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223-092
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 . 50 - 1 0 3 - 2 0 0 5 6 - 0 1 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 A - 1 0 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 3/ 1 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 71 5 0 TV D 61 5 0 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : Di r e c t i o n a l S u r v e y , C B L 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 3/ 1 / 2 0 2 4 61 0 0 7 1 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ 5 M D _ F i n a l . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ F i n a l _ A P _ R u n 1 . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ F i n a l _ A P _ R u n 2 . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ F i n a l _ A P _ R u n 3 . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ F i n a l _ A P _ R u n 4 . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ F i n a l _ A P _ R u n 5 . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 ### # # # # #### # # # # # El e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R T _ F i n a l _ A P _ R u n 6 . l a s 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 2 M D _ F i n a l . c g m 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 2 T V D _ F i n a l . c g m 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 5 M D _ F i n a l . c g m 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 5 T V D _ F i n a l . c g m 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ A P _ F i n a l . c g m 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 2 M D _ F i n a l . p d f 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 2 T V D _ F i n a l . p d f 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 5 M D _ F i n a l . p d f 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ 5 T V D _ F i n a l . p d f 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R T _ A P _ F i n a l . p d f 38 5 4 5 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 1 o f 4 2A - , 10 A _ R T _ 5 M D _ F i n a l . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 0 3 - 2 0 0 5 6 - 0 1 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 A - 1 0 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 3/ 1 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 71 5 0 TV D 61 5 0 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A D e f i n i t i v e S u r v e y s NA D 2 7 . p d f 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A D e f i n i t i v e S u r v e y s NA D 2 7 . t x t 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A D e f i n i t i v e S u r v e y s NA D 8 3 . p d f 38 5 4 5 ED Di g i t a l D a t a DF 3/ 1 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A D e f i n i t i v e S u r v e y s NA D 8 3 . t x t 38 5 4 5 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 69 8 4 6 5 6 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ C O R R E L A T I O N P A S S GU N # 1 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 69 0 1 6 6 4 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ C O R R E L A T I O N P A S S GU N # 2 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 68 2 6 6 5 7 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ C O R R E L A T I O N P A S S GU N # 3 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 68 0 4 6 6 5 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ C O R R E L A T I O N P A S S GU N # 4 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 69 7 9 6 8 3 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 : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ S H O O T I N G P A S S G U N #1 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 69 0 3 6 7 7 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ S H O O T I N G P A S S G U N #2 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 68 2 6 6 6 1 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ S H O O T I N G P A S S G U N #3 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 68 0 6 6 6 6 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ P E R F _ 2 6 F E B 2 4 _ S H O O T I N G P A S S G U N #4 . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 57 7 4 7 0 2 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R B T _ 2 6 F E B 2 4 _ P r o c e s s e d L o g . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 57 7 4 7 0 2 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 A - 10 A _ R B T _ 2 6 F E B 2 4 _ R a w . l a s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ P E R F _ 2 6 F E B 2 4 . p d f 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ P E R F _ 2 6 F E B 2 4 _ i m g . t i f f 38 5 8 0 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a 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 . 50 - 1 0 3 - 2 0 0 5 6 - 0 1 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 A - 1 0 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 3/ 1 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 71 5 0 TV D 61 5 0 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y 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 : 3/ 1 / 2 0 2 4 Re l e a s e D a t e : 11 / 2 7 / 2 0 2 3 DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R B T _ 2 6 F E B 2 4 . p d f 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R B T _ 2 6 F E B 2 4 _ i m g . t i f f 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 10 A _ R B T _ 2 6 F E B 2 4 _ P r o c e s s e d L o g . d l i s 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 10 A _ R B T _ 2 6 F E B 2 4 _ P r o c e s s e d L o g _ V 2 . p d f 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 10 A _ R B T _ 2 6 F E B 2 4 _ P r o c e s s e d L o g _ V 2 . t i f 38 5 8 0 ED Di g i t a l D a t a DF 3/ 4 / 2 0 2 4 E l e c t r o n i c F i l e : 2 A - 1 0 A _ R B T _ 2 6 F E B 2 4 _ R a w . d l i s 38 5 8 0 ED Di g i t a l D a t a DF 8/ 1 4 / 2 0 2 4 66 3 2 6 9 4 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : 4 9 8 8 _ C P A I _ 2 A - 10 A _ P P R O F _ 0 8 - A u g u s t _ 2 0 2 4 . l a s 39 4 5 2 ED Di g i t a l D a t a DF 8/ 1 4 / 2 0 2 4 E l e c t r o n i c F i l e : 4 9 8 8 _ C P A I _ 2 A - 1 0 A _ P P R O F _ 0 8 - Au g u s t _ 2 0 2 4 . p d f 39 4 5 2 ED Di g i t a l D a t a Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a 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 . 50 - 1 0 3 - 2 0 0 5 6 - 0 1 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 A - 1 0 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 3/ 1 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 0 9 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 71 5 0 TV D 61 5 0 Cu r r e n t S t a t u s 1- O I L 1/ 1 3 / 2 0 2 6 UI C No Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Tu e s d a y , J a n u a r y 1 3 , 2 0 2 6 AO G C C P a g e 4 o f 4 1/ 1 4 / 2 0 2 6 M. G u h l 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7150'feet None feet true vertical 6150' feet None feet Effective Depth measured 7150'feet 6744', 6897' feet true vertical 6150' feet 5813', 5938'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6930' MD 5966' TVD Packers and SSSV (type, measured and true vertical depth) 6744' MD 6897' MD N/A 5813' TVD 5938' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 324-139 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Vam Top PxB 17# TNT Packer Packer: Vam Top PxB 17# TNT Packer SSSV: None Adam Klem Adam.Klem@conocophillips.com 263-4529Staff RWO/CTD Engineer 6801-6856', 6909-6919', 6934-6965' 5859-5905', 5949-5957', 5970-5995' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 130 Gas-Mcf MDSize 106" 625 1180178 179 measured TVD 7" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-092 50-103-20056-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025570 Kuparuk River Field /Kuparuk River Oil Pool KRU 2A-10A Plugs Junk measured Length Production Liner 6655' 7095' Casing 5799' 6133' 6690' 7130' 2828' 106'Conductor Surface Intermediate 16" 9-5/8" 71' 2863' 2773' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:15 pm, Mar 27, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.03.27 07:02:07-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem RBDMS JSB 040325 DSR-4/2/25 CDW 03/28/2025 JJL 5/6/25 Page 1/1 2A-10 Report Printed: 3/25/2025 Daily STIM Report ORIG SPUD DATE: [ 1/30/1986 ] DRLG RIG RELEASE: [ 2/8/1986 ] ON PRODUCTION: [ ] DAYS FROM SPUD: [ 13,945.00 ] REPORT # [ 1] REPORT DATE: [ 4/4/2024] API / UWI 5010320056 Original KB/RT Elevation (ft) 123.00 Ground Elevation (ft) 87.99 Original Spud Date 1/30/1986 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# GKA.00298.E.W001.CO. RS Network/Order Number 10455520 AFE+Supp Amt (Cost) Daily Cost Total (Cost) 30,126.96 Cumulative Cost (Cost) 30,126.96 Weather Temperature (°F) Road Condition Wind Last 24hr Summary SET UP TANK FARM. RU UP ADP, BLENDER, CASTLE, 5 PUMPS & MISSILE. LOAD CASTLE WITH 92,000 LBS OF 16/20. IN PROGRESS 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 BECK, BRENT Supervisor Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 06:00 23:59 17.99 COMPZN, STIM RURD P SET UP TANK FARM. RU UP ADP, BLENDER, CASTLE, 5 PUMPS & MISSILE. LOAD CASTLE WITH 92,000 LBS OF 16/20. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/4/2024 06:00 4/4/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/5/2024 00:00 4/5/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/6/2024 00:00 4/6/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/9/2024 00:00 4/9/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/10/2024 00:00 4/10/2024 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 4/9/2024 06:00 4/9/2024 21:30 Page 1/1 2A-10 Report Printed: 3/25/2025 Daily STIM Report ORIG SPUD DATE: [ 1/30/1986 ] DRLG RIG RELEASE: [ 2/8/1986 ] ON PRODUCTION: [ ] DAYS FROM SPUD: [ 13,946.00 ] REPORT # [ 2] REPORT DATE: [ 4/5/2024] API / UWI 5010320056 Original KB/RT Elevation (ft) 123.00 Ground Elevation (ft) 87.99 Original Spud Date 1/30/1986 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# GKA.00298.E.W001.CO. RS Network/Order Number 10455520 AFE+Supp Amt (Cost) Daily Cost Total (Cost) 15,012.30 Cumulative Cost (Cost) 45,139.26 Weather Temperature (°F) Road Condition Wind Last 24hr Summary BEGIN LOADING SEAWATER VIA TRUCK FROM CPF-2. SET SUPPORT TANKS. BEGIN PROCESS OF INSTALLING TREE SAVER. IN PROGRESS 24hr Forecast SET TREE SAVER. RU IRON TO WELLHEAD. RU SUPPORT TANKS & OA AND IA POP OFFS. General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 BECK, BRENT Supervisor Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 10:00 10.00 COMPZN, STIM RURD P STAND BY FOR SEAWATER TRUCK AVALIBILTY 10:00 23:59 13.99 COMPZN, STIM RURD P BEGIN LOADING SEAWATER VIA TRUCK FROM CPF-2. SET SUPPORT TANKS. BEGIN PROCESS OF INSTALLING TREE SAVER Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/4/2024 06:00 4/4/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/5/2024 00:00 4/5/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/6/2024 00:00 4/6/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/9/2024 00:00 4/9/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/10/2024 00:00 4/10/2024 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 4/9/2024 06:00 4/9/2024 21:30 Page 1/1 2A-10 Report Printed: 3/25/2025 Daily STIM Report ORIG SPUD DATE: [ 1/30/1986 ] DRLG RIG RELEASE: [ 2/8/1986 ] ON PRODUCTION: [ ] DAYS FROM SPUD: [ 13,947.00 ] REPORT # [ 3] REPORT DATE: [ 4/6/2024] API / UWI 5010320056 Original KB/RT Elevation (ft) 123.00 Ground Elevation (ft) 87.99 Original Spud Date 1/30/1986 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# GKA.00298.E.W001.CO. RS Network/Order Number 10455520 AFE+Supp Amt (Cost) Daily Cost Total (Cost) 2,500.00 Cumulative Cost (Cost) 47,639.26 Weather Temperature (°F) Road Condition Wind Last 24hr Summary HEAT WATER TO 120 DEGREES. RIGGED UP OIL STATES TREE SAVER. JOB DELAYED DUE TO EMPLOYEE PERSONEL ISSUES. NEW OIL STATES TECH WILL ARRIVE 4/9. IN PROGRESS 24hr Forecast CONTINUE JOB ON 4/9 WHEN NEW OIL STATES TECHNICIAN ARRIVES. General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 BECK, BRENT Supervisor Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 23:59 23.99 COMPZN, STIM RURD P HEAT WATER TO 120 DEGREES. RIGGED UP OIL STATES TREE SAVER. JOB DELAYED DUE TO EMPLOYEE PERSONEL ISSUES. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/4/2024 06:00 4/4/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/5/2024 00:00 4/5/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/6/2024 00:00 4/6/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/9/2024 00:00 4/9/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/10/2024 00:00 4/10/2024 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 4/9/2024 06:00 4/9/2024 21:30 Page 1/2 2A-10 Report Printed: 3/25/2025 Daily STIM Report ORIG SPUD DATE: [ 1/30/1986 ] DRLG RIG RELEASE: [ 2/8/1986 ] ON PRODUCTION: [ ] DAYS FROM SPUD: [ 13,950.00 ] REPORT # [ 4] REPORT DATE: [ 4/9/2024] API / UWI 5010320056 Original KB/RT Elevation (ft) 123.00 Ground Elevation (ft) 87.99 Original Spud Date 1/30/1986 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# GKA.00298.E.W001.CO. RS Network/Order Number 10455520 AFE+Supp Amt (Cost) Daily Cost Total (Cost) 365,787.97 Cumulative Cost (Cost) 413,427.23 Weather Temperature (°F) Road Condition Wind Last 24hr Summary PUMP MINI FRAC TO OBSERVE FOR CLOSURE & FLUID EFFICIENCY. FRAC SINGLE STAGE ZONE IN THE KUPARUK A SAND PER DESIGN WITH 95,185 LBS OF PROPPANT UP TO 7.41 PPG CONCENTRATION. FRAC COMPLETE & BEGIN RIGGING DOWN. 24hr Forecast General Remarks INITIAL T/I/OA/OOA= 650/1111/155/0 FINAL T/I/OA/OOA=1853/700/171/0 ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 BECK, BRENT Supervisor Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 COMPZN, STIM RURD P HALLIBURTON NIGHT CREW RAN 4" LINE FROM MISSILE TO THE FRONT YARD & SET UP EPRV MANIFOLD. 