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DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : GR / R E S / P W D / D I R / A Z I / D E N / N E U / C a l i p e r / P o r o s i t y / A c o u s t i c / N M R / N B I / S o n i c 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 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ A P - L O G _ T I M E _ M E M _ R U N 0 1 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ A P - L O G _ T I M E _ M E M _ R U N 0 2 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ A P - L O G _ T I M E _ M E M _ R U N 0 3 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ A P - L O G _ T I M E _ M E M _ R U N 0 4 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 21 1 2 1 9 1 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 - 05 _ F E _ M E M _ C O M P . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 21 2 2 1 9 1 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 - 05 _ V S S D E P T H _ M E M _ C O M P O S I T E . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ V S S T I M E _ M E M _ R U N 0 1 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ V S S T I M E _ M E M _ R U N 0 2 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ V S S T I M E _ M E M _ R U N 0 3 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 ### # # # # #### # # # # # 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 - 05 _ V S S T I M E _ M E M _ R U N 0 4 . l a s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ A P - LO G _ T I M E _ M E M _ R U N 0 1 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ A P - LO G _ T I M E _ M E M _ R U N 0 2 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ A P - LO G _ T I M E _ M E M _ R U N 0 3 . A S C 36 3 3 1 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 1 o f 1 3 CP A I _ M T 7 - , 05_ F E _ M E M _ CO MP . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ A P - LO G _ T I M E _ M E M _ R U N 0 4 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ V S S TI M E _ M E M _ R U N 0 1 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ V S S TI M E _ M E M _ R U N 0 2 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ V S S TI M E _ M E M _ R U N 0 3 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ V S S TI M E _ M E M _ R U N 0 4 . A S C 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 05 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 05 _ m e m _ L T K _ R 4 _ L M G 1 0 0 _ 0 2 4 0 s c l . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 05 _ m e m _ L T K _ R 4 _ L M G 1 0 0 . d l i s 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 2 M D _ M E M . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 2 T V D _ M E M . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 5 M D _ M E M . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 5 T V D _ M E M . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ M E M _ A P - L O G TI M E . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ M E M _ V S S DE P T H . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ M E M _ V S S TI M E . c g m 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 2 M D _ M E M . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 2 T V D _ M E M . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 5 M D _ M E M . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ 5 T V D _ M E M . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ M E M _ A P - L O G TI M E . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ M E M _ V S S DE P T H . p d f 36 3 3 1 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 2 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : C P A I _ M T 7 - 0 5 _ M E M _ V S S TI M E . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 2 7 _ C o m p a s s Su r e v e y s _ D e f i n i t i v e S u r v e y R e p o r t _ 0 1 2 4 2 0 2 2 . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 2 7 _ C o m p a s s Su r v e y s _ C a n v a s _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 2 7 _ C o m p a s s Su r v e y s _ M a c r o _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 2 7 _ C o m p a s s Su r v e y s _ P e t r e l _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 2 7 _ C o m p a s s Su r v e y s _ S u r v e y s _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 8 3 _ C o m p a s s Su r v e y s _ C a n v a s _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 8 3 _ C o m p a s s Su r v e y s _ D e f i n i t i v e S u r v e y Re r p o r t _ 0 1 2 4 2 0 2 1 1 . p d f 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 8 3 _ C o m p a s s Su r v e y s _ M a c r o _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 8 3 _ C o m p a s s Su r v e y s _ P e t r e l _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 2/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ N A D 8 3 _ C o m p a s s Su r v e y s _ S u r v e y s _ 0 1 2 4 2 0 2 2 . t x t 36 3 3 1 ED Di g i t a l D a t a DF 5/ 3 / 2 0 2 2 52 9 2 1 2 3 2 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 : CP A I _ G r e a t e r _ M o o s e s _ T o o t h _ M T 7 _ 0 5 _ S o n i c S c op e 4 7 5 _ R M _ T O C . l a s 36 5 4 7 ED Di g i t a l D a t a DF 5/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : RM _ S o n i c S c o p e _ T O C _ 1 _ 1 0 0 0 . p d f 36 5 4 7 ED Di g i t a l D a t a DF 5/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : R M _ S o n i c S c o p e _ T O C _ 1 _ 2 0 0 . p d f 36 5 4 7 ED Di g i t a l D a t a DF 5/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : RM _ S o n i c S c o p e _ T O C _ 1 _ 4 0 0 0 . p d f 36 5 4 7 ED Di g i t a l D a t a DF 5/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : R M _ S o n i c S c o p e _ T O C _ 1 _ 5 0 0 . p d f 36 5 4 7 ED Di g i t a l D a t a DF 5/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : RM _ S o n i c S c o p e _ T O C _ 1 _ 6 0 0 0 . p d f 36 5 4 7 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 4 0 1 5 3 9 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ 6 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 3 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 6/ 2 2 / 2 0 2 2 15 4 2 0 1 1 8 5 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ 6 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 3 4 1 5 3 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ 8 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 15 3 8 7 1 1 8 6 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ 8 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 0 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 : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ s s 1 1 8 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 1 6 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 : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ s s 1 2 1 5 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 2 1 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ s s 1 3 1 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 1 0 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ s s 1 4 0 5 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 1 0 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ s s 1 5 0 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 0 8 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e 0 . 3 _ s s 1 5 1 9 2 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 3 6 1 5 3 9 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ C h o k e d _ 1 - 3 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 6 9 3 1 7 7 6 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 5 3 1 5 6 5 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 : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ 0 6 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 15 6 4 1 1 1 8 3 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ 0 6 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 5 4 1 5 5 3 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ 0 8 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 15 5 2 6 1 1 8 3 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ 0 8 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 1 0 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ s s 1 1 8 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 0 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 : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ s s 1 2 1 5 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 1 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ s s 1 3 1 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 4 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 6/ 2 2 / 2 0 2 2 0 1 1 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ s s 1 4 0 5 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 1 0 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ s s 1 5 0 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 9 7 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ F l o w i n g _ s s 1 5 4 9 6 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 6 5 1 6 8 4 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t - i n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 5 1 1 1 9 6 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t I n _ 4 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 9 4 8 1 1 8 4 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t I n _ 4 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 6 4 1 6 8 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t I n _ 6 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 16 8 4 8 1 1 8 5 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t I n _ 6 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 11 8 6 6 1 6 6 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t I n _ 8 0 d w n . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 16 6 5 6 1 1 8 6 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ S h u t I n _ 8 0 u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 17 7 7 1 1 1 6 9 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 : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ 0 6 0 - u p . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 9 0 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 : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ s s 1 2 1 5 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 8 3 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ s s 1 3 1 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 7 9 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ s s 1 4 0 5 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 8 7 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ s s 1 5 0 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 1 0 0 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ s s 1 5 6 0 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 0 8 6 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ s s 1 7 7 3 0 . l a s 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ P P R O F _ 2 2 A P R 2 2 . p d f 36 7 2 8 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 5 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 6/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ i m g . t i f f 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 05 _ P P R O F _ 2 2 A P R 2 2 _ R e p o r t - V 1 . p d f 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 0 5 _ P P R O F _ 2 4 A P R 2 2 . p d f 36 7 2 8 ED Di g i t a l D a t a DF 6/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : M T 7 - 05 _ P P R O F _ 2 4 A P R 2 2 _ i m g . t i f f 36 7 2 8 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 11 3 9 9 1 5 7 9 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ b l f 8 0 d . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 15 9 0 3 1 1 4 3 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ b l f 8 0 u p . 2 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 11 4 6 2 1 5 3 3 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ f 8 0 d 1 . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 11 4 7 0 1 5 4 0 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ f 8 0 d 2 . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 15 3 4 2 1 1 4 6 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ f 8 0 u p 1 . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 15 4 1 2 1 1 4 9 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ f 8 0 u p 2 . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 11 4 2 7 1 6 1 9 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ s 8 0 d 1 . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 11 4 4 1 1 6 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ s 8 0 d 2 . 2 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 16 1 5 8 1 1 4 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ S 8 0 U p 1 . 1 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 16 2 2 2 1 1 4 5 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 : m t 7 - 0 5 _ 0 7 - A p r - 23 _ r u n 1 _ s 8 0 u p 2 . 2 . l a s 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : 2 0 2 3 - 0 4 - 0 7 _ 2 1 1 3 1 _ G M T U _ M T 7 - 05 _ T e m p e r a t u r e S u r v e y _ T r a n s m i t t a l . d o c x 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 5 _ 0 7 - A P r - 23 _ T e m p e r a t u r e S u r v e y . p d f 37 5 9 0 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : M T 7 - 0 5 _ 0 7 - A P r - 23 _ T e m p e r a t u r e S u r v e y . t i f 37 5 9 0 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 9 4 1 7 2 3 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ 2 2 7 0D o w n l o g _ P P R O F _ T T i x _ _ L o g _ 1 1 _ D o w n . l a s 38 4 2 4 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 6 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 1/ 1 9 / 2 0 2 4 11 5 7 8 1 7 6 6 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ R e p ea t - D o w n l o g _ P P R O F _ T T i x _ _ L o g _ 1 3 _ D o w n . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 5 6 8 1 7 2 6 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ U p l og _ P P R O F _ T T i x _ _ L o g _ 1 2 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 2 4 1 7 6 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 : C P A I _ M T 7 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 8 0 F P M _ R e p ea t - U p l o g _ P P R O F _ T T i x _ _ L o g _ 1 4 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 9 4 1 7 2 3 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ D o wn l o g _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 1 1 _ D o w n . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 5 7 8 1 7 6 6 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ R e p ea t - Do w n l o g _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 1 3 _ D o w n . l as 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 2 4 1 7 6 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 : C P A I _ M T 7 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ R e p ea t - U p l o g _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 1 4 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 5 6 8 1 7 2 6 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 8 0 F P M _ U p l og _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 1 2 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 54 1 8 0 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 40 F P M _ D o w n _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 2 _ D o wn . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 54 0 8 0 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 40 F P M _ U p _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 3 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 54 0 8 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 60 F P M _ D o w n _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 4 _ D o wn . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 54 0 8 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 60 F P M _ U p _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 5 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 7 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 1/ 1 9 / 2 0 2 4 54 0 8 0 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 80 F P M _ D o w n _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 6 _ D o wn . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 53 8 8 0 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 80 F P M _ U p _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 7 _ U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 2 2 1 7 6 5 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ S h u t - In _ 4 0 F P M _ D o w n l o g _ S h u t - I n _ D o w n l o g . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 1 2 1 7 6 7 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ S h u t - In _ 6 0 F P M _ U p l o g _ R u n _ 1 _ P P R O F _ T T i x _ _ L o g _ 1 8 _U p . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 10 3 6 9 1 1 8 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 - 05 _ S C M T _ 2 5 D E C 2 1 _ M a i n _ 3 0 F P M _ C o n C u _ R 0 2 _L 0 0 6 U p _ S C M T _ P S T P _ E R S . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 2 5 8 1 1 8 5 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 - 05 _ S C M T _ 2 5 D E C 2 1 _ R e p e a t _ 3 0 F P M _ C o n C u _ R 02 _ L 0 0 3 U p _ S C M T _ P S T P _ E R S . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 10 3 5 1 1 2 2 2 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 - 05 _ S C M T _ 2 7 D E C 2 1 _ M a i n _ 3 0 F P M _ C o n C u _ R 0 2 _L 0 1 3 U p _ S C M T _ P S T P _ E R S . l a s 38 4 2 4 ED Di g i t a l D a t a DF 1/ 1 9 / 2 0 2 4 11 6 6 6 1 2 2 8 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ S C M T _ 2 7 D E C 2 1 _ R e p e a t _ 3 0 F P M _ C o n C u _ R 02 _ L 0 1 1 U p _ S C M T _ P S T P _ E R S . l a s 38 4 2 4 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ 2 2 7 0D o w n l o g _ C o n C u _ R 0 1 _ L 0 1 1 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ R e p ea t - D o w n l o g _ C o n C u _ R 0 1 _ L 0 1 3 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ U p l og _ C o n C u _ R 0 1 _ L 0 1 2 U p . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 1 9 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 8 0 F P M _ R e p ea t - U p l o g _ C o n C u _ R 0 1 _ L 0 1 4 U p . d l i s 38 4 2 4 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 8 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ D o wn l o g _ C o n C u _ R 0 1 _ L 0 1 1 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ R e p ea t - D o w n l o g _ C o n C u _ R 0 1 _ L 0 1 3 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 4 0 F P M _ R e p ea t - U p l o g _ C o n C u _ R 0 1 _ L 0 1 4 U p . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ 8 0 F P M _ U p l og _ C o n C u _ R 0 1 _ L 0 1 2 U p . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 40 F P M _ D o w n _ C o n C u _ R 0 1 _ L 0 0 2 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 40 F P M _ D o w n _ C o n P r _ R 0 1 _ L 0 0 2 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 60 F P M _ D o w n _ C o n C u _ R 0 1 _ L 0 0 4 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 60 F P M _ U p _ C o n C u _ R 0 1 _ L 0 0 5 U p . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 80 F P M _ D o w n _ C o n C u _ R 0 1 _ L 0 0 6 D o w n . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ 2 2 7 0 B O P D _ C a l i b r a t i o n _ 80 F P M _ U p _ C o n C u _ R 0 1 _ L 0 0 7 U p . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ S h u t - In _ 4 0 F P M _ D o w n l o g _ C o n C u _ S h u t - In _ D o w n l o g . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ S h u t - In _ 6 0 F P M _ U p l o g _ C o n C u _ R 0 1 _ L 0 1 8 U p . d l i s 38 4 2 4 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 - 05 _ P P R O F _ 2 0 A p r 2 0 2 3 _ F i e l d - P r i n t . P d f 38 4 2 4 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 9 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No 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 - 05 _ S C M T _ 2 5 D E C 2 1 _ M a i n _ 3 0 F P M _ C o n C u _ R 0 2 _L 0 0 6 U p _ S C M T _ P S T P _ E R S . d l i s 38 4 2 4 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 - 05 _ S C M T _ 2 5 D E C 2 1 _ R e p e a t _ 3 0 F P M _ C o n C u _ R 02 _ L 0 0 3 U p _ S C M T _ P S T P _ E R S . d l i s 38 4 2 4 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 - 05 _ S C M T _ 2 7 D E C 2 1 _ M a i n _ 3 0 F P M _ C o n C u _ R 0 2 _L 0 1 3 U p _ S C M T _ P S T P _ E R S . d l i s 38 4 2 4 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 - 05 _ S C M T _ 2 7 D E C 2 1 _ R e p e a t _ 3 0 F P M _ C o n C u _ R 02 _ L 0 1 1 U p _ S C M T _ P S T P _ E R S . d l i s 38 4 2 4 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 - 05 _ S C M T _ 2 5 D E C 2 1 _ P R I N T . P d f 38 4 2 4 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 4 5 6 1 8 1 1 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 3 0 F P M _ D o w n - R e p e a t . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 4 6 6 1 7 1 7 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 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 3 0 F P M _ D o w n _ T T i X _ P P R O F _ _ L o g _ 1 2 _ D o w n_ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 5 0 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 4 4 7 1 7 1 9 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 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 4 0 F P M _ U p _ T T i X _ P P R O F _ _ L o g _ 1 6 _ U p _ 1 _ __ 1 8 J u n 2 4 _ 2 3 4 9 0 2 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 3 9 4 1 8 1 1 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 8 0 F P M _ U p _ T T i X _ P P R O F _ _ L o g _ 1 8 _ U p _ 1 _ __ 1 8 J u n 2 4 _ 2 3 4 9 1 3 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 86 9 1 1 0 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 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 1 2 0 F P M _ D o w n _ T T i X_ P P R O F _ _ L o g _ 7 _ D o w n _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 3 2 . la s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 89 1 1 1 0 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 1 2 0 F P M _ U p _ T T i X _ PP R O F _ _ L o g _ 6 _ U p _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 2 9 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 88 9 1 1 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 4 0 F P M _ T T i X _ P P R OF _ _ L o g _ 3 _ D o w n _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 1 3 . l a s 39 3 5 1 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 1 0 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No DF 8/ 2 / 2 0 2 4 89 2 1 1 0 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 4 0 F P M _ U p _ T T i X _ P PR O F _ _ L o g _ 2 _ U p _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 1 1 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 89 0 1 1 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 8 0 F P M _ D o w n _ T T i X _P P R O F _ _ L o g _ 5 _ D o w n _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 2 3 . l as 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 89 1 1 1 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 8 0 F P M _ U p _ T T i X _ P PR O F _ _ L o g _ 4 _ U p _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 8 1 7 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 3 8 6 1 8 1 4 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 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 3 0 F P M _ D o w n - Re p e a t _ T T i X _ P P R O F _ _ L o g _ 2 1 _ D o w n _ 1 _ _ _ 1 8 J u n2 4 _ 2 3 4 9 4 9 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 3 5 7 1 8 0 8 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 3 0 F P M _ D o w n _ C o n C u_ T T i X _ P P R O F _ _ L o g _ 1 9 _ D o w n _ 1 _ _ _ 1 8 J u n 2 4 _ 23 4 9 3 7 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 4 0 2 1 8 1 5 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 6 0 F P M _ U p _ T T i X _ P P RO F _ _ L o g _ 2 0 _ U p _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 9 4 3 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 11 4 3 4 1 8 1 2 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 8 0 F P M _ U p _ T T i X _ P P RO F _ _ L o g _ 2 2 _ U p _ 1 _ _ _ 1 8 J u n 2 4 _ 2 3 4 9 5 3 . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 45 4 6 1 4 5 4 6 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 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S t a b i l i z a t i o n - S t a t i o n . l a s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 3 0 F P M _ D o w n - Re p e a t _ C o n C u _ R 0 1 _ L 0 1 7 D o w n . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 3 0 F P M _ D o w n _ C o n C u _ R 0 1 _ L 0 1 2 D o w n . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 4 0 F P M _ U p _ C o n C u _ R 0 1 _ L 0 1 6 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ 7 M M S C F D - Ga s _ 8 0 F P M _ U p _ C o n C u _ R 0 1 _ L 0 1 8 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 1 1 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 1 2 0 F P M _ D o w n _ C o n Cu _ R 0 1 _ L 0 0 7 D o w n . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 1 2 0 F P M _ U p _ C o n C u_ R 0 1 _ L 0 0 6 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 4 0 F P M _ D o w n _ C o n Cu _ R 0 1 _ L 0 0 3 D o w n . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 4 0 F P M _ U p _ C o n C u _R 0 1 _ L 0 0 2 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 8 0 F P M _ D o w n _ C o n Cu _ R 0 1 _ L 0 0 5 D o w n _ . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ C A L 8 0 F P M _ U p _ C o n C u _R 0 1 _ L 0 0 4 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 3 0 F P M _ D o w n - Re p e a t _ C o n C u _ R 0 1 _ L 0 2 1 D o w n . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 3 0 F P M _ D o w n _ C o n C u_ R 0 1 _ L 0 1 9 D o w n . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 6 0 F P M _ U p _ C o n C u _ R0 1 _ L 0 2 0 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S I _ 8 0 F P M _ U p _ C o n C u _ R0 1 _ L 0 2 2 U p . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ S t a b i l i z a t i o n - St a t i o n _ C o n C u _ R 0 1 _ S t a 0 0 2 . d l i s 39 3 5 1 ED Di g i t a l D a t a DF 8/ 2 / 2 0 2 4 E l e c t r o n i c F i l e : C P A I _ M T 7 - 05 _ P P R O F _ 1 8 J u n 2 0 2 4 _ F i e l d P r i n t . p d f 39 3 5 1 ED Di g i t a l D a t a Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 1 2 o f 1 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 0 3 - 2 0 8 3 3 - 0 0 - 0 0 We l l N a m e / N o . G M T U M T 7 - 0 5 Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 1/ 1 7 / 2 0 2 2 Pe r m i t t o D r i l l 22 1 0 8 7 0 Op e r a t o r C o n o c o P h i l l i p s A l a s k a , I n c . MD 21 9 1 6 TV D 82 9 6 Cu r r e n t S t a t u s 1- O I L 4/ 1 0 / 2 0 2 5 UI C No 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 7 / 2 0 2 2 Re l e a s e D a t e : 11 / 3 / 2 0 2 1 Th u r s d a y , A p r i l 1 0 , 2 0 2 5 AO G C C Pa g e 1 3 o f 1 3 M. G u h l 4/ 1 0 / 2 0 2 5 Originated: `§1 600 E 57th Place Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: TRANSMITTAL DATE31-Ju424 Alaska Oil & Gas Conservation Commis 37JUITA-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 MT7-93 50-103-20866-00.00 ICE ORDE4� 223-099 DESCRIPTION Greater Mooses Tooth SERVICE WL DELIVERABLE TTiX PPROF FINAL FIELD r 11-Jun-24 r MT7-05 50-103-20833-00.00 227-087 Greater Mooses Tooth WL TTiX PPROF FINAL FIELD 18-Jun-24 MT7-96 1 50-103-20834-00-00 1 221-100 Greater Mooses Tooth WL TTiX PPROF I FINAL FIELD 21-Jun-24 2N-347 1 50-103-20337-00-00 1 200-063 Kupamk River WL LDL I FINAL FIELD 17-Jul-24 T3935O T39351 T39352 T39353 'mittal Receipt Digitally signed by Gavin p Gavin Gluyas Gl"y" A Delivery Receipt signature confirms that a package (box, envelope, Dzte:3024A8.020833,16 etc.) has been received. The package will be handled/delivered per X -Us W standard company reception procedures. The package's contents hai Name Signature Date not been verified but should be assumed to contain the above noted media. e return via courier or sign/scan and email a copy to Schlumberger. 50lu mberger-Private 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 Moose's Tooth MT6-08 50-103-20772-00 218048_MT6-08_JetCutter_22Apr2022 218048_MT6-08_Puncher_02Feb2022 MT6-09 50-103-20779-00 218134_MT6-09_Puncher_18Feb2022 218134_MT6-09_SBHP_16Feb2022 218134_MT6-09_Tubing Cut_22Feb2022 MT7-01 50-10-320832-00 221052_MT7-01_Perf_29Oct2022 221052_MT7-01_PPROF_03Feb2023 MT7-02 50-103-20840-00 222026_MT7-02_ChemCut_21Dec2022 222026_MT7-02_Plug&Perf_17Apr2023 MT7-03 50-103-20830-00 221024_MT7-03_GR_12Aug23 221024_MT7-03_MechCutter_31Oct23 221024_MT7-03_RBP_1Nov23 MT7-05 50-103-20833-00 221087_MT7-05_PPROF_20Apr2023 221087_MT7-05_SCMT_25Dec2021 MT7-06 50-103-20831-00 221048_MT7-06_IBC-DSLT_04Oct2022 1of 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 T38419 T38420 T38421 T38422 T38423 T38424 T38425 2/29/2024 MT7-05 50-103-20833-00 221087_MT7-05_PPROF_20Apr2023 221087_MT7-05_SCMT_25Dec2021 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:56:14 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-07_21131_GMTU_MT7-05_TemperatureSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21131 GMTU MT7-05 50-103.-20833-00 Temperature Survey 07-Apr-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:221-087 T37590 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 11:42:29 -08'00' Originated:Delivered to:20-Jun-22HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAMEJOB TYPEDATA TYPE LOGGING DATE PRINTS #DIGITAL #1 MT7-05 50-103-20833-00 n/aGreater Mooses ToothProduction Profile Field & Processed 22-Apr-22 0 123MT7-05 is located in a federal oil and gas unit. Only with respect to the MT7-05 Well Data,PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date: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). Transmittal #1304 Detail Date: 5/2/2022 To (External Party): From (CPAI Contact): Email*: meredith.guhl@alaska.gov Email*: richard.e.elgarico@conocophillips.com First Name*: Meredith First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone Number:(907) 793-1235 Phone Number: (907) 265-6580 Company: AOGCC Company: ConocoPhillips Address: 333 W. 7th Ave. Address: 700 G Street City: Anchorage City: Anchorage State: AK State: Alaska Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: ShareFile Tracking #: Justification: Compliance Data Detail Quantity*: Description*: Type*: 1 CD5-93 Sonic TOC LAS, PDF 1 MT7-01 Sonic TOC LAS, PDF 1 MT7-03 Sonic TOC LAS, PDF 1 MT7-04 Sonic TOC LAS, PDF 1 MT7-05 Sonic TOC LAS, PDF 1 MT7-09 Sonic TOC LAS, PDF 1 MT7-96 Sonic TOC LAS, PDF Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ MT7-05 Sonic TOC PTD:221-087 T36547 Kayla Junke Digitally signed by Kayla Junke Date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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: 9. Ref Elevations: KB: 17. Field / Pool(s): GL:100.8 BF: Total Depth: 4355' FSL, 2642'FWL S36 T10N R1E UM 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: GR, RES, PWD, DIR, AZI, DEN, NEU, CALIPER, POROSITY, ACOUSTIC, NMR, NBI, SONIC, Mud 23. BOTTOM 20" H-40 120 10 yrds 13 3/8" L-80 3,061' 9 5/8" L-80 7,483' 7" L-80 8,298' 4.5" L-80 8,300' 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 16" 42" BOTTOM 40'40' 3,515' 10,566' 37 12 1/4" Tail: 42bbls of 15.8ppg Class G STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 1/17/2022 221-087/321-632 50-103-20833-00-00 284584 GMTU MT7-05 AA081800, AA081781, AA081803, AA081784 977' FSL, 1877' FWL, S32 T10N R2E UM 932535000, 932516000. 