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Home My WebLink About223-028DA 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 1 - 0 0 - 0 0 We l l N a m e / N o . P E A R L 1 0 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 6/ 6 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 2 8 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 91 3 8 TV D 89 3 4 Cu r r e n t S t a t u s 1- G A S 11 / 1 7 / 2 0 2 5 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : CB L 6 - 4 - 2 3 , M u d l o g , X R M I , L W D ( D G R , E W R - P 4 , P W D , D D S R , A L D , C T N ) No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 5/ 2 5 / 2 0 2 3 89 9 1 3 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : P e a r l 1 0 L W D Fi n a l . l a s 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l M D . c g m 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l T V D . c g m 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 - D e f i n i t i v e S u r v e y Re p o r t . p d f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 - F i n a l S u r v e y s . x l s x 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 _ D S R A c t u a l _ P l a n . p d f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 _ D S R A c t u a l _ V S e c . p d f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 _ D S R . t x t 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 _ D S R _ G I S . t x t 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l M D . e m f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l T V D . e m f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l M D . p d f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l T V D . p d f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l M D . t i f 37 6 7 0 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D F i n a l T V D . t i f 37 6 7 0 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 10 8 9 3 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P e a r l 1 0 . l a s 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D a i l y R e p o r t s . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F i n a l W e l l R e p o r t . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g MD 2 i n . p d f 37 7 1 1 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 1 o f 6 Su p p l i e d b y Op Su p p l i e d b y Op Pe a r l 1 0 L W D Fi n al. l as Pe a r l 1 0 . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 3 3 - 2 0 7 1 1 - 0 0 - 0 0 We l l N a m e / N o . P E A R L 1 0 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 6/ 6 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 2 8 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 91 3 8 TV D 89 3 4 Cu r r e n t S t a t u s 1- G A S 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g MD 5 i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g TV D 2 i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g TV D 5 i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g M D 2i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g M D 5i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g T V D 2i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g T V D 5i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g M D 2i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g M D 5i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g T V D 2i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g T V D 5i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g M D 2i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g M D 5i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g T V D 2i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g T V D 5i n . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g MD 2 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g MD 5 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g TV D 2 i n . t i f 37 7 1 1 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 2 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 3 3 - 2 0 7 1 1 - 0 0 - 0 0 We l l N a m e / N o . P E A R L 1 0 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 6/ 6 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 2 8 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 91 3 8 TV D 89 3 4 Cu r r e n t S t a t u s 1- G A S 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 D r i l l i n g D y n a m i c s L o g TV D 5 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g M D 2 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g M D 5 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g T V D 2i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 F o r m a t i o n L o g T V D 5i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g M D 2 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g M D 5 i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g T V D 2i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 G a s R a t i o L o g T V D 5i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g M D 2i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g M D 5i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g T V D 2i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 L W D C o m b o L o g T V D 5i n . t i f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 2 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 S h o w R e p o r t s . p d f 37 7 1 1 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 27 9 0 9 1 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ P r o c e s s e d L o g . l a s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 27 9 0 9 1 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ R a w . l a s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : P E A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 . p d f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ i m g . t i f f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ P r o c e s s e d L o g . d l i s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ P r o c e s s e d L o g _ i m g. p d f 37 7 1 8 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 3 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 3 3 - 2 0 7 1 1 - 0 0 - 0 0 We l l N a m e / N o . P E A R L 1 0 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 6/ 6 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 2 8 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 91 3 8 TV D 89 3 4 Cu r r e n t S t a t u s 1- G A S 11 / 1 7 / 2 0 2 5 UI C No DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ P r o c e s s e d L o g _ i m g. t i f f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ W S T T _ 2 4 A P R 2 3 _ R a w . d l i s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : P E A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 . p d f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ i m g . t i f f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ P r o c e s s e d L o g . d l i s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ P r o c e s s e d L o g . v e r 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ P r o c e s s e d _ S T A T I C_ D Y N A M I C _ 1 t o 2 0 . p d f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ P r o c e s s e d _ S T A T I C_ D Y N A M I C _ 1 t o 2 0 _ i m g . t i f f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ R a w . d l i s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 1 4 A P R 2 3 _ R a w . v e r 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : P E A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 . p d f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 _ P r o c e s s e d L o g . d l i s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 _ P r o c e s s e d L o g . v e r 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 _ P R O C E S S E D _ S T A TI C _ D Y N A M I C _ 1 t o 2 0 . p d f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 _ P R O C E S S E D _ S T A TI C _ D Y N A M I C _ 1 t o 2 0 _ i m g . t i f f 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 _ R a w . d l i s 37 7 1 8 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ X R M I _ 2 4 A P R 2 3 _ R a w . v e r 37 7 1 8 ED Di g i t a l D a t a Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 4 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 3 3 - 2 0 7 1 1 - 0 0 - 0 0 We l l N a m e / N o . P E A R L 1 0 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 6/ 6 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 2 8 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 91 3 8 TV D 89 3 4 Cu r r e n t S t a t u s 1- G A S 11 / 1 7 / 2 0 2 5 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l 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 DF 6/ 9 / 2 0 2 3 91 0 1 2 3 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 : PE A R L _ 1 0 _ R B T _ 0 4 J U N 2 3 . l a s 37 7 1 9 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : P E A R L _ 1 0 _ R B T _ 0 4 J U N 2 3 . d l i s 37 7 1 9 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : P E A R L _ 1 0 _ R B T _ 0 4 J U N 2 3 . p d f 37 7 1 9 ED Di g i t a l D a t a DF 6/ 9 / 2 0 2 3 E l e c t r o n i c F i l e : PE A R L _ 1 0 _ R B T _ 0 4 J U N 2 3 _ i m g . t i f f 37 7 1 9 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 3 83 0 4 7 7 5 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 : P e a r l 1 0 _ P e r f _ 0 6 - Ju n - 2 0 2 3 _ ( 4 3 3 4 ) . l a s 37 8 1 6 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 3 E l e c t r o n i c F i l e : P e a r l 1 0 _ P e r f _ 0 6 - J u n - 20 2 3 _ ( 4 3 3 4 ) . p d f 37 8 1 6 ED Di g i t a l D a t a DF 12 / 1 8 / 2 0 2 4 33 8 2 6 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : P E A R L - 1 0 G P T AF T E R P E R F T - 1 4 6 S A N D 8 0 9 2 - 8 1 0 3 9 - 2 5 - 24 . l a s 39 8 8 5 ED Di g i t a l D a t a DF 12 / 1 8 / 2 0 2 4 82 2 0 7 9 4 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 : P E A R L - 1 0 G U N CO R R E L A T I O N T - 1 4 6 S A N D 8 0 9 2 - 8 1 0 3 9 - 2 5 - 24 . l a s 39 8 8 5 ED Di g i t a l D a t a DF 12 / 1 8 / 2 0 2 4 E l e c t r o n i c F i l e : P E A R L - 1 0 G P T A F T E R P E R F T - 14 6 S A N D 8 0 9 2 - 8 1 0 3 9 - 2 5 - 2 4 . p d f 39 8 8 5 ED Di g i t a l D a t a DF 12 / 1 8 / 2 0 2 4 E l e c t r o n i c F i l e : P E A R L - 1 0 G U N CO R R E L A T I O N T - 1 4 6 S A N D 8 0 9 2 - 8 1 0 3 9 - 2 5 - 24 . p d f 39 8 8 5 ED Di g i t a l D a t a DF 12 / 1 8 / 2 0 2 4 E l e c t r o n i c F i l e : P E A R L - 1 0 P E R F - G P T L O G FI N A L 9 - 2 5 - 2 4 . p d f 39 8 8 5 ED Di g i t a l D a t a 6/ 1 3 / 2 0 2 3 27 0 0 9 1 3 8 51 8 4 8 Cu t t i n g s Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 5 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 1 3 3 - 2 0 7 1 1 - 0 0 - 0 0 We l l N a m e / N o . P E A R L 1 0 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 6/ 6 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 2 8 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 91 3 8 TV D 89 3 4 Cu r r e n t S t a t u s 1- G A S 11 / 1 7 / 2 0 2 5 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 : CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 6/ 6 / 2 0 2 3 Re l e a s e D a t e : 4/ 1 0 / 2 0 2 3 Mo n d a y , N o v e m b e r 1 7 , 2 0 2 5 AO G C C Pa g e 6 o f 6 11 / 1 8 / 2 0 2 5 M. G u h l 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:Scott Warner Subject:RE: Pearl 10 Cap String - PTD 223-028 - Sundry 324-473 Date:Friday, October 31, 2025 3:42:00 PM Scott, I will extend the expiration date of this sundry to 12/31/25. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <scott.warner@hilcorp.com> Sent: Friday, October 31, 2025 9:11 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Pearl 10 Cap String - PTD 223-028 - Sundry 324-473 Bryan, This sundry was approved last year and we never ended up installing the cap string. This well has continued to make water and requires frequent soap drops. The perforations referenced in the sundry were not added aside from additional footage in the T- 146 from 8,092-8,103’. If I provide a current schematic is this sundry still valid to add the cap string? Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 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 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 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. 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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 9,138 feet N/A feet true vertical 8,934 feet N/A feet Effective Depth measured 9,071 feet 2,624 feet true vertical 8,868 feet 2,519 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) Tie Back 4-1/2" 12.6# / L-80 2,633' MD 2,528' TVD Packers and SSSV (type, measured and true vertical depth) LTP; SSSV 2,624' MD 2,519' TVD 173' MD/TVD 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: Scott Warner, Operations Engineer 324-236 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 859 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 scott.warner@hilcorp.com 907-564-4506 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 25 Size 120' 0 226733 0 402 38 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-028 50-133-20711-00-00 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: Private Ninilchik/ Beluga-Tyonek Gas Ninilchik Pearl 10 Plugs Junk measured Length Production Liner 6,512' Casing Structural 8,935'9,136' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,818' 7,500psi 2,980psi 6,880psi 8,430psi 2,818' 2,701' Burst Collapse 1,410psi 4,790psi 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 By Grace Christianson at 10:44 am, Nov 19, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.11.18 14:14:01 - 09'00' Noel Nocas (4361) Page 1/1 Well Name: NINU Pearl 10 Report Printed: 11/7/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:8/7/2024 End Date: Report Number 1 Report Start Date 9/25/2024 Report End Date 9/25/2024 Last 24hr Summary PTW/PJSM. MIRU YJ E-line. Well flowing 718 MCFD @ 39 psi. PT lubricator to 250/3000 psi - good test. Perforate T-146 from 8,092'-8,103'. Slight increase in flowrate after firing, POOH. At surface, troubleshoot crane electrical issues. Damaged wire above rope socket stuck in grease head. WO new grease head. Re- head, MU lubricator and MU GPT. RIH and find fluid level @ ~8,160' (in bottom set of perfs). POOH, secure well, RDMO. Report Number 2 Report Start Date 10/20/2024 Report End Date 10/20/2024 Last 24hr Summary Production monitoring complete- no further operations/interventions planned at this time Field: Ninilchik Sundry #: 324-236 State: ALASKA Rig/Service:Permit to Drill (PTD) #:223-028Permit to Drill (PTD) #:223-028 Wellbore API/UWI:50-133-20711-00-00 Updated by DMA 11-07-24 SCHEMATIC Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,071 / TVD = 8,868 TD = 9,138 / TVD = 8,934 RKB to GL = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84 X-56 Weld 15.01 Surf 120 7-5/8" Surf Csg 29.7 L-80 CDC 6.875 Surf 2,818 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958 2,624 9,136 Tieback Detail 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958 Surf 2,633 4 16 7-5/8 9-7/8 hole 4-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 173 3.813 5.500 ONYX SSSV 2 1,525 3.958 4.500 Chemical Injection Sub 3 2,633 4.790 6.340 Seal Stem 4 2,624 4.875 6.540 Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" L 390 sx / T 173 sx 54 bbls cmt to surface 4-1/2 L 503 sx / T 98 sx 43 bbls circulated off liner top (CBL TOC @ 2970; 6/4/23) 6-3/4 hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T146 8,046 8,066 7,855 7,875' 20' 06-06-23 Open 8,072 8,092 7,881 7,901' 20' 06-06-23 Open 8,092 8,103 7,901 7,912 11 09-25-24 Open 8,117' 8,137' 7,926 7,946' 20' 06-06-23 Open T146 From:McLellan, Bryan J (OGC) To:Scott Warner Cc:Donna Ambruz Subject:RE: [EXTERNAL] RE: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 Date:Tuesday, September 10, 2024 1:11:00 PM Scott, Hilcorp has approval to add the additional perf interval listed below as part of sundry 324-236. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, September 10, 2024 11:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 Bryan, Geo/RE identified one more interval we would like to add to sundry 324-236. T-146 ±8,092'±8,103'±7,900'±7,784'±11' Apologies for not including this in yesterday’s request. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, September 9, 2024 3:54 PM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: [EXTERNAL] RE: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 Scott, Hilcorp has approval to add the additional perfs listed below as part of sundry 324-236. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, September 9, 2024 3:36 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 Bryan, We have not executed this work yet due to waiting for production to decline but in the meantime, an additional sand was identified that we would like to add to the already open sundry. Pearl 10 T-65 ±6,762'±6,780'±6,582'±6,600'±18' Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, May 1, 2024 11:30 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com 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 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. From:McLellan, Bryan J (OGC) To:Scott Warner Subject:RE: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 Date:Monday, September 9, 2024 3:54:00 PM Scott, Hilcorp has approval to add the additional perfs listed below as part of sundry 324-236. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, September 9, 2024 3:36 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 Bryan, We have not executed this work yet due to waiting for production to decline but in the meantime, an additional sand was identified that we would like to add to the already open sundry. Pearl 10 T-65 ±6,762'±6,780'±6,582'±6,600'±18' Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, May 1, 2024 11:30 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Install Cap String 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: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,138'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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 16" 7-5/8" See Schematic See Schematic 2,980psi Ninilchik Beluga-Tyonek Gas Liner Top Pkr; SSSV 2,624' MD/2,519' TVD; 173' MD/TVD 8,934'9,071'8,868' 9,136' Perforation Depth MD (ft): Same 8,935'4-1/2" ~2,695psi N/A 120'120' 2,818'2,701' August 20, 2024 Tie Back 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Private 223-028 50-133-20711-00-00 Hilcorp Alaska, LLC Pearl 10CO 701G 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 6,512' Subsequent Form Required: Will perfs require a spacing exception due to property boundaries? 