06:00 11:00 5.00 COMPZN, STIM RURD P WHILE WAITING ON OILSTATES REP TO ARRIVE. HALLIBURTON SWAP OUT WITH NIGHT CREW. RU FRONT YARD & WELL SUPPORT RIGGED UP SUPPORT SUPPORT TANKS & POP OFFS. LRS HEATED BRINE FLUID. 11:00 13:45 2.75 COMPZN, STIM RURD P OIL STATES REP ON LOCATION & CHECKED TOOL. COMPLETE RIGGING UP TO THE WELLHEAD. SPOT BRINE TRANSPORT. RUN REMAINING RESTRAINTS. RUN PRESSURE TRANSDUCER CABLES & CHECK COMMS. 13:45 14:00 0.25 COMPZN, STIM RURD P SAFETY MEETING WITH ALL INVOLVED PARTIES 14:00 15:15 1.25 COMPZN, STIM RURD P STAND BY FOR FUEL. PRIME UP PUMPS. TEST EPRV'S & TRIPS. PRESSURE TEST LINES TO 8000 PSI **PASS** 15:15 16:15 1.00 COMPZN, STIM RURD P BRING ON WATER & CHEMS. MIX TUB OF GEL. WALK LINES TO VERIFY READY TO PUMP DOWN HOLE. 16:15 16:45 0.50 COMPZN, STIM PUMP P EQUALIZE & OPEN THE WELL. BRING ON PUMPS UP TO 15 BPM & BEGIN MAKING X -LINK. STAGE INTO MINI FRAC 16:45 17:30 0.75 COMPZN, STIM PUMP P INTERVAL - MINI FRAC / WATCH FOR 45 MIN TO OBSERVE FOR CLOSURE AVG RATE: 23.7 BPM AVG SURFACE PRESSURE: 3225 psi MAX RATE: 25.07 BPM MAX SURFACE PRESSURE 3354 psi FRAC GRADIENT: 0.723 17:30 18:15 0.75 COMPZN, STIM PUMP P INTERVAL - #1 TOTAL STAGE CLEAN VOLUME (BBLS) - 1468 TOTAL PROPPANT PLACED (LBS) - 95,185 100 MESH (LBS) - 3200 16/20 (LBS) - 91,985 MAX PROP CONC (PPG) - 7.41 AVERAGE SURFACE (PSI) - 3156 AVG BHP (PSI) – N/A AVG RATE (BPM) - 23.1 18:15 20:15 2.00 COMPZN, STIM DMOB P BEGIN BLOWING DOWN IRON. BLEED IA DOWN TO 700 PSI. HAVE LRS RU ON TUBING AND FREEZE PROTECT WITH 20 BBLS OF DIESEL. 20:15 23:59 3.74 COMPZN, STIM DMOB P BEGIN RIGGING DOWN FRONT YARD & WORKING TOWARDS MISSILE. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) BRINE 20.0 20.0 DIESEL 20.0 20.0 SEAWATER 1,468.0 1,468.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/4/2024 06:00 4/4/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/5/2024 00:00 4/5/2024 23:59 FRAC Page 2/2 2A-10 Report Printed: 3/25/2025 Daily STIM Report ORIG SPUD DATE: [ 1/30/1986 ] DRLG RIG RELEASE: [ 2/8/1986 ] ON PRODUCTION: [ ] DAYS FROM SPUD: [ 13,950.00 ] REPORT # [ 4] REPORT DATE: [ 4/9/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/6/2024 00:00 4/6/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/9/2024 00:00 4/9/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/10/2024 00:00 4/10/2024 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 4/9/2024 06:00 4/9/2024 21:30 Page 1/1 2A-10 Report Printed: 3/25/2025 Daily STIM Report ORIG SPUD DATE: [ 1/30/1986 ] DRLG RIG RELEASE: [ 2/8/1986 ] ON PRODUCTION: [ ] DAYS FROM SPUD: [ 13,951.00 ] REPORT # [ 5] REPORT DATE: [ 4/10/2024] API / UWI 5010320056 Original KB/RT Elevation (ft) 123.00 Ground Elevation (ft) 87.99 Original Spud Date 1/30/1986 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# GKA.00298.E.W001.CO. RS Network/Order Number 10455520 AFE+Supp Amt (Cost) Daily Cost Total (Cost) 16,346.14 Cumulative Cost (Cost) 429,773.37 Weather Temperature (°F) Road Condition Wind Last 24hr Summary HALLIBURTON - RIGGED DOWN FRONT YARD, ALL 4" IRON & PUMPS FROM THE MISSILE. OIL STATES - RIGGED DOWN TREE SAVER, WELL SUPPORT - RIGGED DOWN TANKS & ALL 2" HARDLINE. JOB COMPLETE. READY FOR SLICKLINE 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 BECK, BRENT Supervisor Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 23:59 23.99 COMPZN, STIM DMOB P HALLIBURTON - RIGGED DOWN FRONT YARD, ALL 4" IRON & PUMPS FROM THE MISSILE. OIL STATES - RIGGED DOWN TREE SAVER, WELL SUPPORT - RIGGED DOWN TANKS & ALL 2" HARDLINE. JOB COMPLETE. READY FOR SLICKLINE Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) BRINE 20.0 DIESEL 20.0 SEAWATER 1,468.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/4/2024 06:00 4/4/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/5/2024 00:00 4/5/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/6/2024 00:00 4/6/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/9/2024 00:00 4/9/2024 23:59 FRAC HES Frac Equipment CLAYTON, GREG,Wells Supervisor 4/10/2024 00:00 4/10/2024 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 4/9/2024 06:00 4/9/2024 21:30 Sales Order# Prepared By: Keegan Lambe James Campbell Nannok Crew 0909264543 Interval 1 Kuparuk Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk. 2A-10 Conoco Phillips Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20056 Prepared for: Adam Klem April 9, 2024 A-Sand Formation Hybor G Table of Contents Section Page(s) Executive Summary Actual Design Interval Summary Fluid System-Proppant Summary Interval 1 Plots Appendix Well Summary Chemical Summary Planned Design Water Straps Water Analysis 4-9 Real-Time QC Wellbore Information Event Log Prejob Break Test 4-8 Fann 15 Min Test Interval 1 23 24 25 26 3 4 5 18 19 20 6 7 - 15 16 17 21 22 Conoco Phillips - 2A-10 TOC 2 62,150 gallons of 35# Hybor G 10,086 gallons of 35# Linear 1,000 gallons of Freeze Protect 91,000 pounds of Wanli 16/20 Ceramic 4,000 pounds of 100M 55,985 gallons of 35# Hybor G 5,684 gallons of 35# Linear 248 gallons of Freeze Protect 92,500 pounds of Wanli 16/20 Ceramic 3,200 pounds of 100M Thank you, Keegan Lambe Steven Sanders Technical Sales Advisor Senior Technical Professional Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Engineering Executive Summary On April 09, 2024 a stimulation treatment was performed in the A-Sand formation on the 2A-10 well in Harrison Bay County, AK. The 2A-10 was a 1 stage Vertical Plug and Perf Design. The proposed treatment consisted of: The actual treatment fully completed 1 of 1 stages. 0 stages were skipped, 0 stage screened out and 0 stages were cut short of design. The actual treatment consisted of: A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: MO-67 was run as fully concentrated product. All tanks were treated prior to pumping with BE-6. The DFIT and step rate test were not pumped per customer. All proppant was pumped from castle. One 100M bag was placed in the hopper. Post Frac, Little Red started freeze protect at 19:25 and completed at 19:46 . Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. Conoco Phillips - 2A-10 Executive Summary 3 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.30341494LEASE2A-10 SALES ORDEBHST (°F)LONG-150.0196573FORMATIONKuparukDATE Max Pressure (psi)7000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 WG-36 OPTIFLO-IIIOPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In-1-2 Freeze Protect Prime Up Pressure Test 5.0 1,000 248 6 61-3 Shut-In Shut-In-1-4 35# Linear DFIT 15.0 1,680 - 1.00 35.00 2.00 0.25 0.151-5 Shut-In Shut-In-1-6 35# Linear Step Rate Test 15.0 3,360 - 1.00 35.00 2.00 0.25 0.151-7 35# Hybor G Minifrac - Establish Fluid 15.0 8,400 5,484 131 131 2.20 1.00 0.60 35.00 2.00 0.25 0.151-8 35# Hybor G Minifrac - Treatment 25.0 8,350 8,366 199 199 2.20 1.00 0.60 35.00 2.00 0.25 0.151-9 35# Linear Minifrac - Flush 25.0 2,523 2,875 68 68 1.00 35.00 2.00 0.25 0.151-10 Shut-In Shut-In-1-11 35# Hybor G Establish Stable Fluid 15.0 8,400 3,198 76 76 2.20 1.00 0.60 35.00 2.00 0.25 0.151-12 35# Hybor G Pad 25.0 12,700 12,705 303 303 2.20 1.00 0.60 35.00 2.00 0.25 0.151-13 35# Hybor G Conditioning Pad 100M 1.00 25.0 4,000 4,026 96 99 4,000 3,200 2.20 1.00 0.60 35.00 2.00 0.25 0.151-14 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25.0 3,200 3,182 76 80 6,400 4,135 2.20 1.00 0.60 35.00 2.00 0.25 0.151-15 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 25.0 3,300 3,296 78 86 9,900 7,384 2.20 1.00 0.60 35.00 2.00 0.25 0.151-16 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25.0 3,600 3,583 85 98 14,400 12,333 2.20 1.00 0.60 35.00 2.00 0.25 0.151-17 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 25.0 3,700 3,671 87 106 18,500 17,354 2.20 1.00 0.60 35.00 2.00 0.25 0.151-18 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25.0 3,700 3,682 88 110 22,200 21,239 2.20 1.00 0.60 35.00 2.00 0.25 0.151-19 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25.0 2,800 4,792 114 145 19,600 29,540 2.20 1.00 0.60 35.00 2.00 0.25 0.151-20 35# Linear Flush 25.0 2,523 2,809 67 67 1.00 35.00 2.00 0.25 0.151-21 Shut-In Shut-In-73,236 61,917 1,474 1,575 95,000 95,185Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)CL-28M Losurf-300D MO-67 WG-36 OPTIFLO-III OPTIFLO-II BE-662,150 55,985 91,000 91,985 92,500(gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)10,086 5,684 4,000 3,200 3,200 Initial Design Material Volume 136.7 72.2 37.3 2,528.3 144.5 18.1 10.8-- - - Actual Design Material Volume 123.2 61.7 33.6 2,158.4 123.3 15.4 9.3-1,000 248 - - - Physical Material Volume Pumped 125 67 38 2178 180 30 9-- - - - - Physical Material Volume Deviance 1% 9% 13% 1% 46% 95% -3%---** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 121 61 36 2,203 121 15 ----** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance -2% -2% 7% 2% -2% 0% - ---50-103-200560909264543Liquid AdditivesDry Additives-Fluid Type35# Hybor G35# LinearSeawaterFreeze Protect-Proppant TypeWanli 16/20 Ceramic100M-----Interval 1A Sands@ 6909 - 6965 ft - °FConoco Phillips - 2A-10 Actual Design4 4/9/24 16:11 4/9/24 18:15 124 min 26.3 bpm 4,155 psi 23.1 bpm 3,207 psi 3,156 psi 1,813 hhp 655 psi 152 psi 318 psi 7.41 ppg 5 5 41 % 39 % 36 cP 90.4 F 9 Minifrac 23.670 bpm 3225 psi 25.07 bpm 3354 psi 1714 psi 0.723 psi/ft 1867 psi 1830 psi 1788 psi 91,985 lbs 3,200 lbs 95,185 lbs 95,185 lbs 55,985 gal 1,333 bbls 5,684 gal 135 bbls 0 gal 0 bbls 248 gal 6 bbls 12,705 gal 303 bbls 4,026 gal 96 bbls 22,206 gal 529 bbls 2,809 gal 67 bbls 3,198 gal 76 bbls 5,484 gal 131 bbls 8,366 gal 199 bbls 2,875 gal 68 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Adam Klem Greg Clayton Keegan Lambe Total Proppant Pumped* : Minifrac - Treatment Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) Flush Volume: Establish Stable Fluid Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Interval Status: Craig Karpinski James Campbell Diagnostic method Minifrac - Establish Fluid Volume: Minifrac Max Rate: Conditioning Pad Volume: Proppant Laden Fluid Volume: ISDP: Final Fracture Gradient: Final 10 min: Step Rate test and DFIT were not pumped per customer. The well was opened at 16:11 and the minifrac was pumped. After flushing the wellbore, pressure was observed from, 16:34 to 17:25. Crosslink was re-established prior to starting pad. Proppant was brought up slowly, all proppant was pumped from the castle. Interval pumped to design. The above pressure are all surface pressures, this well did not have a down hole gauge. Minifrac - Flush Volume: Proppant Summary Minifrac Average Pressure: Freeze Protect Volume: Average Visc: Average Temp: Max Rate: Max Surface Pressure: Interval Summary 2A-10 - Kuparuk - Interval 1 Interval Summary Start Date/Time: End Date/Time: Average Missile Pressure: Open Well Pressure: Initial OA Pressure: Average Surface Pressure: Average Rate: Max OA Pressure: Pumps Starting Stage: Pad Percentage Design Average Missile HHP: Pumps Ending Stage: Max Proppant Concentration: Pad Volume: Minifrac Max Surface Pressure: 100M Pumped: Final 15 min: Proppant in Formation: 35# Hybor G Volume: 35# Linear Volume: Seawater Volume: Final 5 min: Average pH: Minifrac Average Rate: Pump Time: Pad Percentage Actual Wanli 16/20 Ceramic Pumped: Conoco Phillips - 2A-10 Interval Summary 5 CustomerFormationLeaseAPIDateWell SummaryWanli 16/20 Ceramic 100MTotal Proppantrface PressRate Visc Temp pHrface PressRate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs13156 23.1 36 90.4 9.0 4155 26.3 1,333 5,684 135 248 6 61,917 1,474 91,985 3,200 95,185 Minimum1333 5684 135 248 6 61917 1474 91985 3200 95185 Average1333 5684 135 248 6 61917 1474 91985 3200 95185 Maximum1333 5684 135 248 6 61917 1474 91985 3200 95185 Wanli 16/20 Ceramic 100M Total ProppantPressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned1,480 10,086 240 0 0 1,000 24 73,236 1,744 91,000 4,000 95,000Recorded263 1.9 3 8 0.75 4155 26.3 1,333 5,684 135 0 0 248 6 61,917 1,474 91,985 3,200 95,185Weight Tickets92,500 3,200 95,700** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software calculations based on Total FluidFluidsProppantsFluidsProppantsTotal FluidFreeze ProtectFreeze ProtectAverage MaxSeawater35# Hybor G35# Linear35# Hybor G35# LinearIntervalAverage MaxSeawaterApril 09, 202450-103-200562A-10 KuparukConoco Phillips Conoco Phillips - 2A-10 Fluid System-Proppant Summary6 <-Paste Interval 1 Plots HerePressure Test - 