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224-005
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 3 3 - 2 0 7 1 7 - 0 0 - 0 0 We l l N a m e / N o . K E N A I U N I T 4 1 - 0 8 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 4/ 7 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 0 5 0 Op e r a t o r H i l c o r p A l a s k a , L L C MD 11 0 9 4 TV D 96 7 5 Cu r r e n t S t a t u s 1- G A S 1/ 2 1 / 2 0 2 6 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : CB L 3 - 2 3 - 2 4 , P e r f , , G P T l o g s , G e o t a p , L W D ( P C G , A D R , P W D , D D S R , C T N , A L D ) 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 4/ 5 / 2 0 2 4 5 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 13 1 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 0 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 13 1 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 1 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 15 1 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 1 2 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 16 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 3 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 16 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 4 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 17 1 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 1 5 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 17 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 6 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 18 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 7 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 19 1 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 8 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 19 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 1 9 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 2 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 20 2 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 2 0 . l a s 38 6 8 2 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 1 o f 5 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 3 3 - 2 0 7 1 7 - 0 0 - 0 0 We l l N a m e / N o . K E N A I U N I T 4 1 - 0 8 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 4/ 7 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 0 5 0 Op e r a t o r H i l c o r p A l a s k a , L L C MD 11 0 9 4 TV D 96 7 5 Cu r r e n t S t a t u s 1- G A S 1/ 2 1 / 2 0 2 6 UI C No DF 4/ 5 / 2 0 2 4 22 2 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 2 1 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 22 2 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 2 2 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 23 2 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 2 3 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 2 4 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 1 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 2 5 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 2 6 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 2 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 2 7 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 8 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 3 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 9 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 4 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 9 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 5 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 10 1 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : K U 4 1 - 0 8 - Ge o t a p T e s t 6 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 11 1 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 7 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 12 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 8 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 12 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 : K U 4 1 - 0 8 - Ge o t a p T e s t 9 . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 10 4 1 1 0 9 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 : K U 4 1 - 0 8 L W D Fi n a l . l a s 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 G e o - T a p P r e s s u r e Te s t s . c g m 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 G e o - T a p P r e s s u r e Te s t s . e m f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 G e o - T a p P r e s s u r e Te s t s . p d f 38 6 8 2 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 2 o f 5 KU 4 1 - 0 8 L W D Fi n al. l as 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 3 3 - 2 0 7 1 7 - 0 0 - 0 0 We l l N a m e / N o . K E N A I U N I T 4 1 - 0 8 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 4/ 7 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 0 5 0 Op e r a t o r H i l c o r p A l a s k a , L L C MD 11 0 9 4 TV D 96 7 5 Cu r r e n t S t a t u s 1- G A S 1/ 2 1 / 2 0 2 6 UI C No DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 G e o - T a p P r e s s u r e Te s t s . t i f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 F i n a l G e o t a p R e p o r t . p d f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l M D . c g m 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l T V D . c g m 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 - D e f i n i t i v e S u r v e y Re p o r t . p d f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 - D S R A c t u a l _ P l a n Vi e w . p d f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 - D S R A c t u a l _ V S e c . p d f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 - F i n a l S u r v e y s . x l s x 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 _ D S R - G I S . t x t 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 _ D S R . t x t 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l M D . e m f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l T V D . e m f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l M D . p d f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l T V D . p d f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l M D . t i f 38 6 8 2 ED Di g i t a l D a t a DF 4/ 5 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 L W D F i n a l T V D . t i f 38 6 8 2 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 68 5 9 4 9 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 : K U 4 1 - 0 8 C B L MA I N 7 . 6 2 5 I N C O R R . l a s 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 11 0 0 7 6 7 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 : K U 4 1 - 0 8 C B L MA I N P A S S 4 . 5 I N C O R R . l a s 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 11 0 0 6 1 0 0 3 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 : K U _ 4 1 - 08 _ G P T _ 1 1 - A p r i l - 2 0 2 4 _ ( 4 7 6 7 ) . l a s 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 10 9 0 4 1 0 5 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 : K U _ 4 1 - 08 _ P e r f _ C I B P _ 1 1 - A p r i l - 2 0 2 4 _ ( 4 7 6 7 ) . l a s 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 4 . 5 M A I N P A S S . d l i s 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 7 . 6 2 5 M A I N P A S S . d l i s 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 C B L F I N A L C O R R . p d f 38 7 4 8 ED Di g i t a l D a t a DF 5/ 1 3 / 2 0 2 4 E l e c t r o n i c F i l e : K U 4 1 - 0 8 R E P E A T P A S S . d l i s 38 7 4 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 3 o f 5 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 3 3 - 2 0 7 1 7 - 0 0 - 0 0 We l l N a m e / N o . K E N A I U N I T 4 1 - 0 8 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 4/ 7 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 0 5 0 Op e r a t o r H i l c o r p A l a s k a , L L C MD 11 0 9 4 TV D 96 7 5 Cu r r e n t S t a t u s 1- G A S 1/ 2 1 / 2 0 2 6 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Co m p l e t i o n D a t e : 4/ 7 / 2 0 2 4 DF 5/ 1 3 / 2 0 2 4 E l e c t r o n i c F i l e : K U _ 4 1 - 0 8 _ G P T _ P e r f _ C I B P _ 1 1 - Ap r i l - 2 0 2 4 _ ( 4 7 6 7 ) . p d f 38 7 4 8 ED Di g i t a l D a t a DF 7/ 1 6 / 2 0 2 5 10 2 9 5 1 0 2 0 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 : K U _ 4 1 - 08 _ P l u g _ P e r f _ 2 4 - J u n e - 2 0 2 5 _ ( 5 5 3 0 ) . l a s 40 6 6 7 ED Di g i t a l D a t a DF 7/ 1 6 / 2 0 2 5 E l e c t r o n i c F i l e : K U _ 4 1 - 0 8 _ P l u g _ P e r f _ 2 4 - J u n e - 20 2 5 _ ( 5 5 3 0 ) . p d f 40 6 6 7 ED Di g i t a l D a t a DF 7/ 2 8 / 2 0 2 5 0 3 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 : K U _ 4 1 - 08 _ P P R O F _ 3 0 - J u n e - 2 0 2 5 _ ( 5 5 4 1 ) . l a s 40 6 9 2 ED Di g i t a l D a t a DF 7/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : K U _ 4 1 - 0 8 _ P P R O F _ 3 0 - J u n e - 20 2 5 _ ( 5 5 4 1 ) . p d f 40 6 9 2 ED Di g i t a l D a t a DF 10 / 3 / 2 0 2 5 99 5 0 9 7 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 : K U 4 1 - 0 8 CO R R E L A T I O N P A S S T Y 8 4 - 0 6 S A N D 9 8 5 7 - 98 7 7 8 - 2 8 - 2 5 . l a s 40 9 4 8 ED Di g i t a l D a t a DF 10 / 3 / 2 0 2 5 98 9 2 9 6 9 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 : K U 4 1 - 0 8 T Y 8 4 - 6D S A N D 9 8 3 7 - 9 8 5 7 C O R R E L A T I O N P A S S 8 - 28 - 2 5 . l a s 40 9 4 8 ED Di g i t a l D a t a DF 10 / 3 / 2 0 2 5 99 4 2 9 7 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 : K U _ 4 1 - 08 _ P e r f _ 1 6 - S e p t e m b e r - 2 0 2 5 _ ( 5 6 5 6 ) . l a s 40 9 4 8 ED Di g i t a l D a t a DF 10 / 3 / 2 0 2 5 E l e c t r o n i c F i l e : K U 4 1 - 0 8 P E R F F I N A L . p d f 40 9 4 8 ED Di g i t a l D a t a DF 10 / 3 / 2 0 2 5 E l e c t r o n i c F i l e : K U _ 4 1 - 0 8 _ P e r f _ 1 6 - S e p t e m b e r - 20 2 5 _ ( 5 6 5 6 ) . p d f 40 9 4 8 ED Di g i t a l D a t a We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 4 o f 5 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 3 3 - 2 0 7 1 7 - 0 0 - 0 0 We l l N a m e / N o . K E N A I U N I T 4 1 - 0 8 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 4/ 7 / 2 0 2 4 Pe r m i t t o D r i l l 22 4 0 0 5 0 Op e r a t o r H i l c o r p A l a s k a , L L C MD 11 0 9 4 TV D 96 7 5 Cu r r e n t S t a t u s 1- G A S 1/ 2 1 / 2 0 2 6 UI C No Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Da t e C o m m e n t s De s c r i p t i o n Re l e a s e D a t e : We d n e s d a y , J a n u a r y 2 1 , 2 0 2 6 AO G C C Pa g e 5 o f 5 1/ 2 1 / 2 0 2 6 M. G u h l Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. T40948KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Re-Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: Beluga-Up 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,094'N/A Casing Collapse Structural Conductor 1,410psi Surface 2,470psi Intermediate 4,790psi Production Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng LTP; N/A 6,779' MD / 5,822'TVD; N/A, N/A 9,675'10,290'8,945' Kenai Tyonek Gas Pool, Tyonek Gas 1 16" 13-1/2" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 41-08CO 510C Same ~3746psi See Schematic Length August 29, 2025 11,093'4,314' Tieback 4-1/2" 9,674' Perforation Depth MD (ft): 6,984' 4-1/2" See Attached Schematic 6,890psi 2,980psi 5,210psi 120' 5,992' 120' 1,579' Size 120' 7-5/8"6,984' 1,579' MD Hilcorp Alaska, LLC Proposed Pools: 13.5# / L-80 TVD Burst 6,786' 1,488' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 224-005 50-133-20717-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Stefan Reed, Operations Engineer AOGCC USE ONLY 9,020psi Tubing Grade: stefan.reed@hilcorp.com 206-518-0400 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:35 am, Aug 21, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.21 09:08:29 - 08'00' Noel Nocas (4361) 325-498 BJM 8/22/25 10-404 DSR-8/26/25SFD 8/21/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.27 08:35:12 -08'00'08/27/25 RBDMS JSB 082725 Add Perf Well: KU 41-08 August 2025 Well Name: KU 41-08 API Number: 50-133-20717-00-00 Current Status: Gas Producer Permit to Drill Number: 224-005 First Call Engineer: Stefan Reed (206) 518-0400 (c) (907) 777-8433 Second Call Engineer: Chad Helgeson (907) 229-4824 (c) Maximum Expected BHP: 4600 psi @ 8541’ TVD 2024 RFT Data Max. Potential Surface Pressure: 3746 psi Using 0.1 psi/ft Applicable Frac Gradient: 0.72 psi/ft using 13.83 ppg EMW FIT at the intermediate casing 3/13/24 Shallowest Potential Perf TVD: ૠ࢙ .ૠ࢙ ࢌ࢚ ି.࢙ ࢌ࢚ =ᇱࢀࢂࡰ Top of Pools per CO 510C:Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD Tyonek Gas Pool 1 – 10,303’ MD/8,958’ TVD Brief Well Summary KU 41-08 was drilled and completed with Hilcorp Rig 169 March 2024 targeting Tyonek, Upper Tyonek and Lower Beluga sands at Kenai Gas Field. The well was completed with a 4.5” completion with initial perforations in the Tyonek Gas Pool 1. In June of 2025 the perforations in the Tyonek Gas Pool were isolated with a composite bridge plug. Perforations were added in the 84-6 sand of the Beluga/Upper Tyonek gas pool. No cement was dumped on top of the CBP, and the well is currently considered to be commingled between pools. Currently the well is producing out of the 84-6 sand only at ~1mmscfd at ~1,000psi FTP. The objective of this procedure is to reperforate the 84-6 sand to improve flow rates. Wellbore Conditions: - Currently flowing @ ~1mmscfd, 1,000psi FTP. - Last intervention 6/30/2025, e-line production log. Eline Procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 4000psi high 3. RIH and perforate/reperforate zone per table below: Pool Sand Top MD Btm. MD Top TVD Btm. TVD Ft Bel/UT TY 84-6D ±9,837’±9,881’±8,541’±8,581’±44 4. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing, b. Pending well production, all perf intervals may not be completed. Reperf zone at RE/GEO discretion based on production results. c. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations or patch across perforations. d. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations e. Above perfs are in the Beluga/Upper Tyonek Gas Pool governed by CO 510C 5. RD E-Line Unit and turn well over to production Perforations were added in the 84-6 sand of the Beluga/Upper Tyonek gas pool perforations in the Tyonek Gas Pool were isolated reperforate the 84-6 sand Add Perf Well: KU 41-08 August 2025 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Nitrogen procedure _____________________________________________________________________________________ Updated by DMA 07-14-25 Schematic Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16”Surf 120’ 10-3/4”Surface 45.5 / L-80 / DWC/C 9.950”Surf 1,579’ 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875”Surf 6,984’ 4-1/2"Production 13.5 / L-80 / DWC/C 3.920”6,779’11,093’ Tieback Detail 4-1/2” Tieback 13.5 & / L-80 / TXP & BTC 3.920”Surface 6,786’ JEWELRY DETAIL No Depth Item 1 6,779’5-1/2” Liner Top HRD-E ZXP Packer w/ 4.5” XO 2 6,779’5-1/2” 17# seal Stem, 0.62’ off seat (4.78”ID) 3 10,290’Composite Bridge Plug (6/24/25) 4 10,595 CIBP set 11-Apr-2024 5 10,760’CIBP (5 gallon cmt on top) TOC @ ±10,752’ MD OPEN HOLE / CEMENT DETAIL 10-3/4”122 BBL’s of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2” Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBL’s of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8” Hole. CBL run 3-23-24 TOC @ 1346’ 4-1/2”129 BBL’s of 13ppg lead followed by 15.3 ppg tail in 6-3/4” Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status Top of Pool 6 Pool – 5263’ MD, 4,553’ TVD Top of Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD TY 84_6 9,837’9,877’8,541’8,578’40’6/25/25 Open Top of Tyonek Gas Pool 1 - 10,303’ MD, 8958’ TVD D2 10,323'10,377'8,974'9,023'54'4/11/24 Isolated D3B 10,727'10,741'9,338'9,351'14'4/12/24 Isolated D3D 10,769'10,782'9,376'9,388'13'4/7/24 Isolated NOTES 10’ Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 _____________________________________________________________________________________ Updated by SR 08-15-25 Proposed Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16”Surf 120’ 10-3/4”Surface 45.5 / L-80 / DWC/C 9.950”Surf 1,579’ 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875”Surf 6,984’ 4-1/2"Production 13.5 / L-80 / DWC/C 3.920”6,779’11,093’ Tieback Detail 4-1/2” Tieback 13.5 & / L-80 / TXP & BTC 3.920”Surface 6,786’ JEWELRY DETAIL No Depth Item 1 6,779’5-1/2” Liner Top HRD-E ZXP Packer w/ 4.5” XO 2 6,779’5-1/2” 17# seal Stem, 0.62’ off seat (4.78”ID) 3 10,290’Composite Bridge Plug (6/24/25) 4 10,595 CIBP set 11-Apr-2024 5 10,760’CIBP (5 gallon cmt on top) TOC @ ±10,752’ MD OPEN HOLE / CEMENT DETAIL 10-3/4”122 BBL’s of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2” Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBL’s of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8” Hole. CBL run 3-23-24 TOC @ 1346’ 4-1/2”129 BBL’s of 13ppg lead followed by 15.3 ppg tail in 6-3/4” Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status Top of Pool 6 Pool – 5263’ MD, 4,553’ TVD Top of Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD TY 84_6 9,837’9,877’8,541’8,578’40’6/25/25 Open TY 84_6 ±9,837’±9,881’±8,541’±8,581’±44’TBD Proposed Top of Tyonek Gas Pool 1 - 10,303’ MD, 8958’ TVD D2 10,323'10,377'8,974'9,023'54'4/11/24 Isolated D3B 10,727'10,741'9,338'9,351'14'4/12/24 Isolated D3D 10,769'10,782'9,376'9,388'13'4/7/24 Isolated NOTES 10’ Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 T40692KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: N2 Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,094 feet See Schematic feet true vertical 9,675 feet N/A feet Effective Depth measured 10,290 feet 6,779 feet true vertical 8,945 feet 5,822 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) Tieback 4-1/2' 13.5# / L-80 6,786' MD 5,827' TVD Packers and SSSV (type, measured and true vertical depth) LTP; N/A 6,779' MD 5,822' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Stefan Reed, Operations Engineer 325-363 Sr Pet Eng: 8,540psi Sr Pet Geo: Sr Res Eng: WINJ WAG 459 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A stefan.reed@hilcorp.com 206-518-0400 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 190 Size 120' 0 275900 0 160 1635 measured TVD 7-5/8" 9,020psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-005 50-133-20717-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE A028142 Kenai / Beluga-Up Tyonek Gas Pool, Tyonek Gas 1 Kenai Unit (KU) 41-08 Plugs Junk measured Length Production Liner 6,984' 4,314' Casing Structural 5,992' 4-1/2" 6,984' 11,093' 9,674' 120'Conductor Surface Intermediate 16" 13-1/2" 120' 1,579' 4,790psi 2,980psi 5,210psi 6,890psi 1,579' 11,488' Burst Collapse 1,410psi 2,470psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.07.16 15:22:16 - 08'00' Noel Nocas (4361) BJM 9/25/25 Page 1/1 Well Name: KEU KU 41-08 Report Printed: 7/14/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20717-00-00 Field Name:Kenai Gas Field (KEU KGF)State/Province:ALASKA Permit to Drill (PTD) #:224-005 Sundry #:325-363 Rig Name/No: Jobs Actual Start Date:6/13/2025 End Date: Report Number 1 Report Start Date 6/23/2025 Report End Date 6/23/2025 Last 24hr Summary material Transfer from KGf to KGF KU 41-08 Report Number 2 Report Start Date 6/24/2025 Report End Date 6/25/2025 Last 24hr Summary PTW/PJSM. MIRU Fox N2 and AK E-line. PT N2 lines to 250/4,500 psi. PT WL PCE 250/4,000 psi. Pump 108.9 mscf N2. Set composite plug at 10,290'. Pressure up tubing to 2,290 psi with 211.7 mscf N2. Perforate TY 84-6 Sand from 9,857' - 9,877' with well shut-in. SDFN. SITP 2,615 psi. Report Number 3 Report Start Date 6/25/2025 Report End Date 6/26/2025 Last 24hr Summary Job Continued From 6/24/25. PTW/PJSM. Perforate TY 84-6 Sand from 9,837' - 9,857' with well flowing. RDMO AK E-line.Job Continued From 6/24/25. PTW/PJSM. Perforate TY 84-6 Sand from 9,837' - 9,857' with well flowing. RDMO AK E-line. PTW/PJSM. MIRU Fox N2 and AK E-line. PT N2 lines to 250/4,500 psi. PT WL PCE 250/4,000 psi. Pump 108.9 mscf N2. Set composite p up tubing to 2,290 psi with 211.7 mscf N2. Perforate TY 84-6 Sand from 9,857' - 9,877' with well shut-in. SDFN. SITP 2,615 psi. PTW/PJSM. MIRU Fox N2 and AK E-line. PT N2 lines to 250/4,500 psi. PT WL PCE 250/4,000 psi. Pump 108.9 mscf N2. Set composite plug at 10,290'. Pressure _____________________________________________________________________________________ Updated by DMA 07-14-25 Schematic Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16Surf 120 10-3/4Surface 45.5 / L-80 / DWC/C 9.950Surf 1,579 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875Surf 6,984 4-1/2"Production 13.5 / L-80 / DWC/C 3.9206,77911,093 Tieback Detail 4-1/2 Tieback 13.5 & / L-80 / TXP & BTC 3.920Surface 6,786 JEWELRY DETAIL No Depth Item 1 6,7795-1/2 Liner Top HRD-E ZXP Packer w/ 4.5 XO 2 6,7795-1/2 17# seal Stem, 0.62 off seat (4.78ID) 3 10,290Composite Bridge Plug (6/24/25) 4 10,595 CIBP set 11-Apr-2024 5 10,760CIBP (5 gallon cmt on top) TOC @ ±10,752 MD OPEN HOLE / CEMENT DETAIL 10-3/4122 BBLs of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2 Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBLs of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8 Hole. CBL run 3-23-24 TOC @ 1346 4-1/2129 BBLs of 13ppg lead followed by 15.3 ppg tail in 6-3/4 Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status Top of Pool 6 Pool 5263 MD, 4,553 TVD Top of Beluga/Upper Tyonek Gas Pool 5,483 MD, 4,733 TVD TY 84_6 9,8379,8778,5418,578406/25/25 Open Top of Tyonek Gas Pool 1 - 10,303 MD, 8958 TVD D2 10,323' 10,377' 8,974' 9,023' 54' 4/11/24 Isolated D3B 10,727' 10,741' 9,338' 9,351' 14' 4/12/24 Isolated D3D 10,769' 10,782' 9,376' 9,388' 13' 4/7/24 Isolated NOTES 10 Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP Please include current contact information if different from above. T40659 T40660 T40661 T40662 T40663 T40664 T40664 T40664 T40665 T40665 T40665 T40665 T40666 T40667 T40668 T40669 T40670 T40671 T40672 T40673 KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Stefan Reed Cc:Donna Ambruz Subject:Re: KU 41-08 (PTD# 224-005) - Comingle Date:Tuesday, June 24, 2025 8:08:27 AM Attachments:image001.png Stefan, Approved. Bryan Sent from my iPhone On Jun 23, 2025, at 10:34 AM, Stefan Reed <Stefan.Reed@hilcorp.com> wrote: Bryan, The attached approved sundry (325-363) for well KU 41-08(PTD# 224-005) calls for 25’ of cement on top of the proposed CBP @ ~10,310’ isolating Tyonek Gas Pool 1. Hilcorp requests to forgo the 25’ of cement, treat this as commingling of pools and perform required production logs per CO 510C Rule 5. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 <image001.png> Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient toensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate. <KU 41-08 AOGCC 10-403 325-363 PTD 224-005 Approved 06-20-25.pdf> 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,094'N/A Casing Collapse Structural Conductor 1,410psi Surface 2,470psi Intermediate 4,790psi Production Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng stefan.reed@hilcorp.com 206-518-0400 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Stefan Reed, Operations Engineer AOGCC USE ONLY 9,020psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 224-005 50-133-20717-00-00 Hilcorp Alaska, LLC Proposed Pools: Beluga-Up 13.5# / L-80 TVD Burst 6,786' 1,488' Size 120' 7-5/8"6,984' 1,579' MD 4-1/2" See Attached Schematic 6,890psi 2,980psi 5,210psi 120' 5,992' 120' 1,579' June 24, 2025 11,093'4,314' Tieback 4-1/2" 9,674' Perforation Depth MD (ft): 6,984' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 41-08CO 510C Tyonek Gas Pool, Tyonek Gas 1 ~3746psi 10,595 & 10,760 Length LTP; N/A 6,779' MD / 5,822'TVD; N/A, N/A 9,675'10,595'9,218' Kenai Tyonek Gas Pool 1 16" 13-1/2" See Attached Schematic m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:27 am, Jun 16, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.13 17:33:25 - 08'00' Noel Nocas (4361) BJM 6/18/25 Place 25' of cement on top of plug. Tag top of cement to verify minimum height of cement. Provide 24 hrs notice for opportunity to witness cement tag. DSR-6/18/25 X XX 325-363 CT BOP test to 4000 psi (contingent) 10-404 X A.Dewhurst 17JUN25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.20 13:07:57 -08'00'06/20/25 RBDMS JSB 062425 Add Perf Well: KU 41-08 June 2025 Well Name: KU 41-08 API Number: 50-133-20717-00-00 Current Status: Gas Producer Permit to Drill Number: 224-005 First Call Engineer: Stefan Reed (206) 518-0400 (c) (907) 777-8433 Second Call Engineer: Chad Helgeson (907) 229-4824 (c) Maximum Expected BHP: 4600 psi @ 8541’ TVD 2024 RFT Data Max. Potential Surface Pressure: 3746 psi Using 0.1 psi/ft Applicable Frac Gradient: 0.72 psi/ft using 13.83 ppg EMW FIT at the intermediate casing 3/13/24 Shallowest Potential Perf TVD: ૠ࢙ .ૠ࢙ ࢌ࢚ ି.࢙ ࢌ࢚ =ᇱࢀࢂࡰ Top of Pools per CO 510C: Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD Tyonek Gas Pool 1 – 10,303’ MD/8,958’ TVD Brief Well Summary KU 13-06A was drilled and completed with Hilcorp Rig 169 March 2024 targeting Tyonek, Upper Tyonek and Lower Beluga sands at Kenai Gas Field. The well was completed with a 4.5” completion with initial perforations in the Tyonek Gas Pool 1. The well is currently producing from the D2 sand @ ~415mscfd. The objective of this procedure is to isolate the D2 sand with a composite plug and perforate the TY 84-6 sand in the Beluga/Upper Tyonek Gas pool. A composite plug will be used so the D2 perforations can be accessed in the future for potential commingling. Wellbore Conditions: - Currently flowing @ ~400mscfd, 15psi FTP. - Slickline tagged 6/6/2024 @ 10,592’ w/ 2.3” GR. Eline Procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 4000psi high 3. Push fluid away using N2 or pad gas. 4. RIH w/ 4-1/2” composite bridge plug and set @ ~10,300’ 5. Pressure up well with N2 to ~2500psi (Discuss w/ OE) 6. RIH and perforate per RE/Geo (see table below) Pool Sand Top MD Btm. MD Top TVD Btm. TVD Ft Bel/UT TY 84-6D ±9,837’ ±9,881’ ±8,541’ ±8,581’ ±44 7. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing, b. Pending well production, all perf intervals may not be completed. Reperf zone at RE/GEO discretion based on production results. c. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations or patch across perforations. d. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations e. Above perfs are in the Beluga/Upper Tyonek Gas Pool governed by CO 510C Place 25' of cement on top of plug. Tag top of cement to verify minimum height of cement. -bjm Add Perf Well: KU 41-08 June 2025 8. RD E-Line Unit and turn well over to production 9. Operations to flow well and test zones 10. Test SVS as necessary once well has reached stabile flow rates Coil Procedure (Contingency) If necessary to cleanout or mill CBP with coiled tubing: 11. MIRU Coiled Tubing Unit, PT BOPE to 4,000 psi High/250 psi Low 12. Provide AOGCC 24hrs notice of BOP test 13. PU wash nozzle, RIH and cleanout well to plug. a. If required to mill proposed CBP: MU Motor/Mill assembly. Mill CBP and push to bottom. 14. PU CT jet nozzle and RIH, unload fluid from the wellbore with nitrogen a. Reverse circ out any fluid if perfs are isolated/plugged back and in cased hole 15. RDMO coil tubing Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Fox CT BOP Drawing 4. Nitrogen procedure _____________________________________________________________________________________ Updated by CJD 04-23-24 Schematic Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16”Surf 120’ 10-3/4”Surface 45.5 / L-80 / DWC/C 9.950”Surf 1,579’ 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875”Surf 6,984’ 4-1/2"Production 13.5 / L-80 / DWC/C 3.920”6,779’11,093’ Tieback Detail 4-1/2” Tieback 13.5 & / L-80 / TXP & BTC 3.920”Surface 6,786’ JEWELRY DETAIL No Depth Item 1 6,779’5-1/2” Liner Top HRD-E ZXP Packer w/ 4.5” XO 2 6,779’5-1/2” 17# seal Stem, 0.62’ off seat (4.78”ID) 3 10,595 CIBP set 11-Apr-2024 4 10,760’CIBP (5 gallon cmt on top) TOC @ ±10,752’ MD OPEN HOLE / CEMENT DETAIL 10-3/4”122 BBL’s of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2” Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBL’s of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8” Hole. CBL run 3-23-24 TOC @ 1346’ 4-1/2”129 BBL’s of 13ppg lead followed by 15.3 ppg tail in 6-3/4” Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status Top of Pool 6 Pool – 5263’ MD, 4,553’ TVD Top of Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD Top of Tyonek Gas Pool 1 - 10,303’ MD, 8958’ TVD D2 10,323'10,377'8,974'9,023'54'4/11/24 Open D3B 10,727'10,741'9,338'9,351'14'4/12/24 Isolated D3D 10,769'10,782'9,376'9,388'13'4/7/24 Isolated NOTES 10’ Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 _____________________________________________________________________________________ Updated by SAR 06-04-25 PROPOSED Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16”Surf 120’ 10-3/4”Surface 45.5 / L-80 / DWC/C 9.950”Surf 1,579’ 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875”Surf 6,984’ 4-1/2"Production 13.5 / L-80 / DWC/C 3.920”6,779’11,093’ Tieback Detail 4-1/2” Tieback 13.5 & / L-80 / TXP & BTC 3.920”Surface 6,786’ JEWELRY DETAIL No Depth Item 1 6,779’5-1/2” Liner Top HRD-E ZXP Packer w/ 4.5” XO 2 6,779’5-1/2” 17# seal Stem, 0.62’ off seat (4.78”ID) 3 ±10,310’Composite Bridge Plug 4 10,595 CIBP set 11-Apr-2024 5 10,760’CIBP (5 gallon cmt on top) TOC @ ±10,752’ MD OPEN HOLE / CEMENT DETAIL 10-3/4”122 BBL’s of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2” Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBL’s of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8” Hole. CBL run 3-23-24 TOC @ 1346’ 4-1/2”129 BBL’s of 13ppg lead followed by 15.3 ppg tail in 6-3/4” Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status Top of Pool 6 Pool – 5263’ MD, 4,553’ TVD Top of Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD TY 84_6 ±9,837’±9,881’±8,541’±8,581’44’-Proposed Top of Tyonek Gas Pool 1 - 10,303’ MD, 8958’ TVD D2 10,323'10,377'8,974'9,023'54'4/11/24 Isolated D3B 10,727'10,741'9,338'9,351'14'4/12/24 Isolated D3D 10,769'10,782'9,376'9,388'13'4/7/24 Isolated NOTES 10’ Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/1/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240501 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-13 50231200320000 207151 4/10/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 3/27/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 4/1/2024 YELLOW JACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/22/2024 YELLOW JACKET GPT-PERF KU 33-08 50133207180000 224008 4/30/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/23/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/11/2024 AK E-LINE GPT/Perf/CIBP MPU F-30A 50029226230100 213188 4/12/2024 READ CaliperSurvey MPU S-13 50029230930000 202114 4/16/2024 READ Caliper Survey NCI A-17 50883201880000 223031 3/22/2024 AK E-LINE Perf Paxton 6 50133207070000 222054 4/14/2024 AK E-LINE GPT/Perf PBU PTM P1-13 50029223720000 193074 4/8/2024 YELLOW JACKET CBL SRU 232-15 50133207140000 223091 3/28/2024 YELLOW JACKET GPT-PLUG-PERF SRU 232-15 50133207140000 223091 4/22/2024 YELLOW JACKET PLUG-PERF SRU 241-33B 50133206960000 221053 4/12/2024 YELLOW JACKET GPT-PERF SRU 241-33B 50133206960000 221053 4/4/2024 YELLOW JACKET GPT-PERF Please include current contact information if different from above. T38745 T38746 T38746 T38746 T38747 T38748 T38748 T38749 T38750 T38751 T38752 T38753 T38754 T38754 T38755 T38755 KU 41-08 50133207170000 224005 4/23/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/11/2024 AK E-LINE GPT/Perf/CIBP Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.05.13 09:32:35 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Kenai Gas Field GL:65.2' BF:N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" X-56 120' 10-3/4" L-80 1,488' 7-5/8" L-80 5,992' 4-1/2" L-80 9,674' 4-1/2" L-80 5,827' 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 N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface 6,984' Surface ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, L - 400 sx / T - 99 sx6-3/4" TUBING RECORD Tieback Assy.6,786' L - 378 sx / T - 154 sx Surface 9-7/8" Tieback 13-1/2" Driven Surface L - 287 sx / T - 308 sx 13.5# Surface 6,779' 1,579' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 274946 2361403 50-133-20717-00-00February 26, 2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 4/7/2024 224-005 / 324-185 N/A KU 41-08March 18, 2024609' FNL, 853' FEL, Sec 7, T4N, R11W, SM, AK 83.2' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2360743 SETTING DEPTH TVD 2360784 TOP HOLE SIZE CBL 3-23-24, Perf and GPT logs, Geotap, LWD (PCG, ADR, PWD, DDSR, CTN, ALD) Tyonek Gas Pool 1 FEE A028142 Date of Test: Oil-Bbl: Flowing *** Please see attached schematic for perforation detail *** Gas-Oil Ratio: AMOUNT PULLED 279680 280010 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. PACKER SET (MD/TVD) Surface Conductor 13.5# N/A N/A N/A 11,094' MD / 9,675' TVD 10,760' MD / 9,369' TVD 1068' FNL, 1532' FEL, Sec 8, T4N, R11W, SM, AK 1020' FNL, 1203' FEL, Sec 8, T4N, R11W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 11,093' Surface 5,821 84# 45.5# 120' Water-Bbl: PRODUCTION TEST 4/13/2024 Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 02.981 0 4/17/2024 24 Flow Tubing 2.9 1816 N/A18160 WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 8:52 am, Apr 24, 2024 Completed 4/7/2024 JSB RBDMS JSB 053024 GDSR-6/7/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 10323' Ty D2 5485' 4735' 6275' 5397' 7181' 6163' 8452' 7303' 10139' 8810' 10305' 8959' 10590' 9214' 10872' 9471' Ty D4D 10,982' 9,572' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Tyonek Upper Beluga Ty D1 Ty D4 Mid Beluga Lower Beluga Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. INSTRUCTIONS Ty D2 Ty D3 Wellbore Schematic, Drilling and Completion Reports, Csg and Cmt Reports, Definitive Directional Surveys Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Drilling Manager 04/23/24 Monty M Myers 8975 JSB _____________________________________________________________________________________ Updated by CJD 04-23-24 Schematic Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16”Surf 120’ 10-3/4”Surface 45.5 / L-80 / DWC/C 9.950”Surf 1,579’ 7-5/8"Intermediate 29.7/ L-80/TXP 6.875”Surf 6,984’ 4-1/2"Production 13.5 / L-80 / DWC/C 3.920”6,779’11,093’ Tieback Detail 4-1/2” Tieback 13.5 & / L-80 / TXP & BTC 3.920”Surface 6,786’ JEWELRY DETAIL No Depth Item 1 6,779’5-1/2” Liner Top HRD-E ZXP Packer w/ 4.5” XO 2 6,779’5-1/2” 17# seal Stem, 0.62’ off seat (4.78”ID) 3 10,760’CIBP (5 gallon cmt on top) TOC @ ±10,752’ MD OPEN HOLE / CEMENT DETAIL 10-3/4”122 BBL’s of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2” Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBL’s of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8” Hole. CBL run 3-23-24 TOC @ 1346’ 4-1/2”129 BBL’s of 13ppg lead followed by 15.3 ppg tail in 6-3/4” Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status Top of Pool 6 Pool – 5263’ MD, 4,553’ TVD Top of Beluga/Upper Tyonek Gas Pool – 5,483’ MD, 4,733’ TVD Top of Tyonek Gas Pool 1 - 10,303’ MD, 8958’ TVD D2 10,323'10,377'8,974'9,023'54'4/11/24 Open D3B 10,727'10,741'9,338'9,351'14'4/12/24 Open D3D 10,769'10,782'9,376'9,388'13'4/7/24 Isolated NOTES 10’ Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 Page 1/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:2/22/2024 End Date:3/25/2024 Report Number 1 Report Start Date 2/22/2024 Report End Date 2/23/2024 Operation R/D testing equip. & TRS casing equip. WHR installed BPV. Flushed through all Low/High pressure lines & equip. with Barakeeln pill & CIW and blew down same. R/D gen #3 and mud lab. N/D flow line, flow box, bell nipple, and installed trolley beams. OPened up ram doors, inspected ram cavities & rams (ok). R/D & L/D MGS. Lower degasser into pit #4. R/D centrifuge. Inspected MP's- valves, seats, and pods. Replaced valve & seat on MP. Removed die b locks on IR for repair. Changed over to 5.5" liner/swabs in MP's. Cleaned & vac'd out suction lines, suction screen, and manifold. N/D BOP's, removed from sub base, and installed in craddle with crane. WHR installed dry hole tree, tested void/neck seals and tree T/5000 psi for 10 min. Pulled TWC. Performed MIT's with AOGCC witness. (good tests). Rebuilt IR die blocks and reinstalled. Checked end play on TDS (ok). R/D tarps, spotted crane, picked off wind walls, clam shell, and centrifuge. Removed equalizer lines between pit modules. Winterized pressure washer in pump house & choke house and test pump. Shut in boilers, blew down steam & water lines and R/D same. Removed XO & subs from rig floor. L/D tongs. R/U bails, saver sub, IBOP off TDS. B/O Kelley hose & service loop TDS. R/D TQ bushing off TQ tube/TDS. R/D TDS and L/D same. Stated unplugging Pason/GAI-Tronic cables. R/D hardling from choke house. R/D T-bar on TQ tube. Cont. loading out misc equip & tools. Prepped & scoped derrick to half mast. L/D lower section of TQ tube. Rig crew traveled to KGF, laid felt, liner, and set rig ma ts around KU 41-08. Lowered pit roofs on pits 2 & 3. Cont. working through misc. electrical R/D. R/D TDS HPU. Hung blocks and unspooled drill line. Report Number 2 Report Start Date 2/23/2024 Report End Date 2/24/2024 Operation Rig movers on location @ 0600 pull pit modules 2 & 3, pull, aux fuel tank out, pull boiler, pull pump skids and HPU, Pull pit mod 1 and jig, Lay over derrick and spot in cranes, pull choke house and iron roughneck, Unpin derrick and hoist on to trailers, pull draw works and sub set on trailers, p ull pony subs and mats load out all and transport to KGF. Transport crews and sranes to KGF Arrive at location, spot pony subs over well, spot in cranes and set sub on pony subs and center over well, set draw works and derick on sub and pin, spot in pit 1 and set jig set in Pump modules, finish setting pit modules. Spot doghouse/watertank, spot in gen and top Drive HPU, Spotted boiler and auxiliary fuel tank. Spotted crane, picked & set choke house, IR, and wind walls. Worked on plugging in electrical. Fired gen and turned on to rig. Rasied doghouse and derrick to half mast. Rasied roofs on all three pit modules. Fired boilers to build a head of steam. Worked on steam, water, and air lines through out rig. Rasied degasser in pit #4. Hauled water to rig tank. Started R/U floor. Cont. hauling misc. loads from CF pad. Crew change, held PTSM. Cont. with R/U. Hung tarps through out the rig. Finished R/U steam, air , water lines and got it circulating through out the rig. Spotted service shacks. Cont. with R/U in the pits. R/U choke lines, and TD HPU HYD lines. Off loaded misc trailers. Worked on removing snow fr om pad. Report Number 3 Report Start Date 2/24/2024 Report End Date 2/25/2024 Operation rig movers on location spot in catwalk and raise beaver slide, set in gas buster and raise, spot in gen 3 with crane, R/D offic e trailers and change shack and transport to KGF. Spot in change shack and hook up, spot in electricians and mechanics shack, spotin sleeper and office trailers, hook up power t o third party shacks and get power goin, install lower torque tube, prep and scope derrick, install t bar and turn buckles, prep to P/U top drive. P/U TQ bushing and hung on TQ tube. P/U TDS and hung of TQ bushing. R/U Kelley hose & service loop to TDS. H/U TDS HYD lines. M/U IBOP, saver sub, and bails to TDS. Tested robotics on TDS (ok). Checked pressures in acmulator bottles. R/U centrifuge & degasser in pits and bumptested same (ok). Changed out bad shaker bed rubbers. Hydo tested pits with FW. Built stagging/mud dock around perimeter of pad. Started working through rig acceptance check list. Cont. off loading misc.equip. trailers. Adjusted load collar on TDS, and Kelley hose postion on top side off goose neck. Change out swivel & gear box oil in TDS. Repla ced swivel packing. Dressed out derrick board. Changed out gun line valve in pill pit. Changed out gear oil filters on DWKS. Change out winch line #1 in derrick along with new hook. Removed slip on starting head from spacer spool, M/U slip on starting head to DSA. Installed starter head/DSA to conductor. Started mixing spud mud. Report Number 4 Report Start Date 2/25/2024 Report End Date 2/26/2024 Operation Install Slip on flange to DSA and Riser, Install Gas alarms and Test, Fillpits with water and function test, Install handi berm, Start building spud mud, welder arrive and perform welding prejects, Modify gratings for riser, install riser and grating secure down grating, Change teflon in torque bushing, Tighten bolts on riser and install flow line and mud lines, Finish buidling spud mud, pressure test mud line, pop off leaking change out pop off and retest good, clear floor. Replaced housing seals on rig HPU and changed out filter. Tighten belts on gen #1. Topped off Gen #2 with coolant. Adjusted turn buckles on TQ tube. Accepted rig on 2-25-24 @ 18:00 hrs. P/U 4.5" DP & HWDP singles, built stds. and rack back in the derrick. 27 stds. of DP & 8 s tds of HWDP along with jar std. Crew change, held PTSM and weekly safety meeting with rig crew. Staged BHA #1 on catwalk. Held PJSM on P/U BHA with rig crew. P/U iStart, BaseStart, and ResiStar. Plan was break and reconfigure tools. Went to break out the iStar tool and broke wrong break. Decision was made to L/D tools and P/U back up tools. P/U first stage of BHA #1- 13.5" Tricone bit, 1.5° mud motor, XO, and 1 std. of HWDP. Tagged bottom @ 98'. Attempted to M/U TDS and wash down. TDS was out of alignment. Shut down. Re-shimming TQ bushing extend frame to align TDS. Report Number 5 Report Start Date 2/26/2024 Report End Date 2/27/2024 Operation Continue shimmimg top drive and repair extend frame bolt Fill riser and check for leaks, tighten flange and refill API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169Permit to Drill (PTD) #:224-005 Page 2/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Wash down and tag formation 138' Drill Ahead t/ 168' 350 gpm 30 rpm 2 k WOB Rack back 2 stands of DP, M/U remaining BHA upload MWD, P/U flex collar and crossover to HWDP Drill 13 1/2'' surface hole f/ 138' t/ 511' 450 gpm 1016 psi 50 rpm 8k tq, 10k WOB 37k PUW 37k SOW 39k ROT Cont. directional drilling 13.5" surface hole F/511'-T/975'. P/U-50K S/O-49K ROT-50K GPM-525 SPP-1500 psi RPM-50 WOB-1K Diff-47 psi Flow-44% MW-9.1 ppg ECD-9.4 ppg Max gas- 4 units. Pumped Low-Vis sweep @ 942' to scrub BHA of clay. Cont. directional drilling 13.5" surface hole F/975' to current depth of 1437'. P/U-55K S/O-50K ROT-53K GPM-470 SPP-1120 psi RPM-50 WOB-1K Diff-136 psi Flow-38% MW-9.0 ppg ECD-9.36 ppg Max gas- 30 units. Distance to well plan: 27.03' 13.07' High 23.66' Right Report Number 6 Report Start Date 2/27/2024 Report End Date 2/28/2024 Operation Continue Drilling f/ 1437' t/ 1585' 525 gpm 1510 psi, 50 rpm 7.1k tq on bottom, 10 k WOB, 55k PUW 50k SOW 53k ROT MW 9.0 ppg ECD 9.42 ppg 0 Gas units Obtain survey and flow check well static POOH on elevators f/ 1585' t/ 360' No hole issues Service rig and top drive, grease blocks and crown, inspect draw works and break linkage RIH f/ 360' t/ 1585' No hole issues or fill Pump 20 bbl Hi Vis Nut Plug Sweep around, Back 300 stks early 10% increase in cuttings, Blow down top drive, Flow check well POOH on elevators f/ 1585' t/ 166' No hole issues. Download MWD L/D BHA as per DD/MWD, Motor stab and bit Balled up with clay, drain moto and flush. Break bit Graded 1-1 in gauge Clean and clear rig floor, L/D Lift subs and crossovers Dummy Run hanger L/D, R/U Parker Casing running equipment, Load racks w/ Casing, M/U shoe track. Had to M/U circ swedge and pump through floats. Cont to RIH w/ 10-3/4" casing as per tally t/1555'. Disp: Calc-25.46 bbl, Act-13.4 bbl Diff-12.06 bbl. M/U circ swedge and install bail extensions. P/U and M/U hanger. Land hanger on seat. Circulate at two pipe volumes at 210GPM=63PSI while R/U cementers. MU plug launcher and hardline, Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested li nes at 580 psi low 3150 psi high, good tests. Halliburton pumped 60 bbls 10.5 ppg Tuned Spacer at 5 bpm-141 psi, dropped bottom plug and pumped 122 bbls (287 sx) 12 ppg Type I II lead cement at 5 bpm-99 to 110 psi, followed by 59 bbls (308 sx) 15.8 ppg Type I II tail cement at 5 bpm-130 to 150 psi. Halliburton dropped top plug then displaced with 9.2 ppg Spud Mud at 5 bpm 95 psi to 455 psi. Slowed pump to 3 bpm with 15 bbl to go. Did bump the plug 143 bbls into displacement (calculated 143.7 bbls). Held 1025 psi (FCP of 415 psi) for 3 minutes, bled off and floats held. Bled back 0.75 bbl to truck. Had 60 bbls of Spacer returns to surface and 67 bbls lead cemen t to surface. Added Bridge Maker LCM to lead cement at 2.4 pps. Mix water temp 87 deg. Pumped 75% excess on lead and 75% on tail. Lost 0 bbls throughout the job. Did reciprocate casing. Up wt 95K, dwn wt 60K upon landing hanger 5 bbl into displacement. CIP at 03:52 hrs, 2/28/2024. R/D cement equipment. Back out landing joint. Clean and clear rig floor. Flush riser and flow line with black water. Report Number 7 Report Start Date 2/28/2024 Report End Date 2/29/2024 Operation Clean out cellar,remove chains and flow line Lay over catwalk, remove riser N/U B section of wellhead as per vault rep, test seals t/ 3000 psi f/ 10 min, Crane in BOP stack and transfer to bridge cranes, install 10k x 5k DSA, N/U BOP Stack and choke and kill lines, change swabs and liners t/ 5'' on both mud pumps. Continue hammering up bolts and Nippling up, install flow box and riser, hook up flow line and bleeder , safe out grating aroun d stack, hook up accumulator lines and function test, change out compensator seal, get RKB's, Test gas alarms, Function test BOP's. Perform initial BOPE test at 250/3000 for 5min/5min. Performed koomey draw down test. Remove test plug, instal lwear bushing, flood stack and choke manifold. Test casing to 2700psi / 30min charted. Pumped 1.53 bbl bled back 1.53 bbl. Blow down and R/D test equipment. Install mouse hole, prep rig floor and catwalk to P/U drill pipe. Make adjustments to torque tube. I M/U johnny whacker to E-Kelly. P/U and RIH with 88 joints of 4.5" DP. POOH and rack back. Report Number 8 Report Start Date 2/29/2024 Report End Date 