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DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 0 2 9 - 2 0 1 1 8 - 0 1 - 0 0 We l l N a m e / N o . P R U D H O E B A Y U N I T A - 0 6 A Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 4/ 8 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 1 5 0 Op e r a t o r H i l c o r p N o r t h S l o p e , L L C MD 13 4 5 0 TV D 87 5 0 Cu r r e n t S t a t u s 1- O I L 9/ 5 / 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 : MW D / G R / R E S , R P M No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 4/ 2 4 / 2 0 2 3 10 4 1 8 1 3 4 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A Di g i t a l D a t a . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 1 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 2 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 3 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 4 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 5 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 6 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 7 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 8 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : P B U A - 0 6 A P W D Ru n 0 9 . l a s 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 M D Q C _ L A S Co m p o s i t e . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 2 M D F i n a l L o g . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 2 T V D S S F i n a l Lo g . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 M D F i n a l L o g . c g m 37 6 1 6 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 5 , 2 0 2 5 AO G C C Pa g e 1 o f 4 PB U A - 0 6 A Di git a l D a t a . 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 - 0 2 9 - 2 0 1 1 8 - 0 1 - 0 0 We l l N a m e / N o . P R U D H O E B A Y U N I T A - 0 6 A Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 4/ 8 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 1 5 0 Op e r a t o r H i l c o r p N o r t h S l o p e , L L C MD 13 4 5 0 TV D 87 5 0 Cu r r e n t S t a t u s 1- O I L 9/ 5 / 2 0 2 5 UI C No DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 M D F i n a l Lo g . c g m . m e t a 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 T V D S S F i n a l Lo g . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 1 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 2 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 3 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 4 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 5 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 6 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 7 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 8 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 9 . c g m 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 2 M D F i n a l L o g . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 2 T V D S S F i n a l Lo g . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 M D F i n a l L o g . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 T V D S S F i n a l Lo g . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 1 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 2 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 3 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 4 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 5 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 6 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 7 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 8 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 9 . P D F 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 2 M D F i n a l L o g . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 2 T V D S S F i n a l L o g . t i f 37 6 1 6 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 5 , 2 0 2 5 AO G C C Pa g e 2 o f 4 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 - 0 2 9 - 2 0 1 1 8 - 0 1 - 0 0 We l l N a m e / N o . P R U D H O E B A Y U N I T A - 0 6 A Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 4/ 8 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 1 5 0 Op e r a t o r H i l c o r p N o r t h S l o p e , L L C MD 13 4 5 0 TV D 87 5 0 Cu r r e n t S t a t u s 1- O I L 9/ 5 / 2 0 2 5 UI C No DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 M D F i n a l L o g . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A 5 T V D S S F i n a l L o g . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 1 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 2 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 3 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 4 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 5 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 6 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 7 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 8 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : P B U A - 0 6 A P W D R u n 0 9 . t i f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : A - 0 6 A _ D e f i n i t i v e S u r v e y s . p d f 37 6 1 6 ED Di g i t a l D a t a DF 4/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : A - 0 6 A _ D e f i n i t i v e S u r v e y s . x l s x 37 6 1 6 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 0 1 3 4 5 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ A - 06 A _ M R P M _ G A S V I E W _ 0 6 A P R 2 0 2 3 . l a s 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 10 5 0 0 1 3 3 9 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : PB U _ A _ 0 6 A _ M R P M _ P N C 3 D _ P A S S 1 U P _ 0 6 A P R 20 2 3 _ B H . l a s 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 10 5 0 0 1 3 3 9 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : PB U _ A _ 0 6 A _ M R P M _ P N C 3 D _ P A S S 2 U P _ 0 6 A P R 20 2 3 _ B H . l a s 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ A - 06 A _ M R P M _ G A S V I E W _ 0 6 A P R 2 0 2 3 . m e t a 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ A - 06 A _ M R P M _ G A S V I E W _ 0 6 A P R 2 0 2 3 . P D F 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 E l e c t r o n i c F i l e : PB U _ A _ 0 6 A _ M R P M _ P N C 3 D _ M A I N _ 0 6 A P R 2 0 2 3 _B H . m e t a 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 E l e c t r o n i c F i l e : PB U _ A _ 0 6 A _ M R P M _ P N C 3 D _ M A I N _ 0 6 A P R 2 0 2 3 _B H . P D F 37 7 7 5 ED Di g i t a l D a t a DF 6/ 2 1 / 2 0 2 3 E l e c t r o n i c F i l e : PB U _ A _ 0 6 A _ M R P M _ P N C 3 D _ P A S S 0 1 U P _ 0 6 A P R2 0 2 3 _ B H . d l i s 37 7 7 5 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 5 , 2 0 2 5 AO G C C Pa g e 3 o f 4 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 - 0 2 9 - 2 0 1 1 8 - 0 1 - 0 0 We l l N a m e / N o . P R U D H O E B A Y U N I T A - 0 6 A Co m p l e t i o n S t a t u s 1- O I L Co m p l e t i o n D a t e 4/ 8 / 2 0 2 3 Pe r m i t t o D r i l l 22 3 0 1 5 0 Op e r a t o r H i l c o r p N o r t h S l o p e , L L C MD 13 4 5 0 TV D 87 5 0 Cu r r e n t S t a t u s 1- O I L 9/ 5 / 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 Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 4/ 8 / 2 0 2 3 Re l e a s e D a t e : 2/ 2 3 / 2 0 2 3 DF 6/ 2 1 / 2 0 2 3 E l e c t r o n i c F i l e : PB U _ A _ 0 6 A _ M R P M _ P N C 3 D _ P A S S 0 2 U P _ 0 6 A P R2 0 2 3 _ B H . d l i s 37 7 7 5 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 5 , 2 0 2 5 AO G C C Pa g e 4 o f 4 9/ 5 / 2 0 2 5 M. G u h l PBU A-06A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-015 50-029-20118-01-00 13450 8750 9992 1932 9271 1289 4200 13421 13-3/8" x 9-5/8" 9-5/8" 7" x 5-1/2" x 4-1/2" 7" 3-1/2" x 3-1/4" x 2-7/8" 8760 21 - 10013 20 - 1952 19 - 9290 9407 - 10696 9250 - 13450 21 - 8110 20 - 1951 19 - 7516 7610 - 8685 7483 - 8750 None None 4930 6870 8160 8160 10160 13177 - 13220 4-1/2" 12.6# 13cr 17 - 9082, 9362 - 9448 8844 - 8829 2338 18-5/8" 22 - 2360 22 - 2359 930 4-1/2" HES TNT Packer 8976, 7266 8976 7266 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, Prudhoe Oil ADL 0028286 17 - 7350, 7574 - 7644 Surface - 9232'MD in 7" Scab x 9-5/8" annulus, Surface - 2115'MD in 9-5/8" x 13-3/8" annulus Cement 7" scab w/ 245-bbls 15.3-ppg Class G, Cement 9-5/8" x 13-3/8" annulus w/133-bbls of 15.3-ppg Class G cement. FCP = 2800-psi. Top off OA w 18-gal 13-ppg Finecem cement. 875 351 1065 3764 294 1612 1175 269 310 323-338 Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.06 15:28:30 -08'00' Torin Roschinger (4662) By Grace Christianson at 9:10 am, Sep 07, 2023 DSR-9/11/23WCB 4-9-2024 RBDMS JSB 091123 ACTIVITY DATE SUMMARY 6/22/2023 ***WELL S/I ON ARRIVAL*** EQUALIZE 4-1/2" XX PLUG @9,253' SLM (9,232' MD) GS TOP SUB SWIVELED OFF CORE WHILE LATCHED UP TO PLUG BODY @ 9,232' MD BEAT DOWN ON GS CORE W/ 3.25" BLIND BOX TO TRY AND SHEAR GS RUN 2.60" MAGNET, ATTEMPT TO FISH GS CORE & BODY *** CONTINUE ON 6/23/2023 *** 6/23/2023 *** CONTINUE FROM 6/22/2023 *** CONTINUE RUN W/ 2.60" MAGNET, UNABLE TO RETRIEVE GS CORE & BODY LIH- 3.60" GS BODY W/ 4 DOGS, CORE SPRING, DOG RETAINER & RETAINER SPRING , GS CORE 3.05" x 10-1/8" RIG DOWN, TAKE UNIT TO SHOP *** WELL LEFT S/I ON DEPARTURE, DSO, NOTIFIED OF WELL STATUS *** 6/23/2023 T/I/O/OO = 490/0/300/0. Temp = SI. PPPOT-T **PASS** & PPPOT-IC **PASS** (pre rig). OOA cementd to surface. ALP = 300 psi SI @ CV. PPPOT-T: Stung into THA test port 0+ psi, bled void to 0 psi. Moniored for 10 mins no change in pressure. Functioned all LDS, all move freely. Tourqued LDS to 450 ft/lbs. Pressure void to 5000 psi for 30 min test. Lost 400 psi in the 1st 15 mins, lost 50 psi in the 2nd 15 mins for a **PASS**. Bled void to 0 psi. PPPOT-IC: Stung into test port 900 psi, bled void to 0 psi. Monitored for 10 mins, no change is pressure. Tourqued LDS to 500 ft/lbs. Pressure void to 3500 psi for 30 min test. Lost 100 psi in the 1st 15 mins, lost 0 psi in the 2nd 15 mins for **PASS**. Bled void to 0 psi. WV = LOTO. SV = C. SSV, MV = O. IA, OA, OOA = OTG. 14:00 6/24/2023 ***WELL S/I ON ARRIVAL*** (RWO expense) RECOVERED INTACT GS BODY W/ DOGS (core still in-hole) ***CONTINUE ON 6/25/23 WSR*** 6/25/2023 ***CONTINUED FROM 6/24/23 WSR*** (RWO expense) RECOVERED GS CORE ***COMPLETE GS FISH RECOVERED*** PULLED 3.81" XX-PLUG AT 9,237' SLM DRIFT TBG TO DEPLOYMENT SLEEVE @ 9239' SLM (9250' MD) w/ 10' x 3.66" FOR E-LINE CUTTER (no issues) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** Daily Report of Well Operations PBU A-06A Daily Report of Well Operations PBU A-06A 6/29/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP(good) SET BAKER 3.57" COMPOSITE BRIDGE PLUG AT 9173' MD, CCL STOP DEPTH=9161.2' MD, CCL TO ME=11.8' PERFORM 30 MIN PRESSURE TEST @ 1500PSI AGAINST BAKER CBP(see t-bird report) LOG TIED INTO TUBING TALLY DATED:7-9-2015 CUT TUBING WITH BAKER MECHANICAL CUTTER AT 9115.7' MD.(see Baker log dated 6-29-2023) BAKER REACHED MAX CUTTER EXTENSION ON SRO AFTER 1 HOUR. GOOD INDICATION ON TUBING PRESSURE. T-BIRD CIRCULATED 1 BBLS OF CRUDE DOWN TUBING AND UP IA(see t-bird report) ***WELL LEFT S/I, PAD OP NOTIFIED*** 6/29/2023 T/I/O= 73/0/292 Temp= S/I (TFS Unit 4 Assist E-Line with Load and Test) Pumped 20 bbls of Crude down TBG to Fluid pack well. ****MIT-T PASSED to 1398 psi **** Max applied pressure=1500 psi. Target Pressure= 1350 psi. Pumped 1.3 bbls of Crude down TBG to reach max applied psi. 1st 15 Min TBG lost 76 psi. 2nd 15 Min TBG lost 26 psi. TBG lost 102 psi in a 30 Min test. Circulated 1.5 bbls of Crude down TBG inot IA to flush post TBG Cut and Verify Comm TxIA. E-Line in Control of well upon departure. Tags Hung. Final WHPS 50/0/312 7/3/2023 T/I/O/OO= SI/0/250/0. Remove 3" FMC model 35 3K OOA valve and install new 3" FMC 120 3K valve tag 19. Torque to spec. Peform rolling PT aginst OOA surface cement to 500 PSI (Passed). RDMO ***JOB COMPLETE*** 7/5/2023 T/I/O/OO = SSV/Vac/300/Vac. Temp = SI. Install cemented sign on OOA (WIE request). PBGLJ SI @ CV. No wellhouse, or cellar grating. Flowline is disconnected from the well. Installed cemented sign on OOA. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 14:30 7/6/2023 T/I/O=574/-6/124 (RWO EXPENSE) U-Tube TBG and IA. ***Job Continued 7/7/23*** 7/6/2023 T/I/O=100/0/300 (RWO EXPENSE) - Circ-out well - Pumped 10 bbls of Crude to verify TxIA communication, Circ Out Well w/ 104 bbls of Deep Clean, 1052 bbls of 1% KCl pumping down TBG taking returns up IA to OTT. Freeze protect w. 172 bbls DSL. Attempt to U-Tube DSL FP into IA. Well Secure. Casing valves OTG. FWHPs= 90/150/320 7/7/2023 ***Job Continued 7/6/23*** (RWO EXPENSE) U-TUBE TBG and IA. Secure Well. FWHP=6/14/103 7/16/2023 T/I/O/OO = 480/VAC/90/0+. Temp = SI. Bleed WHPs (pre-RWO). Wellhouse, flowline, and AL removed. Rig scaffolding installed. OA FL @ near surface. Bled OAP to BT from 90 psi to 10 psi in 10 mins. Monitored for 30 mins. OAP increased 20 psi. Bled TP to BT from 490 psi to 300 psi in 10 mins (all fluid 3.69 bbls). Increases back to 480 psi within minutes. Final WHPs 480/VAC/30/0+. SV = C, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 7/24/2023 T/I/O= 390/0/24 (RWO EXPENSE) Circ-out well with 625 bbls of 1% KCL down TBG, up IA, out to Open-Top tanks. Pumped 103 bbls of 120* 1% KCL down IA, up TBG, out to Open-Top tanks with a rate of 1.25 bpm. Pumped 2 bbls 60/40 to FP unit and surface lines. Well support notified to rig down. Tags hung. Pad operator notified upon departure. FWHP's = 0/0/0. Daily Report of Well Operations PBU A-06A 7/25/2023 T/I/O=BPV/0/0. Pre TB #01. Wellhead tech T-Bar 4" CTS BPV. Removed 13" CIW THA and NU 13" CIW BOP w/ 3rd ram on bottom and 13" shooting flange. Torqued flanges to API spec. Pressure tested with N2 to 500 psi. Pass. Bleed off N2 and Hung well sign. ***Job Complete*** Final WHP's BPV/0/0. 7/25/2023 Verify 0 psi tubing, on a vac., set 4" H CTS BPV, nipple down THA & tree, clean hanger void & ID, set CTS plug, make up 4-1/2" TC-II test sub, test 500 psi/5 min., 3500 psi/10 min., good tests, bleed off test psi, rig down test sub, function upper lock down screws one at a time to 4-3/8" clear bowl, buff each lock down screw w/ Emory cloth, lube w/ Kroil, all were fairly tight, but functioned properly, re-torqued to 500 ft/lbs, install new BX-160, RDMO 7/26/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. MIRU TB-1 and support equipment. Service choke and kill manifold. Shell Test BOPE 250 psi low / 3000 psi high. .....Continued on 7/27/23 WSR. 7/27/2023 Pull CTS plug w/ dry rod. Sting into CTSHBPV and monitor for pressure. Pull CTSHBPV. S/B to pull TBG HGR. M/U landing joint to TBG HGR. BOLDS, Pull TBG HGR to rig floor. Wrap TBG HGR, lay down w/ landing joint. 7/27/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Begin BOPE testing as per sundry 250 psi low / 3000 psi high. Tested upper rams w/2-7/8" & 4-1/2" test joints. Test witnessed by AOGCC Austin McLeod. Pulled TWC. Circulate STS w/625 bbls of 1% KCI at 4 bpm / 1400 psi. M/U landing joint, BOLDS. Pull and release hanger 150k, PUW 112k pulling freely. Begin pulling 4-1/2" VamTop completion from cut depth = 9,115' MD. Fill hole every 15 joints pulled. .....Continued on 7/28/23 WSR. 7/28/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Continue pulling 4-1/2" VamTop completion from cut depth = 9,115' MD. Fill hole every 15 joints pulled. Recovered 1 X-nipple Assy, 4 GLM Assy, 215 full joints, and one cut joint = 7.33'. Set test plug. Replaced ram door seals in 4-1/2" x 7" VBR's. Test lower VBR's w/7" test joint to 250 psi low / 3000 psi high. R/D test equipment. BOLDS. Pulled test plug. M/U and TIH w/Baker cleanout BHA #1 - 8.50" Junk Mill & 8.50" String Mill. 63 joints in hole, tagged what appear to be cement at 2,109' ORKB. R/U power swivel. .....Continued on 7/29/23 WSR. 7/28/2023 Set test plug at verified RKB. RILDS. S/B for BOP test. BOLDS. Pull test plug. 7/29/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Attempt to mill through obstruction at 2,109' ORKB. Continuous stalls. Discuss plan forward w/OE. TOH w/BHA # 1 RBWS, L/D BHA # 1 and inspect 8.50" junk mill. Downsize mills, M/U BHA # 2, and TIH w/BHA # 2 - 8.25" junk mill. Tagged up same depth 2,109' ORKB. R/U power swivel and attempt to work 8.25" junk mill through obstruction with repeated stalls. Discuss plan forward w/OE. TOH w/BHA # 2 while mobilizing Slickline / Read Caliper to location. .....Continued on 7/30/23 WSR. Daily Report of Well Operations PBU A-06A 7/30/2023 ***POLLARD #60 ASSIST THUNDERBIRD RIG*** (RWO expense) RAN READ 40 ARM EXTENDED REACH CALIPER TO ~ 9,115' MD TO SURFACE. ****WELL TURNED BACK OVER TO THUNDERBIRD RIG**** 7/30/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. TOH w/BHA # 2 RBWS. L/D BHA # 2, inspect 8.25" mill. Mill shows wear on outer edge, send pics to town. MIRU Pollard Slickline w/.125 wire. Rih w/Read memory 2.75" 40 arm caliper. Logged caliper from 9,115' to surface @ 50 fpm. Download good date. Caliper shows cork screwed casing from 2,109' - 2,130', minimum ID = 7.67". M/U BHA # 3 and TIH w/7.75" string mill. Tagged string mill 2,110' ORKB. Establish baseline parameters 90-100 rpm / 3k ft-lbs. Worked string mill through 9- 5/8" casing restriction, broke through 2,117' ORKB. Made passes rotating 2,100' - 2,130' no issues. .....Continued on 7/31/23 WSR. 7/31/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. TIH w/BHA # 3 no rotation to 2,211' ORKB. R/D power swivel. TOH w/BHA # 3 RBWS. L/D BHA # 3, send BHA to Baker shop to change out string mills. M/U & TIH w/BHA # 4 - 7.938" string mill. Tagged w/string mill 2,110' ORKB. Establish