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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 2 3 2 - 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 0 9 - 0 9 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 2/ 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 5 7 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 12 3 7 0 TV D 89 9 5 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 No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 2/ 1 7 / 2 0 2 3 10 1 8 8 1 2 3 7 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U 0 9 - 0 9 A LW D . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 01 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 02 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 03 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 04 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 05 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 06 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 07 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 08 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 09 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 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 : 0 9 - 0 9 A P W D R u n 10 . l a s 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 2 M D F i n a l L o g . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 2 T V D S S F i n a l Lo g . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 5 M D F i n a l L o g . c g m 37 5 0 4 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 0 9 - 0 9 A LW D . l as DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 0 2 9 - 2 0 2 3 2 - 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 0 9 - 0 9 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 2/ 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 5 7 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 12 3 7 0 TV D 89 9 5 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 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 5 T V D S S F i n a l Lo g . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 1 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 2 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 3 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 4 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 5 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 6 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 7 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 8 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 9 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 1 0 . c g m 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 2 M D F i n a l L o g . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 2 T V D S S F i n a l Lo g . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 5 M D F i n a l L o g . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 5 T V D S S F i n a l Lo g . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 1 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 2 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 3 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 4 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 5 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 6 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 7 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 8 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 9 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 1 0 . P D F 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 2 M D F i n a l L o g . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 2 T V D S S F i n a l L o g . t i f 37 5 0 4 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 2 3 2 - 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 0 9 - 0 9 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 2/ 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 5 7 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 12 3 7 0 TV D 89 9 5 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 DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 5 M D F i n a l L o g . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A 5 T V D S S F i n a l L o g . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 1 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 2 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 3 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 4 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 5 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 6 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 7 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 8 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 0 9 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : P B U 0 9 - 0 9 A P W D R u n 1 0 . t i f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : 0 9 - 0 9 A D e f i n i t i v e S u r v e y s . p d f 37 5 0 4 ED Di g i t a l D a t a DF 2/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : 0 9 - 0 9 A D e f i n i t i v e S u r v e y s . x l s x 37 5 0 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 12 3 4 7 9 7 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ 0 9 - 09 A _ C O I L F L A G _ 1 9 F E B 2 3 . l a s 37 5 4 2 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 12 3 4 7 9 7 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ 0 9 - 09 A _ R B T _ 1 9 F E B 2 3 _ M a i n P a s s . l a s 37 5 4 2 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ 0 9 - 0 9 A _ C O I L F L A G - RB T _ 1 9 F E B 2 3 . p d f 37 5 4 2 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ 0 9 - 0 9 A _ C O I L F L A G - RB T _ 1 9 F E B 2 3 . t i f 37 5 4 2 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ 0 9 - 09 A _ R B T _ 1 9 F E B 2 3 _ M a i n P a s s . d l i s 37 5 4 2 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 2 3 2 - 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 0 9 - 0 9 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 2/ 1 9 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 5 7 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 12 3 7 0 TV D 89 9 5 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 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 : 2 / 1 9 / 2 0 2 3 Re l e a s e D a t e : 1/ 1 3 / 2 0 2 3 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 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 09-09A Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 222-157 50-029-20232-01-00 12370 Conductor Surface Production Scab Liner Liner 8995 77 2696 10851 610 9914 12150 20" 13-3/8" 9-5/8" 7" 2-3/8"" 8880 30 - 107 31 - 2726 29 - 10384 10081 - 10384 9914 - 12370 30 - 107 31 - 2726 29 - 8787 8513 - 8787 8387 - 8995 Unknown 520 2670 4760 5410 11780 12150 1530 5380 6870 7240 11200 11687 - 12265 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 13CR x 13Cr80 27 - 10161 8869 - 8925 Structural 4-1/2" Baker Model D , 10039 , 8491 No SSSV 10039 8491 Bo York Operations Manager Tyson Shriver Tyson.Shriver@hilcorp.com (907) 564-4545 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 028327 27 - 8595 433 1671 426 1430 5435 5231 1552 1555 328 355 323-151 13b. Pools active after work:PRUDHOE OIL 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 Kayla Junke at 9:09 am, Apr 25, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.04.21 08:41:30 -08'00' DSR-4/26/23WCB 12-29-2023 RBDMS JSB 050223 ACTIVITYDATE SUMMARY 3/28/2023 T/I/O= 250/1225/400 Well on line upon arrival Pre Coil Freeze Protect Pumped 5 bbls 60/40 pill down FL before Bleeding IA to FL Pumped 1 bbl 60/40 down TBG Followed by 93 bbls crude Pumped 5 bbls 60/40 followed by 60 bbls crude down FL Tags Hung DSO notified of well status upon departure FWHP=300/825/400 3/28/2023 LRS CTU 2 1.5" Blue Coil, Job Scope: Set CIBP and Extended Adperf Travel from LRS shop and MIRU. Complete weekly BOP test, 250/4000. Make up NS and LRS 1.75" drift BHA. ***Job Continued on 3/29/2023*** 3/29/2023 LRS CTU 2 1.5" Blue Coil, Job Scope: Set CIBP and Extended Adperf MU & RIH w/ Northern MHA w/ Sealed Knuckle Joint, 3ea Stingers & 1.75" JSN. Load well w/ 1% Slick KCL w/ Safelube. Tagged GLM #1. Unable to get past dry or pumping. Pooh. Add a 4th Stinger & RIH w/ same BHA. Dry Tag Dep Slv at 9037' ctm. Unable to get thru pumping down the Coil or backside. RIH w/ 1.75" drift BHA w/ bowspring centralizer. Pass thru Dep Slv with no issues. Lightly Tag PBTD at 12353'. Flag pipe 50' from weight back. Pooh. MU & RIH 2ea 1.50" Stingers & HES GR/CCL w/ Bowspring Centralizer BHA. RIH to green TD flag at 12296 CTMD and log up to 9700', painting a yellow tie-in flag at 12,099'. POOH pumping pipe displacement. ***Coninued on WSR 3-30-23*** 3/30/2023 LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 3-29-23** Job Objective: Post CTD Set CIBP and AddPerf Make up new CTC due to leaks, trim 20.5' of coil. Make up CIBP setting BHA with bowspring centralizer and RIH. Re-load well with slick seawater with safelube to confirm free of gas. Correct depth at Flag. Set Top of CIBP at 12150'. Pooh pumping pipe displacement. Park above Liner and PT CIBP to 525psi for 5 mins - Good Test (Well now a closed sytem). Continue Pooh keeping the hole full. At surface, Perform Passing 10 min No Flow Test. Circulate 60/40 Meth across the top from the trip tank. Recover 3/8" steel ball. Install swivel below MHA & PT. Sky high the T-Bar/Lubricator. Perform Drill w/ Crew. Verify make up of safety joint to perf gun. Deploy HES 1.56" Perf Guns w/ Blanks & HES Bowspring on bottom. Make up Swivel to Firing Head & stab on the well. PT the QTS. RIH w/ HES 1.56" x 413' of Perf Guns w/ Blanks per program. Take pipe disp returns while Rih. Verify depths at Flag. Tag CIBP & Correct to bottom shot depth. Puh & Perforate Intervals: 11687' - 11713', 11755' - 11855', 11867' - 12100'. Pooh. Lost returns after guns fired, then well eventually tightened back up. Pooh keeping the well full. Confirm well killed and retrieve spent perf guns, all shots fired. Well has 20 bbls 60/40 methanol cap, Pad op to POP immediately. RDMO CTU. ***Job Complete*** Daily Report of Well Operations PBU 09-09A MU & RIH 2ea 1.50" Stingers & HESg GR/CCL w/ Bowspring Centralizer BHA. RIH to green TD flag at 12296 CTMD andgg log up to 9700', painting a yellow tie-in flag at 12,099'. POOH Lightly Tag PBTD atgy gg 12353'. Flag pipe 50' from weight back. Poohgg LRS CTU 2 1.5" Blue Coil, Job Scope: Set CIBP and Extended Adperfr Set Top of CIBP at 12150'. g Park above Liner and PT CIBP to 525psi for 5 mins -g Good Test (Well now a closed sytem). y Perform Drill w/ Crew. Verify make up of safety joint to perfyyj gun. Deploy HES 1.56" Perf Guns w/ Blanks & HES Bowspring on bottom. Make upgy g Swivel to Firing Head & stab on the well. PT the QTS. RIH w/ HES 1.56" x 413' ofg Perf Guns w/ Blanks per program. Take pipe disp returns while Rih. Verify depths atgy Flag. Tag CIBP & Correct to bottom shot depth. Puh & Perforate Intervals: 11687' -gg 11713', 11755' - 11855', 11867' - 12100'. Pooh 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 09-09A Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 222-157 50-029-20232-01-00 ADL 028327 12370 Conductor Surface Production Scab Liner Liner 8995 77 2696 10851 610 9914 12364 20" 13-3/8" 9-5/8" 7" 2-3/8"" 8990 30 - 107 31 - 2726 29 - 10384 10081 - 10384 9914 - 12370 2460 30 - 107 31 - 2726 29 - 8787 8513 - 8787 8387 - 8995 Unknown 520 2670 4760 5410 11780 none 1530 5380 6870 7240 11200 12186 - 12265 7" 26# x 5-1/2" 17# x 4-1/2" 13CR x 13Cr80 27 - 10161 Structural 4-1/2" Baker Model D No SSSV 10039 / 8491 Date: David Bjork Sr. Operations Engineer Tyson Shriver Tyson.Shriver@hilcorp.com PRUDHOE BAY 3/17/2023 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 11:27 am, Mar 13, 2023 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888), ou=Users Reason: I am approving this document. Date: 2023.03.13 10:17:05 -08'00' David Bjork (3888) 323-151 DSR-3/14/23SFD 3/13/2023MGR15MAR23 10-404 RBDMS JSB 032123 Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Well Name:09-09A API Number:50-029-20232-01-00 Current Status:Shut in Rig:Coil Estimated Start Date:Feb 2023 Estimated Duration:3 days Regulatory Contact:Carrie Janowski Revision 0 First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Eric Dickerman (907) 564-4061 (O)(307) 250-4013 (M) Current Bottom Hole Pressure:3,295 psi @ 8,800’ TVD 7.3 PPGE | Taken 12/30/2022 Maximum Expected BHP:3,350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP Max. Anticipated Surface Pressure:2,470psi Based on 0.1 psi/ft. gas gradient Last SI WHP: 300psi Taken on 12/30/2022 Min ID:1.995” ID ID of 2-3/8” liner Max Angle:101 Deg @ 11,411’md taken from well plan Tie In Log:LWD from drilling 09-09A sidetrack Brief Well Summary: 09-09A is a horizontal Zone 2 producer from the Ivishak formation. The well logged just over 1,000’ of pay and was drilled with a toe down. Perforations were shot in the toe of the well 2/19/2023 to test production from two small sand packages (21P & 2A). The production came on strong at 433 bopd, 5,435 bwpd (93% w.c.) and no formation gas. Oil rate decreased quickly to ~125 bopd and 5,600 bwpd (98% w.c.). With the quick fall-off of oil rate it is time to move up hole and target the main pay of the 24P sand. This intervention will aim to shut-off the original perforations and shoot extended add perfs in the 24P. Objectives: The objective of this procedure is to shoot extended perforations post sidetrack. Procedure: Coiled Tubing Notes: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. At WSS discretion, MU and RIH with drift nozzle to TD. 3. MU and RIH with GR/CCL and drift nozzle and log from TD to ~9,750’. 