24,480.7 FRAC Sleeve/Port; 24,095.4- 24,097.5 Swell Packer; 23,472.6-23,492.7 FRAC Sleeve/Port; 23,151.0- 23,153.1 Swell Packer; 22,806.3-22,826.4 FRAC Sleeve/Port; 22,513.7- 22,515.8 Swell Packer; 22,167.9-22,187.9 Swell Packer; 21,861.9-21,881.9 FRAC Sleeve/Port; 21,497.2- 21,499.3 Swell Packer; 21,066.8-21,086.9 FRAC Sleeve/Port; 20,695.8- 20,697.9 Swell Packer; 20,274.4-20,294.5 FRAC Sleeve/Port; 19,868.7- 19,870.8 Swell Packer; 19,486.8-19,506.9 FRAC Sleeve/Port; 19,082.2- 19,084.2 Swell Packer; 18,696.6-18,716.6 Swell Packer; 17,912.0-17,932.1 FRAC Sleeve/Port; 17,505.9- 17,507.9 Swell Packer; 17,123.2-17,143.3 FRAC Sleeve/Port; 16,761.5- 16,763.5 Swell Packer; 16,462.1-16,482.1 FRAC Sleeve/Port; 16,100.2- 16,102.3 Swell Packer; 15,758.5-15,778.6 FRAC Sleeve/Port; 15,430.8- 15,432.9 Swell Packer; 15,085.5-15,105.6 FRAC Sleeve/Port; 14,758.7- 14,760.7 Swell Packer; 14,415.1-14,435.2 Swell Packer; 13,991.9-14,011.9 FRAC Sleeve/Port; 13,628.2- 13,630.3 Intermediate 2; 10,855.9- 13,245.0 Float Shoe; 13,242.1-13,245.0 Collar - Float; 13,195.8-13,197.2 Landing Collar; 13,157.8- 13,161.1 Hanger; 13,099.5-13,108.8 Packer (Liner Top); 13,083.2- 13,099.5 Packer (Tubing); 12,838.1 Gauge / Pump Sensor; 12,739.4 Mandrel; 12,632.3 Intermediate String 2 Cement; 11,560.0 ftKB Intermediate 1; -0.8-11,041.0 9-5/8" Davis Lynch Float Shoe, H563. Aluminium nose; 11,037.9 -11,041.0 Collar - Float; 10,950.1-10,952.8 Hanger; 10,880.3-10,889.9 Nipple; 10,877.5-10,880.3 Packer; 10,855.9-10,877.5 Intermediate String 1 Cement; 6,856.0 ftKB Mandrel; 8,628.2 Mandrel; 4,252.3 Surface; 38.1-3,458.6 Float Shoe; 3,456.4-3,458.6 Surface String Cement; 38.2 ftKB Conductor; 40.0-80.0 Casing Hanger; 38.1-39.4 Hanger; 34.1 Casing Hanger; -0.8-37.1 WNS SVC MT7-08 ... WELLNAME WELLBOREMT7-08 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT7-08 GMTU MT7-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 MT7-08 50-103-20846-00-00 222-116-0 W SPT 8200 2221160 2050 1067 1066 1068 1070 40 40 40 40 INITAL P Bob Noble 5/14/2023 Initial MIT-IA post conversion from producer to injector per Sundry 323-141 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 MT7-08 Inspection Date: Tubing OA Packer Depth 370 2500 2430 2410IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230515164348 BBL Pumped:6.6 BBL Returned:6.6 Tuesday, July 25, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Initial MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2023.07.25 11:14:26 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: __Convert Prod to Inj_ ConocoPhillips Alaska Inc Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 29,203 feet NA feet true vertical 8,489 feet NA feet Effective Depth measured 29189 feet 12838 feet true vertical 8489 feet 8192 feet Perforation depth Measured depth 13628-29145 feet True Vertical depth 8350-8491 feet Tubing (size, grade, measured and true vertical depth) 4.5" L80 13086' / 8260' Packers and SSSV (type, measured and true vertical depth) Halliburton TNT 12838' / 8192' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Dana Glessner Contact Email:glessd@conocophillips.com Authorized Title: Contact Phone: 907-265-6478 measured TVD Intermediate 2 Liner 11002 2390 16100 Casing Structural 7368' 8297' 4.5" 11042' 13244' 29189' 8489' Plugs Junk measured 3458' 3025' 20" 13-3/8" Size 120' 9-5/8" 8430 7" 7030 5020 6330 8160 Burst Collapse 2260 3810 NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: AA081800, AA081781, AA081736 Greater Mooses Tooth / Rendezvous STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-116 50-103-20846-00-00 PO Box 100360, Anchorage AK 995103. Address: GMT MT7-08 MD 1100 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 700 400150 NA Length 80 3418 120'Conductor Surface Intermediate Sr Pet Eng: 7500 Sr Pet Geo: Sr Res Eng: WINJ WAG 2250 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Greater Mooses Tooth / Rendezvous Gas-Mcf 9000 4500 960 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dana Glessner DN: CN=Dana Glessner, OU=ConocoPhillips Alaska, E=glessd@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.05.16 12:17:10-08'00' Foxit PDF Editor Version: 12.0.1 Dana Glessner By Kayla Junke at 3:50 pm, May 16, 2023 5/15/23, 4:14 PM Well History (Full) MT7-08 501032084600 https://akapps.cop.net/WebBert/Well/Report/rptWell.aspx?REPORT=..%2f..%2fUserControl%2fWell%2fReport%2fucWellTblEventFull2.ascx&API=5011/5 Well History (Full) MT7-08 : 501032084600 : 5/15/2023 Date Note Type Note Category Well Notes 5/14/2023 2:11:39 PM PRESSURE_BLEED INNER ANNULUS PRESSURE ( Start = 370, End = 370 ) OUTER ANNULUS PRESSURE ( End = 36 ) 5/14/2023 10:25:36AM ANN_COMM_EVENT AC EVAL BLEED-IAFL-IA MIT-IA MT7-08 (ISW) : State/BLM witnessed (Robert Noble/Quinn Sawyer) MIT-IA Passed to 2500 psi. Initial T/I/O = 1067/370/40. IAFL @ surface. Pressurized IAto 2500 psi w/ 6.6 bbls diesel. Starting T/I/O = 1066/2500/40. 15 min T/I/O = 1068/2430/40. (-70). 30 min T/I/O = 1070/2410/40. (-20). Passed. Bled IAto 370 psi, bled back 6.6 bbls. Final T/I/O = 1070/370/40. 5/14/2023 12:00:00AM ANN_COMM_STATE 5/12/2023 4:07:15 PM ANN_COMM_EVENT FL-IA (Pre-SW) : T/I/O = 1026/343/35. IAFL @ surface. 5/7/2023 5:33:39 PM PRESSURE_BLEED INNER ANNULUS PRESSURE ( Start = 26, End = 300 ) OUTER ANNULUS PRESSURE ( End = 33 ) 5/7/2023 2:55:12 PM ANN_COMM_EVENT BLEED-IAFL-IALOAD (Pre-SW) : Bleed IA(Complete), Loaded IAw/ 1.9 bbls diesel to 300 psi. Initial T/I/O = 1032/26/32. IAFL near surface. Bled IAto 0+ psi in 25 min (bled @ reduced rate to keep fluid from coming to surface). LRS pressurized IAto 300 psi w/ 1.9 bbls diesel (heated diesel). Starting T/I/O = 1035/300/33. 15 min T/I/O = 1038/290/33. (-10). Final T/I/O = 1038/290/33. 5/7/2023 11:30:00AM EVENT_LOG_DAILY WELL INTEGRITY (PRE-SW) : BLED IA(COMPLETE), LOADED IAW/ 1.9 BBLS DIESELTO 300 PSI. 5/4/2023 5:46:07AM WELL_EVENT WELL OPEN ( Oil rate = ) 5/4/2023 12:00:00AM EVENT_LOG_DAILY ELECTRIC LINE SLB ELINE LOG DARK VISION ULTRASONIC TOOL, POOHAND RIGDOWN 5/3/2023 5:13:40 PM WELL_EVENT REGULATORY/COMPLIANC WELL SHUTDOWN - REGULATORY/COMPLIANC 5/3/2023 12:00:00AM EVENT_LOG_DAILY ELECTRIC LINE SLB ELINE RIH AND TRACTOR DOWN DARKVISION ULTRASONIC TOOL. TAGGEDAT ~26590'. COULD NOT WORK DEEPER THAN 26612' RKB. BEGAN LOGGING 16 OF 20 SLEEVES 5/2/2023 3:00:00AM EVENT_LOG_DAILY ELECTRIC LINE MIRU FOR DARK VISION 5/15/23, 4:14 PM Well History (Full) MT7-08 501032084600 https://akapps.cop.net/WebBert/Well/Report/rptWell.aspx?REPORT=..%2f..%2fUserControl%2fWell%2fReport%2fucWellTblEventFull2.ascx&API=5012/5 4/26/2023 11:04:20 AM ANN_COMM_EVENT FL-IA MISC (MON) T/I/O = 297/0/32, IA FL @ Near Surface Hung tag on IA, "Please Do Not add gas, prep for SW MIT-IA" 4/24/2023 7:38:41 AM ANN_COMM_EVENT FL-IA (PRE SW) T/I/O = VAC/0/31, IA FL @ 30' (0.6 bbl FUV) 4/22/2023 9:12:42 AM WELL_EVENT WELL OPEN ( Oil rate = ) 4/22/2023 12:00:00 AM WELL_HEADER INJECTION MISCIBLE WAG - INJECTION - ACTIVE 4/14/2023 8:33:52 AM ANN_COMM_EVENT MIT-IA S-LINE PULLED 1" DMY FROM GLM #2 @ 8628' RKB; SET 1" DMY @ SAME; MIT- IA TO 2500 PSI **PASSED**; PULLED BAITED P PRONG @13,052' RKB; PULLED 3.75" DBP PLUG BODY @ 13,059' RKB. JOB COMPLETE. 4/14/2023 6:30:00 AM EVENT_LOG_DAILY SLICK LINE PULLED 1" DMY FROM GLM #2 @ 8628' RKB; SET 1" DMY @ SAME; MIT- IA TO 2500 PSI **PASSED**; PULLED BAITED P PRONG @13,052' RKB; PULLED 3.75" DBP PLUG BODY @ 13,059' RKB. JOB COMPLETE. 4/13/2023 8:31:48 AM ANN_COMM_EVENT AC EVAL S-LINE SET 1" DMY IN GLM #3 @ 12,632' RKB, ATTEMPT TO MITT **FAILED**; TESTED EACH GLM W/ HOLEFINDER, GLM #2 & GLM #3 SUSPECTED LEAK POINT. IN PROGRESS. 4/13/2023 5:30:00 AM EVENT_LOG_DAILY SLICK LINE SET 1" DMY IN GLM #3 @ 12,632' RKB, ATTEMPT TO MITT **FAILED**; TESTED EACH GLM W/ HOLEFINDER, GLM #2 & GLM #3 SUSPECTED LEAK POINT. IN PROGRESS. 4/12/2023 5:30:00 AM EVENT_LOG_DAILY SLICK LINE SET 1" DMY IN GLM #3 @12,632' RKB; ATTEMPT TO MIT-IA **FAILED**; PULLED 1" DMY FROM SAME. IN PROGRESS. 4/12/2023 12:00:00 AM ANN_COMM_EVENT AC EVAL S-LINE SET 1" DMY IN GLM #3 @12,632' RKB; ATTEMPT TO MIT-IA **FAILED**; PULLED 1" DMY FROM SAME. IN PROGRESS. 4/10/2023 5:59:35 PM WELL_EVENT WELL SHUTDOWN 4/4/2023 6:00:00 PM EVENT_LOG_DAILY PUMPING CIRC-OUT TBG/IA. PUMP 580 BBLS CI/SW AND 224 BBLS DIESEL DOWN TUBING UP IA. TAKING RETURNS TO MT7-06. U-TUBE FOR FREEZE PROTECT. JOB COMPLETE 4/4/2023 5:30:00 AM EVENT_LOG_DAILY SLICK LINE PULL 1" OV FROM 12632' RKB & ***OPEN POCKET***. PULL 1" OV & SET DV @ 8628' RKB. PULL 1" OV & SET DV @ 4252' RKB. READY FOR CIRC OUT. JOB IN PROGRESS. 4/3/2023 6:14:25 AM ANN_COMM_EVENT S-LINE GAUGE TBG 3.72" & BRUSH TO 13059' RKB. SET 3.75 DBP @ 13059' RKB. 5/15/23, 4:14 PM Well History (Full) MT7-08 501032084600 https://akapps.cop.net/WebBert/Well/Report/rptWell.aspx?REPORT=..%2f..%2fUserControl%2fWell%2fReport%2fucWellTblEventFull2.ascx&API=5013/5 PERFORM PASSING DDT. LDFN. IN PROGRESS. 4/3/2023 5:30:00 AM EVENT_LOG_DAILY SLICK LINE GAUGE TBG 3.72" & BRUSH TO 13059' RKB. SET 3.75 DBP w/ BAITED PRONG @ 13059' RKB. PERFORM PASSING DDT. LDFN. IN PROGRESS. 3/25/2023 4:37:57 PM WELL_EVENT RESERVIOR UNCONTROLL DRILLSITE SHTDWN - RESERVIOR UNCONTROLL 3/25/2023 4:00:00 PM EVENT_LOG_DAILY PUMPING FREEZE PROTECT TBG 43 BBLS DIESEL 5BBLS DIESEL DOWN FLOWLINE JOB COMPLETE 2/21/2023 4:02:26 AM PRESSURE_BLEED INNER ANNULUS PRESSURE ( End = 623 ) OUTER ANNULUS PRESSURE ( Start = 1, End = 80 ) 2/5/2023 1:08:35 PM WELL_EVENT WELL OPEN ( Oil rate = 1521 ) 2/5/2023 12:38:43 PM WELL_EVENT REGULATORY/COMPLIANC WELL SHUTDOWN - REGULATORY/COMPLIANC 2/4/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONDUCTED 2ND / FINAL SURGE WITH OPS ASSIST (FINAL STEP PRIOR TO RD) BALLCATCHER WAS CLEAN AFTER A BOTTOMS-UP. (NO DEBRIS) LRS DID BLOWDOWN AND RD. JOB COMPLETE. 2/3/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / CLEAN UP WELL PER PROCEDURE. LRS CONDUCTED 1ST SURGING WITH OPS ASSIST (FINAL STEP PRIOR TO RD) 2/2/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / CLEAN- UP WELL PER PROCEDURE, LRS RETRIEVED SOME DEBRIS / DART MATERIAL FROM THE BALLCATCHER. 2/1/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / CLEAN- UP WELL PER PROCEDURE, LRS CONTINUES THE SURGING PROCESS TO ATTEMPT TO GET MORE DEBRIS / BOARDS TO COME TO SURFACE. LRS RETRIEVED SOME DEBRIS / DART MATERIAL FROM THE BALLCATCHER. 1/31/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / CLEAN- UP WELL PER PROCEDURE, LRS RU CNG GL HOSE IN ORDER TO BACKFLOW DOWN THE TBG, IN AN ATTEMPT TO DISLODGE DEBRIS/BOARDS AND GET THEM TO FLOW TO SURFACE. LRS CONTINUES THE SURGING PROCESS TO ATTEMPT TO GET MORE DEBRIS / BOARDS TO COME TO SURFACE. LRS RETRIEVED DEBRIS / BOARD FROM BALLCATCHER (7 TOTAL BOARDS RECOVERED) 5/15/23, 4:14 PM Well History (Full) MT7-08 501032084600 https://akapps.cop.net/WebBert/Well/Report/rptWell.aspx?REPORT=..%2f..%2fUserControl%2fWell%2fReport%2fucWellTblEventFull2.ascx&API=5014/5 1/30/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / CLEAN- UP WELL PER PROCEDURE, LRS ACHIEVED FULL OPEN CHOKE, THEN BY-PASSED CHOKE. LRS STARTED SURGING PROCESS TO ATTEMPT TO GET MORE DEBRIS / BOARDS TO COME TO SURFACE. NO DEBRIS / BOARDS HAVE BEEN SEEN OVER THE LAST 24 HRS. ONLY 6 OF 21 BOARDS HAVE BEEN RECOVERED SO FAR. 1/29/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / CLEAN- UP WELL PER PROCEDURE, INCREASING CHOKE AS WELL CONDITIONS PERMIT. LRS RETRIEVING SMART DART DEBRIS FROM BALLCATCHER. 1/28/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / UNLOAD / CLEAN-UP WELL PER PROCEDURE, INCREASING CHOKE AS WELL CONDITIONS PERMIT. LRS RETRIEVING SMART DART DEBRIS FROM BALLCATCHER. OPS SHUT OFF GL SINCE FORM GAS HAS INCREASED. DHD SHOT IA F/L AT 1PM, WAS AT 10192' (2440' ABOVE 3RD/BOTTOM STAT) 1/27/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS CONTINUES TO FLOW / UNLOAD / CLEAN-UP WELL PER PROCEDURE, INCREASING CHOKE AS WELL CONDITIONS PERMIT. 1/26/2023 2:10:00 PM WELL_EVENT WELL OPEN ( Oil rate = 0 ) 1/26/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING LRS COMPLETED RU AT 2AM. LRS / OPS COMPLETED WALKDOWN/SIGNOFF OF THE RU. LRS STARTED PT AT 3AM. DHD SHOT IA F/L AT 7AM, WAS AT 5790' (2838' ABOVE 2ND STAT). LRS COMPLETED PT OF THE INLET HL AND BALLCATCHER. (GOOD PT) LRS FINISHED WRAPPING / HEATING THE INLET HL AND BALLCATCHER. LRS POP'D MT7-08 AT 2:10PM DHD SHOT IA F/L AT 3:45PM, WAS AT 6818'' (1810' ABOVE 2ND STAT). 1/25/2023 12:00:00 AM EVENT_LOG_DAILY WELL TESTING WELL SUPPORT SET WELLHOUSE WELL SUPPORT INSTALLED TEMP GL LINE FROM MT7-09 TO MT7-08. LRS PUMPED 10 BBL METHANOL PILL DOWN IA OPS STARTED GL TO MT7-08 AT 5PM TO START DE-INVENTORY IA. LRS STARTED RU OF THE INLET HL & BALLCATCHER AT 6:30PM 1/24/2023 12:00:00 AM EVENT_LOG_DAILY FRAC CONTINUE PUMPING DOWN DARTS 17,18,19,20 FREEZE PROTECT WELL START RIGGING DOWN NIPPLE DOWN LAUNCHER 5/15/23, 4:14 PM Well History (Full) MT7-08 501032084600 https://akapps.cop.net/WebBert/Well/Report/rptWell.aspx?REPORT=..%2f..%2fUserControl%2fWell%2fReport%2fucWellTblEventFull2.ascx&API=5015/5 1/23/2023 12:00:00 AM EVENT_LOG_DAILY FRAC PUMPED DARTS 1-16, DART 1 AND 2 HAD A GOOD SEAT AND DIFFERENTIAL PSI, DART 3 HAD A SLIGHT PRESSURE DECREASE AND NO PRESSURE INCREASE, THE BACKUP DART WAS LAUNCHED WITH THE SAME ENDING RESULTS. DART 4 WAS LAUNCHED WITH A VERY SLIGHT PSI INCREASE 20 BBL EARLY, THE REMAINING DARTS ALL HAD A GOOD SEAT AND PRESSURE DIFFERENTIAL. 1/22/2023 12:00:00 AM EVENT_LOG_DAILY FRAC COMPLETED RIG IN OF DART LAUNCH EQUALIZATION LINE TANK FARM READY TO FILL@ 18:00 RESUMED FILLING TANKS 1/21/2023 12:00:00 AM EVENT_LOG_DAILY FRAC RIGGING IN IRON TO WELL, SET POP OFF AND BLEED TANKS, TIE IN, NIPPLE UP GREAT NORTH DART LAUNCH EQUIPMENT, HEAT LVT, PREPARE TO FLOW WATER 1/20/2023 5:30:00 AM EVENT_LOG_DAILY FRAC DIGGING OUT EQUIPMENT, STARTING TRACTORS, DIGGING OUT IRON, STARTING TCC 1/18/2023 12:00:00 AM EVENT_LOG_DAILY SLICK LINE SET 7/16" OV IN STA # 2 @ 8628' RKB. PULL DMY VLV @ STA #3 12.632' RKB AND REPLACED w/ 7/16" OV. PULL BAIT SUB CATCHER, BALL AND ROD; PULLED RHC PLUG BODY @ 13,059' RKB. JOB COMPLETE. 1/17/2023 5:30:00 AM EVENT_LOG_DAILY SLICK LINE SET BAITED CATCHER ON BALL & ROD @ 13,050' RKB; PULLED 1" SOV FROM GLM #1 @ 4252' RKB; SET 1" 7/16" OV IN STA # 1 @ 4252' RKB. PULLED DMY VLV STA # 2 @ 8628' RKB. JOB IN PROGRESS 1/12/2023 12:00:00 AM WELL_HEADER PRODUCTION OIL - PRODUCTION - ACTIVE 1/12/2023 12:00:00 AM WELL_HEADER RIG RELEASE 12/28/2022 12:00:00 AM WELL_DIR_SRVY IIFR-MS-SAG DEFINITIE FINAL; TIE IN TO MT7- 08PB1@ 21907.09; TOP KOP 21974.95'; LST SVY PT 29173.18; PROJ TD 29203' MD 12/27/2022 11:22:15 AM WELL_EVENT SAND CODE 12/27/2022 11:02:30 AM WELL_EVENT WELL SHUTDOWN 10/28/2022 12:00:00 AM WELL_HEADER SERVICE SERVICE - PROPOSED 57 records retrieved for Well History (Full) Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Injection Prep MT7-08 4/14/2023 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: LTP @ 13,083' not tested due to damaged seal in running tool. Can't be used as a barrier. 1/12/2023 rmoore22 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 19.12 40.0 80.0 80.0 94.00 L80 Welded Surface 13 3/8 12.42 38.1 3,458.6 3,025.0 68.00 L-80 H563 Intermediate 1 9 5/8 8.76 -0.8 11,041.0 7,367.5 43.50 L80 Hyd563 Intermediate 2 7 6.28 10,855.9 13,245.0 8,298.1 26.00 L-80 TSH 563 Liner 4 1/2 3.96 13,083.2 29,193.0 8,489.3 12.60 L-80 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.1 Set Depth 13,089.8 Set Depth 8,261.3 String Ma 4 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 34.1 34.1 0.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril HYD 563 FMC TC-EMS 3.958 1,854.7 1,818.5 21.34 Nipple - X 4.500 NIPPLE,LANDING, ,X, H563 HES X Nipple 3.813 4,252.3 3,473.2 55.25 Mandrel 4.500 4-1/2" x 1" KBG 4-5 GLM,12.6# H563 Camco KBG4-5 3.865 8,628.2 5,983.5 55.07 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.860 12,632.3 8,125.6 69.77 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.860 12,739.4 8,161.5 70.98 Gauge / Pump Sensor 4.500 Halliburton Opsis Mandrel w/ Downhole gauge HES DHG 3.920 12,838.1 8,192.7 72.36 Packer 4.500 Halliburton TNT Packer HES TNT 3.880 13,059.3 8,253.8 75.67 Nipple - DB 4.500 NIPPLE,LANDING, DB, H563 SLB OSDB-6 3.750 13,080.9 8,259.1 75.78 No-go Nipple 4.940 No-Go locator sub- 5.76" OD Baker 3.910 13,086.6 8,260.5 75.80 Mule Shoe 4.500 HES Self indexing Mule Shoe HES Self orienting 3.958 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,252.3 3,473.2 55.25 1 GAS LIFT DMY BK 1 4/4/2023 8,628.2 5,983.5 55.07 2 GAS LIFT DMY BK 1 4/14/2023 12,632.3 8,125.6 69.77 3 GAS LIFT DMY BK 1 4/14/2023 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,628.3 8,350.4 85.35 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 13,991.9 8,379.8 85.80 Swell Packer 4.500 Baker Rapidswell 906 3.910 14,415.1 8,390.9 89.58 Swell Packer 4.500 Baker Rapidswell 906 3.910 14,758.7 8,393.3 89.59 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 15,085.5 8,397.5 89.12 Swell Packer 4.500 Baker Rapidswell 906 3.910 15,430.8 8,404.5 88.60 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 15,758.5 8,412.6 88.63 Swell Packer 4.500 Baker Rapidswell 906 3.910 16,100.2 8,420.1 89.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 16,462.1 8,420.9 90.09 Swell Packer 4.500 Baker Rapidswell 906 3.910 16,761.5 8,421.5 89.60 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 17,123.2 8,424.0 89.61 Swell Packer 4.500 Baker Rapidswell 906 3.910 17,505.9 8,425.3 90.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 17,912.1 8,424.8 90.08 Swell Packer 4.500 Baker Rapidswell 906 3.910 18,696.6 8,435.6 88.10 Swell Packer 4.500 Baker Rapidswell 922 3.910 19,082.2 8,451.4 87.55 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 HORIZONTAL, MT7-08, 5/2/2023 9:33:19 PM Vertical schematic (actual) Liner; 13,083.2-29,193.0 Intermediate 2; 10,855.9- 13,245.0 Mule Shoe; 13,086.6 Pup Joint; 13,081.5 No-go Nipple; 13,080.9 Nipple - DB; 13,059.3 Packer; 12,838.1 Mandrel; 12,632.3 Intermediate String 2 Cement; 11,560.0 ftKB Intermediate 1; -0.8-11,041.0 Intermediate String 1 Cement; 6,856.0 ftKB Mandrel; 8,628.2 Mandrel; 4,252.3 Surface; 38.1-3,458.6 Nipple - X; 1,854.7 Surface String Cement; 38.2 ftKB Conductor; 40.0-80.0 Hanger; 34.1 WNS INJ KB-Grd (ft) 39.00 RR Date 1/12/2023 Other Elev MT7-08 ... TD Act Btm (ftKB) 29,203.0 Well Attributes Field Name RENDE Wellbore API/UWI 501032084600 Wellbore Status INJ Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBOREMT7-08 Annotation End DateH2S (ppm) DateComment Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 19,486.8 8,465.5 88.75 Swell Packer 4.500 Baker Rapidswell 922 3.910 19,868.8 8,467.0 90.11 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 20,274.5 8,465.4 90.59 Swell Packer 4.500 Baker Rapidswell 922 3.910 20,695.9 8,457.8 91.57 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 21,066.8 8,455.6 89.50 Swell Packer 4.500 Baker Rapidswell 922 3.910 21,497.2 8,462.0 89.