932538000, 932519000 12/3/2021 21,916'MD/8296'TVD N/A P.O. Box 100360, Anchorage, AK 99510-0360 5915800 CASING WT. PER FT. 289955 Top of Productive Interval: 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, 1/6/2022 980'MD/980'TVD SETTING DEPTH TVD TOP N/A 68 120' AMOUNT PULLED 140.2 280397 TOP SETTING DEPTH MD 40' 40' 5910953 5919450 94 CASING, LINER AND CEMENTING RECORD GRADE PRODUCTION TEST HOLE SIZE ACID, FRACTURE, CEMENT SQUEEZE, ETC. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Lead: 490bbls of 11ppg Deep Crete Tail: 69bbls of 15.8ppg Class G CEMENTING RECORD 11,442'MD/7985'TVD SIZE DEPTH SET (MD) Per 20 AAC 25.283 (i)(2) attach electronic information 12.6 7,982' PACKER SET (MD/TVD) TUBING RECORD 9 7/8"11,435' 20,782' 4.5" 11,340'MD/7,934TVD 3401 73136826 2/1/2022 Date of Test: Oil-Bbl: Choke Size:Water-Bbl: 41212501797 2/1/2022-02/09/2022 198 Flow Tubing N/A 37.4 Oil-Bbl:Water-Bbl: 107160329 Gas lifted producer flowback Perfed Pups/Liner @11,435'MD/ 7,982'TVD to 20,782'MD/8,300'TVD 56311 Gas-Oil Ratio: 1262' FSL, 1791' FWL, S6 T9N R2E UM Sr Res EngSr Pet GeoSr Pet Eng 100 Greater Mooses Tooth/Rendevous Pool Tail: 52bbl 15.8 Class G26 10,402' 12,252' 7,378' 9 7/8" 43.5 37' WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 7:34 am, Feb 16, 2022 Completion Date 1/17/2022 MDG RBDMS 2/16/2022 MDG No mudlogs see email 5/31/2022 GDSR-2/16/22DLB 04-20-2022 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 980 980 C40 1086 1085 1419 1411 2043 1996 3419 3008 4450 3619 4748 3806 HRZ 10547 7470 N/A 10647 7533 LCU/Miluveach 10842 7655 Top of Productive Interval (Alpine C):12303 8310 Formation at total depth (TD): Alpine C 21916 8176 31. List of Attachments: Cement Report, Directional Survey, Well Schematic, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Celie Hull Contact Email:cecilia.hull@conocophillips.com Authorized Contact Phone:907-263-4754 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 summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS 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, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. C30 Albian 97 Kalubik C10 K-3 INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: Jenna Taylor Senior Wells Analyst 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. 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. Albian 96 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). 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. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, 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). No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Jenna Taylor DN: C=US, CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.comReason: I am the author of this document Location: your signing location here Date: 2022.02.15 11:29:26-09'00'Foxit PDF Editor Version: 11.0.0 Tubing / Liner Completion: 1) 4-½” ‘X’ Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG 4-5 GLM (3x) 3) HES Opsis Downhole Gauge 4) Baker Premier Production Packer 5) 4-½” ‘DB” Landing Nipple (3.75" ID) w/ RHC Plug Body 6) Baker ZXP Liner Top Packer / Flex-Lock Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner Non-Stimulated frac: 11,877' MD Swell #5: 12,218' MD Non-Stimulated Frac Sleeve: 12,685' MD Swell #4: 13,148' MD Stimulated Frac Sleeve #3: 13,660' MD Swell #3: 14,122' MD Stimulated Frac Sleeve #2: 14,593' MD Swell #2: 15,094' MD Stimulated Frac Sleeve #1: 15,565' MD Swell #1: 16,065' MD 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-3/16” Production Hole TD at 21,916' MD / 8,296' TVD Tubing 4-1/2" 12.6# L-80 Hyd563 MT7-05 GLGL X GLGL GLGL 1/17/2022 MEW Production Packer 11,340' MD / 7,934' TVD DHG 16" Surface Hole Surface Casing 13-3/8" 68# L-80 Hyd563 set at 3,515' MD / 3061' TVD 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7" 26# L-80 Hyd563 to 11,195' MD X 7" 29# TN-110SS Hyd563 (Special drift to 6.125") Liner top at 10,401' MD / 7,377' TVD Shoe at 12,252' MD / 8,298' TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8" 43.5# L-80 TXP & 9-7/8" 62.8 Hyd523 Set at 10,566' MD / 7,482' TVD Top HRZ 10,546' MD / 7,470' TVD 4-String Northern Producer Final Schematic Top Alpine D 12,158' MD / 8,271' TVD Estimated Int1 TOC 10,066' MD / 7,158' TVD Evaluated Int2 TOC 11,900' MD / 8,185' TVD Liner Top Packer 11,435' MD / 7,982' TVD Top Alpine C 12,302' MD / 8,310' TVD SP #1SP #2SP #3SP #4 SP #5 FS #1FS #2FS #3FS #4 FS #5 DHG 10,338' MD / 7,337' TVD Page 1/50 MT7-05 Report Printed: 2/1/2022 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) 11/29/2021 09:00 11/29/2021 10:30 1.50 MIRU, MOVE DMOB P Pin well house, Blow down steam lines t/ BOP deck, Remove equipment f/ well house, Remove mud lines f/ pump t/ pit complexes 0.0 0.0 11/29/2021 10:30 11/29/2021 12:00 1.50 MIRU, MOVE DMOB P Remove saver sub, Lower IBOP, & Upper IBOP, Clean & inspect TDS quill, Inspect and measure load collar 0.0 0.0 11/29/2021 12:00 11/29/2021 15:00 3.00 MIRU, MOVE DMOB P C/O hydraulic tank bladder on TDS 0.0 0.0 11/29/2021 15:00 11/29/2021 17:30 2.50 MIRU, MOVE DMOB T Perform annual inspections on accumulator electrical box. Inspect all expansion boots, replace boot on jet pump. PMs in pipeshed.crane/skate and conveyor. 0.0 0.0 11/29/2021 17:30 11/29/2021 18:30 1.00 MIRU, MOVE DMOB T CO link tilt cylinder on top drive. 0.0 0.0 11/29/2021 18:30 11/29/2021 20:15 1.75 MIRU, MOVE DMOB T Install upper and lower IBOPs and change out saver sub on top drive. 0.0 0.0 11/29/2021 20:15 11/29/2021 22:00 1.75 MIRU, MOVE DMOB T Cut/slip 110' of drill line. 0.0 0.0 11/29/2021 22:00 11/30/2021 00:00 2.00 MIRU, MOVE DMOB T Inspect demco valves in pump room. CO valve on MP #1. CO swabs and liners to 6 1/2" 0.0 0.0 11/30/2021 00:00 11/30/2021 06:00 6.00 MIRU, MOVE DMOB T Prep derrick to scope down. Install bridal yoke and secure blocks. Perform derrick inspection. Change out swab and liner on MP #2. 0.0 0.0 11/30/2021 06:00 11/30/2021 10:00 4.00 MIRU, MOVE DMOB T C/O Swabs & liners t/ 6.5'' on mud pump #2, Replace pop offs on both pumps, Pop offs set @ 4300 psi, Replace lower pipe rams, Complete BWM 0.0 0.0 11/30/2021 10:00 11/30/2021 13:00 3.00 MIRU, MOVE DMOB P Bridal up t/ scope derrick, Remove Geolog tools and equipment f/ pits, Build heating tents around pipe shed, pump, & pits modules. Install air heaters in tents to warm up hydraulics, Blow down steam lines t/ BOP deck, pits, & lower pit room 0.0 0.0 11/30/2021 13:00 11/30/2021 15:00 2.00 MIRU, MOVE DMOB P Scope derrick down, pin TDS t/ derrick, tie off drill line t/ spool 0.0 0.0 11/30/2021 15:00 11/30/2021 18:30 3.50 MIRU, MOVE DMOB P Blow down steam to rig floor. Starp down energy track on derrick. Secure bails on top drive. Pull back and secure roof on on sub. Raise C-section and pin. Lower cattle chute. 0.0 0.0 11/30/2021 18:30 11/30/2021 19:45 1.25 MIRU, MOVE DMOB P PJSM. Skid rig floor. Extend cylinders to lay derrick over. SimOps: Move motor complex. 0.0 0.0 11/30/2021 19:45 11/30/2021 22:30 2.75 MIRU, MOVE DMOB P Lay over derrick. SimOps: Stomp pump and pit complex. 0.0 0.0 11/30/2021 22:30 12/1/2021 00:00 1.50 MIRU, MOVE DMOB P Unpin pipeshed/sub. Stomp pipeshed away from sub. Level Pad to lay mats f/ pump complex. 0.0 0.0 12/1/2021 00:00 12/1/2021 06:00 6.00 MIRU, MOVE DMOB P Level pad f/ pump complex.Stomp sub out from MT7-01 well. Prep pad and matting boards f/ sub. Crew members swapping out with each other taking breaks to warm up. 0.0 0.0 12/1/2021 06:00 12/1/2021 12:00 6.00 MIRU, MOVE MOB P Walk sub complex in place over MT7- 05, COPA & Doyon verfied rig over center of well & level 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 2/50 MT7-05 Report Printed: 2/1/2022 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) 12/1/2021 12:00 12/1/2021 17:30 5.50 MIRU, MOVE MOB P Walk pipe shed in place & pin to sub, walk pits, pumps, & engine complex t/ sub & pin same together, Walk casing shed over t/ sub complex & pin together, Spot ball mill in place w/ Peak trucks 0.0 0.0 12/1/2021 17:30 12/1/2021 18:30 1.00 MIRU, MOVE MOB P PJSM. Raise derrick and retract derrick cylinders. Walking pit complex. 0.0 0.0 12/1/2021 18:30 12/1/2021 21:00 2.50 MIRU, MOVE MOB P Prep and skid rig floor. Install handrails and grating to rig floor. Secure rig floor doors. Lower Csection. Prep to raise cattle chute. 0.0 0.0 12/1/2021 21:00 12/1/2021 23:00 2.00 MIRU, MOVE MOB P RAise cattle chute. Spot and shim pit and pump complex. Connect power cables to pit and pump complex. 0.0 0.0 12/1/2021 23:00 12/2/2021 00:00 1.00 MIRU, MOVE MOB P Raise backend of cattle chute. Connect power lines in pits and pump room. Connect derrick counter weight and descent line. 0.0 0.0 12/2/2021 00:00 12/2/2021 06:00 6.00 MIRU, MOVE MOB P Spot Ball Mill. Hook up all interconnectiong lines. Prep to scope up derrick. PJSM. Scope derrick up, Unbridal and tie back lines, Lower derrick ladder, plug in upper section of derrick lights. SIMOPS- hook up pit lines Rig accepted @ 09:00 on 12/2/21 0.0 0.0 12/2/2021 06:00 12/2/2021 08:30 2.50 MIRU, MOVE MOB P Connect steam in the BOP deck, lower tank room, & pits Function test pipe skate & conveyor 0.0 0.0 12/2/2021 08:30 12/2/2021 12:00 3.50 MIRU, MOVE NUND P PJSM, P/U starting head, diverter T, & riser & install same on well head, Install 4'' conductor valves, P/U 17' surface riser, Nipple up diverter bad, Install flow box, hook up fill up lines & jet lines, Install turn buckles on riser SIMOPS- Swap rig to high line power 0.0 0.0 12/2/2021 12:00 12/2/2021 16:30 4.50 MIRU, MOVE NUND P MU 17' surface riser. NU surface bag and riser. Install flow box. MU fowline, jetlines, hole fill lines. Install turnbuckles. 0.0 0.0 12/2/2021 16:30 12/2/2021 17:30 1.00 MIRU, MOVE BHAH P Install master bushings. Bring up BHA #1 tools to rig floor. Load pipeshed w/ BHA #1. 0.0 0.0 12/2/2021 17:30 12/2/2021 18:45 1.25 MIRU, MOVE BHAH P Rack back 5" HWDP and jars. 0.0 0.0 12/2/2021 18:45 12/2/2021 20:00 1.25 MIRU, MOVE BHAH P PJSM. MU and RIH w/ BHA #1 to 90'. 0.0 90.0 12/2/2021 20:00 12/2/2021 21:00 1.00 MIRU, MOVE CIRC P Flood lines and pressure test to 3500psi. Good test. 90.0 90.0 12/2/2021 21:00 12/2/2021 21:30 0.50 MIRU, MOVE SVRG P Service Rig. 90.0 90.0 12/2/2021 21:30 12/2/2021 23:30 2.00 MIRU, MOVE CIRC T Attempt to circulate w/ mud pumps. not getting fluid Troubleshoot line ups. Pit room control board issue. Repair and retest lines to 3500psi for precaution. 90.0 90.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 3/50 MT7-05 Report Printed: 2/1/2022 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) 12/2/2021 23:30 12/3/2021 00:00 0.50 SURFAC, DRILL WASH P Wash down and tag @ 105'. Drill 16" surface hole f/ 105' to 125' WOB 5-6k GPM 400 PSI 546 RPM 50 Bit hrs- .2 90.0 125.0 12/3/2021 00:00 12/3/2021 01:15 1.25 SURFAC, DRILL DDRL P Drill 16" hole f/ 125' to 279' WOB 5-6k GPM-450-500 PSI- 785-945 RPM - 50 TQ On bttm-4k ft/lbs TQ Off bttm- 1.5k ft/lbs Mud Wt. 10.5 ppg Bit hrs - 125.0 279.0 12/3/2021 01:15 12/3/2021 02:30 1.25 SURFAC, DRILL TRIP P Circulate hole clean while pulling 1 std. TOOH to bit. Clean clays off of stabilizer and bit. Scribe motor. 279.0 0.0 12/3/2021 02:30 12/3/2021 05:30 3.00 SURFAC, DRILL BHAH P Continue MU BHA#1 and and RIH. Plug into MWD/Gyro and synchronize TF. Wash down 249' to 279' for precaution. 0.0 279.0 12/3/2021 05:30 12/3/2021 06:00 0.50 SURFAC, DRILL DDRL P Drill 16" surface hole 279' to 300' WOB 5-6k GPM-500 PSI- 945 RPM - 50 TQ On bttm-4k ft/lbs TQ Off bttm- 1.5k ft/lbs Mud Wt. 10.5 ppg Bit hrs - 279.0 300.0 12/3/2021 06:00 12/3/2021 12:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/300' t/ 900' WOB 5-6k GPM-775 PSI- 2753 RPM - 50 TQ On bttm-4k ft/lbs TQ Off bttm- 1.5k ft/lbs Mud Wt. 10.5 ppg AST- .4 ADT- 3.9 Total Bit hrs- 5.6 Jars- 53.9 300.0 900.0 12/3/2021 12:00 12/3/2021 18:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 900' t/ 1558' MD. Start weighting up f/ 10.5ppg to 11.0ppg @ 970' MD WOB 8k GPM-900 PSI- 3640 RPM - 60 TQ On bttm-6k ft/lbs TQ Off bttm- 2k ft/lbs PU-112k SO-94k ROT 99k Mud Wt. 11.0 ppg AST- .6 ADT- 4.2 Total Bit hrs- 9.8 Jars- 58.1 900.0 1,558.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 4/50 MT7-05 Report Printed: 2/1/2022 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) 12/3/2021 18:00 12/4/2021 00:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 1580' t/ 2345' MD. 2257' TVD. WOB 8k GPM-900 PSI- 3100 RPM - 60 TQ On bttm-6k ft/lbs TQ Off bttm- 2k ft/lbs PU-112k SO-94k ROT 105k Mud Wt. 11.0 ppg AST- 1.3 ADT- 3.8 Total Bit hrs- 13.6 Jars- 61.9 1,558.0 2,345.0 12/4/2021 00:00 12/4/2021 06:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 2,345' t/ 2,957' MD. WOB- 25k GPM-900 PSI- 3150 RPM - 60 TQ On bttm-25k ft/lbs TQ Off bttm- 10k ft/lbs PU-122k SO-116k ROT 118k Mud Wt. 11.0 ppg AST- 2.5 ADT- 4.7 Total Bit hrs- 18.5 Jars- 66.6 2,345.0 2,957.0 12/4/2021 06:00 12/4/2021 12:00 6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 2,957' t/ 3,490' MD. WOB- 22k GPM-900 PSI- 3477 RPM - 60 TQ On bttm-20k ft/lbs TQ Off bttm- 10k ft/lbs PU-130k SO-114k ROT- 118k Mud Wt. 11.0 ppg AST- .2 ADT- 3.8 Total Bit hrs- 22.3 Jars- 70.4 2,957.0 3,490.0 12/4/2021 12:00 12/4/2021 13:00 1.00 SURFAC, DRILL OTHR T Remove master bushings to clean clay out of Joe's box. Pull hatches on flow line to unplug clay from flow line Stage pumps back up to full drilling rate of 900 GPM after cleaning clay from Joe's Box & flow line 3,490.0 3,490.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 5/50 MT7-05 Report Printed: 2/1/2022 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) 12/4/2021 13:00 12/4/2021 13:45 0.75 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 3,490' t/ 3,525' MD. WOB- 22k GPM-900 PSI- 3230 RPM - 60 TQ On bttm-10k ft/lbs TQ Off bttm- 10k ft/lbs PU-130k SO-114k ROT- 118k Mud Wt. 11.0 ppg AST- .0 ADT- .4 Total Bit hrs- 22.7 Jars- 70.8 3,490.0 3,525.0 12/4/2021 13:45 12/4/2021 17:30 3.75 SURFAC, CASING CIRC P Circ. 4 bottoms up racking a stand back after each bottoms up f/ 3525' to 3060' GPM-900 PSI-3050 RPM-50 Torq-4.5 3,525.0 3,060.0 12/4/2021 17:30 12/4/2021 20:45 3.25 SURFAC, CASING BKRM P BROOH f/ 3060' to 1973' Stage up f/ 500 fph to 900fph. GPM-900 PSI-3050 RPM-50 Torq-4.5 3,160.0 1,973.0 12/4/2021 20:45 12/4/2021 22:15 1.50 SURFAC, CASING PMPO T Hole unloading. Eddy pump at cuttings pit went down. Slow pumps to keep from running over cuttings pit. Continue pumping out of hole at reduced rate while repairing eddy pump. 1973' to 1727. GPM-124 PSI-360 RPM- Torq-4.5 1,973.0 1,727.0 12/4/2021 22:15 12/5/2021 00:00 1.75 SURFAC, CASING PMPO T Stage rate up to 900gpm. Start BROOH. Auger went down. Bad bearing. Slow rate and continue pumping out of hole at reduced rate while repairing auger. 1727' to 1450' MD. GPM-124 PSI-360 RPM- Torq-4.5 1,727.0 1,450.0 12/5/2021 00:00 12/5/2021 02:30 2.50 SURFAC, CASING PMPO T Repair cuttings auger. Pump out of hole at reduced rate f/ 1450' to 1370' GPM-124 PSI-360 RPM- Torq-4.5 1,450.0 1,370.0 12/5/2021 02:30 12/5/2021 03:45 1.25 SURFAC, CASING BKRM P BROOH f/ 1370' to 1087' MD. GPM-900 PSI-2900 RPM-40 Torq-4.5 1,370.0 1,087.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 6/50 MT7-05 Report Printed: 2/1/2022 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) 12/5/2021 03:45 12/5/2021 06:45 3.00 SURFAC, CASING PMPO P Pump out of hole w/ no rotation through perma frost. 1087' to 300'. GPM-500 PSI-1045 1,087.0 300.0 12/5/2021 06:45 12/5/2021 07:00 0.25 SURFAC, CASING OWFF P Flow check well. Well static 615.0 300.0 12/5/2021 07:00 12/5/2021 10:15 3.25 SURFAC, CASING BHAH P PJSM, Rack back drill collars, L/D NMDC, filter sub, flaot sub, stop sub, & BCPM, Drain motor, break bit, L/D motor, stab, & MWD 300.0 0.0 12/5/2021 10:15 12/5/2021 11:00 0.75 SURFAC, CASING BHAH P L/D BHA components out the beaver slide 0.0 0.0 12/5/2021 11:00 12/5/2021 13:00 2.00 SURFAC, CASING RURD P PJSM, Rig 13 3/8'' casing running equipment 0.0 0.0 12/5/2021 13:00 12/5/2021 14:15 1.25 SURFAC, CASING PUTB P PJSM, M/U 13 3/8'' shoe track & float collar, test same, test OK 0.0 145.0 12/5/2021 14:15 12/5/2021 17:15 3.00 SURFAC, CASING PUTB P RIH w/ 13 3/8'' 68# L80 H563 casing f/ 145' t/ 1100' filling casing on the fly & topping off every 10 joints Monitoring fill ups on pits #2 & #4 145.0 1,100.0 12/5/2021 17:15 12/5/2021 17:45 0.50 SURFAC, CASING CIRC P Circulate Bttoms up @ 1100'. Stage rate up to 800gpm.2750psi. 1,100.0 1,100.0 12/5/2021 17:45 12/6/2021 00:00 6.25 SURFAC, CASING PUTB P RIH w/ 13 3/8'' 68# L80 H563 casing f/ 1100' t/ 3175' filling casing on the fly & topping off every 10 joints Monitoring fill ups on pits #2 & #4 1,100.0 3,175.0 12/6/2021 00:00 12/6/2021 01:00 1.00 SURFAC, CASING PUTB P RIH w/ 13 3/8'' 68# L80 H563 casing f/ 1100' t/ 3175' filling casing on the fly & topping off every 10 joints Monitoring fill ups on pits #2 & #4 3,175.0 3,515.0 12/6/2021 01:00 12/6/2021 01:30 0.50 SURFAC, CASING PUTB P MU FMC casing hanger and landing joint. Wash down as precaution at 1 bpm. 50psi. Land hanger. Shoe depth 3515.27'. 3,515.0 3,515.0 12/6/2021 01:30 12/6/2021 03:30 2.00 SURFAC, CEMENT CIRC P Circulate and condition mud. Stage up rate f/ 1bpm to 8bpm. 45-224psi Reciprocating pipe. ttl strokes=6126stks ttl bbls = 725bbls 3,515.0 3,515.0 12/6/2021 03:30 12/6/2021 04:00 0.50 SURFAC, CEMENT RURD P Blow down top drive and mu cement line to swivel on Volant tool. 3,515.0 3,515.0 12/6/2021 04:00 12/6/2021 04:30 0.50 SURFAC, CEMENT CIRC P Break circulation and stage up to 8bpm 400psi. Reciprocating casing. 3,515.0 3,515.0 12/6/2021 04:30 12/6/2021 06:45 2.25 SURFAC, CEMENT CIRC T Eddy pump motor went out. Swap out motor before starting cement job. Continue circulation at 8bpm 400psi. Reciprocating casing while waiting on motor to be swapped out. Hold PJSM w/ cementers. 3,515.0 3,515.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 7/50 MT7-05 Report Printed: 2/1/2022 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) 12/6/2021 06:45 12/6/2021 12:00 5.25 SURFAC, CEMENT CMNT P SLB pump 5 bbls of fresh H2O. Tested lines to 500 psi low/ 3500 psi high, pump 100 bbls of 11.0 ppg Mud Push II @ 3 bbls/min, 300 psi, 9.0% F/O, Dropped bottom plug. Start batching lead. Pump 490 bbls of 11.0 ppg DeepCRETE cement at 5.0 bbls/min, 725 psi ICP, F/O 13%. Batch and pump 69 bbls of G Blend Tail 15.8 ppg cement @ 4.0 bbls/min, 600 psi, F/O 11%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg Ksi mud @ 8 bbls/min, 770 psi, F/O 28%. Bump plug with 920 psi (493 bbls + 20 bbls). 4186 strokes, final circ. PSI 372 @ 3 bpm, Pressure up to 920 psi & hold for 5 minutes. Bleed off pressure, Check floats, Floats holding, 215 bbls 11.0 ppg cement to surface. 3,515.0 3,515.0 12/6/2021 12:00 12/6/2021 13:00 1.00 SURFAC, CEMENT CMNT P Rig down volant, drain stack, fill riser & diverter w/ black water, back out landing joint, R/D cement lines, L/D volant & casing handling tools 0.0 0.0 12/6/2021 13:00 12/6/2021 14:00 1.00 SURFAC, CEMENT CMNT P L/D landing joint, remove master bushings, clean flow box, function & clean diverter bag, jet flow line w/ black water SIMOPS- Clean cuttings pit t/ change out Eddy pump 0.0 0.0 12/6/2021 14:00 12/6/2021 15:00 1.00 SURFAC, CEMENT CMNT P Remove bell nipple, blow down hole fill & jet lines, remove flow box& flow line, remove surface bag 0.0 0.0 12/6/2021 15:00 12/6/2021 16:15 1.25 SURFAC, CEMENT CMNT P Remove 90' mouse hole, remove 17' surface spool, remove diverter T & speed head 0.0 0.0 12/6/2021 16:15 12/6/2021 18:30 2.25 SURFAC, WHDBOP NUND P Clean out cellar box. PU well head. Prep and MU wellhead. per FMC rep. 0.0 0.0 12/6/2021 18:30 12/6/2021 20:00 1.50 SURFAC, WHDBOP NUND P Skid over BOPE and install on Hi pressure riser. MU choke/kill lines. MU flow lines. 0.0 0.0 12/6/2021 20:00 12/6/2021 22:30 2.50 SURFAC, WHDBOP NUND P Test lower wellhead seal to 1000psi f/ 10 minutes(Witnessed by DSV).Torque down bolts on riser and BOPE. Seal flow box. Install MPD lines.Install 90' MH. 0.0 0.0 12/6/2021 22:30 12/6/2021 23:00 0.50 SURFAC, WHDBOP NUND P Install 5" elevators. MU floor valves for testing. Set lower test plug per FMC rep. 0.0 0.0 12/6/2021 23:00 12/7/2021 00:00 1.00 SURFAC, WHDBOP MPDA P Remove 5" test joint. Install MPD test cap. fill stack and test MPD equipment. 250psi low/1250psi High. (Good test). Pull MPD test cap. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 8/50 MT7-05 Report Printed: 2/1/2022 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) 12/7/2021 00:00 12/7/2021 07:00 7.00 SURFAC, WHDBOP BOPE P Tested BOPE. All tests to 250 psi (low for 5 minutes) and 3,500 psi (high for 10 minutes) all charted. WIth exception to manual operated and super choke tested to 250 psi (low) & 2,000 psi (high) for 5 charted minutes, w/ 5" test joint tested annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, Test choke valves 1- 15, Manual operated and super choke, choke and kill manuals and HCR's, 4" valve on kill line, 2 x 5" FOSV, 5" dart valve, Upper and lower IBOP. Blind/Shear rams; Performed Koomey draw down, ACC = 3000 pis, Manifold = 1500 psi, ACC = 1650 psi after all functions on bottles, sec for 200 psi. Build w/ 2 electric pumps, 95 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 23 sec. UPR = 10 sec, Blind / Shears = 16 sec, LPR = 16 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms, AOGCC Waived witness . Witnessed by BLM rep Quinn . 0.0 0.0 12/7/2021 07:00 12/7/2021 08:00 1.00 SURFAC, WHDBOP BOPE P Rig down BOP test equipment 0.0 0.0 12/7/2021 08:00 12/7/2021 09:00 1.00 SURFAC, WHDBOP OTHR P M/U wear bushing running tool, Install same as per FMC rep, L/D running tool Wear Bushing ID - 12.437'' 0.0 0.0 12/7/2021 09:00 12/7/2021 11:00 2.00 SURFAC, WHDBOP BHAH P PJSM, P/U MWD, Ontrak, & RSS, Program tools, M/U bit, P/U NMDC, filter sub, & XO, make up collar out of derrick 0.0 197.0 12/7/2021 11:00 12/7/2021 12:15 1.25 SURFAC, WHDBOP TRIP P TIH w/ 12 1/4'' BHA f/ 197' t/ 2,437' Fill pipe every 20 stands Monitor returns on trip tanks 197.0 2,437.0 12/7/2021 12:15 12/7/2021 13:00 0.75 SURFAC, WHDBOP CIRC P SHT MWD @ 2,437' Test Good GPM-750 PSI-1480 F/0- 39% 2,437.0 2,437.0 12/7/2021 13:00 12/7/2021 14:30 1.50 SURFAC, WHDBOP TRIP P Cont. TIH w/ 12 1/4'' BHA f/ 2,437' t/ 3,286' Fill pipe every 20 stands Monitor returns on trip tanks 2,437.0 3,286.0 12/7/2021 14:30 12/7/2021 16:00 1.50 SURFAC, WHDBOP PRTS P PJSM, Pressure test surface casing t/ 3,500 psi f/ 30 min. Test good 3,286.0 3,286.0 12/7/2021 16:00 12/7/2021 16:30 0.50 SURFAC, WHDBOP WASH P Wash in hole f/ 3,286' t/ 3,429' GPM-500 PSI- 800 F/O- 26% P/U- 125K S/O- 106K 3,286.0 3,429.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 9/50 MT7-05 Report Printed: 2/1/2022 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) 12/7/2021 16:30 12/7/2021 20:15 3.75 SURFAC, DRILLOUT DRLG P Drill surface shoe track f/ 3,429' t/ 3,525' + 20' new hole to 3545' Displace hole w/ 10.0ppg LSND fluid. Ream through shoe twice no issues. GPM- 660 PSI - 910 RPM - 80 TQ - 6k WOB - 5-15k 3,429.0 3,545.0 12/7/2021 20:15 12/7/2021 21:00 0.75 SURFAC, DRILLOUT CIRC P Circulate and condition mud f/ FIT. GPM - 670 PSI - 900 3,545.0 3,545.0 12/7/2021 21:00 12/7/2021 22:30 1.50 SURFAC, DRILLOUT FIT P Pull back inside casing t/ 3480' MH std. BD top drive. RU f/ FIT. Perform FIT to 18.5ppg EMW Pressure up to 1360psi. w/ 10.0ppg mud. Monitor f/ 15 minutes. 3bbls pumped/2bbls returned. EMW= 18.5ppg Bleed off pressure and RD test equipment. 3,545.0 3,545.0 12/7/2021 22:30 12/7/2021 23:00 0.50 INTRM1, DRILL SVRG P Service rig. 3,545.0 3,545.0 12/7/2021 23:00 12/7/2021 23:30 0.50 INTRM1, DRILL CIRC T Troubleshoot pump issue. 3,545.0 3,545.0 12/7/2021 23:30 12/8/2021 00:00 0.50 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 3545' to 3561' MD. WOB- 15k GPM-800 PSI- 1195 RPM - 90 TQ On bttm-10k ft/lbs TQ Off bttm- 10k ft/lbs PU-k SO-k ROT- k Mud Wt. 10.0 ppg AST- .0 ADT- Total Bit hrs- Jars- 3,545.0 3,561.0 12/8/2021 00:00 12/8/2021 06:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 3,561' t/ 4,522' MD. WOB- 15k GPM- 1065 PSI- 2600 RPM - 170 TQ On bttm-12-14k ft/lbs TQ Off bttm- 8-10k ft/lbs PU- 130k SO- 131k ROT- 143k Mud Wt. 10.0 ppg ADT- 3.9 Total Bit hrs- 4.5 Jars- 75.3 3,561.0 4,522.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 10/50 MT7-05 Report Printed: 2/1/2022 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) 12/8/2021 06:00 12/8/2021 12:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 4,522' t/ 5,585' MD. WOB- 30k GPM- 1065 PSI- 2605 RPM - 170 TQ On bttm-12-14k ft/lbs TQ Off bttm- 8-10k ft/lbs PU- 130k SO- 131k ROT- 143k Mud Wt. 10.0 ppg ADT- 3.9 Total Bit hrs- 7.8 Jars- 78.6 4,522.0 5,585.0 12/8/2021 12:00 12/8/2021 18:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 5,585' t/ 6,642' MD. WOB- 35k GPM- 1064 PSI- 2720 RPM - 180 TQ On bttm-15k ft/lbs TQ Off bttm- 8-10k ft/lbs PU- 173k SO- 143k ROT- 156k Mud Wt. 10.1 ppg ADT- 3.9 Total Bit hrs- 11.7 Jars- 82.5 5,585.0 6,642.0 12/8/2021 18:00 12/9/2021 00:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 6,642' t/ 7,507' MD. WOB- 35k GPM- 1060 PSI- 2844 RPM - 180 TQ On bttm-14-15k ft/lbs TQ Off bttm- 5k ft/lbs PU- 179k SO- 152k ROT- 1169k Mud Wt. 10.1 ppg ADT- 3.5 Total Bit hrs- 15.2 Jars- 86 Pack off at 6,63' MD Max ECD increase 13.58ppg Pack off at 7,399' MD Max ECD increase 14.06ppg, large chunk of cement recoverd from flow line. 6,642.0 7,507.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 11/50 MT7-05 Report Printed: 2/1/2022 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) 12/9/2021 00:00 12/9/2021 06:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 7,507' t/ 8,293' MD. WOB- 26k GPM- 1060 PSI- 2950 RPM - 180 TQ On bttm-15k ft/lbs TQ Off bttm- 8k ft/lbs PU- 203k SO- 161k ROT- 171k ADT-4.2 Total Bit hrs-19.4 Jars- 90.2 Pack off at 8,114' MD Max ECD increase 12.58ppg 7,507.0 8,293.0 12/9/2021 06:00 12/9/2021 12:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 8,293' t/ 9,000' MD. WOB- 31k GPM- 1060 PSI- 3195 RPM - 170 TQ On bttm-20k ft/lbs TQ Off bttm- 10k ft/lbs PU- 212k SO- 160k ROT- 176k ADT-4.3 Total Bit hrs-23.7 Jars- 94.5 Slight pack off at 8,683' MD Max ECD increase 11.42ppg during down link. 8,293.0 9,000.0 12/9/2021 12:00 12/9/2021 18:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 9,000' t/ 9,685' MD. WOB- 35k GPM- 1050 PSI- 3095 RPM - 170 TQ On bttm-18k ft/lbs TQ Off bttm- 10k ft/lbs PU- 229k SO- 171k ROT- 186k ADT-3.9 Total Bit hrs-27.6 Jars- 98.4 Pack off at 9,460' MD Max ECD increase 13.62ppg 9,000.0 9,685.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 12/50 MT7-05 Report Printed: 2/1/2022 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) 12/9/2021 18:00 12/10/2021 00:00 6.00 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 9,685' t/ 10,266' MD. WOB- 34k GPM- 1054 PSI- 3480 RPM - 170 TQ On bttm-21k ft/lbs TQ Off bttm- 12k ft/lbs PU- 244k SO- 169k ROT- 204k ADT-4.4 Total Bit hrs-32 Jars- 102.8 9,685.0 10,266.0 12/10/2021 00:00 12/10/2021 04:30 4.50 INTRM1, DRILL DDRL P Drill 12 1/4" Intermediate 1 section f/ 10,266' t/ 10,586' MD. TD of well section WOB- 34k GPM- 1047 PSI- 3473 RPM - 170 TQ On bttm-19k ft/lbs TQ Off bttm- 12k ft/lbs PU- 244k SO- 169k ROT- 204k ADT-3.4 Total Bit hrs-35.4 Jars-106.2 10,266.0 10,586.0 12/10/2021 04:30 12/10/2021 05:30 1.00 INTRM1, CASING CIRC P TD well section at 10,586' MD 7,495' TVD. Take bottom survey and Circulate 4 hole volumes from TD to top of HRZ at official depth 10,546.5' MD 7,470.4' TVD. Spot 20bbls black-product pill from10,586' to 10,536'. Continue back ream stand to 10,480'. 10,586.0 10,586.0 12/10/2021 05:30 12/10/2021 12:00 6.50 INTRM1, CASING BKRM P BROOH from 10,480' to 9,991' circulating clean up cycles pulling one stand/ btms up. GPM- 1035 PSI- 3200 RPM - 80 TQ- 17k ft/lbs PU- 184k 10,586.0 9,991.0 12/10/2021 12:00 12/10/2021 13:00 1.00 INTRM1, CASING BKRM P BROOH from 9,991' to 9,894' circulating clean up cycles pulling one stand/ btms up. GPM- 1035 PSI- 3200 RPM - 150 TQ- 17k ft/lbs PU- 184k 9,991.0 9,894.0 12/10/2021 13:00 12/10/2021 13:30 0.50 INTRM1, CASING OWFF P Flow check well, Static, Rotate / 5 min TQ- 12k ft/lbs 9,894.0 9,894.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 13/50 MT7-05 Report Printed: 2/1/2022 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) 12/10/2021 13:30 12/10/2021 18:00 4.50 INTRM1, CASING BKRM P BROOH from 9,894' to 9,051' @ 430ft/hr GPM- 1054 PSI- 3480 RPM - 170 TQ- 12k ft/lbs ROT- 204k Pack off at 9,357' BROOH @ 560ft/hr ECD 12.58ppg 9,894.0 9,051.0 12/10/2021 18:00 12/11/2021 00:00 6.00 INTRM1, CASING BKRM P BROOH from 9,051' to 7,604' @ 430ft/hr to 500ft/hr GPM- 1044 PSI- 3053 RPM - 150 TQ- 12k ft/lbs ROT- 147k PU- 212k Note: Found wash out pin on stand #78 and box on stand #77 9,051.0 7,604.0 12/11/2021 00:00 12/11/2021 06:00 6.00 INTRM1, CASING BKRM P BROOH from 7,604' to 6,765' @ 150ft/hr to 500ft/hr GPM- 1044 PSI- 2761 RPM - 150 TQ- 10k-17k ft/lbs ROT- 141k Note:Unstable torque from 7,300' to 6,765'. Very little cuttings noticed at shakers. Albian 93 formation slight packoff @ 7,111' 7,078' 7,014' 6,886' 6,829' 6,796' 7,604.0 6,765.0 12/11/2021 06:00 12/11/2021 12:00 6.00 INTRM1, CASING BKRM P BROOH from 6,765' to 6,222' @ 150ft/hr to 325 ft/hr GPM- 1044 PSI- 2685 RPM - 150 TQ- 8k-15k ft/lbs ROT- 133k Note:Unstable torque from 6,765' to 6,222'. Very little cuttings noticed at shakers. Albian 94 formation slight packoff @ 6,464' 6,233' 6,190' 6,765.0 6,222.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 14/50 MT7-05 Report Printed: 2/1/2022 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) 12/11/2021 12:00 12/11/2021 18:00 6.00 INTRM1, CASING BKRM P BROOH from 6,222' to 5,623' @ 150ft/hr to 325 ft/hr GPM- 1044 PSI- 2596 RPM - 150 TQ- 8.7k-17k ft/lbs ROT- 128k Very little cuttings noticed at shakers. Albian 95 formation slight packoff @ 5,692' 6,222.0 5,623.0 12/11/2021 18:00 12/12/2021 00:00 6.00 INTRM1, CASING BKRM P BROOH from 5,622' to 4,681' @ 150ft/hr to 225 ft/hr GPM- 1044 PSI- 2460 RPM - 150 TQ- 6k-13k ft/lbs ROT- 122k Noticed at 5,466' starting to have larger cutting balls at shakers. 5,623.0 4,681.0 12/12/2021 00:00 12/12/2021 06:00 6.00 INTRM1, CASING BKRM P BROOH from 4,681' to 3,943' @ 150ft/hr to 350 ft/hr GPM- 1044 PSI- 2230 RPM - 150 TQ- 6k-12k ft/lbs ROT- 112k Noticed at 4,350' shakers starting to load up with larger cutting balls at shakers. Note:Unstable torque from 4,247' to 4,943'. 03:23 hrs: Brief communication lost to drillers controls. 4,681.0 3,943.0 12/12/2021 06:00 12/12/2021 09:30 3.50 INTRM1, CASING BKRM P BROOH from 3,943' to '3,480 @ 150ft/hr to 350 ft/hr GPM- 1044 PSI- 2230 RPM - 150 TQ- 8k-12k ft/lbs ROT- 112k 3,943.0 3,480.0 12/12/2021 09:30 12/12/2021 10:30 1.00 INTRM1, CASING CIRC P Circulate, pump 100bbls weighted 11.8ppg high vis sweep. GPM- 1044 PSI- 2100 RPM - 60 TQ- 6k ft/lbs ROT- 112k Note: Little increase on returned sweep. 3,480.0 3,480.0 12/12/2021 10:30 12/12/2021 11:00 0.50 INTRM1, CASING OWFF P OWFF 30min. (Static) Pump 22bbls 13ppg slug 3,480.0 3,480.