4. Flag pipe as appropriate per WSS for CIBP and addperf runs. 5. MU and RIH with CIBP. Set plug at ~12,150’ MD. 6. Well should be a closed system. Ensure well is dead before POOH, and circulate a kill with 8.4ppg 1% KCl as necessary. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to estimated PBTD of 12,364’ = 286 bbls Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 b. 7” tubing – 3,005’ X 0.0383bpf = 115 bbls c. 5-1/2” Tubing – (9,900 – 3,005’) X 0.0232bpf = 160 bbls d. 4-1/2” Tubing – (9,914’ – 9,900’) X 0.0152bpf = 1 bbl e. 2-3/8” Liner – (12,364’ – 9,914’) X 0.0039bpf = 10 bbl 7. POOH pumping pipe displacement and freeze protect tubing as needed. 8. Confirm good log data. 9. At surface, prepare for deployment of TCP guns. 10. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 11.Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. f.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 12.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *Planned for 1.56” Halliburton Perfecta charges, max swell 1.74”, 3.62#/ft loaded weight. Perf Interval Perf Length Gun Length Weight of Gun (lbs) Comments Run 1 11,687’ 11,713’ Blank 11,755’ – 11,855’ Blank 11,867’ – 12,100’ 359’ 359’ guns 42’ blank 12’ blank 1,495 lbs (3.62ppf) BHAs will be limited to 500’ for any individual run. Run 2 N/A Total 359’ 413’ 13. MU lubricator at QTS. 14. RIH with perf gun and tie-in to coil flag correlation. Pick up and perforate interval per Perf Schedule above. g. Note any tubing pressure change in WSR. 15. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 16. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 17. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 18. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 19. Repeat steps 8 through 16 for subsequent runs to complete the desired perforated footage. 20. RDMO CTU. 21. RTP or FP well. Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Sundry Change Form Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Current Wellbore Schematic Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Proposed Wellbore Schematic Plug set @ ~12150' Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Equipment Layout Diagram Well: 09-09A PTD: 222-157 API: 50-029-20232-01-00 Sundry Change Form 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 Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/08/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230308 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 09-09A 50029202320100 222157 2/19/2023 HALLIBURTON COILFLAG-RBT PBU 09-43A 50029220780100 222156 3/4/2023 HALLIBURTON RBT PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON IPROF PBU 11-40 50029235530000 215122 2/20/2023 READ MULTIPLEARRAYPRODUCTION PROFILE Please include current contact information if different from above. PBU 09-09A 50029202320100 222157 2/19/2023 HALLIBURTON COILFLAG-RBT 1000 sx Class G, 300 sx AS, 250 sx Class GMN-80 / S-00 -95 / RS-95 RECEIVED BY James Brooks on 3/6/2023 at 3:08 PM Completed 2/19/2023 JSB RBDMS JSB 030923 GMGR02AUG2023DSR-3/14/23 3.6.2023 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: 2023.03.06 14:38:21 -09'00' Monty M Myers Activity Date Ops Summary 1/23/2023 Continue moving rig to Drill Site 9. Rig on location. Wait on final gravel pad lift. Install rig mat dance floor. PJSM with Cruz. Back trucks under. Spot sub module over well. Spot pit module. Set down and accept rig at 23:00. R/U Cellar. Connect PUTZ. Spot return tanks. LTT tree valves. Master valve leaking. Call grease crew. Continue MIRU checklist. LTT tree valves. Pass. N/U BOP stack. 1/24/2023 Continue NU BOPE. NU MPD Line and Choke Trailer line to 3-1/2" modified spool. Well support rigging up TT return line and choke trailer (for drilling liner annulus bleed off). Valve Crew on location to RU and set a 2-Way Check in 7". WO Well Support to finish return line RU and PT. Return line & choke trailer RU and PT'd to 4250psi. Stab Valve Crew Lubricator on stack and PT 250 low and 3500 high. Good PT bleed off to 700psi and open M & S Valves. Set 2-way check and PT to 250psi low and 3500psi high. Good PT, bleed off and blow down stack to the TT, pressure not bleeding off, line inside the rig is froze up, bleed off lubricator to bleed trailer. Ice plug at the valve just outside the rig, steamed line and line is thawed. Blow down line and remove VC lubricator. Remove hyd and LD Lubricator in PS. Tools LD, MU a nozzle on the coil, stab on and fluid pack coil and surface lines. During fluid pack of coil tubing, pressure exceeded 4800 psi and then fell off suddenly. Rig injector back and test eline. Eline failed MEG test. Cut coil and eline to find competent eline. Test eline every 100'. Discover bird nested eline in coil. Continue cutting coil and eline. Verify collector and pressure bulkhead eline test is good. Continue cutting coil and eline. Testing every 100' for wireline integrity. Cut total of 2000' of coil and eline. Discuss options moving forward. Continue cutting coil and testing eline until final length of 13,000'. Simultaneously prep to blow down and swap reels. 1/25/2023 Continue cutting coil testing eline every 100'. We have cut 2423', we are at the minimum length we would need to drill this well and the next on and eline is still not testing. Prep to blow down and swap reels. MU a CTC for nozzle to blow down. HES N2 on location, spot unit, RU and cool down to blow down reel. Pressure bulkhead was removed last night, PT Reel iron to 3500psi. N2 cooled down ready to PT, hold PJSM to blow down reel. Pad Op notified for venting N2 on the pad. PT N2 line to 35500psi and pump 5 bbls of neat meth into the coil. N2 line PT'd, online with N2 at 1500sqft/min for 15 min. N2 at the WH, shut down N2 and bleed off. Remove reel iron and pressure bulkhead. MU grapple and coil and prep to unstab coil. Unstab coil and secure at reel. Continue prep reel for offload. Lower reel onto truck and secure for transport. Take old reel to Nabors 1ES yard and offload. Load up new reel and bring to rig. Spot reel truck at rig, open reel doors and hook up slings. Lift new reel into stand, close reel doors. Torque up saddle clamps. Remove stripper, install new brass. Remove shipping wrap from reel. 1/26/2023 Continue with reel swap. Stab coil into injector. Ream coil for CTC. MU CTC and pull test. Good pull test to 40k. Remove Snow and Ice from inner reel to MU the reel iron. Head up BHI UQC. MU the pressure bulkhead. Secure reel iron and move injector cart. Remove drilling riser install night cap. Line up valves to fill stack. Fluid pack BOP stack and surface lines. Shell test BOP stack 250 / 3500 psi against TWC, bleeding off slightly. Bleed off pressure get small amount of gas back, TWC not holding. Close tree valves. Will test BOPs against closed tree valves then change out TWC. Circ and fluid pack lines. Grease valves. Get stack measurements. Test BOPs as per Hilcorp and AOGCC Regulations. All tests to 250 / 3500 psi. Test witness waived by AOGCC inspector Adam Earl. Test 1: C7, C9, C10, C11 - Pass. Test 2: Blind/Shears, R2, BL2, C15 - Pass. Install test joint. Test 3: Annular (2"), TIW1, B1, B4 - Pass. Test 4: Upper 2" Pipe/Slips, TIW2, B2, B3. Grease valves T1, T2, both swabs and inside gate valve on 3-1/2" tubing spool. Test 5: Lower 2" Pipe/Slip, C5, C6, C8, TV2 - F/P on Lower 2" Pipe/Slip cycle rams then pass. Test 6: Choke A, Choke C - Pass. Test 7: VBR (2-3/8"), C1, C4, TV1 - F/P on TV1, grease then pass. Test 8: VBR (3-1/2"), C2, C3 - Pass. Rig down BOP test equipment purge w/ air. Install nozzle for filling reel forward. Change CT packoffs. 1/27/2023 Fluid pack pump line with methanol taking fresh water returns to the TT. Reel Temp - Inner 65, Outer = 85. Line up to pump 10 bbls of methanol into reel followed by Hot Fresh Water to fluid pack the coil. Coil fluid packed. Test Gas Alarms. Test #10 - Pack off, Inner Reel Valve - Pass. Pump 1 circulation forward at max rate to pump slack forward. Rate = 2.4 bpm at 4900psi. Shut down pump and PU injector, install test plate and PT Reel Iron to the CTC to 6700psi. Good PT, bleed off, move injector back. Pull TWC and set a new one. New TWC set and is leaking, checked all possible flow paths and no leaks. TWC profile might be damaged. Discuss with DE. 2nd TWC not holding, perform rolling test on T1 & T2 Valves and passed. Pull TWC and pump methanol through TWC Profile. Reset TWC to test Swab 1 & Swab 2. Swab 1 passed, bleed off and test swab 2. Good test, PU VC Lubricator and swap tools to retrieve the TWC. Pull TWC. Offload TWC pulling equipment. Flush stack out to tiger tank. Swap out risers, install QTS. Install floats in UQC. PT connection and floats, good. Install weight bars for testing PDLs. Test PDLs, good. M/U XO on dart and TIW back to BOP test hose fitting. Test one of the dart valve and TIW for the velocity string, good. Rig down test equipment, prep to BH kill well. M/U nozzle and stinger. BH kill well . 10 bbls MeOH. 420 bbls 1% KCl. Open to tiger tank, check loss rate 4.75 bpm In / 1.35 bpm Out. 30 bbls Polyswell. 20 bbls Fresh water. 225 bbls 1% KCl. 1/28/2023 BH Kill completed, in rate = 4.75 bpm, out rate = 1.35 bpm, loss rate = 204 bph. Increase LCM PolySwell Pill from 10.5 ppb to 20 ppb. Mix 25 bbls at 20 ppb PolySwell Pill (hesitate 10min) then Bullhead - 27 bbls PolySwell, 10 bbls KCl, 22 bbls Freshwater at 3.5 bpm, swap to 1% KCl and increase rate to 7+ bpm. Frac info = 12.8 ppg eq, Max WHP = 2013psi. 289 bbls away PolySwell at the perfs WHP = 760 psi at 7.3 bpm. 300 bbls away WHP = 1560psi. 304 bbls away WHP = 1624psi reduce rate to 5.5 bpm. 316 bbls away WHP = 1430psi all PolySwell away. 326 bbls away WHP = 1061psi Freshwater at the perfs reduce rate to 1 bpm. 330 bbls away WHP = 0psi increase rate to 1.5 bpm to maintain a little WHP. 338 bbls away WHP = 33psi at 1.5 bpm. 348 bbls away WHP = 28psi at 1.5 bpm, line up to take returns back to the pits circulating across the top. Allow PolySwell to soak for 1-hr. Rate across the top = 2.17 bpm, out rate = 0.85 bpm, loss rate 1.32 bpm or 79 bph. Static loss rate is still the same at ~84 bph. Close the choke and see what the WHP builds up to. 2.5 bpm = 365psi WHP. 5.5 bpm = 935 psi WHP. 6.5 bpm = 1030 psi WHP. Prep to pump another 20 ppb pill. Fire Drill with Jones Crew. PolySwell Pill #2 - Mix 25 bbls at 20 ppb PolySwell Pill (hesitate 10min) then Bullhead - 29 bbls PolySwell, 10 bbls KCl, 20 bbls Freshwater at 3.5 bpm, swap to 1% KCl and increase rate to 5.0 bpm, WHP = 770psi. Frac info = 12.8 ppg eq, Max WHP = 2013psi. Very minimal PolySwell came back to surface be. 285 bbls away PolySwell at the perfs WHP = 1300 psi at 4.5 bpm. 300 bbls away WHP = 1389psi at 3.5 bpm. 303 bbls away WHP = 1709psi reduce rate to 1.6 bpm. 318 bbls away. WHP = 1229psi all PolySwell away. 328 bbls away WHP = 866psi Freshwater at the perfs reduce rate to 1 bpm. 331 bbls away WHP = 345psi at 1.0 bpm. First pill at this point we were at 28 psi WHP at 1.5 bpm. Reduce rate to 0.75 bpm, WHP = 217 psi. 0.75 bpm at 261psi WHP and slowly climbing. Loss rate is between 20-24 bph. Prep to PU WS and RIH to set. PU the NSAK WS & BHI MWD. RIH with WS BHA. 9877 WT CK = 42k, RIH WT = 27k. 10200' log gamma tie in. Logged down to 10,319' and Geo is not seeing anything that the PDC Log has for tie in. PUH and CCL Log to see if we can see the Nipple and WLEG in the TBG Tail. Shift CCL +80' correction. PU log GR again from 10240' correct -2'. Up wt 43k. PU log CCL again from 10100' match jewelry within 2' of PDC. RIH to set depth. Bit depth 10390.75' places top WS at 10382.0' at 0L TF. Get up wt back to 40k. Close EDC, pressure up setting tool shears out at 2171 psi Diff. Slackoff 4.1k DWOB hold for 1 min, solid. Good set. Top WS at 10382.0 at 0L TF. Open EDC POOH pump 1.8 bpm. Tag stripper, assess loss rate 24 bbl/hr with injector on. L/D BHA #1, setting tool has functioned normally. Keep well full through MP line. Remove QTS and CT riser sections. Continue strapping and drifting 3-1/2" liner for velocity string. Remove flange to riser on top of annular and install spool. 1/29/2023 7-1/16 riser MU. Continue loading, strapping and drifting 3-1/2 tubing. Inspect and grease top drive. Review tally and jt count. Rig up choke on hole fill line for continuous hole fill. M/U 3-1/2" velocity string. Maintain continuous hole fill 28 - 30 bbl/hr. D1 drill w/ McGrath crew while M/U velocity string. 50-029-20232-01-00API #: Well Name: Field: County/State: PBE 09-09A Prudhoe Bay East Hilcorp Energy Company Composite Report , Alaska 1/31/2023Spud Date: 1/30/2023 Continue running 3-1/2" Velocity string, on jt 172 of 314. All 235 jts of 3-1/2" ST-L ran, MU thread X-O to 3-1/2" VamTop and run 79 jts. 270 jts ran, hold KWT Drill (Jones crew). Well secured in 3:10, no deficiencies to report. Continue running TBG. MU Hanger and landing joint, land hanger, 5' stick in 21.9'. PU WT = 100k, Hanging WT = 93k, SO WT = 72k. Hanger landed on depth, RILDS. Close Swab 1 & 2. Line up on MPD Line for hole fill. Swap out 7-1/16 Riser for 7-1/16 Otis Flange & Drilling Riser. Risers swapped, prep to fluid pack and PT Swabs 1 & 2 then swap rams. Both swabs leaking, call out grease crew to service tree valves. Service both valves, swab 1 failed. Re-grease, swab 1 pass. Swab 2 pass. Vac out stack past BOPs. De-energize koomey, remove 2-3/8" x 3-1/2" VBR install 2-3/8" Pipe/Slip rams. Test 2-3/8" Pipe/Slip rams 250 / 3500 psi, good. Test witness is waived by AOGCC Inspector Brian Bixby. Remove test riser install QTS. PT riser break, good. M/U BHA #2 window mill and reamer. Mill and reamer 2.80" NoGo 2.81" Go. M/U injector. RIH BHA #2, window mill and reamer. Tie-in depth from 10200', correct -10'. Up wt at 10340 is 43k. Close EDC. Light tag (1.7k DWOB) dry at 10385'. Pick up bring pump to 1.8 bpm. Ease down to engage casing. Mill window from 10384.5'. 