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 21,861.9 8,463.3 90.09 Swell Packer 4.500 Baker Rapidswell 922 3.910 22,167.9 8,467.5 87.86 Swell Packer 4.500 Baker Rapidswell 922 3.910 22,513.7 8,478.2 88.55 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 22,806.3 8,483.8 89.10 Swell Packer 4.500 Baker Rapidswell 922 3.910 23,151.0 8,489.4 88.95 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 23,472.6 8,499.7 87.88 Swell Packer 4.500 Baker Rapidswell 922 3.910 24,095.4 8,492.9 91.97 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 24,460.6 8,485.9 89.97 Swell Packer 4.500 Baker Rapidswell 922 3.910 24,843.1 8,483.8 89.98 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 25,166.1 8,485.2 90.00 Swell Packer 4.500 Baker Rapidswell 922 3.910 25,550.6 8,484.9 89.46 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 25,913.3 8,485.5 89.97 Swell Packer 4.500 Baker Rapidswell 922 3.910 26,295.1 8,481.2 89.75 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 26,621.0 8,491.9 87.93 Swell Packer 4.500 Baker Rapidswell 922 3.910 27,005.0 8,500.9 88.95 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 27,330.3 8,506.8 88.96 Swell Packer 4.500 Baker Rapidswell 922 3.910 27,667.8 8,512.6 89.88 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 28,035.8 8,503.9 91.12 Swell Packer 4.500 Baker Rapidswell 922 3.910 28,425.8 8,503.3 89.56 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 28,757.7 8,501.7 90.92 Swell Packer 4.500 Baker Rapidswell 922 3.910 29,145.6 8,490.9 91.97 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 HORIZONTAL, MT7-08, 5/2/2023 9:33:20 PM Vertical schematic (actual) Liner; 13,083.2-29,193.0 Intermediate 2; 10,855.9- 13,245.0 Mule Shoe; 13,086.6 Pup Joint; 13,081.5 No-go Nipple; 13,080.9 Nipple - DB; 13,059.3 Packer; 12,838.1 Mandrel; 12,632.3 Intermediate String 2 Cement; 11,560.0 ftKB Intermediate 1; -0.8-11,041.0 Intermediate String 1 Cement; 6,856.0 ftKB Mandrel; 8,628.2 Mandrel; 4,252.3 Surface; 38.1-3,458.6 Nipple - X; 1,854.7 Surface String Cement; 38.2 ftKB Conductor; 40.0-80.0 Hanger; 34.1 WNS INJ MT7-08 ... WELLNAME WELLBOREMT7-08 JLC 3/15/2023 RBDMS JSB 032323 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: __Convert Inj to Prod_ ConocoPhillips Alaska Inc Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 29,203 feet NA feet true vertical 8,489 feet NA feet Effective Depth measured 29189 feet 12838 feet true vertical 8489 feet 8192 feet Perforation depth Measured depth 13628-29145 feet True Vertical depth 8350-8491 feet Tubing (size, grade, measured and true vertical depth) 4.5" L80 13086' / 8260' Packers and SSSV (type, measured and true vertical depth) Halliburton TNT 12838' / 8192' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3458' 3025' Burst Collapse 2260 3810 7030 5020 6330 8160 measured TVD Intermediate 2 Liner 11002 2390 16100 Casing Structural 7368' 8297' 4.5" 11042' 13244' 29189' 8489' Plugs Junk measured NA Length 80 3418 120'Conductor Surface Intermediate 20" 13-3/8" NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: AA081800, AA081781, AA081736 Greater Mooses Tooth / Rendezvous STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-116 50-103-20846-00-00 Size 120' 265 5743438 1195 407285 406 9-5/8" 8430 7" PO Box 100360, Anchorage AK 995103. Address: GMT MT7-99 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1067 Gas-Mcf MD 578 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Sr Pet Eng: 7500 Sr Pet Geo: Sr Res Eng: WINJ WAG 3641 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Greater Mooses Tooth / Rendezvous Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Staff Production Engineer Dana Glessner glessd@conocophillips.com 907-265-6478 By Samantha Carlisle at 12:30 pm, Feb 28, 2023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 28 February 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well GMTU MT7-08 (PTD 222-116) to convert the well from injection to production. GMTU MT7-08 was originally permitted as an injector and planned to preproduce for less than 30 days. However due to status changes with other wells on the pad it was decided to extend the preproduction period on MT7-08 for more than 30 days. The well was first placed on production post drilling and completion on 01/26/2023 and CPAI intends to continue production through March 2023 now. Please contact me at 265-6478 if you have any questions. Sincerely, Dana Glessner Staff Production Engineer ConocoPhillips Alaska, Inc. Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLVs, pull B&R & RHC post rig MT7-08 1/18/2023 rmoore22 General Notes: Last 3 entries Com Date Last Mod By No BPV in wellhead 1/12/2023 d25cm Liner Top Packer @ 13,083' not tested due to damaged seal in running tool. Cannot be used as barrier for future work. 1/12/2023 d25cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 19.12 40.0 80.0 80.0 94.00 L80 Welded Surface 13 3/8 12.42 38.1 3,458.6 3,025.0 68.00 L-80 H563 Intermediate 1 9 5/8 8.76 -0.8 11,041.0 7,367.5 43.50 L80 Hyd563 Intermediate 2 7 6.28 10,855.9 13,245.0 8,298.1 26.00 L-80 TSH 563 Liner 4 1/2 3.96 13,083.2 29,193.0 8,489.3 12.60 L-80 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.1 Set Depth 13,089.8 Set Depth 8,261.3 String Ma 4 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 34.1 34.1 0.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril HYD 563 FMC TC-EMS 3.958 1,854.7 1,818.5 21.34 Nipple - DB, XN, DS, D 4.500 NIPPLE,LANDING,4 1/2","X",3.813", H563 HES X Nipple 3.813 4,252.3 3,473.2 55.25 Mandrel 4.500 4-1/2" x 1" KBG 4-5 GLM,12.6# H563 Camco KBG4-5 3.865 8,628.2 5,983.5 55.07 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.860 12,632.3 8,125.6 69.77 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.860 12,739.4 8,161.5 70.98 Gauge / Pump Sensor 4.500 Halliburton Opsis Mandrel w/ Downhole gauge HES DHG 3.920 13,059.3 8,253.8 75.67 Nipple - DB, XN, DS, D 4.500 NIPPLE,LANDING,4 1/2",DB,3.75", H563 SLB OSDB-6 3.750 13,080.9 8,259.1 75.78 No-go Nipple 4.940 No-Go locator sub- 5.76" OD Baker 3.910 13,086.6 8,260.5 75.80 Mule Shoe 4.500 HES Self indexing Mule Shoe HES Self orienting 3.958 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,252.3 3,473.2 55.25 1 GAS LIFT OV BK 1 1/17/2023 0.438 8,628.2 5,983.5 55.07 2 GAS LIFT OV BK 1 1/18/2023 0.438 12,632.3 8,125.6 69.77 3 GAS LIFT OV BK 1 1/18/2023 0.438 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,628.3 8,350.4 85.35 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 13,991.9 8,379.8 85.80 Swell Packer 4.500 Baker Rapidswell 906 3.910 14,415.1 8,390.9 89.58 Swell Packer 4.500 Baker Rapidswell 906 3.910 14,758.7 8,393.3 89.59 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 15,085.5 8,397.5 89.12 Swell Packer 4.500 Baker Rapidswell 906 3.910 15,430.8 8,404.5 88.60 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 15,758.5 8,412.6 88.63 Swell Packer 4.500 Baker Rapidswell 906 3.910 16,100.2 8,420.1 89.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 16,462.1 8,420.9 90.09 Swell Packer 4.500 Baker Rapidswell 906 3.910 16,761.5 8,421.5 89.60 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 17,123.2 8,424.0 89.61 Swell Packer 4.500 Baker Rapidswell 906 3.910 17,505.9 8,425.3 90.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 17,912.1 8,424.8 90.08 Swell Packer 4.500 Baker Rapidswell 906 3.910 18,696.6 8,435.6 88.10 Swell Packer 4.500 Baker Rapidswell 922 3.910 19,082.2 8,451.4 87.55 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 HORIZONTAL, MT7-08, 1/18/2023 10:10:31 AM Vertical schematic (actual) Liner; 13,083.2-29,193.0 Shoe; 29,188.2-29,193.0 FRAC Sleeve/Port; 29,145.6- 29,147.7 Swell Packer; 28,757.7-28,777.7 FRAC Sleeve/Port; 28,425.8- 28,427.9 Swell Packer; 28,035.8-28,055.9 FRAC Sleeve/Port; 27,667.8- 27,669.8 Swell Packer; 27,330.3-27,350.3 FRAC Sleeve/Port; 27,005.0- 27,007.1 Swell Packer; 26,621.0-26,641.0 FRAC Sleeve/Port; 26,295.1- 26,297.2 Swell Packer; 25,913.2-25,933.3 FRAC Sleeve/Port; 25,550.6- 25,552.6 Swell Packer; 25,166.1-25,186.2 FRAC Sleeve/Port; 24,843.1- 24,845.1 Swell Packer; 24,460.6-24,480.7 FRAC Sleeve/Port; 24,095.4- 24,097.5 Swell Packer; 23,472.6-23,492.7 FRAC Sleeve/Port; 23,151.0- 23,153.1 Swell Packer; 22,806.3-22,826.4 FRAC Sleeve/Port; 22,513.7- 22,515.8 Swell Packer; 22,167.9-22,187.9 Swell Packer; 21,861.9-21,881.9 FRAC Sleeve/Port; 21,497.2- 21,499.3 Swell Packer; 21,066.8-21,086.9 FRAC Sleeve/Port; 20,695.8- 20,697.9 Swell Packer; 20,274.4-20,294.5 FRAC Sleeve/Port; 19,868.7- 19,870.8 Swell Packer; 19,486.8-19,506.9 FRAC Sleeve/Port; 19,082.2- 19,084.2 Swell Packer; 18,696.6-18,716.6 Swell Packer; 17,912.0-17,932.1 FRAC Sleeve/Port; 17,505.9- 17,507.9 Swell Packer; 17,123.2-17,143.3 FRAC Sleeve/Port; 16,761.5- 16,763.5 Swell Packer; 16,462.1-16,482.1 FRAC Sleeve/Port; 16,100.2- 16,102.3 Swell Packer; 15,758.5-15,778.6 FRAC Sleeve/Port; 15,430.8- 15,432.9 Swell Packer; 15,085.5-15,105.6 FRAC Sleeve/Port; 14,758.7- 14,760.7 Swell Packer; 14,415.1-14,435.2 Swell Packer; 13,991.9-14,011.9 FRAC Sleeve/Port; 13,628.2- 13,630.3 Intermediate 2; 10,855.9- 13,245.0 Float Shoe; 13,242.1-13,245.0 Collar - Float; 13,195.8-13,197.2 Landing Collar; 13,157.8- 13,161.1 Hanger; 13,099.5-13,108.8 Packer (Liner Top); 13,083.2- 13,099.5 Packer (Tubing); 12,838.1 Gauge / Pump Sensor; 12,739.4 Mandrel; 12,632.3 Intermediate String 2 Cement; 11,560.0 ftKB Intermediate 1; -0.8-11,041.0 9-5/8" Davis Lynch Float Shoe, H563. Aluminium nose; 11,037.9 -11,041.0 Collar - Float; 10,950.1-10,952.8 Hanger; 10,880.3-10,889.9 Nipple; 10,877.5-10,880.3 Packer; 10,855.9-10,877.5 Intermediate String 1 Cement; 6,856.0 ftKB Mandrel; 8,628.2 Mandrel; 4,252.3 Surface; 38.1-3,458.6 Float Shoe; 3,456.4-3,458.6 Surface String Cement; 38.2 ftKB Conductor; 40.0-80.0 Casing Hanger; 38.1-39.4 Hanger; 34.1 Casing Hanger; -0.8-37.1 WNS SVC KB-Grd (ft) 39.00 RR Date Other Elev MT7-08 ... TD Act Btm (ftKB) 29,203.0 Well Attributes Field Name RENDE Wellbore API/UWI 501032084600 Wellbore Status SVC Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBOREMT7-08 Annotation End DateH2S (ppm) DateComment Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 19,486.8 8,465.5 88.75 Swell Packer 4.500 Baker Rapidswell 922 3.910 19,868.8 8,467.0 90.11 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 20,274.5 8,465.4 90.59 Swell Packer 4.500 Baker Rapidswell 922 3.910 20,695.9 8,457.8 91.57 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 21,066.8 8,455.6 89.50 Swell Packer 4.500 Baker Rapidswell 922 3.910 21,497.2 8,462.0 89.09 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 21,861.9 8,463.3 90.09 Swell Packer 4.500 Baker Rapidswell 922 3.910 22,167.9 8,467.5 87.86 Swell Packer 4.500 Baker Rapidswell 922 3.910 22,513.7 8,478.2 88.55 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 22,806.3 8,483.8 89.10 Swell Packer 4.500 Baker Rapidswell 922 3.910 23,151.0 8,489.4 88.95 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 23,472.6 8,499.7 87.88 Swell Packer 4.500 Baker Rapidswell 922 3.910 24,095.4 8,492.9 91.97 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 24,460.6 8,485.9 89.97 Swell Packer 4.500 Baker Rapidswell 922 3.910 24,843.1 8,483.8 89.98 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 25,166.1 8,485.2 90.00 Swell Packer 4.500 Baker Rapidswell 922 3.910 25,550.6 8,484.9 89.46 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 25,913.3 8,485.5 89.97 Swell Packer 4.500 Baker Rapidswell 922 3.910 26,295.1 8,481.2 89.75 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 26,621.0 8,491.9 87.93 Swell Packer 4.500 Baker Rapidswell 922 3.910 27,005.0 8,500.9 88.95 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 27,330.3 8,506.8 88.96 Swell Packer 4.500 Baker Rapidswell 922 3.910 27,667.8 8,512.6 89.88 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 28,035.8 8,503.9 91.12 Swell Packer 4.500 Baker Rapidswell 922 3.910 28,425.8 8,503.3 89.56 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 28,757.7 8,501.7 90.92 Swell Packer 4.500 Baker Rapidswell 922 3.910 29,145.6 8,490.9 91.97 FRAC Sleeve/Port 4.500 Advance d Upstrea m LOLC 3.505 HORIZONTAL, MT7-08, 1/18/2023 10:10:32 AM Vertical schematic (actual) Liner; 13,083.2-29,193.0 Shoe; 29,188.2-29,193.0 FRAC Sleeve/Port; 29,145.6- 29,147.7 Swell Packer; 28,757.7-28,777.7 FRAC Sleeve/Port; 28,425.8- 28,427.9 Swell Packer; 28,035.8-28,055.9 FRAC Sleeve/Port; 27,667.8- 27,669.8 Swell Packer; 27,330.3-27,350.3 FRAC Sleeve/Port; 27,005.0- 27,007.1 Swell Packer; 26,621.0-26,641.0 FRAC Sleeve/Port; 26,295.1- 26,297.2 Swell Packer; 25,913.2-25,933.3 FRAC Sleeve/Port; 25,550.6- 25,552.6 Swell Packer; 25,166.1-25,186.2 FRAC Sleeve/Port; 24,843.1- 24,845.1 Swell Packer; 24,460.6-24,480.7 FRAC Sleeve/Port; 24,095.4- 24,097.5 Swell Packer; 23,472.6-23,492.7 FRAC Sleeve/Port; 23,151.0- 23,153.1 Swell Packer; 22,806.3-22,826.4 FRAC Sleeve/Port; 22,513.7- 22,515.8 Swell Packer; 22,167.9-22,187.9 Swell Packer; 21,861.9-21,881.9 FRAC Sleeve/Port; 21,497.2- 21,499.3 Swell Packer; 21,066.8-21,086.9 FRAC Sleeve/Port; 20,695.8- 20,697.9 Swell Packer; 20,274.4-20,294.5 FRAC Sleeve/Port; 19,868.7- 19,870.8 Swell Packer; 19,486.8-19,506.9 FRAC Sleeve/Port; 19,082.2- 19,084.2 Swell Packer; 18,696.6-18,716.6 Swell Packer; 17,912.0-17,932.1 FRAC Sleeve/Port; 17,505.9- 17,507.9 Swell Packer; 17,123.2-17,143.3 FRAC Sleeve/Port; 16,761.5- 16,763.5 Swell Packer; 16,462.1-16,482.1 FRAC Sleeve/Port; 16,100.2- 16,102.3 Swell Packer; 15,758.5-15,778.6 FRAC Sleeve/Port; 15,430.8- 15,432.9 Swell Packer; 15,085.5-15,105.6 FRAC Sleeve/Port; 14,758.7- 14,760.7 Swell Packer; 14,415.1-14,435.2 Swell Packer; 13,991.9-14,011.9 FRAC Sleeve/Port; 13,628.2- 13,630.3 Intermediate 2; 10,855.9- 13,245.0 Float Shoe; 13,242.1-13,245.0 Collar - Float; 13,195.8-13,197.2 Landing Collar; 13,157.8- 13,161.1 Hanger; 13,099.5-13,108.8 Packer (Liner Top); 13,083.2- 13,099.5 Packer (Tubing); 12,838.1 Gauge / Pump Sensor; 12,739.4 Mandrel; 12,632.3 Intermediate String 2 Cement; 11,560.0 ftKB Intermediate 1; -0.8-11,041.0 9-5/8" Davis Lynch Float Shoe, H563. Aluminium nose; 11,037.9 -11,041.0 Collar - Float; 10,950.1-10,952.8 Hanger; 10,880.3-10,889.9 Nipple; 10,877.5-10,880.3 Packer; 10,855.9-10,877.5 Intermediate String 1 Cement; 6,856.0 ftKB Mandrel; 8,628.2 Mandrel; 4,252.3 Surface; 38.1-3,458.6 Float Shoe; 3,456.4-3,458.6 Surface String Cement; 38.2 ftKB Conductor; 40.0-80.0 Casing Hanger; 38.1-39.4 Hanger; 34.1 Casing Hanger; -0.8-37.1 WNS SVC MT7-08 ... WELLNAME WELLBOREMT7-08 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: 5024' FSL, 1169' FWL SESW S7 T9N R2E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 100.8 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" L-80 80' 13 3/8" L-80 3025' 9 5/8" L-80 7368' 7" L-80 8298' 4 1/2" L-80 8489' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner: 13,083'MD/8,260' TVD - 29,193'MD/8,489'TVD Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A GR, RES, DEN, DIR, AZI, PWD, SONIC, CALIPER 40' 40' Per 20 AAC 25.283 (i)(2) attach electronic information 43.5 13245' 40' 7262' 94 68 80' 40' 11041' SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 13083' 42" 12.6 5915772 Greater Mooses Tooth/Rendevous Pool AA081800, AA081781, AA081736 932535000, 932516000, 300840000 40' 26 40' 10856' 3459' 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 283919 290759 CEMENTING RECORD 5909454 982'MD/980'TVD SETTING DEPTH TVD 5895166 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 1/12/2023 222-116 501-103-20846-00-00 GMT/MT7-08 12/2/2022 29203'MD/8489'TVD N/A 139.8 P.O.Box 100360, Anchorage, AK 99510-0360 289901 948' FSL, 1824' FWL SESW S32 T10N R2E 1493' FSL, 3187' FWL SESW S20 T9N R2E 1/4/2023 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 79bbls 15.8ppg Class G8.5"x9 7/8" TUBING RECORD 29193' Lead: 73bbl 13ppg Class G Tail: 258bbl 15.8ppg Class G 8260' 12 1/4" 6 1/8" 13090'4.5 10,856'MD/7,276'TVD 12838'MD/8,220'TVD 13,083'MD/8,266' TVD BOTTOM 16" Lead: 395bbl 11ppg DeepCRETE Tail: 72bbl 15.8ppg Class G CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Completed 1/12/2023 JSB RBDMS JSB 021323 Received 2/6/2023 G DSR-2/15/23SFD 3/08/2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 985 980 C-30 1426 1411 2038 1987 3400 2994 K-2 4009 3334 Albian 97 4477 3602 Albian 96 4822 3801 HRZ 11041 7368 Kalubik 11288 7505 Kuparuk C 11504 7621 11517 7628 13353 8319 29203 8489 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: Jenna Taylor Digital Signature with Date: Contact Phone:907-263-4522 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 D Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval Alpine C 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: jenna.l.taylor@conocophillips.com Authorized Title: Wells Analyst K-3 Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jenna Taylor DN: CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.com Reason: I am the author of this document Location: Date: 2023.02.10 09:31:00-09'00' Foxit PDF Editor Version: 12.0.1 Jenna Taylor Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG 4-5 (3x) 3) HES Opsis Downhole Gauge 4) HES TNT Production Packer 5) 4-½” DB Landing Nipple (3.75" ID) 6) Baker Liner Top Packer / Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner w/ swell packers and closeable AU frac sleeves MW: 9.5 Visc Brine 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-5/16” Production Hole TD at 29,203' MD / 8,489' TVD Tubing 4-1/2" 12.6# L-80 Hyd563 MT7-08 Final Schematic X GLGL GLGL 01/18/2023 Production Packer ZXP Liner Top Packer Downhole Gauge 16" Surface Hole Surface Casing 13-3/8" 68# L-80 Hyd563 Set at 3,458' MD / 3,025' TVD 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7" 29# L-80 HYD563 Liner top at +/- 10,854' MD / 7,261' TVD Shoe set @ 13,244' MD / 8,297' TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8" 43.5# L-80 HYD563 + 5000' 47# T-95 HYD563 Set @ 11,042' MD / 7,368' TVD Top HRZ 11,041' MD / 7,368' TVD 4-String Southern Injector Top Alpine D 13,131' MD / 8,272' TVD Top Albian Sub 93 7,356' MD / 5,255' TVD Estimated Int1 TOC 6,675' MD / 4,860' TVD Top Alpine C 13,353' MD / 8,319' TVD Logged Int2 TOC 11,560' MD / 7,650' TVD Flotation Sub Page 1/50 MT7-08 Report Printed: 1/26/2023 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) 11/30/2022 00:00 11/30/2022 02:00 2.00 MIRU, MOVE DMOB P Unbridal and pin top drive, spool drilling line off drum and secure top drive and service loops in the derrick. Blow down water and steam lines. 