4-94/9/202415:1015:1115:1215:1315:1415:1515:1615:174/9/202415:18Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)14131211Global Event Log11121314Intersection IntersectionPressure Test - Global Pressure Test - LocalsPressure Test - Max Pressure Test - 5 Minute15:09:46 15:09:5515:10:44 15:15:44TP TP1321 13208134 7878TPP TPP207.2 247.57974 7746IGKP IGKP25.00 80008000 8000PKP PKP1200 50.678000 8000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Apr-2024Sales Order #: 0909264543Well Description: 2A 10UWI: 50-103-20056Conoco Phillips - 2A-10 Interval 1 Plots7 <-Paste Interval 1 Plots HereePRV Test - 4/94/9/202414:5815:0015:0215:044/9/202415:06Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)10987Global Event Log78910Intersection IntersectionePRV Test - Primary IA ePRV Test - Primary TubingePRV Test - Secondary IA ePRV Test - Secondary Tubing14:57:49 14:59:5215:02:44 15:05:59TP TP359.2 992.81369 1343TPP TPP329.4 105.9139.6 167.6IGKP IGKP1000.0 1000010000 10000Conoco Phillips - 2A-10 Interval 1 Plots8 <-Paste Interval 1 Plots HereBlender Chemical Plot - Bucket Test 4-94/9/202415:2015:2515:3015:3515:4015:454/9/202415:50Time0.00.51.01.52.02.53.0A0123456BCL-28M Conc (gal/Mgal)Losurf-300D Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AABBAConoco Phillips - 2A-10 Interval 1 Plots9 <-Paste Interval 1 Plots HereTreatment Plot - MiniFrac4/9/202415:5016:0016:1016:2016:304/9/202416:40Time01000200030004000500060007000A0102030405060708090100B012345678910CTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)ABCC987Conoco Phillips - 2A-10 Interval 1 Plots10 Blender Chemical Plot - Minifrac4/9/202416:1516:2016:254/9/202416:30Time0.00.51.01.52.02.53.0A0123456BCL-28M Conc (gal/Mgal)Losurf-300D Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AABBA98Conoco Phillips - 2A-10 Interval 1 Plots11 ADP Chemical Plots - Minifrac4/9/202416:0516:1016:1516:2016:2516:304/9/202416:35Time01020304050607080WG-36 Conc (lb/Mgal)987Conoco Phillips - 2A-10 Interval 1 Plots12 Treatment Plot - Interval 014/9/202417:2017:3017:4017:5018:0018:104/9/202418:20Time01000200030004000A01020304050B012345678910CTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)ABCC20191817161514131211Conoco Phillips - 2A-10 Interval 1 Plots13 Blender Chemical Plot - Interval 014/9/202417:3017:4017:5018:004/9/202418:10Time0.00.51.01.52.02.53.0A0123456BCL-28M Conc (gal/Mgal)Losurf-300D Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AABBA20191817161514131211Conoco Phillips - 2A-10 Interval 1 Plots14 ADP Chemical Plots - Interval 014/9/202417:2017:3017:4017:5018:0018:104/9/202418:20Time01020304050607080WG-36 Conc (lb/Mgal)20191817161514131211Conoco Phillips - 2A-10 Interval 1 Plots15 Sales Order# - - - - - - - - - - Wellbore Information Fann 15 Minute Field Break Test Event Log Real-Time QC Well Summary Stimulation Treatment Appendix Chemical Summary Planned Design Water Straps Water Analysis Prepared for: Adam Klem April 9, 2024 Harrison Bay County, AK 0909264543 Conoco Phillips 2A-10 Interval 1 Kuparuk A-Sand Formation API: 50-103-20056 Conoco Phillips - 2A-10 Appendix 16 Interval Date Designed Proppant (lbs) Proppant in Formation (lbs) Designed Fluid (bbl) Vol Clean (bbl) Vol Slurry (bbl) Pad Percentage Design Pad Percentage Actual Proppant Aggressiv ness (lb/bbl Clean) Top Packer (ft) Bottom Packer (ft) Fluid System 1 4/9/2024 95,000 95,185 1,744 1474 1,575 40.9 39 174 6,909 6,965 Hybor G 2A-10 Interval Highlights Conoco Phillips - 2A-10 Well Summary 17 CustomerConoco Phillips FormationKuparukLease2A-10 API50-103-20056DateInterval Summary - Chemicals CL-28M Losurf-300D MO-67 WG-36 OPTIFLO-III OPTIFLO-II BE-6(gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)Prime Up00000001125 67 38 2178 180 30 9Total 125 67 38 2178 180 30 9w/o Prime Up125 67 38 2178 180 30 9Interval4/9/2024Dry AdditivesLiquid AdditivesConoco Phillips - 2A-10 Chemical Summary18 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.30341494LEASE2A-10 SALES ORDERBHST (°F)LONG-150.0196573FORMATIONKuparukDATE Max Pressure (psi)7000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In1:31:33 1-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:31:33 1-3 Shut-In Shut-In1:26:47 1-4 35# Linear DFIT 15 1,680 40 40 0:02:40 1:26:47 1.00 35.00 2.00 0.250.151-5 Shut-In Shut-In1:24:07 1-6 35# Linear Step Rate Test 15 3,360 80 80 0:05:20 1:24:07 1.00 35.00 2.00 0.250.151-7 35# Hybor G Minifrac - Establish Fluid 15 8,400 200 200 0:13:20 1:18:47 2.20 1.00 0.60 35.00 2.00 0.250.151-8 35# Hybor G Minifrac - Treatment 25 8,350 199 199 0:07:57 1:05:27 2.20 1.00 0.60 35.00 2.00 0.250.151-9 35# Linear Minifrac - Flush 25 2,523 60 60 0:02:24 0:57:30 1.00 35.00 2.00 0.250.151-10 Shut-In Shut-In0:55:06 1-11 35# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 0:55:06 2.20 1.00 0.60 35.00 2.00 0.250.151-12 35# Hybor G Pad 25 12,700 302 302 0:12:06 0:41:46 2.20 1.00 0.60 35.00 2.00 0.250.151-13 35# Hybor G Conditioning Pad 100M 1.00 25 4,000 95 100 4,000 0:03:59 0:29:40 2.20 1.00 0.60 35.00 2.00 0.250.151-14 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,200 76 83 6,400 0:03:20 0:25:41 2.20 1.00 0.60 35.00 2.00 0.250.151-15 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 25 3,300 79 89 9,900 0:03:34 0:22:22 2.20 1.00 0.60 35.00 2.00 0.250.151-16 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 3,600 86 101 14,400 0:04:03 0:18:47 2.20 1.00 0.60 35.00 2.00 0.250.151-17 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 25 3,700 88 108 18,500 0:04:20 0:14:44 2.20 1.00 0.60 35.00 2.00 0.250.151-18 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 3,700 88 112 22,200 0:04:29 0:10:25 2.20 1.00 0.60 35.00 2.00 0.250.151-19 35# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 2,800 67 87 19,600 0:03:31 0:05:55 2.20 1.00 0.60 35.00 2.00 0.250.151-20 35# Linear Flush 25 2,523 60 60 0:02:24 0:02:24 1.00 35.00 2.00 0.250.151-21 Shut-In Shut-In73,236 1,744 1,845 95,000Design Total (gal)Design Total (lbs)CL-28M Losurf-300D MO-67 WG-36 OPTIFLO-III OPTIFLO-II BE-662,15091,000(gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)10,0864,000Initial Design Material Volume 136.7 72.2 37.3 2,528.3 144.5 18.1 10.8-1,000-Whole Units to be ordered--CL-28M Losurf-300D MO-67 WG-36 OPTIFLO-III OPTIFLO-II BE-6-(gpm) (gpm) (gpm) ppm ppm ppm ppm-Max Additive Rate 2.3 1.1 0.8 36.8 2.1 2.1 0.2-Min Additive Rate4/9/24Liquid AdditivesDry Additives50-103-200560909264543Fluid Type35# Hybor G35# LinearSeawaterFreeze Protect----Proppant TypeWanli 16/20 Ceramic100M---Interval 1A Sands@ 6909 - 6965 ft - °F1:31:33 Conoco Phillips - 2A-10 Planned Design19 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Wichita CPF-2 108 21,000 500 110 108 21,000 5002 Wichita CPF-2 102 20,580 490 108 60 11,760 2803 Wichita CPF-2 102 20,580 490 105 10 1,890 454 Wichita CPF-2 102 20,580 490 112 9 1,722 415 Wichita CPF-2 98 19,740 470 108 9 1,722 41Gallons Barrels Gallons Barrels Gallons Barrels102,480 2,440 38,094 907 64,386 1,533Zones: 1Volume Needed for X Intervals (BBL):Number of Tanks Needed:000 0Tank Bottoms (BBL):488 488 488 488Pre-Job Barrel BottomsGeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips 2A-10 4/9/2024A-Sand0909264543Conoco Phillips - 2A-10 Water Straps 20 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe -Mycometer 1 N 1.024 85.0 2 30,290 1,200 2,400 800 3,200 32.0 7.50 7.80 9.40 Y 321 2 N 1.028 60.0 2 27,570 1,200 2,000 1,200 3,200 31.0 7.70 7.90 9.40 Y 288 3 N 1.026 60.0 5 33,390 1,200 2,400 800 3,200 31.0 7.60 7.60 9.20 Y 492 4 N 1.028 60.0 5 25,170 1,200 2,400 1,000 3,400 32.0 7.60 7.60 9.40 Y 276 5 N 1.028 60.0 5 30,290 1,200 2,600 600 3,200 31.0 7.80 7.70 9.40 Y 369 Average 1.027 65.0 4 24,452 1200 1,967 733 2,700 31.4 7.64 7.72 9.36 - 349 Maximum 1.028 85.0 5 33,390 1,200 2,600 1,200 3,400 32.0 7.80 7.90 9.40 - 492 Minimum 1.024 60.0 2 25,170 1,200 2,000 600 3,200 31.0 7.50 7.60 9.20 - 276 Range 0.004 25.0 3 8,220 0 600 600 200 1.0 0.30 0.30 0.20 - 216 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:2-A , 10 Water Source:CPF-2 Conoco Phillips - 2A-10 Water Analysis 4-9 21 Linear Linear XL XL XL Lip time Interval Stage Visc pH Temp °F pH min 1 Pad 34 8.7 90 9 2 Pad 35 8.7 95 9 1.5 1# 36 8.7 103 9 2 2# 36 8.4 95 9 2 36 Avg Linear Visc 3# 37 8.4 85 8.9 1.5 90.4 Avg XLTemp 4# 37 8.3 84 9 1 9.0 Avg XL pH 5# 37 8.3 90 9 2 6# 38 8.5 90 9 1.5 7# 37 8.7 82 9.1 1 Customer:ConocoPhillips Alaska, Inc. Wellname & #:2A-10 Date:April 9, 2024 Comments Comments Conoco Phillips - 2A-10 Real-Time QC 22 Conoco Phillips Kuparuk2A-10 50-103-20056*Exceeds 80% of burst pressure*Description OD (in) ID (in) Wt (#) GradeFUF (gal/ft)MD Top (ft)MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing3.5 2.992 9.3 L-80 0.3652 0 6,930 2,531 8,430Total6,9302,531Top MD (ft)Btm MD (ft)Average TVD (ft)Interval # Formation DescriptorAverage Interval Temperature (F)Toe6,909 6,965 5,9721A Sands-Displacement to Top Sleeve/Perf (gal)(BBLS)2,52360.1Interval #1Max Pressure (psi)7,000Isolation TypeCemented LinerTreatment TubularsCustomerFormationLeaseAPIDate4/9/2024Sleeve/Perf DepthConoco Phillips - 2A-10 Wellbore Information23 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate1 12:44:13 (04/09/24) Start Job Starting Job 0 15 14 01 12:44:13 (04/09/24) Next Treatment Treatment Interval 1 0 15 14 02 12:44:39 Other Fire up equipment 0 15 14 03 13:34:28 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 15 11 04 13:53:41 Other Ready Equipment 0 -12 3 05 14:14:14 Other Hi Cal - Low Cal Blender 0 -13 -8 06 14:28:46 Prime Pumps Prime Pumps 0.19 9 10 07 14:57:49 Pressure Test ePRV Test - Primary IA 0.19 359 329 08 14:59:52 Pressure Test ePRV Test - Primary Tubing 0.19 993 106 09 15:02:44 Pressure Test ePRV Test - Secondary IA 0.19 1369 140 010 15:05:59 Pressure Test ePRV Test - Secondary Tubing 0.19 1343 168 011 15:09:45 Pressure Test Pressure Test - Global 0.19 1321 207 012 15:09:54 Pressure Test Pressure Test - Locals 0.19 1320 247 013 15:10:43 Pressure Test Pressure Test - Max 0.19 8134 7974 014 15:15:43 Pressure Test Pressure Test - 5 Minute 0.19 7878 7746 015 15:18:38 Other Load Chemicals - Mix Gel 0.19 126 110 016 15:31:45 Other Stinger Checking Valves 0.19 102 75 017 15:41:08 Other Little Red equalize to IA 0.19 240 81 018 15:56:25 Other Equalize to well 0.19 262 286 019 15:57:53 Other First Gel Sample 100cP 0.19 2685 2650 020 16:07:27 Other Second Gel Sample 58cP 0.19 2461 2461 021 16:11:14 Open Well Open Well 0.19 655 615 022 16:18:35 Alarm Delta Stage At Top Perf = 7 65.63 2753 2753 15.123 16:26:08 Alarm Delta Stage At Top Perf = 8 196.59 3345 3346 24.424 16:34:08 Alarm Delta Stage At Top Perf = 9 395.86 1206 1727 2525 16:34:12 ISIP ISIP 396.95 1714 1168 19.626 16:38:26 Other Offline for Minifrac Data 398.41 1555 1328 027 17:25:14 Other Resuming pumping 398.41 1015 638 028 17:30:57 Alarm Delta Stage At Top Perf = 11 464.23 2456 2418 15.129 17:34:36 Alarm Delta Stage At Top Perf = 12 540.22 3299 3240 2530 17:46:44 Alarm Delta Stage At Top Perf = 13 842.99 3286 3237 24.931 17:50:42 Alarm Delta Stage At Top Perf = 14 940.87 3208 3157 24.832 17:53:56 Alarm Delta Stage At Top Perf = 15 1021.37 3226 3182 2533 17:57:22 Alarm Delta Stage At Top Perf = 16 1107.55 3178 3126 2534 18:01:19 Alarm Delta Stage At Top Perf = 17 1206.11 3208 3168 2535 18:05:34 Alarm Delta Stage At Top Perf = 18 1312.43 3289 3246 2536 18:07:25 Other Rate Bobble 1358.41 3303 3261 25.137 18:09:59 Alarm Delta Stage At Top Perf = 19 1422.92 3432 3373 2538 18:11:42 Other All Sand in Hopper 1465.44 3538 3480 2539 18:12:27 Other Cleaning Screws 1484.2 3513 3486 2540 18:15:43 Alarm Delta Stage At Top Perf = 20 1568.94 1117 1468 26.141 18:15:47 ISIP ISIP 1570.04 2048 1442 19.542 18:20:47 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 1570.33 1867 1145 043 18:25:46 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 1570.33 1830 1055 044 18:30:48 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 1570.33 1788 962 045 18:37:32 Shut In Well Shut In Well 1570.33 1682 849 046 18:47:31 Other Blow Down - Freeze protect surface lines 1570.33 475 496 047 19:19:02 Other Stinger Open Well 1570.33 81 81 048 19:20:55 Other Fanning out pump 1570.33 1586 5138 049 19:25:33 Other Little Red Freeze Protect Well 1570.33 1451 82 050 19:46:54 Other Little Red Freeze Protect Complete 1570.33 1683 3 0Event Log Conoco Phillips - 2A-10 Event Log24 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @0.0625Break Test 1Break Test 2Break Test 32-A , 10Stage(s):Break Test160Water Source:CPF 2ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:4/6/2024ConocoPhillipsProject No:EE.. BRITTONHydration Visc:3268Temperature was held at 140 degres for the duration of the testAll chemical concentrations below are in gallons per thousand / pounds per thousand5900Water pH:7.50a SandsHydration pH:7.80Temp 0FPHLOSURF-300DCL-28MMO-67Optiflo-IIIOptiflo-II1409.501.002.200.502.000.2505001000150020002500300035004000450000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:00 30:00 00:00 00:00 00:00 00:00 00:0000:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips - 2A-10 Prejob Break Test 4-825 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @2A-10Stage(s):1160Water Source:CPF-2ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:4/9/2024ConocoPhillipsProject