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 15/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/12/2021 11:00 12/12/2021 12:00 1.00 INTRM1, CASING TRIP P POOH on elevatore from 3,480' to 2,727'. ((Observed Swabing)) 3,480.0 2,727.0 12/12/2021 12:00 12/12/2021 13:00 1.00 INTRM1, CASING BKRM P BROOH from 2,727' to 2,321' @ 900ft/hr to 1800 ft/hr GPM- 522 PSI- 576 RPM - 60 TQ- 3k ft/lbs ROT- 99k 2,727.0 2,321.0 12/12/2021 13:00 12/12/2021 14:00 1.00 INTRM1, CASING TRIP P POOH on elevatore from 2,727' to 1,198'. PU- 108k SO- 115k 2,321.0 1,198.0 12/12/2021 14:00 12/12/2021 14:30 0.50 INTRM1, CASING SVRG P Service Rig 1,198.0 1,198.0 12/12/2021 14:30 12/12/2021 15:30 1.00 INTRM1, CASING TRIP P POOH on elevatore from 1,198' to 561'. PU- 80k OWFF,, (Static) PJSM, L/D BHA 1,198.0 561.0 12/12/2021 15:30 12/12/2021 19:00 3.50 INTRM1, CASING BHAH P Rack back 5" HWT in derrick and L/D BHA BHA BHA was clean Minor fluid wash on top stabilizer blade One chip cutter on bit 561.0 0.0 12/12/2021 19:00 12/12/2021 22:30 3.50 INTRM1, CASING OWFF P OWFF, (Static) Clean and clear rig floor Flush BOP stack and pull wear bushing Install 9-5/8" casing rams 0.0 0.0 12/12/2021 22:30 12/13/2021 00:00 1.50 INTRM1, CASING PRTS P M/U 9-5/8" test joint. Test annular with 9-5/8" casing 250/5min Leak on X/O on top of test joint. Working to seal leak to achive high test. 0.0 0.0 12/13/2021 00:00 12/13/2021 03:00 3.00 INTRM1, CASING PRTS P M/U 9-5/8" test joint. Test annular with 9-5/8" test joint 250/5min Leak on X/O on top of test joint. Working to seal leak to achive high test. Test annular with 9-5/8" test joint 250/5min X 3,500psi/5min Test 9-5/8"casing rams 250/5min X 3,500psi/5min L/D 9-5/8" test joint 0.0 0.0 12/13/2021 03:00 12/13/2021 05:00 2.00 INTRM1, CASING PRTS P M/U 9-7/8" test joint. Test annular with 9-7/8" test joint 250/5min X 3,500psi/10min. 0.0 0.0 12/13/2021 05:00 12/13/2021 05:30 0.50 INTRM1, CASING RURD P L/D 9 7/8" test joint. B/D chooke and kill lines. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 16/50 MT7-05 Report Printed: 2/1/2022 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) 12/13/2021 05:30 12/13/2021 07:00 1.50 INTRM1, CASING RURD P R/U casing running equipment and P/U kick joint. Discussed with rig crew on closing in the well. 0.0 0.0 12/13/2021 07:00 12/13/2021 12:00 5.00 INTRM1, CASING PUTB P PJSM, M/U 9-5/8" 43.5# L80 shoe track and RIH w/ 9 7/8" casing to 124' MD. Make up cross over joint, continue RIH 9 7/8" 62.8# L80 H523 casing as per CPAI running tally from 124' MD to 1051' MD 0.0 124.0 12/13/2021 12:00 12/13/2021 13:30 1.50 INTRM1, CASING PUTB P Continue RIH 9 7/8" 62.8# L80 H523 casing as per CPAI running tally from 1051' MD to 1631' MD (Total 37joints) 124.0 1,631.0 12/13/2021 13:30 12/13/2021 18:00 4.50 INTRM1, CASING PUTB P Make up cross over joint and continue RIH 9 5/8" 43.5# L80 INT casing as per CPAI running tally from 1,631' MD to 3,468' MD 3,468' PU- 170k SO- 168k 1,631.0 3,468.0 12/13/2021 18:00 12/14/2021 00:00 6.00 INTRM1, CASING PUTB P Continue RIH 9 5/8" 43.5# L80 INT casing as per CPAI running tally from 3,458' MD to 5,965' MD 5,965' SO- 192k 3,468.0 5,965.0 12/14/2021 00:00 12/14/2021 00:30 0.50 INTRM1, CASING PUTB P Continue RIH 9 5/8" 43.5# L80 INT casing as per CPAI running tally from 5,965' MD to 6,256' MD 5,965' SO- 195k 5,965.0 6,256.0 12/14/2021 00:30 12/14/2021 02:00 1.50 INTRM1, CASING CIRC P Circulate and condition mud at 6,256', Stage pumps up to 8bpm 257psi monitoring mud weight 10.8 ppg mud weight out 10.8ppg, Caught mud sample @ bottoms up 6,256' PU- 237k SO- 199k 6,256.0 6,256.0 12/14/2021 02:00 12/14/2021 06:00 4.00 INTRM1, CASING PUTB P Continue RIH 9 5/8" 43.5# L80 INT casing as per CPAI running tally from 6,256' MD to 7,847' MD 7,847' SO- 222k 6,256.0 7,847.0 12/14/2021 06:00 12/14/2021 12:00 6.00 INTRM1, CASING PUTB P Continue RIH 9 5/8" 43.5# L80 INT casing as per CPAI running tally from 7,847' MD to 10,151' MD 10,151' SO- 205-220k 7,847.0 10,151.0 12/14/2021 12:00 12/14/2021 13:00 1.00 INTRM1, CASING PUTB P Continue RIH 9 5/8" 43.5# L80 INT casing as per CPAI running tally from 10,151' MD to 10,531' MD 10,531' SO- 205-220k 10,151.0 10,531.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 17/50 MT7-05 Report Printed: 2/1/2022 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) 12/14/2021 13:00 12/14/2021 13:30 0.50 INTRM1, CASING PUTB P M/U FMC hanger and landing joint. RIH from 10,531' MD to 10,544' MD. PU- 440k SO- 246k 10,531.0 10,544.0 12/14/2021 13:30 12/14/2021 14:30 1.00 INTRM1, CASING OTHR T Stacking weight at 10,544' MD, Attempt to break circulation (packing off) Continue pull to 550k to break free. 10,544.0 10,544.0 12/14/2021 14:30 12/14/2021 22:00 7.50 INTRM1, CASING WASH T Obtain circulation and stage up pumps to 3bpm 365psi, work pipe to 10,552' MD. PU- 525, SO- 170, Packing off at 10,552' MD Continue working pipe PU- 400k, SO- 250k to 10,552' MD. Attempt to reduce pump rate @1bpm 230psi up to 4bpm 337psi, unable to work pass 10,552' MD. Discuess with team to L/D hanger and P/U working joint. 10,544.0 10,552.0 12/14/2021 22:00 12/15/2021 00:00 2.00 INTRM1, CASING PUTB T Set in slips and release Volant to insure it would release. M/U Volant, pull and L/D landing joint. Volant wouldn't release off hanger. Attempt to release volant with tongs. 10,552.0 10,552.0 12/15/2021 00:00 12/15/2021 01:30 1.50 INTRM1, CASING PUTB T Volant wouldn't release from hanger. Lower hanger and Install rig tongs to break out volant tool. Visual Inspect tool, clean threads and torque through cement swivel to 42k. 10,552.0 10,531.0 12/15/2021 01:30 12/15/2021 02:30 1.00 INTRM1, CASING PUTB T L/D hanger and pick up single 9-5/8" working joint. 10,531.0 10,531.0 12/15/2021 02:30 12/15/2021 13:45 11.25 INTRM1, CASING WASH T Circulate and stage up pumps to 3bpm 365psi, work pipe from 10,531' MD to 10,552' MD. PU- 410, SO- 257, MD Continue working pipe setting 170k. Stage pump rate to 9bpm 400psi, work pipe down to10,568' MD. P/U 10' space out pup and continue washing, unable to get pass 10,570' MD. 10,531.0 10,570.0 12/15/2021 13:45 12/15/2021 16:30 2.75 INTRM1, CASING PUTB T Attempt to L/U 10' pup joint, Volant tool would't release out of pup joint. L/D pup joint and Volant together. 10,570.0 10,531.0 12/15/2021 16:30 12/15/2021 19:30 3.00 INTRM1, CASING CIRC P M/U casing swedge and lines, Circulate and condition mud for cementing. 0.5 to 8bpm 442psi 10,531.0 10,566.0 12/15/2021 19:30 12/15/2021 22:00 2.50 INTRM1, CASING RGRP T Trouble with rig Amphion system. Lost communication to drillers chair. Check service lines to Schlumberger cement unit incase needed to finish dispacing if neeeded. 10,566.0 10,566.0 12/15/2021 22:00 12/16/2021 00:00 2.00 INTRM1, CEMENT CMNT P SLB pump 5 bbls of fresh H2O. Tested lines to 3500 psi high, pump 60 bbls of 11.5 ppg Mud Push II @ 4.1 bbls/min, 225 psi, Dropped bottom plug. (cement wet @ 22:49hrs) Pump 42 bbls of Class G 15.8 ppg cement. @ 4.2bpm 230psi 10,566.0 10,566.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 18/50 MT7-05 Report Printed: 2/1/2022 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) 12/16/2021 00:00 12/16/2021 02:00 2.00 INTRM1, CEMENT CMNT P Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 10.8 ppg LSND mud @ 8 bbls/min,416 psi. Slow down rate to 3bpm 227psi at 740bbls pumped. At 6432 strokes 761 bbls displaced land bottom plug pumping at 3bpm 320psi @ 0133hrs, pressure up to 960 psi, Held pressure for 5 min Bled pressure off (floats holding) 10,566.0 0.0 12/16/2021 02:00 12/16/2021 09:30 7.50 INTRM1, DRILLOUT WOC P Waiting on cement, clean and clear rig floor. Prepare to lift stack and set emergency slips. Prepare to change rams. Changed mud pump liners from 6.5" to 6". Service rig, clean service lines, Pull PS- 21 and clean Joe's box and drain/flush stack 0.0 0.0 12/16/2021 09:30 12/16/2021 12:00 2.50 INTRM1, DRILLOUT NUND P Nipple Down between casing spool and tubing spool and P/U risers and BOP stack. 0.0 0.0 12/16/2021 12:00 12/16/2021 15:00 3.00 INTRM1, DRILLOUT WWSP P Attempt to set emergency slips, noticed slip marks on 9-5/8" casing and light scatched in casing head. Made call to CPAI for final path forward. Position 9-5/8" casing to set emergency slips to have minimum polish work to perform on casing in pack off area. 0.0 0.0 12/16/2021 15:00 12/16/2021 17:00 2.00 INTRM1, DRILLOUT WWSP P Set 9-5/8" emergency slip with 275k. Make rough cut on 9-5/8" casing and L/D cut joint. (42.68') 0.0 0.0 12/16/2021 17:00 12/16/2021 21:00 4.00 INTRM1, DRILLOUT WWSP T Found tubing spool had light scratches from centralizers and lock rings. Made call to CPAI for final instruction from field evaluations. FMC preformed light field polish to remove scratches in seal areas. 0.0 0.0 12/16/2021 21:00 12/17/2021 00:00 3.00 INTRM1, DRILLOUT WWSP P N/U tubing head and set packoff. Test packoff to 3040psi for 15min, Witness by COP 0.0 0.0 12/17/2021 00:00 12/17/2021 01:30 1.50 INTRM1, DRILLOUT NUND P Land BOP's/ riser and torque same, Change rams from 7-5/8" to 4-1/2" X 7", 0.0 0.0 12/17/2021 01:30 12/17/2021 02:30 1.00 INTRM1, DRILLOUT NUND P Install Orbit valve, Rig up Test Pump, fill stack with H20 work air out of MPD skid. Install MPD test cap. Install test sub on top drive. 0.0 0.0 12/17/2021 02:30 12/17/2021 03:30 1.00 INTRM1, DRILLOUT NUND P Perge air and test MPD equipment 250psi/1250psi 5min/10min. 0.0 0.0 12/17/2021 03:30 12/17/2021 04:00 0.50 INTRM1, DRILLOUT PRTS P Pull MPD test plug, install trip nipple and PS-21's. 0.0 0.0 12/17/2021 04:00 12/17/2021 04:30 0.50 INTRM1, DRILLOUT PRTS P Make up 5" test joint and perge air from system. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 19/50 MT7-05 Report Printed: 2/1/2022 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) 12/17/2021 04:30 12/17/2021 11:30 7.00 INTRM1, DRILLOUT PRTS P Test BOPE all tests 250 psi low for 5 min, 3,500 psi high for 10 minutes each with 5" and 7" test joints - test annular, 4 1/2" x 7" UPR and 2 7/8" X 5 1/2" LPR, 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, upper and lower IBOP, blind/shear rams. Perform Koomey drawdown, ACC=2980 psi, manifold=1550 psi initial. After all functions, accumulator=1625 psi, 12 secs to 200 psi with two electric pumps, 77 secs to build to full system pressure with two electric and two air pumps. Closing times, annular=23 secs, UPR=18 secs, blind/shears=16 secs, LPR=16 secs, choke HCR=2 secs, kill HCR=2 secs. 6 Nitrogen bottles back-up avg=1816 psi, CPAI witnessed. Tested PVT, gain/loss, flow out, LEL and H2S alarms. AOGCC Rep Austin McLeod BOP witness waived 12-14-21 @ 1046hrs. Note: Failed test on 7" test with 4 1/2" x 7" UPR. 0.0 0.0 12/17/2021 11:30 12/17/2021 12:15 0.75 INTRM1, DRILLOUT BOPE T Pull 7" test joint and test plug. Drain stack and change 4-1/2" X 7" upper pipe rams. 0.0 0.0 12/17/2021 12:15 12/17/2021 14:00 1.75 INTRM1, DRILLOUT PRTS P Run and set test plug with 7" test joint, Flood and perge BOPs with water. Test 4-1/2" X 7" upper pipe rams 250 psi low for 5 min, 3,500 psi high for 10 minutes with 5" and 7" test joints. 0.0 0.0 12/17/2021 14:00 12/17/2021 15:00 1.00 INTRM1, DRILLOUT RURD P Pull and L/D test plug, Drain stack and B/D lines. Install wear bushing as per FMC. Clean and clear rig floor. 0.0 0.0 12/17/2021 15:00 12/17/2021 18:00 3.00 INTRM1, DRILLOUT BHAH P PJSM, P/U and run 8-1/2" X 9-7/8" BHA, 25K below jars. to 548' MD. 0.0 548.0 12/17/2021 18:00 12/18/2021 00:00 6.00 INTRM1, DRILLOUT TRIP P Trip in hole with Intermedate #2, 8-1/2" X 9-7/8" BHA #3 from 548' MD to 9,311' MD, fill pipe every 20 stands. Shallow test tools at 2,434' MD 615 gpm 1170 psi PU- 247k SO-128K 548.0 9,311.0 12/18/2021 00:00 12/18/2021 00:30 0.50 INTRM1, DRILLOUT TRIP P Trip in hole with Intermedate #2, 8-1/2" X 9-7/8" BHA #3 from 9,311' MD to 10,263' MD, fill pipe every 20 stands. Shallow test tools at 2,434' MD 615 gpm 1170 psi PU- 247k SO-128K 9,311.0 10,263.0 12/18/2021 00:30 12/18/2021 02:30 2.00 INTRM1, DRILLOUT SLPC P Hang block and cut and slip 146' drill line. Reset all safety devices. Recalibrate hook load, Preform safety critical MP2 on deadman. 10,263.0 10,263.0 12/18/2021 02:30 12/18/2021 03:30 1.00 INTRM1, DRILLOUT CIRC P Circulate and condition must at 10,263' MD 650 gpm @ 1945psi 10,263.0 10,263.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 20/50 MT7-05 Report Printed: 2/1/2022 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) 12/18/2021 03:30 12/18/2021 05:00 1.50 INTRM1, DRILLOUT PRTS P B/D top drive, Rig up and test 9 5/8" casing to 3660 si for 30 min on chart CPAI witness. Pumped 8.75 bbls, returned 8.3 bbls Mud wt- 10.5ppg 10,263.0 10,263.0 12/18/2021 05:00 12/18/2021 12:30 7.50 INTRM1, DRILLOUT DRLG P Wash and ream from 10,263' MD to float collar at 10,481' MD, Drill Float collar, cement and shoe to 10,566' MD, Clean out rat hole to 10,586' MD. WOB- 10k GPM- 600 PSI- 2506 RPM - 30/80 TQ On bttm-25k ft/lbs TQ Off bttm- 23k ft/lbs PU- 180k SO- 140k ROT- 172k Mud Wt. 10.5 ppg 10,263.0 10,486.0 12/18/2021 12:30 12/18/2021 13:30 1.00 INTRM2, DRILL DDRL P Drill 8-1/2" hole from 10,586' MD to 10,606' MD 7,507' TVD (20' new formation). Displacing well to 10.5ppg LSND. WOB- 10k GPM- 600 PSI- 2506 RPM - 100 TQ On bttm-25k ft/lbs TQ Off bttm- 23k ft/lbs PU- 180k SO- 140k ROT- 172k Mud Wt. 10.5 ppg 10,486.0 10,606.0 12/18/2021 13:30 12/18/2021 14:45 1.25 INTRM2, DRILL CIRC P Circulate and condition mud @ 10,606' MD while displacing to 10.5ppg LSND to prepare for FIT. GPM- 605 PSI- 2506 RPM- 40 TQ- 10k ECD- 11.4ppg 10,606.0 10,606.0 12/18/2021 14:45 12/18/2021 15:45 1.00 INTRM2, DRILL FIT P POOH to 10,542' MD, B/D top drive, R/U and preform FIT with 10.5ppg mud. Pumped 3.8bbls 1,370psi, after 10min 1,325psi, Bled back 3.3bbls. EMW 14.0ppg 10,606.0 10,542.0 12/18/2021 15:45 12/18/2021 16:30 0.75 INTRM2, DRILL MPDA P Pull trip nipple and install RCD bearing SIMOPS: LOT on AO 480psi, EMW 11.3ppg. Freezer protect from surface to 1200' MD with 75bbls diesel. 10,542.0 10,542.0 12/18/2021 16:30 12/18/2021 17:30 1.00 INTRM2, DRILL REAM P Wash and ream from 10,542' MD to 10,606' MD 10,542.0 10,606.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 21/50 MT7-05 Report Printed: 2/1/2022 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) 12/18/2021 17:30 12/18/2021 18:00 0.50 INTRM2, DRILL DDRL P Drill 8-1/2" hole from 10,606' MD to 10,630' MD 7,524' TVD WOB- 10k GPM- 600 PSI- 2506 RPM - 100 TQ On bttm-25k ft/lbs TQ Off bttm- 23k ft/lbs PU- 180k SO- 140k ROT- 172k Mud Wt. 10.5 ppg 10,606.0 10,630.0 12/18/2021 18:00 12/18/2021 19:45 1.75 INTRM2, DRILL DDRL P Drill 8-1/2" hole from 10,630' MD to 10,690' MD 7,524' TVD WOB- 10k GPM- 600 PSI- 2506 RPM - 100 TQ On bttm-25k ft/lbs TQ Off bttm- 23k ft/lbs PU- 180k SO- 140k ROT- 172k Mud Wt. 10.5 ppg ECD- maintained at 11.84ppg 10,630.0 10,690.0 12/18/2021 19:45 12/18/2021 21:15 1.50 INTRM2, DRILL CIRC P P/U to 10,675' MD, Obtain base and final perameters, Ledge test with 10k to insure reamer is open. Took SPR's with reamer open. Reamer closed GPM- 630 PSI- 2701 TRPM- 5109 Dropped 1.25" ball Reamer open GPM- 630 PSI- 2490 TRPM- 4761 10,675.0 10,675.0 12/18/2021 21:15 12/19/2021 00:00 2.75 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 10,690' MD to 10,827 MD 7,645.36' TVD WOB- 10k GPM- 600 PSI- 2506 RPM - 100 TQ On bttm-25k ft/lbs TQ Off bttm- 23k ft/lbs PU- 180k SO- 140k ROT- 172k Mud Wt. 10.5 ppg ECD- maintained at 11.84ppg ADT- 3.3 Total Bit hrs- 4.3 Jars- 110.5 10,675.0 10,827.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 22/50 MT7-05 Report Printed: 2/1/2022 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) 12/19/2021 00:00 12/19/2021 06:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 10,827' MD 7,645 TVD to 11,205 MD 7,862' TVD WOB- 15-20k GPM- 680 PSI- 2940 RPM - 150 TQ On bttm-20k ft/lbs TQ Off bttm- 17k ft/lbs PU- 228k SO- 170k ROT- 186k Mud Wt. 10.5 ppg ECD- 12.01ppg ADT- 5.2 Total Bit hrs- 9.5 Jars- 115.7 MPD connection back pressure- 640psi 10,827.0 11,205.0 12/19/2021 06:00 12/19/2021 12:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 11,205' MD 7,862 TVD to 11,522 MD 8,023' TVD WOB- 15-20k GPM- 680 PSI- 3005 RPM - 150 TQ On bttm-18k ft/lbs TQ Off bttm- 17k ft/lbs PU- 228k SO- 170k ROT- 188k Mud Wt. 10.5 ppg ECD- 12.01ppg ADT- 4.6 Total Bit hrs- 14.1 Jars- 120.3 MPD connection back pressure- 640psi 11,205.0 11,522.0 12/19/2021 12:00 12/19/2021 18:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 11,522' MD 8,023 TVD to 11,862 MD 8,171' TVD WOB- 15-20k GPM- 680 PSI- 3145 RPM - 150 TQ On bttm-17k ft/lbs TQ Off bttm- 17k ft/lbs PU- 228k SO- 170k ROT- 183k Mud Wt. 10.5 ppg ECD- 12.07ppg ADT- 5.0 Total Bit hrs- 19.1 Jars- 125.3 MPD connection back pressure- 640psi 11,522.0 11,862.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 23/50 MT7-05 Report Printed: 2/1/2022 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) 12/19/2021 18:00 12/20/2021 00:00 6.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 11,862' MD 8,171 TVD to 12,147 MD 8,269' TVD WOB- 22k GPM- 680 PSI- 3142 RPM - 150 TQ On bttm-17k ft/lbs TQ Off bttm- 17k ft/lbs PU- 236k SO- 150k ROT- 186k Mud Wt. 10.5 ppg ECD- 12.04ppg ADT- 5.1 Total Bit hrs- 24.2 Jars- 130.4 MPD connection back pressure- 640psi 11,862.0 12,147.0 12/20/2021 00:00 12/20/2021 03:00 3.00 INTRM2, DRILL DDRL P Drill 8-1/2" X 9-7/8" hole from 12,147' MD 8,269' TVD to 12,262 MD 8,300.72' TVD WOB- 22k GPM- 680 PSI- 3142 RPM - 150 TQ On bttm-17k ft/lbs TQ Off bttm- 17k ft/lbs PU- 236k SO- 150k ROT- 186k Mud Wt. 10.5 ppg ECD- 12.04ppg MPD connection back pressure- 640psi 12,147.0 12,262.0 12/20/2021 03:00 12/20/2021 04:00 1.00 INTRM2, CASING CIRC P Circulate and condition mud at 12,262' MD 8,300.72' TVD. Record base perameters. Drop 1.625" closing ball pump down and close reamer. Record final perameters. Took SPR's with reamer closed. PU- 228k SO- 157k ROT- 185k Reamer open GPM- 630 PSI- 2930 TRPM- 4600 Dropped 1.25" ball Reamer closed GPM- 630 PSI- 3302 TRPM- 5200 12,262.0 12,262.0 12/20/2021 04:00 12/20/2021 07:30 3.50 INTRM2, CASING BKRM P BROOH, clean up cycles from 12,262' MD to 12,057' MD GPM- 680 PSI- 3198 RPM- 150 TQ Off bttm- 12k ft/lbs 12,262.0 12,057.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 24/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/20/2021 07:30 12/20/2021 12:00 4.50 INTRM2, CASING BKRM P BROOH @ 450-500' FPH from 12,057' MD to 11,112' MD GPM- 680 PSI- 3120 RPM- 135 TQ Off bttm- 12-14k ft/lbs PU- 238k SO- 185k ROT- 176k ECD- 12.01ppg 12,057.0 11,112.0 12/20/2021 12:00 12/20/2021 15:30 3.50 INTRM2, CASING BKRM P BROOH @ 250-300' FPH from 11,112' MD to 10,545' MD GPM- 680 PSI- 3120 RPM- 135 TQ Off bttm- 12-14k ft/lbs PU- 238k SO- 185k ROT- 176k ECD- 12.01ppg 11,112.0 10,545.0 12/20/2021 15:30 12/20/2021 18:30 3.00 INTRM2, CASING COND P Circulate and condition mud at 10,545' MD. Circulate 2 BTM;s up till shakers are clean. Weight up from 10.5ppg to11.0ppg. GPM- 680 PSI- 3062 RPM- 60 TQ Off bttm- 11k ft/lbs PU- 238k SO- 185k ROT- 176k ECD- 12.01ppg 10,545.0 10,451.0 12/20/2021 18:30 12/21/2021 00:00 5.50 INTRM2, CASING STRP P SOOH as per Schedule from 10,545' MD to 8,283' MD W/ 370 PSI in slips, Out of Slips 620 psi at 30'/min. Dropped 2.44" tailed drift 10,451.0 8,283.0 12/21/2021 00:00 12/21/2021 04:30 4.50 INTRM2, CASING STRP P SOOH as per Schedule from 8,283' MD to 3,388' MD W/ 370 PSI in slips, Out of Slips 620 psi at 30'/min. Increased SOOH at 4,419' MD to 42'/min W/ 370 PSI in slips, Out of Slips 490 psi. 8,283.0 3,388.0 12/21/2021 04:30 12/21/2021 05:00 0.50 INTRM2, CASING CIRC P Spot 500' viscous Gel Pill from 3,388' to 2,888' Md. Pump 48bbl pill and chase with 45bbl 13.5pph LSND Mud at 200gpm. BD top drive. 3,388.0 3,388.0 12/21/2021 05:00 12/21/2021 05:30 0.50 INTRM2, CASING STRP P SOOH from 3,388' to 2,888' MD at 25'/min. 3,388.0 2,888.0 12/21/2021 05:30 12/21/2021 06:30 1.00 INTRM2, CASING CIRC P Displace 11.0ppg to 13.5ppg mud as Beyon rollover procedure. ICR 640GPM at 2065psi FCR 187GPM at 372psi. 2,888.0 2,888.0 12/21/2021 06:30 12/21/2021 09:00 2.50 INTRM2, CASING STRP P SOOH from 2,888' to 643' MD, Mud pupm on hole at 4bpm, MPD holding 0psi in slips and 160psi out. 2,888.0 643.0 12/21/2021 09:00 12/21/2021 10:00 1.00 INTRM2, CASING MPDA P OWFF for 30min (static) Pull RCD and install trip nipple. 643.0 643.0 12/21/2021 10:00 12/21/2021 13:30 3.50 INTRM2, CASING BHAH P L/D 8-1/2" X 9-7/8" BHA. 643.0 0.0 12/21/2021 13:30 12/21/2021 15:30 2.00 INTRM2, CASING RURD P OWFF, Clean and clear rig floor, Move casing running equipment to floor. M/U Baker dart launcher to single and L/D. Service topdrive and R/U 7" liner running equipment 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 25/50 MT7-05 Report Printed: 2/1/2022 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) 12/21/2021 15:30 12/21/2021 19:30 4.00 INTRM2, CASING PUTB P PJSM, M/U 7" shoe, Float collar and Baker landing collar. (Baker Lok) shoe track and continue runn 7" 29# liner to 9,21' MD, Continue running 7" 26# casing to 1,809' MD. PU- 77k SO- 85k 0.0 1,809.0 12/21/2021 19:30 12/21/2021 21:00 1.50 INTRM2, CASING MPDA P M/U Baker 7" x 9-5/8" ZXP liner hanger. fill liner top with Zan Plex D 1,809.0 1,809.0 12/21/2021 21:00 12/22/2021 00:00 3.00 INTRM2, CASING STRP P SIH with 7" liner om 5" drill pipe from 1809' MD to 2,749' MD at 8'/min as per Beyond surge analysis. PU-104k SO- 99k 1,809.0 2,749.0 12/22/2021 00:00 12/22/2021 03:30 3.50 INTRM2, CASING STRP P SIH with 7" liner om 5" drill pipe from 2,749' MD to 4,023' MD at 8'/min as per Beyond surge analysis. PU-104k SO- 99k 2,749.0 4,023.0 12/22/2021 03:30 12/22/2021 05:00 1.50 INTRM2, CASING CIRC P Displace well at 4,023' MD from 13.5ppg to 11.0ppg LSND as per Beyond rollover analysis to maintain ECD of 12.0ppg. RPM - 20 TQ- 3k ft/lbs PU- 109k SO- 100k ROT- 104k Highest mud weight recorded out 11.8ppg 4,023.0 4,023.0 12/22/2021 05:00 12/22/2021 06:00 1.00 INTRM2, CASING STRP P SIH with 7" liner on 5" drill pipe from 4,023' MD to 4,400' MD at 25'/min as per Beyond surge analysis. PU-104k SO- 99k 4,023.0 4,400.0 12/22/2021 06:00 12/22/2021 12:00 6.00 INTRM2, CASING STRP P SIH with 7" liner on 5" drill pipe from 4,400' MD to 9,651' MD at 25'/min as per Beyond surge analysis. MPD- 370psi on 170 off slips to 6,200' MD, backed off pressure to 240psi on 50psi off slips PU-186k SO- 145k 4,400.0 9,651.0 12/22/2021 12:00 12/22/2021 13:15 1.25 INTRM2, CASING STRP P SIH with 7" liner on 5" drill pipe from 9,651' MD to 10,438' MD at 25'/min as per Beyond surge analysis. MPD- 240psi on 50psi off slips PU-186k SO- 145k 9,651.0 10,438.0 12/22/2021 13:15 12/22/2021 18:00 4.75 INTRM2, CASING CIRC P Circulate and condition mud, cut mud weight back to 10.5ppg. Note: No trace of 13.5ppg mud returned, Average mud returned 11.4ppg and the max 11.8ppg. 10,438.0 10,438.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 26/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/22/2021 18:00 12/22/2021 20:30 2.50 INTRM2, CASING CIRC P Circulate and condition mud, cut mud weight back to 10.5ppg. Note: No trace of 13.5ppg mud returned, Average mud returned 11.4ppg and the max 11.8ppg. 10,438.0 10,438.0 12/22/2021 20:30 12/23/2021 00:00 3.50 INTRM2, CASING STRP P SIH with 7" liner on 5" drill pipe from 10,438' MD to 12,230' MD at 17'/min as per Beyond surge analysis. MPD- 570psi on 390psi off slips, At 12,060' MD 12'/min, 12,170' MD 8'/min, 12,180' MD 4'/min and 12,197 to 12,230' MD 2'/min. RPM - 20 TQ- 7.5k ft/lbs PU- 195k SO- 163k ROT- 175k Mud Wt. 10.5 ppg 10,438.0 12,230.0 12/23/2021 00:00 12/23/2021 00:30 0.50 INTRM2, CASING RURD P PU and MU cement head and dart launcher. SIH and set on depth at 12,252'. PU- 225k SO- 123k 12,230.0 12,252.0 12/23/2021 00:30 12/23/2021 19:30 19.00 INTRM2, CEMENT CIRC T With liner on depth at 12,252' MD and TOL at 10,401' MD, Establish circulation and stage up from 1/2bpm to 6bpm 885psi. 370bbls into circulation pack off accrued, At 02:15hrs staging pumps back up to regain circulation at 1/2bpm At 03:00 hrs regain 100% returns at 1/2bpm. Stage up pumps to 4bpm 670psi, At 03:49hrs pumping at 4bpm for 5min packed off again. Drop rate to 1bpm 418psi and stage pumps up again every 10min to 3bpm 417psi At 04:46hrs packed off again, dropped rate to 1/2bpm to regain full retunes. Staging up pumps and rotation at 10rpm 10k torque from 2bpm to 4.5bpm 560psi, at 05:50hrs packed off and torqued up. Stage pumps up in 1/2bbl increments with rotation to 3bpm 883psi (oberserving intermitting packoff) 1200hrs continue working with pump rates and rotation staging pumps up to 4bpm 480psi for one hr. At 1830hrs stage pumps down to 0gpm 0psi, and ramp pumps up 1/2bbl increments to 3.5bpm, continue circulating to simulate cement operations for 30min with full returns. PU- 223k SO-162k ROT- 201k MW- 10.5ppg in/out 12,252.0 12,252.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 27/50 MT7-05 Report Printed: 2/1/2022 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) 12/23/2021 19:30 12/23/2021 22:30 3.00 INTRM2, CEMENT CMNT P Perform 7" liner cement job Flood lines and test to 4500psi. Pump 60bbls of 13.0ppg mud push staging up pumps from 1bpm to 3 bpm. 407psi. Drop 1st dart at 21:06hrs. Mix and pump 52bbls of 15.8ppg cement staging rate up to 3bpm. Drop 2nd dart at 21:28hrs. Pump 20 bbls FW w/ cement unit. Swap over to rig pumps and displace at 3bpm avg 47psi. At 97bbls into displacement observed decrease in returns and pressure increase to 1325psi (dart latched bottom plug) Pressure decreased to 102psi. At120 bbls into displacement slow rate to 2.0 bpm 624psi, 147 bbls into displacemen second dart landed and released top plug with 1204psi. (note full returns before top plug released, mud lost started after plug released) Plug bumped at 213 bbls 940psi (12 bbls early) at 23:30hrs 12/23/21. Total fluid lost during displacement 27bbls recorded from pit strap. 12,252.0 12,252.0 12/23/2021 22:30 12/24/2021 00:00 1.50 INTRM2, CEMENT CMNT P Set hanger per Baker procedure at 12,252' MD TOL 10,401' MD. Pressure up to 4200psi. hold f/ 5 minutes. SO to confirm liner set 142k down. P/U to free travel 200k (HRDE tool released) Bleed off pressure and check floats (good). Expose dog sub and rotate at 15rpm S/O and confirmed sheared. pressure up tp 500psi and P/U and pressure dumped. Circulate and clean liner top. 12,252.0 12,252.0 12/24/2021 00:00 12/24/2021 01:30 1.50 INTRM2, CEMENT RURD P B/D top drive, L/D backer surface equipment. Pump out hole one stand to 12,172' MD at 540gpm 1191psi. 12,252.0 12,172.0 12/24/2021 01:30 12/24/2021 02:30 1.00 INTRM2, CEMENT CIRC P Circulate wipper ball at 12,172' MD at 540gpm 1195psi. 12,172.0 12,172.0 12/24/2021 02:30 12/24/2021 03:00 0.50 INTRM2, CEMENT OWFF P B/D top drive and OWFF 30min. (static) 12,172.0 12,172.0 12/24/2021 03:00 12/24/2021 04:00 1.00 INTRM2, CEMENT MPDA P Pull RCD and install trip nipple and lines 10,400.0 10,400.0 12/24/2021 04:00 12/24/2021 09:00 5.00 INTRM2, CEMENT TRIP P POOH with Baker running tools from 10,400' MD to 1,696' MD 10,400.0 1,696.0 12/24/2021 09:00 12/24/2021 11:30 2.50 INTRM2, CEMENT BHAH P POOH L/D 5" drill pipe and Baker running tools. 1,696.0 0.0 12/24/2021 11:30 12/24/2021 12:00 0.50 INTRM2, CEMENT CLEN P Clean and clear rig floor 0.0 0.0 12/24/2021 12:00 12/24/2021 13:30 1.50 INTRM2, WHDBOP WWWH P P/U BOP wash tool and jet BOP's at 450gpm with 80psi. Pull wear bushing and drain BOP's. 0.0 0.0 12/24/2021 13:30 12/24/2021 14:30 1.00 INTRM2, WHDBOP BOPE P Close blind rams and change top rams to 2.875" X 5.5" VBR. 0.0 0.0 12/24/2021 14:30 12/24/2021 15:30 1.00 INTRM2, WHDBOP RURD P R/U BOP test equipment 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 28/50 MT7-05 Report Printed: 2/1/2022 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) 12/24/2021 15:30 12/24/2021 21:30 6.00 INTRM2, WHDBOP BOPE P BOPE Test All tests to 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 4" Test joint,Test Annular Preventer and 2 7/8” x 5 ½” UPP and LPR, 5" Test joint, Test Annular Prevente, Test Valves: 1, 13, 14, 15, 4” Kill Line (Rig Floor), Upper IBOP. 2. Upper Pipe Rams 2 7/8” x 5 ½” Valves: 2, 10, 12, HCR Kill, lower IBOP 3. Valves, 6, 9, 11, Manual Kill & 5”- Dart Valve 4. Valves 5, 7, 8 & 5’’- FOSV #1 5. Valve 3, 4” & 5’’- FOSV #2 6. Lower Pipe Rams 2 7/8” x 5 ½” VBR’S, HCR Choke 8, Manual Choke Perform Koomey drawndown test 6 bootles avg 1950 psi ACC 3000 psi MANIF. 1500 psi = 1500 psi after all functions on bottles were made 18 saec for 200 psi build with 2 Elec puimps 97 sec to buils full system psi w/2 Elec pumps 2 Air pumps. Closing times Annnular 23 sec Upr 18 sec Blind Shear 16 sec LPR 16 Sec Choke HCR 2 sec Test PVT Gain Loss Alarms And flow out alarms Test LEL and H2S alarms. AOGCC REP ROBERT NOBLE WAIVED WITNESS @ 06:28hrs on 12/24/21 0.0 0.0 12/24/2021 21:30 12/24/2021 22:00 0.50 INTRM2, WHDBOP RURD P R/D Test equipment, Pull test joint and B/D top drive and equipment. 0.0 0.0 12/24/2021 22:00 12/24/2021 23:00 1.00 INTRM2, DRILLOUT RURD P Move 4" handling equipment to rig floor and prep pipe shed to P/U 4" pipe. 0.0 0.0 12/24/2021 23:00 12/24/2021 23:30 0.50 INTRM2, DRILLOUT SVRG P Service rig and equipment, Prep rig floor equipment to P/U 4" drill pipe. 0.0 0.0 12/24/2021 23:30 12/25/2021 00:00 0.50 INTRM2, DRILLOUT PULD P Install wear ring 0.0 0.0 12/25/2021 00:00 12/25/2021 02:30 2.50 INTRM2, DRILLOUT PULD P While waiting on CBL tools, P/U and rack back 11 stands 4" drill pipe. M/U sections of Baker BHA #4 and L/D in pipe shed. Note: Wire Line truck arrived at 0200hrs. Truck shut down again. Installed charge on truck. 0.0 0.0 12/25/2021 02:30 12/25/2021 04:00 1.50 INTRM2, DRILLOUT QEVL T Attempt to R/U Schlumberger wire line equipment. Stringing out cable from unit and truck shut down again. Clean and inspect top drive saver sub 0.0 0.0 12/25/2021 04:00 12/25/2021 07:45 3.75 INTRM2, DRILLOUT PULD P Continue P/U 4" drill pipe in rack back in derrick. Total 4" racked back, 25 stands 2372.36' 0.0 0.0 12/25/2021 07:45 12/25/2021 14:45 7.00 INTRM2, DRILLOUT QEVL P Rig up Schlumberger eline tool and equipment. Run CBL to 11,800' MD, made second attempt and tools stopped at 11, 730' MD twice. Log up to 11.300' MD (free pipe) pull out hole and rig down logging equipment. 0.0 0.0 12/25/2021 14:45 12/25/2021 15:45 1.00 INTRM2, DRILLOUT BHAH P Move BHA #4 componets to rig floor. Make up 6.125" bit and sonic scope tools. BHA 130.51' MD. 0.0 130.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 29/50 MT7-05 Report Printed: 2/1/2022 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) 12/25/2021 15:45 12/25/2021 21:45 6.00 INTRM2, DRILLOUT TRIP P Trip in hole with BHA #4 to 2505.55' MD, X/O to 5" drill pipe and continue trip in hole to 7,995' MD. Log 40' free ring pipe at 5,400' MD PU- 150k SO- 129k 130.0 7,995.0 12/25/2021 21:45 12/25/2021 23:00 1.25 INTRM2, DRILLOUT DLOG P Log with Schlumberger sonic scope from 7,995' MD to 9,109' MD at 1600'/hr. PU- 172 SO- 145 7,995.0 9,106.0 12/25/2021 23:00 12/25/2021 23:30 0.50 INTRM2, DRILLOUT SVRG P Service rig and reset Amphion system. 9,106.0 9,106.0 12/25/2021 23:30 12/26/2021 00:00 0.50 INTRM2, DRILLOUT DLOG P Continue with Schlumberger sonic scope log on drill pipe from 9,106' MD to 9,295' MD at 1600'/hr. PU- 172 SO- 145 9,106.0 9,295.0 12/26/2021 00:00 12/26/2021 02:45 2.75 INTRM2, DRILLOUT DLOG P Continue with Schlumberger sonic scope log on drill pipe from 9,295' MD to 12,028' MD at 1600'/hr. PU- 172 SO- 145 9,295.0 12,025.0 12/26/2021 02:45 12/26/2021 04:00 1.25 INTRM2, DRILLOUT CIRC P Circulate and condition mud at 12,028' MD at 220gpm 1045psi. Blow down top drive. PU-208k SO-161k ROT- 178K RPM-40 TQ- 9k ft/lbs 12,025.0 12,025.0 12/26/2021 04:00 12/26/2021 05:30 1.50 INTRM2, DRILLOUT PRTS P Space out and rig up service lines. Test casing and Liner top to 3,500psi 30min. (good test) 9.0bbls pumped 9.2bbls returned. Blow down lines and rig down pump in equipment. 