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 writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer Proposed Pools: Noel Nocas, Operations Manager 907-564-5278 Perforation Depth TVD (ft): Length Size 120' 2,818' MD Suspension Expiration Date: 12.6# / L-80 TVD Burst 2,633' 8,430psi scott.warner@hilcorp.com 907-564-4506 6,880psi m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.08.16 14:10:35 - 08'00' Noel Nocas (4361) 324-473 By Grace Christianson at 2:46 pm, Aug 16, 2024 SFD 8/19/2024 August 20, 2024 BJM 8/20/24 Aug 16, 2024 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.21 11:45:54 -08'00'08/21/24 RBDMS JSB 082324 Well Prognosis Well: Pearl 10 Date: 8/8/24 Well Name: Pearl 10 API Number: 50-133-20711-00-00 Current Status: Producing Gas Well Permit to Drill Number: 223-028 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 3488 psi @ 7926’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:2695 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.67 psi/ft using 12.8 ppg EMW FIT the surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.75-0.1) = 2695 psi / 0.63 = 4277‘ TVD Top of Applicable Gas Pool: 1690’ MD/ 1640’ TVD Well Status: Online Gas Producer flowing at 823 mcfd, 5 bwpd, 40 psi FTP Brief Well Summary Pearl 10 is a grass roots well drilled in 2023 targeting the Beluga and Tyonek sands in the southernmost portion of the Ninilchik Unit. Initial perforations were added in the T-146 and came on at 2 mmscfd but has been on steady decline since. The purpose of this sundry is to install a cap string for soap injection to optimize well performance. This will require the SSSV to be blocked open at surface while the cap string is installed. Notes Regarding Wellbore Condition x Inclination o Max deviation of 35.01° @ 2562’ MD o Max DLS of 4.32°/100’ @ 702’ MD x Recent Tags/Min ID o 06/06/2023 Perforated T-146 sand from: 8046’-8137’ with 2-3/4” guns o 09/23/23 D&T w/ 2.5” x 4’ DD bailer. Tag fluid @ 8205’ SLM. Tag TD @ 9071’ SLM o 01/30/24 D&T w/ 2.5” x 2’ DD bailer. Tag TD @ 9089’ KB (18’RKB to GL) o 08/7/24 D&T w/ 2.5”x 6’ DD bailer- sat down at 8132’ KB, broke through to 9068’ Procedure: 1. RU Cap String Truck 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 3000 psi 3. RIH with 3/8” capillary string to ±8050’ MD a. Set cap string as deep as practical in fluid 4. Install slips and connect tubing to chemical injection pump 5. Set spool of remaining line near well 6. RD cap string Unit, and turn well over to production Attachments: 1. Current Schematic 2. Proposed Schematic pp Shallowest Allowable Perf TVD: Top of Applicable Gas Pool: 1690’ MD/ 1640’ TVD 4277‘ TVD Updated by SRW 8-6-24 SCHEMATIC Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,071’ / TVD = 8,868’ TD = 9,138’ / TVD = 8,934’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 7-5/8" Surf Csg 29.7 L-80 CDC 6.875” Surf 2,818’ 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 2,624’ 9,136’ 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 2,633’ 4 16” 7-5/8” 9-7/8” hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 173’ 3.813” 5.500” ONYX SSSV 2 1,525’ 3.958” 4.500” Chemical Injection Sub 3 2,633’ 4.790” 6.340” Seal Stem 4 2,624’ 4.875” 6.540” Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" L – 390 sx / T – 173 sx 54 bbls cmt to surface 4-1/2” L – 503 sx / T – 98 sx 43 bbls circulated off liner top (CBL TOC @ 2970’; 6/4/23) 6-3/4” hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T146 8,046’ 8,066’ 7,855’ 7,875' 20' 06-06-23 Open 8,072’ 8,092’ 7,881’ 7,901' 20' 06-06-23 Open 8,117' 8,137' 7,926’ 7,946' 20' 06-06-23 Open T146 Updated by DMA 08-08-24 PROPOSED Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,071’ / TVD = 8,868’ TD = 9,138’ / TVD = 8,934’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 7-5/8" Surf Csg 29.7 L-80 CDC 6.875” Surf 2,818’ 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 2,624’ 9,136’ Tieback Detail 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 2,633’ 4 16” 7-5/8” 9-7/8” hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 173’ 3.813” 5.500” ONYX SSSV 2 1,525’ 3.958” 4.500” Chemical Injection Sub 3 2,633’ 4.790” 6.340” Seal Stem 4 2,624’ 4.875” 6.540” Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" L – 390 sx / T – 173 sx 54 bbls cmt to surface 4-1/2” L – 503 sx / T – 98 sx 43 bbls circulated off liner top (CBL TOC @ 2970’; 6/4/23) 6-3/4” hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-81 ±7,085' ±7,092' ±6,902' ±6,909' ±7' Proposed 324-236 T-81 ±7,120' ±7,130' ±6,937' ±6,947' ±10' Proposed 324-236 T-83 ±7,157' ±7,185' ±6,974' ±7,001' ±28' Proposed 324-236 T-100 ±7,446' ±7,457' ±7,260' ±7,271' ±11' Proposed 324-236 T-115 ±7,546' ±7,557' ±7,359' ±7,370' ±11' Proposed 324-236 T-119 ±7,691' ±7,705' ±7,503' ±7,517' ±14' Proposed 324-236 T-144 ±7,956' ±7,974' ±7,766' ±7,784' ±18' Proposed 324-236 T146 8,046’ 8,066’ 7,855’ 7,875' 20' 06-06-23 Open 8,072’ 8,092’ 7,881’ 7,901' 20' 06-06-23 Open 8,117' 8,137' 7,926’ 7,946' 20' 06-06-23 Open T146 T81-T144 Capillary String 3/8” Proposed Top Bottom MD 0’ ±8,050’ TVD 0’ ±7,859’ Note: TheT-81 through T-144 perfs are part of a separate approved sundry # 324-236, however the T146 are the only currently open perfs. See attached email from Scott Warner -bjm 1 McLellan, Bryan J (OGC) From:Scott Warner <Scott.Warner@hilcorp.com> Sent:Tuesday, August 20, 2024 3:57 PM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] Pearl 10 (PTD 223-028) cap string sundry Attachments:Pearl 10 AOGCC 10-403 324-236 PTD 223-028 Approved 05-01-24.pdf; Pearl 10 AOGCC 10-403 PTD 223-028 Submitted 08-16-24.pdf Bryan, The current perfs in the well are only the T146. We have an approved Sundry, 324-236 to add perforaƟons which are shown in the proposed diagram for the cap string but this was strictly to show we had an already approved Sundry for those perforaƟons. Apologies for the confusion. We had planned to add these perforaƟons months ago but producƟon has conƟnued to be stable enough that we don’t want to add these perforaƟons just yet since this is 1 of 2 wells leŌ that we have the T146 sand open in. We have had to increase the number of Ɵmes we soap this well per day and feel we can opƟmize producƟon and maximize recovery by installing a cap string prior to adding the perforaƟons that were approved in Sundry 324-236. Thanks, ScoƩ Warner Kenai – OperaƟons Engineer Oĸce: (907) 564-4506 Cell: (907) 830-8863 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. 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: 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: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,138' N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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 Liner Top Pkr; SSSV 2,624' MD/2,519' TVD; 173' MD/TVD 8,934' 9,071' 8,868' 16" 7-5/8" See Schematic Pearl 10CO 701H Same 8,935'4-1/2" ~2,647psi N/A May 3, 2024 Tie Back 4-1/2" 9,136' Perforation Depth MD (ft): See Schematic 2,980psi 6,880psi 120'120' 2,818' 8,430psi 2,701' Size 120' 2,818' MD 6,512' Length STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Private 223-028 50-133-20711-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: Will perfs require a spacing exception due to property boundaries? 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 Scott Warner, Operations Engineer Ninilchik Beluga-Tyonek Gas scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: 12.6# / L-80 TVD Burst 2,633' m n P s 66 t 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 9:30 am, Apr 22, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.04.19 17:16:44 - 08'00' Noel Nocas (4361) CO 701G SFD Perforate 10-404 DSR-4/23/24SFD 4/29/2024BJM 4/30/24JLC 5/1/2024 Well Prognosis Well: Pearl 10 Date: 4/18/24 Well Name: Pearl 10 API Number: 50-133-20711-00-00 Current Status: Producing Gas Well Permit to Drill Number: 223-028 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 3425 psi @ 7784 TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2647 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .73 psi/ft using 14.0 ppg EMW FIT at the surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.75-0.1) = 2647 psi / 0.63 = 4201 TVD Top of Applicable Gas Pool: 1690 MD/ 1640 TVD Well Status: Online Gas Producer flowing at 1334 mcfd, 5 bwpd, 52 psi FTP Brief Well Summary Pearl 10 is a grass roots well drilled in 2023 targeting the Beluga and Tyonek sands in the southernmost portion of the Ninilchik Unit. Initial perforations were added in the T-146 and came on at 2 mmscfd but has been on steady decline since. The purpose of this sundry is to perforate additional footage in the Tyonek 81-144 sands to increase production. Notes Regarding Wellbore Condition 06/06/2023 Perforated T-146 sand from: 8046-8137 with 2-3/4 guns 09/23/23 D&T w/ 2.5 x 4 DD bailer. Tag fluid @ 8205 SLM. Tag TD @ 9071 SLM. 01/30/24 D&T w/ 2.5 x 2 DD bailer. Tag TD @ 9089 KB (18RKB to GL). Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,000 psi high 3. RIH and perforate Tyonek 81- 144 sands while flowing from bottom up with 2-3/4 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval T-81 ±7,085' ±7,092' ±6,902' ±6,909' ±7' T-81 ±7,120' ±7,130' ±6,937' ±6,947' ±10' T-83 ±7,157' ±7,185' ±6,974' ±7,001' ±28' T-100 ±7,446' ±7,457' ±7,260' ±7,271' ±11' T-115 ±7,546' ±7,557' ±7,359' ±7,370' ±11' T-119 ±7,691' ±7,705' ±7,503' ±7,517' ±14' T-144 ±7,956' ±7,974' ±7,766' ±7,784' ±18' Well Prognosis Well: Pearl 10 Date: 4/18/24 a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating i. RU Cap String Truck ii. Stab 3/8 capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 2500 psi iii. RIH with 3/8 capillary string to ±8300 MD a. Set cap string as deep as practical in fluid iv. Install slips and connect tubing to chemical injection pump v. Set spool of remaining line near well vi. RD cap string Unit, and turn well over to production Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure N2 Operations Updated by CJD 06-15-23 SCHEMATIC Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,071 / TVD = 8,868 TD = 9,138 / TVD = 8,934 RKB to GL = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84 X-56 Weld 15.01 Surf 120 7-5/8" Surf Csg 29.7 L-80 CDC 6.875 Surf 2,818 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958 2,624 9,136 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958 Surf 2,633 4 16 7-5/8 9-7/8 hole 4-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 173 3.613 5.500 SSSV 2 1,525 3.958 4.500 Chemical Injection Sub 3 2,633 4.790 6.340 Seal Stem 4 2,624 4.875 6.540 Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" L 390 sx / T 173 sx 54 bbls cmt to surface 4-1/2 L 503 sx / T 98 sx 43 bbls circulated off liner top (CBL TOC @ 2970; 6/4/23) 6-3/4 hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T146 8,046 8,066 7,855 7,875' 20' 06-06-23 Open 8,072 8,092 7,881 7,901' 20' 06-06-23 Open 8,117' 8,137' 7,926 7,946' 20' 06-06-23 Open T146 Updated by SRW 04-18-24 PROPOSED Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,071 / TVD = 8,868 TD = 9,138 / TVD = 8,934 RKB to GL = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84 X-56 Weld 15.01 Surf 120 7-5/8" Surf Csg 29.7 L-80 CDC 6.875 Surf 2,818 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958 2,624 9,136 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958 Surf 2,633 4 16 7-5/8 9-7/8 hole 4-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 173 3.613 5.500 SSSV 2 1,525 3.958 4.500 Chemical Injection Sub 3 2,633 4.790 6.340 Seal Stem 4 2,624 4.875 6.540 Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" L 390 sx / T 173 sx 54 bbls cmt to surface 4-1/2 L 503 sx / T 98 sx 43 bbls circulated off liner top (CBL TOC @ 2970; 6/4/23) 6-3/4 hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-81 ±7,085' ±7,092' ±6,902' ±6,909' ±7' Proposed TBD T-81 ±7,120' ±7,130' ±6,937' ±6,947' ±10' Proposed TBD T-83 ±7,157' ±7,185' ±6,974' ±7,001' ±28' Proposed TBD T-100 ±7,446' ±7,457' ±7,260' ±7,271' ±11' Proposed TBD T-115 ±7,546' ±7,557' ±7,359' ±7,370' ±11' Proposed TBD T-119 ±7,691' ±7,705' ±7,503' ±7,517' ±14' Proposed TBD T-144 ±7,956' ±7,974' ±7,766' ±7,784' ±18' Proposed TBD T146 8,046 8,066 7,855 7,875' 20' 06-06-23 Open 8,072 8,092 7,881 7,901' 20' 06-06-23 Open 8,117' 8,137' 7,926 7,946' 20' 06-06-23 Open T146 T81-T144 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 Geo Tech 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: 07/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230422 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-26 50283200830000 212050 6/2/2023 AK E-LINE PPROF BRU 222-34 50283201860000 222039 6/14/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 6/17/2023 AK E-LINE Patch Paxton 12 50133207100000 223014 6/7/2023 AK E-LINE Perf PBU 18-29C 50029223160300 209055 6/2/2023 AK E-LINE CBL Pearl 10 50133207110000 223028 6/6/2023 AK E-LINE Perf Pearl 11 50133207120000 223032 6/8/2023 AK E-LINE Perf Please include current contact information if different from above. PTD: 190-042 T37810 T37811 T37812 T37813 T37814 T37815 T37816 T37817 Pearl 10 50133207110000 223028 6/6/2023 AK E-LINE Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.10 13:32:37 -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): Ninilchik Unit GL: 122.2' 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' 7-5/8" L-80 2,702' 4-1/2" L-80 8,932' 4-1/2" L-80 2,528' 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 4-1/2" Tieback SIZE DEPTH SET (MD) LTP @ 2,624' / 2,519' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 2,624' 9,136' 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, Tieback Assy.Tieback TUBING RECORD L - 503 sx / T - 98 sx6-3/4" 2,633' 9-7/8" Driven Surface L - 390 sx / T - 173 sx 12.6# Surface Surface 2,818' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 203196 2225781 50-133-20711-00-00April 12, 2023 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6/6/2023 223-028 / 323-273 LOCI 17-001 Pearl 10April 23, 2023366' FNL, 719' FEL, Sec 23, T1S, R14W, SM, AK 140.2' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2226217 SETTING DEPTH TVD 2226299 TOP HOLE SIZE CBL 6-4-23, Mudlog, XRMI, LWD (DGR, EWR-P4, PWD, DDSR, ALD, CTN) Beluga-Tyonek Gas Pool Private Date of Test: Oil-Bbl: Flowing *** Please see attached schematic for perforation detail *** Gas-Oil Ratio: AMOUNT PULLED 204688 204831 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) Cond N/A N/A 173' MD / 173' TVD 9,138' MD / 8,934' TVD 9,071' MD / 8,868' TVD 186' FSL, 744' FWL, Sec 13, T1S, R14W, SM, AK 271' FSL, 884' FWL, Sec 13, T1S, R14W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 12.6# 2,633' 2,519' Surface 84# 29.7# 120' Water-Bbl: PRODUCTION TEST 6/7/2023 Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 00790 0 6/10/2023 24 Flow Tubing 0 1948 N/A19480 WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:27 am, Jun 16, 2023 Completed 6/6/2023 JSB RBDMS JSB 062023 GDSR-6/28/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval T 146 8,046' 7,855' 826' 819' 1265' 1238' 3895' 3744' 3950' 3798' 3957' 3805' 4477' 4320' 5191' 5027' 6324' 6149' 7328' 7143' 7705' 7517' 8026' 7835' 8692' 8495' 8,978' 8776' 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. Ty 90 Tyonek ST 1 Ty 2 Ty 50 Bel A Bel 136 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 200 Ty 7 Ty 14 Ty 120 Ty 146 Ty 180 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 6.16.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.06.16 07:03:35 -08'00' Monty M Myers Updated by CJD 06-15-23 SCHEMATIC Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,071’ / TVD = 8,868’ TD = 9,138’ / TVD = 8,934’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 7-5/8" Surf Csg 29.7 L-80 CDC 6.875” Surf 2,818’ 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 2,624’ 9,136’ 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 2,633’ 4 16” 7-5/8” 9-7/8” hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 173’ 3.613” 5.500” SSSV 2 1,525’ 3.958” 4.500” Chemical Injection Sub 3 2,633’ 4.790” 6.340” Seal Stem 4 2,624’ 4.875” 6.540” Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" L – 390 sx / T – 173 sx 54 bbls cmt to surface 4-1/2” L – 503 sx / T – 98 sx 43 bbls circulated off liner top (CBL TOC @ 2970’; 6/4/23) 6-3/4” hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T146 8,046’ 8,066’ 7,855’ 7,875' 20' 06-06-23 Open 8,072’ 8,092’ 7,881’ 7,901' 20' 06-06-23 Open 8,117' 8,137' 7,926’ 7,946' 20' 06-06-23 Open T146 Activity Date Ops Summary 4/9/2023 Tore out Pump #1 and HPU skid, scoped down derrick, lowered roof on pit 1, transferred BOP stack to cradle, tore out jig and all three pit mods, offload excess diesel, tore out catwalk, prep and lay over derrick, tore out gen skid, picked choke house and IR off floor, LD windwalls on derrick.;Lowered dog house and tore out same, LD V door windwall, staged cranes and picked derrick off carrier, picked carrier off sub, picked sub off pony walls, transport equipment to pearl pad, crews laid felt liner and set mats for rig;Finish setting mats, spot pony subs over well, set in hydraulic unit in side pony subs, remove eztorque from off drillers side of derrick, change out SRL in derrick, continue transporting equipment and mats, cleaned up felt and liner on Paxton pad Wait on rig movers to transport sub to pearl pad 4/10/2023 Lay last couple rig mats on Pearl 10, CCI on Paxton pad at 07:00 and warming up cranes/trucks. Transported sub base and cranes to Pearl pad. Staged cranes, set sub on pony walls, set carrier on sub, set and pinned derrick on carrier. Stood derrick windwalls, set iron roughneck, stood V door windwall;Set doghouse/water tank, set all three pit mods, set jig, set both pump skids, set HPU skid, raised roof on pit 1, set choke house with crane, scoped up doghouse, set gen skid, set boiler skid, set poorboy degasser skid.;Set centrifuge with crane, hung windwalls, layed out felt/liner and mats for catwalk, set catwalk, folded beaver slide over, set huricane vac, stood mast, set clam shell, reloaded fuel, raised degasser in pits, hook up mod inter-connects, lay felt for Pearl 11.;Lay liner for Pearl 11 and seam tape, lay mats for Pearl 11, clear spot for office trailers, cont loading items at Paxton for transport to Pearl, spot third party shacks, spool up drilling line, hook up lower section of torque tube and pin, scope derrick into drilling position, raise gas buster;Continue Rigging up mud tanks, hang T bar and secure to torque tube, stage top drive on skate, hook up steam lines, stage up boiler temp/psi, get steam goin around rig, hook up Pason system, P/U top drive and attach to blocks, P/U torque bushing and attach to top drive and torque rail;install turn buckles in derrick on torque tube, hook up service loop and kelly hose, Change liners and swabs t/ 5.5'', continue rigging up systems around rig. 4/11/2023 Cont RU on Pearl Pad, Prep office trailers for move from Paxton to Pearl. Sent 24 hr notice to AOGCC for diverter function test. Installed HandyBerm around rig footprint. RD all trailers and shops on Paxton Pad, transported same to Pearl Pad. Set mats for trailers, set office trailers and sleeper.;Set safety shack, change shack and gen trailer, Set shops, Wired in and powered up same. Off loaded mud product, set wear ring and run tool in wellhead, MU DSA and diverter T, MU annular and flow riser, installed flow line. Installed knife valve. Took on water checked surface equipment in pits.;Installed 16" vent line and anchor blocks, pulled measurements on same, started building spud mud. Cont. working through rig acceptance check list. Function tested IR, and MP's. Tested surface lines T/2200 psi. Function tested knife;valve and diverter annular. Added gear oil to TD gear box.;Crew change, held PTSM. cont. R/U , mixing mud and working on rig acceptance check list. R/U catwalk pipe racks. Pulled test plug. Strapped & tallied 4.5" DP on catwalk. M/U Johnny Wacker to joint of DP, singled in the hole, tagged;bottom at 135'. Checked crown-o-matic. Checked TD torque against IR, and tongs. Completed rig acceptance check list and accepted rig @ 04:00 hrs.;Installed rotary table mouse hole. Currently P/U 4.5" DP singles, building stands and racking back in derrick.;Hauled: 0 bbls Solids to KGF G&I Cumulative: 0 bbls Hauled: 0 bbls Fluid to KGF G&I Cumulative: 0 bbls Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Fluid Lost Down Hole: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 4/12/2023 Finished building total 50 stands 4 1/2" DP stands and racked back, stood back 9 stands HWDP and jars, policed rig and location, function tested diverter on jnt of 4 1/2". Quadco Rep on location and checked all audio/visual gas alarms. Set up racks for casing, dusted up spud mud to 8.9 ppg.;AOGCC Rep Kam StJohn on location at 12:00, Function tested knife and annular with 4 1/2" jnt in hole. Performed drawdown, tested gas alarms, measured ventline, functioned PVT's and flow alarms, no issues.;Staged BHA at catwalk. Flooded conductor with 26 bbls spud mud, no leaks. MU 9.875 HDBS PDC to 6 3/4" motor with 1.5 bend (RR bit going in at 1-1), MU IBS, DM, scribed with an RFO of 86.80, MU EWR-M5, TM-HOC, plugged in to download, intermittent comm with TM-HOC. L/D same, C/O inner tool,;PU TM-HOC, plugged in, downloaded no issue. PU one NMDC. Eased in hole one stand HWDP to 118'. MU topdrive.;Broke circ at 400 gpm-1089 psi, 30 rpm-1453 ft/lbs off bott torque, S/O and spudded well at 135'. 