No:EEzraa BrittonHydration Visc:5900Water pH:A-SandsHydration pH:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsPad2 ppg4 ppg6 ppg7 ppg8 ppgFluid is broken at 200cpConoco Phillips - 2A-10 Fann 15 Min Test Interval 126 Hydraulic Fracturing Fluid Product Component Information Disclosure 4/9/2024 Alaska HARRISON BAY 50-103-20056 CONOCOPHILLIPS 2A 10 -150.0196 70.3034 NAD83 none Oil 6150 61,669 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone SEAWATER (SG 8.52)Halliburton Base Fluid Water 7732-18-5 100.00%83.96612%525420 Density = 8.52 Halliburton BA-20 BUFFERING AGENT Halliburton Buffer Listed Below Listed Below 0 BC-140 X2 Halliburton Initiator Listed Below Listed Below 0 BE-6(TM) Bactericide Halliburton Microbiocide Listed Below Listed Below 0 CAT-3 ACTIVATOR Halliburton Activator Listed Below Listed Below 0 CL-28M CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0 LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA LVT-200 Baker Hughes Additive Listed Below Listed Below 0 NA MO-67 Halliburton pH Control Listed Below Listed Below 0 OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Listed Below 0 OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Listed Below 0 WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below Listed Below 0 Ceramic Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA SAND, COMMON BROWN 100 MESH Halliburton Proppant Listed Below Listed Below 0 NA Calcium Chloride Customer Salt Solution Listed Below Listed Below 0 NA Ingredients Listed Above Listed Above 0.00%0.00000%0 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00081%6 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00000%0 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00144%9 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00002%1 Acetic acid 64-19-7 30.00%0.00000%0 Ammonia 7664-41-7 1.00%0.00000%0 Ammonium acetate 631-61-8 100.00%0.00000%0 Ammonium chloride 12125-02-9 5.00%0.00000%0 Ammonium persulfate 7727-54-0 100.00%0.03356%210 Borate salts Proprietary 60.00%0.12693%795 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 C.I. pigment Orange 5 3468-63-1 1.00%0.00005%1 Calcium Chloride 10043-52-4 100.00%0.00000%0 Calcium magnesium carbonate 16389-88-1 1.00%0.00212%14 Corundum 1302-74-5 65.00%9.60844%60125 Crystalline silica, quartz 14808-60-7 100.00%0.52071%3259 Distillates (petroleum), hydrotreated light 64742-47-8 100.00%0.00000%0 EDTA/Copper chelate Proprietary 30.00%0.00000%0 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ethanol 64-17-5 60.00%0.04882%306 Ethylene glycol 107-21-1 30.00%0.00000%0 Gluteraldehyde 111-30-8 1.00%0.00212%14 Guar gum 9000-30-0 100.00%0.34806%2178 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.02441%153 Inorganic mineral 1317-65-3 5.00%0.01058%67 Inorganic mineral Proprietary 1.00%0.00212%14 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Magensium chloride 7786-30-3 0.01%0.00002%1 Magnesium nitrate 10377-60-3 0.01%0.00002%1 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00021%2 Monoethanolamine borate 26038-87-9 100.00%0.00000%0 Mullite 1302-93-8 45.00%6.65199%41625 Naphthalene 91-20-3 5.00%0.00407%26 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02441%153 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxyalkylated phenolic resin Proprietary 10.00%0.00814%51 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxylated phenolic resin Proprietary 30.00%0.01007%63 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00407%26 Polymer Proprietary 1.00%0.00212%14 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Potassium chloride 7447-40-7 5.00%0.01058%67 Sodium bisulfate 7681-38-1 0.10%0.00021%2 Sodium chloride 7647-14-5 5.00%4.19895%26276 Sodium hydroxide 1310-73-2 30.00%0.01929%121 Water 7732-18-5 100.00%0.19124%1197 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: Page 1/2 2A-10 Report Printed: 3/26/2025 Operations Summary (with Timelog Depths) Job: INITIAL COMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/4/2024 06:00 4/4/2024 23:59 17.99 COMPZN, STIM RURD P SET UP TANK FARM. RU UP ADP, BLENDER, CASTLE, 5 PUMPS & MISSILE. LOAD CASTLE WITH 92,000 LBS OF 16/20. 4/5/2024 00:00 4/5/2024 10:00 10.00 COMPZN, STIM RURD P STAND BY FOR SEAWATER TRUCK AVALIBILTY 4/5/2024 10:00 4/5/2024 23:59 13.99 COMPZN, STIM RURD P BEGIN LOADING SEAWATER VIA TRUCK FROM CPF-2. SET SUPPORT TANKS. BEGIN PROCESS OF INSTALLING TREE SAVER 4/6/2024 00:00 4/6/2024 23:59 23.99 COMPZN, STIM RURD P HEAT WATER TO 120 DEGREES. RIGGED UP OIL STATES TREE SAVER. JOB DELAYED DUE TO EMPLOYEE PERSONEL ISSUES. 4/9/2024 00:00 4/9/2024 06:00 6.00 COMPZN, STIM RURD P HALLIBURTON NIGHT CREW RAN 4" LINE FROM MISSILE TO THE FRONT YARD & SET UP EPRV MANIFOLD. 4/9/2024 06:00 4/9/2024 11:00 5.00 COMPZN, STIM RURD P WHILE WAITING ON OILSTATES REP TO ARRIVE. HALLIBURTON SWAP OUT WITH NIGHT CREW. RU FRONT YARD & WELL SUPPORT RIGGED UP SUPPORT SUPPORT TANKS & POP OFFS. LRS HEATED BRINE FLUID. 4/9/2024 11:00 4/9/2024 13:45 2.75 COMPZN, STIM RURD P OIL STATES REP ON LOCATION & CHECKED TOOL. COMPLETE RIGGING UP TO THE WELLHEAD. SPOT BRINE TRANSPORT. RUN REMAINING RESTRAINTS. RUN PRESSURE TRANSDUCER CABLES & CHECK COMMS. 4/9/2024 13:45 4/9/2024 14:00 0.25 COMPZN, STIM RURD P SAFETY MEETING WITH ALL INVOLVED PARTIES 4/9/2024 14:00 4/9/2024 15:15 1.25 COMPZN, STIM RURD P STAND BY FOR FUEL. PRIME UP PUMPS. TEST EPRV'S & TRIPS. PRESSURE TEST LINES TO 8000 PSI **PASS** 4/9/2024 15:15 4/9/2024 16:15 1.00 COMPZN, STIM RURD P BRING ON WATER & CHEMS. MIX TUB OF GEL. WALK LINES TO VERIFY READY TO PUMP DOWN HOLE. 4/9/2024 16:15 4/9/2024 16:45 0.50 COMPZN, STIM PUMP P EQUALIZE & OPEN THE WELL. BRING ON PUMPS UP TO 15 BPM & BEGIN MAKING X-LINK. STAGE INTO MINI FRAC 4/9/2024 16:45 4/9/2024 17:30 0.75 COMPZN, STIM PUMP P INTERVAL - MINI FRAC / WATCH FOR 45 MIN TO OBSERVE FOR CLOSURE AVG RATE: 23.7 BPM AVG SURFACE PRESSURE: 3225 psi MAX RATE: 25.07 BPM MAX SURFACE PRESSURE 3354 psi FRAC GRADIENT: 0.723 4/9/2024 17:30 4/9/2024 18:15 0.75 COMPZN, STIM PUMP P INTERVAL - #1 TOTAL STAGE CLEAN VOLUME (BBLS) - 1468 TOTAL PROPPANT PLACED (LBS) - 95,185 100 MESH (LBS) - 3200 16/20 (LBS) - 91,985 MAX PROP CONC (PPG) - 7.41 AVERAGE SURFACE (PSI) - 3156 AVG BHP (PSI) – N/A AVG RATE (BPM) - 23.1 4/9/2024 18:15 4/9/2024 20:15 2.00 COMPZN, STIM DMOB P BEGIN BLOWING DOWN IRON. BLEED IA DOWN TO 700 PSI. HAVE LRS RU ON TUBING AND FREEZE PROTECT WITH 20 BBLS OF DIESEL. Rig: HES Frac Equipment RIG RELEASE DATE 4/10/2024 Page 2/2 2A-10 Report Printed: 3/26/2025 Operations Summary (with Timelog Depths) Job: INITIAL COMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/9/2024 20:15 4/9/2024 23:59 3.74 COMPZN, STIM DMOB P BEGIN RIGGING DOWN FRONT YARD & WORKING TOWARDS MISSILE. 4/10/2024 00:00 4/10/2024 23:59 23.99 COMPZN, STIM DMOB P HALLIBURTON - RIGGED DOWN FRONT YARD, ALL 4" IRON & PUMPS FROM THE MISSILE. OIL STATES - RIGGED DOWN TREE SAVER, WELL SUPPORT - RIGGED DOWN TANKS & ALL 2" HARDLINE. JOB COMPLETE. READY FOR SLICKLINE Rig: HES Frac Equipment RIG RELEASE DATE 4/10/2024 DTTMSTART JOBTYP SUMMARYOPS 4/3/2024 SUPPORT OTHER OPERATIONS MEASURE SBHP @ 6925' RKB (3005 PSI) READY FOR FRAC. 4/4/2024 INITIAL COMPLETION SET UP TANK FARM. RU UP ADP, BLENDER, CASTLE, 5 PUMPS & MISSILE. LOAD CASTLE WITH 92,000 LBS OF 16/20. IN PROGRESS 4/5/2024 INITIAL COMPLETION BEGIN LOADING SEAWATER VIA TRUCK FROM CPF-2. SET SUPPORT TANKS. BEGIN PROCESS OF INSTALLING TREE SAVER. IN PROGRESS 4/6/2024 INITIAL COMPLETION HEAT WATER TO 120 DEGREES. RIGGED UP OIL STATES TREE SAVER. JOB DELAYED DUE TO EMPLOYEE PERSONEL ISSUES. NEW OIL STATES TECH WILL ARRIVE 4/9. IN PROGRESS 4/9/2024 INITIAL COMPLETION PUMP MINI FRAC TO OBSERVE FOR CLOSURE & FLUID EFFICIENCY. FRAC SINGLE STAGE ZONE IN THE KUPARUK A SAND PER DESIGN WITH 95,185 LBS OF PROPPANT UP TO 7.41 PPG CONCENTRATION. FRAC COMPLETE & BEGIN RIGGING DOWN. 4/10/2024 INITIAL COMPLETION HALLIBURTON - RIGGED DOWN FRONT YARD, ALL 4" IRON & PUMPS FROM THE MISSILE. OIL STATES - RIGGED DOWN TREE SAVER, WELL SUPPORT - RIGGED DOWN TANKS & ALL 2" HARDLINE. JOB COMPLETE. READY FOR SLICKLINE 4/11/2024 SUPPORT OTHER OPERATIONS TAGGED AT 6951' RKB. INSTALLED POST FRAC GLD. ST# 1 1'' BTM LATCH 1/4'' PORT OV (TRO 1200) 2688' RKB, ST # 2 1'' BTM LATCH 5/16'' OV 4371' RKB, ST# 3 1'' BTM LATCH DMY 6655' RKB. BLED IA DOWN AFTER EACH VLV SET, GOOD TEST. JOB COMPLETE. NOTE: NO EROSION NOTED ON LATCHES. 2A-10 Frac Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,951.0 2A-10A 4/11/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By ReV Reason: Open Sliding sleeve. 2A-10A 7/11/2024 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 106.0 106.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 35.0 2,862.7 2,772.0 36.00 J-55 BTC PRODUCTION 7" Tie- Back w/Patch 7 6.28 24.8 2,125.6 2,115.3 26.00 L-80 TCII PRODUCTION 7 6.28 35.0 6,690.1 5,770.6 26.00 J-55 BTC Liner 5.88 4.95 32.6 7,130.8 6,134.0 15.50 L-80 HYD 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 6,930.4 Set Depth … 5,966.5 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.5 24.5 0.00 Hanger 10.844 FMC Gen-V 3.5" x 11" Tubing hanger w/ H profile FMC Gen V 2.950 2,688.5 2,627.2 31.61 Mandrel – GAS LIFT 4.728 3.5" x 1" KBG 2-9 Hyd 563 SLB KBG 2-9 2.818 4,371.1 3,972.4 38.32 Mandrel – GAS LIFT 4.724 3.5" x 1" KBG 2-9 Hyd 563 SLB KBG 2-9 2.818 6,655.0 5,743.5 39.90 Mandrel – GAS LIFT 4.732 3.5" x 1" KBG 2-9 Hyd 563 SLB KBG 2-9 2.818 6,743.9 5,813.1 36.97 Packer 4.767 3.5" 9.2# Vam Top P x B 17# TNT packer S#4908812-01 HES TNT Packer 2.830 6,797.8 5,856.6 35.38 Nipple - X 3.920 3.5" x 2.813" HES X Nipple TN110 TxB S#3634088-03 HES X Nipple 2.813 6,844.9 5,895.3 34.03 Sleeve - Sliding 4.230 Baker CMU 2.813" x 3.5" C110 Vam Top S#108594598. (Opened 7/11/24) Baker CMU Sliding Sleeve 2.813 6,896.9 5,938.5 33.67 Packer 4.767 3.5" 9.2# Vam Top P x B 17# TNT packer S#4980684-01 HES TNT Packer 2.830 6,920.1 5,957.9 33.56 Nipple - X 3.920 3.5" x 2.813" HES X Nipple TN110 TC-II TxB HES X Nipple 2.813 6,929.9 5,966.1 33.52 Wireline Guide 4.255 3.5" WLEG IBT Box Top 2.993 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,688.5 2,627.2 31.61 1 GAS LIFT GLV BTM 1 1,200.0 4/11/2024 SLB Other 0.250 4,371.1 3,972.4 38.32 2 GAS LIFT OV BTM 1 0.0 4/11/2024 SLB Other 0.313 6,655.0 5,743.5 39.90 3 GAS LIFT DMY BTM 1 0.0 4/11/2024 SLB Other 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,608.6 5,708.2 41.15 XO Threads 5.900 X/over coupling 15.5# HYD 563 B x 17# HYD 521 P 4.892 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,801.0 6,856.0 5,859.3 5,904.6 2/28/2024 6.0 IPERF 60 deg ph; 6SPF 3-1/8" millennium EXPRS 6,909.0 6,919.0 5,948.6 5,957.0 2/28/2024 6.0 IPERF 60 deg ph; 6SPF 3-1/8" millennium EXPRS 6,934.0 6,965.0 5,969.5 5,995.3 2/28/2024 IPERF 60 deg ph; 6SPF 3-1/8" millennium EXPRS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,385.0 7,150.0 5,546.1 6,150.0 Production String 1 Cement 20 Bbls 11.5 PPG Tuned Pime Spacer 25 Bbls 15.3 PPG Primary Cement w/ BridgeMaker II int the middle 10 Bbls at 5 lb/bbl. Displaced w/ 9.8 PPG brine. Plug bumped on time. 2/25/2024 2A-10A, 3/26/2025 9:48:07 AM Vertical schematic (actual) Liner; 32.6-7,130.8 IPERF; 6,934.0-6,965.0 Nipple - X; 6,920.0 IPERF; 6,909.0-6,919.0 Packer; 6,896.9 Sleeve - Sliding; 6,844.9 IPERF; 6,801.0-6,856.0 Nipple - X; 6,797.8 Production String 1 Cement; 6,385.0 ftKB Packer; 6,743.9 PRODUCTION; 2,122.0-6,690.1 Mandrel – GAS LIFT; 6,655.0 CASING LEAK; 4,563.0 Mandrel – GAS LIFT; 4,371.1 SURFACE; 35.0-2,862.7 Mandrel – GAS LIFT; 2,688.5 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB CONDUCTOR; 35.0-106.0 Hanger; 24.5 KUP PROD KB-Grd (ft) 35.01 RR Date 2/8/1986 Other Elev… 2A-10A ... TD Act Btm (ftKB) 7,150.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005601 Wellbore Status PROD Max Angle & MD Incl (°) 45.00 MD (ftKB) 6,374.31 WELLNAME WELLBORE2A-10A Annotation Last WO: End Date 3/1/2024 H2S (ppm) 150 Date 11/20/2015 Comment ORIGINATED TRANSMITTAL DATE: 8/13/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4988 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4988 2A-10A 501032005601 Production Profile (PPROF) 8-Aug-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 223-092 T39452 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 10:04:18 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 From:Brooks, Phoebe L (OGC) To:Yearout, Paul Cc:Regg, James B (OGC) Subject:RE: Nabors 7ES 02-27-24 Date:Wednesday, April 10, 2024 3:32:23 PM Attachments:Nabors 7ES 02-27-24 Revised.xlsx Thank you for the information. I’ve attached a revised report changing the operation/test type to Initial Drilling for KRU 2A-10A, PTD #2230920. Please update your copy or let me know if you disagree. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Yearout, Paul <Paul.Yearout@nabors.com> Sent: Wednesday, April 10, 2024 5:58 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Re: Nabors 7ES 02-27-24 Yes it was. There are two in our well file this one has the correct Sundry and PTD. Thank you Paul Yearout 7ES Toolpusher Nabors Alaska Drilling Inc. Office 907-670- 6132 Cell 907-244-6322 paul.yearout@nabors.com From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Tuesday, April 9, 2024 11:36 AM To: Yearout, Paul <Paul.Yearout@nabors.com> Subject: [EXT]RE: Nabors 7ES 02-27-24 CAUTION! Email External to Nabors | ¡PRECAUCIÓN! Correo electrónico externo a Nabors | !