free spin 80 rpm / 600 ft-lbs. Worked string mill through 9-5/8" casing restriction, broke through 2,117' ORKB. Made passes rotating 2,100' - 2,130' no issues. Continue TIH w/BHA # 4. At 4,088', no sign of fill indicated on caliper report. Reverse circulate 3x bottoms up 2.5 bpm / 400 psi. Continue TIH w/BHA # 4. .....Continued on 8/1/23 WSR. 8/1/2023 ***SUPPORT RWO THUNDERBIRD *** (5' OF TBG PUNCHER) RIH W/CH/WB/CCL/DE CENT/5' OF 1.56'' 4 spf TBG PUNCHER CCL CORRELATED TO TBG TALLY DATED 4/17/90 PUNCH HOLE FROM 1900' TO 1905' MD CCL TO TOP SHOT=7.7 CCL STOP=1892.3' WELL READY FOR CIRCULATION *** JOB COMPLETE*** 8/1/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Continue TIH w/BHA # 4. Tagged 4-1/2" tubing stub 9,117' ORKB. Reverse circulate 2x bottoms up 2.5 bpm / 700 psi. TOH w/BHA # 4. L/D BHA # 4. Circulate IA x OA .6 bpm / 1400 psi. Discuss plan forward w/OE, mobilize Eline tubing punch. MIRU YellowJacket Eline. Correlate to 9-5/8" casing tally 4/17/1990. Log CCL on shot depth confirmed by OE. Shoot circulation interval 1,900' - 1,905' (4 spf). Step Rate Circulate IA x OA: 1 bpm / 50 psi, 2 bpm / 150 psi, 3 bpm / 200 psi, 4 bpm / 240 psi. RDMO & release YellowJacket Eline. M/U & TIH w/BHA # 5 - Dress Off 4-1/2" tubing stub. Tagged 3' on joint # 61 = 2,141' ORKB......7.938" string mill depth = 2,111' ORKB. R/U power swivel. Establish free spin. Begin working 7.938" string mill through 9-5/8" restriction. .....Continued on 8/2/23 WSR. Daily Report of Well Operations PBU A-06A 8/2/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Worked 7.938" string mill through 9-5/8" restriction 2,111' ORKB. Make passes rotating to polish restriction. Continue TIH w/BHA # 5 on 2-7/8" PH-6 workstring (stands). Tagged 4-1/2" Tubing Stub at 9,122' ORKB (6' Washpipe). R/U washington head / power swivel. Dress off tubing stub while reverse circulating 3 bpm / 800 psi. Recovered coarse metal shavings in returns. Tagged high on 4-1/2" tubing stub, possible fill/shavings around tubing stub. Discuss plan forward w/OE. TOH w/BHA # 5 RBWS. R/U power swivel. Work 7.938" string mill through 9-5/8" casing restriction at 2.109' ORKB until BHA freely passes up/down. TOH w/BHA # 5 and L/D. Pulled wear ring. Set test plug. .....Continued on 8/3/23 WSR. 8/3/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Set test plug. Shell test BOPE 250 psi low / 3000 psi as per sundry. AOGCC Bob Noble waived witness. BOPE test 250 psi low / 3000 psi high w/2-7/8", 4-1/2", and 7" test joints. R/D test equipment. Pulled test plug, installed wear bushing. M/U & TIH w/Cleanout BHA # 6 - Magnets, BootBasket, 10' WP. Tagged 4-1/2" tubing stub 2.78' in on joint # 289 = 9,118' ORKB. R/U washington head / power swivel. Troubleshoot power swivel leak. Lay down power swivel on ground to swap out pack off. .....Continued on 8/3/23 WSR. 8/4/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. Lay down power swivel on ground. R/U TIW/Kelly hose. Circulate 1% KCI down workstring while taking returns up casing. Washover stub at 9,118' ORKB while replacing pack off on power swivel. Reverse circulate 2x bottoms up 3.5 bpm / 800 psi. R/U power swivel. Free spin 30 RPM, 2100 ft-lbs, 3.3 bpm/1000 psi. Rotate & washover 4-1/2" tubing stub down to 9,128' ORKB. Dry drift over 4-1/2" tubing stub 3x, no issues. Reverse circulate 3x bottoms up 3.3 bpm / 800 psi. TOH w/BHA # 6 RBWS. L/D BHA, clean magnets. M/U & TIH w/BHA # 7 - Dress Off. ........Continued on 8/6/23 WSR... 8/5/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. TIH w/BHA # 7 - Dress Off. At 288 joints in hole, R/U washington head & power swivel. Free spin 3.2 bpm @ 700 psi, 60 RPM Torque 2-3k. Dressed off 8" of 4-1/2" tubing stub. Dry tagged 4-1/2" tubing stub 9,119' ORKB, shoe at 2125' ORKB. Repeat tag w/no issues getting over. Pick up off 4-1/2" tubing stub and reverse circulate 2x bottoms up. R/D washington head & swivel. TOH w/BHA # 7 racking back stands. ........Continued on 8/6/23 WSR 8/6/2023 M/U wear bushing r/r tool to working joint. RIH, "J" into wear bushing. B/O (4) LDS. Pull wear bushing to floor and lay down tools. Daily Report of Well Operations PBU A-06A 8/6/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. TOH w/BHA # 7. L/D drill collars. Clean magnets, L/D BHA # 7 and inspect. Good ring on dress off mill. Pulled wear ring. R/U GBR tongs/handling equipment and layout 7" completion. P/U Logan Overshot, PBR Assembly, NCS sleeve, 5-1/2" BTC x 7" JFE Bear x-over. RIH w/7" tieback completion as per tally, no issues getting through 9-5/8" casing restriction. 165 of 243 joints in hole. ........Continued on 8/7/23 WSR 8/7/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, run 7" tieback & cement, Run 4.5" completion. RIH w/7" tieback completion as per tally. PUW 255k, SOW 160k. Tagged up on 4- 1/2" tubing stub 9,118' ORKB. Attempt to rotate pipe and work overshot over stub with no success. Circulate 1% KCI w/Safelube down 7" casing taking returns up 9- 5/8" x 7" annulus. Slack off and see 2' of travel then stack weight 10k down. PT inside of 7" casing to 700 psi for 15 min, good test. PT 9-5/8" x 7" annulus to 500 psi, good test. Pulled up to 280k and shear seal assembly, PUW 255k. Re-tagged PBR 17.90' in on joint # 244 and calculate space out = 32.96'. Lay down joints 244, 243, 242. M/U 32.96' of space out pups and joint # 242 on top. M/U casing hanger. ........Continued on 8/8/23 WSR 8/8/2023 Make up 7" slip hanger to string, remove slip retention bolts and handling equipment. Run in and land hanger, visually through IA valve, Torque LDS at 550 ft lbs., torque gland nuts to 400 ft lbs. One LDS left in the out position, we will change it when we swap the tubing head. Test 7" casing to 500 psi for 10 min with IA open. (good test) Close IA valve, RDMO LDS in = 3-1/2" to 3-5/8" 8/8/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. M/U 7" casing hanger. C/O elevators for 3-1/2" IF Baker spear (150 ton). M/U spear to 7" casing hanger. Land hanger, PUW 255k, SOW 160k. RILDS. Test 7" casing to 500 psi, good. R/D GBR equipment. M/U NCS Shifting Tool BHA #8 and TIH. Reverse circulate 50 bbl powervis pill and spot above NCS BHA. Locate sleeve 14' in on Jt #295, Shift NCS sleeve open. Circulate 280 bbls of 1% KCI up 9-5/8" casing. Circulate 130 bbls 1% KCI up 13-3/8" casing. MIRU HES cement unit. PJSM. Cement 9-5/8" x 7" casing to surface with 245 bbls 15.3 ppg Class G cement, good cement returns off 9-5/8" casing. Open OA and shut in IA on the fly. Begin cementing 13-3/8" x 9-5/8" casing w/133 bbls of 15.3 ppg Class G cement. ........Continued on 8/9/23 WSR Daily Report of Well Operations PBU A-06A 8/9/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. Cemented 13-3/8" x 9-5/8" casing w/133 bbls of 15.3 ppg Class G cement, good cement returns off 13-3/8" casing. Shut in OA. Shift NCS sleeve closed 10k over, good idication of shift. Bleed 7" casing to zero and monitor, no flow verifying sleeve shifted all the way closed. Reverse circulate down 7" casing taking returns up 2-7/8" workstring until clean gel returns. Flow check good. Flushed surface lines w/KCI to return tank. Pull and lay down 6 joints of 2-7/8" PH-6 workstring. Set 7" storm packer 42' below WH and test to 500 psi, good test. Bleed to zero and flow check good. RD scaffold, RD Floor & prep for BOP break. PJSM for for Crane lift. Remove stack and ND lower 4-1/2" x 7" Rams. Cut and dress 7" casing stub. Install new tubing spool w/secondary packoff. N/U BOPE stack. N/U choke/kill sides. R/U rig floor. .........Continued on 8/10/23 WSR 8/10/2023 ND BOP, cut 7" casing 6-3/4" up from the flange face, bevel 7" casing ID / OD, nipple up tubing head with YBT bushing. Attempt to energize Y seal, pump 5 sticks of packing without returns. Attempt to test against lower ID T seal & lower OD T seal, got fluid returns though open injection port. Attempt to test with injection port closed & got fluid returns past both OD T seal into the tubing head. Test failed. Nipple up BOP, test BOP / storm packer to 250 psi low / 3000 psi high with OA open and both injection port and test ports open with gauges. Both ports tracked test pressure with no fluid loss by the primary packing. Primary packing passed. Closed OA valve RDMO. 8/10/2023 Land tubing hanger for BOP test verify mark though IA valve, torque GN & LDS. Set TWC with dry rod from rig floor. Shell test BOP at 250 psi / 3000 psi (good test). Pull TWC, BOLDS, pull tubing hanger. RDMO 8/10/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. R/U Koomey hoses and function stack. Test BOPE break to 3000 psi, charted. Pulled 7" storm packer and lay down. TOH w/NCS BHA # 8 RBWS. MIT 7" casing to 3000 psi for 30 min, charted. Drain stack and install Tubing Hanger / TWC. RILDS. R/U BOPE test equipment. Shell test BOPE 250 psi low / 3000 psi high. AOGCC waived witness (Sean Sullivan). Begin BOPE testing with 2-7/8" & 4-1/2" test joints as per sundry. .........Continued on 8/11/23 WSR 8/11/2023 T/I/O/OO = 0/0/0/0. Temp = SI. Strap TOC (rig req). Thunder bird is over well tripping pipe. Removed bull plug from the casing valve @ the 9 o'clock. Strapped TOC @ 36'. Thunder bird in control of well upon departure. 10:00 8/11/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. Completed BOPE testing with 2-7/8" & 4-1/2" test joints as per sundry. Pulled TWC / Tubing hanger. MU & TIH w/BHA # 10 - RCJB / Burn Shoe. (D1) KWT drill. RIH to 9,130' MD. Tag what appears to be fill. Swivel up and circulate down from 9130' to 9134'. TOH w/BHA # 10. L/D BHA # 10, recovered less than cup of soft cement in junk basket. R/U washington head. .........Continued on 8/12/23 WSR Daily Report of Well Operations PBU A-06A 8/12/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. R/U washington head. M/U & TIH w/BHA # 11 - 3.68" SawTooth Mule Shoe (2.5" ID). Make up swivel on jnt #298. Tag fill at 9,134', Wash & ream down From 9134 to 9165'. On jnt # 298. Pump 10 bbl high vis sweep STS 265 bbls. Dump sweep to OTT. PU Jnt 299 wash and ream from 9165' to 9174' md, Tag CBP 11' in on 299 = 9174' MD. Hard Tag with some torque up. Pump 10 bbl sweep STS on CBP. Rack back swivel. TOH w/ BHA # 11 RBWS. .........Continued on 8/13/23 WSR 8/13/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. TOH w/ BHA # 11 RBWS. L/D BHA # 11. M/U & TIH w/BHA # 12 - Make up 298 & 10' pup. MU Swivel. SD C/O Battery in the Koomy Generator. Mill CBP at 9,173' MD and pushed plug down to top of deployment sleeve at 9,251' MD. Unable to BH down well, appears nose cone seated in sleeve. Discuss plan forward w/Wells Foreman. TOH w/BHA # 12 LDSW. 150 joints OOH. .........Continued on 8/14/23 WSR 8/14/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. TOH w/BHA # 12 LDSW. L/D BHA # 12 and inspect. R/U to run 4-1/2", 12.6# 13-CR VT Gas lifted completion w/Tbird TTS. Function test TQ turn equipment. PJSM for completion run, review run order. Line up completion & Run per approved Tally. Trouble shoot the McCoy tongs. RD TB Tongs and TQ Turn. Call out GBR to run 4- 1/2" completion. R/U GBR tongs/power pack. RIH w/4-1/2" VamTop completion as per run tally. .........Continued on 8/15/23 WSR 8/15/2023 Ensure that stack is completely drained & rinsed, make up 4-1/2" VamTop tubing hanger pup to string, 5" in hole to 13.20', verify landed through IA valve verification mark, run in lock down screws per Cameron procedure, torque to 550 ft/lbs, close annular on landing joint, test top of hanger 500 psi/~5 min., good test, bleed off, back out landing joint, stand by for pump, ball & rod, etc, set 4" H CTS BPV, RDMO 8/15/2023 Thunderbird-1 RWO Job Scope: Pull 4.5" completion, Run 7" tieback & cement, Run 4.5" completion. RIH w/4-1/2" VamTop completion as per run tally. PU Hanger, drain the stack. Land hanger, PUW 98K, SOW 80K. RILDS. Reverse circulate 30 bbls of corrosion inhibited 1% KCI, chased with 135 bbls of 1% KCI. Dropped Ball & Rod. Set HES TNT Production Packer. MIT-T to 3000 psi, 30 min charted - Passing test. Bleed Tbg to 1500 psi. MIT-IA to 3000 psi for 30 min charted - Passing test. Bleed tubing pressure to zero, DCK valve sheared. Set BPV. RDMO Thunderbird-1. .........RWO Program Completed. 8/16/2023 Clean Void, hanger neck ID,& BPV profile, install CTS plug, new DX seal, & new BX 160, inspect & grease THA ID, S/B for well support to torque THA, test void 500 psi/5 min, 0 psi loss, test 5000 psi/30 min., 0 psi loss, bleed off, rig down test equipment, well support to test tree & pull CTS plug & BPV, RDMO 8/16/2023 T/I/O=BPV/0/0. Post TB #01. ND 13" BOP, NU 13" CIW THA and 4" CIW Tree with Baker C actuator. Torqued flanges to spce. Pressure tested against CTS BPV to 500/5000 psi. Passed. Pulled CTS plug and 4" BPV. Installed production piping and set wellhouse. ***Job Complete*** Final WHP"s 0/0/0. Daily Report of Well Operations PBU A-06A 8/17/2023 ***WELL S/I ON ARRIVAL***(post rwo) T-BIRD PUMP DIESEL F/P AND LET U-TUBE SET BAITED 3.60" BELL GUIDE, 2" RB ON B&R @ 9,053' SLM (use as catcher and hold pressure) PULLED BK-DGLV'S FROM STA #1 @ 8,874' MD, STA #2 @ 8,240' MD, STA #3 @ 7,400' MD ***CONT WSR ON 8/18/23*** 8/17/2023 T/I/O= 179/260/0 Temp=S/I (TFS unit 4 post rig freeze protect) Pumped 1 BBL of 60/40 followed by 90 BBLS of diesel down IA for freeze protect. Further pumped 1 BBL of 60/40 for spacer. U-tubed fluid to TBG for an hour. Final WHPS=0/76/0 8/18/2023 ***CONT WSR FROM 8/17/23*** (rwo expense) PULLED BK-DGLV FROM STA #4 @ 6,231' MD PULLED BEK-CIRC VALVE FROM STA #5 @ 3,723' MD SET BK-LGLVS IN STA #5 @ 3,723' MD, STA #4 @ 6,231' MD, STA #3 @ 7,400' MD & STA #2 @ 8,240' MD. SET BK-OGLV IN STA #1 @ 8,874' MD. PULLED BAITED RB W/ BALL & ROD ASSY FROM RHC BODY @ 9,029' MD. PULLED RHC BODY FROM X-NIPPLE @ 9,029' MD. ATTEMPTED TO RUN 3.70" CENT, 3.50" LIB, SD IN STA #3 @ 7,423' SLM (impression of top of bk latch) SET 4 1/2" X-CATCHER IN X-NIPPLE @ 8,947' MD ***CONT WSR ON 8/19/23*** 8/18/2023 T/I/O/OO/OOO = 300/250/VAC/0/0. Temp = SI. Top out OA w/ cement. Used 18 gallons of ultra fine 13 ppg cement to fill OA. Installed heater. SL in control of valves upon departure. 23:00 8/19/2023 ***CONT WSR FROM 8/18/23*** (rwo expense) PULLED/RESET BK-LGLV IN STA #3 @ 7,400' MD (packing tore up) PULLED EMPTY X-CATCHER FROM 8,973' SLM RAN 3.70" CENT, 3.50" LIB TO 9,266' SLM (impression of possible cbp) MADE 3 RUNS W/ 10' x 3.5" PUMP BAILER TO 9,266' SLM (large aluminium chunk, cbp chunks) MADE 2 RUNS W/ 10' x 2.50" PUMP BAILER TO (min recovery) MADE 1 RUN W/ 10' x 2.25" PUMP BAILER TO 9,266' SLM (min recovery) ***CONT WSR ON 8/20/23*** 8/20/2023 ***CONT WSR FROM 8/19/23*** (rwo expense) RAN 2.68" CENT, 1.75" SAMPLE BAILER TO 9,266' SLM (no recovery) RAN 10' x 2.50" PUMP BAILER W/ 2.50" INLINE CENT TO 9,266' SLM (min recovery) RAN 3.70" CENT, 3.50" LIB TO 9,266' SLM (impression of large piece of debris) RAN 10' x 3.50" PUMP BAILER TO 9,266' SLM.(recovered pieces of cbp & large chunk of steel) SET 4-1/2" DREAM CATCHER ASSY IN X-NIPPLE @ 8,947' MD. CONFIRMED GOOD SET W/ 4-1/2" CHECK SET.(sheared) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU A-06A 8/22/2023 ***WELL FLOWING ON ARRIVAL*** TAG STA.