1.77 / 1.21 bpm In/Out. 2350 - 2400 psi Circ. MW 8.39 / 8.39 ppg. Window ECD = 8.88 ppg. 1/31/2023 Continue milling window at 10386.4. Rate In 1.77 bpm, Out Rate = 1.18 bpm, Loss Rate = ~35 bph. Density In = 8.38 ppg, Out Density = 8.39 ppg. Window ECD = 8.91 ppg. Continue milling window at 10386.4. Rate In 1.77 bpm, Out Rate = 1.21 bpm, Loss Rate = ~34 bph. Density In = 8.38 ppg, Out Density = 8.39 ppg. Window ECD = 8.94 ppg. Continue milling window at 10388.0. Rate In 1.74 bpm, Out Rate = 1.23 bpm, Loss Rate = ~31 bph. Density In = 8.39 ppg, Out Density = 8.39 ppg. Window ECD = 8.98 ppg. 10388.1 slow progress with 3.38k WOB, PU 2' to check WOB then ease back down. WOB is correct, the mill is at the mid-point of the 9-5/8" and the string mill is dressing the bottom of the window. COM problem w/ BHI connection in Putz. Troubleshoot and restart computers. DWOB went to 0 on restart, pick up and get parameters again. Continue milling window at 10388.9. Rate In 1.74 bpm, Out Rate = 1.22 bpm. Density In = 8.39 ppg, Out Density = 8.39 ppg. Window ECD = 8.96 ppg. Stall at 10389.7' likely casing exit depth. Keep milling 1 ft/hr to let reamer work. Rate In 1.74 bpm, Out Rate = 1.28 bpm. Density In = 8.39 ppg, Out Density = 8.39 ppg. Window ECD = 9.00 ppg. Drill rathole to 10400'. Pump 10 bbls mud sweep. 1st reaming pass up 0L see 70 psi Motor Work 10388'. 1st pass down 0L 30 psi MW 10386.6'. 2nd up 0L 50 psi MW 10384'. 2nd down 0L 30 psi MW 10386'. Continue reaming window. 3rd up 0L 45 psi MW 10384'. 3rd down 0L 40 psi MW 10386'. 4th up 0L 35-40 psi MW 10384'. 4th down 0L 30 psi MW 10386'. 5th up 0L 35-40 psi MW. Continue reaming window. 5th down 0L 25-30 psi MW 10386'. 6th up 0L 30-35 psi MW 10383'. 6th down 0L 25-30 psi MW 10386'. 7th up 15L 30-35 psi MW 10384'. 2/1/2023 Continue reaming window. 7th down 0L 25 psi MW 10386'. 8th up 15R 30-35 psi MW 10384'. Dry drift is clean tag 10400'. Pick up and open EDC, swap well to mud. Losses 40 - 50 bbl/hr on mud, POOH. Tag stripper, 10 min flow check is good, no flow. Lift injector off and slide back. Stand injector back. Lay down BHA#2 Window milling assembly. Both reamer and mill 2.81" Go / 2.80" NoGo. Make up nozzle assembly to jet the stack. Jet stack. Circ out 1%KCL out of 7" x 3-1/2" Annulus. Line up down kill line, Taking returns from 7" x 3-1/2" Annulus to tiger tank. ICP: 330 psi / FCP 580 psi. MW in: 8.81 ppg. Rate in: 3.0 bpm. Once Annulus volume returned. S/I and blow down lines, MT tiger tank. 10 min flow check. Fill well 20 bph loss rate. Make up BHA #3. RIH with 3.25 Build BHA #3. Rate: 1.02 bpm in, 1.20 bpm out. Circ pressure: 1953psi. Mud Weight: 8.82 ppg in, 8.82 ppg out. Log down for tie-in from 10200' to 10270.96' MD (HRZ) with -7 correction. Close EDC. Clean through window. Drill 3.25 build from 10400 MD to 10415 MD. Free spin: 3632 psi, 1.75 bpm. Rate: 1.75 bpm in, 0.56 bpm out. Circ pressure: 3632 - 3895 psi. Mud weight: 8.81 ppg in, 8.69 ppg out, ECD: 10.16 ppg. ROP: 30 fph, WOB: 1.6 -2.2 KLBS. 10440' ROP drops to 10-20 ft/hr. Rate: 1.75 bpm in, 0.34 bpm out. Circ pressure: 3600 - 3930 psi. Mud weight: 8.78 ppg in, 8.81 ppg out, Window ECD: 10.02 ppg. ROP: 10-20 fph, WOB: 1 - 3 KLBS. 10457' 5 bbls lo / hi vis, PU 45k here clean. Drill 3.25" build from 10497'. Pump 5 bbls lo/hi vis sweep. MW: 8.79 ppg in, 8.79 ppg out, Window ECD: 10.32 ppg. ROP: 10-50 fph, WOB: 1 - 3 KLBS. 1.75 / 0.81 bpm In / Out. Pull 100' wiper trip from 10550' clean pass up and down. Drill 3.25" build from 10550'. MW: 8.75 ppg in, 8.77 ppg out, Window ECD: 10.39 ppg. ROP: 5-50 fph, WOB: 1 - 2 KLBS. 1.75 / 0.97 bpm In / Out. TD Build at 10605'. 10590' 5 bbls lo/hi vis. 2/2/2023 Build landed at 10605' MD. Wiper to window clean, Perform jog below and above window. Open EDC. Jet 7" up to 3-1/2" TTL at 20 fpm. Pooh for lateral. Mud Weight: 8.74 ppg in, 8.81 ppg out. Rate: 2.07 bpm in, 1.51 bpm out. Perform 500' jog at 1000'. Tag up. Space out and Function test 2-3/8" Pipe/ Slip rams. 12 bph loss rate. Lay down BHA#3. Bit graded 2-2-RO-N-X-IN-CT-BHA. Perform weekly BOPE function test. Rih with 3.25" Lateral BHA#4. Mud Weight: 8.75 ppg in, 8.77 ppg out. Rate: 1.01 bpm in, 1.09 bpm out. Gradually begin increasing ECD to 10.5 ppg. Log down for tie-in from 10230' to 10293.40 MD (HRZ) with -9' correction. Close EDC. Log RA tag at 10387' (TOWS 10380'). Drill 3.25 lateral from 10605' MD to 10627' MD. Free spin: 4064 psi, 1.82 bpm (615 psi Diff). Rate: 1.82 bpm in, 1.19 bpm out. Circ pressure: 4064 - 4362 psi. Mud weight: 8.75 ppg in, 8.76 ppg out, Window ECD: 10.6 ppg. ROP: 40-60 fph, WOB: 0.5 1.5 KLBS. Drilling erratic. Stalling at min. Drilling became erratic. Relatively clean PU weight. Come off bottom. Min rate getting 6-800 psi diff. Appears motor is chunking out. Pull to window at min rate. Open EDC. Pooh. Mud Weight: 8.76 ppg in, 8.78 ppg out. Rate: 2.01 bpm in, 1.47 bpm out. Traces of rubber on shaker. Tag up. Finish bleeding well off. 10 min Flow check. PJSM. Fill hole. Lift injector and slide back. Pull BHA #4, bit OK run new motor. M/U BHA #5. RIH. Increase window ECD to 10.5# while RIH. Tie-in depth from 10230' correct -22'. Close EDC. Pass window 0L, 0 pump no issues. Pump min rate through build. Drill 3.25" lateral from 10627'. 1.75 bpm In / 1.32 bpm Out. 8.76 ppg In / 8.77 ppg Out. Window ECD 10.68 ppg on open choke. Circ 3900 - 4200 psi. Stall at 10714' and lose returns. Up wt 49k. ECD goes to 7.8 ppg. Close choke, Pull to window. Organize trucks and fluids for drilling w/ no returns. Jog above window and open EDC. Recip slowly in 4- 1/2" while waiting on mud pump 1.5 bpm. Adequate mud on location. RIH to tie in depth get hole fill pump on CT annulus adjusted to 40 - 50 bbl/hr. Correct +4'. Close EDC. Pass window no issues, clean pass to TD. Drill from 10718' 150 ft/hr. Wt ck at 10755' is 50k clean. Drill to 10800' ECD reading low about 7.9 ppg. Pull wiper trip uphole a ways to verify 3-1/2" tubing is clear of cuttings and full of clean mud. Pull through window and jog, open EDC. 2/3/2023 Complete wiper up to 3500' MD. Nothing observed. Start running in hole. Swap to pumping down 3-1/2" x 7" annulus with charge pump. Caught fluid around ~23 bbls ( 871'). Swap back to coil. Rih with closed choke. 1.9 bpm rate. Log tie in with +6' correction. Swap to annulus fill while closing EDC. Run to bottom at min rate. Filling in top at 0.5 bpm while running to TD. Establish drilling rate, Come off hole fill. Drill 3.25 lateral from 10800 MD to 11040' MD. Free spin: 3088 psi, 1.80 bpm (584 psi diff). Rate: 1.80 bpm in, S/I bpm out. Circ pressure: 3088 - 3130 psi. Mud weight: 8.67 ppg in, S/I ppg out, ECD: 8.23 ppg 100% losses. ROP: 150 fph, WOB: 0.4 - 1.5 KLBS. Multiple wipers up to thief zone. Drill 3.25 lateral from 11040' MD to 11256' MD. Free spin: 2997 psi, 1.80 bpm (584 psi diff). Rate: 1.80 bpm in, Closed choke bpm out. Circ pressure: 2997 - 3262 psi. Mud weight: 8.68 ppg in, S/I ppg out, ECD: 8.66 ppg 100% losses. ROP: 110-150 fph, WOB: 0.4 - 1.5 KLBS. Shoot surveys. Long wiper to window. Rate: 1.80 bpm in, S/I bpm out. Circ pressure: 3615 psi. Mud weight: 8.68 ppg in, S/I ppg out, Window ECD: 9.3 ppg 100% losses. Perform jog in the hole below window. Pull through without issue. Attempt to break circulation. 9.41 ppg ECD. No luck. Log tie in with +4' correction. PU to 9700' MD. CCL log from 9700' MD to 10200' MD. Drill 3.25 lateral from 11256' MD. Free spin: 2997 psi, 1.80 bpm (581 psi diff). Rate: 1.80 bpm in, Closed choke bpm out. Circ pressure: 2997 - 3766 psi. Mud weight: 8.7 ppg in, S/I ppg out, ECD: 9.96 ppg 100% losses. ROP: 140 - 150 fph, WOB: 1.2 - 1.5 KLBS. Wipers to loss zone every ~100'. Continue drilling to 11539' PU heavy, differentially stuck. Open choke, work pipe 5k to 80k pump 5 bbls hi-vis. Getting returns 1.8 / 0.8 bpm. Drop pump work pipe free. Wiper to 10700' above loss zone. 1.86 / 0.86 bpm while tripping. Get missed surveys on the way down. Drill 3.25 lateral from 11543' MD to 11600' MD. Rate 1.88 / 0.99 bpm Free spin 3630 psi Window ECD = 10.05 ppg. MW In 8.69 ppg / MW Out 8.73 ppg. ROP 80 - 150 ft/hr. High vibration erratic NBI around 11550'. 11590' 5 bbls hi-vis. Wiper to window from 11600' PU 47k. Jog below window and pull through clean 0.4 bpm. Pump 5 bbls hi- vis. Jog up to tubing tail and back down at full rate. Open EDC PU 10 ft/min pump 2.16 / 1.02 bpm. 3k drag at 10155'. Tie-in depth from 10230' finish B/U. Correct +12' close EDC. Pass window RIH to bottom. Drill 3.25" lateral from 11600' MD. Rate 1.88 / 0.94 bpm Free spin 3600 psi Window ECD = 9.96 ppg. MW In 8.72 ppg / MW Out 8.74 ppg. ROP 20 - 50 ft/hr. 11650 pump 5 bbls hi-vis. 150' wiper trip from 11740' clean up and down. Drill 3.25" lateral from 11740' MD. Rate 1.85 / 0.98 bpm Free spin 3650 psi Window ECD = 10.14 ppg. MW In 8.72 ppg / MW Out 8.78 ppg. ROP 100 - 150 ft/hr. 11840' 5 bbls hi - vis. window from 10384.5 2/4/2023 Drill 3.25" lateral from 11884' MD to 12050' MD. Rate 1.85 / 0.93 bpm Free spin 3623 psi Window ECD = 10.14 ppg. MW In 8.73 ppg / MW Out 8.79 ppg. ROP 100 - 150 ft/hr. Wiper to window without issue. Circulate bottoms up. Log tie in with +9' correction. Run to bottom without issue. Drill 3.25 lateral from 12056 MD to 12255' MD. Free spin: 3597 psi, 1.80 bpm. Rate: 1.80 bpm in, 1.39 bpm out. Circ pressure: 3597 3854 psi. Mud weight: 8.73 ppg in, 8.75 ppg out, ECD: 10.0 ppg. ROP: 85-150 fph, WOB: 1.5 - 3.3KLBS. Start turning down at 12,100' MD. Multiple pick ups to keep drilling at TD. Free spin: 3686 psi, 1.80 bpm. Rate: 1.84 bpm in, 1.33 bpm out. Circ pressure: 3686 - 4139 psi. Mud weight: 8.73 ppg in, 8.75 ppg out, ECD: 10.2 ppg. ROP: 30-40 fph, WOB: 1.5 - 3.3KLBS. Continue drilling from 12300' pump 5 bbls lo/hi vis. Stacking wt, frequent BHA length wiper trips to keep drilling. 57k PU at 12359' pull 100' wiper clean up/down. Drill to TD 12370'. Wiper trip to window. Pump 5 bbls lo/hi vis. Jog below 22N reduce pump rate through there 11510' - 11650'. Jog below window pull through clean. Jog above window open EDC. Jet tubing while tie-in depth. Pump sweeps to surface 2.2 / 1.8 bpm window ECD 10.31 ppg. Tie-in depth correct +9'. Sweeps bring back little additional cuttings. Close EDC. RIH 0.5 bpm. 1.5k DWOB bobble at 10560' otherwise clean. Tag 12370' official Drilled TD. Go to 1.8 bpm wiper trip to window. Pump 5 bbls lo / hi vis sweeps. Jog below 22N reduce pump rate through there 11510' - 11650'. Clean pass to window. Jog and pull through. Jog above window and open EDC. Jet whipstock tray and 7" at 10 ft/min pump another 5 bbls lo / hi vis. 2.6 / 2.1 bpm window ECD = 10.4 ppg. Pull wiper to swab. Tag stripper, reset depth. RIH. 2/5/2023 RIH with 3.25 drilling BHA # 5. Rate: 0.52 bpm in, 0.55 bpm out. Circ pressure: 1512 psi. Mud Weight: 8.72 ppg in, 8.74 ppg out. Log down for tie-in (HRZ) with -26 correction. Close EDC, Drift OH at min rate. No issues. Light tag at 12370' MD. Pump 20 bbls of 8.7 ppg Powerpro w/ 1.5 ppb Alpine beads. Tail with 9.8 ppg NaCl. KWF from 10615' MD. Pull through window. Open EDC. Finish circulating KWF to surface. Pooh. Paint yellow flag 9842.65' Bit depth (9770.43' CEOP). Paint white flag 7852.70' Bit depth (7780.48' CEOP). Perform 10 min flow check. Well on 30 bph losses. Inspect pipe for flat spot above connector (0.160" wall) Will cut out after liner run. Clean and clear rig floor. Prep floor for running liner. PJSM. Verify count with all parties involved. Pick up Joint#1, Build shoe track off bottom. ORCA, Float , 4' pup, Float , Bullnose. Make up 2-3/8" 4.7# Solid 13Cr liner. Filling every 15 joints. Continue M/U jt #31 on continuous hole fill. Fill every 15 jts. M/U BHI to GS spear to deployment sleeve. M/U injector. Continue hole fill. Circ a liner volume to push air out then RIH. Start mud down the CT. Stop at first flag correct -29.2'. Continue circ mud to shoe 0.5 bpm to prevent GS release. After mud at shoe unable to circulate 9.8# out, on losses. Line up to circ down MP line take returns from tubing. Circ out 9.8# 1.56 / 0.54 bpm, returns slowly increasing. Mud at surface, RIH. Wt ck at window is 44k. Pass window RIH with liner. Stack wt in 22N shale 11529' start working liner. Work down to 11590' pump LVT + spacers 5/20/5 bbls. LVT at shoe, start working liner again from 11590'. 