3/1/2024 Operation Continue P/U and Rack Back DP total of 90 stands in derrick. Service rig and top drive, grease blocks and crown. M/U BHA as per DD/MWD, upload MWD and shallow test tools P/U remaining BHA t/ 718' RIH P/U DP singles from rack f/ 718' t/ 1470' where tag up on cement. Washed down f/1470' t/1490' and set down 5k tagging up on wiper plugs 425GPM=1140PSI, 30RPM=5.5k TQ Drilled through wiper plugs and float collar to 1493', shoe track and shoe t/ 1579', cemented rat hole t/1585' with 5-15k WOB. Drill 20' of new formation t/1605, 425GPM=1025PSI, 30RPM=4k TQ, 1k WOB. CBU to clear hole of cement and cuttings, 425GPM=950PSI. Then shut down and clean under shakers. Held PJSM on displacement. Displace well from spud mud to new 6% KCL mud at 350GPM=628PSI. CBU x 2 to get mud even for FIT. R/U and attempt to perform FIT. Achieved high permeability test. Pumped 16.1 gal. Bled back 9.2 gal. B/D and R/D test equipment. Obtained SPR's. Drill 9-7/8” Hole F/ 1605’ t/ 1961' MD (1816' TVD) Total 361 (AROP 72') 400GPM= 837psi, 50 RPM=5.5k TRQ, 1-3k WOB, ECD 9.12 Max Gas 33u. MW 8.9ppg P/U 65k, S/O 53k, ROT 58k. Report Number 9 Report Start Date 3/1/2024 Report End Date 3/2/2024 Operation Continue Drilling 9 7/8'' Intermediate Hole f/ 1961' t/ 2390' 400 gpm 925 psi, 50 rpm 6.5k tq, 3k WOB, 73k PUW 58k SOW 65k ROT Pumped 20 bbl Hi Vis Sweep 50 strokes early 10% increase. API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 3/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Continue Drilling 9 7/8'' Hole Section f/ 2390' t/ 2634' 400 gpm 948 psi 50 rpm 6.5k TQ on bottom, 3k WOB, 80k PUW 57k SOW 67k ROT. Circulate bottoms up, obtain survey and SPR's Flow Check Well static. Make Wiper trip f/ 2634' t/ 15890' with no issues Service rig and top drive, grease blocks and crown RIH f/ 1580' t/ 2634' with no issues, wash last stand to bottom, Pump Hi Vis Sweep resume drilling ahead Drill 9-7/8” Hole f/ 2634’ t/ 3101' MD (2714' TVD) Total 467 (AROP 77') 403GPM = 1018psi, 50 RPM=7.3k TRQ, 4-6k WOB, ECD 9.3 Max Gas 14u. MW 8.9ppg P/U 89k, S/O 64k, ROT 75k. Sweep back 3.4 bbl early w/10 % increase. Drill 9-7/8” Hole f/ 3101’ t/ 3562' MD (3132' TVD) Total 461' (AROP 77') 403GPM = 1030psi, 50 RPM=7.4k TRQ, 4-6k WOB, ECD 9.28 Max Gas 20u. MW 8.9ppg P/U 95k, S/O 66k, ROT 77k. Sweep back 7 bbl early w/15 % increase. Distance to WP06: 14.00', 10.34' high, 9.43' right. Report Number 10 Report Start Date 3/2/2024 Report End Date 3/3/2024 Operation Continue Drilling 9 7/8'' Hole Section f/ 3562' t/ 3624' 400 gpm 1030 psi 50 rpm 7.4k tq on bottom, 4k WOB, 95k PUW 66k SOW 77k ROT Max gas 20 units, 8.9 ppg MW in 9.0 ppg MW out Circulate bottoms up, obtains survey and SPR's Flow check well static. POOH f/ 3654' t/ 2636' with no issues Service rig and top drive, Grease blocks and crown, inspect draw works. RIH t/ bottom no hole issues, wash last stand to bottom, Pump Hi Vis Sweep resume Drilling Ahead, sweep back 200 stks early 75% increase in cuttings. Continue Drilling Ahead 9 7/8'' Hole section f/ 3624' t/ 3748' 400 gpm 1056 psi 50 rpm 7.5k tq on bottom, 2 k WOB, 99k PUW 70k SOW 80k ROT, MW 8.95 ppg in 8.95 ppg out Continue Drilling Ahead 9 7/8'' Hole Section f/ 3748' t/ 3949' 400 GPM 1068 psi 50 rpm 7.9k tq on bottom 4k WOB , 107k PUW 73k SOW 85k ROT , MW 9.0 ppg in 9.0ppg out Maintain 40 ROP controled rate for Pool Depleted Zones. Back ground LCM and black product insystem Drill 9-7/8” Hole f/ 3948’ t/ 4148' MD (3630' TVD) Total 200 (AROP 33') 400GPM = 1052psi, 50 RPM= 8.4k TRQ, 4-6k WOB, ECD 9.26 Max Gas 13u. MW 8.9ppg P/U 110k, S/O 73k, ROT 87k. Control drilling at 40'/hr to minimize ECD and avoid losses through depleted zones. Drill 9-7/8” Hole f/ 4148’ t/ 4364' MD (3811' TVD) Total 216' (AROP 36') 350GPM = 1000psi, 50 RPM= 8.3k TRQ, 4-6k WOB, ECD 9.33 Max Gas 89u. MW 8.9ppg P/U 111k, S/O 76k, ROT 88k. Control drilling at 40'/hr to minimize ECD and avoid losses through depleted zones. At 4195' return flo w dropped from 30 to 24% and started seeing losses. Lost 38 bbl over an hour. On next connection at 4238' reduced flow rate to 350GPM loss rate slowed to 8bbl/hr. S tarted double back reaming connections. Distance from WP06: 8.37', 8.73' low, 0.18' right. Report Number 11 Report Start Date 3/3/2024 Report End Date 3/4/2024 Operation Drilling 9 7/8'' Hole f/ 4364' 't/ 4530' 350 gpm 1056 psi, 50 rpm 8.3k tq on bottom, 4k WOB, 117k PUW 75k SOW, 90k ROT, MW 9.15 ppg in 9.0 ppg out, continue drilling at controled rate 40 ROP no majar losses observed. Drill 9 7/8'' Hole f/ 4530' t/ 4672' 350 gpm 1052 psi 50 rpm 8.8k tq on bottom, 4 k WOB, 122k PUW 76k SOW 93k ROT, MW 9.0 ppg in and out, Max gas 13 units, Continue Dirlling at controled rate of 40 ROP, no losses observed Circulate bottoms up, obtain survey and SPR's Flow check well static POOH on elevators f/ 4672' t/ 3626' observe over pulls of 25k @ 4197' and 4021' worked through and wiped clean Service rig and top drive, change oil on floor motor, perform PM on crown and top drive. Monitor well on trip tank static loss rate of 1.5bbl/hr. RIH f/3626' t/4672' without issue. P/U 125k S/O 75k. Displacement: Calc-18.2 bbl, Act-16.8. Drill 9-7/8” Hole f/ 4672’ t/ 4797' MD (4154' TVD) Total 125' (AROP 31') 350GPM = 1069psi, 50 RPM= 9.0k TRQ, 4k WOB, ECD 9.30 Max Gas 57u. MW 9.1 ppg P/U 126k, S/O 76k, ROT 95k. Control drilling at 40'/hr to minimize ECD and avoid losses through depleted zones. Drill 9-7/8” Hole f/ 4797’ t/ 4981' MD (4322' TVD) Total 184' (AROP 31') 350GPM = 1035psi, 50 RPM= 9.0k TRQ, 4k WOB, ECD 9.32 Max Gas 133u. MW 9.05 ppg P/U 133k, S/O 80k, ROT 96k. Control drilling at 40'/hr to minimize ECD and avoid losses through depleted zones. Distance to WP06: 9 .21', 8.32' high. 3.95' left. Report Number 12 Report Start Date 3/4/2024 Report End Date 3/5/2024 Operation Drill 9 7/8'' Hole section f/ 4981' t/ 5167' 350 gpm 1150 psi 50 rpm 9k tq on bottom 5k WOB, 139k PUW 81k SOW 100k ROT MW 9.05 in 9.1 Out, Maintain 40 ROP at controlled rate Drill 9 7/8'' Hole Section f/ 5167' t/ 5352' 350 gpm 1100 psi 50 rpm 10k tq on bottom, 4k WOB, 143k PUW 82k SOW 111k ROT, MW 9.o in and out, Maintain controled ROP 40 fph Drill 9-7/8” Hole f/ 5352’ t/ 5477' MD (4712' TVD) Total 125' (AROP 31') 350GPM = 1100psi, 50 RPM= 11k TRQ, 4-10k WOB, ECD 9.24 Max Gas 58u. MW 9.1 ppg P/U 150k, S/O 82k, ROT 106k. Control drilling at 40'/hr to minimize ECD and avoid losses through depleted zones. Top of beluga form ation entered at 5408' MD. Increased pump rate to 375GPM. Drill 9-7/8” Hole f/ 5477’ t/ 5663' MD (4887' TVD) Total 186' (AROP 31') 400GPM = 1320psi, 50 RPM= 10.4k TRQ, 4-10k WOB, ECD 9.28 Max Gas 115u. MW 9.0 ppg P/U 155k, S/O 84k, ROT 109k. Control drilling at 40'/hr to minimize ECD and avoid losses through depleted zones. Report Number 13 Report Start Date 3/5/2024 Report End Date 3/6/2024 Operation Cont drilling 9 7/8" hole from 5663' to 5848', rot wob 3-4K, 401 gpm-1374 psi, 60 rpm-9900 to 11,500 ft/lbs on bott torque, 50 ft/hr ROP. Sliding wob 1-5K, 405 gpm-1315 psi, 75 psi diff, 24 ft/hr ROP. MW 9.1/vis 60. ECD 9.3 ppg, BGG 48 units, max gas 218 units. CBU at 406 gpm-1314 psi, 60 rpm-9600 to 12,400 ft/lbs off bott torque. Obtained on bottom survey and SPR's, fluid dropped 4' over 10 minutes during flow check. API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 4/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Pulled up hole on elevators from 5848 to 5564', up wt 163K, with no issue. At 5564' started pulling tight and swabbing. MU topdrive and back reamed up hole, occasionally able to pull a stand on elevators, occasionally able to pump OOH but seeing psi increase. Back reamed to 4119'. Cont backreaming from 4119' to 1547' 450GPM=1200PSI, 60RPM=6.7k TQ. Replaced grabber dies and bolts on dog bones. Greased and serviced draworks, blocks, topdrive, iron roughneck, and crown. Cleaned suction screens on Mud pumps. Monitor well on trip tank: 0.15 bph static loss rate. CBU x3 to clean up the casing. Got back lots of fines and sand. 460GPM=1250PSI, 30RPM=5.4k TQ. RIH on elevators f/1547' t/3698' fill pipe and continue RIH f/3698' t/4560'. Report Number 14 Report Start Date 3/6/2024 Report End Date 3/7/2024 Operation Cont TIH on elevators from 4560' to 4616', set down 3 times, MU topdrive and filled pipe, washed and reamed down to 4671', cont trip on elevators to 5779' and set down 3 times. MU topdrive, filled pipe, washed and reamed to bottom at 5848'. Pumped a 20 bbl hi-vis nutplug sweep around at 420 gpm-1444 psi, 60 rpm-8700 to 10,250 ft/lbs off bott torque. Max gas at bottoms up 54 units, sweep back 50 strokes early and 25% increase in cuttings. Cont drilling 9 7/8" hole from 5848' to 5938'. Rot wob 3K, 430 gpm-1533 psi, 65 rpm-11,400 ft/lbs on bott torque, 60 ft/hr ROP. Sliding wob 7K, 433 gpm-1700 psi, 90 psi diff, 5 to 20 ft/hr ROP. MW 9.1+/vis 67, ECD 9.3+ ppg, BGG 7 units, max gas 39 units. Cont drilling from 5938' to 6157'. Rot wob 6K, 430 gpm-1607 psi, 65 rpm-11,500 ft/lbs on bott torque, 60 ft/hr ROP. Sliding wob 5K, 440 gpm-1614 psi, 97 psi diff, 35 ft/hr ROP. MW 9.1+/vis 60, ECD 9.4+, BGG 18 units, max gas 45 units. Drill 9-7/8” Hole f/ 6157’ t/ 6345' MD (5444' TVD) Total 188' (AROP 31') 428GPM = 1582psi, 60 RPM= 11.5k TRQ, 4-10k WOB, ECD 9.5 Max Gas 87u. MW 9.2 ppg P/U 160k, S/O 90k, ROT 114k. Control drilling at 60'/hr to minimize ECD and avoid losses through depleted zones. Drill 9-7/8” Hole f/ 6345’ t/ 6529' MD (5623' TVD) Total 184' (AROP 31') 440GPM = 1668psi, 60 RPM= 11.7k TRQ, 6-10k WOB, ECD 9.50 Max Gas 45u. MW 9.1 ppg P/U 126k, S/O 76k, ROT 95k. Control drilling at 60'/hr to minimize ECD and avoid losses through depleted zones. Pump sweep at 6402' back 17bbl early with a 15% increase. Report Number 15 Report Start Date 3/7/2024 Report End Date 3/8/2024 Operation Cont drilling 9 7/8" hole from 6529' to 6681'. Rot wob 4K, 440 gpm-1699 psi, 60 rpm-11,800 ft/lbs on bott torque, 60 ft/hr ROP. Sliding wob 9-10K, 439 gpm-1700 psi, 117 psi diff, 10-40 ft/hr ROP. MW 9.2+/vis 65, ECD 9.5 ppg, BGG 16 units, max gas 63 units. Cont drilling from 6681' to 6881', rot wob 7K, 440 gpm-1748 psi, 60 rpm-12,000 ft/lbs on bott torque, 60 ft/hr ROP. Sliding wob 5K, 440 gpm-1792 psi, 140 psi diff, 40 ft/hr ROP. MW 9.3/vis 56, ECD 9.5+, BGG 27 units, max gas 69 units. Drill 9-7/8” Hole f/ 6881’ t/ 6990' MD (5999' TVD) Total 109' (AROP 31') 440GPM = 1668psi, 60 RPM= 12.5k TRQ, 6-10k WOB, ECD 9.57 Max Gas 45u. MW 9.3 ppg P/U 173k, S/O 95k, ROT 123k. Control drilling at 60'/hr to minimize ECD and avoid losses through depleted zones. Distance to WP06: 5.38', 4.27' low, 3.27' left. CBU x1 then pump sweep around. Sweep back 23bbl early with a 25% increase in cuttings. 500GPM=1990PSI, 60RPM=11.9kTQ. Obtain SPR's flow check well, fluid dropped 3' in 10 minutes. Blow down top drive. POOH f/6990' t/6619' assembly pulled tight and trying to swab. Decision made to back ream. BROOH f/6619' t/5745'. Experincing f ull stall stick slip and pressure ups. 450GPM=1700PSI, 60RPM=11-16kTQ. Report Number 16 Report Start Date 3/8/2024 Report End Date 3/9/2024 Operation Cont backreaming from 5745' to 5473'. 450 gpm-1653 psi, 60 rpm-9800 to 17,000 ft/lbs off bott torque. At 5634' we pulled 2 stands clean, then parked at 5538'. CBU at 480 gpm-1747 psi, 60 rpm-9800 to 10,000 ft/lbs off bott torque. MW 9.3/vis 60, ECD 9.6 ppg, BGG 5 units. Service rig and topdrive. Hole taking .93 bph on trip tank. TIH on elevators from 5538' to 6934' with no issue, filled pipe on last stand and started a 20 bbl sweep down drillstring, wash ed and reamed to bottom at 6990'. Circulated 20 bbl hi-vis nutplug sweep around at 450 gpm-1724 psi, 60 rpm-11,300 to 12,000 ft/lbs off bott torque. Sweep back 2 bbls early and 100% increase in fine cuttings/silt. Did an additional bottoms up until shakers cleaned up. Fluid dropped 5' over 10 minute flow check. L/D single jnt, pulled up hole racking back stands from 6960' to 5400', up wt 180K. At 5400' started pulling tight and swabbing . MU topdrive, pumped OOH from 5412' to 5294', BROOH to 5100', pulled on elevators to 4976', pumped OOH to 4300', pumped every otherstand to 3940', pulled on elevators with no issue from 3940' to 1644'. MU topdrive and CBU x 2 at 443 gpm-1093 psi, 30 rpm-4500 ft/lbs torque. Did not see much on shakers at bottoms up. Shut down and blew down topdrive. Ease bit into casing shoe and cont POOH to HWDP at 718'. Rack back HWDP, L/D jars and HWDP single. PJSM, download MWD data. L/D directional BHA. Bit Graded: 1-4-BT-G-X-2-NO-TD Clean and clear rig floor. Drain stack, pull wear ring and dummy run hanger. Set test plug and change upper pipe rams from 2-7/8"x5" to 7-5/8". Test annular and 7-5/8" rams 250/3500 5/5 minutes charted. R/D test equipment and clean floor. R/U Parker TRS casing equipment. Monitor well on trip tank-1.7bph static loss rate. M/U and baker lock shoe track. Check floats-good. Cont. to RIH with 7-5/8" casing as per tally t/166'. Report Number 17 Report Start Date 3/9/2024 Report End Date 3/10/2024 Operation Cont PU single in hole with 7 5/8" 29.7# P-110 GB CD BTC casing from 166' to 1559', shouldered up at 9,000 ft/lbs then torqued to 12,000 ft/lbs. At 1559' switched over to 7 5/8" 29.7# L-80 DWC casing torqued to 23,400 ftlbs and singled in to 2054' (50 joints ran), installing a centralizer on ea ch joint. TIH at 20 to 30 ft/minute. MU circ swedge and topdrive, eased into circulating bottoms up at 112 gpm-65 psi with no issue. Removed and blew down topdrive. Cont PU single in hole with 7 5/8" DWC from 2054' to 4007' installing a centralizer on each joint (97 total). API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 5/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation MU circ swedge and topdrive. Eased into circulating bottoms up at 112 gpm-122 psi, max gas 16 units. Removed and blew down topdrive. Cont PU single in hole with 7-5/8" DWC f/ 4007' t/ 5992', installling a centralizer on each joint to joint 146 (147 total). Fil ling on the fly topping off every 10 joints. MU circ swedge and topdrive. Circulated bottoms up at 113 gpm-183 psi, max gas 29 units. Removed and blew down topdrive. Cont. to RIH as per tally with 7-5/8" DWC f/ 6003' t/ 6412', filling on the fly topping off every 10 joints. Hole displacement: Calc-43.9 bbl, act 32.5bbl. P/U 225k, S/O 115k. Cont to RIH as per tally with 7-5/8" DWC f/ 6460' t/ 6888', filling on the fly topping off every 10 joints. P/U 250k, S/O 125k . Encounter tight spot at 6888'. M/U circ swedge and wash down /work tight hole down t/ 6956’ 180GPM=260PSI. P/U 250k, S/O 125k. P/U full joint and wash to bottom at 6990' with no set downs. POOH to L/D tag joint. Report Number 18 Report Start Date 3/10/2024 Report End Date 3/11/2024 Operation Broke out and LD jnt #169, installed circ swedge in landing joint, PU and MU same, MU topdrive, broke circ at 112 gpm staging up to 138 gpm-215 psi, up wt 245K, dwn wt 115K. S/O and landed hanger twice on depth (shoe at 6983.81'), cont circ at 144 gpm-207 psi, RD casing tongs, clean and clear rig floor, increased to 221 gpm-223 psi seeing no fluid loss. Staged plug launcher and circ hose on rig floor, loaded plugs in launcher, shut down pump, held PJSM with cementers and rig team, broke off and blew down topdrive. MU plug launcher and hardline, Halliburton loaded lines with 10 bbls water and checked for leaks. Halliburton pressure tested l ines at 550 low 4270 high, good tests. Halliburton pumped 60 bbls 10.5 ppg Tuned Spacer at 4.5 bpm 230 psi, dropped bottom plug and pumped 286 bbls (678 sx) 12 ppg Type I II lead cement at 5 bpm 204-100 psi, followed by 31 bbls (154 sx) 15.3 ppg Type I II tail cement at 3 bpm 100-98 psi. Halliburton dropped top plug, the n displaced with 9.3 ppg 6% KCL PHPA mud at 5 bpm 98-1200 psi. Slowed pump to 3 bpm with 30 bbls to go. Did bump the plug 305.25 bbls into displacement (calculated 316 bbls). Held 1665 psi (FCP of 1276 psi) for 3 minutes, bled back 1.25 bbls to truck, floats held. CIP at 11:19 on 3-10-24. Had 30 bbls of Spacer returns to surface and 0 bbls lead cement to surface. Added LCM to lead cement at 2.4 pps. Mix water temp 80 deg. Pumped 40% excess on lead. Lost 15 bbls throughout the job. Did reciprocate until 260 bbl into displacement. Up wt 210K, down wt 93K at time of landing hanger (263K up/125K down at start of job). RD washed up and released Halliburton. Blew down circ lines, drained BOP stack, backed out landing joint, drained, flushed and LD same. Removed casing elevators and bail extensions, PU kelly joint, MU brush tool, flushed and brushed packoff profile in wellhead with black water, flushed BOP stack, shut down and C/O brush tool with packoff run tool. RIH landed packoff, tested same at 5000 psi for 10 min, good test, bled off. Rotated left 4 rounds to engage lockring in wellhead, rotated right 3 rounds then pull tested 15K over block weight, rotated right and released from packoff, LD kelly join t, XO and run tool. PU 4 1/2" test joint and test plug, set plug, opened upper ram doors and C/O rams to VBR's, tested audio/visual gas alarms. Buttoned up ram doors, opened upper annulus valve, flooded stack and surface equipment, RU for BOP test and purged air, shell tested at 250/3500 psi. Performed bi-weekly BOP test (early) at 250 low, 3500 high for 5 min each. Performed draw down test, tested PVT gain/loss and functioned flow show alarms. Witness of test was waived by AOGCC Jim Regg on 3-9-24 at 21:01. R/D and blow down test equipment and install wear bushing. R/U geospan in cellar area. Change out grabber dies on top drive. Rack strap and tally 4.5" DP. RIH picking up 4.5" dp singles form the catwalk t/896'. Cont. to RIH picking up 4.5" DP singles f/896' t/2035' Slip and cut 18 wraps of drill line. POOH and stand back 4.5" DP f/2035' t/ surface. R/U test equipment on kill line. Flood stack and surface lines. Purged air and closed blind rams. Pressuring up on 7-5/8" casin g for test. Report Number 19 Report Start Date 3/11/2024 Report End Date 3/12/2024 Operation Pumped 151.8 gallons to achieve 3561 psi on 7 5/8" casing and held 30 min on chart. Pressure bled to 3539 psi over 30 minutes. Bled back 145 gallons. RD test equipment, opened rams, lined up mud line to circ through Sperry GeoSpan unit in cellar, shut in on down stream side and pressured up to 2300 psi with no leaks or issues, bled off and blew down GeoSpan unit and plumbing. Held PJSM with rig crew and Sperry Reps, PU 4 3/4" motor w/1.5° bend and MU 6 3/4" HDBS PDC jetted w/5x11's. PU and MU DM, PCG, ADR, ALD, CTN, Geo-Tap and TM collars. RFO of 30.12°. Plugged in and uploaded MWD data twice, shallow pulse tested and having issue with Geo-Tap tool. Shallow pulse tested again and downloaded MWD data. After speaking with ROC Rep decision made to LD primary tool, PU spare. LD TM and Geo-Tap, PU spare and TM, uploaded and seeing same issue with spare. Ar per ROC rep decision made to PU primary tool (10K draw down) and run that. LD TM and Geo-Tap, PU primary and TM. Uploaded MWD and shallow pulse tested with both pumps individually. Cont TIH with HWDP and jars to 694'. PU single in hole with 4-1/2" DP to 2166', fill pipe and test MWD tools-good. resume picking up singles t/2667' for a total of 64 jnts picked up. Cont TIH on stands to 3781'. Replace air fitting and hose on drawworks clutch. Cont. to RIH out of derrick f/3781' t/6874'. Filled pipe, washed/reamed down at 250 gpm-16650 psi, 30 rpm-12.5 ft/lbs torque and tagged up on wiper plugs at 6897'. Drill float equipment on depth f/6874' t/6983', drill cemented rat hole and 20' of new formation t/7010'. 250GPM=1650PSI, 30RPM=12.5k TQ. Circulate hole hole clean and get good even 9.8ppg MW in and out prior to FIT test. B/D top drive. R/U to perform FIT. Report Number 20 Report Start Date 3/12/2024 Report End Date 3/13/2024 Operation RU test pump on stump and kill line, purged air, closed upper rams, purged air from choke manifold, pumped 50.6 gallons to achieve 1257 psi and held 15 minutes. Bled down to 1124 psi over 15 min and bled off 47 gallons. 