# 3 @ 7,400' MD (valve in pocket) BLEED IA FROM 900 psi DOWN TO 450 psi PULL 4-1/2" X-LOCK DREAM CATCHER @ 8,975' MD (Rubber clumps inside, screen partially plugged) ***CONTINUE 8/24/23*** 8/22/2023 T/I/O/OO/OOO = 180/1050/0/0/0. Temp = 90°. IA FL (GLE). ALP = 1050 psi, AL online. IA FL @ 7570' (1304' above sta #1, SO). Second shot @ 7630', between first & second shot well began producing fluids. Third shot unchanged from 2nd shot @ 7630'. SV = C. WV, SSV, MV = O. IA, OA, OOA, OOOA = OTG. 17:15 8/23/2023 ****WELL FLOWING ON ARRIVAL*** (RWO expense) PULLED 4-1/2" DREAMCATCHER AT 8,947' MD (recovered ~1/8 cup small rubber chunks) RAN BARBELLED 3.50" LIB TO DEPLOYMENT SLEEVE AT 9,250' MD (impression of deployment sleeve) ***CONTINUE ON 8/24/23 WSR*** 8/23/2023 ***CONTINUE FROM 8/22/23*** SET 4-1/2" X-LOCK DREAM CATCHER @ 8,947' MD (x-line shifted @ svln) RAN 4-1/2" CHECKSET S/D @ 8,947' MD ***WELL TURNED OVER TO PRODUCTION*** 8/24/2023 ***CONTINUED FROM 8/23/23 WSR*** (RWO expense) RAN 5' x 2.25" PUMP BAILER TO 9,237' SLM (recovered ~1 cup of rubber/metal/ composite pieces) RAN 10' x 2.25" PUMP BAILER W/ 2.60" FINGER BASKET TO 9,237' SLM (bailer rod threads pulled out of piston) RECOVERED BAILER FISH AT 9,237' SLM (four CIBP slip fragments inside) ***WELL S/I ON DEPARTURE*** 8/25/2023 CTU 9, 1.75" 0.156" CT Job Scope: Clear LNR Debris / push CBP to Btm MIRU CTU 9. MU YJ Venturi BHA. Pump slick seawater w/ SL down Tbg. Pressure up after 42 bbls. Pump min rate and RIH for chrome management. Tagged @ 9267' CTM / 9278' Mech. PUH 33' and start pumping and Venturi on top of Depolyment SLV making four passes. PUH Venturi past 9000'. POOH. Recovered aluminum core from composite plug, 3/8" ball, and ~1/2 cup of slips various other debris. RBIH with Venturi, recip top of deployment slv, 5 passes. POOH, venturi basket clean ***Continue to WSR on 8/26/23*** 8/26/2023 CTU 9, 1.75" 0.156" CT Job Scope: Clear LNR Debris / push CBP to Btm M/U YJ 2.13" motor w/ 2.75 venturi burnshoe. RIH. Tag multiple times at deployment sleeve, unable to get in. POOH. Chunk of Composite 2"x4" and small pieces Recovered. Cut 100' CT. MU YJ 2.70" venturi burnshoe. RIH. Tag LNR @ 9269' CTM. Worked up and down made into LNR. RIH dry drift down 11,098' CTM. POOH. BD 2.70" Venturi, recovered composite pieces and metal shavings. MU 2.30" Venturi/burnshoe. RIH dry drift. Push to PBTD @ 13,444CTMD. POOH, RDMO ***Continued to WSR on 8/27/23*** 8/27/2023 T/I/O/OO/OOO = SSV/1220/0/0/50. Temp = SI. IA FL (Ops). ALP = 1950 psi, SI @ CV. IA FL @ 8874' (sta # 1 SO). SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 03:00 Daily Report of Well Operations PBU A-06A 8/27/2023 CTU 9, 1.75" 0.156" CT Job Scope: Clear LNR Debris / push CBP to Btm RDMO ***Job Complete*** 8/31/2023 LRS Well Testing Unit 6, Begin WSR, IL A-06 / OL A-06 KF, Rate Verification, Unit Move, RU, PT, Pop/Flow/Test well, Cont WSR on 9-1-23 9/1/2023 LRS Well Testing Unit 6, Cont WSR from 8/31/23, IL A-06 / OL A-06 KF, Rate Verification, Complete 12 HR Welltest, Divert out of WTU, BD, RD, UM, End WSR on 9/1/23 2023-0802_BOP_Hilcorp_Thunderbird1_choke-manifold_PBU_A-06A_bn Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 8/2/2023 P. I. Supervisor FROM: Bob Noble SUBJECT: BOPE – Choke Manifold Petroleum Inspector Thunderbird 1 PBU A-06A; PTD 2230150 Hilcorp North Slope LLC 8/2/2023: After reading Austin McLeod’s notes and discussing the issues with Adam Earl (both AOGCC Inspectors that have recently been at Thunderbird rig), I decided I would pay Hilcorp an unannounced visit and see where they were at on fixing the issues that Austin had discovered (new choke manifold installed without notice with several threaded connections and questionable valves; using the kill line as fill line). I traveled to PBU A-06A and met with Hilcorp representative Daniel Scarpella. We discussed what Austin had found during his last witnessed BOPE test (see 7/28/2023 report). Mr. Scarpella said their old choke manifold was compliant with the regulations but a while back they replaced it to the new choke manifold. He said that parts are going to be at location in a few days, and the Thunderbird rig was granted approval by AOGCC to use the new choke manifold on this well but must be brought into compliance or replaced with the previous choke manifold before entering the next well. He plans on changing the parts in-between wells. Mr. Scarpella confirmed he has the old manifold as a backup if parts don’t show up or are wrong. He also said 5K psi rated whip checks are included in the parts for the hoses that don’t have them installed. A 5K psi test will be performed on the choke manifold after it is repaired. The other issue that we discussed was using the kill line for filling the well. He told me they have a riser with a 1502 connection on it that they will use as the fill line. It will be installed after this well. Attachments: none STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT A-06A JBR 09/15/2023 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:5 2-7/8 & 4-1/2 joints. LPR NT. CMV 4 greased for a pass. Dart replaced for a pass. Ch misc-New choke/kill manifold since 6/2 with three threaded connections on choke manifold. Threaded connections must be remedied prior to next well. Designated fill up line must be installed prior to next well. Test Results TEST DATA Rig Rep:Brandon StifflerOperator:Hilcorp North Slope, LLC Operator Rep:Eli Wilson Rig Owner/Rig No.:Hilcorp Thunderbird 1 PTD#:2230150 DATE:7/27/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSAM230727185454 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 2370 Sundry No: 323-338 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 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 FP FSV Misc 0 NA 10 FPNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 3 FCH Misc Stripper 0 NA Annular Preventer 1 13-5/8 P #1 Rams 1 2-7/8x5 P #2 Rams 1 Blinds P #3 Rams 1 4-1/2x7 NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8 P HCR Valves 1 3-1/8 P Kill Line Valves 3 3-1/8 & 2 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P30 Full Pressure Attained P141 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P3@2233 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P7 #2 Rams P8 #3 Rams NT0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 99999 9 9 9 9 9 9 6HHDWWDFKHGHPDLOUHJDUGLQJWKHFKRNHPDQLIROGDQGILOOXSOLQH-5HJJ FP NT F FP NT CMV 4 Dart misc-New choke/kill manifold since 6/2 with three threaded connections on choke manifold.must be remedied prior to next well fill up line must be installed prior to next well. 1 Regg, James B (OGC) From:McLeod, Austin (OGC) Sent:Friday, July 28, 2023 2:40 PM To:Daniel Scarpella Cc:Regg, James B (OGC) Subject:TB1 manifold/fill up line Dan, I’ve talked with Jim. You guys are approved to conƟnue ops unƟl the end of this well. The two (2) 1/2” NPT threads and the one (1) 2Ͳinch NPT threads that are on your choke manifold must have a like Piper ball valve similar to the rest of the choke manifold valves installed in front of them before your next well. Also some sort of Įll up line must be put in place in the same Ɵme frame. I’d suggest modifying your drip pan on top of the annular to accept a 2Ͳinch line coming oī your centrifugal to Įll the hole when pulling pipe or otherwise needed. Someone will be in touch with further quesƟons. Thank you AusƟn McLeod Petroleum Inspector Cell 907Ͳ715Ͳ0880 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: 06/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230420 Well API #PTD #Log Date Log Company Log Type BCU 04RD 50133202390100 219011 5/16/2023 AK E-LINE Perf BCU 04RD 50133202390100 219011 5/17/2023 AK E-LINE Strip Guns NS-23 50029231460000 203050 4/25/2023 HALLIBURTON MFC PBU GNI-02A 50029228510100 206119 5/30/2023 READ Pressure Temperature Survey PBU GNI-03 50029228200000 197189 5/31/2023 READ Pressure Temperature Survey PBU J-29 50029234860000 213033 4/18/2023 BAKER SPN PBU A-06A 50029201180100 223015 4/6/2023 BAKER MRPM Please include current contact information if different from above. T37770 T37770 T37771 T37772 T37773 T37774 T37775PBU A-06A 50029201180100 223015 4/6/2023 BAKER MRPM Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.21 13:29:44 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PTD223-015, Sundry 323-338, Questions Date:Tuesday, June 13, 2023 3:54:19 PM From: Kirsty Glasheen <Kirsty.Glasheen@hilcorp.com> Sent: Tuesday, June 13, 2023 1:18 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Michael Hibbert <Michael.Hibbert@hilcorp.com> Subject: RE: PTD223-015, Sundry 323-338, Questions Hi Mel, I am covering for Michael on A-06A RWO while he is OOO on PTO. Please see my responses in red below and let me know if you need anything else. Thanks! Kirsty Glasheen GC1 Operations Engineer 907-350-4310 907-564-5258 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, June 12, 2023 4:30 PM To: Michael Hibbert <Michael.Hibbert@hilcorp.com> Subject: [EXTERNAL] PTD223-015, Sundry 323-338, Questions Michael, A few questions: 1. Is it possible to test the CBP set at 9165’ to 1500 psi to see if it is holding (step 3)? Yes, the well has competent tubing, so once the CBP is set, we can do a PT to confirm it is holding. 2. Will the 7” be hung in the same spool that the current 4-1/2” tubing is hung in? Yes. We are planning to tie the 7” back to the current tubing spool and add a new tubing spool. 3. On step 28 a., will you circulate brine before pumping cement? Yes, we will plan to circulate a bottoms up of brine prior to pumping the cement. 4. On step 28 a., what is the planned cement volume. ? Planning to pump~280 bbls of cement. This is the volume of the 9-5/8”x7” annulus plus 20% excess. 5. On step 28 b., will you shut in the 7” x 9-5/8” to take returns for the new OA? Yes, we will shut in the 7”x9-5/8” for this step. We will take returns out the leak path. When I say leak path, I mean the 0.14 gpm leak that occurs when the IA and OA are pressured to 2500 psi. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU A-06A Casing Tieback Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-015 50-029-20118-01-00 341J ADL 0028286 13450 Surface Intermediate Tieback Liner Liner 8750 2338 9992 1932 1289 4200 9232 18-5/8" 13-3/8" x 9-5/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 7469 22 - 2360 21 - 10013 20 - 1952 9407 - 10696 9250 - 13450 2370 22 - 2359 21 - 8110 20 - 1951 7610 - 8685 7483 - 8750 None 870 2270 4760 7020 10530 9232 930 4930 6870 8160 10160 13177 - 13220 4-1/2" 12.6# L-80 18 - 9290, 9362 - 94488844 - 8829 Conductor 85 30" 23 - 108 23 - 108 4-1/2" HES TNT Packer 4-1/2" Otis HB Packer 9196, 7440 9362, 7574 Date: Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 6/19/2023 Current Pools: Prudhoe Oil Proposed Pools: Prudhoe Oil STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-338 By Kayla Junke at 3:12 pm, Jun 12, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.12 12:45:19 -08'00' Torin Roschinger (4662) 10-404 DSR-6/12/23SFD 6/12/2023 BOPE test to 3000 psi. Annular to 2500 psi. MGR13JUN23 2370 GCW 06/13/2023 JLC 6/13/2023 06/14/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.14 09:23:54 -08'00' RBDMS JSB 061423 RWO A-06A PTD:223-015 Well Name:A-06A API Number:50-029-20118-01 Current Status:Shut-In, Not operable Rig:Thunderbird #1 Estimated Start Date:July 2023 Estimated Duration:14 days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:223-015 First Call Engineer:Michael Hibbert 907-903-5990 Second Call Engineer:Kirsty Glasheen 907-564-5258 907-350-4310 Current Bottom Hole Pressure:3,250 psi @ 8,800’ TVD 7.4 PPGE Max. Anticipated Surface Pressure:2,370 psi (Based on 0.1 psi/ft. gas gradient to surface) Last Shut in WHP:1500 psi (Taken on 4/16/2023) Min ID:2.370” ID @ 11,079’ 3-3/16” x 2-7/8” XO in production liner Max Angle:109 Deg @ 13,290’ Brief Well Summary: A-06A is a recently CTD sidetracked well that was brought online in April 2023. Well began exhibiting IA x OOA communication. An OOA downsqueeze was pumped on 5/22/23. Post cement job the well failed a CMIT-IAxOA and MIT-IA. An Eline LDL was run and found a leak from the IA to the OA (.5 bpm @ 1500 psi) at the 9-5/8” x 13-3/8” packer at 1925’. No other leak signatures were found, but another leak of .14 gpm occurs when the IA and OA are pressured up to 2500 psi (not leaking into tubing and the tree/wellhead does not appear to be the leak point). Objective: Pull the existing 4-1/2” 13Cr tubing out of the well. Repair the casing integrity by installing a fully cemented 7” tieback and cementing 7” x 9-5/8” and 9-5/8” x 13-3/8” annuli. Run new 4-½” 13Cr gas lifted completion. Achieve a passing MIT-IA & MIT-T. Notes on Wellbore Condition: - Well is currently secured with a X-plug at 9232’. Pre-rig the X-plug will be pulled and a CBP will be set ~9180’. - Leak rate outside the IA and OA is .14 gpm @ 2500 psi. Leak rate down the IA to the OA is .5 bpm @ 1500 psi with open bleed on OA. - All existing perforations will be isolated with a bridge plug that will be drilled out after cement job on the rig. 8/28/2022 PPPOT-T passed 5,000psi 8/28/2022 PPPOT-IC passed 3,500psi Wellwork Program: Pre RWO work (non-Sundry): DHD: 1. Cycle tubing hanger LDS. 2. PPPOT-T and PPPOT-IC. Slickline: 3. Pull X-plug from 9232’. 4. Set CBP @ ~9165’. Pressure test tubing to 1500 psi to confirm plug integrity. - mgr 2,370 psi RWO A-06A PTD:223-015 * Sundry Procedure (approval Required to Proceed) Eline: 5. Cut TBG at ~9,114’ (5’ below top collar of first full Joint above X-nipple @ 9165’). Tie in to tubing tally dated 7/9/15. 6. Circulate 2x surface to surface volume with 1% KCl. 7. U-tube in diesel protect to tubing and IA – 172 bbls. DHD: 8. Bleed WHPs to 0psi. Valve Shop: 9. Set and test TWC. 10. ND production tree and tubing head adapter. 11. Inspect lift threads. 12. NU BOPE. a. Top down: Annular, 2-7/8” x 5” VBRs, Blinds, Flow Cross, 4-1/2” x 7” VBRs. Proposed RWO Procedure: 13. MIRU Thunder Bird #1. a. RU a return line from the OA to the flowback tank. b. OA has a failed packer @ 1925’. c. Well is secured with plug at ~9165’. d. Known leaks are IA x OA leak at the 9-5/8” x 13-3/8” production packer at 1925’ and a leak of .14 gpm when the IA and OA are pressured up to 2500 psi (likely depth is 9-5/8” FOCs at 2150’ and 2232’). e. Tubing had integrity prior to cut at 9114’. f. Well is circulated with 1% KCL and has a FP cap to 2500’ with 9.8 ppg NaCl, no diesel freeze protect. 14. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Thunderbird #1 BOP test procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8” x 5” VBR’s with 4-1/2” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. Test the 4-1/2” x 7” VBRs with 4-1/2” and 7” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Pull TWC. Use lubricator if pressure is expected. 16. No control line spooler needed. 17. Rock out diesel freeze protect. Circulate bottoms up with 1% KCL. 18. MU landing joint or spear, BOLDS, and pull hanger to the floor. Pull up to 50k # over to ensure good cut a. Expected PU weigh = 140k #. 19. Pull existing 4-1/2” tubing from cut and lay down. a. If completion will not pull then perform free point. Likely have residual cement around tubing near cement circulating point at 2115’. b. Consider cutting tubing at appropriate depth based on free point calculation (likely ~2050’) and jarring RWO A-06A PTD:223-015 c. Drift the cut end with the overshot. 20. EL – punch 9-5/8” with 5’ of punches @ 1900’. If circulation from step 17 is adequate then this step can be cancelled. 21. Pick up work string and mill. Perform cleanout run to ensure 9-5/8” casing is clear of any cement strings. 22. Make dress-off BHA and washover the 4-1/2” stub. The Logan overshot to be ran on 7” tieback is ~5ft long, so please run at least 5’ of washpipe. 23. SBWS. 24. Run 7” L-80 tieback with centralizers every other joint. Order of 7” tie-back - a. 4-1/2” Logan sealing overshot b. NCS cementing sleeve c. PBR d. 7” casing back to surface 25. Collect PUW and SOW then overshot the 4-1/2” stub. Set at least 10k # down to shear the packer protector sleeve inside the overshot. PU 10k # over to see if grapple in overshot is engaged. a. If unable to engage fish, may have to rotate slowly. b. Packer protector sleeve in overshot pinned to shear at 4.5k # down. 26. After overshot is planted, pressure test inside of 7” to verify overshot is sealing to ~700psi. 27. Space out and land 7”. 28. Make up NCS sleeve shifting BHA + drill collar on workstring, TIH to sleeve to cement tieback to surface. a. Pump cement down WS through NCS sleeve until good cement returns seen coming back from the 7” x 9-5/8” – close in 7” x 9-5/8”. b. Pump an additional 125 bbls of cement down the WS taking returns from the 9-5/8” x 13-3/8” displace cement and close NCS sleeve. 29. Pull a few joints of workstring OOH then set a storm packer below the wellhead and test to 500psi. 30. Confirm no flow then break BOP stack and stack new tubing spool with secondary packoff. a. Test packoff to 3,500psi. 31. NU BOPs, install test plug in new hanger profile. Test break to 3,000psi, then pull test plug. 32. Pull storm packer, turn the well over to 1%KCl. 33. MIT 7” casing to 3,000psi for 30min. 34. Mill out CBP and recover remnants. Bullhead kill the well. Maintain hole-fill at minimum rate or keep fluid level at surface. Lay down workstring. 35. Run 4-1/2” 13Cr gas lifted completion per tally. a. The packer will be set @ ~9100. This should put the NCS sleeve behind the bottom joint of tubing that is mule-shoed. 36. Land tubing hanger and reverse in corrosion inhibited 1% KCl into the IA. 37. Drop ball and rod, set packer, MIT-T and MIT-IA to 3,000psi. 38. Shear valve in top GLM and freeze protect well to 2,500’. 39. Set TWC. 40. RDMO. Valve Shop: 41. ND BOPE 42. NU tree and tubing head adapter. ~280 bbls of 15.8 ppg cement (20% excess 7" x 9-5/8" annulus) -mgr 7" x 9-5/8" annulus to be shut in. -mgr Circulate wellbore volume to assure balanced fluids before cementing.-mgr RWO A-06A PTD:223-015 43. Test both tree and tubing hanger void to 500psi low/5,000psi high. 44. Pull TWC. * End of 10-403 Sundry Work Slickline: 45. Pull ball and rod. 46. Set GLV’s per GL Engineer. 47. Pull RHC. Contingent Coil: 48. MU and RIH with mill to clear liner of any debris/push CBP to bottom. 49. RDMO. Hand well over to put on production. Operations: 50. Test SVS within 5 days of putting well online. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO A-06A PTD:223-015 1. Current Wellbore Schematic RWO A-06A PTD:223-015 2. Proposed Wellbore Schematic ~9078’ 7” shear out PBR and seal assembly, ID = 6.151” ~9114 ~9110 ~9114 ~9028 ~8968 ~8918 9165’ 4-1/2” OTIS x nip ID=3.813” RWO A-06A PTD:223-015 RWO A-06A PTD:223-015 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU A-06A OOA Cement Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-015 50-029-20118-01-00 13450 Surface Intermediate Tieback Liner Liner 8750 2338 9992 1932 1289 4200 9232 18-5/8" 13-3/8" x 9-5/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 7469 22 - 2360 21 - 10013 20 - 1952 9407 - 10696 9250 - 13450 22 - 2359 21 - 8110 20 - 1951 7610 - 8685 7483 - 8750 None 870 2270 4760 7020 10530 9232 930 4930 6870 8160 10160 13177 - 13220 4-1/2" 12.6# L-80 18 - 9290, 9362 - 9448 8844 - 8829 Conductor 85 30" 23 - 108 23 - 108 4-1/2" HES TNT Packer 9362, 7574 9196, 9362 7440, 7574 Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028286 18 - 7516, 7574 - 7644 OOA from Surface to 2115' Pump 285-bbls 15.8-ppg Cement with 495-psi final treating pressure. 