0.0 0.0 11/30/2022 02:00 11/30/2022 05:30 3.50 MIRU, MOVE MOB P Put modules on individaul power, rig down interconects and flow line. Scope down derrick, lower cattle shoot, raise C section and skid the rig floor. Put pipe shed in suspension. 0.0 0.0 11/30/2022 05:30 11/30/2022 06:30 1.00 MIRU, MOVE MOB P Pre-job safety meeting, lay over the derrick. 0.0 11/30/2022 06:30 11/30/2022 12:00 5.50 MIRU, MOVE MOB P Move pump, pits, and motor modules away from rig and stage. Unpin pipe shed and stomp out, shuffle rig mats. 0.0 0.0 11/30/2022 12:00 11/30/2022 14:00 2.00 MIRU, MOVE MOB P Continue stomping pipe shed out to hook on truck. Put on suspension, hook up sow and move down pad. 0.0 0.0 11/30/2022 14:00 11/30/2022 19:00 5.00 MIRU, MOVE MOB P Stomp sub away from MT7-96 and line up for trucks. Install jeep and put on suspension. Move sub down pad and set in line for stomping over MT7-08. 0.0 0.0 11/30/2022 19:00 11/30/2022 21:00 2.00 MIRU, MOVE MOB P Stomp sub and spot over MT7-08, shim and level. 0.0 0.0 11/30/2022 21:00 12/1/2022 00:00 3.00 MIRU, MOVE MOB P Back pipe shed towards the sub, release truck and begin spotting pipe shed to the sub. 0.0 0.0 12/1/2022 00:00 12/1/2022 00:00 MIRU, MOVE 0.0 12/1/2022 00:00 12/1/2022 06:30 6.50 MIRU, MOVE MOB P Continue to stomp pipeshed into position. Stomp pits, motor, and pump modules and stage for spot. Hook sow up to casing shed and stage next to pipe shed for spotting. 0.0 0.0 12/1/2022 06:30 12/1/2022 09:00 2.50 MIRU, MOVE MOB P Shim pits and sub as needed for pinning. Pin pipe shed to the sub. 0.0 0.0 12/1/2022 09:00 12/1/2022 10:00 1.00 MIRU, MOVE MOB P Stomp pits module and spot to the sub. Crib around well head for lower cellar. 0.0 0.0 12/1/2022 10:00 12/1/2022 11:00 1.00 MIRU, MOVE MOB P Stop pump module and spot against pits module. 0.0 0.0 12/1/2022 11:00 12/1/2022 12:00 1.00 MIRU, MOVE MOB P Stop motor shed and spot against the pump module. Begin stomping casing shed into position. Lower stairs around the rig and secure landing and walkways. 0.0 0.0 12/1/2022 12:00 12/1/2022 14:00 2.00 MIRU, MOVE MOB P Stomp casing shed into position and shim to level. Set lower cellar, and scope up cellar rams. Begin working on electrical interconnects and hooking up mud lines in the pump room. 0.0 0.0 12/1/2022 14:00 12/1/2022 16:30 2.50 MIRU, MOVE MOB P Pre-job safety meeting, raise derrick and pin in place. Skid the rig floor and center over well. Close doors and secure. Continue working on electrical interconnects and hooking up mud lines in the pump room. 0.0 0.0 12/1/2022 16:30 12/1/2022 19:00 2.50 MIRU, MOVE MOB P Pre-job safety meeting, lower C-section and raise the cattle chute. Finish hooking up electrical interconnects and swap modules to main gen power. hook up mud lines in the pit complex, Install covers around the cattle chute and install the rear house. Energize amphion system. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 2/50 MT7-08 Report Printed: 1/26/2023 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) 12/1/2022 19:00 12/2/2022 00:00 5.00 MIRU, MOVE MOB P Pre-job safety meeting, untie lines in the derrick, bridal up, scope derrick and set in saddles. Remove bridal lines and secure all lines in the derrick. Lower derrick ladder, plug in upper section of derrick lights. Install kelly hose on the top drive. Continue working on interconnects in the pits. Rig accepted 23:30 hrs 12-01-2022 0.0 0.0 12/2/2022 00:00 12/2/2022 06:00 6.00 MIRU, MOVE NUND P Nipple up diverter tee, surface riser, begin changing saver sub to NC50, swap liners in pump #2 to 6.5". Begin taking on 10.5 ppg KSi mud and 13 ppg maintenance fluid and 13 ppg spike fluid. 0.0 0.0 12/2/2022 06:00 12/2/2022 10:30 4.50 MIRU, MOVE NUND P Install surface bag on riser, install jet lines, lower pressure riser, chink Joes box, install flow line, air up all boots, blank off kill line hose, chain 4" kill line valve closed, hook up downlink skid to mud manifold. Install fetter ring on save sub and install 5" bell guide. Continue taking on 10.5 ppg KSi mud and 13 ppg maintenance fluid and 13 ppg spike fluid. Load BHA components on the rig floor. 0.0 0.0 12/2/2022 10:30 12/2/2022 12:00 1.50 SURFAC, DRILL PULD P Install elevators on top drive, inspect hand slips, pick up and rack back 3 stands of 5" HWDP and 1 jar stand. 0.0 0.0 12/2/2022 12:00 12/2/2022 14:30 2.50 SURFAC, DRILL BHAH P Pre-job safety meeting with all hands, pick up BHA #1 per Baker DD. Fill conductor and riser (42 bbls), circulate at 150 gpm and check for leaks. Pressure test lines to 3,500 psi (good test). Wash down and tag at 98' MD. 0.0 98.0 12/2/2022 14:30 12/2/2022 16:30 2.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 98' - t/ 246' MD, 246' TVD, 575 gpm, 770 psi, 62% f/o, 40 rpm, 4k tq. 60k up wt, 62k dn wt. .8 hrs ADT, 21.2 bit hrs. 98.0 246.0 12/2/2022 16:30 12/2/2022 17:30 1.00 SURFAC, DRILL BKRM P Back ream out of the hole f/ 246' - t/ 56' MD, 575 gpm, 660 psi, 58% f/o, 40 rpm, 3k tq. 246.0 246.0 12/2/2022 17:30 12/2/2022 21:00 3.50 SURFAC, DRILL BHAH P Pick up remaining BHA #1 components f/ 56' - t/ 243' MD. Scribe motor to MWD and GWD tools for TF offsets per Baker DD, and SDI MWD. Make up to stand, test tools and shoot survey. 246.0 246.0 12/2/2022 21:00 12/3/2022 00:00 3.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 246' - t/ 582' MD, 581' TVD, 700 gpm, 1450 psi, 61% f/o, 11.3 ppg ECD, 10.5 pgg MW, 6k wob, 70 rpm, 6k tq, 78k up wt, 81k dn wt, 78k rot wt. 0.6 hrs AST, 1.2 hrs ART, 1.8 hrs ADT, 23 hrs total bit time. Consistent shaker load with uniform cuttings observed at the shakers. 246.0 582.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 3/50 MT7-08 Report Printed: 1/26/2023 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) 12/3/2022 00:00 12/3/2022 06:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 582' - t/ 1,090' MD, 1,086' TVD, 900 gpm, 2150 psi, 70% f/o, 11.5 ppg ECD, 11 ppg MW, 6- 20k wob, 60 rpm, 6k tq, 92k up wt, 97k dn wt, 92k rot wt. .4 hrs AST, 3.2 hrs ART, 3.6 hrs ADT, 6.2 bit run hrs, 27.1 hrs total bit time. 3.6 hrs on jars. Began weighing up mud to 11 ppg at 820' MD. Observed increase in fine cutting towards the BOPF 582.0 1,090.0 12/3/2022 06:00 12/3/2022 12:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 1,090' - t/ 1,758' MD, 1,728' TVD, 900 gpm, 2470 psi, 70% f/o, 11.6 ppg ECD, 11 ppg MW, 7- 15k wob, 60 rpm, 6k tq, 103k up wt, 103k dn wt, 106k rot wt. 1.4 hrs AST, 2.7 hrs ART, 4.1 hrs ADT, 10.3 bit run hrs, 30.7 hrs total bit time. 7.7 hrs on jars. 1,090.0 1,758.0 12/3/2022 12:00 12/3/2022 18:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 1,758' - t/ 2,410' MD, 2,310' TVD, 900 gpm, 2840 psi, 70% f/o, 11.7 ppg ECD, 11 ppg MW, 7- 15k wob, 60 rpm, 8k tq. 1.7 hrs AST, 2.6 hrs ART, 4.3 hrs ADT, 14.6 bit run hrs, 35 hrs total bit time. 12 hrs on jars. 1,758.0 2,410.0 12/3/2022 18:00 12/4/2022 00:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 2,410' - t/ 3,158' MD, 2,858' TVD, 900 gpm, 3130 psi, 70% f/o, 11.9 ppg ECD, 11 ppg MW, 10- 16k wob, 60 rpm, 10k tq, 127k up wt, 121k dn wt, 118k rot wt. 1.7 hrs AST, 2.5 hrs ART, 4.2 hrs ADT, 18.8 bit run hrs, 39.2 hrs total bit time. 16.2 hrs on jars. 2,410.0 3,158.0 12/4/2022 00:00 12/4/2022 03:00 3.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 2,410' - t/ 3,469' MD, 3,030' TVD, 900 gpm, 3410 psi, 70% f/o, 12 ppg ECD, 11.1 ppg MW, 10- 16k wob, 80 rpm, 10k tq, 127k up wt, 121k dn wt, 118k rot wt. .4 hrs AST, 1.6 hrs ART, 2 hrs ADT, 20.8 bit run hrs, 41.2 hrs total bit time. 18.2 hrs on jars. 3,158.0 3,469.0 12/4/2022 03:00 12/4/2022 05:00 2.00 SURFAC, TRIPCAS CIRC P Acquire final survey, circulate 2 bottoms up while racking back 1 stand per bottoms up f/ 3,469' - t/ 3,254' MD, 900 gpm, 3075 psi, 11.8 ppg ECD, 70% f/o, 80 rpm, 5k tq, 111k rot wt while pulling. Pump 1ea 15 bbl nut plug sweeps per bottoms up circulated. As second bottoms up returned to surface flow packed off. 3,469.0 3,469.0 12/4/2022 05:00 12/4/2022 07:30 2.50 SURFAC, TRIPCAS P Shoveled clay out of the rotary table and cleared flow line. Continued circulating reducing rate as needed to handle clay returns on surface. Increased rate to 900 gpm and circulated 2 bottoms up. 3075 psi, 11.8 ppg EMW, 70% f/o, 80 rpm, 5k tq, 3,469.0 3,469.0 12/4/2022 07:30 12/4/2022 08:00 0.50 SURFAC, TRIPCAS OWFF P Observe well for flow - Static 3,469.0 3,469.0 12/4/2022 08:00 12/4/2022 17:30 9.50 SURFAC, TRIPCAS BKRM P Back ream out of the hole f/ 3,254' - t/ 970' MD, 900 gpm, 2540 psi, 11.7 ppg ECD, 70% f/o, 80 rpm, 3k tq, 86k rot wt while pulling. 3,469.0 3,469.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 4/50 MT7-08 Report Printed: 1/26/2023 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) 12/4/2022 17:30 12/4/2022 18:30 1.00 SURFAC, TRIPCAS BKRM P Reduced flow rate to 800 gpm and continued back reaming out of the hole f/ 970' - t/ 611' MD. 1900 psi, 11.7 ppg ECD, 70% f/o, 80 rpm, 3k tq, 81k rot wt while pulling. 3,469.0 3,469.0 12/4/2022 18:30 12/4/2022 22:00 3.50 SURFAC, TRIPCAS BHAH P Observed well for flow - static. rack back HWDP, jars and drill collars. Lay down remaining BHA components per Baker DD. 3,469.0 3,469.0 12/4/2022 22:00 12/4/2022 22:45 0.75 SURFAC, TRIPCAS CLEN P Clean and clear the rig floor of BHA equipment. 3,469.0 3,469.0 12/4/2022 22:45 12/5/2022 00:00 1.25 SURFAC, CASING RURD P Load rig floor with casing running equipment and rig to run 13-3/8" surface casing. 3,469.0 3,469.0 12/5/2022 00:00 12/5/2022 03:30 3.50 SURFAC, CASING PUTB P Picked up 13-3/8" shoe track, baker lok'd connections to the pin of jt #4, check floats (good), Ran 13-3/8", 68#, L80, Hyd563, R3 surface casing to 1,050' MD, 107k dn wt. Installed 13-3/8"x 16" Centek SII centralizers every joint to joint #13, and installed centralizers every other joint. Tq'd connections to 26k ft/lbs. 3,469.0 3,469.0 12/5/2022 03:30 12/5/2022 04:00 0.50 SURFAC, CASING CIRC P Circulate 1.5 bottoms up at 1,050' MD, stage up pumps to 8 bbls/min, 110 psi, 103k up wt, 107k dn wt. 3,469.0 3,469.0 12/5/2022 04:00 12/5/2022 10:30 6.50 SURFAC, CASING PUTB P Continue running 13-3/8", 68#, L80, Hyd563, R3 surface casing f/ 1,050' - t/ 2,862' MD. 175k dn wt. continued install 13-3/8" Centek SII centralizers every other joint Tq'd connections to 26k ft/lbs. 3,469.0 3,469.0 12/5/2022 10:30 12/5/2022 14:15 3.75 SURFAC, CASING PUTB P Began seeing drag deviating, wash casing down f/ 2,862' - t/ 3,419, 55 gpm, 150 psi. Make up casing hanger and landing joint, wash down and land on hanger at 3,458' MD. 227k up wt, 198k dn wt. Installed total of 44 ea 13-3/8" Centek SII centralizer and 6 stop rings. 0 remakes, 0 rejects. 3,469.0 3,469.0 12/5/2022 14:15 12/5/2022 15:00 0.75 SURFAC, CEMENT CIRC P Stage up pump rate to 8 bbls/min and condition mud for cement job. 410 psi, 216k up wt, 197k dn wt. 3,469.0 3,469.0 12/5/2022 15:00 12/5/2022 16:30 1.50 SURFAC, CEMENT RURD P Blow down kelly hose, rig up cement line to Volant swivel, re-establish circulation. Pre-job safety meeting with all parties on cement job. 3,469.0 3,469.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 5/50 MT7-08 Report Printed: 1/26/2023 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) 12/5/2022 16:30 12/5/2022 21:00 4.50 SURFAC, CEMENT CMNT P Line up to cement unit, pump 5 bbl's of fresh water and PT lines to 3,500 psi. Pump 100 bbl's of 10.9ppg MudPush II, 4.5 bbls/min installed bottom cement plug, pumped 395 bbl's 11 ppg DeepCRETE lead cement, 4.8 bbl's/min, 395psi, pump 72 bbl's of 15.8 class G tail cement 4.3 bbl's/min, 450 psi ICP - 350 psi FCP, install top plug and kick out with 20 bbl's of fresh water, swap to rig pumps and displace cement with 11 ppg KSi mud at 8 bbl's/min, 435 psi ICP - 700 psi FCP, slow pumps to 3 bbl's/min at 3900 stks, plugs bumped on strokes at 4105 stks - 360 psi ICP - 370 psi FCP, increase pressure to 1000 psi and hold for 5 min, bleed off pressure and check floats. Reciprocated casing 6 ft stoke lengths throughout the job. (144 bbl's of cement returned to surface, no losses observed) Lead CMT wet @16:53 hrs Tail CMT wet @ 18:23 hrs CIP @ 20:21 hrs. 3,469.0 3,469.0 12/5/2022 21:00 12/5/2022 23:00 2.00 SURFAC, CEMENT RURD P Rig down cementing equipment, drained stack and began flushing with sweet and sour pill, back out landing joint, laid down Volant tool, pulled and laid down landing joint, clear clean surface equipment and casing running equipment. 3,469.0 3,469.0 12/5/2022 23:00 12/6/2022 00:00 1.00 SURFAC, CEMENT NUND P Pulled drilling riser to the rig floor and laid down. Nipple down surface annular and racked back. Prepped to pull lower surface riser. Simops: staged well head in the BOP deck. 3,469.0 3,469.0 12/6/2022 00:00 12/6/2022 02:00 2.00 SURFAC, CEMENT NUND P Nipple down lower surface riser and FMC starting head, remove BOP deck hatches for cellar access. Simops: continue cleaning cement from flow line. 3,469.0 3,469.0 12/6/2022 02:00 12/6/2022 06:00 4.00 SURFAC, WHDBOP NUND P Install FMC wellhead, nipple up high pressure drilling riser and BOP's, test wellhead seals to 1000 psi for 10 min (good test). 3,469.0 3,469.0 12/6/2022 06:00 12/6/2022 09:00 3.00 SURFAC, WHDBOP NUND P Continue torque bop bolts, install flow box and flow line, install jet lines, install the mouse hole. Simops: begin making up floor valve testing assemblies, install test sub for upper and lower IBOP, rig up test hoses and chart recorder. 3,469.0 3,469.0 12/6/2022 09:00 12/6/2022 11:00 2.00 SURFAC, WHDBOP MPDA P Install test plug, install MPD test cap. Attempt to pressure test MPD equipment. Close blinds and pressure up on MPD equipment to trouble shoot problem. 3,469.0 3,469.0 12/6/2022 11:00 12/6/2022 12:00 1.00 SURFAC, WHDBOP OTHR T Pull test plug, inspect and re-dope seals, install test plug per FMC, pull test joint and install MPD test cap. 3,469.0 3,469.0 12/6/2022 12:00 12/6/2022 13:30 1.50 SURFAC, WHDBOP MPDA P Flood lines and purge air out of the system. Test MPD equipment to 1250 psi for 10 min. Pull MPD test cap and rig down MPD testing equipment. 3,469.0 3,469.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 6/50 MT7-08 Report Printed: 1/26/2023 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) 12/6/2022 13:30 12/6/2022 14:45 1.25 SURFAC, WHDBOP RURD P Install trip nipple, hook up hole fill line and air up boots, install 5" test joint, purge air out of system and shell test BOPE 3,469.0 3,469.0 12/6/2022 14:45 12/6/2022 23:30 8.75 SURFAC, WHDBOP BOPE P Test BOPE all tests 250 psi low for 5 min, 5,000 psi high for 10 minutes with exception to annular preventor and manual and super choke - test annular to 250 psi low for 5 min and 3,500 psi high for 10 min, test manual and super choke to 250 psi low and 2,000 psi high for 5 min each test. Test annular and 2 7/8" x 5 1/2" UPR and LPR with 5" test joint, test choke valves 1-15, manual and super choke, choke and kill manual's and HCR's, 4" valve on kill line, 2 x 4" FOSV, IBOP dart valve, upper and lower IBOP, blind/shear rams. Perform Koomey drawdown, ACC=3050 psi, manifold=1500 psi initial. After all functions, accumulator=1600 psi, 15 sec's to 200 psi with two electric pumps, 96 sec's to build to full system pressure with two electric and two air pumps. Closing times, annular=27 sec's, UPR=12 sec's, blind/shears=15 sec's, LPR=14 sec's, choke HCR=2 sec's, kill HCR=2 sec's. 6 Nitrogen bottles back- up avg=2091 psi, CPAI witnessed. Tested PVT, gain/loss, flow out, LEL and H2S alarms. Test witnessed by AOGCC Rep Guy Cook, BLM Rep Quinn Sawyer waived witness of test via email on 12/05/2022 @ 1:01 pm. 3,469.0 3,469.0 12/6/2022 23:30 12/7/2022 00:00 0.50 SURFAC, WHDBOP RURD P Rig down and blow down testing equipment, pull test plug per FMC rep. 3,469.0 3,469.0 12/7/2022 00:00 12/7/2022 00:00 SURFAC, WHDBOP 3,469.0 12/7/2022 00:00 12/7/2022 00:30 0.50 SURFAC, WHDBOP RURD P Rig up to test casing. Purge air out of system. close blind rams. 3,469.0 3,469.0 12/7/2022 00:30 12/7/2022 01:30 1.00 SURFAC, WHDBOP PRTS P Test 13-3/8" surface casing to 3,500 psi for 30 minutes (good test). 3,469.0 3,469.0 12/7/2022 01:30 12/7/2022 02:00 0.50 SURFAC, WHDBOP RURD P Rig down and blow down lines. Install wear bushing per FMC rep. ID = 12.75" 3,469.0 3,469.0 12/7/2022 02:00 12/7/2022 05:00 3.00 SURFAC, DRILLOUT BHAH P Pre-job safety meeting. Pick up BHA per Baker DD and MWD. 3,469.0 3,469.0 12/7/2022 05:00 12/7/2022 05:30 0.50 SURFAC, DRILLOUT RURD P Install PS-21's, change orientation of guide block pins. 3,469.0 3,469.0 12/7/2022 05:30 12/7/2022 07:30 2.00 SURFAC, DRILLOUT TRIP P RIH f/ 193' to 2909' MD. 3,469.0 3,469.0 12/7/2022 07:30 12/7/2022 08:00 0.50 SURFAC, DRILLOUT CIRC P Fill pipe. Perform shallow test w/ MWD. Good test. 3,469.0 3,469.0 12/7/2022 08:00 12/7/2022 08:30 0.50 SURFAC, DRILLOUT TRIP P RIH f/ 2909' to 3105' MD. 3,469.0 3,469.0 12/7/2022 08:30 12/7/2022 09:30 1.00 SURFAC, DRILLOUT WASH P Wash f/ 3105' to 3363'. Tag plugs @ 3363'. 130 GPM 130 PSI 3,469.0 3,469.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 7/50 MT7-08 Report Printed: 1/26/2023 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) 12/7/2022 09:30 12/7/2022 13:30 4.00 SURFAC, DRILLOUT DRLG P Drill out plugs/FC/shoetrack/FS. Drill 20' formation to 3489' MD. 15-24k WOB 660 GPM 2100 PSI 50-70 RPM 12-17k TQ 11.3ppg ECD 3,469.0 3,489.0 12/7/2022 13:30 12/7/2022 15:00 1.50 SURFAC, DRILLOUT CIRC P Circulate and condition mud for FIT. Backream back up into shoe. 3,489.0 3,489.0 12/7/2022 15:00 12/7/2022 15:30 0.50 SURFAC, DRILLOUT FIT P RU. Perform FIT to 18.5ppg EMW.RD test equipment. 3,489.0 3,489.0 12/7/2022 15:30 12/7/2022 18:00 2.50 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 3489' MD 3602' MD/ 3102' TVD. Displace to 12.0 ppg while drilling ahead. 2k WOB 900 GPM 1740 PSI on bttm 150 RPM 10k TQ on bttm 4k TQ off bttm 12.5ppg ECD 117k PU 110k SO 111k ROT 1.3 Bit hrs 19.5 Jar hrs. 3,489.0 3,602.0 12/7/2022 18:00 12/8/2022 00:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 3602' MD 4510' MD/ 3621' TVD. 22k WOB 1000 GPM 2530 PSI on bttm 170 RPM 9k TQ on bttm 4k TQ off bttm 12.9ppg ECD 127k PU 117k SO 115k ROT 5.3 Bit hrs 23.5 Jar hrs. 3,602.0 4,510.0 12/8/2022 00:00 12/8/2022 06:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 4510' MD 5179' MD/ 4006' TVD. Decreased ROP to 150 ft/hr for ECD. 14k WOB 990 GPM 2780 PSI on bttm 170 RPM 9k TQ on bttm 3k TQ off bttm 13.1ppg ECD 137k PU 121k SO 119k ROT 9.5 Bit hrs 30.6 Jar hrs. 4,510.0 5,179.0 12/8/2022 06:00 12/8/2022 08:30 2.50 INTRM1, DRILL CIRC T Circulate and condition mud due to high ECDs. Observed several packoffs while backreaming stand. Clean out flowline and shakers. 