12,025.0 12,025.0 12/26/2021 05:30 12/26/2021 06:30 1.00 INTRM2, DRILLOUT DRLG P Wash in hole from 12025' MD to 12,153' MD PU-209k SO-160k ROT- 191K GPM- 220 PSI- 1040 RPM- 40/90 TQ- 10/14k ft/lbs 12,025.0 12,153.0 12/26/2021 06:30 12/26/2021 12:00 5.50 INTRM2, DRILLOUT DDRL P Drill cement plugs, Landing collar, float collar and cement from 12,153' MD to 12,215' MD. PU-214k SO-175k ROT- 191K GPM- 230 PSI- 1008 RPM- 40/90 TQ- 10/14k ft/lbs 12,153.0 12,215.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 30/50 MT7-05 Report Printed: 2/1/2022 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) 12/26/2021 12:00 12/26/2021 12:30 0.50 INTRM2, DRILLOUT DRLG P Drill cement from 12,215' MD to 12,237' MD. PU-214k SO-175k ROT- 191K GPM- 230 PSI- 1008 RPM- 40/90 TQ- 10/14k ft/lbs 12,215.0 12,237.0 12/26/2021 12:30 12/26/2021 14:00 1.50 INTRM2, DRILLOUT CIRC P Circulate and condition mud at 12,237' MD at 300gpm 1317psi. Blow down top drive. PU-208k SO-161k ROT- 178K RPM-90 TQ- 17/18k ft/lbs 12,237.0 12,237.0 12/26/2021 14:00 12/26/2021 14:30 0.50 INTRM2, DRILLOUT OWFF P Observe well for flow. (Static) 12,237.0 12,237.0 12/26/2021 14:30 12/26/2021 15:00 0.50 INTRM2, DRILLOUT CIRC P Pump 20bbl slug @ 12.5ppg 12,237.0 12,237.0 12/26/2021 15:00 12/26/2021 17:00 2.00 INTRM2, DRILLOUT TRIP P POOH from 12,237' MD to 9,295' MD , Pipe pulling wet. Mix 2nd slug. 12,237.0 9,295.0 12/26/2021 17:00 12/26/2021 17:30 0.50 INTRM2, DRILLOUT SVRG P Service rig and reset Amphion system. 9,295.0 9,295.0 12/26/2021 17:30 12/26/2021 18:00 0.50 INTRM2, DRILLOUT CIRC P Pump 2nd 20bbl slug @ 12.5ppg 9,295.0 9,295.0 12/26/2021 18:00 12/26/2021 19:15 1.25 INTRM2, DRILLOUT RGRP T Rig shut down, Working on Amphion system. 9,295.0 9,295.0 12/26/2021 19:15 12/26/2021 21:00 1.75 INTRM2, DRILLOUT TRIP P POOH from 9,295' MD to 6,467' MD PU-137k SO-124k 9,295.0 6,467.0 12/26/2021 21:00 12/27/2021 00:00 3.00 INTRM2, DRILLOUT RGRP T Rig shut down, Working on Amphion system. 6,467.0 6,467.0 12/27/2021 00:00 12/27/2021 04:30 4.50 INTRM2, DRILLOUT PUTB P PJSM, Rig up 4" handling equipment. Picking up and racking back 4" drill pipe. Drift with 2.55" while working on rig Amphion system. Total 18 stands 4" drill pipe racked back. 6,467.0 6,467.0 12/27/2021 04:30 12/27/2021 06:00 1.50 INTRM2, DRILLOUT TRIP P POOH from 6,467' MD to 4,443' MD PU-137k SO-124k 6,467.0 4,443.0 12/27/2021 06:00 12/27/2021 09:15 3.25 INTRM2, DRILLOUT TRIP P POOH from 4,443' MD to 130' MD 4,443.0 130.0 12/27/2021 09:15 12/27/2021 10:15 1.00 INTRM2, DRILLOUT BHAH P Lay down baker BHA and Schlumberger sonic tools. 130.0 0.0 12/27/2021 10:15 12/27/2021 10:45 0.50 INTRM2, DRILLOUT CLEN P Clean and clear tools from rig floor. 0.0 0.0 12/27/2021 10:45 12/27/2021 16:30 5.75 INTRM2, DRILLOUT SVRG P While waiting on Schlumberger Sonic evaluation log. Change out top drive IBOP and saver sub. 0.0 0.0 12/27/2021 16:30 12/27/2021 23:00 6.50 INTRM2, DRILLOUT ELOG P Rig up Schlumberger e-line tools and equipment. RIH with CBL log to 12,124' MD, log out hole to evaluate TOC. 0.0 0.0 12/27/2021 23:00 12/28/2021 00:00 1.00 INTRM2, DRILLOUT PRTS P Rig up and flood top drive to test IBOP. Work air from system. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 31/50 MT7-05 Report Printed: 2/1/2022 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) 12/28/2021 00:00 12/28/2021 03:30 3.50 INTRM2, DRILLOUT PRTS T Test IBOP 250psi/3,500psi, 5min/10min. Test lower. 250psi/3500psi. Unable to get high test. Trouble shooting leak path. Found ice plug in system, retest 250psi/3500psi 5min/10min. 0.0 0.0 12/28/2021 03:30 12/28/2021 04:00 0.50 INTRM2, DRILLOUT RURD P Rig down and blow down test equipment. 0.0 0.0 12/28/2021 04:00 12/28/2021 06:00 2.00 INTRM2, DRILLOUT SLPC P Cut and slip 103' Drill line. Reset crown, floor saver and recalibrate system. 0.0 0.0 12/28/2021 06:00 12/28/2021 09:45 3.75 INTRM2, DRILLOUT BHAH P PJSM, Pick up Baker BHA #5 (BHA wt 60k) 0.0 247.0 12/28/2021 09:45 12/28/2021 12:00 2.25 INTRM2, DRILLOUT PUTB P Single in 4" drill pipe from 247' MD to 2,141' MD. Shallow test 350gpm 1200psi. 247.0 2,141.0 12/28/2021 12:00 12/28/2021 19:00 7.00 INTRM2, DRILLOUT PUTB P Continue single in 4" drill pipe from 2,141' MD to 7,932' MD. 2,141.0 7,932.0 12/28/2021 19:00 12/28/2021 22:00 3.00 INTRM2, DRILLOUT TRIP P Continue trip in hole w/4" drill pipe from 7,932' MD to 12,015' MD. PU- 176k SO- 125k 7,932.0 12,015.0 12/28/2021 22:00 12/28/2021 22:15 0.25 INTRM2, DRILLOUT TRIP P Make up X/O and continur trip in hole with 5" drill pipe from 12,015' MD to 12,167' MD. 12,015.0 12,167.0 12/28/2021 22:15 12/28/2021 22:45 0.50 INTRM2, DRILLOUT WASH P Wash in hole from 12,167' MD to 7" shoe at 12,249' MD. GPM- 220 PSI- 1690 RPM- 30 TQ- 8k ft/lbs 12,167.0 12,249.0 12/28/2021 22:45 12/28/2021 23:15 0.50 INTRM2, DRILLOUT DRLG P Drill out 7" shoe and 1' MD formation from 12,249 to12,253' MD. GPM- 220 PSI- 1712 RPM- 50 TQ- 10k ft/lbs ECD- 11.11ppg 12,249.0 12,253.0 12/28/2021 23:15 12/29/2021 00:00 0.75 INTRM2, DRILLOUT CIRC P Circulate and condition mud at 12,253' MD GPM- 321 PSI- 2725 RPM- 50 TQ- 8k ft/lbs ECD- 10.87ppg MW- 10.0/10.6+ ppg in / 10.2/11.3+ ppg out 12,253.0 12,253.0 12/29/2021 00:00 12/29/2021 02:30 2.50 INTRM2, DRILLOUT CIRC P Circulate and condition mud at 12,253' MD, MW- 10.0/10.6+ ppg in / 10.2/11.3+ ppg out GPM- 321 PSI- 2725 RPM- 50 TQ- 8k ft/lbs ECD- 10.87ppg MW- 10.0+ ppg in / 10.0+ ppg out 12,253.0 12,253.0 12/29/2021 02:30 12/29/2021 03:30 1.00 INTRM2, DRILLOUT FIT P Blow down top drive and rig up test equipment. Perform FIT at 7" shoe 12,252' MD 8,298' TVD. Pumped 1.6bbls returned 1.6bbls. FIT 620psi. with 10.1ppg mud, 11.5ppg EMW 12,253.0 12,253.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 32/50 MT7-05 Report Printed: 2/1/2022 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) 12/29/2021 03:30 12/29/2021 07:00 3.50 INTRM2, DRILLOUT CIRC P Circulate and condition mud at 12,253' MD GPM- 321 PSI- 2565 RPM- 30 TQ- 9k ft/lbs ECD- 10.62ppg MW- 10.0+ ppg in / 10.0+ ppg out Waiting on AOGCC approval to move forward. 12,253.0 12,253.0 12/29/2021 07:00 12/29/2021 07:30 0.50 INTRM2, DRILLOUT DDRL P Drill 6-1/8" hole from 12,253' MD to 12,282' MD 8,305' TVD WOB- 8k GPM- 280 PSI- 2600 RPM - 60 TQ On bttm-11k ft/lbs Mud Wt. 10.2 ppg ECD- 10.45ppg 12,253.0 12,282.0 12/29/2021 07:30 12/29/2021 09:00 1.50 PROD1, DRILL CIRC P Circulate and condition mud from 12,282' MD to 12,204' MD WOB- 8k GPM- 280 PSI- 2600 RPM - 30 TQ off bttm- 9k ft/lbs Mud Wt. 10.2 ppg ECD- 10.45ppg Waiting on AOGCC approval to move forward. 12,282.0 12,204.0 12/29/2021 09:00 12/29/2021 09:30 0.50 PROD1, DRILL OWFF P OWFF at 12,204' MD 12,204.0 12,204.0 12/29/2021 09:30 12/29/2021 11:00 1.50 PROD1, DRILL FIT P Blow down top drive and rig up test equipment. Perform FIT at 12,252' MD 8,298' TVD. Pumped 4bbls returned 4.1bbls. FIT 1450psi. with 10.2ppg mud, 13.5ppg EMW 12,204.0 12,204.0 12/29/2021 11:00 12/29/2021 12:00 1.00 PROD1, DRILL MPDA P PJSM, pull trip nipple and install RCD bearing 12,204.0 12,204.0 12/29/2021 12:00 12/29/2021 15:30 3.50 PROD1, DRILL CIRC P PJSM, displace 10.2ppg LSND to 8.8ppg VersaPro fluid w/ all personnel involved. Pump 40bbls WATER + 75bbls viscosified spacer + 8.8ppg VersaPro fluid. 300gpm. 2293psi. 10.6-10.48 ECD Once 8.8ppg Versapro NAF to surface.SD pumps and rotary. close MPD and monitor well. 12,204.0 12,282.0 12/29/2021 15:30 12/29/2021 18:00 2.50 PROD1, DRILL CLEN P Monitor well on MPD, Offload LSND, clean all surface pits and equipment. take on 8.8ppg NAF. 12,282.0 12,282.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 33/50 MT7-05 Report Printed: 2/1/2022 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) 12/29/2021 18:00 12/30/2021 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 12,282' MD 8,305 TVD to 12,673 MD 8,384' TVD WOB- 6k GPM- 275 PSI- 2651 RPM - 120 TQ On bttm-10k ft/lbs TQ Off bttm- 8k ft/lbs PU- 175k SO- 145k ROT- 155k Mud Wt. 8.8 ppg ECD- 9.3ppg ADT- 4.4 Total Bit hrs- 4.4 MPD close in on connections. 12,282.0 12,673.0 12/30/2021 00:00 12/30/2021 01:15 1.25 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 12,673' MD 8,384 TVD to 12,785' MD 8,401' TVD WOB- 6k GPM- 275 PSI- 2651 RPM - 120 TQ On bttm-10k ft/lbs TQ Off bttm- 8k ft/lbs PU- 175k SO- 145k ROT- 155k Mud Wt. 8.7+ ppg ECD- 9.33ppg MPD close in on connections. 12,673.0 12,785.0 12/30/2021 01:15 12/30/2021 02:15 1.00 PROD1, DRILL CIRC T Trouble shoot Baker tools. Reboot surface equipment. 12,785.0 12,785.0 12/30/2021 02:15 12/30/2021 06:00 3.75 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 12,785' MD 8,401 TVD to 13,161' MD 8,406' TVD WOB- 6k GPM- 275 PSI- 2600 RPM - 120 TQ On bttm-10k ft/lbs TQ Off bttm- 8k ft/lbs PU- 175k SO- 145k ROT- 160k Mud Wt. 8.7+ ppg ECD- 9.3ppg ADT- 4.1 Total Bit hrs- 8.5 MPD close in on connections. 12,785.0 13,161.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 34/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/30/2021 06:00 12/30/2021 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 13,161' MD 8,406 TVD to 13,709' MD 8,395' TVD, Lost returns to formation while drilling at 13,490' MD with lost rate at 150bph, Continue drilling at 13,700' MD static lost rate at 60bph, Continue drilling to 13,709' MD. WOB- 10k GPM- 260 PSI- 2380 RPM - 130 TQ On bttm-11k ft/lbs TQ Off bttm- 8k ft/lbs PU- 175k SO- 148k ROT- 164k Mud Wt. 8.7+ ppg ECD- 9.3ppg ADT- 4.0 Total Bit hrs- 12.5 MPD close in on connections. 13,161.0 13,709.0 12/30/2021 12:00 12/30/2021 13:30 1.50 PROD1, DRILL DDRL P Continue drilling from 13,709' MD, static lost rate at 60bph, Continue drilling to 13,804' MD while up LCM 15sx/hr SC750 and 5sx/hr NPF 13,709.0 13,804.0 12/30/2021 13:30 12/30/2021 15:45 2.25 PROD1, DRILL CIRC T Open well commander, drop and pump down 1.75" ball at 2bpm 415psi, ball on seat at 674stks, Stage pressure up and shift WC open with 1605psi, Circulate 2bpm at 244psi. Drop 1.698" shutoff ball and pump down, on seat at 671 stks, 2bpm 235psi. 13,804.0 13,804.0 12/30/2021 15:45 12/30/2021 17:15 1.50 PROD1, DRILL CIRC T Circulate and spot 35bbls 80ppb procor V pill at 13490' MD. 13,804.0 13,801.0 12/30/2021 17:15 12/30/2021 18:30 1.25 PROD1, DRILL TRIP T Blow down top drive and POOH from 13,801' MD to 12,864' MD 13,801.0 12,864.0 12/30/2021 18:30 12/30/2021 21:15 2.75 PROD1, DRILL CIRC T Monitor well, circulating accross surface Start 14.4bph final 2.8bph. 12,864.0 12,864.0 12/30/2021 21:15 12/31/2021 00:00 2.75 PROD1, DRILL CIRC T Circulate at 12,864' MD stage pumps up 1.0bpm 107psi - 12/18bph losses 1.5bpm 158psi - 8.4/13.2bph losses 2.0bpm 210psi - 3.6/36bph losses 12,864.0 12,864.0 12/31/2021 00:00 12/31/2021 01:30 1.50 PROD1, DRILL TRIP T TIH to 13,495' MD 12,864.0 13,485.0 12/31/2021 01:30 12/31/2021 03:00 1.50 PROD1, DRILL CIRC T Pump and spot 39.5bbls 80#/bbl ProCor V pill at 13,485' MD Displace with 150bbls 8.8ppg NAF at 2.5bpm 352psi. 13,485.0 13,485.0 12/31/2021 03:00 12/31/2021 05:00 2.00 PROD1, DRILL TRIP T Blow down top drive and POOH to shoe at 12,197' MD Note: Amphion shut down for 8min and came back on line. 13,485.0 12,197.0 12/31/2021 05:00 12/31/2021 05:15 0.25 PROD1, DRILL OWFF T OWFF for 15min at 12,197' MD (Static) 12,197.0 12,197.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 35/50 MT7-05 Report Printed: 2/1/2022 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) 12/31/2021 05:15 12/31/2021 10:00 4.75 PROD1, DRILL CIRC T Break circulation at 12,197' MD, close annular and hesitation squeeze. Pump 5bbls and shut down pump for 10min. continue pump 1bbls every 10min. Pump at 1/2bpm 1bbl - 182psi 2bbl - 203psi 3bbl - 211psi 4bbl - 221psi 5bbl - 229psi - to final 25bbl - 220psi 12,197.0 12,197.0 12/31/2021 10:00 12/31/2021 10:30 0.50 PROD1, DRILL CIRC T Bleed psi off annular & let formation relax, blow down top drive & pump through kill line monitoring for static losses (Static) 12,197.0 12,197.0 12/31/2021 10:30 12/31/2021 12:00 1.50 PROD1, DRILL CIRC T Line up & pump down drill string, Stage pumps up t/ 260 gpm (28bph dynamic losses) 12,197.0 12,197.0 12/31/2021 12:00 12/31/2021 12:30 0.50 PROD1, DRILL CIRC T Drop 1.75'' closing ball to close well commander. pump at 2bpm 218psi, ball landed on seat at 536stks stange up to 1250psi, continue stage up pump to 1900psi, Well commander closed. Continue circulate at 260gpm 2332psi. 12,197.0 12,197.0 12/31/2021 12:30 12/31/2021 14:00 1.50 PROD1, DRILL TRIP T TIH f/ 12,197' t/ 13,321' Monitoring returns on trip tank 12,197.0 13,321.0 12/31/2021 14:00 12/31/2021 15:45 1.75 PROD1, DRILL WASH T Wash in hole f/ 13,321' t/ 13,609' GPM-80 PSI- 435 13,321.0 13,609.0 12/31/2021 15:45 12/31/2021 16:15 0.50 PROD1, DRILL WASH T Wash in hole f/ 13,609' t/ 13,709' GPM- 225 PSI- 1990 RPM-60 Downlink t/ RSS while reaming down 13,609.0 13,804.0 12/31/2021 16:15 12/31/2021 18:00 1.75 PROD1, DRILL DDRL P Drill 6-1/8" production hole from13,804' MD 8,390 TVD to 13,896' MD 8,386' TVD, Losses averaging 40 bbls per/hr WOB- 5k GPM- 225 PSI- 1965 RPM - 120 TQ On bttm-10k ft/lbs TQ Off bttm- 8k ft/lbs PU- 175k SO- 148k ROT- 164k Mud Wt. 8.7+ ppg ECD- 9.26 ppg ADT- 2.1 Total Bit hrs- 14.6 13,804.0 13,896.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 36/50 MT7-05 Report Printed: 2/1/2022 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) 12/31/2021 18:00 1/1/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from13,804' MD 8,390 TVD to 14,181' MD 8,376' TVD, Losses averaging 11 bbls per/hr WOB- 5k GPM- 225 PSI- 1965 RPM - 120 TQ On bttm-10k ft/lbs TQ Off bttm- 8k ft/lbs PU- 175k SO- 160k ROT- 170k Mud Wt. 8.7+ ppg ECD- 9.26 ppg ADT- 4.5 Total Bit hrs- 19.1 13,896.0 14,181.0 1/1/2022 00:00 1/1/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from14,181' MD 8,376 TVD to 14,602' MD 8,376' TVD, Losses averaging 7 bbls per/hr WOB- 7 k GPM- 225 PSI- 2000 RPM - 120 TQ On bttm-11 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 184 k SO- 150 k ROT- 174 k Mud Wt. 8.8 ppg ECD- 9.47 ppg ADT- 4.6 Total Bit hrs- 23.7 14,181.0 14,602.0 1/1/2022 06:00 1/1/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from14,602' MD 8,376' TVD to 15,084' MD 8,401' TVD, Losses averaging 19 bbls per/hr WOB- 7 k GPM- 225 PSI- 2000 RPM - 120 TQ On bttm-11 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 184 k SO- 150 k ROT- 174 k Mud Wt. 8.8 ppg ECD- 9.47 ppg ADT- 4.7 Total Bit hrs- 28.4 14,602.0 15,084.0 1/1/2022 12:00 1/1/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from15,084' MD 8,401' TVD to 15,496' MD 8,392' TVD, Losses averaging 39 bbls per/hr WOB- 8 k GPM- 240 PSI- 2194 RPM - 130 TQ On bttm-13 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 194 k SO- 148 k ROT- 177 k Mud Wt. 8.9 ppg ECD- 9.47 ppg ADT- 4.6 Total Bit hrs- 33.0 15,084.0 15,496.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 37/50 MT7-05 Report Printed: 2/1/2022 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) 1/1/2022 18:00 1/2/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from15,496' MD 8,392' TVD to 15,984' MD 8,364' TVD, Losses averaging 40 bbls per/hr Held safety stand down with crew on incident WOB- 8 k GPM- 240 PSI- 2194 RPM - 130 TQ On bttm-13 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 194 k SO- 148 k ROT- 177 k Mud Wt. 8.7+ ppg ECD- 9.47 ppg ADT- 4.6 Total Bit hrs- 33.0 15,496.0 15,984.0 1/2/2022 00:00 1/2/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from15,984' MD 8,364' TVD to 16,517' MD 8,331' TVD, Losses averaging 44 bbls per/hr WOB- 8 k GPM- 240 PSI- 2200 RPM - 130 TQ On bttm-13 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 207 k SO- 148 k ROT- 170 k Mud Wt. 8.7+ ppg ECD- 9.59 ppg ADT- 4.4 Total Bit hrs- 41.9 15,984.0 16,517.0 1/2/2022 06:00 1/2/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from16,517' MD 8,331' TVD to 16,715' MD 8,322' TVD, Losses averaging 30 bbls per/hr WOB- 5 k GPM- 240 PSI- 2250 RPM - 130 TQ On bttm-13 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 212 k SO- 149 k ROT- 172 k Mud Wt. 8.7+ ppg ECD- 9.59 ppg ADT- 4.0 Total Bit hrs- 45.9 16,517.0 16,715.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 38/50 MT7-05 Report Printed: 2/1/2022 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) 1/2/2022 12:00 1/2/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from16,715' MD 8,322' TVD to 16,846' MD 8.318' TVD, Losses averaging 20 bbls per/hr WOB- 3 k GPM- 240 PSI- 2106 RPM - 140 TQ On bttm-12 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 212 k SO- 149 k ROT- 172 k Mud Wt. 8.7+ ppg ECD- 9.5 ppg ADT- 5.3 Total Bit hrs- 51.2 16,715.0 16,846.0 1/2/2022 18:00 1/3/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from16,846' MD 8,318' TVD to 17,022' MD 8.320' TVD, Losses averaging 21 bbls per/hr WOB- 3 k GPM- 240 PSI- 2106 RPM - 140 TQ On bttm-12 k ft/lbs TQ Off bttm- 8 k ft/lbs PU- 212 k SO- 149 k ROT- 172 k Mud Wt. 8.7+ ppg ECD- 9.5 ppg ADT- 5.5 Total Bit hrs- 56.7 16,846.0 17,022.0 1/3/2022 00:00 1/3/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from17,022' MD 8,320' TVD to 17,365' MD 8.330' TVD, Losses averaging 15 bbls per/hr WOB- 5 k GPM- 240 PSI- 2125 RPM - 130 TQ On bttm-14 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 214 k SO- 147 k ROT- 175 k Mud Wt. 8.7+ ppg ECD- 9.57 ppg ADT- 4.7 Total Bit hrs- 61.4 17,022.0 17,365.0 1/3/2022 06:00 1/3/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from17,365' MD 8,330' TVD to 17,766' MD 8.334' TVD, Losses averaging 29 bbls per/hr WOB- 2 k GPM- 230 PSI- 2125 RPM - 140 TQ On bttm-14 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 230 k SO- 134 k ROT- 170 k Mud Wt. 8.8 ppg ECD- 9.78 ppg ADT- 4.3 Total Bit hrs- 65.7 17,365.0 17,766.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 39/50 MT7-05 Report Printed: 2/1/2022 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) 1/3/2022 12:00 1/3/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from17,766' MD 8,334' TVD to 18,143' MD 8.331' TVD, Losses averaging 29 bbls per/hr WOB- 3 k GPM- 245 PSI- 2460 RPM - 140 TQ On bttm-14 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 240 k SO- 134 k ROT- 181 k Mud Wt. 8.8 ppg ECD- 9.99 ppg ADT- 4.5 Total Bit hrs- 70.2 17,766.0 18,143.0 1/3/2022 18:00 1/4/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from18,143' MD 8,331' TVD to 18,614' MD 8.328' TVD, Losses averaging 22 bbls per/hr WOB- 5 k GPM- 240 PSI- 2290 RPM - 140 TQ On bttm-15 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 248 k SO- 147 k ROT- 180 k Mud Wt. 8.7 ppg ECD- 9.79 ppg ADT- 4.3 Total Bit hrs- 74.5 18,143.0 18,614.0 1/4/2022 00:00 1/4/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from18,614' MD 8,328' TVD to 19,150' MD 8.315' TVD, Losses averaging 23 bbls per/hr WOB- 5 k GPM- 240 PSI- 2310 RPM - 140 TQ On bttm-15 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 251 k SO- 140 k ROT- 172 k Mud Wt. 8.7 ppg ECD- 9.82 ppg ADT- 4.1 Total Bit hrs- 78.6 18,614.0 19,150.0 1/4/2022 06:00 1/4/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from19,150' MD 8,315' TVD to 19,653' MD 8.310' TVD, Losses averaging 25 bbls per/hr WOB- 5 k GPM- 240 PSI- 2310 RPM - 140 TQ On bttm-15 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 252 k SO- 130 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.8 ppg ADT- 3.8 Total Bit hrs- 82.4 19,150.0 19,653.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 40/50 MT7-05 Report Printed: 2/1/2022 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) 1/4/2022 12:00 1/4/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from19,653' MD 8,310' TVD to 20,210x' MD 8.305' TVD, Losses averaging 40 bbls per/hr WOB- 5 k GPM- 240 PSI- 2310 RPM - 140 TQ On bttm-15 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 252 k SO- 130 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.8 ppg ADT- 4.0 Total Bit hrs- 86.4 19,653.0 20,210.0 1/4/2022 18:00 1/5/2022 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,210' MD 8,305' TVD to 20,438' MD 8.301' TVD, (Control drilling for steering) Losses averaging 27 bbls per/hr WOB- 3 k GPM- 240 PSI- 2308 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 256 k SO- 0 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.79 ppg ADT- 4.8 Total Bit hrs- 91.2 20,210.0 20,438.0 1/5/2022 00:00 1/5/2022 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,438' MD 8,301' TVD to 20,495' MD 8.299' TVD, (Control drilling for steering) Losses averaging 22 bbls per/hr WOB- 2 k GPM- 240 PSI- 2308 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 256 k SO- 0 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.69 ppg Note: Cut LCM additions in half while control drilling to conserve material. Losses averaged 22 bph. 20,438.0 20,495.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 41/50 MT7-05 Report Printed: 2/1/2022 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) 1/5/2022 06:00 1/5/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,495' MD 8,299' TVD to 20,537' MD 8.299' TVD, (Control drilling for steering) Losses averaging 22 bbls per/hr WOB- 2 k GPM- 240 PSI- 2315 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 256 k SO- 0 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.69 ppg 20,495.0 20,537.0 1/5/2022 12:00 1/5/2022 14:30 2.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,537' MD 8,299' TVD to 20,584' MD 8.297' TVD, (Control drilling for steering) Losses averaging 22 bbls per/hr WOB- 2 k GPM- 240 PSI- 2315 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 256 k SO- 0 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.69 ppg 20,537.0 20,584.0 1/5/2022 14:30 1/5/2022 16:00 1.50 PROD1, DRILL CIRC P Circulate BU. Reciprocating DS f/ 20584'-20560' 260 gpm 2685 psi 20,584.0 20,584.0 1/5/2022 16:00 1/6/2022 00:00 8.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,584' MD 8.297' TVD to 20,729' MD 8,299' TVD, (Control drilling for steering) Losses averaging 17 bbls per/hr. WOB- 2-8 k GPM- 240 PSI- 2360 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 256 k SO- 0 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.7 ppg Note: Reduced LCM additives to 1.2ppb SafeCarb 750/.6 ppb SafeCarb 250 and walnut plug fine. Losses averaging 17 bbls/hr. 20,584.0 20,729.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 42/50 MT7-05 Report Printed: 2/1/2022 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) 1/6/2022 00:00 1/6/2022 04:00 4.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,729' MD 8.299' TVD to 20910' MD 8,300' TVD, (Control drilling for steering) Losses averaging 17 bbls per/hr. WOB- 2-8 k GPM- 240 PSI- 2315 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 256 k SO- 0 k ROT- 184 k Mud Wt. 8.7 ppg ECD- 9.7 ppg 20,729.0 20,910.0 1/6/2022 04:00 1/6/2022 04:30 0.50 PROD1, DRILL RGRP T Amphion system shut down. Reset and restart. NOV tech onsite troubleshooting system. 20,910.0 20,910.0 1/6/2022 04:30 1/6/2022 06:00 1.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 20,910.' MD 8.300' TVD to 21,020' MD 8,300' TVD, (Control drilling for steering) Losses averaging 17 bbls per/hr. WOB- 2-8 k GPM- 240 PSI- 2330 RPM - 140 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 263 k SO- 0 k ROT- 187 k Mud Wt. 8.7 ppg ECD- 9.7 ppg 20,910.0 21,020.0 1/6/2022 06:00 1/6/2022 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 21,020.' MD 8.300' TVD to 21,358' MD 8,295' TVD, Losses averaging 15 bbls per/hr. WOB- 2-8 k GPM- 240 PSI- 2340 RPM - 150 TQ On bttm-16 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 263 k SO- 0 k ROT- 187 k Mud Wt. 8.7 ppg ECD- 9.7 ppg 21,020.0 21,358.0 1/6/2022 12:00 1/6/2022 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 21,358' MD 8.295' TVD to 21,730' MD 8,290' TVD, Losses averaging 17 bbls per/hr. WOB- 4 k GPM- 240 PSI- 2432 RPM - 150 TQ On bttm-17 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 262 k SO- 0 k ROT- 187 k Mud Wt. 8.7 ppg ECD- 10.0 ppg 21,358.0 21,730.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 43/50 MT7-05 Report Printed: 2/1/2022 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) 1/6/2022 18:00 1/6/2022 22:30 4.50 PROD1, DRILL DDRL P Drill 6-1/8" production hole from 21,730' MD 8.295' TVD to 21,916' MD 8,296' TVD, Losses averaging 19 bbls per/hr. TD section @ 22:30hrs 1/6/21 WOB- 4 k GPM- 240 PSI- 2517 RPM - 150 TQ On bttm-17 k ft/lbs TQ Off bttm- 10 k ft/lbs PU- 262 k SO- 0 k ROT- 187 k Mud Wt. 8.7 ppg ECD- 10.14 ppg 21,730.0 21,916.0 1/6/2022 22:30 1/7/2022 00:00 1.50 PROD1, CASING CIRC P Circulate BU at drilling parameters GPM- 240 PSI- 2517 RPM - 130 TQ Off bttm- 10 k ft/lbs PU- 262 k SO- 0 k ROT- 187 k Mud Wt. 8.7 ppg ECD- 9.92 ppg 21,916.0 21,916.0 1/7/2022 00:00 1/7/2022 00:45 0.75 PROD1, CASING CIRC P Finish circulating BU. Shakers clean. 21,916.0 21,916.0 1/7/2022 00:45 1/7/2022 01:30 0.75 PROD1, CASING OWFF P Blow down Top Drive. Flow check and fingerprint well. 1st 56psi 2nd 40 psi 3rd 32 psi 4th 28psi 5th 24 psi 6th 27 psi 7th 20 psi 8th 18 psi 21,916.0 21,916.0 1/7/2022 01:30 1/7/2022 03:30 2.00 PROD1, CASING BKRM P BROOH at 1 BU per std. Shakers clean. Losses averaging 23 bph GPM- 240 PSI- 2417 RPM - 130 TQ 15.7 k/ft/lbs Mud Wt. 8.7 ppg ECD- 9.92 ppg 21,916.0 21,821.0 1/7/2022 03:30 1/7/2022 12:00 8.50 PROD1, CASING BKRM P BROOH f/ 21,821' to 19,750'. Slack off regained Losses averaging 19 bph GPM- 240 PSI- 2366 RPM - 140 TQ 15-17 k/ft/lbs Mud Wt. 8.7 ppg ECD- 9.90 ppg 21,821.0 19,750.0 1/7/2022 12:00 1/7/2022 19:30 7.50 PROD1, CASING SMPD P SOOH f/ 19,750' to 12,204' Holding 75 psi while pulling, 50 psi while in slips Monitor returns on pit #5 19,750.0 12,204.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 44/50 MT7-05 Report Printed: 2/1/2022 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) 1/7/2022 19:30 1/7/2022 23:00 3.50 PROD1, CASING CIRC P Displace hole f/ 8.8 ppg to 9.0 ppg KWM 240 gpm 1988 psi 20 rpm 12,204.0 12,204.0 1/7/2022 23:00 1/8/2022 00:00 1.00 PROD1, CASING MPDA P Flow check well. Static. Retrieve MPD bearing assembly and install trip nipple. 12,204.0 12,204.0 1/8/2022 00:00 1/8/2022 01:30 1.50 PROD1, CASING MPDA P Finish installing trip nipple. Swap handling tools f/ 5"to 4". 12,204.0 12,204.0 1/8/2022 01:30 1/8/2022 04:00 2.50 PROD1, CASING TRIP P POOH and rack back 24 stds of 4" DP to 9745'. 12,204.0 9,745.0 1/8/2022 04:00 1/8/2022 15:00 11.00 PROD1, CASING PULD P POOH LD 4" DP f/ 9745' to BHA. Keeping constant hole fill with trip tank 9,745.0 247.0 1/8/2022 15:00 1/8/2022 15:30 0.50 PROD1, CASING OWFF P Flow check well, well static 247.0 247.0 1/8/2022 15:30 1/8/2022 18:00 2.50 PROD1, CASING BHAH P PJSM, L/D 4'' HWDP. drill & ream, Unload sources, l/d visi trak, filter sub, float sub, & stab, Break bit, l/d zone trak, stab, BCPM, On trak, & auto trak 247.0 0.0 1/8/2022 18:00 1/8/2022 19:00 1.00 PROD1, CASING CLEN P Clean and clear rig floor. 0.0 0.0 1/8/2022 19:00 1/8/2022 20:30 1.50 PROD1, CASING BOPE P MU jetting tool and flush stack. Retrieve wear bushing. 0.0 0.0 1/8/2022 20:30 1/8/2022 21:45 1.25 PROD1, CASING BOPE P RU to test BOPE 0.0 0.0 1/8/2022 21:45 1/9/2022 00:00 2.25 PROD1, CASING BOPE P BOPE Test All tests to 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 4" Test joint,Test Annular Preventer and 2 7/8” x 5 ½” UPP and LPR, 5" Test joint, Test Annular Preventer, Test Valves: 1, 13, 14, 15, 4” Kill Line (Rig Floor), Upper IBOP. 2. Upper Pipe Rams 2 7/8” x 5 ½” Valves: 2, 10, 12, HCR Kill, lower IBOP 3. Valves, 6, 9, 11, Manual Kill & 5”- Dart Valve 4. Valves 5, 7, 8 & 5’’- FOSV #1 5. Valve 3, 4” & 5’’- FOSV #2 6. Lower Pipe Rams 2 7/8” x 5 ½” VBR’S, HCR Choke 8, Manual Choke Perform Koomey drawndown test 6 bottles avg 1950 psi ACC 3000 psi MANIF. 1500 psi = 1500 psi after all functions on bottles were made 18 sec for 200 psi build with 2 Elec pumps 93 sec to build full system psi w/2 Elec pumps 2 Air pumps. Closing times Annnular 23 sec Upr 18 sec Blind Shear 16 sec LPR 16 Sec Choke HCR 2 sec Test PVT Gain Loss Alarms And flow out alarms Test LEL and H2S alarms. AOGCC LOU LAUBENSTEIN WAIVED WITNESS @ 08:16hrs on 1/08/21 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 45/50 MT7-05 Report Printed: 2/1/2022 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) 1/9/2022 00:00 1/9/2022 05:00 5.00 PROD1, CASING BOPE P Continue BOPE Test All tests to 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 4" Test joint,Test Annular Preventer and 2 7/8” x 5 ½” UPR and LPR, 5" Test joint, Test Annular Preventer, Test Valves: 1, 13, 14, 15, 4” Kill Line (Rig Floor), Upper IBOP. 2. Upper Pipe Rams 2 7/8” x 5 ½” Valves: 2, 10, 12, HCR Kill, lower IBOP 3. Valves, 6, 9, 11, Manual Kill & 5”- Dart Valve 4. Valves 5, 7, 8 & 5’’- FOSV #1 5. Valve 3, 4” & 5’’- FOSV #2 6. Lower Pipe Rams 2 7/8” x 5 ½” VBR’S, HCR Choke 8, Manual Choke Perform Koomey drawndown test 6 bottles avg 1950 psi ACC 3000 psi MANIF. 1500 psi = 1500 psi after all functions on bottles were made 18 sec for 200 psi build with 2 Elec pumps 93 sec to build full system psi w/2 Elec pumps 2 Air pumps. Closing times Annnular 23 sec Upr 18 sec Blind Shear 16 sec LPR 16 Sec Choke HCR 2 sec Test PVT Gain Loss Alarms And flow out alarms Test LEL and H2S alarms. AOGCC LOU LAUBENSTEIN WAIVED WITNESS @ 08:16hrs on 1/08/21 0.0 0.0 1/9/2022 05:00 1/9/2022 05:45 0.75 PROD1, CASING BOPE P RD BOPE test equipment. Retrieve test plug. 0.0 0.0 1/9/2022 05:45 1/9/2022 06:30 0.75 PROD1, CASING SLPC P Blow down choke & kill lines 0.0 0.0 1/9/2022 06:30 1/9/2022 07:00 0.50 PROD1, CASING OTHR P Install wear bushing as per FMC 0.0 0.0 1/9/2022 07:00 1/9/2022 09:00 2.00 COMPZN, CASING SLPC P PJSM, slip & cut drill line, Calibrate drawworks 0.0 0.0 1/9/2022 09:00 1/9/2022 20:30 11.50 COMPZN, CASING PUTB P PJSM, RIH w/ 4.5'' 12.6#, L80, H563 liner f/ 0 t/ 9315' 0.0 9,315.0 1/9/2022 20:30 1/9/2022 21:30 1.00 COMPZN, CASING CIRC P MU XO and circulate liner volume. Stage up to 320gpm 255psi. 150bbls pumped. Blow down Top Drive and LD XO. 9,315.0 9,315.0 1/9/2022 21:30 1/9/2022 22:15 0.75 COMPZN, CASING PULD P MU Liner hanger Assembly per Baker. Fill tie back sleeve w/ Zan Plex D. 9,315.0 9,315.0 1/9/2022 22:15 1/9/2022 22:45 0.50 COMPZN, CASING CIRC P MU 1st std of 4" DP and RIH to bury liner hanger below BOPE. Circulate 10 bbls to confirm liner hanger clear. Take parameters: Depth: 9448' PU 122k SO 110k Rot 123k 10 RPM TQ 3650 ft/lbs 20 RPM TQ 3800 ft/lbs 9,315.0 9,448.0 1/9/2022 22:45 1/10/2022 00:00 1.25 COMPZN, CASING RUNL P RIH w/ 4 1/2" lower completion on 4" DP f/ 9448' to 11634' 9,448.0 11,634.0 1/10/2022 00:00 1/10/2022 00:30 0.50 COMPZN, CASING RUNL P RIH w/ 4 1/2" lower completion on 5" DP f/ 11634' t/ 12201' Parameters @ 12098' PU 154k SO 130k ROT 142k 10 RPM 4600 ft/lbs 20 RPM 4950 ft/lbs 11,634.0 12,201.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 46/50 MT7-05 Report Printed: 2/1/2022 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) 1/10/2022 00:30 1/10/2022 01:00 0.50 COMPZN, CASING CIRC P Fill pipe @ 12,201' & obtain parameters P/U - 156 k S/O - 130 k Torq @ 10 rpm 4.6 k Torq @ 20 rpm 4.9k 12,201.0 12,201.0 1/10/2022 01:00 1/10/2022 10:00 9.00 COMPZN, CASING RUNL P RIH w/ 4 1/2'' lower completion on 5'' drill pipe f/ 12,201' t/ 20,781' P/U- 270 k S/O- 135 k 12,201.0 20,781.0 1/10/2022 10:00 1/10/2022 12:00 2.00 COMPZN, CASING SIPB T Observed abnormal fill up on 5 stands, Observed well for flow, well flowing, well shut in @ 10:20 hrs ISIP- 100 psi 20,781.0 20,781.0 1/10/2022 12:00 1/10/2022 13:00 1.00 COMPZN, CASING SIPB T Monitor pressure via choke. 