2/6/2023 Work liner from 11590'. Stage LVT out as we run in hole. Continue working liner to bottom. Land liner on bottom 12370' MD. Circulate LVT and spacers out to tiger tank. Log CCL from 9700' to tag. +12' correction to pre liner CCL. Liner top at 9914' MD. Difficulty latching back up . Discuss with drilling engineer. Flow check. Pooh to inspect G-Spear. Pooh. Mud Weight: 8.75 ppg in, 8.75 ppg out. Rate: 1.53 bpm in, 1.08 bpm out. 10 min flow check. Well taking 8.5 bph loss rate. No obvious marks on the G-Spear. Seals gone. Source 1.75" JSN. Make up MWD with (2) -1" CSH joints, XO. Disco body, 1.75" JSN to drift liner top. Rih. Mud Weight: 8.75 ppg in, 8.75 ppg out. Rate: 0.64 bpm in, 0.82 bpm out. Stop at previous white window flag: Correct depth to 7884.01' (-38.56' correction). Flag pipe at 9654.53' bit depth (9551.1' EOP). Flow check well, good no flow. POOH displace CT to KCl on the way out. Flag pipe 7215.5' bit depth (7112' EOP). Tag stripper 10 min no-flow. Lift injector off slide back, L/D BHA #7. Install night cap and PT for circ out. Pump KCl down MP line recover mud from tubing. While circ out mud: Remove UQC and cut 19' of CT and cable. Dress CT and install new CT connector, pull test 50k. Install boot on cable. Inspect packoffs. Finished circ out surface to surface + 20 bbls have 8.45 ppg In / Out. 10 min no-flow, good. PT CT connector 4500 psi, good. PT packoffs and riser, good. Pump cable slack out, recover 189 ft. Rig up to pump 5/8" drift ball. 2/7/2023 Finish pumping 5/8 ball. Recover ball. Clear rig floor. Verify tally. PJSM. Make up 1" CSH XO, Disconnect (1/2" Ball) ORCA G spear,. Rih w/ 1" CSH workstring, Had to kick #5 out and add #83. Ran a total of 82 joints. Make up disconnect and 6 joints 2-1/16" CSH. Make up Northern Solutions lockable swivel. Stab injector. Rih. Rate: 0.65 bpm in, 0.93 bpm out. Circ pressure: 732 psi. Mud Weight: 8.44 ppg in, 8.43 ppg out. Correct to white flag with a -30.5' correction. PUW 37K, RIW 24K. Attempt to work into liner. Work pumps. Circulate at various rates. No joy. PU 100' MD. Tag top of patch at 9893' (9900'MD). Kill pump. Went by patch. Tag liner top. Attempt bullhead around liner. No luck. PU 1000', Rih and tag same spot. Pooh. Rate: 1.69 bpm in, 1.15 bpm out. Circ pressure: 2900 psi. Mud Weight: 8.44 ppg in, 8.43 ppg out. Tag stripper, 10 min no-flow. Lift injector and skid back. L/D 6 jts of 2-1/16" CSH and 82 jts 1" CSH on continuous hole fill about 10-12 bbl/hr. Clean and clear rig floor. Inspect NSAK cement stinger, some compression marks on the nose. Prep to run BHA #9. M/U BHA #9, cement stinger + 7 jts 2- 1/16" CSH. RIH BHA #9. Stop at flag from previous run correct -16'. Wt ck at 9850 is 40k. Get circ pressures before entering sleeve. 0.5 bpm = 260 psi. 1 bpm = 620 psi. RIH pump 0.5 bpm. Tag 9912' see +150 psi circ pressure. Go to 1 bpm = 920 psi appear to have entered sleeve. Stack 5k down Circ mud out from liner annulus 1.5 / 1.2 bpm. After 60 bbls out see 8.6# returns. Pump down kill line to check seals, appear to be leaking circ pressure is equalizing w/ WHP. Try pulling out of the seal bore and re-engage, same result. POOH to inspect seals. 2/8/2023 Continue out of hole. 10 min flow check. Well still taking 8 bph average. Lay down 7 joints of 2-1/16" CSH. Lay down seal stinger. Ring indicates we were fully stung in. Seal intact. Pressure test CTC, swivel to 3500 psi. Good test. All indications are floats not holding. Discuss plan with Drilling engineer. NS modifying nose of ORCA stinger to mimic a nozzle. Source 12' of stinger. Swap lockable swivel out for non lockable. PT to 3500#. Perform weekly BOPE function test on 2" and 2-3/8" test joint. PJSM. Make up NS ORCA stinger with modified bullnose, and 1.75" stingers. M/U 1" CSH work string. M/U 2 1/16" CSH tubing. M/U injector to cement string. RIH with NS ORCA cement BHA. In Rate 1.02 bpm, Out Rate 1.06 bpm. In MM = 8.30 ppg, Out MM = 8.41 ppg. IA = 933, OA = 271. Stop at flag and correct depth. WT CK and record circulating pressure at 1.5 bpm. 1.5 bpm = 3024 psi. WT CK 36k, RIW 26k. WT CK 40k above ORCA cementing valve. Establish pump rates. 0.5 bpm = 615 psi. 1.0 bpm = 1813 psi. 1.5 bpm = 3200 psi. Tag @ 12451.64' with 7k down. Investigate injector counter issues. Pump .5 bpm min rate to shear rupture disk. Rupture disk burst @ 2600 psi. Continue displacing liner and well to 1% KCL. In Rate 1.1 bpm, Out Rate = .81 bpm. In MM = 8.31 ppg, Out MM = 8.41 ppg. Continue circulating 1% KCL @ 1.05 bpm. -3544 psi circ pressure. Spot and R/U all fluid support trucks. R/U HES cementers. Pressure test HES cement line to 5k. Pass. Mix 30 bbls 15.3 ppg liner cement blend. Charge pump 1.5 ppg Geovis to cementers. Pump 21.9 bbls 15.3 ppg cement into reel. Cement @ weight at 04:17. Thickening time 7 hrs, 21 minutes. Pump 1.5 ppg Geovis to cementers. Line up to rig pump and displace cement with Geovis. 2/9/2023 Pump total of 21.9 bbls 15.3 ppg cement. -Unsting from ORCA with 48k PUW. Confirm no flow from well. POOH pumping .5 bpm Geovis. Estimated 13 bbls behind pipe. Estimated TOC = 10272' MD. Complete jetting liner up to just below liner top with exhaust pill. Saw minimal density increase from above ORCA valve. Good cement in shoe. No signs of liner top cement. Perform 10 min flow check. Well static. Finish jetting liner top, Patch, 5-1/2" tubing up to 3-1/2" WLEG with exhaust. Pooh. Mud Weight: 8.40 ppg in, 8.50 ppg out. Rate: 1.16 bpm in, 0.85 bpm out. 1% KCL from 9847' to surface. Chase exhaust pill out of hole. Circulate FW around work string. Tag up. PJSM. Perform 10 min flow check. Well static. Break out swivel, and skid injector back. Lay down 7 joint 2-1/16" CSH, Disconnect, X-over. Lay down 82 joints 1.0" CSH work string . Lay down stingers and disconnect. Recovered ORCA stinger. Make up stinger and 2.5" swizzle stick. Jet hanger and stack with remaining exhaust pill. Valve crew grease swabs. close valves. Perform LTT to 3500#. Remove injector and QTS. Install test risers. Prepare for ram swap. Remove 2-3/8" pipe/slip rams. Install 2-3/8" x 3-1/2" VBR's. Test to 250/3500psi per PTD and well program. Pass. Install flanged riser and air boot. Reverse circulate 380 bbls 1% KCL down back side of 3 1/2" work string. In Rate = 5.14 bpm, Out Rate 5.12 bpm. In MM = 8.29 ppg, Out MM = 8.41 ppg. IA = 987 psi, OA = 263 psi. PJSM with wellhead specialist and rig crew. Verify no flow and well stable. M/U 3 1/2" landing joint to hanger. Back out LDS and pull hanger to floor with 91k PUW. L/D 3-1/2" VamTop/STL work string. Filling hole every 10 joints Estimated 13 bbls behind pipe. Estimated TOC = 10272' 2/10/2023 PJSM, Incoming crew. 95 joints out of the hole. Continue pulling 3-1/2" 9.3# tubing. Continuous hole fill. Well only taking metal displacement. Recovered 3-1/2" velocity string and WLEG. Clean and clear rig floor of handling equipment. R/D LP riser. R/U HP riser. M/U 2.5" nozzle freeze protect BHA #11. PT riser and check valves to 3500 psi. Pass. RIH with freeze protect BHA #11. Pressure test LRS pump line to 4500 psi. Pass. Park coil at 2500' and being pumping freeze protect. Pump 100bls diesel followed by 5 bbls neat methanol. POOH from 2500' pumping diesel for coil displacement. Stop at 100' and cap well with neat methanol. Tag up and close tree valves. Grease crew service tree and spool valves. PT swab valve to 3500 psi. L/D freeze protect BHA. Reverse circulate into reel and cut 251' of coil to find eline. M/U injector and attempt to pump additional slack into reel. No further movement of eline. Total coil cut = 256', eline cut = 5'. Dress coil and M/U Nabors CTC. Pull test to 50k. M/U BHI UQC. Test connection. Pass. 2/11/2023 Pressure test UQC break. Remove MPD gate valve and 90 off MPD line. Remove line to choke trailer. Swap out 2-3/8" x 3-1/2" Variable ram for 2-3/8" Pipe / Slip. Leak test door seals to 3500#. Verify B7 valve clear. Remove MPD hose off manifold. Install new MPD hose to manifold. Nipple down BOPE. Continue with rig down checklists. N/U tree cap and flange. Fluid pack with neat methanol. PT to 3500 psi. Pass. Release rig at 19:00. ACTIVITYDATE SUMMARY 2/12/2023 T/I/O=SI/950/500. PT tree against CIW 6" J TWC #424 300 psi low and 5000 psi high (PASSED). Pulled TWC. ***JOB COMPLETE***.FinalWHP's=0/950/500. RDMO. 2/14/2023 ***WELL S/I ON ARRIVAL*** SET 5-1/2" WHIDDON CATCHER @9,908' SLM (9,900' MD) PULLED ST# 3 RK-DMY FROM 3017' MD PULLED ST# 2 RK-DMY FROM 5339' MD PULLED ST# 1 RK-DMY FROM 7311' MD RAN IN AND ATTEMPTED TO SET LGLV IN STA#1 @ 7311' MD, BUT UNABLE TO LOCATE OR SET DOWN. POOH AND VALVE (DROPPED VLV) ***WSR CONT ON 2-15-23*** 2/14/2023 Pressure Test Liner Lap (PERFORATING) Pumped 3 bbls -20* DSL into Tbg and Tbg lost49 psi in 10 mins. Bled Tbg to 0 psi and got back 3 bbls. SV,WV,SSV=C MV=O IA,OA=OTG 2/15/2023 ***WSR CONT FROM 2-14-23*** RAN KJ, 5-1/2" BLB, DOUBLE KJ, 2-1/2" JD (gutted) RADDLE GLM's DOWN TO WSC @ 9904' SLM (no valve) RAN KJ, 4.30" CENT. 5' x 1-1/2" STEM, 2-1/2" JD (gutted) S/D INSIDE WCS @ 9,906' SLM (no valve) RAN KJ, 5-1/2" OM-1, 3" EXT, 1.75" LIB TO ST#1, LOC & S/D @ 3,002' SLM ( impression of vlv) RAN KJ, 5-1/2" OM-1, RK1 TO ST#1, LOC & S/D @ 3,002' SLM ( tattletale pins sheared, arm broke over) SET STA #1 RK-LGLV (16/64" ports, tro 1661 psi) @ 3,017' MD SET STA #2 RK-LGLV (16/64" ports, tro 1688 psi) @5,339' MD SET STA #3 RK-OGLV (28/64" ports ) @7,311' MD PULL CATCHER FROM 9,902' SLM ***WELL S/I ON DEPARTURE*** 2/17/2023 T/I/O = CTU/950/500. Temp = SI. IA FL (CTU req). Coil unit on well. IA FL @ 900' (2117' above sta #1, Dome). SV, WV, SSV, MV = O. IA, OA = OTG. 00:00. 2/17/2023 LRS CTU #2 1.5" Blue Coil. Job Scope: Perf MIRU & PT. RIH w/ 2.75" DJN and tag LNR top at 9922' CTM / 9911' MD. RIH w/ 1.75" JSN and unable to get into the LNR top. POOH to check tools. ***Job in progress*** 2/18/2023 LRS CTU #2 1.5" Blue Coil. Job Scope: CBL, Perforate Continue POOH to check tools. Add a 4' stinger and knuckle, and RBIH. Able to work through the deployment sleeve, but started sitting down around ~ 10055'. POOH and MU 1-11/16" BOT milling BHA with venturi & 1.85" burnshoe. RIH, mill at ~ 10055', and then able to dry drift to TD at 12372' CTM. POOH and MU HES RBT/GR/CCL logging tools. ***Job in Progress*** 2/19/2023 LRS CTU #2 1.5" Blue Coil. Job Scope: CBL, Perforate Log HES RBT/GR/CCL from 12349' - 9750' at 50 FPM. Paint a ***red*** flag at 12219.93' E / 12175' M / 12218.60' HES. POOH & confirm good data (-2' correction). MU 1.56" x 20' HES gun (11' loaded, 6 SPF, 60 deg phase), RIH & unable to pass the deployment sleeve at 9914' MD. POOH & add a bowpspring & knuckle. RIH and perforate 12254' - 12265'. MU 1.56" x 20' HES gun (6 SPF, 60 deg phase), RIH & perforate 12186' - 12206'. POOH & freeze protect the well to 2500' TVD with DSL. Start rigging down. ***Job Complete*** Daily Report of Well Operations PBU 09-09A WELL NAME Date : Shoe @ :FC @ :Top Liner @ : Type: Type : Type : Type : Type : Yes No Yes X No Yes X No X Yes No X Yes No Date : Volume lost during displacement (bbls) : 8.40 Remarks:ORCA Valve (Cement Retainer) @ 12,364' - Closed Cement In Place At :06:17 2/9/2023 Estimated TOC :10272' Method Used To Determine TOC :Calculated Casing Rotated?Reciprocated?% Returns during job :59% Cement returns to surface?Spacer returns?Vol to Sur : FCP (psi) :Pump used for disp : GD Plug Bumped?Bump press : Volume :160 Displacement : 1.5 ppb Geovis Density (ppg) :8.4 Rate (bpm) :1 Volume (actual / calculated) : Post Flush (Spacer) 1.5 ppb Geovis Density (ppg) :8.4 Rate (bpm) :1 Yield : Sacks : Mixing / Pumping Rate (bpm) : Tail Slurry Volume (bbls) :Density (ppg) : Lead Slurry Class G Volume (bbls):21.9 Density (ppg) : FI R S T S T A G E 12370 12364' & 12368'9914 Preflush (Spacer) 1% KCL w/ safelube Density (ppg) :8.4 Volume pumped (bbls) : DS09-09A CEMENT REPORT 9-Feb-23 Hole Size :3.25 Casing Size :2.375" 15.3 Yield : 1.24 Sacks : 100 Mixing / Pumping Rate (bpm) : 1 10272' 59% 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 ] 34 . 0 0 10 3 4 9 . 0 0 01 / 2 2 / 2 3 10 3 4 9 . 0 0 12 3 7 0 . 0 0 02 / 0 3 / 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 1 9 3 . 9 3 0 . 0 0 - 5 4 . 0 0 0 . 0 0 0 . 0 0 7 1 8 3 7 0 . 9 5 5 9 4 3 1 6 5 . 5 7 7 0 ° 1 4 ' 5 0 . 3 0 0 1 " N 1 4 8 ° 1 4 ' 8 . 7 2 0 2 " 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 34 . 0 0 0 . 0 0 1 9 3 . 9 3 3 4 . 0 0 - 2 0 . 0 0 0 . 0 0 0 . 0 0 7 1 8 3 7 0 . 9 5 5 9 4 3 1 6 5 . 5 7 7 0 ° 1 4 ' 5 0 . 3 0 0 1 " N 1 4 8 ° 1 4 ' 8 . 7 2 0 2 " 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 . 2 7 1 9 3 . 9 3 1 0 0 . 0 0 4 6 . 0 0 - 0 . 1 5 - 0 . 0 4 7 1 8 3 7 0 . 9 2 5 9 4 3 1 6 5 . 4 2 7 0 ° 1 4 ' 5 0 . 2 9 8 6 " N 1 4 8 ° 1 4 ' 8 . 7 2 1 3 " W 0 . 4 1 - 1 6 7 . 7 4 8 0 . 4 1 0 . 0 0 - 0 . 1 4 4 0 . 0 0 4 0 . 0 0 6 . 4 3 2 8 3. 9 3 20 0 . 0 0 0 . 0 9 1 6 6 . 6 4 2 0 0 . 0 0 1 4 6 . 0 0 - 0 . 4 6 - 0 . 0 8 7 1 8 3 7 0 . 8 9 5 9 4 3 1 6 5 . 1 1 7 0 ° 1 4 ' 5 0 . 2 9 5 6 " N 1 4 8 ° 1 4 ' 8 . 7 2 2 4 " W 0 . 1 9 3 4 . 1 4 8 - 0 . 1 8 - 2 7 . 2 9 - 0 . 4 1 4 0 . 0 0 4 0 . 0 0 6 . 4 3 94 . 6 6 30 0 . 0 0 0 . 3 7 1 9 2 . 9 4 3 0 0 . 0 0 2 4 6 . 0 0 - 0 . 8 5 - 0 . 1 3 7 1 8 3 7 0 . 8 4 5 9 4 3 1 6 4 . 7 2 7 0 ° 1 4 ' 5 0 . 2 9 1 8 " N 1 4 8 ° 1 4 ' 8 . 7 2 4 0 " W 0 . 2 9 - 1 6 2 . 8 4 2 0 . 2 8 2 6 . 3 0 - 0 . 7 6 4 0 . 0 0 4 0 . 0 0 6 . 4 3 27 2 . 4 7 40 0 . 0 0 0 . 2 5 1 8 4 . 2 1 4 0 0 . 0 0 3 4 6 . 0 0 - 1 . 3 8 - 0 . 2 2 7 1 8 3 7 0 . 7 7 5 9 4 3 1 6 4 . 1 8 7 0 ° 1 4 ' 5 0 . 2 8 6 5 " N 1 4 8 ° 1 4 ' 8 . 7 2 6 6 " W 0 . 1 3 - 4 7 . 5 1 3 - 0 . 1 2 - 8 . 7 3 - 1 . 2 4 4 0 . 0 0 4 0 . 0 0 6 . 4 4 94 . 3 0 50 0 . 0 0 0 . 2 9 1 7 6 . 1 7 5 0 0 . 0 0 4 4 6 . 0 0 - 1 . 8 5 - 0 . 2 2 7 1 8 3 7 0 . 7 9 5 9 4 3 1 6 3 . 7 1 7 0 ° 1 4 ' 5 0 . 2 8 1 9 " N 1 4 8 ° 1 4 ' 8 . 7 2 6 5 " W 0 . 0 6 1 6 7 . 8 1 0 . 0 4 - 8 . 0 4 - 1 . 6 1 4 0 . 0 0 4 0 . 0 0 6 . 4 5 9 3 .3 8 60 0 . 0 0 0 . 1 0 2 0 1 . 7 4 6 0 0 . 0 0 5 4 6 . 0 0 - 2 . 1 8 - 0 . 2 3 7 1 8 3 7 0 . 7 8 5 9 4 3 1 6 3 . 3 8 7 0 ° 1 4 ' 5 0 . 2 7 8 6 " N 1 4 8 ° 1 4 ' 8 . 7 2 7 0 " W 0 . 2 0 - 1 5 0 . 0 0 7 - 0 . 1 9 2 5 . 5 7 - 1 . 8 9 4 0 . 0 0 4 0 . 0 0 6 . 4 62 7 4 . 4 0 70 0 . 0 0 0 . 0 5 1 4 2 . 9 4 7 0 0 . 0 0 6 4 6 . 0 0 - 2 . 3 0 - 0 . 2 4 7 1 8 3 7 0 . 7 8 5 9 4 3 1 6 3 . 2 6 7 0 ° 1 4 ' 5 0 . 2 7 7 5 " N 1 4 8 ° 1 4 ' 8 . 7 2 7 2 " W 0 . 0 9 - 7 5 . 1 5 1 - 0 . 0 5 - 5 8 . 8 0 - 1 . 9 9 4 0 . 0 1 4 0 . 0 0 6 . 4 79 2 . 7 6 80 0 . 0 0 0 . 1 0 9 6 . 6 9 7 9 9 . 9 9 7 4 5 . 9 9 - 2 . 3 4 - 0 . 1 3 7 1 8 3 7 0 . 8 9 5 9 4 3 1 6 3 . 2 2 7 0 ° 1 4 ' 5 0 . 2 7 7 1 " N 1 4 8 ° 1 4 ' 8 . 7 2 3 9 " W 0 . 0 7 - 1 9 . 8 7 2 0 . 0 5 - 4 6 . 2 5 - 1 . 9 6 4 0 . 0 1 4 0 . 0 1 6 . 4 9 8 5. 7 2 90 0 . 0 0 0 . 3 3 8 2 . 7 3 8 9 9 . 9 9 8 4 5 . 9 9 - 2 . 3 2 0 . 2 5 7 1 8 3 7 1 . 2 6 5 9 4 3 1 6 3 . 2 6 7 0 ° 1 4 ' 5 0 . 2 7 7 3 " N 1 4 8 ° 1 4 ' 8 . 7 1 3 0 " W 0 . 2 3 1 9 . 9 5 8 0 . 2 3 - 1 3 . 9 6 - 1 . 7 1 4 0 . 0 1 4 0 . 0 1 6 . 5 0 7 7 . 41 10 0 0 . 0 0 0 . 