5,179.0 5,179.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 8/50 MT7-08 Report Printed: 1/26/2023 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) 12/8/2022 08:30 12/8/2022 12:00 3.50 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 5179' MD 5588' MD/ 4241' TVD. 22k WOB 1033 GPM 3150 PSI on bttm 170 RPM 9k TQ on bttm 3k TQ off bttm 13.1ppg ECD 143k PU 126k SO 124k ROT 12.4 Bit hrs 33.5 Jar hrs. 5,179.0 5,588.0 12/8/2022 12:00 12/8/2022 18:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 5588' MD 6204' MD/ 4593' TVD. 27k WOB 1033 GPM 3340 PSI on bttm 170 RPM 10k TQ on bttm 4k TQ off bttm 13.2ppg ECD 140k PU 137k SO 133k ROT 16.9 Bit hrs 36.1 Jar hrs. 5,588.0 6,204.0 12/8/2022 18:00 12/9/2022 00:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 6204' MD 6563' MD/ 4798' TVD. 20k WOB 1033 GPM 3580 PSI on bttm 140 RPM 8k TQ on bttm 4k TQ off bttm 12.9ppg ECD 147k PU 127k SO 136k ROT 22.1 Bit hrs 40.3 Jar hrs. Note: Slowed ROP to100 ft/hr then 50 ft/hr due to high ECDs (13.1-13.2ppg). ECD decreased to 12.9ppg 6,204.0 6,563.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 9/50 MT7-08 Report Printed: 1/26/2023 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) 12/9/2022 00:00 12/9/2022 01:00 1.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 6563' MD 6614' MD. 20k WOB 1033 GPM 3580 PSI on bttm 140 RPM 8k TQ on bttm 4k TQ off bttm 12.9ppg ECD 147k PU 127k SO 136k ROT 22.1 Bit hrs 40.3 Jar hrs. Note: Performed 500bbl dump and dilute @ 6590'. 6,563.0 6,614.0 12/9/2022 01:00 12/9/2022 02:00 1.00 INTRM1, DRILL CIRC T MWD tools stopped pulsing. Recycle and troubleshoot. Started back pulsing. 6,614.0 6,614.0 12/9/2022 02:00 12/9/2022 10:00 8.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 6614' MD 7415' MD/ 5289' TVD. 27k WOB 1033 GPM 3520 PSI on bttm 150 RPM 13k TQ on bttm 4k TQ off bttm 12.9ppg ECD 164k PU 140k SO 144k ROT 22.1 Bit hrs 40.3 Jar hrs. 6,614.0 7,415.0 12/9/2022 10:00 12/9/2022 11:00 1.00 INTRM1, DRILL CIRC T Observed packoff @ 7415'. Pump pressure increased f/ 3510 to 3725psi. ECD went f/ 129ppg to 13.4ppg. PU and circulate BU. 7,415.0 7,415.0 12/9/2022 11:00 12/9/2022 16:30 5.50 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 7415' MD 8003' MD/ 5639' TVD. 25k WOB 1033 GPM 3560 PSI on bttm 150 RPM 15k TQ on bttm 6k TQ off bttm 12.5ppg ECD 181k PU 148k SO 151k ROT Bit hrs Jar hrs. Note: MW @ 11.5ppg after circulating due to diluting system while cleaning flowline and shakers. Decision made to leave MW @ 11.5ppg. 7,415.0 8,003.0 12/9/2022 16:30 12/9/2022 17:30 1.00 INTRM1, DRILL CIRC T Observed pinhole leak in on #1 MP settling chamber. Repair same. Circulate w/ #2 MP 511 GPM 1070 PSI. 8,003.0 8,003.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 10/50 MT7-08 Report Printed: 1/26/2023 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) 12/9/2022 17:30 12/9/2022 19:30 2.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 8003' MD 8193' MD/ 5735' TVD. 25k WOB 1033 GPM 3560 PSI on bttm 150 RPM 15k TQ on bttm 6k TQ off bttm 12.5ppg ECD 181k PU 148k SO 151k ROT Bit hrs Jar hrs. 8,003.0 8,193.0 12/9/2022 19:30 12/9/2022 23:00 3.50 INTRM1, DRILL CIRC T Observed #1 MP settling chamber leaking. Repair same. Circulate w/ #2 MP 511 GPM 1070 PSI. 8,193.0 8,193.0 12/9/2022 23:00 12/10/2022 00:00 1.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 8191' MD 8278' MD/ 5783' TVD. 28k WOB 1000 GPM 3250 PSI on bttm 150 RPM 15k TQ on bttm 7k TQ off bttm 11,6ppg MW 12.5ppg ECD 183k PU 149k SO 157k ROT 36.3Bit hrs 54.5 Jar hrs. 8,193.0 8,278.0 12/10/2022 00:00 12/10/2022 06:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 8278' MD 8807' MD/ 6086' TVD. 30k WOB 1000 GPM 3610 PSI on bttm 140 RPM 15k TQ on bttm 8k TQ off bttm 11,9ppg MW 13.1ppg ECD 194k PU 152k SO 162k ROT 40.8Bit hrs 59.0 Jar hrs. Note:. Decreased ROP to 100 FPH due to increasing ECDs. 8,278.0 8,807.0 12/10/2022 06:00 12/10/2022 06:30 0.50 INTRM1, DRILL CIRC T Blew pop off on MP #1. Atttempt to reset. Unsuccessful. Shut in pump and swap out pop off valve. Circulate w/ MP #2. 8,807.0 8,807.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 11/50 MT7-08 Report Printed: 1/26/2023 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) 12/10/2022 06:30 12/10/2022 09:00 2.50 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 8807' MD 8989' MD/ 6190' TVD. 29k WOB 993 GPM 3780 PSI on bttm 140 RPM 17k TQ on bttm 8k TQ off bttm 11,7ppg MW 12.9ppg ECD 193k PU 154k SO 159k ROT 40.8 Bit hrs 59.0 Jar hrs. Note:. Decreased ROP to 100 FPH due to increasing ECDs. 8,807.0 8,989.0 12/10/2022 09:00 12/10/2022 10:00 1.00 INTRM1, DRILL CIRC T Observed pack off. Pressure increase f/ 3780psi to 4000psi. ECD f/ 12.9ppg to 13.8ppg. PU and circulate BU. 8,989.0 8,989.0 12/10/2022 10:00 12/10/2022 12:30 2.50 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 8989' MD 9226' MD/ 6297' TVD. 29k WOB 993 GPM 3800 PSI on bttm 140 RPM 17k TQ on bttm 10k TQ off bttm 11,7ppg MW 12.8ppg ECD 201k PU 163k SO 161k ROT 44.2 Bit hrs 62,4 Jar hrs. 8,989.0 9,226.0 12/10/2022 12:30 12/10/2022 13:30 1.00 INTRM1, DRILL CIRC T Observed pack off. 160psi pressure increase. PU and circulate BU. 9,226.0 9,226.0 12/10/2022 13:30 12/10/2022 17:30 4.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 9226' MD 9544' MD. 25k WOB 1000 GPM 3880 PSI on bttm 170 RPM 17k TQ on bttm 13k TQ off bttm 11,8ppg MW 12.7ppg ECD 199k PU 164k SO 173k ROT 47.7 Bit hrs 65.5 Jar hrs. 9,226.0 9,544.0 12/10/2022 17:30 12/10/2022 18:00 0.50 INTRM1, DRILL CIRC T Pop off blew on MP #2. Isolate and swap out. Circulate while changing out. 9,544.0 9,544.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 12/50 MT7-08 Report Printed: 1/26/2023 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) 12/10/2022 18:00 12/11/2022 00:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 9544' MD 10030' MD/ 6787' TVD. 28k WOB 950 GPM 3760 PSI on bttm 170 RPM 16k TQ on bttm 13k TQ off bttm 12.0ppg MW 12.8ppg ECD 222k PU 160k SO 181k ROT 52 Bit hrs 70.5 Jar hrs. 9,544.0 10,030.0 12/11/2022 00:00 12/11/2022 06:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 10030' MD to 10620' MD/ 7127' TVD. 28k WOB 948 GPM 3756 PSI on bttm 170 RPM 21k TQ on bttm 15k TQ off bttm 12.0ppg MW 12.6ppg ECD 238k PU 165k SO 184k ROT 57.4 Bit hrs 72.2 Jar hrs. 10,030.0 10,620.0 12/11/2022 06:00 12/11/2022 11:30 5.50 INTRM1, DRILL DDRL P Drill 12 1/4" hole f/ 10620' MD to 11057' MD/ 7377' TVD. 17k WOB 913 GPM 3700 PSI on bttm 170 RPM 25k TQ on bttm 22k TQ off bttm 12.0ppg MW 12.6ppg ECD 219k PU 198k SO 211k ROT 61.8 Bit hrs 76.6 Jar hrs. 10,620.0 11,057.0 12/11/2022 11:30 12/11/2022 15:30 4.00 INTRM1, TRIPCAS CIRC P Circulate cuttings above BHA. Downlink and take final survey. Circulate 3 x BU at 1 BU per std from 11057' to 10740'. 915 GPM 3820 PSI 120 RPM 18k TQ 12.7 ECD. 11,057.0 10,740.0 12/11/2022 15:30 12/11/2022 16:00 0.50 INTRM1, TRIPCAS OWFF P BD topdrive. Flow check well. Static 10,740.0 10,740.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 13/50 MT7-08 Report Printed: 1/26/2023 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) 12/11/2022 16:00 12/12/2022 00:00 8.00 INTRM1, TRIPCAS BKRM P BROOH f/ 10740' to 8800'. 915 GPM 3680 PSI 120 RPM 16k TQ 12.0ppg MW 12.7ppg ECD Note: Packoff @ 8870' 150 PSI increase. 12.8-13.6ppg ECD. 10,740.0 8,800.0 12/12/2022 00:00 12/12/2022 06:00 6.00 INTRM1, TRIPCAS BKRM P BROOH f/ 8800' to 7720'. 920-950 GPM 3000-3600 PSI 120-150 RPM 15-20k TQ 12.0ppg MW 12.7-13.1ppg ECD Note: Packoff @ 8870'/8705'/8560'/8365'. 125-300PSI increases.12.9-13.9ppg ECD. Pumping 20bbl nutplug sweeps every 2-3 stds. 8,800.0 7,800.0 12/12/2022 06:00 12/12/2022 12:00 6.00 INTRM1, TRIPCAS BKRM P BROOH f/ 7720' to 6900' MD. 920-1000 GPM 3300-3600 PSI 120 RPM 15-20k TQ 12.0ppg MW 12.7-13.1ppg ECD Note: Pumping 20bbl nutplug sweeps every 2-3 stds. 7,800.0 6,900.0 12/12/2022 12:00 12/12/2022 18:00 6.00 INTRM1, TRIPCAS BKRM P BROOH f/ 6900' to 6026' MD. 900 GPM 2800 PSI 140 RPM 15k TQ 12.0ppg MW 12.8-13.1ppg ECD Note: Pumping 20bbl nutplug sweeps every 2-3 stds. 6,900.0 6,026.0 12/12/2022 18:00 12/13/2022 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH f/ 6026' to 4645' MD. 900 GPM 2420 PSI 140 RPM 10k TQ 12.0ppg MW 12.6ppg ECD Note: Pumping 20bbl nutplug sweeps every 2-3 stds. 6,026.0 4,645.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 14/50 MT7-08 Report Printed: 1/26/2023 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) 12/13/2022 00:00 12/13/2022 05:30 5.50 INTRM1, TRIPCAS BKRM P BROOH f/ 4645' to 3388' MD. Attempt to pull into shoe with pumps only. Observed OP. BROOH into shoe with no issues. 900 GPM 2420 PSI 140 RPM 10k TQ 12.0ppg MW 12.6ppg ECD Note: Pumping 20bbl nutplug sweeps every 2-3 stds. 4,645.0 3,410.0 12/13/2022 05:30 12/13/2022 08:00 2.50 INTRM1, TRIPCAS CIRC P Circulate BU. Pump 2 x 40 bbl nut plug sweeps. Rotate and reciprocate f/ 3388'- 3200' while circulating. 1000 GPM 2400 PSI 80 RPM 7-9k TQ 3,388.0 3,200.0 12/13/2022 08:00 12/13/2022 08:30 0.50 INTRM1, TRIPCAS OWFF P Flow check. Static. POOH f/ 3200'- 2920'. Pump slug and blow down TD. 3,200.0 2,920.0 12/13/2022 08:30 12/13/2022 10:00 1.50 INTRM1, TRIPCAS TRIP P POOH to BHA @ 600'. 2,920.0 600.0 12/13/2022 10:00 12/13/2022 10:30 0.50 INTRM1, TRIPCAS OWFF P Flow check. Static. PJSM f/ BHA. SimOps: Pull PS21 slips and install master bushings. 600.0 600.0 12/13/2022 10:30 12/13/2022 13:00 2.50 INTRM1, TRIPCAS BHAH P Rack back HWDP. LD BHA. 600.0 0.0 12/13/2022 13:00 12/13/2022 14:30 1.50 INTRM1, CASING WWWH P Retrieve wear ring and MU jetting tool. Jet WH and BOP. 0.0 0.0 12/13/2022 14:30 12/13/2022 15:30 1.00 INTRM1, CASING BOPE P Drain stack. Swap out UPR to 9.625" casing rams. RU to test casing rams. 0.0 0.0 12/13/2022 15:30 12/13/2022 17:30 2.00 INTRM1, CASING BOPE P Test annular 250/2500PSI f/ 5/10 m in each. Test 9 5/8" casing rams 250/4000PSI f/ 5/10 min ea. Good test. RD test equipment. 0.0 0.0 12/13/2022 17:30 12/13/2022 19:30 2.00 INTRM1, CASING RURD P RU csg running equipment. Perorm dummy run w/ landing joint and hanger. LD landing joint and hanger. 0.0 0.0 12/13/2022 19:30 12/13/2022 20:00 0.50 INTRM1, CASING PUTB P PJSM. PU shoetrack and RIH. Threadlock each connection. Pump through shoetrack and check floats. Good. 0.0 170.0 12/13/2022 20:00 12/14/2022 00:00 4.00 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563 casing f/ 170' to 2078' as per tally. Using fillup line and topping off every 10 jts. MU Torques: 9 5/8" 47# T95 H563: 15.8k ft/lbs 9 5/8" 43.5# L80 H563: 14.3k ft/lbs 170.0 2,078.0 12/14/2022 00:00 12/14/2022 02:00 2.00 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563 casing f/ 2078' to 3450' as per tally. Using fillup line and topping off every 10 jts. MU Torques: 9 5/8" 47# T95 H563: 15.8k ft/lbs 9 5/8" 43.5# L80 H563: 14.3k ft/lbs 2,078.0 3,450.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 15/50 MT7-08 Report Printed: 1/26/2023 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) 12/14/2022 02:00 12/14/2022 03:00 1.00 INTRM1, CASING CIRC P Circulate BU @ 3450'. Stage rate up to 6 BPM. Reciprocate pipe f/ 3400' to 3445'. 150 PSI - 2BPM 160 PSI - 3 BPM 170 PSI - 4 BPM 180 PSI - 5 BPM 190 PSI - 6 BPM 160k PU 155k SO 154k ROT TQ: 7k 10 RPM 7k 20 RPM 3,450.0 3,450.0 12/14/2022 03:00 12/14/2022 08:30 5.50 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563 casing f/ 3450' to 6372' as per tally. Using fillup line and topping off every 10 jts. MU Torques: 9 5/8" 47# T95 H563: 15.8k ft/lbs 9 5/8" 43.5# L80 H563: 14.3k ft/lbs 3,450.0 6,372.0 12/14/2022 08:30 12/14/2022 09:30 1.00 INTRM1, CASING CIRC P Circulate BU @ 6372'. Stage rate up to 6 BPM. 300 PSI - 3 BPM 325 PSI - 4 BPM 350 PSI - 5 BPM 380 PSI - 6 BPM 253 FCP @ 6 BPM 237k PU 199k SO 6,372.0 6,372.0 12/14/2022 09:30 12/14/2022 14:00 4.50 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563 casing f/ 6372' to 9440' as per tally. Using fillup line and topping off every 10 jts. MU Torques: 9 5/8" 47# T95 H563: 15.8k ft/lbs 9 5/8" 43.5# L80 H563: 14.3k ft/lbs 6,372.0 9,440.0 12/14/2022 14:00 12/14/2022 15:30 1.50 INTRM1, CASING CIRC P Circulate BU @ 9440'. Stage rate up to 8 BPM. 8 BPM 473 PSI 347k PU 222k SO 9,440.0 9,440.0 12/14/2022 15:30 12/14/2022 18:30 3.00 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563 casing f/ 9440' to 11041' as per tally. Land out hanger. FS @ 11041' MD Using fillup line and topping off every 10 jts. MU Torques: 9 5/8" 47# T95 H563: 15.8k ft/lbs 9 5/8" 43.5# L80 H563: 14.3k ft/lbs 9,440.0 11,041.0 12/14/2022 18:30 12/14/2022 21:00 2.50 INTRM1, CEMENT CIRC P Circulate and condition mud f/ cement job. Stage up rate to *BPM w/ no losses. PJSM f/ cement job. 8 BPM 333 PSI. 11,041.0 11,041.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 16/50 MT7-08 Report Printed: 1/26/2023 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) 12/14/2022 21:00 12/15/2022 00:00 3.00 INTRM1, CEMENT CMNT P Line up cement unit. flush w/ 3 bbls FW. Test lines to 3650psi. Good test. Mix and pump 60bbls 12.5ppg mud push II at 4 bpm. SD and drop bottom plug. Mix and pump 161bbls 13 ppg G lead cement at 4 bpm, 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 6bpm. 11,041.0 11,041.0 12/15/2022 00:00 12/15/2022 02:30 2.50 INTRM1, CEMENT DISP P Continue displace cement at 6bpm 200psi 770bbls slow rate to 3bpm 939psi. Plug bumped @ 6747 stks (calculated stks6758). Pressure up to 1500psi. Check floats. Good. Cement in place @ 02:21hrs 12/15/22. 11,041.0 11,041.0 12/15/2022 02:30 12/15/2022 04:00 1.50 INTRM1, CEMENT PRTS P Line up and test casing to 3500PSI for 30 minutes. Good test. 11.5bbls pumped. 10.4 bbls returned. 11,041.0 11,041.0 12/15/2022 04:00 12/15/2022 05:30 1.50 INTRM1, WHDBOP RURD P LD landing joint and RD casing equipment. 11,041.0 11,041.0 12/15/2022 05:30 12/15/2022 07:00 1.50 INTRM1, WHDBOP WWSP P Drain stack and install Packoff. Test to 5000psi. COP witness. SimOps: Cleaning pits. C/O UPR to 4 1/2" x 7" VBR. 11,041.0 11,041.0 12/15/2022 07:00 12/15/2022 10:00 3.00 INTRM1, WHDBOP BOPE P Install test plug. Test UPR w/ 5 " and 7" test joints. 250psi/4000psi 5/10min each. Test annular w/ 7" test joint 250/2500psi 5/10 min ea. 11,041.0 11,041.0 12/15/2022 10:00 12/15/2022 11:00 1.00 INTRM1, WHDBOP RURD P B/D kil line. R/D test equipment. Retrieve tets pug and install 8.6875" wear bushing. 11,041.0 11,041.0 12/15/2022 11:00 12/15/2022 13:00 2.00 INTRM1, DRILLOUT SLPC P Slip/Cut drill line. 0.0 0.0 12/15/2022 13:00 12/15/2022 16:00 3.00 INTRM1, DRILLOUT BHAH P PJSM. PU and RIH w/ BHA #3 f/ Interm 2 section tp 544'. 0.0 544.0 12/15/2022 16:00 12/15/2022 16:30 0.50 INTRM1, DRILLOUT SVRG P Rig service. 544.0 544.0 12/15/2022 16:30 12/15/2022 20:00 3.50 INTRM1, DRILLOUT TRIP P RIH w/ BHA # 3 f/ 544' to 2900'. Single in 5" DP f/ pipe shed. 544.0 2,900.0 12/15/2022 20:00 12/15/2022 20:30 0.50 INTRM1, DRILLOUT CIRC P Shallow test MWD. Good test. 2,900.0 2,900.0 12/15/2022 20:30 12/16/2022 00:00 3.50 INTRM1, DRILLOUT TRIP P RIH w/ BHA # 3 f/ 2900' to 8250'. 2,900.0 8,250.0 12/16/2022 00:00 12/16/2022 01:30 1.50 INTRM1, DRILLOUT TRIP P RIH w/ BHA # 3 f/ 8250' to 10729' MD. 8,250.0 10,729.0 12/16/2022 01:30 12/16/2022 02:30 1.00 INTRM1, DRILLOUT WASH P Break circulation and wash/ream down. Tag @ 10948' MD 50 RPM 10.5k TQ 590 GPM 3600 PSI . 10,729.0 10,948.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 17/50 MT7-08 Report Printed: 1/26/2023 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) 12/16/2022 02:30 12/16/2022 07:30 5.00 INTRM1, DRILLOUT DRLG P Drill out plugs/FC/Shoetrack and FS. Ream through FS. Clean out RH. Drill 20' new formation to 11077' MD. SimOps: MU and rack back stds of 4" DP. 10,948.0 11,077.0 12/16/2022 07:30 12/16/2022 09:00 1.50 INTRM1, DRILLOUT CIRC P Circulate BU and BROOH back into shoe to 11008'. 650 GPM 3200 PSI 60 RPM 12k TQ 11,077.0 11,008.0 12/16/2022 09:00 12/16/2022 10:00 1.00 INTRM1, DRILLOUT FIT P RU and perform FIT to 14.0ppg EMW. 5.1 bbls pumped. 2.9 bbls returned.RD test equipment. 11,008.0 11,008.0 12/16/2022 10:00 12/16/2022 11:30 1.50 INTRM2, DRILL MPDA P Retrieve trip nipple.Install mpd beaaring assembly. 11,008.0 11,008.0 12/16/2022 11:30 12/16/2022 12:00 0.50 INTRM2, DRILL WASH P Wash down to 11077'. Sim Ops: freeze protect w/ ball mill 11,008.0 11,077.0 12/16/2022 12:00 12/16/2022 13:30 1.50 INTRM2, DRILL DDRL P Drill 11077' MD to 11159' MD. 15k WOB 600 GPM 3420 PSI 120 RPM 15k TQ 13.0ppg ECD 223 PU 146k SO 175k ROT 11,077.0 11,159.0 12/16/2022 13:30 12/16/2022 15:00 1.50 INTRM2, DRILL CIRC P Take baseline parameters and drop 1.25" Torlon undrerreamer activation ball. Pump down @ 250 GPM 990 PSI f/ 1000stks. Slow to 100 GPM 590 PSI. Observed shear @ 1384 PSI. 1970stks pumped. Confirm activation with parameters and perform ledge test. 11,159.0 11,159.0 12/16/2022 15:00 12/16/2022 18:00 3.00 INTRM2, DRILL DDRL P Drill 11159' MD to 11325' MD/ 7525' TVD. 14k WOB 630 GPM 3420 PSI 150 RPM 17k TQ 13.0ppg ECD 226 PU 146k SO 180k ROT 11,159.0 11,325.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 18/50 MT7-08 Report Printed: 1/26/2023 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) 12/16/2022 18:00 12/17/2022 00:00 6.00 INTRM2, DRILL DDRL P Drill Interm 2 section f/ 11325' MD to 11717' MD/ 7730' TVD. 14k WOB 630 GPM 3420 PSI 150 RPM 17k TQ 13.0ppg ECD 226 PU 146k SO 180k ROT Sim Ops. Freeze protect w/ ball mill. 11,325.0 11,717.0 12/17/2022 00:00 12/17/2022 05:30 5.50 INTRM2, DRILL DDRL P Drill Interm 2 section f/ 11717' MD to 11985' MD/ 7860' TVD. 15k WOB 625 GPM 3368 PSI 150 RPM 17k TQ 550 PSI MPD pressure on connections. 13.0ppg ECD 226 PU 146k SO 180k ROT SimOps: Freeze protect w/ ball mill. 11,717.0 11,985.0 12/17/2022 05:30 12/17/2022 06:00 0.50 INTRM2, DRILL SVRG P Service rig. 11,985.0 11,985.0 12/17/2022 06:00 12/17/2022 12:00 6.00 INTRM2, DRILL DDRL P Drill Interm 2 section f/ 11985' MD to 12216' MD/ 7964' TVD. 16k WOB 625 GPM 3420 PSI 150 RPM 17k TQ 650 PSI MPD pressure on connections. 13.0ppg ECD 241 PU 153k SO 181k ROT SimOps: Freeze protect w/ ball mill. 11,985.0 12,216.0 12/17/2022 12:00 12/17/2022 18:00 6.00 INTRM2, DRILL DDRL P Drill Interm 2 section f/ 12216' MD to 12518' MD/ 8085' TVD. 17k WOB 625 GPM 3425 PSI 150 RPM 18k TQ 650 PSI MPD pressure on connections. 