1257 psi = 13.83 EMW. Sent data to town, RD test equipment and blew down, opened upper rams. Re-clocked kelly hose and serviced rig. Cont drilling 6 3/4" hole from 7010' to 7213'. Rot wob 3 to 6K, 286 gpm-2174 psi, 37 rpm-12,900 ft/lbs on bottom torque, 60 ft/hr ROP. Once BHA cleared casing we increased to 60 rpm-13,600 ft/lbs on bott torque. Sliding wob 4K, 282 gpm-2225 psi, 220 psi diff, 80 ft/hr ROP. MW 9.9+/vis 56, ECD 10.9 ppg, BGG 12, max gas 204 units. (increasing MW as we drill ahead to be at 10.7 ppg by 7000' tvd) API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 6/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Cont drilling from 7213' to 7605'. Rot wob 5K, 283 gpm-2400 psi, 60 rpm-13,580 ft/lbs on bott torque,120 ft/hr ROP. Sliding wob 4-9K, 284 gpm-2370 psi, 200 psi diff, 80 ft/hr ROP. MW 10/vis 54, ECD 11.1 ppg, BGG 22 units, max gas 412 units. Strapped all tubing and pups. Cont drilling F/7605'-T/7922'. P/U-190K S/O-84K ROT-119K GPM-280 SPP-2491 psi RPM-60 TQ-13.8K WOB-8K Diff-311 psi MW-10.7 ppg ECD-11.7 ppg Max gas- 253 units. Obtained new SPR's @ 7798'. Crew change, held PTSM. Resumed drilling 6.75" production hole F/7922'. At 7932' started torquing up and stalling out with max torque. Racked back 1 std. CBU while backreaming std to clean up hole. Started bring up lube percent to 1% by volume with NXS lube to mud system. Resumed drilling ahead F/7932' to wiper trip depth of 8045'. Pumped Hi-Vis @ 7981'. P/U-193K S/O-82K ROT-123K GPM-278 SPP-3050 psi RPM-60 TQ-14.2K WOB-9K Diff-358 psi MW-10.7 ppg ECD-11.91 ppg Max gas- 84 units. Distance to well plan: 8.16' 3.25' High 7.49' Left. Sweep came back on time with a 10% increase in cuttings. Circulated till shakers cleaned up. Shot on bottom survey. Obtained new SPR's. Flow checked well (slight seepage). Attempted to POOH & pump OOH with no luck. BROOH F/8045' to current depth of 7673'. GPM-272 SPP-2420 psi RPM-60 TQ-14.2K MW-10.7 ppg ECD-11.72 ppg Max gas- 21 units. Report Number 21 Report Start Date 3/13/2024 Report End Date 3/14/2024 Operation Cont backreaming from 7673' to 7120', 269 gpm-2500 psi, 60 rpm-13,600 to 15,000 ft/lbs torque. At 7120' smart tools still outside casing shoe. CBU at 275 gpm-2252 psi, 80 rpm-13,800 ft/lbs torque, 30% increase in cuttings, then pulled on elevators up inside the casing. Serviced rig and topdrive, re-wrapped service loop sock. TIH on elevators from 6989' to 7981', filled pipe on last stand, washed/reamed to bottom while starting a 20 bbl hi-vis nutplug sweep down DP. Circulated sweep around at 270 gpm-2320 psi, 80 rpm-15,546 ft/lbs torque. Had a max of 36 units trip gas at bottoms up, sweep back on time with a 100% increase in cuttings. Cont drilling 6 3/4" hole from 8045' to 8105'. Sliding wob 2K, 275 gpm-2400 psi, 223 psi diff, 40 ft/hr ROP. Rot wob 6K, 278 gpm-2729 psi, 60 rpm-13,527 ft/lbs on bott torque, 100 ft/hr ROP. MW 10.7/vis 58, ECD 11.9. BGG 6 units, max gas 113 units. Started bring lube up to 2% in active system. Cont drilling from 8105' to 8421'. Rot wob 6K, 274 gpm-2669 psi, 60 rpm-14,400 ft/lbs on bott torque. Sliding wob 3K, 276 gpm-2526 psi, 140 psi diff, 29 ft/hr ROP. MW 10.8/vis 58, ECD 11.7, BGG 43, max gas 436 units. Cont drilling 6.75" production hole F/8421'-T/8663'. Pumped weighted Hi-Vis sweep @ 8538', sweep came back on time w/ a 40% inc rease in cuttings. Obtained new SPR's @ 8538'. P/U-195K S/O-95K ROT-130K GPM-275 SPP-2750 psi RPM-60 TQ-14.5K WOB-7K Diff-350 psi MW-10.9 ppg ECD-12.1 ppg Max gas- 256 units. Cont. w/ MW weight up schedule. Crew change, held PTSM. Cont drilling 6.75" production hole F/8663' to current depth of 8940'. P/U-203K S/O-92K ROT-130K GPM-278 SPP-2890 psi RPM-60 TQ-14.9K WOB-7/9K Diff-361 psi MW-10.9 ppg ECD-12.2 ppg Max gas- 212 units. Distance to well plan: 8.86' 5.62' High 6.84' Left Report Number 22 Report Start Date 3/14/2024 Report End Date 3/15/2024 Operation Cont drilling from 8940' to 9033'. Rot wob 9K, 276 gpm-2853 psi, 60 rpm-15,000 ft/lbs on bott torque, 30 to 120 ft/hr ROP. MW 11/vis 57, ECD 12.1 ppg, BGG 21 units, max gas 358 units, maintaining 2% lube in active system. CBU twice at 278 gpm-2528 psi, 60 rpm-14,100 to 15,100 ft/lbs off bott torque. Obtained on bottom survey and SPR's, 10 minute flow check fluid dropped 2" in wellbore. Pulled up hole on elevators from 9033' to 7178'. Up wt coming off bottom 210 to 220K. Calc hole fill 13.8 bbls, actual hole fill 13.9 bbls. CBU with BHA outside casing shoe, 274 gpm-2287 psi, 80 rpm-12,400 ft/lbs torque. Not much increase in cuttings at bottoms up. Pulled up hole couple more stands to get BHA inside casing. Hung blocks, slipped and cut 32' drill line, checked crown saver, calibrated hook load/block height, service rig and topdrive. TIH from 6995' to 8665', dwn wt 90K. At 8665' filled pipe and mad passed to 8700'. TIH on elevators to 8866' and set down. Had to work pipe a couple times to free up, MU topdrive, filled pipe, washed and reamed to 8907', worked stand with no pump or rotary, no issues, ran one stand on elevator s, MU topdrive on last stand, filled pipe, started sweep down hole, washed and reamed to bottom at 9033'. Circulated sweep around at 276 gpm-2584 psi, 80 rpm-10,800 to 14,600 ft/lbs torque. Had a max of 224 units trip gas. Sweep back on time with a 20% inc in cuttings. Cont drilling 6.75" production hole F/9033'-T/9218'. P/U-196K S/O-101K ROT-137K GPM-275 SPP-2880 psi RPM-60 TQ-14.4K WOB-10K Diff-240 psi MW-11.1 ppg ECD-12.02 ppg Max gas- 347 units. Crew change, held PTSM. Cont drilling 6.75" production hole F/9218' to current depth of 9453'. P/U-195K S/O-106K ROT-136K GPM-273 SPP-2950 psi RPM-60 TQ-15.1K WOB-10K Diff-370 psi MW-11.15 ppg ECD-12.3 ppg Max gas- 138 units. Distance to well plan: 7.02' .61' Low 6.99' Left Report Number 23 Report Start Date 3/15/2024 Report End Date 3/16/2024 Operation Cont drilling 6 3/4" hole from 9453' to 9527', sliding wob 10-11K, 273 gpm-3030 psi, 200 to 340 psi diff, 9 to 70 ft/hr ROP. Rot wob 8-9K, 274 gpm-3100 psi, 60 rpm-15,300 ft/lbs on bott torque, 55-120 ft/hr ROP. MW 11.1+/vis 62, ECD 12.4+, BGG 29 units, max gas 354 units. Pumped a 20 bbl 12.1 ppg hi-vis nutplug sweep around at 246 gpm-2320 psi, 80 rpm-14,200 ft/lbs torque. Sweep back on time with 10% increase in cuttings. Cont drilling from 9527', to 9652'. Rot wob 12K, 273 gpm-3000 psi, 60 rpm-14,200 ft/lbs on bott torque, 13 to 50 ft/hr ROP. MW 11.1+/vis 56, ECD 12.4 ppg, BGG 28 units, max gas 455 units. Distance to well plan: 5.64' 4.80' Low 2.59' Right. Just as we drilled last 4' of stand down we started losing pump pressure. Checked pumps and plumbing to rig floor, determined we had a washout in drill string. Added 3 sacks nutplug to suction pit for a marker if we have to pump or ba ckream up hole. Pulled up hole on elevators from 9652', up wt 225K, for the most part had to run into it to get pipe moving then cont pull at reduced speed, no more than 255K. Pulled to 8881' looking for washout. Found hole 1' below tool joint on stand 133 (jnt 265). Replaced bad joint. TIH from 8820' to 9592', dwn wt 100K, no issues TIH. At 9592' MU topdrive, filled pipe, washed/reamed to bottom, pump pressures normal for off bottom. API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 7/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Resumed drilling from 9652' to 9730', sliding wob 2-5K, 275 gpm-2960 psi, diff 229 psi, 18 to 48 ft/hr ROP. Rot wob 6 to 12K, 274 gpm-3100 psi, 60 rpm-14,800 ft/lbs on bott torque, 45 to 120 ft/hr ROP. MW 11.2/vis 54, ECD 12.4 ppg, BGG 20 units, max gas 1029 at bottoms up (trip gas). At 9730' lost pump pressure again as with previous washout. Checked pumps and plumbing, no issues, added 3 sacks nutplug to suction pit. POOH on elevators F/9730' to inside 7-5/8" casing shoe @ 6934'. Had to wash through tight spot @ 8497'. P/U-235K S/O-120K. B/D TDS, flow check- static. Resumed POOH looking for washout F/6934', found washout on top jt of std # 31, above pin end of tool jt. (see photos). L/D and replaced bad jt. Calculated hole fill =50.6 bbls Act= 47.8 bbls Diff= 2.8 bbls. Servied rig. Inspected & greased crown, blocks, wash pipe, TDS, IR, DWKS, brake linkage, and drive shaft. Inspected saver sub, cleaned both suction screens on MP's, and suction manifold. RIH on elevators, filling pipe every 1500'. F/2605'-T/7297'. Office & camp gen shut down. Trouble shot gen. Worked pipe, circulated across the hole, and monitored well on the TT. Got gen refired, worked through Pason issues. Resumed RIH F/7306' to current depth of 8287'. Report Number 24 Report Start Date 3/16/2024 Report End Date 3/17/2024 Operation TIH on elevators from 8287’ to 9621’, down wt 100K, set down three times, MU topdrive, filled pipe, washed and reamed to bottom two more stands to 9730'. CBU at 275 gpm-2821 psi, 60 rpm-14,600 to 15,400 ft/lbs off bott torque. Half way into bott up hole unloaded 100% increase in cuttings, max gas of 1877 units. At bott up gas down to 136 units. Circ until clean shakers. No more than started to drill and lost Pason base computer. PU off bottom and cont to circ at 274 gpm-40 rpm while Tool Pusher working with Pason helpdesk. Cont drilling from 9730' to 9827', rot wob 14K, 274 gpm-2944 psi, 60 rpm-11,200 ft/lbs on bott torque, 25 to 120 ft/hr ROP. MW 11.2+/vis 52, ECD 12.3 ppg, BGG 22 units, max gas 67 units After backream before connection Pason base computer dropped offline again, parked string off bottom and cont to circ at 274 gpm-40 rpm, made numerous calls for network assistance, eventually getting Hilcorp Network Engineer and Pason helpdesk involved. Reconfigured rigs network set up, back up and running. Cont drilling from 9827' to 9959', rot wob 4 to 7K, 273 gpm-2984 psi, 60 rpm-12,760 ft/lbs on bott totrque, 40 to 120 ft/hr ROP . Sliding wob 2-11K, 274 gpm-2881 psi, 300 psi diff, 65 to 95 ft/hr ROP. MW 11.2+/vis 53, ECD 12.3 ppg, BGG 32 units, max gas 643 units. Cont drilling 6.75" production hole F/9959'-T/10,218'. P/U-200K S/O-112K ROT-149K GPM-275 SPP-3101 psi RPM-60 TQ-12.7K WOB-8K Diff-350 psi MW-11.2 ppg ECD-12.71 ppg Max gas- 557 units. Crew change, held PTSM. Cont drilling 6.75" production hole F/10,218' to current depth of 10,456'. P/U-205K S/O-115K ROT-153K GPM-279 SPP-3100 psi RPM-60 TQ-14.1K WOB-8K Diff-328 psi MW-11.3ppg ECD-12.4 ppg Max gas- 193 units. Distance to well plan: 14.8' 3.62' Low 14.35' Right Report Number 25 Report Start Date 3/17/2024 Report End Date 3/18/2024 Operation Cont drilling 6 3/4" hole from 10,456' to 10,517', rot wob 6-7K, 278 gpm-3083 psi, 60 rpm-14,700 ft/lbs on bott torque, 40 to 70 ft/hr ROP. MW 11.2/vis 55, ECD 12.3+ ppg, BGG 26 units, max gas 134 units. Pumped a 20 bbl hi-vis weighted (12.1 ppg) nutplug sweep around at 279 gpm-2879 psi, 80 rpm-14,700 ft/lbs off bott torque. Sweep back on time with 10% inc in cuttings. Obtained SPR's at 10,517' md/9150' tvd. Drilled from 10,517' to 10,536' and started losing pump pressure. Checked all surface equipment (ok) indicating we had another washout. Pulled up hole from 10,536', pulled to 280K multiple times, could not break free. Had to MU topdrive and circ at drill rate, th en start rotating to get broke loose, stopping rotary and pump as we pulled up hole at 240K. At and above 10,000' able to pull free at 275K. At and above 9700' able to break free with much less overpull. At 8,883' we found the washout in jnt #265 (bottom of stnd 133) which was the same joint we replaced on 1st washout trip. Replaced bad joint, MU topdrive and CBU to check pump pressure and clean up the hole. 276 gpm-2626 psi, 80 rpm-12,105 ft/lbs off bott torque. Max gas 69 units at bottoms up. TIH on elevators from 8,883' to 10,520', dwn wt 110K, filled pipe, washed and reamed to bottom at 10,536'. Cont drilling from 10,536' to 10,726', rot wob 4 to 8K, 266 gpm-2805 psi, 60 rpm-13,300 ft/lbs on bott torque, 36 to 120 ft/hr ROP. MW 11.2/vis 55, ECD 12.21 ppg, BGG 30 units, max gas 497 units. Recieved 400 sacks lead cement in silo. Cont drilling from 10,726' to 10,891', rot wob 5 to 8K, 266 gpm-2976 psi, 60 rpm-11,400 to 12, 200 ft/lbs on bott torque, 89 ft/hr ROP. MW 11.2/vis 53, ECD 12.23 ppg, BGG 29 units, max gas 200 units. Distance to well plan:13.05' 11.55' Low 6.08' Left At 10,876' started seeing pump pressure d rop as we drilled last of stand down. Checked surface equipment, no issues found indicating we have a washout. Started pulling up hole on elevators from 10,891' to 10,516' but swabbing. MU topdrive and idle pump as we pull to 10,460'. Pul led on elevators F/10,460'-T/10,207', Started swabbing again. BROOH F/10,207'-T/10,148'. Cont. POOH on elevators F/10,148' with accurate hole. Found washout @ 4956'. Replaced bad jt. RIH F/4955'-T/6991'. Off line changed out pop off on MP #1. Filled pipe. Circulated on the hole with bit just outside casing shoe to conserve battery life on MWD tools while servicing rig at report time. Report Number 26 Report Start Date 3/18/2024 Report End Date 3/19/2024 Operation Cut and slipped 67' of drill line, checked crown saver, calibrated hook load and block height, attempted to test #1 pump pop-of f (fail). Blew down topdrive. TIH on elevators from 6992' to 10,740' (filled every 1500'). At 10,740' set down three times, MU topdrive, and filled, washed a nd reamed down to 10,890'. CBU at 266 gpm-2807', 80 rpm-14,200 ft/lbs off bott torque, max gas 516 units at bottoms up, 50% increase in heavy fines. Resumed drilling 6 3/4" hole from 10,890' to 10,962', rot wob 6K, 266 gpm-2891 psi, 60 rpm-13,500 to 14,100 ft/lbs on bott torque, 30 to 78 ft/hr ROP. MW 11.1+/vis 52, ECD 12.2 ppg, BGG 37 units, max gas 213 units. At 10,962' had another washout. Pulled up hole on elevators with no issue from 10,962' to 10,179', up wt 240 to 250K and found the bad jnt. Replaced jnt #307 (bott of stnd 154), TIH to 10,954', dwn wt 125K and filled pipe. API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 8/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Cont drilling from 10,962' to 11,094', rot wob 3-5K, 251 gpm-2648 psi, 60 rpm-13,100 ft/lbs on bott torque, 26 to 40 ft/hr ROP. MW 11.3/vis 54, ECD 12.12 ppg, BGG 26 units, max gas 219 units. Distance to well plan: 36.75' 23.05' Low 28.62' Left. Lost ~800 psi on SPP, P/U off bottom, shot survey. Shut down MP. Attempted to POOH on elevators F/11,094' with no luck due to over pulling. Pumped at idle and rotated 30 RPM, half of each std. F/11,094'-T/10,317'. POOH on elevators F/10,317', found washout at 7799'. Replaced bad jt. M/U TDS to stump. Broke circulation. Circulated on the hole to save battery life on MWD tool. Perform rig service. RIH on elevators F/7794'-T/10,030'. Madd passed F/10,024'-T/10,008' to correlate to depth. Pulled up and set on depth at station #1 - bit depth of 9971'. Currently working on first station. Report Number 27 Report Start Date 3/19/2024 Report End Date 3/20/2024 Operation Continue Geo Tapping First station, conitnue logging stations up hole as per DD/MWD Madd Passing sections as needed, Currently logging station 6, pumps @ 251 gpm 1477 psi @ 8190' Obatained Geo-Tap data from stations 7-16 with a total of 27 test. Finished testing. GPM-246 SPP-1998 psi. SIMOPS- Cleaned between pits & carrier, choke house, rig floor, and worked on misc EAM's. Flow checked-static. POOH racking back stds. F/7344'-T/6967' - 7-5/8" casing shoe. Cont. POOH- L/D 4.5" DP singles and kicking out non-inspected jts. F/6967'. Vacuuming wiper balls through tubulars on racks, re -doping threads, and installing thread protectors on tight. Current depth of 5553'. Report Number 28 Report Start Date 3/20/2024 Report End Date 3/21/2024 Operation Continue POOH L/D DP f/ 5553' t/ 2190' flushing and sucking wiper balls through pipe on the ground, seperating pipe for inspect ion. Slip and cut drilling line 36' cut off Continue POOH L/D DP f/ 2190' t/ 790' flushing pipe and sucking wiper balls through on the ground, seperateing pipe for inspect ion. L/D HWDP, Unload sources, download MWD, L/D remaining BHA, Bit graded a 1-2 In Gauge, Clear floor M/U Johnny Wacker, RIH out of derrick with the remainder of 4.5" DP F/surface-T/ 4188'. L/D same, kicking out non-inspected jts. Vacuuming wiper balls through tubulars, re-doping threads, and installing protectors on tight. Held kick while tripping drill, had good responce time from drilling crew. B/D & R/D MWD Geo-Span unit. Cleaned & cleared rig floor. B/D & R/D MWD Geo-Span unit. Cleaned & cleared rig floor. Loaded racks with 4.5" inspected DP. Crew change, held PTSM. Finished cleaning rig floor, tallied 4.5" DP. Serviced rig- Inspected & greased crown, blocks, TDS, wash pipe, IR, DWKS, brake linkage, and drive shaft. M/U Johnny Wacker to jt. of 4.5" DP. Cont. P/U & singling in the hole w/ 4.5" inspected DP off the walk F/surface to current depth of 2903'. At 2:20 hrs while loading out drilling mud onto a super sucker. Truck went into regen mode and dropped vac. Discharging 3 gals of drilling mud onto pad from quick clip clamp area on XO. Discharge was reported & immediatly cleaned up. All proper personal were contacted. Report Number 29 Report Start Date 3/21/2024 Report End Date 3/22/2024 Operation Continue RIH w/ Inspected 4.5'' DP f/ 2903' t/ 6736' POOH f/ 6736' t/ Surface racking back DP. R/U Parker Liner Equipment, P/U Centralizers and Crossovers f/ Wel control. M/U float equipment and fill check Floats (good) coontinue RIH w/ 4.5'' Liner as per detail installing centralizers every jt, filling on the fly and topping off every 10 jts. F/45'-T/4297'. P/U & M/U Baker Flex Lock V hanger / HRD-E ZXP packer as per Baker rep. Mixed and pored in hanger Xan-plex barrier fluid. RIH on std of 4.5" DP P/U-69K S/O-50K. M/U TDS, broke circ. Staged up pump- GPM-218 SPP-365 psi. Cont. RIH with 4.5" liner on DP F/4403' to 7-5/8" casing, filling pipe every 1500'. CBU, staging up MP. GPM-210 SSP-540 psi Max gas- 39 units MW-11.1 ppg Pump off- P/U-115K S/O-77K. B/D TDS. RIOH with 4.5" liner F/6961', Filled pipe @ 8192', P/U-140K S/O-85K. Resumed RIOH with 4.5" liner to current depth of 9942'. Report Number 30 Report Start Date 3/22/2024 Report End Date 3/23/2024 Operation Circulate Bottoms up stage pumps t/ 5 bpm 700 psi packing off is setting still, continue reciprocating pipe until cleaned up. Attempt t/ cotinue Running liner setting down @ 9952' unable to work past setting down 30-50k, attempt to wash through staging rate to 5 bpm packing off, P/U and establish free rotating torque 10.2k wash and ream down through tight spot f/ 9952-9965' work through until able to pass freely Continue RIH t/ 11052 set down unable to work down wash and ream to bottom 11094' stage rate to 5 bpm 20 rpm Circulate and condition for cement Job stage rate to 5 bpm 800 psi, spot in cementers and R/U, M/U cement head and circulating lines, reciprocate pipe while holding PJSM. Cement as per detail, Pump 10 bbls water head, PT lines 250/4000, Pump 30 bbls of 12.5 ppg spacer @ 4 bpm follwed by 129 bbls 13 ppg lead cement @ 5 bpm chased w/ 18 bbls 15.3 ppg tail @ 4 bpm, washed up over top of head to cuttings box, kicked out liner wiper plug w/ 10 bbbls of water followed by 146.1 bbls of mud bumped plug @ 1.5 bpm 1550 psi held 500 psi over bled off and checked floats .75 bled back floats held CIP 1600 hrs, Pressured up t/ 2100 psi and set anchor take pressure up t/ 4000 psi hold and nuetralize pusher tool bleed off pressure and P/U to dogs out set down 50k Rotating 30 rpm, Pull up and L/D cement head. M/U top drive, Pull running tool out of liner, circulate bottoms up stage pumps t/ 9.6 bpm 1550 psi 30 bbls of spacer and 49 bb ls of cement to surface. POOH f/ 6492' t/ surface. Inspected & L/D Baker hanger running tool (Good indication hanger set). Had calculated hole fill for the trip. P/U-140K S/O-85K Cleaned & cleared rig floor. Flushed stack, B/O pups & XO's off Baker cmt head. Rig Service- Inspected & greased crown, blocks, TDS, wash pipe, IR (changed dies), DWKS, brake linkage, and drive shaft. Inspected saver sub (ok). API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 9/9 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation M/U Baker polishing mills. RIH F/surface, tagged TOL @ 6769' DPM. Set down 8K on liner top, polished PBR and dressed off liner top. P/U-130K S/O-84K ROT-103K RPM-50 TQ--9.25K MW-11.0 ppg CBU. GPM-253 SPP-590 psi. Held PJSM on displacement. Displaced well over to CIW. Pumped 15 bbl Hi-Vis spacer, followed by 274 bbls of 8.4 ppg CIW. GPM-275 SPP-1300 psi. Currently performing 30 min negative flow check. Report Number 31 Report Start Date 3/23/2024 Report End Date 3/24/2024 Operation Continue POOH L/D DP f/ 6759' t/ Surface flushing pipe and sucking wiper balls through pipe on the ground. Clear floor R/U Haliburton Eline, M/U CBL tool String RIH to liner top and log 7 5/8 casing RIH t/ Log 4.5'' Liner. L/D logging tools, R/D & released Yellow Jacket E-line unit. R/U testing equip. Tested liner lap- 7-5/8" casing x 4.5" liner T/3500 psi on chart for 30 min. (good test) Pumped in - 4.81 bb ls Bled back - 4.7 bbls. R/D testing equip. AT 21:45 hrs had 8 gal discharge of CIW/soap to pad. While vaccing out CIW/soap from premint tanks with super sucker, truck corked off, dicharging CIW/soap fliud from side tubes on super suck. Discharge was reported to proper Hilcorp personal, contained, and cleaned up. Drained stack, pulled 7' wear ring, L/D same. M/U well head brushing tool, brushed multi bowl well head, L/D same. Cleared & cleaned rig floor. Crew change, held PTSM. R/U TRS power tongs and handling equip. Loaded out racks with tie back tubulars. Held PJSM on P/U & running tie back with casing hands & Baker rep. P/U bullets seal assy. M/U XO & bullet seals to first 4.5" tie back jt. Cont. P/U and RIH 4.5" 13.5# L-80 DWC/C tubing as per run tally. F/surface to current depth of 4665'. Report Number 32 Report Start Date 3/24/2024 Report End Date 3/25/2024 Operation Continue RIH w/ 4.5'' tieback assembly f/ 4665' t/ 6779' Set down on Liner top 20k x 2 Space out, L/D 2 jts of tubing, M/U 28' of space out pups c,d,e,f M/U hanger and landing jts, Land on hanger w/ 67k down weight, engage hanger over pull 40k, back outt landing jt. R/U and test tubing t/ 3500 psi f/ 30 min Pumped in 2.05 bbls bled back 1.95 bbls, R/U on IA and pressured up to 3500 psi f/ 30 min pumped in 2.73 bbls bled pack 2.3 bbls Set TWC and Clear floor Flush Mud lines and choke manifold, gas buster and degasser, and stack drain and blow down lines. Open ram doors and inspect rams and do mothly PM's on BOP's, close up doors, remove riser and flow line, drop flow box, install trolly beam and hook up bridge cranes, remove choke and kill lines, hoist stack off wellhead and trolly to beaver slide side. Set & N/U tree on multi bowl. Tested tub ing hanger neck seals, void, and tree T/5000 psi for 10 min (ok). Picked clam shell off back side of derrick, and wind walls off pit module #1. Checked backlash & end play on TDS. Reoved choke & kill line hoses. Changed out oil in TDS drive swivel & gear box. R/D gen #3. Unplugged MWD/DD shack. Finished pit cleaning and R/D equalizer lines. R/D shakers and installed shipping blocks. Changed MP liners & swabs over to 5.5". Starte d R/D Pason & Gai-Tronic cords. R/D lines from MGS to pits & choke manifold. Removed door tarps on rig floor and bubble over centrifuge on pits. Removed suction lines in pump house. Installed shipping beams in sub base. L/D TDS. Hooked up bridle lines. Loaded out misc. equip, tools, and mud products onto floats. Crew change, held PTSM and weekly safety meeting with rig crew. Inspected & prepped derrick to scope. Removed T-bar & turnbuckles from TQ tube. Scoped derrick, removed & L/D lower section of TQ tube onto the catwalk. Hung blocks, unspooled drill line from drum (cut 57'). Hung & secured service loop, Kelley hose, and drilling in derrick. Laid over beaver slide onto catwalk. Disconnected HYD & electrical lines from catwalk. Finished R/D pits 1-3 and MP's 1-2. Laid over MGS. R/D steam, water, and air. Worked on removing Handy Berm around the rig. Report Number 33 Report Start Date 3/28/2024 Report End Date 3/29/2024 Operation API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 224-005 State: ALASKA Rig/Service: P 169 Page 1/2 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:3/27/2024 End Date: Report Number 1 Report Start Date 3/27/2024 Report End Date 3/28/2024 Operation Move in field triplex pump with methanol. Rig up to pump in sub with pump hose and isolation manifold. Install crystal gaug e. Pressure up down production tubing to 3834 psi. @ 0950 hrs. Finish MIT 3820 psi @ 1023 hrs. Good MIT. Bleed down well. Rig down pump. Wellsite secure. Hand over to construction/bolt up crew. Report Number 2 Report Start Date 4/4/2024 Report End Date 4/5/2024 Operation Held PJSM and approved PTW. Travel to pad and warmed eq. Spot in Cruz Crane and Fox CTU #8, R/u eq. N/u BOP's, set choke manifold and hard line into return tank. Vac truck loaded 400bbl supply tank with fresh water. Function and shell test BOPE. Tested BOP's as per Sundry 250psi/3500psi. Performed draw down test. No failures. MIRU CT pump truck and circulating lines. Spot in N2 pump and transport. Secured location and SDFN. Report Number 3 Report Start Date 4/5/2024 Report End Date 4/6/2024 Operation Held PJSM and approved PTW. Travel to Pad. Warmed up eq. P/u Injector head and M/u Riser. Stab on well. Filled reel with 33bbls of fresh water. Come off well M/u BHA. Fox CTC, 2-1/8" x 4-1/2" pup jt and 3.70" scraper/wash nozzel. Stab on well, PT 250psi/3500psi. Good test. Open well RIH with well displacing. Preformed wieght check at 5000' (22k). AT 6500'came on line with fluid pump at 1bpm. no iss ues going thru TOL at 6779'. Wt check at 10,000' (34k). Tagged PBTD at 11,021'ctm. Increased rate to 2bpm/2000psi returns drilling mud. Circulated BU after 150bbls returns of fresh water. SD Pump. Lined up to reverse circulale. Online with N2 at 1000scfm unloaded 20bbls. Circulating pressure built to 4400psi. SD N2 due to high circ pressures. Lost retruns, Picked up from 11,011'ctm to 7000'ctm. Come on with N2 pressured up to 4000psi, could not establish returns. POOH from 7000' to surface, Shut in well, L/d tools nozzle was plugged off, R/d riser and injector. SDFN Report Number 4 Report Start Date 4/6/2024 Report End Date 