1-2K wob, 80 ft/hr ROP. Immediately getting coal back on shakers. Drilled to 150' and coupler on #1 pump liner wash failed. PU off bottom, CBU with pump #2, shut down pumps and rotary.;Replaced liner wash pump coupler on #1 pump.;Resumed drilling ahead from 150' to 178', racked back stand of HWDP, PU second NM flex DC, re-ran 1st stand HWDP. Started drilling/sliding for 3 per/100' for Inc @ 178'. WOB 1-3K, 418 gpm-1305 psi, 30 rpm-1806 ft/lbs on bott torque, 100 ft/hr ROP, MW 8.9/vis 200, ECD's at 9.49 ppg, no gas.;Drilled/sliding ahead T/392'. Racked back 3 stds on HWDP. P/U jar std. RIH and resumed drilling/sliding T/552'. P/U-40K S/O-39K ROT-40K GPM-430 SPP- 1530 psi WOB-1-3K TQ-2/3K Max gas 17 units RPM-30 DIFF-18 MW-8.9 ppg ECD-9.85 ppg.;Crew change. held PTSM. Cont. drilling/sliding F/552' to current depth of 952'. P/U-47K S/O-47K ROT-47K GPM-452 SPP-1820 psi WOB-1-3K TQ-2.5/3K Max gas 91 units RPM-40 DIFF-30 MW-8.9 ppg ECD-9.54 ppg . Distance to well plan: 7.3' 7' High 1.7' Right. 18 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Pearl 10 Ninilchik Hilcorp Energy Company Composite Report Contractor AFE #: AFE $: Job Name:231-00055 Pearl 10 Drilling Spud Date: 4/13/2023 Cont drilling 9 7/8" surface hole from 952' to 1447'. Sliding wob 3-4K 452 gpm-1804 psi, 15 psi diff, 40-100 ft/hr ROP. Rot wob 2-3K, 500 gpm-1542 psi, 60 rpm- 2600 ft/lbs on bott torque, 120 ft/hr ROP, MW 8.9/vis 161 to 217 vis, ECD's at 9.46 ppg, BGG 33 units, max gas 85 units.;Received surface casing, landing joint/hanger, shoe track, B section and packoff.;CBU at 501 gpm-1609 psi, 60 rpm-3300 ft/lbs off bott torque. Obtained survey on bottom. Blew down topdrive. Flow check = static.;Pulled up hole on elevators from 1443' to 366', up wt 58K, S/O and parked at 396'. No issues during trip. Calc hole fill = 9.72 bbls, actual hole fill = 10 bbls.;Serviced rig and topdrive. Completed EAM on draw works brakes.;RIH on elevators from 396' to 1384' with no issue. MU topdrive on last stand, filled pipe, washed to bottom at 1447'. CCI drifting surface casing.;Pumped a 20 bbl hi-vis nutplug sweep around at 512 gpm-1655 psi, 60 rpm-2800 ft/lbs off bott torque. Had 51 units trip gas at bottoms up. Hole unloaded at bottoms up. Sweep back on time with 10% increase in cuttings.;Cont drilling surface from 1447' to 1678', Rot wob 4-5K, 517 gpm-1880 psi, 60 rpm-3700 to 4100 ft/lbs on bott torque, 120 ft/hr ROP. Sliding wob 3-4K, 517 gpm-1746 psi, 53 psi diff, 110 ft/hr ROP. MW 8.9+/vis 172, BGG 22 units, max gas 50 units.;Cont. drilling surface F/1678'-T/2101'. P/U-65K S/O-56K ROT-60K GPM-510 SPP-1900 psi WOB- 4/7K TQ-4.5K Max gas 103 units RPM-60 DIFF-100 MW-9.0 ppg ECD-9.55 ppg.;Crew change, held PTSM. Cont. drilling surface F/2101'-T/2626'. P/U-74K S/O- 62K ROT-68K GPM-520 SPP-2145 psi WOB-7/9K TQ-4.5/5K Max gas 75 units RPM-60 DIFF-135 MW-9.15 ppg ECD-9.8 ppg . Distance to well plan: 2.5' 2.2' Low 1.2' Left. 4/14/2023 Cont drilling 9 7/8" surface hole from 2626' to TD at 2823' md/2706' tvd. Rot wob 4 to 7K, 521 gpm-2180 psi, 60 rpm-5700 ft/lbs on bott torque, 120 ft/hr ROP, MW 9.2/vis 130, ECD's at 9.7+, BGG 22 units, max gas 51 units. At TD: Inc 19.85, Azi 73.47, 3.12' high and 0.86' left of the line.;Sent 48 hr notice to AOGCC for upcoming BOP test.;CBU up 522 gpm-2087 psi, 60 rpm-3560 ft/lbs off bott torque. Racked one stand back and flow checked (very slight seepage). Racked one more stand back and blew down topdrive.;Pulled up hole on elevators and odd breaks, up wt 84K, from 2747' to jars at 395', parked string at 442'. Calc hole fill = 18.4 bbls, actual hole fill = 21.1 bbls.;Serviced rig and topdrive.;TIH on elevators from 442' to 1939' and filled pipe. Cont TIH from 1939' to 2785'. MU topdrive on last stand, filled pipe, washed down to bottom at 2823'. No issues tripping. Calc displacement = 46.6 bbls, actual displacement = 45.4 bbls. Received 390 sacks lead cement in silo.;Pumped a 20 bbl hi-vis nutplug/condet sweep around at 415 gpm-1384 psi, 20 rpm-3484 ft/lbs off bott torque. Hole unloaded at bottoms up with 64 units trip gas. Sweep back on time with maybe 10% increase in clay cuttings. Leveled sub base while circulating shakers clean.;LD top single joint and flow checked (slight seepage). Pulled 5 stands, up wt 80K, then blew down topdrive. Cont POOH on even breaks racking back HWDP, jars and NM flex DC's. Plugged in and uploaded MWD data.;LD smart tools, drained and flushed motor. Re-run PDC graded 2-1 engauge. E-Line on location at 18:30. Cleared catwalk. Cleared and cleaned rig floor.;Spotted e-line unit, held PJSM, RU, MU tool string- multi conductor jar enhancer, multi conductor E-line jars, Gamma telemetry tool, XRMI Navigation-Insite, XRMI Imager-Insite, J-Latch, Cabbage head (total tool length 62.62'). RIH and tagged bottom at 2820' WLM. Logged OH. L/D E-line tools and R/D;and released E-line unit. Cleaned & cleared rig floor and staged BHA #2 on catwalk.;Crew change, held PTSM. P/U & M/U 9-7/8" cleanout assy. - BHA #2. RIH on elevators F/Surface-T/1552' w/ no issues. Filled pipe. P/U-50K S/O-47K.;Cont. RIH F/1552'-T/2805' w/ no issues, P/U & M/U single off walk to string, broke circulation, washed to bottom @ 2823' w/ no fill on bottom. Had calculated pipe displacement for the trip.;Pumped 20 bbl Hi-Vis sweep w/ walnut & condet. Sweep came back on time w/ no increase in cuttings. Circ. & conditioned mud for cement job. Flow checked well (slight seepage). P/U-75K S/O-60K GPM-520 SPP-1283 psi MW-9.15 ppg . Gave Parker casing crew 3 hr. notice.;POOH F/2823' to current depth of 2185'. P/U-75K S/O-60K. 4/15/2023 Cont POOH with cleanout assembly from 2185', racked back HWDP.;LD jars, NM flex DC's, IBS, bit sub and bit. Bit graded a 1-1 and in gauge. Calc hole fill= 24.8 bbls, actual hole fill = 25.4 bbls.;Cleaned and cleared rig floor and catwalk. Drained stack and pulled wear ring. Dummy ran hanger/landing joint. LD same.;RU casing tools and fill up line, staged centralizers and casing, held PJSM with rig crew and casing crew. Updated AOGCC Rep on BOP test time for 4- 16-23.;MU shoe track filling and Baker Locked each joint, stroked pipe and verified floats working. Cont PU single in hole with 7 5/8" CDC casing, torqued to 15,500 ft/lbs, top filling on the fly, topped off every 10 joints. At 1610' MU XO and topdrive.;CBU at 136 gpm-89 to 0 psi, shut down broke off topdrive and XO.;Cont PU single in hole from 1610' to 2787', installed buddy bails on topdrive, installed XO in landing jnt. PU and MU landing joint/hanger, MU topdrive, broke circ at 136 gpm-106 psi and washed down landing hanger with no issues. Down wt 76K, up wt 105K, calc displacement = 28.91 bbls;actual displacement = 19.1 bbls.;CBU staging pump rate up to 252 gpm-130 psi, water on at 10 bph to drop MW from 9.3 to 9.2, stroked pipe 5' every 10 minutes. RD casing tongs and removed from floor. Staged cementers.;Held PJSM on cmt job. Loaded plugs into cement head. Shut down MP's. M/U cmt head to stump. MU plug launcher and hardline, Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 808 psi low 4282 psi high, good tests. Halliburton pumped 60 bbls 10.5;ppg Tuned Spacer at 5 bpm- 160-77 psi, dropped bottom plug and pumped 173 bbls (390 sx) 12 ppg Type I II lead cement at 5 bpm-77- 165 psi, followed by 36 bbls (173 sx) 15.8 ppg Type I II tail cement at 4.5 bpm-165 to 48 psi. Halliburton dropped top plug, then displaced with 9.2 ppg Spud Mud;at 6 bpm 48-680 psi. Slowed pump to 2 bpm with 20 bbl to go. Did bump the plug at 118 bbls into displacement (calculated 125.6 bbls). Held 1093 psi (FCP of 680 psi) for 3 minutes, bled off and floats held. Bled back .5 bbls to truck. Had 60 bbls of Spacer returns to surface and 54 bbls lead cement;to surface. Added Bridge Maker LCM to lead cement at 2.4 pps. Mix water temp 72 deg. Pumped 75% excess on lead cement. Lost 17 bbls throughout the job. Did reciprocate casing. CIP at 21:50 hrs, 4/15/2023. RD and released Halliburton.;Drained & rinsed stack, B/O LJ, R/D buddy bails and casing elevators. Installed DP elevators, M/U Johnny Whacker to E-Kelley and flushed stack and annular w/ black water. Set pack off as per WHR, RILD's. Started N/D diverter system, hauling off spud mud and cleaning tank bottoms.;Crew change, held PTSM. Cont. N/D diverter system and cleaning pits. Gave CCI crane operator 3 hr. notice on picking BOP stack. R/D flow line, flow riser, knife valve, annular preventer, diverter T, and DSA. Cont. to haul off mud and clean tank bottom.;N/U "B" section w/ WHR, tested HPS-seals & void T/3000 psi 15 min (Good).;Spotted crane, picked BOP's from cradle. Transferred BOP's from crane to sub base bridge cranes, set stack on "B" section. Currently N/U BOP's. 4/16/2023 Cont NU BOP stack, drip pan, riser, flow line, choke/kill lines, install 4 way chains. Swap mud pumps to 5" swabs/liners. Transfer 9.0 ppg KCL mud to pits 9-10. Installed koomey lines, charged system and function tested rams etc. Set test plug and MU TIW/dart valves.;Double check nuts on bottom of BOP stack, installed caps on conductor outlets, opened annulus valve, flooded stack, kill/choke lines, choke manifold. Functioned variable rams and bag, purged air. Closed annular and pressured up at 250 psi, then 3500 psi for shell test. Quadco Rep on location at;13:30. Discovered a flange leak between annular and double gate. Bled pressure off stack and koomey unit, start removing lift plate from under annular. AOGCC Rep on location at 13:40. Notified Rep of shell test leak and current ops. Loaded 82 jnts DP on racks.;Tested audio/visual gas alarms, released Quadco Rep, tested PVT's and flow show, finished lift plate removal, tightened flange bolts, installed koomey lines and powered up unit. Shell tested ok. Resumed testing all BOPE at 250 low, 3500 high for 5 min each. Performed draw down test then blinds.;Tested auto and manual chokes on choke manifold. 4 hour test with no failures. Strapped DP during testing.;RD test equipment, blew down surface equipment, broke off TIW and dart from test joint, pulled test plug, set 9" wear ring. RU and re-installed lift plate under annular. Greased choke manifold. Strapped & tallied 82 jts of 4.5" DP on walk. Cont. mixing mud.;M/U mule shoe & dart valve, P/U and singled in the hole w/ 4.5" DP off the walk F/Surface-T/2529'.;Crew change, held PTSM and weekly safety meeting w/ rig crew. POOH racking back 4.5" DP stds. F/2529'-T/Surface. Strapped & tallied an additional 26 jts of 4.5" DP on walk. P/U and singled in the hole F/Surface-T/1076' w/ 4.5" DP. POOH racking back 4.5" DP stds. F/1076'-T/Surface.;Service rig- Greased crown, blocks, TD, DWKS, drive shaft, brake linkage, IR, and wash pipe. Checked pulsation dampeners- MP #1 = 700 psi MP #2 = 800 psi. Checked Mp suction & discharge screens (clean). Finished building 6% KCL PHPA mud.;R/U testing equip. Filled stack, mud lines, and choke manifold w/ water, purged out air. Tested 7-5/8" surface casing test T/3500 psi on chart for 30 min (Good test). R/D tested equip. Pumped in 1.6 bbls Bled back 1.3 bbls. Drained stack, blew down mud lines and choke manifold. R/D test equip at;report time. 4/17/2023 RD test equipment, blew down surface lines and equipment, held PJSM with Sperry DD/MWD.;PU 4 3/4" 1.5 bend motor and MU Baker DD405T PDC jetted with 5 x 11's. MU DM, SP4, ALD, CTN, PWD and TM collars. Scribed at 289.40. Plugged in and downloaded MWD tools, shallow pulse tested and loaded sources. MU NM flex DC's, HWDP and jars to 727'.;Racked and tallied 64 jnts 4 1/2" DP.;PU singled in hole 64 jnts from 727' to 2705', MU topdrive and filled pipe. Up wt 70K, dwn wt 56K, S/O and tagged wiper plugs on depth at 2733'.;Drilled wiper plugs, float collar, 80' shoe track and shoe to 2818', 5' rathole cement to 2823'. Rot wob 2-4K, 200 gpm-1297 psi, 30 rpm-3600 ft/lbs torque, +/- 65 ft/hr ROP.;Drilled new formation from 2823' to 2843'. Rot wob 3-4K, 202 gpm-1141 psi, 28 rpm-3700 ft/lbs on bott torque, 80 ft/min ROP. PU and CBU while holding PJSM on displacing to 6% KCL.Bottoms up sample is sand and claystone at 2843'.;Pumped 20 bbl hi-vis spacer followed with 9.1 ppg 6% KCL PHPA mud. Total pumped = 130 bbls. CBU x2, pull bit back into shoe.;R/U testing equip. Performed FIT to EMW of 14 ppg w/ 688 psi (Good test). R/D testing equip.;Resumed drilling/sliding 6.75" production interval F/2843'-T/2951'. P/U-76K S/O-61K ROT-67K GPM-200 SPP-1080 psi RPM-30 WOB-2/5K TQ-3.5/4K DIFF-246 psi Max gas-64 units MW-9.1 ppg ECD-9.83 ppg.;Crew change, held PJSM. Cont. drilling/sliding 6.75" production interval F/2843' to current depth of 3360'. P/U-79K S/O-71K ROT-74K GPM-258 SPP-1401 psi RPM-60 WOB-2/5K TQ-4K DIFF- 165 psi Max gas-89 units MW-9.1 ppg ECD-10.11 ppg. Distance to well plan: 5.7' 5.5' High 1.5' Left. 4/18/2023 Cont drilling 6 3/4" hole from 3360' to 3790', rot wob 5K, 257 gpm-1460 psi, 50 rpm-4340 ft/lbs on bott torque, 120 ft/hr ROP. Sliding wob 2-3K, 255 gpm-1500 psi, 255 psi diff, 72 ft/hr ROP. MW 9.1/vis 61, ECD's at 10.2 ppg, BGG 120 units, max gas 355 units. P/U 83K, S/O 73K, ROT 76K.;SPR's @ 3500' MD, 3360' TVD. MP#1 SPM 46 PSI 476, MP#2 SPM 46 PSI 472.;Continue Drilling 6-3/4" Production section F/ 3790' T/ 3880' MD GPM 255, SPP 1500psi, RPM 50, TQ 4.5K, WOB 5K, ECD 10.2ppg, Max gas at 125 units. MW in 9.1 MW out 9.1 P/U 87K, S/O 73K, ROT 80K with pumps on. CBU and monitor well, Static. B/D Top Drive.;POOH F/ 3880' T/ 2828' with no overpulls observed. P/U 100K S/O 70K. Calculated pipe displacement: 7.82 BBLs, Actual: 7.6 BBLs.;Grease Crown, Blocks, Top Drive, Draworks and Drive Shaft. Inspect Brake bands and Brake Linkage.;RIH F/ 2828' T/ 3880' filling pipe and washing last stand down with no set downs and no fill. P/U 100K S/O 70K. Calculated displacement: 19.52 BBLs. Actual: 18.9 BBLs.;Send Hi-Vis Sweep and return to surface on time with a 50% increase in cuttings containing sandy clay.;Continue Drilling 6-3/4" Production section F/ 3880' T/ 4381' MD GPM 255, SPP 1500psi, RPM 50, TQ 4.8K, WOB 5K, DIFF 255 psi MW 9.2 ppg ECD 10.2ppg, Max gas at 617 units. MW in 9.1 MW out 9.1 P/U 95K, S/O 80K, ROT 86K with pumps on. Pumped sweep @ 4381', sweep came back 6 bbls;early w/ a 40% increase in cuttings.;Crew change, held PJSM. Cont. drilling/sliding 6.75" production interval F/4381' to current depth of 4825'. P/U-99K S/O-86K ROT-94K GPM-258 SPP-1650 psi RPM-60 WOB-5/7K TQ-5.5K DIFF-280 psi Max gas-259 units MW-9.2 ppg ECD-10.27 ppg. Distance to well plan: 1.3' .2' High 1.2' Right. 4/19/2023 Continue Drilling 6-3/4" Production section F/ 4825' T/ 4936' MD GPM 255, SPP 1635psi, RPM 50, TQ 5.1K, WOB 5K, ECD 10.23ppg, Max gas at 108 units. MW in 9.2 MW out 9.25 P/U 102K, S/O 91K, ROT 95K with pumps on.;Circulate Bottoms Up and obtain SPRs @ 4930' MD 4775' TVD MP#1 46 SPM 475psi, MP#2 46 SPM 471psi. Shoot survey @ 4930' MD. Flow check well. No flow. B/D Top Drive.;POOH F/ 4936' T/ 3880' with no issues. P/U 110K S/O 87K Calculated hole fill: 6.9 BBLs. Actual 5.74 BBLs. P/U 110K S/O 87K.;Service Blocks, Top Drive, Iron Roughneck, Draworks, Gear Box, Drive Line, Floor Motor and Brake Linkage. Clean Mud Pump suction screens, Both were 75% full of clay. Monitoring well on trip tank with no gains or losses.;RIH W/ 6-3/4" Triple Combo BHA F/ 3880' T/ 4936' with no set downs or fill. Calculated Displacement: 28.74 BBLs. Actual Displacement: 15.64 BBLs. P/U 110K S/O 87K.;Fill pipe & send 20 BBL Hi-Vis sweep & Continue Drilling 6-3/4" Production section F/ 4936' T/ 5061' MD GPM 255, SPP 1520psi, RPM 50, TQ 5.5K, WOB 8K, ECD 10.30ppg, Max gas at 71 units. MW in 9.2 MW out 9.25 P/U 108K, S/O 98K, ROT 88K with pumps on. Sweep came back 6-1/2 BBLs early w/ 25% increase.;Drilling 6-3/4" Production section F/ 5061' T/ 5865' MD P/U-121K S/O-98K ROT-108K GPM-255 SPP-1850 psi RPM-50 WOB-6K TQ-6K DIFF-350 psi Max gas-332 units MW-9.3 ppg ECD-10.43 ppg. Pumped Hi-Vis sweep w/ walnut & condet @ 5431', sweep came back on time w/ a 25% increase in cuttings.;Crew change, held PJSM. Cont. drilling/sliding 6.75" production interval F/4381' to wiper depth of 6049'. P/U-124K S/O-103K ROT-112K GPM-256 SPP-1820 psi RPM-50 WOB-7K TQ-6.3K DIFF-377 psi Max gas-241 units MW-9.3 ppg ECD-10.51 ppg. Distance to well plan: 1.4' .2' High 1.4' Left;Circ. till shakers cleaned up, shot on bottom survey. Obtained new set of SPR's. Flow checked well (slight seepage). GPM-255 SPP-1500 RPM-70 MW- 9.3 ppg ECD- 10.45 ppg Max gas- 105 units.;POOH on elevators F/6501'-T/2804' with no issues. Had calculated hole fill for the trip. Currently cleaning rig floor and prepping to service rig. 4/20/2023 Service Blocks, Top Drive, Iron Roughneck, Draworks, Gear Box, Drive Line, Floor Motor and Brake Linkage. Clean MP#1 & MP#2 suction screens. Monitor well on trip tank with no gains or losses.;RIH with 6-3/4" Directional Triple Combo F/ 2800' T/ 6049' filling pipe and washing last stand down with no fill encountered or any set downs on trip. Calculated Displacement: 46.36 BBLs Actual Displacement: 45.20 BBLs. P/U 130K S/O 110K;Drill 6-3/4" Production section F/ 6049' T/ 6266' MD GPM 260, SPP 1830psi, RPM 50, TQ 6.2K, WOB 7K MW in 9.3 MW out 9.35 ECD 10.37ppg, Max gas at 422 units P/U 126K, S/O 105K, ROT 115K. Pumped sweep @ 6049', BU came back with 100% increase and sweep came back on time with 50% increase.;Drill 6-3/4" Production section F/ 6266' T/ 6630' MD GPM 255, SPP 2025psi, RPM 70, TQ 7.6K, WOB 7K MW in 9.4 MW out 9.45 ECD 10.64ppg, Max gas at 300 units P/U 135K, S/O 106K, ROT 117K. SPRs@ 6545' MD 6357' TVD MP#1 48 SPM 633psi. MP#2 46 SPM 608psi.;Hi-Vis Sweep that was pumped at 6614' came back on time with 30% increase in cuttings.;Cont. drilling/sliding 6.75" production interval F/6630'-T/6979'. P/U-144K S/O-111K ROT-125K GPM-260 SPP-1930 psi RPM-70 WOB-7K TQ-7.8K DIFF-315 psi Max gas-851 units MW-9.4 ppg ECD-10.54 ppg;Crew change, held PJSM. Cont. drilling/sliding 6.75" production interval F/4381' to wiper depth of 7163'. P/U-148K S/O-115K ROT-129K GPM-257 SPP-1950 psi RPM-70 WOB-7K TQ-8.1K DIFF-370 psi Max gas-342 units MW-9.4 ppg ECD-10.48 ppg. Distance to well plan: 1.6' .4' High 1.5' Left;Circulated till shakers cleaned up, obtained new SPR's, flow checked well (static). P/U-145K S/O-118K ROT-128K GPM-256 SPP-1522 psi;POOH on elevators F/7163'-T/5990'. P/U-158K S/O-125K. Had discrepancy in hole fill (swabbing). Flow checked well (static).;CBU GPM-257 SPP-1376 psi RPM-70. 