13.0ppg ECD 247 PU 147k SO 192k ROT SimOps: Freeze protect w/ ball mill. 12,216.0 12,518.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 19/50 MT7-08 Report Printed: 1/26/2023 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) 12/17/2022 18:00 12/18/2022 00:00 6.00 INTRM2, DRILL DDRL P Drill Interm 2 section f/ 12518' MD to 12875' MD/ 8204' TVD. 18k WOB 625 GPM 3530 PSI 150 RPM 21k TQ 650 PSI MPD pressure on connections. 13.0ppg ECD 247 PU 147k SO 192k ROT 27.8 Bit hrs. 104.4 Jar hrs SimOps: Freeze protect w/ ball mill. 12,518.0 12,875.0 12/18/2022 00:00 12/18/2022 08:00 8.00 INTRM2, DRILL DDRL P Drill Interm 2 section f/ 12875' MD to 13250' MD. 17k WOB 625 GPM 3425 PSI 150 RPM 18k TQ 650 PSI MPD pressure on connections. 13.0ppg ECD 241 PU 147k SO 192k ROT 34.5 Bit hrs. 111.1 Jar hrs SimOps: Freeze protect w/ ball mill. 12,875.0 13,250.0 12/18/2022 08:00 12/18/2022 08:30 0.50 INTRM2, TRIPCAS CIRC T Observed losses. Take base parameters f/ closing under reamer. Drop 1.625" UR closing ball. Pump LCM pill behind closing ball. Spot LCM pill and BROOH 1 std. Note: LCM pill consists of: 5PPB Gseal 10PPB Tiger Bullets 10PPB Nut Plug fine 10PPB Nut Plug medium 13,250.0 13,170.0 12/18/2022 08:30 12/18/2022 12:00 3.50 INTRM2, TRIPCAS CIRC T Stage up rates f/ 84gpm to 400gpm. 360 -2120psi. Observed losses up to 80bbls/hr. 13,170.0 13,240.0 12/18/2022 12:00 12/18/2022 15:30 3.50 INTRM2, TRIPCAS CIRC T Pump 50bbl LCM pill. 260 GPM 890 PSI 80 RPM 16k TQ Note: LCM pill consists of: 5PPB Gseal 10PPB Tiger Bullets 10PPB Nut Plug fine 10PPB Nut Plug medium 13,240.0 13,240.0 12/18/2022 15:30 12/18/2022 17:30 2.00 INTRM2, TRIPCAS CIRC T Pump down well commander opening ball. Sheared @ 1366PSI. Pump down isolation ball. 13,240.0 13,240.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 20/50 MT7-08 Report Printed: 1/26/2023 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) 12/18/2022 17:30 12/18/2022 18:00 0.50 INTRM2, TRIPCAS CIRC T Pump and spot 56bbl of 75ppb LCM pill. Note: LCM pill consists of: 3 ppb Vinseal Medium 28 ppb G-Seal 8 ppb Nut Plug Medium 8 ppb Nut Plug Fine 28 ppb Tiger Bullets 13,240.0 13,240.0 12/18/2022 18:00 12/18/2022 20:00 2.00 INTRM2, TRIPCAS TRIP T POOH on elevators 10 stds to 12333' MD. Note: drop well commander closing ball on 9th std. 13,240.0 12,333.0 12/18/2022 20:00 12/18/2022 21:00 1.00 INTRM2, TRIPCAS CIRC T Pump closing ball down @ 2-3 BPM. Ball landed and held pressure @ 800psi. Staged up rates to shear WC closed. Sheared @ 3300psi. 12,333.0 12,333.0 12/18/2022 21:00 12/19/2022 00:00 3.00 INTRM2, TRIPCAS BKRM P Stage up rates to 450 GPM monitoring for losses. No losses. BROOH f/ 12333' to 11857' MD. Holding ECD @ 12.5ppge 12,333.0 11,857.0 12/19/2022 00:00 12/19/2022 05:30 5.50 INTRM2, TRIPCAS BKRM P BROOH f/ 11857' to 11036' inside shoe. Observed losses/TQ spikes and packoffs f/ 11370' to 11041'. 200-450 GPM GPM 1000-2095 PSI 50-120 RPM 10-25kk TQ 12.5ppg ECD 11,857.0 11,036.0 12/19/2022 05:30 12/19/2022 08:30 3.00 INTRM2, TRIPCAS CIRC P Circulate and clean hole.Stage rates up to 425 GPM/1980 PSI. 50 RPM/13k TQ. Observed losses and slowed rate. Mix and spot 63bbl LCM pill at shoe. Note: LCM pill consists of: 5PPB Gseal 10PPB Tiger Bullets 10PPB Nut Plug fine 10PPB Nut Plug medium 11,036.0 11,036.0 12/19/2022 08:30 12/19/2022 10:00 1.50 INTRM2, TRIPCAS SMPD P SOOH f/ 11036' to 10445' MD. Holding 300PSI on annulus. Note: dropped 2.4" hollow drift. 11,036.0 10,445.0 12/19/2022 10:00 12/19/2022 12:00 2.00 INTRM2, TRIPCAS CIRC P Stage up rates and circulate BU. Rotate and reciprocate f/ 10445 to 10351'. 250-425 GPM 766-2063 PSI 20 RPM 12k TQ 10,445.0 10,351.0 12/19/2022 12:00 12/19/2022 12:30 0.50 INTRM2, TRIPCAS OWFF P Flow check. Static. Blow down TD. 10,351.0 10,351.0 12/19/2022 12:30 12/19/2022 14:00 1.50 INTRM2, TRIPCAS SMPD P SOOH f/ 10351' to 9604'. Observed 30k OP @ 9604'. 10,351.0 9,604.0 12/19/2022 14:00 12/19/2022 16:30 2.50 INTRM2, TRIPCAS CIRC P Circulate BU. Rotate and reciprocate f/ 9604' to 9515'. 375 GPM 1632 PSI 80 RPM 10k TQ 9,604.0 9,515.0 12/19/2022 16:30 12/19/2022 18:00 1.50 INTRM2, TRIPCAS SMPD P SOOH f/ 9515' to 8746'. Observed 30k O/P at 8746'. 9,515.0 8,746.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 21/50 MT7-08 Report Printed: 1/26/2023 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) 12/19/2022 18:00 12/19/2022 21:00 3.00 INTRM2, TRIPCAS BKRM P Attempt to pump out of hole. Observed 150psi increase @ 8610'. Drop down and BROOH f. 8620' to 7993'. 300 GPM 1075 PSI 40 RPM 9k TQ 8,746.0 7,993.0 12/19/2022 21:00 12/20/2022 00:00 3.00 INTRM2, TRIPCAS SMPD P SOOH f/ 7993' to 5639'. Holding 90psi out/20psi in slips w/ MPD. 7,993.0 5,639.0 12/20/2022 00:00 12/20/2022 06:00 6.00 INTRM2, TRIPCAS SMPD P SOOH f/ 5639' to 547' Holding 90psi out/20psi in slips w/ MPD. 5,639.0 547.0 12/20/2022 06:00 12/20/2022 07:00 1.00 INTRM2, TRIPCAS MPDA P OWFF. Static. Retrieve MPD bearing assembly and install trip nipple. Clean rig floor. 547.0 547.0 12/20/2022 07:00 12/20/2022 10:30 3.50 INTRM2, TRIPCAS BHAH P LD Interm 2 BHA. 547.0 0.0 12/20/2022 10:30 12/20/2022 12:00 1.50 INTRM2, CASING CLEN P Clean/clear rig floor. RU to run 7" liner. 0.0 0.0 12/20/2022 12:00 12/20/2022 16:00 4.00 INTRM2, CASING PUTB P PJSM. MU shoetrack and RIH w/ 7" 29# L80 H563 liner. Threadlock connections through pin #4. MU TQ 14.7k 0.0 2,350.0 12/20/2022 16:00 12/20/2022 16:30 0.50 INTRM2, CASING PULD P PU and MU liner hanger as per Baker. Fill w/ ZanPlex D. 2,350.0 2,390.0 12/20/2022 16:30 12/20/2022 17:00 0.50 INTRM2, CASING RURD P RD casing equipment and RU DP handling tools. RIH w/ 1 std of DP. 2,390.0 2,584.0 12/20/2022 17:00 12/20/2022 17:30 0.50 INTRM2, CASING MPDA P Retrieve trip nipple and install MPD bearing assembly. 2,584.0 2,584.0 12/20/2022 17:30 12/20/2022 18:30 1.00 INTRM2, CASING CIRC P Break circulation and stage up rates to 6 BPM. Pump 1.5 x liner volume. No losses observed. 250 GPM 284 PSI PU 99k SO 101k 102 ROT TQ: 2k @ 10 RPM 2k @ 20 RPM 2,584.0 2,584.0 12/20/2022 18:30 12/21/2022 00:00 5.50 INTRM2, CASING RUNL P RIH w/ 7" liner on DP f/ 2584' to 8055'. Holding 11.8ppg EMW in/out slips w/ MPD. 2,584.0 8,055.0 12/21/2022 00:00 12/21/2022 03:00 3.00 INTRM2, CASING RUNL P RIH w/ 7" liner on DP f/ 8055' to 10975'. Holding 11.8ppg EMW in/out slips w/ MPD. S/O-135l 8,055.0 10,975.0 12/21/2022 03:00 12/21/2022 03:45 0.75 INTRM2, CASING CIRC P Break circulation. Take parameters. MU pup joint to cement head and lay back down. 84 GPM 215 PSI PU 214k SO 165k ROT 192k TQ 12 k 10 & 20rpm 10,975.0 10,975.0 12/21/2022 03:45 12/21/2022 05:45 2.00 INTRM2, CASING RUNL P RIH w/ 7" liner on 5" DP f/ 10975' to 13,144', holding 11.8 ppg EMW in/out of slips. S/O-161k 10,975.0 13,144.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 22/50 MT7-08 Report Printed: 1/26/2023 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) 12/21/2022 05:45 12/21/2022 06:15 0.50 INTRM2, CASING CIRC P Wash down f/ 13,144' to 13,239' at 2 bmp, w/ 320 psi. 13,144.0 13,239.0 12/21/2022 06:15 12/21/2022 06:45 0.50 INTRM2, CEMENT PULD P Pick up cement swivel & space out at 13,244'. 13,239.0 13,244.0 12/21/2022 06:45 12/21/2022 08:15 1.50 INTRM2, CEMENT CIRC P Stage pumps to 3 bpm w/ 450 psi, 8% F/O. Circulate & condition mud. Pumped 3933 stks. 13,244.0 13,244.0 12/21/2022 08:15 12/21/2022 08:45 0.50 INTRM2, CEMENT PRTS P Blow down topdrive. Rig up cement line. SLB pressure test lines to 4600 psi on chart. 13,244.0 13,244.0 12/21/2022 08:45 12/21/2022 09:15 0.50 INTRM2, CEMENT CMNT P Pump 70 bbls of KCL @ 3 bpm, 880 psi, 6% F/O w/830 stks. 13,244.0 13,244.0 12/21/2022 09:15 12/21/2022 09:45 0.50 INTRM2, CEMENT CMNT P Drop bottom dart, witnessed by CPAI rep. SLB pump 79 bbls of 15.8 ppg cement slurry at 15.8 ppg. Drop top dart, witnessed by CPAI rep. Pump 20 bbls of water. 13,244.0 13,244.0 12/21/2022 09:45 12/21/2022 10:45 1.00 INTRM2, CEMENT DISP P Rig pumps displace dart w/ 3 bpm. Slow pumps to 2 bpm at 950 stks, dart landed at 985 stks & sheared 880 psi, reduce rate to 2 bpm at 1850 stks. Dart landed @ 1905 stks & sheared at 1619 psi. 13,244.0 13,244.0 12/21/2022 10:45 12/21/2022 12:00 1.25 INTRM2, CEMENT DISP P Pump at 2 bpm, bottom plug landed at 1995 stks & sheared at 821 psi. Top plug landed at 2921 stks & pressured up to 1200 psi for 5 min. Pumped 2928 stks total. Bleed off pressure to confirm floats holding. 1.2 bbls bled back. Floats holding. 13,244.0 13,244.0 12/21/2022 12:00 12/21/2022 12:30 0.50 INTRM2, CEMENT PACK P Pump up to 2500 psi on DP & set hanger. Set down on hanger 50k to confirm set. Pump up to 3500 psi to release running tool, bleed off pressure. P/u 6' to expose dog sub, slack off to set packer. (shear observed @ 118k hook load). Set down 80k, p/u & set 50k down, rotate 10 rpm, 10k TQ to confirm packer set. Top of packer (Baker 7"x9.625" HRDE SLZXP-HD liner top at 10,855'. 13,244.0 13,244.0 12/21/2022 12:30 12/21/2022 13:00 0.50 INTRM2, CEMENT PRTS P Rig up & pressure test liner top packer to 3500 psi f/ 10 min-good test. Bleed off pressure & r/d test equipment. 13,244.0 13,244.0 12/21/2022 13:00 12/21/2022 13:30 0.50 INTRM2, CEMENT PULD P L/d cement head & 15' pup joint. 13,244.0 13,244.0 12/21/2022 13:30 12/21/2022 14:00 0.50 INTRM2, CEMENT OTHR P Pump up to 500 psi on DP. P/u to pull out w/ liner RT. Observed the pressure drop off to zero psi. Clear indication of Liner top at 10,855' MD. 13,244.0 10,855.0 12/21/2022 14:00 12/21/2022 15:00 1.00 INTRM2, CEMENT CIRC P At 10,845', install 7" wiper ball in DP & circ b/u w/ 500 gpm w/ 1275 psi at 21% F/O, pumped 7798 stks. Simops: Clear & clean rig floor. 10,855.0 10,845.0 12/21/2022 15:00 12/21/2022 15:30 0.50 INTRM2, CEMENT CIRC P Pump slug w/ 126 gpm, 290 psi. Total of 589 stks pumped. 10,845.0 10,845.0 12/21/2022 15:30 12/21/2022 16:30 1.00 INTRM2, CEMENT OWFF P Hold PJSM, pull RCD, install trip nipple. Blow down lines, r/u hole fill line w/ OWFF. Static. 10,845.0 10,845.0 12/21/2022 16:30 12/21/2022 23:30 7.00 INTRM2, CEMENT TRIP P POOH f/ 10845' to surface. LD running tool.Visually all good. Simops: OA Freeze protect: injected 1.5 bbls at 1230 psi. 10,845.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 23/50 MT7-08 Report Printed: 1/26/2023 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) 12/21/2022 23:30 12/22/2022 00:00 0.50 INTRM2, CEMENT RURD P Retrieve wear bushing per FMC. Simops: Cleaning mud pits in preparation for FloPro displacement. 0.0 0.0 12/22/2022 00:00 12/22/2022 00:30 0.50 INTRM2, WHDBOP OTHR P Retrieve wear bushing. 0.0 0.0 12/22/2022 00:30 12/22/2022 01:30 1.00 INTRM2, WHDBOP WWWH P Make up stack washer & flush BOP & WH profile w/ 6502 gpm & 150 psi w/ 25 rpm. 0.0 0.0 12/22/2022 01:30 12/22/2022 02:30 1.00 INTRM2, WHDBOP OTHR P Drain BOP stack & change out UPR to 2 7/8" x 5 1/2" VBR rams. 0.0 0.0 12/22/2022 02:30 12/22/2022 04:00 1.50 INTRM2, WHDBOP CLEN P Clean & clear rig floor. Prepare to test BOPE. Run test plug on 5" test joint. Fill stack w/ FW. 0.0 0.0 12/22/2022 04:00 12/22/2022 05:00 1.00 INTRM2, WHDBOP SVRG P Service rig. Troubleshoot chart recorder and 3" manual kill valve. 0.0 0.0 12/22/2022 05:00 12/22/2022 13:30 8.50 INTRM2, WHDBOP BOPE P BOPE Test All tests to 250psi/5min 4000psi/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/Shear rams. Performed Koomey draw down, ACC = 3000 psi, Manifold = 1500 psi, ACC = 1700 psi after all functions on bottles,18 sec for 200 psi. Build w/ 2 electric pumps, 97 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 27 sec. UPR = 12 sec, Blind / Shears = 15 sec, LPR = 14 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms AOGCC waived witness. 0.0 0.0 12/22/2022 13:30 12/22/2022 15:00 1.50 INTRM2, WHDBOP RURD P RD test equipment. Retrieve test plug. Install wear bushing. Clear & clean rig floor. 0.0 0.0 12/22/2022 15:00 12/22/2022 16:30 1.50 INTRM2, WHDBOP PRTS P RU to test casing. Test casing to 3500PSI f/ 30 minutes. Charted. Good test. 13.4 bbls pumped. 11 bbls back. 0.0 0.0 12/22/2022 16:30 12/22/2022 17:00 0.50 INTRM2, WHDBOP OTHR P Change out 4 1/2" I.F. saver sub on top drive & lower IBOP. 0.0 0.0 12/22/2022 17:00 12/22/2022 19:00 2.00 INTRM2, WHDBOP SLPC P Hold PJSM, cut & slip 97' of drill line. Service topdrive & blocks. Calibrate TDS HT, crown saver & floor saver, check C.O.M. 0.0 0.0 12/22/2022 19:00 12/22/2022 22:00 3.00 INTRM2, DRILLOUT BHAH P Hold PJSM, P/u & rih w/ 6 1/8" Production BHA to 238' MD as per Baker DD/MWD. 0.0 238.0 12/22/2022 22:00 12/23/2022 00:00 2.00 INTRM2, DRILLOUT TRIP P TIH f/ derrick w/ 4" DP f/ 238' to 2887' MD P/u - 69k Monitoring displacement to trip tank. Continue OA Freeze protect injecting-- 67.25 bbls pumped to date. 238.0 2,887.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 24/50 MT7-08 Report Printed: 1/26/2023 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) 12/23/2022 00:00 12/23/2022 01:00 1.00 INTRM2, DRILLOUT TRIP P Perform MWD shallow pulse test at 2887' MD w/ 265 gpm, 2017 psi & 26% F/O. Good test. 2,887.0 2,887.0 12/23/2022 01:00 12/23/2022 01:30 0.50 INTRM2, DRILLOUT PULD P Tih picking up singles of 4" DP w/ the 6 1/8" bha f/ 2887' to 3427' MD. P/u-74k S/o-86k Monitoring displacement on trip tank. Drifting all tubulars. 2,887.0 3,427.0 12/23/2022 01:30 12/23/2022 08:30 7.00 INTRM2, DRILLOUT PULD P Tih picking up singles of 4" Dp f/ 3427' to 7505' MD logging in the hole with the Sonic Scope at 1800 fph. Filling pipe every 25 stds & monitor displacement on trip tank. Drifting DP f/ pipe shed. 3,427.0 7,505.0 12/23/2022 08:30 12/23/2022 13:30 5.00 INTRM2, DRILLOUT PULD P Tih picking up singles of 4" Dp f/ 7505' to 11800' MD at normal running speed. Filling pipe every 25 stds & monitor displacement on trip tank. Drifting DP f/ pipe shed. 7,505.0 11,800.0 12/23/2022 13:30 12/23/2022 16:00 2.50 INTRM2, DRILLOUT PULD P Tih picking up singles of 4" Dp f/ 11800' to 12,941' MD logging in the hole with the Sonic Scope at 1800 fph. Filling pipe every 25 stds & monitor displacement on trip tank. Drifting DP f/ pipe shed. 11,800.0 12,941.0 12/23/2022 16:00 12/23/2022 17:00 1.00 INTRM2, DRILLOUT WASH P Wash/Ream f/ 12,941' to 13,037' MD w/ 225 gpm, 2580 psi. Tagged up on cement. 12,941.0 13,037.0 12/23/2022 17:00 12/23/2022 18:00 1.00 INTRM2, DRILLOUT WASH P Wash/Ream f/ 13,037' to 13,156' MD. Tagged up on LC depth. GPM-230 PSI-2600 RPM-40 TQ-8k F/O-21% 13,037.0 13,156.0 12/23/2022 18:00 12/23/2022 21:30 3.50 INTRM2, DRILLOUT DRLG P Drilling plugs/landing collar at 13,156' to 13,160' MD. GPM-225 PSI-2430 TQ-9k ft/lbs WOB-5k to 10k RPM-50 F/O-21% 13,156.0 13,160.0 12/23/2022 21:30 12/23/2022 23:00 1.50 INTRM2, DRILLOUT DRLG P Drilling cement in 7" liner f/ 13,160' to 13,199' MD. GPM-275 PSI-3490 WOB-10-15k RPM-50 TQ-8k ft/lbs F/O-21% 13,160.0 13,199.0 12/23/2022 23:00 12/24/2022 00:00 1.00 INTRM2, DRILLOUT DRLG P Drilling out float collar at 13,199' to 13,201' MD. GPM-275 PSI-3490 WOB-10-15k RPM-50 TQ-8k ft/lbs F/O-21% Held PJSM with midnight Drill crew on displacing to FloPro. 13,199.0 13,201.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 25/50 MT7-08 Report Printed: 1/26/2023 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) 12/24/2022 00:00 12/24/2022 00:45 0.75 INTRM2, DRILLOUT DRLG P Drilling out float collar at 13,201' to 13,202' MD. GPM-275 PSI-3490 WOB-10-15k RPM-50 TQ-8k ft/lbs F/O-21% Held PJSM with midnight Drill crew on displacing to FloPro. 13,199.0 13,202.0 12/24/2022 00:45 12/24/2022 01:00 0.25 INTRM2, DRILLOUT DRLG P Drilling cement f/ 13,202' to 13.222' MD. Preparing for displacement to 8.8 ppg FloProNT mud. 13,202.0 13,222.0 12/24/2022 01:00 12/24/2022 04:45 3.75 INTRM2, DRILLOUT CIRC P Displace 11.5 ppg SBM to 8.8 ppg FloProNT at 263 gpm w/ 2400 psi. Pump 45 bbls LVT. Pump 110 bbls of WB transition spacer Pump 100 bbls of cleaning spacer Pump 50 bbls Hi-vis FPNT tail spacer Chase w/ FloProNT @ 8.8 ppg f/ pits 3- 4-5-6-7. Taking returns into pits #1 & #2. 13,222.0 13,222.0 12/24/2022 04:45 12/24/2022 09:00 4.25 INTRM2, DRILLOUT CLEN P Clean up surface equipment following the displacement to 8.8 ppg FloProNT. Clean pits, shakers, flow line, & possum belly. Note: Completed Freeze protection on OA with a total of 73.25 bbls pumped at max pressure of 1320 psi. 13,222.0 13,222.0 12/24/2022 09:00 12/24/2022 10:00 1.00 INTRM2, DRILLOUT MPDA P Retrieve trip nipple and install 4" RCD bearing assembly. 13,222.0 13,222.0 12/24/2022 10:00 12/24/2022 15:00 5.00 INTRM2, DRILLOUT DRLG P Drill cement and FS f// 13222' to 13245' MD. Clean out RH and drill 20' new formation to 13270' MD. Pressuring up at and below the shoe. Work through several times. GPM-270 PSI-1630 WOB-5k to 10k RPM-50 TQ-8k ft/lbs F/O-13% 13,222.0 13,270.0 12/24/2022 15:00 12/24/2022 16:30 1.50 INTRM2, DRILLOUT CIRC P BROOH back into shoe to 13,225' MD and CBU. Prep for FIT test. Mud wt in-8.8 ppg Mud wt out-8.8 ppg 13,270.0 13,225.0 12/24/2022 16:30 12/24/2022 17:00 0.50 INTRM2, DRILLOUT FIT P Perform LOT to 11.9 ppg EMW w/ current MW of 8.8 ppg w/ 1280 psi surface pressure. APWD data indicated a 11.8 ppg EMW LOT. Pumped 5.1 bbls during test. Bled off pressure and received 3.5 bbls returns. 13,225.0 13,225.0 12/24/2022 17:00 12/24/2022 17:45 0.75 PROD1, DRILL CIRC P Break circulation, Take SPR's at 13,270' MD w/ 8.8 ppg mud. Wash & ream from 13,244' to 13,270' MD. #1 pump-----------------------#2 pump at 8303' TVD Psi------------Spm-------------Psi 260----------20----------------280 410----------30----------------420 13,225.0 13,270.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 26/50 MT7-08 Report Printed: 1/26/2023 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) 12/24/2022 17:45 12/25/2022 00:00 6.25 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 13,270' to 13,700' MD 8356' TVD. Controlled drill with decreased parameters until the DNR was out of the shoe. At 13,241' MD, the DNR cleared the shoe and increased RPMs. O psi w/ MPD on connections. WOB-20k GPM-270 PSI on bottom-1850 RPM-140 TQ on bottom-8k ft/lbs F/O-18% ECD-9.5 ppg P/U wt-175k S/O wt-140k RWT-152k ADT-5.1 Total bit hrs-6.4 13,270.0 13,700.0 12/25/2022 00:00 12/25/2022 06:00 6.00 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 13,700' to 14,405' MD 8391' TVD. O psi w/ MPD on connections. WOB-20k GPM-281 PSI on bottom-1990 RPM-140 TQ on bottom-8k ft/lbs F/O-18% ECD-9.5 ppg MW-8.8 ppg P/U wt-175k S/O wt-140k RWT-152k R0P-175 ft/hr 13,700.0 14,405.0 12/25/2022 06:00 12/25/2022 12:00 6.00 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 14405' to 15024' MD 8397' TVD. 0 psi w/ MPD on connections. WOB-17k GPM-300 PSI on bottom-2480 RPM-140 TQ on bottom-10k ft/lbs F/O-30% ECD-9.7 ppg MW-8.9 ppg P/U wt-171k S/O wt-140k RWT-155k R0P-175 ft/hr SPR @ 14,740' MD 8393' TVD @ 09:00 hrs #1 pump--------------------#2 pump PSI--------------SPM---------PSI 470-------------30------------470 610-------------40-----------600 14,405.0 15,024.