4/7/2024 Operation Held PJSM and approved PTW at KGF office. Travel to pad. Warmed eq. Picked up injector head and riser, M/u 2.13" OD nozzle w/1" throat. Stab on well, PT 250psi/ 3500psi. Good test. Open well and RIH, wt check at 5500' (19k), came on line with N2 1000scfm at 7300'. Continue RIH and stopped at 10,970'ctm. Unl oaded total of 80bbls and SD ops due to a hydraulic leak. Repaired washed out hydraulic gauge and cleaned up area. Notified ops and safety that 1 cup of hydraulic fluid spilled on pad. Resume ops. Back on line with N2, reverse circulating N2 at 1000scfm/3300psi and recovered 163bbls (well vol 166bbls). POOH. Bu mped up. Shut in well with 3050psi L/d tools, riser and injector head. Break iron and N/d BOP's, RDMO Fox CTU. Secured well SDFN. Report Number 5 Report Start Date 4/7/2024 Report End Date 4/8/2024 Operation Held PJSM and approved PTW, travel to pad. Warmed eq. Spot in and R/u AK Eline, longer rig up time due to muddy conditions. M/u lubricator and PCE. M/u 1-11/16" max OD tool string. Stab on well PT 250psi / 3500psi. Good test. Open well with 2838psi. RIH with GPT tag 10,990'. FL at 10950'. Logged up pass. POOH. Sent GPT log to town. Made 1' correction. L/d GPT. M/u Gamma-CCL, shock sub and 15' x 2-7/8" perf gun (loaded 13' 6spf). CCL to Top Shot 9.8'. RIH, made correlation pass, sent t o town. On depth. WHP 2800psi. Perf Tyk D3D zone (10,769-10,782'). Seen wt lose. No change in WHP. POOH L/d tools. All shot fired gun. Plug was dry. Released EL for the night. Ops to flow test well. Report Number 6 Report Start Date 4/8/2024 Report End Date 4/9/2024 Operation Held PJSM and approved PTW, travel to pad. M/u tools (max OD 1-11/16"), P/u lubricator. WPH 1700psi, Open well and RIH with GPT, tagged bottom at 10930', log up and found FL at 6300'. POOH, L/d Tools and Lubricator. R/u Fox N2 pump. PT iron to 4500psi, good test. Pumped 15,00scf and shut down to transfer N2. Lost prime coming back oline. Could not keep N2 pump primed up. Began troubleshooting issue. Continue pumping 230,000scf N2, pressure up to 3750 psi, shut down, transfer N2. Unable to catch prime with pump after transfer, Shut down for night, Wellhead pressure @ 2950psi Report Number 7 Report Start Date 4/9/2024 Report End Date 4/10/2024 Operation PJSM, PTW, mobe to location & fire up Eq. P/U, RIH w/GPT tool string (max OD 1-11/16"), Tag bottom @ 10908', log OOH found fluid level @ 10775', continure POOH l/d GPT tools. WHP 2900psi M/U 3.5" Bridge plug, CCL/gamma, API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 324-185 State: ALASKA Rig/Service:Permit to Drill (PTD) #:224-005 Page 2/2 Well Name: KU 41-08 Report Printed: 4/19/2024www.peloton.com Well Operations Summary Operation Open well WHP 2900psi, attempt to rih unable to go down, shut in well, bleed down,pulled out of rope socket while bleeding pres sure off through pump in sub, break off lubricator, found plug partially set in pump in sub, L/D lubricator & tools. (upon investigation, found setting tool had an ext ra O ring behind relief disk creating a leak into setting tool, when well bore pressure at 2900 psi was introduced into lubricator it leaked into setting tool causing plug to pa rtially set, while bleeding pressure off lubricator below plug the trapped pressure above element plunged tool string down causing it to shear free from rope socket) Break down tool string, Re-head, add WT bar, test good, m/u Lubricator, PT 250/3500 good, m/u tool string, 7' 1.69" wt bar, 3.125 GR CCL, Baker 10/ 3.71" CIBP RIH, t/10860' pull correlation log, send to town for verification, good, pull plug into position, CCL @ 10749.1', CCL to top of plug 10.9', placing top of plug @ 10760', set plug, good indication at surface plug set, P/U free, RIH tag plug good. POOH, OOH with running tool, good. P/U 3 1/2" Dump bailer, mix & load 5 gal 17 PPG CMT, RIH tag top of plug @ 10760', P/U dump bailer above plug & work, POOH, EST top of CMT 10,752' , OOH bailer MT, secure well for night. Report Number 8 Report Start Date 4/10/2024 Report End Date 4/11/2024 Operation Production bleed well down t/190 psi, R/U to start pressuring up with gas, build slow t/210psi, decision made to run small gun for preshot, Mobe out 2" 3' gun. M/U 2" x 3' gun 6 SPF, 60deg phasing, stab on well, open & RIH t/tag @10752', run correlation pass & send to town, made 1' shift as per Engioneer, pull gun on depth ccl-10726.5', 8.5' ccl to top shot, @ 10735' fire gunc good indication at surface gun fired perforating D3B ZONE 10735-10738', inital pressure 207PSI no change 5 min 207 psi 10 min 207psi 15 min 207 psi POOH, all shots fired, bull plug damp, M/U 3 1/8" tool string, GR CCl, shock sub, 15' 2 7/8" gun, 6 SPF 60 deg phasing, RIH tag @ 10752', pull correlation log, send t o town for adjustment. on depth, pull into position ccl@10718', 9' ccl to top shot, fire gun good indication at surface gun fired, perforated 10,727-10,741' no inital cha nge in pressure, start pressure 202 psi 5 min 202 psi 10 min 202 psi 15 min 202 psi POOH, all shots fired, bull plug wet,break down tool string, secure well for night, Report Number 9 Report Start Date 4/11/2024 Report End Date 4/12/2024 Operation PTW/PJSM. SIWHP 38 psi. RIH with GPT, found fluid level at 10,610'. Tag bottom at 10,752'. POH and LD tools. PU 3.71" CIBP and RIH. Ops pressured up well to 250 psi with gas. Found fluid level at 10,598' based on weight change. Set plug at 10,595'. Tagged plug to confirm set. POH and LD tools. GIH with 2-7/8" x 14' guns with gamma/CCL. Guns loaded with 15g Geo charges 6 spf, 60 deg phasing. Correlate on depth with geologist in town. Perforate D2 Sand from 10,363 - 10,377'. Init SIWHP: 228 psi 5 min: 228 psi 10 min: 229 psi 15 min: 229 psi POH and LD guns. Guns dry. Confirmed all shots fired. GIH with 2-3/4" x 20' guns with CCL. Guns loaded with 15g Geo charges 6 spf, 60 deg phasing. Correlate on depth with geologist in town. Perforate D2 Sand from 10,343 - 10,363'. Init SIWHP: 239 psi 5 min: 240 psi 10 min: 240 psi 15 min: 240 psi POH and LD guns. Guns dry. Confirmed all shots fired. GIH with 2-3/4" x 20' guns with CCL. Guns loaded with 15g Geo charges 6 spf, 60 deg phasing. Correlate on depth with geologist in town. Perforate D2 Sand from 10,323 - 10,343'. Init SIWHP: 240 psi 5 min: 241 psi 10 min: 240 psi 15 min: 239 psi POH and LD guns. Guns dry. Confirmed all shots fired. SIWHP: 237 psi. RDMO E-line unit. Turn well over to production ops to flow. API: 50133207170000 Field: Kenai Gas Field (KEU KGF) Sundry #: 324-185 State: ALASKA Rig/Service: Page 1/1 Well Name: KU 41-08 Report Printed: 4/23/2024 www.peloton.com Casing Surface Wellbore Wellbore Name: Original Hole Total Depth of Wellbore (ftKB): 11,094.00 Original KB/RT Elevation (ft): 83.20 RKB to GL (ft): 18.00 KB-Casing Flange Distance (ft): KB-Tubing Hanger Distance (ft): PBTDs Depth (ftKB): 11,047.0 Casing Casing Description: Surface Run Date: 2/27/2024 Set Depth (ftKB): 1,579.50 Casing Weight on Slips (1000lbf): 45,000.0 Pick Up Weight (1000lbf): 95,000.0 Block Weight (1000lbf): 15,000.0 Make-Up Contractor: Parker Number Hrs to Run (hr): 5.00 Ft/Min (ft/min): 5.27 Run Job: 241-00010 KU 41-08 Drilling, Drilling - Drilling, 2/22/2024 06:00 Set Depth (ftKB): 1,579.50 Set Depth (TVD) (ftKB): 1,488.5 Centralizer Detail: 19 Attribute Subtype: Value: Pipe Reciprocated?: Yes Pipe Rotated?: No Float Failed?: No Test Subtype: Pressure (psi): Casing (Or Liner) Details Jts Item Des OD Nominal (in)Nominal ID (in) Wt (lb/ft) Grade Top Thread Make Section Length (ft)Btm (ftKB) Top (ftKB) 1 Casing Hanger 15 9.95 0.75 23.58 22.83 1 Casing Pup Joint 10 3/4 9.95 45.50 L-80 4.06 27.64 23.58 22 Casing Joints 10 3/4 9.95 45.50 L-80 Vam21 1,466.26 1,493.90 27.64 1 Float Collar 11 3/4 9.95 DWC 1.50 1,495.40 1,493.90 2 Casing Joints 10 3/4 9.95 45.50 L-80 BTC 82.15 1,577.55 1,495.40 1 Float Shoe 11 3/4 9.95 BTC 1.95 1,579.50 1,577.55 Page 1/1 Well Name: KU 41-08 Report Printed: 4/23/2024 www.peloton.com Cement Surface Casing Cement Type Casing Description Surface Casing Cement Cemented String Surface, 1,579.50ftKB Wellbore Original Hole Job 241-00010 KU 41-08 Drilling, Drilling - Drilling, 2/22/2024 06:00 Cementing Start Date 2/28/2024 Cementing End Date 2/28/2024 Top Depth (ftKB) 24.3 Cement Stages Stage Number: 1 Description Surface Casing Cement Top Depth (ftKB) 24.3 Bottom Depth (ftKB) 1,585.0 Top Measurement Method Returns to Surface Pump Start Date 2/28/2024 Cement in Place At 2/28/2024 Final Circulating Pressure (psi) 415.0 Plug Bump Pressure (psi) 1,025.0 Full Return? No Returns During Job (%) 100 Volume to Surface (bbl) 67.0 Volume Lost (bbl) 0.0 Bump Plug? Yes Float Failed? No Pipe Reciprocated? Yes Pipe Rotated? No Slurry Type Class Amount (sacks) Yield (ft³/sack) Dens (lb/gal) Actual Volume Pumped (bbl) Calculated Volume Pumped (bbl)Q Avg (bbl/min) Pump Used Preflush (Spacer) Tuned Spacer 1.20 10.50 60.0 60.0 5 Halliburton Lead Slurry Type I II A 287 2.44 12.00 122.0 122.0 5 Halliburton Tail Slurry Type I II A 308 1.16 15.80 59.0 61.0 5 Halliburton Displacement Spud Mud 9.20 143.7 143.7 5 Halliburton Post Job Calculations Subtype Value Page 1/1 Well Name: KU 41-08 Report Printed: 4/23/2024 www.peloton.com Casing Intermediate1 Wellbore Wellbore Name: Original Hole Total Depth of Wellbore (ftKB): 11,094.00 Original KB/RT Elevation (ft): 83.20 RKB to GL (ft): 18.00 KB-Casing Flange Distance (ft): KB-Tubing Hanger Distance (ft): PBTDs Depth (ftKB): 11,047.0 Casing Casing Description: Intermediate1 Run Date: 3/9/2024 Set Depth (ftKB): 6,983.81 Casing Weight on Slips (1000lbf): 78,000.0 Pick Up Weight (1000lbf): 263,000.0 Block Weight (1000lbf): 15,000.0 Make-Up Contractor: Parker Number Hrs to Run (hr): 25.00 Ft/Min (ft/min): 4.66 Run Job: 241-00010 KU 41-08 Drilling, Drilling - Drilling, 2/22/2024 06:00 Set Depth (ftKB): 6,983.81 Set Depth (TVD) (ftKB): 5,992.8 Centralizer Detail: 147 Attribute Subtype: Value: Pipe Reciprocated?: Yes Pipe Rotated?: No Float Failed?: No Test Subtype: Pressure (psi): Casing (Or Liner) Details Jts Item Des OD Nominal (in)Nominal ID (in) Wt (lb/ft) Grade Top Thread Make Section Length (ft)Btm (ftKB) Top (ftKB) 1 Casing Hanger 11 6.88 0.57 21.95 21.38 1 Casing Pup Joint 7 5/8 6.88 29.70 L-80 BTC 1.45 23.40 21.95 130 Casing Joints 7 5/8 6.88 29.70 L-80 DWC 5,400.43 5,423.83 23.40 36 Casing Joints 7 5/8 6.88 29.70 P-110 GB CD-BTC 1,474.84 6,898.67 5,423.83 2 Float Collar 8 1/2 BTC 1.32 6,899.99 6,898.67 1 Casing Joints 7 5/8 6.88 29.70 P-110 BTC 82.21 6,982.20 6,899.99 Float Shoe 8 1/2 BTC 1.61 6,983.81 6,982.20 Page 1/1 Well Name: KU 41-08 Report Printed: 4/23/2024 www.peloton.com Cement Intermediate Casing Cement Type Casing Description Snteru ef iate Casing Ceu ent Ceu entef mtring Snteru ef iated, 1,579.7d0tKB Wellbore Original Hole Job 24d-UUUdUK8 4d-U7 Drilling, Drilling - Drilling, 2/22/2U24 U16UU Ceu enting mtart Date 9/dU/2U24 Ceu enting : nf Date 9/dU/2U24 Top DeptEh0tKB( d,941.U Cement Stages Stage Number: 1 Description Snteru ef iate Casing Ceu ent Top DeptEh0tKB( d,941.U Bottou DeptEh0tKB( 1,579.7 Top ) eas3reu ent ) etEof CBM R3u p mtart Date 9/dU/2U24 Ceu ent in Rlace At Pinal Circ3lating Rress3re hpsi( d,2F1.U Rl3g B3u p Rress3re hpsi( d,11?.U P3ll Net3rn% Ves Net3rns D3ring Job hL ( dUU Yol3u e to m3r0ace hbbl( 9U.U Yol3u e Most hbbl( d?.U B3u p Rl3g% Ves Ploat Pailef % ko Ripe Neciprocatef % Ves Ripe Notatef % ko ml3rry Type Class Au o3nt hsac³s( Vielf h0tQ/sac³( Dens hlb/gal( Act3al Yol3u e R3u pef hbbl( Calc3latef Yol3u e R3u pef hbbl(vAIghbbl/uin( R3up8sef Rre0l3sEhmpacer( t3nef priu e 9.72 dU.?U 1d.U 1U.U ? Hallib3rton Meaf ml3rry l ll 1F7 2.95 d2.UU 271.U 271.U ? Halib3rton Tail ml3rry l ll d?4 d.24 d?.9U 9d.U 9d.U 9 Hallib3rton Displaceu ent 1L KCM Rolyu er )3f 5.9U 9U?.9 9d1.F ? Hallib3rton Post Job Calculations m3btype Yal3e Page 1/1 Well Name: KU 41-08 Report Printed: 4/23/2024 www.peloton.com Casing ProdSction1 Welluore Welluore Name: Original Hole f otal beptT oDWelluore hDtK( B:11,094.00 ) riginal K( /Rf OleEation hDtB:83.20 RK( to v GhDtB:18.00 K( -Casing Llange bistance hDtB: K( -f Suing Fanger bistance hDtB: P( f bs beptThDtK( B:11,047.0 Casing Casing bescription: Production1 RSn bate: 3/21/2024 Het beptT hDtK( B:11,093.00 Casing WeigTt on Hlips h1000luDB:63,000.0 Pick Up WeigTt h1000luDB:230,000.0 (lockWeigTth1000luDB:15,000.0 Make-Up Contractor: Parker NSmuer Frs to RSn hTrB:18.50 Lt/Min hDt/minB:9.99 RSn Jou: 241-00010 KU 41-08 Drilling, Drilling - Drilling, 2/22/2024 06:00 Het beptT hDtK( B:11,093.00 Het beptT hfVbBhDtK( B: Centralizer betail: 108 AttriuSte HSutype: ValSe: Pipe Reciprocated?: Yes Pipe Rotated?: No Lloat Lailed?: No f est HSutype: PressSre hpsiB: Casing h) r GinerBbetails Jts Item Des OD Nominal (in)Nominal ID (in) Wt (lb/ft) Grade Top Thread Make Section Length (ft)Btm (ftKB) Top (ftKB) Liner Hanger 7.63 5.75 Baker 31.99 6,811.33 6,779.34 XO 6 3.94 TSH H563 1.92 6,813.25 6,811.33 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 TXP Tenaris 486.90 7,300.15 6,813.25 8 Plain-End Liner 4 1/2 3.92 13.50 L-80 DWC/C VAM 321.22 7,621.37 7,300.15 Marker pup jt 4 1/2 3.92 13.50 L-80 DWC/C VAM 6.04 7,627.41 7,621.37 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 DWC/C VAM 486.11 8,113.52 7,627.41 Marker pup jt 4 1/2 3.92 13.50 L-80 DWC/C VAM 6.15 8,119.67 8,113.52 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 DWC/C VAM 491.08 8,610.75 8,119.67 Marker pup jt 4 1/2 3.92 13.50 L-80 DWC/C VAM 10.05 8,620.80 8,610.75 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 DWC/C VAM 488.79 9,109.59 8,620.80 RA marker pup jt 4 1/2 3.92 13.50 L-80 DWC/C VAM 10.00 9,119.59 9,109.59 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 DWC/C VAM 492.45 9,612.04 9,119.59 Marker pup jt 4 1/2 3.92 13.50 L-80 DWC/C VAM 10.06 9,622.10 9,612.04 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 DWC/C VAM 496.03 10,118.13 9,622.10 RA marker pup jt 4 1/2 3.92 13.50 L-80 DWC/C VAM 10.07 10,128.20 10,118.13 Marker pup jt 4 1/2 3.92 13.50 L-80 TXP Tenaris 10.12 10,138.32 10,128.20 12 Plain-End Liner 4 1/2 3.92 13.50 L-80 TXP Tenaris 490.84 10,629.16 10,138.32 RA marker pup jt 4 1/2 3.92 13.50 L-80 TXP Tenaris 10.02 10,639.18 10,629.16 10 Plain-End Liner 4 1/2 3.92 13.50 L-80 TXP Tenaris 408.77 11,047.95 10,639.18 Landing collar 5.05 3.92 BTC JHOBBS 1.08 11,049.03 11,047.95 1 Plain-End Liner 4 1/2 3.92 13.50 L-80 BTC Tenaris 41.30 11,090.33 11,049.03 Float Collar 5.05 3.92 BTC OMD 1.31 11,091.64 11,090.33 Shoe 5.05 3.92 BTC OMD 1.36 11,093.00 11,091.64 Page 1/1 Well Name: KU 41-08 Report Printed: 4/23/2024 www.peloton.com Cement Liner Cement Type Casing Description Siner Ceu ent Ceu entef mtring drof , ction1511579. 077KtBW lebbOo r e HriginabJ obe 2oO 4- 1U77717 B8 - 1U7/ Dribbing5Dribbing U Dribbing5 46446474- 7: E77 Ceu enting mtart Date .6446474- Ceu enting hnf Date .6446474- Top Dept( )KtBW3 :5MM90. Cement Stages Stage Number: 1 Description Siner Ceu ent Top Dept( )KtBW3 :5MM90. 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enjamin Hand Digitally signed by Benjamin Hand Date: 2024.03.20 14:02:24 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2024.03.22 10:06:38 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Cody Dinger To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] FW: Logged 10-407 Hilcorp KU 41-08 10-407 Date:Thursday, May 30, 2024 8:04:23 AM Hi James, The TVD at TPI is 8,975’. Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Thursday, May 30, 2024 7:59 AM To: Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] FW: Logged 10-407 Hilcorp KU 41-08 10-407 Hi, This 407 is missing the tpi TVD value in box 29. Please provide that data. 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: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, April 24, 2024 9:23 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: Logged 10-407 Hilcorp KU 41-08 10-407 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 James, Attached is stamped 10-407 for KU 41-08; it is logged in the 10-407 Excel spreadsheet. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 From: Cody Dinger <cdinger@hilcorp.com> Sent: Tuesday, April 23, 2024 3:00 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: KU 41-08 10-407 Hello, Attached is the 10-407 for KU 41-08. Thank you! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Brooks, Phoebe L (OGC) To:Rance Pederson - (C); Justin Gruenberg - (C) Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: Rig 169 / KU 41-08 Initial BOP Test Report Date:Wednesday, April 3, 2024 2:51:16 PM Attachments:Hilcorp 169 02-28-24 Revised.xlsx Attached is a revised report changing the high test pressure to reflect 3500. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Wednesday, April 3, 2024 1:49 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Justin Gruenberg - (C) <Justin.Gruenberg@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: Rig 169 / KU 41-08 Initial BOP Test Report Jim here is a copy of the test chart for BOP test done on 2-28-24. Rance From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, April 3, 2024 1:11 PM To: Justin Gruenberg - (C) <Justin.Gruenberg@hilcorp.com> Cc: Rance Pederson - (C) <rpederson@hilcorp.com>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] RE: Rig 169 / KU 41-08 Initial BOP Test Report Please provide test charts for BOPE test done 2/28/2024 on KU 41-08. Thank you. Kenai Unit 41-08 PTD 2240050 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:Joshua Riley - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Subject:BOPE Test Report Date:Sunday, March 24, 2024 3:28:48 PM Attachments:KU 41-08 MIT-T & MIT-IA testing form.xlsx Some people who received this message don't often get email from jriley@hilcorp.com. Learn why this isimportant Here is the post rig work MIT. Thank You Josh RileyHilcorp DSM: 907-283-1369Cell: 907-252-1211 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kenai Unit 41-08 PTD 2240050 ===========MIT Tbg and MIT IA jbr Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2240050 Type Inj N Tubing 3700 3680 3670 Type Test P Packer TVD 5781 BBL Pump 2.1 IA 200 195 195 Interval O Test psi 3500 BBL Return 2.0 OA 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2240050 Type Inj N Tubing 350 350 350 Type Test P Packer TVD 5781 BBL Pump 2.7 IA 3620 3610 3610 Interval O Test psi 3500 BBL Return 2.4 OA 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska LLC Kenai Gas Field KU 41-08 Wavied Josh Riley 03/29/24 Notes:Post well work, MIT Tubing Notes: Notes: Notes: KU 41-08 Ku 41-08 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Post well work, MIT IA Notes: Notes: Form 10-426 (Revised 01/2017)2024-0324_MIT_KU_41-08_2tests ========3/24/2024 jbr; 5/13/2024 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from justin.gruenberg@hilcorp.com. Learn why this is important Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Justin Gruenberg - (C) <Justin.Gruenberg@hilcorp.com> Sent: Thursday, February 29, 2024 4:44 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Joshua Riley - (C) <jriley@hilcorp.com> Subject: Rig 169 / KU 41-08 Initial BOP Test Report Attached is the test report for the Initial BOP test on KU 41-08. Justin Gruenberg Hilcorp DSM – HEC 169 Office Phone (907) 283-1369 Cell Phone (907) 715-4195 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:169 DATE:2/28/24 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2240050 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:3486 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11'' P Pit Level Indicators P P #1 Rams 1 2 7/8'' x 5''P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8'' X 5''P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8 P Time/Pressure Test Result HCR Valves 2 3 1/8 & 2 1/16 P System Pressure (psi)3000 P Kill Line Valves 1 2 1/16 P Pressure After Closure (psi)1600 P Check Valve 0 NA 200 psi Attained (sec)22 P BOP Misc 0 NA Full Pressure Attained (sec)95 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2450 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 13 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/27/2024 14:19 Waived By Test Start Date/Time:2/28/2024 19:30 (date)(time)Witness Test Finish Date/Time:2/28/2024 22:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Hilcorp Tested with 4.5'' Test Joint at 250 low, 3500 high for 5 min each, (250/2500 on annular). Rig Electrician tested all audio and visual gas alarms. Test 2- Valve mis-alignment-Bleed down re-test. Test 5- Bleed air- Re-test. The waived by / witness was left blank due to no response back to us. Van Evera / Aguilera Hilcorp Alaska LLC Riley / Gruenberg KU 41-08 Test Pressure (psi): jvan-evera@hilcorp.com justin.gruenberg@hilcorp.com Form 10-424 (Revised 08/2022)2024-0228_BOP_Hilcorp169_KU_41-08 J. Regg; 4/3/2024 Kenai Unit 41-08 PTD 2240050 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:Brooks, Phoebe L (OGC) To:Rance Pederson - (C) Cc:Regg, James B (OGC) Subject:RE: Hilcorp Rig 169 BOP Test Results Date:Tuesday, April 2, 2024 5:25:10 PM Attachments:Hilcorp 169 03-10-24 Revised.xlsx Rance, I made a minor revision, rounding the Control System Response Times (no decimals). Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Sunday, March 10, 2024 9:11 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Hilcorp Rig 169 BOP Test Results Please see the attached BOP test results for KU 41-08. Rance Pederson Drilling Foreman Kenai Unit 907-283-1369 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the Kenai Unit 41-08 PTD 2240050 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:169 DATE:3/10/24 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2240050 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:X Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3486 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11'' P Pit Level Indicators P P #1 Rams 1 2 7/8'' x 5''P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8'' X 5''FP H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8" & 2 1/16"P System Pressure (psi)3025 P Kill Line Valves 1 2 1/16"P Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)24 P BOP Misc 0 NA Full Pressure Attained (sec)88 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2488 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 12 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:3.