116psi shut in pressure. Bleed off pressure and shut in. Built back to 135 psi. Put manual gauge on drill pipe and had 60 psi on drill pipe 20,781.0 20,781.0 1/10/2022 13:00 1/10/2022 14:30 1.50 COMPZN, CASING CIRC T Pump 9.0 ppg fluid to top perforated joint taking returns through choke. Stage up to 4 bpm. 162 gpm 801 psi. 156 psi casing pressure 294k PU 133k SO 20,781.0 20,781.0 1/10/2022 14:30 1/10/2022 15:30 1.00 COMPZN, CASING MPDA T BD Top Drive. RU to retrieve trip nipple and install MPD bearing assembly. 20,781.0 20,781.0 1/10/2022 15:30 1/10/2022 17:15 1.75 COMPZN, CASING OTHR T Attempt to work string. Could not free up or down. Work string 450k up. 80k down. No success. 20,781.0 20,781.0 1/10/2022 17:15 1/10/2022 18:00 0.75 COMPZN, CASING CIRC T Circulate 9.0ppg fluid taking returns through choke. SD after 150bbls pumped to build volume. 160gpm 742 psi 70 psi casing pressure. 20,781.0 20,781.0 1/10/2022 18:00 1/10/2022 20:00 2.00 COMPZN, CASING COND T Take on 9.0 ppg fluid and build volume in pits. 20,781.0 20,781.0 1/10/2022 20:00 1/10/2022 22:30 2.50 COMPZN, CASING CIRC T Circulate 9.0 ppg fluid taking returns through choke. Circulate til 9.0 ppg in/out. 134 gpm 597 psi. 20,781.0 20,781.0 1/10/2022 22:30 1/10/2022 23:00 0.50 COMPZN, CASING OWFF T Shut in well. Monitor for pressure. No pressure. Check for flow through choke. Static. Open annular and flow check. Static. 20,781.0 20,781.0 1/10/2022 23:00 1/11/2022 00:00 1.00 COMPZN, CASING OTHR T Work string. 400k over. 80k down. No success 20,781.0 20,781.0 1/11/2022 00:00 1/11/2022 00:30 0.50 COMPZN, CASING MPDA T LD MPD bearing assembly. Install trip nipple. 20,781.0 20,781.0 1/11/2022 00:30 1/11/2022 01:00 0.50 COMPZN, CASING OTHR T Attempt to free pipe. work up to 450k. Down to 80k SO 20,781.0 20,781.0 1/11/2022 01:00 1/11/2022 04:00 3.00 COMPZN, CASING COND T Build Hi Vis pill and move mud for displacement. Received approval to set hanger f/ AOGCC and BLM. 20,781.0 20,781.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 47/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2022 04:00 1/11/2022 06:00 2.00 COMPZN, CASING CIRC P Pump 5 bbls HI VIS pill ahead. Drop 1 5/8" setting ball down string. Pump 10 bbls Hi Vis Pill behind and chase w/ 9.0 ppg fluid at 3 bpm. Slow rate to 1 bpm before ball landed on seat. Set hanger as per Baker rep. 20,781.0 20,781.0 1/11/2022 06:00 1/11/2022 06:30 0.50 COMPZN, CASING PRTS P PJSM, test 4.5'' liner top packer t/ 2,500 psi f/ 10 minutes, Test good 20,781.0 20,781.0 1/11/2022 06:30 1/11/2022 14:45 8.25 COMPZN, WELLPR CIRC P Clean pits, pumps, shakers, & mud lines of OBM SIMOPS- Displace well t/ 9.0 ppg brine GPM- 168 FCP- 200 20,781.0 20,781.0 1/11/2022 14:45 1/11/2022 15:45 1.00 COMPZN, WELLPR CIRC P Pump 50 bbl 9.8ppg slug. 20,781.0 20,781.0 1/11/2022 15:45 1/11/2022 19:30 3.75 COMPZN, WELLPR PULD P POOH LD DP f/ 11397' 7490' 20,781.0 7,490.0 1/11/2022 19:30 1/11/2022 20:00 0.50 COMPZN, WELLPR SVRG P Service Rig. 7,490.0 7,490.0 1/11/2022 20:00 1/11/2022 22:15 2.25 COMPZN, WELLPR MPDA P Strip new bearing assembly off of 5" DP. Had to steam element to get it to move. Clean and clear rig floor. 7,490.0 7,490.0 1/11/2022 22:15 1/12/2022 00:00 1.75 COMPZN, WELLPR PULD P POOH LD DP f/ 7810' to 6169'. 7,490.0 6,169.0 1/12/2022 00:00 1/12/2022 10:30 10.50 COMPZN, WELLPR PULD P POOH LD DP f/ 6169' t/ 45'. RIH w/ 7 stds of 5" DP in derrick. POOH LD DP Losses at 8 bph. 6,169.0 45.0 1/12/2022 10:30 1/12/2022 11:00 0.50 COMPZN, WELLPR OTHR P PJSM, Pull PS-21's & install master bushings 45.0 45.0 1/12/2022 11:00 1/12/2022 11:30 0.50 COMPZN, WELLPR PULD P PJSM, Break down & lay out Baker liner running tool 45.0 0.0 1/12/2022 11:30 1/12/2022 12:00 0.50 COMPZN, RPCOMP OTHR P M/U wear bushing pulling tool & pull same as per FMC 0.0 0.0 1/12/2022 12:00 1/12/2022 13:00 1.00 COMPZN, RPCOMP CIRC P M/U stack flushing toll & flush stack 0.0 0.0 1/12/2022 13:00 1/12/2022 14:00 1.00 COMPZN, RPCOMP BOPE P PJSM, M/U BOP test plug as per FMC & install same in wellhead 0.0 0.0 1/12/2022 14:00 1/12/2022 15:00 1.00 COMPZN, RPCOMP BOPE P Test annular, 5'' TIW, Upper pipe rams, HCR, & super choke 250 psi low f/ 5 minutes, 3,500 psi high f/ 10 minutes 0.0 0.0 1/12/2022 15:00 1/12/2022 16:00 1.00 COMPZN, RPCOMP BOPE P RD test equipment 0.0 0.0 1/12/2022 16:00 1/12/2022 19:00 3.00 COMPZN, RPCOMP RURD P RU Csg equipment and spooler w/ control line. PJSM on running upper comnpletion. 0.0 0.0 1/12/2022 19:00 1/12/2022 20:00 1.00 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 0 to 254'. Used torque turn on the 2 xo joints at the gauge mandrel. 0.0 254.0 1/12/2022 20:00 1/12/2022 21:30 1.50 COMPZN, RPCOMP RCST P Terminate control line at gauge mandrel. Testcontrol line to 5000psi f/ 5 minutes. Good test. 254.0 254.0 1/12/2022 21:30 1/13/2022 00:00 2.50 COMPZN, RPCOMP RCST P Continue RIH w/ upper completion f. 254' to 1407'. Test control line every 1000'. 254.0 1,407.0 1/13/2022 00:00 1/13/2022 12:00 12.00 COMPZN, RPCOMP RCST P RIH w/ 4 1/2" upper completion f/ 1407' to 8210' Testing control line every 1000'. Monitoring returns on trip tank 1,407.0 8,210.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 48/50 MT7-05 Report Printed: 2/1/2022 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) 1/13/2022 12:00 1/13/2022 18:00 6.00 COMPZN, RPCOMP RCST P Cont. RIH w/ 4 1/2" upper completion f/ 8210' to 11440' Testing control line every 1000'. Monitoring returns on trip tank 8,210.0 11,430.0 1/13/2022 18:00 1/13/2022 19:00 1.00 COMPZN, RPCOMP RCST P Locate TOL. Calculate space out. POOH and LD 3 jts of tbg. MU 3 pup joints 1.77'/5.79'/7.80' f/ spaceout. MU 1 jt of 4 1/2" tbg. TOL @ 11434' Note: Last test on control line had bad readings. Sent data to town for troubleshooting. Discuss with office. 11,430.0 11,434.0 1/13/2022 19:00 1/13/2022 21:00 2.00 COMPZN, RPCOMP CIRC P Pump 410 bbls of 9.0ppg CI brine. 199 gpm. 309 psi. 11,434.0 11,434.0 1/13/2022 21:00 1/13/2022 22:30 1.50 COMPZN, RPCOMP RURD T Discussion with office and decision made to POOH and replace gauge. Blow down TD. LD XO. RD single stack tongs and RU double stack to POOH. PJSM before POOH. 11,434.0 11,434.0 1/13/2022 22:30 1/14/2022 00:00 1.50 COMPZN, RPCOMP PULL T POOH LD tbg and spooling control line back onto spool to 11016'. Motor on spooler stopped. Troubleshoot. 11,434.0 11,016.0 1/14/2022 00:00 1/14/2022 00:45 0.75 COMPZN, RPCOMP PULL T Repair motor on control line spooling unit. 11,016.0 11,016.0 1/14/2022 00:45 1/14/2022 06:00 5.25 COMPZN, RPCOMP PULL T POOH LD Tbg f/ 11016' t/ 8500'. Spooling control line back on to spool. Attempted test at 10000' (depth of last good test) with no success. 11,016.0 8,500.0 1/14/2022 06:00 1/14/2022 11:30 5.50 COMPZN, RPCOMP PULL T POOH LD Tbg f/ 8500' t/ 6201'. Spooling control line back on to spool. Attempted test at 10000' (depth of last good test) with no success. 8,500.0 6,201.0 1/14/2022 11:30 1/14/2022 12:00 0.50 COMPZN, RPCOMP CIRC T Circulate 50 bbls down tubing to keep from U-tubing GPM - 180 PSI - 150 6,201.0 6,201.0 1/14/2022 12:00 1/15/2022 00:00 12.00 COMPZN, RPCOMP PULL T POOH LD Tbg f/ 6201' t/ 680'. Spooling control line back on to spool. 6,201.0 680.0 1/15/2022 00:00 1/15/2022 00:30 0.50 COMPZN, RPCOMP PULL T POOH LD 4 1/2" tbg f/ 680' to 430'. Observed control line parted at lower GLM. 680.0 430.0 1/15/2022 00:30 1/15/2022 01:45 1.25 COMPZN, RPCOMP PULL T Secure control line. POOH LD tbg f/ 430' to 250' cutting control line at each connection. Discussion ongoing w/ office on plan forward. 430.0 250.0 1/15/2022 01:45 1/15/2022 02:45 1.00 COMPZN, RPCOMP PULL T RU and test gauge at surface. Good test. 250.0 250.0 1/15/2022 02:45 1/15/2022 03:30 0.75 COMPZN, RPCOMP PULL T Discuss w/ office plan forward. Decision made to move gauge assembly and lower GLM to a shallower depth above top of 7" liner. 250.0 250.0 1/15/2022 03:30 1/15/2022 06:00 2.50 COMPZN, RPCOMP PULL T LD 2 x XO jts and gauge assembly. All threads visually inspected good. Spool off 1,500' of control line and check line. 250.0 150.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 49/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2022 06:00 1/15/2022 09:00 3.00 COMPZN, RPCOMP RCST T RIH w/ 4.5'' 12.6# L-80 HYD 563 tubing f/ 150' t/ 1,143' M/U HES OPSIS gauge w/ torq turn f/ TSH Blue connections 150.0 1,143.0 1/15/2022 09:00 1/15/2022 12:45 3.75 COMPZN, RPCOMP OTHR T Make TEC wire field spice & test same t/ 5,000 psi f/ 10 minutes, good test, Make up t/ mandrel & test t/ 5,000 psi f/ 10 minutes, test ok, Test communication through TEC wire with OHM meters, test OK 1,143.0 1,143.0 1/15/2022 12:45 1/16/2022 00:00 11.25 COMPZN, RPCOMP RCST T RIH w/ 4.5'' 12.6# L-80 HYD 563 tubing & completion jewelry f/ 1,143' t/ 8235' Testing TEC wire every 1,000' Monitoring returns on trip tanks 1,143.0 8,235.0 1/16/2022 00:00 1/16/2022 02:15 2.25 COMPZN, RPCOMP RCST T RIH w/ 4.5'' 12.6# L-80 HYD 563 tubing & completion jewelry f/ 8235' t/ 10060' Testing TEC wire every 1,000' Monitoring returns on trip tanks 8,235.0 10,060.0 1/16/2022 02:15 1/16/2022 03:30 1.25 COMPZN, RPCOMP RGRP T Pipe skate down. Replace hydraulic cylinder. 10,060.0 1,060.0 1/16/2022 03:30 1/16/2022 06:00 2.50 COMPZN, RPCOMP RCST T RIH w/ 4.5'' 12.6# L-80 HYD 563 tubing & completion jewelry f/ 10060' t/ 11404' Testing TEC wire every 1,000' Monitoring returns on trip tanks 10,060.0 11,404.0 1/16/2022 06:00 1/16/2022 07:00 1.00 COMPZN, RPCOMP RCST T P/U 2 additional joints to tag & verify depth, Verified depth w/ Baker locator, L/D 3 joints, P/U space out pups & 1 joints liner 11,404.0 11,404.0 1/16/2022 07:00 1/16/2022 10:00 3.00 COMPZN, RPCOMP CIRC P Circ 9.0 ppg CI Brine GPM - 195 ICP - 270 FCP - 265 Total Strokes - 4650 SIMOPS- rig up equipment for testing 11,404.0 11,404.0 1/16/2022 10:00 1/16/2022 11:30 1.50 COMPZN, RPCOMP RCST P P/U FMC hanger & landing joint, terminate TEC wire through hanger & test termination t/ 5,000 psi f/ 10 minutes, test OK, RIH & land out tubing as per FMC, RILDS & torq. same as per FMC SIMOPS- Drop ball & rod for testing tubing. 11,404.0 11,441.0 1/16/2022 11:30 1/16/2022 14:30 3.00 COMPZN, RPCOMP PRTS P R/U testing equipment & test FMC hanger seal t/ 3,000 psi f/ 30 minutes, Test good 11,441.0 11,441.0 1/16/2022 14:30 1/16/2022 17:15 2.75 COMPZN, RPCOMP PRTS P R/U testing equipment & test tubing t/ 3,500' psi f/ 30 minutes, test good, Bleed down tubing t/ 3,000 psi & pressure up IA t/ 3,700 psi f/ 30 minutes, test good, Bleed tubing pressure down t/ 0 & witnessed SOV shear @ 1,200 psi, Bled IA t/ 0 psi 11,441.0 11,441.0 1/16/2022 17:15 1/16/2022 18:00 0.75 COMPZN, RPCOMP OWFF P Observed IA for flow f/ 10 minutes, Well static, L/D landing joint as per FMC 11,441.0 11,441.0 1/16/2022 18:00 1/16/2022 19:30 1.50 COMPZN, WHDBOP PRTS P Install HP-BPV. Test same in direction of flow to 2500psi f/ 15 minutes. Good test. Bleed off pressure. RD test equipment. 11,441.0 11,441.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 Page 50/50 MT7-05 Report Printed: 2/1/2022 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/16/2022 19:30 1/16/2022 23:00 3.50 COMPZN, WHDBOP NUND P LD 90' MH. ND MPD. RD choke/kill lines. ND stack and riser. Set BOP stack back. LD riser. 11,441.0 11,441.0 1/16/2022 23:00 1/17/2022 00:00 1.00 COMPZN, WHDBOP NUND P Terminate control line at WH. 11,441.0 11,441.0 1/17/2022 00:00 1/17/2022 05:30 5.50 COMPZN, WHDBOP NUND P Terminate control line at WH. Having issue sliding swagelock fitting over control line and MU to WH. 11,441.0 11,441.0 1/17/2022 05:30 1/17/2022 06:00 0.50 COMPZN, WHDBOP NUND P NU flange adapter and test 5000psi f/ 5 minutes. 11,441.0 11,441.0 1/17/2022 06:00 1/17/2022 11:30 5.50 COMPZN, WHDBOP NUND P Install 10k Frac tree. Fill tree w/ diesel & attempt to test tree with no success, could not get no more than 4K psi on tree. Closed lower master valve on frac tree and pressured tree up t/ 4,500 psi and pressure held with no bleed off, bled off pressure and opened up lower frac valve. Checked IA & found 150 psi on IA. Fluid was leaking by dart. Decision made to procede with freeze protect of well. Bled IA pressure back t/ pits. 1 bbsl bled back. Rigged up & pulled dar & BPV. SIMOPS- Remove 4'' handling equipment f/ rig floor 11,441.0 11,441.0 1/17/2022 11:30 1/17/2022 12:00 0.50 COMPZN, WHDBOP OTHR P Rig up hoses & manifold for Lil Red to freeze protect well 11,441.0 11,441.0 1/17/2022 12:00 1/17/2022 12:45 0.75 COMPZN, WHDBOP CIRC P Pump 65 bbls diesel @ 2 bpm max psi 980, taking returns to pits, Close in LRS and blow down lines 11,441.0 11,441.0 1/17/2022 12:45 1/17/2022 13:45 1.00 COMPZN, WHDBOP OTHR P Open valve manifold to U-tube well between IA & tubing 11,441.0 11,441.0 1/17/2022 13:45 1/17/2022 18:00 4.25 COMPZN, WHDBOP OTHR P Close in IA & master valve on frac tree, R/D manifold & hoses for U-tubing the well, Rig FMC lubricator & install H-BPV, R/D lubricator, install gauges on IA & tubing 11,441.0 11,441.0 1/17/2022 18:00 1/17/2022 21:30 3.50 DEMOB, MOVE RURD P Install yokes on top drive. RU scoping lines. Scope down Derrick. Blow down steam lines in in pits and BOP deck. 11,441.0 11,441.0 1/17/2022 21:30 1/17/2022 23:00 1.50 DEMOB, MOVE RURD P C/O scoping lines in derrick. 11,441.0 11,441.0 1/17/2022 23:00 1/18/2022 00:00 1.00 DEMOB, MOVE RURD P Blow down steam on rig floor. Prep to lower cattle chute. Releaser rig @ 00:00 hrs 1/18/22 11,441.0 11,441.0 Rig: DOYON 25 RIG RELEASE DATE 1/18/2022 ! " # " !$%& ' ( ) ( *%" ( !+ ( ( ( , ( !" !" "( ## $%%&'(!) *+ , $- -( !" , ($'" . ( $%%&'(!) *+ , $- ( !" )( )( ' . ( ) )(/ '0 *$1 2 - '0 *++/- 3 . 3/ . 4!( % / , 2 / ,, 2 2 2 *-" ( *" ( / -( -( 0/1% 0 1% 2 "* ( !" !)! !)! "30'"3 00)" 5030"()"( '!!)5 "/ ( !)! !6'!78)" 8 '"'6('7 )' ( , 345 6 " - 3!5 ) - 345 !" " ) - 9!' ':(:! '();8 5!)(! " 3'85)"0 500"; (+ ( " ( - !" ')! /% + ( 6)3!+ 5 3 5 0 1% 3 5 345 0/1% 3 5 ! 7 (80)( 50)8!)!!)!80)( 6) 3 5 -) ! ) 3 , 5 ! 3 5 ':(:! < , , '(0)! 05()" !" '* !"-':(:!'=8! >?@>> + >?@> ,> 2 '3!'!)! 83((0)" !" * !"-':(:!'=88 >?@>> + >?@> ,> 2 83"85)! 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'3"! )8 53;0 ) 53';0)0 "30' 3"( ); 5'38!)" !) 53 !;);0 >?@>>*"- '030!() 0!) ; 888)'; 538!0)" '3"0)8 53 (!) 53';0)8 "30' 3;88)0 5'3;')5 !)5 53 ")(' >?@>>*"- '03005)( 0!)5 888)'0 538!5) '3; ;)( 53 58) 53';5)! "30' 3 '0)! 5'3') !)' 535(8)0 >?@>>*"- !3!0) 0!)5 888)'( 538!;)0 '3 ;!)" 535")5 53';;) "30' 35!()8 5'3'5')" !)' 530'') >?@>>*"- !3'5;); 0!) 0 888)(( 538!"); '35(()( 535;5)! 53';")( "30' 3550)8 5'3'('); !)8 530 5)5 >?@>>*"- !35!); 0!) 888)! 538!()8 '305)8 530'!) 53';()' "30' 30 ()( 5'3'!')5 !)8 03!(;)(" >?@>>*"- !38 ")8 0')5 888)8 538!) 3!')0 530")5 53';)" "30'53!;!)' 5'3!;')" !); 03''();; >?@>>*"- !3(;0) 0')'" 88')5 538!!) 3!0;) 5300;) 53';!)" "30'53'(")! 5'3!!)( '); 03'58)8 >?@>>*"- !3";() 0!)" 88')!( 5300) 3' 0) 03!(')" 53'"0)! "30'530)8 5!30 )" ')! 03"8)"' >?@>>*"- !3;"5)" 50)" 88!)88 5300)' 3;')0 03!5 ); 53'"5)0 "30'538')5 5!3088) ')8 038() >?@>>*"- !3 ")" 50)0! 888)"8 5300); 38(()0 03'8')0 53'"0)( "30'5380;)0 5!350') 8)( 03808)(" >?@>>*"- !35(;)" 50)5! 88) ( 5300)5 3(5); 03' ()8 53'"0); "30'53(5')5 5!35"') !)5 03(;')' >?@>>*"- !30(') 50) ( 888)80 538!!) 3"'8); 03' )( 53';!)! "30'53"; )0 5!35'!)0 !) 03"8!)!' >?@>>*"- '3!8;); 0!)(" 888);8 538!!)! 3"05)" 03"0)5 53'"0)5 "30'53;"()! 5!3 !)0 !)5 03"05)!" >?@>>*"- '3'8')" 0!) 888) 5300)' 3;58)( 038!) 53'"5)0 "30'53 (!)! 5!3 8!)0 !)" 03;;;)'0 >?@>>*"- '38) 0!)55 888)'0 530 )5 3 ;") 038(8)" 53'" ); "30'535)0 5!3;0')0 !) 03 8)'5 >?@>>*"- '38'5)' 0')!; 888)85 530;) 35"!)! 0385;)' 53'";)! "30'530!5)0 5!3;"'); !)8 035!!)"' >?@>>*"- '3(')( 0!) 0 888) ( 530() 308()( 03(5)' 53'"()" "30'5300()( 5!3;')! !)" 035;5)!" >?@>>*"- '3"! ) 0')8' 888);( 530)0 83!'0)8 03( !)' 53'") "30'03!5!)" 5!3" )( !); 0308") ; >?@>>*"- '3;!) 0')' 888)5 530!)0 83'!()( 03"'); 53'"!) "30'03';;) 5!3"8)8 !)( '!3!!8)0 >?@>>*"- '3;0")" 50)(5 888)!! 530!)( 83'5 ); 03""() 53'"!) "30'03"')! 5!3(0)" ')5 '!3! '); >?@>>*"- '3 50)" 55)(0 88) 8 530)' 83 ') 03"0 ); 53'"')0 "30'0388") 5!3(")! ')' '!3'80)8" >?@>>*"- '35 )5 55)!" 888)8( 530() 838(0)0 03;8 ); 53'"()" "30'03('")" 5!3('()' !)0 '!3!8)'( >?@>>*"- '30';)! 55)!" 888)8( 530;)! 8385()! 03;"() 53'"")5 "30'03("!)' 5!380 )0 !)! '!38!);' +A$$ Page 1/1 MT7-05 Report Printed: 2/1/2022 Cement Detail Report Cement Details Description Surface String Cement Cementing Start Date 12/6/2021 06:45 Cementing End Date 12/6/2021 12:00 Wellbore Name MT7-05 Comment SLB pump 5 bbls of fresh H2O. Tested lines to 500 psi low/ 3500 psi high, pump 100 bbls of 11.0 ppg Mud Push II @ 3 bbls/min, 300 psi, 9.0% F/O, Dropped bottom plug. Start batching lead. Pump 490 bbls of 11.0 ppg DeepCRETE cement at 5.0 bbls/min, 725 psi ICP, F/O 13%. Batch and pump 69 bbls of G Blend Tail 15.8 ppg cement @ 4.0 bbls/min, 600 psi, F/O 11%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg Ksi mud @ 8 bbls/min, 770 psi, F/O 28%. Bump plug with 920 psi (493 bbls + 20 bbls). 4186 strokes, final circ. PSI 372 @ 3 bpm, Pressure up to 920 psi & hold for 5 minutes. Bleed off pressure, Check floats, Floats holding, 215 bbls 11.0 ppg cement to surface. Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 3,515.0 Full Return? Yes Vol Cement … 215.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 8 P Pump Final (psi) 372.0 P Plug Bump (psi) 372.0 Recip? Yes 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) 40.0 Est Btm (ftKB) 3,015.0 Amount (sacks) Class G Volume Pumped (bbl) Yield (ft³/sack) 1.92 Mix H20 Ratio (gal/sa… 6.73 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 177.0 Thickening Time (hr) 6.38 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 3,015.0 Est Btm (ftKB) 3,515.0 Amount (sacks) Class G Volume Pumped (bbl) Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sa… 5.06 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 89.0 Thickening Time (hr) 4.27 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Surface String Cement Job: DRILLING ORIGINAL, 11/29/2021 09:00 Page 1/1 MT7-05 Report Printed: 2/1/2022 Cement Detail Report Cement Details Description Intermediate String 1 Cement Cementing Start Date 12/15/2021 22:00 Cementing End Date 12/16/2021 02:00 Wellbore Name MT7-05 Comment SLB pump 5 bbls fresh water to prime lines PT lines to 3500 psi Pump 60 bbl’s 11.5 Mudpush II Drop bottom plug. SLB will pump 42 bbl’s 15,8 ppg G blend tail cement. Drop top plug. SLB will pump 20 bbl’s H-2/O on top of plug. Displace cement with rig at 8 bpm rate with 10.8 LSND. Slow to 3 bpm 169 strokes prior to bumping plug. 761 bbl’s of 10.8 LSND will be pumped to bump plug. Strokes to bump 6,432. Max strokes 6,477. Bump plug pressure up 500 psi over displacement pressure. Bleed off pressure check to verify floats held. Cement in place as of 12/16/2021 01:33 hr Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 10,071.0 Bottom Depth (ftKB) 10,566.0 Full Return? Yes Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 8 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 320.0 P Plug Bump (psi) 960.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 10,071.0 Est Btm (ftKB) 10,566.0 Amount (sacks) 203 Class G Volume Pumped (bbl) 42.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.03 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 5.39 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate String 1 Cement Job: DRILLING ORIGINAL, 11/29/2021 09:00 Page 1/1 MT7-05 Report Printed: 2/1/2022 Cement Detail Report Cement Details Description Intermediate String 2 Cement Cementing Start Date 12/23/2021 21:30 Cementing End Date 12/23/2021 23:30 Wellbore Name MT7-05 Comment PT lines to 4500 psi. Line up SLB to pump via Baker LFC swivel. SLB pumped 60 bbl Mud Push II 13 ppg, release #1 Dart, SLB pumped 52 bbl 15.8 G Blend Tail, release #2 dart. Chase with 20 bbl water. Displace with 10.5 ppg LSND. Plug bumped at 2116 stks, lost 27 bbl to formation. CIP 23:30 hrs Cement Stages Stage # 1 Description Intermediate String 2 Cement Objective Cement liner to 10,000' TOC Top Depth (ftKB) 10,401.0 Bottom Depth (ftKB) 12,252.0 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) 940.0 P Plug Bump (psi) 3,000.0 Recip? No Stroke (ft) Rotated? Yes Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost 69 bbl to formation during displacement Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 11,514.0 Est Btm (ftKB) 12,252.0 Amount (sacks) 250 Class G Volume Pumped (bbl) 52.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.02 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 80.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate String 2 Cement Job: DRILLING SUPPORT - CAPITAL, 1/11/202… From:Brooks, James S (OGC) To:Guhl, Meredith D (OGC) Subject:FW: [EXTERNAL]FW: MT7-99 Completion Report (PTD 222-102) Date:Thursday, October 27, 2022 12:41:37 PM Here you go. thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Thursday, October 27, 2022 12:40 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: Re: [EXTERNAL]FW: MT7-99 Completion Report (PTD 222-102) Alpine C Get Outlook for iOS From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Thursday, October 27, 2022 12:37:22 PM To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]FW: MT7-99 Completion Report (PTD 222-102) 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. Hi, What is the formation name for TD and TPI as they are not listed on the form ? thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 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: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Monday, October 24, 2022 9:59 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: MT7-99 Completion Report (PTD 222-102) From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Monday, October 24, 2022 9:50 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Gorham, Brad <Brad.Gorham@conocophillips.com> Subject: MT7-99 Completion Report (PTD 222-102) Hello - See attached MT7-99 Completion Report (10-407). Thank you, Jenna Jenna Taylor kGMG~ ConocoPhillips Alaska, Inc. 700 G Street Anchorage, AK 99501 907-263-4522 jenna.l.taylor@conocophillips.com T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA February 12, 2022 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-05 Greater Mooses Tooth API #: 50-103-20833-00 Permit No: 221-087 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. MT7-05 is located in a federal oil and gas unit. Only with respect to the MT7-05 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 υωιΓӔӔӓӒӚәӒ κάψСаΓӕӘӕӕӓ 02/14/2022 By Abby Bell at 11:20 am, Feb 14, 2022 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Garrett.Brown@conocophillips.com A Carolina Martinez Arelys.Martinez@bakerghes.com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y Samantha Carlisle at 8:52 am, Jan 18, 2022 'LJLWDOO\VLJQHGE\0DGHOLQH:RRGDUG '1 &1 0DGHOLQH:RRGDUG ( PDGHOLQHHZRRGDUG#FRQRFRSKLOOLSVFRP& 86 5HDVRQ ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ \RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ 0DGHOLQH :RRGDUG CDW 1/19/2022 DLB 01/19/2022 WAKHU waiver to 20 AAC 25.030(d)(5) to allow the TOC of the 7" liner to be 258' MD/86' TVD above the Alpine D versus the regulation 250' TVD is approved with the mitigation measures of placing the first frac sleeve >750' MD from the 7" liner shoe and the successful 7" shoe test of 11.5 ppg EMW. A waiver to 20 AAC 25.283 (c) (1) to allow the LTP to be set above the INT2 TOC versus the regulation of set at least 100' below the TOC is approved with mitigation measures of reducing MAWP and tubing punch of trapped annulus. X 10-404 VTL 01/20/2022 DSR-1/18/22 X dts 1/21/2022 JLC 1/21/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.21 12:54:15 -09'00' RBDMS HEW 1/22/2022 January 20, 2022 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: MT7-05 Stimulation Sundry Waiver Requests To: Victoria Loepp For the recently submitted fracture stimulation sundry for the subject well, waivers of the following regulatory requirements are requested: 1. 20 AAC 25.030(d)(5): Cement Height Requirement above hydrocarbon intervals for intermediate casing strings. A waiver is requested for this requirement because pack-off and losses occurred during the cementing of the intermediate 2 section of the well. These losses placed the top of cement for the 7” liner 258’ MD and 86’ TVD above the Alpine D reservoir top. This was confirmed with sonic and cement bond logs. This fell short of the 250’ TVD required by regulation. The attached Halliburton frac model indicates the frac will not grow into the Miluveach, therefore it’s ConocoPhillips position that the 258’ MD of cement above the top of the Alpine sands was considered adequate to isolate the frac with the successful shoe test of 11.5 ppg EMW. As an additional precaution, the first frac sleeve used for stimulation was moved to greater than 750’ MD from the 7” liner shoe. Please see attached documentation on rationale and communications with AOGCC to date. 2. 20 AAC 25.283 (c) (1): Packer depth of fracturing string placed 100’ below the cement top of the intermediate casing. A waiver is requested for this requirement because the production liner became differentially stuck 678’ MD from the planned set depth and was not movable. The production liner top packer was set above the intermediate 2 cement top, however, the liner top packer and production packer were set in the 7” 29# TN110SS intermediate 2 liner. For additional precaution, the MAWP was reduced to 7,700 psi to ensure that the 7” liner is not exposed to pressures exceeding ConocoPhillips corporate design factors due to the production packer being M. E. Woodard Completions Engineer Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6086 above top of cement. A tubing punch will be used to mitigate risks associated with the trapped annulus between the liner top packer and the shallowest swell packer. Please call me at 265-6086 if you need further information to support the sundry request. Sincerely, Attachments: 1. AOGCC Communication on 20 AAC 25.030(d)(5) 2. Halliburton Frac Model 3. AOGCC Communication on 20 AAC 25.283(c)(1) Madeline Woodard Completions Engineer ! 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Ϯ͘ϬϬϬ͘ϭϱϭͲϴ ϯϱη,LJďŽƌ' DŝŶŝĨƌĂĐ ϭϱ ϲ͕ϯϬϬ ϭϱϬ ϭϱϬ Ϭ͗ϭϬ͗ϬϬ ϭ͗ϱϮ͗ϱϮ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϵ ϯϱη>ŝŶĞĂƌ &ůƵƐŚ ϯϬ ϵ͕ϵϰϵ Ϯϯϳ Ϯϯϳ Ϭ͗Ϭϳ͗ϱϰ ϭ͗ϰϮ͗ϱϮ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϬ ^ŚƵƚͲ/Ŷ ^ŚƵƚͲ/Ŷϭ͗ϯϰ͗ϱϴϭͲϭϭ ϯϱη>ŝŶĞĂƌ WƌĞͲWĂĚ ϯϬ ϴ͕ϰϬϬ ϮϬϬ ϮϬϬ Ϭ͗Ϭϲ͗ϰϬ ϭ͗ϯϰ͗ϱϴ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϮ ϯϱη>ŝŶĞĂƌ ƐƚĂďůŝƐŚ^ƚĂďůĞ&ůƵŝĚ ϯϬ ϱ͕ϬϬϬ ϭϭϵ ϭϭϵ Ϭ͗Ϭϯ͗ϱϴ ϭ͗Ϯϴ͗ϭϴ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϯ ϯϱη,LJďŽƌ' WĂĚ ϯϬ ϯϯ͕ϬϬϬ ϳϴϲ ϳϴϲ Ϭ͗Ϯϲ͗ϭϭ ϭ͗Ϯϰ͗ϮϬ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϰ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϭ͘ϬϬ ϯϬ ϰ͕ϵϬϬ ϭϭϳ ϭϮϮ ϰ͕ϵϬϬ Ϭ͗Ϭϰ͗Ϭϰ Ϭ͗ϱϴ͗Ϭϴ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϱ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ Ϯ͘ϬϬ ϯϬ ϳ͕ϳϬϬ ϭϴϯ ϮϬϬ ϭϱ͕ϰϬϬ Ϭ͗Ϭϲ͗ϰϬ Ϭ͗ϱϰ͗Ϭϰ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϲ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϯ͘ϬϬ ϯϬ ϵ͕ϴϱϬ Ϯϯϱ Ϯϲϲ Ϯϵ͕ϱϱϬ Ϭ͗Ϭϴ͗ϱϯ Ϭ͗ϰϳ͗Ϯϰ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϳ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϰ͘ϬϬ ϯϬ ϭϮ͕ϲϱϬ ϯϬϭ ϯϱϲ ϱϬ͕ϲϬϬ Ϭ͗ϭϭ͗ϱϮ Ϭ͗ϯϴ͗ϯϭ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϴ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϰ͘ϱϬ ϯϬ ϭϬ͕ϭϬϬ ϮϰϬ Ϯϴϵ ϰϱ͕ϰϱϬ Ϭ͗Ϭϵ͗ϰϬ Ϭ͗Ϯϲ͗ϯϵ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϭϵ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϱ͘ϬϬ ϯϬ ϲ͕ϰϳϬ ϭϱϰ ϭϴϵ ϯϮ͕ϯϱϬ Ϭ͗Ϭϲ͗ϭϴ Ϭ͗ϭϲ͗ϱϵ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϮϬ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϱ͘ϱϬ ϯϬ ϰ͕ϵϬϬ ϭϭϳ ϭϰϲ Ϯϲ͕ϵϱϬ Ϭ͗Ϭϰ͗ϱϮ Ϭ͗ϭϬ͗ϰϭ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϮϭ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϲ͘ϬϬ ϯϬ ϯ͕ϯϬϬ ϳϵ ϭϬϬ ϭϵ͕ϴϬϬ Ϭ͗Ϭϯ͗ϮϬ Ϭ͗Ϭϱ͗ϰϵ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϭͲϮϮ ϯϱη,LJďŽƌ' ^ƉĂĐĞƌĂŶĚĂƌƚƌŽƉ ϭϮ ϭ͕ϮϱϬ ϯϬ ϯϬ Ϭ͗ϬϮ͗Ϯϵ Ϭ͗ϬϮ͗Ϯϵ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬ Ϭ͘ϭϱϮͲϭ ϯϱη>ŝŶĞĂƌ WƌĞͲWĂĚ ϯϬ ϴ͕ϰϬϬ ϮϬϬ ϮϬϬ Ϭ͗Ϭϲ͗ϰϬ ϭ͗ϯϲ͗ϯϲ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϮ ϯϱη,LJďŽƌ' WĂĚ ϯϬ ϯϮ͕ϬϬϬ ϳϲϮ ϳϲϮ Ϭ͗Ϯϱ͗Ϯϰ ϭ͗Ϯϵ͗ϱϲ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϯ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϭ͘ϬϬ ϯϬ ϰ͕ϱϬϬ ϭϬϳ ϭϭϮ ϰ͕ϱϬϬ Ϭ͗Ϭϯ͗ϰϰ ϭ͗Ϭϰ͗ϯϯ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϰ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ Ϯ͘ϬϬ ϯϬ ϳ͕ϰϬϬ ϭϳϲ ϭϵϮ ϭϰ͕ϴϬϬ Ϭ͗Ϭϲ͗Ϯϱ ϭ͗ϬϬ͗ϰϵ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϱ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϯ͘ϬϬ ϯϬ ϵ͕ϬϬϬ Ϯϭϰ Ϯϰϯ Ϯϳ͕ϬϬϬ Ϭ͗Ϭϴ͗Ϭϳ Ϭ͗ϱϰ͗Ϯϰ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϲ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϰ͘ϬϬ ϯϬ ϭϭ͕ϱϬϬ Ϯϳϰ ϯϮϯ ϰϲ͕ϬϬϬ Ϭ͗ϭϬ͗ϰϴ Ϭ͗ϰϲ͗ϭϳ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϳ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϰ͘ϱϬ ϯϬ ϵ͕ϬϬϬ Ϯϭϰ Ϯϱϴ ϰϬ͕ϱϬϬ Ϭ͗Ϭϴ͗ϯϳ Ϭ͗ϯϱ͗Ϯϵ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϴ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϱ͘ϬϬ ϯϬ ϱ͕ϳϱϭ ϭϯϳ ϭϲϴ Ϯϴ͕ϳϱϱ Ϭ͗Ϭϱ͗ϯϲ Ϭ͗Ϯϲ͗ϱϯ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϵ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϱ͘ϱϬ ϯϬ ϰ͕ϵϬϬ ϭϭϳ ϭϰϲ Ϯϲ͕ϵϱϬ Ϭ͗Ϭϰ͗ϱϮ Ϭ͗Ϯϭ͗ϭϲ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϭϬ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϲ͘ϬϬ ϯϬ ϯ͕ϯϬϬ ϳϵ ϭϬϬ ϭϵ͕ϴϬϬ Ϭ͗Ϭϯ͗ϮϬ Ϭ͗ϭϲ͗Ϯϱ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϭϭ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϳ͘ϬϬ ϯϬ Ϯ͕ϯϴϱ ϱϳ ϳϱ ϭϲ͕ϲϵϱ Ϭ͗ϬϮ͗ϯϬ Ϭ͗ϭϯ͗Ϭϰ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϭϮ ϯϱη>ŝŶĞĂƌ &ůƵƐŚ ϯϬ ϵ͕ϯϮϴ ϮϮϮ ϮϮϮ Ϭ͗Ϭϳ͗Ϯϰ Ϭ͗ϭϬ͗ϯϱ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϮͲϭϯ &ƌĞĞnjĞWƌŽƚĞĐƚ &ƌĞĞnjĞWƌŽƚĞĐƚ ϭϱ Ϯ͕ϬϬϬ ϰϴ ϰϴ Ϭ͗Ϭϯ͗ϭϬ Ϭ͗Ϭϯ͗ϭϬ ϭϬϬϬ͘ϬϬϮͲϭϰ ^ŚƵƚͲ/Ŷ ^ŚƵƚͲ/ŶϯͲϭ ^ŚƵƚͲ/Ŷ ^ŚƵƚͲ/Ŷϭ͗ϱϯ͗ϯϲϯͲϮ &ƌĞĞnjĞWƌŽƚĞĐƚ WƌŝŵĞhƉWƌĞƐƐƵƌĞdĞƐƚ ϭϬ ϭ͕ϱϬϬ ϯϲ ϯϲ Ϭ͗Ϭϯ͗ϯϰ ϭ͗ϱϯ͗ϯϲ ϭϬϬϬ͘ϬϬϯͲϯ ^ŚƵƚͲ/Ŷ ^ŚƵƚͲ/Ŷϭ͗ϱϬ͗ϬϭϯͲϰ ϯϱη>ŝŶĞĂƌ ^ƉĂĐĞƌĂŶĚĂƌƚƌŽƉ ϭϮ ϱ͕ϬϬϬ ϭϭϵ ϭϭϵ Ϭ͗Ϭϵ͗ϱϱ ϭ͗ϱϬ͗Ϭϭ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϱ ϯϱη>ŝŶĞĂƌ WƌĞͲWĂĚ ϯϬ ϴ͕ϰϬϬ ϮϬϬ ϮϬϬ Ϭ͗Ϭϲ͗ϰϬ ϭ͗ϰϬ͗Ϭϲ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϲ ϯϱη>ŝŶĞĂƌ ƐƚĂďůŝƐŚ^ƚĂďůĞ&ůƵŝĚ ϯϬ ϱ͕ϬϬϬ ϭϭϵ ϭϭϵ Ϭ͗Ϭϯ͗ϱϴ ϭ͗ϯϯ͗Ϯϲ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϳ ϯϱη,LJďŽƌ' WĂĚ ϯϬ ϯϮ͕ϬϬϬ ϳϲϮ ϳϲϮ Ϭ͗Ϯϱ͗Ϯϰ ϭ͗Ϯϵ͗Ϯϴ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϴ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϭ͘ϬϬ ϯϬ ϰ͕ϱϬϬ ϭϬϳ ϭϭϮ ϰ͕ϱϬϬ Ϭ͗Ϭϯ͗ϰϰ ϭ͗Ϭϰ͗Ϭϰ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϵ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ Ϯ͘ϬϬ ϯϬ ϳ͕ϰϬϬ ϭϳϲ ϭϵϮ ϭϰ͕ϴϬϬ Ϭ͗Ϭϲ͗Ϯϱ ϭ͗ϬϬ͗ϮϬ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϬ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϯ͘ϬϬ ϯϬ ϵ͕ϬϬϬ Ϯϭϰ Ϯϰϯ Ϯϳ͕ϬϬϬ Ϭ͗Ϭϴ͗Ϭϳ Ϭ͗ϱϯ͗ϱϲ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϭ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϰ͘ϬϬ ϯϬ ϭϭ͕ϱϬϬ Ϯϳϰ ϯϮϯ ϰϲ͕ϬϬϬ Ϭ͗ϭϬ͗ϰϴ Ϭ͗ϰϱ͗ϰϴ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϮ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϰ͘ϱϬ ϯϬ ϵ͕ϬϬϬ Ϯϭϰ Ϯϱϴ ϰϬ͕ϱϬϬ Ϭ͗Ϭϴ͗ϯϳ Ϭ͗ϯϱ͗Ϭϭ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϯ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϱ͘ϬϬ ϯϬ ϱ͕ϳϱϭ ϭϯϳ ϭϲϴ Ϯϴ͕ϳϱϱ Ϭ͗Ϭϱ͗ϯϲ Ϭ͗Ϯϲ͗Ϯϰ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϰ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϱ͘ϱϬ ϯϬ ϰ͕ϵϬϬ ϭϭϳ ϭϰϲ Ϯϲ͕ϵϱϬ Ϭ͗Ϭϰ͗ϱϮ Ϭ͗ϮϬ͗ϰϴ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϱ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϲ͘ϬϬ ϯϬ ϯ͕ϯϬϬ ϳϵ ϭϬϬ ϭϵ͕ϴϬϬ Ϭ͗Ϭϯ͗ϮϬ Ϭ͗ϭϱ͗ϱϲ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϲ ϯϱη,LJďŽƌ' WƌŽƉƉĂŶƚ>ĂĚĞŶ&ůƵŝĚ tĂŶůŝϮϬͬϰϬĞƌĂŵŝĐ ϳ͘ϬϬ ϯϬ Ϯ͕ϯϴϱ ϱϳ ϳϱ ϭϲ͕ϲϵϱ Ϭ͗ϬϮ͗ϯϬ Ϭ͗ϭϮ͗ϯϲ Ϯ͘ϲϬ ϭ͘ϬϬ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϳ ϯϱη>ŝŶĞĂƌ &ůƵƐŚ ϯϬ ϴ͕ϳϯϭ ϮϬϴ ϮϬϴ Ϭ͗Ϭϲ͗ϱϲ Ϭ͗ϭϬ͗Ϭϲ ϭ͘ϬϬ ϯϱ͘ϬϬ Ϯ͘ϬϬϬ͘ϭϱϯͲϭϴ &ƌĞĞnjĞWƌŽƚĞĐƚ &ƌĞĞnjĞWƌŽƚĞĐƚ ϭϱ Ϯ͕ϬϬϬ ϰϴ ϰϴ Ϭ͗Ϭϯ͗ϭϬ Ϭ͗Ϭϯ͗ϭϬ ϭϬϬϬ͘ϬϬϯͲϭϵ ^ŚƵƚͲ/Ŷ ^ŚƵƚͲ/Ŷϯϵϭ͕ϴϱϬ ϵ͕ϯϯϬ ϭϬ͕Ϭϱϴ ϲϳϱ͕ϬϬϬĞƐŝŐŶdŽƚĂů;ŐĂůͿĞƐŝŐŶdŽƚĂů;ůďƐͿ>ͲϮϮh >ŽƐƵƌĨͲϯϬϬ DKͲϲϳ >sdͲϮϬϬ t'Ͳϯϲ KƉƚŝ&ůŽͲ/// ^WƌĞĂŬĞƌ ͲϲϮϳϵ͕ϴϵϮϲϳϱ͕ϬϬϬ;ŐĂůͿ ;ŐĂůͿ ;ŐĂůͿ ;ŐĂůͿ ;ůďƐͿ ;ůďƐͿ ;ůďƐͿ ;ůďƐͿϭϬϰ͕ϵϱϴͲ/ŶŝƚŝĂůĞƐŝŐŶDĂƚĞƌŝĂůsŽůƵŵĞ ϳϮϳ͘ϳ ϯϴϰ͘ϴ Ϯϳϵ͘ϵ ϳ͕ϬϬϬ͘Ϭ ϭϯ͕ϰϲϵ͘ϳ ϳϲϵ͘ϳ ϱϳ͘ϳͲϳ͕ϬϬϬͲͲͲ>ͲϮϮh >ŽƐƵƌĨͲϯϬϬ DKͲϲϳ >sdͲϮϬϬ t'Ͳϯϲ KƉƚŝ&ůŽͲ/// ^WƌĞĂŬĞƌ ͲϲͲϵ͕ϯϯϬ;ŐƉŵͿ ;ŐƉŵͿ ;ŐƉŵͿ ;ŐƉŵͿ ƉƉŵ ƉƉŵ ƉƉŵ ƉƉŵͲDĂdžĚĚŝƚŝǀĞZĂƚĞ ϯ͘ϯ ϭ͘ϯ ϭ͘ϯ ϭ͕ϮϲϬ͘Ϭ ϰϰ͘ϭ Ϯ͘ϱ Ϭ͘ϲ Ϭ͘ϮͲDŝŶĚĚŝƚŝǀĞZĂƚĞϭͬϮϬͬϮϮ>ŝƋƵŝĚĚĚŝƚŝǀĞƐƌLJĚĚŝƚŝǀĞƐϱϬͲϭϬϯͲϮϬϴϯϯ&ůƵŝĚdLJƉĞϯϱη,LJďŽƌ'ϯϱη>ŝŶĞĂƌ^ĞĂǁĂƚĞƌ&ƌĞĞnjĞWƌŽƚĞĐƚͲͲͲͲWƌŽƉƉĂŶƚdLJƉĞtĂŶůŝϮϬͬϰϬĞƌĂŵŝĐͲͲͲͲ,QWHUYDO$/36DQG#IW ),QWHUYDO$/36DQG# IW ),QWHUYDO$/36DQG#IW )ϲ͗Ϯϲ͗ϱϳŽŶŽĐŽWŚŝůůŝƉƐͲDdϳͲϬϱWůĂŶŶĞĚĞƐŝŐŶϭ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All rights reserved.MT7 Model 2© 2021 Halliburton. All rights reserved.Base CaseRendezvous 3 LogUpdated Pump schedules for MT7-0530bpm rate 3© 2021 Halliburton. All rights reserved.DisclaimerThese models was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results 4© 2021 Halliburton. All rights reserved.Interval 01 Pump Schedule 5© 2021 Halliburton. All rights reserved.Interval 01 Height ResultsMax Height TVD: 8205ftHeight Growth: 110ftAvg Width: .287inPropped Half Length: 620ftALP D Top 8155 ftALP C Top 8210 ft 6© 2021 Halliburton. All rights reserved.Interval 02-04 Pump Schedules 7© 2021 Halliburton. All rights reserved.Interval 02 Height ResultsMax Height TVD: 8205ftHeight Growth: 110ftAvg Width: 0.3036inPropped Half Length: 660ftALP D Top 8155 ftALP C Top 8210 ft 8© 2021 Halliburton. All rights reserved.Interval 03 Height ResultsMax Height TVD: 8205ftHeight Growth: 110ftAvg Width: 0.312inPropped Half Length: 740ftALP D Top 8155 ftALP C Top 8210 ft 9© 2021 Halliburton. All rights reserved.Interval 04 Height Results Max Height TVD: 8195ftHeight Growth: 120ftAvg Width: 0.3036inPropped Half Length: 640ftALP D Top 8155 ftALP C Top 8210 ft 10© 2021 Halliburton. All rights reserved. !"