843 Well Not Online 1065 3764 1612 100 269 1120 323-262 13b. Pools active after work:Prudhoe Oil 4-1/2" Otis HB Packer 9196, 7440 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:55 pm, Jun 09, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.09 12:35:23 -08'00' Torin Roschinger (4662) DSR-6/12/23 RBDMS JSB 071723 WCB 1-31-2024 ACTIVITY DATE SUMMARY 5/18/2023 T/I/O/OO=200/200/230/230 Circ Out Well (Cement Squeeze) Pump down Tbg taking returns UP IA to A-43 FL w/ 5 bbls 60/40, 567 bbls 1% KCL. Pump 170 bbls DSL down IA taking returns up TBG to A-43 FL. U-Tube FP into TBG. FWHP=430/430/120/390 Casing Valves OTG, S-Line on locaion upon departure. *Complete* 5/18/2023 ***WELL SHUT IN ON ARRIVAL*** PULL OGLV & SET FLOSLV IN ST #2 (7,556' MD) LRS CIRCED OUT w/ 567BBLS CISW, 170BBL DSL FP. PULL FLOSLV & SET RK-DGLV IN ST #2 (7,556' MD) PULL GLV AT ST #3 (5,531' MD) ***CONTINUED ON 5/19/23 WSR*** 5/19/2023 ***CONTINUED FROM 5/18/23 WSR*** SET RK-DGLV AT ST #3 (5,531' MD) PULLED GLV & SET RKP-FLOSLV AT ST #4 (3,297' MD) ***WELL S/I ON DEPARTURE*** 5/20/2023 T/I/O/OO= 400/400/103/239. LRS 72 Circulate Wellbore (CEMENT SQUEEZE). Pumped down the IA while taking OOA returns to A-43 Flowline. Pumped 270 bbls of 160*F diesel and 115 bbls of 9.8 ppg brine. Let the diesel soak in the OOA for 1 hour. Pumped another 365 bbls of 9.8 ppg brine to displace the diesel out of the well. Final T/I/O/OO= 600/191/117/188 5/22/2023 T/I/O/OO= 471/0/95/0. LRS 72 Assist HES with CEMENT SQUEEZE(OA/IA DWNSQZ). HES pumped 100 bbls of surfactant and 285 bbls of 15.8 ppg cement down the OOA while taking IA returns to OTT. 1 to 1 returns. LRS pumped 30 bbls of gel and 250 bbls of 140*F SW at 4 bpm down the TBG with IA returns choked back to 1100 psi. OOA was at 380 psi. LRS pumped 605 bbls of 160*F SW down the TBG with IA returns to help set up cement. Pumped 250 bbls 160* Diesel to freeze protect well. TOC in OOA at surface. FWHP T/I/O = 1113/1289/260/18 SV/WV/SSV = S, MV = O, IA/OA/OOA = OTG Pad op notified upon LRS departure. 5/24/2023 T/I/O/OO = SSV/380/110/0. Temp = SI. Strap OOA cement top (IAxOOA). ALP = 300 psi SI @ CV. Removed flanged from top of OOA riser. Cemented to surface, cement not fully cured. SV = C. WV= LOTO. SSV, MV = O. IA, OA, OOA = OTG. 13:45 5/25/2023 T/I/O/OOA= 114/67/95/0 (CMIT-TxIA) **Attempted CMIT-TxIA** Pumped 12.8 bbls of diesel into TBG to bring TxIA up to 1590/1557 psi. OA communication halted CMIT- TxIA. Pumped a total of 1.35 bbls of Diesel down OA to troubleshoot communication. Bled back ~9 bbls from TxIA. Bled back ~1.1 bbls from OA. Valve Positions - SV/WV/ SSV= Closed, MV= Open, IA/OA/OOA= OTG FWHPs= 56/34/69/0 5/25/2023 T/I/O/OO = 100/70/100/0. Temp = SI. POT-IC (Fullbore req). ALP = 300 psi, AL SI @ casing valve. POT-IC: Stung into test port, 300 psi. Bled void to 0 psi & monitored while LRS pumped down TBG & IA as with no change in pressure. Monitor while LRS pumped down OA with no changes in void. LRS in control of well upon departure. 17:30 5/26/2023 T/I/O/00=3/0/98/0 (ANN-COMM) TBG,IA,OA Communicationg Testing TBG,IA,OA. Did multipule tests look at Log for Pressures / Pressure Loss Test Inconclusive.FWHP=3/0/98 Daily Report of Well Operations PBU A-06A () Pumped down the IA while taking OOA returns to A-43 Flowline. Pumped 270 bbls ofg 160*F diesel and 115 bbls of 9.8 ppg brine.Let the diesel soak in the OOA for 1 hour. g Pumped another 365 bbls of 9.8 ppg brine to displace the diesel out of the well. ( HES pumped 100 bbls of surfactant and 285 bbls of 15.8 ppg cement ) down the OOA while taking IA returns to OTT. 1 to 1 returns Daily Report of Well Operations PBU A-06A 5/27/2023 T/I/O=91/119/111. (ANN-COMM) Combo MIT-TxIAxOA to 2600 Psi. Pumped 11 bbls down tbg to reach test pressure. Tested 6 times look at AWGRS for pressures. FWHP=63/97/102. Left well in dso Control. 5/28/2023 T/I/O = 80/120/120/0. Temp = SI. Bleed WHPs to 0 psi (eval failed CMIT TxIAxOA). ALP = 100 psi, SI @ CV. T, IA, and OA FL near surface. Bled TP to BT from 80 psi to 0 psi in 30 min (2 bbls). IAP decreased 60 psi during TP bleed. Bled IAP to BT from 60 psi to 0 psi in 45 min (0.5 bbls). Bled OAP to BT from 110 psi to 80 psi in 30 min (4 bbls). No monitor. Final WHPs = 0/0/80/0. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 17:00 5/29/2023 T/I/O = Vac/10/70/0. Temp = SI. Bleed WHPs to 0 psi (eval failed CMIT-TxIAxOA). ALP = 200 psi, SI @ CV. Bled OAP to BT from 70 psi to 0 psi in 3 hrs (2 bbls) held an open bleed on the OA for 2 hr. IAP decreased 10 psi during OAP bleed. Monitored for 30 min. WHPs unchanged. Final WHPs = Vac/0/0/0. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 13:30 5/30/2023 T/I/O/OO= 0/0/6/0 CMIT TxIAxOA FAILED to 2500 psi ( MA=2600 psi ) Pumped 18.4 bbls crude to pressure up. CMIT failed multiple attempts. See log for details. Bled back 10 bbls FWHPs=0/30/40/0 ***OOA remained at 0 psi for the duration of job*** 5/31/2023 T/I/O/OO= 179/197/211/0 (CEMENT SQUEEZE (OA/IA DOWNSQZ)) ***MIT-T to 2,634 psi PASSED*** ***CMIT-IAxOA to 2620/2625 psi FAILED*** ***LLR of IAxOA ~0.651 gallons/min*** Pressured up TBG to 2,721 psi with 2.52 bbls of Crude. 1st 15-minute loss 62 psi, 2nd 15-minute loss of 25 psi, total loss loss of 87 psi in 30 minutes, Bled back ~1.6 bbls. Attempted CMIT-IAxOA by pressuring up strings with 8.57 bbls of Crude. MITs failed with a LLR of ~0.651 gallons/minute. See "Data" and "Log" tab for details. Bled back ~7.9 bbls SL in control of well upon departure. FWHPs= 205/105/105/0 5/31/2023 ***WELL S/I UPON ARRIVAL*** (Cement squeeze) SET 4-1/2" WHIDDON CATCHER ON TOP OF PLUG AT 9232' MD PULLED RKP-FLWSLV IN ST# 4 AT 3297' MD, REPLACED w/ RK-DGLV LRS PERFORMED PASSING MIT-T TO 2500 psi LRS PERFORMED FAILING CMIT-TxIA MULTIPLE TIMES PULLED EMPTY 4-1/2" WHIDDON AT 9,232' MD ***WELL S/I UPON DEPARTURE*** 6/1/2023 T/I/O/OO = 730/140/150/Vac. Temp = SI. MIT-IA FAILED to 2500 psi w/Diesel & IAxOA LLR (eval IAxOA). ALP = 300 psi, SI @ CV. Max applied = 200 psi, Target = 2500 psi. Used 2 bbls of diesel to pressure IAP from 140 psi to 200 psi. Unable to catch pressure and increase IAP more than 200 psi FAIL. OAP tracked IAP increase pound for pound. Unable to achieve LLR @ 2500 psi because the LLR exceeded the 0.25 bbls/min rating of the DHD triplex. Bled OAP to BT from 200 psi to 70 psi in 5 min. IAP decreased 140 psi. A total of 2.5 bbls of diesel was bled back to the BT. Final WHPs = 730/60/70/Vac. SV, WV = C. SSV, MV = O. IA, OA, & OOA = OTG. 11:00 MIT-IA FAILED to 2500 psi LRS PERFORMED FAILING CMIT-TxIA MULTIPLE TIMES CMIT TxIAxOA FAILED to 2500 psi ( MA=2600 psi ) Pumped 18.4( bbls crude to pressure up. CMIT failed multiple attempts Daily Report of Well Operations PBU A-06A 6/8/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 2" WB, REED ACCOUSTIC TOOL (22' OAL, 2" MAX OD) LOG BASELINE TEMP PASS DOWN @ 120 FPM TO 9,225' T-BIRD PUMP CRUDE DOWN IA @ .5 BPM TAKING RETURNS FROM OA LOG DYNAMIC TEMP PASS UP @ 120 FPM FROM 9,225'-2,500' LOG DYNAMIC TEMP PASS UP @ 100 FPM FROM 2,500' TO SURFACE TEMP AND ACCOUSTIC TEMP SUGGESTS LEAK @ 1,925' (OA PACKER) ISOLATE OA BLEED, PRESSURE UP IA & OA TO 2,500 PSI LOG DYNAMIC ACCOUSTIC PASS UP FROM 9,225'-SURFACE PERFORM STATION STOPS ACROSS FOC'S @ 2,232' & 2,150' LLR WITH OA BLEED CLOSED=.14 GPM NO LEAK FOUND W/ IA & OA @ 2,500 PSI 79.5 BBLS TOTAL CRUDE PUMPED TREECAP INSTALLED & TESTED, TREE VALVES RETURNED TO NORMAL ***WELL LEFT S/I*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU A-06A OOA Cement Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-015 50-029-20118-01-00 341J ADL 0028286 13450 Surface Intermediate Tieback Liner Liner 8750 2338 9992 1932 1289 4200 9232 18-5/8" 13-3/8" x 9-5/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 7469 22 - 2360 21 - 10013 20 - 1952 9407 - 10696 9250 - 13450 2450 22 - 2359 21 - 8110 20 - 1951 7610 - 8685 7483 - 8750 None 870 2270 4760 7020 10530 9232 930 4930 6870 8160 10160 13177 - 13220 4-1/2" 12.6# L-80 18 - 9290, 9362 - 94488844 - 8829 Conductor 85 30" 23 - 108 23 - 108 4-1/2" HES TNT Packer 4-1/2" Otis HB Packer 9196, 7440 9362, 7574 Date: Torin Roschinger Area Operations Manager Michael Hibbert - (C) Michael.Hibbert@hilcorp.com PRUDHOE BAY 5/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: Prudhoe Oil STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Kayla Junke at 1:31 pm, May 01, 2023 323-262 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.01 12:49:21 -08'00' Torin Roschinger (4662) DSR-5/2/23SFD 5/2/2023 2450 MGR02MAY23 10-404 GCW 05/03/23JLC 5/3/2023 5/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.03 09:46:46 -08'00' RBDMS JSB 050423 Well: A-06A PTD: 223-015 Well Name:A-06A API Number:50-029-20118-01 Current Status:Under Eval; Secured; IAxOOA Comms. Rig:FB/SL Estimated Start Date:May 2023 Estimated Duration:2 weeks Reg.Approval Req’std? Yes Date Reg. Approval Rec’vd: First Call Engineer:Michael Hibbert 907-903-5990 Second Call Engineer:Aras Worthington 907-564-4763 Current Bottom Hole Pressure:Est. 3250 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2450 psi (based on previous SIWHPs) Max Inc:See Schematic Integrity Issues:OOAxIA LLR (5 bpm @ 800 psi) @ 2115’ MD Brief Well Summary A-06A is an Under Eval Ivishak producer that developed IAxOOA communication post-CTD sidetrack (LLR is 5 bpm @ 800 psi). Well was POP’d on 4/10/23 and started seeing OOA pressure on 4/12/23. Well has since been fluid packed, secured and an LDL was run to determine leak depth. Leak was found at 2115’. MIT-T passed to 2674 psi on 4/20/23 verifying tubing and plug integrity. MIT-OA passed to 500 psi on 4/24/23. Objective OOA cement down-squeeze to repair the IAxOOA communication. Procedure Slickline w/ Fullbore Assist 1. Pull SO from GLM #2 2. Set flow sleeve in GLM #2 3. Pump into tbg taking returns from the IA – pump at 4-5 bpm, do not exceed ~500 psi on OOA. ¾480 bbls of seawater/FW ¾40 bbls of 60/40 methanol 4. Dummy off GLM #2 and #3 5. Set flow sleeve in GLM #4– Slickline can rigdown. 6. Pump the following into the IA taking returns from the OOA – Pump at 4-5 bpm with max pressure on the OOA of 500 psi: ¾Methanol spear if needed ¾275 bbls of 160°F of diesel ¾113 bbls of 200°F 9.8 ppg brine ¾Shutdown pump – let diesel soak in OOA for 1 hour to break up arctic pack ¾200 bbls of 200°F 9.8 brine at max rate (4-5 bpm) ¾100 bbls of 200°F FW+surfactant ¾387 bbls of hot seawater/FW (full IA/OOA volume from leak depth of 2115’) 7. Ideally go straight into cement downsqueeze. If not possible, then freeze protect IA and OOA with water based fluids (either 9.8 brine or 50/50 methanol – don’t use diesel or crude) 8. Pump 300 bbls of 12-15.8 ppg Class G cement down the OOA with returns from the IA to cement the OOA from surface to IAxOOA leak at 2115’. Pump the following at max rate staying below 500 psi treating pressure on the OOA: ¾Methanol spear if needed ¾10 bbls of weighted spacer ¾300 bbls of 12-15.8 ppg Class G cement Well: A-06A PTD: 223-015 9. Shut down pumps and record tubing, IA and OOA pressures. Maintain that tubing and IA pressures as a minimum through the remainder of the pumping operation to prevent additional cement from entering the IA. Based on calculations this should be ~630 psi. 10. Pump the following down the tubing taking returns from the IA while maintaining back pressure on the IA: ¾20 bbls of gel – both to sweep and contaminate any cement in the IA ¾230 bbls at max rate – roughly surface to surface volume through the flow sleave at GLM #4 @ 3297’ ¾400+ bbls of seawater/FW at minimum rate until cement reaches 1.5x thickening time ¾5 bbls of methanol ¾230 bbls of 140°F diesel – continue pumping at minimum rate to allow cement time to gel and set as the IA is circulated). Keep at least 630 psi on the IA as it is circulated and walk pressure up to ~1000 psi on the IA as diesel is circulated to surface. Trap ~1000 psi on the IA when done circulating to keep cement in place. Volumes: Top MD bot MD Size ID bbls/ft.Ft. volume bbls 4-1/2” Tubing to Flow Sleeve 0 3297’4-1/2” 12.6#3.958”0.0152 3297’50 IA Total Volume to Flowsleeve 0 3297’4-1/2”x9-5/8”8.681”x4.5”.0535 3297’177 18-5/8” x 13-3/8” annulus 0 2115’ 18-5/8”109.3# x 13-3/8” 68# 17.655” x 13.375”0.129 2115’273 Ppg:14 ppg Class G – Mix on the fly Slurry Temperature:between 80° and 110°F API fluid loss:40 - 200 cc (20-100cc/30min) Thickening Time:Minimum 7 hours Compressive Strength:2000 psi in 24 – 60 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 5 Cement contamination 2 Safety 0 Minimum required thickening time:7 DHD/Operations 1. Strap TOC in OOA and determine if top job is necessary. Top job with Wellock or cement. 2. CMIT TxIA to 2500 psi. 3. Re-classify well as Operable. Slickline 1. Pull TTP 2. Install GL design per GL Engineer 3. Turn well over to Operations and POP Well: A-06A PTD: 223-015 A-06A Current Well: A-06A PTD: 223-015 A-06A Proposed Cemented OOA Surface to Leak @ 2,115’ MD Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: May 1, 2023Subject: Changes to Approved Sundry Procedure for Well A-06ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date David Douglas Hilcorp North Slope, 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: Hilcorp North Slope, LLC Date: 04/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU A-06A PTD: 223-015 API: 50-029-20118-01-00 FINAL LWD FORMATION EVALUATION LOGS (03/22/2023 to 03/29/2023) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 223-015 T37616 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.24 15:26:44 -08'00' 13-3/8"x9-5/8" 96.5#/109.3# L-80/N-80 3-1/2"x3-1/4" x2-7/8"9.3#/6.6#/6.5# By James Brooks at 3:18 pm, Apr 25, 2023 Completed 4/8/2023 JSB RBDMS JSB 05082023 G MGR03AUG2023 DSR-10/25/23 4.17.2023 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: 2023.04.17 15:08:59 -08'00' Monty M Myers Activity Date Ops Summary 3/20/2023 Arrive A-pad spot drill module and pit module. Accept rig at 15:30. Start MIRU checklists. Verify flowline pressure is zero. Leak tight test on swab, leaking. Grease crew out to service tree valves. Continue MIRU checklists. Spot shop module, build up floor in cellar. Grease valves for BOP test. Grease tree valves, Get good LTT on SV, MV. Close SSV. Remove tree cap. Set BOP stack down. Install MP line. Install BOPs. Finish greasing valves. M/U nozzle, M/U injector to well. Change packoffs. Fill reel forward w/ 10 bbls MeOH + fresh water. Fluid pack reel and surface lines. 3/21/2023 Fluid pack surface lines for shell test. Shell test stack, surface lines and Inner Reel Iron and Packoffs. Leaking Grease Port on Stack HCR, bleed off and Grease. Good Shell Test. Test BOPs as per Hilcorp and AOGCC regulations. Test witness is waived by AOGCC Inspector A. McLeod. All tests 250 / 3500 psi. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind/Shear, R2, BL2, C15 - Pass. Test 3: Annular (2-3/8"), TIW1, B1, B4 - Pass. Test 4: Upper 2-3/8" Pipe/Slips, TIW2, B2, B3 - Pass F/P on B2. Test 5: Lower 2-3/8" Pipe/Slip, C5, C6, C8, TV2 - Pass. Test 6: Choke A, Choke C - Pass. Stop testing to replace Sequencing Valve on 3" Combi Ram. Test 7: C4, C1, TV1 - Pass. Test 8: 3" Pipe/Slip, C2, C3 - Pass. Testing completed, RD test equipment. Change lubricators, install BHI Floats and test. Body test UQC, good test, test floats, good test. PT PDL's, to 250 low and 3500 high. M/U nozzle BHA. Skid injector over M/U to well. Finish offloading KCl to pits. Change out valve C13 and PT, good. Calibrate In/Out MM w/ fresh water. BH kill well. Pump 10 bbls MeOH followed by 1% KCl. Unable to get enough rate for effective BH kill, pumping 1.9 bpm / 1500 psi. Prep for nozzle run. Move new MeOH pup into position. Pump 15 bbls MeOH to end of CT followed by hot KCl at 3.4 bpm to push slack forward. RIH w/ nozzle BHA 200 psi WHP keeps returns < 1:1 to tiger tank. Stack wt 9378' up wt is 51k each time. Try various pump rates and running speeds, different WHP unable to pass. Swap well to KCl from 9380' keep 200 psi WHP. Stop and vac out tiger tank. POOH keep 200 psi WHP. 3/22/2023 OOH, tag up and close the swab, line up on the MP Line and maintain 200psi WHP. Purge Lubricator and blow down stack to the tiger tank. LD Nozzle BHA. Test eline, good test, PU the milling BHA in the PDL. Stab PDL onto the stack and PD the milling BHA. RIH on a closed choke with the milling BHA. WT CHK at 9266' = 42k, RIH WT = 21k. Slow down at 9340' for 9-5/8 x 4-1/2 PKR. Tag 3x at 9377', close the EDC, lightly tag, roll the pump and see if we can make through the PKR. Set down 2.5k, roll pump and rolled through. Log tie in at 10460'. Correct depth -15', RIH to tag pinch point. WT CK = 62k, RIH WT = 29k. Tag pinch point on depth at 10695' (TOWS 10690'). Online with pumps for bottoms up kill taking all returns to the TT. WHP = 263 psi, IAP = 617 psi, OAP = 543 psi. 92 bbls of 141 bbls back getting gas back at surface, maintain <150psi DS of the choke. Bottoms up is clean, purge lubricator. Reduce rate to milling rate, 2.81 bpm in and 2.47 bpm out ~20 bph loss rate w/145psi WHP from TT line. 180 bbls back, bring returns inside, loss rate or 9 bph. Shut down pump, close EDC, online with pump and work down to start milling the window. Vibration on MWD at 4 with free spin at 2.5 bpm. On bottom milling at 10696.0'. Rate In = 2.72 bpm, Rate Out = 2.58 bpm out. MWT In = 8.27 ppg, MWT Out = 8.38 ppg. WOB = 2.98k. Mill window at 10700.0'. Rate In = 2.74 bpm, Rate Out = 2.63 bpm out. MWT In = 8.27 ppg, MWT Out = 8.39 ppg. WOB = 2.64k. Pump 10 bbls hi-vis every 1 ft drilled. Casing exit at 10704' continue time milling to let reamer work. After 10705' drill rathole to 10714'. Geo confirms Shublik in sample. 1st reaming pass up 80 psi MW at 10696.6'. 1st down 60 psi MW at 10697.8'. 2nd up 55 psi MW at 10696.1'. 2nd down 48 psi MW at 10697.7'. 3rd up 44 psi MW at 10696.0'. Continue reaming passes 1 ft/min. 3rd down 40 psi MW at 10697.7'. 4th up 29 psi at 10696.0'. 4th down 36 psi 10697.6'. 