9 7 9 6 . 0 2 9 9 9 . 9 9 9 4 5 . 9 9 - 2 . 3 7 1 . 3 7 7 1 8 3 7 2 . 3 9 5 9 4 3 1 6 3 . 2 4 7 0 ° 1 4 ' 5 0 . 2 7 6 8 " N 1 4 8 ° 1 4 ' 8 . 6 8 0 3 " W 0 . 6 5 1 5 9 . 1 8 8 0 . 6 4 1 3 . 2 9 - 1 . 0 8 4 0 . 0 1 4 0 . 0 1 6 . 5 2 6 9 .5 2 11 0 0 . 0 0 0 . 5 5 1 1 4 . 0 1 1 0 9 9 . 9 8 1 0 4 5 . 9 8 - 2 . 6 5 2 . 6 5 7 1 8 3 7 3 . 6 8 5 9 4 3 1 6 2 . 9 9 7 0 ° 1 4 ' 5 0 . 2 7 4 0 " N 1 4 8 ° 1 4 ' 8 . 6 4 3 0 " W 0 . 4 8 1 1 9 . 8 3 2 - 0 . 4 2 1 7 . 9 9 - 0 . 5 4 4 0 . 0 1 4 0 . 0 1 6 . 54 6 3 . 7 5 12 0 0 . 0 0 0 . 4 8 1 3 7 . 5 6 1 1 9 9 . 9 7 1 1 4 5 . 9 7 - 3 . 1 6 3 . 3 8 7 1 8 3 7 4 . 4 1 5 9 4 3 1 6 2 . 5 1 7 0 ° 1 4 ' 5 0 . 2 6 9 0 " N 1 4 8 ° 1 4 ' 8 . 6 2 2 1 " W 0 . 2 2 1 4 7 . 6 4 9 - 0 . 0 7 2 3 . 5 5 - 0 . 5 2 4 0 . 0 2 4 0 . 0 1 6 . 57 6 0 . 7 9 13 0 0 . 0 0 0 . 3 5 1 5 2 . 4 2 1 2 9 9 . 9 7 1 2 4 5 . 9 7 - 3 . 7 4 3 . 8 0 7 1 8 3 7 4 . 8 5 5 9 4 3 1 6 1 . 9 4 7 0 ° 1 4 ' 5 0 . 2 6 3 3 " N 1 4 8 ° 1 4 ' 8 . 6 0 9 7 " W 0 . 1 7 - 1 4 0 . 5 9 3 - 0 . 1 3 1 4 . 8 6 - 0 . 7 3 4 0 . 0 2 4 0 . 0 1 6 .5 9 2 4 0 . 1 9 14 0 0 . 0 0 0 . 2 8 1 3 9 . 3 1 1 3 9 9 . 9 7 1 3 4 5 . 9 7 - 4 . 1 9 4 . 1 0 7 1 8 3 7 5 . 1 7 5 9 4 3 1 6 1 . 5 0 7 0 ° 1 4 ' 5 0 . 2 5 8 9 " N 1 4 8 ° 1 4 ' 8 . 6 0 1 0 " W 0 . 1 0 1 3 5 . 1 9 8 - 0 . 0 7 - 1 3 . 1 1 - 0 . 9 2 4 0 . 0 2 4 0 . 0 2 6 .6 2 5 9 . 7 7 15 0 0 . 0 0 0 . 3 1 2 3 4 . 9 8 1 4 9 9 . 9 7 1 4 4 5 . 9 7 - 4 . 5 3 4 . 0 4 7 1 8 3 7 5 . 1 2 5 9 4 3 1 6 1 . 1 5 7 0 ° 1 4 ' 5 0 . 2 5 5 5 " N 1 4 8 ° 1 4 ' 8 . 6 0 2 8 " W 0 . 4 4 1 3 3 . 9 3 8 0 . 0 3 9 5 . 6 7 - 1 . 2 3 4 0 . 0 2 4 0 . 0 2 6 . 6 52 4 1 . 8 5 16 0 0 . 0 0 0 . 2 5 2 5 2 . 1 6 1 5 9 9 . 9 7 1 5 4 5 . 9 7 - 4 . 7 6 3 . 6 1 7 1 8 3 7 4 . 6 9 5 9 4 3 1 6 0 . 9 2 7 0 ° 1 4 ' 5 0 . 2 5 3 3 " N 1 4 8 ° 1 4 ' 8 . 6 1 5 3 " W 0 . 1 0 - 1 3 7 . 7 1 9 - 0 . 0 6 1 7 . 1 8 - 1 . 6 6 4 0 . 0 3 4 0 . 0 2 6 .6 8 2 4 6 . 9 2 17 0 0 . 0 0 0 . 1 7 1 9 6 . 0 8 1 6 9 9 . 9 7 1 6 4 5 . 9 7 - 4 . 9 7 3 . 3 6 7 1 8 3 7 4 . 4 5 5 9 4 3 1 6 0 . 7 0 7 0 ° 1 4 ' 5 0 . 2 5 1 3 " N 1 4 8 ° 1 4 ' 8 . 6 2 2 5 " W 0 . 2 1 - 4 9 . 2 7 - 0 . 0 8 - 5 6 . 0 8 - 1 . 9 8 4 0 . 0 3 4 0 . 0 3 6 . 72 2 5 0 . 9 7 18 0 0 . 0 0 0 . 2 0 1 8 6 . 9 1 1 7 9 9 . 9 7 1 7 4 5 . 9 7 - 5 . 2 8 3 . 3 0 7 1 8 3 7 4 . 4 0 5 9 4 3 1 6 0 . 3 8 7 0 ° 1 4 ' 5 0 . 2 4 8 2 " N 1 4 8 ° 1 4 ' 8 . 6 2 4 3 " W 0 . 0 4 2 9 . 2 5 3 0 . 0 3 - 9 . 1 7 - 2 . 2 7 4 0 . 0 3 4 0 . 0 3 6 . 7 5 25 3 . 3 2 19 0 0 . 0 0 0 . 3 2 1 9 8 . 3 8 1 8 9 9 . 9 7 1 8 4 5 . 9 7 - 5 . 7 2 3 . 1 9 7 1 8 3 7 4 . 3 0 5 9 4 3 1 5 9 . 9 4 7 0 ° 1 4 ' 5 0 . 2 4 3 8 " N 1 4 8 ° 1 4 ' 8 . 6 2 7 5 " W 0 . 1 3 1 6 5 . 3 6 4 0 . 1 2 1 1 . 4 7 - 2 . 6 9 4 0 . 0 4 4 0 . 0 3 6 . 7 92 5 5 . 4 2 20 0 0 . 0 0 0 . 2 1 2 0 6 . 3 9 1 9 9 9 . 9 7 1 9 4 5 . 9 7 - 6 . 1 5 3 . 0 2 7 1 8 3 7 4 . 1 4 5 9 4 3 1 5 9 . 5 1 7 0 ° 1 4 ' 5 0 . 2 3 9 6 " N 1 4 8 ° 1 4 ' 8 . 6 3 2 4 " W 0 . 1 2 - 1 6 8 . 3 2 5 - 0 . 1 1 8 . 0 1 - 3 . 1 3 4 0 . 0 4 4 0 . 0 4 6 . 83 2 5 7 . 8 6 21 0 0 . 0 0 0 . 1 7 5 2 . 5 4 2 0 9 9 . 9 6 2 0 4 5 . 9 6 - 6 . 2 2 3 . 0 6 7 1 8 3 7 4 . 1 8 5 9 4 3 1 5 9 . 4 4 7 0 ° 1 4 ' 5 0 . 2 3 8 9 " N 1 4 8 ° 1 4 ' 8 . 6 3 1 4 " W 0 . 3 7 2 . 3 1 8 - 0 . 0 4 - 1 5 3 . 8 5 - 3 . 1 7 4 0 . 0 5 4 0 . 0 4 6 . 8 7 7 7 . 3 1 22 0 0 . 0 0 0 . 9 9 5 4 . 4 6 2 1 9 9 . 9 6 2 1 4 5 . 9 6 - 5 . 6 3 3 . 8 8 7 1 8 3 7 4 . 9 9 5 9 4 3 1 6 0 . 0 5 7 0 ° 1 4 ' 5 0 . 2 4 4 7 " N 1 4 8 ° 1 4 ' 8 . 6 0 7 5 " W 0 . 8 2 1 3 . 4 6 1 0 . 8 2 1 . 9 2 - 2 . 2 0 4 0 . 0 5 4 0 . 0 4 6 . 9 2 7 3 .5 7 23 0 0 . 0 0 1 . 6 0 5 9 . 6 4 2 2 9 9 . 9 3 2 2 4 5 . 9 3 - 4 . 4 2 5 . 7 8 7 1 8 3 7 6 . 8 6 5 9 4 3 1 6 1 . 3 2 7 0 ° 1 4 ' 5 0 . 2 5 6 6 " N 1 4 8 ° 1 4 ' 8 . 5 5 2 0 " W 0 . 6 2 1 7 0 . 5 5 6 0 . 6 1 5 . 1 8 - 0 . 1 0 4 0 . 0 5 4 0 . 0 5 6 . 9 7 6 9. 5 2 24 0 0 . 0 0 1 . 2 5 6 2 . 3 2 2 3 9 9 . 9 0 2 3 4 5 . 9 0 - 3 . 2 1 7 . 9 5 7 1 8 3 7 8 . 9 9 5 9 4 3 1 6 2 . 5 9 7 0 ° 1 4 ' 5 0 . 2 6 8 5 " N 1 4 8 ° 1 4 ' 8 . 4 8 8 9 " W 0 . 3 6 1 5 4 . 0 1 6 - 0 . 3 5 2 . 6 8 2 . 1 7 4 0 . 0 6 4 0 . 0 5 7 . 0 2 6 5. 2 5 25 0 0 . 0 0 0 . 8 6 7 5 . 8 9 2 4 9 9 . 8 8 2 4 4 5 . 8 8 - 2 . 5 2 9 . 6 5 7 1 8 3 8 0 . 6 7 5 9 4 3 1 6 3 . 3 3 7 0 ° 1 4 ' 5 0 . 2 7 5 3 " N 1 4 8 ° 1 4 ' 8 . 4 3 9 7 " W 0 . 4 6 - 1 7 3 . 9 0 4 - 0 . 3 9 1 3 . 5 7 3 . 7 4 4 0 . 0 6 4 0 . 0 6 7 . 0 76 1 . 1 1 26 0 0 . 0 0 0 . 6 9 7 4 . 3 8 2 5 9 9 . 8 8 2 5 4 5 . 8 8 - 2 . 1 8 1 0 . 9 6 7 1 8 3 8 1 . 9 6 5 9 4 3 1 6 3 . 7 1 7 0 ° 1 4 ' 5 0 . 2 7 8 7 " N 1 4 8 ° 1 4 ' 8 . 4 0 1 6 " W 0 . 1 7 5 0 . 8 2 9 - 0 . 1 7 - 1 . 5 1 4 . 7 9 4 0 . 0 7 4 0 . 0 6 7 . 1 3 57 . 2 1 27 0 0 . 0 0 0 . 8 2 8 4 . 4 9 2 6 9 9 . 8 7 2 6 4 5 . 8 7 - 1 . 9 5 1 2 . 2 5 7 1 8 3 8 3 . 2 5 5 9 4 3 1 6 3 . 9 8 7 0 ° 1 4 ' 5 0 . 2 8 1 0 " N 1 4 8 ° 1 4 ' 8 . 3 6 4 1 " W 0 . 1 9 - 1 3 . 5 8 1 0 . 1 3 1 0 . 1 1 5 . 7 5 4 0 . 0 7 4 0 . 0 7 7 . 1 9 53 . 5 9 27 2 6 . 0 0 1 . 1 3 8 0 . 7 2 2 7 2 5 . 8 6 2 6 7 1 . 8 6 - 1 . 8 9 1 2 . 6 9 7 1 8 3 8 3 . 6 8 5 9 4 3 1 6 4 . 0 5 7 0 ° 1 4 ' 5 0 . 2 8 1 6 " N 1 4 8 ° 1 4 ' 8 . 3 5 1 3 " W 1 . 2 2 - 9 . 7 4 7 1 . 1 9 - 1 4 . 5 0 6 . 0 6 4 0 . 0 8 4 0 . 0 7 7 . 2 0 52 . 6 8 28 0 0 . 0 0 2 . 0 3 7 6 . 3 8 2 7 9 9 . 8 3 2 7 4 5 . 8 3 - 1 . 4 6 1 4 . 6 8 7 1 8 3 8 5 . 6 6 5 9 4 3 1 6 4 . 5 4 7 0 ° 1 4 ' 5 0 . 2 8 5 7 " N 1 4 8 ° 1 4 ' 8 . 2 9 3 3 " W 1 . 2 3 - 3 0 . 8 9 1 1 . 2 2 - 5 . 8 6 7 . 5 9 4 0 . 0 8 4 0 . 0 7 7 . 2 5 50 . 1 0 29 0 0 . 0 0 5 . 3 9 5 6 . 6 2 2 8 9 9 . 6 1 2 8 4 5 . 6 1 1 . 5 4 2 0 . 3 2 7 1 8 3 9 1 . 2 2 5 9 4 3 1 6 7 . 7 0 7 0 ° 1 4 ' 5 0 . 3 1 5 3 " N 1 4 8 ° 1 4 ' 8 . 1 2 9 2 " W 3 . 5 5 - 1 5 . 5 6 2 3 . 3 6 - 1 9 . 7 6 1 3 . 3 7 4 0 . 0 9 4 0 . 0 8 7 . 3 14 6 . 7 0 30 0 0 . 0 0 9 . 3 4 4 9 . 9 4 2 9 9 8 . 7 7 2 9 4 4 . 7 7 9 . 3 5 3 0 . 4 6 7 1 8 4 0 1 . 1 3 5 9 4 3 1 7 5 . 8 0 7 0 ° 1 4 ' 5 0 . 3 9 2 1 " N 1 4 8 ° 1 4 ' 7 . 8 3 4 4 " W 4 . 0 4 4 5 . 2 4 3 . 9 5 - 6 . 6 8 2 5 . 6 9 4 0 . 0 9 4 0 . 0 8 7 . 3 7 4 4 .0 6 30 2 5 . 0 0 1 1 . 2 5 5 9 . 1 2 3 0 2 3 . 3 7 2 9 6 9 . 3 7 1 1 . 9 1 3 4 . 1 1 7 1 8 4 0 4 . 7 0 5 9 4 3 1 7 8 . 4 6 7 0 ° 1 4 ' 5 0 . 4 1 7 2 " N 1 4 8 ° 1 4 ' 7 . 7 2 8 4 " W 1 0 . 0 5 9 9 . 0 3 5 7 . 6 4 3 6 . 7 2 2 9 . 9 2 4 0 . 0 9 4 0 . 0 9 7 . 38 4 1 . 4 7 30 5 0 . 0 0 1 1 . 2 3 5 9 . 7 9 3 0 4 7 . 8 9 2 9 9 3 . 8 9 1 4 . 3 9 3 8 . 3 0 7 1 8 4 0 8 . 8 2 5 9 4 3 1 8 1 . 0 6 7 0 ° 1 4 ' 5 0 . 4 4 1 6 " N 1 4 8 ° 1 4 ' 7 . 6 0 6 4 " W 0 . 5 3 4 0 . 0 0 1 - 0 . 0 8 2 . 6 8 3 4 . 4 1 4 0 . 1 0 4 0 . 0 9 7 . 4 03 8 . 9 4 30 7 5 . 0 0 1 1 . 6 9 6 1 . 6 7 3 0 7 2 . 3 9 3 0 1 8 . 3 9 1 6 . 8 1 4 2 . 6 4 7 1 8 4 1 3 . 0 8 5 9 4 3 1 8 3 . 6 1 7 0 ° 1 4 ' 5 0 . 4 6 5 5 " N 1 4 8 ° 1 4 ' 7 . 4 8 0 4 " W 2 . 3 7 3 7 . 6 7 1 1 . 8 4 7 . 5 2 3 8 . 9 4 4 0 . 1 0 4 0 . 0 9 7 . 4 1 38 . 2 2 31 0 0 . 0 0 1 2 . 1 3 6 3 . 2 7 3 0 9 6 . 8 5 3 0 4 2 . 8 5 1 9 . 2 0 4 7 . 2 1 7 1 8 4 1 7 . 5 8 5 9 4 3 1 8 6 . 1 2 7 0 ° 1 4 ' 5 0 . 4 8 8 9 " N 1 4 8 ° 1 4 ' 7 . 3 4 7 3 " W 2 . 2 0 2 1 . 8 6 1 . 7 6 6 . 4 0 4 3 . 5 9 4 0 . 1 0 4 0 . 0 9 7 . 4 3 3 7. 6 0 31 2 5 . 0 0 1 2 . 5 2 6 3 . 9 9 3 1 2 1 . 2 8 3 0 6 7 . 2 8 2 1 . 5 7 5 1 . 9 9 7 1 8 4 2 2 . 2 9 5 9 4 3 1 8 8 . 6 3 7 0 ° 1 4 ' 5 0 . 5 1 2 2 " N 1 4 8 ° 1 4 ' 7 . 2 0 8 3 " W 1 . 6 8 1 1 . 6 6 1 . 5 6 2 . 8 8 4 8 . 3 4 4 0 . 1 0 4 0 . 0 9 7 . 4 5 3 7. 5 7 31 5 0 . 0 0 1 3 . 0 0 6 4 . 4 3 3 1 4 5 . 6 6 3 0 9 1 . 6 6 2 3 . 9 7 5 6 . 9 7 7 1 8 4 2 7 . 1 9 5 9 4 3 1 9 1 . 1 8 7 0 ° 1 4 ' 5 0 . 5 3 5 8 " N 1 4 8 ° 1 4 ' 7 . 0 6 3 7 " W 1 . 9 6 1 7 . 8 3 6 1 . 9 2 1 . 7 6 5 3 . 2 4 4 0 . 1 0 4 0 . 0 9 7 . 4 6 38 . 0 5 31 7 5 . 0 0 1 3 . 5 7 6 5 . 2 1 3 1 6 9 . 9 9 3 1 1 5 . 9 9 2 6 . 4 1 6 2 . 1 7 7 1 8 4 3 2 . 3 2 5 9 4 3 1 9 3 . 7 7 7 0 ° 1 4 ' 5 0 . 5 5 9 9 " N 1 4 8 ° 1 4 ' 6 . 9 1 2 5 " W 2 . 3 9 2 9 . 6 1 7 2 . 2 8 3 . 1 2 5 8 . 3 0 4 0 . 1 1 4 0 . 1 0 7 . 4 8 38 . 8 1 32 0 0 . 0 0 1 3 . 8 1 6 5 . 7 8 3 1 9 4 . 2 8 3 1 4 0 . 2 8 2 8 . 8 7 6 7 . 5 5 7 1 8 4 3 7 . 6 3 5 9 4 3 1 9 6 . 3 8 7 0 ° 1 4 ' 5 0 . 5 8 4 0 " N 1 4 8 ° 1 4 ' 6 . 7 5 6 0 " W 1 . 1 0 3 1 . 3 7 4 0 . 9 6 2 . 2 8 6 3 . 4 8 4 0 . 1 1 4 0 . 1 0 7 . 5 0 40 . 0 3 32 2 5 . 0 0 1 4 . 5 5 6 7 . 5 6 3 2 1 8 . 5 2 3 1 6 4 . 5 2 3 1 . 2 9 7 3 . 1 7 7 1 8 4 4 3 . 1 8 5 9 4 3 1 9 8 . 9 6 7 0 ° 1 4 ' 5 0 . 6 0 7 8 " N 1 4 8 ° 1 4 ' 6 . 5 9 2 5 " W 3 . 4 4 3 0 . 6 4 7 2 . 9 6 7 . 1 2 6 8 . 7 9 4 0 . 1 1 4 0 . 1 0 7 . 5 1 41 . 3 5 32 5 0 . 0 0 1 4 . 7 7 6 8 . 0 7 3 2 4 2 . 7 0 3 1 8 8 . 7 0 3 3 . 6 8 7 9 . 0 3 7 1 8 4 4 8 . 9 7 5 9 4 3 2 0 1 . 5 2 7 0 ° 1 4 ' 5 0 . 6 3 1 3 " N 1 4 8 ° 1 4 ' 6 . 4 2 2 1 " W 1 . 0 2 4 5 . 9 4 7 0 . 8 8 2 . 0 4 7 4 . 2 0 4 0 . 1 2 4 0 . 1 0 7 . 5 3 42 . 9 4 32 7 5 . 0 0 1 5 . 0 1 6 9 . 0 2 3 2 6 6 . 8 6 3 2 1 2 . 8 6 3 6 . 0 3 8 5 . 0 1 7 1 8 4 5 4 . 8 8 5 9 4 3 2 0 4 . 0 4 7 0 ° 1 4 ' 5 0 . 6 5 4 4 " N 1 4 8 ° 1 4 ' 6 . 2 4 8 2 " W 1 . 3 7 4 6 . 1 3 9 0 . 9 6 3 . 8 0 7 9 . 6 5 4 0 . 1 2 4 0 . 1 0 7 . 5 5 44 . 9 1 33 0 0 . 0 0 1 5 . 2 6 7 0 . 0 0 3 2 9 1 . 0 0 3 2 3 7 . 0 0 3 8 . 3 1 9 1 . 1 2 7 1 8 4 6 0 . 9 2 5 9 4 3 2 0 6 . 5 0 7 0 ° 1 4 ' 5 0 . 6 7 6 9 " N 1 4 8 ° 1 4 ' 6 . 0 7 0 4 " W 1 . 4 3 3 5 . 0 2 5 1 . 0 0 3 . 9 2 8 5 . 1 4 4 0 . 1 2 4 0 . 1 1 7 . 5 6 46 . 8 3 33 2 5 . 0 0 1 5 . 4 7 7 0 . 5 5 3 3 1 5 . 1 0 3 2 6 1 . 1 0 4 0 . 5 5 9 7 . 3 6 7 1 8 4 6 7 . 0 9 5 9 4 3 2 0 8 . 9 2 7 0 ° 1 4 ' 5 0 . 6 9 8 9 " N 1 4 8 ° 1 4 ' 5 . 8 8 9 1 " W 1 . 0 2 4 8 . 7 5 8 0 . 8 4 2 . 2 0 9 0 . 6 5 4 0 . 1 3 4 0 . 1 1 7 . 5 8 48 . 7 5 33 5 0 . 0 0 1 5 . 9 1 7 2 . 3 5 3 3 3 9 . 1 7 3 2 8 5 . 1 7 4 2 . 7 0 1 0 3 . 7 7 7 1 8 4 7 3 . 4 3 5 9 4 3 2 1 1 . 2 5 7 0 ° 1 4 ' 5 0 . 7 2 0 0 " N 1 4 8 ° 1 4 ' 5 . 7 0 2 7 " W 2 . 6 2 2 2 . 1 9 6 1 . 7 6 7 . 2 0 9 6 . 2 0 4 0 . 1 3 4 0 . 1 1 7 . 6 05 0 . 5 0 33 7 5 . 0 0 16 . 3 1 72 . 9 3 33 6 3 . 1 9 33 0 9 . 1 9 44 . 7 6 11 0 . 3 9 71 8 4 7 9 . 9 9 59 4 3 2 1 3 . 5 1 70 ° 1 4 ' 5 0 . 7 4 0 4 " N 14 8 ° 1 4 ' 5 . 5 1 0 2 " W 1. 7 2 17 . 8 0 4 1. 6 0 2. 3 2 10 1 . 8 2 40 . 1 4 40 . 1 1 7. 6 2 52 . 1 8 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 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 DS 0 9 09 - 0 9 09 - 0 9 A 09 - 0 9 A 09 - 0 9 A 02 / 0 3 / 2 0 2 3 09 - 0 9 _ G y r o d a t a 0 - 1 0 3 4 9 ; C B F i l m 1 0 4 2 6 - 1 0 8 0 0 ) a t 1 0 3 4 9 . 0 0 M D Ul r i c a r d Mi n i m u m c u r v a t u r e 54 . 0 0 f t E 0 . 0 0 f t N 0 . 0 0 f t Ma g n e t i c N o r t h i s 1 5 . 7 9 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 WA _ A N C _ D e f n 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 09 - 0 9 ( 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 02 / 0 7 / 2 3 a t 0 7 : 2 7 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 5 4 1. 6 6 E a s t Sl o t 09 - 0 9 ( R T ) 09 - 0 9 ( R T ) Me a n S e a L e v e l 36 . 6 6 ° in c l u d e d 50 - 0 2 9 - 2 0 2 3 2 - 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 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 ] 22 2 1 . 6 6 [f t ] 12 1 6 . 6 3 Gr i d E a s t [U S f t ] 71 8 3 7 0 . 9 5 71 7 2 1 8 . 9 0 65 1 9 5 8 . 0 0 [U S f t ] 59 4 3 1 6 5 . 5 7 59 4 0 9 0 9 . 8 8 59 7 4 8 1 2 . 0 0 La t i t u d e 70 ° 1 4 ' 5 0 . 3 0 0 1 " N 70 ° 1 4 ' 2 8 . 4 5 1 1 " N 70 ° 2 0 ' 1 7 . 5 5 2 2 " N 14 8 ° 1 4 ' 8 . 7 2 0 2 " W 14 8 ° 1 4 ' 4 4 . 0 9 7 7 " W 14 8 ° 4 6 ' 1 . 0 0 0 6 " W Ho r i z U n c e r t 1 s d [f t ] 0. 0 0 20 . 0 0 Gy r o d a t a 2 0 1 5 - C T + W I R + D P I P E 0 9 - 0 9 ( G y r o d a t a 0 - 1 0 3 4 9 ) 0 9 - 0 9 BH C o i l T r a k ( 2 0 1 9 ) ( S t a n d a r d ) 0 9 - 0 9 A < C o i l T r a k 1 0 3 4 9 - 1 2 3 7 0 > 0 9 - 0 9 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 5 34 0 0 . 0 0 1 6 . 8 9 7 3 . 5 7 3 3 8 7 . 1 5 3 3 3 3 . 1 5 4 6 . 8 2 1 1 7 . 2 3 7 1 8 4 8 6 . 7 7 5 9 4 3 2 1 5 . 7 7 7 0 ° 1 4 ' 5 0 . 7 6 0 6 " N 1 4 8 ° 1 4 ' 5 . 3 1 1 3 " W 2 . 4 3 1 0 . 6 2 1 2 . 3 2 2 . 5 6 1 0 7 . 5 5 4 0 . 1 4 4 0 . 1 1 7 . 63 5 3 . 8 5 34 2 5 . 0 0 1 7 . 4 5 7 3 . 9 2 3 4 1 1 . 0 3 3 3 5 7 . 0 3 4 8 . 8 9 1 2 4 . 3 2 7 1 8 4 9 3 . 7 9 5 9 4 3 2 1 8 . 0 4 7 0 ° 1 4 ' 5 0 . 7 8 0 9 " N 1 4 8 ° 1 4 ' 5 . 1 0 5 3 " W 2 . 2 8 - 1 . 9 3 1 2 . 2 4 1 . 4 0 1 1 3 . 4 4 4 0 . 1 5 4 0 . 1 2 7 . 65 5 5 . 4 4 34 5 0 . 0 0 1 8 . 0 0 7 3 . 8 6 3 4 3 4 . 8 5 3 3 8 0 . 8 5 5 1 . 0 0 1 3 1 . 6 3 7 1 8 5 0 1 . 0 4 5 9 4 3 2 2 0 . 3 6 7 0 ° 1 4 ' 5 0 . 8 0 1 7 " N 1 4 8 ° 1 4 ' 4 . 8 9 2 7 " W 2 . 2 0 1 . 4 5 4 2 . 2 0 - 0 . 2 4 1 1 9 . 5 0 4 0 . 1 5 4 0 . 1 2 7 . 67 5 6 . 9 7 34 7 5 . 0 0 1 8 . 5 0 7 3 . 9 0 3 4 5 8 . 5 9 3 4 0 4 . 5 9 5 3 . 1 7 1 3 9 . 1 5 7 1 8 5 0 8 . 4 9 5 9 4 3 2 2 2 . 7 5 7 0 ° 1 4 ' 5 0 . 8 2 3 1 " N 1 4 8 ° 1 4 ' 4 . 6 7 4 0 " W 2 . 0 0 - 8 . 8 3 5 2 . 0 0 0 . 1 6 1 2 5 . 7 3 4 0 . 1 6 4 0 . 1 2 7 . 69 5 8 . 4 2 35 0 0 . 0 0 1 8 . 9 6 7 3 . 6 8 3 4 8 2 . 2 7 3 4 2 8 . 2 7 5 5 . 4 1 1 4 6 . 8 6 7 1 8 5 1 6 . 1 3 5 9 4 3 2 2 5 . 2 1 7 0 ° 1 4 ' 5 0 . 8 4 5 1 " N 1 4 8 ° 1 4 ' 4 . 4 4 9 8 " W 1 . 8 6 4 . 7 3 7 1 . 8 4 - 0 . 8 8 1 3 2 . 1 3 4 0 . 1 7 4 0 . 1 2 7 . 70 5 9 . 7 4 35 2 5 . 0 0 1 9 . 6 5 7 3 . 8 5 3 5 0 5 . 8 6 3 4 5 1 . 8 6 5 7 . 7 3 1 5 4 . 7 9 7 1 8 5 2 4 . 0 0 5 9 4 3 2 2 7 . 7 5 7 0 ° 1 4 ' 5 0 . 8 6 7 8 " N 1 4 8 ° 1 4 ' 4 . 2 1 9 1 " W 2 . 7 7 1 4 . 9 9 7 2 . 7 6 0 . 6 8 1 3 8 . 7 2 4 0 . 1 7 4 0 . 1 3 7 . 72 6 0 . 9 1 35 5 0 . 0 0 2 0 . 0 6 7 4 . 1 7 3 5 2 9 . 3 7 3 4 7 5 . 3 7 6 0 . 0 6 1 6 2 . 9 6 7 1 8 5 3 2 . 0 9 5 9 4 3 2 3 0 . 3 3 7 0 ° 1 4 ' 5 0 . 8 9 0 8 " N 1 4 8 ° 1 4 ' 3 . 9 8 1 7 " W 1 . 7 0 8 . 2 4 5 1 . 6 4 1 . 2 8 1 4 5 . 4 7 4 0 . 1 8 4 0 . 1 3 7 . 7 46 1 . 9 5 35 7 5 . 0 0 2 0 . 7 7 7 4 . 4 6 3 5 5 2 . 8 0 3 4 9 8 . 8 0 6 2 . 4 2 1 7 1 . 3 5 7 1 8 5 4 0 . 4 1 5 9 4 3 2 3 2 . 9 3 7 0 ° 1 4 ' 5 0 . 9 1 4 0 " N 1 4 8 ° 1 4 ' 3 . 7 3 7 6 " W 2 . 8 7 1 7 . 1 4 1 2 . 8 4 1 . 1 6 1 5 2 . 3 8 4 0 . 1 9 4 0 . 1 3 7 . 76 6 2 . 9 0 36 0 0 . 0 0 2 1 . 4 1 7 5 . 0 0 3 5 7 6 . 1 3 3 5 2 2 . 1 3 6 4 . 7 9 1 8 0 . 0 3 7 1 8 5 4 9 . 0 2 5 9 4 3 2 3 5 . 5 4 7 0 ° 1 4 ' 5 0 . 9 3 7 3 " N 1 4 8 ° 1 4 ' 3 . 4 8 5 2 " W 2 . 6 8 1 0 . 5 4 5 2 . 5 6 2 . 1 6 1 5 9 . 4 6 4 0 . 2 0 4 0 . 1 3 7 . 