ϪϳΑϧΗ ίέϭΑΎϧ ϰϟ· ϲΟέΎΧ ϲϧϭέΗϛϟ· ΩϳέΑ Was the window cut at the time of this test report (2/27/24)? .XSDUXN5LYHU8QLW$$ 37' revised report operation/test type Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Yearout, Paul <Paul.Yearout@nabors.com> Sent: Tuesday, April 9, 2024 7:22 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Re: Nabors 7ES 02-27-24 Good morning, Phoebe Sorry I'm a bit slow getting back to you. I hope the Well numbers are straight as well. I leave the slope tomorrow, but I work nights so if it isn't right I try to fix it before I go. Thank you Paul Yearout 7ES Toolpusher Nabors Alaska Drilling Inc. Office 907-670- 6132 Cell 907-244-6322 paul.yearout@nabors.com From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Thursday, April 4, 2024 2:25 PM To: Yearout, Paul <Paul.Yearout@nabors.com> Subject: [EXT]RE: Nabors 7ES 02-27-24 CAUTION! Email External to Nabors | ¡PRECAUCIÓN! Correo electrónico externo a Nabors | !ϪϳΑϧΗ ίέϭΑΎϧ ϰϟ· ϲΟέΎΧ ϲϧϭέΗϛϟ· ΩϳέΑ Paul, I was following up on this email. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (OGC) Sent: Thursday, March 28, 2024 2:23 PM To: Yearout, Paul <Paul.Yearout@nabors.com> Subject: RE: Nabors 7ES 02-27-24 Paul, PTD # 1860020 is for well KRU 2A-10 and sundry 323-029 does not belong to well 2A-10 or 2A-10A; please advise. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Yearout, Paul <Paul.Yearout@nabors.com> Sent: Friday, March 1, 2024 2:40 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Cc: greg.s.hobbs@conocophillips.com; Morales, Tony <Tony.Morales@nabors.com>; Turcotte, Matthew <Matthew.Turcotte@nabors.com>; Cozby, Kelly <Kelly.Cozby@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com> Subject: Nabors 7ES 02-27-24 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thank you Paul Yearout 7ES Toolpusher Nabors Alaska Drilling Inc. Office 907-670- 6132 Cell 907-244-6322 paul.yearout@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 2/27/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22230920 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2204 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T90 FP Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate FP System Pressure (psi)3050 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0NA200 psi Attained (sec)13 P BOP Misc 1 2 1/16" Gate P Full Pressure Attained (sec)105 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5 @ 2100 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 24 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/25/24 7:35 Waived By Test Start Date/Time:2/27/2024 9:00 (date) (time)Witness Test Finish Date/Time:2/27/2024 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Test BOPE with 3.5'' test joint 250/3500. Annular tested 250/3500 as per COP. Choke HCR valve regreased - tested good. Annular open and closed - tested good. Alarms tested. Tony Morales / Matt Turcotte ConocoPhillips Mark Adams / Kevin Barr KRU 2A-10A Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2024-0227_BOP_Nabors7ES_KRU_2A-10A 9 9 9 9 9 999 9 9 9 9 9 -5HJJ FP FP X X Choke HCR Annular FALSE Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _______________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 88' Total Depth: 3771' FSL, 1106' FEL, Sec 23, T11N, R8E, UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" H-40 106' 9-5/8" J-55 2773' 7" L-80 2116' 7" L-80 5799' 5.5" L-80 6134' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng None Oil-Bbl: Water-Bbl: 6744'MD/5813'TVD 6897'MD/5939'TVD Directional Survey, CBL Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 26 PACKER SET (MD/TVD) Liner ran on: 2/25/2024 33'MD/33'TVD to 7131'MD/6134'TVD Perforations: 6801'MD/5859'TVD to 6856'MD/5905'TVD 6909'MD/5949'TVD to 6919'MD/5957'TVD 6934'MD/5970'TVD to 6965'MD/5995'TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. Flow Tubing SIZE 24" DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): TUBING RECORD 6930'3.5" 25bbls 15.3 primary cement 33' 12-1/4"34' 8-1/2" 35' 35' 8-1/2" 26 7131' 25' 9.3 6690' 35' 35' 33' 2863' 7" 62.5 36 106' 25' 2126' 35' 5958105 1500'MD/1500'TVD SETTING DEPTH TVD 5957913 TOP HOLE SIZE AMOUNT PULLED 497287 497289 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. Kuparuk River Field/ Kuparuk River Oil Pool 6123'MD/5350'TVD BOTTOM CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, CASING WT. PER FT.GRADE CEMENTING RECORD 50-103-20056-01-00 KRU 2A-10A ADL 0025570 86-2 2/20/2024 7150' MD/6150'TVD 123' P.O. Box 100360 Anchorage, AK 99510-0360 498341 5960748 3963' FSL, 1108' FEL, Sec. 23, T11N, R8E, UM 2/22/20241326' FSL, 53' FEL, Sec 14, T11N, R8E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/1/2024 223-092 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 1:19 pm, May 02, 2024 RBDMS JSB 040924 Completed 3/1/2024 JSB GDSR-5/2/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface Base of Permafrost 1500 1500 6800 5857 6908 5946 6934 5968 7150 6148 (Miluveach) 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Adam klem Digital Signature with Date:Contact Email:adam.klem@cop.com Contact Phone:907-263-4529 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Top of Productive Interval (Kuparuk A4) Authorized Title: Drilling Engineer Operations Summary, Cementing Summary, Well Schematic, Directional Survey Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Top of Productive Interval (Kuparuk A3) Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Formation Name at TD: TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Top of Productive Interval (Kuparuk C4) Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Top of Permafrost If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Adam Klem Digitally signed by Adam Klem Date: 2024.03.28 08:55:40 -08'00' Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Liner 5.88 4.95 32.6 7,130.8 6,134.0 15.50 L-80 HYD 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 6,930.4 String Max No… 3 1/2 Set Depth … 5,966.5 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.5 24.5 0.00 Hanger 10.844 FMC Gen-V 3.5" x 11" Tubing hanger w/ H profile FMC Gen V 2.950 2,688.5 2,627.2 31.61 Mandrel – GAS LIFT 4.728 3.5" x 1" KBG 2-9 Hyd 563 SLB KBG 2-9 2.818 4,371.1 3,972.4 38.32 Mandrel – GAS LIFT 4.724 3.5" x 1" KBG 2-9 Hyd 563 SLB KBG 2-9 2.818 6,655.0 5,743.5 39.90 Mandrel – GAS LIFT 4.732 3.5" x 1" KBG 2-9 Hyd 563 SLB KBG 2-9 2.818 6,743.9 5,813.1 36.97 Packer 4.767 3.5" 9.2# Vam Top P x B 17# TNT packer S#4908812-01 HES TNT Packer 2.830 6,797.8 5,856.6 35.38 Nipple - X 3.920 3.5" x 2.813" HES X Nipple TN110 TxB S#3634088-03 HES X Nipple 2.813 6,844.9 5,895.3 34.03 Sleeve - Sliding 4.230 Baker CMU 2.813" x 3.5" C110 Vam Top S#108594598 Baker CMU Sliding Sleeve 2.813 6,896.9 5,938.5 33.67 Packer 4.767 3.5" 9.2# Vam Top P x B 17# TNT packer S#4980684-01 HES TNT Packer 2.830 6,920.1 5,957.9 33.56 Nipple - X 3.920 3.5" x 2.813" HES X Nipple TN110 TC-II TxB HES X Nipple 2.813 6,929.9 5,966.1 33.52 Wireline Guide 4.255 3.5" WLEG IBT Box Top 2.993 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,914.0 5,952.8 33.59 BALL & ROD 84" OAL Set in RHC plug in X- Nipple at 6921. 2/29/2024 6,920.0 5,957.8 33.56 TUBING PLUG RHC 2.81" X' Lock halliburto n 36318 93-01 2/29/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,688.5 2,627.2 31.61 1 GAS LIFT SOV BTM 1 2/29/2024 S#241 83-07 SLB Other 4,371.1 3,972.4 38.32 2 GAS LIFT DMY BTM 1 2/29/2024 S#241 83-10 SLB Other 0.000 6,655.0 5,743.5 39.90 3 GAS LIFT DMY Btm 1 2/29/2024 S#241 83-11 SLB Other 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,608.6 5,708.2 41.15 XO Threads 5.900 X/over coupling 15.5# HYD 563 B x 17# HYD 521 P 4.892 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,801.0 6,856.0 5,859.3 5,904.6 2/28/2024 6.0 IPERF 60 deg ph; 6SPF 3-1/8" millennium EXPRS 6,909.0 6,919.0 5,948.6 5,957.0 2/28/2024 6.0 IPERF 60 deg ph; 6SPF 3-1/8" millennium EXPRS 6,934.0 6,965.0 5,969.5 5,995.3 2/28/2024 IPERF 60 deg ph; 6SPF 3-1/8" millennium EXPRS 2A-10A, 3/21/2024 1:13:13 PM Vertical schematic (actual) Liner; 32.6-7,130.8 IPERF; 6,934.0-6,965.0 Nipple - X; 6,920.0 TUBING PLUG; 6,920.0 BALL & ROD; 6,914.0 IPERF; 6,909.0-6,919.0 Packer; 6,896.9 Sleeve - Sliding; 6,844.9 IPERF; 6,801.0-6,856.0 Nipple - X; 6,797.8 Production String 1 Cement; 6,385.0 ftKB Packer; 6,743.9 Mandrel – GAS LIFT; 6,655.0 PRODUCTION; 2,122.0-6,690.1 CASING LEAK; 4,563.0 Mandrel – GAS LIFT; 4,371.1 SURFACE; 35.0-2,862.7 Mandrel – GAS LIFT; 2,688.5 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB CONDUCTOR; 35.0-106.0 Hanger; 24.5 KUP PROD KB-Grd (ft) 35.01 RR Date 2/8/1986 Other Elev… 2A-10A ... TD Act Btm (ftKB) 7,150.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005601 Wellbore Status PROD Max Angle & MD Incl (°) 45.00 MD (ftKB) 6,374.31 WELLNAME WELLBORE2A-10A Annotation Last WO: End Date 3/1/2024 H2S (ppm) 150 Date 11/20/2015 Comment Page 1/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2024 12:00 2/10/2024 18:00 6.00 MIRU, MOVE MOB P Trucks on location moving Electrician shack, Tool shack ect...Set rig tongs on floor and Bridle up blocks. Set top drive in stump and BD steam and water lines. 0.0 0.0 2/10/2024 18:00 2/11/2024 00:00 6.00 MIRU, MOVE RURD P RDMO Perform rig down checklists, prep location for move, prep loads for transport to 2A pad 0.0 0.0 2/11/2024 00:00 2/11/2024 06:00 6.00 MIRU, MOVE MOB P Move Sub towards 2A-pad 0.0 0.0 2/11/2024 06:00 2/11/2024 12:00 6.00 MIRU, MOVE RURD P Rig on pad. prep for backing over 2A- 10. Spot over well back in pits, shim up rig and pits raise derrick continue working pre acceptance checklist. spot in kill tanks and cutting tanks. 0.0 0.0 2/11/2024 12:00 2/11/2024 14:30 2.50 MIRU, MOVE RURD P Move CDR3 service module from 2B- pad to 2A-pad. work post rig move checklist, Bring fluid into pits 0.0 0.0 2/11/2024 14:30 2/11/2024 20:30 6.00 MIRU, WELCTL RURD P Accept Rig @ 14:30pm. RU to kill well. Call pad operator to openSSSV. Inial PSI OA = cemented/ IA = 200 psi/ TBG = 350 psi 0.0 0.0 2/11/2024 20:30 2/11/2024 22:00 1.50 MIRU, WELCTL SEQP P PT surface lines to tiger tank 2500 psi. 0.0 0.0 2/11/2024 22:00 2/11/2024 23:00 1.00 MIRU, WELCTL DISP P Displace well with 285 bbls at 5 BPM/800 psi until clean seawater T/surface. 0.0 0.0 2/11/2024 23:00 2/11/2024 23:30 0.50 MIRU, WELCTL OWFF P Flow checked well- no flow. 0.0 0.0 2/11/2024 23:30 2/12/2024 00:00 0.50 MIRU, WELCTL MPSP P Set BPV. 0.0 0.0 2/12/2024 00:00 2/12/2024 02:00 2.00 MIRU, WHDBOP NUND P ND tree, function LDS, clean and inspect hanger threads, 10 turns with XO. Install blanking plug. 0.0 0.0 2/12/2024 02:00 2/12/2024 05:00 3.00 MIRU, WHDBOP NUND P Install DSA and set stack on wellhead. TQ flanges and install riser. 0.0 0.0 2/12/2024 05:00 2/12/2024 08:00 3.00 MIRU, WHDBOP OTHR P MU XO's and TIW's T/test joints, Mark donut joint for rams. Steam IBOP, BD top drive, MU sub to top drive. RU test hoses. Fill stack, choke manifold and purge all air from choke and 5.5 test joint. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 2/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2024 08:00 2/12/2024 18:00 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3,500 PSI for 5 Min each W/ 3 1/2" and 5 1/2" test joints. Test #1: Blind Rams, CMV 1,2,3, & 16, 2" Rig Floor Kill, IBOP, Outer Test SPool Valve. Test #2: Blind Rams, CMV, 4,5,& 6, HCR Kill, Inner Test Spool Valve, Manual IBOP, PU 5 1/2" TJ. Test #3: LPR, XT- 39 TIW, XT-39 dart valve. Test #4: UPR, CMV 7-8-9, Manual kill. Test #5: Super and manual adjustable choke (1,500 psi). Test #6: Annular, CMV 10- 11, Manual Kill. PU 3 1/2" TJ. Test #7: LPR, 3 1/2" FOSV. Test #8: UPR, CMV 12-13-15. Test #9: Annular, CMV 14. Test #10: HCR Choke. Test #11: Manual Choke. Perform accumulator test. Initial pressure = 3,000 PSI, after closure = 1550 PSI, 200 PSI attained = 14 sec, full recovery attained = 114 sec. UVBR's = 5 sec, Annular= 28 sec. Simulated blinds = 5 sec. LVBR’s = 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT, and flow show. Test Witness by AOGCC rep Brian D Bixby. 0.0 0.0 2/12/2024 18:00 2/12/2024 19:00 1.00 MIRU, WHDBOP RURD P Blowdown lines. Drain Stack. R/D testing equipment. Clean and clear rig floor. Prep floor to pull 3 1/2" Completions. 0.0 0.0 2/12/2024 19:00 2/12/2024 20:00 1.00 MIRU, WHDBOP MPSP P Pull slip-on blanking plug. Pull BPV. 0.0 6,138.0 2/12/2024 20:00 2/12/2024 21:30 1.50 SLOT, RPCOMP THGR P M/U and screw in landing joint to hanger neck threads. Set 10K down with Top Drive. BOLDS. PJSM. Unseated hanger @ 90K. Pull tubing hanger to rig floor @ 80K. 6,138.0 6,111.0 2/12/2024 21:30 2/12/2024 22:00 0.50 SLOT, RPCOMP RURD P L/D tubing hanger and pup. L/D landing joint. OWFF for 15-min. M/U head pin and circ. hose. 6,111.0 6,111.0 2/12/2024 22:00 2/12/2024 22:30 0.50 SLOT, RPCOMP CIRC P Circ BU. Pump 170 bbls 8.6# Seawater @ 5 BPM and 380 psi. Maintaining 1:1 returns. Measured 8.6# in and out. 6,111.0 6,111.0 2/12/2024 22:30 2/12/2024 22:45 0.25 SLOT, RPCOMP OWFF P OWFF. 6,111.0 6,111.0 2/12/2024 22:45 2/13/2024 00:00 1.25 SLOT, RPCOMP PULL P Pull 3 1/2" completions from 6,111' to midnight depth of 5,370'. 