1100 stks in BU flow climbed F/21%-T/35%. Spaced out, shut down rotation, shut down MP, shut in UPR, ISICP=390 psi, climbed T/643 psi in 6 min. Choke was lined up through MGS. Brought on MP at idle 46 SPM, held casing pressure;constant with electric choke-570 psi. Currently circulating out gas through MGS. 4/21/2023 Well was shut in @ 05:23 and well was lined up through MGS to remove gas that was swabbed in. Brought pumps up T/ 112 GPM with 530 psi ICP, Casing pressure was held constant @ 643 psi. Circulated STS through MGS. Shut pump down and DP pressure was 145psi and Casing pressure was;85psi. Monitored for pressure increase.and bled off casing pressure to 51psi and monitored for pressure increase. With no pressure increase observed. Bled off casing and stand pipe pressure to Zero and monitored for 20 minutes with no flow from DP or Casing. Received approval to open well;Open UPRs and close Choke HCR.;RIH F/ 6023' T/ 7099' with no issues whatsoever. Calculated displacement: 20.74 BBLs Actual displacement: 15.2 BBLs;Close UPRs and open Choke HCR, Open electric choke to CBU through MGS @ 113 GPM W/ SPP at 600psi to 560psi. No gas returns observed. B/D Choke and Kill lines. B/D Choke Manifold and suck out MGS.;Fill Pipe and send 20BBLs Hi-Vis sweep that came back 4.6 BBLs early with 25% increase. Continue Drilling 6-3/4" Production section F/ 7163' T/ 7227' GPM 245, SPP 1390psi, RPM 65, TQ 8.5K, WOB 8K MW in 9.4 MW out 9.45 ECD 10.34ppg, P/U 155K, S/O 125K, ROT 133K;Max gas at 1671 observed while reaming back to bottom at 7163'.;Drill 6-3/4" Production section F/ 7227' T/ 7535' MD GPM 257, SPP 1950psi, RPM 70, TQ 8.1K, WOB 7K MW in 9.6 MW out 9.55 ECD 10.55ppg, Max gas at 353 units P/U 156K, S/O 117K, ROT 131K.;Notification to AOGCC Jim Regg of BOPE Usage @13:30 via telephone. Send AOGCC BOPE USAGE REPORT to aogcc.reporting@alaska.gov and CC Jim Regg @ 14:46.;Cont. drilling/sliding 6.75" production interval F/7535'-T/7755. P/U-163K S/O-120K ROT-137K GPM-257 SPP-2000 psi RPM-70 WOB-5.5K TQ-8.1K DIFF-370 psi Max gas-454 units MW-9.6 ppg ECD-10.55 ppg. Pumped Hi- Vis sweep w/ walnut & condet @7661', sweep came back on time w/ a 30% increase in cuttings.;Crew change, held PJSM. Cont. drilling/sliding 6.75" production interval F/7755' to current depth of 8063'. P/U-165K S/O-123K ROT-141K GPM-258 SPP-2072 psi RPM-70 WOB-7K TQ-8.5K DIFF-318 psi Max gas-566 units MW-9.6 ppg ECD-10.63 ppg. Distance to well plan: 9.5' 8.7' Low 3.8' Left 4/22/2023 Drill 6-3/4" Production section F/ 8063' T/ 8159' MD GPM 260, SPP 1990psi, RPM 70, TQ 8.4K, WOB 8K MW in 9.6 MW out 9.6 ECD 10.62ppg, Max gas at 779 units P/U 165K, S/O 123K, ROT 141K.;CBU while rotating and reciprocating pipe. P/U 170K S/O 126K ROT 144K, Obtain SPRs @ 8149' MD 7960' TVD MW 9.6ppg MP#1 46 SPM 667psi MP#2 46 SPM 651psi. Flow check: Slight seepage.;POOH F/ 8159' T/ 7150' with no overpulls. Calculated Fill: 7.36 BBLs Actual Fill: 6.9 BBLs P/U 180K S/O 132K.;Service Crown, Blocks, Top Drive, Iron Roughneck, Draworks, Gear Box, Floor Motor and Brake Linkage. Inspect Draworks Eaton Brake. Change out selector switch for Top Drive Rotation on Drillers Console. Monitor Well on Trip Tank with 1/2 BPH losses.;RIH F/ 7150' T/ 8159' with no set downs or fill. Calculated Displacement: 18.3 BBLs Actual Displacement: 15.1 BBLs. P/U 180K S/O 132K;Fill Pipe, Pump 20 BBL Hi-Vis sweep @ 8159' Drill 6-3/4" Production section F/ 8159' T/ 8447' MD GPM 260, SPP 2025psi, RPM 70, TQ 9.5K, WOB 7-10K MW in 9.65 MW out 9.7 ECD 10.73ppg, Max gas at 264 units P/U 168K, S/O 126K, ROT 144K.Sweep came back 3 BBLs early W/ 25% increase in cuttings.;Cont. drilling/sliding 6.75" production interval F/8447'- T/8686'. P/U-180K S/O-128K ROT-150K GPM-260 SPP-2074 psi RPM-70 WOB-5/7K TQ-9.6K DIFF-380 psi Max gas-200 units MW-9.6 ppg ECD-10.69 ppg. Pumped Hi-Vis sweep w/ walnut & Condet @ 8653'.;Crew change, held PJSM. Cont. drilling/sliding 6.75" production interval F/8686'. Sweep came back on time w/ a 25% increase in cuttings. Current depth at report time 8890'. P/U-182K S/O-132K ROT-153K GPM-258 SPP-2030 psi RPM-70 WOB-7K TQ-9.5K DIFF-330 psi Max gas-84 units;MW-9.6 ppg ECD-10.58 ppg. Distance to well plan: 20.1' 2.8' Low 19.9' Left 4/23/2023 Drill 6-3/4" Production section F/ 8890' T/ 9138' MD GPM 260, SPP 2075psi, RPM 65, TQ 9.7K, WOB 7K MW in 9.6 MW out 9.6 ECD 10.67ppg, Max gas at 91 units P/U 182K, S/O 133K, ROT 153K. Obtain Survey & SPRs @ 9138' MD 8934' TVD MP#1 46 SPM 734 PSI MP#2 46 SPM 707 PSI.;Sent notification @ 07:50 to AOGCC for witnessing test of BOPE components used for closing well on 4/21/23 @ 05:23am. Directionally we are Bit projected at 10.51 Inc. 48.18 Az Distance: 41.10' from wp05. 15.74' High and 37.96' Left.;CBU @ 260 GPM with 1750 PSI Reciprocating and Rotating @ 65 RPM. Flow Check Well. Static. B/D Top Drive.;POOH F/ 9138' T/ 2818' with no issues. Calculated Hole Fill: 46.46 BBLs Actual Hole Fill: 46.4 BBLs. DIFF .06 BBLs P/U 200K S/O 140K.;Monitored well on TT, static loss rate= 1.1 bph. Rig service- Greased blocks, crown, DWKS, TD, wash pipe, IR, brake linkage, and drive shaft. Performed weekly BOP component functions- annular, UPR, LPR, HCR kill, and HCR choke.;Slip & cut drill line for a total of 21 wraps = 97'. Recalibrated hook load, set crown-o- matic.;RIH on elevators F/2824'-T/5921' at 30-40 fpm, filling pipe every 1500', and circ. string volume. P/U-130K S/O-90K Performed kick while tripping drill.;Crew change, held PTSM and weekly safety meeting on well control. Cont. RIH F/5921'-T/9086' at 30-40 fpm w/ no issues. Broke circ. Washed last std. to bottom w/ no fill. Pipe displacement- Cal Disp.= 124.44 bbls Act Disp.= 101.08 bbls DIFF.= 23.36 bbls;CBU, had 100% increase in cuttings at BU, mostly coal, w/ sand, clay, and super fines. GPM-233 SPP-1537 psi RPM-60 MW-9.7 ppg ECD-10.45 ppg Max gas 1432 units. Pumped 20 bbl Hi-Vis sweep w/ walnut, and condet. Sweep came back 5.7 bbls late w/ a 10% increase in cuttings.;Blow down TD. Currently performing 10 min flow check 4/24/2023 Complete Flow-Check. Static. POOH F/ 9138' T/ 2700' with no issues during trip and pulling through 7-5/8" Shoe. P/U 200K S/O 140K. Calculated Hole Fill: 50.6 BBLs Actual Hole Fill: 50 BBLs.;Continue POOH F/ 2700' T/ 755'. Flow Check well: Slight seepage. P/U 75K S/O 65K. Continued Total Calculated Hole Fill: 74.06 BBLs Actual Total Hole Fill: 74.14 BBLs.;POOH standing back HWDP, Jars and Flex Collars. PJSM, Unload sources, Download Data, B/O and L/D TM Collar, PWD, CTN, ALD, SP4, DM Collars, B/O, L/D Bit and Motor. Static loss rate while downloading MWD was .8 BBL per hour via trip tank. Bit graded a 1- 1.;Pull wear bushing & clean stack with fresh water pumping through Stack Washer. Install test plug with 4-1/2" Test joint & Test Kill HCR, UPRs (2-7/8" X 5" VBRs), CMV's 1, 2, 8, 14 & E-Choke T/ 250psi low 3500psi High for 5 minutes each on test chart. Install 9" ID Wear Ring. Function Blind Rams.;Cleaned & cleared rig floor. Spotted & R/U HES E-line unit. Held PJSM w/ E-line personal and rig crew. M/U E-line logging tools - Releasable wireline head, multi conductor jars enhancer, standard transmitter, standard isolator, wave receiver section-offset dipole, wave lower electronic - insite,;centralizer - 25" body, XRMI navigation- insite, XRMI imager - insite, J latch 3.65" OD, and hole finder. Total length = 98.26'. RIH w/ HES E-line tagged bottom @ 9124' WLM. POOH logging OH @ 30 fpm = 1800' fph. Seen slight set down @ 5460' (coal). Rig crew worked on housekeeping and cleaning.;Crew change, held PTSM. Cont. OH logging on HES E- line. Pulled tight and hung up @ 5536'. Worked wire multiple times firing E-line jars. Worked P/U weight F/2100 lbs. to max P/U of 12,000 lbs. freed logging tool. Resumed logging OH. Lost communications to pad #2 on IRMI-I Mandrel tool.;R/D HES E-line logging tools, and unit. Released HES E-line. Static loss rate during logging = .4 bph.;M/U 6.75" cleanout assy. - BHA #4. RIH F/Surface to current depth of 1792'. P/U-52K S/O-48K 4/25/2023 Continue RIH with 6-3/4" Cleanout assembly BHA #4 F/ 1792' T/ 3085' with no issues. P/U 52K S/O 48K;Fill pipe and CBU at 200 GPM W/ SPP of 275psi.;Continue RIH with 6-3/4" Cleanout assembly BHA #4 F/ 3085' T/ 5250' with no issues. P/U 110K S/O 95K;Fill pipe and CBU at 206 GPM W/ SPP of 425- 510psi.;Continue RIH with 6-3/4" Cleanout assembly BHA #4 F/ 5250' T/ 9069' with no issues. P/U 165K S/O 125K;Fill pipe, Obtain circ, Ream back to bottom F/ 9069' T/ 9138' at 259 GPM w/ 950-1050psi RPM 50 TQ 9-15K & CBU at 277 GPM W/ SPP of 1000psi. BU came back on time with 100% increase in coal cuttings. Sent Hi-Vis sweep, Came back 8.7 BBBLs late w/ 10% increase P/U 163K S/O150K R 156K. Max Gas 167units.;Flow Check Well: Static. POOH F/ 9138' T/ 2568' Drop 2.37" Drift with 80' of slickline at 3720'.;Slip and cut drilling line 10 wraps 45' static loss rate .6 bph;POOH f/ 2568' t/ 625' flow check well static;L/D BHA HWDP Collars and Jars, L/D stab and bit Calc. Hole fill 72.32 bbls Act 73.9 bbls;R/U Parker TRS, PJSM, P/U shoe Jt, and RIH, P/U float collar Threads on top of Float jt is JFE Lion, Threads on Float collar BTC No crossovers or thread combinations on location, send off jts t/ be recut, R/D Parker TRS;M/U Clean Out BHA as per Haliburton RIH t/ 1855' 4/26/2023 POOH F/ 1855' T/ 600' Standing back 4-1/2" DP. Monitor Well before pulling BHA into stack. Losses at 1/2 BPH.;Lay down 11 jts. HWDP and observed Jars were cocked. Ran 2 stands of drill pipe back in hole. M/U TD and pumped at 400 GPM and shut down pumps and allowed jars to release. Complete L/D Jars, HWDP, Stabilizer and Bit. Calculated Hole Fill: 19.64 BBLs Actual Hole Fill: 19.1 BBLs;Service Blocks, Top Drive, Iron Roughneck, Draworks, Gear Box, Drive Line, Floor Motor, Brake Linkage and Catwalk.;R/U Parker TRS equipment on floor. Bring centralizers needed for run to floor, Assemble Floor Valve and crossovers, Hydraulic Tongs. Rig up fill-up line while monitoring well on trip tank @ 1/4 BPH loss rate.;PJSM for running 4-1/2" 12.6# L-80 Range II JFE-LION Liner assembly. P/U and M/U shoe track and test floats. Good test. Continue RIH w/ 4-1/2" Liner F/ 96' T/ 6455' monitoring well on trip tank. P/U 93K S/O 68K, M/U Liner hanger as per baker rep, Mix pal Mix and crossover to DP;Circulate and condition mud, stage pumps t/ 5 bpm 400 psi;Continue RIH w/ 4.5'' Liner on 4.5'' DP f' 6950' t/ 9138' wash last stand to bottom;Circulate and condition mud f/ cement job stage pumps t/ 5 bpm 815 psi, R/U cement equipment and blow through cement hoses, 4/27/2023 Continue circulating while cementers rig up. P/U 127K S/O 96K. B/O and L/D E-Kelly joint. P/U and M/U cement head/ Hoses and Iron on rig floor.;PJSM, With all personnel involved in cement job. Pump 5 BBLs of water to flush lines. PT Lines from cementer T/ 550 psi. low and 4800 psi high. Good Test. Bleed psi off and batch up. Pump 30 BBLs of 10.5ppg Tuned Prime Spacer @ 4 BPM w/ 730psi. Pump 503 sks of lead cement;12.00ppg 2.39FT/ Sk 14.07GL/ SK with 2 PPSK Bridge Maker in Lead cement. Pumped a total of 213 BBLs at 5 BPM w/ 615 psi. Pump 98 SKS of Tail cement at 15.30lb/ Gl 1.24Ft/ Sk 5.58 Gl/ Sk Pump a total of 21.5 BBLs at 3 BPM w/ 135 psi. Wash pumps and lines by pumping across top of;Cement head with a total of 15 BBLs of H2O to cuttings box. Launch DP wiper dart with witness of DSM. 24 BBLs of displacement caught DP Wiper dart. 33 BBLs into displacement seen DP Wiper dart latch liner wiper plug. Pump 134 BBLs of 9.7ppg mud at 5 BPM w/ 85 psi. Slow rate at 100 BBLs;into displacement to 3 BPM w/ 1540 psi. Slow rate at 124 BBLs into displacement to 2 BPM w/ 1800psi. Bumped Plug at 2100 psi. and pressured up to 2500 psi. Check floats, Bled back 1 BBL. Good floats. Pressure up to 2450 psi. and confirm liner set. Pressure up to 4029 psi and observed Packer;set at 3638 psi Stack 50K weight down on Packer and confirm Packer set. Bleed off pressure to HES unit. Unable to open upper TIW valve on cement head. Break off and L/D cement head and M/U Top Drive to 15' DP pup. Pressure up to 500 psi and release pack-off increase pump speed to 12 BPM;w/ 875 psi. circulate 3X bootoms up from top of liner. Returned back 30 BBLs Tuned Spacer and 43 BBLs of 12.0ppg Lead Cement. CIP @ 10:52. Pull stinger from assembly and CBU X3;Complete cleaning top of liner and casing at 354 GPM w/ 357 psi.;POOH W/ Liner running tool F/ 2583' T/ Surface break running tool in half and L/D.;M/U stack washer, Drain stack and wash stack with Black Water solution at 112 GPM w/ 0 psi. P/U Cement head and break down. Clean and Clear rig floor.;P/U and M/U Polish Mill Assembly.;RIH with polish mill F/ 20' T/ 2636' dress off top of liner;Displace well with Corrosion Inhibited Water, Monitor well f/ 30 min well static,;POOH L/D DP f/ 2615' to surface, dress off mill showed good indication of liner top;RIH f/ Surface t/ 2470' 40 stands, POOH L/D DP;Rig Up and test Liner top packer to 3500 psi f/ 30 min good test< R/D test equipment;RIH f/ DP f/ surface t/ 2511' POOH L/D DP t/ 1100' 4/28/2023 POOH and L/D Drill Pipe F/ 1100' T/ Surface. RIH with remaining DP T/ 1027', POOH and L/D remaining 32 joints of Drill Pipe.;Clean and Clear rig floor. Pull 9" ID Wear Ring.;Rig up Parker TRS equipment for running 4-1/2" 12.6# L-80 Range II JFE-LION Tie-Back assembly.;PJSM, RIH W/ 5-3/4" Bullet Seal assembly and 4-1/2" JFE-LION Tubing F/ 16' T/ 1086'.;R/U Pollard control line spoolers.;P/U and M/U Chemical Injection Mandrel assembly and connect control line to mandrel. Pressure Test Control line T/ 2000psi F/ 10 minutes. Good Test. Bleed line pressure down to 1000psi. and cont. RIH.;Continue RIH with 4-1/2" 12.6# L- 80 Range II JFE-LION Tubing F/ 1121' T/ 2445' banding control line to Tubing. P/U and M/U ONYX SSSV assembly. Connect control line and pressure test line T/ 5000psi. F/ 10 minutes. Good Test. Function SSSV open and closed two times opening at 1800psi.;Pressure up T/ 5000psi. and lower in hole. Physically observe valve open. Continue RIH F/ 2462' and Locate PBR and No-Go on Joint # 288 with 12' in at 2634.28'. L/D Jts. 288 & 287. P/U XO pup, 10' IBT & 8' IBT pup. M/U hanger and terminate control lines and feed through hanger.;Secure control lines and land hanger at 2632.96' 1.35' off of No-Go. P/U 50K S/O 45K. Total of 105 Stainless Steel Bands.;RILDS, pull landing jt, R/U and test tubing t/ 3500 psi f/ 30 min pumped 1.64 bbls in bled back 1.6 bbls R/U and test IA t/ 3500 psi f/ 30 min pumped in 1.15 bbl bled back .7 bbls install TWC;Flush through mud pumps, mud lines, choke manifold and gas buster w/ bara clean soap pill;Open ram doors and perform monthly inspection on ram cavities, close doors, remove koomey lines, pull suction lines on pumps and clean out;N/D flow line and riser, pull flow box, remove choke and kill lines, hook up bridge cranes and unbolt stack and remove from wellhead, clean ring grove and seals, set in dry hole tree and tighten bolts, test void, neck seals and tree t/ 5000 psi f/ 15 min each;Remove bails on top drive and disconnect service loops, install mix pump in pit 2, R/D mud pump #1 and #2 change swabs and liners t/ 5.5'' Change AFE to Pearl 11 @ 0600 hrs Activity Date Ops Summary 6/3/2023 Travel to Susan Dionne.,PJSM & permits for Fox CT / Fox N2 / Cruz crane / Cruz water transport / Cruz vac truck / Rain for Rent.,Travel to Pearl pad.,Spot & rig up. 1st load of 130 BBL's water from Kelotsa arrived.,Pressure test BOPE. AOGCC witness was waived by Jim Regg via e-mail 6/2/2023.,2nd delivery of 130 BBL's water arrived. Transferred to Rain for Rent tank. Total of 260 BBL's water on stand by.,Secure equipment.,Return to base. Plan forward to begin CT circulating out drilling fluids in morning. 6/4/2023 Travel to Susan Dionne.,PJSM & permits.,Travel to Pearl pad.,Stand up injector. Install CT connector. Pull test 15k and 30k. Test good.,Install YJ BHA consisting of: Dual flapper Check Valve, Disco, X-over and 2.875" Down Jet Nozzle.,Stab lubricator and injector on to BOPE. Fill CT with 24.5 BBL's fresh water.,Pressure test lubricator 250 / 3000 PSI. Test good.,Run in hole w/ YJ BHA.,Pick up weight at 8800' at 24K. Slowly go down hole till tagged fill at 9092' CTM zeroed at BOPE. Pick up to 9087'. Line up pump.,Injecting down CT taking returns to Rain for Rent tank at 1-3/4 BPM at 3800 PSI.,35 BBL's away. Returns are dark kill fluid.,57 BBL's away. Begin pulling out of hole slowly while circulating.,OOH. 180 BBL's total of fresh water circulated out of well. (140 BBL capacity). Returns are clean. Break off jet nozzle. Make up Halliburton memory tool. Stab back on.,RIH w/ Halliburton memory tool. Timer set to engage at 16:05. Schedule to start logging at 16:15. Hung off standing by at 9094' CTM.,(16:15) Start POOH logging at 40 FPM.,At 2300' (Liner at 2624'). Made 5 minute stop. Logging complete. POOH at 100 FPM,OOH. Break off Halliburton memory tools. Lay down injector, lubricator and crane. Night cap well. Secure equipment.,Return to base. 6/5/2023 Travel to Susan Dionne.,PJSM & permits.,Travel to Pearl pad.,R/D and move mud pump. Change stripper rubber in injector.,M/U reverse out YJ BHA consisting of 2-1/8" Reverse Nozzle, 5' Mandrel, CT Connector.,RIH w/ YJ BHA. On bottom at 9079' CTM.,Hammer up N2 lines. Cooling down N2.,PT N2 injection lines 500 / 4000 PSI. Test good.,Inject N2 down backside and up CT at 935 PSI / 500 scf. Immediate returns of water to Rain for Rent tank.,52 BBL's recovered. 1500 PSI / 1200 scf.,73 BBL's recovered. 2450 PSI / 1500 scf.,90 BBL's recovered. 2850 PSI / 1500 scf.,110 BBL's recovered. 3270 PSI / 1500 scf.,156 BBL's recovered. N2 returned to surface. Well is dry. POOH.,OOH. Lay down injector and lubricator. Install night cap. Secure well and equipment.,Return to base. Plan forward: Will pull BOPE stack in morning and swing directly on to Pearl 11 to perform same job as Pearl 10. AK E-Line to be out in morning as well to perforate Pearl 10. 6/6/2023 AK E-Line travel direct to Pearl pad.,PJSM and permit. SIMOPS w/ Fox CT on Pearl 11.,Rig up AK E-Line,,PT 500 / 3000 PSI. Test good.,RIH w/ 20' x 2-3/4" Gun ONE to shoot T-146 zone at 8046' to 8066'. CCL to TS = 9' / CCL depth will be 8037' + 9' to place top shot at 8046'.,Correlation pass made. Send log to town for approval.,Town approved log. Current tubing PSI 1695. Town requested 1350 PSI. Bled tubing down to 1356 PSI.,Fire Gun ONE perforating T-146 zone at 8046' to 8066'. POOH. Start PSI 1356 / 5 Min 1373 / 10 Min 1392 / 15 Min 1396 / 20 Min 1408 / 25 Min 1422.,OOH. Lay down Gun ONE. All shots fired. Pick up Gun TWO and stab back on well.,RIH w/ 20' x 2-3/4" Gun TWO to shoot T-146 zone at 8072' to 8092'. CCL to TS = 9' / CCL depth will be 8063' + 9' to place top shot at 8072'.,Correlation pass made. Send log to town for approval. Town approved log.,Fire Gun TWO perforating T-146 zone at 8072' to 8092'. POOH. Start PSI 1723 / 5 Min 1756 / 10 Min 1768 / 15 Min 1779 / 20 Min 1788 / 25 Min 1798.,OOH. Lay down Gun TWO. All shots fired. Pick up Gun THREE and stab back on well.,RIH w/ 20' x 2-3/4" Gun THREE to shoot T-146 zone at 8117' to 8137'. CCL to TS = 9' / CCL depth will be 8108' + 9' to place top shot at 8117'.,Correlate & position gun. Fire Gun THREE perforating T-146 zone at 8117' to 8137'. POOH. Start PSI 1920 / 5 Min 1946 / 10 Min 1953 / 15 Min 1956 / 20 Min 11962 / 25 Min 1967.,OOH. Lay down Gun THREE. All shots fired.,RDMO AK E-Line. Move unit and equipment to Paxton 12. Return to base. Plan forward: Paxton 12 single gun run for T-120 zone. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Pearl 10 Ninilchik Hilcorp Energy Company Composite Report Contractor AFE #: AFE $: Job Name:231-00055 Pearl 10 Completion Spud Date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enjamin Hand Digitally signed by Benjamin Hand Date: 2023.04.26 11:20:53 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2023.04.27 15:20:40 -08'00' TD Shoe Depth: PBTD: Jts. 2 67 Yes X No X Yes No 5 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Type I II 390 2.44 Type I II 173 1.16 5 21.66 Hanger 16 CDC Cactus 1.61 21.66 20.05 2,735.45 24.87 Pup Jnt 7 5/8 29.7 L-80 CDC USS 3.21 24.87 1.30 2,736.75 2,735.45 Casing 7 5/8 29.7 L-80 CDC USS 2,710.58 Float Collar 8 5/8 BTC Innovex Every Other Joint Up to 345' Casing 7 5/8 29.7 L-80 BTC USS 79.94 2,816.69 2,736.75 www.wellez.net WellEz Information Management LLC ver_04818br 4.5 Type of Shoe:Bullnose Casing Crew:Parker 12 173 2,818.212,823.00 2,735.45 CEMENTING REPORT Csg Wt. On Slips:60,000 Spud Mud 21:50 4/15/2023 0 15.8 36 Bump press Visual Bump Plug? 118/125.6 1093 255 HES FI R S T S T A G E 10.5Tuned spacer 60 9.2 6 96.7 680 Csg Wt. On Hook:75,000 Type Float Collar:Innovex No. Hrs to Run:6.5 BTC Innovex 1.52 2,818.21 2,816.69 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Pearl 10 Date Run 15-Apr-23 CASING RECORD County State Supv.R Pederson / J Richardson 2,735.45 Floats Held Spud Mud Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 2818.21 FC @ Top of Liner Casing (Or Liner) Detail Shoe 8 5/8 TD Shoe Depth: PBTD: Jts. 1 1 1 1 1 105 1 1 Yes x No Yes x No Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Shoe 5 Rotate Csg Recip Csg Ft. Min. PPG9.6 Shoe @ 9136.06 FC @ Top of Liner 26249,102.24 Floats Held Mud CASING RECORD County State Supv.J Murphy / J Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Pearl 10 Date Run 27-Apr-23 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top 1.45 9,136.06 9,134.61 Csg Wt. On Hook: Type Float Collar:Innovex No. Hrs to Run: 9.7 5 100 1800 FI R S T S T A G E 10.5Spaces 30 134/134 2100 43 Rig 15.3 21.5 Bump press Returns Bump Plug? 10:52 4/27/2023 2,624 9,136.009,138.00 9,070.00 CEMENTING REPORT Csg Wt. On Slips: Mud 12 213 Type of Shoe: Casing Crew: HRD-E ZXP www.wellez.net WellEz Information Management LLC ver_04818br 3 Every joint on shoe track, every other joint 5-197 Liner 4 1/2 12.6 L-80 JFE LION 31.06 9,134.61 9,103.55 Float Collar 5 1.31 9,103.55 9,102.24 Liner 4 1/2 12.6 L-80 JFE LION 30.34 9,102.24 9,071.90 Landing Collar 5 1.06 9,071.90 9,070.84 Liner 4 1/2 12.6 L-80 JFE LION 6,413.18 9,070.84 2,657.66 Crossover 5 1/2 1.85 2,657.66 2,655.81 r Hanger / Packer A 6 5/8 Baker 31.81 2,655.81 2,624.00 Extended 503 2.39 Conventional 98 1.24 5 9i,1ei,rp kLL-U. LT Date: 06/13/2023 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 To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: PEARL 10 PTD: 223-028 API: 50-133-20711-00-00 Washed and Dried Well Samples (04/23/2023) B Set (5 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) PEARL 10 BOX 1 OF 5 2700' - 4200' MD PEARL 10 BOX 2 OF 5 4200' - 5460' MD PEARL 10 BOX 3 OF 5 5460' - 6900' MD PEARL 10 BOX 4 OF 5 6900' - 8010' MD PEARL 10 BOX 5 OF 5 8010' - 9138' MD Please include current contact information if different from above. aa3- () 18gE ECEiVE0 J U N 13 2023 Please acknowledge receipt by signing and returning one copy of this transmittal. Received Date: � � � I v __ 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: 06/09/2023 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Well: Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 Radial Cement Bond Log (06/04/2023) Folder Contents: Please include current contact information if different from above. PTD: 223-028 T37719 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.09 16:25:57 -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: 06/09/2023 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Well: Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 OPEN HOLE WIRELINE LOGS (04/14/2023 to 04/24/2023) 1. EXTENDED MICRO IMAGER (XRMI) RAW & PROCESSED (RUN 1: 04/14/2023) 2. EXTENDED MICRO IMAGER (XRMI) RAW & PROCESSED (RUN 2: 04/24/2023) 3. WAVEFORM SONIC (WSST) RAW & PROCESSED (RUN 2: 04/24/2023) Folder Contents (Electronic Plots and Digital Data): Please include current contact information if different from above. PTD: 223-028 T37718 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.09 13:05:47 -08'00' From:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: [EXTERNAL] RE: Pearl 10 CBL (Field Print) - PTD 223-028 Date:Monday, June 5, 2023 11:00:00 AM Attachments:image003.png image004.png image005.png Jake, Based on the CBL, Hilcorp has approval to proceed with perforating per the approved sundry. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <jake.flora@hilcorp.com> Sent: Monday, June 5, 2023 10:28 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Pearl 10 CBL (Field Print) - PTD 223-028 Hi Bryan, I’ve attached the current WBD showing the LTP depth. I have TOC at ~2970’. Snapshot below of both. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 5, 2023 9:21 AM To: Jacob Flora <jake.flora@hilcorp.com> Subject: [EXTERNAL] RE: Pearl 10 CBL (Field Print) - PTD 223-028 Jake, Do you have a current wellbore diagram? The one below says “proposed”. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <jake.flora@hilcorp.com> Sent: Monday, June 5, 2023 7:11 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Pearl 10 CBL (Field Print) - PTD 223-028 Good Morning Bryan, Please see attached CBL for Pearl 10. We are blowing it down today with N2 and with approval will perforate tomorrow. Let me know if you need anything else on the CBL- Thanks, Jake 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 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 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. 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 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 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. 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: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PEARL 10 PTD: 223-028 API: 50-133-20711-00-00 MUDLOGS - EOW DRILLING REPORTS (04/12/2023 to 04/23/2023) 1. FINAL EOW REPORT 2. DAILY REPORTS 3. SHOW REPORTS 4. DIGITAL DATA (LAS) 5. MUDLOG PRINTS (2” and 5” MD and TVD COLOR PRINTS – TIFF AND PDF FORMATS) Formation Log LWD Combo Log Gas Ratio Log Drilling Dynamics Log SFTP Transfer Folder Contents: Please include current contact information if different from above. PTD: 223-028 T37711 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.05 09:20:21 -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: 5/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Well: Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 FINAL LWD FORMATION EVALUATION LOGS (04/10/2023 to 04/26/2023) EWR-M5, AGR, DGR, ADR, SLIM PHASE-4, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Folder Contents: Please include current contact information if different from above. PTD: 223-028 T37670 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.25 10:25:07 -08'00' 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 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,138'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,430psi8,935'9,138' 120' 2,818' Perforation Depth MD (ft): 6,514'4-1/2" 16" 7-5/8" 120' 2,818' 2,980psi 6,880psi 120' 2,701' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 8,935'9,070'8,867'2702psi N/A MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Private 223-028 50-133-20711-00-00 Ninilchik Beluga-Tyonek Gas Same CO 701G Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Pearl Prospect Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 12.6# / L-80 2,632' May 22, 2023 Liner Top Pkr; N/A 2,624' MD/2,519' TVD; N/A See Schematic See Schematic Tie Back 4-1/2" 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: AOGCC USE ONLY Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 m n P s t 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-273 By Kayla Junke at 10:59 am, May 09, 2023 Pearl 10 KMJ Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.05.08 16:12:53 -08'00' Noel Nocas (4361) Passing MIT-T & MIT-IA to MPSP required prior to perforating. Submit CBL to AOGCC and gain approval before proceeding with perforations. BJM 5/15/23 10-407 DSR-5/11/23SFD 5/10/2023 Perforate GCW 05/16/23JLC 5/16/2023 05/16/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.16 10:45:20 -08'00' RBDMS JSB 051823 Well Prognosis Well Name: Pearl 10 API Number: 50-133-20711-00-00 Current Status: Gas Producer Permit to Drill Number: 223-028 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) Maximum Expected BHP: 3496 psi @ 7946’ TVD (Based on 0.44 psi/ft gradient)) Max. Potential Surface Pressure: 2702 psi (Based on 0.1 psi/ft gas gradient to surface) Well Status: New Drill Initial Completion Brief Well Summary: Paxton 10 is a grass roots well targeting the Beluga and Tyonek sands in the southernmost portion of the Ninilchik Unit. The objective of this sundry is to blow the wellbore down with coil tubing and perforate multiple Beluga sands. Wellbore Conditions: Drilling will leave the cemented 4.5” liner full of drilling mud, with the 4.5” tubing and annulus displaced to KCL. Procedure: 1. Review all approved COAs 2. Provide AOGCC 48hrs notice for BOP test 3. MIRU Coiled Tubing, PT BOPE to 3000 psi Hi 250 Low 4. Clean out wellbore to TD, displace to water 5. Log CBL, submit results to AOGCC a. Log CBL on coil with memory toolstring OR b. RU E-line over coil, PT lubricator to 3000psi, log CBL 6. RIH, reverse out wellbore with nitrogen, trap ~1700 psi on wellbore 7. RDMO coil tubing 8. RU E-line, PT lubricator to 3000 psi 9. Perforate and test the below sands from the bottom up: FORMATION Sand MD TOP MD Base Total Ftg TVD TOP TVD Bot Tyonek T10 4690 4705 15 4531 4546 Tyonek T10A 4718 4747 29 4558 4587 Tyonek T17 5466 5528 62 5300 5362 Tyonek T19 5694 5721 27 5525 5552 Tyonek T38 5850 5858 8 5680 5688 Tyonek T65 Upper 6763 6772 9 6583 6592 Tyonek T65 6776 6842 66 6596 6662 Tyonek T81 7112 7128 16 6929 6945 Tyonek T83 7158 7183 25 6975 7000 Tyonek T100 7438 7456 18 7252 7270 Tyonek T115 7537 7569 32 7350 7382 Passing MIT-T & MIT-IA to MPSP required prior to perforating. -bjm Submit CBL to AOGCC and gain approval before proceeding with perforations. -bjm Pearl Tyonek SFD 5/10/2023 Well Prognosis Tyonek T119 7692 7705 13 7504 7517 Tyonek T120 7710 7725 15 7521 7536 Tyonek T144 7958 7971 13 7767 7780 Tyonek T146 8046 8137 91 7855 7946 a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. Frac Calcs: Using 14.0 ppg EMW FIT at the surface casing shoe (0.728 psi/ft frac grad) c. Shallowest Allowable Perf TVD = MPSP/(0.728-0.1) = 2702 psi / 0.628 = 4302‘ TVD 10. RDMO 11. Turn well over to production & flow test well Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Coil Tubing BOP Diagram 4. Standard Nitrogen Operations Agree. -bjm Updated by DMA 05-08-23 CURRENT SCHEMATIC Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,070’ / TVD = 8,867’ TD = 9,138’ / TVD = 8,935’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 7-5/8" Surf Csg 29.7 L-80 CDC 6.875” Surf 2,818’ 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 2,624’ 9,138’ 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 2,632’ 4 16” 7-5/8” 9-7/8” hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 173’ 3.613” 5.500” SSSV 2 1,525’ 3.958” 4.500” Chemical Injection Sub 3 2,632’ 4.790” 6.340” Seal Stem 4 2,624’ 4.875” 6.540” Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" Est. TOC @ Surface (50% excess) 4-1/2” Est. TOC @ TOL (40% excess) 6-3/4” hole 3 2 1 Updated by DMA 05-08-23 PROPOSED Ninilchik Unit Pearl 10 PTD: 223-028 API: 50-133-20711-00-00 PBTD = 9,070’ / TVD = 8,867’ TD = 9,138’ / TVD = 8,935’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 7-5/8" Surf Csg 29.7 L-80 CDC 6.875” Surf 2,818’ 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 2,624’ 9,138’ 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 2,632’ 4 16” 7-5/8” 9-7/8” hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 173’ 3.613” 5.500” SSSV 2 1,525’ 3.958” 4.500” Chemical Injection Sub 3 2,632’ 4.790” 6.340” Seal Stem 4 2,624’ 4.875” 6.540” Liner hanger / LTP Assembly OPEN HOLE / CEMENT DETAIL 7-5/8" Est. TOC @ Surface (50% excess) 4-1/2” Est. TOC @ TOL (40% excess) 6-3/4” hole 3 2 1 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T10 ±4,690' ±4,705' ±4,531' ±4,546' ±15' Proposed TBD T10A ±4,718' ±4,747' ±4,558' ±4,587' ±29' Proposed TBD T17 ±5,466' ±5,528' ±5,300' ±5,362' ±62' Proposed TBD T19 ±5,694' ±5,721' ±5,525' ±5,552' ±27' Proposed TBD T38 ±5,850' ±5,858' ±5,680' ±5,688' ±8' Proposed TBD T65 Upper ±6,763' ±6,772' ±6,583' ±6,592' ±9' Proposed TBD T65 ±6,776' ±6,842' ±6,596' ±6,662' ±66' Proposed TBD T81 ±7,112' ±7,128' ±6,929' ±6,945' ±16' Proposed TBD T83 ±7,158' ±7,183' ±6,975' ±7,000' ±25' Proposed TBD T100 ±7,438' ±7,456' ±7,252' ±7,270' ±18' Proposed TBD T115 ±7,537' ±7,569' ±7,350' ±7,382' ±32' Proposed TBD T119 ±7,692' ±7,705' ±7,504' ±7,517' ±13' Proposed TBD T120 ±7,710' ±7,725' ±7,521' ±7,536' ±15' Proposed TBD T144 ±7,958' ±7,971' ±7,767' ±7,780' ±13' Proposed TBD T146 ±8,046' ±8,137' ±7,855' ±7,946' ±91' Proposed TBD 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 10 PEARL 10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 10 50-133-20711-00-00 223-028-0 N SPT 2701 2230280 3500 0 3677 3654 3643 0 0 0 0 OTHER P Bob Noble 4/28/2023 MIT-T per 323-273 post completion. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PEARL 10 Inspection Date: Tubing OA Packer Depth 0 20 20 20IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230429173721 BBL Pumped:1.6 BBL Returned:1.6 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 99 9 99 9 9 *DV3URGXFHU MIT-T per 323-273 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 14:50:25 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 10 PEARL 10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 10 50-133-20711-00-00 223-028-0 N SPT 2701 2230280 3500 0 61 40 30 0 0 0 0 OTHER P Bob Noble 4/28/2023 MIT-IA per 323-273 post completion for production. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PEARL 10 Inspection Date: Tubing OA Packer Depth 0 3590 3580 3580IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230429175410 BBL Pumped:1.2 BBL Returned:0.7 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 99 9 9 9 9 9 *DV3URGXFHU MIT-IA per 323-273 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 14:52:41 -08'00'         jbr STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PEARL 10 JBR 05/12/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tested with 4 1/2" test joint, tested all gas alarms and PVT's, Precharge Bottles = 11@1050 psi and 4@1000psi. Test Results TEST DATA Rig Rep:Brandon DavisOperator:Hilcorp Alaska, LLC Operator Rep:Rance Peterson Rig Owner/Rig No.:Hilcorp 169 PTD#:2230280 DATE:4/16/2023 Type Operation:DRILL Annular: 250/2500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB230417072312 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 3038 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 2 7/8"x5"P #2 Rams 1 Blinds P #3 Rams 1 2 7/8"x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8",2 1/16"P Kill Line Valves 1 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1700 200 PSI Attained P22 Full Pressure Attained P88 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2487 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P4 #2 Rams P4 #3 Rams P4 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1      STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: Reviewed By: P.I. Suprv Comm ________PEARL 10 JBR 05/12/2023 MISC. INSPECTIONS: GAS DETECTORS: DIVERTER SYSTEM:MUD SYSTEM: P/F P/F P/F Alarm Visual Alarm Visual Time/Pressure Size Number of Failures:0 Remarks:Function tested annular and knife valve with joint of 4 1/2" DP in hole. Verified annular holding by slacking off on blocks. Performed draw down test of koomey unit. Quadco Rep tested all audio/visual gas alarms and lights on 4-12-23 with AOGCC witness. Measured vent line and outlet from sub base and knife valve. Function tested PVT's and showed audio/visual alarms. Well on diverter signs are posted. One at pad entrance, one on pit side of rig. Barricades are in place 75' from vent line outlet to block any traffic. Accumulator bottle precharge is 15@ 1036 psi TEST DATA Rig Rep:Branden DavisOperator:Hilcorp Alaska, LLC Operator Rep:Rance Pederson Contractor/Rig No.:Hilcorp 169 PTD#:2230280 DATE:4/12/2023 Well Class:DEV Inspection No:divKPS230412185234 Inspector Kam StJohn Inspector Insp Source Related Insp No: Test Time:1 ACCUMULATOR SYSTEM: Location Gen.:P Housekeeping:P Warning Sign P 24 hr Notice:P Well Sign:P Drlg. Rig.P Misc:NA Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:NA NA Designed to Avoid Freeze-up?P Remote Operated Diverter?P No Threaded Connections?P Vent line Below Diverter?P Diverter Size:21.25 P Hole Size:9.875 P Vent Line(s) Size:16 P Vent Line(s) Length:134.5 P Closest Ignition Source:88 P Outlet from Rig Substructure:122.9 P Vent Line(s) Anchored:P Turns Targeted / Long Radius:NA Divert Valve(s) Full Opening:P Valve(s) Auto & Simultaneous: Annular Closed Time:30 P Knife Valve Open Time:1 P Diverter Misc:0 NA Systems Pressure:P2950 Pressure After Closure:P1825 200 psi Recharge Time:P19 Full Recharge Time:P67 Nitrogen Bottles (Number of):P4 Avg. Pressure:P2450 Accumulator Misc:NA0 P PTrip Tank: P PMud Pits: P PFlow Monitor: NA NAMud System Misc: 9 9 9 9 9 $QQXODU&ORVH7LPHDOORZHG VHFMEU 9 Function tested PVT's and showed audio/visual alarms. tested all audio/visual gas alarms and lights on 4-12-23 with AOGCC witness. THE S'1NFE °'ALASKA WVE'RNOR MIKE DUNLFAVY Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Suite 1400 Anchorage, AK, 99503 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 Re: Ninilchik Pearl Prospect, Beluga/Tyonek Gas, Pearl 10 Hilcorp Alaska, LLC Permit to Drill Number: 223-028 Surface Location: 366' FNL, 717' FEL, Sec 23, TIS, R14W, SM, AK Bottomhole Location: 232' FSL, 898' FWL, Sec 13, TIS, R14W, 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. HuberDigitally signed by Brett W. Huber. Sr. Sr. Date: 2023.04.1014:00:39 -08,00, Brett W. Huber, Sr. Chair, Commissioner DATED this 10 day of A p r i I , 2023. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2n AAr: gs-nns RECEIVED By Kayla Junke at 10:12 am, Mar 30, J2023 1 a Type of Work: 1b. Proposed Well pass: Exploratory -Gas Service - WAG LJ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development - 01 ❑ 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: Hilcorp Alaska, LLC Bond No. 022224484 Pearl 10 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 MD: 9,138' TVD: 8,935' Ninilchik Unit Pearl Prospect 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 366' FNL, 717' FEL, Sec 23, T1 S, R14W, SM, AK Private Beluga/Tyonek Gas Top of Productive Horizon: 8e DNR Approval Number: 13. Approximate Spud Date: 75' FNL, 51' FEL, Sec 23, T1 S, R14W, SM, AK LOCI 17-001 4/11/2023 Total Depth: 9- Acres in Property: 14. Distance to Nearest Property: 232' FSL, 898' FWL, Sec 13, T1 S, R14W, SM, AK -67.5 -1' to unit boundary 4b. Location of Well (State Base Plane Coo ates- NAD 27): SFS 10. KB Elevation above MSL (ft): 139.9' Distance to Nearest Well Open Surface: x -2P40 203197.5 Y- 3P<772 2225781.7 Zone -4 GL / BF Elevation above MSL (ft): 121.9' 115. to Same Pod: 2000' to Peal 2A 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 19.2 degrees Downhole: 3931 Surface: 3038 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' Driven 9-7/8" 7-5/8" 29.7# L-80 CDC 2,813' Surface Surface 2,813' 2,696' L - 816 ft3 / T - 182 ft3 6-3/4" 41/2" 126# L-80 JFE LION 6,525' 2,613' 2,507' 9,138' 8,935' L-1185 ft3 / T 104 ft3 Tieback 41/2" 12.6# L-80 JFE LION 2,613' Surface Surface 2,613' 2,507' Tieback Assy. 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (fi): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No ❑✓ 20. Attachments: Property Plat Q BOP Sketch ❑Drilling Program ❑ Time v. Depth Plot ❑ ✓ Shallow Hazard Analysis ❑ Diverter Sketch Seabed Report Drilling Fluid Program ✓ 20 A AC 25.050 requirements ✓ 21. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Frank Roach Authorized Name: Monty Myers Contact Email: frank, roaCho)hlcoroxom Authorized Title: Drilling Manager Contact Phone: 907-777-8413 DN: cn=Monty M Myers, Monty M DpalysgnedbyMollyM yore o=Hlcoro gash, LLC, owT,TechnicJ Authorized Signature: S�-^KD^i"� Date: 3 .2 9.2 0 2 3 myelsReason: mapproving this documern Dam: 202303.2915:53.37-08'00' Commission Use Only Permit to Drill API Number:Permit Approval See cover letter for other Number: 223-028 50-133-20711-00-00 Date: requirements. 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: �] BOP test to 3500 psi, annular test to 2500 psi. Samples req'd: Yes ❑ NoJE Mud log req'd: Yes❑ No0 Submit FIT/LOT results within 48 hrs of performing test. 112S measures: Yes ❑ No0 Directional svy req'd: Yes© No[-] Spacing exception req'd: Yes P] No ❑ Inclination -only svy req'd: Yes ❑ No Post initial injection MIT req'd: Yes[-] No[-] Brett W. Huber, Sr. w9eam:ioa a ,ftW W `Sr. Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: 04/10/2023 ComnLJLC 4/10/2023 lComm. GCW 04/10/23 JSrPetEng BJM 4/5/23 JSr Pet Geo MDG 4/10/2023 ISr Res Eng ; __ �' -i -31/23 Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Hilcorp Alaska, LLC Pearl 10 Drilling Program Ninilchik Unit March 28, 2023 REV 0 Hilcorp Rne�gy Company 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 N/U 21-1/4" Conductor............................................................................................................11 11.0 Drill 9-7/8" Hole Section..........................................................................................................13 12.0 Run 7-5/8" Surface Casing......................................................................................................15 13.0 Cement 7-5/8" Surface Casing.................................................................................................18 14.0 BOP N/U and Test.................................................................................................................... 21 15.0 Drill 6-3/4" Hole Section..........................................................................................................22 16.0 Run 4-1/2" Production Liner...................................................................................................25 17.0 Cement 4-1/2" Production Liner.............................................................................................28 18.0 4-1/2" Liner Tieback Polish Run............................................................................................. 31 19.0 4-1/2" Tieback Run.................................................................................................................. 32 20.0 Diverter Schematic.................................................................................................................. 