5th up 29 psi at 10696.0'. Dry drift is clean, tag bottom of rathole. Pick up above whipstock, open EDC 10 min no flow is good. POOH. 3/23/2023 Continue POOH with window milling BHA. OOH, flow check well. Good no flow, PU the injector, LD the BHA and gauge mills. Window Mill = 3.79 go 3.78 no go - Mill was rung out on the leading edge of the gauge. String Mill = 3.81 go, 3.80 no go. MU a nozzle and jet the stack. MU the build BHA w/2.3 bend motor and 1-1 HYC 3D Cutter Bit. A little tight going through the 4-1/16" Tree Valves. BHA MU, RIH. Log tie in at 10460'. -15' correction, RIH to 10690' and displace well to Mud. Displace well to mud. On bottom drilling build. Circ PSI = 2975 psi, IAP = 1189 psi, OAP = 463 psi. In Rate = 2.78 bpm, Out Rate = 2.78 bpm. Density In = 8.58 ppg, Density Out = 8.69 ppg, ECD = 9.6 ECD. Surf WT = 23k, WOB = 3.24k. Slow ROP Drilling in Shublik. Circ PSI = 2928 psi, IAP = 1293 psi, OAP = 474 psi. In Rate = 2.76 bpm, Out Rate = 2.78 bpm. Density In = 8.60 ppg, Density Out = 8.75 ppg, ECD = 9.67 ECD. Surf WT = 26k, WOB = 2.25k. Drill from 10800'. Pump Rate: 2.78 / 2.70 bpm In / Out. MW: 8.61 / 8.74 ppg In / Out. Window ECD = 9.67 ppg on open choke. 10800' 5 bbls lo/hi vis. At 10842' lose returns. Wiper trip to window, pull through and establish loss rate. Returns slowly coming back. Losses 70 bbl/hr at 2.8 bpm close EDC and RIH. Drill from 10842' returns improving. Pump Rate: 2.78 / 2.03 bpm In / Out. MW: 8.63 / 8.75 ppg In / Out. Window ECD = 9.57 ppg on open choke. 10920' 5 bbls lo/hi vis. 150' wiper trip from 11000' is clean up/down. Drill from 11000'. Pump Rate: 2.83 / 2.60 bpm In / Out. MW: 8.67 / 8.82 ppg In / Out. Window ECD = 9.70 ppg on open choke. Drill to TD of build section 11075'. Pump 5 bbls lo/hi vis sweeps wiper to window. Jog below window pull through clean. Jog above window, open EDC. Jet whipstock tray. Jet 7" casing at 20 ft/min. 3/24/2023 Continue POOH at 5900' for lateral BHA. OOH, flow check well. Good no flow, LD build BHA. Bit Grade = 2-1-CT. MU the lateral BHA w/1.1 bend motor, RB HYC 4.25" Bi-Center Bit. RIH with lateral BHA. Tag at 9382' at 9-5/8" PKR, HS, orient to 30 ROHS and passed through. 10460' Log Tie In, correct depth -17'. PUH to 9100' and log CCL for LTP. Log CCL from 9100' to 9600'. RIH to continue drilling. Drill from 11,073'. Pump Rate: 2.84 / 2.64 bpm In / Out. MW: 8.68 / 8.81 ppg In / Out. Window ECD = 9.86 ppg on open choke. KWD Drill with Jones Crew. Drill from 11,359'. Pump Rate: 2.83 / 2.69 bpm In / Out. MW: 8.71 / 8.84 ppg In / Out. Window ECD = 9.91 ppg on open choke. 150' wiper trip from 11420' clean up/down. Drill from 11,420' to 11500'. Pump Rate: 2.77 / 2.67 bpm In / Out. MW: 8.74 / 8.89 ppg In / Out. Window ECD = 9.86 ppg on open choke. 11470' 5 bbls lo/hi vis. Wiper trip to window from 11500' clean pass. Jog below window and pull through. Jog above window, open EDC. Jet whipstock tray. Clean 7" at 30 ft/min. Turn around at 9380' and stack wt, continue wiper trip through 9-5/8" section. RIH 30R slight push at 9355' uncorrected. Tie-in depth 10480' correct +4.5'. Close EDC, RIH through window to bottom. Drill from 11500' to 11545'. Pump Rate: 2.78 / 2.71 bpm In / Out. MW: 8.73 / 8.88 ppg In / Out. Window ECD = 9.87 ppg on open choke. 11515' 5 bbls lo/hi vis. Average ROP falls < 10 ft/hr POOH for bit. Clean pass to window, jog then pull through. Jog above window then open EDC. Jet whipstock tray. POOH pump 3 bpm keep 9.8# ECD at window. 50-029-20118-01-00API #: Well Name: Field: County/State: PBW A-06A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 3/22/2023Spud Date: 3/25/2023 4000' continue POOH for bit trip. OOH, PUD the lateral BHA, floats leaking, switch to PU Checklist for failed bottom floats. BHA OOH, Bit Grade = 4-4-BT. MU and the lateral BHA and PD. BHA deployed, good test on tools, RIH. Log tie in, correct depth -17', close EDC and RIH to continue drilling. Drill lateral from 11,545'. Pump Rate: 2.78 / 2.73 bpm In / Out. MW: 8.73 / 8.89 ppg In / Out. Window ECD = 9.95 ppg on open choke. Drill lateral from 11,650'. Pump Rate: 2.78 / 2.73 bpm In / Out. MW: 8.74 / 8.89 ppg In / Out. Window ECD = 9.96 ppg on open choke. Diff stuck on bottom at 11736'. Pull 80k while waiting for permission to pull 100k. 6 pulls to 80k no movement, 15 min got permission for 100k and pulled free. Pull short wiper then RIH to continue drilling. Drill to 11800'. 150' wiper trip from 11800' clean up/down. Drill lateral from 11800', frequent pickups diff sticking. Pump Rate: 2.82 / 2.74 bpm In / Out. MW: 8.77 / 8.92 ppg In / Out. Window ECD = 10.01 ppg on open choke. 11860', 11930' 5 bbls lo/hi vis. Wiper trip to window from 11950' clean pass. Jog below window and pull through. Jog above window, open EDC jet whipstock tray and 7" until returns clean. Tie-in depth correct +8'. Close EDC, RIH pass window. RIH to bottom. Drill lateral from 11950', frequent pickups diff sticking. Pump Rate: 2.83 / 2.79 bpm In / Out. MW: 8.76 / 8.90 ppg In / Out. Window ECD = 9.96 ppg on open choke. Differentially stuck at 11985'. Work pipe 15k to 95k pop free. 150' wiper clean up/down. Drill lateral from 11985', frequent pickups diff sticking. Pump Rate: 2.88 / 2.82 bpm In / Out. MW: 8.75 / 8.92 ppg In / Out. Window ECD = 10.01 ppg on open choke. 150' wiper trip from 12100' clean up/down. Drill lateral from 12100', frequent pickups diff sticking. Pump Rate: 2.87 / 2.79 bpm In / Out. MW: 8.75 / 8.92 ppg In / Out. Window ECD = 10.02 ppg on open choke. 12115' 5 bbls lo/hi vis. 3/26/2023 Continue drilling lateral at 12,297'. In Rate = 2.87 bpm, Out Rate = 2.79 bpm. In Density = 8.79 ppg, Out Density = 8.96 ppg, ECD = 10.01. WHP = 0 psi, IAP = 553 psi, OAP = 511 psi, OOAP = 50 psi. Surf WT = 23.5k, WOB = 2.8k. Drilled 450' to 12400, pull long wiper to the window. Wiper trip to the window was clean jog below the window and pull through at min rate. Open the EDC, jet across the WS tray then PUH to 9450' with EDC inside the 4-1/2 TBG then RIH at 100 fpm to increase AV's. Log tie in at 10480', correct depth +10'. Stop above the TOWS and continue to Circ at max rate, still getting a lot of cuttings, circ at max rate until shaker is clean. Shaker has cleaned up, RIH to continue drilling. Back on bottom drilling at 12405'. In Rate = 3.10 bpm, Out Rate = 3.00 bpm. In Density = 8.80 ppg, Out Density = 8.94 ppg, ECD = 10.01. WHP = 0 psi, IAP = 611 psi, OAP = 520 psi, OOAP = 50 psi. Surf WT = 21.5k, WOB = 1.75k. Drilling at 12540'. In Rate = 2.86 bpm, Out Rate = 2.81 bpm. In Density = 8.80 ppg, Out Density = 8.96 ppg, ECD = 10.05. WHP = 0 psi, IAP = 701 psi, OAP = 523 psi, OOAP = 50 psi. Surf WT = 16.5k, WOB = 2.60k. 12590', 12640', 12665' 5 bbls lo/hi vis. Wt transfer and ROP are poor now with inc > 96 deg. POOH for agitator and check bit. Clean pass to window, jog and pull through. Jog above window and open EDC, jet tray. Clean 7" at 30 ft/min. POOH keep 9.9# ECD at window. Pressure undeploy BHA #5. DBV not holding, use alternate PUD checklist. L/D BHA bit is 3-2 RO. Function test BOPs. Inspect 20' of CT above connector. 3/27/2023 Pressure deploy BHA #6. RIH BHA #6, shallow hole test agitator is good. Tie in and correct -15'. RIH through window clean. Begin displacing to new 8.6 ppg PowerPro mud system. Drill ahead from 12676' to 12,900' and BHA wiper trip. In Rate = 2.80, Out Rate = 2.76. In Mud WT = 8.63 ppg, Out Mud WT = 8.94 ppg. IA = 228, OA = 483. Circ pressure = 3611, WOB 2.2 - 2.7k. Drill to 12,935' and become differentially stuck. Pump High/Low vis sweeps and work coil to max over pull. Pump 10 bbls LVT with 1% KCL spacers. Pump 8 bbls around BHA and pull free. Circ out LVT and wiper to window. Wiper to 12,218' and circulate all LVT out to tiger tank. RIH to resume drilling. Drill ahead from 12,935'. In Rate = 2.81, Out Rate = 2.83. In Mud WT = 8.67 ppg, Out Mud WT = 8.84 ppg. IA = 491, OA = 492. Circ pressure = 3281, WOB 2.2 - 2.7k. 150' wiper trip from 13000' clean up/down. Drill from 13000' frequent pickups diff sticking. In Rate = 2.80, Out Rate = 2.73. In Mud WT = 8.69 ppg, Out Mud WT = 8.86 ppg. Circ pressure = 3500 - 3650 psi Window ECD = 10.02 ppg. Wt transfer is poor now drilling at 109 deg inc. Wiper trip to window from 13108'. 12220' +4k drag slow pulling speed, otherwise clean. Jog below window and pull through. Jog above window open EDC jet tray. Jet 7" up to 9250' until returns clean up. Tie-in depth correct +12' close EDC. Pass window 0L 0 pump nothing seen. RIH to bottom pump 0.6 bpm. Drill from 13108' frequent pickups diff sticking. In Rate = 2.80, Out Rate = 2.71. In Mud WT = 8.69 ppg, Out Mud WT = 8.84 ppg. Circ pressure = 3500 - 3550 psi Window ECD = 10.09 ppg. 3/28/2023 Drill from 13108' to 13,324' frequent pickups diff sticking. In Rate = 2.79 Out Rate = 2.74. In Mud WT = 8.72 ppg, Out Mud WT = 8.87 ppg. Circ pressure = 3500 - 3550 psi Window ECD = 10.14 ppg. Wiper trip to window from 13,324' to tie in after depth discrepancy between BHI and Nabors. Jog below window and pull through clean. Open EDC and pump at max rate. Log tie in and correc +6.5'. Close EDC and RIH through window clean. Drill from 13,323' frequent heavy pickups diff sticking. In Rate = 2.79 Out Rate = 2.74. In Mud WT = 8.72 ppg, Out Mud WT = 8.87 ppg. Circ pressure = 3500 - 3550 psi Window ECD = 10.14 ppg. 13410', 13433' 5 bbls lo/hi vis. TD called at 13450'. Wiper to window, clean pass. Jog below window and pull through. Jog above window, open EDC pump 10 bbls lo/hi vis jet tray. Jet 7" at 20 ft/min. Wiper trip to surface at 50 ft/min. Tag up and reset depth. RIH tie-in depth from 10480' correct -17'. Close EDC pass window, RIH to bottom to lay in bead pill followed by 9.9# brine. 3/29/2023 Tag and confirm TD @ 13450'. Lay in liner running pill with 1.5 ppb Alpine Drilling beads from 13450'. Circulate 9.9 ppg brine from 11000' to surface. Confirm 9.9 ppg brine at surface. Flow check well and confirm no flow. POOH pumping min rate. In Rate = .95, Out Rate = .39. In Mud WT = 9.82 ppg, Out Mud WT = 9.81 ppg. IA = 190, OA = 480. Paint EOP flag for TD at 9000' (yellow). Paint EOP flag for window @ 6200' (white). OOH - Flow check well. Well on 5 bph losses. Inspect last 20' of coil. Rig injector off of well. L/D BHA #6. Bit graded 2-1. Prep to pump eline slack forward. Pump max rate forward. Break off well and cut 210' Should have 284' of slack. Boot eline and pump forward additional sequence. No additional eline recovered. Cut 16' damaged section of coil out. M/U Nabors CTC pull test 50k is good. PT connector 4k, good. Install nozzle, get on well. Pump 7/8" ball around and recover. Install test risers. Good leak tight test on SV and MV. LO/TO on koomey. Vac out stack down to BOPs. Remove 3" P/S rams install 2-3/8" x 3-1/2" VBRs. 2 bbl/hr losses. Test VBRs 250 / 3500 psi with 2-3/8" then 3-1/2" test joints. Test witness waived by AOGCC Inspector Kam Stjohn. Rig down test equipment, remove test riser. Install nozzle, PT riser break. 2 bbl/hr losses. M/U BHA #7 to drift past 9-5/8" packer, 1 jt 2-7/8" liner + NSAK glide shoe. RIH BHA #7 to 9500' nothing seen. POOH ~2 bbl/hr losses. 3/30/2023 OOH - Flow check well and confirm no flow. L/D drift BHA w/NSAK glide shoe. Service top drive. R/U floor for liner running. M/U and RIH w/2-7/8" 6.5#, L-80, HYD511 solid liner. Fill liner every 10 joints. ~ 4 bph loss rate. Continue M/U liner assembly. 3-1/4" 6.6#, 13Cr, TCII solid liner. 3-1/2" 9.3#, 13Cr, ST-L solid liner. Fill liner every 10 joints. ~ 4 bph loss rate. M/U SELRT + 6 jts PH6. M/U swivel on BHA. Close 2-3/8" P/S rams Strip down over liner, too heavy for injector cart. Get string wt back, open rams, tag up. Circ at surface to clear liner. RIH slow past 9-5/8" packer, tag at 9378' up wt 50k'. Try different running speeds and pump rates stack wt 6 times. Pick up to 9000' and try again various speeds and pump rates stack 7 times. 10 min no-flow is good. Make 1 last attempt then POOH. Tag out and space out. 10 min no-flow is good. Close 2-3/8" P/S rams and strip up. Skid injector back. P/U string wt with blocks (25k), pup jt lifter parts at the XO thread to 2-3/8" PH-6. Change elevators and P/U string wt. Open rams, fill well w/ 4 bbls. L/D 6 jts PH-6 and SELRT tool. L/D 3-1/2" liner. 3/31/2023 Continue L/D liner. Clean and clear rig floor. Break out shoe track and Baker-lock connections. Joint#7 pin galled. Replaced with Joint #62. Joint #40-41 galled. Replace with Joint #58-59. Joint #46 galled. Replace with Joint #60. Run Total of 57 jts of 2-7/8" HYD 511. Swap elevators and make up 10 joints of 3-1/4" liner. Swap elevators make up 44 jts 3-1/2" liner. Fill every 10 jts. Swap elevators M/U SELRT tool + 6 jts PH-6. Hang off liner BHA in 2-3/8" P/S rams, strip injector down over. P/U string wt and open rams. Circ at surface to clear liner RIH slowly. RIH. 4/1/2023 Rate: 0.57 bpm in, 0.27 bpm out. Circ pressure: 449 psi. Mud Weight: 9.82 ppg in, 8.52 ppg out. Stop at white flag (10611.88') - 10584.8' Corrected depth = -27' correction. Rih to window. Start circulating mud. 58K PUW / RIW 25K. Circulated mud to bit. Bring 10 bbls above bit. Run through window without issue. Run liner to bottom. Multiple tags at 13435' MD and motor stalling both times. Discuss with Drilling engineer. Load and launch 3/4" ball. Made multiple attempts to get to seat. Load and launch 2nd 3/4" Ball. Launched with 10 bbls 1%KCL. Ball landed and sheared out at 4300#. PU to breakover twice 13437' to 13431' with a 42K breakover. Release verified. Begin swapping well over to 1% KCL. Line up through Cement MM. KCL around. PJSM with Halliburton. PT low / High to 5000#. Halliburton hydrating water. PJSM w/ all crews for liner cement job. Pump 48.7 bbls cmt into CT, shut down and clear lines back to HES Rig displace cement. Zero out MM when cmt reaches shoe. With 3 bbls cmt left in CT, pick up and side exhaust 4.5 bbls. Stack down 14' higher and launch LWP shears out 3200 psi. Push plug 2 bpm bumps at 29.0 bbls (29.1 calculated). Check floats, holding. Unsting wash liner top 3.5 bpm. POOH pump 3.5 bpm slight losses. Returns go to 9.2# for a short time, only cmt exhaust coming back. Total of 40.8 bbls cmt behind pipe. Tag stripper, 10 min no-flow is good. L/D 6 jts of PH-6 and liner running tools. Tools have functioned normally. Recover both 3/4" balls. M/U nozzle BHA w/ DBPV. Jet stack then RIH to freeze protect well from 2500' with diesel and 60/40 MeOH from 100'. Tag stripper close MV, SSV. Pump remaining FP fluid out to tiger tank. L/D freeze protect BHA. Install nozzle, get on well pump cable back. 4/2/2023 Reverse circulate e-line slack back into reel. Cut 278' coil for 1.8% slack. Make up CTC. Pull test to 50K. Install stinger. Pump slack forward. BHI make up UQC w/o floats. Test electrically. Good test. Pressure test CTC and UQC to 3500#. Perform LTT between SSV and swab. Remove 2-3/8" x 3-1/2" Variables Install 3" Pipe / Slip rams. Pressure test door seals. No leaks. Begin blowing rig down with air. Nipple down MPD line. Nipple down BOPE stack. Install tree cap and test, good. Release rig 18:00. ACTIVITYDATE SUMMARY 4/2/2023 Assist CDR2 w/ Freeze Protect. Pumped 60 bbls 80* Diesel and 10 bbls 60/40 meth into cement line for freeze protect. 4/3/2023 T/I/O=0/35/373 MIT TBG to 1500 psi ( Liner Lap Test ) Pump 2.75 bbls diesel down tbg to 1650 psi to test Liner Lap. TP lost 77 psi 1st 15 min & 18 psi 2nd 15 min Bled back 2.5 bbls to 200 psi FWHPs=200/33/370 4/3/2023 ***WELL S/I ON ARRIVAL*** LRS TEST LINER LAP 1500PSI, (Pass) 2.75 bbls to psi - loss 77psi/18psi) DRIFTED 1-3/4'' SAMPLE BAILER, DEVIATE OUT @ 10,935' SLM (no sample, ~80 deg) TAG DEPLOY SLV w/ 4-1/2" X-CATCHER @ 9,254' SLM / 9,246' MD SET 4-1/2" X-CATCHER @ 9,240' SLM / 9,232' MD ****** ( ~14' BETWEEN X-NIP & DEPLOY SLV )****** ATTEMPTED TO PULL ST#2 @ 7,556' MD ***WSR CONT ON 4-4-23*** 4/4/2023 ***WSR CONT FROM 4-3-23*** PULLED ST#2 RK-DMY FROM 7,556' MD PULLED ST#3 RK-DMY FROM 5,531' MD PULLED ST#4 RK-DMT FROM 3,297' MD SET ST#4 RK-LGLV (16/64"PORTS, 1654#TRO) @ 3,297' MD SET ST#3 RK-LGLV (16/64"PORTS, 1643#TRO) @ 5,531' MD SET ST#2 RK-OGLV (20/64'' PORTS) @ 7556'MD PULLED 4-1/2'' X-CATCHER FROM 9232'MD ***WELL LEFT S/I ON DEPARTURE*** 4/5/2023 (Assist CTU) TFS U-3, Assisted CTU in pressure testing hard iron, coil tubing and BOP's. ***Job Continued on 4-6-23*** 4/5/2023 CTU #9 1.75" CT 0.156". Job Scope: Post CTD: RPM Log & Adperfs Road CTU 9 from Slb Yard. MIRU CTU 9 ***Continue on to WSR 4/6/23*** 4/6/2023 ***Job Continued from 4-5-23*** ((Assist CTU)) TFS U-3, Pumped 34 bbls DSL, 50 bbls 60/40, and 128 bbls 1% KCL assisting CTU. ***Job Continued on 4-7-23*** 4/6/2023 CTU #9 1.75" CT 0.156". Job Scope: Post CTD: RPM Log & Adperfs Finish BOP test, recover 1.188" drift ball, Make up BOT CTC and shorty MHA. MU HES Mem GR/CCL w/ 2.25" DJN. RIH pumping slick 1% kcl w/ SL. Tag PBTD @ 13,421.2. CTM / 13,428' Mech w/ 3K down. Log Up 50 fpm (wgt back 13,412'). Flag 50' up @ 13,362.2' CTM / 13,369' Mech. Log up 50 fpm to 9050' stop 5 mins. POOH. L/D HES ***Job In Progress*** 4/7/2023 ***Job Continued from 4-6-23*** ((Assist CTU)) TFS U-3, Pumped 5 bbls 60/40 assisting CTU. 4/7/2023 CTU #9 1.75" CT 0.156". Job Scope: Post CTD: RPM Log & Adperfs Continue RPM log. Log from 13391 to 10500. paint flag at 13140. POOH L/D BOT RPM log tools, PT connector at surface and had to re-head. Software issues with BOT fixed, working on processing data ***Continued on WSR 4/8/23*** 4/7/2023 (TFS Unit 4 Assist CTU#9) Pumped 1 bbls of 60/40 followed by 136 bbls of KCL down Coil. Further pumped 35 bbls of DSL to Freeze Protect Coil. ***WSR Continued on 04/08/2023**** Daily Report of Well Operations PBU A-06A Daily Report of Well Operations PBU A-06A 4/8/2023 CTU #9 1.75" CT 0.156". Job Scope: Post CTD: RPM Log & Adperfs Processing RPM logging data, Make up HES TCP 1.56" Geo force gun run #1, RIH. Tag Btm and Corr Depth 13,414.94'. PUH and Perf 13,210' - 13,220'. Paint Flag @ 13,187'. POOH. BD Spent Perf Guns. MU 10' HES TCP 1.56" Geo force Perf guns. RIH #2. Corr Depth at Flag. Perf 13,177' - 13187'. POOH. Pulling heavy off bottom, circulate safe lube around. POOH weights lowered by 15k. POOH, Freeze protect well, L/D perf guns, RDMO ***Job Complete*** 4/8/2023 *****WSR Continued from 04/07/2023***** (TFS Unit 4 Assist CTU#9) Pumped 36 bbls of DSL to ignite perf gun, followed by 4 bbls 60/40 spacer. Further pumped 27 bbls of KCL with 1 bbl of 60/40 for a spacer. 