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 27/50 MT7-08 Report Printed: 1/26/2023 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) 12/25/2022 12:00 12/25/2022 18:00 6.00 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 15024' to 15,642' MD 8409' TVD. 100 psi w/ MPD on connections. WOB-13k GPM-300 PSI on bottom-2460 PSI off bottom-2445 RPM-140 TQ on bottom-13k ft/lbs TQ off bottom-7k ft/lbs F/O-15% ECD-9.9 ppg MW-8.9 ppg P/U wt-176k S/O wt-132k RWT-150k R0P-175 ft/hr ADT-4.0 hrs T Bit hrs-18.8 15,024.0 15,642.0 12/25/2022 18:00 12/26/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production interval f/ 15,642' to 16,353' MD 8420' TVD. WOB-14k GPM-300 PSI on-2522 RPM-140 TQ on - 13k ft/lbs TQ off- 7k ft/lbs F/O-23% ECD-10.0 ppg MW-8.8 to 9.0 ppg P/u-176k S/O- 132k RW-150k ADT-4.3 hrs T bit hrs-23.1 1360 grams of metal on ditch magnets 90 psi back pressure on MPD for connections. OA-303 psi Max gas - 6085 units SPR at 16,165' MD, 8420' TVD w/ 9.0 ppg mud wt at 22:00 hrs #1 pump----------------------------------#2 pump PSI--------------------SPM----------------PSI 580---------------------20------------------580 780---------------------30------------------720 15,642.0 16,353.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 28/50 MT7-08 Report Printed: 1/26/2023 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) 12/26/2022 00:00 12/26/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production interval f/ 16,353' to 17087' MD 8424' TVD. WOB-13k GPM-300 PSI on-2774 RPM-140 TQ on - 12k ft/lbs TQ off- 8k ft/lbs F/O-21% ECD-10.4 ppg MW-8.8 to 9.0 ppg P/u-176k S/O- 132k RW-150k BG gas-412 units 90 psi back pressure on MPD for connections. OA-280 psi Max gas-3520 units 16,353.0 17,087.0 12/26/2022 06:00 12/26/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 17087' to 17692' MD 8425' TVD. WOB-13k GPM-320 PSI on-3074 RPM-140 TQ on - 11k ft/lbs TQ off- 8k ft/lbs F/O-21% ECD-10.4 ppg MW- 9.0 ppg P/u-177k S/O- 128k RW-150k BG gas-412 units ADT-4.3hrs 90 psi back pressure on MPD for connections. OA- psi Max gas- units SPR @ 17,106' MD 8299' TVD w/ 9.0 ppg mud #1 pump---------------------#2 pump PSI--------------SPR---------PSI 680-------------20-------------680 900------------30--------------820 17,087.0 17,692.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 29/50 MT7-08 Report Printed: 1/26/2023 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) 12/26/2022 12:00 12/26/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 17,692' to 18,373' MD 8430' TVD. WOB-13k GPM-320 PSI on-3050 RPM-140 TQ on - 12k ft/lbs TQ off- 8k ft/lbs F/O-21% ECD-10.3 ppg MW- 9.0 ppg P/u-173k S/O- 132k RW-152k BG gas-412 units ADT-4.6hrs 100 psi back pressure on MPD for connections. OA-160 psi Max gas- 1953 units SPR @ 17,106' MD 8299' TVD w/ 9.0 ppg mud #1 pump---------------------#2 pump PSI--------------SPR---------PSI 680-------------20-------------680 900------------30--------------820 17,692.0 18,373.0 12/26/2022 18:00 12/26/2022 22:00 4.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 18,373' to 18,787' MD 8445' TVD. WOB-12k GPM-320 PSI on-3042 RPM-140 TQ on - 11k ft/lbs TQ off- 7k ft/lbs F/O-19% ECD-10.2 ppg MW- 9.0 ppg P/u-171k S/O- 125k RW-152k BG gas-412 units ADT-4.6hrs 100 psi back pressure on MPD for connections. OA-135 psi Max gas- 1953 units 18,373.0 18,787.0 12/26/2022 22:00 12/26/2022 22:15 0.25 PROD1, DRILL CIRC P Circ at 320 gpm w/ 3050 psi w/ rotating and reciprocating @ 140 rpm. 18,787.0 18,787.0 12/26/2022 22:15 12/26/2022 22:30 0.25 PROD1, DRILL OWFF P OWFF prior to RCD bearing change out. L/d 2 singles of 4" DP. 18,787.0 18,720.0 12/26/2022 22:30 12/26/2022 23:00 0.50 PROD1, DRILL MPDA P Remove 4" bearing and replace with 5" bearing. Install 4" XT39 pin X NC 50 box crossover and 5" DP. 18,720.0 18,787.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 30/50 MT7-08 Report Printed: 1/26/2023 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) 12/26/2022 23:00 12/27/2022 00:00 1.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 18,787' to 18,855' MD 8440' TVD. WOB-12k GPM-320 PSI on-3042 RPM-140 TQ on - 11k ft/lbs TQ off- 7k ft/lbs F/O-19% ECD-10.2 ppg MW- 9.0 ppg P/u-171k S/O- 125k RW-152k BG gas-412 units ADT-3.3hrs 100 psi back pressure on MPD for connections. OA-135 psi Max gas- 1953 units SPR @ 18,632' MD w/ 9.0 ppg @ 20:15 hrs #1 pump--------------------#2 pump PSI---------------SPM---------PSI 640----------------20-------------640 780----------------30-------------780 18,787.0 18,855.0 12/27/2022 00:00 12/27/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 18,855' to 19,574' MD 8467' TVD. WOB-12k GPM-320 PSI on-3174 RPM-140 TQ on - 11k ft/lbs TQ off- 7k ft/lbs F/O-19% ECD-10.5 ppg MW- 9.0 ppg P/u-190k S/O- 128k RW-152k ADT-4.6 hrs BG gas-357 units Max gas-1577 units 100 psi back pressure on MPD for connections. OA-143 psi 18,855.0 19,574.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 31/50 MT7-08 Report Printed: 1/26/2023 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) 12/27/2022 06:00 12/27/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 19,574' to 20,226' MD 8466' TVD. WOB-13k GPM-320 PSI on-3246 RPM-140 TQ on - 12k ft/lbs TQ off- 9k ft/lbs F/O-21% ECD-10.6 ppg MW- 9.0 ppg P/u-192k S/O- 131k RW-152k ADT-4.4 hrs BG gas-357 units 100 psi back pressure on MPD for connections. OA-120 psi SPR's @ 20,047' MD 8466' TVD w/ 9.0 ppg mud wt at 10:20 hrs #1 pump-----------------------#2 pump PSI----------------SPM--------PSI 700----------------30------------700 880----------------40------------870 19,574.0 20,226.0 12/27/2022 12:00 12/27/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 20,226' to 20,890' MD 8453' TVD. WOB-14k GPM-320 PSI on-3250 RPM-140 TQ on - 11k ft/lbs TQ off- 7k ft/lbs F/O-21% ECD-10.6 ppg MW- 9.0 ppg P/u-194k S/O- 129k RW-157k ADT-4.4 hrs BG gas-350 units 100 psi back pressure on MPD for connections. OA-80 psi 20,226.0 20,890.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 32/50 MT7-08 Report Printed: 1/26/2023 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) 12/27/2022 18:00 12/28/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 20,890' to 21,520' MD 8463' TVD. WOB-14k GPM-320 PSI on-3250 RPM-140 TQ on - 11k ft/lbs TQ off- 7k ft/lbs F/O-21% ECD-10.6 ppg MW- 9.0 ppg P/u-194k S/O- 129k RW-157k ADT-4.5 hrs Total bit hrs-58 BG gas-305 units 100 psi back pressure on MPD for connections. OA-67 psi SPR @ 21,371' MD 8460' TVD w/ 9.0 ppg mud wt @ 22:30 hrs #1 pump---------------------------#2 pump PSI------------------SPM------------PSI 760------------------30---------------780 920------------------40---------------1020 20,890.0 21,520.0 12/28/2022 00:00 12/28/2022 04:30 4.50 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 21,520' to 21,975' MD 8463' TVD. WOB-14k GPM-320 PSI on-3330 RPM-140 TQ on - 12k ft/lbs TQ off- 8k ft/lbs F/O-21% ECD-10.7 ppg MW- 9.1 ppg P/u-194k S/O- 129k RW-157k ADT-3.5 hrs BG gas-280 units Max gas-2993 units @ 21,793' MD 100 psi back pressure on MPD for connections. OA-57 psi 21,520.0 21,975.0 12/28/2022 04:30 12/28/2022 05:00 0.50 PROD2, DRILL CIRC P Prepare for OHST. Pooh to 21,937' MD, rih to 21,975'. Downlink to steer mode & set up to ST as per Baker procedures 21,975.0 21,975.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 33/50 MT7-08 Report Printed: 1/26/2023 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) 12/28/2022 05:00 12/28/2022 10:00 5.00 PROD2, TRIPCAS DDRL P Drill OHST at 21,975' MD to 22,385' MD. WOB-14k GPM-320 PSI on-3330 RPM-140 TQ on - 12k ft/lbs TQ off- 8k ft/lbs F/O-21% ECD-10.7 ppg MW- 9.1 ppg P/u-194k S/O- 129k RW-157k ADT- hrs BG gas-280 units ADT-4.8 hrs 100 psi back pressure on MPD for connections. OA-55 psi 21,975.0 22,385.0 12/28/2022 10:00 12/28/2022 11:00 1.00 PROD2, TRIPCAS BKRM P BROOH f/ 22385' MD to 21937' MD. 320 GPM 3513 PSI 100 RPM 10k TQ 10.7ppg ECD 150k ROT Holding 100pis w/ MPD on connections. 22,385.0 21,937.0 12/28/2022 11:00 12/28/2022 13:30 2.50 PROD2, TRIPCAS DDRL P Begin troughing for OHST as per Baker Directional @ 21,937' to 21,975' MD w/ : GPM-320 PSI-3632 RPM-100 TQ-9K ft/lbs F/O-19% ECD-10.5 ppg RT WT-162k 21,937.0 21,975.0 12/28/2022 13:30 12/28/2022 18:00 4.50 PROD1, DRILL DDRL P Time drill OHST as per Baker Directional at 21,975' MD. GPM-230 PSI-2195 RPM-100 TQ-11k ft/lbs ECD-9.9.0 ppg RT Wt-160k Increase in gas at 17:00 hrs and applied 75 psi w/ MPD increasing ECD to 10.0 ppg. Gas continued increasing to 1600 units and increased ECD to 10.2 ppg w/ 160 psi on MPD. 21,975.0 21,975.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 34/50 MT7-08 Report Printed: 1/26/2023 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) 12/28/2022 18:00 12/29/2022 00:00 6.00 PROD1, DRILL DDRL P Time drill OHST as per Baker Directional at 21,975' to 21,986' MD. GPM-230 PSI-2280 RPM-100 TQ-12k ft/lbs ECD-10.3 ppg RT Wt-160k F/O-29% ADT-6 hrs Total bit hrs-74.2 OA-0 psi Holding 220 psi dynamically on MPD to maintain 10.3 ppg ECD. BG gas-42 units 21,975.0 21,986.0 12/29/2022 00:00 12/29/2022 04:00 4.00 PROD1, DRILL DDRL P Time drill OHST as per Baker Directional at 21,986' to 22,004' MD. GPM-230 PSI-2280 RPM-100 TQ-12k ft/lbs ECD-10.3 ppg RT Wt-160k F/O-13.5% ADT-4.5 hrs OA-0 psi Holding 220 psi dynamically on MPD to maintain 10.3 ppg ECD. BG gas-61 units 21,986.0 22,004.0 12/29/2022 04:00 12/29/2022 04:30 0.50 PROD1, DRILL DDRL P Drilling 6 5/16" x 6 1/8" production interval f/ 22,004' MD to 22,020' MD. GPM-230 PSI-2280 RPM-100 TQ-12k ft/lbs ECD-10.3 ppg RT Wt-160k F/O-13.5% ADT-4.5 hrs OA-0 psi Holding 220 psi dynamically on MPD to maintain 10.3 ppg ECD. BG gas-61 units 22,004.0 22,020.0 12/29/2022 04:30 12/29/2022 05:00 0.50 PROD1, DRILL CIRC P Confirm separation f/ original well bore. Backream f/ 22,020' to 21,960' MD. Work through several times. Take surveys to confirm. 22,020.0 22,020.0 12/29/2022 05:00 12/29/2022 06:00 1.00 PROD1, DRILL DDRL P Drilling 6 5/16" x 6 1/8" production interval f/ 22,020' MD to 22,060' MD. 22,020.0 22,060.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 35/50 MT7-08 Report Printed: 1/26/2023 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) 12/29/2022 06:00 12/29/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 22060' to 22644' MD 8481' TVD. WOB-15k GPM-300 PSI on-3149 RPM-140 TQ on - 13k ft/lbs TQ off- 10k ft/lbs F/O-18% ECD-10.4 ppg MW- 9.0 ppg P/u-202k S/O- 134k RW-173k BG gas- 100-225units ADT-4.5hrs 100 psi back pressure on MPD for connections. OA-0 psi Max gas- 1218 units 22,060.0 22,644.0 12/29/2022 12:00 12/29/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 22,644' to 23,237' MD 8491' TVD. WOB-8k GPM-307 PSI on-3100 RPM-140 TQ on - 12k ft/lbs TQ off- 10k ft/lbs F/O-20% ECD-10.6 ppg MW- 9.0 ppg P/u-208k S/O- 130k RW-163k BG gas- 100-225units ADT-4.6hrs 125 psi back pressure on MPD for connections. OA-0 psi Max gas- 2811 units BG gas-170 units 22,644.0 23,237.0 12/29/2022 18:00 12/29/2022 21:00 3.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 23,237' to 23,413' MD 8494' TVD. WOB-10k GPM-320 PSI on-3100 RPM-140 TQ on - 14k ft/lbs TQ off- 10k ft/lbs F/O-20% ECD-10.6 ppg MW- 8.9 ppg P/u-208k S/O- 130k RW-163k ADT-1.7hrs Total bit hrs-90.2 125 psi back pressure on MPD for connections. OA-0 psi Max gas- 1615 units BG gas-170 units 23,237.0 23,413.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 36/50 MT7-08 Report Printed: 1/26/2023 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) 12/29/2022 21:00 12/29/2022 23:00 2.00 PROD1, DRILL CIRC T Baker MWD not decoding properly. Troubleshooting same. Checked mud pumps, changed pumps, changed stdpipe transducer & cabling. Pumped 20 bbls FW through drillstring attempting to clear any debris. Failed pulsar. Decision made to SOOH for bha failure. 23,413.0 23,413.0 12/29/2022 23:00 12/30/2022 00:00 1.00 PROD1, DRILL MPDA T Blow down topdrive. Perform fingerprinting for trip out of hole. 9.3 ppg EMW PP without trip margin. 23,413.0 23,330.0 12/30/2022 00:00 12/30/2022 00:30 0.50 PROD1, DRILL MPDA T Finish perform MPD fingerprinting in preparation to SOOH. 9.3 ppg EMW. Beyond MPD sent out stripping schedule with a 9.5 ppg EMW for trip margin. 23,330.0 23,330.0 12/30/2022 00:30 12/30/2022 04:00 3.50 PROD1, DRILL CIRC T Circ 1.5 b/u at 349 to 267 gpm. Gas increased to 3637 units and aligned returns to MGS. Adjust pump rate for MGS. Rotating and reciprocating DS in creep mode up to 23,206' MD. Take SPR's prior to shutting down mud pumps. GPM-349 PSI-3525 GPM-267 PSI-2361 RPM-140 TQ-=13k ft/lbs 23,330.0 23,206.0 12/30/2022 04:00 12/30/2022 11:30 7.50 PROD1, DRILL SMPD T SOOH f/ 23,206' to 18780' MD at initial rate of 17'/min as per MPD stripping schedule. Floats not holding. Screw in to topdrive ech std. Stage up speed to 25ft/min. Able to pull on elevators. 23,206.0 18,780.0 12/30/2022 11:30 12/30/2022 12:30 1.00 PROD1, DRILL MPDA T PJSM on Swapping Bearing assemblies. Lined up to maintain pressure below annular. Hold 300psi w/ MPD w/ annular closed. Retrieve 5" bearing and install 4" bearing assembly. 18,780.0 18,737.0 12/30/2022 12:30 12/30/2022 19:30 7.00 PROD1, DRILL SMPD T SOOH f/ 18737'MD to 10,855' MD-TOL on 4" DP. Monitoring displacement on pits #2 & #3. Maintaining MPD backpressure as per Beyond's stripping schedule. 18,737.0 10,855.0 12/30/2022 19:30 12/30/2022 20:00 0.50 PROD1, DRILL SFTY T Hold PJSM with all personnel for displacement procedure-9.5 ppg KWB in, 8.9 ppg FPNT out. 10,855.0 10,855.0 12/30/2022 20:00 12/30/2022 22:30 2.50 PROD1, DRILL CIRC T Displacing 8.9 ppg FPNT with 9.5 ppg KWB at 250 gpm using Beyond's rollover schedule. PSI-1100 F/O-15% RPM-100 9480 total stks pumped. 10,855.0 10,855.0 12/30/2022 22:30 12/30/2022 23:30 1.00 PROD1, DRILL OWFF T Blow down Topdrive. OWFF. Initial rate of 3.6 bph flow back and decreasing rate with every 10 min check. Continued to slow to .5 bph then static. 10,855.0 10,855.0 12/30/2022 23:30 12/31/2022 00:00 0.50 PROD1, DRILL MPDA T Hold PJSM & pull 4" RCD bearing assy. Weekly function test of BOPs. 10,855.0 10,855.0 12/31/2022 00:00 12/31/2022 00:30 0.50 PROD1, DRILL MPDA T Hold PJSM & pull 4" RCD bearing assy. Install trip nipple. 10,855.0 10,855.0 12/31/2022 00:30 12/31/2022 01:00 0.50 PROD1, DRILL CIRC T Pump 50 bbls of 10.2 dry job. 10,855.0 10,855.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 37/50 MT7-08 Report Printed: 1/26/2023 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) 12/31/2022 01:00 12/31/2022 05:00 4.00 PROD1, DRILL TRIP T Pooh w/ 6 1/8" bha on 4" DP f/ 10,855' MD to 5735' MD racking in the derrick. 10,855.0 5,735.0 12/31/2022 05:00 12/31/2022 08:30 3.50 PROD1, DRILL PULD T Pooh w/ 6 1/8" bha on 4" DP, laying down in doubles to the pipe shed. 5,735.0 242.0 12/31/2022 08:30 12/31/2022 09:00 0.50 PROD1, DRILL BHAH T Flow check. Static. PJSM on LD BHA. 5,000.0 238.0 12/31/2022 09:00 12/31/2022 11:00 2.00 PROD1, DRILL BHAH T LD BHA #4. Bit Grade-1-1-NO-A-X-I-NO-DTF. 238.0 0.0 12/31/2022 11:00 12/31/2022 11:30 0.50 PROD1, DRILL CLEN T Clean/clear rig floor. Service Top drive. Download data f/ SLB Sonic tool. 0.0 0.0 12/31/2022 11:30 12/31/2022 15:00 3.50 PROD1, DRILL BHAH T PU and RIH w/ 6 5/16" x 6 1/8" BHA #5 0.0 208.0 12/31/2022 15:00 12/31/2022 20:00 5.00 PROD1, DRILL TRIP T RIH w/ 6 5/16' x 6 1/8" BHA #5 f/ 208' to 5699' MD w/ 4" doubles f/ pipe shed. Perform shallow test and observe pulse on tools each fillup, monitoring displacement on trip pit #3. 208.0 5,699.0 12/31/2022 20:00 1/1/2023 00:00 4.00 PROD1, DRILL TRIP T TIH w/ 6 5/16" x 6 1/8" BHA #5 f/ 5699' to 12,532' MD f/ Drk. Monitoring displacement on trip pit #3. Slowed down going through the 7" TOL at 10,855' MD, no tag. Slowed to 60'/min while tripping in the 7" liner as per surge analysis. 5,699.0 12,532.0 1/1/2023 00:00 1/1/2023 01:15 1.25 PROD1, DRILL TRIP T Tih w/ 6 5/16" x 6 1/8" bha 12,532' to 13,244' MD through the 7" liner. Monitoring displacement on Trip pit. 12,532.0 13,244.0 1/1/2023 01:15 1/1/2023 02:30 1.25 PROD1, DRILL SLPC T Slip & cut drill line w/ monitoring well on trip tank. Check C-O-M & calibrate crown & floor savers. 13,244.0 13,244.0 1/1/2023 02:30 1/1/2023 03:30 1.00 PROD1, DRILL MPDA T PJSM, remove trip nipple & install 4" RCD bearing. Monitor well on trip tank. 13,244.0 13,244.0 1/1/2023 03:30 1/1/2023 07:00 3.50 PROD1, DRILL CIRC T Hold PJSM. Displace casing w/ 8.9 ppg FPNT f/ 9.5 ppg KWB w/ 150 to 250 gpm as per Beyond's rollover schedule. Max gas observed 2950 units. 13,244.0 13,244.0 1/1/2023 07:00 1/1/2023 08:00 1.00 PROD1, DRILL SMPD T SIH f/ 13244' MD to 14017''. Observed taking weight 20-30k. PU and attempt again w/ no success. 13,244.0 14,017.0 1/1/2023 08:00 1/1/2023 09:30 1.50 PROD1, DRILL WASH T Wash down f/ 14,017' to 14325' with no issues. 250 GPM 1680 PSI 14,017.0 14,325.0 1/1/2023 09:30 1/1/2023 13:30 4.00 PROD1, DRILL SMPD T SIH f/ 14325' to ' 18,697'' MD as per Beyond's stripping schedule. 14,325.0 18,697.0 1/1/2023 13:30 1/1/2023 15:00 1.50 PROD1, DRILL MPDA T PJSM, OWFF. Change out RCD bearing under pressure utilizing the annular preventer. Install 5" RCD bearing. 18,697.0 18,697.0 1/1/2023 15:00 1/1/2023 18:30 3.50 PROD1, DRILL CIRC T SIH f/ 18,697' to 23,100' MD as per Beyond's stripping schedule. 18,697.0 23,100.0 1/1/2023 18:30 1/1/2023 19:30 1.00 PROD1, DRILL WASH T Wash/ream f/ 23,100' to 23,413' MD, relogging with MWD at 300'/hr w/ 250 gpm, 2224 psi. 23,100.0 23,413.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 38/50 MT7-08 Report Printed: 1/26/2023 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) 1/1/2023 19:30 1/1/2023 21:30 2.00 PROD1, DRILL CIRC T Circ b/u at 23,413' MD. GPM-300 PSI-2771 RPM-60 TQ-12.5k ft/lbs ECD-10.2 ppg Gas-2500 Max gas- P/u- 240k S/o- 138k RW-173k Take SPR's at 23,413' MD 8496' TVD w/ 8.9 ppg #1 pump------------------------#2 pump PSI----------------SPM-------------PSI 540-----------------20----------------560 780-----------------30----------------740 23,413.0 23,413.0 1/1/2023 21:30 1/2/2023 00:00 2.50 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 23,413' to 23,639' MD 8506' TVD. WOB-15k GPM-300 PSI on-2955 RPM-140 TQ on - 14k ft/lbs TQ off- 10k ft/lbs F/O-21% ECD-10.5 ppg MW- 8.9 ppg P/u-241k S/O- 138k RW-178k ADT-1.7hrs Total bit hrs-1.7 hrs 150 psi back pressure on MPD for connections. OA-0 psi Max gas- 2795 units BG gas-900 units 23,413.0 23,639.0 1/2/2023 00:00 1/2/2023 03:00 3.