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/9/24 03:46 Waived By Test Start Date/Time:3/10/2024 16:00 (date)(time)Witness Test Finish Date/Time:3/10/2024 19:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 4.5'' Test Joint at 250 low, 3500 high for 5 min each, (250/3500 on annular). Had F/P on lower pipe ram low test. Functioned lower rams and re-tested OK. Rig Electrician tested all audio and visual gas alarms. Porterfield Hilcorp Alaska, LLC Pederson KU 41-08 Test Pressure (psi): kenneth.porterfield@hilcorp.com rpederson@hilcorp.com Form 10-424 (Revised 08/2022)2024-0310_BOP_Hilcorp169_KU_41-08 jbr J. Regg; 4/3/2024 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Initial Completion, N2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,094' N/A Casing Collapse Structural Conductor 1,410psi Surface 2,470psi Intermediate 4,790psi Production 8,540psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng LTP; N/A 6,779' MD / 5,822'TVD; N/A, N/A 9,675' 11,089' 9,670' Kenai Tyonek Gas Pool 1 16" 13-1/2" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 41-08CO 510C Same 9,674'4-1/2" 566 4,314' N/A Length April 3, 2024 Tieback 4-1/2" 11,093' Perforation Depth MD (ft): 6,983' See Attached Schematic 6,890psi 2,980psi 5,210psi 120' 5,992' 120' 1,579' Size 120' 7-5/8"6,983' 1,579' MD Hilcorp Alaska, LLC Proposed Pools: 13.5# / L-80 TVD Burst 6,786' 9,020psi 1,488' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 224-005 50-133-20717-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:29 pm, Mar 28, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.03.28 12:20:02 - 08'00' Noel Nocas (4361) Yes, for CT portion only 4/3/24 Bryan McLellan CT BOP test to 3500 psi 10-404 X Perforate BJM 3/29/24 SFD 3/28/2024JLC 4/5/2024 Initial Completion Well: KU 41-08 Well Name: KU 41-08 API Number: 50-133-20717-00-00 Current Status: New Drill Gas Producer Permit to Drill Number: 224-005 First Call Engineer: Chad Helgeson (907) 229-4824 (c) Second Call Engineer: Scott Warner (907) 830-8863 (c) Maximum Expected BHP: 1500 psi @ 9344 TVD Offset Pressure data Max. Potential Surface Pressure: 566 psi Using 0.1 psi/ft Applicable Frac Gradient: 0.72 psi/ft using 13.83 ppg EMW FIT at the intermediate casing 3/13/24 Shallowest Potential Perf TVD: NA for proposed perfs (Beluga/UT Pool when perfed will be 6,039 TVD) Top of Pools per CO 510C:Beluga/Upper Tyonek Gas Pool 5,483 MD, 4,733 TVD Tyonek Gas Pool 1 10,303 MD/8,958 TVD Brief Well Summary KU 13-06A was drilled and completed with Hilcorp Rig 169 March 2024 targeting Tyonek, Upper Tyonek and Lower Beluga sands at Kenai Gas Field. The well was TD last week and completed with a 4.5 completion. The objective of this sundry is to clean out the liner with coil tubing, reverse the water from the well and perforate the Tyonek sands. Initial targeted sands will be in the Kenai Tyonek Gas Pool 1 per CO 510C Wellbore Conditions: - Liner full of 11.1 ppg mud - Tubing and IA displaced to 8.4 ppg CIW - PT IA 3500 psi (30 min 3/24/24) - PT Tubing 3800 psi (30 min 3/27/24) Coiled Tubing Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high a. Provide AOGCC and BLM 24hr notice for BOP test 3. MU cleanout BHA 4. RIH to PBTD (11,047) cleanout well and swap well over to 8.4 ppg water 5. Once well is clean with 8.4 ppg water a. Reverse circulate water b. Target recovery = 166bbls i. Coil Reel volume: 34 bbls ii. Tubing x CT annulus volume: 132 bbls 6. RDMO CT 7. Bleed any N2 off well Eline Procedure 8. MIRU E-line and pressure control equipment 9. PT lubricator to 250psi low / 3000psi high 10. Ops pressure up well to 400 psi -bjm Beluga/Upper Tyonek Gas Pool 5,483 MD 3500 psi high PT, per attached email from Chad Helgeson. -bjm 3190 psi MPSP 4128 psi @ 9382' TVD per Chad Helgeson email 4/3/24 attached. Tyonek Gas Pool 1 10,303 MD/ Initial Completion Well: KU 41-08 11. RIH and perforate per RE/Geo (see table below) Pool Bench Top MD Btm. MD Top TVD Btm. TVD Ft Tyonek 1 D2 ±10,323 ±10,377 ±8974 ±9023 ±54 Tyonek 1 D3B ±10,727 ±10,741 ±9338 ±9351 ±14 12. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing, b. Pending well production, all perf intervals may not be completed c. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations d. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations e. Above perfs are in the Tyonek Gas Pool 1 governed by CO 510C 13. RD E-Line Unit and turn well over to production 14. Operations to flow well and test zones 15. Test SVS as necessary once well has reached stabile flow rates Coil Procedure (Contingency) If necessary to cleanout or unload well with coiled tubing: 16. MIRU Coiled Tubing Unit, PT BOPE to 3,000 psi High/250 psi Low 17. Provide AOGCC 24hrs notice of BOP test 18. PU wash nozzle, RIH and cleanout well to below perfs or proposed plug depth 19. PU CT jet nozzle and RIH, unload fluid from the wellbore with nitrogen a. Reverse circ out any fluid if perfs are isolated/plugged back and in cased hole 20. RDMO coil tubing Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Fox CT BOP Drawing 4. Nitrogen procedure See additional perf interval in attached email from Chad Helgson 4/3/24. -bjm _____________________________________________________________________________________ Updated by DMA 03-26-24 CURRENT SCHEMATIC Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16Surf 120 10-3/4Surface 45.5 / L-80 / DWC/C 9.950Surf 1,579 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875Surf 6,983 4-1/2"Production 13.5 / L-80 / DWC/C 3.9206,77911,093 Tieback Detail 4-1/2 Tieback 13.5 & 12.8 / L-80 / TXP & BTC 3.920Surface 6,786 JEWELRY DETAIL No Depth Item 1 6,7795-1/2 Liner Top HRD-E ZXP Packer w/ 4.5 XO 2 6,7795-1/2 17# seal Stem, 0.62 off seat (4.78ID) OPEN HOLE / CEMENT DETAIL 10-3/4122 BBLs of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2 Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBLs of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8 Hole. CBL run 3-23-24 TOC @ 1346 4-1/2129 BBLs of 13ppg lead followed by 15.3 ppg tail in 6-3/4 Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC 6779 = (TOL) NOTES 10 Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 _____________________________________________________________________________________ Updated by DMA 03-26-24 PROPOSED Kenai Gas Field Well: KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor 84 / X-56 / Weld 16Surf 120 10-3/4Surface 45.5 / L-80 / DWC/C 9.950Surf 1,579 7-5/8"Intermediate 29.7 / L-80 / TXP 6.875Surf 6,983 4-1/2"Production 13.5 / L-80 / DWC/C 3.9206,77911,093 Tieback Detail 4-1/2 Tieback 13.5 & 12.8 / L-80 / TXP & BTC 3.920Surface 6,786 JEWELRY DETAIL No Depth Item 1 6,7795-1/2 Liner Top HRD-E ZXP Packer w/ 4.5 XO 2 6,7795-1/2 17# seal Stem, 0.62 off seat (4.78ID) OPEN HOLE / CEMENT DETAIL 10-3/4122 BBLs of 12 ppg lead followed by 59 bbls of 15.8 ppg cement in 13-1/2 Hole. Returned 67 bbls of lead to Surface 7-5/8"286 BBLs of 12 ppg lead followed by 31 bbls of 15.3 ppg w/ 15 bbls of losses cement in 9-7/8 Hole. CBL run 3-23-24 TOC @ 1346 4-1/2129 BBLs of 13ppg lead followed by 15.3 ppg tail in 6-3/4 Hole. 49 bbls of cmt returned off liner. CBL run 3-23-24 TOC @ 6779 = (TOL) PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Date Status D2 ±10,323'±10,377'±8,974'±9,023'±54'Proposed TBD D3B ±10,727'±10,741'±9,338'±9,351'±14'Proposed TBD NOTES 10 Short Joints @ 10122, 9124, 8122, 7629, 7138 RA Tags @ 10625, 9623, 8624 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Wednesday, April 3, 2024 5:23 PM To:McLellan, Bryan J (OGC) Cc:Roby, David S (OGC); Donna Ambruz Subject:KU 41-08 (PTD# 224-005) Additional Perf request Bryan, My geologist just asked if I could add one more zone to be perforated and tested in the Tyonek Gas Pool 1. This would be the 1 st zone we would want to shoot or test. We would like to add: Pool Bench Top MD Btm. MD Top TVD Btm. TVD Ft Tyonek 1 D3D ±10,769 ±10,782 ±9,376 ±9,388 ±13 The di erence this has, is this zone is not depleted, and expect the max poten al BHP to be 4,128 psi @ 9382,and a MPSP to be 3,190 psi. We would increase the PT pre perf to 3500 psi for this zone. Please let me know if you can a ach this request to the sundry when it gets approved or if I need to submit something addi onal. Chad From:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent:Wednesday, April 3, 2024 2:29 PM To:Chad Helgeson <chelgeson@hilcorp.com> Cc:Wade Hudgens <Wade.Hudgens@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject:RE: [EXTERNAL] RE: KU 41 08 (PTD# 224 005) Cement Bond Log Chad, Hilcorp has verbal approval to perform the CT por on of the sundry. CT BOP test to 3500 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250 9193 CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 2 From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Wednesday, April 3, 2024 1:30 PM To:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc:Wade Hudgens <Wade.Hudgens@hilcorp.com> Subject:RE: [EXTERNAL] RE: KU 41 08 (PTD# 224 005) Cement Bond Log Bryan, We are planning on doing the coil work (MIRU and BOP test) on this new drill well tomorrow and RIH with coil on Friday. Were you able to look at this sundry yet? It was coil cleanout and 2 zones to perf. If not, could we get verbal approval to start the coil work this week? Chad From:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent:Thursday, March 28, 2024 12:14 PM To:Chad Helgeson <chelgeson@hilcorp.com> Subject:[EXTERNAL] RE: KU 41 08 (PTD# 224 005) Cement Bond Log Chad, Could you send the wellbore diagram? Are you wai ng for approval from me for anything? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250 9193 From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Thursday, March 28, 2024 11:28 AM To:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc:Donna Ambruz <dambruz@hilcorp.com> Subject:KU 41 08 (PTD# 224 005) Cement Bond Log CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 3 Bryan A ached is the cement bond log for KU 41 08. This was run on the rig due to needing the bond log across the 7 5/8 casing with Pool 6. The pool tops are: Sterling Pool 6 5263MD:4553TVD Beluga/Upper Tyonek Gas Pool 5,483MD,4,733TVD Tyonek Gas Pool 1 10,303 MD/8,958TVD We have good cement through both casing strings. Chad Helgeson Operations Engineer Kenai Asset Team 907 777 8405 O 907 229 4824 C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. 1 From:McLellan, Bryan J (OGC) Sent:Wednesday, April 3, 2024 2:29 PM To:Chad Helgeson Cc:Wade Hudgens; Roby, David S (OGC) Subject:RE: [EXTERNAL] RE: KU 41-08 (PTD# 224-005) Cement Bond Log Chad, Hilcorp has verbal approval to perform the CT por on of the sundry. CT BOP test to 3500 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250 9193 From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Wednesday, April 3, 2024 1:30 PM To:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc:Wade Hudgens <Wade.Hudgens@hilcorp.com> Subject:RE: [EXTERNAL] RE: KU 41 08 (PTD# 224 005) Cement Bond Log Bryan, We are planning on doing the coil work (MIRU and BOP test) on this new drill well tomorrow and RIH with coil on Friday. Were you able to look at this sundry yet? It was coil cleanout and 2 zones to perf. If not, could we get verbal approval to start the coil work this week? Chad From:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent:Thursday, March 28, 2024 12:14 PM To:Chad Helgeson <chelgeson@hilcorp.com> Subject:[EXTERNAL] RE: KU 41 08 (PTD# 224 005) Cement Bond Log Chad, Could you send the wellbore diagram? CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Are you wai ng for approval from me for anything? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250 9193 From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Thursday, March 28, 2024 11:28 AM To:McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc:Donna Ambruz <dambruz@hilcorp.com> Subject:KU 41 08 (PTD# 224 005) Cement Bond Log Bryan A ached is the cement bond log for KU 41 08. This was run on the rig due to needing the bond log across the 7 5/8 casing with Pool 6. The pool tops are: Sterling Pool 6 5263MD:4553TVD Beluga/Upper Tyonek Gas Pool 5,483MD,4,733TVD Tyonek Gas Pool 1 10,303 MD/8,958TVD We have good cement through both casing strings. Chad Helgeson Operations Engineer Kenai Asset Team 907 777 8405 O 907 229 4824 C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 04/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 FINAL LWD FORMATION EVALUATION LOGS (02/26/2023 to 03/20/2024) BaseStar, ResiStar, DGR, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. 224-005 T38682 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.05 07:31:53 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 04/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 41-08 PTD: 224-005 API: 50-133-20717-00-00 Final GeoTap Formation Pressure Tester (02/26/2023 to 03/20/2024) SFTP Transfer - Data Folders: Please include current contact information if different from above. 224-005 T38682 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.05 07:32:15 -08'00' 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 Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Kenai Gas, Tyonek Gas Pool 1, KU 41-08 Hilcorp Alaska, LLC Permit to Drill Number: 224-005 Surface Location: 609' FNL, 953' FEL, Sec 7, T4N, R11W, SM, AK Bottomhole Location: 1048' FNL, 1163' FEL, Sec 8, T4N, R11W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this 13 day of February 2024. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.13 16:59:53 -06'00' 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: 11,098' TVD: 9,683' 4a. Location of Well (Governmental Section): 7.Property Designation: Surface: Top of Productive Horizon: 8.DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property:14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 83.2 15. Distance to Nearest Well Open Surface: x-274946 y- 2361403 Zone-4 65.2 to Same Pool: 1365' to KBU 11-08Z 16. Deviated wells: Kickoff depth: 250 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 33 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' 13-1/2" 10-3/4" 45.5# L-80 DWC/C 1,584' Surface Surface 1,584' 1,500' 9-7/8" 7-5/8" 29.7# L-80 TXP 6,976' Surface Surface 6,976' 6,000' 6-3/4" 4-1/2" 13.5# L-80 DWC/C 4,322' 6,776' 5,831' 11,098' 9,683' Tieback 4-1/2" 13.5# L-80 DWC/C 6,776' Surface Surface 6,776' 5,831' 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: Contact Email: Contact Phone: 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 3/3/2024 5367' to nearest unit boundary Sean Mclaughlin sean.mclaughlin@hilcorp.com 907-223-6784 L - 297 sx / T - 86 sx Tieback Assy. Drilling Manager Monty Myers 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):Perforation Depth MD (ft): Production Liner Intermediate Conductor/Structural Authorized Title: Authorized Signature: Authorized Name: LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) Driven L - 286 sx / T - 330 sx Effect. Depth MD (ft): Effect. Depth TVD (ft): 2494 18. Casing Program: Top - Setting Depth - BottomSpecifications 4080 GL / BF Elevation above MSL (ft): Total Depth MD (ft): Total Depth TVD (ft): 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 L - 681 sx / T - 147 sx 3486 1073' FNL, 2336' FWL, Sec 8, T4N, R11W, SM, AK 1048' FNL, 1163' FEL, Sec 8, T4N, R11W, SM, AK N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC 609' FNL, 953' FEL, Sec 7, T4N, R11W, SM, AK FEE A028142 KU 41-08 Kenai Gas Field Tyonek Gas Pool 1 Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No 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) Drilling Manager 01/18/24 Monty M Myers By Grace Christianson at 2:12 pm, Jan 18, 2024 DSR-1/26/24 Note: Need to make determination on diverter waiver request. -bjm 50-133-20717-00-00 Submit FIT data to AOGCC within 48 hrs of performing test. 224-005 BOP test to 3500 psi, Annular test to 2500 psi SFD 2/12/2024 Diverter waiver approved due to lack of shallow gas in nearby wells. BJM 2/13/24 4454, pg 44 -bjm Recommend approving requested diverter waiver. (See page 8.) SFD 2/12/2024 ($8JLC 2/13/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.02.13 17:00:14 -06'00'02/13/24 02/13/24 KU 41-08 Drilling Program Kenai Gas Field Rev. PTD January 15, 2024 KU 41-08 Drilling Procedure Contents 1.0 Well Summary................................................................................................................................ 2 2.0 Management of Change Information ........................................................................................... 3 3.0 Tubular Program:.......................................................................................................................... 4 4.0 Drill Pipe Information: .................................................................................................................. 4 5.0 Internal Reporting Requirements ................................................................................................ 5 6.0 Planned Wellbore Schematic ........................................................................................................ 6 7.0 Drilling / Completion Summary ................................................................................................... 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................... 8 9.0 R/U and Preparatory Work ........................................................................................................ 10 10.0 KU 41-08 location on KGF 41-7 Pad: ........................................................................................ 11 11.0 Drill 13-1/2” Surface Hole Section.............................................................................................. 11 12.0 Run 10-3/4” Surface Casing ........................................................................................................ 13 13.0 Cement 10-3/4” Surface Casing .................................................................................................. 15 14.0 BOP N/U and Test........................................................................................................................ 18 15.0 Drill 9-7/8” Hole Section .............................................................................................................. 19 16.0 Run 7-5/8” Intermediate Casing ................................................................................................. 21 17.0 Cement 7-5/8” Intermediate Casing ........................................................................................... 23 18.0 Drill 6-3/4” Hole Section .............................................................................................................. 26 19.0 Run 4-1/2” Production Liner ...................................................................................................... 28 20.0 Cement 4-1/2” Production Liner ................................................................................................ 30 21.0 4-1/2” Liner Tieback Polish Run / CBL ..................................................................................... 34 22.0 4-1/2” Tieback Run ...................................................................................................................... 34 23.0 BOP Schematic ............................................................................................................................. 36 24.0 Wellhead Schematic ..................................................................................................................... 37 25.0 Anticipated Drilling Hazards ...................................................................................................... 38 26.0 Hilcorp Rig 169 Layout ............................................................................................................... 40 27.0 FIT/LOT Procedure .................................................................................................................... 41 28.0 Rig 169 Choke Manifold Schematic ........................................................................................... 42 29.0 Casing Design Information ......................................................................................................... 43 30.0 9-7/8” Hole Section MASP .......................................................................................................... 44 31.0 6-3/4” Hole Section MASP .......................................................................................................... 45 32.0 Spider Plot (Governmental Sections NAD27) ........................................................................... 46 33.0 Surface Plat (As-Built NAD27 & NAD83) ................................................................................. 47 Page 2 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 1.0 Well Summary Well KU 41-08 Pad & Old Well Designation KGF 41-7 pad Planned Completion Type 4-1/2” Production Liner w/Tieback Target Reservoir(s) Lower Beluga through Deep Tyonek Planned Well TD, MD / TVD 11,098’ MD / 9,683’ TVD AFE Number AFE Drilling Days 31 AFE Drilling Amount Maximum Anticipated Pressure (Surface) 3486 psi Maximum Anticipated Pressure (Downhole/Reservoir) 4080 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 83.20 Ground Elevation 65.20 BOP Equipment 11” 5M Annular BOP 11” 5M Double Ram 11” 5M Single Ram Page 3 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 2.0 Management of Change Information Page 4 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 16” 15.01” 14.822” 17” 84 X-56 Weld 2980 1410 - Surface 13-1/2” 10-3/4” 9.95” 9.875” 11.75” 45.5 L-80 DWC/C 5210 2470 1040 Intermediate 9-7/8” 7-5/8” 6.875” 6.750” 8.500” 29.7 L-80 TXP 6890 4790 683 Prod 6-3/4” 4-1/2” 3.920” 3.795” 5.0” 13.5# L-80 DWC/C 9020 8540 307 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2” 3.826 2.6875” 5.25” 16.6 S-135 CDS40 17,693 16,769 468k Page 5 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellview. x Report covers operations from 6am to 6am x Ensure time entry adds up to 24 hours total. x Capture any out of scope work as NPT. 5.2 Afternoon Updates x Submit a short operations update each work day to KenaiCIODrilling@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. 5.4 EHS Incident Reporting x Notify EHS field coordinator. 1. Brad Duwe (907-398-6558) 2. Jacob Nordwall: O: (907) 777-8418 C: (907) 748-0753 3. For Spills: Jason Hobart – 907-598-5889 © 907-283-1358 (O) x Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to sean.mclaughlin@hilcorp.com, and cdinger@hilcorp.com 5.6 Casing and Cmt report x Send casing and cement report for each string of casing to sean.mclaughlin@hilcorp.com, and cdinger@hilcorp.com Page 6 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 6.0 Planned Wellbore Schematic Page 7 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 7.0 Drilling / Completion Summary KU 41-08 will target the lower Beluga through deep Tyonek sands drilled from Pad 41-7. The Lower Beluga through Deep Tyonek section at KGF needs downspacing. Utilizing and existing conductor the grassroots well will be drilled to the West with a maximum hole angle of 39 degrees. The TD of the three string well will be 11098’ TMD/ 9683’ TVD. Drilling operations are expected to commence in March 2024. The Hilcorp Rig # 169 will be used to drill the wellbore then run casing and cement. 10-3/4” surface casing will be run and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: 1. MOB Hilcorp Rig # 169 to KGF 41-7 pad x No diverter required 2. Drill 13-1/2” hole to 1584’ MD. Run and cmt 10-3/4” surface casing. 3. N/U & test 11” x 5M BOP to 3500 psi 4. Test Surface casing to 3000 psi. 5. Drill out shoe and perform a FIT to 12.8 ppg EMW 6. Drill 9-7/8” intermediate hole to 6976’ MD 7. RIH w/ 7-5/8” casing and cement to surface. 8. Perform casing test to 3500 psi. Swap rams to 4-1/2”. Test BOPE to 3500 psi 9. PU 6-3/4” motor drilling assembly and TIH to window. 