6,111.0 5,370.0 2/13/2024 00:00 2/13/2024 06:30 6.50 SLOT, RPCOMP PULL P Continue pulling 3 1/2" completions from 5,370' to surface. L/D21.22' cut joint. 5,370.0 0.0 2/13/2024 06:30 2/13/2024 11:30 5.00 SLOT, RPCOMP RURD P Clean and clear rig floor. Load the rest of the drill pipe. Install wear ring. Continue to lioad drill pipe, heavy weight and collars in shed to strap and tally. Load tools for drift/cleanout run. 0.0 0.0 2/13/2024 11:30 2/13/2024 12:00 0.50 SLOT, RPCOMP SVRG P Service rig 0.0 0.0 2/13/2024 12:00 2/13/2024 14:00 2.00 SLOT, WHPST BHAH P PU BHA #1 drift/cleanout (Window mill, Lower mill, flex joint, upper mill, bit sub, HWDP, MWD, 2 jts HWDP, drilling jars, 4 jts HWDP and 3 string magnets) 0.0 360.0 2/13/2024 14:00 2/13/2024 22:00 8.00 SLOT, WHPST PULD P RIH with BHA #1 F/360' T/6,130' RIH F/pipe shed 125K UP 108K DN 360.0 6,130.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 3/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/13/2024 22:00 2/13/2024 22:30 0.50 SLOT, WHPST PULD P Slack off F/6,130' T/6,145', tag @ 13K DN @ 6145.82' P/U 10', bring on pump @ 4 BPM 590 PSI, slack off tag @ 6146.29' W/25K DN x 3 6,130.0 6,146.0 2/13/2024 22:30 2/14/2024 00:00 1.50 SLOT, WHPST CIRC P Pump 33 BBL Hi vis sweep S/S Chase with 8.6 PPG seawater @ 6 BPM 1100 PSI Stand one stand back T/6,060' 6,146.0 6,060.0 2/14/2024 00:00 2/14/2024 00:30 0.50 SLOT, WHPST OWFF P B/D top drive, flow check 6,060.0 6,060.0 2/14/2024 00:30 2/14/2024 02:45 2.25 SLOT, WHPST TRIP P POOH F/6,060' T/360' 6,060.0 360.0 2/14/2024 02:45 2/14/2024 04:30 1.75 SLOT, WHPST BHAH P L/D BHA #1 Nothing on magnets 360.0 0.0 2/14/2024 04:30 2/14/2024 05:00 0.50 SLOT, WHPST BHAH P Clean clear rig floor 0.0 0.0 2/14/2024 05:00 2/14/2024 05:30 0.50 SLOT, WHPST BHAH P M/U BHA #2 TST-3 test packer 0.0 17.0 2/14/2024 05:30 2/14/2024 07:30 2.00 SLOT, WHPST PULD P RIH F/15' T/4457' Pick up singles from pipe shed 17.0 1,444.0 2/14/2024 07:30 2/14/2024 09:00 1.50 SLOT, WHPST TRIP P RIH F/1440 T/4457' From derrick 95K UP 87K DN 1,444.0 4,457.0 2/14/2024 09:00 2/14/2024 11:00 2.00 SLOT, WHPST PRTS P Set Test packer @ 4,452' C.O.E.,attempt to test 7" CSG above T/2000 PSI, pump 0.5 bpm and could only get up to 619 psi. Failed Test Move test packer up hole 1 stand to 4393' 4,388' C.O.E.. Set Test packer, pump 0.5 bpm with same results. 4,457.0 4,393.0 2/14/2024 11:00 2/14/2024 11:30 0.50 SLOT, WHPST PRTS P Trip out of hole 10 stands. Set Test packer at 3411' 3,406' C.O.E., Pump 0.5 bpm pressured up to 2005 psi in 18 strokes and held solid for 15 minutes. Good Test 4,393.0 3,411.0 2/14/2024 11:30 2/14/2024 14:00 2.50 SLOT, WHPST PRTS P Trip in hole 5 stands. Set Test packer at 3886'. 3,881' C.O.E. 80K UP 77K DN Test back side Pump 0.5 bpm pressured up to 2173 psi in 20 strokes and held solid for 15 minutes. Good Test 3,411.0 3,886.0 2/14/2024 14:00 2/14/2024 14:30 0.50 SLOT, WHPST PRTS P Trip in hole 3 stands. Set Test packer at 4171' 4,166' C.O.E., 3,886.0 4,171.0 2/14/2024 14:30 2/14/2024 17:30 3.00 SLOT, WHPST PRTS P Test packer at 4,171', 4,166' C.O.E., Pump 1.5 bpm pressured up to 2192 psi in 21 strokes and held solid for 15 minutes. Good Test. Perform 20 minute LOT: pump 0.5 bpm at 35 strokes pressure broke over at 600 psi and stayed flat. Shut In for 20 minutes and pressure held pretty solid only losing 34 psi in 20 minutes. Perform 20 minute LOT: pump 3.0 bpm at 22 strokes pressure hit 750 psi so we SIt. Shut In for 20 minutes and pressure held pretty solid only losing 99 psi in 20 minutes. 4,171.0 4,171.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 4/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/14/2024 17:30 2/14/2024 18:00 0.50 SLOT, WHPST PRTS P RIH F/4,171' T/4,330' Set packer @ 4,325 C.O.E. Attempt to test 7" casing, get to 630 PSI and break over, bad test 90K UP 83K DN 4,171.0 4,330.0 2/14/2024 18:00 2/14/2024 19:00 1.00 SLOT, WHPST PRTS P Pick up to 4,292', 4,287' C.O.E. Test 7" casing to 2000 PSI F/15 Min, OA = 0 PSI Good test Hole in 7" casing between 4,325' and 4,287' Bleed off PSI, open rams, slack off T/4,393', B/D all lines and top drive 90K UP 83K DN 4,330.0 4,393.0 2/14/2024 19:00 2/14/2024 21:00 2.00 SLOT, WHPST TRIP P RIH F/4,393' T/6,133' 105K UP 90K DN Blend mud at CDR pits to 10.5 PPG and haul to rig 4,393.0 6,133.0 2/14/2024 21:00 2/15/2024 00:00 3.00 SLOT, WHPST SLPC P Slip/cut 70' drilling line Grease crown, top drive, service rig Blend mud at CDR pits to 10.5 PPG and haul to rig 6,133.0 6,133.0 2/15/2024 00:00 2/15/2024 01:30 1.50 SLOT, WHPST COND P Blend mud at CDR pits to 10.5 PPG, build 8.6 PPG Hi vis spacer Prep pits for displacement Flush mud pumps with 10.5 PPG LSND 6,133.0 6,133.0 2/15/2024 01:30 2/15/2024 03:00 1.50 SLOT, WHPST DISP P Pump 33 BBLS 8.6 PPG Hi Vis spacer Chase with 280 BBLS 10.5 PPG LSND mud Pump @ 4 BPM 430 PSI Lots of sand back when 10.5 PPG mud back to surface 6,133.0 6,133.0 2/15/2024 03:00 2/15/2024 04:30 1.50 SLOT, WHPST CIRC P Circulate condition mud @ 3.9 BPM 444 PSI Start staging pumps up in 1/4 BBL increments to establish a loss rate 3.9 BPM/165 GPM 444 PSI 4.1 BPM/175 GPM 470 PSI 4.4 BPM/185 GPM 500 PSI 4.6 BPM/195 GPM 545 PSI 4.8 BPM/205 GPM 570 PSI 5.1 BPM/215 GPM 590 PSI 5.3 BPM/225 GPM 620 PSI Note: lots of sand come back until 6700 STKS after mud to surface 386 BBLS = 2.7 bottoms up Circulate a total of 447 BBLS after 10.5 PPG mud back 6,133.0 6,133.0 2/15/2024 04:30 2/15/2024 05:00 0.50 SLOT, WHPST OWFF P Flow check, B/D top drive 6,133.0 6,133.0 2/15/2024 05:00 2/15/2024 08:30 3.50 SLOT, WHPST TRIP P POOH F/6,133' T/17' UWT=120K DWT=95K 6,133.0 17.0 2/15/2024 08:30 2/15/2024 09:00 0.50 SLOT, WHPST BHAH P L/D TST-3 test packer Clean and clear rig floor 17.0 0.0 2/15/2024 09:00 2/15/2024 09:30 0.50 SLOT, WHPST RURD P Pull wear bushing 0.0 0.0 2/15/2024 09:30 2/15/2024 10:00 0.50 SLOT, WHPST NUND P Prep to ND BOP, BD choke and kill lines, pull riser, release chains from BOP 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 5/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/15/2024 10:00 2/15/2024 14:00 4.00 SLOT, WHDBOP WAIT T Waiting on a 7" CSG spear W/pack off from Baker in Dead Horse. At 14:00 HRS 7" spear on location Process 5 1/2" HYD 563 pipe 0.0 0.0 2/15/2024 14:00 2/15/2024 15:30 1.50 SLOT, WHDBOP NUND T Start to nipple down BOP, realize spear has wrong size pack off installed, call for correct pack off from Baker shop. Break spear apart, fill hole W/2 BBLS mud 0.0 0.0 2/15/2024 15:30 2/15/2024 17:00 1.50 SLOT, WHDBOP WAIT T Waiting on correct packoff from Baker in Dead Horse. Continue to process 5 1/2" HYD 563 and HYD 521 pipe in shed 0.0 0.0 2/15/2024 17:00 2/15/2024 17:30 0.50 SLOT, WHDBOP OWFF P With stack drained Flow check the well in accordance with the Corporate dispensation. No flow. Start operation inaccordance with Corporate Dispensation. 0.0 0.0 2/15/2024 17:30 2/15/2024 19:00 1.50 SLOT, WHDBOP NUND P Loosen choke/kill lines on stack, N/D BOP and rack back on stump 0.0 0.0 2/15/2024 19:00 2/15/2024 19:15 0.25 SLOT, WHDBOP RURD P Remove 13 5/8" 5K x 7 1/16" 5K DSA, check hanger void 0.0 0.0 2/15/2024 19:15 2/15/2024 20:30 1.25 SLOT, WHDBOP NUND P N/D TBG head adaptor and remove 2 1/16" gate valve from side outlet 0.0 0.0 2/15/2024 20:30 2/15/2024 22:45 2.25 SLOT, WHDBOP NUND P N/U FMC 5 1/2" casing head, install 2 1/16" side out let valve on IA 0.0 0.0 2/15/2024 22:45 2/15/2024 23:15 0.50 SLOT, WHDBOP PRTS P Test pack off and 11" 3K flange T/3000 PSI F/10 min 0.0 0.0 2/15/2024 23:15 2/16/2024 00:00 0.75 SLOT, WHDBOP NUND P N/U 13 5/8" x 11" 5K DSA, set test plug, get RKB to 5 1/2" CSG head lock downs 26.77' 0.0 0.0 2/16/2024 00:00 2/16/2024 01:00 1.00 SLOT, WHDBOP NUND P P/U stack off BOP stump and N/U BOP stack on wellhead 0.0 0.0 2/16/2024 01:00 2/16/2024 04:15 3.25 SLOT, WHDBOP NUND P Tighten nuts on BOP stack, DSA Install riser and tighten choke and kill line flanges up Hook up turn buckles and center stack 0.0 0.0 2/16/2024 04:15 2/16/2024 05:00 0.75 SLOT, WHDBOP RURD P Fill stack with water, purge air from lines, rig up to test BOP breaks 0.0 0.0 2/16/2024 05:00 2/16/2024 05:30 0.50 SLOT, WHDBOP BOPE P Test BOP breaks to 250/3500 PSI 5 min each. Off Cororation Dispensation. 0.0 0.0 2/16/2024 05:30 2/16/2024 07:00 1.50 SLOT, WHDBOP RURD P Rig down testing equipment, blow down lines Pull test plug, set wear ring, LD spear, pull test plug, set wear ring, run in LDS and LD running tool and single joint of drill pipe. 0.0 0.0 2/16/2024 07:00 2/16/2024 10:00 3.00 SLOT, WHDBOP BHAH P MU Whipstock BHA #2. T/353' Whipstock has 35K shear bolt and anchor has 10,695 LB shear pins 0.0 353.0 2/16/2024 10:00 2/16/2024 11:30 1.50 SLOT, WHDBOP TRIP P RIH F/353' T/1,389' Max running speed 60 FPM 54K UP 54K DN 353.0 1,389.0 2/16/2024 11:30 2/16/2024 12:00 0.50 SLOT, WHDBOP DHEQ P Shallow test MWD tool at 138 GPM 350 PSI Blow down top drive 1,389.0 1,389.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 6/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/16/2024 12:00 2/16/2024 16:00 4.00 SLOT, WHPST TRIP P RIH F/1,389' T/6058' 120K UP 100K DN 1,389.0 6,058.0 2/16/2024 16:00 2/16/2024 17:00 1.00 SLOT, WHPST WPST P Orient the WS to 45 LOHS Set down 12K at 6143' to set WS and saw a good shear, top of whipstock @ 6,123' PU 122K (only 2K above UPW) and no whipstock Rotate 8 RPM, TQ limit set at @ 3K to stall out rotatry, lug back up mills to whipstock, tool face go to 116° ROHS - 180° out from planned, P/U see 30K over pull then pick up clean Confirm tool face again at 123° ROHS with mills lugged up to whipstock We believe the WS was disconnected from the BHA and we just pushed it to bottom. 6,058.0 6,143.0 2/16/2024 17:00 2/16/2024 21:15 4.25 SLOT, WHPST CIRC P Circulate, stage up pumps 350 GPM or 12.1 ECD max to montior loss rate 223 GPM 940 PSI 11.3 ECD - no losses 250 GPM 1220 PSI 11.6 ECD down to 11.5 ECD - no losses 260 GPM 1300 PSI 11.6 ECD down to 11.5 ECD - no losses 270 GPM 1330 PSI 11.5 ECD - pump 38 BBL 11.7 PPG 85 Vis, weighted high vis sweep, max ECD = 12.0 when sweep coming up hole - no losses 280 GPM 1450 PSI 11.7 ECD down to 11.6 ECD - no losses 290 GPM 1540 PSI 11.8 ECD - down to 11.7 ECD - no losses 300 GPM 1620 PSI 11.8 ECD - no losses 310 GPM 1720 PSI 12-11.8 ECD - no losses 320 GPM 1800 PSI 11.9-12.0 ECD - no losses 330 GPM 1900 PSI 12.0 - 12.1 ECD - no losses 340 GPM 1990 PSI 11.9 - 12.1 ECD - no losses 350 GPM 2100 PSI 12.0 - 12.1 ECD - no losses 2 1/2 bottoms up before well cleaned up. Mud samples sent to D142 Geologist for analisis. 6,143.0 6,143.0 2/16/2024 21:15 2/16/2024 22:00 0.75 SLOT, WHPST OWFF T Flow check- slight flow, static in 15 min 6,143.0 6,143.0 2/16/2024 22:00 2/16/2024 22:30 0.50 SLOT, WHPST OTHR T Pump 15 BBL 12.5 PPG dry job B/D top drive 6,143.0 6,143.0 2/16/2024 22:30 2/17/2024 00:00 1.50 SLOT, WHPST TRIP T POOH F/6,143' T/3,200' 120K UP 100K DN 6,143.0 3,200.0 2/17/2024 00:00 2/17/2024 01:30 1.50 SLOT, WHPST TRIP T POOH F/3,200' T/331' 3,200.0 331.0 2/17/2024 01:30 2/17/2024 01:45 0.25 SLOT, WHPST OWFF T Flow check - static 331.0 331.0 2/17/2024 01:45 2/17/2024 03:30 1.75 SLOT, WHPST BHAH T L/D BHA #4 331.0 0.0 2/17/2024 03:30 2/17/2024 04:15 0.75 SLOT, WHPST BHAH T Clean clear rig floor 0.0 0.0 2/17/2024 04:15 2/17/2024 05:30 1.25 SLOT, WHPST BHAH T M/U BHA #5 T/80' whipstock hook MWD off set @ 216° 0.0 80.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 7/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/17/2024 05:30 2/17/2024 06:45 1.25 SLOT, WHPST TRIP T RIH F/80 T/2386' 69K UPW 65K DNW 80.0 2,386.0 2/17/2024 06:45 2/17/2024 07:15 0.50 SLOT, WHPST DHEQ T Shallow test MWD Stage Pumps to 130 GPM 560 PSI Blow down top drive 2,386.0 2,386.0 2/17/2024 07:15 2/17/2024 09:45 2.50 SLOT, WHPST TRIP T RIH F/2380' T/6134' 112K UPW 95K DNW Well still unloading sand at shakers, sand sample sent to D142 for analysis. 2,386.0 6,134.0 2/17/2024 09:45 2/17/2024 10:45 1.00 SLOT, WHPST FISH T At 6134' set down 5K. On third attemp hooked the WS at 6,129' then pulled 72K over string weight to shear WS release pin. 6,134.0 6,134.0 2/17/2024 10:45 2/17/2024 16:00 5.25 SLOT, WHPST TRIP T Pump dry job, BD TD, install stripping rubbers and POOH F/6073' T/80' at 60FPM 120K UPW 95K DNW 6,134.0 80.0 2/17/2024 16:00 2/17/2024 17:30 1.50 SLOT, WHPST BHAH T L/D BHA # 5 80.0 0.0 2/17/2024 17:30 2/17/2024 18:00 0.50 SLOT, WHPST BHAH T Clean and clear rig floor 0.0 0.0 2/17/2024 18:00 2/17/2024 19:30 1.50 SLOT, WHPST BHAH T M/U BHA #6 T/79' 6 1/8" junk mill clean out run 0.0 79.0 2/17/2024 19:30 2/17/2024 22:45 3.25 SLOT, WHPST TRIP T RIH F/79' T/6,075' 115K UP 98K DN 79.0 6,075.0 2/17/2024 22:45 2/17/2024 23:00 0.25 SLOT, WHPST WASH T Wash DN @ 2 BPM 350 PSI F/6,075' T/6,145' Tag at 6,145' W/5K DN 115K UP 98K DN 6,075.0 6,145.0 2/17/2024 23:00 2/17/2024 23:15 0.25 SLOT, WHPST CIRC T Work mills F/6,145' T/6,130' tag TBG stump 4 times and clean up, no increase in pump pressure, TQ go up to 3300 FT/LBS Circulate @ 4 BPM 590 PSI Rotate @ 10 RPM 2600-3000 TQ 105K Rot WT Stop rotary, set down on TBG stump 10K, trying to wash away fill if any inside TBG and between 3 1/2" x 7" 6,145.0 6,145.0 2/17/2024 23:15 2/18/2024 00:00 0.75 SLOT, WHPST CIRC T Circulate and rotate pipe to clean up casing work pipe F/6,140' T/6,070' Pump 29 BBL 11.1 PPG 78 vis sweep around Stage up to 340 GPM 1800 PSI 50 RPM 2500 FT/LBS TQ Note: no increase in sand/fines at shakers on first bottoms up, no increase in sand/fines at shakers when sweep come back 6,145.0 6,145.0 2/18/2024 00:00 2/18/2024 01:15 1.25 SLOT, WHPST CIRC T Cont circulating and rotating at 340 GPM 1770 PSI 50 RPM 2500 TQ Work pipe F/6,140' T/6,070' No real increase in sand/fines at shakers No losses observed at surface Stand one stand back T/6,072' 6,145.0 6,072.