152 bbls of KCL was pumped to help get coil out of hole. Pumped 33 bbls of DSL for FP. Pressure tested coil to 3800 psi PT=PASS. 35 bbls of 60/40 were pumped to ignite second perf gun. Pumped 146 bbls KCL, 34 bbls 60/40 and 51 bbls DSL while Coil POOH. Coil in control of well upon Departure. WELL NAME Date : Shoe @ :FC @ :Top Liner @ : Type: Type : Type : Type : Type : XYes No Yes X No Yes X No Yes X No Yes No Date : Volume lost during displacement (bbls) : 5.00 Remarks: Cement In Place At :21:00 4/1/2023 Estimated TOC :~10,100' Method Used To Determine TOC :Calculated 2500 Casing Rotated?Reciprocated?% Returns during job :89% Cement returns to surface?Spacer returns?Vol to Sur : FCP (psi) :2500 Pump used for disp : GD Plug Bumped?Bump press : Volume :195 Displacement : 1.5 ppb Geovis Density (ppg) :8.33 Rate (bpm) :2 Volume (actual / calculated) :29.0 / 29.1 Post Flush (Spacer) 1.5 ppb Geovis Density (ppg) :8.33 Rate (bpm) :2 Yield : Sacks : Mixing / Pumping Rate (bpm) : Tail Slurry Volume (bbls) :Density (ppg) : Lead Slurry Class G Volume (bbls):48.7 Density (ppg) : FI R S T S T A G E 13450 13,424', 13,435 9,250' Preflush (Spacer) 1% SL KCL w/ safelube Density (ppg) :8.4 Volume pumped (bbls) : A-06A CEMENT REPORT 1-Apr-23 Hole Size :4.25 Casing Size :3-1/2" x 3-1/4" x 2-7/8" 15.3 Yield : 1.236 Sacks : 221 Mixing / Pumping Rate (bpm) : 2 ~10,100' 89% Calculated Ve r t U n c e r t 1 s d [f t ] 0. 0 0 3. 0 0 St a r t M D En d M D Su r v e y D a t e [f t ] [f t ] 19 . 4 5 10 6 7 5 . 0 0 10 6 7 5 . 0 0 13 4 5 0 . 0 0 3/ 2 3 / 2 0 2 3 MD In c l i n a t i o n Az i m u t h TV D TV D S S No r t h Ea s t Gr i d E a s t Gr i d N o r t h La t i t u d e Lo n g i t u d e DL S To o l f a c e Bu i l d R a t e Tu r n R a t e Ve r t S e c t Ma j o r Se m i Mi n o r Se m i Ve r t S e m i Mi n o r Az i m Co m m e n t s [f t ] [° ] [° ] [f t ] [f t ] [f t ] [f t ] [U S f t ] [U S f t ] [° / 1 0 0 f t ] [° ] [° / 1 0 0 f t ] [° / 1 0 0 f t ] [f t ] [f t ] [f t ] [f t ] [° ] 0. 0 0 0 . 0 0 2 4 9 . 8 4 0 . 0 0 - 6 5 . 3 5 0 . 0 0 0 . 0 0 6 5 4 4 5 9 . 9 9 5 9 4 8 6 5 1 . 0 0 7 0 ° 1 5 ' 5 9 . 7 9 3 1 " N 1 4 8 ° 4 5 ' 3 . 6 1 6 4 " W 0 . 0 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 19 . 4 5 0 . 0 0 2 4 9 . 8 4 1 9 . 4 5 - 4 5 . 9 0 0 . 0 0 0 . 0 0 6 5 4 4 5 9 . 9 9 5 9 4 8 6 5 1 . 0 0 7 0 ° 1 5 ' 5 9 . 7 9 3 1 " N 1 4 8 ° 4 5 ' 3 . 6 1 6 4 " W 0 . 0 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 10 0 . 0 0 0 . 4 1 2 4 9 . 8 4 1 0 0 . 0 0 3 4 . 6 5 - 0 . 1 0 - 0 . 2 7 6 5 4 4 5 9 . 7 2 5 9 4 8 6 5 0 . 9 0 7 0 ° 1 5 ' 5 9 . 7 9 2 2 " N 1 4 8 ° 4 5 ' 3 . 6 2 4 3 " W 0 . 5 1 - 1 6 6 . 5 9 7 0 . 5 1 0 . 0 0 - 0 . 0 7 4 0 . 0 0 4 0 . 0 0 6 . 4 2 1 5 9. 8 4 20 0 . 0 0 0 . 2 1 1 1 0 . 1 5 2 0 0 . 0 0 1 3 4 . 6 5 - 0 . 2 9 - 0 . 4 3 6 5 4 4 5 9 . 5 6 5 9 4 8 6 5 0 . 7 1 7 0 ° 1 5 ' 5 9 . 7 9 0 3 " N 1 4 8 ° 4 5 ' 3 . 6 2 9 0 " W 0 . 5 9 1 7 2 . 2 9 2 - 0 . 2 0 - 1 3 9 . 6 9 - 0 . 0 1 4 0 . 0 0 4 0 . 0 0 6 . 43 1 2 8 . 8 8 30 0 . 0 0 0 . 0 6 1 3 0 . 4 4 3 0 0 . 0 0 2 3 4 . 6 5 - 0 . 3 8 - 0 . 2 2 6 5 4 4 5 9 . 7 8 5 9 4 8 6 5 0 . 6 1 7 0 ° 1 5 ' 5 9 . 7 8 9 4 " N 1 4 8 ° 4 5 ' 3 . 6 2 2 9 " W 0 . 1 6 - 5 6 . 0 8 1 - 0 . 1 5 2 0 . 2 9 0 . 1 9 4 0 . 0 0 4 0 . 0 0 6 . 4 3 5 9. 7 5 32 5 . 0 0 0 . 1 0 1 0 4 . 2 2 3 2 5 . 0 0 2 5 9 . 6 5 - 0 . 4 0 - 0 . 1 9 6 5 4 4 5 9 . 8 1 5 9 4 8 6 5 0 . 6 0 7 0 ° 1 5 ' 5 9 . 7 8 9 2 " N 1 4 8 ° 4 5 ' 3 . 6 2 1 9 " W 0 . 2 1 - 7 3 . 3 2 7 0 . 1 6 - 1 0 4 . 8 8 0 . 2 2 4 0 . 0 0 4 0 . 0 0 6 . 4 3 54 . 1 8 35 0 . 0 0 0 . 1 3 7 8 . 3 6 3 5 0 . 0 0 2 8 4 . 6 5 - 0 . 4 0 - 0 . 1 4 6 5 4 4 5 9 . 8 6 5 9 4 8 6 5 0 . 6 0 7 0 ° 1 5 ' 5 9 . 7 8 9 2 " N 1 4 8 ° 4 5 ' 3 . 6 2 0 5 " W 0 . 2 4 1 3 8 . 0 6 6 0 . 1 2 - 1 0 3 . 4 4 0 . 2 5 4 0 . 0 0 4 0 . 0 0 6 . 4 3 4 6. 2 7 37 5 . 0 0 0 . 1 4 1 7 8 . 0 7 3 7 5 . 0 0 3 0 9 . 6 5 - 0 . 4 2 - 0 . 1 1 6 5 4 4 5 9 . 8 9 5 9 4 8 6 5 0 . 5 8 7 0 ° 1 5 ' 5 9 . 7 8 9 0 " N 1 4 8 ° 4 5 ' 3 . 6 1 9 7 " W 0 . 8 3 2 6 . 7 0 3 0 . 0 4 3 9 8 . 8 4 0 . 2 8 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 2 5. 7 8 40 0 . 0 0 0 . 3 9 1 9 5 . 4 9 4 0 0 . 0 0 3 3 4 . 6 5 - 0 . 5 3 - 0 . 1 4 6 5 4 4 5 9 . 8 7 5 9 4 8 6 5 0 . 4 6 7 0 ° 1 5 ' 5 9 . 7 8 7 9 " N 1 4 8 ° 4 5 ' 3 . 6 2 0 3 " W 1 . 0 4 - 1 3 2 . 1 4 4 1 . 0 0 6 9 . 6 8 0 . 3 6 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 33 . 6 2 42 5 . 0 0 0 . 2 9 1 4 9 . 0 1 4 2 5 . 0 0 3 5 9 . 6 5 - 0 . 6 7 - 0 . 1 3 6 5 4 4 5 9 . 8 8 5 9 4 8 6 5 0 . 3 3 7 0 ° 1 5 ' 5 9 . 7 8 6 6 " N 1 4 8 ° 4 5 ' 3 . 6 2 0 0 " W 1 . 1 3 1 6 4 . 6 8 5 - 0 . 4 0 - 1 8 5 . 9 2 0 . 4 8 4 0 . 0 0 4 0 . 0 0 6 . 4 32 3 6 . 8 7 45 0 . 0 0 0 . 2 2 1 5 4 . 0 7 4 5 0 . 0 0 3 8 4 . 6 5 - 0 . 7 7 - 0 . 0 7 6 5 4 4 5 9 . 9 3 5 9 4 8 6 5 0 . 2 3 7 0 ° 1 5 ' 5 9 . 7 8 5 6 " N 1 4 8 ° 4 5 ' 3 . 6 1 8 5 " W 0 . 2 9 1 5 7 . 3 5 1 - 0 . 2 8 2 0 . 2 4 0 . 5 9 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 36 . 7 3 47 5 . 0 0 0 . 1 6 2 7 9 . 4 5 4 7 5 . 0 0 4 0 9 . 6 5 - 0 . 8 0 - 0 . 0 9 6 5 4 4 5 9 . 9 2 5 9 4 8 6 5 0 . 1 9 7 0 ° 1 5 ' 5 9 . 7 8 5 2 " N 1 4 8 ° 4 5 ' 3 . 6 1 8 9 " W 1 . 3 6 - 4 7 . 3 7 9 - 0 . 2 4 5 0 1 . 5 2 0 . 6 2 4 0 . 0 0 4 0 . 0 0 6 . 4 3 23 9 . 3 1 50 0 . 0 0 0 . 3 8 2 5 0 . 1 2 5 0 0 . 0 0 4 3 4 . 6 5 - 0 . 8 3 - 0 . 2 0 6 5 4 4 5 9 . 8 1 5 9 4 8 6 5 0 . 1 7 7 0 ° 1 5 ' 5 9 . 7 8 5 0 " N 1 4 8 ° 4 5 ' 3 . 6 2 2 1 " W 1 . 0 1 - 2 1 . 7 2 5 0 . 8 8 - 1 1 7 . 3 2 0 . 5 7 4 0 . 0 0 4 0 . 0 0 6 . 4 3 24 4 . 3 7 52 5 . 0 0 0 . 4 6 2 4 6 . 2 0 5 2 5 . 0 0 4 5 9 . 6 5 - 0 . 9 0 - 0 . 3 7 6 5 4 4 5 9 . 6 4 5 9 4 8 6 5 0 . 1 0 7 0 ° 1 5 ' 5 9 . 7 8 4 3 " N 1 4 8 ° 4 5 ' 3 . 6 2 7 1 " W 0 . 3 4 - 7 3 . 5 2 7 0 . 3 2 - 1 5 . 6 8 0 . 5 3 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 51 . 7 9 55 0 . 0 0 0 . 6 5 2 1 5 . 4 1 5 5 0 . 0 0 4 8 4 . 6 5 - 1 . 0 5 - 0 . 5 4 6 5 4 4 5 9 . 4 7 5 9 4 8 6 4 9 . 9 4 7 0 ° 1 5 ' 5 9 . 7 8 2 8 " N 1 4 8 ° 4 5 ' 3 . 6 3 2 1 " W 1 . 3 9 1 5 2 . 3 6 5 0 . 7 6 - 1 2 3 . 1 6 0 . 5 6 4 0 . 0 0 4 0 . 0 0 6 . 4 3 25 9 . 6 3 57 5 . 0 0 0 . 6 0 2 1 7 . 9 4 5 7 4 . 9 9 5 0 9 . 6 4 - 1 . 2 7 - 0 . 7 0 6 5 4 4 5 9 . 3 1 5 9 4 8 6 4 9 . 7 2 7 0 ° 1 5 ' 5 9 . 7 8 0 6 " N 1 4 8 ° 4 5 ' 3 . 6 3 6 9 " W 0 . 2 3 1 4 3 . 9 4 1 - 0 . 2 0 1 0 . 1 2 0 . 6 5 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 64 . 6 2 60 0 . 0 0 0 . 5 6 2 2 0 . 9 8 5 9 9 . 9 9 5 3 4 . 6 4 - 1 . 4 7 - 0 . 8 6 6 5 4 4 5 9 . 1 6 5 9 4 8 6 4 9 . 5 2 7 0 ° 1 5 ' 5 9 . 7 7 8 7 " N 1 4 8 ° 4 5 ' 3 . 6 4 1 5 " W 0 . 2 0 1 0 4 . 4 1 6 - 0 . 1 6 1 2 . 1 6 0 . 7 2 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 67 . 8 9 62 5 . 0 0 0 . 5 8 2 5 6 . 1 5 6 2 4 . 9 9 5 5 9 . 6 4 - 1 . 5 9 - 1 . 0 7 6 5 4 4 5 8 . 9 6 5 9 4 8 6 4 9 . 3 9 7 0 ° 1 5 ' 5 9 . 7 7 7 5 " N 1 4 8 ° 4 5 ' 3 . 6 4 7 5 " W 1 . 3 8 1 6 9 . 7 7 0 . 0 8 1 4 0 . 6 8 0 . 7 1 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 7 1. 5 6 65 0 . 0 0 0 . 4 6 2 5 8 . 8 6 6 4 9 . 9 9 5 8 4 . 6 4 - 1 . 6 4 - 1 . 2 9 6 5 4 4 5 8 . 7 3 5 9 4 8 6 4 9 . 3 4 7 0 ° 1 5 ' 5 9 . 7 7 7 0 " N 1 4 8 ° 4 5 ' 3 . 6 5 3 9 " W 0 . 4 9 1 7 8 . 8 8 8 - 0 . 4 8 1 0 . 8 4 0 . 6 3 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 75 . 7 9 67 5 . 0 0 0 . 2 4 2 5 9 . 8 8 6 7 4 . 9 9 6 0 9 . 6 4 - 1 . 6 7 - 1 . 4 4 6 5 4 4 5 8 . 5 9 5 9 4 8 6 4 9 . 3 0 7 0 ° 1 5 ' 5 9 . 7 7 6 7 " N 1 4 8 ° 4 5 ' 3 . 6 5 8 3 " W 0 . 8 8 - 8 7 . 0 8 3 - 0 . 8 8 4 . 0 8 0 . 5 6 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 8 0. 2 1 70 0 . 0 0 0 . 4 6 2 0 4 . 2 0 6 9 9 . 9 9 6 3 4 . 6 4 - 1 . 7 7 - 1 . 5 3 6 5 4 4 5 8 . 4 9 5 9 4 8 6 4 9 . 2 0 7 0 ° 1 5 ' 5 9 . 7 7 5 8 " N 1 4 8 ° 4 5 ' 3 . 6 6 1 0 " W 1 . 5 2 2 4 . 0 2 8 0 . 8 8 - 2 2 2 . 7 2 0 . 6 0 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 82 . 7 8 72 5 . 0 0 0 . 4 8 2 0 5 . 2 6 7 2 4 . 9 9 6 5 9 . 6 4 - 1 . 9 5 - 1 . 6 2 6 5 4 4 5 8 . 4 1 5 9 4 8 6 4 9 . 0 1 7 0 ° 1 5 ' 5 9 . 7 7 3 9 " N 1 4 8 ° 4 5 ' 3 . 6 6 3 5 " W 0 . 0 9 1 3 4 . 1 5 1 0 . 0 8 4 . 2 4 0 . 7 0 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 8 3 .5 7 75 0 . 0 0 0 . 3 5 2 3 9 . 1 5 7 4 9 . 9 9 6 8 4 . 6 4 - 2 . 0 9 - 1 . 7 3 6 5 4 4 5 8 . 3 1 5 9 4 8 6 4 8 . 8 8 7 0 ° 1 5 ' 5 9 . 7 7 2 6 " N 1 4 8 ° 4 5 ' 3 . 6 6 6 7 " W 1 . 0 9 6 8 . 6 1 5 - 0 . 5 2 1 3 5 . 5 6 0 . 7 5 4 0 . 0 0 4 0 . 0 0 6 . 4 4 2 85 . 4 8 77 5 . 0 0 0 . 5 3 2 6 9 . 8 2 7 7 4 . 9 9 7 0 9 . 6 4 - 2 . 1 3 - 1 . 9 1 6 5 4 4 5 8 . 1 3 5 9 4 8 6 4 8 . 8 3 7 0 ° 1 5 ' 5 9 . 7 7 2 2 " N 1 4 8 ° 4 5 ' 3 . 6 7 1 9 " W 1 . 1 6 4 8 . 7 2 5 0 . 7 2 1 2 2 . 6 8 0 . 6 8 4 0 . 0 0 4 0 . 0 0 6 . 4 4 2 8 8. 6 4 80 0 . 0 0 0 . 6 2 2 7 8 . 5 7 7 9 9 . 9 9 7 3 4 . 6 4 - 2 . 1 1 - 2 . 1 6 6 5 4 4 5 7 . 8 8 5 9 4 8 6 4 8 . 8 5 7 0 ° 1 5 ' 5 9 . 7 7 2 4 " N 1 4 8 ° 4 5 ' 3 . 6 7 9 2 " W 0 . 5 0 1 4 2 . 3 7 4 0 . 3 6 3 5 . 0 0 0 . 5 2 4 0 . 0 0 4 0 . 0 0 6 . 4 4 2 9 2. 3 9 82 5 . 0 0 0 . 3 9 3 1 7 . 0 0 8 2 4 . 9 8 7 5 9 . 6 3 - 2 . 0 3 - 2 . 3 5 6 5 4 4 5 7 . 6 8 5 9 4 8 6 4 8 . 9 3 7 0 ° 1 5 ' 5 9 . 7 7 3 2 " N 1 4 8 ° 4 5 ' 3 . 6 8 4 8 " W 1 . 5 9 - 1 6 9 - 0 . 9 2 1 5 3 . 7 2 0 . 3 5 4 0 . 0 0 4 0 . 0 0 6 . 4 4 2 9 5 .5 9 85 0 . 0 0 0 . 1 3 2 9 3 . 0 8 8 4 9 . 9 8 7 8 4 . 6 3 - 1 . 9 5 - 2 . 4 3 6 5 4 4 5 7 . 6 0 5 9 4 8 6 4 9 . 0 0 7 0 ° 1 5 ' 5 9 . 7 7 3 9 " N 1 4 8 ° 4 5 ' 3 . 6 8 7 2 " W 1 . 1 0 - 1 5 0 . 0 9 6 - 1 . 0 4 - 9 5 . 6 8 0 . 2 4 4 0 . 0 0 4 0 . 0 0 6 . 4 42 9 9 . 4 1 87 5 . 0 0 0 . 0 9 1 8 9 . 0 5 8 7 4 . 9 8 8 0 9 . 6 3 - 1 . 9 6 - 2 . 4 6 6 5 4 4 5 7 . 5 7 5 9 4 8 6 4 8 . 9 9 7 0 ° 1 5 ' 5 9 . 7 7 3 9 " N 1 4 8 ° 4 5 ' 3 . 6 8 8 1 " W 0 . 7 0 1 0 9 . 0 6 5 - 0 . 1 6 - 4 1 6 . 1 2 0 . 2 3 4 0 . 0 0 4 0 . 0 0 6 . 4 41 2 0 . 6 3 90 0 . 0 0 0 . 3 8 2 8 5 . 1 8 8 9 9 . 9 8 8 3 4 . 6 3 - 1 . 9 6 - 2 . 5 5 6 5 4 4 5 7 . 4 8 5 9 4 8 6 4 8 . 9 9 7 0 ° 1 5 ' 5 9 . 7 7 3 9 " N 1 4 8 ° 4 5 ' 3 . 6 9 0 5 " W 1 . 6 0 9 6 . 0 5 8 1 . 1 6 3 8 4 . 5 2 0 . 1 8 4 0 . 0 0 4 0 . 0 0 6 . 4 4 3 0 1. 8 5 92 5 . 0 0 0 . 4 1 3 1 4 . 0 7 9 2 4 . 9 8 8 5 9 . 6 3 - 1 . 8 7 - 2 . 6 9 6 5 4 4 5 7 . 3 4 5 9 4 8 6 4 9 . 0 7 7 0 ° 1 5 ' 5 9 . 7 7 4 7 " N 1 4 8 ° 4 5 ' 3 . 6 9 4 7 " W 0 . 8 0 1 1 9 . 6 8 9 0 . 1 2 1 1 5 . 5 6 0 . 0 3 4 0 . 0 0 4 0 . 0 0 6 . 4 4 3 05 . 3 0 95 0 . 0 0 0 . 4 1 1 3 . 4 5 9 4 9 . 9 8 8 8 4 . 6 3 - 1 . 7 2 - 2 . 7 3 6 5 4 4 5 7 . 2 9 5 9 4 8 6 4 9 . 2 2 7 0 ° 1 5 ' 5 9 . 7 7 6 2 " N 1 4 8 ° 4 5 ' 3 . 6 9 6 0 " W 1 . 6 2 1 2 9 . 3 9 3 0 . 0 0 2 3 7 . 5 2 - 0 . 1 2 4 0 . 0 0 4 0 . 0 0 6 . 4 4 3 07 . 6 1 97 5 . 0 0 0 . 4 0 9 0 . 4 6 9 7 4 . 9 8 9 0 9 . 6 3 - 1 . 6 4 - 2 . 6 3 6 5 4 4 5 7 . 4 0 5 9 4 8 6 4 9 . 3 1 7 0 ° 1 5 ' 5 9 . 7 7 7 0 " N 1 4 8 ° 4 5 ' 3 . 6 9 2 8 " W 2 . 0 2 1 5 2 . 6 0 1 - 0 . 0 4 3 0 8 . 0 4 - 0 . 1 3 4 0 . 0 0 4 0 . 0 0 6 . 4 4 12 7 . 5 7 10 0 0 . 0 0 0 . 3 0 1 0 0 . 9 1 9 9 9 . 9 8 9 3 4 . 6 3 - 1 . 6 5 - 2 . 4 7 6 5 4 4 5 7 . 5 5 5 9 4 8 6 4 9 . 3 0 7 0 ° 1 5 ' 5 9 . 7 7 6 9 " N 1 4 8 ° 4 5 ' 3 . 6 8 8 4 " W 0 . 4 7 1 6 7 . 8 7 5 - 0 . 4 0 4 1 . 8 0 - 0 . 0 3 4 0 . 0 0 4 0 . 0 0 6 . 4 41 2 3 . 9 9 10 2 5 . 0 0 0 . 2 8 2 5 5 . 7 8 1 0 2 4 . 9 8 9 5 9 . 6 3 - 1 . 6 8 - 2 . 4 7 6 5 4 4 5 7 . 5 6 5 9 4 8 6 4 9 . 2 7 7 0 ° 1 5 ' 5 9 . 7 7 6 6 " N 1 4 8 ° 4 5 ' 3 . 6 8 8 3 " W 2 . 2 6 1 3 4 . 2 0 3 - 0 . 0 8 6 1 9 . 4 8 - 0 . 0 1 4 0 . 0 0 4 0 . 0 0 6 .4 4 3 0 3 . 4 7 10 5 0 . 0 0 0 . 2 7 3 4 1 . 9 6 1 0 4 9 . 9 8 9 8 4 . 6 3 - 1 . 6 4 - 2 . 5 5 6 5 4 4 5 7 . 4 8 5 9 4 8 6 4 9 . 3 1 7 0 ° 1 5 ' 5 9 . 7 7 7 0 " N 1 4 8 ° 4 5 ' 3 . 6 9 0 5 " W 1 . 5 0 6 2 . 6 6 6 - 0 . 0 4 3 4 4 . 7 2 - 0 . 0 8 4 0 . 0 0 4 0 . 0 0 6 . 45 3 0 6 . 5 2 10 7 5 . 0 0 0 . 3 4 3 5 9 . 7 6 1 0 7 4 . 9 8 1 0 0 9 . 6 3 - 1 . 5 1 - 2 . 5 7 6 5 4 4 5 7 . 4 6 5 9 4 8 6 4 9 . 4 4 7 0 ° 1 5 ' 5 9 . 7 7 8 3 " N 1 4 8 ° 4 5 ' 3 . 6 9 1 1 " W 0 . 4 7 1 7 4 . 5 4 6 0 . 2 8 7 1 . 2 0 - 0 . 2 0 4 0 . 0 0 4 0 . 0 0 6 . 45 3 0 9 . 2 3 11 0 0 . 0 0 0 . 2 2 1 6 5 . 8 6 1 0 9 9 . 9 8 1 0 3 4 . 6 3 - 1 . 4 8 - 2 . 5 5 6 5 4 4 5 7 . 4 7 5 9 4 8 6 4 9 . 4 7 7 0 ° 1 5 ' 5 9 . 7 7 8 6 " N 1 4 8 ° 4 5 ' 3 . 6 9 0 7 " W 2 . 2 2 1 2 7 . 7 7 1 - 0 . 4 8 6 6 4 . 4 0 - 0 . 2 2 4 0 . 0 0 4 0 . 0 0 6. 4 5 1 2 9 . 0 0 11 2 5 . 0 0 0 . 2 3 2 4 4 . 5 1 1 1 2 4 . 9 8 1 0 5 9 . 6 3 - 1 . 5 5 - 2 . 5 9 6 5 4 4 5 7 . 4 3 5 9 4 8 6 4 9 . 4 0 7 0 ° 1 5 ' 5 9 . 7 7 7 9 " N 1 4 8 ° 4 5 ' 3 . 6 9 1 7 " W 1 . 1 4 5 5 . 3 1 7 0 . 0 4 3 1 4 . 6 0 - 0 . 1 8 4 0 . 0 0 4 0 . 0 0 6 . 45 3 0 8 . 1 1 11 5 0 . 0 0 0 . 5 3 2 7 8 . 9 2 1 1 4 9 . 9 8 1 0 8 4 . 6 3 - 1 . 5 5 - 2 . 7 5 6 5 4 4 5 7 . 2 8 5 9 4 8 6 4 9 . 3 9 7 0 ° 1 5 ' 5 9 . 7 7 7 9 " N 1 4 8 ° 4 5 ' 3 . 6 9 6 3 " W 1 . 4 6 1 5 5 . 7 9 1 1 . 2 0 1 3 7 . 6 4 - 0 . 2 7 4 0 . 0 0 4 0 . 0 0 6 .4 5 3 1 1 . 3 0 11 7 5 . 0 0 0 . 2 6 3 1 1 . 4 2 1 1 7 4 . 9 8 1 1 0 9 . 6 3 - 1 . 5 0 - 2 . 9 0 6 5 4 4 5 7 . 1 2 5 9 4 8 6 4 9 . 4 4 7 0 ° 1 5 ' 5 9 . 7 7 8 4 " N 1 4 8 ° 4 5 ' 3 . 7 0 0 9 " W 1 . 3 6 - 1 4 4 . 3 3 8 - 1 . 0 8 1 3 0 . 0 0 - 0 . 4 0 4 0 . 0 0 4 0 . 0 06 . 4 5 3 1 4 . 7 4 12 0 0 . 0 0 0 . 1 7 2 8 4 . 0 0 1 1 9 9 . 9 8 1 1 3 4 . 6 3 - 1 . 4 5 - 2 . 9 8 6 5 4 4 5 7 . 0 4 5 9 4 8 6 4 9 . 4 9 7 0 ° 1 5 ' 5 9 . 7 7 8 9 " N 1 4 8 ° 4 5 ' 3 . 7 0 3 2 " W 0 . 5 4 - 7 5 . 8 7 4 - 0 . 3 6 - 1 0 9 . 6 8 - 0 . 4 9 4 0 . 0 0 4 0 . 0 06 . 4 5 3 1 8 . 1 1 12 2 5 . 0 0 0 . 3 4 2 3 7 . 1 3 1 2 2 4 . 9 8 1 1 5 9 . 6 3 - 1 . 4 8 - 3 . 0 8 6 5 4 4 5 6 . 9 4 5 9 4 8 6 4 9 . 4 6 7 0 ° 1 5 ' 5 9 . 7 7 8 6 " N 1 4 8 ° 4 5 ' 3 . 7 0 6 1 " W 1 . 0 2 3 7 . 2 5 9 0 . 6 8 - 1 8 7 . 4 8 - 0 . 5 2 4 0 . 0 0 4 0 . 0 0 6 .4 5 3 1 9 . 8 2 12 5 0 . 0 0 0 . 7 5 2 5 8 . 4 6 1 2 4 9 . 9 8 1 1 8 4 . 6 3 - 1 . 5 5 - 3 . 3 0 6 5 4 4 5 6 . 7 2 5 9 4 8 6 4 9 . 3 8 7 0 ° 1 5 ' 5 9 . 7 7 7 9 " N 1 4 8 ° 4 5 ' 3 . 7 1 2 5 " W 1 . 8 0 3 4 . 4 7 7 1 . 6 4 8 5 . 3 2 - 0 . 5 8 4 0 . 0 0 4 0 . 0 0 6 . 4 63 2 1 . 2 9 12 7 5 . 0 0 0 . 7 8 2 5 9 . 9 6 1 2 7 4 . 9 8 1 2 0 9 . 6 3 - 1 . 6 2 - 3 . 6 3 6 5 4 4 5 6 . 3 9 5 9 4 8 6 4 9 . 3 1 7 0 ° 1 5 ' 5 9 . 7 7 7 2 " N 1 4 8 ° 4 5 ' 3 . 7 2 2 1 " W 0 . 1 4 1 7 6 . 6 2 3 0 . 1 2 6 . 0 0 - 0 . 7 1 4 0 . 0 0 4 0 . 0 0 6 . 4 63 2 3 . 3 9 13 0 0 . 0 0 0 . 3 4 2 6 4 . 3 5 1 2 9 9 . 9 8 1 2 3 4 . 6 3 - 1 . 6 5 - 3 . 8 7 6 5 4 4 5 6 . 1 5 5 9 4 8 6 4 9 . 2 7 7 0 ° 1 5 ' 5 9 . 7 7 6 9 " N 1 4 8 ° 4 5 ' 3 . 7 2 9 1 " W 1 . 7 7 4 3 . 7 0 6 - 1 . 7 6 1 7 . 5 6 - 0 . 8 2 4 0 . 0 0 4 0 . 0 0 6 . 46 3 2 4 . 4 3 13 2 5 . 0 0 0 . 5 5 2 8 2 . 7 7 1 3 2 4 . 9 7 1 2 5 9 . 6 2 - 1 . 6 3 - 4 . 0 6 6 5 4 4 5 5 . 9 6 5 9 4 8 6 4 9 . 2 8 7 0 ° 1 5 ' 5 9 . 7 7 7 1 " N 1 4 8 ° 4 5 ' 3 . 7 3 4 7 " W 1 . 0 1 - 7 8 . 8 9 9 0 . 8 4 7 3 . 6 8 - 0 . 9 4 4 0 . 0 0 4 0 . 0 0 6 . 46 3 2 6 . 0 7 13 5 0 . 0 0 0 . 5 6 2 7 8 . 4 0 1 3 4 9 . 9 7 1 2 8 4 . 6 2 - 1 . 5 9 - 4 . 3 0 6 5 4 4 5 5 . 7 2 5 9 4 8 6 4 9 . 3 2 7 0 ° 1 5 ' 5 9 . 7 7 7 5 " N 1 4 8 ° 4 5 ' 3 . 7 4 1 6 " W 0 . 1 7 - 3 9 . 1 8 4 0 . 0 4 - 1 7 . 4 8 - 1 . 1 1 4 0 . 0 0 4 0 . 0 0 6 .4 6 3 2 8 . 2 0 13 7 5 . 0 0 0. 8 9 26 2 . 6 4 13 7 4 . 9 7 13 0 9 . 6 2 -1 . 6 0 -4 . 6 1 65 4 4 5 5 . 4 1 59 4 8 6 4 9 . 3 1 70 ° 1 5 ' 5 9 . 7 7 7 4 " N 14 8 ° 4 5 ' 3 . 7 5 0 7 " W 1. 5 3 -1 5 2 . 6 9 5 1. 3 2 -6 3 . 0 4 -1 . 2 9 40 . 0 0 40 . 0 0 6. 4 6 32 9 . 7 6 Ac t u a l W e l l p a t h G e o g r a p h i c R e p o r t - i n c l u d i n g P o s i t i o n U n c e r t a i n t y Re p o r t b y B a k e r H u g h e s Op e r a t o r Ar e a We l l p a t h We l l b o r e l a s t r e v i s e d Si d e t r a c k f r o m Us e r 65 . 3 5 f t E 0 . 0 0 f t 1. 1 8 E a s t Sl o t Ri g o n A - 0 6 ( R T ) Ri g o n A - 0 6 ( R T ) Me a n S e a L e v e l Ca l c u l a t i o n m e t h o d Fi e l d Fa c i l i t y Sl o t We l l We l l b o r e A- P a d A- 0 6 A- 0 6 A A- 0 6 A A- 0 6 A _ a w p 03 / 2 1 / 2 0 2 3 A- 0 6 a t 1 0 6 7 5 . 0 0 M D Tu f t s c o d Mi n i m u m c u r v a t u r e N 0 . 0 0 f t Ma g n e t i c N o r t h i s 1 5 . 1 7 d e g r e e s E a s t o f T r u e N o r t h 2. 0 0 S t d D e v We l l A r c h i t e c t D B L o c a l Pr o j e c t i o n S y s t e m No r t h R e f e r e n c e Sc a l e Co n v e r g e n c e a t S l o t Ho r i z o n t a l R e f e r e n c e P o i n t Ve r t i c a l R e f e r e n c e P o i n t MD R e f e r e n c e P o i n t Fi e l d V e r t i c a l R e f e r e n c e Ri g o n A - 0 6 ( R T ) T o M e a n S e a L e v e l Se c t i o n O r i g i n X Se c t i o n O r i g i n Y 3/ 2 9 / 2 0 2 3 a t 5 : 2 4 : 5 3 A M u s i n g W e l l A r c h i t e c t 6 . 0 Hi l c o r p No r t h S l o p e , A l a s k a Pr u d h o e B a y NA D 2 7 / T M A l a s k a S P , Z o n e 4 ( 5 0 0 4 ) , U S f e e t Tr u e 0. 9 9 9 9 2 7 14 5 . 6 5 ° in c l u d e d 50 - 0 2 9 - 2 0 1 1 8 - 0 1 - 0 0 Lo c a l E a s t G r i d N o r t h L o n g i t u d e Se c t i o n A z i m u t h Su r f a c e P o s i t i o n U n c e r t a i n t y AP I # De c l i n a t i o n El l i p s e C o n f i d e n c e L i m i t Da t a b a s e Gr i d E a s t Ho r i z U n c e r t 1 s d Sl o t L o c a t i o n Fa c i l i t y R e f e r e n c e P t Fi e l d R e f e r e n c e P t Lo c a l N o r t h [f t ] 24 9 9 . 7 2 La t i t u d e 70 ° 1 5 ' 5 9 . 7 9 3 1 " N 70 ° 1 5 ' 3 5 . 2 0 9 2 " N 70 ° 2 0 ' 1 7 . 