10. Mill shoe track and 20’ of new hole. 11. Perform FIT to 13.3 ppg EMW 12. Drill 6-3/4” production hole to 11098’ MD 13. Run and cmt 4-1/2” production liner. 14. PU polish mill assembly and RIH to polish sealbore 15. Displace well above liner top to CI water. 16. RU eline and Run CBL across 7-5/8” and 4-1/2” tubing strings. 17. RIH and land 4-1/2” tieback string in liner top. 18. MIT Tubing and IA to 3500 psi. 19. N/D BOP, N/U dry hole tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res LWD 2. Intermediate hole: GR + Res LWD 3. Production Hole: Triple Combo LWD + GeoTap RFT Page 8 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/10 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation or could be assumed damaged, test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements” x Ensure AOGCC drilling permit is posted on the rig floor and in Co Man office. x Review all conditions of approval of the AOGCC PTD. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. AOGCC Regulation Variance Request: x 20 AAC 25.035(h)(2) - Diverter waiver request requested due to the recent drilling of KU 13-06A, KU 11-07X , KU 24-05B, KU 24-32, KU 42-12, KU 44-08, and KU 44-01B. No issues or shallow gas was experienced on these wells while drilling surface hole. Surface casing will be set at a similar depth of these wells. o Divert waiver requests granted on KU 14-05, KBU 31-06X, KBU 42-06Y, KDU 10, KBU 23-05 (all on 41-7 pad). Recommend approving requested diverter waiver: AOGCC reviewed records for ten nearby wells: KU 43-07, KDU 2 (21-08), KDU 4, KBU 41-07, KBU 41-07X, KBU 11-08Z, KDU 10, KU 14-05, KU 24-05B, and KBU 31-06X. None of these wells reported encountering significant gas while drilling to surface casing points at depths ranging from -1,140’ to -2,913' TVDSS. However, nearby well KU 24-05B (2190720) encountered 40 units of gas at 1,135' MD (-1,040' TVDSS) and a maximum of 62 units of gas were measured at 1,370' MD (-1,267' TVDSS), which are equivalent to about 1,150’ to 1,410’ MD in proposed well KU 41-08. Monitoring of gas and caution are advised while drilling to surface casing point. SFD 2/12/2024 Diverter waiver request r g, No issues or shallow,,,,, gas was experienced on these wells while drilling surface hole. Page 9 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 13-1/2” x 21-1/4” x 2M Riser N/A 9-7/8” and 6-3/4” x 11” x 5M Annular BOP x 11” x 5M Double Ram o Blind ram in btm cavity x Mud cross x 11” x 5M Single Ram x 3-1/8” 5M Choke Line x 2-1/16” x 5M Kill line x 3-1/8” x 2-1/16” 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3500 (Annular 2500 psi) Subsequent Tests: 250/3500 (Annular 2500 psi) x Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). x Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to testing BOPs. x Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Bryan McLellan / Petroleum Engineer / (O): 907-793-1226 / Email: bryan.mclellan@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) 2016 Waste Prevention Rule - Waste Minimization Plan for Drilling: Hilcorp Alaska will not be venting or flaring any gas while drilling this well. The only waste produced from this well will be used mud and cuttings and will be handled at the Kenai Gas Field G&I facility for injection disposal. Page 10 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 9.0 R/U and Preparatory Work 9.1 Set 16” conductor at +/-120’ below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4” 3M “A” section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Hilcorp Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 13-1/2” hole section. 9.9 Install 5-1/2” liners in mud pumps. x HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2” liners. Page 11 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 10.0 KU 41-08 location on KGF 41-7 Pad: 11.0 Drill 13-1/2” Surface Hole Section 11.1 P/U directional drilling assy: x 13-1/2” Openhole, 8” drilling tools x Ensure BHA components have been inspected previously. Page 12 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Workstring will be 4.5” 16.6# S-135 CDS40 11.2 Begin drilling out from 16” conductor at reduced flow rates to avoid broaching the conductor. 11.3 Drill surface hole section to 1584’ MD/ 1500’ TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at ~700 gpm. Ensure shaker screens are set up to handle this flowrate. x Utilize Kenai and Inlet experience to drill through coal seams efficiently. x Keep swab and surge pressures low when tripping. x Make wiper trips every 800’ or every couple days unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. x Take MWD surveys every stand drilled (60’ intervals). 11.4 13-1/2” hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 9.0 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, and Toolpusher office. System Type: 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-1584’ 8.8 – 9.5 85-150 20 - 40 25 - 45 <10 8.5-9.0 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER SODA ASH AQUAGEL CAUSTIC SODA 0.905 bbl 0.5 ppb 12-15 ppb 0.1 ppb (9 pH) Page 13 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G X-TEND II as needed as required for weight if required for <12 FL 0.1 ppb 0.02 ppb 11.5 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16” conductor shoe. 11.6 TOH with the drilling assy, handle BHA as appropriate. 12.0 Run 10-3/4” Surface Casing 12.1 R/U and pull wear bushing. 12.2 R/U Parker 10-3/4” casing running equipment. x Ensure 10-3/4” DWC/C x CDS 40 XO on rig floor and M/U to FOSV. x R/U fill-up line to fill casing while running. x Ensure all casing has been drifted on the location prior to running. x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ float shoe bucked on (thread locked). x (1) Joint with coupling thread locked. x (1) Joint with float collar bucked on pin end & thread locked. x Install (2) centralizers on shoe joint over a stop collar. 10’ from each end. x Install (1) centralizer, mid tube on thread locked joint and on FC joint. x Ensure proper operation of float equipment. 12.5 Continue running 10-3/4” surface casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Note M/U torque values required to achieve this position. x Install (1) centralizer every other joint to 200’. Do not run any centralizers above 200’ in the event a top job is needed. x Utilize a collar clamp until weight is sufficient to keep slips set properly. Page 14 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD Page 15 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Slow in and out of slips. 12.7 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.8 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.9 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.10 After circulating, lower string and land hanger in wellhead again. 13.0 Cement 10-3/4” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x Discuss how to handle cmt returns at surface. x Confirm which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Determine positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls spacer. Test surface cmt lines. 13.5 Pump remaining spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 75% open hole excess. Job will consist of lead & tail, TOC brought to surface. Page 16 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD Estimated Total Cement Volume: Cement Slurry Design: Lead Slurry (1084’ MD to surface) Tail Slurry (1584’ to 1084’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.40 ft3/sk 1.16 ft3/sk Mixed Water 14.25 gal/sk 5.04 gal/sk Mixed Fluid 14.25 gal/sk 5.04 gal/sk Additives Code Description Code Description Type I/II Cement Class A Type I/II Cement Class A Halad-344 Fluid Loss Halad-344 Fluid Loss CalSeal Accelerator CalSeal Accelerator VersaSet Thixotropic CFR-3 Dispersant D-Air 5000 Anti Foam UCS Slurry Conditioner Econolite Light-weight add. Super CBL Anti-Gas Migration SA-1015 Suspension Agent BridgeMaker II Lost Circulation Verified cement calcs. -bjm Page 17 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. 13.12 Do not overdisplace by more than 1 shoe track volume. Total volume in shoe track is 11 bbls. 13.13 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.14 R/D cement equipment. Flush out wellhead with FW. 13.15 Back out and L/D landing joint. Flush out wellhead with FW. 13.16 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.17 Lay down landing joint and pack-off running tool. Ensure to report the following on wellview: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Page 18 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and sean.mclaughlin@hilcorp.com. 14.0 BOP N/U and Test 14.1 ND Riser 14.2 N/U multi-bowl wellhead assy. Install 10-3/4” packoff P-seals. Test to 3000 psi. 14.3 N/U 11” x 5M BOP as follows: x BOP configuration from Top down: 11” x 5M annular BOP/11” x 5M double ram /11” x 5M mud cross/11” x 5M single ram x Double ram should be dressed with 7-5/8” fixed bore rams in top cavity, blind ram in btm cavity. x Single ram should be dressed with 2-7/8” x 5” variable bore rams x N/U bell nipple, install flowline. x Install (2) manual valves & a check valve on kill side of mud cross. x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run BOP test assy, land out test plug (if not installed previously). x Utilize 7-5/8” and 4-1/2” test joints. x Test BOP to 250/3500 psi for 5/10 min. x Test annular to 250/2500 psi for 5/10 min with a 4-1/2” test joint x Ensure to leave “B” section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.1 ppg 6% KCL PHPA mud system. 14.8 Rack back as much 4-1/2” DP in derrick as possible to be used while drilling the hole section. Page 19 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 15.0 Drill 9-7/8” Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm all LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. 15.7 Workstring will be 4.5” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.8 9-7/8” hole section mud program summary: Starting mud weight for the production interval is 9.1ppg. Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, and Toolpusher office. System Type: 9.1 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 1584’- 6976’ 9.0 – 9.7 40-53 15-25 15-25 8.5-9.5 11.0 Page 20 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.9 TIH w/ 6-3/4” directional BHA assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.10 R/U and test casing to 2700 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 10-3/4” burst is 5210 psi / 2 = 2605 psi. 15.11 Drill out shoe track and 20’ of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FIT to 12.8 ppg EMW. (12.5 FIT, 8.5 ppg BHP, 9.1 ppg MW = 23 bbl KTV) x Send FIT test results to the AOGCC within 48 hours. 15.14 Drill 9-7/8” hole section to 6976’ MD / 6000’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at ~400 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 1000’ unless hole conditions dictate otherwise. Halfway through the hole section make a wiper back to the shoe. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Low BHP between Pool 3 and 6 (3700’ – 5500’). To minimize LC risk keep MW at 9.1 ppg, minimize ECD, stage up pumps on connections, add Black products and sized Calcium Carbonate to the mug, Control drill at 40 fph. 15.15 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4” shoe. 15.16 TOH with the drilling assy, standing back enough drill pipe for the upcoming liner run Page 21 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 15.17 POOH LDDP and BHA. 15.18 Ensure 7-5/8” FBRs previously installed in BOP stack and tested with 7-5/8” test joint. 16.0 Run 7-5/8” Intermediate Casing 1. R/U and pull wear bushing. 2. R/U Parker 7-5/8” casing running equipment. x Ensure 7-5/8” TXP x CDS40 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Ensure all casing has been drifted to 6.75” on the location prior to running. x Note that 29.7# drift is 6.75” x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 3. P/U shoe joint, visually verify no debris inside joint. 4. Continue M/U & thread locking 80’ shoe track assembly consisting of: 7-5/8” Float Shoe 1 joint – 7-5/8” BTC, 1 Centralizer 10’ from bottom w/ stop ring 7-5/8” Float Collar 1 joint – 7-5/8” BTC, 1 Free floating centralizer 7-5/8” Landing collar 5. Continue running 7-5/8” intermediate casing x Centralization: x 1 centralizer every joint to 1000’ MD (Planned TOC) x Utilize a collar clamp until weight is sufficient to keep slips set properly. Page 22 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD Page 23 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 6. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 7. Slow in and out of slips. 8. P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 9. Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Conventional circulation is not permissible once casing hanger is landed. 10. P/U and R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger off seat to avoid plugging. Stage up pump slowly and monitor losses closely while circulating. 11. After circulating, lower string and land hanger in wellhead again. Cement to surface is not expected. However, in the event cement is circulated out ensure hose is in place to take returns to the cellar. 17.0 Cement 7-5/8” Intermediate Casing 1. Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amount of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 2. Document efficiency of all possible displacement pumps prior to cement job. 3. Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. Page 24 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 4. R/U cement line (if not already done so). 5. Fill surface cement lines with water and pressure test. 6. Pump remaining 60 bbls 10.5 ppg tuned spacer. 7. Mix and pump cement per below calculations, confirm actual cement volumes with cementer after TD is reached. 8. Cement volume based on annular volume + 40% open hole excess. Job will consist of lead & tail, TOC brought to 1000’. Estimated Cement Volume: Cement Slurry Design: Lead Slurry 6476’-1000’ Tail Slurry 6976’- 6476’ System EconoCem HalCem Density 12.0 lb/gal 15.3 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mix Water 13.92 gal/sk 4.98 gal/sk Verified cement volumes. -bjm Page 25 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 9. Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation, land hanger, and continue with the cement job. 10. After pumping cement, drop wiper plug and displace cement with mud out of mud pits. a. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 11. Ensure rig pump is used to displace cement. 12. Land hanger. 13. Displacement volume is in Table above. 14. Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. 15. If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 1 shoe track volume, ±4 bbls before consulting with Drilling Engineer. 16. Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 17. Be prepared for cement returns to surface. Cement return to be taken to cellar. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. 18. R/D cement equipment. Flush out wellhead with FW. 19. Back out and L/D landing joint. Flush out wellhead with FW. 20. M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 21. Lay down landing joint and pack-off running tool. Ensure to report the following on wellview: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid Page 26 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to sean.mclaughlin@hilcorp.com and cody.dinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. 18.0 Drill 6-3/4” Hole Section 1. Set test plug, Swap 7-5/8” FBR to 2-7/8” x 5” VBR, test all rams to 3500 psi., Pull test plug, run and set wear bushing 2. Ensure BHA components have been inspected previously. 3. Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 4. TIH, conduct shallow hole test of MWD and confirm all LWD functioning properly (triple combo and GeoTap). 5. Ensure TF offset is measured accurately and entered correctly into the MWD software. 6. Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. 7. Workstring will be 4.5” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 8. 6-3/4” hole section mud program summary: Starting mud weight for the production interval is 9.8 ppg or the intermediate interval mud weight at TD, whichever is heavier. (10.7 ppg required at 7000’ TVD, 11.5 ppg required at TD) Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, and Toolpusher office. Page 27 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD System Type: 11.5 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 6976’- 11098’ 9.8 – 12.5 40-53 15-25 15-25 8.5-9.5 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 9. TIH w/ 4-3/4” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 10. R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 7-5/8” burst is 6880 psi / 2 = 3440 psi. 11. Drill out shoe track and 20’ of new formation. 12. CBU and condition mud for FIT. 13. Conduct FIT to 13.3 ppg EMW. (13.0 FIT, 8.8 ppg BHP, 11.5 ppg MW = 18 bbl KTV) x Send FIT results to the AOGCC within 48 hrs. 14. Drill 6-3/4” hole section to 11098’ MD / 9683’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at ~200-270 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. Page 28 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD x Make wiper trips every 1000’ unless hole conditions dictate otherwise. Halfway through to interval make a wiper trip to the shoe. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Mud Weight: 10.7 ppg required at 7000’ TVD, 11.5 ppg required at TD 15. At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8” shoe. 16. TOH with the drilling assy, standing back enough drill pipe for the upcoming liner run 17. POOH LDDP and BHA. 18. Ensure 2-7/8” x 5” VBRs previously installed in BOP stack and tested with 4-1/2” test joint 19.0 Run 4-1/2” Production Liner 1. R/U Parker 4-1/2” casing running equipment. x Ensure 4-1/2” DWC/C x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill casing while running. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 2. P/U shoe joint, visually verify no debris inside joint. 3. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x (1) Joint with Baker landing collar bucked on pin end & threadlocked. x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x MU a marker joint (short joint with RA tag) every 500’. 4. Continue running 4-1/2” production liner x Fill liner while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. Page 29 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD x Install solid body centralizers on every joint x Differential sticking risk: Keep Mud “clean” as possible, remove low gravity solid (drilled solids), Centralizers every joint, Minimize connection time, Slow running speeds to reduce surge, Keep pipe moving whenever possible 5. Run in hole w/ 4-1/2” liner to the 7-5/8” casing shoe. 6. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 7. Obtain slack off weight, PU weight, rotating weight and torque of the casing. Page 30 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 8. Circulate 2X bottoms up at shoe, ease casing thru shoe. 9. Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 10. Set casing slowly in and out of slips. 11. PU 4-1/2” X 7-5/8” Baker liner hanger/LTP assembly. RIH 1 stand and circulate one liner volume to clear string. Obtain slack off weight, PU weight, rotating weight and torque parameters of the liner. 12. Continue running in hole at slow speeds to avoid surging well. Target 20 ft/min and adjust slower as hole conditions dictate. 13. Swedge up and wash last stand to bottom. P/U 5’ off bottom. Note slack-off and pick-up weights. 14. Stage pump rates up slowly to circulating rate. Circ and condition mud with liner on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. 20.0 Cement 4-1/2” Production Liner 1. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x Plan for cmt returns at surface, regardless of how unlikely it is that this should occur. x Determine which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 2. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 3. Pump 5 bbls spacer. 4. Test surface cmt lines to 4500 psi. Page 31 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 5. Pump remaining spacer. 6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 40% OH excess. Estimated Total Cement Volume: Verified cement calcs. -bjm Page 32 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD Cement Slurry Design: 7. Drop drillpipe dart and displace with drilling mud. If hole conditions allow – continue rotating and reciprocating liner throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 8. Displace cement at max rate of 4 bbl/min. Reduce pump rate to 2-3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 10. Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (ensure pressure is above nominal setting pressure, but below pusher tool activation pressure). Hold pressure for 3-5 minutes. 11. Slack off total liner weight plus 30k to confirm hanger is set. 12. Do not overdisplace by more than 2 shoe track volumes. Shoe track volume is 1 bbls. 13. Continue pressuring up to activate LTP pusher tool and set packer with running tool in compression. 14. Pressure up to 4,500 psi to neutralize the pusher tool and release the running tool (HRD-E) from the liner. Lead Slurry (10598’ MD to 6776’ MD) Tail Slurry (11098’ to 10598’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Additives Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaCl2 0.1 % BWOC Page 33 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 15. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 16. P/U past free-travel verify setting tool is released, confirmed by loss of liner weight 17. Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 18. Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 19. Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 20. RD cementers and flush equipment. POOH, LDDP and running tool. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 21. If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 22. NOTE: Some hole conditions may require movement of the drillpipe to “work” the torque down to the setting tool. 23. After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Ensure to report the following on wellview: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight Page 34 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and sean.mclaughlin@hilcorp.com. 21.0 4-1/2” Liner Tieback Polish Run / CBL 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. CBU and displace well to CI water. 18.4. POOH LDDP and BHA 18.5. RU eline and run CBL across the 7-5/8” casing and 4-1/2” liner. x Send CBL results to the AOGCC as soon as the data is available. 18.6. If not completed, test 4-1/2” liner lap to 3500 psi for 10 minutes 22.0 4-1/2” Tieback Run 19.1 PU 4-1/2” tieback assembly and RIH with 4-1/2” 13.5# L-80 TXP tubing x No SSSV, GLM, or CIM required. 