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 8/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/18/2024 01:15 2/18/2024 02:00 0.75 SLOT, WHPST OWFF T Flow check - slight flow, blow down top drive, continue to flow check Static in 20 min, gain .5 BBL 6,072.0 6,072.0 2/18/2024 02:00 2/18/2024 02:30 0.50 SLOT, WHPST CIRC T Pump 15 BBL 11.7 PPG dry job Blow down top drive 6,072.0 6,072.0 2/18/2024 02:30 2/18/2024 07:00 4.50 SLOT, WHPST TRIP T POOH F/6,072' T/79' 6,072.0 79.0 2/18/2024 07:00 2/18/2024 08:00 1.00 SLOT, WHPST BHAH T L/D BHA #6 79.0 0.0 2/18/2024 08:00 2/18/2024 10:30 2.50 SLOT, WHPST BHAH T Clean clear rig floor Mobilize BHA #7 components to rig floor MU BHA per Baker fishing hand and DD. Anchor pinned @ 14,260 Shear bolt = 35K 0.0 355.0 2/18/2024 10:30 2/18/2024 11:30 1.00 SLOT, WHPST TRIP T TIH from 355' to1961' @ 60FPM UPW=64K/DNW=61K 355.0 1,961.0 2/18/2024 11:30 2/18/2024 12:00 0.50 SLOT, WHPST DHEQ T Stage Pumps to 220 GPM 700 PSI Blow down top drive 1,961.0 1,961.0 2/18/2024 12:00 2/18/2024 15:00 3.00 SLOT, WHPST TRIP T TIH from1961' to 6,060' @ 60FPM max UPW=123K/DNW=100K 1,961.0 6,060.0 2/18/2024 15:00 2/18/2024 16:00 1.00 SLOT, WHPST WPST T Stage up pumps to 200 GPM/980 psi Orient tool face to 315 degrees 123K UP 100K DN Slack off to set anchor see anchor shear @ 10K DN, slack off to 15K DN P/U pull 15K over, S/O set DN 15K, P/U pull 15K over, slack off set DN 25K, cont to slack off shear off whipstock @ 38K DN = 62K on hook Set top of whipstock at 6123' LD one joint of drill pipe 6,060.0 6,123.0 2/18/2024 16:00 2/19/2024 00:00 8.00 SLOT, WHPST KOST P Off bottom parameters 4 BPM 800 PSI, 70/80/90 RPM 3400/3500/3600 TQ Rot WT = 108K Milling window in 7" casing F/6,123' T/6,139' 4.5 BPM 945 PSI 80 RPM 3300 - 4400 TQ 1-2K WOM at start, work up to 3-5K WOM 11.7 ECD Stall rotary @ 6,127.60' @ 12K 6,123.0 6,139.0 2/19/2024 00:00 2/19/2024 04:30 4.50 SLOT, WHPST KOST P Milling window in 7" casing F/6,139' T/6,156' 4.5 BPM 945 PSI 80 RPM 3300 - 4400 TQ 5-8K WOM 11.7 ECD Pump 23 BBL Hi Vis sweep at 6,156' 6,139.0 6,156.0 2/19/2024 04:30 2/19/2024 08:30 4.00 SLOT, WHPST DRLG P Drill rat hole F/6,156' T/6,181' with 6 1/2" window mill 4.5 BPM 945 PSI 80 RPM 945 PSI - 3600 TQ 7-10K WOM 11.7 ECD 6,156.0 6,181.0 2/19/2024 08:30 2/19/2024 09:30 1.00 SLOT, WHPST KOST P Drift window W/ mills as per Baker hand 123K UP 100K DN 80 RPM Function test BOP 6,181.0 6,181.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 9/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/19/2024 09:30 2/19/2024 10:00 0.50 SLOT, WHPST CIRC P Pump 23 BBL 115 Hi Vis sweep 3 BPM - 600 psi 4.5 BPM - 960 psi 6,181.0 3,181.0 2/19/2024 10:00 2/19/2024 10:30 0.50 SLOT, WHPST OWFF P Flow check well- no flow BD TD 6,181.0 6,181.0 2/19/2024 10:30 2/19/2024 11:00 0.50 SLOT, WHPST DISP P Pump dry jpob 10 BBL of 12.1 PPG 60 Vis slug BD TD 6,181.0 6,181.0 2/19/2024 11:00 2/19/2024 11:30 0.50 SLOT, WHPST TRIP P TOOH F/6181' T/4896' 123K UP 100K DN 6,181.0 4,896.0 2/19/2024 11:30 2/19/2024 12:00 0.50 SLOT, WHPST SVRG P Grease air slips 4,896.0 4,896.0 2/19/2024 12:00 2/19/2024 15:30 3.50 SLOT, WHPST TRIP P TOOH F/4896' T/331' 123K UP 100K DN 4,896.0 331.0 2/19/2024 15:30 2/19/2024 18:00 2.50 SLOT, WHPST BHAH P LD Window milling BHA #7 F/331' Function test blind rams 331.0 0.0 2/19/2024 18:00 2/19/2024 19:00 1.00 SLOT, WHPST WWWH P Flush stack with johnny wacker, blow down choke and kill lines 0.0 0.0 2/19/2024 19:00 2/19/2024 22:30 3.50 PROD1, DRILL BHAH P PJSM, M/U BHA #8 - 4 3/4" x 7" drilling BHA T/352' Note: tag up at 46', pull BHA out turn 7" reamer in line with low side of motor, contuine to M/U BHA 0.0 352.0 2/19/2024 22:30 2/20/2024 00:00 1.50 PROD1, DRILL TRIP P RIH F/352' T/2,255' 50K UP 50K DN 352.0 2,255.0 2/20/2024 00:00 2/20/2024 00:45 0.75 PROD1, DRILL TRIP P RIH F/2,255' T/3,205' 75K UP 75K DN 2,255.0 3,205.0 2/20/2024 00:45 2/20/2024 01:30 0.75 PROD1, DRILL CIRC P Attempt to fill pipe and circulate Pressure up to 2000 PSI - bleed off Blow air thru surface equipment make sure clear - good B/D top drive - flow check static 3,205.0 3,205.0 2/20/2024 01:30 2/20/2024 04:00 2.50 PROD1, DRILL TRIP T POOH F/3,205' T/352' 3,205.0 352.0 2/20/2024 04:00 2/20/2024 06:45 2.75 PROD1, DRILL BHAH T L/D BHA T/48' Kelly up and pump at HWDP - no circulation Stand back jar stand T/261' Kelly up and pump at 261' - unable, B/D top drive STD BK 1 STD HWDP, L/D X/over and well commander T/126' Attempt to pump - unable, B/D top drive L/D filter sub, Monel DC, MWD T/48' When breaking off MWD, it was dry Pick inspect motor,reamer and bit - able to pump B/D top drive 352.0 48.0 2/20/2024 06:45 2/20/2024 07:45 1.00 PROD1, DRILL BHAH T Install lift sub, pull up milk motor and check bearings L/D pony collar, stab and motor 48.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 10/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/20/2024 07:45 2/20/2024 10:30 2.75 PROD1, DRILL BHAH T M/U BHA #9 T/352 Pump thru motor 2 BPM 350 PSI ICP - 280 FCP P/U MWD tool, pump at 120 GPM 500 PSI confirm tools clear Cont M/U BHA MWD to motor offset = 162° 0.0 352.0 2/20/2024 10:30 2/20/2024 11:00 0.50 PROD1, DRILL SVRG P Service draw works rough neck and air slips. 352.0 352.0 2/20/2024 11:00 2/20/2024 14:00 3.00 PROD1, DRILL TRIP T RIH F/352' T/6120' Fill pipe with charge pump only 115K UP 91K DN 352.0 6,120.0 2/20/2024 14:00 2/20/2024 17:00 3.00 PROD1, DRILL CIRC P Exit window, circulate to make sure pipe clear 1 BPM 630 PSI Slide to 6181' PR=220 GPM @1350 PSI 25% return flow Mud Wt. in 10.5# Mud Wt. out 10.5 ECD 11.82 PPG. Drill ahead to 6181' increase PR to 275 GPM @ 1750 PSI 31% return flow ECD 11.8 PPG. 6,120.0 6,181.0 2/20/2024 17:00 2/20/2024 22:45 5.75 PROD1, DRILL DDRL P Drill F/ 6181' T/ 6408' @ 330 GPM, 2400 PSI. 40' slide interval. followed by 55' of rotation @ 50 RPM, 4K Tq. WOB=5-10. Mud Wt in 10.5#, Mud we out 10.5. Vis= 47. (ECD= 12.0-12.18). ROP>100 Ft/Hr. Pumping small volume nut plug pills 1every 150' (6 sacks in 140 Bbls.) Obtained good survey indicating 26' of separation from mother bore @ 6804' MD. 6,181.0 6,804.0 2/20/2024 22:45 2/21/2024 00:00 1.25 PROD1, DRILL WASH P Phase 3 called field wide @ 22:45 Hrs. Orient T/ hi side. Circ hole clean. Pump out F/ 6804', T/ 6249', @ 320 GPM, 2150 PSI, PUW=125K pumps on. Orient T/ 45* to left, cut pumps back to 80 GPM to keep bit from rotating, pull up into shoe. 6,804.0 6,249.0 2/21/2024 00:00 2/21/2024 00:30 0.50 PROD1, DRILL WASH T Pump out F/ 6249', T/ 6160'', @ 320 GPM, 2150 PSI, PUW=125K pumps on. Orient T/ 45* to left, cut pumps back to 80 GPM to keep bit from rotating, pull up through window, 5K bobble seen coming through window. Rack back stand T/ 6059' 6,249.0 6,059.0 2/21/2024 00:30 2/21/2024 16:00 15.50 PROD1, DRILL WAIT T Wait on weather. Circ @ 80 GPM. 6,059.0 6,059.0 2/21/2024 16:00 2/21/2024 16:30 0.50 PROD1, DRILL SFTY P Safety meeting for resuming drilling operations. 6,059.0 6,059.0 2/21/2024 16:30 2/21/2024 16:45 0.25 PROD1, DRILL TRIP P TIH F/6055' T/ 6124' 6,059.0 6,124.0 2/21/2024 16:45 2/22/2024 00:00 7.25 PROD1, DRILL DDRL P Resume with drilling establish drilling parameters. PUW=143K SOW=100K at the window. Ease on the pumps starting at 60 GPM working the rate up to 275 GPM while sliding back to 6408' Drill F/ 6408' T/ 6589'. @ 330 GPM, 2500 PSI, 12.0 ECD, Rotate F/6408' T/6439' @ 50 RPM, 4K Tq. Alternate between sliding and rotating as per DD. WOB=10-15K. ROP>100 Ft/Hr. 6,124.0 6,589.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 11/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2024 00:00 2/22/2024 05:00 5.00 PROD1, DRILL DDRL P Drill F/ 6589' T/ 6737'. @ 330 GPM, 2500 PSI, 12.0 ECD, ROT @ 50 RPM, 4K Tq. Alternate between sliding and rotating as per DD. WOB=10-20K. ROP>100 Ft/Hr. 6,589.0 6,737.0 2/22/2024 05:00 2/22/2024 14:00 9.00 PROD1, DRILL DDRL P Drill F/6737' T/7150 @ 330 GPM, 2500 PSI, 12.0 ECD, ROT @ 50 RPM, 4K Tq. Alternate between sliding and rotating as per DD. WOB=10-20K. ROP>100 Ft/Hr. Well on 6 BPH loss rate after drilling into C sands. 6,737.0 7,150.0 2/22/2024 14:00 2/22/2024 17:00 3.00 PROD1, DRILL CIRC P Circulate 2 x BUS with sweeps on bottom. 7,150.0 7,150.0 2/22/2024 17:00 2/22/2024 18:15 1.25 PROD1, TRIPCAS TRIP P TOOH F/7150' T/6059, PUW=145K. Hole taking slightly over calculated hole fill. Pulled clean off of bottom and pulled through window clean. 7,150.0 6,059.0 2/22/2024 18:15 2/22/2024 18:45 0.50 PROD1, TRIPCAS OWFF P B/D TD. OWFF - fluid level falling slightly in stack. 6,059.0 6,059.0 2/22/2024 18:45 2/23/2024 00:00 5.25 PROD1, TRIPCAS PULD P LDDP F/ 6059' T/ 1965', PUW=130K, SOW=98K. Hole taking slightly over calculated hole fill.. 6,059.0 1,965.0 2/23/2024 00:00 2/23/2024 02:30 2.50 PROD1, TRIPCAS PULD P Cont LDDP F/ 1965' T/ 352". PUW=65K. Hole taking slightly over calculated hole fill.. 1,965.0 352.0 2/23/2024 02:30 2/23/2024 03:15 0.75 PROD1, TRIPCAS TRIP P RIH w/ 15 stands out of derrick T/ 1784'. SOW=53K. 352.0 1,784.0 2/23/2024 03:15 2/23/2024 05:15 2.00 PROD1, TRIPCAS PULD P LDDP F/ 1784' T/ 352'. PUW=55K. Hole taking additional 2 Bbls over calculated hole fill.. 1,784.0 352.0 2/23/2024 05:15 2/23/2024 05:45 0.50 PROD1, TRIPCAS OWFF P OWFF - Fluid level falling in stack. Static loss rate = 5 BPH. 352.0 352.0 2/23/2024 05:45 2/23/2024 08:00 2.25 PROD1, TRIPCAS BHAH P LD BHA 352.0 0.0 2/23/2024 08:00 2/23/2024 08:30 0.50 PROD1, TRIPCAS RURD P Remove wear ring 0.0 0.0 2/23/2024 08:30 2/23/2024 09:00 0.50 PROD1, TRIPCAS OWFF P OWFF 30 minutes. 0.0 0.0 2/23/2024 09:00 2/23/2024 11:00 2.00 PROD1, TRIPCAS RURD P Clean and clear rig floor RU to run casing. 0.0 0.0 2/23/2024 11:00 2/23/2024 11:30 0.50 PROD1, TRIPCAS SVRG P Service rig 0.0 0.0 2/23/2024 11:30 2/23/2024 17:30 6.00 COMPZN, CASING PUTB P RIH with 5 1/2', 17#, L-80, Hyd 521" shoe track. Baker lock all shoe track joints. fill casing every joint. Check that floats were holding. Centralizers tight in casing pushing in hole w/ 5K TD weight T/ 520'. No SOW. 5 1/2", 17#, Hyd 521 torque turned T/ 6200 Ft/lbs. Best'O'Life Arctic grade dope used. 0.0 520.0 2/23/2024 17:30 2/23/2024 22:15 4.75 COMPZN, CASING PUTB P Cont RIH w/ 5 1/2", 15.5#, L-80, Hyd 563 liner F/ 520' T/ 2137'. Cont pushing pipe in hole w/ 5K TD weight T/ 2137', began to gain string weight. 5 1/2", 15.5# Hyd 563 torque turned T/ 6200 Ft/lbs. Best'O'Life Arctic grade dope used. Displacement lossing 3.25 Bbls in 10 joints. 118.0 2,137.0 2/23/2024 22:15 2/23/2024 22:45 0.50 COMPZN, CASING RURD P R/D XO assembly for pushing pipe in hole. R/U MYC slip type elevators. 2,137.0 2,137.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 12/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/23/2024 22:45 2/24/2024 00:00 1.25 COMPZN, CASING PUTB P Cont RIH w/ 5 1/2", 15.5#, L-80, Hyd 563 liner F/ 2137' T/ 2797'. SOW=35K. 2,137.0 2,797.0 2/24/2024 00:00 2/24/2024 05:00 5.00 COMPZN, CASING PUTB P Cont RIH w/ 5 1/2", 15.5#, L-80, Hyd 563 liner F/ 2797' T/ 5888''. SOW=55K. 2,797.0 5,888.0 2/24/2024 05:00 2/24/2024 06:00 1.00 COMPZN, CASING PUTB P Continue to RIH F/5888' T/5965' 5,888.0 5,965.0 2/24/2024 06:00 2/24/2024 12:15 6.25 COMPZN, CASING CIRC P Circulate and condition hole Circ SxS P PR 1BPM 550 -600 PSI 50% loss rate. Reciprocate pipe to minimize ECD on formation. Change out bails for long casing bails to accommodate cement head. 5,965.0 5,965.0 2/24/2024 12:15 2/24/2024 15:15 3.00 COMPZN, CASING PUTB P RIH with 5.5" 15.5# L-80 Hyd 563 F/5965 T/7126' PUW=128K SOW=68K Casing started dragging at 6814' T/7130.8' ORKB PU clean 5,965.0 7,130.8 2/24/2024 15:15 2/24/2024 15:45 0.50 COMPZN, CEMENT RURD P Attempt to RU HES cement 7,130.8 7,130.8 2/24/2024 15:45 2/24/2024 17:15 1.50 COMPZN, CEMENT RURD T Re-rig the cementing hard line to compensate for incorrect cement head. Install casing swedge and surface hardliner. 7,130.8 7,130.8 2/24/2024 17:15 2/24/2024 17:45 0.50 COMPZN, CEMENT CIRC P Break circ @ 1 BPM, 1130 PSI. Begin reciprocating pipe staggering reciprocation in 5', 10', 15' increments. PUW=115K, SOW=70K. 50% loss rate. 7,130.8 7,130.8 2/24/2024 17:45 2/25/2024 00:00 6.25 COMPZN, CEMENT DISP P Displace 10.5 PPG LSND w/ 9.8 PPG brine. Pump 25 Bbls hi vis spacer followed by 9.8 PPG brine @ .5 BPM, 960 PSI. Reciprocating pipe staggering reciprocation in 5', 10', 15' increments. PUW=115K, SOW=70K. ~20% loss rate. Staged pumps up T/ 3 BPM, 9.8 PPG back to surface. 