77 6 3 . 7 5 36 2 5 . 0 0 2 1 . 8 5 7 5 . 2 2 3 5 9 9 . 3 7 3 5 4 5 . 3 7 6 7 . 1 6 1 8 8 . 9 4 7 1 8 5 5 7 . 8 5 5 9 4 3 2 3 8 . 1 7 7 0 ° 1 4 ' 5 0 . 9 6 0 6 " N 1 4 8 ° 1 4 ' 3 . 2 2 6 3 " W 1 . 7 9 1 2 . 2 6 1 . 7 6 0 . 8 8 1 6 6 . 6 7 4 0 . 2 1 4 0 . 1 4 7 . 7 96 4 . 5 7 36 5 0 . 0 0 2 2 . 3 4 7 5 . 5 0 3 6 2 2 . 5 3 3 5 6 8 . 5 3 6 9 . 5 3 1 9 8 . 0 3 7 1 8 5 6 6 . 8 7 5 9 4 3 2 4 0 . 8 1 7 0 ° 1 4 ' 5 0 . 9 8 3 9 " N 1 4 8 ° 1 4 ' 2 . 9 6 1 7 " W 2 . 0 0 - 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5 1 . 3 5 5 - 0 . 8 0 - 1 4 . 3 2 2 0 5 . 0 1 4 0 . 2 7 4 0 . 15 7 . 8 9 6 7 . 7 8 37 7 5 . 0 0 2 3 . 1 9 6 6 . 1 8 3 7 3 7 . 8 3 3 6 8 3 . 8 3 8 4 . 5 4 2 4 3 . 8 5 7 1 8 6 1 2 . 2 3 5 9 4 3 2 5 7 . 1 3 7 0 ° 1 4 ' 5 1 . 1 3 1 5 " N 1 4 8 ° 1 4 ' 1 . 6 2 9 5 " W 3 . 7 1 - 5 2 . 9 3 4 2 . 3 6 - 7 . 3 6 2 1 3 . 4 0 4 0 . 2 9 4 0 . 1 5 7. 9 1 6 8 . 0 4 38 0 0 . 0 0 2 3 . 5 6 6 4 . 9 7 3 7 6 0 . 7 8 3 7 0 6 . 7 8 8 8 . 6 4 2 5 2 . 8 8 7 1 8 6 2 1 . 1 4 5 9 4 3 2 6 1 . 4 9 7 0 ° 1 4 ' 5 1 . 1 7 1 8 " N 1 4 8 ° 1 4 ' 1 . 3 6 6 9 " W 2 . 4 2 - 9 8 . 2 1 1 . 4 8 - 4 . 8 4 2 2 2 . 0 8 4 0 . 3 0 4 0 . 1 5 7 .9 3 6 8 . 1 1 38 2 5 . 0 0 2 3 . 4 8 6 3 . 4 5 3 7 8 3 . 7 0 3 7 2 9 . 7 0 9 2 . 9 8 2 6 1 . 8 6 7 1 8 6 2 9 . 9 9 5 9 4 3 2 6 6 . 0 9 7 0 ° 1 4 ' 5 1 . 2 1 4 5 " N 1 4 8 ° 1 4 ' 1 . 1 0 5 7 " W 2 . 4 5 - 9 8 . 3 0 9 - 0 . 3 2 - 6 . 0 8 2 3 0 . 9 3 4 0 . 3 2 4 0 . 1 57 . 9 5 6 8 . 1 0 38 5 0 . 0 0 2 3 . 4 2 6 2 . 3 5 3 8 0 6 . 6 4 3 7 5 2 . 6 4 9 7 . 5 1 2 7 0 . 7 2 7 1 8 6 3 8 . 7 1 5 9 4 3 2 7 0 . 8 8 7 0 ° 1 4 ' 5 1 . 2 5 9 1 " N 1 4 8 ° 1 4 ' 0 . 8 4 8 1 " W 1 . 7 7 - 7 1 . 5 9 5 - 0 . 2 4 - 4 . 4 0 2 3 9 . 8 5 4 0 . 3 4 4 0 . 1 67 . 9 7 6 8 . 0 1 38 7 5 . 0 0 2 3 . 6 0 6 1 . 0 4 3 8 2 9 . 5 6 3 7 7 5 . 5 6 1 0 2 . 2 4 2 7 9 . 5 0 7 1 8 6 4 7 . 3 5 5 9 4 3 2 7 5 . 8 6 7 0 ° 1 4 ' 5 1 . 3 0 5 6 " N 1 4 8 ° 1 4 ' 0 . 5 9 2 8 " W 2 . 2 1 - 4 4 . 6 7 3 0 . 7 2 - 5 . 2 4 2 4 8 . 8 8 4 0 . 3 6 4 0 . 1 67 . 9 9 6 7 . 8 6 39 0 0 . 0 0 2 4 . 2 3 5 9 . 5 4 3 8 5 2 . 4 2 3 7 9 8 . 4 2 1 0 7 . 2 6 2 8 8 . 3 0 7 1 8 6 5 6 . 0 0 5 9 4 3 2 8 1 . 1 4 7 0 ° 1 4 ' 5 1 . 3 5 5 0 " N 1 4 8 ° 1 4 ' 0 . 3 3 6 9 " W 3 . 5 0 - 3 0 . 9 3 8 2 . 5 2 - 6 . 0 0 2 5 8 . 1 7 4 0 . 3 7 4 0 . 1 68 . 0 1 6 7 . 6 9 39 2 5 . 0 0 2 4 . 7 2 5 8 . 8 4 3 8 7 5 . 1 7 3 8 2 1 . 1 7 1 1 2 . 5 7 2 9 7 . 1 9 7 1 8 6 6 4 . 7 4 5 9 4 3 2 8 6 . 7 0 7 0 ° 1 4 ' 5 1 . 4 0 7 2 " N 1 4 8 ° 1 4 ' 0 . 0 7 8 2 " W 2 . 2 8 - 9 . 5 6 7 1 . 9 6 - 2 . 8 0 2 6 7 . 7 4 4 0 . 3 9 4 0 . 1 6 8. 0 3 6 7 . 4 6 39 5 0 . 0 0 2 5 . 4 6 5 8 . 5 5 3 8 9 7 . 8 1 3 8 4 3 . 8 1 1 1 8 . 0 8 3 0 6 . 2 5 7 1 8 6 7 3 . 6 3 5 9 4 3 2 9 2 . 4 7 7 0 ° 1 4 ' 5 1 . 4 6 1 3 " N 14 8 ° 1 3 ' 5 9 . 8 1 4 9 " W 3. 0 0 - 2 0 . 2 1 1 2 . 9 6 - 1 . 1 6 2 7 7 . 5 6 4 0 . 4 1 4 0 . 1 7 8 . 0 5 6 7 . 2 0 39 7 5 . 0 0 2 5 . 9 6 5 8 . 1 3 3 9 2 0 . 3 4 3 8 6 6 . 3 4 1 2 3 . 7 7 3 1 5 . 4 8 7 1 8 6 8 2 . 7 0 5 9 4 3 2 9 8 . 4 2 7 0 ° 1 4 ' 5 1 . 5 1 7 3 " N 14 8 ° 1 3 ' 5 9 . 5 4 6 4 " W 2. 1 3 6 . 2 0 6 2 . 0 0 - 1 . 6 8 2 8 7 . 6 4 4 0 . 4 3 4 0 . 1 7 8 . 0 7 6 6 . 9 3 40 0 0 . 0 0 2 6 . 4 1 5 8 . 2 4 3 9 4 2 . 7 7 3 8 8 8 . 7 7 1 2 9 . 5 9 3 2 4 . 8 5 7 1 8 6 9 1 . 9 0 5 9 4 3 3 0 4 . 5 1 7 0 ° 1 4 ' 5 1 . 5 7 4 5 " N 14 8 ° 1 3 ' 5 9 . 2 7 3 8 " W 1. 8 1 1 . 2 0 3 1 . 8 0 0 . 4 4 2 9 7 . 9 0 4 0 . 4 6 4 0 . 1 7 8 . 0 9 6 6 . 6 5 40 2 5 . 0 0 2 6 . 8 4 5 8 . 2 6 3 9 6 5 . 1 2 3 9 1 1 . 1 2 1 3 5 . 4 8 3 3 4 . 3 8 7 1 8 7 0 1 . 2 5 5 9 4 3 3 1 0 . 6 8 7 0 ° 1 4 ' 5 1 . 6 3 2 5 " N 14 8 ° 1 3 ' 5 8 . 9 9 6 8 " W 1. 7 2 1 . 4 1 2 1 . 7 2 0 . 0 8 3 0 8 . 3 2 4 0 . 4 8 4 0 . 1 7 8 . 1 1 6 6 . 3 8 40 5 0 . 0 0 2 7 . 4 0 5 8 . 2 9 3 9 8 7 . 3 7 3 9 3 3 . 3 7 1 4 1 . 4 7 3 4 4 . 0 8 7 1 8 7 1 0 . 7 6 5 9 4 3 3 1 6 . 9 5 7 0 ° 1 4 ' 5 1 . 6 9 1 4 " N 14 8 ° 1 3 ' 5 8 . 7 1 4 9 " W 2. 2 4 1 2 . 7 1 9 2 . 2 4 0 . 1 2 3 1 8 . 9 1 4 0 . 5 0 4 0 . 1 8 8 . 1 3 6 6 . 1 2 40 7 5 . 0 0 2 7 . 9 4 5 8 . 5 5 4 0 0 9 . 5 1 3 9 5 5 . 5 1 1 4 7 . 5 5 3 5 3 . 9 7 7 1 8 7 2 0 . 4 7 5 9 4 3 3 2 3 . 3 1 7 0 ° 1 4 ' 5 1 . 7 5 1 2 " N 14 8 ° 1 3 ' 5 8 . 4 2 7 3 " W 2. 2 1 5 . 9 0 4 2 . 1 6 1 . 0 4 3 2 9 . 7 0 4 0 . 5 3 4 0 . 1 8 8 . 1 5 6 5 . 8 8 41 0 0 . 0 0 2 8 . 4 0 5 8 . 6 5 4 0 3 1 . 5 5 3 9 7 7 . 5 5 1 5 3 . 7 0 3 6 4 . 0 4 7 1 8 7 3 0 . 3 6 5 9 4 3 3 2 9 . 7 5 7 0 ° 1 4 ' 5 1 . 8 1 1 7 " N 14 8 ° 1 3 ' 5 8 . 1 3 4 3 " W 1. 8 5 - 1 . 9 3 1 1 . 8 4 0 . 4 0 3 4 0 . 6 4 4 0 . 5 6 4 0 . 1 8 8 . 1 7 6 5 . 6 5 41 2 5 . 0 0 2 9 . 2 7 5 8 . 5 9 4 0 5 3 . 4 5 3 9 9 9 . 4 5 1 5 9 . 9 8 3 7 4 . 3 3 7 1 8 7 4 0 . 4 7 5 9 4 3 3 3 6 . 3 2 7 0 ° 1 4 ' 5 1 . 8 7 3 4 " N 14 8 ° 1 3 ' 5 7 . 8 3 5 0 " W 3. 4 8 - 2 . 0 1 5 3 . 4 8 - 0 . 2 4 3 5 1 . 8 3 4 0 . 5 9 4 0 . 1 9 8 . 1 9 6 5 . 4 4 41 5 0 . 0 0 2 9 . 9 8 5 8 . 5 4 4 0 7 5 . 1 8 4 0 2 1 . 1 8 1 6 6 . 4 3 3 8 4 . 8 8 7 1 8 7 5 0 . 8 2 5 9 4 3 3 4 3 . 0 7 7 0 ° 1 4 ' 5 1 . 9 3 6 8 " N 14 8 ° 1 3 ' 5 7 . 5 2 8 4 " W 2. 8 4 5 . 5 2 1 2 . 8 4 - 0 . 2 0 3 6 3 . 2 9 4 0 . 6 2 4 0 . 1 9 8 . 2 0 6 5 . 2 4 41 7 5 . 0 0 3 0 . 7 2 5 8 . 6 8 4 0 9 6 . 7 6 4 0 4 2 . 7 6 1 7 3 . 0 1 3 9 5 . 6 6 7 1 8 7 6 1 . 4 1 5 9 4 3 3 4 9 . 9 6 7 0 ° 1 4 ' 5 2 . 0 0 1 5 " N 14 8 ° 1 3 ' 5 7 . 2 1 4 8 " W 2. 9 7 - 3 . 0 2 5 2 . 9 6 0 . 5 6 3 7 5 . 0 1 4 0 . 6 5 4 0 . 1 9 8 . 2 2 6 5 . 0 4 42 0 0 . 0 0 3 1 . 3 1 5 8 . 6 2 4 1 1 8 . 1 8 4 0 6 4 . 1 8 1 7 9 . 7 1 4 0 6 . 6 6 7 1 8 7 7 2 . 2 1 5 9 4 3 3 5 6 . 9 8 7 0 ° 1 4 ' 5 2 . 0 6 7 4 " N 14 8 ° 1 3 ' 5 6 . 8 9 4 9 " W 2. 3 6 8 . 9 8 6 2 . 3 6 - 0 . 2 4 3 8 6 . 9 5 4 0 . 6 8 4 0 . 1 9 8 . 2 4 6 4 . 8 5 42 2 5 . 0 0 3 1 . 9 8 5 8 . 8 2 4 1 3 9 . 4 6 4 0 8 5 . 4 6 1 8 6 . 5 2 4 1 7 . 8 7 7 1 8 7 8 3 . 2 2 5 9 4 3 3 6 4 . 1 1 7 0 ° 1 4 ' 5 2 . 1 3 4 4 " N 14 8 ° 1 3 ' 5 6 . 5 6 8 9 " W 2. 7 1 0 2 . 6 8 0 . 8 0 3 9 9 . 1 1 4 0 . 7 2 4 0 . 2 0 8 . 2 6 6 4 . 6 7 42 5 0 . 0 0 3 2 . 7 5 5 8 . 8 2 4 1 6 0 . 5 8 4 1 0 6 . 5 8 1 9 3 . 4 5 4 2 9 . 3 2 7 1 8 7 9 4 . 4 6 5 9 4 3 3 7 1 . 3 6 7 0 ° 1 4 ' 5 2 . 2 0 2 5 " N 14 8 ° 1 3 ' 5 6 . 2 3 6 0 " W 3. 0 8 - 3 . 3 4 2 3 . 0 8 0 . 0 0 4 1 1 . 5 0 4 0 . 7 5 4 0 . 2 0 8 . 2 8 6 4 . 5 0 42 7 5 . 0 0 3 3 . 4 1 5 8 . 7 5 4 1 8 1 . 5 3 4 1 2 7 . 5 3 2 0 0 . 5 2 4 4 0 . 9 9 7 1 8 8 0 5 . 9 2 5 9 4 3 3 7 8 . 7 7 7 0 ° 1 4 ' 5 2 . 2 7 2 1 " N 14 8 ° 1 3 ' 5 5 . 8 9 6 6 " W 2. 6 4 - 3 . 7 7 8 2 . 6 4 - 0 . 2 8 4 2 4 . 1 4 4 0 . 7 9 4 0 . 2 0 8 . 3 0 6 4 . 3 4 43 0 0 . 0 0 3 4 . 3 5 5 8 . 6 4 4 2 0 2 . 2 8 4 1 4 8 . 2 8 2 0 7 . 7 6 4 5 2 . 9 0 7 1 8 8 1 7 . 6 1 5 9 4 3 3 8 6 . 3 5 7 0 ° 1 4 ' 5 2 . 3 4 3 3 " N 14 8 ° 1 3 ' 5 5 . 5 5 0 4 " W 3. 7 7 - 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1 1 2 . 7 9 8 - 2 . 6 3 - 9 . 3 4 4 2 2 2 . 8 1 8 4 . 3 5 5 1 . 3 6 1 9 . 2 0 2 4 3 . 9 2 11 3 0 3 . 5 7 8 7 . 8 5 2 8 9 . 7 1 8 8 9 6 . 5 3 8 8 4 2 . 5 3 2 7 8 4 . 1 8 3 3 1 7 . 6 3 7 2 1 6 0 6 . 3 6 5 9 4 6 0 4 4 . 5 8 7 0 ° 1 5 ' 1 7 . 6 7 5 3 " N 14 8 ° 1 2 ' 3 2 . 2 1 3 4 " W 10 . 9 7 1 1 2 . 2 3 8 - 4 . 2 4 - 1 0 . 1 2 4 2 1 4 . 2 4 8 4 . 4 9 5 1 . 9 2 1 9 . 2 9 2 4 4 . 4 3 11 3 3 3 . 8 2 8 6 . 7 1 2 9 2 . 5 1 8 8 9 7 . 9 6 8 8 4 3 . 9 6 2 7 9 5 . 0 6 3 2 8 9 . 4 5 7 2 1 5 7 7 . 8 7 5 9 4 6 0 5 4 . 6 4 7 0 ° 1 5 ' 1 7 . 7 8 2 4 " N 14 8 ° 1 2 ' 3 3 . 0 3 3 2 " W 9. 9 8 8 5 . 9 5 - 3 . 7 7 9 . 2 6 4 2 0 6 . 1 4 8 4 . 6 3 5 2 . 4 4 1 9 . 3 7 2 4 4 . 9 4 11 3 6 3 . 0 7 8 7 . 0 2 2 9 6 . 7 7 8 8 9 9 . 5 6 8 8 4 5 . 5 6 2 8 0 7 . 2 4 3 2 6 2 . 9 1 7 2 1 5 5 0 . 9 9 5 9 4 6 0 6 6 . 0 4 7 0 ° 1 5 ' 1 7 . 9 0 2 2 " N 14 8 ° 1 2 ' 3 3 . 8 0 5 0 " W 14 . 5 8 6 1 . 5 3 2 1 . 0 6 1 4 . 5 6 4 2 0 0 . 0 6 8 4 . 7 8 5 2 . 9 8 1 9 . 4 6 2 4 5 . 4 5 11 4 0 3 . 6 9 9 0 . 4 6 3 0 3 . 0 9 8 9 0 0 . 4 6 8 8 4 6 . 4 6 2 8 2 7 . 4 9 3 2 2 7 . 7 4 7 2 1 5 1 5 . 2 5 5 9 4 6 0 8 5 . 2 6 7 0 ° 1 5 ' 1 8 . 1 0 1 5 " N 14 8 ° 1 2 ' 3 4 . 8 2 7 9 " W 17 . 7 1 7 2 . 9 1 8 8 . 4 7 1 5 . 5 6 4 1 9 5 . 3 1 8 4 . 9 8 5 3 . 8 0 1 9 . 5 8 2 4 6 . 1 8 11 4 2 5 . 1 8 9 1 . 3 5 3 0 5 . 9 9 8 9 0 0 . 1 2 8 8 4 6 . 1 2 2 8 3 9 . 6 7 3 2 1 0 . 0 4 7 2 1 4 9 7 . 2 1 5 9 4 6 0 9 6 . 9 2 7 0 ° 1 5 ' 1 8 . 2 2 1 4 " N 14 8 ° 1 2 ' 3 5 . 3 4 2 5 " W 14 . 1 1 7 8 . 5 2 2 4 . 1 4 1 3 . 4 9 4 1 9 4 . 5 1 8 5 . 0 8 5 4 . 2 6 1 9 . 6 5 2 4 6 . 5 6 11 4 5 5 . 7 1 9 2 . 2 7 3 1 0 . 5 5 8 8 9 9 . 1 5 8 8 4 5 . 1 5 2 8 5 8 . 5 6 3 1 8 6 . 0 9 7 2 1 4 7 2 . 7 2 5 9 4 6 1 1 5 . 1 1 7 0 ° 1 5 ' 1 8 . 4 0 7 3 " N 14 8 ° 1 2 ' 3 6 . 0 3 9 0 " W 15 . 2 3 8 5 . 1 6 5 3 . 0 1 1 4 . 9 4 4 1 9 5 . 3 7 8 5 . 2 1 5 4 . 9 3 1 9 . 7 5 2 4 7 . 1 1 11 4 8 4 . 0 4 9 2 . 4 6 3 1 2 . 8 2 8 8 9 7 . 9 8 8 8 4 3 . 9 8 2 8 7 7 . 3 9 3 1 6 4 . 9 5 7 2 1 4 5 1 . 0 5 5 9 4 6 1 3 3 . 3 2 7 0 ° 1 5 ' 1 8 . 5 9 2 6 " N 14 8 ° 1 2 ' 3 6 . 6 5 3 6 " W 8. 0 3 3 5 . 0 3 9 0 . 6 7 8 . 0 1 4 1 9 7 . 8 5 8 5 . 3 2 5 5 . 5 8 1 9 . 8 4 2 4 7 . 6 1 11 5 1 1 . 1 0 9 4 . 6 2 3 1 4 . 3 4 8 8 9 6 . 3 1 8 8 4 2 . 3 1 2 8 9 6 . 0 0 3 1 4 5 . 3 9 7 2 1 4 3 0 . 9 5 5 9 4 6 1 5 1 . 3 6 7 0 ° 1 5 ' 1 8 . 7 7 5 7 " N 14 8 ° 1 2 ' 3 7 . 2 2 2 5 " W 9. 7 5 2 8 . 0 4 6 7 . 9 8 5 . 6 2 4 2 0 1 . 1 1 8 5 . 4 2 5 6 . 2 0 1 9 . 9 2 2 4 8 . 1 0 11 5 3 4 . 4 1 9 7 . 6 7 3 1 5 . 9 8 8 8 9 3 . 8 2 8 8 3 9 . 8 2 2 9 1 2 . 4 3 3 1 2 9 . 0 5 7 2 1 4 1 4 . 1 4 5 9 4 6 1 6 7 . 3 1 7 0 ° 1 5 ' 1 8 . 9 3 7 4 " N 14 8 ° 1 2 ' 3 7 . 6 9 7 7 " W 14 . 8 4 4 7 . 5 6 1 3 . 0 8 7 . 0 4 4 2 0 4 . 5 3 8 5 . 5 1 5 6 . 7 4 2 0 . 0 0 2 4 8 . 5 3 11 5 6 0 . 4 3 1 0 0 . 7 2 3 1 9 . 3 9 8 8 8 9 . 6 6 8 8 3 5 . 6 6 2 9 3 1 . 4 2 3 1 1 1 . 7 6 7 2 1 3 9 6 . 3 1 5 9 4 6 1 8 5 . 7 8 7 0 ° 1 5 ' 1 9 . 1 2 4 2 " N 14 8 ° 1 2 ' 3 8 . 2 0 0 4 " W 17 . 4 6 7 1 . 2 8 1 1 . 7 2 1 3 . 1 1 4 2 0 9 . 4 4 8 5 . 6 0 5 7 . 3 5 2 0 . 0 9 2 4 8 . 9 9 11 5 9 0 . 2 6 1 0 1 . 8 0 3 2 2 . 7 0 8 8 8 3 . 8 3 8 8 2 9 . 8 3 2 9 5 4 . 1 7 3 0 9 3 . 3 7 7 2 1 3 7 7 . 2 7 5 9 4 6 2 0 7 . 9 9 7 0 ° 1 5 ' 1 9 . 3 4 8 0 " N 14 8 ° 1 2 ' 3 8 . 7 3 5 1 " W 11 . 4 7 7 6 . 9 5 4 3 . 6 2 1 1 . 1 0 4 2 1 6 . 7 1 8 5 . 6 8 5 8 . 0 4 2 0 . 1 9 2 4 9 . 5 2 11 6 1 3 . 1 9 1 0 2 . 3 7 3 2 5 . 2 7 8 8 7 9 . 0 3 8 8 2 5 . 0 3 2 9 7 2 . 3 0 3 0 8 0 . 1 8 7 2 1 3 6 3 . 5 7 5 9 4 6 2 2 5 . 7 3 7 0 ° 1 5 ' 1 9 . 5 2 6 4 " N 14 8 ° 1 2 ' 3 9 . 1 1 8 4 " W 11 . 2 4 - 1 7 8 . 5 0 7 2 . 4 9 1 1 . 2 1 4 2 2 3 . 3 9 8 5 . 7 4 5 8 . 5 8 2 0 . 2 6 2 4 9 . 9 0 11 6 7 1 . 0 9 9 4 . 7 0 3 2 5 . 0 7 8 8 7 0 . 4 4 8 8 1 6 . 4 4 3 0 1 9 . 2 6 3 0 4 7 . 5 0 7 2 1 3 2 9 . 5 4 5 9 4 6 2 7 1 . 7 3 7 0 ° 1 5 ' 1 9 . 9 8 8 4 " N 14 8 ° 1 2 ' 4 0 . 0 6 8 5 " W 13 . 2 5 - 1 4 0 . 9 8 3 - 1 3 . 2 5 - 0 . 3 5 4 2 4 1 . 5 5 8 5 . 9 0 5 9 . 9 7 2 0 . 4 9 2 5 0 . 9 4 11 7 1 5 . 4 2 8 9 . 3 9 3 2 0 . 7 8 8 8 6 8 . 8 6 8 8 1 4 . 8 6 3 0 5 4 . 5 9 3 0 2 0 . 8 1 7 2 1 3 0 1 . 8 4 5 9 4 6 3 0 6 . 2 6 7 0 ° 1 5 ' 2 0 . 3 3 5 9 " N 14 8 ° 1 2 ' 4 0 . 8 4 4 6 " W 15 . 3 9 - 6 7 . 2 2 8 - 1 1 . 9 8 - 9 . 6 8 4 2 5 3 . 9 5 8 6 . 0 5 6 1 . 0 6 2 0 . 7 5 2 5 1 . 8 8 11 7 5 3 . 8 5 9 1 . 8 4 3 1 4 . 9 4 8 8 6 8 . 4 5 8 8 1 4 . 4 5 3 0 8 3 . 0 7 2 9 9 5 . 0 4 7 2 1 2 7 5 . 2 5 5 9 4 6 3 3 3 . 9 8 7 0 ° 1 5 ' 2 0 . 6 1 6 1 " N 14 8 ° 1 2 ' 4 1 . 5 9 3 9 " W 16 . 4 8 - 9 6 . 8 2 5 6 . 3 8 - 1 5 . 2 0 4 2 6 1 . 4 2 8 6 . 2 3 6 2 . 0 1 2 0 . 9 2 2 5 2 . 8 5 11 7 9 4 . 9 6 9 1 . 3 5 3 1 0 . 8 8 8 8 6 7 . 3 0 8 8 1 3 . 3 0 3 1 1 1 . 0 4 2 9 6 4 . 9 5 7 2 1 2 4 4 . 3 7 5 9 4 6 3 6 1 . 0 7 7 0 ° 1 5 ' 2 0 . 8 9 1 3 " N 14 8 ° 1 2 ' 4 2 . 4 6 8 9 " W 9. 9 4 - 9 4 . 3 6 5 - 1 . 1 9 - 9 . 8 8 4 2 6 5 . 8 9 8 6 . 5 0 6 3 . 0 0 2 1 . 0 8 2 5 4 . 0 7 11 8 2 9 . 2 9 9 1 . 1 1 3 0 7 . 7 6 8 8 6 6 . 5 7 8 8 1 2 . 5 7 3 1 3 2 . 7 9 2 9 3 8 . 4 0 7 2 1 2 1 7 . 2 0 5 9 4 6 3 8 2 . 0 3 7 0 ° 1 5 ' 2 1 . 1 0 5 3 " N 14 8 ° 1 2 ' 4 3 . 2 4 1 0 " W 9. 1 1 - 7 6 . 0 4 1 - 0 . 7 0 - 9 . 0 9 4 2 6 7 . 4 9 8 6 . 7 7 6 3 . 8 0 2 1 . 2 2 2 5 5 . 2 0 11 8 5 1 . 2 4 9 1 . 7 2 3 0 5 . 3 0 8 8 6 6 . 0 2 8 8 1 2 . 0 2 3 1 4 5 . 8 5 2 9 2 0 . 7 7 7 2 1 1 9 9 . 2 0 5 9 4 6 3 9 4 . 5 8 7 0 ° 1 5 ' 2 1 . 2 3 3 8 " N 14 8 ° 1 2 ' 4 3 . 7 5 3 7 " W 11 . 5 4 - 1 2 0 . 0 3 9 2 . 7 8 - 1 1 . 2 1 4 2 6 7 . 4 4 8 6 . 9 7 6 4 . 2 8 2 1 . 3 0 2 5 5 . 9 8 11 8 8 3 . 6 5 8 9 . 6 3 3 0 1 . 6 9 8 8 6 5 . 6 4 8 8 1 1 . 6 4 3 1 6 3 . 7 3 2 8 9 3 . 7 5 7 2 1 1 7 1 . 6 7 5 9 4 6 4 1 1 . 6 7 7 0 ° 1 5 ' 2 1 . 4 0 9 8 " N 14 8 ° 1 2 ' 4 4 . 5 3 9 6 " W 12 . 8 7 - 1 4 5 . 7 - 6 . 4 5 - 1 1 . 1 4 4 2 6 5 . 6 5 8 7 . 3 1 6 4 . 9 6 2 1 . 4 4 2 5 7 . 2 0 11 9 1 4 . 0 6 8 7 . 3 6 3 0 0 . 1 4 8 8 6 6 . 4 4 8 8 1 2 . 4 4 3 1 7 9 . 3 4 2 8 6 7 . 6 7 7 2 1 1 4 5 . 1 5 5 9 4 6 4 2 6 . 5 2 7 0 ° 1 5 ' 2 1 . 5 6 3 5 " N 14 8 ° 1 2 ' 4 5 . 2 9 8 0 " W 9. 0 4 - 7 8 . 6 7 5 - 7 . 4 6 - 5 . 1 0 4 2 6 2 . 6 1 8 7 . 6 7 6 5 . 5 5 2 1 . 5 7 2 5 8 . 4 0 11 9 4 3 . 4 6 8 7 . 9 8 2 9 7 . 0 6 8 8 6 7 . 6 4 8 8 1 3 . 6 4 3 1 9 3 . 4 0 2 8 4 1 . 8 8 7 2 1 1 1 8 . 9 7 5 9 4 6 4 3 9 . 8 3 7 0 ° 1 5 ' 2 1 . 7 0 1 9 " N 14 8 ° 1 2 ' 4 6 . 0 4 8 1 " W 10 . 6 8 - 7 0 . 4 5 1 2 . 1 1 - 1 0 . 4 8 4 2 5 8 . 4 9 8 8 . 0 6 6 6 . 0 9 2 1 . 6 9 2 5 9 . 6 0 11 9 7 2 . 6 5 8 8 . 8 3 2 9 4 . 6 7 8 8 6 8 . 4 5 8 8 1 4 . 4 5 3 2 0 6 . 1 3 2 8 1 5 . 6 3 7 2 1 0 9 2 . 3 6 5 9 4 6 4 5 1 . 7 9 7 0 ° 1 5 ' 2 1 . 8 2 7 1 " N 14 8 ° 1 2 ' 4 6 . 8 1 1 6 " W 8. 6 9 - 9 3 . 1 1 9 2 . 9 1 - 8 . 1 9 4 2 5 3 . 0 3 8 8 . 4 8 6 6 . 5 7 2 1 . 8 2 2 6 0 . 8 2 12 0 0 0 . 1 3 8 8 . 6 8 2 9 1 . 8 9 8 8 6 9 . 0 5 8 8 1 5 . 0 5 3 2 1 6 . 9 9 2 7 9 0 . 3 9 7 2 1 0 6 6 . 8 2 5 9 4 6 4 6 1 . 9 1 7 0 ° 1 5 ' 2 1 . 9 3 4 0 " N 14 8 ° 1 2 ' 4 7 . 5 4 5 6 " W 10 . 1 3 - 6 6 . 6 1 9 - 0 . 5 5 - 1 0 . 1 2 4 2 4 6 . 6 7 8 8 . 9 3 6 6 . 9 7 2 1 . 9 4 2 6 1 . 9 6 12 0 4 0 . 1 9 9 0 . 0 0 2 8 8 . 8 4 8 8 6 9 . 5 1 8 8 1 5 . 5 1 3 2 3 0 . 9 3 2 7 5 2 . 8 5 7 2 1 0 2 8 . 8 9 5 9 4 6 4 7 4 . 7 5 7 0 ° 1 5 ' 2 2 . 0 7 1 2 " N 14 8 ° 1 2 ' 4 8 . 6 3 7 8 " W 8. 3 0 1 2 1 . 6 2 3 . 3 0 - 7 . 6 1 4 2 3 5 . 4 4 8 9 . 6 3 6 7 . 4 8 2 2 . 1 1 2 6 3 . 6 1 12 0 7 2 . 3 1 8 8 . 5 6 2 9 1 . 1 8 8 8 6 9 . 9 1 8 8 1 5 . 9 1 3 2 4 1 . 9 2 2 7 2 2 . 6 7 7 2 0 9 9 8 . 4 1 5 9 4 6 4 8 4 . 8 6 7 0 ° 1 5 ' 2 2 . 1 7 9 4 " N 14 8 ° 1 2 ' 4 9 . 5 1 5 5 " W 8. 