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 23,639' to 23,940' MD 8498' TVD. #1 Mud pump stopped without warning while drilling at 23,940' MD. Multiple alarms activated. Turned off the Novos system and brought pump back on & continued drilling. WOB-15k GPM-300 PSI on-2955 RPM-140 TQ on - 14k ft/lbs TQ off- 10k ft/lbs F/O-24% ECD-10.5 ppg MW- 8.9 ppg P/u-241k S/O- 138k RW-178k ADT-2.0 hrs Total bit hrs-3.7 hrs 225 psi back pressure on MPD for connections. 50 psi MPD w/drilling OA-0 psi Max gas- 3488 units BG gas-400 units 23,639.0 23,940.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 39/50 MT7-08 Report Printed: 1/26/2023 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) 1/2/2023 03:00 1/2/2023 06:00 3.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 23,940' to 24,256' MD 8492' TVD. WOB-15k GPM-300 PSI on-2955 RPM-140 TQ on - 14k ft/lbs TQ off- 10k ft/lbs F/O-24% ECD-10.5 ppg MW- 8.9 ppg P/u-241k S/O- 138k RW-178k ADT-4.4 hrs Total bit hrs-6.1 hrs 225 psi back pressure on MPD for connections. 50 psi MPD w/drilling OA-0 psi Max gas-3358 units BG gas-538 units 23,940.0 24,256.0 1/2/2023 06:00 1/2/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 24256' to 24,878' MD 8483' TVD. WOB-9k GPM-320 PSI on-3310 RPM-140 TQ on - 16k ft/lbs TQ off- 11k ft/lbs F/O-17% ECD-10.9 ppg MW- 8.9 ppg P/u-225k S/O- 125k RW-178k ADT- 4.3hrs Total bit hrs- 10.4 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 3521 units BG gas-120 units SPR's at 24,540' MD 8457' TVD w/ 8.9 ppg #1 pump-----------------------#2 pump PSI--------------SPM-------------PSI 850--------------20-----------------840 1000------------30----------------1040 24,256.0 24,878.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 40/50 MT7-08 Report Printed: 1/26/2023 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) 1/2/2023 12:00 1/2/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 24,878' to 25,483' MD 8483' TVD. WOB-8k GPM-320 PSI on-3348 RPM-140 TQ on - 15k ft/lbs TQ off- 11k ft/lbs F/O-17% ECD-11.0 ppg MW- 8.9 ppg P/u-228k S/O- 125k RW-170k ADT- 4.8hrs Total bit hrs- 15.2 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 1125 units BG gas-195 units Ditch magnets-3 lbs 24,878.0 25,483.0 1/2/2023 18:00 1/3/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 25,483' to 26,100' MD 8484' TVD. WOB-6k GPM-320 PSI on-3285 RPM-140 TQ on - 16k ft/lbs TQ off- 12k ft/lbs F/O-20% ECD-11.0 ppg MW- 8.9 ppg P/u-228k S/O- 118k RW-170k ADT- 4.8hrs Total bit hrs- 20.0 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 200 units BG gas-195 units SPR's @ 25,956' MD 8485' TVD w/ 8.9 ppg #1 pump--------------------#2 pump PSI---------------SPM-----------PSI 800----------------20--------------800 970----------------30-------------1010 25,483.0 26,100.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 41/50 MT7-08 Report Printed: 1/26/2023 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) 1/3/2023 00:00 1/3/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 26,100' to 26,708' MD 8495' TVD. WOB-9k GPM-320 PSI on-3320 RPM-140 TQ on - 18k ft/lbs TQ off- 13k ft/lbs F/O-18% ECD-11.0 ppg MW- 8.9 ppg P/u-233k S/O- 106k RW-175k ADT-4.9 hrs Total bit hrs- 24.9 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 405 units BG gas-195 units 26,100.0 26,708.0 1/3/2023 06:00 1/3/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 26,708' to 27,237' MD 8505' TVD. WOB-9k GPM-320 PSI on-3430 RPM-140 TQ on - 19k ft/lbs TQ off- 12k ft/lbs F/O-20% ECD-11.1 ppg MW- 8.9 ppg P/u-239k S/O- 103k RW-179k ADT-4.3 hrs Total bit hrs- 29.2 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 405 units BG gas-195 units SPR's at 21,177' MD 8505' TVD w/ 8.9 ppg FPNT #1 pump-----------------------#2 pump PSI------------------SPM----------PSI 800------------------20--------------860 1020----------------30---------------1060 Ditch magnet metal recovery-1.0 lbs 26,708.0 27,237.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 42/50 MT7-08 Report Printed: 1/26/2023 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) 1/3/2023 12:00 1/3/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 27,237' to 27,800' MD 8509' TVD. WOB-16k GPM-320 PSI on-3460 RPM-140 TQ on - 21k ft/lbs TQ off- 14k ft/lbs F/O-20% ECD-11.1 ppg MW- 8.9 ppg P/u-241k S/O- 95k RW-178k ADT-4.5 hrs Total bit hrs- 33.7 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 254 units BG gas-216 units 27,237.0 27,800.0 1/3/2023 18:00 1/4/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 27,800' to 28,285' MD 8502' TVD. WOB-8k GPM-300 PSI on-3249 RPM-140 TQ on - 18k ft/lbs TQ off- 14k ft/lbs F/O-20% ECD-11.1 to 11.2 ppg MW- 8.9 ppg P/u-248k S/O- xxx k Lost down weight @ 27,800' MD. RW-180k ADT-4.8 hrs Total bit hrs- 38.5 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 485 units BG gas-250 units SPR's at 28,215' MD 8503' TVD w/ 8.9 ppg FPNT #1 pump-----------------------#2 pump PSI------------------SPM----------PSI 925------------------20--------------940 1100----------------30---------------1140 27,800.0 28,285.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 43/50 MT7-08 Report Printed: 1/26/2023 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) 1/4/2023 00:00 1/4/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 28,285' to 28,772' MD 8501' TVD. WOB-10k GPM-305 PSI on-3355 RPM-140 TQ on - 20k ft/lbs TQ off- 15k ft/lbs F/O-20% ECD-11.1 to 11.2 ppg MW- 8.9 ppg P/u-255k S/O- xxx k RW-192k ADT-4.8 hrs Total bit hrs-43.3 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 414 units BG gas-303 units 28,285.0 28,772.0 1/4/2023 06:00 1/4/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 28,772' MD to 29,171' MD 8490' TVD. WOB-10k GPM-305 PSI on-3355 RPM-140 TQ on - 20k ft/lbs TQ off- 15k ft/lbs F/O-20% ECD-11.1 to 11.2 ppg MW- 8.9 ppg P/u-255k S/O- xxx k RW-192k ADT-5.1 hrs Total bit hrs-48.4 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 414 units BG gas-303 units Metal recovered f/ ditch magnets-3628 grams (8 lbs) Metal cum-12 lbs 28,772.0 29,171.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 44/50 MT7-08 Report Printed: 1/26/2023 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) 1/4/2023 12:00 1/4/2023 13:00 1.00 PROD1, DRILL DDRL P Drill 6 5/16" x 6 1/8" production interval f/ 29,171' MD to 29,203' MD 8489' TVD. (TD of hole section) Obtain final survey and downlink directional tools off. WOB-10k GPM-305 PSI on-3340 RPM-140 TQ on - 21k ft/lbs TQ off- 15k ft/lbs F/O-18% ECD-11.1 to 11.2 ppg MW- 9.0 ppg P/U-256k S/O- xxx k RW-195k ADT-.6 hrs Total bit hrs-49.0 hrs 250 psi back pressure on MPD for connections. 0 psi MPD w/drilling OA-0 psi Max gas- 300 units BG gas-150 units 29,171.0 29,203.0 1/4/2023 13:00 1/4/2023 16:00 3.00 PROD1, DRILL CIRC P Circulate BTM's up at 29,203' to 29,160' MD GPM-320 PSI-3400 F/O-18% RPM-140 TQ-19-23k ft/lbs ECD-11.1 ppg P/U-256k RT Wt-195k After b/u circulated, slowed pumps to 100 gpm for 30 min, prior to fingerprinting. SIMOPS: L/D excess 5" drill pipe from derrick 29,203.0 29,160.0 1/4/2023 16:00 1/4/2023 17:00 1.00 PROD1, DRILL MPDA P Perform Beyond fingerprinting procedure at 29,193' MD. Rotating at 5 rpm w/ 14.5k ft/lbs TQ. Initial shut in pressure after 15 min was 98 psi. Bled off for 5 min and gained 1.2 bbls. Shut in pressure after 15 min-31 psi, and bled off 0.2 bbls back. 29,193.0 29,103.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 45/50 MT7-08 Report Printed: 1/26/2023 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) 1/4/2023 17:00 1/5/2023 00:00 7.00 PROD1, TRIPCAS CIRC P Circulating well cleanup cycles-4 b/u at 29,103' to 28,976' MD, racking back 1 std per 2 b/u. Total of 36,800 stks pumped at midnight (3 b/u) GPM-320 PSI-3400 F/O-18% RPM-140 TQ-19-23k ft/lbs ECD-11.1 ppg P/U-256k RT WT-195k Max gas-752 units BG gas-130 units SPR's at 29,203' MD 8489' TVD w/ 8.9 ppg #1 pump-------------------------#2 pump PSI------------------SPM------------PSI 920-------------------20---------------920 1160-----------------30--------------1130 29,103.0 28,976.0 1/5/2023 00:00 1/5/2023 01:30 1.50 PROD1, TRIPCAS CIRC P Circulating well cleanup cycles-4 b/u at 28,976' MD. GPM-320 PSI-3400 F/O-18% RPM-140 TQ-19-23k ft/lbs ECD-11.1 ppg P/U-256k RT WT-195k Max gas-150 units BG gas-130 units 28,976.0 28,976.0 1/5/2023 01:30 1/5/2023 02:00 0.50 PROD1, TRIPCAS WASH P Wash back to TD f/ 28,976' MD to 29,203' MD. GPM-300 RPM-120 TQ-15k ft/lbs ECD-11.0 ppg P/U-256k 28,976.0 29,203.0 1/5/2023 02:00 1/5/2023 10:00 8.00 PROD1, TRIPCAS CIRC P Hold PJSM and displace f/ 8.9 ppg FPNT to 9.5 ppg KW Brine as per Beyond's rollover schedule at max of 150 gpm, for a maximum ECD of 11.1 ppg as per model. 29,203.0 29,203.0 1/5/2023 10:00 1/5/2023 10:30 0.50 PROD1, TRIPCAS OWFF P OWFF, (Static) 29,203.0 29,190.0 1/5/2023 10:30 1/5/2023 12:00 1.50 PROD1, TRIPCAS STRP P Blow down top drive, SOOH from 29,190' MD to 28,131' MD. 25psi in slips/210psi out slips. PU: 265k 29,190.0 28,131.0 1/5/2023 12:00 1/5/2023 18:00 6.00 PROD1, TRIPCAS STRP P Continue SOOH from 28,131' MD to 19,831' MD. 20psi in slips/150psi out slips. PU: 205k 28,131.0 19,831.0 1/5/2023 18:00 1/5/2023 19:00 1.00 PROD1, TRIPCAS STRP P Continue SOOH from 19,831' MD to 18,697' MD. 25psi in slips/180psi out slips. PU: 198k 19,831.0 18,697.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 46/50 MT7-08 Report Printed: 1/26/2023 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) 1/5/2023 19:00 1/5/2023 20:00 1.00 PROD1, TRIPCAS MPDA P OWFF, static, Change out 5" RCD for 4" 18,697.0 18,697.0 1/5/2023 20:00 1/6/2023 00:00 4.00 PROD1, TRIPCAS STRP P Continue SOOH from 18,697' MD to 15,673' MD. 25psi in slips/160psi out slips. L/D 4" drill pipe doubles. PU: 192k 18,697.0 15,673.0 1/6/2023 00:00 1/6/2023 00:30 0.50 PROD1, TRIPCAS STRP P Continue SOOH from 15,673' MD to 15,530' MD. 25psi in slips/160psi out slips. L/D 4" drill pipe doubles. Corva trending .4 FF. PU: 192k 15,673.0 15,530.0 1/6/2023 00:30 1/6/2023 04:30 4.00 PROD1, TRIPCAS CIRC P Circulate at 15,530' MD to 15,465' MD, Shaker clean, Max gas 907 units, Blow down top drive. PU:150k GPM: 150 PSI: 620 RPM: 100 Trq: 7k 15,530.0 15,465.0 1/6/2023 04:30 1/6/2023 06:00 1.50 PROD1, TRIPCAS STRP P Continue SOOH from 15,465' MD to 14,402' MD. 25psi in slips/160psi out slips. L/D 4" drill pipe doubles 15,465.0 14,402.0 1/6/2023 06:00 1/6/2023 07:00 1.00 PROD1, TRIPCAS STRP P Continue SOOH from 15,465' MD to 13,255' MD. 25psi in slips/60psi out slips. L/D 4" drill pipe doubles 14,402.0 13,255.0 1/6/2023 07:00 1/6/2023 08:00 1.00 PROD1, TRIPCAS CIRC P Circulate at 13,255' MD to 13,240' MD, Shaker clean, Blow down top drive. PU:150k SO: 150k ROT: 146k GPM: 327 PSI: 1965 ECD: 9.9ppg RPM: 30 Trq: 5k 13,255.0 13,240.0 1/6/2023 08:00 1/6/2023 12:00 4.00 PROD1, TRIPCAS STRP P Continue SOOH from 13,240' MD to 10,983' MD. 25psi in slips/60psi out slips. L/D 4" drill pipe doubles and singles. Drop 1.75" well commander ball. PU:162k 13,240.0 10,983.0 1/6/2023 12:00 1/6/2023 13:30 1.50 PROD1, TRIPCAS CIRC P Open well commander, Circulate at 10,983' MD to 10,920' MD, Shaker clean, Close well commander, Drop 1.75" ball, pump down at 84gpm, ball on seat at 537stks, pressure up to 1300psi and hold 30sec, continue pressure up and shear at 2012psi. Blow down top drive. PU:135k SO: 141k ROT: 140k GPM: 700 PSI: 2380 RPM: 20 Trq: 3k 10,983.0 10,920.0 1/6/2023 13:30 1/6/2023 14:00 0.50 PROD1, TRIPCAS OWFF P OWFF (static) 10,920.0 10,920.0 1/6/2023 14:00 1/6/2023 15:00 1.00 PROD1, TRIPCAS MPDA P Pull 4" RCD and install trip nipple. 10,920.0 10,920.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 47/50 MT7-08 Report Printed: 1/26/2023 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) 1/6/2023 15:00 1/6/2023 17:30 2.50 PROD1, TRIPCAS TRIP P POOH from 10,920' MD to 8,454' MD racking back 26 stands of 4" drill pipe. 10,920.0 8,454.0 1/6/2023 17:30 1/6/2023 18:00 0.50 PROD1, TRIPCAS RURD P Pull master bushings and install PS- 21's, Prep floor to L/D 4" drill pipe. 8,454.0 8,454.0 1/6/2023 18:00 1/6/2023 23:30 5.50 PROD1, TRIPCAS PULD P POOH from 8,454' MD to 4,867' MD L/D 4" drill pipe. 8,454.0 4,867.0 1/6/2023 23:30 1/7/2023 00:00 0.50 PROD1, TRIPCAS SVRG P Service rig, Pull PS-21's and install master bushings. 4,867.0 4,867.0 1/7/2023 00:00 1/7/2023 06:00 6.00 PROD1, TRIPCAS TRIP P POOH from 4,867' MD to 213' MD L/D 4" drill pipe. Total 110 joints 4" drill pipe culled. 4,867.0 213.0 1/7/2023 06:00 1/7/2023 08:00 2.00 PROD1, TRIPCAS BHAH P OWFF (Static) L/D BHA # 5. 213.0 0.0 1/7/2023 08:00 1/7/2023 08:30 0.50 PROD1, TRIPCAS CLEN P Clean and clear rig floor. 0.0 0.0 1/7/2023 08:30 1/7/2023 09:30 1.00 PROD1, TRIPCAS SLPC P Cut and Slip 118' Drill line. Calibrate Blocks 0.0 0.0 1/7/2023 09:30 1/7/2023 11:00 1.50 PROD1, TRIPCAS RURD P R/U 4.5" liner running equipment and tools. 0.0 0.0 1/7/2023 11:00 1/7/2023 18:00 7.00 COMPZN, CASING PUTB P M/U 4.5" Citadel shoe and continue P/U 4.5" 12.6ppf L80 Hyd 563 liner (floating) to 6,073' MD. Avg 867'/hr. 0.0 6,073.0 1/7/2023 18:00 1/8/2023 00:00 6.00 COMPZN, CASING PUTB P P/U 4.5" 12.6ppf L80 Hyd 563 liner (floating) From 6,073' MD to 10,975' MD. Avg 817'/hr. 6,073.0 10,975.0 1/8/2023 00:00 1/8/2023 05:30 5.50 COMPZN, CASING PUTB P P/U 4.5" 12.6ppf L80 Hyd 563 liner (floating) From 10,975' MD to 16,076' MD. Avg 855'/hr. At 13,210' MD PU: 86k SO: 80k 10,975.0 16,076.0 1/8/2023 05:30 1/8/2023 06:30 1.00 COMPZN, CASING PULD P PU and MU 4 1/2" liner hanger and ZXHD packer per Baker. Fill tie back sleeve w/ Zan Plex. RIH w/ 1 std 4" Drill pipe. Take parameters: PU- 93k SO- 80k ROT- 88k TQ- 3.5k. 16,076.0 16,210.0 1/8/2023 06:30 1/8/2023 07:30 1.00 COMPZN, CASING RUNL P Run 4.5" liner on 4" drill pipe from 16,210' MD to 18,580' MD. Top filling drill pipe. 16,210.0 18,580.0 1/8/2023 07:30 1/8/2023 12:00 4.50 COMPZN, CASING RUNL P Run 4.5" liner on 5" drill pipe from 18,580' MD to 23,385' MD. Top filling drill pipe. 18,580.0 23,385.0 1/8/2023 12:00 1/8/2023 17:30 5.50 COMPZN, CASING RUNL P Run 4.5" liner on 5" drill pipe from 23,385' MD to 29,193' MD. Top filling drill pipe. 23,385.0 29,193.0 1/8/2023 17:30 1/8/2023 18:30 1.00 COMPZN, CASING CIRC P Space out and Fill pipe 63stks (5.3bbls) Shear floatation sub 1218psi. Continue fill liner at 336gpm 2311stks (196bbls) PU: 230k SO: 140k 29,193.0 29,193.0 1/8/2023 18:30 1/8/2023 23:30 5.00 COMPZN, CASING CIRC P Continue circulate btms up at 29,193' MD at 181gpm 1000psi Max gas 3763 units 29,193.0 29,193.0 1/8/2023 23:30 1/9/2023 00:00 0.50 COMPZN, CASING CIRC P Drop 1.125" hanger setting ball and pump down at 121gpm 545psi 29,193.0 29,193.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 48/50 MT7-08 Report Printed: 1/26/2023 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) 1/9/2023 00:00 1/9/2023 03:15 3.25 COMPZN, CASING OTHR P Pump 1.125" setting ball down @ 121 gpm, Ball on seat at 2193 strokes. Once ball on seat pressure up t/ 2,300 psi, verify hanger was set, Pressure up t/ 4,400 psi to blow ball seat, Pressure continued to bled off, Trouble shoot surface equipment (No issues found) Attempt to pressure up 5th time to 2000psi and noticed returns at shakers. P/U string to 230k to confirm release from liner hanger. P/U string 230k expose dog sub, S/O rotating at 10rpm, witness shear @ 40k S/O to 124k.(60k on pkr) Verified w/ Baker rep that packer was set. Liner top: 13083' MD Shoe: 29,193' MD 29,193.0 29,193.0 1/9/2023 03:15 1/9/2023 04:15 1.00 COMPZN, CASING PRTS T Pressure test liner top with drill pipe open to atmosphere, pump at 0.5bpm to 3500psi. Pumped 7.2bbps, Pressure bled down 200psi/ 20 min. Attempt to pressure back up, Fluid leaking up drill string. Possible leak path above RS packoff/drill string. 29,193.0 29,193.0 1/9/2023 04:15 1/9/2023 05:00 0.75 COMPZN, CASING OTHR T Consult with town for path forward. 29,193.0 29,193.0 1/9/2023 05:00 1/9/2023 06:00 1.00 COMPZN, CASING OTHR T As Per Baker recommendations, Attempt tp reset Packer and retest. S/O with 20rpm 8k set 80k on Pkr, P/U and pressure test backside with drill string open to atmosphere to 3500psi, Fluid leaking up drill pipe to confirn down hole tool string leak. 29,193.0 29,193.0 1/9/2023 06:00 1/9/2023 06:30 0.50 COMPZN, WELLPR OTHR T Blow down surface equipment and pull string above liner top to 13,066' MD. 13,066.0 13,066.0 1/9/2023 06:30 1/9/2023 09:00 2.50 COMPZN, WELLPR CIRC P Circulate and displace well to 9.5 CI brine at 328gpm 620psi, 13,066.0 13,066.0 1/9/2023 09:00 1/9/2023 09:30 0.50 COMPZN, WELLPR OWFF P Blow down top drive and OWFF (Static) 13,066.0 13,066.0 1/9/2023 09:30 1/9/2023 12:00 2.50 COMPZN, WELLPR TRIP P POOH from 13,066' MD to 7,550' MD. 13,066.0 7,550.0 1/9/2023 12:00 1/9/2023 16:00 4.00 COMPZN, WELLPR TRIP P Continue POOH from 13,066' MD to 7,550' MD. 7,550.0 0.0 1/9/2023 16:00 1/9/2023 16:30 0.50 COMPZN, WELLPR OTHR P Inspect running tools. Visual damage on cup seals. Tools to be sent in for further inspection. 0.0 0.0 1/9/2023 16:30 1/9/2023 18:30 2.00 COMPZN, WELLPR SVRG P Pull rotary table cover, Clean and inspect bull gear and table dog sensor. 0.0 0.0 1/9/2023 18:30 1/9/2023 20:00 1.50 COMPZN, WELLPR SLPC P Slip and cut 103' Drill line. Calibrate block hight and function COM. 0.0 0.0 1/9/2023 20:00 1/9/2023 21:00 1.00 COMPZN, WELLPR CLEN P Clean and clear rig floor, Pull master bushings and install PS-21's 0.0 0.0 1/9/2023 21:00 1/9/2023 22:00 1.00 COMPZN, WELLPR TRIP P RIH with 4" drill pipe to 2464' MD. 0.0 2,464.0 1/9/2023 22:00 1/10/2023 00:00 2.00 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe from 2,464' MD to 947' MD. 2,464.0 947.0 1/10/2023 00:00 1/10/2023 01:00 1.00 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe from 947' MD to surface. 947.0 0.0 1/10/2023 01:00 1/10/2023 03:30 2.50 COMPZN, WELLPR TRIP P M/U 5" Mule shoe and TIH to 5.605' MD. 0.0 5,605.0 1/10/2023 03:30 1/10/2023 05:30 2.00 COMPZN, WELLPR PULD P POOH L/D 5" drill pipe from 5,605' MD to 4,815' MD. 5,605.0 4,815.