19.2 No-go tieback seal assembly in liner PBR and mark pipe. PU pup joint(s) if necessary to space out tieback seals in PBR. 19.3 PU hanger and land string in hanger bowl. Note distance of seals from no-go. Page 35 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 19.4 Install packoff and test hanger void. 19.5 Test 4-1/2” liner and tieback to 3500 psi and chart for 30 minutes. 19.6 Test 7-5/8” x 4-1/2” annulus to 3500 psi and chart for 30 minutes. 19.7 Install BPV in wellhead 19.8 N/D BOPE 19.9 N/U dry hole tree or full tree (if available). 19.10 RDMO Hilcorp Rig #169 Page 36 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 23.0 BOP Schematic Page 37 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 24.0 Wellhead Schematic Page 38 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 25.0 Anticipated Drilling Hazards 9-7/8” Hole Section: Lost Circulation: High risk in Pool 3-6 due to Low BHP between 3700’ – 5500’. To minimize LC risk keep MW at 9.1 ppg, minimize ECD, stage up pumps on connections, add Black products and sized Calcium Carbonate to the mug, Control drill at 40 fph. Drilling through low pressure intervals: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 – 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of ~50 - ~60 lbs/100ft2 to combat this issue. Maintain low flow rates for the initial 200’ of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 – 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. Abnormal pressures or temperatures: None Page 39 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 6-3/4” Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. Reservoir Pressure: Abnormal pressures expected in the deep Tyonek inteval Page 40 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 26.0 Hilcorp Rig 169 Layout Page 41 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 27.0 FIT/LOT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 42 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 28.0 Rig 169 Choke Manifold Schematic Page 43 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 29.0 Casing Design Information Page 44 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 30.0 9-7/8” Hole Section MASP Page 45 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 31.0 6-3/4” Hole Section MASP Page 46 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 32.0 Spider Plot (Governmental Sections NAD27) Page 47 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD 33.0 Surface Plat (As-Built NAD27 & NAD83) Page 48 Version PTD January, 2024 KU 41-08 Drilling Procedure Rev PTD ! "##$ % & %&' -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 Tr u e V e r t i c a l D e p t h ( 1 5 0 0 u s f t / i n ) -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 Vertical Section at 96.00° (1500 usft/in) Shady Grove wp01 Tgt1 Shady Grove wp01 Tgt2 10 3/4" x 13 1/2" 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 5 00 1 0 0 0 1 5 0 0 2 0 0 0 2 5 0 0 3 0 0 0 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 0 0 0 9 5 0 0 1 0 0 0 0 1 0 5 0 0 1 1 0 0 0 1 1 0 9 8 KU 41-08 wp03 Start Dir 2.5º/100' : 250' MD, 250'TVD Start Dir 3.5º/100' : 700' MD, 697.11'TVD Start Dir 4º/100' : 900' MD, 890.44'TVD End Dir : 1598.45' MD, 1512.35' TVD Start Dir 3º/100' : 6859.56' MD, 5900.84'TVD End Dir : 7121.1' MD, 6127.2' TVD Total Depth : 11098.31' MD, 9683.2' TVD Top Pool 3 Top Pool 4 Top Pool 5 Top Pool 6 Top Upper Beluga Top Middle Beluga Top Lower Beluga Top Upper Tyonek Top Tyonek D1 Tyonek D5 Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: KU 41-08 65.20 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2361403.52 274946.51 60° 27' 28.2669 N151° 14' 48.1858 W SURVEY PROGRAM Date: 2024-01-09T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 3382.00 KU 41-08 wp03 (KU 41-08) 3_MWD+IFR1+MS+Sag 3382.00 7120.00 KU 41-08 wp03 (KU 41-08) 3_MWD+IFR1+MS+Sag 7120.00 11098.31 KU 41-08 wp03 (KU 41-08) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 3324.56 3241.36 3771.00 Top Pool 3 3805.86 3722.66 4348.00 Top Pool 4 3938.48 3855.28 4506.99 Top Pool 5 4473.17 4389.97 5148.00 Top Pool 6 4737.59 4654.39 5465.00 Top Upper Beluga 5380.71 5297.51 6236.00 Top Middle Beluga 6105.71 6022.51 7097.00 Top Lower Beluga 7232.21 7149.01 8357.00 Top Upper Tyonek 8899.70 8816.50 10222.00 Top Tyonek D1 9682.93 9599.73 11098.01 Tyonek D5 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: KU 41-08, True North Vertical (TVD) Reference:As-Built RKB @ 83.20usft (HEC 169) Measured Depth Reference:As-Built RKB @ 83.20usft (HEC 169) Calculation Method: Minimum Curvature Project:Kenai Gas Field Site:KGF 41-7 Pad Well:Plan: KU 41-08 Wellbore:KU 41-08 Design:KU 41-08 wp03 CASING DETAILS TVD TVDSS MD Size Name 1500.00 1416.80 1583.67 10-3/4 10 3/4" x 13 1/2" 6000.00 5916.80 6976.38 7-5/8 7 5/8" x 9 7/8" 9683.20 9600.00 11098.31 4-1/2 4 1/2" x 6 3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 2.5º/100' : 250' MD, 250'TVD 3 700.00 11.25 145.00 697.11 -36.07 25.26 2.50 145.00 28.89 Start Dir 3.5º/100' : 700' MD, 697.11'TVD 4 900.00 18.18 141.11 890.44 -76.39 56.08 3.50 -10.00 63.76 Start Dir 4º/100' : 900' MD, 890.44'TVD 5 1100.00 25.84 134.84 1075.75 -131.51 106.66 4.00 -20.00 119.82 6 1598.45 33.47 96.80 1512.35 -225.34 322.36 4.00 -85.40 344.15 End Dir : 1598.45' MD, 1512.35' TVD 7 6859.56 33.47 96.80 5900.84 -568.84 3203.75 0.00 0.00 3245.66 Start Dir 3º/100' : 6859.56' MD, 5900.84'TVD 8 7121.10 26.61 89.16 6127.20 -576.53 3334.14 3.00 -154.16 3376.14 Shady Grove wp01 Tgt1 End Dir : 7121.1' MD, 6127.2' TVD 9 10218.09 26.61 89.16 8896.20 -556.27 4721.07 0.00 0.00 4753.35 Shady Grove wp01 Tgt2 10 11098.31 26.61 89.16 9683.20 -550.52 5115.26 0.00 0.00 5144.78 Total Depth : 11098.31' MD, 9683.2' TVD -2 2 0 0 -1 9 2 5 -1 6 5 0 -1 3 7 5 -1 1 0 0 -8 2 5 -5 5 0 -2 7 5 0 27 5 55 0 82 5 11 0 0 13 7 5 South(-)/North(+) (550 usft/in) 0 2 7 5 5 5 0 8 2 5 1 1 0 0 1 3 7 5 1 6 5 0 1 9 2 5 2 2 0 0 2 4 7 5 2 7 5 0 3 0 2 5 3 3 0 0 3 5 7 5 3 8 5 0 4 1 2 5 4 4 0 0 4 6 7 5 4 9 5 0 5 2 2 5 We s t ( - ) / E a s t ( + ) ( 5 5 0 u s f t / i n ) Sh a d y G r o v e w p 0 1 T g t 2 Sh a d y G r o v e w p 0 1 T g t 1 10 3 / 4 " x 1 3 1 / 2 " 7 5 / 8 " x 9 7 / 8 " 4 1 / 2 " x 6 3 / 4 " 25 0 5 0 0 7 5 0 1 0 0 0 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 9500 9750 10000 10250 10500 10750 11000 11098 KU 4 1 - 0 8 w p 0 3 St a r t D i r 2 . 5 º / 1 0 0 ' : 2 5 0 ' M D , 2 5 0 ' T V D St a r t D i r 3 . 5 º / 1 0 0 ' : 7 0 0 ' M D , 6 9 7 . 1 1 ' T V D St a r t D i r 4 º / 1 0 0 ' : 9 0 0 ' M D , 8 9 0 . 4 4 ' T V D En d D i r : 1 5 9 8 . 4 5 ' M D , 1 5 1 2 . 3 5 ' T V D St a r t D i r 3 º / 1 0 0 ' : 6 8 5 9 . 5 6 ' M D , 5 9 0 0 . 8 4 ' T V D En d D i r : 7 1 2 1 . 1 ' M D , 6 1 2 7 . 2 ' T V D To t a l D e p t h : 1 1 0 9 8 . 3 1 ' M D , 9 6 8 3 . 2 ' T V D CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 15 0 0 . 0 0 1 4 1 6 . 8 0 1 5 8 3 . 6 7 1 0 - 3 / 4 1 0 3 / 4 " x 1 3 1 / 2 " 60 0 0 . 0 0 5 9 1 6 . 8 0 6 9 7 6 . 3 8 7 - 5 / 8 7 5 / 8 " x 9 7 / 8 " 96 8 3 . 2 0 9 6 0 0 . 0 0 1 1 0 9 8 . 3 1 4 - 1 / 2 4 1 / 2 " x 6 3 / 4 " Pr o j e c t : K e n a i G a s F i e l d Si t e : K G F 4 1 - 7 P a d We l l : P l a n : K U 4 1 - 0 8 We l l b o r e : K U 4 1 - 0 8 Pl a n : K U 4 1 - 0 8 w p 0 3 WE L L D E T A I L S : P l a n : K U 4 1 - 0 8 65 . 2 0 +N / - S + E / - W No r t h i n g E a s t i n g L a t i t u d e Lo n g i t u d e 0. 0 0 0 . 0 0 23 6 1 4 0 3 . 5 2 2 7 4 9 4 6 . 5 1 6 0 ° 2 7 ' 2 8 . 2 6 6 9 N 1 5 1 ° 1 4 ' 4 8 . 1 8 5 8 W RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l P l a n : K U 4 1 - 0 8 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : As - B u i l t R K B @ 8 3 . 2 0 u s f t ( H E C 1 6 9 ) Me a s u r e d D e p t h R e f e r e n c e : As - B u i l t R K B @ 8 3 . 2 0 u s f t ( H E C 1 6 9 ) Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e -2 6 2 5 -2 2 5 0 -1 8 7 5 -1 5 0 0 -1 1 2 5 -7 5 0 -3 7 5 0 37 5 75 0 11 2 5 15 0 0 18 7 5 22 5 0 South(-)/North(+) (750 usft/in) -1 1 2 5 - 7 5 0 - 3 7 5 0 3 7 5 7 5 0 1 1 2 5 1 5 0 0 1 8 7 5 2 2 5 0 2 6 2 5 3 0 0 0 3 3 7 5 3 7 5 0 4 1 2 5 4 5 0 0 4 8 7 5 5 2 5 0 5 6 2 5 6 0 0 0 We s t ( - ) / E a s t ( + ) ( 7 5 0 u s f t / i n ) Sh a d y G r o v e w p 0 1 T g t 2 Sh a d y G r o v e w p 0 1 T g t 1 1 5 0 0200025003000350040004500500055006000650070007500800085009250 106 20 KU 1 4 - 0 5 750 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 7000 9900 KB U 1 1 - 0 8 Z 1000 2000 2500 3000 3500 4000 4500 5000 5414 KU 1 1 - 8 1000 1500 2000 2500 3000 3500 4000 5000 KB U 1 1 - 8 Y 3 0 0 0 4 2 5 0 4 7 5 0 5 7 5 0 6 5 0 0 7 5 0 0 8 2 5 0 87 5 0 1 0 0 0 0 10210 KU 2 4 - 0 5 B 1 2 5 0 1 7 5 0 2 0 0 0 2 2 5 0 2 5 0 0 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 5 0 0 4 7 5 0 5 0 0 0 5 2 5 0 KB U 3 1 - 0 6 X 3 5 0 0 8 2 5 010250 1 2 0 2 6 KD U 1 0 250 1000 1 5 0 0 2000 2250 2500 375040004250KB U 4 2 - 6 X 175 0 325 0 4000 4500 5000 5500 6250 7250 10572 KD U 0 2 ( 2 1 - 8 ) 6 2 5 065006750700072507500775080008250850087509000925095009847 KB U 3 2 - 0 8 1500 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 47 5 0 5000 5250 5707 KU 4 3 - 7 3500 3750 4000 4250 4500 5000 5250 5500 5750 6000 6250 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11098 KU 41-08 wp03 Pr o j e c t : K e n a i G a s F i e l d Si t e : K G F 4 1 - 7 P a d We l l : P l a n : K U 4 1 - 0 8 We l l b o r e : K U 4 1 - 0 8 Pl a n : K U 4 1 - 0 8 w p 0 3 -1 5 0 0 15 0 South(-)/North(+) (300 usft/in) -3 0 0 - 1 5 0 0 1 5 0 3 0 0 4 5 0 6 0 0 We s t ( - ) / E a s t ( + ) ( 3 0 0 u s f t / i n ) 7 5 01000 1 5 0 0 17502000 KU 1 4 - 0 5 500 1250 1500 2000 KB U 1 1 - 0 8 Z 250 5 0 0 750 1000 1250 1500 1750 KU 1 1 - 8 2 5 0 1 5 0 0 1000 1 2 5 0 1 5 0 0 KB U 3 1 - 0 6 X 4000 5500 9250 1 0 0 0 010750 1 2 0 2 6 KD U 1 0 250 500 750 1000 KB U 4 2 - 6 X 1250 1500 KU 4 3 - 7 1 0 0 0 1250 1500 1750 2000 KU 4 1 - 0 8 w p 0 3 ( $ ) # $ * +,- * . . / ! ! 0$ 12 "#$#$% $ &$ &'!()* $ + ,-./0 - 3 !1 ( -/ 23 4 5 2 6 1- * &$ &'!()* $ + ,-./0 4 2 * 7 ! 4$ 1 ) % -) ( 1 5 )-) /*,-8 $ 0 2 6/*,2 63232 0 9 " % :7 + :: + & ) # # 3 4 2 3 6 3 % $ 03 $ + ;: $ + $ + <) / =((;. * (. .*)* * !>*)! >) . <*?*!)!*/>2 ><?> ) .(7 . . # 3 # 6 3 4 2 3 $ + 768. 748 $ + $ + $ + % #0 ! $ + $ + ) ) * (. 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(>) *.). *(*)* >.!)> ( !!).!/).*! !**)> * (. .). /) ) ( /*>) + + " ! ) *.). * ).. >.!) ( / .)!!/).*! !).* (. .)>* !). ) ( /)!. ! > ) *.). (. ) >.)> ( />).>!/).*! !!.)>>* (. .)(( *.)! ) ( /!/)(( ! . ) *.). /)! >..)!. ( //.)!/).*! /()((* (. .)( (..)*! ) (()! ! ) *.). >(!)!! >..)* )**!/).*! /.)** (. . )/ >>).! ) !)* ! ! ) *.). .*!)*/ >.>)>> !.) !/).*/ * )/ * (. . )> >>) / ) **) ! / ) *.). ) >.)/ ( )/!/).*/ .>)./* (. . )>> .()> ) .)* / ) *.). ! ) >.)* >)>!/).*/ )* (. . )(. *()/ ) *). / ) *.). !/.)>* >.()>/ ** )(>!/).*/ >>)*.* (. . ) !()(* ) *>.) / * ) *.). /!>)/( >.*)/( *.>)!/).*/ * ) * (. >/)/ / *)( ) ( ). / ( ) *.). ! >)( >.*)*! ( /)/*!/).*/ *)!(* (. >/)! //*) ) (>) ! / ) *.). ! .)> >.).( (>) !/).*/ *!/).** (. >/)>!! !)>> ) (!/)>> / > ) *.). ! *>). >. )/ (//)!!/).*/ (() * (. >/)(/! )/. ) () * / . ) *.). ! (()> >. )(* )*!/).*/ (/)/* (. >/)* ! *. )( ) !)/ / ) *.). ! (*)/! >>/).. !/) >!/).*/ *()/* (. >/) ! (/)! ) >**)/. / ! ) *.). ! >**)(/ >>/) >(()!(!/).*/ .!).* (. >!)!! (/)/ ) >.)( / / ) *.). ! .)! >>!)(. >!).*!/).*/ >()>* (. >!).*! >*!). ) .)/ ) *.). ! )* >>) .*() !/).*/ >>!)((* (. >!)*! .!) ) .>.)( ) *.). ! / ).* >>) > ..!)!!/).*/ . ()* (. >!)*(! )* ) )! * ) *.). ! !! ) ( >>.)(/ *)/!/).*/ .)/ * (. >!) ! /.)!( ) >)( ( $ ) # $ * +,- * . . / ! ! 0$ 12 "#$#$% $ &$ &'!()* $ + ,-./0 - 3 !1 ( -/ 23 4 5 2 6 1- * &$ &'!()* $ + ,-./0 4 2 * 7 ! 4$ 1 - 2 9 *; = 9:; !> )2 9:; 768. 9 *; 1 4 2 3 9 *; 1 6 3 9 *; 748 9 *; 0 , - 2 9 *; +,- * -# B , *!) / *.). ! !/.)* >>.)* *) !/).*/ .>.) * (. >!) ! !() ) >()(> 2% 0 +3 ***) *.). ! !//) >>.)*> **)!*!/).*/ .>)>* (. >)//! !.)> ) >>) / + + "- ( ) *.). ! /./) >>>) >)>!/).*/ ./*).!* (. >)!! !!.)* ) !/)! ) *.). / >!)!> >>>) ! ! *)>(!/).*/ ()* (. >).>! />).> ) !()* > ) *.). / !)*. >>)( !)(!/).*/ !*)*.* (. >)>/ .>) . ) !!) . ) *.). / *().. >>()! !/*) !/).*/ !*) * (. >)*./ >). ) /*()! ) *.). / (*) >>()* /(.)!!!/).*/ !)!(* (. >) / *()! ) /.).> ! ) *.). / .)! >>*) /!)..!/).*/ /.).* (. >.)!/ ((()*! ) > *)* / ) *.). / > >)!/ >>)! > *.)>!/).*/ /.) * (. >.).!/ **)./ ) > >.)>/ ) *.). / >/>)( >>). > )*(!/).*! .)!* (. >.)// >*) ) > ) . /!) *.). / .!*)/( >> )>* > >)*!/).*! > ) !* (. >.)( / >//)( ) > ). + "-A /!)( *.). / .!()* >> )>* > >)*.!/).*! > )** (. >.)*// . ) ) > )! + - 2EB D1-E@ BD+,- +34) 2 8) 3 2 +,- 9 *; 4 2 3 9 *; 6 3 9 *; 748 9 *; 768. 9 *; +3 - !3 9:; - - B 9:; @ A%1 4: . *)* * (. .) *! *./) >.)>( ( (() ) ) @ : , $ * ) 0 @ A%1 4: *! !/.)* * (. >!) */ .>.) >>.)* *) ) ) @ : , $ * ) 0 , - 2 9 *; 1 - 2 9 *; $ 3 - ) 9F; - ) 9F;4) $ 3 (;=8(;*= > ) >!(). 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" # ' ( " " * + 1 * ' ( " " * + 1 * ' ( " " * + 1 .% & , 2 - " & % 2 & 2 - ) ) & % ) & + " + - " & 0 * ' ( " " * + 1 * ' ( " " * + 1 * ' ( " " * + 1 .) & 2 . - " % & % / & 2 + - + " & % ) & + . , - " % & * ' ( " " * + 1 * ' ( " " * + 1 * ' ( " " * + 1 .) & / % - " . & , , % / & , ) - " " & 2 + ) & , 2 . - " . & , , 0 * ' ( " " * + 3 * ' ( " " * + 3 * ' ( " " * + 3 ), % & 2 / - / & ) / . & / . / - / ) & , ) + & " , /- / & 0 * ' ( " " * + 3 * ' ( " " * + 3 * ' ( " " * + 3 ), & " % / - % & ) / / & + ) / - / + % & / / + & + + /- % & * ' ( " " * + 3 * ' ( " " * + 3 * ' ( " " * + 3 ), & + / - % " 2 & 2 ) / / & , ) / - / , + & . + & ) " . /- % " 2 & 2 0 * ' ( ) " * 2 4 * ' ( ) " * 2 4 * ' ( ) " * 2 4 "% ) & / / . . . & + " ) % & % / . , & ) % + & % . .. . & + * ' ( ) " * 2 4 * ' ( ) " * 2 4 * ' ( ) " * 2 4 "% % & " . + % & " ) 2 & + + + ) & / + + & / + " + % & 0 * ' ( / * 2 4 * ' ( / * 2 4 * ' ( / * 2 4 " & % " " + & , + & + , & . + 2 " & , / / "+ & 0 * ' ( / * 2 4 * ' ( / * 2 4 * ' ( / * 2 4 " & % " % & , + & + + , & 2 , 2 " & / / , % & * ' ( / * 2 4 * ' ( / * 2 4 * ' ( / * 2 4 ") & + ) / % & " 2 & + . / ) % & % ) ) & " , /% & 0 * ' ( * 5 " * + 6* ' ( 5 " * + 6* ' ( 5 " * + 6 )/ + & " . " + & ) / 2 & " , 2 & . + " . % & , % . "+ & 0 * ' ( * 5 " * + 6* ' ( 5 " * + 6* ' ( 5 " * + 6 )/ + & + ) & ) / / & . ) 2 & % . 2 & . + ) & * ' ( * 5 " * + 6* ' ( 5 " * + 6* ' ( 5 " * + 6 . , & , % - . % & % . & % + % - 2 " . & / , / & % + " %- . % & 0 * ' ( * " * ' ( " * ' ( " /% & . + 2 . & / / / ) & " 2 + & 2 . " 2 & % ) 2 . & / / 0 * ' ( * " * ' ( " * ' ( " /% & + + ) & / & , ) " & " , " % & ) . ) & * ' ( * " * ' ( " * ' ( " %% & / % % % & % & . 2 % % & / " " " & + 2 %% & 0 * '( " " * + * ' ( " " * + * ' ( " " * + , & / . / - " . % & " % & / - 2 " & 2 2 & + + + /- " . % & 0 * '( " " * + * ' ( " " * + * ' ( " " * + , & % / - & " / , & , , / - + ) & " % & + , ) /- & * '( " " * + * ' ( " " * + * ' ( " " * + , & / / - " & . ) " % & / - + / & 2 / & + , ) /- " & . ) 0 * '( " / * % * ' ( " / * % * ' ( " / * % +/ & / 2 % / 2 & " . . , & " " % / % & " % & . . %/ 2 & " . 0 * '( " / * % * ' ( " / * % * ' ( " / * % +/ & / . % % & . , & , % / + & , " % & 2 , % %% & * '( " / * % * ' ( " / * % * ' ( " / * % ," & ) + . % & + / & + . " . & 2 + " ) & + , 2 . % & 0 * ) # $ % ! & ! % ! & ' ( 1 5 ! 1 @ 5 ! * + <= * , = * / ) 0 7 / ) 0 <= * , % 3 ) ) % 3 = - 7 % 5 +$ 3 6 & 3 ( ) 3 = * , 3 , ( * # - . * / +, ) 0 ) * +$ ! " # ! # $ % ! & ! % ! & ! % ! & ' ( = * , ; = 1 + '( / * % * ' ( / * % * ' ( / * % ) & . " + & " & / . " + & , , " & ) 2 , "+ & 0 * '( / * % * ' ( / * % * ' ( / * % / & ) ) % & " , / & / ) ) & & . " / ) % & * '( / * % * ' ( / * % * ' ( / * % / ) & % % . . % & ) & ) " . ) + & ) / " + & ) , + .. % & 0 * '( / ) * . * ' ( / ) * . * ' ( / ) * . %% & " " - ) % & % 2 ) . & / . " - ) 2 & 2 ) ) & " ) 2 "- ) % & % 2 0 * '( / ) * . * ' ( / ) * . * ' ( / ) * . %% & , , " - ) % & ) . & ) 2 " - ) . . & ) & % "- ) % & * '( / ) * . * ' ( / ) * . * ' ( / ) * . %, & , 2 " - ) % & ) , & , , " - ) , + & 2 + ) & ) "- ) % & 0 * / ) 0 ? / ) 0 . A # . ? "+ & ) - ) + & ' ( / " * + ) ) 7 8 9 ! " ! 8 ! : )- ) + & . - " & ' ( / " * + ) ) 7 8 9 ! " ! 8 ! : .- " & " " - , + & ) " ' ( / " * + ) ) 7 8 9 ! " ! 8 ! : ; < = > * & < ? & 0 < < $ & 0 @ $ # 5 $ * 6 & : ? ? & < < : 8 ; < ; 0 < = < ; & 0. 0 0 1. 0 0 2. 0 0 3. 0 0 4. 0 0 Separation Factor 0 6 0 0 1 2 0 0 1 8 0 0 2 4 0 0 3 0 0 0 3 6 0 0 4 2 0 0 4 8 0 0 5 4 0 0 6 0 0 0 6 6 0 0 7 2 0 0 7 8 0 0 8 4 0 0 9 0 0 0 9 6 0 0 1 0 2 0 0 1 0 8 0 0 1 1 4 0 0 Me a s u r e d D e p t h ( 1 2 0 0 u s f t / i n ) KB U 1 1 - 0 8 Z KU 1 1 - 8 KD U 0 2 ( 2 1 - 8 ) KU 4 3 - 7 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : P l a n : K U 4 1 - 0 8 N A D 1 9 2 7 ( N A D C O N C O N U S ) A l a s k a Z o n e 0 4 65 . 2 0 +N / - S +E / - W N o r t h i n g Ea s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0. 0 0 23 6 1 4 0 3 . 5 2 27 4 9 4 6 . 5 1 6 0 ° 2 7 ' 2 8 . 2 6 6 9 N 1 5 1 ° 1 4 ' 4 8 . 1 8 5 8 W RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l P l a n : K U 4 1 - 0 8 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : A s - B u i l t R K B @ 8 3 . 2 0 u s f t ( H E C 1 6 9 ) Me a s u r e d D e p t h R e f e r e n c e : As - B u i l t R K B @ 8 3 . 2 0 u s f t ( H E C 1 6 9 ) Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 15 0 0 . 0 0 1 4 1 6 . 8 0 1 5 8 3 . 6 7 1 0 - 3 / 4 1 0 3 / 4 " x 1 3 1 / 2 " 60 0 0 . 0 0 5 9 1 6 . 8 0 6 9 7 6 . 3 8 7 - 5 / 8 7 5 / 8 " x 9 7 / 8 " 96 8 3 . 2 0 9 6 0 0 . 0 0 1 1 0 9 8 . 3 1 4 - 1 / 2 4 1 / 2 " x 6 3 / 4 " SU R V E Y P R O G R A M Da t e : 2 0 2 4 - 0 1 - 0 9 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m De p t h T o Su r v e y / P l a n To o l 18 . 0 0 3 3 8 2 . 0 0 K U 4 1 - 0 8 w p 0 3 ( K U 4 1 - 0 8 ) 3_ M W D + I F R 1 + M S + S a g 33 8 2 . 0 0 7 1 2 0 . 0 0 K U 4 1 - 0 8 w p 0 3 ( K U 4 1 - 0 8 ) 3_ M W D + I F R 1 + M S + S a g 71 2 0 . 0 0 1 1 0 9 8 . 3 1 K U 4 1 - 0 8 w p 0 3 ( K U 4 1 - 0 8 ) 3_ M W D + I F R 1 + M S + S a g 0. 0 0 40 . 0 0 80 . 0 0 12 0 . 0 0 16 0 . 0 0 20 0 . 0 0 Centre to Centre Separation (80.00 usft/in) 60 0 1 2 0 0 1 8 0 0 2 4 0 0 3 0 0 0 3 6 0 0 4 2 0 0 4 8 0 0 5 4 0 0 6 0 0 0 6 6 0 0 7 2 0 0 7 8 0 0 8 4 0 0 9 0 0 0 9 6 0 0 1 0 2 0 0 1 0 8 0 0 1 1 4 0 0 Me a s u r e d D e p t h ( 1 2 0 0 u s f t / i n ) KU 1 4 - 0 5 KB U 1 1 - 0 8 Z KB U 3 1 - 0 6 X KD U 1 0 KB U 4 2 - 6 X KU 4 3 - 7 GL O B A L F I L T E R A P P L I E D : A l l w e l l p a t h s w i t h i n 2 0 0 ' + 1 0 0 / 1 0 0 0 o f r e f e r e n c e 18 . 0 0 T o 1 1 0 9 8 . 3 1 Pr o j e c t : K e n a i G a s F i e l d Si t e : K G F 4 1 - 7 P a d We l l : P l a n : K U 4 1 - 0 8 We l l b o r e : K U 4 1 - 0 8 Pl a n : K U 4 1 - 0 8 w p 0 3 La d d e r / S . F . P l o t s Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. Tyonek Gas Pool 1 224-005 Kenai Gas Kenai Unit 41-08 W E L L P E R M I T C H E C K L I S T Co m p a n y Hi l c o r p A l a s k a , L L C We l l N a m e : KE N A I U N I T 4 1 - 0 8 In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 82 0 Un i t 51 1 2 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 4 0 0 5 0 KE N A I , T Y O N E K G A S - 4 4 8 5 7 0 NA 1 P e r m i t f e e a t t a c h e d Ye s E n t i r e W e l l l i e s w i t h i n F E E A 0 2 8 1 4 2 . 2 L e a s e n u m b e r a p p r o p r i a t e Ye s 3 U n i q u e w e l l n a m e a n d n u m b e r Ye s K e n a i , T y o n e k G a s P o o l 1 - 4 4 8 5 7 0 , g o v e r n e d b y C O 5 1 0 C . 4 W e l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y Ye s 6 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 S u f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 I f d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 O p e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 O p e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 P e r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 P e r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 C a n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r s e r v NA 15 A l l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 P r e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 N o n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) Ye s 18 C o n d u c t o r s t r i n g p r o v i d e d Ye s 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s 20 C M T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s T o p o f c e m e n t t a r g e t i s 1 0 0 0 ' M D . S u r f a c e C a s i n g s h o e 1 5 8 4 ' M D 21 C M T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s 22 C M T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 23 C a s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s 24 A d e q u a t e t a n k a g e o r r e s e r v e p i t NA 25 I f a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s 26 A d e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d NA D i v e r t e r W a i v e r r e q u e s t e d a n d a p p r o v e d . M a n y n e a r b y w e l l s , n o h i s t o r y o f s h a l l o w g a s h a z a r d . 27 I f d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s 28 D r i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s 29 B O P E s , d o t h e y m e e t r e g u l a t i o n Ye s M P S P = 3 4 8 6 p s i . B O P r a t e d t o 5 0 0 0 p s i ( B O P T e s t t o 3 5 0 0 p s i ) 30 B O P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s 31 C h o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 W o r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n No 33 I s p r e s e n c e o f H 2 S g a s p r o b a b l e NA 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) Ye s M e a s u r e s n o t r e q u i r e d . N e a r b y w e l l s d i d n o t e n c o u n t e r H 2 S g a s . 35 P e r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s P l a n n e d m u d w e i g h t s a p p e a r a d e q u a t e t o c o n t r o l t h e o p e r a t o r ' s f o r e c a s t o f m o s t l i k e l y p o r e p r e s s u r e s . 36 D a t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA S t e r l i n g t o U p p e r B e l u g a e x p e c t e d t o b e u n d e r - p r e s s u r e d t o s e v e r e l y u n d e r - p r e s s u r e d w i t h M i d d l e 37 S e i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA B e l u g a s a n d s n o r m a l l y p r e s s u r e d a n d U p p e r T y o n e k e x p e c t e d t o b e o v e r p r e s s u r e d ( 1 0 . 2 p p g E M W ) . L o s t 38 S e a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA c i r c u l a t i o n m a t e r i a l s w i l l b e o n s i t e ; m i t i g a t i o n d i s c u s s e d i n A n t i c i p a t e d D r i l l i n g H a z a r d s ( p . 3 8 - 3 9 ) . 39 C o n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r SF D Da t e 2/ 1 2 / 2 0 2 4 Ap p r BJ M Da t e 2/ 1 3 / 2 0 2 4 Ap p r SF D Da t e 2/ 1 2 / 2 0 2 4 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e Re c o m m e n d a p p r o v i n g r e q u e s t e d d i v e r t e r w a i v e r : A O G C C r e v i e w e d r e c o r d s f o r t e n n e a r b y w e l l s : K U 4 3 - 0 7 , K D U 2 ( 2 1 - 0 8 ) , K D U 4 , KB U 4 1 - 0 7 , K B U 4 1 - 0 7 X , K B U 1 1 - 0 8 Z , K D U 1 0 , K U 1 4 - 0 5 , K U 2 4 - 0 5 B , a n d K B U 3 1 - 0 6 X . N o n e o f t h e s e w e l l s r e p o r t e d e n c o u n t e r i n g si g n i f i c a n t g a s w h i l e d r i l l i n g t o s u r f a c e c a s i n g p o i n t s . H o w e v e r , m o n i t o r i n g o f g a s a n d c a u t i o n a r e a d v i s e d w h i l e d r i l l i n g t o su r f a c e ca s i n g p o i n t . *& : JL C 2 / 1 3 / 2 0 2 4