5 5 1 6 7 . 3 2 4 - 4 . 4 8 7 . 2 9 4 2 2 6 . 2 4 9 0 . 2 4 6 7 . 8 6 2 2 . 2 6 2 6 4 . 9 2 12 1 1 3 . 1 4 8 1 . 9 0 2 9 2 . 6 9 8 8 7 3 . 3 1 8 8 1 9 . 3 1 3 2 5 7 . 1 0 2 6 8 4 . 9 5 7 2 0 9 6 0 . 2 6 5 9 4 6 4 9 8 . 9 5 7 0 ° 1 5 ' 2 2 . 3 2 8 9 " N 14 8 ° 1 2 ' 5 0 . 6 1 2 7 " W 16 . 7 2 - 1 7 8 . 9 1 5 - 1 6 . 3 1 3 . 7 0 4 2 1 5 . 9 0 9 1 . 0 5 6 8 . 3 3 2 2 . 4 6 2 6 6 . 5 5 12 1 4 0 . 3 9 7 7 . 7 7 2 9 2 . 6 1 8 8 7 8 . 1 1 8 8 2 4 . 1 1 3 2 6 7 . 4 3 2 6 6 0 . 2 0 7 2 0 9 3 5 . 2 3 5 9 4 6 5 0 8 . 5 5 7 0 ° 1 5 ' 2 2 . 4 3 0 6 " N 14 8 ° 1 2 ' 5 1 . 3 3 2 5 " W 15 . 1 6 1 7 6 . 7 0 1 - 1 5 . 1 6 - 0 . 2 9 4 2 0 9 . 4 1 9 1 . 6 0 6 8 . 6 3 2 2 . 6 2 2 6 7 . 6 1 12 1 7 3 . 3 1 7 2 . 6 3 2 9 2 . 9 2 8 8 8 6 . 5 2 8 8 3 2 . 5 2 3 2 7 9 . 7 4 2 6 3 0 . 8 6 7 2 0 9 0 5 . 5 5 5 9 4 6 5 2 0 . 0 1 7 0 ° 1 5 ' 2 2 . 5 5 1 7 " N 14 8 ° 1 2 ' 5 2 . 1 8 5 9 " W 15 . 6 4 - 1 7 7 . 6 3 - 1 5 . 6 1 0 . 9 4 4 2 0 1 . 7 7 9 2 . 2 7 6 8 . 9 6 2 2 . 7 9 2 6 8 . 8 3 12 2 0 4 . 1 5 6 7 . 4 9 2 9 2 . 6 9 8 8 9 7 . 0 3 8 8 4 3 . 0 3 3 2 9 0 . 9 8 2 6 0 4 . 1 5 7 2 0 8 7 8 . 5 2 5 9 4 6 5 3 0 . 4 6 7 0 ° 1 5 ' 2 2 . 6 6 2 3 " N 14 8 ° 1 2 ' 5 2 . 9 6 3 0 " W 16 . 6 8 1 7 4 . 1 8 2 - 1 6 . 6 7 - 0 . 7 5 4 1 9 4 . 8 4 9 2 . 9 0 6 9 . 2 4 2 2 . 9 6 2 6 9 . 8 9 12 2 3 0 . 1 6 6 3 . 7 9 2 9 3 . 1 1 8 9 0 7 . 7 6 8 8 5 3 . 7 6 3 3 0 0 . 1 9 2 5 8 2 . 3 2 7 2 0 8 5 6 . 4 4 5 9 4 6 5 3 9 . 0 4 7 0 ° 1 5 ' 2 2 . 7 5 3 0 " N 14 8 ° 1 2 ' 5 3 . 5 9 7 7 " W 14 . 3 0 - 1 7 4 . 8 2 1 - 1 4 . 2 3 1 . 6 1 4 1 8 9 . 2 0 9 3 . 4 2 6 9 . 4 5 2 3 . 0 9 2 7 0 . 7 2 12 2 6 4 . 2 9 5 7 . 0 2 2 9 2 . 3 8 8 9 2 4 . 6 1 8 8 7 0 . 6 1 3 3 1 1 . 6 7 2 5 5 4 . 9 7 7 2 0 8 2 8 . 7 7 5 9 4 6 5 4 9 . 7 2 7 0 ° 1 5 ' 2 2 . 8 6 6 0 " N 14 8 ° 1 2 ' 5 4 . 3 9 3 3 " W 19 . 9 2 - 1 6 8 . 5 5 5 - 1 9 . 8 4 - 2 . 1 4 4 1 8 2 . 0 8 9 4 . 0 7 6 9 . 6 9 2 3 . 2 6 2 7 1 . 7 0 12 2 8 6 . 0 7 5 3 . 1 1 2 9 1 . 3 9 8 9 3 7 . 0 8 8 8 8 3 . 0 8 3 3 1 8 . 3 2 2 5 3 8 . 4 1 7 2 0 8 1 2 . 0 2 5 9 4 6 5 5 5 . 8 9 7 0 ° 1 5 ' 2 2 . 9 3 1 5 " N 14 8 ° 1 2 ' 5 4 . 8 7 5 1 " W 18 . 3 3 - 1 7 0 . 1 0 1 - 1 7 . 9 5 - 4 . 5 5 4 1 7 7 . 5 3 9 4 . 4 6 6 9 . 8 2 2 3 . 3 8 2 7 2 . 2 6 12 3 2 5 . 8 6 4 6 . 3 1 2 8 9 . 7 5 8 9 6 2 . 7 9 8 9 0 8 . 7 9 3 3 2 9 . 0 0 2 5 1 0 . 0 2 7 2 0 7 8 3 . 3 3 5 9 4 6 5 6 5 . 7 4 7 0 ° 1 5 ' 2 3 . 0 3 6 6 " N 14 8 ° 1 2 ' 5 5 . 7 0 0 9 " W 17 . 3 8 - 1 7 9 . 0 2 1 - 1 7 . 0 9 - 4 . 1 2 4 1 6 9 . 1 4 9 5 . 1 2 7 0 . 0 1 2 3 . 5 6 2 7 3 . 1 1 12 3 4 2 . 1 4 4 3 . 1 1 2 8 9 . 6 7 8 9 7 4 . 3 6 8 9 2 0 . 3 6 3 3 3 2 . 8 6 2 4 9 9 . 2 4 7 2 0 7 7 2 . 4 4 5 9 4 6 5 6 9 . 2 9 7 0 ° 1 5 ' 2 3 . 0 7 4 6 " N 14 8 ° 1 2 ' 5 6 . 0 1 4 4 " W 19 . 6 6 0 - 1 9 . 6 6 - 0 . 4 9 4 1 6 5 . 8 1 9 5 . 3 6 7 0 . 0 7 2 3 . 6 3 2 7 3 . 4 1 12 3 7 0 . 0 0 43 . 1 1 28 9 . 6 7 89 9 4 . 7 0 89 4 0 . 7 0 33 3 9 . 2 7 24 8 1 . 3 1 72 0 7 5 4 . 3 4 59 4 6 5 7 5 . 1 8 70 ° 1 5 ' 2 3 . 1 3 7 7 " N 14 8 ° 1 2 ' 5 6 . 5 3 5 9 " W 0. 0 0 N/ A 0. 0 0 0. 0 0 41 6 0 . 2 4 95 . 7 7 70 . 1 7 23 . 7 4 27 3 . 8 9 Pr o j e c t i o n t o T D Pa g e 5 o f 5 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: 02/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 09-09A PTD: 222-157 API: 50-029-20232-01-00 FINAL LWD FORMATION EVALUATION LOGS (01/28/2023 to 02/05/2023) 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:2/9/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221570 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250/3500 Annular:N/A Valves:N/A MASP:2460 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 4 NA Test Fluid Water Inside BOP 0 NA FSV Misc 2 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2"NA Trip Tank P NA Annular Preventer 1 7 1/16" GK NA Pit Level Indicators P NA #1 Rams 1 Blind / Shears NA Flow Indicator P NA #2 Rams 1 2.0" Pipe / Slip NA Meth Gas Detector P NA #3 Rams 1 2-3/8" x 3-1/2" VBR P H2S Gas Detector P NA #4 Rams 1 2.0" Pipe / Slip NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"NA Time/Pressure Test Result HCR Valves 2 2-1/16"NA System Pressure (psi)NA Kill Line Valves 1 2-1/16"NA Pressure After Closure (psi)NA Check Valve 0 NA 200 psi Attained (sec)NA BOP Misc 2 2.0" Piper NA Full Pressure Attained (sec)NA Blind Switch Covers:All stations NA CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 12 NA ACC Misc 0 NA Manual Chokes 1 NA Hydraulic Chokes 1 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer NA #1 Rams NA Coiled Tubing Only:#2 Rams NA Inside Reel valves 1 NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:1.0 HCR Choke NA Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 02/07/23 03:36 Waived By Test Start Date/Time:2/9/2023 20:00 (date)(time)Witness Test Finish Date/Time:2/9/2023 21:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nabors This was a test following a single ram swap. The 2-3/8" Pipe / Slips were removed and 2-3/8" x 3-1/2" VBR rams were installed. N.W heeler / T. Henson Hilcorp North Slope, LLC J.Perl / R. Burnett PBU 09-09A Test Pressure (psi): nathan.wheeler@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2023-0209_BOP_Nabors_CDR2AC_ram-change_PBU_09-09A J. Regg; 6/12/2023 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 09-09A Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 50-029-20232-01-00 ADL 028327 ~12365 Conductor Surface Intermediate Production Scab Liner ~8956 77 2696 10851 610 ~12325 20" 13-3/8" 9-5/8" 7" 30 - 107 31 - 2726 29 - 10780 10081 ~ 10385 2460 30 - 107 31 - 2726 29 - 9115 Unknown 520 2670 5080 / 4760 5410 none 1530 5380 8150 / 6870 7240 10382 - 10667 MH-80 x 13CR x 13Cr80 27 - 101618770 - 9017 Structural 4-1/2" Baker Model D No SSSV 10039 / 8477 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY 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 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 222-157 ~8956 2/15/2023 8513 ~ 8773 By Samantha Carlisle at 2:25 pm, Jan 13, 2023 323-022 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002), ou=Users Reason: Signed for Bo York with Approval Date: 2023.01.13 13:57:45 -09'00' Eric Dickerman (4002) DSR-1/17/23 X MGR24JAN23 10-404 DLB 01/17/2023GCW 01/30/23 JLC 1/30/2023 1/30/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.01.30 14:26:43 -09'00' RBDMS JSB 020223 Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Well Name:09-09A API Number:50-029-20232-01-00 Current Status:Shut in Rig:Coil Estimated Start Date:Feb 2023 Estimated Duration:3 days Regulatory Contact:Carrie Janowski First Call Engineer:Eric Dickerman (907) 564-4061 (O)(307) 250-4013 (M) Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M) Current Bottom Hole Pressure:3,295 psi @ 8,800’ TVD 7.3 PPGE | Taken 12/30/2022 Maximum Expected BHP:3,350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP Max. Anticipated Surface Pressure:2,470psi Based on 0.1 psi/ft. gas gradient Last SI WHP: 300psi Taken on 12/30/2022 Min ID:1.995” ID ID of 2-3/8” liner Max Angle:101 Deg @ 11,411’md taken from well plan Tie In Log:LWD from drilling 09-09A sidetrack Brief Well Summary: 09-09A is planned to be a horizontal Zone 2 producer from the Ivishak formation. The rig is expected to be moving off the well February 20, 2023, at which time service coil will move in and perform an extended add perf operation. Objectives: The objective of this procedure is to shoot Extended Addperfs for the initial perforations post sidetrack. Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. MU and RIH with drift nozzle to TD. 3. MU and RIH with GR/CCL/CBL and drift nozzle and log from TD to ~9,750’. 4. Flag pipe as appropriate per WSS for addperf runs. 5. Well should be a closed system. Ensure well is dead before POOH, and circulate a kill with 8.4ppg 1% KCl as necessary. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to estimated PBTD of 12,365’ = 287 bbls b. 7” tubing – 3,005’ X 0.0383bpf = 115 bbls c. 5-1/2” Tubing – (9,900 – 3,005’) X 0.0232bpf = 160 bbls d. 4-1/2” Tubing – (10,120’ – 9,900’) X 0.0152bpf = 4 bbl e. 2-3/8” Liner – (12,365’ – 10,120’) X 0.0039bpf = 9 bbl 6. POOH pumping pipe displacement and freeze protect tubing as needed. Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 7. Confirm good log data. 8. At surface, prepare for deployment of TCP guns. 9. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 10.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. f.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 11.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *Planned for 1.56” Halliburton Perfecta charges, max swell 1.74”, 3.62#/ft loaded weight. Perf Interval Perf Length Gun Length Weight of Gun (lbs) Comments Run 1 TBD ~500’ 500’ 1810 lbs (3.62ppf) Final lengths TBD after analyzing open hole and cement log data. BHAs will be limited to 500’ for any individual run. Run 2 TBD ~200’ 200’ 724 lbs (3.62ppf) Total ~700’ 700’ 12. RIH with perf gun and tie-in to coil flag correlation. Pick up and perforate interval per Perf Schedule above. g. Note any tubing pressure change in WSR. 13. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 17. Repeat steps 8 through 16 for subsequent runs to complete the desired perforated footage. 18. RDMO CTU. 19. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Sundry Change Form Make up PCE. Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Current Wellbore Schematic Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Proposed Wellbore Schematic Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Equipment Layout Diagram Well: 09-09A PTD: 222-157 API:50-029-20232-01-00 Sundry Change Form 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 Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-09A Hilcorp North Slope, LLC Permit to Drill Number: 222-157 Surface Location: 1698' FSL, 2' FEL, Sec. 02, T10N, R15E, UM, AK Bottomhole Location: 122' FNL, 2412' FWL, Sec. 01, T10N, R15E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair DATED this ___ day of January, 2023. Brett W. Huber, Sr. 13 1a. Contact Name:Sean McLaughlin Contact Email:sean.mclaughlin@hilcorp.comAuthorized Name: Monty Myers Authorized Title:Drilling Manager Authorized Signature: Contact Phone:907-223-6784 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 09-09A TVD:12365'8956' 12. Field/Pool(s): PRUDHOE BAY, PRUDHOE OILMD: ADL 028327 ADL 028327 February 1, 2023 4a. Surface: Top of Productive Horizon: Total Depth: 1698' FSL, 2' FEL, Sec. 02, T10N, R15E, UM, AK 1198' FNL, 1484' FEL, Sec. 01, T10N, R15E, UM, AK Kickoff Depth:10385'feet Maximum Hole Angle: 101 degrees Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:Surface:3340 2460 17.Deviated wells:16. Surface: x-y- Zone -718371 5943166 4 10. KB Elevation above MSL: GL Elevation above MSL: feet feet 54.0' 20.0' 15.Distance to Nearest Well Open to Same Pool: Cement Quantity, c.f. or sacks MD Casing Program: 10120'8546' 19.PRESENT WELL CONDITION SUMMARY Production 77 300 sx Arctic Set 10800 9133 10396 8782 Unknown 30 - 107 Surface 6100 Arctic Set 8770 - 9017 Seabed Report Drilling Fluid Program 5 20 AAC 25.050 requirements Shallow Hazard Analysis 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): 4.6# 2696 10382 - 10667 50-029-20232-01-00 185 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 122' FNL, 2412' FWL, Sec. 01, T10N, R15E, UM, AK Time v. Depth Plot 5 5 Drilling Program 8000' (To be completed for Redrill and Re-Entry Operations) 20" 13-3/8" Hyd 511 610 8513 - 9038 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 429' 18.Specifications Top - Setting Depth - Bottom Casing Weight Grade TVDHole Coupling Length TVD (including stage data) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft):Junk (measured): Casing Length Size MD 30 - 107 30 - 2726 30 - 2726 10851 9-5/8"1000 sx Class G, 300 sx Arctic Set, 250 sx Class G 29 - 10780 29 - 9115 Liner 7"10081 - 10691 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 Cement Volume Comm. 12365'8956'105 sx Class G3-1/4"2-3/8"L-80 2245' Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) 10396, 10404, 10492, 10502 By Anne Prysunka at 11:10 am, Dec 28, 2022 X 222-157 X X X DLB X DLB 01/03/2023 X X Concur DLB X Sean McLaughlin for: Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311), ou=Users Date: 2023.01.04 08:38:57 -09'00' Sean McLaughlin (4311) BOPE test to 3500 psi. MGR11JAN2023 2460 Alternate plug placement approved per 20 AAC 25.112(i). DSR-1/11/23 Brett W. Huber, Sr. GCW 01/13/23JLC 1/13/2023 1/13/23 To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin Drilling Engineer Date: December 27, 2022 Re: PBU 09-09A Permit to Drill Approval is requested for drilling a CTD sidetrack from well PBU 09-09 with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for 09-09A Producer: See 09-09 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. A hang off spool will be added to the wellhead to accommodate a temporary 3-1/2" drilling liner. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A 3-1/2" drilling liner will be run to 9850' to cover up large ID tubing. A 3-1/2" x 7" HEW whipstock will be set with the rig and then cemented in place. A 2.80" dual string window +10’ of formation will be milled out of the 7" and 9-5/8” casing strings. The well will kick off drilling in the Ivishak Zone 2 and target Zone 2 sands. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner and cemented in place. The well will be selectively perforated. 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 09-09 Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: Pre-Rig Work 1 Slickline Dummy WS drift and caliper to PBTD (~10,396) 2 Fullbore MIT- IA to 2500 psi 3Valve ShopBleed wellhead pressures down to zero. 4Valve ShopBleed production, flow and GL lines down to zero and blind flange. 