33 21.0 BOP Schematic........................................................................................................................ 34 22.0 Wellhead Schematic.................................................................................................................35 23.0 Days Vs Depth..........................................................................................................................36 24.0 Geo-Prog.................................................................................................................................. 37 25.0 Anticipated Drilling Hazards.................................................................................................. 38 26.0 Hilcorp Rig 169 Layout........................................................................................................... 40 27.0 FIT/LOT Procedure................................................................................................................. 41 28.0 Choke Manifold Schematic...................................................................................................... 42 29.0 Casing Design Information......................................................................................................43 30.0 6-3/4" Hole Section MASP....................................................................................................... 44 31.0 Spider Plot (Governmental Sections) and 660' Radius for SSSV........................................... 45 32.0 Surface Plat (As -Staked NAD27)............................................................................................. 46 PEARL 10 Drilling Procedure REV 0 Hilcorp EneW c., 1.0 Well Summary Well Pearl 10 Pad & Old Well Designation Pearl Pad / grassroots well Planned Completion Type 4-1/2" Cemented Production Liner Target Reservoirs Belu a/T onek Gas Sands Planned Well TD, MD / TVD 9,138' MD / 8,935' TVD PBTD MD / TVD 9 058' MD / 8,855' TVD Surface Location Governmental 366' FNL 717' FEL Sec 23 TIS R14W SM AK Surface Location AD 27 X=203197.50 Y=2225781.70 Top of Productive Horizon Governmental 73' FNL 49' FEL Sec 23 T1 S R14W SM AK TPH Location AD 27 X=203889.42 Y=2225978.28 BHL Governmental 232' FSL 898' FWL Sec 13 Tl S R14W SM AK BHL AD 27 X=204843.51 Y=2226260.11 AFE Number AFE Drilling Das 4 MOB 21 DRLG AFE Completion Days AFE Drilling Amount AFE Completion Amount Maximum Anticipated Pressure Surface 3038 psi Maximum Anticipated Pressure Downhole/Reservoir 3931 psi Work String 4-1/2" 16.6# S-135 CDS-40 RKB — GL 139.9' 021.9 + 18 Ground Elevation 121.9' BOP Equipment 11" 5M Annular BOP 1 l" 5M Double Ram 11" 5M Single Ram Page 2 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp 8nergy company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp lincrgy ('ompany Changes to Approved Permit to Drill Date: January 9, 2023 Subject: Changes to Approved Permit to Drill for Pearl 10 File #: Pearl 10 Drilling Program Any modifications to Pearl 10 Drilling Program will be documented and approved below. Changes to an approved PTD will be communicated to and approved by the AOGCC prior to continuing with work. Sec Page Date Procedure Change Approved Approved 13 Approval: Monty Myers Drilling Manager Date Prepared: Frank Roach Drilling Engineer Date Page 3 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp Energy Company 3.0 Tubular Program: Hole Section OD in ID (in) Drift in Conn OD in(#/ft) Wt Grade Conn Burst (psi) Collapse (psi) Tension (k -lbs) Cond 16" 15.01" 14.822" - 84 X-56 Weld 2980 1410 - 16 082 194k Surface 9-7/8" 7-5/8" 6.875" 6.750" 8.500" 29.7 1-80 CDC 6880 4790 683 Prod 6-3/4" 4-1/2" 3.958" 3.833" 5.002" 12.6 L-80 JFE LION 8430 7500 288 4.0 Drill Pipe Information: Hole Section OD in ID (in) TJ ID in TJ OD in(#/ft) Wt 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 Cleanout 2-7/8" 2.323 2.265" 3.438" 7.9 P-110 PH -6 16,896 16 082 194k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 March, 2023 5.0 Internal Reporting Requirements PEARL 10 Drilling Procedure REV 0 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to mmyersna- hilcorp.com, Frank.Roach@hilcoEp.com, and cdinger@hilcorp.com 5.3 intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Jacob Nordwall: O: (907) 777-8418 C: (907) 748-0753 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers ,hilcorp com, Frank.Roach@hilcorp.com, and cdin er&hilcoW.com 5.6 Casing and Cmt report Send casing and cement report for each string of casing to mmvers&hilcorp.com, Frank.Roach a,hilcorp.com, and cdinger(a)hilcorp.com Page 5 Version 0 March, 2023 M JIM PEARL 10 Drilling Procedure REV 0 Hi1mTEnergy Company 6.0 Planned Wellbore Schematic a hole 7.5/8" Niniichik Unit PROPOSED SCHEMATIC PTD: API: RKB t0 GL = 18' PBTD = 9,058'/ TVD = 8,855' TD = 9,138'/ TVD = 8,935' CASING DETAIL Size —Type- Wt Grade Conn. ID Top Elm 16" Conductor - Driven to Set Depth 84 X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 CDC 6.875" Surf 2,813' 4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958" 2,613' 9,]38' 4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958" Surf 2,613' IFWFI Ry r1FTAll No. Depth ID OD Item 1 2,613' 4.875" 6.540" Liner hanger / LTP Assembly 2 2,613' 4.790" 6,340" Seal Stem 3 4 -1,500' ^150' 3.958" 3.613" 4.500" 5.500" Chemical Injection Sub SSSV OPEN HOLE /CEMENT DETAIL 7.518" Est. TOC @ Surface (SO% excess) 4-1/2" 1 Est. TOC @ TOL (40% excess) Page 6 Version 0 March, 2023 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary PEARL 10 Drilling Procedure REV 0 Pearl 10 is a grassroots delineation/development well to be drilled from Pearl Pad. This well will be targeting the Beluga and Tyonek sands identified for gas production based on the data from the 2022 Pearl Pad wells and Paxton 6. The base plan is a directional wellbore with a kickoff point at —300' MD. Maximum hole angle will be —20 deg before dropping to 8 deg and TD of the well will be 9,138' TMD/ 8,935' TVD. Drilling operations are expected to commence approximately April 11, 2023. The Hilcorp Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 2,813' MD / 2,696' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a cement evaluation log (CBL/VDL or temperature log for example) will be run to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. 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 well site 2. N/U Diverter 3. Drill 9-7/8" hole to 2,813' MD. 4. Run and cement 7-5/8" surface casing. ND conductor riser, N/U & test 11" x 5M BOP. 6. Drill Out shoe and perform FIT. 7. Drill 6-3/4" hole section to 9,138' MD. Perform wiper trips as needed. 8. POOH w/drillpipe. 9. Run and cmt 4-1/2" production liner. 10. Polish PBR 11. RIH and land 4-1/2" tieback string in liner top. 12. MIT -T, MIT -IA 13. N/D BOP, N/U tree, RDMO. Reservoir Evaluation Plan: Surface hole: Gr/Res MWD w/e-line image log after TD • e -line log dependent on hole conditions Production Hole: Triple Combo MWD w/e-line sonic and image logs after TD • e -line logs dependent on hole conditions Mud loggers from surface casing point to TD. Page 7 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilc EneW Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our 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. • BON shall be tested at (2) week intervals during the drilling of PEARL 10. Ensure to provide AOGCC at least 24 hrs notice prior to testing BOPS. • 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 5/5 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 PTD. • If the BOP is used to shut in on the well in a well control situation, we must test all BDP 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. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permits are posted on the rig floor and in Co Man office. • Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. Regulation Variance Requests: Page 8 Version 0 March, 2023 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements PEARL 10 Drilling Procedure REV 0 Hole Section Equipment Test Pressure(psi) 9-7/8" • 21-1/4" x 2M diverter Function Test Only • 11" x 5M Annular BOP • 11" x 5M Double Ram Initial Test: 250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 6-3/4" 0 11" x 5M Single Ram • 3-1/8" 5M Choke Line Subsequent Tests: • 2-1/16" x 5M Kill line 250/3500 3-1/8" x 2-1/16" 5M Choke manifold (Annular 2500 psi) • Standpipe, floor valves etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing Diverter and BOPS. • 24 hours notice prior to casing running & cement operations. • 48 hours notice prior to performing MITIA. • Any other notifications required in PTD. Additional requirements may be stipulated on PTD and/or Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regg�alaska.gov Bryan McLellan / Petroleum Engineer / (0): 907-793-1226 / Email: brvan.mclellan cr alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loeppnalaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors&alaska.cov Test/Inspection notification standardization format: httn://doa.alaska.2ov/oiic/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 16" conductor and cellar installed and surveyed. 9.2 Install slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.3 Level pad and ensure enough room for layout of rig footprint and R/U. 9.4 Layout Herculite on pad to extend beyond footprint of rig. 9.5 WU Hilcorp Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.6 RU Mud loggers on surface hole section for gas detection only. No samples required 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 9-7/8" hole section. 9.9 Install 5-1/2" liners in mud pumps. • HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2" liners. Page 10 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 HiImTEnergy Company 10.0 N/U 21-1/4" Conductor 10.1 N/U 21-1/4" Diverter • N/U 21-1/4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. Ensure to notify AOGCC inspector to witness function test of diverter. • NOTE: Ensure closing time on diverter annular is in line with API RP 64: o Annular element ID 20" or smaller: Less than 30 seconds o Annular element ID greater than 20": Less than 45 seconds 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 11 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp Energy Company 10.5 Rig 169 Orientation: Note: Actual layout may be different on location PEARL DRILL PAD i r i IX ♦0 1p Page 12 Version 0 March, 2023 0 HilcoT EneW Company 11.0 Drill 9-7/8" Hole Section PEARL 10 Drilling Procedure REV 0 11.1 P/U 9-7/8" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 4-1/2" Workstring & HWDP will come from Hilcorp. 11.3 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 9-7/8" hole section to 2,813' MD/ 2,696' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize past experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500'-1000' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • Take MWD surveys every stand drilled (60' intervals). 11.5 9-7/8" 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 8.8 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, Toolpusher office, and mud loggers office. System Type: 8.8 — 9.5 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point AN FL pH 120-2815' 8.8-9.5 85-150 20-40 25-45 <10 1 8.5-9.0 Page 13 Version 0 March, 2023 Hilcorp Energy Company 11.6 11.7 11.8 PEARL 10 Drilling Procedure REV 0 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER 0.905 bbl SODA ASH 0.5 ppb AQUAGEL 12-15 ppb CAUSTIC SODA 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC -L /DEXTRID LT if required for <12 FL ALDACIDE G 0.1 ppb X TEND II 0.02 PPb At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. TOH with the drilling assy, handle BHA as appropriate. RU E -Line and perform wireline logging plan. RD e -line. 11.9 PU 9-7/8" cleanout assembly and RIH to TD, noting any tight spots along the way. CBU at least once at TD to ensure hole is clean for casing run. POOH and LD cleanout assembly. Page 14 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp EneW Company 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8" CDC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill -up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • 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: • (1) Shoe joint w/ float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end & thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 7-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" 29.7# USS -CDC torclues Casing OD Minimum Maximum Yield 7-5/8" 14,000 ft -lbs 17,000 ft -lbs 20.900 ft -lbs Page 15 Version 0 March, 2023 PEARL 10 Drilling Procedure ff REV 0 HilcoT E—u compaey USS U. S. Steel Tubular Products 7.625" 29.70lb/ft (0.375" Wali) L80 USS -CDC® MECHANICAL PROPERTIES Pipe USS -CDC® _ Minimum Yield Strength 80,000 psi Maximum Yield Strength 95,000 psi Minimum Tensile Strength 95,000 psi DIMENSIONS Pipe USS -CDC" _ Outside Diameter 7,625 81500 in, Wall Thickness 0.375 in. Inside Diameter 6.875 6.875 in. Standard Drift 6.750 6.750 in. Alternate Drift in. Nominal Linear Weight, T&C 29.70 Ib/ft Plain End Weight 29.06 Ib/ft SECTION AREA Pipe USS -CDC® _ Critical Area 8.541 8.541 sq. in. Joint Efficiency 100.0 % PERFORMANCE Pipe USS -CDC® _ Minimum Collapse Pressure 4,790 4,790 psi External Pressure Leak Resistance 3,830 psi Minimum Internal Yield Pressure 6,880 6,880 psi Minimum Pipe Body Yield Strength 683,000 Ib Joint Strength 721,000 Ib Compression Rating 433,000 Ib Reference Length 16,184 ft Maximum Uniaxial Bend Rating 30.5 deg/100 ft MAKE-UP DATA Pipe USS -CDC® _ Make -Up Loss 5.19 in. Minimum Make -Up Torque 14,000 ft -Ib Maximum Make -Up Torque 17,000 ft -Ib Connection Yield Torque 20,900 ft -Ib Page 16 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hil=En� 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 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. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 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. 12.11 After circulating, lower string and land hanger in wellhead again. Page 17 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 HiIc,oj Energy Company 13.0 Cement 7-5/8" 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. • Pump 20 bbls of freshwater through all of Halliburton's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • 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 volume. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. verified cement volumes. -bjm Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol 0 12.0 ppg LEAD: 120' x .16239 bpf = 19.49 109.4 16" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD: (2313' - 120') x .03825 bpf x 125.82 706.5 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: Total LEAD: 145.31 bbl 815.9 ft3 15.4 ppg TAIL: (2813'- 2313') x .03825 bpf x 28.69 161.1 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: 15.4 ppg TAIL: 80 x .04592 bpf = 3.67 20.6 7-5/8" Shoe track: Total TAIL: 32.36 bbl 181.7 ft3 TOTAL CEMENT VOL: 177.67 bbl 997.6 ft3 Page 18 Version 0 March, 2023 HilmTEneW Company Cement Slurry Design: PEARL 10 Drilling Procedure REV 0 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 Displacement calculation: 2813'- 80' = 2733' x .04592 bpf = 126 bbls verified -bjm 13.12 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. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than %2 shoe track volume. Total volume in shoe track is 3.6 bbls. Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 — 18 hours after CIP or a CBLNDL after cement has started building compressive strength. Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 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. 13.15 R/D cement equipment. Flush out wellhead with FW. Page 19 Version 0 March, 2023 Lead Slurry (2313' MD to surface) Tail Slurry (2813' to 2313' MD) System Extended Conventional Density 12 Ib/gal 15.8 Ib/gal Yield 2.44 ft3/sk 1.16 ft3/sk Mixed Water 14.40 al/sk 5.03 al/sk Mixed Fluid 14.40 gal/sk 5.03 gal/sk 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 Displacement calculation: 2813'- 80' = 2733' x .04592 bpf = 126 bbls verified -bjm 13.12 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. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than %2 shoe track volume. Total volume in shoe track is 3.6 bbls. Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 — 18 hours after CIP or a CBLNDL after cement has started building compressive strength. Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 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. 13.15 R/D cement equipment. Flush out wellhead with FW. Page 19 Version 0 March, 2023 13.16 Back out and L/D landing joint. Flush out wellhead with FW. PEARL 10 Drilling Procedure REV 0 13.17 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. 13.18 Lay down landing joint and pack -off running tool. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Page 20 Version 0 March, 2023 iI MIN Page 20 Version 0 March, 2023 14.0 BOP N/U and Test 14.1 ND conductor riser. PEARL 10 Drilling Procedure REV 0 14.2 N/U multi -bowl wellhead assy. Install 7-5/8" packoff P -seals. Test to 3000 psi. 14.3 N/U 11" x 5M BOP as follows: • 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 • Double ram should be dressed with 2-7/8" x 5" variable bore rams in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" variable bore rams • N/U bell nipple, install flowline. • Install (2) manual valves & a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Utilize 4-1/2" test joint. • 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 9.0 ppg 6% KCL PHPA mud system. If MW at surface TD was greater than 9.0 ppg, increase density of new mud to match. 14.8 WU mud loggers for production hole section. 14.9 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. Page 21 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp Energy C—npa^Y 15.0 Drill 6-3/4" 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. Hydraulics calculations and recommended TFA is attached below. 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 6-3/4" hole section mud program summary: 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, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Plastic Viscosity yield Point pH HPHT Wei ht Viscosity 2.815'- 9.142' 9.0-10.0 40-53 15-25 15-25 8.5-9.5 < 11.0 Page 22 Version 0 March, 2023 Hilcorp HneW Company PEARL 10 Drilling Procedure REV 0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb (initially 0.25 ppb) DEXTRID LT 1-2 ppb PALL I ppb BARACARB 5/25/50 15 - 20 ppb (5 ppb of each) BAROID 41 as required for a 9.0-10.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 1 0.5 ppb maintain per dilution rate 15.9 TIH w/ 6-3/4" directional 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 3500 psi / 30 min. Ensure to record volume /pressure and plot on FIT/LOT graph. AOGCC requirement is 50% of burst. 7-5/8" burst is 6890 psi / 2 = 3445 psi. 15.11 Drill out shoe track and 20' of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FIT. Target value 14.0 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8 " shoe to be between 11.5 — 21.0 ppg EMW. A 14.0 ppg FIT results in a > 15 bbl kick tolerance while drilling with the planned MW of 9.8 ppg and an assumed 0. Sppg kick intensity over anticipated pore pressure. Agree. -bjm 15.14 Drill 6-3/4" hole section to 9,138' MD / 8,935' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 250 - 350 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1000' unless hole conditions dictate otherwise. • On the third wiper trip (around 6,000' MD), trip back to the 7-5/8" shoe to split the hole section in half. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every 100' drilled. Surveys can be taken more frequently if deemed necessary. • Collect samples every 20'. • NOTE: Running Coals in Tyonek required a 9.8ppg after TD on Pearl 2A. Be ready to weight up if needed for hole stability. See section 25.0. Page 23 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp EneW Compony 15.15 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. NOTE (again): be prepared to increase mud weight prior to final wiper trip to address potential coal stability issues that were encountered in Pearl 2A. 15.16 TOH with the drilling assy, standing back drill pipe. 15.17 LD BHA 15.18 RU E -Line and perform wireline logging plan. 15.19 RD E -Line. PU 6-3/4" clean out BHA, and TIH to TD. 15.20 Pump sweep, CBU and condition mud for casing run. 15.21 POOH and LD BHA 15.22 2-7/8" x 5-1/2" VBRs previously installed in BOP stack and tested with 4-1/2" test joint. Page 24 Version 0 March, 2023 0 Hil=Energyv�r 16.0 Run 4-1/2" Production Liner PEARL 10 Drilling Procedure REV 0 16.1. R/U 4-1/2" casing running equipment. • Ensure 4-1/2" HE LION x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill liner while running. • Ensure all liner has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U liner tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • (1) Joint with Baker landing collar bucked on pin end & threadlocked. • Solid body centralizers will be pre-installed on shoe joint, FC joint, and landing collar joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 4-1/2" production liner • Fill liner while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 7-5/8" shoe. Leave the centralizers free floating. 16.5. Continue running 4-1/2" production liner 4-1/2" 12.6# HELION M/U torques Casing OD I Minimum Optimum Maximum 4-1/2" 1 6,030 ft -lbs 6,690 ft -lbs 7,360 ft -lbs Page 25 Version 0 March, 2023 Hilcorp Energy Company J JFE /S° Standard Bevel L'r'_J'�j Graph Signature Torque vs Turns PEARL 10 Drilling Procedure REV 0 JFELION" �f Data Sheet Aug 25, 2022 ..,"r WEIGHT GRADE COUP f 4.500 in 12.6 Ib/ft L80 STD API Modified - Carbon 114.30 mm 18.75 kg/m Imperial Metric Pipe Body Wall 0.271 in 6.88 mm Pipe ID 3.958 in 100.53 mm Drift Diameter 3.833 in 97.36 mm PIPE Pipe Cross Section 3.60 int 2323 mm2 Collapse Pressure 7500 psi 51.71 MPa Internal Yield Pressure 8430 psi 58.12 MPa Pipe Body Yield Strength 288 kip 1281 kN Min 80000 psi 552 MPa Yield Strength MATERIAL Max 95000 psi 655 MPa Min Tensile Strength 95000 psi 655 MPa OD/Turning Dia 5.002 in 127.05 mm Coupling Diameter COUPLING ID 3.9220 in 99.62 mm Tensile Efficiency 100% 100% is identification c code for didistinguishing Coupling Length 6.620 in 168.15 mm interchangeability. Make-up Loss Length SD: 29 ** 2.9000 in 73.66 mm Bearing Face Load 172 kip 765.71 kN Collapse Pressure 7500 psi 51.71 MPa Internal Yield Pressure 8430 psi 58.12 MPa CONNECTION Joint Strength 288 kip 1281 kN PERFORMANCE Joint Tensile Efficiency 100% 100% Compression Rating 288 kip 1281 kN Min 6030 ft -Ib 8176 Nm FIELD MAKE-UP Torque Opt 6690 ft -Ib 9070 Nm TORQUE Max 7360 ft -Ib 9979 Nm Min 669 ft -lb 907 Nm API Modified - Shoulder Carbon Max 5687 ft -Ib 7711 Nm Max Torque with Sealability 7360 ft -Ib 9979 Nm Page 26 Version 0 March, 2023 0 Hi1COrp Energy CbMpany 16.6. Run in hole w/ 4-1/2" liner to the 7-5/8" casing shoe. PEARL 10 Drilling Procedure REV 0 16.7. Fill the liner with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight, and torque of the liner. 16.9. Circulate 2X bottoms up at shoe, ease liner thru shoe. 16.10. Continue to RIH w/ liner no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set liner slowly in and out of slips. 16.12. 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. 16.13. Continue running in hole at slow speeds to avoid surging well. Target 20 ft/min and adjust slower as hole conditions dictate. 16.14. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.15. Swedge up and wash last stand to bottom. P/U 2-5' off bottom. Note slack -off and pick-up weights. 16.16. 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 (whichever is longer). Reduce the low-end rheology of the drilling fluid by adding water and thinners. 16.17. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 27 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcm EneCompany rgy 17.0 Cement 4-1/2" Production Liner 17.1. 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. • Pump 20 bbls of freshwater through all of Halliburton's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 17.3. Pump 5 bbls spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining spacer. 17.6. 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 volumes -bjm Section: Calculation: Vol (BBLS) Vol ft3 12.0 ppg LEAD: 7-5/8" csg x 4-1/2" drillpipe annulus: 200' x .02624 bpf = 5.25 29.5 12.0 ppg LEAD: 7-5/8" csg x 4-1/2" liner annulus: 200' x.02624 bpf = 5.25 29.5 12.0 ppg LEAD: 6-3/4" OH x 4-1/2" annulus: (8638' — 2813') x .02459 bpf x 1.4 = 200.53 1125.9 Total LEAD: 211.03 bbl 1184.9 ft3 15.4 ppg TAIL: 6-3/4" OH x 4-1/2" annulus: (9138'- 8638') x .02459 bpf x 1.4 = 17.21 96.6 15.4 ppg TAIL: 4-1/2" Shoe track: 80 x.01522 bpf = 1.22 6.8 Total TAIL: 18.43 bbl 103.5 ft3 TOTAL CEMENT VOL: 229.46 bbl 1288.4 ft3 Page 28 Version 0 March, 2023 Hilcorp Energy Company Cement Slurry Design: PEARL 10 Drilling Procedure REV 0 17.7. 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. 17.8. Displace cement at max rate of 5 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. 17.9. 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. 17.10. 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. 17.11. Slack off total liner weight plus 30k to confirm hanger is set. 17.12. Do not overdisplace by more than Y2 shoe track. Shoe track volume is 1.2 bbls. 17.13. Continue pressuring up to activate LTP pusher tool and set packer with running tool in compression. 17.14. Pressure up to 4,500 psi to neutralize the pusher tool and release the running tool (HRD-E) from the liner. 17.15. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.16. P/U past free -travel verify setting tool is released, confirmed by loss of liner weight. 17.17. 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 Page 29 Version 0 March, 2023 Lead Slurry (8638' MD to 2613' MD) Tail Slurry (9138' to 8638' MD) System Extended Conventional Density 12 Ib/gal 15.3 lb/gal Yield 2.4 ft3/sk 1.24 ft3/sk Mixed Water 14.09 al/sk 5.58 al/sk Mixed Fluid 14.09 al/sk 5.58 al/sk 17.7. 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. 17.8. Displace cement at max rate of 5 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. 17.9. 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. 17.10. 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. 17.11. Slack off total liner weight plus 30k to confirm hanger is set. 17.12. Do not overdisplace by more than Y2 shoe track. Shoe track volume is 1.2 bbls. 17.13. Continue pressuring up to activate LTP pusher tool and set packer with running tool in compression. 17.14. Pressure up to 4,500 psi to neutralize the pusher tool and release the running tool (HRD-E) from the liner. 17.15. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.16. P/U past free -travel verify setting tool is released, confirmed by loss of liner weight. 17.17. 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 Page 29 Version 0 March, 2023 Hilcorp PEARL 10 Drilling Procedure REV 0 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). 17.18. 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. 17.19. 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. 17.20. 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: 17.21. 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. 17.22. NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 17.23. 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. 17.24. WOC minimum of 12 hours before testing liner to 3500 psi and chart for 30 minutes. Page 30 Version 0 March, 2023 Hilcorp EnoW Company PEARL 10 Drilling Procedure REV 0 Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if liner is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job IIN iN I I fill 0i Mill11 1 -MMER?"! R?"! MIi flit 18.0 4-1/2" Liner Tieback Polish Run 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. POOH, LDDP and polish mill. • NOTE: If a cleanout run inside the 4-1/2" is needed, BOPS need to be tested with 2-7/8" test joint to cover cleanout assembly. 18.4. Test casing and liner lap to 3,500 psi / 30 min. Ensure to chart record casing test. Page 31 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilco p E+ -V C—vOr 19.0 4-1/2" Tieback Run, ND/NU, RDMO 19.1 PU 4-1/2" tieback assembly and RIH with 4-1/2" 12.6# L-80 DWC/C-HT tubing. • Install Chemical injection mandrel at 1500'. OD should be 5.9" • Install SSSV at —150' in tieback string o Dual control line spooler needed 1/2" 12.6# JFEL1UN M/U torques Casing OD Minimum Optimum Maximum 4-1/2" 6,030 ft -lbs 6,690 ft -lbs 7,360 ft -lbs 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 Circulate inhibited completion fluid. 19.4 PU hanger and terminate control line through hanger. Land string in hanger bowl. Note distance of seals from no-go. 19.5 Install packoff and test hanger void. 19.6 Test 4-1/2" liner and tieback to 3,500 psi / 30 min and chart for 30 minutes. 24hr AOGCC notice required. 19.7 Test 7-5/8" x 4-1/2" annulus to 3,500 psi / 30 min and chart for 30 minutes. 24hr AOGCC notice required. 19.8 Install BPV in wellhead 19.9 N/D BOPE 19.10 N/U dry -hole tree and test 19.11 RDMO Page 32 Version 0 March, 2023 Hilcorp Energy Company 20.0 Diverter Schematic 16" casii below c PEARL 10 Drilling Procedure REV 0 Page 33 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp Energy Compmy 21.0 BOP Schematic Page 34 Version 0 March, 2023 Hilcorp Enew COMPITly 22.0 Wellhead Schematic ay '---w —- ..... 1. J. AA, �. .. PEARL 10 Drilling Procedure REV 0 Page 35 Version 0 March, 2023 Hilcorp Fina Company 23.0 1,000 2,000 3,000 6,000 t 4E a ar v 5,000 H 10 W 00 6,000 7,000 a,0ac a,OGC PEARL 10 Drilling Procedure REV 0 Days Vs Depth 110 15 20 Day -S Page 36 Version 0 March, 2023 HilmTEnergy Company 24.0 Geo - PEARL 10 Drilling Procedure REV 0 Drill production / development well on the southeastern side of the Pearl structure Proposed Pearl 10 well will test the gas potential in the Tyonek section between Pearl 2A and Pearl 1 TOP NAME( LITNOLOGY I O , � I � I �S I Est. Pressure I Gradient 7VDss UncertairKv FLUID Surface Casing 2,813 2,696.1 -2556 1186 0.44 +/-50' BEL 110 Sand i Shales I Coals Water r Gas 3,567 3,417.7 -3278 1504 0.44 +/- 50' Top Tyonek Unconformitj Sand / Shales , Coats Water Gas 3,961 3,807.7 -3668 1675 0.44 +/- 50' T-6 Sand 1 Shates i Coals Gas 4.315 4.159.0 -4019 1830 0.44 +1-50' T 17 Sand i Shnim; ; 154101% Gns 5,445 5,278.3 -5138 2322 044 +/-50' T-55 Sand / Shates Cuals Gas 0,613 6,433.7 -0294 2831 0.44 +/-50' T-90 Sand (Shales / Coats Gas 7,320 7,134.4 -6994 3139 0.44 +/- 50' T-146 Sand r Shales ; Coals Gas 8,048 7,855.5 -7715 2671 0.34 +l- 50' T-150 Sand I Shales Coals Water i Gas 8,242 8,046.9 -7907 3541 0.44 +/- 50' T-160 Sand / Shales! Cuals Water i Gas 8,359 8,163.0 -8023 3592 0.44 +!- 50' T-170 Sand / Shales Coals Water + Gas 8,594 8,395.8 -8256 3694 0.44 +l- 50' 7-180 Sand t Shales i Coals Water / Gas 8,699 8,500.1 -8360 3740 0.44 +/-50' T-190 Sand / Shales 1 Cuals Water r Gas 8,811 8,610.8 -8471 3789 0.44 +/ 50' T-200 Sand t Shales i Coals Water I Gas 8.891 8,689.6 -8550 3823 0.44 +l- 50' TD 9,138 8,935.1 -8795 3931 0.44 +l- 50' 300 FT Mudiog to include chromatograph, pixler plots, show reports, 30ft sample intervals and two sets of samples washed and dried. GR/Res in surface hole. Triple Combo in production hole Dipole sonic in production hole. Dipmeter (FMI) in surface and production holes None Page 37 Version 0 March, 2023 PEARL 10 Drilling Procedure REV 0 Hilcorp 25.0 Anticipated Drilling Hazards 9-7/8" Hole Section: Lost Circulation: 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. No abnormal pressures or temperatures are present in this hole section. Page 38 Version 0 March, 2023 0 Hilc T Energy Com . 6-3/4" Hole Section: PEARL 10 Drilling Procedure REV 0 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. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. 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. Hole stability issues in the Tyonek were seen in Pearl 2A (March, 2022). Weight up of 0.5ppg from 9.3ppg to 9.8ppg allowed for openhole logging and liner running/cementing. Pearl 9 needed 9.7ppg, Pearl 8 needed 9.5ppg, and Paxton 6 needed 9.4ppg. 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. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 39 Version 0 March, 2023 HilwEnergy Company 26.0 Hilcorp Rig 169 Layout 11147 PEARL 10 Drilling Procedure REV 0 Page 40 Version 0 March, 2023 27.0 FIT/LOT Procedure Formation Inteerity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: PEARL 10 Drilling Procedure REV 0 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 41 Version 0 March, 2023 Hilcorp Ewa COMPZY PEARL 10 Drilling Procedure REV 0 28.0 Choke Manifold Schematic 9 Page 42 Version 0 March, 2023 Hilcorp EneW Company PEARL 10 Drilling Procedure REV 0 29.0 Casing Design Information Calculation & Casing Design Factors Hole Size 9-7/8" Hole Size 6-3/4" Hole Size DATE: 03128/2023 WELL: Pearl 10 FIELD: Ninilchik DESIGN BY: Frank Roach Design Criteria: Mud Density: 9.0 ppg Mud Density: 9.8 ppg Mud Density: Drilling Mode MASP: 3038 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 3038 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.45 psi/ft) and the casing evacuated for the internal stress Page 43 Version 0 March, 2023 Casing Section Calculation/Specification 1 2 3 4 Casing OD 7-5/8" 4-1/2" Top (MD) 0 0 Top (TVD) Bottom (MD) 0 2,813 0 9,138 Bottom (TVD) 2,696 8,935 Length 2,813 9,138 Weight (ppf) 29.7 12.6 Grade L-80 L-80 Connection CDC JFE LION Weight w/o Bouyancy Factor (lbs) 83,546 115,139 Tension at Top of Section (lbs) 198,685 115,139 Min strength Tension (1000 lbs) 683 288 Worst Case Safety Factor (Tension) 3.44 2.50 Collapse Pressure at bottom (Psi) 1,213 4,021 Collapse Resistance w/o tension (Psi) 4,790 7,500 Worst Case Safety Factor (Collapse) 3.95 1.87 MASP (psi) 908 3,038 Minimum Yield (psi) 6,880 8,130 Worst case safety factor (Burst) 7.58 2.77 Page 43 Version 0 March, 2023 HilcoT Energy Company 30.0 6-3/4" 11 !VIC= PEARL 10 Drilling Procedure REV 0 Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4" Hole Section WELL: Pearl 10 FIELD: Ninilchik Planned Top Planned TD: Anticipated Formations and Pressures: MD TVD 2,813 2,696 9,138 8,935 Formation TVD Est Pressure Oil/Gas/Wet PPG Grad BEL -110 3418 1504 Water / Gas 8.46 0.440 Top Tyonek Unconformity 3808 1675 Water / Gas 8.46 0.440 T-6 4159 1830 Gas 8.46 0.440 T-17 5278 2322 Gas 8.46 0.440 T-55 6434 2831 Gas 8.46 0.440 T-90 7134 3139 Gas 8.46 0.440 T-146 7856 2671 Gas 6.54 0.340 T-150 8047 3541 Water / Gas 8.46 0.440 T-160 8163 3592 Waler / Gas 8.46 0.440 T-170 8396 3694 Water / Gas 8.46 0.440 T-180 8500 3740 Water / Gas 8.46 0.440 T-190 8611 3789 Water / Gas 8.46 0.440 T-200 869n 3823 Water f Gas 846 n.44n TD 8935 3931 Gas 8.46 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date Paxton 11 9.0-9.5 1,380 5,023 2022 Pearl 2A 9.0-9.8 1,863 8,165 2022 Paxton 6 9.1-9.4 1,735 8,111 2022 Pearl 8 9.0-9.5 2,675 8,296 2022 Pearl 9 9.0-9.7 1 2,565 8,334 2022 Assumptions: 1. Fracture gradient at shoe (2696' TVD) is estimated at >16.0 ppg based on sonic data and offset LOT data. 2. Maximum planned mud density for the 6-3/4" hole section is 9.8 ppg for hole stability. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 100% evacuation of wellbore to gas. Fracture Pressure at 7-5/8" shoe considering a full column of gas from shoe to surface: TVD Frac Grad 2696 ft X 0.860 psi/ft 2319 psi Downhole 2319(psi) - [0.1(psi/ft)*2696(ft)]= 2049 psi Surface MASP from pore pressure during production mode (Complete evacuation to gas) 8935 ft X 0.440 psi/ft 3931 psi Downhole 3931(psi) - [0.1(psi/ft)* 8935 (ft)]= 3038 psi Surface Summary: 1. MASP while drilling 6-3/4" production hole is governed by frac pressure at 7-5/8" shoe with entire wellbore evacuated to gas Page 44 Version 0 March, 2023 Hilcorp Energy C�mpmy 31.0 PEARL 10 Drilling Procedure REV 0 0 600 1,200 Pearl 10 Feet wp04 Alaska State Plane Zone 4, NAD27 Ilih—p %I -k.- I-I'l Map Dew 312012023 Page 45 Version 0 March, 2023 PEARL 10 0 Drilling Procedure REV 0 Hilcorp sR�18y 32.0 Suri .ace Flat (As -Staked NAD2 i 3 FND W.0 M C _3 24 �7 M END SEC SNSUBDIVIDED N: 2225883.80 PROPCRTY DN6 • _ • • • • E: 1343943.09: 111 u ' (TYPICAL) NAD27 Ll N: 2226125.25J E: 203923.4 •. .. /PFARL n t __- +--�-� 714' FEL % PEARL 410 7IT FEL LOT 1 'I I HM 78-59 '•\ ®PEARL NIA t ®PEARL ►B I '\ 1 PEARL 89 •\ ` j —` PEARL DRILL PAD TR D1 4y4\ �Qn HM 2002-09 ! 111 \ fit._ IUI TR. E-1 LOT 4 HM 2002.09 \ 1` oI HM 78.59 t � y� \ ' - I Igo' � °!y4 ` All *:•� •*gyp 850326. .:.�_ jam.. v CONTROL NOTE ��GN 1. BASIS OF HORIZONTAL DATUM IS NORTH AMERICA DATUM 1983. ALASKA STATE PLANE FND w C ZONE 4, US SURVEY FEET. N6 2 BASIS OF VERTICAL DATUM IS NORTH AMERICA VERTICAL DATUM 88. 3 BASIS OF COORDINATES IS ADOT CONTROL POINT WITH ALASKA STATE PLANE COORDINATES (ASP) ZONE 4 N• 2224638.763 E • 1343896.062 ELEV' t75 997' (NAVD88 GEOID 12ELAKI 4 DATUM TRANSFORMATIONS FROM NAD83 TO NAD27 WERE DONE USING CORPSCON FNL I FEL I ELEV S&M E 0 '00 200 rtr imEw _ I mA, • 200 It a HILCORP ALASKA. LLC PEARL PAD PEARL #10 & #11 WELLS AS -STAKED SURFACE LOCATION �.� M enA1fT b SECTION 23, T1 R14W v cwry cwew<w Ililrorp llu.l u. LLI SEWARD MERIDIAN. ALASKA Page 46 Version 0 March, 2023 AS -STAKED SURFACE LOCATION TABLE WELLN NAD83 LATITUDE NAD83 LONGITUDE NAD83 NORTHING NAD83 EASTING PEARL 1130 N 60.04' 55.38' W 151.37' 39.79' 2225S40.T 1343217.2' PEARL NI I N 60'04'55.80" W 151' 37'39.72" 2225582.3' 1343221.8' WELL NAD27 LATITUDE NAD27 LONGITUDE NA027 NORTHING NAD27 EASTING PEARL #10 N 60' 04'57.53" W 151'37'31.84- 2225781.7' 203197.5' PEARL 411 N 60' 04' 57.95' W 151' 37' 31.77" 2225823.8' 203202.1' FNL I FEL I ELEV S&M E 0 '00 200 rtr imEw _ I mA, • 200 It a HILCORP ALASKA. LLC PEARL PAD PEARL #10 & #11 WELLS AS -STAKED SURFACE LOCATION �.