# $ %$ &' ( '& )* '+, % - '. //0' - %'$ (( - & 123 4 5( % ( 6 4 ! "## $# % &' (# ( " ) " * + , - . / $ 0 $ 1 2/ 3 %,.4' 5!#6# !7 8 8 * 58 *8 6 ##(79 + /# . 5/# .+6 ##(79 + , * ! 5"!6 ##(79 : 0 50 : 6 ##(79 ;<< = 5= ;<<6 ##(79 / 0 5/ 0 6 ##(79 8## , 3 5, 38## 6 ##(7 / > 3" (# # " + # #" (# # $ <! # ##" <$ #" ( "## "## " $ <" / #? ( " @,2A @422A B +C # ! 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( #? ) "##< $ " , > E> %' % '%,' 1 2 ( ( " ## 8; # # " HH + ## 8; "##< " # " ( ( @C## ## " $ * 2# I + , - . $ $ 4 J &# " 6 ##( BEF>FF %-' 1 Carlisle, Samantha J (OGC) From:Regg, James B (OGC) Sent:Thursday, January 13, 2022 12:16 PM To:AOGCC Records (CED sponsored) Subject:FW: D25 MT7-05 Attachments:MT7-05 Lower completion stuck pipe and proposed plan forward Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: WSC Rig Advisor <wscrigadvisor@conocophillips.com> Sent: Tuesday, January 11, 2022 5:38 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Hull, Celie <Cecilia.Hull@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; WSC Operations Engineer <wscopsengineer@conocophillips.com>; Hull, Celie <Cecilia.Hull@conocophillips.com> Subject: D25 MT7‐05 All, BOPE use to prevent flow has been previously reported in attached email. This email is to unsure it reaches all required. Date, Time of BOPE Use 1/10/22 at 10:20 AM Well/Location/PTD Number MT7-05, Alpine, 221-087 Rig Name Doyon 25 Operator Contact Greg Hobbs 907-263-4749 Operations Summary, including events leading up to BOPE use Running lower completion liner. Observed some losses to wellbore requiring lower running speeds. Observed incorrect pipe displacement and flow observed, well shut in. Performed 2 ea 2 bbl bleed offs with no pressure reduction, circulated existing 9.0 ppg mud to heel, pressures reduced to 0 on DP and 65psi on csg. Observed string was stuck. Circulated 9.0 ppg mud around to surface through choke, observed well static, open preventer and continued completion operations. BOPE Used Upper VBRs, annular, choke system Reason for BOPE Use To diagnose flow from wellbore Actions TakenITo Be Taken (including the date used BOPE was tested) Will test BOPE components used when out of hole. Currently coming out of hole and anticipate testing BOPE components used (UPR VBR, Annular and utilized choke components) 1/12/22 at 8AM Some people who received this message don't often get email from wscrigadvisor@conocophillips.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 CPAI WSC Rig Advisor wscrigadvisor@conocophillips.com 1-907-263-4546 1 Carlisle, Samantha J (OGC) From:WSC Operations Engineer <wscopsengineer@conocophillips.com> Sent:Monday, January 10, 2022 9:02 PM To:Loepp, Victoria T (OGC) Cc:Buck, Brian R; Woodard, Madeline E; WSC Rig Advisor; Njoku, Johnson; Hobbs, Greg S; Vanderhorst, Mark J; Brillon, Chris L Subject:MT7-05 Lower completion stuck pipe and proposed plan forward Attachments:MT7-05 4 String - Liner as run.pdf Victoria, While running the lower completion into open hole today the rig observed losses, followed by flow from the well. The well was shut in today between 10‐11AM utilizing the upper pipe rams with SICP=122 psi and SIDPP= 60 psi. We’d like this note to serve as the required notification to AOGCC in accordance with 20 AAC 25.035 (e) (11). Next, 175 bbls of 9.0 ppg was circulated down the drill pipe taking returns through the choke. Pressures after the circulation were rechecked at SIDPP=0 and SICP=65 psi. Before attempting to move the pipe, the annular BOP was closed, and the pipe rams were opened. At this stage an attempt was made to continue running the liner in the well with the drillpipe running string. However, no pipe movement was possible. The pipe was worked up to a maximum pickup weight minus a safety factor and the pipe did not move. After evaluating options, ConocoPhillips would like set the lower completion at the current location and proposes the following plan forward: 1. Attempt to free pipe without failing any of the completion equipment 2. Circulate a 9.0 ppg mud surface to surface 3. If pipe is not free proceed to set the completion where it is (shoe 20,773’, liner top packer 11,426’). See proposed schematic attached. 4. Implications on the frac stimulation include not fracturing through two frac sleeves noted below: a. Current frac sleeve, swell packer, and 7” shoe locations: i. Frac Sleeve 11,868’ – Inside Casing – No Frac ii. Swell packer – 12,202’ iii. 7” Casing Shoe 12,252’ iv. Frac Sleeve 12,677’ – No Frac v. Swell Packer – 13,135’ vi. Frac Sleeve – 13,652’ vii. Swell Packer – 14,109’ viii. Frac Sleeve –14,584’ ix. Swell Packer – 15,081’ x. Frac Sleeve – 15,556’ xi. Swell Packer – 16,052’ 5. The proposed completion packer setting depth is : 11,323’ After pulling the liner running string from the well, we plan to test the BOPE components utilized prior to the next wellbore reentry in accordance with 20 AAC 25.035 (e) (10)(C) 2 Note: Pore pressure determined from fingerprinting with the drilling BHA on the final trip out of the hole was 8.8 ppg. With the drilling BHA at the 7” casing shoe the wellbore was displace with 9.0 ppg mud from the 7” shoe to surface. I’ll call to discuss this with you. Regards, Scott Polaris – WSC Operations Engineer Sydney Deering / Scott Kolstad wscopsengineer@conocophillips.com 907.263.4544 (Office) Tubing / Liner Completion: 1) 4-½” ‘X’ Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG 4-5 GLM (3x) 3) HES Opsis Downhole Gauge 4) Baker Premier Production Packer 5) 4-½” ‘DB” Landing Nipple (3.75" ID) w/ RHC Plug Body 6) Baker ZXP Liner Top Packer / Flex-Lock Hanger w/ Tie Back sleeve 4-½” 12.6# L-80 Hyd563 Liner Non-Stimulated frac: 11,868' MD Swell #5: 12,202' MD Non-Stimulated Frac Sleeve: 12,677' MD Swell #4: 13,135' MD Stimulated Frac Sleeve #3: 13,652' MD Swell #3: 14,109' MD Stimulated Frac Sleeve #2: 14,584' MD Swell #2: 15,081' MD Stimulated Frac Sleeve #1: 15,556' MD Swell #1: 16,052' MD 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-3/16” Production Hole TD at 21,916' MD / 8,296' TVD Tubing 4-1/2" 12.6# L-80 Hyd563 MT7-05 X GLGL GLGL 1/10/2022 MEW Production Packer ~11,323' MD 16" Surface Hole Surface Casing 13-3/8" 68# L-80 Hyd563 set at 3,515' MD / 3061' TVD 8-½” X 9-7/8" Intermediate 2 Hole Intermediate 2 Liner 7" 26# L-80 Hyd563 to 11,195' MD X 7" 29# TN-110SS Hyd563 (Special drift to 6.125") Liner top at 10,401' MD / 7,377' TVD Shoe at 12,252' MD / 8,298' TVD 12-¼” Intermediate 1 Hole Intermediate 1 Casing 9-5/8" 43.5# L-80 TXP & 9-7/8" 62.8 Hyd523 Set at 10,566' MD / 7,482' TVD Top HRZ 10,546' MD / 7,470' TVD 4-String Northern Producer Proposed Completion Top Alpine D 12,158' MD / 8,271' TVD Estimated Int1 TOC 10,066' MD / 7,158' TVD Evaluated Int2 TOC 11,900' MD / 8,185' TVD Liner Top Packer 11,417' MD Top Alpine C 12,302' MD / 8,310' TVD SP #1SP #2SP #3SP #4 SP #5 FS #1FS #2FS #3FS #4 FS #5 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:Ward, Dusty K To:Loepp, Victoria T (OGC) Cc:NSK RWO CM; Senden, R. Tyler; DOA AOGCC Prudhoe Bay; Regg, James B (OGC) Subject:3M-05 MPSP update Date:Sunday, January 2, 2022 10:41:46 AM Attachments:9_3M-05 10-403 RWO APPROVED - Copy.pdf EXTERNALKRU 3M-05 Test Pressure to 2700 psig..msg Victoria, Hope this finds you well. We’ve made it through the subsidence portion on this well pretty smoothly! We’re now back on scope removing the lower packer and tubing tail with plug installed in preparation to install the Tandem Wedges for upcoming CTD. I just sent a BOPE closure email to you with the details, but effectively, once we re-established communication with formation, the BHP has appeared to have charged up a bit since our last SBHP. I wanted to follow up with you also with this correspondence. Our new MPSP calculated with the pressure we’re seeing at surface and the pressure we still had on drill pipe with 10.2ppg around is: 2836 psig MPSP. (10.2ppg x 0.052 x 6168 TVD (top perf)) + ~ 180 psig on DP= 3452 psi for the estimated BHP. 3452 psi – 616 psi = 2836 psig MPSP. Our plan forward is: Increase KWF until we get a no flow test. (Currently circulating 10.7 ppg in.) Will do an additional weight up if still seeing pressure on DP. Since it’s just A-sand, we think we might be charging it up a bit, so will check for ballooning. TOOH with DP Re-test full BOPE to 3500 psig on 3.5” OD joint. This is because our last BOPE test was too 2700 psig, based on most recent SBHP. We’re now on a 5k tubing head (versus the 3k casing head we were on during subsidence portion), so we’ll just go to the 3500 psig for good measure. The new MPSP we’re calculating based on fluids in hole and pressure at surface is 2834 psig. We have less than 300’ of 2-7/8” left in the hole (only about 125’), so plan to treat that as BHA. Back to fishing last part of the 2-7/8” completion. It should come out in 2 small sections if the seals pull off of the SBR. The rig will stay in communication with your field team for planning the next BOPE test when we’re out of hole. I think we were getting close to the bi-weekly test anyways. Please forward as appropriate. I think I got the right emails in the cc for BOPE specific items. Thanks for your time and let me know if you have any questions. Have a great day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 1 Junke, Kayla M (OGC) From:WSC Operations Engineer <wscopsengineer@conocophillips.com> Sent:Saturday, December 25, 2021 1:30 PM To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; WSC Rig Advisor; Hull, Celie; Lee, David L; Buck, Brian R; Woodard, Madeline E Subject:MT7-05 Intermediate II Cement Update Follow Up Flag:Follow up Flag Status:Flagged Hi Victoria, Operational update on MT7‐05: ‐ Rigged up E‐Line and RIH with CBL to obtain top of cement on the 7” liner ‐ E‐line tagged up at 11,730’ MD on a potential cement stringer and was to get any deeper in the wellbore Current operations: ‐ Pulling out of hole with E‐Line Plan forward on MT7‐05: ‐ Finish pulling out of hole with E‐Line ‐ PU cleanout BHA with SonicScope ‐ RIH and clean out down to above 7” liner shoe that is set at 12,252’ MD ‐ Obtain free ringing pipe, log intermediate I cement, and log intermediate II cement The results of the SonicScope will be submitted to the AOGCC after they have been processed with cement interpretation. With SonicScope logs indicating good cement, ConocoPhillips will plan to procced with drilling the production hole as per plan. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) 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. 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:WSC Operations Engineer To:Loepp, Victoria T (OGC) Cc:Njoku, Johnson; Hull, Celie; WSC Rig Advisor; Lee, David L; Buck, Brian R; Woodard, Madeline E Subject:MT7-05 Intermediate 2 Cement Operations Update Date:Friday, December 24, 2021 9:54:25 AM Attachments:image001.png MT7-05 Intermediate 2 Plot Report.pdf RE EXTERNALMT7-05 (PTD #221-087 Sundry 321-632) Schematic.msg Hi Victoria, Doyon 25 performed MT7-05’s intermediate 2 liner cement operation on 12/23/21 from 19:30 to 23:30 with the following order of operations and results: MT7-05 Intermediate 2 Liner Cement Operations Summary Shoe depth 12,252’ MD / 8,298’ TVD Planned TOC 11,500’ MD / 8,013’ TVD Top of Alpine D 12,158’ MD / 8,271’ TVD Pumped 60 bbls of 13.0 ppg mud push II Dropped bottom dart followed by 52 bbls of 15.8 ppg cement Dropped top dart, pumped 20 bbls of water and displaced with 10.5 ppg mud system Both darts latched into plug system, plugs were bumped and floats held Liner hanger and liner top packer were both set successfully Lift pressure and returns were observed during cement displacement with 27 bbls of losses Cement was in place at 23:23 on 12/23/21 MT7-05 Path Forward Doyon 25 is now tripping out of the hole with 5” DP and will proceed to perform a BOP test. After BOP testing Doyon 25 will perform the following: Pick up and make up 6-1/8” production hole BHA with SonicScope Log intermediate 1 and 2 top of cements with SonicScope (in memory mode) Pressure test intermediate 2 liner to 3,500 psi for 30 min Drillout shoe track and perform FIT to 11.5 ppg min. / 13.5 ppg max. RU RCD and displace to 8.8 ppg versapro mud system Drill 6-1/8” production section to TD of ~22,262’ MD / 8,292’ TVD The results of the SonicScope will be submitted after TD of the production section and tripping to surface. Attached for reference is the current schematic. Also, please find attached the previously sent information regarding the successful MT7-05 intermediate 1 cement operation which placed the intermediate 1 casing shoe in the HRZ formation. Please let us know if you have any concerns with the above plan forward. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) 12/24/2021 01:27:21 Cementing Job Report CemCAT v1.7 Well MT7-05 Field GPB Engineer Country United States Client COPA SIR No. Job Type 7" LINER Job Date 12-23-2021 Time 12/23/2021 03:06:35 12/23/2021 23:25:23 hh:mm:ss 20:21:14 20:36:00 20:51:00 21:06:00 21:21:00 21:36:00 21:51:00 22:06:00 22:21:00 22:36:00 22:51:00 23:06:00 23:25:23 23:25:23 Pressure PSI 0.00 1200 2400 3600 4800 6000 Rate B/M 0.00 2.0 4.0 6.0 8.0 10.0 Density LB/G 5.0 9.0 13.0 17.0 21.0 25.0 WHP PSI 0.00 1200 2400 3600 4800 6000 Messages Fill lines Reset Total, Vol = 2.00 bbl Low PT, trips work High PT Good PT, bleed off Start spacer End Spacer Reset Total, Vol = 60 bbl Drop Bottom Plug CMT wet Start cmt mix water temp+ 83 deg mud ballance @ 15.8 ppg Reset Total, Vol = 52 bbl End cmt Drop Top Plug Pump water behind Reset Total, Vol = 20 bbl turn over to rig Bumped plug Bump plug @ 2116 storkes Customer COPA Job NumberWellMT7-05 Location (legal)Alpine Schlumberger Location Job StartDec/23/2021FieldGPBFormation Name/Type Deviation deg Bit Size in Well MD ft Well TVD ftCountyState/ProvinceWell Master API/UWI BHP psi BHST degF BHCT degF Pore Press. Gradient lb/galRig Name Drilled For Service Via Offshore Zone Well Class Well Type Drilling Fluid Type Max. Density lb/gal Plastic Viscosity cP Service Line Cementing Job Type 7" LINER Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection Service Instructions Treat Down Displacement bbl Packer Type Packer Depth ft Tubing Vol. bbl Casing Vol. bbl Annular Vol. bbl Openhole Vol. bbl Casing/Tubing Secured 1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze Job Lift Pressure psi Shoe Type Squeeze Type Pipe Rotated Pipe Reciprocated Shoe Depth ft Tool Type No. Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Dec/23/2021 Arrived on Location Dec/23/2021 Leave Location Dec/23/2021 Collar Type Tail Pipe Depth ft Collar Depth ft Sqz. Total Vol. bbl Casing/LinerDepth, ft Size, in Weight, lb/ft Grade Thread Tubing/Drill Pipe T/D Depth, ft Size, in Weight, lb/ft Grade Thread Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval ft ft ft ft ft Diameter in ft ft Cementing Service Report Date Time 24-hr clock Treating Pressure PSI Flow Rate B/M Density LB/G Stage BBL Total BBL WHP PSI Message 12/23/2021 03:06:35 -6 0.0 0.01 0.0 0.0 -3665 Started Acquisition 12/23/2021 03:08:05 102 4.0 0.01 0.5 0.5 -3665 12/23/2021 03:09:35 97 0.0 0.01 0.0 0.0 -3664 12/23/2021 03:11:05 2 0.0 0.01 0.0 0.0 -3665 12/23/2021 03:11:28 -1 0.0 0.00 0.0 0.0 -3667 Rate checks good 12/23/2021 20:21:35 -7 0.0 0.01 0.0 0.0 72 12/23/2021 20:22:22 13 1.9 0.01 0.5 0.5 87 Fill lines 12/23/2021 20:23:05 308 0.7 0.00 1.8 1.8 343 12/23/2021 20:24:35 96 0.0 0.00 2.0 2.0 159 12/23/2021 20:25:30 86 0.0 0.01 2.0 2.0 153 Reset Total, Vol = 2.00 bbl 12/23/2021 20:26:05 84 0.0 0.01 0.0 2.0 150 12/23/2021 20:26:39 648 0.0 0.01 0.0 2.0 728 Low PT, trips work 12/23/2021 20:27:35 2739 0.0 0.01 0.0 2.0 2829 12/23/2021 20:28:35 4536 0.0 0.01 0.0 2.0 4625 High PT 12/23/2021 20:29:05 4526 0.0 0.01 0.0 2.0 4613 12/23/2021 20:29:56 1113 0.0 0.00 0.0 2.0 1142 Good PT, bleed off 12/23/2021 20:30:35 31 0.0 0.00 0.0 2.0 175 12/23/2021 20:32:05 83 0.0 0.00 0.0 2.0 172 12/23/2021 20:33:35 79 0.0 10.86 0.0 2.0 160 12/23/2021 20:35:05 84 0.0 12.95 0.0 2.0 181 12/23/2021 20:35:56 251 1.0 13.03 0.3 2.3 373 Start spacer Page 1 of 4 Customer COPA Job NumberWellMT7-05 Location (legal)Alpine Schlumberger Location Job StartDec/23/2021FieldGPBFormation Name/Type Deviation deg Bit Size in Well MD ft Well TVD ftCountyState/ProvinceWell Master API/UWI BHP psi BHST degF BHCT degF Pore Press. Gradient lb/galRig Name Drilled For Service Via Offshore Zone Well Class Well Type Drilling Fluid Type Max. Density lb/gal Plastic Viscosity cP Service Line Cementing Job Type 7" LINER Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection Service Instructions Treat Down Displacement bbl Packer Type Packer Depth ft Tubing Vol. bbl Casing Vol. bbl Annular Vol. bbl Openhole Vol. bbl Casing/Tubing Secured 1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze Job Lift Pressure psi Shoe Type Squeeze Type Pipe Rotated Pipe Reciprocated Shoe Depth ft Tool Type No. Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Dec/23/2021 Arrived on Location Dec/23/2021 Leave Location Dec/23/2021 Collar Type Tail Pipe Depth ft Collar Depth ft Sqz. Total Vol. bbl Casing/LinerDepth, ft Size, in Weight, lb/ft Grade Thread Tubing/Drill Pipe T/D Depth, ft Size, in Weight, lb/ft Grade Thread Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval ft ft ft ft ft Diameter in ft ft Cementing Service Report Well MT7-05 Field GPB Job StartDec/23/2021 Customer COPA Job NumberDateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G StageBBL TotalBBL WHPPSI Message12/23/2021 20:38:05 428 2.0 12.98 3.7 5.7 477 12/23/2021 20:39:35 430 2.1 12.88 6.8 8.8 458 12/23/2021 20:41:05 447 2.5 12.81 10.2 12.2 453 12/23/2021 20:42:35 408 2.5 12.91 14.0 16.0 420 12/23/2021 20:44:05 477 3.1 12.91 18.0 20.0 434 12/23/2021 20:45:35 463 3.1 13.13 22.5 24.5 407 12/23/2021 20:47:05 390 3.0 13.05 27.1 29.1 363 12/23/2021 20:48:35 371 3.0 12.77 31.7 33.7 337 12/23/2021 20:50:05 353 3.0 13.06 36.3 38.3 306 12/23/2021 20:51:35 306 3.0 12.96 40.8 42.8 274 12/23/2021 20:53:05 253 2.8 12.79 45.4 47.4 227 12/23/2021 20:54:35 194 2.5 12.91 49.2 51.2 191 12/23/2021 20:56:05 126 2.0 12.98 52.5 54.5 152 12/23/2021 20:57:35 122 2.0 12.98 55.6 57.6 141 12/23/2021 20:59:05 98 2.0 12.82 58.7 60.7 106 12/23/2021 21:00:04 16 0.0 12.84 60.0 62.0 88 End Spacer 12/23/2021 21:00:13 4 0.0 12.80 60.0 62.0 84 Reset Total, Vol = 60 bbl 12/23/2021 21:00:35 5 0.0 12.80 0.0 62.0 85 12/23/2021 21:00:36 3 0.0 12.79 0.0 62.0 87 Drop Bottom Plug 12/23/2021 21:02:05 6 0.0 8.63 0.0 62.0 83 12/23/2021 21:02:36 8 0.0 10.68 0.0 62.0 85 CMT wet 12/23/2021 21:03:35 11 0.0 14.72 0.0 62.0 87 12/23/2021 21:05:05 13 0.0 15.85 0.0 62.0 83 12/23/2021 21:06:35 93 1.0 15.83 1.1 63.1 94 12/23/2021 21:08:05 165 2.0 15.86 2.8 64.8 120 12/23/2021 21:09:35 162 2.0 15.86 5.9 67.8 139 12/23/2021 21:10:22 194 2.2 15.82 7.4 69.4 147 Start cmt 12/23/2021 21:11:05 214 2.5 15.72 9.2 71.2 154 12/23/2021 21:12:35 209 2.5 15.88 13.0 75.0 164 12/23/2021 21:14:05 229 2.5 15.74 16.8 78.8 159 12/23/2021 21:14:42 233 2.5 15.70 18.4 80.3 156 mix water temp+ 83 deg 12/23/2021 21:15:19 293 2.9 16.05 19.9 81.9 169 mud ballance @ 15.8 ppg 12/23/2021 21:15:35 324 3.1 16.09 20.7 82.7 182 12/23/2021 21:17:05 323 3.0 15.77 25.3 87.3 176 12/23/2021 21:18:35 328 3.1 15.88 29.9 91.9 178 12/23/2021 21:20:05 316 3.1 15.91 34.5 96.4 178 12/23/2021 21:21:35 335 3.0 16.00 39.0 101.0 178 12/23/2021 21:23:05 330 3.1 15.84 43.6 105.6 180 12/23/2021 21:24:35 240 2.6 15.98 47.7 109.7 162 12/23/2021 21:26:05 164 2.0 15.84 51.0 113.0 137 12/23/2021 21:26:46 24 0.0 15.84 52.0 113.9 91 Reset Total, Vol = 52 bbl 12/23/2021 21:26:57 22 0.0 15.84 0.0 113.9 90 End cmt 12/23/2021 21:27:09 21 0.0 15.85 0.0 113.9 89 Drop Top Plug 12/23/2021 21:27:35 24 0.0 15.84 0.0 113.9 89 12/23/2021 21:28:43 67 1.4 15.85 1.2 115.1 106 Pump water behind 12/23/2021 21:29:05 64 1.4 15.85 1.7 115.6 106 12/23/2021 21:30:35 142 3.0 15.85 5.7 119.7 97 12/23/2021 21:32:05 167 3.1 15.86 10.3 124.2 119 12/23/2021 21:33:35 164 3.0 15.85 14.9 128.8 121 12/23/2021 21:35:05 159 3.1 15.86 19.4 133.4 121 12/23/2021 21:35:28 38 0.0 15.86 20.0 134.0 98 Reset Total, Vol = 20 bbl 12/23/2021 21:35:52 26 0.0 15.86 0.0 134.0 102 turn over to rig 12/23/2021 21:36:35 29 0.0 15.86 0.0 134.0 153 12/23/2021 21:38:05 28 0.0 14.68 0.0 134.0 150 Page 2 of 4 Well MT7-05 Field GPB Job StartDec/23/2021 Customer COPA Job Number Well MT7-05 Field GPB Job StartDec/23/2021 Customer COPA Job NumberDateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G StageBBL TotalBBL WHPPSI Message12/23/2021 21:41:05 21 0.0 14.93 0.0 134.0 143 12/23/2021 21:42:35 19 0.0 15.03 0.0 134.0 162 12/23/2021 21:44:05 18 0.0 14.66 0.0 134.0 156 12/23/2021 21:45:35 19 0.0 12.78 0.0 134.0 163 12/23/2021 21:47:05 112 0.0 12.27 0.0 134.0 173 12/23/2021 21:48:35 6 0.0 12.15 0.0 134.0 173 12/23/2021 21:50:05 4 0.0 12.39 0.0 134.0 157 12/23/2021 21:51:35 -0 0.0 7.45 0.0 134.0 153 12/23/2021 21:53:05 3 0.0 8.35 0.0 134.0 158 12/23/2021 21:54:35 3 0.0 8.34 0.0 134.0 160 12/23/2021 21:56:05 2 0.0 8.34 0.0 134.0 160 12/23/2021 21:57:35 3 0.0 8.34 0.0 134.0 156 12/23/2021 21:59:05 3 0.0 8.33 0.0 134.0 157 12/23/2021 22:00:35 6 0.0 8.30 0.0 134.0 158 12/23/2021 22:02:05 1 0.0 8.30 0.0 134.0 155 12/23/2021 22:03:35 122 0.0 7.02 0.0 134.0 156 12/23/2021 22:05:05 19 0.0 6.89 0.0 134.0 818 12/23/2021 22:06:35 63 0.0 6.87 0.0 134.0 120 12/23/2021 22:08:05 138 0.0 6.87 0.0 134.0 130 12/23/2021 22:09:35 18 0.0 6.86 0.0 134.0 118 12/23/2021 22:11:05 126 0.0 6.84 0.0 134.0 110 12/23/2021 22:12:35 127 0.0 6.84 0.0 134.0 152 12/23/2021 22:14:05 8 0.0 4.32 0.0 134.0 210 12/23/2021 22:15:35 -3 0.0 0.01 0.0 134.0 142 12/23/2021 22:17:05 -3 0.0 0.01 0.0 134.0 174 12/23/2021 22:18:35 -5 0.0 0.00 0.0 134.0 197 12/23/2021 22:20:05 -3 0.0 0.00 0.0 134.0 219 12/23/2021 22:21:35 -5 0.0 0.01 0.0 134.0 255 12/23/2021 22:23:05 -4 0.0 0.01 0.0 134.0 289 12/23/2021 22:24:35 -7 0.0 0.01 0.0 134.0 318 12/23/2021 22:26:05 -5 0.0 0.00 0.0 134.0 356 12/23/2021 22:27:35 -7 0.0 0.00 0.0 134.0 622 12/23/2021 22:29:05 -5 0.0 0.01 0.0 134.0 642 12/23/2021 22:30:35 -6 0.0 0.01 0.0 134.0 512 12/23/2021 22:32:05 -1 0.0 0.00 0.0 134.0 502 12/23/2021 22:33:35 1 0.0 0.00 0.0 134.0 433 12/23/2021 22:35:05 -0 0.0 0.00 0.0 134.0 661 12/23/2021 22:36:35 6 0.0 -0.00 0.0 134.0 752 12/23/2021 22:38:05 10 0.0 0.01 0.0 134.0 775 12/23/2021 22:39:35 -1 0.0 0.01 0.0 134.0 437 12/23/2021 22:41:05 9 0.0 0.00 0.0 134.0 295 12/23/2021 22:42:35 7 0.0 0.01 0.0 134.0 877 12/23/2021 22:44:05 9 0.0 0.00 0.0 134.0 1039 12/23/2021 22:45:35 8 0.0 0.00 0.0 134.0 1154 12/23/2021 22:47:05 -5 0.0 0.01 0.0 134.0 773 12/23/2021 22:48:35 -4 0.0 0.00 0.0 134.0 686 12/23/2021 22:50:05 -8 0.0 0.01 0.0 134.0 946 12/23/2021 22:51:35 -8 0.0 0.01 0.0 134.0 932 12/23/2021 22:53:05 -5 0.0 0.01 0.0 134.0 752 12/23/2021 22:54:35 -6 0.0 0.00 0.0 134.0 801 12/23/2021 22:56:05 -8 0.0 0.01 0.0 134.0 992 12/23/2021 22:57:35 -5 0.0 0.00 0.0 134.0 937 12/23/2021 22:59:05 -5 0.0 0.01 0.0 134.0 884 12/23/2021 23:00:35 -3 0.0 0.01 0.0 134.0 1018 Page 3 of 4 Well MT7-05 Field GPB Job StartDec/23/2021 Customer COPA Job Number Well MT7-05 Field GPB Job StartDec/23/2021 Customer COPA Job NumberDateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G StageBBL TotalBBL WHPPSI Message12/23/2021 23:03:35 -7 0.0 -0.00 0.0 134.0 1041 12/23/2021 23:05:05 -9 0.0 0.01 0.0 134.0 1054 12/23/2021 23:06:35 -5 0.0 0.01 0.0 134.0 1076 12/23/2021 23:08:05 -6 0.0 0.01 0.0 134.0 1095 12/23/2021 23:09:35 -7 0.0 0.00 0.0 134.0 1152 12/23/2021 23:11:05 -9 0.0 0.00 0.0 134.0 1162 12/23/2021 23:12:35 -9 0.0 0.00 0.0 134.0 1217 12/23/2021 23:14:05 -4 0.0 0.00 0.0 134.0 1348 12/23/2021 23:15:35 -6 0.0 0.00 0.0 134.0 1361 12/23/2021 23:17:05 -6 0.0 0.00 0.0 134.0 1406 12/23/2021 23:18:35 -7 0.0 0.00 0.0 134.0 2790 12/23/2021 23:20:05 -9 0.0 0.01 0.0 134.0 3252 12/23/2021 23:21:21 -9 0.0 0.01 0.0 134.0 3252 Bumped plug 12/23/2021 23:21:35 -11 0.0 0.00 0.0 134.0 3255 12/23/2021 23:23:05 -9 0.0 0.01 0.0 134.0 3261 12/23/2021 23:23:51 3 0.0 0.01 0.0 134.0 3441 Bump plug @ 2116 storkes Post Job Summary Volume of Fluid Injected, bbl N2 Maximum Rate 4.1 Average Pump Rates, bbl/min Slurry 2.5 Mud Total Slurry 134.0 Mud 0.0 Spacer 0.0 N2 Treating Pressure Summary, psi Breakdown Fluid Maximum 4553 Final 3 Average 184 Bump Plug to Breakdown Type Volume bbl Density lb/gal Avg. N2 Percent % Designed Slurry Volume 0.0 bbl Displacement 0.0 bbl Mix Water Temp degF Cement Circulated to Surface?Volume bbl Washed Thru Perfs To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost Job Completed -- Page 4 of 4 Post Job Summary Volume of Fluid Injected, bbl N2 Maximum Rate 4.1 Average Pump Rates, bbl/min Slurry 2.5 Mud Total Slurry 134.0 Mud 0.0 Spacer 0.0 N2 Treating Pressure Summary, psi Breakdown Fluid Maximum 4553 Final 3 Average 184 Bump Plug to Breakdown Type Volume bbl Density lb/gal Avg. N2 Percent % Designed Slurry Volume 0.0 bbl Displacement 0.0 bbl Mix Water Temp degF Cement Circulated to Surface?Volume bbl Washed Thru Perfs To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost Job Completed -- Well MT7-05 Field GPB Job StartDec/23/2021 Customer COPA Job Number MT7-D5 1212412021 As Drilled Estimated TOC 10,066' MDf 7,158' TVD @ 480 inc 9-5/8" 43.5# LSO TP x 9-7/8" 62,8# L80 HYD52.3 10,556' MDf 7,482' TVD @ 50° iric 7" 26# L-30 HYD563 x 7" 299 TN110SS HYD563 ----------- 12,252' MD / 8,298' TVD 75` Inc ........................................ 20" 94# H-40 Welded Conductor to120' 13-3/8" 689 L-80 HYD563 x BTCM 3,515'MDf 3,061TVD @55°inc Planned Top of 7" Liner r------------------ 10,401' M D f 7,37T TVD Planned TOC 7" Liner ----------------- 11,500' MDJ 8,013' TIED Top of Alpine D 12,155' MD/8,271'TVD 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:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Hull, Celie; Njoku, Johnson; WSC Rig Advisor; Lee, David L; Woodard, Madeline E Subject:RE: [EXTERNAL]MT7-05 (PTD #221-087, Sundry 321-632) Schematic Date:Wednesday, December 22, 2021 1:24:11 PM Attachments:image001.png MT7-05 INTERMEDIATE JOB REPORT (1).pdf Hi Victoria, Please see the attached intermediate I cement job report, as requested. Intermediate I Cement Report: SLB pumped 63 bbls of 11.5 ppg Mush Push SLB pumped 42 bbls of 15.8 ppg cement SLB pumped 20 bbls of water Rig displaced with 10.8 ppg drilling fluid at 8 bpm as planned Plug bumped at 6,438 stokes into displacement as planned Floats held and job was conducted with full returns to surface Cement was in place on 12/16/2021 @ 01:33 hrs Shoe depth at 10,566’ MD / 7,482’ TVD Top of HRZ at 10,546’ MD / 7,470’ TVD Estimated TOC 10,066’ MD / 7,158’ TVD No hydrocarbon bearing zones observed in the intermediate I hole section Doyon 25 is currently running the intermediate II liner: Planned set depth 12,252’ MD / 8,298’ TVD Planned TOL at 10409’ MD / 7,382’ TVD Planned TOC at 11,500’ MD / 8,013’ TVD Top of Alpine D at 12,158’ MD / 8,271’ TVD Planned production packer set depth at ~12,000’ MD / 8,221’ TVD Once the 7” intermediate II liner is at set depth, ConocoPhillips will pump cement as per plan. With a successful cement job Concophillips will POOH with the liner running assembly, conduct a BOPE test, pick up 6-1/8” production drilling assembly with SonicScope, run in hole, log TOC for intermediate II liner, conduct FIT, and drill the production lateral to planned TD. Once the BHA is back at surface the log results from the SonicScope will be submitted to the AOGCC with interpretation. If you have questions, please let us know. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 22, 2021 10:25 AM To: WSC Operations Engineer <wscopsengineer@conocophillips.com> Cc: Hull, Celie <Cecilia.Hull@conocophillips.com> Subject: [EXTERNAL]MT7-05 (PTD #221-087, Sundry 321-632) Schematic 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 provide the following: Int 2 TOC MD TVD/MD for the LTP and the production packer Is the Int 2 TOC above the production packer Thanx, Victoria From: Loepp, Victoria T (OGC) Sent: Wednesday, December 22, 2021 9:12 AM To: WSC Operations Engineer <wscopsengineer@conocophillips.com> Cc: Hull, Celie <Cecilia.Hull@conocophillips.com> Subject: MT7-05 9-5/8" Casing Pressure Test and FIT (PTD #221-087) Please send the cement job report and interpretation/summary for the Int 1 Thanx, Victoria From: WSC Operations Engineer <wscopsengineer@conocophillips.com> Sent: Saturday, December 18, 2021 5:59 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Njoku, Johnson <Johnson.Njoku@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Hull, Celie <Cecilia.Hull@conocophillips.com> Subject: MT7-05 9-5/8" Casing Pressure Test and FIT (PTD #221-087) 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. Hi Victoria, Please see the attached. The 9-5/8” casing was tested to 3500 psi and a LOT of 14.0 ppg EMW was achieved. Thanks, Polaris – WSC Operations Engineer Celie Hull / Shane McCracken wscopsengineer@conocophillips.com 907.263.4544 (Office) 12/16/2021 13:25:39 Cementing Job Report CemCAT v1.7 Well MT7-05 Field ALPINE Engineer T.SIMSON Country United States Client COPA SIR No. O.1012355.01.52 Job Type 9-5/8 INTERMEDIATE Job Date 12-15-2021 Time 12/15/2021 16:45:53 12/16/2021 01:31:34 hh:mm:ss 16:45:53 17:26:00 18:06:00 18:46:00 19:26:00 20:06:00 20:46:00 21:26:00 22:06:00 22:46:00 23:26:00 00:06:00 00:46:00 01:26:00 01:31:34 Pressure PSI 0.00 1000 2000 3000 4000 5000 Rate B/M 0.00 2.0 4.0 6.0 8.0 10.0 Density LB/G 5.0 10.0 15.0 20.0 25.0 WHP PSI 0.00 800 1600 2400 3200 4000 Messages h-hEAD rATE Reset Total, Vol = 3.10 bbl 82 DEG WATER ON TRUCK FLUID PACK LINES LOW STALL HIGH PT GOOD PT, BLEED OFF Reset Total, Vol = 2.32 bbl PUMP SPACER End Spacer Reset Total, Vol = 63.46 bbl Drop Bottom Plug START SLURRY Start Cement Slurry End Cement Slurry END SLURRY Reset Total, Vol = 42.02 bbl DROPPING TOP PLUG WATER BEHIND Reset Total, Vol = 20.00 bbl END WATER, TURN OVER TO RIG RIG DISPLACING 6438 STROKES TO BUMP Reset Total, Vol = 0.00 bbl Reset Total, Vol = 0.00 bbl Customer COPA Job NumberO.1012355.01.52WellMT7-05 MT7-05 Location (legal)Schlumberger LocationANCHORAGE Job StartDec/15/2021FieldALPINEFormation Name/Type Deviation deg Bit Size12.3 in Well MD10586.0 ft Well TVD7495.0 ftCountyUSAState/Province AKWell Master 0066450983 API/UWI 50103208330000 BHP psi BHST168 degF BHCT 112 degF Pore Press. Gradient lb/galRig Name DOYON 25 Drilled ForOil & Gas Service ViaLand Offshore Zone Well Class New Well Type Development Drilling Fluid Type Max. Density 10.50 lb/gal Plastic Viscosity cP Service Line Cementing Job Type 9-5/8 INTERMEDIATE Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection Single Cement head Service Instructions CEMENT 9-5/8 INTERMEDIATE CASING W/ TOC 500' ABOVE SHOE. Treat Down Casing Displacement 783.0 bbl Packer Type Packer Depth ft Tubing Vol. bbl Casing Vol. 6.2 bbl Annular Vol. 209.0 bbl Openhole Vol. 1187.0 bbl Casing/Tubing Secured 1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze Job Lift Pressure psi Shoe Type Float Squeeze Type Pipe Rotated Pipe Reciprocated Shoe Depth 10572.0 ft Tool Type No. Centralizers 71 Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Single Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Dec/15/2021 Arrived on Location Dec/15/2021 Leave Location Dec/15/2021 Collar Type Float Tail Pipe Depth ft Collar Depth 10488.0 ft Sqz. Total Vol. bbl Casing/LinerDepth, ft Size, in Weight, lb/ft Grade Thread 8899.0 9.6 43.5 L-80 API 10572.0 9.6 62.8 L-80 ANTARES Tubing/Drill Pipe T/D Depth, ft Size, in Weight, lb/ft Grade Thread Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval ft ft ft ft ft Diameter in ft ft Cementing Service Report Date Time 24-hr clock Treating Pressure PSI Flow Rate B/M Density LB/G Volume BBL Message 12/15/2021 16:45:53 29 0.0 5.83 0.0 Started Acquisition 12/15/2021 16:46:23 31 3.0 5.82 0.8 h-hEAD rATE 12/15/2021 16:46:53 32 3.0 5.80 2.3 12/15/2021 16:46:53 31 3.0 5.79 2.3 12/15/2021 19:19:53 -4 0.0 5.34 0.0 12/15/2021 19:20:53 -2 0.0 5.33 0.0 12/15/2021 19:21:53 -3 0.0 5.32 0.0 12/15/2021 19:22:53 -10 0.0 5.32 0.0 12/15/2021 19:23:53 -7 0.0 5.32 0.0 12/15/2021 19:24:53 -8 0.0 5.31 0.0 12/15/2021 19:25:53 -4 0.0 5.31 0.0 12/15/2021 19:26:53 -4 0.0 5.31 0.0 12/15/2021 19:27:53 -5 0.0 5.30 0.0 12/15/2021 19:28:53 0 0.0 5.29 0.0 12/15/2021 19:29:53 3 0.0 5.29 0.0 12/15/2021 19:30:53 25 0.0 5.29 0.0 12/15/2021 19:31:53 11 0.0 5.29 0.0 12/15/2021 19:32:53 -10 0.0 5.28 0.0 12/15/2021 19:33:53 -4 0.0 5.28 0.0 12/15/2021 19:34:53 0 0.0 5.28 0.0 12/15/2021 19:35:53 -6 0.0 5.27 0.0 Page 1 of 9 Customer COPA Job NumberO.1012355.01.52WellMT7-05 MT7-05 Location (legal)Schlumberger LocationANCHORAGE Job StartDec/15/2021FieldALPINEFormation Name/Type Deviation deg Bit Size12.3 in Well MD10586.0 ft Well TVD7495.0 ftCountyUSAState/Province AKWell Master 0066450983 API/UWI 50103208330000 BHP psi BHST168 degF BHCT 112 degF Pore Press. Gradient lb/galRig Name DOYON 25 Drilled ForOil & Gas Service ViaLand Offshore Zone Well Class New Well Type Development Drilling Fluid Type Max. Density 10.50 lb/gal Plastic Viscosity cP Service Line Cementing Job Type 9-5/8 INTERMEDIATE Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection Single Cement head Service Instructions CEMENT 9-5/8 INTERMEDIATE CASING W/ TOC 500' ABOVE SHOE. Treat Down Casing Displacement 783.0 bbl Packer Type Packer Depth ft Tubing Vol. bbl Casing Vol. 6.2 bbl Annular Vol. 209.0 bbl Openhole Vol. 1187.0 bbl Casing/Tubing Secured 1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze Job Lift Pressure psi Shoe Type Float Squeeze Type Pipe Rotated Pipe Reciprocated Shoe Depth 10572.0 ft Tool Type No. Centralizers 71 Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Single Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Dec/15/2021 Arrived on Location Dec/15/2021 Leave Location Dec/15/2021 Collar Type Float Tail Pipe Depth ft Collar Depth 10488.0 ft Sqz. Total Vol. bbl Casing/LinerDepth, ft Size, in Weight, lb/ft Grade Thread 8899.0 9.6 43.5 L-80 API 10572.0 9.6 62.8 L-80 ANTARES Tubing/Drill Pipe T/D Depth, ft Size, in Weight, lb/ft Grade Thread Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval ft ft ft ft ft Diameter in ft ft Cementing Service Report Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/15/2021 19:37:53 -15 0.0 5.27 0.0 12/15/2021 19:38:53 -16 0.0 5.27 0.0 12/15/2021 19:39:53 -13 0.0 5.26 0.0 12/15/2021 19:40:53 -20 0.0 5.26 0.0 12/15/2021 19:41:53 -24 0.0 5.26 0.0 12/15/2021 19:42:53 -22 0.0 5.26 0.0 12/15/2021 19:43:53 -25 0.0 5.25 0.0 12/15/2021 19:44:53 -24 0.0 5.25 0.0 12/15/2021 19:45:53 -25 0.0 5.25 0.0 12/15/2021 19:46:53 -24 0.0 5.25 0.0 12/15/2021 19:47:53 -26 0.0 5.25 0.0 12/15/2021 19:48:53 -25 0.0 5.24 0.0 12/15/2021 19:49:53 -22 0.0 5.24 0.0 12/15/2021 19:50:53 87 0.0 5.24 0.0 12/15/2021 19:51:53 -9 0.0 5.24 0.0 12/15/2021 19:52:53 22 0.0 5.24 0.0 12/15/2021 19:53:53 -23 0.0 5.24 0.0 12/15/2021 19:54:53 -21 0.0 5.24 0.0 12/15/2021 19:55:53 -23 0.0 5.23 0.0 12/15/2021 19:56:53 -24 0.0 5.23 0.0 12/15/2021 19:57:53 -22 0.0 5.23 0.0 12/15/2021 19:58:53 -24 0.0 5.23 0.0 12/15/2021 19:59:53 -23 0.0 5.23 0.0 12/15/2021 20:00:53 -23 0.0 5.23 0.0 12/15/2021 20:01:53 -24 0.0 5.23 0.0 12/15/2021 20:02:53 -25 0.0 5.22 0.0 12/15/2021 20:03:53 -24 0.0 5.22 0.0 12/15/2021 20:04:53 -24 0.0 5.22 0.0 12/15/2021 20:05:53 -23 0.0 5.22 0.0 12/15/2021 20:06:53 -23 0.0 5.22 0.0 12/15/2021 20:07:53 -23 0.0 5.22 0.0 12/15/2021 20:08:53 -23 0.0 5.22 0.0 12/15/2021 20:09:53 -24 0.0 5.22 0.0 12/15/2021 20:10:53 -22 0.0 5.22 0.0 12/15/2021 20:11:53 -22 0.0 5.22 0.0 12/15/2021 20:12:53 -24 0.0 5.22 0.0 12/15/2021 20:13:53 -23 0.0 5.22 0.0 12/15/2021 20:14:53 -19 0.0 5.22 0.0 12/15/2021 20:15:53 -23 0.0 5.22 0.0 12/15/2021 20:16:53 -23 0.0 5.21 0.0 12/15/2021 20:17:53 -24 0.0 5.22 0.0 12/15/2021 20:18:53 -22 0.0 5.21 0.0 12/15/2021 20:19:53 -22 0.0 5.22 0.0 12/15/2021 20:20:53 -24 0.0 5.21 0.0 12/15/2021 20:21:53 -21 0.0 5.21 0.0 12/15/2021 20:22:53 -21 0.0 5.21 0.0 12/15/2021 20:23:53 -22 0.0 5.21 0.0 12/15/2021 20:24:53 -20 0.0 5.21 0.0 12/15/2021 20:25:53 -19 0.0 5.21 0.0 12/15/2021 20:26:53 -24 0.0 5.21 0.0 12/15/2021 20:27:53 -23 0.0 5.21 0.0 12/15/2021 20:28:53 -21 0.0 5.21 0.0 12/15/2021 20:29:53 -21 0.0 5.21 0.0 12/15/2021 20:30:53 -23 0.0 5.21 0.0 Page 2 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/15/2021 20:32:53 -24 0.0 5.21 0.0 12/15/2021 20:33:53 -25 0.0 5.21 0.0 12/15/2021 20:34:53 -24 0.0 5.21 0.0 12/15/2021 20:35:53 -23 0.0 5.21 0.0 12/15/2021 20:36:53 -26 0.0 5.21 0.0 12/15/2021 20:37:53 -24 0.0 5.21 0.0 12/15/2021 20:38:53 -27 0.0 5.21 0.0 12/15/2021 20:39:53 -22 0.0 5.21 0.0 12/15/2021 20:40:53 -23 0.0 5.21 0.0 12/15/2021 20:41:53 -24 0.0 5.21 0.0 12/15/2021 20:42:53 -24 0.0 5.21 0.0 12/15/2021 20:43:53 -24 0.0 5.20 0.0 12/15/2021 20:44:53 -25 0.0 5.21 0.0 12/15/2021 20:45:53 -23 0.0 5.20 0.0 12/15/2021 20:46:53 -21 0.0 5.20 0.0 12/15/2021 20:47:53 -23 0.0 5.20 0.0 12/15/2021 20:48:53 -25 0.0 5.21 0.0 12/15/2021 20:49:53 -23 0.0 5.21 0.0 12/15/2021 20:50:53 -25 0.0 5.21 0.0 12/15/2021 20:51:53 -25 0.0 5.20 0.0 12/15/2021 20:52:53 -25 0.0 5.21 0.0 12/15/2021 20:53:53 -25 0.0 5.20 0.0 12/15/2021 20:54:53 -22 0.0 5.20 0.0 12/15/2021 20:55:53 -25 0.0 5.20 0.0 12/15/2021 20:57:53 -25 0.0 5.20 0.0 12/15/2021 20:57:53 -23 0.0 5.20 0.0 12/15/2021 20:59:53 -24 0.0 5.20 0.0 12/15/2021 21:00:53 -23 0.0 5.21 0.0 12/15/2021 21:01:53 -25 0.0 5.20 0.0 12/15/2021 21:02:53 -23 0.0 5.20 0.0 12/15/2021 21:03:53 -23 0.0 5.20 0.0 12/15/2021 21:04:53 -24 0.0 5.20 0.0 12/15/2021 21:05:53 -23 0.0 5.20 0.0 12/15/2021 21:06:53 -26 0.0 5.20 0.0 12/15/2021 21:07:53 -24 0.0 5.20 0.0 12/15/2021 21:08:53 -24 0.0 5.20 0.0 12/15/2021 21:09:53 -25 0.0 5.20 0.0 12/15/2021 21:10:53 -24 0.0 5.20 0.0 12/15/2021 21:11:53 -26 0.0 5.19 0.0 12/15/2021 21:12:53 -23 0.0 5.19 0.0 12/15/2021 21:13:53 -25 0.0 5.19 0.0 12/15/2021 21:14:53 -26 0.0 5.19 0.0 12/15/2021 21:15:53 -25 0.0 5.20 0.0 12/15/2021 21:16:53 -25 0.0 5.20 0.0 12/15/2021 21:17:53 -23 0.0 5.20 0.0 12/15/2021 21:18:53 -25 0.0 5.20 0.0 12/15/2021 21:19:53 -25 0.0 5.19 0.0 12/15/2021 21:20:53 -23 0.0 5.19 0.0 12/15/2021 21:21:53 -24 0.0 5.20 0.0 12/15/2021 21:22:53 -25 0.0 5.19 0.0 12/15/2021 21:23:53 -22 0.0 5.19 0.0 12/15/2021 21:24:53 -30 0.0 4.98 0.0 12/15/2021 21:25:53 -27 0.0 4.97 0.0 12/15/2021 21:26:53 -25 0.0 4.97 0.0 Page 3 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/15/2021 21:28:53 -26 0.0 4.96 0.0 12/15/2021 21:29:53 -26 0.0 4.96 0.0 12/15/2021 21:30:53 -25 0.0 4.96 0.0 12/15/2021 21:31:53 -25 0.0 4.96 0.0 12/15/2021 21:32:53 -25 0.0 4.96 0.0 12/15/2021 21:33:53 -24 0.0 4.96 0.0 12/15/2021 21:34:53 -22 0.0 4.96 0.0 12/15/2021 21:35:53 -25 0.0 4.96 0.0 12/15/2021 21:36:53 -23 0.0 4.96 0.0 12/15/2021 21:37:53 -22 0.0 4.96 0.0 12/15/2021 21:38:53 -25 0.0 4.96 0.0 12/15/2021 21:39:53 -25 0.0 4.95 0.0 12/15/2021 21:40:53 -23 0.0 4.96 0.0 12/15/2021 21:41:53 -25 0.0 4.95 0.0 12/15/2021 21:42:53 -26 0.0 4.96 0.0 12/15/2021 21:43:53 -22 0.0 4.95 0.0 12/15/2021 21:44:53 -23 0.0 4.96 0.0 12/15/2021 21:45:53 -24 0.0 4.96 0.0 12/15/2021 21:46:53 -23 0.0 4.95 0.0 12/15/2021 21:47:53 -23 0.0 4.96 0.0 12/15/2021 21:48:53 -22 0.0 4.95 0.0 12/15/2021 21:49:53 -22 0.0 4.96 0.0 12/15/2021 21:50:53 -24 0.0 4.95 0.0 12/15/2021 21:51:53 -25 0.0 4.95 0.0 12/15/2021 21:52:53 -22 0.0 4.95 0.0 12/15/2021 21:53:53 -23 0.0 4.95 0.0 12/15/2021 21:54:53 -23 0.0 4.95 0.0 12/15/2021 21:55:53 -21 0.0 4.95 0.0 12/15/2021 21:56:53 -22 0.0 4.95 0.0 12/15/2021 21:57:53 -25 0.0 4.95 0.0 12/15/2021 21:58:53 -25 0.0 4.95 0.0 12/15/2021 21:59:53 -22 0.0 4.95 0.0 12/15/2021 22:00:53 -21 0.0 4.95 0.0 12/15/2021 22:01:53 -21 0.0 4.95 0.0 12/15/2021 22:02:53 -22 0.0 4.95 0.0 12/15/2021 22:03:53 -23 0.0 4.95 0.0 12/15/2021 22:04:53 -23 0.0 4.95 0.0 12/15/2021 22:05:53 -18 0.0 4.95 0.0 12/15/2021 22:06:53 -25 0.0 4.95 0.0 12/15/2021 22:07:53 -21 0.0 4.95 0.0 12/15/2021 22:08:53 -25 0.0 4.95 0.0 12/15/2021 22:09:53 5 0.3 6.46 0.1 12/15/2021 22:10:14 -7 0.8 5.45 0.3 FLUID PACK LINES 12/15/2021 22:10:53 97 1.2 5.64 1.0 12/15/2021 22:11:53 86 0.0 5.32 2.2 12/15/2021 22:12:53 688 0.0 5.32 2.3 12/15/2021 22:12:57 681 0.0 5.31 2.3 LOW STALL 12/15/2021 22:13:53 3442 0.1 5.31 2.3 12/15/2021 22:14:10 3644 0.0 4.90 2.3 HIGH PT 12/15/2021 22:14:53 3614 0.0 4.34 2.3 12/15/2021 22:15:53 3590 0.0 4.34 2.3 12/15/2021 22:16:53 -16 0.0 4.33 2.3 12/15/2021 22:17:01 -19 0.0 4.34 2.3 GOOD PT, BLEED OFF 12/15/2021 22:17:53 95 0.0 6.33 2.3 Page 4 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/15/2021 22:18:53 115 0.0 8.32 2.3 12/15/2021 22:19:53 102 0.0 10.49 2.3 12/15/2021 22:20:53 99 0.0 10.90 2.3 12/15/2021 22:21:53 90 0.0 11.61 2.4 12/15/2021 22:22:53 47 0.1 11.44 2.4 12/15/2021 22:23:23 154 1.8 11.43 2.8 PUMP SPACER12/15/2021 22:23:53 301 3.0 11.35 4.2 12/15/2021 22:24:53 300 3.0 11.41 7.1 12/15/2021 22:25:53 299 3.0 11.49 10.1 12/15/2021 22:26:53 332 3.4 11.53 13.5 12/15/2021 22:27:53 350 3.3 11.57 16.9 12/15/2021 22:28:53 322 3.2 11.50 20.2 12/15/2021 22:29:53 322 3.2 11.52 23.3 12/15/2021 22:30:53 316 3.2 11.46 26.5 12/15/2021 22:31:53 307 3.2 11.67 29.7 12/15/2021 22:32:53 404 4.1 11.43 33.5 12/15/2021 22:33:53 415 4.1 11.59 37.5 12/15/2021 22:34:53 413 4.1 11.67 41.6 12/15/2021 22:35:53 405 4.1 11.54 45.7 12/15/2021 22:36:53 404 4.1 11.51 49.8 12/15/2021 22:37:53 412 4.1 11.39 53.9 12/15/2021 22:38:53 389 4.1 11.39 57.9 12/15/2021 22:39:53 390 4.1 11.64 62.0 12/15/2021 22:40:53 124 0.9 11.64 65.3 12/15/2021 22:41:37 63 0.0 11.54 65.8 End Spacer 12/15/2021 22:41:44 62 0.0 11.53 65.8 Reset Total, Vol = 63.46 bbl 12/15/2021 22:41:53 61 0.0 11.38 65.8 12/15/2021 22:42:53 -11 0.0 11.28 65.8 Drop Bottom Plug 12/15/2021 22:43:53 -15 0.0 11.42 65.8 12/15/2021 22:44:53 41 0.0 8.78 65.8 12/15/2021 22:45:53 36 0.0 10.15 65.8 12/15/2021 22:46:53 -11 0.0 9.95 65.8 12/15/2021 22:47:53 11 0.0 8.55 65.8 12/15/2021 22:48:53 -16 0.0 7.89 65.8 12/15/2021 22:49:53 45 0.0 8.38 65.8 12/15/2021 22:50:53 60 0.0 10.93 65.8 12/15/2021 22:51:53 94 0.0 15.92 65.8 12/15/2021 22:52:53 94 0.0 15.90 65.8 12/15/2021 22:53:53 95 0.0 15.91 65.8 12/15/2021 22:54:53 89 0.0 15.92 65.8 12/15/2021 22:55:53 95 0.0 15.92 65.8 12/15/2021 22:56:53 94 0.0 15.92 65.8 12/15/2021 22:57:53 102 0.0 15.92 65.8 12/15/2021 22:58:53 95 0.0 15.92 65.8 12/15/2021 22:59:53 95 0.0 15.91 65.8 12/15/2021 23:00:53 73 0.0 15.91 65.8 12/15/2021 23:01:53 76 0.0 15.91 65.8 12/15/2021 23:02:53 73 0.0 15.91 65.8 12/15/2021 23:03:53 79 0.0 15.91 65.8 12/15/2021 23:04:53 75 0.0 15.91 65.8 12/15/2021 23:05:53 75 0.0 15.82 65.8 12/15/2021 23:06:20 134 1.3 15.82 65.9 START SLURRY 12/15/2021 23:06:21 140 1.4 15.82 65.9 Start Cement Slurry 12/15/2021 23:06:53 469 3.8 15.80 67.4 Page 5 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/15/2021 23:08:53 731 4.5 15.82 75.9 12/15/2021 23:09:53 681 4.4 15.91 80.3 12/15/2021 23:10:53 662 4.3 15.89 84.6 12/15/2021 23:11:53 521 4.0 15.84 88.8 12/15/2021 23:12:53 542 4.0 15.82 92.8 12/15/2021 23:13:53 523 4.0 15.83 96.8 12/15/2021 23:14:53 499 4.0 15.82 100.7 12/15/2021 23:15:53 483 4.0 15.86 104.7 12/15/2021 23:16:52 -4 0.0 15.87 107.8 End Cement Slurry 12/15/2021 23:16:53 -5 0.0 15.87 107.8 END SLURRY 12/15/2021 23:16:58 -1 0.0 15.85 107.8 Reset Total, Vol = 42.02 bbl 12/15/2021 23:17:53 -27 0.0 15.54 107.8 12/15/2021 23:18:53 75 0.0 15.91 107.8 12/15/2021 23:19:53 -1 0.0 15.89 107.8 12/15/2021 23:20:53 130 0.0 13.13 107.8 12/15/2021 23:21:53 79 0.0 13.44 107.8 12/15/2021 23:22:53 -12 0.0 13.39 107.8 12/15/2021 23:23:53 51 0.0 9.16 107.8 12/15/2021 23:24:53 22 0.0 8.88 107.8 12/15/2021 23:24:57 22 0.0 8.84 107.8 DROPPING TOP PLUG 12/15/2021 23:25:53 28 0.0 8.50 107.8 12/15/2021 23:26:53 22 0.0 8.22 107.8 12/15/2021 23:27:53 31 0.0 8.15 107.8 12/15/2021 23:28:53 21 0.0 8.09 107.8 12/15/2021 23:29:53 55 0.0 8.50 107.8 12/15/2021 23:30:53 49 0.0 8.51 107.8 12/15/2021 23:31:53 50 0.0 8.41 107.8 12/15/2021 23:32:53 39 0.0 8.10 107.8 12/15/2021 23:33:53 10 0.0 8.00 107.8 12/15/2021 23:34:25 432 4.7 8.23 108.6 WATER BEHIND 12/15/2021 23:34:53 354 5.6 8.30 111.1 12/15/2021 23:35:53 509 5.6 8.32 116.7 12/15/2021 23:36:53 487 5.5 8.34 122.3 12/15/2021 23:37:53 159 2.4 8.35 127.5 12/15/2021 23:38:10 26 0.0 8.30 127.8 Reset Total, Vol = 20.00 bbl 12/15/2021 23:38:28 13 0.0 8.23 127.8 END WATER, TURN OVER TO RIG 12/15/2021 23:38:53 -7 0.0 8.20 127.8 12/15/2021 23:39:53 -2 0.0 8.10 127.8 12/15/2021 23:40:53 107 0.0 8.02 127.8 12/15/2021 23:41:53 54 0.0 7.99 127.8 12/15/2021 23:42:53 -15 0.0 7.98 127.8 12/15/2021 23:43:32 -15 0.0 7.93 127.8 RIG DISPLACING 12/15/2021 23:43:53 -20 0.0 7.93 127.8 12/15/2021 23:44:53 -22 0.0 8.34 127.8 12/15/2021 23:45:53 -21 0.0 8.34 127.8 12/15/2021 23:46:53 -24 0.0 8.33 127.8 12/15/2021 23:47:53 -22 0.0 8.34 127.8 12/15/2021 23:48:53 11 0.0 8.34 127.8 12/15/2021 23:49:53 -20 0.0 8.28 127.8 12/15/2021 23:50:53 -21 0.0 7.84 127.8 12/15/2021 23:51:53 42 0.0 8.32 127.8 12/15/2021 23:52:53 -20 0.0 7.77 127.8 12/15/2021 23:53:53 -21 0.0 8.16 127.8 12/15/2021 23:54:53 -21 0.0 8.31 127.8 Page 6 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/15/2021 23:56:53 -19 0.0 8.09 127.8 12/15/2021 23:57:53 -22 0.0 7.84 127.8 12/15/2021 23:58:53 -22 0.0 7.67 127.8 12/15/2021 23:59:53 -11 0.0 7.75 127.8 12/16/2021 00:00:53 72 0.0 6.86 127.8 12/16/2021 00:01:53 80 0.0 6.91 127.8 12/16/2021 00:02:53 64 0.0 7.07 127.8 12/16/2021 00:03:53 70 0.0 7.02 127.8 12/16/2021 00:04:53 37 0.0 6.36 127.8 12/16/2021 00:05:53 80 0.0 7.03 127.8 12/16/2021 00:06:53 79 0.0 7.06 127.8 12/16/2021 00:07:53 76 0.0 6.78 127.8 12/16/2021 00:08:53 -5 0.0 4.27 127.8 12/16/2021 00:09:53 -15 0.0 4.29 127.8 12/16/2021 00:10:53 -21 0.0 4.28 127.8 12/16/2021 00:11:53 -21 0.0 4.27 127.8 12/16/2021 00:12:53 -19 0.0 4.26 127.8 12/16/2021 00:13:53 -19 0.0 4.25 127.8 12/16/2021 00:14:53 -23 0.0 4.24 127.8 12/16/2021 00:15:53 -21 0.0 4.23 127.8 12/16/2021 00:16:53 -23 0.0 4.22 127.8 12/16/2021 00:17:53 -9 0.0 4.21 127.8 12/16/2021 00:18:53 -17 0.0 4.21 127.8 12/16/2021 00:19:53 -13 0.0 4.20 127.8 12/16/2021 00:20:53 -17 0.0 4.19 127.8 12/16/2021 00:21:53 -19 0.0 4.18 127.8 12/16/2021 00:22:53 -14 0.0 4.17 127.8 12/16/2021 00:23:53 -17 0.0 4.16 127.8 12/16/2021 00:24:53 -11 0.0 6.80 127.8 12/16/2021 00:25:53 -15 0.0 7.13 127.8 12/16/2021 00:26:53 -15 0.0 6.82 127.8 12/16/2021 00:27:53 -13 0.0 8.25 127.8 12/16/2021 00:28:53 -23 0.0 7.67 127.8 12/16/2021 00:29:53 -22 0.0 6.42 127.8 12/16/2021 00:30:53 -14 0.0 8.30 127.8 12/16/2021 00:31:53 -17 0.0 8.29 127.8 12/16/2021 00:32:53 -22 0.0 5.89 127.8 12/16/2021 00:33:53 -22 0.0 5.49 127.8 12/16/2021 00:34:53 -20 0.0 5.11 127.8 12/16/2021 00:35:53 -21 0.0 5.11 127.8 12/16/2021 00:36:53 52 0.0 8.29 127.8 12/16/2021 00:37:53 44 0.0 8.25 127.8 12/16/2021 00:38:53 42 0.0 8.26 127.8 12/16/2021 00:39:53 46 0.0 8.26 127.8 12/16/2021 00:40:53 47 0.0 8.26 127.8 12/16/2021 00:41:53 0 0.0 7.63 127.8 12/16/2021 00:42:53 -8 0.0 7.50 127.8 12/16/2021 00:43:53 40 0.0 8.23 127.8 12/16/2021 00:44:53 39 0.0 8.26 127.8 12/16/2021 00:45:53 -6 0.0 6.76 127.8 12/16/2021 00:46:53 -20 0.0 6.20 127.8 12/16/2021 00:47:53 -22 0.0 5.86 127.8 12/16/2021 00:48:53 -21 0.0 5.62 127.8 12/16/2021 00:49:53 -21 0.0 5.43 127.8 Page 7 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52DateTime24-hrclock TreatingPressurePSI FlowRateB/M DensityLB/G VolumeBBL Message12/16/2021 00:51:53 -20 0.0 5.28 127.8 12/16/2021 00:52:53 -20 0.0 5.26 127.8 12/16/2021 00:53:53 -23 0.0 5.25 127.8 12/16/2021 00:54:53 -23 0.0 5.25 127.8 12/16/2021 00:55:53 -21 0.0 5.26 127.8 12/16/2021 00:56:53 -22 0.0 5.25 127.8 12/16/2021 00:57:53 -23 0.0 5.25 127.8 12/16/2021 00:58:53 -22 0.0 5.25 127.8 12/16/2021 00:59:53 -24 0.0 5.25 127.8 12/16/2021 01:00:53 -24 0.0 5.25 127.8 12/16/2021 01:01:53 -23 0.0 5.25 127.8 12/16/2021 01:02:53 -21 0.0 5.25 127.8 12/16/2021 01:04:53 -22 0.0 5.25 127.8 12/16/2021 01:05:53 -21 0.0 5.25 127.8 12/16/2021 01:06:53 -23 0.0 5.25 127.8 12/16/2021 01:07:53 -23 0.0 5.25 127.8 12/16/2021 01:08:53 -23 0.0 5.24 127.8 12/16/2021 01:09:53 -24 0.0 5.25 127.8 12/16/2021 01:10:53 -21 0.0 5.25 127.8 12/16/2021 01:11:53 -19 0.0 5.24 127.8 12/16/2021 01:12:53 -23 0.0 5.25 127.8 12/16/2021 01:13:53 -23 0.0 5.25 127.8 12/16/2021 01:14:53 -24 0.0 5.24 127.8 12/16/2021 01:15:53 -21 0.0 5.20 127.8 12/16/2021 01:16:53 -21 0.0 5.20 127.8 12/16/2021 01:17:53 -20 0.0 5.20 127.8 12/16/2021 01:18:53 -21 0.0 5.20 127.8 12/16/2021 01:19:53 -22 0.0 5.21 127.8 12/16/2021 01:20:53 -21 0.0 5.20 127.8 12/16/2021 01:21:53 -22 0.0 5.20 127.8 12/16/2021 01:22:53 -21 0.0 5.18 127.8 12/16/2021 01:23:53 -21 0.0 5.17 127.8 12/16/2021 01:24:53 -19 0.0 5.18 127.8 12/16/2021 01:25:53 -24 0.0 5.18 127.8 12/16/2021 01:26:26 -25 0.0 5.17 127.8 6438 STROKES TO BUMP 12/16/2021 01:26:53 -25 0.0 5.18 127.8 12/16/2021 01:27:00 -25 0.0 5.18 127.8 Reset Total, Vol = 0.00 bbl 12/16/2021 01:27:09 -23 0.0 5.18 127.8 Reset Total, Vol = 0.00 bbl 12/16/2021 01:27:53 -24 0.0 5.18 0.0 12/16/2021 01:28:53 -23 0.0 5.17 0.0 12/16/2021 01:29:53 -25 0.0 5.09 0.0 12/16/2021 01:30:53 -25 0.0 5.07 0.0 Page 8 of 9 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Post Job Summary Volume of Fluid Injected, bblN2Maximum Rate6.2Average Pump Rates, bbl/minSlurry3.2 Mud Total Slurry42.0 Mud 760.9 Spacer 63.4 N2Treating Pressure Summary, psi Breakdown FluidMaximum3668Final-24 Average272 Bump Plug to960 Breakdown Type Volume bbl Density lb/galAvg. N2 Percent %Designed Slurry Volume42.0 bbl Displacement780.9 bbl Mix Water Temp82 degF Cement Circulated to Surface?Volume bblWashed Thru Perfs To ftCustomer or Authorized RepresentativeCOPA REP Schlumberger SupervisorT.SIMSON Circulation Lost Job Completed X -- Page 9 of 9 Post Job Summary Volume of Fluid Injected, bblN2Maximum Rate6.2Average Pump Rates, bbl/minSlurry3.2 Mud Total Slurry42.0 Mud 760.9 Spacer 63.4 N2Treating Pressure Summary, psi Breakdown FluidMaximum3668Final-24 Average272 Bump Plug to960 Breakdown Type Volume bbl Density lb/galAvg. N2 Percent %Designed Slurry Volume42.0 bbl Displacement780.9 bbl Mix Water Temp82 degF Cement Circulated to Surface?Volume bblWashed Thru Perfs To ftCustomer or Authorized RepresentativeCOPA REP Schlumberger SupervisorT.SIMSON Circulation Lost Job Completed X -- Well MT7-05 MT7-05 Field ALPINE Job StartDec/15/2021 Customer COPA Job NumberO.1012355.01.52 Service Quality EvaluationClient:COPAField:ALPINERig:DOYON 25Well:MT7-05Service Line:CementingJob Type:9-5/8 INTERMEDIATE Service Order #:Date:Dec/15/2021Operating Time (hh:mm): 00:00Client Rep:COPA REPSchlumberger Engineer:T.SIMSONSchlumberger FSM:Main Objective:pump 42 bbls 15.8 ppg cmt To be completed by Company Rep. Please answer Y (Yes) or N (No) and add any comments below. Comments: (Please include a brief explanation for a "NO" response and summarize any innovations attempted on this well.) Client:Schlumberger: Client Signature:Schlumberger Signature: 1 1a 1b 1c 2 2a 2b 2c 2d 3 3a 3b 3c 3d 3e 3f 3g 3h 3i 3j 4 4a Score Yes / No Result HSE Free of lost time injury and compliance with SLB and loc. spec. HSE practice Free of environmental spill or non-compliant discharge Wellsite left clean 5 5 4 yes X yes X yes X no no no 5 5 4 Sub-total 100% Design / Preparation Program incl. job simulation (CemCADE) & pump schedule / tool hydraulic calcs Equipment maintenance schedule completed / Green tagged All materials and equipment required for job/contingency checked & on location Safety / pre-job meeting conducted with all involved present 3 2 2 2 yes yes yes yes no X no X no X no X 0 0 0 0 Sub-total 0% Execution Lost time < 30 mins Equipment pressure tested succesfully All key parameters monitored and recorded accurately (Pressure, Rate, Density) Plugs / darts released and tested succesfully Density variation met expectations Personnel performed as per expectations Equipment performed as per expectations Job pumped as per design Did job start on time Free of Operational failures (screen out, Cementing Example, etc.) 3 3 2 2 2 2 2 3 2 3 yes yes yes yes yes yes yes yes yes yes no X no X no X no X no X no X no X no X no X no X 0 0 0 0 0 0 0 0 0 0 Sub-total 0% Evaluation Main job objective achieved with no consequential non-productive time 10 yes no X 0 Sub-total 0% Total 24% Service Quality Evaluation 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG3HUIRUDWH2WKHU6WLPXODWH3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU BBBBBBBBBBBBBBBBBBB 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\'HYHORSPHQW $GGUHVV 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ :HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO"07 :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ"<HV1R 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU )LHOG3RRO V 7RWDO'HSWK0' IW 7RWDO'HSWK79' IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363 SVL 3OXJV 0' -XQN 0' 1$1$1$1$ &DVLQJ &ROODSVH 6WUXFWXUDO &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU 3DFNHUVDQG66697\SH 3DFNHUVDQG66690' IW DQG79' IW $WWDFKPHQWV 3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU :HOO6WDWXVDIWHUSURSRVHGZRUN &RPPHQFLQJ2SHUDWLRQV 2,/:,1-:'63/6XVSHQGHG 9HUEDO$SSURYDO 'DWH *$6 :$**6725 63/8* $2*&&5HSUHVHQWDWLYH *,1-2S6KXWGRZQ $EDQGRQHG &RQWDFW1DPH &HOLH+XOO &KULV%ULOORQ &RQWDFW(PDLO FHOLHKXOO#FRQRFRSKLOOLSVFRP &RQWDFW3KRQH $XWKRUL]HG7LWOH :HOOV(QJLQHHULQJ0DQDJHU &RQGLWLRQVRIDSSURYDO 1RWLI\$2*&&VRWKDWDUHSUHVHQWDWLYHPD\ZLWQHVV 6XQGU\1XPEHU 3OXJ,QWHJULW\ %237HVW 0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 2WKHU 3RVW,QLWLDO,QMHFWLRQ0,75HT G"<HV 1R 6SDFLQJ([FHSWLRQ5HTXLUHG"<HV 1R 6XEVHTXHQW)RUP5HTXLUHG $33529('%< $SSURYHGE\ &200,66,21(5 7+($2*&& 'DWH &RPP &RPP 6U3HW(QJ 6U3HW*HR 6U5HV(QJ ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< 7XELQJ*UDGH 7XELQJ0' IW 1$ 3HUIRUDWLRQ'HSWK79' IW 7XELQJ6L]H 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $$$$$$$$ 32%R[$QFKRUDJH$ODVND &RQRFR3KLOOLSV *UHDWHU0RRVHV7RRWK5HQGH]YRXV /HQJWK 6L]H 1$ 79'%XUVW 1$ 0' [ 3HUIRUDWLRQ'HSWK0' IW 1$1$ 6SXGZHOORQ([SHFWHGWREHJLQ SURSRVHGFKDQJHV 1$ 1$ 3HUIRUDWH 5HSDLU:HSDLU:HOO ([SORUDWRU\6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH %237HVW0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 1R 1R )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 2:38 pm, Dec 21, 2021 ; '/% ; '65 %23 WHVW WR SVLJ $QQXODU SUHYHQWHU WHVW WR SVLJ ,QWHUPHGLDWH FHPHQW &%/ UHTXLUHG EHIRUH GULOOLQJ SURGXFWLRQ KROH ILOH Z 37' ; 97/ &RQGLWLRQV RI DSSURYDO LQ RULJLQDO 37' DSSO\ dts 12/22/2021 Jeremy Price Digitally signed by Jeremy Price Date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´,QWHUPHGLDWHOLQHUWRSSDFNHU $IWHUFRQFHUQVZLWKFHPHQWTXDOLW\SXPSLQJDODUJHYROXPHFHPHQWYROXPHZDVUHGXFHGRQ07DQGFHPHQWZDV VXFFHVVIXOO\SXPSHGWR¶79'RU¶0'DERYHWKH$OSLQH'IRUPDWLRQWRS,WLVSURSRVHGWKDWWKHXSFRPLQJRSHUDWLRQDW 07IROORZDVLPLODUGHVLJQ $GGLWLRQDOO\GXHWRXSGDWHGFDVLQJZHDUPRGHOLQJLWLVSURSRVHGWKDWD³KHDY\KHHO´LQWKH´OLQHUZLOOEHKHDYLHU LQFUHDVLQJ ZHLJKWIURPWKHRULJLQDOO\SODQQHGOEIW/+\GOLQHUWRLQFOXGHa ¶RI OEIW7166+\GDWWKHERWWRPRI WKHOLQHUVWULQJ7KHOLQHUZLOOEHUXQZLWK´[´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¶79'RU¶0'DERYHWKH $OSLQH'IRUPDWLRQWRS,WLVSURSRVHGWKDWWKHXSFRPLQJRSHUDWLRQDW\S S 07IROORZDVLPLODUGHVLJQ GXHWRXSGDWHGFDVLQJZHDUPRGHOLQJLWLVSURSRVHGWKDWD³KHDY\KHHO´LQWKH ´OLQHUZLOOEHKHDYLHU LQFUHDVLQJ\ S JJSS \ J ZHLJKWIURPWKHRULJLQDOO\SODQQHGOEIW/+\GOLQHUWRLQFOXGHa ¶RI OEIW7166+\GDWWKHERWWRPRIJ WKHOLQHUVWULQJ7 &DVLQJDQG&HPHQWLQJ3URJUDP Hole Section Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. 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V[RISSJ&ODVV*$GGV#IWVN 'ULOOLQJ)OXLG3URJUDP 5HTXLUHPHQWVRI$$& F 1RWHWKDW6XUIDFH,QWHUPHGLDWHDQGSURGXFWLRQGULOOLQJIOXLGSODQVDUHXQFKDQJHG ,QWHUPHGLDWH +ROH6L]HLQ[ &DVLQJ6L]HLQ 0XG6\VWHP/61' 'HQVLW\33* /6<3±OEVIW± <3OEIW± 6HF*HOVOEIW± 0LQXWH*HOVOEIW $3,)OXLG/RVVFFPLQ +3+7)OXLG/RVVFFPLQ S+ ± 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:Ward, Dusty K To:Loepp, Victoria T (OGC) Cc:DOA AOGCC Prudhoe Bay; Regg, James B (OGC) Subject:RE: [EXTERNAL]KRU 3M-05 Test Pressure to 2700 psig. Date:Monday, December 20, 2021 7:32:48 PM Some people who received this message don't often get email from dusty.ward@conocophillips.com. Learn why this is important Victoria, Thank you very much! Have a great evening. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, December 20, 2021 7:29 PM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL]KRU 3M-05 Test Pressure to 2700 psig. 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. Dusty, Approval is granted to lower the BOP test pressure to 2700 psig. The approved sundry should be available tomorrow. Please include this approval with your current approved sundry and available to the State Inspector on site. Thanx, Victoria Sent from my iPhone On Dec 20, 2021, at 7:06 PM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: 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. Victoria, Hope this finds you well. I wanted to get confirmation to lower our test pressures from 3000 psig in original Sundry to 2700 psig for the remainder of 3M-05. This is due to the updated SBHP that we got in the pre-rig. MPSP: 2555 psi using 0.1 psi/ft gradient Static BHP: 3174 psi / 6194’ TVD measured on 10/09/2021 I normally don’t split hairs and go in 500 psig increments, but since we have some room to lower from original 3000 psig and still be above MPSP, and considering the scope now has a 3K flange on the casing head, I think it’s worth doing.. I know your reviewing the full updated scope I submitted to you earlier today, but wanted to confirm this part of it as soon as possible. I wasn’t sure how long the full review would take, but know we’d e-mailed in the past on these types of changes. I will try to follow up with a call a little later, unless I see you respond before. Thank you for your time and working this with us over the weekend and today as the subsidence has been a bit of a pivot! Let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 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:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; WSC Rig Advisor; Hull, Celie Subject:MT7-05 9-5/8" Casing Pressure Test and FIT (PTD #221-087) Date:Saturday, December 18, 2021 5:59:07 PM Attachments:image001.png MT7-05 Intermediate1 csg test and FIT 12-18-2021.pdf MT7-05 Int 1 Casing test and FIT 12-18-21.xlsx Hi Victoria, Please see the attached. The 9-5/8” casing was tested to 3500 psi and a LOT of 14.0 ppg EMW was achieved. Thanks, Polaris – WSC Operations Engineer Celie Hull / Shane McCracken wscopsengineer@conocophillips.com 907.263.4544 (Office) Well Name: Rig: Date:Drilling Supervisor:Pump used:2Strokesarrels234Casing TestPressure Integrity TestHole Size:88.5RKB-CHF:37.0Ft10566.0Ft-MD7494.0Ft-TVD10606.0Ft-MD7499.0Ft-TVDStrkspsiMinpsiStrkspsiMinpsi8.835 50003660 0 00.001370385136602900.251370Mud Weight: 10.5ppgMud Weight:10.5ppg61502336041200.501370Mud 10 min Gel: 5.0Lb/100 Ft2Mud 10 min Gel:5.0Lb/100 Ft292403336062001.001370Test Pressure: 3500.0psi Rotating Weight:######Lbs12 35543660 8 2751.501375Rotating Weight: ######LbsBlocks/Top Drive Weight:43000.0Lbs1547553660103502.001375Blocks/Top Drive Weight:43000.0LbsDesired PIT EMW:14.0ppg1860063660124252.501360Estimates for Test:9.6bblsEstimates for Test:1364psi 3.8 bbls2174073660145003.0013601124 87583660 16 6003.501360EMW = Leak-off Pressure + Mud Weight =27100093660186754.001360 0.052 x TVD0.052 x7494301125103665207504.50136014.0ppg33 1250153665 22 8255.00135036 1370203665 24 9005.501350391490253665269756.0013504216103036702810506.5013504517403011257.0013504818703212007.5013405120003412758.0013405421253613508.5013405722503713709.0013256023809.50132563251010.0013256626406927757229107530407831808133108434508736608.8Bbls8.3Bbls3.7Bbls3.3BblsComments:Volume Bled BackShut-in Pumping Shut-inVolume PumpedPRESSURE INTEGRITY TESTType of Test:Casing TestPressure IntegrityTestHole DepthCasing Shoe DepthCasing Size and Description:Pump Rate: 12/18/2021R. Reinhardt / P. AngelleVolume/Stroke7.00Pumping0.1007MT7-05 Doyon 25CONOCOPHILLIPS Alaska, Inc.Pumping downEMW at 10566 Ft-MD (7494 Ft-TVD) =137010.51370+PIT 15 SecondShut-in Pressure, psiVolume PumpedVolume Bled BackVolume Input05001000150020002500300035004000012345678910PRESSURECASING TESTLEAK-OFF TESTPIT PointBarrels0 5 10 15 20 25 30Shut-In time, MinutesLost 0 psi during test, held 100% of test pressure.MT7-05 Int 1 Casing test and FIT 12-18-21.xlsxSummary 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. 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. 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:Ward, Dusty K To:Loepp, Victoria T (OGC) Subject:Re: [EXTERNAL]Re: 3M-05 Scope Change Date:Saturday, December 18, 2021 12:48:48 PM Thanks Victoria! Sounds good. Sent via the Samsung Galaxy S10e, an AT&T 5G Evolution capable smartphone Get Outlook for Android From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Saturday, December 18, 2021 11:15:31 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]Re: 3M-05 Scope Change Dusty, Approval is granted to proceed with change out of the rams. Please submit a 10-403 Sundry for Change of Approved program by Monday, Dec 20, 2021. Thanx, Victoria Sent from my iPhone On Dec 18, 2021, at 9:27 AM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, Hope this finds you well. We tried to slim up our BHA and get past a little tight spot in our 7” casing, but did not succeed with getting a drift for the new packer. This pushes us into doing a Full subsidence. Please find attached update scope that includes Pull and Replace of the 7” Production casing as well (red text is added scope). I also attached a schematic showing the cemented OA we’ll have when we’re done. Please call my cell if you have any questions. I also included original approved sundry for convenience. I’ll try to get a hold of you on the phone here next. Thank you. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; WSC Rig Advisor; Hull, Celie Subject:MT7-05 Surface Casing Pressure Test and FIT Form Date:Wednesday, December 8, 2021 4:27:00 AM Attachments:image001.png MT7-05 Surface csg test and LOT 12-7-2021.xlsx MT7-05 Surface csg test and LOT 12-7-2021.pdf Hi Victoria, Attached is the MT7-05 surface casing pressure test and formation integrity test form and sheet. If you have any questions, please let us know. Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) Well Name: Rig: Date:Drilling Supervisor:Pump used:2Strokesarrels234Casing TestPressure Integrity TestHole Size:10RKB-CHF:39.7Ft3515.0Ft-MD3060.0Ft-TVD3545.0Ft-MD3065.0Ft-TVDStrkspsiMinpsiStrkspsiMinpsi12.42 20003552 0 00.0013543108135482800.25Mud Weight: 11.0ppgMud Weight:10.0ppg62332354541290.50Mud 10 min Gel: 5.0Lb/100 Ft2Mud 10 min Gel:5.0Lb/100 Ft294253354362201.001340Test Pressure: 3500.0psi Rotating Weight:######Lbs12 63943541 8 3281.50Rotating Weight: ######LbsBlocks/Top Drive Weight:43000.0Lbs1584553539104372.001317Blocks/Top Drive Weight:43000.0LbsDesired PIT EMW:18.5ppg18102763537125492.50Estimates for Test:5.8bblsEstimates for Test:1353psi 2.3 bbls21121573536146523.0013001124 138383534 16 7603.50EMW = Leak-off Pressure + Mud Weight =27161693533188554.001284 0.052 x TVD0.052 x3060301755103531209444.5018.5ppg33 1955153525 22 10365.00127036 2165203520 24 11245.503923652535152612146.0012564225803035112813006.504528003013687.001244483002327.50513300348.001234543552368.5057389.00122360409.50634210.001214664469467248755052548.9Bbls6.2Bbls6.4Bbls4.5BblsComments:Volume Bled BackShut-in Pumping Shut-inVolume PumpedPRESSURE INTEGRITY TESTType of Test:Casing TestPressure IntegrityTestHole DepthCasing Shoe DepthCasing Size and Description:Pump Rate: 12/7/2021B. Book/L. ShirleyVolume/Stroke3.00Pumping0.1183MT7-05 Doyon 2513 3/8" Casing test, LOT to 18.5 ppg EMW with 10.0 ppg LSND and 1352 psi surface pressure.CONOCOPHILLIPS Alaska, Inc.Pumping downEMW at 3515 Ft-MD (3060 Ft-TVD) =Fill in FIT Columns ==>101350+PIT 15 SecondShut-in Pressure, psiVolume PumpedVolume Bled BackVolume Input05001000150020002500300035004000012345678910PRESSURECASING TESTLEAK-OFF TESTPIT PointBarrels0 5 10 15 20 25 30Shut-In time, MinutesLost 41 psi during test, held 98.8% of test pressure.MT7-05 Surface csg test and LOT 12-7-2021.xlsxSummary Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Engineering Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Rendevous Oil Pool, MT7-05 ConocoPhillips Alaska, Inc. Permit to Drill Number: 221-087 Surface Location: 977’ FSL, 1877’ FWL, SESW, SEC. 32, T10N, R2E Bottomhole Location: 2219’ FSL, 1009’ FEL, NWSW, SEC. 25, T10N, R1E Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of November, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.03 23:50:06 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 25479 TVD: 8253 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 11/18/2021 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 8340' to AA081805 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 100.4 15. Distance to Nearest Well Open Surface: x-289954.54 y- 5915799.56 Zone-4 39.5 to Same Pool: 822.5' to RENDEZVOUS 3 16. Deviated wells: Kickoff depth: 650 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H-40 Welded 80.5 39.5 39.5 120 120 16" 13.375" 68 L-80 TXP 3469.5 39.5 39.5 3509 3027.63 12.25"9.625 / 9.87 43.5 / 62.8 L-80 TXP / Hyd56 10494.1 39.5 39.5 10533.6 7456.9 8.75 / 9.875 7" 26 L-80 Hyd563 1934.4 10383.6 7408 12318 8308.9 6.125" 4.5" 12.6 L-80 Hyd563 0 12168 8159 25479 8252.9 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name:Cecilia Hull Chris Brillon Contact Email:cecilia.hull@conocophillips.com Engineering Manager Contact Phone:907-354-7078 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MT7-05 Greater Mooses Tooth Rendezvous Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 0 sx 11 ppg, 870sx 15.8 ppg Class G 1832 1299' FSL,1752' FWL,SESW S6 T9N R2E 2219' FSL, 1009' FEL, NWSW S25 T10N R1E 932535000, 932516000, 932519000, 932538000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips 977' FSL, 1877' FWL, SESW S32 T10N R2E AA081800, AA081781, AA081784, AA081803 3776, 5720, 5756, 5756 18. Casing Program: Top - Setting Depth - BottomSpecifications 3648 Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) 10 yds 2570sx 11 ppg, 270sx 15.8 ppg Conductor/Structural LengthCasing Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Commission Use Only See cover letter for other requirements. 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 660sx ppg Class G Uncemented liner w/ frac sleeves and perf joints Effect. Depth MD (ft): Effect. Depth TVD (ft): Stratigraphic Test No Mud log req'ddd:YYYes No Directional svy req'd: Yes Seabed Report Drilling Fluid Program 20 AAC 25.050 requirementsDrilling Fluid Program BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis gg p y Single Well Gas Hydrates No Inclination-only svy req'dd:YYYes Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal ddd:YYYes No Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Samantha Carlisle at 8:59 am, Oct 19, 2021 SFD 10/19/21 DSR-10/19/21SFD 10/21/2021 221-087 50-103-20833-00-00 139.9 100.4 X VTL 11/3/21 BOP test to 3500 psig Annular preventer test to 2500 psig Diverter variance granted per 20 AAC 25.035(h)(2) Intermediate 2 cement CBL required before drilling production hole Surface casing LOT results to AOGCC as soon as obtained. dts 11/3/2021 JLC 11/3/2021 11/3/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.03 23:52:09 -08'00' ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 18, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-05 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand Producer well from the MT7 drilling pad. The intended spud date for this well is 11/18/2021. It is intended that Doyon 25 be used to drill the well. MT7-05 will utilize a 16 and will TD above the K3 sand and then 13.375 surface. The 12.25 intermediate hole will be drilled to above the top of the HRZ and landed at ~51°. A 9.625 / 9.875 casing above the highest hydrocarbon bearing zone. There is potential to encounter the Tusk sand in the upper part of the intermediate 1 section, and if it is present a 2nd . The 8.75 / 9.875 underreamed intermediate 2 section will be drilled and landed in the Alpine D and landed at ~ 76°. A 7 liner string will be set and cemented from TD to secure the shoe and cover above any hydrocarbon-bearing zones. The production interval will be comprised of a 6.125 hole that will be geo-steered in the Alpine C sand. The well will be completed as a fracture stimulated Producer with 4.5 It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3.Diagram of riser set up. If you have any questions or require further information, please contact Celie Hull at 907-354-7078 / celie.hull@conocophillips.com, or Chris Brillon at 907-265-6120 / chris.l.brillon@conocophillips.com Sincerely, cc: MT7-05 Well File / Jenna Taylor ATO 1560 Dave Lee ATO 1726 Cecilia Hull Chris Brillon ATO 1548 Drilling Engineer Lanston Chin Kuukpik Corp. neer Tusk sand i within p completed as a fracture stimulated Producer (Per email from C. Hull, CPAI.) SFD 10/21/2021 variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. DLB 11/01/2021 MT7-05 Saved: 18-Oct-21 MT7-05 Page 1 of 15 Printed: 18-Oct-21 MT7-05 Well Plan Application for Permit to Drill Table of Contents 1.Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3.Proposed Drilling Program ...................................................................................... 5 4.Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) .................. 6 5.MASP Calculations ................................................................................................... 7 6.Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 8 7.Casing and Cementing Program ............................................................................. 8 8.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................. 10 9.Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................. 11 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ........................................ 11 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ....................... 11 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................. 11 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ..................... 11 (Requirements of 20 AAC 25.005 (c)(14)) ........................................................................... 11 14. Drilling Hazards Summary ..................................................................................... 13 15. Proposed Completion Schematic ......................................................................... 15 MT7-05 Saved: 18-Oct-21 MT7-05 Page 2 of 15 Printed: 18-Oct-21 1.Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-05 2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 977' FSL, 1877' FWL, SESW S32 T10N R2E, UM NAD27 Northings: 289954.54 Eastings: 5915799.56 RKB Elevation 39.5’ AMSL Pad Elevation 100.4’ AMSL Top of Productive Horizon (Heel) 1299' FSL, 1752' FWL , SESW S6 T9N R2E, UM NAD27 Northings: 284546.49 Eastings: 5910991.44 Measured Depth, RKB: 12410’ Total Vertical Depth, RKB: 8332’ Total Vertical Depth, SS: 8192’ Total Depth (Toe) 2219' FSL, 1009' FEL, NWSW S25 T10N R1E, UM NAD27 Northings: 278855.62 Eastings: 5922640.62 Measured Depth, RKB: 25479’ Total Vertical Depth, RKB: 8253’ Total Vertical Depth, SS: 8113’ Please see attached well stick diagram for the current planned development of the pad. SFD 10/21/2021 139.9 MT7-05 Saved: 18-Oct-21 MT7-05 Page 3 of 15 Printed: 18-Oct-21 MT7 Pad Layout MT7 Pad Well Stick Diagram MT7-05 Saved: 18-Oct-21 MT7-05 Page 4 of 15 Printed: 18-Oct-21 MT7-05 PTD Plat MT7-05 Saved: 18-Oct-21 MT7-05 Page 5 of 15 Printed: 18-Oct-21 3.Proposed Drilling Program 1. MIRU Doyon 25 onto well over pre-installed 20” insulated conductor. Install diverter and function test. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan, with KSI WBM. (LWD Program: GR/RES). 4. Run and cement new 13.375” surface casing to surface. Results of the cement operation will be submitted as soon as possible. 5. Install BOPE with the following equipment/configuration: 13-5/8” annular preventer, 3-1/2” x 6” VBR, blind ram and 3-1/2” x 6” VBR. 6. Test BOPE to 250 psi low / 3,500 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12.25” drilling BHA to drill intermediate #1. 8. Chart casing pressure test to 3,500 psi for 30 minutes. 9. Drill out shoe track and 20’ of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 11. Displace well to 9.6 PPG LSND WBM. 12. Drill 12.25” hole to the casing point. 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9.625” solid body rams. Test same to 250 psi low / 3,500 psi high. 15. Run 9.625 / 9.875” intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe or 500’ MD above uppermost hydro-carbon bearing zone. Note that a shallower hydrocarbon bearing sand may be encountered, and a 2nd stage cement job will be completed if the one is detected while drilling. Results of the cement operation will be submitted as soon as possible. a. There is potential for the presence of the Tusk sand, which may be hydrocarbon bearing and require a second stage cement job to place cement 50’ TVD above and below the interval. The required equipment and cement plans are prepared if this becomes necessary. 17. Change upper 9.625” solid body rams to 3-1/2” x 6” VBRs. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 18. Pick up and run in hole with 8.75 / 9.875” drilling BHA to drill intermediate pilot hole. SimOps, perform 9.625 / 9.875” annulus LOT with Ball mill and freeze protect. 19. Chart casing pressure test to 3,500 psi for 30 minutes. 20. Drill out shoe track and 20’ of new hole. 21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.5 ppg EMW. 22. Drill 8.75 / 9.875" hole to section TD. A. As an identified contingency plan: If Casing Drilling is required due to Geologic Instability in Intrm 2 section, refer to below steps: 1. Pick up and run in hole with the 7” steerable drilling liner. Pick up and stab in 6” pilot BHA assembly. (LWD Program: GR/RES). 2. RIH to bottom with 7” SDL on 5” drill pipe. 3. Drill 7” SDL hole to production casing point into the Alpine C sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). e Tusk sand, VTL 11/3/21 Notify AOGCC if shallower HC bearing sand is encountered MT7-05 Saved: 18-Oct-21 MT7-05 Page 6 of 15 Printed: 18-Oct-21 4. Land 7” liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. 5. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparations for cementing. 6. Cement 7” liner to top of liner. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5” drill pipe. 7. Continue to Step 28 below. 23. Circulate wellbore clean and POOH. 24. Change out upper rams to 4-1/2” x 7” VBRs. Test same to 250 psi low / 3,500 psi high. 25. Pick up and run in hole with the 7” liner on 5” DP to section TD 26. Circulate and condition mud in preparations for cementing. 27. Cement 7” liner to required TOC. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5” drill pipe. Results of the cement operation will be submitted as soon as possible. 28. Pick up 4” DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 29. Pick up and RIH with 6.125” drilling assembly. (LWD Program: GR/Azimuthal RES). 30. Chart casing pressure test to 3,500 psi for 30 minutes and record results. 31. Drill out and perform FIT to 13.5 PPG EMW maximum. Minimum acceptable leak-off for drilling ahead is 11.0 ppg EMW. 32. Drill 6.125" horizontal hole to section TD (LWD Program: GR/Azimuthal RES. 33. Circulate the hole clean and POOH. 34. Run 4.5” liner on 4” DP, set liner hanger and packer. Chart casing pressure test 3500psi for 30 min. POOH LD DP. 35. Run new 4.5” tubing with landing nipple, gas lift mandrel(s), DHG and production packer. Displace mud in production casing to kill weight brine, space out, and land tubing hanger with pre-installed, pre-tested BPV. 36. Pressure test seals to 5,000 psi. Nipple down BOP 37. Install tubing head adapter assembly. Pressure test adapter assembly to 5,000 psi. Remove BPV. 38. Connect tubing and IA, then pump freeze protect down IA taking returns up the tubing. Allow freeze protect to u-tube leaving freeze protect in both 200’ TVD below base of permafrost. 39. Secure well. Rig down and move out. 4. Diverter and BOP Information (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP and diverter schematics on file for Doyon 25 MT7-05 Saved: 18-Oct-21 MT7-05 Page 7 of 15 Printed: 18-Oct-21 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD (ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 3509 / 3028 14.5 1370 1980 9.625 / 9.875 10533.6 / 7457 16.5 3374 2929 7.00 12318 / 8332 12.5 3760 2909 4.5 25479/ 8253 12.5 3740 n/a PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 115 = 54 psi OR ASP = FPP – (0.1 x D) = 1370 – (0.1 x 3028’) = 1067psi Minimum MW needed = 8.7 PPG 2. Drilling below 13.375” surface casing ASP = [(FG x 0.052) – 0.1] D = [(14.5 x 0.052) – 0.1] x 3028’ = 1980psi OR ASP = FPP – (0.1 x D) = 3374 – (0.1 x 7457) = 2628 psi Minimum MW needed = 8.8 PPG MT7-05 Saved: 18-Oct-21 MT7-05 Page 8 of 15 Printed: 18-Oct-21 3. Drilling below first 9.625 / 9.875” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 7457 = 5652 psi OR ASP = FPP – (0.1 x D) = 3760 – (0.1 x 8332’) = 2929 psi Minimum MW needed = 8.7 PPG 4. Drilling below 7” production liner ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 8332 = 4570 psi OR ASP = FPP – (0.1 x D) = 3740 – (0.1 x 8253) = 2909 psi Minimum MW needed = 8.8 PPG (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 16 68 L-80 TXP Cement to Surface 9.625 / 9.875 12.25 43.5 / 62.8# L-80 TXP / Hyd563 250’ TVD or 500’ MD, whichever is greater, above highest producing zone 7 8.75 / 9.875 26 L-80 Hyd563 Cement to Intrm 2 Liner Top 4.5 6.125 12.6 L-80 Hyd563 Uncemeneted open hole liner with frac ports and perf joints MT7-05 Saved: 18-Oct-21 MT7-05 Page 9 of 15 Printed: 18-Oct-21 13.375” Surface Casing run to 3509’ MD / 3028’ TVD Cement Plan: Cement from 3509’ MD to 3009' (500’ of tail) with Deepcrete + Add's. @ 15.8 ppg, and from 3009' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1088’ MD), zero excess in 20” conductor. Lead slurry from 3009’ MD to surface with Arctic Lite Crete @ 11.0 ppg Total Volume = 4429 ft3 => 2570 sx of 11.0 ppg Deepcrete + Add's @ 1.73 ft3 /sk Tail slurry from 3509’ MD to 3009’ MD with 15.8 ppg Deepcrete + Add's Total Volume = 349 ft3 => 270.0 sx of 15.8 ppg Class G + Adds @ 1.33 ft3/sk 9.625 / 9.875” Intermediate Casing run to 10533.6’ MD / 7457’ TVD Cement Plan: Top of slurry is designed to be at 8675’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone, the Susitna Sand. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2 stage cement job will be performed to isolate this zone. Assume 40% excess annular volume in open hole. Tail slurry from 10533.6’ MD to 8675’ MD with 15.8 ppg Class G + Adds Total Volume = 1006 ft3 => 870 sx of 15.8 ppg Class G + Adds @ 1.16 ft3/sk 7” Intermediate Casing run to 12318’ MD / 8309’ TVD Cement Plan: Top of slurry is designed to be at 10298’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest hydrocarbon bearing zone Alpine C. Assume 40% excess annular volume. Tail slurry from 12318’ MD to 10298’ MD with 15.8 ppg Class G + Adds Total Volume = 756.8 ft3 => 660 sx of 15.8 ppg Class G + Adds@ 1.16 ft3/sk MT7-05 Saved: 18-Oct-21 MT7-05 Page 10 of 15 Printed: 18-Oct-21 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Intermediate #2 Production Hole Size in. 16 12.25 8.75 / 9.875 6.125 Casing Size in. 13.375 9.625 / 9.875 7 4.5 Density PPG 10.5 – 11/0 9.6 – 10.8 10.8 – 13.0 8.8 – 9.5 PV cP 13 10 10 15 YP lb./100 ft2 35-50 20 - 28 20 - 28 15 - 20 Funnel Viscosity s/qt. 200 40 - 50 40 - 50 60 - 80 Initial Gels lb./100 ft2 50 10 10 10 10 Minute Gels lb./100 ft2 60 15 20 15 API Fluid Loss cc/30 min. N.C. – 15.0 5.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0 – 12.0 8.0 – 12.0 10.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A freshwater drilling fluid (KSI) will be used for the surface interval. Keep flow line viscosity at r 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.5 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.2 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with OBM weighted to 8.8-9.5 ppg. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 25 Mud System on file. to mitigate shale instability and cycling. gy g Managed Pressure Drilling (MPD) will be utilized g MT7-05 Saved: 18-Oct-21 MT7-05 Page 11 of 15 Printed: 18-Oct-21 Drilling fluid practices will be in accordance with appropriate regulations. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT7-05 will be injected into a permitted annulus on the MT7 pad, or hauled to the Class 1 disposal well on CD1. The MT7-05 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to ~2000' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre- drill interpretations. Once MT7-05 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the C10 formation, above the K3. These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig’s specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3028’) + 1,500 psi = 3389 psi Pore Pressure = 1370 psi Therefore Differential = 3389– 1,370 = 2019 psi. above the K3. Surface casing w within SFD 10/21/2021 consideration may be given to permit this well for annular injection. MT7-05 Saved: 18-Oct-21 MT7-05 Page 12 of 15 Printed: 18-Oct-21 The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 13.375” 68 L-80 3 TXP 2260 psi 1921 psi 5020 psi 4267 psi 9.625 / 9.875” 43.5 / 62.8 L-80 3 TXP / Hyd563 3810 psi 3238 psi 6330 psi 5380 psi MT7-05 Saved: 18-Oct-21 MT7-05 Page 13 of 15 Printed: 18-Oct-21 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13.375” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Surface Formations Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running speeds 12.25” Hole / 9.625 / 9.875” Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8.75 / 9.875” Hole / 7” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT7-05 Saved: 18-Oct-21 MT7-05 Page 14 of 15 Printed: 18-Oct-21 6.125” Hole / 4.5” Pre-Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT7-05 Saved: 18-Oct-21 MT7-05 Page 15 of 15 Printed: 18-Oct-21 15. Proposed Completion Schematic 40 515 515 1014 1014 1515 1515 2015 2015 2515 2515 3015 3015 5015 5015 8014 8014 12015 12015 18014 18014 23015 MT7-05_wp04 Plan Summary 0 3 Dogleg Severity3500 7000 10500 14000 17500 21000 24500 Measured Depth Surface INT 1 INT 2 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in] 100 1096 1581 MT7-01_wp10 40 992 MT7-02 wp04 40 999 2478 2970 MT7-03 40 991 MT7-04 40 993 MT7-06 402021 2534 3045 MT7-07 wp02 40 1518 MT7-09 wp02 40 MT7-99 wp02 1104 614 GMT2-211 wp01 MT7-06PB1 0 4500 True Vertical Depth-2000 0 2000 4000 6000 8000 10000 Vertical Section at 333.00° Surface INT 1 INT 2 0 50 100 Centre to Centre Separation0 1000 2000 3000 4000 5000 6000 7000 Measured Depth Equivalent Magnetic Distance DDI 7.247 SURVEY PROGRAM Date: 2017-03-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.50 1000.00 MT7-05_wp04 (MT7-05) GYD-GC-SS 1000.00 1500.00 MT7-05_wp04 (MT7-05) MWD OWSG 1500.00 3509.00 MT7-05_wp04 (MT7-05) MWD+IFR2+SAG+MS 3509.00 3909.00 MT7-05_wp04 (MT7-05) MWD-INC_ONLY (INC>10°) 3909.00 5409.00 MT7-05_wp04 (MT7-05) MWD OWSG 5409.00 10533.00 MT7-05_wp04 (MT7-05) MWD+IFR2+SAG+MS 10533.00 11033.00 MT7-05_wp04 (MT7-05) MWD-INC_ONLY (INC>10°) 11033.00 11533.00 MT7-05_wp04 (MT7-05)MWD OWSG 11533.00 12318.00 MT7-05_wp04 (MT7-05)MWD+IFR2+SAG+MS 12318.00 12818.00 MT7-05_wp04 (MT7-05) MWD-INC_ONLY (INC>10°) 12818.00 14318.00 MT7-05_wp04 (MT7-05) MWD OWSG 14318.00 25479.64 MT7-05_wp04 (MT7-05) MWD+IFR2+SAG+MS Surface Location North / 5915543.69 East / 1429990.67 Ground / 100.00 CASING DETAILS TVD MD Name 3028.15 3509.00 Surface 7456.84 10533.60 INT 1 8308.90 12318.32 INT 2 Mag Model & Date: BGGM2020 01-Oct-21 Magnetic North is 14.72° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.40° 57144.89nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 650.00 0.00 170.00 650.00 0.00 0.00 0.00 170.00 0.00 Start Build 1.50 3 850.00 3.00 170.00 849.91 -5.16 0.91 1.50 170.00 -5.01 Start Build 2.00 41150.00 9.00 170.00 1148.13 -36.02 6.35 2.00 0.00 -34.98 Start DLS 2.50 TFO 47.66 5 2942.78 51.22 211.94 2673.50 -806.82 -357.73 2.50 47.66 -556.47 Start 6416.91 hold at 2942.83 MD 6 9359.78 51.22 211.94 6692.68 -5051.88 -3004.17 0.00 0.00-3137.40 Start DLS 3.00 TFO 106.77 710533.60 51.00 260.48 7456.84 -5532.70 -3721.59 3.18 106.12-3240.11 810641.60 51.00 260.48 7524.81 -5546.58 -3804.37 0.00 0.00-3214.90 912318.32 76.00 312.00 8308.90 -5077.95 -5143.09 3.08 75.82-2189.57 1012378.32 76.00 312.00 8323.42 -5038.99 -5186.35 0.00-2135.22 1112934.69 88.47 326.68 8398.87 -4622.12 -5543.02 3.44 50.62-1601.86 1212958.25 88.47 326.68 8399.50 -4602.45 -5555.95 0.00 0.00-1578.46 MT7-05 T01 102920 1313162.10 90.69 332.81 8401.01 -4426.46 -5658.59 3.20 70.14-1375.06 1425479.64 90.69 332.81 8253.50 6529.65-11285.66 0.00 0.0010941.55 MT7-05 T02 102920 FORMATION TOP DETAILS TVDPathFormation 1256.34 C-40 1507.34 C-30 1851.48 C-10 2857.72 K-3 3470.46 Alb 97 3661.13 Alb 96 3855.86 Alb 95 4382.49 Alb 94 4786.91 Alb 93 6074.25 Alb 92 6289.51 Alb 91 7291.86 HRZ 7480.70 LCU 8191.62 Alpine C By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan 100+39.5 @ 139.50usft 0300060009000True Vertical Depth (1500 usft/in)-3000 0 3000 6000 9000Vertical Section at 333.00° (1500 usft/in)MT7-05 T01 102920MT7-05 T02 102920SurfaceINT 1INT 21000200030004000500060007000800090001000011000120001300014 000 15 000 16000 17 000 18000 19 000 20000 21000 22000 23000240002500025480MT7-05/MT7-05_wp04 Section View Project: Western North SlopeSite: GMT2 Rendezvous PadWell: MT7-05Wellbore: MT7-05Design: MT7-05_wp04 Plan View Project: Western North SlopeSite: GMT2 Rendezvous PadWell: MT7-05Wellbore: MT7-05Design: MT7-05_wp04-500005000South(-)/North(+) (2500 usft/in)-15000 -10000 -5000 0 5000West(-)/East(+) (2500 usft/in)MT7-05 T01 QMMT7-05 T02 102920SurfaceINT 1INT 21000200030004000500060007000MT7-05/MT7-05_wp04 NAD 83 ! ! 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(37!#. 27#27 !#7 7. 7#" ) (".(#2! 0 "3!"#. 737"(#77 3 #27 !3.# 05 !#@? 7# (37#(7 23!22#2. .32# 7 3..7# (#) (7#(2 0 (3"7#(2 23!""#! .3".#2" 37#2" (#) ("7#(2 0 (3"2#(2 23.#( .32# 3 # 05 (#@?7(# !3.2.# 23!"# 7 .3 .# 32# (2#!7) !.2.# 0 (3."(#.. 0 (."(#.7 + )9<E )9<E 0 E 1 Davies, Stephen F (CED) From:Hull, Celie <Cecilia.Hull@conocophillips.com> Sent:Wednesday, October 20, 2021 7:24 PM To:Davies, Stephen F (CED) Subject:Re: [EXTERNAL] GMTU MT7-05 (PTD 221-087) - Request HiStephen, Iapologizefornotcatchingthisemailyesterday,andIthankyouforbeingdiligent. ThecoverletterisincorrectandIhavejustupdatedthetemplatewehavebeenusingforthose.Wewillbesetting surfacecasingwithintheK3intervalasitismoresuitedforpotentialfutureannulardisposal,andwillhavegamma/ resistivitywhiledrillingtodeterminetheformationtop.Ifyouwouldlikeamoredetailedgeologicalexplanation,please letmeknowandIcansetthatupwithoneofourgeologists. Thankyou, CelieHull DrillingEngineer Cell:(907)354Ͳ7078 From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Wednesday,October20,20215:02:29PM To:Hull,Celie<Cecilia.Hull@conocophillips.com> Subject:RE:[EXTERNAL]GMTUMT7Ͳ05(PTD221Ͳ087)ͲRequest HiCelie, Didyougetachancetolookatmyemailbelow?I’dliketokeepCPAI’sPermittoDrillApplicationforGMTUMT7Ͳ05 movingthroughAOGCC’sreviewprocess. Thanksandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Davies,StephenF(CED) Sent:Tuesday,October19,20212:03PM To:Hull,Celie<Cecilia.Hull@conocophillips.com> Cc:Boyer,DavidL(CED)<david.boyer2@alaska.gov>;Loepp,VictoriaT(CED)<victoria.loepp@alaska.gov> Subject:RE:[EXTERNAL]GMTUMT7Ͳ05(PTD221Ͳ087)ͲRequest Celie, Quickquestion:InoticethatthecoverletterforCPAI’sGMTUMT7Ͳ05PermittoDrillapplicationstates: 2 ButCPAI’sdirectionalsurveyplanshowstheMDforKͲ3asfollows: Typically,thesesurveyplansplacethehorizon/markerlabelinthelinebeneaththecorrespondingfootage,suchas CPAI’sforecastof3,509’MDforthesurfacecasingshoeshowninthesameplan: So,unlessI’mmisreadingthese,hastheestimateddepthforKͲ3changed?HowwillCPAIensurethatthesurfacecasing shoeisplacedattheproperdepth? Thanksforyourhelpandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Hull,Celie<Cecilia.Hull@conocophillips.com> Sent:Tuesday,October19,202110:47AM To:Davies,StephenF(CED)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]GMTUMT7Ͳ05(PTD221Ͳ087)ͲRequest Soundsgood,IwillmakesuretonotethatandincludeanExceldirectionalplanforourfuturepermits. Asalways,pleasereachoutwithquestionsanytime. CelieHull DrillingEngineerͲConocoPhillipsAlaska CellͲ(907)354Ͳ7078 celie.hull@conocophillips.com From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Tuesday,October19,202110:45AM To:Hull,Celie<Cecilia.Hull@conocophillips.com> Subject:RE:[EXTERNAL]GMTUMT7Ͳ05(PTD221Ͳ087)ͲRequest Celie, Noneedforanyextrawork.FordataloadingpurposesIonlyneedMD,inclination,andazimuthvaluestoloadintomy workstation. AOGCChasretainedNAD27asourreferencedatumsothatallofAOGCC’slocationcoordinatesareconsistent throughouttimetopreventconversionerrors.OnthePermittoDrillapplicationformandonthefollowupWell 3 CompletionReportformtheoperatorͲprovidedcoordinatesinbox4bmustreferenceNAD27,butnotnecessarilyonthe directionalplan. Thanksforyourhelpandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Hull,Celie<Cecilia.Hull@conocophillips.com> Sent:Tuesday,October19,202110:28AM To:Davies,StephenF(CED)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]GMTUMT7Ͳ05(PTD221Ͳ087)ͲRequest Steve, IhavethisExceldirectionalplanreadilyavailable,thoughitshouldbenotedthatoursoftwareoperatesinNAD83rather thantheNAD27datumwetypicallysendtotheAOGCC.Ofcoursethedirectionalplanitselfisthesame,butthe Northing/Eastingsetc.willnotbeconsistentwithwhatwetypicallysendtoyou. IfyouwillneedthisplaninNAD27,pleaseletmeknowandIcanhaveourdirectionalplannerbeginworkingonanexcel versionofit. Pleasereachoutanytimeifyouhavequestionsorrequireadditionalinformation. Thankyou! CelieHull DrillingEngineerͲConocoPhillipsAlaska CellͲ(907)354Ͳ7078 celie.hull@conocophillips.com From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Tuesday,October19,20219:55AM To:Hull,Celie<Cecilia.Hull@conocophillips.com> Subject:[EXTERNAL]GMTUMT7Ͳ05(PTD221Ͳ087)ͲRequest 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. Cecilia, I’mreviewingCPAI’sPermittoDrillapplicationforGMTUMT7Ͳ05.ItwouldhelpmyportionofthisreviewifCPAIcould provideacopyoftheplanneddirectionalsurveydatainspreadsheetorcommaͲdelimitedtextformat.Thiswillspeed loadingofthedataintomyworkstationandensureaccuracy. Thanksandstaysafe, SteveDavies SeniorPetroleumGeologist AlaskaOilandGasConservationCommission(AOGCC) Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Greater Moose's Tooth Greater Moose's Tooth, Rendezvous Oil 221-087 Greater Moose's Tooth Unit MT07-05 X X WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:GMTU MT7-05Initial Class/TypeDEV / PENDGeoArea890Unit10750On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2210870GRTR MOOSES TOOTH, RENDEZV OIL - 2822NA1Permit fee attachedYesSurface Location lies within AA081800; Top Productive Interval lies in AA081781;2Lease number appropriateYesPortion of Productive Interval lies in AA081784; TD lies in AA081803.3Unique well name and numberYesGreater Mooses Tooth, Rendezvous Oil Pool – 2822004Well located in a defined poolYesConservation Order No. 793, issued July 13, 2021, governs Rendezvous Oil Pool.5Well located proper distance from drilling unit boundaryYesAs planned, this well conforms with spacing requirements.6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesProperty plat and vertical section view provided.8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor provided18Conductor string providedYes19Surface casing protects all known USDWsYes226% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented frac sleeves and perf joints22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYesDiverter variance granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax formation pressure is 3648 psig(8.7 ppg EMW); will drill w/ 8.8- 13.0 ppg EMW & MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1832 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)YesH2S not expected; rig has sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure gradient is 8.7 ppg EMW. Managed Pressure Drilling (MPD) technique will be used36Data presented on potential overpressure zonesNAto maintain borehole stability and mitigate any abnormal pressure encountered. Rig is prepared to37Seismic analysis of shallow gas zonesNAweight up mud if over-pressure is encountered.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate10/21/2021ApprVTLDate11/1/2021ApprSFDDate10/19/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03JLC 11/3/2021