5Valve Shop Pre-CTD wellhead and tree work (install hang off spool with side outlet valves for monitoring pressure, leak-tight master) 6 Operations Remove wellhouse and level pad. Rig Work - (Estimated to start in February 2023): 1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,460 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Testing of 3-1/2” liner rams required d. Load pits with drilling fluid e. Open well and ensure zero pressure 2. Run Whipstock and cement in place a. Kill well prior to picking up whipstock assembly b. 3-1/2” x 7” HEW to be set at 10,382’ 0 ROHS c. Lay down WS running tools and PU a blind sub, stinger, and a nozzle d. Pump 13 bbls of 15.8 ppg cement past the whip and lay in 2 bbl above the WS. e. Wash cement to 10’ above top of the WS tray. POOH 1:1 3. Run 3-1/2” drilling liner to 9850’. a. Hang off liner in tubing spool 4. Mill 2.80” single string window (out of 7” and 9-5/8”) plus 10’ of rathole a. Swap 3-1/2” liner rams for 2-3/8” liner rams. Perform ram test b. Top of window (whipstock pinch point) at 10,385’ MD. c. Mill window with straight motor d. Hold 11.0 ppg MPD while milling window 5. Drill – Build & Lateral a. 2-3/8” BHA with GR/RES / Bi-center Bit (3.25”) b. 40° DLS build section – 301’ MD / Planned TD 10,686’ MD c. 12° DLS lateral section – 1679’ MD / Planned TD 12,365’ 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 6. Run and Cement 2-3/8” L-80 solid liner a. Have 2” safety joint with TIW valve ready to be picked up while running liner b. Release from liner and come out of hole. c. Make up cementing BHA and sting into liner shoe. Swap the well over to 2% KCl. d. Cement liner with 23 bbls, 15.3 ppg Class G (TOC to TOL).* 7. Recover 3-1/2” drilling liner and perforate a. Swap to 3-1/2” liner rams b. Pull 3-1/2” drilling liner c. Perforate ~700’ of Zone 2 sand with 1.56” guns. i. If cement quality is suspect, perforating will be done post rig after running a CBL d. Freeze protect well from ~2200’ MD (min) e. RDMO Post Rig: 1. V: Valve & tree work (remove hang off spool) 2. S: Set LTP* (if necessary) 3. S: Set live LGLVs 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. DLBpressure. Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom holegp g q py p pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surfacep Managed Pressure Drilling:gg PTD 222-157 Sundry 323-009 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 (10,385’ MD - 8773’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)5,018 psi 5,018 psi 11 B Annular friction - ECD (psi/ft)935 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3,923 psi 3,923 psi 8.6 B+C Mud + ECD Combined 4,858 psi 3,923 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 160 psi 1,095 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,340 psi at 8,800’ TVD (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2460 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 9.8 ppg 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 9.8 ppg KWF to be used for liner deployment. 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 3.25” hole for the entirety of the production hole section. Liner Program: x 2-3/8”, 4.6#, L-80 solid/cemented liner: 10120’ MD – 12365’ MD (2245’ 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 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. MPD Pressure at the Planned Window (10,385’ MD - 8773’ TVD) 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 3-1/2” rams required for running the drilling liner x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole. x 2” safety joint will be utilized while running 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” 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 101°. Inclination at kick off point is 30°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 8000’ x Distance to nearest well within pool – 429’ 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. Perforating: x ~700’ planned perforation in Z2 using 1.56” guns Anti-Collision Failures: x WP08 fail AC scan with 09-33A and 09-42 x 09-33A is an operable producer with close approach near the 2-3/8” shoe in the Ivishak. No Action to be taken. x 09-42 has been plugged. No action to be taken. Hazards: x PBU DS09 is an H2S pad. o The highest recorded H2S well on the pad was from 09-05A (1,361 ppm) in 2000. o Last recorded H2S on 09-09 was 400 ppm in 2022 x No fault crossings expected. x Low lost circulation risk. Sean McLaughlin CC: Well File Drilling Engineer Joseph Lastufka 907-223-6784 6WDQGDUG3URSRVDO5HSRUW 'HFHPEHU 3ODQ $ZS +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ 3ODQ $ 85508700885090009150930094509600True Vertical Depth (300 usft/in)-2400 -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 -750 -600 -450 -300 -150 0 150 300 450Vertical Section at 300.00° (300 usft/in)09-09A wp08 tgt109-09A wp08 tgt209-09A wp08 tgt309-09A wp08 tgt409-09A wp08 tgt5105001080009-099 5/8" TOW2 7/8" x 4 1/4"105001100011 5 0 0 1200012365 09-09A wp08KOP : Start Dir 9º/100' : 10385' MD, 8772.69'TVD : 0° RT TFStart Dir 40º/100' : 10405' MD, 8789.78'TVDStart Dir 39.99º/100' : 10611' MD, 8892.83'TVDStart Dir 12º/100' : 10686' MD, 8891.07'TVDStart Dir 12.01º/100' : 11311' MD, 8893.41'TVDStart Dir 12º/100' : 11411' MD, 8879.57'TVDTotal Depth : 12364.66' MD, 8955.56' TVDHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: 09-09Ground Level: 20.00+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005943165.960718370.860 70° 14' 50.3040 N 148° 14' 8.7225 WSURVEY PROGRAMDepth From Depth To Survey/Plan Tool133.00 10385.00 1 : Camera based gyro multisho (09-09) 3_CB-Film-GMS10385.00 12364.66 09-09A wp08 (09-09A) 3_MWDFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 09-09, True NorthVertical (TVD) Reference:KB @ 54.00usft (12 : 09 11/10/1976 00:00)Measured Depth Reference:KB @ 54.00usft (12 : 09 11/10/1976 00:00)Calculation Method:Minimum CurvatureProject:Prudhoe BaySite:09Well:Plan: 09-09Wellbore:09-09ADesign:09-09A wp08CASING DETAILSTVD TVDSS MD SizeName8772.70 8718.70 10385.01 9-5/8 9 5/8" TOW8955.56 8901.56 12364.66 2-7/8 2 7/8" x 4 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 10385.00 30.38 63.27 8772.69 2387.26 3796.50 0.00 0.00 -2094.24 KOP : Start Dir 9º/100' : 10385' MD, 8772.69'TVD : 0° RT TF2 10405.00 32.18 63.27 8789.78 2391.93 3805.77 9.00 0.00 -2099.93 Start Dir 40º/100' : 10405' MD, 8789.78'TVD3 10611.00 91.41 349.99 8892.83 2545.41 3843.63 40.00 -75.00 -2055.98 Start Dir 39.99º/100' : 10611' MD, 8892.83'TVD4 10686.00 91.22 319.99 8891.07 2612.58 3812.29 39.99 -90.00 -1995.25 Start Dir 12º/100' : 10686' MD, 8891.07'TVD5 10886.00 88.89 296.10 8890.88 2734.94 3655.94 12.00 -95.48 -1798.666 11036.00 88.94 314.10 8893.74 2820.82 3533.74 12.00 90.01 -1649.907 11211.00 89.01 293.10 8896.91 2917.11 3388.82 12.00 -90.00 -1476.258 11311.00 94.99 282.68 8893.41 2947.77 3293.89 12.00 -60.03 -1378.71 Start Dir 12.01º/100' : 11311' MD, 8893.41'TVD9 11411.00 100.88 293.25 8879.57 2978.19 3199.83 12.01 59.98 -1282.04 Start Dir 12º/100' : 11411' MD, 8879.57'TVD10 11599.66 89.15 312.72 8862.95 3080.08 3043.39 12.00 120.01 -1095.6111 11624.66 89.20 315.72 8863.31 3097.51 3025.48 12.00 89.07 -1071.3812 11889.66 89.85 283.93 8865.56 3227.61 2798.52 12.00 -88.99 -809.7813 12064.66 90.22 304.93 8865.45 3299.59 2640.08 12.00 89.00 -636.5814 12364.66 54.22 304.93 8955.56 3460.48 2409.70 12.00 180.00 -356.63 Total Depth : 12364.66' MD, 8955.56' TVD 2100 2275 2450 2625 2800 2975 3150 3325 3500 3675 3850 4025 4200 4375 4550 4725 4900 5075 South(-)/North(+) (350 usft/in)1750 1925 2100 2275 2450 2625 2800 2975 3150 3325 3500 3675 3850 4025 4200 West(-)/East(+) (350 usft/in) 09-09A wp08 tgt5 09-09A wp08 tgt4 09-09A wp08 tgt3 09-09A wp08 tgt2 09-09A wp08 tgt1 80008 2 50 850087509000913309-099 5/8" TOW 2 7/8" x 4 1/4"895609-09A wp08KOP : Start Dir 9º/100' : 10385' MD, 8772.69'TVD : 0° RT TF Start Dir 40º/100' : 10405' MD, 8789.78'TVD Start Dir 39.99º/100' : 10611' MD, 8892.83'TVD Start Dir 12º/100' : 10686' MD, 8891.07'TVD Start Dir 12.01º/100' : 11311' MD, 8893.41'TVD Start Dir 12º/100' : 11411' MD, 8879.57'TVD Total Depth : 12364.66' MD, 8955.56' TVD CASING DETAILS TVD TVDSS MD Size Name 8772.70 8718.70 10385.01 9-5/8 9 5/8" TOW 8955.56 8901.56 12364.66 2-7/8 2 7/8" x 4 1/4" Project: Prudhoe Bay Site: 09 Well: Plan: 09-09 Wellbore: 09-09A Plan: 09-09A wp08 WELL DETAILS: Plan: 09-09 Ground Level: 20.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 5943165.960 718370.860 70° 14' 50.3040 N 148° 14' 8.7225 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: 09-09, True North Vertical (TVD) Reference: KB @ 54.00usft (12 : 09 11/10/1976 00:00) Measured Depth Reference:KB @ 54.00usft (12 : 09 11/10/1976 00:00) Calculation Method:Minimum Curvature 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 79'5HIHUHQFH 6LWH +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ 6WDQGDUG3URSRVDO5HSRUW :HOO :HOOERUH 3ODQ $ 6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH .%#XVIW 'HVLJQ $ZS 'DWDEDVH 1257+86&$1$'$ 0'5HIHUHQFH .%#XVIW 1RUWK5HIHUHQFH :HOO3ODQ 7UXH 0DS6\VWHP *HR'DWXP 3URMHFW 0DS=RQH 6\VWHP'DWXP 866WDWH3ODQH ([DFWVROXWLRQ 1$' 1$'&21&2186 3UXGKRH%D\1RUWK6ORSH81,7('67$7(6 $ODVND=RQH 0HDQ6HD/HYHO 8VLQJ:HOO5HIHUHQFH3RLQW 8VLQJJHRGHWLFVFDOHIDFWRU 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&HQWUH'LVWDQFH 3DVV $3% $3% &HQWUH'LVWDQFH3DVV $3% $3% &OHDUDQFH)DFWRU3DVV &HQWUH'LVWDQFH 3DVV (OOLSVH6HSDUDWLRQ 3DVV &OHDUDQFH)DFWRU 3DVV3ODQ &OHDUDQFH)DFWRU 3DVV6XUYH\WRROSURJUDP)URP XVIW 7R XVIW 6XUYH\3ODQ 6XUYH\7RRO B&%)LOP*06 $ZS B0:''HFHPEHU &203$663DJHRI 3UXGKRH%D\+LOFRUS1RUWK6ORSH//&$QWLFROOLVLRQ5HSRUWIRU3ODQ $ZS(OOLSVHHUURUWHUPVDUHFRUUHODWHGDFURVVVXUYH\WRROWLHRQSRLQWV6HSDUDWLRQLVWKHDFWXDOGLVWDQFHEHWZHHQHOOLSVRLGV&DOFXODWHGHOOLSVHVLQFRUSRUDWHVXUIDFHHUURUV&OHDUDQFH)DFWRU 'LVWDQFH%HWZHHQ3URILOHV 'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ 'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG'HFHPEHU &203$663DJHRI 0.001.002.003.004.00Separation Factor10500 10625 10750 10875 11000 11125 11250 11375 11500 11625 11750 11875 12000 12125 12250 12375 12500 12625 12750Measured Depth (250 usft/in)04-4309-33A09-42A09-4209-42APB109-0809-09No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: 09-09 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 20.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005943165.960718370.86070° 14' 50.3040 N148° 14' 8.7225 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 09-09, True NorthVertical (TVD) Reference: KB @ 54.00usft (12 : 09 11/10/1976 00:00)Measured Depth Reference:KB @ 54.00usft (12 : 09 11/10/1976 00:00)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-12-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool133.00 10385.00 1 : Camera based gyro multisho (09-09) 3_CB-Film-GMS10385.00 12364.66 09-09A wp08 (09-09A) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)10500 10625 10750 10875 11000 11125 11250 11375 11500 11625 11750 11875 12000 12125 12250 12375 12500 12625 12750Measured Depth (250 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria10385.00 To 12364.66Project: Prudhoe BaySite: 09Well: Plan: 09-09Wellbore: 09-09APlan: 09-09A wp08CASING DETAILSTVD TVDSS MD Size Name8772.70 8718.70 10385.01 9-5/8 9 5/8" TOW8955.56 8901.56 12364.66 2-7/8 2 7/8" x 4 1/4" Well Slimhole 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" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" Pipe/Slips 12.6 ft CL 2" 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 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2" Pipe/Slips 7-1/16" 5k Mud Cross 2" Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" 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. X X 222-157 X Prudhoe Bay Unit PBU 09-09A Prudhoe Oil WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 09-09AInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2221570PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes4 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 unitYes Directional plan view included, no land plat.8 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) (For servNA15 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 DS09-09A is an inzone sidetrack. Parent well integrity established.18 Conductor string providedYes DS09-09A is an inzone sidetrack. Parent well integrity established.19 Surface casing protects all known USDWsYes DS09-09A is an inzone sidetrack. Parent well integrity established.20 CMT vol adequate to circulate on conductor & surf csgYes DS09-09A is an inzone sidetrack. Parent well integrity established.21 CMT vol adequate to tie-in long string to surf csgYes DS09-09A is an inzone sidetrack. Parent well integrity established. Fully cemented liner.22 CMT will cover all known productive horizonsYes DS09-09A is an inzone sidetrack. Parent well integrity established.23 Casing designs adequate for C, T, B & permafrostYes CDR2 has adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 322-723 approved25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan identifies 09-33A is another operable inzone producer. No HSE risk. 09-42 is plug26 Adequate wellbore separation proposedYes All drilling on BOPE.27 If diverter required, does it meet regulationsYes MPD drilling, liner running with KWF.28 Drilling fluid program schematic & equip list adequateYes 1 CT packoff, 1 annular, 4 ram stack29 BOPEs, do they meet regulationYes 5000 psi stack tested to 3500 psi30 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 DS 09 is an H2S pad. Monitors required.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No DS 09 wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate12/29/2022ApprMGRDate1/11/2023ApprDLBDate1/3/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 1/13/2023