5 5 2 2 " N [U S f t ] 65 4 4 5 9 . 9 9 65 3 5 0 9 . 4 2 65 1 9 5 8 . 0 0 14 8 ° 4 5 ' 3 . 6 1 6 4 " W 14 8 ° 4 5 ' 3 2 . 7 7 4 5 " W 14 8 ° 4 6 ' 1 . 0 0 0 6 " W [f t ] 10 0 1 . 8 0 [f t ] 0. 0 0 20 . 0 0 [U S f t ] 59 4 8 6 5 1 . 0 0 59 4 6 1 3 1 . 5 7 59 7 4 8 1 2 . 0 0 Gy r o d a t a s t a n d a r d - C o n t i n u o u s g y r o ( s u p e r s e d e d m o d e l ) A - 0 6 < G Y D - C T - C M S < 1 0 0 - 1 0 8 6 3 > C B - G Y R O - M S < 1 0 9 0 0 - 1 1 3 0 0 > A - 0 6 BH C o i l T r a k ( 2 0 1 9 ) ( S t a n d a r d ) B H I C o i l T r a k S t a n d a r d - 1 0 6 7 5 - X X X A - 0 6 A Po s i t i o n a l U n c e r t a i n t y M o d e l L o g N a m e / C o m m e n t We l l b o r e Pa g e 1 o f 7 14 0 0 . 0 0 0 . 6 2 2 4 8 . 7 6 1 3 9 9 . 9 7 1 3 3 4 . 6 2 - 1 . 6 7 - 4 . 9 3 6 5 4 4 5 5 . 0 9 5 9 4 8 6 4 9 . 2 3 7 0 ° 1 5 ' 5 9 . 7 7 6 7 " N 1 4 8 ° 4 5 ' 3 . 7 6 0 0 " W 1 . 3 0 - 1 7 0 . 3 3 2 - 1 . 0 8 - 5 5 . 5 2 - 1 . 4 0 4 0 . 0 0 4 0 . 0 06 . 4 6 3 3 0 . 2 0 14 2 5 . 0 0 0 . 4 0 2 4 3 . 3 4 1 4 2 4 . 9 7 1 3 5 9 . 6 2 - 1 . 7 6 - 5 . 1 4 6 5 4 4 5 4 . 8 9 5 9 4 8 6 4 9 . 1 4 7 0 ° 1 5 ' 5 9 . 7 7 5 8 " N 1 4 8 ° 4 5 ' 3 . 7 6 5 9 " W 0 . 9 0 6 4 . 9 5 2 - 0 . 8 8 - 2 1 . 6 8 - 1 . 4 5 4 0 . 0 0 4 0 . 0 0 6 .4 7 3 3 0 . 1 9 14 5 0 . 0 0 0 . 7 5 2 7 9 . 4 0 1 4 4 9 . 9 7 1 3 8 4 . 6 2 - 1 . 7 7 - 5 . 3 8 6 5 4 4 5 4 . 6 5 5 9 4 8 6 4 9 . 1 2 7 0 ° 1 5 ' 5 9 . 7 7 5 7 " N 1 4 8 ° 4 5 ' 3 . 7 7 2 9 " W 1 . 9 5 - 1 9 . 6 3 1 1 . 4 0 1 4 4 . 2 4 - 1 . 5 7 4 0 . 0 0 4 0 . 0 0 6 .4 7 3 3 1 . 1 8 14 7 5 . 0 0 1 . 1 2 2 7 2 . 7 7 1 4 7 4 . 9 6 1 4 0 9 . 6 1 - 1 . 7 3 - 5 . 7 8 6 5 4 4 5 4 . 2 4 5 9 4 8 6 4 9 . 1 5 7 0 ° 1 5 ' 5 9 . 7 7 6 1 " N 1 4 8 ° 4 5 ' 3 . 7 8 4 7 " W 1 . 5 4 - 5 0 . 3 4 9 1 . 4 8 - 2 6 . 5 2 - 1 . 8 3 4 0 . 0 0 4 0 . 0 0 6 .4 7 3 3 3 . 2 1 15 0 0 . 0 0 1 . 2 9 2 6 4 . 3 7 1 4 9 9 . 9 6 1 4 3 4 . 6 1 - 1 . 7 5 - 6 . 3 1 6 5 4 4 5 3 . 7 2 5 9 4 8 6 4 9 . 1 2 7 0 ° 1 5 ' 5 9 . 7 7 5 9 " N 1 4 8 ° 4 5 ' 3 . 7 9 9 9 " W 0 . 9 8 1 3 5 . 3 6 4 0 . 6 8 - 3 3 . 6 0 - 2 . 1 1 4 0 . 0 0 4 0 . 0 0 6 .4 7 3 3 4 . 3 6 15 2 5 . 0 0 1 . 0 1 2 8 3 . 5 5 1 5 2 4 . 9 5 1 4 5 9 . 6 0 - 1 . 7 2 - 6 . 8 0 6 5 4 4 5 3 . 2 3 5 9 4 8 6 4 9 . 1 4 7 0 ° 1 5 ' 5 9 . 7 7 6 2 " N 1 4 8 ° 4 5 ' 3 . 8 1 4 3 " W 1 . 8 9 1 7 . 3 4 7 - 1 . 1 2 7 6 . 7 2 - 2 . 4 1 4 0 . 0 0 4 0 . 0 0 6 . 47 3 3 5 . 2 9 15 5 0 . 0 0 1 . 2 8 2 8 7 . 2 9 1 5 4 9 . 9 5 1 4 8 4 . 6 0 - 1 . 5 9 - 7 . 2 8 6 5 4 4 5 2 . 7 4 5 9 4 8 6 4 9 . 2 6 7 0 ° 1 5 ' 5 9 . 7 7 7 5 " N 1 4 8 ° 4 5 ' 3 . 8 2 8 3 " W 1 . 1 2 - 7 . 5 8 7 1 . 0 8 1 4 . 9 6 - 2 . 8 0 4 0 . 0 0 4 0 . 0 0 6 . 4 83 3 6 . 7 1 15 7 5 . 0 0 1 . 8 0 2 8 5 . 0 9 1 5 7 4 . 9 4 1 5 0 9 . 5 9 - 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0 . 5 5 - 1 1 . 2 0 6 5 4 4 4 8 . 8 1 5 9 4 8 6 5 0 . 2 2 7 0 ° 1 5 ' 5 9 . 7 8 7 7 " N 1 4 8 ° 4 5 ' 3 . 9 4 2 3 " W 1 . 0 0 - 9 9 . 4 1 6 0 . 1 2 - 2 7 . 0 0 - 5 . 8 6 4 0 . 0 0 4 0 . 0 0 6. 4 8 3 4 3 . 6 5 17 0 0 . 0 0 2 . 1 0 2 7 5 . 7 8 1 6 9 9 . 8 6 1 6 3 4 . 5 1 - 0 . 4 3 - 1 2 . 1 1 6 5 4 4 4 7 . 8 9 5 9 4 8 6 5 0 . 3 2 7 0 ° 1 5 ' 5 9 . 7 8 8 9 " N 1 4 8 ° 4 5 ' 3 . 9 6 8 8 " W 0 . 6 3 1 5 8 . 4 2 7 - 0 . 0 8 - 1 6 . 9 6 - 6 . 4 8 4 0 . 0 0 4 0 . 0 06 . 4 9 3 4 3 . 8 9 17 2 5 . 0 0 1 . 5 4 2 8 4 . 3 0 1 7 2 4 . 8 5 1 6 5 9 . 5 0 - 0 . 3 0 - 1 2 . 8 9 6 5 4 4 4 7 . 1 1 5 9 4 8 6 5 0 . 4 4 7 0 ° 1 5 ' 5 9 . 7 9 0 2 " N 1 4 8 ° 4 5 ' 3 . 9 9 1 5 " W 2 . 4 8 - 1 5 1 . 5 1 8 - 2 . 2 4 3 4 . 0 8 - 7 . 0 3 4 0 . 0 0 4 0 . 0 06 . 4 9 3 4 4 . 1 1 17 5 0 . 0 0 1 . 2 9 2 7 8 . 0 8 1 7 4 9 . 8 4 1 6 8 4 . 4 9 - 0 . 1 8 - 1 3 . 4 9 6 5 4 4 4 6 . 5 0 5 9 4 8 6 5 0 . 5 5 7 0 ° 1 5 ' 5 9 . 7 9 1 4 " N 1 4 8 ° 4 5 ' 4 . 0 0 9 1 " W 1 . 1 7 - 8 2 . 9 5 6 - 1 . 0 0 - 2 4 . 8 8 - 7 . 4 7 4 0 . 0 0 4 0 . 0 06 . 4 9 3 4 4 . 3 3 17 7 5 . 0 0 1 . 3 4 2 6 7 . 9 5 1 7 7 4 . 8 4 1 7 0 9 . 4 9 - 0 . 1 5 - 1 4 . 0 6 6 5 4 4 4 5 . 9 3 5 9 4 8 6 5 0 . 5 6 7 0 ° 1 5 ' 5 9 . 7 9 1 7 " N 1 4 8 ° 4 5 ' 4 . 0 2 5 7 " W 0 . 9 5 5 6 . 9 4 3 0 . 2 0 - 4 0 . 5 2 - 7 . 8 1 4 0 . 0 0 4 0 . 0 0 6 .4 9 3 4 4 . 5 0 18 0 0 . 0 0 1 . 4 4 2 7 3 . 6 4 1 7 9 9 . 8 3 1 7 3 4 . 4 8 - 0 . 1 4 - 1 4 . 6 7 6 5 4 4 4 5 . 3 3 5 9 4 8 6 5 0 . 5 6 7 0 ° 1 5 ' 5 9 . 7 9 1 8 " N 1 4 8 ° 4 5 ' 4 . 0 4 3 4 " W 0 . 6 8 1 2 8 . 2 2 2 0 . 4 0 2 2 . 7 6 - 8 . 1 6 4 0 . 0 0 4 0 . 0 0 6 .5 0 3 4 4 . 9 1 18 2 5 . 0 0 1 . 2 5 2 8 6 . 6 9 1 8 2 4 . 8 2 1 7 5 9 . 4 7 - 0 . 0 4 - 1 5 . 2 4 6 5 4 4 4 4 . 7 5 5 9 4 8 6 5 0 . 6 5 7 0 ° 1 5 ' 5 9 . 7 9 2 8 " N 1 4 8 ° 4 5 ' 4 . 0 6 0 1 " W 1 . 4 4 1 4 8 . 0 5 7 - 0 . 7 6 5 2 . 2 0 - 8 . 5 7 4 0 . 0 0 4 0 . 0 0 6. 5 0 3 4 5 . 6 7 18 5 0 . 0 0 1 . 0 0 2 9 6 . 1 5 1 8 4 9 . 8 2 1 7 8 4 . 4 7 0 . 1 3 - 1 5 . 7 0 6 5 4 4 4 4 . 2 9 5 9 4 8 6 5 0 . 8 1 7 0 ° 1 5 ' 5 9 . 7 9 4 5 " N 1 4 8 ° 4 5 ' 4 . 0 7 3 4 " W 1 . 2 4 - 1 4 6 . 6 0 8 - 1 . 0 0 3 7 . 8 4 - 8 . 9 7 4 0 . 0 0 4 0 . 0 0 6. 5 0 3 4 6 . 4 3 18 7 5 . 0 0 0 . 8 1 2 8 6 . 7 4 1 8 7 4 . 8 2 1 8 0 9 . 4 7 0 . 2 8 - 1 6 . 0 7 6 5 4 4 4 3 . 9 2 5 9 4 8 6 5 0 . 9 5 7 0 ° 1 5 ' 5 9 . 7 9 5 9 " N 1 4 8 ° 4 5 ' 4 . 0 8 4 0 " W 0 . 9 6 - 8 0 . 7 4 - 0 . 7 6 - 3 7 . 6 4 - 9 . 3 0 4 0 . 0 0 4 0 . 0 0 6 .5 0 3 4 7 . 1 0 19 0 0 . 0 0 0 . 8 6 2 7 4 . 3 7 1 8 9 9 . 8 1 1 8 3 4 . 4 6 0 . 3 5 - 1 6 . 4 2 6 5 4 4 4 3 . 5 6 5 9 4 8 6 5 1 . 0 1 7 0 ° 1 5 ' 5 9 . 7 9 6 6 " N 1 4 8 ° 4 5 ' 4 . 0 9 4 4 " W 0 . 7 5 - 1 4 6 . 7 5 8 0 . 2 0 - 4 9 . 4 8 - 9 . 5 5 4 0 . 0 0 4 0 . 0 0 6. 5 1 3 4 7 . 5 5 19 2 5 . 0 0 0 . 7 2 2 6 6 . 7 1 1 9 2 4 . 8 1 1 8 5 9 . 4 6 0 . 3 5 - 1 6 . 7 7 6 5 4 4 4 3 . 2 2 5 9 4 8 6 5 1 . 0 1 7 0 ° 1 5 ' 5 9 . 7 9 6 6 " N 1 4 8 ° 4 5 ' 4 . 1 0 4 4 " W 0 . 7 0 - 1 0 6 . 6 3 - 0 . 5 6 - 3 0 . 6 4 - 9 . 7 5 4 0 . 0 0 4 0 . 0 0 6. 5 1 3 4 7 . 7 7 19 5 0 . 0 0 0 . 6 9 2 5 1 . 1 4 1 9 4 9 . 8 1 1 8 8 4 . 4 6 0 . 2 9 - 1 7 . 0 7 6 5 4 4 4 2 . 9 2 5 9 4 8 6 5 0 . 9 4 7 0 ° 1 5 ' 5 9 . 7 9 6 0 " N 1 4 8 ° 4 5 ' 4 . 1 1 3 1 " W 0 . 7 7 - 8 7 . 1 8 6 - 0 . 1 2 - 6 2 . 2 8 - 9 . 8 7 4 0 . 0 0 4 0 . 0 0 6. 5 1 1 6 7 . 7 1 19 7 5 . 0 0 0 . 7 1 2 4 0 . 0 4 1 9 7 4 . 8 1 1 9 0 9 . 4 6 0 . 1 7 - 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0 . 4 0 - 1 8 . 3 6 6 5 4 4 4 1 . 6 5 5 9 4 8 6 5 0 . 2 3 7 0 ° 1 5 ' 5 9 . 7 8 9 2 " N 1 4 8 ° 4 5 ' 4 . 1 5 0 7 " W 0 . 1 0 - 5 8 . 2 3 1 - 0 . 0 8 6 . 1 2 - 1 0 . 0 3 4 0 . 0 1 4 0 . 0 0 6. 5 3 1 6 6 . 0 0 21 0 0 . 0 0 0 . 6 7 2 3 8 . 9 3 2 0 9 9 . 8 0 2 0 3 4 . 4 5 - 0 . 5 3 - 1 8 . 6 1 6 5 4 4 4 1 . 4 0 5 9 4 8 6 5 0 . 0 9 7 0 ° 1 5 ' 5 9 . 7 8 7 9 " N 1 4 8 ° 4 5 ' 4 . 1 5 7 9 " W 0 . 3 5 - 1 2 7 . 5 7 3 0 . 2 0 - 2 5 . 4 0 - 1 0 . 0 6 4 0 . 0 1 4 0 . 00 6 . 5 3 1 6 5 . 7 0 21 2 5 . 0 0 0 . 6 0 2 2 9 . 1 0 2 1 2 4 . 8 0 2 0 5 9 . 4 5 - 0 . 6 9 - 1 8 . 8 3 6 5 4 4 4 1 . 1 8 5 9 4 8 6 4 9 . 9 2 7 0 ° 1 5 ' 5 9 . 7 8 6 4 " N 1 4 8 ° 4 5 ' 4 . 1 6 4 4 " W 0 . 5 2 1 5 8 . 6 5 6 - 0 . 2 8 - 3 9 . 3 2 - 1 0 . 0 5 4 0 . 0 1 4 0 . 00 6 . 5 3 1 6 5 . 2 5 21 5 0 . 0 0 0 . 5 4 2 3 1 . 6 1 2 1 4 9 . 8 0 2 0 8 4 . 4 5 - 0 . 8 5 - 1 9 . 0 2 6 5 4 4 4 0 . 9 9 5 9 4 8 6 4 9 . 7 6 7 0 ° 1 5 ' 5 9 . 7 8 4 8 " N 1 4 8 ° 4 5 ' 4 . 1 7 0 0 " W 0 . 2 6 - 6 9 . 9 2 4 - 0 . 2 4 1 0 . 0 4 - 1 0 . 0 3 4 0 . 0 1 4 0 . 0 0 6 . 5 4 1 6 4 . 7 7 21 7 5 . 0 0 0 . 5 5 2 2 8 . 9 3 2 1 7 4 . 7 9 2 1 0 9 . 4 4 - 1 . 0 0 - 1 9 . 2 0 6 5 4 4 4 0 . 8 1 5 9 4 8 6 4 9 . 6 1 7 0 ° 1 5 ' 5 9 . 7 8 3 3 " N 1 4 8 ° 4 5 ' 4 . 1 7 5 3 " W 0 . 1 1 1 4 7 . 5 0 9 0 . 0 4 - 1 0 . 7 2 - 1 0 . 0 1 4 0 . 0 1 4 0 . 0 0 6 . 5 4 1 6 4 . 3 0 22 0 0 . 0 0 0 . 4 6 2 3 6 . 4 0 2 1 9 9 . 7 9 2 1 3 4 . 4 4 - 1 . 1 4 - 1 9 . 3 8 6 5 4 4 4 0 . 6 4 5 9 4 8 6 4 9 . 4 7 7 0 ° 1 5 ' 5 9 . 7 8 2 0 " N 1 4 8 ° 4 5 ' 4 . 1 8 0 4 " W 0 . 4 5 1 3 7 . 3 5 - 0 . 3 6 2 9 . 8 8 - 1 0 . 0 0 4 0 . 0 1 4 0 . 0 0 6. 5 4 1 6 3 . 9 0 22 2 5 . 0 0 0 . 3 8 2 4 8 . 8 5 2 2 2 4 . 7 9 2 1 5 9 . 4 4 - 1 . 2 2 - 1 9 . 5 4 6 5 4 4 4 0 . 4 8 5 9 4 8 6 4 9 . 3 8 7 0 ° 1 5 ' 5 9 . 7 8 1 1 " N 1 4 8 ° 4 5 ' 4 . 1 8 5 1 " W 0 . 4 8 - 1 3 4 . 0 3 5 - 0 . 3 2 4 9 . 8 0 - 1 0 . 0 2 4 0 . 0 1 4 0 . 00 6 . 5 5 1 6 3 . 7 1 22 5 0 . 0 0 0 . 3 4 2 4 1 . 3 5 2 2 4 9 . 7 9 2 1 8 4 . 4 4 - 1 . 2 9 - 1 9 . 6 8 6 5 4 4 4 0 . 3 4 5 9 4 8 6 4 9 . 3 1 7 0 ° 1 5 ' 5 9 . 7 8 0 5 " N 1 4 8 ° 4 5 ' 4 . 1 8 9 2 " W 0 . 2 5 1 4 0 . 3 1 4 - 0 . 1 6 - 3 0 . 0 0 - 1 0 . 0 4 4 0 . 0 1 4 0 . 00 6 . 5 5 1 6 3 . 5 6 22 7 5 . 0 0 0 . 2 9 2 5 0 . 1 4 2 2 7 4 . 7 9 2 2 0 9 . 4 4 - 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7 1 . 7 2 3 0 . 0 0 - 1 1 . 7 8 - 4 1 0 0 . 2 0 6 4 . 5 3 5 8 . 3 1 2 2 . 0 1 1 7 5 . 7 2 12 3 7 0 . 6 6 9 1 . 9 4 1 4 7 . 4 4 8 9 3 4 . 9 0 8 8 6 9 . 5 5 5 3 8 4 . 5 0 6 6 5 . 3 4 6 5 5 0 1 4 . 6 7 5 9 5 4 0 4 7 . 6 2 7 0 ° 1 6 ' 5 2 . 7 4 9 2 " N 14 8 ° 4 4 ' 4 4 . 2 3 7 4 " W 15 . 0 1 - 9 6 . 6 4 4 . 7 0 - 1 4 . 2 6 - 4 0 7 0 . 0 7 6 4 . 6 4 5 8 . 5 8 2 2 . 1 4 1 7 2 . 8 8 12 4 0 0 . 3 6 9 1 . 3 8 1 4 2 . 6 8 8 9 3 4 . 0 4 8 8 6 8 . 6 9 5 3 6 0 . 1 7 6 8 2 . 3 3 6 5 5 0 3 2 . 1 6 5 9 5 4 0 2 3 . 6 4 7 0 ° 1 6 ' 5 2 . 5 0 9 9 " N 14 8 ° 4 4 ' 4 3 . 7 4 2 3 " W 16 . 1 3 - 1 0 8 . 7 8 4 - 1 . 8 9 - 1 6 . 0 3 - 4 0 4 0 . 3 9 6 4 . 7 9 5 8 . 8 6 2 2 . 2 6 1 6 9 . 8 1 12 4 3 0 . 3 5 8 9 . 8 5 1 3 8 . 1 9 8 9 3 3 . 7 2 8 8 6 8 . 3 7 5 3 3 7 . 0 6 7 0 1 . 4 3 6 5 5 0 5 1 . 7 2 5 9 5 4 0 0 0 . 9 3 7 0 ° 1 6 ' 5 2 . 2 8 2 6 " N 14 8 ° 4 4 ' 4 3 . 1 8 6 2 " W 15 . 8 2 - 9 5 . 2 4 2 - 5 . 1 0 - 1 4 . 9 7 - 4 0 1 0 . 5 3 6 4 . 9 9 5 9 . 1 8 2 2 . 4 0 1 6 6 . 4 1 12 4 6 0 . 1 8 8 9 . 6 3 1 3 5 . 7 9 8 9 3 3 . 8 6 8 8 6 8 . 5 1 5 3 1 5 . 2 5 7 2 1 . 7 8 6 5 5 0 7 2 . 5 1 5 9 5 3 9 7 9 . 5 4 7 0 ° 1 6 ' 5 2 . 0 6 8 0 " N 14 8 ° 4 4 ' 4 2 . 5 9 3 7 " W 8. 0 8 - 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3 8 6 0 . 5 7 6 6 . 9 0 6 0 . 3 8 2 3 . 0 9 1 4 8 . 2 7 12 6 1 0 . 1 3 9 3 . 0 1 1 4 6 . 8 4 8 9 2 8 . 2 4 8 8 6 2 . 8 9 5 2 0 4 . 6 5 8 2 1 . 9 3 6 5 5 1 7 4 . 9 1 5 9 5 3 8 7 1 . 0 2 7 0 ° 1 6 ' 5 0 . 9 8 0 1 " N 14 8 ° 4 4 ' 3 9 . 6 7 6 8 " W 9. 8 1 7 5 . 5 0 3 - 3 . 3 6 9 . 2 3 - 3 8 3 3 . 2 2 6 7 . 3 8 6 0 . 3 9 2 3 . 2 2 1 4 6 . 2 1 12 6 4 0 . 7 9 9 4 . 5 5 1 5 2 . 8 9 8 9 2 6 . 2 1 8 8 6 0 . 8 6 5 1 7 8 . 2 0 8 3 7 . 2 9 6 5 5 1 9 0 . 8 0 5 9 5 3 8 4 4 . 9 0 7 0 ° 1 6 ' 5 0 . 7 2 0 0 " N 14 8 ° 4 4 ' 3 9 . 2 2 9 8 " W 20 . 3 2 8 8 . 7 8 9 5 . 0 2 1 9 . 7 3 - 3 8 0 2 . 7 2 6 7 . 9 3 6 0 . 3 4 2 3 . 3 7 1 4 4 . 5 1 12 6 7 0 . 3 3 9 4 . 6 5 1 5 8 . 7 8 8 9 2 3 . 8 4 8 8 5 8 . 4 9 5 1 5 1 . 3 5 8 4 9 . 3 3 6 5 5 2 0 3 . 3 9 5 9 5 3 8 1 8 . 3 0 7 0 ° 1 6 ' 5 0 . 4 5 5 9 " N 14 8 ° 4 4 ' 3 8 . 8 7 9 0 " W 19 . 8 8 8 9 . 8 3 8 0 . 3 4 1 9 . 9 4 - 3 7 7 3 . 7 5 6 8 . 4 5 6 0 . 2 5 2 3 . 5 1 1 4 3 . 4 9 12 7 0 9 . 2 2 9 4 . 6 4 1 6 5 . 0 4 8 9 2 0 . 6 9 8 8 5 5 . 3 4 5 1 1 4 . 5 2 8 6 1 . 3 6 6 5 5 2 1 6 . 1 8 5 9 5 3 7 8 1 . 7 3 7 0 ° 1 6 ' 5 0 . 0 9 3 7 " N 14 8 ° 4 4 ' 3 8 . 5 2 8 7 " W 16 . 0 4 9 3 . 9 0 9 - 0 . 0 3 1 6 . 1 0 - 3 7 3 6 . 5 6 6 9 . 0 9 6 0 . 0 8 2 3 . 6 9 1 4 2 . 8 0 12 7 3 4 . 1 0 9 4 . 2 4 1 7 0 . 6 0 8 9 1 8 . 7 6 8 8 5 3 . 4 1 5 0 9 0 . 2 8 8 6 6 . 6 0 6 5 5 2 2 1 . 9 0 5 9 5 3 7 5 7 . 6 1 7 0 ° 1 6 ' 4 9 . 8 5 5 4 " N 14 8 ° 4 4 ' 3 8 . 3 7 6 4 " W 22 . 3 4 9 4 . 3 1 6 - 1 . 6 1 2 2 . 3 5 - 3 7 1 3 . 6 0 6 9 . 4 6 5 9 . 9 6 2 3 . 8 1 1 4 2 . 6 7 12 7 6 0 . 2 0 9 3 . 9 6 1 7 4 . 2 1 8 9 1 6 . 8 9 8 8 5 1 . 5 4 5 0 6 4 . 4 8 8 7 0 . 0 4 6 5 5 2 2 5 . 8 7 5 9 5 3 7 3 1 . 8 9 7 0 ° 1 6 ' 4 9 . 6 0 1 6 " N 14 8 ° 4 4 ' 3 8 . 2 7 6 3 " W 13 . 8 4 9 1 . 7 6 - 1 . 0 7 1 3 . 8 3 - 3 6 9 0 . 3 6 6 9 . 8 1 5 9 . 8 3 2 3 . 9 4 1 4 2 . 7 1 12 7 8 9 . 1 2 9 3 . 8 2 1 7 8 . 4 3 8 9 1 4 . 9 3 8 8 4 9 . 5 8 5 0 3 5 . 7 0 8 7 1 . 8 9 6 5 5 2 2 8 . 3 1 5 9 5 3 7 0 3 . 1 5 7 0 ° 1 6 ' 4 9 . 3 1 8 5 " N 14 8 ° 4 4 ' 3 8 . 2 2 2 5 " W 14 . 5 7 7 9 . 7 4 - 0 . 4 8 1 4 . 5 9 - 3 6 6 5 . 5 4 7 0 . 1 7 5 9 . 6 8 2 4 . 0 8 1 4 2 . 9 0 12 8 2 0 . 1 0 9 4 . 4 6 1 8 2 . 0 2 8 9 1 2 . 6 9 8 8 4 7 . 3 4 5 0 0 4 . 8 0 8 7 1 . 7 7 6 5 5 2 2 8 . 8 3 5 9 5 3 6 7 2 . 2 6 7 0 ° 1 6 ' 4 9 . 0 1 4 6 " N 14 8 ° 4 4 ' 3 8 . 2 2 6 1 " W 11 . 7 4 - 6 6 . 0 7 2 . 0 7 1 1 . 5 9 - 3 6 4 0 . 1 1 7 0 . 5 2 5 9 . 5 4 2 4 . 2 4 1 4 3 . 2 2 12 8 4 6 . 4 6 9 5 . 7 3 1 7 9 . 1 3 8 9 1 0 . 3 5 8 8 4 5 . 0 0 4 9 7 8 . 5 5 8 7 1 . 5 0 6 5 5 2 2 9 . 1 0 5 9 5 3 6 4 6 . 0 1 7 0 ° 1 6 ' 4 8 . 7 5 6 5 " N 14 8 ° 4 4 ' 3 8 . 2 3 3 9 " W 11 . 9 4 - 7 7 . 4 7 6 4 . 8 2 - 1 0 . 9 6 - 3 6 1 8 . 5 8 7 0 . 8 1 5 9 . 4 2 2 4 . 3 7 1 4 3 . 5 1 12 8 7 3 . 7 5 9 6 . 5 0 1 7 5 . 5 9 8 9 0 7 . 4 5 8 8 4 2 . 1 0 4 9 5 1 . 4 5 8 7 2 . 7 5 6 5 5 2 3 0 . 9 1 5 9 5 3 6 1 8 . 9 4 7 0 ° 1 6 ' 4 8 . 4 8 9 9 " N 14 8 ° 4 4 ' 3 8 . 1 9 7 6 " W 13 . 2 0 - 8 5 . 8 4 2 2 . 8 2 - 1 2 . 9 7 - 3 5 9 5 . 5 0 7 1 . 1 5 5 9 . 3 0 2 4 . 5 0 1 4 3 . 7 3 12 9 0 6 . 4 7 9 6 . 9 0 1 6 9 . 5 4 8 9 0 3 . 6 2 8 8 3 8 . 2 7 4 9 1 9 . 2 4 8 7 6 . 9 5 6 5 5 2 3 5 . 7 7 5 9 5 3 5 8 6 . 8 3 7 0 ° 1 6 ' 4 8 . 1 7 3 2 " N 14 8 ° 4 4 ' 3 8 . 0 7 5 3 " W 18 . 4 0 - 1 1 9 . 8 8 5 1 . 2 2 - 1 8 . 4 9 - 3 5 6 6 . 5 4 7 1 . 6 1 5 9 . 1 6 2 4 . 6 7 1 4 3 . 8 8 12 9 3 0 . 4 2 9 6 . 1 9 1 6 8 . 3 0 8 9 0 0 . 8 9 8 8 3 5 . 5 4 4 8 9 5 . 8 9 8 8 1 . 5 3 6 5 5 2 4 0 . 8 2 5 9 5 3 5 6 3 . 5 8 7 0 ° 1 6 ' 4 7 . 9 4 3 5 " N 14 8 ° 4 4 ' 3 7 . 9 4 2 2 " W 5. 9 4 - 9 6 . 4 5 3 - 2 . 9 6 - 5 . 1 8 - 3 5 4 4 . 6 8 7 1 . 9 9 5 9 . 0 6 2 4 . 7 9 1 4 3 . 9 1 12 9 6 0 . 3 3 9 5 . 9 1 1 6 5 . 8 6 8 8 9 7 . 7 4 8 8 3 2 . 3 9 4 8 6 6 . 9 1 8 8 8 . 1 8 6 5 5 2 4 8 . 0 6 5 9 5 3 5 3 4 . 7 4 7 0 ° 1 6 ' 4 7 . 6 5 8 4 " N 14 8 ° 4 4 ' 3 7 . 7 4 8 7 " W 8. 1 7 - 5 7 . 1 3 1 - 0 . 9 4 - 8 . 1 6 - 3 5 1 7 . 0 0 7 2 . 4 9 5 8 . 9 4 2 4 . 9 4 1 4 3 . 9 1 12 9 9 0 . 4 8 9 7 . 5 5 1 6 3 . 2 9 8 8 9 4 . 2 1 8 8 2 8 . 8 6 4 8 3 8 . 0 4 8 9 6 . 1 4 6 5 5 2 5 6 . 6 1 5 9 5 3 5 0 6 . 0 5 7 0 ° 1 6 ' 4 7 . 3 7 4 5 " N 14 8 ° 4 4 ' 3 7 . 5 1 6 9 " W 10 . 0 6 - 3 3 . 8 5 4 5 . 4 4 - 8 . 5 2 - 3 4 8 8 . 6 8 7 3 . 0 2 5 8 . 8 3 2 5 . 1 0 1 4 3 . 8 6 13 0 2 0 . 4 6 1 0 0 . 4 2 1 6 1 . 3 3 8 8 8 9 . 5 3 8 8 2 4 . 1 8 4 8 0 9 . 8 4 9 0 5 . 1 3 6 5 5 2 6 6 . 1 8 5 9 5 3 4 7 8 . 0 3 7 0 ° 1 6 ' 4 7 . 0 9 7 1 " N 14 8 ° 4 4 ' 3 7 . 2 5 5 0 " W 11 . 5 5 - 2 7 . 1 3 7 9 . 5 7 - 6 . 5 4 - 3 4 6 0 . 3 1 7 3 . 5 8 5 8 . 7 3 2 5 . 2 5 1 4 3 . 7 7 13 0 5 0 . 4 3 1 0 3 . 6 4 1 5 9 . 6 3 8 8 8 3 . 2 8 8 8 1 7 . 9 3 4 7 8 2 . 2 1 9 1 4 . 9 2 6 5 5 2 7 6 . 5 4 5 9 5 3 4 5 0 . 6 2 7 0 ° 1 6 ' 4 6 . 8 2 5 4 " N 14 8 ° 4 4 ' 3 6 . 9 7 0 0 " W 12 . 0 9 - 2 8 . 0 8 7 1 0 . 7 4 - 5 . 6 7 - 3 4 3 1 . 9 8 7 4 . 1 5 5 8 . 6 3 2 5 . 4 1 1 4 3 . 6 5 13 0 8 0 . 5 6 1 0 6 . 0 5 1 5 8 . 2 9 8 8 7 5 . 5 6 8 8 1 0 . 2 1 4 7 5 5 . 0 3 9 2 5 . 3 8 6 5 5 2 8 7 . 5 5 5 9 5 3 4 2 3 . 6 6 7 0 ° 1 6 ' 4 6 . 5 5 8 1 " N 14 8 ° 4 4 ' 3 6 . 6 6 5 6 " W 9. 0 8 - 4 7 . 2 8 6 8 . 0 0 - 4 . 4 5 - 3 4 0 3 . 6 4 7 4 . 7 3 5 8 . 5 5 2 5 . 5 6 1 4 3 . 5 1 13 1 1 0 . 4 2 1 0 8 . 5 6 1 5 5 . 4 0 8 8 6 6 . 6 8 8 8 0 1 . 3 3 4 7 2 8 . 8 2 9 3 6 . 5 8 6 5 5 2 9 9 . 2 8 5 9 5 3 3 9 7 . 6 9 7 0 ° 1 6 ' 4 6 . 3 0 0 3 " N 14 8 ° 4 4 ' 3 6 . 3 3 9 4 " W 12 . 4 9 - 3 0 . 9 2 8 . 4 1 - 9 . 6 8 - 3 3 7 5 . 6 8 7 5 . 3 3 5 8 . 4 7 2 5 . 7 1 1 4 3 . 3 5 13 1 4 0 . 5 4 1 1 0 . 9 4 1 5 3 . 8 7 8 8 5 6 . 5 0 8 7 9 1 . 1 5 4 7 0 3 . 2 1 9 4 8 . 7 2 6 5 5 3 1 1 . 9 5 5 9 5 3 3 7 2 . 3 3 7 0 ° 1 6 ' 4 6 . 0 4 8 4 " N 14 8 ° 4 4 ' 3 5 . 9 8 6 0 " W 9. 2 4 - 1 0 0 . 5 8 1 7 . 9 0 - 5 . 0 8 - 3 3 4 7 . 6 9 7 5 . 9 4 5 8 . 4 1 2 5 . 8 5 1 4 3 . 1 5 13 1 7 3 . 6 1 1 1 0 . 2 5 1 5 0 . 1 6 8 8 4 4 . 8 6 8 7 7 9 . 5 1 4 6 7 5 . 8 8 9 6 3 . 2 4 6 5 5 3 2 7 . 0 3 5 9 5 3 3 4 5 . 3 1 7 0 ° 1 6 ' 4 5 . 7 7 9 6 " N 14 8 ° 4 4 ' 3 5 . 5 6 3 1 " W 10 . 7 1 - 1 2 9 . 2 2 - 2 . 0 9 - 1 1 . 2 2 - 3 3 1 6 . 9 3 7 6 . 6 4 5 8 . 3 5 2 6 . 0 1 1 4 2 . 8 9 13 2 0 5 . 5 4 1 0 9 . 2 2 1 4 8 . 8 3 8 8 3 4 . 0 8 8 7 6 8 . 7 3 4 6 4 9 . 9 9 9 7 8 . 5 0 6 5 5 3 4 2 . 8 1 5 9 5 3 3 1 9 . 7 4 7 0 ° 1 6 ' 4 5 . 5 2 4 9 " N 14 8 ° 4 4 ' 3 5 . 1 1 8 8 " W 5. 0 8 - 9 3 . 3 1 6 - 3 . 2 3 - 4 . 1 7 - 3 2 8 6 . 9 4 7 7 . 3 4 5 8 . 3 1 2 6 . 1 6 1 4 2 . 5 9 13 2 3 0 . 7 1 1 0 9 . 0 6 1 4 6 . 2 4 8 8 2 5 . 8 3 8 7 6 0 . 4 8 4 6 2 9 . 9 3 9 9 1 . 2 6 6 5 5 3 5 5 . 9 8 5 9 5 3 2 9 9 . 9 4 7 0 ° 1 6 ' 4 5 . 3 2 7 6 " N 14 8 ° 4 4 ' 3 4 . 7 4 7 2 " W 9. 7 4 - 8 7 . 7 4 - 0 . 6 4 - 1 0 . 2 9 - 3 2 6 3 . 1 8 7 7 . 9 1 5 8 . 2 9 2 6 . 2 8 1 4 2 . 3 3 13 2 6 0 . 5 3 1 0 9 . 1 8 1 4 1 . 1 3 8 8 1 6 . 0 5 8 7 5 0 . 7 0 4 6 0 7 . 2 3 1 0 0 7 . 9 4 6 5 5 3 7 3 . 1 2 5 9 5 3 2 7 7 . 6 0 7 0 ° 1 6 ' 4 5 . 1 0 4 4 " N 14 8 ° 4 4 ' 3 4 . 2 6 1 6 " W 16 . 2 0 - 4 4 . 1 9 4 0 . 4 0 - 1 7 . 1 4 - 3 2 3 5 . 0 3 7 8 . 6 2 5 8 . 2 8 2 6 . 4 2 1 4 1 . 9 6 13 2 9 0 . 4 7 1 0 9 . 4 9 1 4 0 . 8 1 8 8 0 6 . 1 4 8 7 4 0 . 7 9 4 5 8 5 . 2 9 1 0 2 5 . 7 3 6 5 5 3 9 1 . 3 6 5 9 5 3 2 5 6 . 0 2 7 0 ° 1 6 ' 4 4 . 8 8 8 5 " N 14 8 ° 4 4 ' 3 3 . 7 4 3 5 " W 1. 4 5 - 4 9 . 3 6 9 1 . 0 4 - 1 . 0 7 - 3 2 0 6 . 8 8 7 9 . 3 5 5 8 . 2 8 2 6 . 5 6 1 4 1 . 5 4 13 3 2 0 . 2 8 1 1 0 . 3 0 1 3 9 . 8 0 8 7 9 6 . 0 0 8 7 3 0 . 6 5 4 5 6 3 . 7 2 1 0 4 3 . 6 3 6 5 5 4 0 9 . 7 0 5 9 5 3 2 3 4 . 8 3 7 0 ° 1 6 ' 4 4 . 6 7 6 4 " N 14 8 ° 4 4 ' 3 3 . 2 2 2 2 " W 4. 1 9 - 8 3 . 4 7 9 2 . 7 2 - 3 . 3 9 - 3 1 7 8 . 9 7 8 0 . 0 8 5 8 . 2 8 2 6 . 7 1 1 4 1 . 1 4 13 3 5 0 . 3 7 1 1 0 . 5 7 1 3 7 . 0 8 8 7 8 5 . 4 9 8 7 2 0 . 1 4 4 5 4 2 . 6 2 1 0 6 2 . 3 4 6 5 5 4 2 8 . 8 3 5 9 5 3 2 1 4 . 1 2 7 0 ° 1 6 ' 4 4 . 4 6 8 9 " N 14 8 ° 4 4 ' 3 2 . 6 7 7 6 " W 8. 5 2 - 8 0 . 3 0 8 0 . 9 0 - 9 . 0 4 - 3 1 5 1 . 0 0 8 0 . 8 3 5 8 . 3 0 2 6 . 8 5 1 4 0 . 7 2 13 3 8 0 . 2 7 1 1 0 . 9 1 1 3 4 . 8 6 8 7 7 4 . 9 0 8 7 0 9 . 5 5 4 5 2 2 . 5 2 1 0 8 1 . 7 7 6 5 5 4 4 8 . 6 7 5 9 5 3 1 9 4 . 4 2 7 0 ° 1 6 ' 4 4 . 2 7 1 1 " N 14 8 ° 4 4 ' 3 2 . 1 1 1 8 " W 7. 0 4 - 8 2 . 5 9 5 1 . 1 4 - 7 . 4 2 - 3 1 2 3 . 4 4 8 1 . 6 0 5 8 . 3 2 2 7 . 0 0 1 4 0 . 2 7 13 4 1 1 . 5 2 1 1 1 . 2 0 1 3 2 . 3 1 8 7 6 3 . 6 7 8 6 9 8 . 3 2 4 5 0 2 . 4 2 1 1 0 2 . 8 9 6 5 5 4 7 0 . 2 0 5 9 5 3 1 7 4 . 7 6 7 0 ° 1 6 ' 4 4 . 0 7 3 4 " N 14 8 ° 4 4 ' 3 1 . 4 9 6 7 " W 7. 6 7 0 0 . 9 3 - 8 . 1 6 - 3 0 9 4 . 