� M enA1fT b SECTION 23, T1 R14W v cwry cwew<w Ililrorp llu.l u. LLI SEWARD MERIDIAN. ALASKA Page 46 Version 0 March, 2023 Hilcorp Alaska, LLC Ninilchik Unit Pearl Pad Pearl 10 Pearl 10 Plan: Pearl 10 wp04 Standard Proposal Report 29 March, 2023 HALLIBURTON - Sperry Drilling Services HALLIBURTON 4500 121.90 Hilcorp Alaska, LLC Longitude REFERENCE INFORMATION N 151 °37' 31.8410 - ---- SURVEY PROGRAM Date: 2023-03-21T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature W4800 Co-ordinate (N/E) Reference: Well Pearl 10, True North Sperry Orilling 2696.42 2556.52 2813.00 7-5/8 75/8"x97/8" 18.00 2813.00 Pearl 10 wp04 (Pearl 10) 3_MWD+AX+Sag 2813.00 9138.44 Pead 10 wp04 (Pearl 10) Error System: ISCWSA Vertical (TVD) Reference: Pearl 10 as staked RKB @ 139.90usft j T-17 Scan Method: Closest Approach 3D 35400 Measured Depth Reference: Pearl 10 as staked RKB @ 139.90usft Error Surface: Ellipsoid Separation Calculation Method: Minimum Curvature 6000 Project: Ninilchik Unit 6000 Warning Method: Error Ratio Site: Pearl Pad Well; Pearl 10 T-55 SECTION DETAILS ec 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 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Dir 31/100' :300' MD, 300'TVD 3 941.50 19.24 72.73 929.50 31.68 101.92 3.00 72.73 106.72 End Dir : 941.5' MD, 929.5' TVD 4 3192.87 19.24 72.73 3055.06 251.98 810.53 0.00 0.00 848.73 Start Dir 31/100': 3192.87' MD, 3055.06'TVD 5 3567.05 8.02 71.99 3418.12 278.44 894.51 3.00 -179.47 936.78 Pead 10 wp01 tgtl End Dir : 3567.05' MD, 3418.12' TVD 6 8638.44 8.02 71.99 8439.90 497.19 1567.47 0.00 0.00 1644.39 Pearl 10 wp01 tgt2 7 9138.44 8.02 71.99 8935.01 518.76 1633.82 0.00 0.00 1714.16 Total Depth : 9138.44' MD, 8935.01' TVD 0 Start Dir 34/100' : 300' MD, 300'TVD 600 500 End Dir : 941.5' MD, 929.5' TVD 10p0 1200 `500 WELL DETAILS: Pead 10 4500 121.90 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 2225781.700 203197.500 60°4' 57.5342 N 151 °37' 31.8410 SURVEY PROGRAM Date: 2023-03-21T00:00:00 Validated: Yes Version: W4800 Depth From Depth To Survey/Plan Tool 2696.42 2556.52 2813.00 7-5/8 75/8"x97/8" 18.00 2813.00 Pearl 10 wp04 (Pearl 10) 3_MWD+AX+Sag 2813.00 9138.44 Pead 10 wp04 (Pearl 10) 3_MWD+AX+Sag 1800 Zp00 2400- - 400 2500 Start Dir 34/100' : 3192.87' MD, 3055.067VD 7 5/8" x 9 7/8" 30p0 3000 BEL -110 Pearl 10 wp01 tgtl End Dir : 3567.05' MD, 3418.12' TVD X500 c 3600 rn Top Tyonek Unconformify 0 4000 0 N , ...13200 E T 6 4500 CASING DETAILS ii m 0 TVD TVDSS MD Size Name W4800 5000 2696.42 2556.52 2813.00 7-5/8 75/8"x97/8" 8935.01 8795.11 9138.44 4-1/2 4 1/2" x 6 3/4" 'C j T-17 35400 5500 6000 Project: Ninilchik Unit 6000 Site: Pearl Pad Well; Pearl 10 T-55 6500 Wellbore: Pearl 10 6600 Design: Pearl 10 wp04 7000 T-90 7500 T-146 8000 T-150 T-160 Pearl 10 wp01 tgt2_ 8500 T-170 _ T-180 - - T-190 8000 4 1/2" x 6 3/4" T-200 Pearl 10 wp01 tgt3 A3$ Pearl 10 wp04 Total Depth: 9138.44' MD, 8935.01' TVD -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 Vertical Section at 72.00° (1200 usft/in) } » ) Gn nm& (+)«om/(- mS \ e k k \ k 2 HALLIBURTON Database: NORTH US + CANADA Company: HlcorpAlaska, LLC Project: Ninichik Unit Site: Peal Pad Well: Peal 10 Wellbore: Peal 10 Design: Peal 10 wp04 Standard Proposal Report Local Co-ordinate Reference: Well Peal 10 TVD Reference: Pearl 10 as staked RKB @ 139.90usft MD Reference: Pearl 10 as staked RKB @ 139.90usft North Reference: True Survey Calculation Method: Minimum Curvature )roject Ninilchik Unit Rap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level xeo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Rap Zone: Alaska Zone 04 Using geodetic scale factor Site Peal Pad Site Position: Northing: 2,224,511.630usft Latitude: 60° 4'45.6700 N From: Map Easting: 205,854.039usft Longitude: 151' 36'38.8781 W Position Uncertainty: 0.00 usft Slot Radius: 13.3/16" Grid Convergence: -1.40 ° Well Pead 10 Well Position +N/ -S 0.00 usft Northing: 2,225,781.700 usft Latitude: 60° 4' 57.5342 N +E/ -W 0.00 usft Easting: 203,197.500 usft Longitude: 151 ° 37' 31.8410 W Position Uncertainty 1.00 usft Wellhead Elevation: usft Ground Level: 121,90usft Wellbore Peal 10 Magnetics Model Name Sample Date Declination Dip Angie Field Strength (°) (°) (nT) BGGM2022 3/30/2023 13.81 72.86 54,733.10265178 i Design Pearl 10 wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From (TVD) +N/ -S +66W Direction (usft) (usft) (usft) (°) 18,00 0.00 0.00 72.00 Plan Sections Measured Vertical TVD Dogleg Bund Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tod Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 18.00 0.00 0.00 18.00 -121.90 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 160.10 0.00 0.00 0.00 0.00 0.00 0.00 941.50 19.24 72.73 929.50 789.60 31.68 101.92 3,00 3.00 0.00 72.73 3,192.87 19.24 72.73 3,055.06 2,915.16 251.98 810.53 0,00 0.00 0.00 0.00 3,567.05 8.02 71.99 3,418.12 3,278.22 27&44 894.51 3.00 -3.00 -0.20 -179.47 8,638.44 8,02 71.99 8,439.90 8,300.00 497.19 1,567.47 0,00 0.00 0.00 0.00 9,13&44 8.02 71.99 8,935.01 8.795.11 51&76 1,633.82 0.00 0.00 0.00 0.00 3/29/2023 2:53:50PM Page 2 COMPASS 5000 15 Build 91E Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Peal 10 Company: Hlcorp Alaska, LLC TVD Reference: Pearl 10 as staked RKB @ 139.90usft Project: Ninlchik Unit MD Reference: Pearl 10 as staked RKB @ 139.90usft Site: Pearl Pad North Reference: True Well: Peart 10 Survey Calculation Method: Minimum Curvature Wellbore: Peal 10 (°) (°) Design: Pearl 10 wp04 (usft) (usft) Planned Survey Measured Vertical Map Map 1,000.00 19.24 Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -121.90 1,200.00 18.00 0.00 0.00 18.00 -121.90 0.00 0.00 2,225,781.700 203,197.500 0.000 0.00 100.00 0.00 0.00 100.00 -39.90 0.00 0.00 2,225,781.700 203,197.500 0.000 0.00 200.00 0.00 0.00 200.00 60.10 0.00 0.00 2,225,781.700 203,197.500 0.000 0.00 300.00 0.00 0.00 300.00 160.10 0.00 0.00 2,225,781.700 203,197.500 0.000 0.00 Start Dir 31/100' : 300' MD, 300'TVD 1,551.21 1,411.31 96.12 309.18 2,225,870.186 203,508.948 0.000 400.00 3.00 72.73 399.95 260.05 0.78 2.50 2,225,782.415 203,200.018 3.000 2.62 500.00 6.00 72.73 499.63 359.73 3.11 9.99 2,225,784,559 203,207.564 3.000 10.46 600.00 9.00 72.73 598.77 458.87 6.98 22.45 2,225,788.126 203,220.118 3.000 23.51 700.00 12.00 72.73 697.08 557,18 12.39 39.85 2,225,793.106 203,237,646 3.000 41.73 800.00 15.00 72.73 794.31 654.41 19.32 62.14 2,225,799.485 203,260.099 3.000 65.07 900.00 18.00 72.73 890.18 750.28 27.75 89.26 2,225,807.246 203,287.417 3.000 93.47 941.50 19.24 72.73 929.51 789.61 31.68 101.92 2,225,810.868 203,300.164 3.000 106.72 End Dir : 941.5' MD, 929.5' TVD 1,000.00 19.24 72.73 984.74 844.84 37.41 120.33 2,225,816.138 203,318.712 0.000 126.00 1,100.00 19.24 72.73 1,079.15 939.25 47.19 151.80 2,225,825.146 203,350.418 0.000 15&96 1,200.00 19.24 72.73 1,173.56 1,033.66 56.98 183.28 2,225,834.154 203,382.124 0.000 191.92 1,300.00 19.24 72.73 1,267.97 1,12&07 66.76 214.75 2,225,843.162 203,413.830 0.000 224.87 1,400.00 19.24 72.73 1,362.38 1,222.48 76.55 246.23 2,225,852.170 203,445.536 0.000 257.83 1,500.00 19.24 72.73 1,456.80 1,316.90 86.33 277.70 2,225,861.178 203,477.242 0.000 290.79 1,600.00 19.24 72.73 1,551.21 1,411.31 96.12 309.18 2,225,870.186 203,508.948 0.000 323.75 1,700.00 19.24 72.73 1,645.62 1,505.72 105.90 340.65 2,225,879.194 203,540.654 0.000 356.71 1,800.00 19.24 72.73 1,740.03 1,600.13 115.69 372.13 2,225,88&202 203,572.360 0.000 389.66 1,900.00 19.24 72.73 1,834.44 1,694.54 125.47 403.60 2,225,897.210 203,604.066 0.000 422.62 2,000.00 19.24 72.73 1,928.85 1,78&95 135.26 435.08 2,225,906.218 203,635.772 0.000 455.58 2,100.00 19.24 72.73 2,023.27 1,883.37 145.04 466.55 2,225,915.226 203,667.478 0.000 48&54 2,200.00 19.24 72.73 2,117.68 1,977.78 154.83 49&03 2,225,924.234 203,699.184 0.000 521.50 2,300.00 19.24 72.73 2,212.09 2,072.19 164.61 529.50 2,225,933.242 203,730.890 0.000 554.45 2,400.00 19.24 72.73 2,306.50 2,166.60 174.40 560.98 2,225,942.250 203,762.596 0.000 587.41 2,500.00 19.24 72.73 2,400.91 2,261.01 184.18 592.45 2,225,951.258 203,794.302 0.000 620.37 2,600.00 19.24 72.73 2,495.32 2,355.42 193.97 623.93 2,225,960.266 203,826.008 0.000 653.33 2,700.00 19.24 72.73 2,589.74 2,449.84 203.75 655.40 2,225,969.274 203,857.714 0.000 686.29 2,800.00 19.24 72.73 2,684.15 2,544.25 213.54 686.88 2,225,978.282 203,889.420 0.000 719.25 2,813.00 19.24 72.73 2,696.42 2,556.52 214.81 690.97 2,225,979.453 203,893.542 0.000 723.53 7 5/8" x 9 7/8" 2,900.00 19.24 72.73 2,778.56 2,63&66 223.32 718.35 2,225,987.290 203,921.126 0.000 752.20 3,000.00 19.24 72.73 2,872.97 2,733.07 233.11 749.83 2,225,996.298 203,952.832 0.000 785.16 3,100.00 19.24 72.73 2,967.38 2,827.48 242.89 781.30 2,226,005.306 203,984.538 0.000 818.12 3,192.87 19.24 72.73 3,055.06 2,915.16 251.98 810.53 2,226,013.672 204,013.984 0.000 848.73 Start Dir 311100' : 3192.87' MD, 3055.06'TVD 3,200.00 19.03 72.72 3,061.80 2,921.90 252.67 812.76 2,226,014.311 204,016.232 3.000 851.07 3,300.00 16.03 72.62 3,157.14 3,017.24 261.64 841.52 2,226,022.569 204,045.197 3.000 881.18 3,400.00 13.03 72.48 3,253.93 3,114.03 269.16 865.45 2,226,029.498 204,069.309 3.000 906.27 3,500.00 10.03 72.24 3,351.90 3,212.00 275.21 884.50 2,226,035.080 204,088.502 3.000 926.26 3,566.42 8.04 72.00 3,417.50 3,277.60 27&41 894.43 2,226,038.035 204,098.506 3.000 936.69 BEh110 3/2.912023 2,53:50PM Pace 3 COMPASS 5000 15 Build 91E HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Peal 10 Company: Hlcorp Alaska, LLC TVD Reference: Pearl 10 as staked RKB @ 139.90usft Project: Ninichik Unit MD Reference: Pearl 10 as staked RKB @ 139.90usft Site: Peal Pad North Reference: True Well: Peal 10 Survey Calculation Method: Minimum Curvature Wellbore: Peal 10 Design: Peal 10 wp04 Planned Survey Measured Vertical Map Map Depth Indination Azimuth Depth TVDss +NAS +E/-W Northing Easting DLS Vert Section (usft) (°) (I (usft) usft (usft) (usft) (usft) (usft) 3,27&22 3,567.05 8.02 71.99 3,418.12 3,278.22 278.44 894.51 2,226,038.060 204,098.590 2,996 936.78 End Dir : 3567.05' MD, 341&12' TVD 3,600.00 8.02 71.99 3,450.75 3,310.85 279.86 898.89 2,226,039.373 204,102.996 0.000 941.37 3,700.00 &02 71.99 3,549.77 3,409.87 284.17 912.16 2,226,043,359 204,116,368 0.000 955.33 3,800.00 8.02 71.99 3,648.79 3,508,89 288.49 925.43 2,226,047,345 204,129,739 0.000 969.28 3,900.00 &02 71.99 3,747.81 3,607.91 292.80 938.69 2,226,051.331 204,143.111 0.000 983.23 3,960.28 8.02 71.99 3,807.50 3,667.60 295.40 946.69 2,226,053,734 204,151.171 0,000 991,64 Top Tyonek Unconformity 4,000.00 &02 71.99 3,846.84 3,706.94 297.12 951.96 2,226,055.317 204,156.483 0.000 997.19 4,100.00 8.02 71.99 3,945.86 3,805.96 301.43 965.23 2,226,059.303 204,169.854 0.000 1,011,14 4,200.00 8.02 71.99 4,044.88 3,904,98 305.74 978.50 2,226,063,289 204,183.226 0.000 1,025.09 4,300.00 &02 71.99 4,143.90 4,004,00 310.06 991.77 2,226,067,275 204,196,598 0.000 1,039.04 4,315.05 8.02 71.99 4,158.80 4,01&90 310.70 993.77 2,226,067.874 204,19&610 0.000 1,041.14 T-6 4,400.00 8.02 71.99 4,242.92 4,103.02 314.37 1,005.04 2,226,071.261 204,209.970 0.000 1,053.00 4,500.00 8.02 71.99 4,341.94 4,202.04 31&68 1,01&31 2,226,075.246 204,223.341 0.000 1,066.95 4,600.00 8.02 71.99 4,440.97 4,301.07 323.00 1,031.58 2,226,079.232 204,236.713 0.000 1,080.90 4,700.00 8.02 71.99 4,539.99 4,400.09 327.31 1,044.85 2,226,083.218 204,250.085 0.000 1,094.86 4,800.00 &02 71.99 4,639.01 4,499.11 331.62 1,05&12 2,226,087.204 204,263.456 0.000 1,10&81 4,900.00 8.02 71.99 4,738.03 4,59&13 335.94 1,071.39 2,226,091.190 204,276.828 0.000 1,122.76 5,000.00 8.02 71.99 4,837.05 4,697.15 340.25 1,084.66 2,226,095.176 204,290.200 0.000 1,136.72 5,100.00 8.02 71.99 4,936.08 4,796.18 344.56 1,097.93 2,226,099.162 204,303.571 0.000 1,150.67 5,200.00 8.02 71.99 5,035.10 4,895.20 34&88 1,111.20 2,226,103.148 204,316.943 0.000 1,164.62 5,300.00 8.02 71.99 5,134.12 4,994.22 353.19 1,124.47 2,226,107.134 204,330.315 0.000 1,17&58 5,400.00 8.02 71.99 5,233.14 5,093.24 357.50 1,137.74 2,226,111.119 204,343.686 0.000 1,192.53 5,445.40 &02 71.99 5,278.10 5,13&20 359.46 1,143.76 2,226,112.929 204,349.758 0.000 1,19&86 T-17 5,500.00 8.02 71.99 5,332.16 5,192.26 361.82 1,151.01 2,226,115.105 204,357.058 0.000 1,206.48 5,600.00 8.02 71.99 5,431.18 5,291.28 366.13 1,164.28 2,226,119.091 204,370.430 0.000 1,220.44 5,700.00 8.02 71.99 5,530.21 5,390.31 370.44 1,177.55 2,226,123.077 204,383.801 0.000 1,234.39 5,800.00 8.02 71.99 5,629.23 5,489.33 374.76 1,190.82 2,226,127.063 204,397.173 0.000 1,24134 5,900.00 8.02 71.99 5,728.25 5,58&35 379.07 1,204.09 2,226,131.049 204,410.545 0.000 1,262.29 6,000.00 8.02 71.99 5,827.27 5,687.37 383.39 1,217.36 2,226,135.035 204,423.916 0.000 1,276.25 6,100.00 8.02 71.99 5,926.29 5,786.39 387.70 1,230.63 2,226,139.021 204,437.288 0.000 1,290.20 6,200.00 8.02 71.99 6,025.31 5,885.41 392.01 1,243.90 2,226,143.007 204,450.660 0.000 1,304.15 6,300.00 8.02 71.99 6,124.34 5,984.44 396.33 1,257.17 2,226,146.992 204,464.031 0.000 1,318,11 6,400.00 &02 71.99 6,223.36 6,083.46 400.64 1,270.44 2,226,150.978 204,477.403 0.000 1,332.06 6,500.00 &02 71.99 6,322.38 6,182.48 404.95 1,283.70 2,226,154.964 204,490.775 0.000 1,346.01 6,600.00 8.02 71.99 6,421.40 6,281.50 409.27 1,296.97 2,226,15&950 204,504.146 0.000 1,359.97 6,612.22 8.02 71.99 6,433.50 6,293.60 409.79 1,29&60 2,226,159.437 204,505.780 0.000 1,361.67 T-55 6,700.00 &02 71.99 6,520.42 6,380.52 413.58 1,310.24 2,226,162.936 204,517.518 0.000 1,373.92 6,800.00 8.02 71.99 6,619.45 6,479.55 417.89 17323.51 2,226,166.922 204,530.890 0.000 1,387.87 6,900.00 8.02 71.99 6,718.47 6,578.57 422.21 1,336.78 2,226,170.908 204,544.262 0.000 1,401.83 7,000.00 8.02 71.99 6,817.49 6,677.59 426.52 1,350.05 2,226,174.894 204,557.633 0.000 1,415.78 3/29/2023 2 53.50PM Page 4 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Map Company: Hilcorp Alaska, LLC +N/ -S Project: Ninlchik Unit Easting DLS Vert Section Site: Peal Pad (usft) (usft) 6,776.61 Well: Peal 10 1,363.32 2,226,178.880 204,571.005 Wellbore: Peal 10 435.15 1,376.59 2,226,182.865 Design: Peal 10 wp04 1,443.68 439.46 Planned Survey 2,226,186.851 204,597.748 0.000 1,457.64 Measured 1,392.49 2,226,187.642 Vertical 0.000 Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 7,100.00 8.02 71.99 6,916.51 6,776.61 7,200.00 8.02 71.99 7,015.53 6,875.63 7,300.00 8.02 71.99 7,114.55 6,974.65 7,319.84 8.02 71.99 7,134.20 6,994.30 T-90 1,527.40 465.34 1,469.48 2,226,210.767 7,400.00 8.02 71.99 7,213.58 7,073.68 7,500.00 &02 71.99 7,312.60 7,172.70 7,600.00 8.02 71.99 7,411.62 7,271,72 7,700.00 &02 71.99 7,510.64 7,370.74 7,800.00 &02 71.99 7,609.66 7,469.76 7,900.00 &02 71.99 7,708.68 7,568.78 8,000.00 8.02 71.99 7,807.71 7,667.81 8,04&06 &02 71.99 7,855.30 7,715.40 T-146 2,226,229.046 204,739.301 0.000 1,605.35 8,100.00 8.02 71.99 7,906.73 7,766.83 8,200.00 8.02 71.99 8,005.75 7,865.85 8,241.35 8.02 71.99 8,046.70 7,906.80 T-150 0.000 1,63&15 495.54 1,562.37 8,300.00 8.02 71.99 8,104.77 7,964.87 8,358.60 8.02 71.99 8,162.80 8,022.90 T-160 1,575.51 2,226,242.615 204,784.822 0.000 8,400.00 8.02 71.99 8,203.79 8,063.89 8,500.00 8.02 71.99 8,302.82 8,162.92 8,593.70 8.02 71.99 8,395,60 8,255.70 T-170 204,799.771 0.000 1,668.44 508.06 8,600.00 8.02 71.99 8,401.84 8,261.94 8,63&44 8.02 71.99 8,439.90 8,300.00 8,699.03 8.02 71.99 8,499.90 8,360.00 T-180 1,694.84 517.10 1,62&72 2,226,25&597 8,700.00 8.02 71.99 8,500.86 8,360.96 8,800.00 8.02 71.99 8,599.88 8,459.98 8,810.83 8.02 71.99 8,610.60 8,470.70 T-190 8,890.40 8.02 71.99 8,689.40 8,549.50 T-200 8,900.00 8.02 71.99 8,698.90 8,559.00 9,000.00 8.02 71.99 8,797.92 8,65&02 9,100.00 8.02 71.99 8,896.95 8,757.05 9,13&44 8.02 71.99 8,935.01 8,795.11 Total Depth : 9138.44' MD, 8935.01' TVD Standard Proposal Report Local Co-ordinate Reference: Well Peal 10 TVD Reference: Pearl 10 as staked RKB @ 139.90usft MD Reference: Pearl 10 as staked RKB @ 139.90usft North Reference: True Survey Calculation Method: Minimum Curvature 3/29/2023 2:53.50PM Page 5 COMPASS 5000 15 Build 91E Map Map +N/ -S +E/ W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 6,776.61 430.83 1,363.32 2,226,178.880 204,571.005 0.000 1,429.73 435.15 1,376.59 2,226,182.865 204,584.377 0.000 1,443.68 439.46 1,389.86 2,226,186.851 204,597.748 0.000 1,457.64 440.32 1,392.49 2,226,187.642 204,600.401 0.000 1,460.41 443.77 1,403.13 2,226,190.837 204,611.120 0.000 1,471.59 448.09 1,416.40 2,226,194.823 204,624.492 0.000 1,485.54 452.40 1,429.67 2,226,198.809 204,637.863 0.000 1,499.50 456.71 1,442.94 2,226,202.795 204,651,235 0.000 1,513.45 461.03 1,456.21 2,226,206.781 204,664,607 0.000 1,527.40 465.34 1,469.48 2,226,210.767 204,677,978 0.000 1,541.36 469.66 1,482.75 2,226,214.753 204,691.350 0.000 1,555.31 471.73 1,489.13 2,226,216.668 204,697.777 0.000 1,562.02 473.97 1,496.02 2,226,21&738 204,704.722 0.000 1,569.26 478.28 1,509.29 2,226,222.724 204,718.093 0.000 1,583.22 480.07 1,514.78 2,226,224.373 204,723.623 0.000 1,58&99 482.60 1,522.56 2,226,226.710 204,731.465 0.000 1,597.17 485.12 1,530.33 2,226,229.046 204,739.301 0.000 1,605.35 486.91 1,535.83 2,226,230.696 204,744.837 0.000 1,611.12 491.22 1,549.10 2,226,234.682 204,75&208 0.000 1,625.08 495.26 1,561.53 2,226,238.417 204,770.738 0.000 1,63&15 495.54 1,562.37 2,226,23&668 204,771.580 0.000 1,639.03 497.19 1,567.47 2,226,240.200 204,776.720 0.000 1,644.39 499.81 1,575.51 2,226,242.615 204,784.822 0.000 1,652.85 499.85 1,575.64 2,226,242.654 204,784.952 0.000 1,652.98 504.16 1,588.91 2,226,246.640 204,798.323 0.000 1,666.93 504.63 1,590.34 2,226,247.071 204,799.771 0.000 1,668.44 508.06 1,600.90 2,226,250.243 204,810.412 0.000 1,679.55 50&48 1,602.18 2,226,250.626 204,811.695 0.000 1,680.89 512.79 1,615.45 2,226,254.611 204,825.067 0.000 1,694.84 517.10 1,62&72 2,226,25&597 204,838.438 0.000 1,70&79 518.76 1,633.82 2,226,260.129 204,843.578 0.000 1,714.16 3/29/2023 2:53.50PM Page 5 COMPASS 5000 15 Build 91E HALL1BURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Pearl 10 Company: Hicorp Alaska, LLC TVD Reference: Pearl 10 as staked RKB @ 139.90usft Project: Ninichik Unit MD Reference: Pearl 10 as staked RKB @ 139.90usft Site: Pearl Pad North Reference: True Well: Pearl 10 Survey Calculation Method: Minimum Curvature Wellbore: Peal 10 +N/ -S +EDW (usft) Design: Pearl 10 wp04 Comment 0.00 0.00 Start Dir 30/100' : 300' MD, 300'TVD 31.68 Targets End Dir : 941.5' MD, 929.5' TVD 251.98 810.53 Start Dir 31/100' : 3192.87' MD, 3055.06'TVD 278.44 Target Name End Dir : 3567.05' MD, 3418.12' TVD 518.76 1,633.82 Total Depth: 913&44' MD, 8935.01' TVD - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E -W - Shape (°) (I (usft) (usft) (usft) Pearl 10wp01 tgt3 0.00 0.00 8,935.01 51&74 1,633.75 - plan misses target center by 0.07usft at 9138.43usft MD (8935.00 TVD, 518.76 N, 1633.81 E) - Point Pearl 10 wp01 tgt2 0.00 0.00 8,439.90 497.19 1,567.47 - plan hits target center -Point Pead 10wp01 tgtl 0.00 0.00 3,418.12 27&44 894.51 - plan hits target center - Point 2,813.00 2,696.42 7 5/8" x 9 7/8" 9,138.44 8,935.01 4 1/2" x 6 3/4" Formations Measured Depth (usft) 7,319.84 8,358.60 3,960.28 8,593.70 3,566.42 8,048.06 5,445.40 6,612.22 8,241.35 8,810.83 8,890.40 4,315.05 8,699.03 Plan Annotations Measured Depth (usft) 300.00 941.50 3,192.87 3,567.05 9,138.44 Vertical Depth (usft) 7,134.20 8,162.80 3,807.50 &395.60 3,417.50 7,855.30 5,27&10 6,433.50 8,046.70 8,610.60 8,689.40 4,15&80 8,499.90 Vertical Depth (usft) 300.00 929.51 3,055.06 3,418.12 8,935.01 Vertical Depth SS Name T-90 T-160 Top Tyonek Unconformity T-170 BEL_110 T-146 T-17 T-55 T-150 T-190 T-200 T-6 T-180 Lithology Northing Easting (usft) (usft) 2,226,260.110 204,843.510 2,226,240.200 204,776.720 2,226,038.060 204.09&590 7-5/89.7/8 4-1/2 6.3/4 Local Coordinates +N/ -S +EDW (usft) (usft) Comment 0.00 0.00 Start Dir 30/100' : 300' MD, 300'TVD 31.68 101.92 End Dir : 941.5' MD, 929.5' TVD 251.98 810.53 Start Dir 31/100' : 3192.87' MD, 3055.06'TVD 278.44 894.51 End Dir : 3567.05' MD, 3418.12' TVD 518.76 1,633.82 Total Depth: 913&44' MD, 8935.01' TVD Dip Dip Direction (1 (°) 3/29/2023 2:53.50PM Page 6 COMPASS 5000.15 Build 91E v L m C 0 L L 01 Q U) N 7 Co R 0 o 0 N C O U m N N CO) aQ N w L N d M _Q O A, M O W X x + L N O � c Lr)i � O O N J d N N ,�NwL io ■� � a' o c o c r W o m� a A! o m 3 m `R LC LL � oot ami mLu a O NdZ� ma d y N m d Q-WV .C, ■ �/� o a vri c M � '= p L M a dN�oi"Q�� O o aN'_a°2 IS m. 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O _ p p 1N Lo l tcam Zx¢ Z „z -- o -- -- - O LO� � mooE TO I N ^'mm� o moo O co Ocu zm� P inaa w ¢¢¢ ir w v amy o go c ---- ----- -__.------ Cl j .. 0 Ln O _ _...- O j p M O O CD Ln N co m zaaaa o o _ d - Oa - -- - - ----- ----- ---- - -- O N N .0 CL p CL cz -CD_.. occ 5 tm c - I ---1--- o CD c O o 0 --._ ------ --`-- Z CD Y o cc cu "O O > _ N r N y O O r LLO O .V1 fT�S m U U Z m c L M p O q q q 1 q. o o c J a o O > m m L o c LQ Q L o m u> o m a a " ch joloe-A uoileaedag o _ �, (ui/4sn 00'09) uoileaedag ailuao of ailuao TRANSMITTAL LETTER CHECKLIST WELL NAME: Pearl 10 PTD: 223-028 X Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Ninilchik POOL: Beluga/Tyonek Gas Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL Number, API Number 50- (If last two digits Production from or injection into this wellbore must be reported under in API number are the original API Number stated above. between 60-69) The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce or inject is contingent upon issuance of a X Exception conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30 -foot sample intervals from below the permafrost or from where samples are first caught and 10 -foot sample intervals through target zones. Please note the following special condition of this permit: Production or Non- production testing of coal bed methane is not allowed for this well until Conventional after the Operator has designed and implemented a water -well testing Well 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. 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: X Well Logging Requirements 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. Revised 7/2022 0 V Zy a' E U M N O N pCC 0 a N W E J U _ ...................................... . , . . , . , , , • , , , , , , r , , • , . . . r , Q , , , , , , , , , , , , , , . , , o a d . . . . . : . . : . : . . . . . ; ; . . . . . . . . . . ; . . `o ; y ' y . n . . . , . . . . . . I C4 0 , . N E O pa 5 a E uy n . . . . , . . ; ; ; ; : pp an y O rE. m a . d c o y 4 N d c3 Q , , . . . . rin O J q t E O N LLf j4 O., N O OL O N' LL . r O e „ o. • E . a ar v as 04 m o W. Ol '1 J a 5. p d `r �, U N N G .p Q -' .30 �v • Qi ' °' v O s G . 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