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 49/50 MT7-08 Report Printed: 1/26/2023 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) 1/10/2023 05:30 1/10/2023 07:00 1.50 COMPZN, WELLPR TRIP P TIH with 5" drill pipe from 4,815' MD to 9,663' MD. 4,815.0 9,663.0 1/10/2023 07:00 1/10/2023 12:00 5.00 COMPZN, WELLPR PULD P POOH L/D 5" drill pipe from 9,663' MD to 4,920' MD. 9,663.0 4,920.0 1/10/2023 12:00 1/10/2023 17:30 5.50 COMPZN, WELLPR PULD P Continue POOH L/D 5" drill pipe from 4,920' MD to surface 4,920.0 0.0 1/10/2023 17:30 1/10/2023 19:00 1.50 COMPZN, WELLPR WWWH P Retrieve wear ring, M/U stack washer, Jet BOP stack 645gpm 130psi. 0.0 0.0 1/10/2023 19:00 1/10/2023 20:00 1.00 COMPZN, RPCOMP RURD P R/U 4.5" tubing running equipment. 0.8bph static losses 0.0 0.0 1/10/2023 20:00 1/10/2023 21:30 1.50 COMPZN, RPCOMP RCST P RIH w/ Baker index shoe, Self indexing mule shoe, 3.75" landing nipple, Halliburton production packer & Halliburton Opsis Mandrel w/ Down hole gauge (S/N OPS-002341) 0.0 360.0 1/10/2023 21:30 1/10/2023 22:00 0.50 COMPZN, RPCOMP PRTS P P/U HES downhole gauge assembly & test to 10,000psi. 5min Good test. CPAI witness 360.0 360.0 1/10/2023 22:00 1/11/2023 00:00 2.00 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 360' MD to 1,680' MD. Running TEC line and installing Cannon clamps every joint. Checking control line every 1000' MD. 360.0 1,680.0 1/11/2023 00:00 1/11/2023 06:00 6.00 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 1,680' MD to 6,194' MD. Running TEC line and installing Cannon clamps every joint. Checking control line every 1000' MD. 1,680.0 6,194.0 1/11/2023 06:00 1/11/2023 12:00 6.00 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 6,194' MD to 10,600' MD. Running TEC line and installing Cannon clamps every joint. Checking control line every 1000' MD. 6,194.0 10,600.0 1/11/2023 12:00 1/11/2023 16:00 4.00 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 10,600' MD to 13,083' MD. Running TEC line and installing Cannon clamps every joint. Checking control line every 1000' MD. Tagged up on locator sub, Confirm pace out measurements & laid down 3 joints of tubing 10,600.0 13,083.0 1/11/2023 16:00 1/11/2023 20:00 4.00 COMPZN, RPCOMP HOSO P Make up space out pups as per CPAI rep & Baker, Make up FMC tubing hanger & TEC wire through tubing hanger Pressure test splice t/ 5,000 psi f/ 10 minutes, Test witnessed by CPAI rep, Land hanger with 152K 2.17' MD form full locating. RILD, test top of hanger to 3,000psi 5 min. witnessed by CPAI rep 13,083.0 13,083.0 1/11/2023 20:00 1/11/2023 22:30 2.50 COMPZN, RPCOMP PRTS P Drop 1 5/16'' ball & rod, Pressure up tubing, set pkr and test tbg to 4,200 & hold for 30 minutes Bleed tubing down to 3,000 psi & bring pressure on IA to 4,200 psi & hold pressure for 30 minutes Bleed tubing to 0 psi, SOV sheared at 1900psi, Tubing & IA equalized & bled to 0 psi Observed IA for flow for 30 minutes, No flow 13,083.0 13,083.0 1/11/2023 22:30 1/12/2023 00:00 1.50 COMPZN, RPCOMP PRTS P Vac out BOP stack, Pull landing joint and install BPV, Pump down IA, Test BPV in direction of flow to 3,000psi 10min. Good test. 13,083.0 13,083.0 1/12/2023 00:00 1/12/2023 01:00 1.00 COMPZN, WHDBOP RURD P RD lines in cellar area. Blow down kill and injection lines. Clean Joe's box flush flow line, 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 Page 50/50 MT7-08 Report Printed: 1/26/2023 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) 1/12/2023 01:00 1/12/2023 04:00 3.00 COMPZN, WHDBOP NUND P LD 90' MH. ND MPD. RD choke/kill lines. ND stack and riser. Set BOP stack back. LD riser. SIMOPS: Cleaning mud pits. 0.0 0.0 1/12/2023 04:00 1/12/2023 06:00 2.00 DEMOB, MOVE NUND P Complete control line termination at WH. NU adapter flange.Test flange adapter to 5000psi for 5 minutes. Good test SIMOPS: Clean and clear rig floor, BD mud pump service liners and equipment. 0.0 0.0 1/12/2023 06:00 1/12/2023 09:00 3.00 DEMOB, MOVE NUND P N/U 5k tree, Filled tree w/ diesel and function valves to purge. R/U to test. Pressure tested tree from 250 psi low/5,000 psi high, CPAI witnessed. 0.0 0.0 1/12/2023 09:00 1/12/2023 15:00 6.00 DEMOB, MOVE FRZP P R/U service lines to LRS and test to 3,500psi, Pump 90 bbls diesel freeze protect down IA up tubing. FCP: 670psi at 1.86bpm. Static final pressure 200psi. U-Tube fluid 1hr final IA: 100psi, Tbg: 100psi. Secure well. Blow down and R/D service lines and equipment. SIMOPS: Perp rig for move to MT7-02 well. Rig release at 1500hrs -1-12-23 0.0 0.0 1/12/2023 15:00 1/12/2023 15:00 DEMOB, MOVE Drilling F/xxx to T/xxx md xx Psi xx SPP xx Psi xx SPP 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/12/2023 !"#$ # !"%&' 50-103-20846-00 () * ) +&# ) ", ) ) ) -) !" !"!#)## $ %& '()*+,"! -'. .) !"- )/) 0 ! )$ %& '()*+,"! -'. ) !" ! *) *) ( ! /) **)1 )+-/2$ . )+-331. 4 041 05!6 7 1 8 $ 1 88 $ $$ +.#) +#) 0 .) .) 102& 12& 3 #+) !" !,!! !,!! 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Page 1/1 MT7-08 Report Printed: 1/26/2023 Cement Cement Details Description Surface String Cement Cementing Start Date 12/5/2022 16:00 Cementing End Date 12/5/2022 20:30 Wellbore Name MT7-08 Comment SLB pump 5 bbls of fresh H2O. Tested lines to 500 psi low/ 3500 psi high, pump 100 bbls of 10.9 ppg Mud Push II @ 4.5 bbls/min, 320 psi, 16% F/O, Dropped bottom plug. Start batching lead. Pump 395 bbls of 11.0 ppg DeepCRETE cement at 4.8 bbls/min, 320 psi ICP, F/O 14%. Batch and pump 72 bbls of G Blend Tail 15.8 ppg cement @ 4.2 bbls/min, 450 psi, F/O 14%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg Ksi mud @ 8 bbls/min, 435 psi ICP, 700 psi FCP, F/O 51%. Slow pumps 20 bbls prior to calculated bump to 3 bbls/min, 360 psi ICP, Bump plug with 1000 psi (485 bbls + 20 bbls). 4005 strokes, final circ. PSI 370 Pressure up to 1000 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 144 bbls cement to surface. Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 38.2 Bottom Depth (ftKB) 3,458.6 Full Return? Yes Vol Cement … 144.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 7 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 8 P Pump Final (psi) 370.0 P Plug Bump (psi) 1,000.0 Recip? Yes Stroke (ft) 6.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 38.2 Est Btm (ftKB) 2,958.0 Amount (sacks) 1,155 Class Blend Volume Pumped (bbl) 395.0 Yield (ft³/sack) 1.92 Mix H20 Ratio (gal/sack) 6.74 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 143.0 Thickening Time (hr) 6.75 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,958.0 Est Btm (ftKB) 3,458.6 Amount (sacks) 346 Class G Volume Pumped (bbl) 72.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 5.07 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 80.0 Thickening Time (hr) 4.25 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 MT7-08 Report Printed: 1/26/2023 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 12/14/2022 21:30 Cementing End Date 9/15/2022 02:30 Wellbore Name MT7-08 Comment Line up cement unit. flush w/ 3 bbls FW. Test lines to 3650psi. Good test. Mix and pump 60bbls 12.5ppg mud push II at 4 bpm. SD and drop bottom plug. Mix and pump 160bbls 13 ppg G lead cement at 4.5 bpm, 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. Swap over to rig pumps. Displace cement at 6bpm 200psi 770bbls slow rate to 3bpm 939psi. Plug bumped @ 6747 stks (calculated stks6758). Pressure up to 1500psi. Check floats. Good. Cement in place @ 02:21hrs 12/15/22. Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 6,856.0 Bottom Depth (ftKB) 11,041.7 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 5 Q Pump Avg (bbl/…P Pump Final (psi) 960.0 P Plug Bump (psi) 1,500.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class G Volume Pumped (bbl) 73.2 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 10.27 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) Est Btm (ftKB) Amount (sacks) Class G Volume Pumped (bbl) 258.2 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 5.08 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 MT7-08 Report Printed: 1/26/2023 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 12/21/2022 09:00 Cementing End Date 12/21/2022 12:00 Wellbore Name MT7-08 Comment Line up cement unit. Pump 70 bbls KCL at 3 bpm. Drop bottom dart, SLB pumped 79 bbls 15.8 ppg slurry at 3 bpm. Drop top dart, pumped 20 bbls water behind. Rig chase w/ 3 bpm and dart landed at 985 stks & sheard at 880 psi, reduce rate to 2 bpm and dart landed at 1905 stks and sheared at 1619 psi. Bottom plug landed at 1995 stks and sheared at 821 psi. To plug landed at 2921 stks and pressure to 1200 psi, 2928 stks total, check floats--good. Cement in place at 12:00 hrs on 12/21/2022. Cement Stages Stage # 1 Description Intermediate String 2 Cement Objective Top Depth (ftKB) 11,560.0 Bottom Depth (ftKB) 13,244.0 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 3 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 3 P Pump Final (psi) 1,200.0 P Plug Bump (psi) 1,200.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 13,017.0 Est Btm (ftKB) 13,097.0 Amount (sacks) 353 Class G Volume Pumped (bbl) 79.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sack) 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 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Jan 17, 2023 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-08 /MT7-08PB1 Greater Mooses Tooth API #: 50-103-20846-00/ 50-103-20846-70 Permit No: 222-116 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. MT7-08 is located in a federal oil and gas unit. Only with respect to the MT7-08 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 By Meredith Guhl at 9:01 am, Jan 19, 2023 T37444 T37445- PB1 222-116 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.19 09:30:10 -09'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CDDirectional SurveyMT7-08 50-103-20846-00-00 222-116 GMTU MEMORY SonicScope TOC FINAL FIELD 1#REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!MT7-08 is located in a federal oil and gas unit. Only with respect to the MT7-08 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.Transmittal Receipt________________________________ X____________________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.VTuong@slb.comSLB Auditor -A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point.# Schlumberger-PrivateBy Meredith Guhl at 9:15 am, Jan 04, 2023222-116T37415Meredith GuhlDigitally signed by Meredith Guhl Date: 2023.01.04 09:15:53 -09'00' 1 Regg, James B (OGC) From:Rig 25 <rig25@doyondrilling.com> Sent:Friday, December 23, 2022 4:17 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; Greg.S.Hobbs@conocophillips.com; Ben Wedin; Bill Walter; Samuel Dye Subject:Doyon 25 BOP test 12-22-22 Attachments:Doyon 25 12-22-22 Test Sequence.docx; Doyon 25 12-22-22.xlsx; Test Chart #1 12-22-22.pdf; Test Chart #2 12-22-22.pdf; Test Chart #3 12-22-22.pdf 12‐22‐22 BOPE test report attached Chance Bali Rig 25 Tourpusher 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 Tootn Unit MT7-08PTD 2221160 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:12/22/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221160 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250 / 4000 Annular:250 / 2500 Valves:250 / 4000 MASP:3916 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 FP 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 FP Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 0 NA Full Pressure Attained (sec)97 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 / 2058 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 27 sec P #1 Rams 12 sec P Coiled Tubing Only:#2 Rams 15 sec P Inside Reel valves 0 NA #3 Rams 14 sec P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:7.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/17/2022 / 17:40 Waived By Test Start Date/Time:12/22/2022 5:00 (date)(time)Witness Test Finish Date/Time:12/22/2022 12:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Doyon Test annular 250/2500 w/ 5" and 4" test joint, Ram #1 and #3 w/ 5" and 4" test joint to 250/4000 psi f/ 5/10 min. Test ram #2 to 250/4000 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. Rig floor kill valve failed initial test. Replace valve seat. Retest good. Change out lower IBOP retest, good. BLM Sawyer Quinn waved witness. Everett Potter CPAI Lloyd Shirley GMTU MT7-08 Test Pressure (psi): rig25@doyondrilling.com d25cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1222_BOP_Doyon25_GMTU_MT7-08    ====4249 === === === ===     J. Regg; 5/23/2023 BOPE Test - Doyon 25 GMTU MT7-08 PTD 2221160 12/22/2022 BOPE Test - Doyon 25 GMTU MT7-08 PTD 2221160 12/22/2022 BOPE Test - Doyon 25 GMTU MT7-08 PTD 2221160 12/22/2022 MT7-08 12/22/2022 250 Low for 5 min – 4000 High for 10 min 5” Test Jt 1.Annular Preventer ( 250 low / 2500 high) 2.Upper 2 7/8” x 5 ½ VRB’s, Valves: # 1, 13, 14, 15, 4” Kill Valve. Upper IBOP 3.Valves: # 2, 10, 12, HCR kill 4.Valves: # 6,9 ,11, manual kill, 5” dart 5.Valves: # 5,7, 8 5” FOSV #1 6.Valves: #3, FOSV #2 7.Lower Pipe Rams 2 7/8” x 5 ½” VRB’s, 4” dart 8.Blind Rams, # 4, 4” FOSV #1 9.Super and manual choke 10.Annular 4” test joint 11.Upper VBR’s, HCR Choke, 4” FOSV#2 12.Manual Choke 13.Lower VBRs 14.Lower IBOP BOPE Test - Doyon 25 GMTU MT7-08 PTD 2221160 12/22/2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GMTU MT7-08 JBR 02/17/2023 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 5" test joint was used for testing. Test#2 the pen was lifted off the chart coming up to the high due to the guide pin being bent. The guide pin was fixed and the test was restarted at the high portion of the test. The blinds failed. The blinds were cycled and the air was purged again and they retested for a pass. Test Results TEST DATA Rig Rep:R. Fritz/N. WherleyOperator:ConocoPhillips Alaska, Inc.Operator Rep:J. Benedict/M. Tucker Rig Owner/Rig No.:Doyon 25 PTD#:2221160 DATE:12/6/2022 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC221203163706 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9 MASP: 3916 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8" x 5.5" P #2 Rams 1 Blind/Shear FP #3 Rams 1 2 7/8" x 5.5" P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1600 200 PSI Attained P15 Full Pressure Attained P96 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2091 ACC Misc NA P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P27 #1 Rams P12 #2 Rams P15 #3 Rams P14 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 FP MT7-08 12/6/2022 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, Manual Kill, 5” FOSV # 1 4.Valves: # 9 ,11, HCR Kill, 5” FOSV # 2 5.Valves: # 7, 8 & UIBOP 6.Valves: # 3 , 6, & LIBOP 7.Lower Pipe Rams 2 7/8” x 5 ½” VRB’s 8.Blind Rams, # 4, 5 9.Manual Choke Valve 10.HCR Choke Valve 11.Manually Operated & Super Choke ( 11A = Man Choke – 11B = Super) 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:McLellan, Bryan J (OGC) To:weifeng.dai@conocophillips.com; Hobbs, Greg S Cc:Loepp, Victoria T (OGC); Rixse, Melvin G (OGC); garrett.timmerman@conocophillips.com; steve.m.gieryic@conocophillips.com; Regg, James B (OGC) Subject:RE: [EXTERNAL]RE: GMT MT7-08 (PTD 222-116) Date:Monday, October 31, 2022 10:55:00 AM Weifeng, Conoco Phillips has approval to reduce BOP test pressure to 4000 psi based on the new estimate of reservoir pressure. Max bottomhole pressure of 10.8 ppg EMW @ 8484’ TVD = 4764 psi. MPSP = BHP minus 0.1 psi/ft gas gradient = 3916 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, October 31, 2022 9:42 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Fwd: [EXTERNAL]RE: GMT MT7-08 (PTD 222-116) Sent from my iPhone Begin forwarded message: From: "Dai, Weifeng" <Weifeng.Dai@conocophillips.com> Date: October 31, 2022 at 9:05:01 AM AKDT To: "Loepp, Victoria T (OGC)" <victoria.loepp@alaska.gov> Cc: "Timmerman, Garrett" <Garrett.Timmerman@conocophillips.com>, "Gieryic, Steve M" <Steve.M.Gieryic@conocophillips.com> Subject: RE: [EXTERNAL]RE: GMT MT7-08 (PTD 222-116) Morning Victoria, We confirmed with subsurface group (Reservoir Engineer and Petrophysicist copied) recently that in unlikely cases, the max PP is 10.8 ppg instead of 11.5 ppg as originally predicted Even IF the conduit extends from injector MT7-03 to MT7-08 heel, please see the attached note for details. In this case, the Maximum Potential Pressure on surface is 3,916 psi. With that been said, is it acceptable to test BOP to 4,000 psi instead of 4,500 psi as stated in the approved PTD? From: Dai, Weifeng Sent: Monday, October 24, 2022 10:26 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: GMT MT7-08 (PTD 222-116) Good morning Victoria, Just check in on MT7-08 permit. Looks like the well is going to be spud around the mid of November now, appreciate if you can prioritize it. Thanks again and let me know if any questions. From: Dai, Weifeng Sent: Wednesday, October 12, 2022 11:43 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]RE: GMT MT7-08 (PTD 222-116) Morning Victoria, Below is the excerpt I got from RE about 2 months ago. I just clarified with him that it is very unlikely that ~11.5 ppg PP will be encountered in MT7-08. The most likely range of PP is from 8.5-9.0 ppg. With that being said, I updated the cells in 401 form. I also updated the 7” liner cement calculation, thanks for catching and letting me know. Please let me know if any other questions or comments. Excerpt from RE email: “I expect MT7-08 to be normally pressured if that conduit from MT7-04 to MT7-06 does not extend to MT7-08. This would be ~8.9 to 9.0 ppg, or ~3800 psi. This range could extend from ~8.5 ppg on the low end, up to ~11.5 ppg on the high end if MT7-03 injection reached MT7-08 through that conduit. “ From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, October 12, 2022 11:07 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]RE: GMT MT7-08 (PTD 222-116) 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. Please check cement calculations for the 7” intermediate. From: Loepp, Victoria T (OGC) Sent: Wednesday, October 12, 2022 10:55 AM To: Dai, Weifeng (Weifeng.Dai@conocophillips.com) <Weifeng.Dai@conocophillips.com> Cc: Hobbs, Greg S (Greg.S.Hobbs@conocophillips.com) <Greg.S.Hobbs@conocophillips.com> Subject: GMT MT7-08 (PTD 222-116) Weifeng, The max reservoir pressure is listed at 5076 psig with a surface MPSP of 4249 psig on the 10-401 form. BOP test pressure is listed at 3500 psig. Please clarify. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov 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 &KULV%ULOORQ :HOOV(QJLQHHULQJ0DQDJHU &RQRFR3KLOOLSV$ODVND,QF 32%R[ $QFKRUDJH$ODVND 5H *UHDWHU0RRVHV7RRWK)LHOG5HQGH]YRXV2LO3RRO*708 07 &RQRFR3KLOOLSV$ODVND,QF 3HUPLWWR'ULOO1XPEHU 6XUIDFH/RFDWLRQ¶)6/¶):/6(6:6715(80 %RWWRPKROH/RFDWLRQ¶)6/¶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essie L. 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