9 2 8 2 . 4 0 5 8 . 3 6 2 7 . 1 5 1 3 9 . 7 9 13 4 5 0 . 0 0 11 1 . 2 0 13 2 . 3 1 87 4 9 . 7 6 86 8 4 . 4 1 44 7 8 . 2 7 11 2 9 . 4 2 65 5 4 9 7 . 2 1 59 5 3 1 5 1 . 1 6 70 ° 1 6 ' 4 3 . 8 3 5 8 " N 14 8 ° 4 4 ' 3 0 . 7 2 4 2 " W 0. 0 0 N/ A 0. 0 0 0. 0 0 -3 0 6 0 . 0 1 83 . 4 1 58 . 4 2 27 . 3 3 13 9 . 1 9 Pr o j e c t i o n t o T D Pa g e 7 o f 7 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-06A Hilcorp North Slope, LLC Permit to Drill Number: 223-015 Surface Location: 1796' FNL, 922' FEL, Sec. 35, T11N, R13E, UM, AK Bottomhole Location: 2520' FNL, 326' FWL, Sec. 25, T11N, R13E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of February, 2023. 23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.23 14:35:06 -09'00' 1a. Contact Name:Trevor Hyatt Contact Email:trevor.hyatt@hilcorp.comAuthorized Name: Monty Myers Authorized Title:Drilling Manager Authorized Signature: Contact Phone:907-777-8396 Approved by:COMMISSIONER APPROVED BY THE COMMISSION Date: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Drill Type of Work: Redrill 5 Lateral 1b.Proposed Well Class:Exploratory - Gas 5 Service - WAG 5 1c. Specify if well is proposed for: Development - Oil Service - Winj Multiple Zone Exploratory - Oil Gas Hydrates Geothermal Hilcorp North Slope, LLC Bond No. 107205344 11.Well Name and Number: PBU A-06A TVD:13510'8729' 12. Field/Pool(s): PRUDHOE BAY, PRUDHOE OILMD: ADL 028286 69-026 March 9, 2023 4a. Surface: Top of Productive Horizon: Total Depth: 1796' FNL, 922' FEL, Sec. 35, T11N, R13E, UM, AK 1856' FNL, 1352' FEL, Sec. 26, T11N, R13E, UM, AK Kickoff Depth:10695'feet Maximum Hole Angle: 111 degrees Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:Surface:3313 2433 17.Deviated wells:16. Surface: x-y- Zone -654460 5948651 4 10. KB Elevation above MSL: GL Elevation above MSL: feet feet 65.35' 45.9' 15.Distance to Nearest Well Open to Same Pool: Cement Quantity, c.f. or sacks MD Casing Program: 9250'7484' 19.PRESENT WELL CONDITION SUMMARY Tieback 85 11411 9291 10869, 11096 10869 8832 Unknown, 11035 23 - 108 Surface 5309 sx Permafrost II 8803 - 9046 Seabed Report Drilling Fluid Program 5 20 AAC 25.050 requirements Shallow Hazard Analysis 5 Commission Use Only See cover letter for other 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: Samples req'd: Yes No H2S measures Yes No Spacing exception req'd: Yes No Mud log req'd: Yes No Directional svy req'd: Yes No Inclination-only svy req'd: Yes No Other: Date: Address: Location of Well (State Base Plane Coordinates - NAD 27): 9.3#/6.6# 2338 10835 - 11121 50-029-20118-01-00 21 - 10013 425 sx Class G Intermediate Conductor/Structural Single Zone Service - Disp No YesPost initial injection MIT req'd: No Yes 5 Diverter Sketch Comm. TVD API Number: MD Sr Pet Geo 1750 sx Class G, 530 sx PF II 2520' FNL, 326' FWL, Sec. 25, T11N, R13E, UM, AK Time v. Depth Plot 5 5 Drilling Program 24950 (To be completed for Redrill and Re-Entry Operations) 30" 18-5/8" 13-3/8"x9-5/8" STL / TCII 9992 1994 7610 - 9282 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Stratigraphic Test Development - Gas Service - Supply Coalbed Gas Shale Gas 2.Operator Name:5.Bond Blanket 5 Single Well 3. 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 6. Proposed Depth: 7. Property Designation (Lease Number): 8. DNR Approval Number:13.Approximate spud date: 9.Acres in Property: 14. Distance to Nearest Property: Location of Well (Governmental Section): 4b. 2560 730 18.Specifications Top - Setting Depth - Bottom Casing Weight Grade TVDHole Coupling Length TVD (including stage data) 2-7/8" /6.5# /STL Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft):Junk (measured): Casing Length Size MD 23 - 108 22 - 2360 22 - 2360 1932 9-5/8"20 - 1952 20 - 1952 Liner 7"9407 - 11401 Perforation Depth MD (ft):Perforation Depth TVD (ft): 20. Attachments Property Plat BOP Sketch Permit to Drill Number: Permit Approval Date: Reentry Hydraulic Fracture planned? Sr Pet Eng Sr Res Eng 21 - 8111 Cement Volume Comm. 13510'8729'317 sx Class G4-1/4"3-1/2"x3-1/4"13Cr85 4260' Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) 2.21.2023 By Samantha Carlisle at 11:06 am, Feb 21, 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: 2023.02.21 10:53:53 -09'00' Monty M Myers SFD 2/21/2023 Alternate plug placement approved per 20 AAC 25.112(i) with fully cemented liner. BOPE test to 3500 psi. MGR21FEB2023 2433 223-015 DSR-2/22/23GCW 02/23/23 JLC 2/23/2023 2/23/23 2/23/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.02.23 14:35:26 -09'00' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: February 21, 2023 Re: PBU A-06A Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well PBU A-06 with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for A-06A Producer: See A-06 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2"x7" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x7" whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Sag and lands in Ivishak Zone 4. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference A-06 Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: 1. Slickline: Dummy WS drift 2. Fullbore: MITs 3. E-Line/Coil: Mill XN Nipple and set whipstock 4. Coil: Mill window 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work - (Estimated to start in March 2023): 1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,433 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure 2. Only if not done pre-rig – Set 4-1/2"x7" whipstock. a. Top of whipstock at 10,690’ MD oriented at 0° ROHS. 3. Only if not done pre-rig – Mill 3.80” single string window (out of 7”) plus 10’ of rathole. a. Top of window (whipstock pinch point 5’ down from top) at 10,695’ MD. 4. Drill – Build & Lateral a. 3” BHA with GR/RES / Bi-center Bit (4.25”) b. 30° DLS build section – 397’ MD / Planned TD 11,092’ MD c. 12° DLS lateral section – 2,419’ MD / Planned TD 13,511’ MD d. Drill with a constant bottom hole pressure for entire sidetrack e. Pressure deployment will be utilized f. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run g. No flow test prior to laying down drilling BHA. Assure well is dead prior to picking up liner. ,p yppg(p completion will completely isolate and abandon the parent Ivishak perfs. Sundry PTD 5. Run and Cement Liner a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Swap BOP rams from 3” pipe/slip (drilling) to 2-3/8”x3-1/2” VBRs (running liner) and test to 3500 psi. c. Run 3-1/2”x3-1/4”x2-7/8” 13Cr solid liner to TD d. Swap well over to KCl e. Cement Liner with 70 bbls - 15.3 ppg Class G cement (TOC to TOL)* f. Only if not able to do with service coil post rig - Perforate well ~20’ g. Freeze protect well from ~2200’ TVD (min) h. RDMO Post Rig: 1. V: Valve & tree work 2. S: Set LTP* (if necessary) – RPM Log 3. C: Post rig perforate (~20’) 4. T: Portable Test Separator Flowback * Approved alternate plug placement per 20 AAC 25.112(i) Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (10,695’ MD - 8,684’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,425 psi 4,425 psi 9.8 B Annular friction - ECD (psi/ft)535 psi 0 psi 0.05 C Mud Hydrostatic (ppg)3,883 psi 3,883 psi 8.6 B+C Mud + ECD Combined 4,418 psi 3,883 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 7 psi 542 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,313 psi at 8,800’ TVD (7.24 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,433 psi (from estimated reservoir pressure). Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain constant BHP. x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring. x Completion: A minimum MW 8.6 ppg KWF to be used for liner deployment. Will target 9.8 ppg to match managed pressure target. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 4.25” hole for the entirety of the production hole section. Liner Program: x 3-1/2”, 9.3#, 13Cr solid/cemented liner: 9,250’ MD – 10,675’ MD (1425’ liner) x 3-1/4”, 6.6#, 13Cr solid/cemented liner: 10,675’ MD – 11,100’ MD (425’ liner) x 2-7/8”, 6.5#, 13Cr solid/cemented liner: 11,100’ MD – 13,510’ MD (2411’ liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary x A X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 2,500 psi. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8”x3-1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. x A X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. x 2-3/8” safety joint will be utilized while running 2-7/8”, 3-1/4”, 3-1/2” solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-installed TIW valve). When closing on a 2-3/8” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 111°. Inclination at kick off point is 32°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 24,950’ x Distance to nearest well within pool – 730’ Logging: x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. x Possible RPM log will be run in cased hole post rig. Perforating: x ~20’ perforated post rig (See future perforating sundry request – if extended perforating is used) x 2” perf guns, 6 SPF, 60 deg phasing x If extended perforating is not an option, the well will be perforated with the rig or post rig under this PTD. Anti-Collision Failures: x No failures for A-06A WP08 Hazards: x PBU A-pad is an H2S pad. o The highest recorded H2S well on the pad was from A-37 (400 ppm) in 1998. o Last recorded H2S on A-06 was 20 ppm in 2020 x Two fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 6WDQGDUG3URSRVDO5HSRUW )HEUXDU\ 3ODQ $$ZS +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ $ 3ODQ $ 3ODQ $$ 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 South(-)/North(+) (400 usft/in)-800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 West(-)/East(+) (400 usft/in) A-06A wp08 polygon A-06A wp08 tgt5 A-06A wp08 tgt3 A-06A wp08 tgt2A-06A wp08 tgt1 A-06A wp08 tgt4 A-06 7" TOW 2 3/8" x 4 1/4" 8750 8729A-06A wp08KOP : Start Dir 9º/100' : 10695' MD, 8683.98'TVD : 0° RT TF Start Dir 25º/100' : 10715' MD, 8700.85'TVD Start Dir 12º/100' : 11091.52' MD, 8803.97'TVD Total Depth : 13510.44' MD, 8729.49' TVD CASING DETAILS TVD TVDSS MD Size Name 8684.83 8619.48 10696.00 7 7" TOW 8729.49 8664.14 13510.44 2-3/8 2 3/8" x 4 1/4" Project: Prudhoe Bay Site: A Well: Plan: A-06 Wellbore: Plan: A-06A Plan: A-06A wp08 WELL DETAILS: Plan: A-06 Ground Level: 45.90 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 5948651.000 654459.995 70° 15' 59.7931 N 148° 45' 3.6162 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: A-06, True North Vertical (TVD) Reference:KB @ 65.35usft (A-06 As-Built) Measured Depth Reference:KB @ 65.35usft (A-06 As-Built) Calculation Method:Minimum Curvature 8500862587508875900091259250937595009625True Vertical Depth (250 usft/in)-1000 -875 -750 -625 -500 -375 -250 -125 0 125 250 375 500 625 750 875 1000 1125 1250 1375Vertical Section at 145.65° (250 usft/in)A-06A wp08 tgt4A-06A wp08 tgt1A-06A wp08 tgt2A-06A wp08 tgt3A-06A wp08 tgt5A-06A wp08 polygon105001100011411A-067" TOW2 3/8" x 4 1/4"110 0011500 12000 12500 1 3 0 0 0 1 3 5 0 013510A-06A wp08KOP : Start Dir 9º/100' : 10695' MD, 8683.98'TVD : 0° RT TFStart Dir 25º/100' : 10715' MD, 8700.85'TVDStart Dir 12º/100' : 11091.52' MD, 8803.97'TVDTotal Depth : 13510.44' MD, 8729.49' TVDHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: A-06Ground Level: 45.90+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005948651.000654459.995 70° 15' 59.7931 N 148° 45' 3.6162 WSURVEY PROGRAMDate: 2023-02-20T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool100.00 10695.00 A-06 GYD-CT-CMS (A-06) 3_Gyro-CT_Drill pipe10695.00 13510.44 A-06A wp08 (Plan: A-06A) 3_MWDFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: A-06, True NorthVertical (TVD) Reference:KB @ 65.35usft (A-06 As-Built)Measured Depth Reference:KB @ 65.35usft (A-06 As-Built)Calculation Method: Minimum CurvatureProject:Prudhoe BaySite:AWell:Plan: A-06Wellbore:Plan: A-06ADesign:A-06A wp08CASING DETAILSTVD TVDSS MD SizeName8684.83 8619.48 10696.00 7 7" TOW8729.49 8664.14 13510.44 2-3/8 2 3/8" x 4 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 10695.00 31.57 5.19 8683.98 5171.31 -438.53 0.00 0.00 -390.32 KOP : Start Dir 9º/100' : 10695' MD, 8683.98'TVD : 0° RT TF2 10715.00 33.37 5.19 8700.85 5182.00 -437.56 9.00 0.00 -398.60 Start Dir 25º/100' : 10715' MD, 8700.85'TVD3 10941.52 90.00 5.19 8803.97 5372.62 -420.26 25.00 0.00 -546.214 11091.52 90.00 42.69 8803.97 5507.28 -360.48 25.00 90.00 -623.66 Start Dir 12º/100' : 11091.52' MD, 8803.97'TVD5 11191.52 90.00 54.69 8803.97 5573.18 -285.50 12.00 90.00 -635.766 11341.52 90.00 72.69 8803.97 5639.39 -151.59 12.00 90.00 -614.877 11571.52 62.40 72.69 8858.31 5705.20 59.60 12.00 180.00 -550.058 11671.52 74.40 72.69 8895.05 5732.82 148.20 12.00 0.00 -522.859 12001.82 90.75 109.25 8939.07 5725.42 468.87 12.00 69.00 -335.8110 12551.82 90.31 175.25 8933.36 5314.23 787.28 12.00 90.00 183.3311 12801.82 95.25 145.61 8920.99 5081.60 869.83 12.00 -80.00 421.9712 13001.82 100.86 169.19 8892.59 4900.29 945.60 12.00 75.00 614.4113 13203.61 110.00145.89 8838.27 4721.80 1018.44 12.00 -65.00 802.8714 13510.44 110.02 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B0:'(OOLSVHHUURUWHUPVDUHFRUUHODWHGDFURVVVXUYH\WRROWLHRQSRLQWV6HSDUDWLRQLVWKHDFWXDOGLVWDQFHEHWZHHQHOOLSVRLGV&DOFXODWHGHOOLSVHVLQFRUSRUDWHVXUIDFHHUURUV&OHDUDQFH)DFWRU 'LVWDQFH%HWZHHQ3URILOHV 'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ 'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG)HEUXDU\ &203$663DJHRI 0.001.002.003.004.00Separation Factor10800 10950 11100 11250 11400 11550 11700 11850 12000 12150 12300 12450 12600 12750 12900 13050 13200 13350 13500Measured Depth (300 usft/in)A-06D-09D-09AD-20D-20APB1No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: A-06 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 45.90+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005948651.000654459.99570° 15' 59.7931 N148° 45' 3.6162 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: A-06, True NorthVertical (TVD) Reference: KB @ 65.35usft (A-06 As-Built)Measured Depth Reference:KB @ 65.35usft (A-06 As-Built)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2023-02-20T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool100.00 10695.00 A-06 GYD-CT-CMS (A-06) 3_Gyro-CT_Drill pipe10695.00 13510.44 A-06A wp08 (Plan: A-06A) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)10800 10950 11100 11250 11400 11550 11700 11850 12000 12150 12300 12450 12600 12750 12900 13050 13200 13350 13500Measured Depth (300 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference10695.00 To 13510.44Project: Prudhoe BaySite: AWell: Plan: A-06Wellbore: Plan: A-06APlan: A-06A wp08Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name8684.83 8619.48 10696.00 7 7" TOW8729.49 8664.14 13510.44 2-3/8 2 3/8" x 4 1/4" Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 3" Pipe/Slips 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 15-Jan-21 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 3" Pipe/Slips Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 223-015 PRUDHOE OILPRUDHOE BAY PBU A-06A WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT A-06AInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2230150PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes Entire Well lies within ADL0028286.2 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE OIL POOL - 64015, governed by CO 341J4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes PBU A-06A is an in-zone sidetrack from an existing wellbore.18 Conductor string providedYes PBU A-06A is an in-zone sidetrack from an existing wellbore.19 Surface casing protects all known USDWsYes PBU A-06A is an in-zone sidetrack from an existing wellbore.20 CMT vol adequate to circulate on conductor & surf csgYes PBU A-06A is an in-zone sidetrack from an existing wellbore.21 CMT vol adequate to tie-in long string to surf csgYes Fully cemented production liner.22 CMT will cover all known productive horizonsYes PBU A-06A is an in-zone sidetrack from an existing wellbore.23 Casing designs adequate for C, T, B & permafrostYes CDR2 has adequate tankage and good trucking support24 Adequate tankage or reserve pitYes Sundry 323-11225 If a re-drill, has a 10-403 for abandonment been approvedYes No collision risks identified in the Halliburton anticollision report26 Adequate wellbore separation proposedNA PBU A-06A is an in-zone sidetrack from an existing wellbore.27 If diverter required, does it meet regulationsYes MPD will be utilized. Choke pressure applied to keep reservoir fluids in place while drilling.28 Drilling fluid program schematic & equip list adequateYes 1 CT packoff, 1 annular, 4 ram CT stack29 BOPEs, do they meet regulationYes 5M psi stack tested to 5000 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes Monitoring will be required33 Is presence of H2S gas probableNA PBU A-06A will a producer34 Mechanical condition of wells within AOR verified (For service well only)No A-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 7.24 ppg EMW (0.38 psi/ft). MPD will be utilized along with 8.4 ppg mud to36 Data presented on potential overpressure zonesNA maintain an ECD of 9.8 ppg EMW at the window to manage wellbore stability.37 Seismic analysis of shallow gas zonesNA Two faults will be crossed. Lost circulation: medium potential; discussed on p. 5.38 Seabed condition survey (if off-shore)NA LWD GR and resistivity with real-time bore pressure will be used.39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate2/21/2023ApprMGRDate2/22/2023ApprSFDDate2/21/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateGCW 02/23/23JLC 2/23/2023