750 PSI. PUW=135K, SOW=90K.. 7,130.8 7,130.8 2/25/2024 00:00 2/25/2024 00:30 0.50 COMPZN, CEMENT SFTY P PJSM w/ HES & rig crew on primary cement job. 7,130.8 7,130.8 2/25/2024 00:30 2/25/2024 00:45 0.25 COMPZN, CEMENT PRTS P PT cement line & hose T/ 4000 PSI. 7,130.8 7,130.8 2/25/2024 00:45 2/25/2024 03:00 2.25 COMPZN, CEMENT CMNT P HES pump 20 Bbls, 11.5 PPG tuned Prime Spacer @ 2.2 BPM, 560 PSI. Pump 25 Bbls 15.3 PPG cement w/ BridgeMaker II LCM @ 5 lb/bbl, added to middle 10 Bbls. Cement wet @ 12:52 Hrs. Drop wiper plug. HES pump 20 Bbls fresh H2O @ 2 BPM, 100 PSI. Swap over and displace with rig pumps pumping 9.8 PPG brine @ 3 BPM, ICP=1200. Pressure built T/ 1780 PSI. Back rate down T/ 2 BPM, 1830 PSI, Back rate down T/ 1 BPM. FCP-1860 PSI. Bumped plug on time @ 168 Bbls. Cement in place @ 2:32 Hrs. Pressure up T/ 2380 PSI and hold for 5 Min. Bleed off. Open up check floats - holding no flow. 7,130.8 7,130.8 2/25/2024 03:00 2/25/2024 05:00 2.00 COMPZN, CEMENT RURD P B/D, R/D cementing equipment. Clean out RF manifold. C/O bails back to short bails. 7,130.8 7,130.8 2/25/2024 05:00 2/25/2024 08:00 3.00 COMPZN, CEMENT RURD P Blow down lines clean CMT manifold. Clean mud manifold continue processing tubing for completion. 7,130.8 7,130.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 13/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/25/2024 08:00 2/25/2024 13:00 5.00 COMPZN, CEMENT OWFF T OWFF 5.5" x 7" casing flowing inconsistent return rates. Continue to process 3.5" tubing 22 gallons returned in 5 Hrs @ 4.4 GPH average 13:00 Hrs. light crude in returns. Called out E-Line to perform CBL. 7,130.0 7,130.0 2/25/2024 13:00 2/25/2024 15:00 2.00 COMPZN, CEMENT OWFF T RU secondary kill IA. Install 4.5" FOSV and Otis connection on casing stump. Continue to monitor IA returns and log flow back rates and volumes. Continue to process tubing. E-line on location at 1500. 7,130.0 7,130.0 2/25/2024 15:00 2/25/2024 20:00 5.00 COMPZN, CEMENT OWFF T Continue to OWFF, 28 Gallons returned total for additional 6 Bbls in 5 Hrs. flow diminishing T/ 1.6 GPH. Trace crude in returns. Spot in logging unit. Mobilize PC equipment T/ RF. Re head E-line. 7,130.0 7,130.0 2/25/2024 20:00 2/26/2024 00:00 4.00 COMPZN, EVALWB ELNE T PJSM with HES E-Line and Nabors. RU E-Line to hoist Bond log. Continue to OWFF, 30 Gallons returned total for additional 2 Bbls in 4 Hrs, flow diminishing T/ ..5 BPH average. 7,130.0 7,130.0 2/26/2024 00:00 2/26/2024 01:30 1.50 COMPZN, EVALWB ELNE T Complete R/U HES lubricator w/ full PC. M/U CBL tool string. 0 @ RF. Stab on. Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 01:30 2/26/2024 02:00 0.50 COMPZN, EVALWB PRTS T PT lubricator T/ 3500 PSI; Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 02:00 2/26/2024 04:00 2.00 COMPZN, EVALWB ELNE T Attempt T/ RIH. Unable T/ move down hole. Believe grease head to be problem. R/U steam hose & steam grease head. Unsuccessful in achieving line movement. Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 04:00 2/26/2024 04:30 0.50 COMPZN, EVALWB SFTY T PJSM w/ HES & rig crew on R/D lubricator to get to grease head. Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 04:30 2/26/2024 07:00 2.50 COMPZN, EVALWB ELNE T R/D lubricator & PC. L/D tool string. Send lubricator down skate to troubleshoot grease head. Continue to OWFF, 32,63 Gallons returned total for additional 2.63 Gal in 6 Hr. Flow @ .438 GPH average. 7,130.0 7,130.0 2/26/2024 07:00 2/26/2024 11:30 4.50 COMPZN, EVALWB WAIT T Wait on HES personnel to get some sleep. Close LPR, shut IA in let pressure build for 1 Hr.0 PSI. Bleed off IA .5 gal returned. Continue with same schedule. 7,130.0 7,130.0 2/26/2024 11:30 2/26/2024 12:00 0.50 COMPZN, EVALWB SVRG T Service rig. Grease roughneck @ pipe skate. 7,130.0 7,130.0 2/26/2024 12:00 2/26/2024 14:00 2.00 COMPZN, EVALWB WAIT T Wait on HES personnel to get some sleep. Shut IA in let pressure build for 1 Hr.0 PSI. Bleed off IA .4 gal returned. Continue with same IA schedule. 7,130.0 7,130.0 2/26/2024 14:00 2/26/2024 17:00 3.00 COMPZN, EVALWB ELNE P R/U E-line lubricator & tool string w/ full PC. Stab on. Continue with same IA schedule; 7,130.0 7,130.0 2/26/2024 17:00 2/26/2024 17:30 0.50 COMPZN, EVALWB PRTS P PT lubricator T/ 500 PSI for 5 Min. Continue with same IA schedule 7,130.0 7,130.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 14/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/26/2024 17:30 2/26/2024 20:00 2.50 COMPZN, EVALWB ELOG P RIH w/ E-line T/ 7012'. Log up with CBL T/ 5750. POOH w/ E-line. Field log show good cement up T/ 6375'. Shut IA in let pressure build for 1 Hr.0 PSI. Bleed off IA .3 gal returned. Continue with same schedule. 7,130.0 0.0 2/26/2024 20:00 2/26/2024 23:00 3.00 COMPZN, EVALWB ELNE P R/D E-Line lubricator, PC equipment & tool string. Stage lubicator & PC equipment on rig. Leve unit in place. Consult w/ town. Decision made to proceed w/ plan. 0.0 0.0 2/26/2024 23:00 2/27/2024 00:00 1.00 COMPZN, EVALWB RURD P Prep for N/D. Suck fluid out of liner. Flip new tubing head over for installation . Verify all equipment needed for tubing head installation is accounted for in cellar. Open LPR. IA died - no flow. 0.0 0.0 2/27/2024 00:00 2/27/2024 00:30 0.50 COMPZN, EVALWB SFTY P PJSM w/ FMC & rig crew about working under dispensation for N/D BOP and install new tubing head. 0.0 0.0 2/27/2024 00:30 2/27/2024 02:00 1.50 COMPZN, EVALWB NUND P N/D BOP, lift stack. Install 11" x 5 1/2" emergency slips. Set slips w/ 75K tension. Cut 5 1/2" with Whacks saw. Pull cut joint. Rack back BOP. 0.0 0.0 2/27/2024 02:00 2/27/2024 03:30 1.50 COMPZN, EVALWB NUND P Intall pack off. N/U new 11" 5K tubing head. 0.0 0.0 2/27/2024 03:30 2/27/2024 04:00 0.50 COMPZN, EVALWB PRTS P PT pack off T/ 4000 PSI for 15 Min. 0.0 0.0 2/27/2024 04:00 2/27/2024 07:30 3.50 COMPZN, EVALWB NUND P N/U BOP. Install sencondary IA valve. 0.0 0.0 2/27/2024 07:30 2/27/2024 09:00 1.50 COMPZN, EVALWB RURD P RU to test BOPs Fill Stack with water perform shell test to 0.0 0.0 2/27/2024 09:00 2/27/2024 14:00 5.00 COMPZN, EVALWB BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, UVBR's, LVBR's w/ 3 1/2" test joint. Test blinds rams. Tested choke valves #1 to #16, upper and lower top drive well control valves. Tested 4-1/2" FOSV and XT-39 TIW and XT-39 IBOP. Tested 2" rig floor Demco kill valves. Tested manual and HCR kill valves & manual and HCR choke valves. Tested two ea 2 1/6" gate auxiliary valves below LPR. Tested hydraulic and manual choke valves to 1500 PSI and demonstrated bleed off. Performed accumulator test. Initial pressure=3050 PSI, after closure=1650 PSI, 200 PSI attained =13 sec, full recovery attained =105 sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular= 24 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =2100 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Austin McLeod. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 15/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/27/2024 14:00 2/27/2024 15:30 1.50 COMPZN, EVALWB RURD P Test BOP breaks to 250/3500 PSI 5 min each. Off Corporation Dispensation. R/D testing equipment drain stack Pulled test plug. Blow down all surface lines. Prepare to RU E-Line. 0.0 0.0 2/27/2024 15:30 2/27/2024 17:30 2.00 COMPZN, PERF RURD P Make up mule shoe, attempt to land hanger, brake off mule shoe Land Hanger, RI LDS, P/T 1000 psi 5 mins (good test) 0.0 0.0 2/27/2024 17:30 2/27/2024 18:30 1.00 COMPZN, PERF RURD P Crew change, P/T hanger down the IA to 1,000 psi (good test), R/D testing equipment 0.0 0.0 2/27/2024 18:30 2/27/2024 23:30 5.00 COMPZN, PERF ELNE P R/U HES E-line w/full PCE & QTS, open up IA and monitor, P/T to 3,500 psi, (good test) 0.0 0.0 2/27/2024 23:30 2/28/2024 00:00 0.50 COMPZN, PERF ELNE P R/D testing equipment and blow down kelly hose 0.0 0.0 2/28/2024 00:00 2/28/2024 00:30 0.50 COMPZN, PERF ELNE P M/U perf gun Haliburton 3-1/8" Millennium Exprs 6spf @ 60° shots, P/T QTS 3,000 psi 0.0 0.0 2/28/2024 00:30 2/28/2024 01:45 1.25 COMPZN, PERF ELNE P RIH w/E-line, run #1, log CCL/Gamma, tag bottom 7,004' ELMD, correlate logs, perforate Interval F/6,934'' T/6.965' 0.0 0.0 2/28/2024 01:45 2/28/2024 03:15 1.50 COMPZN, PERF ELNE P POOH w/E-line, at Surface, confirm and L/D spent guns 0.0 0.0 2/28/2024 03:15 2/28/2024 04:00 0.75 COMPZN, PERF ELNE P M/U Perf gun run #2, Haliburton 3-1/8" Millennium Exprs 6spf @ 60° shots, P/T QTS 3,000 psi 0.0 0.0 2/28/2024 04:00 2/28/2024 06:30 2.50 COMPZN, PERF ELNE P RIH w/E-line, run #2, log CCL/Gamma, correlate logs, perforate interval 6919'- 6909' 0.0 0.0 2/28/2024 06:30 2/28/2024 08:00 1.50 COMPZN, PERF ELNE P M/U Perf gun run #3, Haliburton 3-1/8" Millennium Exprs 6spf @ 60° shots, P/T QTS 3,000 psi 0.0 0.0 2/28/2024 08:00 2/28/2024 09:30 1.50 COMPZN, PERF ELNE P RIH w/E-line, run #3, log CCL/Gamma, correlate logs, perforate interval 6856'- 6822' 0.0 0.0 2/28/2024 09:30 2/28/2024 10:00 0.50 COMPZN, PERF ELNE P M/U Perf gun run #4, Haliburton 3-1/8" Millennium Exprs 6spf @ 60° shots, P/T QTS 3,000 psi 0.0 0.0 2/28/2024 10:00 2/28/2024 12:00 2.00 COMPZN, PERF ELNE P RIH w/E-line, run #4, log CCL/Gamma, correlate logs, perforate interval 6824- 6801' 0.0 0.0 2/28/2024 12:00 2/28/2024 12:15 0.25 COMPZN, PERF SFTY P PJSM to LD E-line and clear tools form rig. 0.0 0.0 2/28/2024 12:15 2/28/2024 14:30 2.25 COMPZN, PERF ELNE P R/D Eline and clear tools from rig floor 0.0 0.0 2/28/2024 14:30 2/28/2024 16:30 2.00 COMPZN, PERF OWFF P OWFF establish loss rate 3 BPH Clear floor set up to run tubing. 0.0 0.0 2/28/2024 16:30 2/28/2024 18:30 2.00 COMPZN, PERF SLKL P RU Slick line to drift casing. 0.0 0.0 2/28/2024 18:30 2/28/2024 20:30 2.00 COMPZN, PERF SLKL P Drift casing 4.75", tag and work wire past 6,853', tag bottom x 5 @ 6,964', POOH, R/D SL 0.0 0.0 2/28/2024 20:30 2/28/2024 21:30 1.00 COMPZN, RPCOMP PUTB P Clean RF and set up for completion ops. , Confirm pipe and jewerly in shed 0.0 0.0 2/28/2024 21:30 2/28/2024 22:00 0.50 COMPZN, RPCOMP SFTY P PJSM with rig crew, HES packer hand, GBR, and MI SWACO. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 16/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/28/2024 22:00 2/29/2024 00:00 2.00 COMPZN, RPCOMP PUTB P M/U cross over to FOSV, P/U 3.5" L-80 HYD 563, 3.5" L-80 TN110SS HYD 563 as per approved tally. 0.0 877.0 2/29/2024 00:00 2/29/2024 07:30 7.50 COMPZN, RPCOMP PUTB P Continue to P/U 3.5" L-80 HYD 563, 3.5" L-80 TN110SS HYD 563 as per tally F877' T/6905' 877.0 6,905.0 2/29/2024 07:30 2/29/2024 09:00 1.50 COMPZN, RPCOMP RURD P PU LDG joint and RU circulating equipment MU Tbg hanger to landing joint. 6,905.0 6,905.0 2/29/2024 09:00 2/29/2024 09:30 0.50 COMPZN, RPCOMP THGR P MU Tbg Hgr to tubing string. RIH land hanger verify hanger is landed. RILDS. 6,905.0 6,929.0 2/29/2024 09:30 2/29/2024 10:00 0.50 COMPZN, RPCOMP RURD P R/U to reverse circulate well to 9.8# CI brine. 6,929.0 6,929.0 2/29/2024 10:00 2/29/2024 11:30 1.50 COMPZN, RPCOMP CIRC P Reverse circulate well to 9.8# corrosion inhibited brine at 2BPM=360 PSI. 2BPM max rate per HES compeletion representative. Pump 10BBL's 9.8# CI down tubing at 1.5 BPM=150 PSI to clear ball seat per completion representative. 6,929.0 6,929.0 2/29/2024 11:30 2/29/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service Rig Blocks and draw works 6,929.0 6,929.0 2/29/2024 12:00 2/29/2024 12:30 0.50 COMPZN, RPCOMP RURD P Blow down circulating lines. Remove surface hardline. Drop ball and rod. Rig up surface lines to set packer and test. allow ball and rod to fall. 6,929.0 6,929.0 2/29/2024 12:30 2/29/2024 13:00 0.50 COMPZN, WHDBOP PRTS P Pressure up to 3500 PSI on tubing set packer. 20 STKS 1.17 BBL's pumped. 6,929.0 6,929.0 2/29/2024 13:00 2/29/2024 13:30 0.50 COMPZN, WHDBOP PRTS P Bleed Tubing back to 2000 PSI. Pressure up IA to 3300 PSI for 30 minutes. Dump tubing and shear SOV. 6,929.0 6,929.0 2/29/2024 13:30 2/29/2024 14:30 1.00 COMPZN, WHDBOP PRTS P Set BPV and test P/T 1,000 psi charted 10 mins 6,929.0 6,929.0 2/29/2024 14:30 2/29/2024 17:30 3.00 COMPZN, WHDBOP OTHR P P/U DP, M/U XO and Johnny Wacker, jet stack, empty and clean pits 6,929.0 6,929.0 2/29/2024 17:30 2/29/2024 23:30 6.00 COMPZN, WHDBOP OTHR P Perform BWM, open up all ram doors, clean & inspect and take photos, close all ram doors 6,929.0 6,929.0 2/29/2024 23:30 3/1/2024 00:00 0.50 DEMOB, MOVE NUND P N/D BOPE and rack back 6,929.0 6,929.0 3/1/2024 00:00 3/1/2024 02:30 2.50 DEMOB, MOVE NUND P Continue N/D stack, rack back and secure BOPE, remove DSA F/Wellhead 6,929.0 6,929.0 3/1/2024 02:30 3/1/2024 04:00 1.50 DEMOB, MOVE NUND P N/U Tree and adapter, torque up, install 1502 companion flange on OA 5.5"x7". test tree packoff to 5,000 psi for 15 mins. 6,929.0 6,929.0 3/1/2024 04:00 3/1/2024 05:30 1.50 DEMOB, MOVE FRZP P M/U hoses to Tubing and IA, pump 126 bbls of diesel down the IA taking returns up the tubing to kill tank. 6,929.0 6,929.0 3/1/2024 05:30 3/1/2024 10:30 5.00 DEMOB, MOVE FRZP P M/U LRS to OA pump 14.9 bbl of diesel Max pressure 700 psi. RD LRS and released at 1030. 6,929.0 6,929.0 3/1/2024 10:30 3/1/2024 11:30 1.00 DEMOB, MOVE RURD P RD circulating equipment and obtained final pressures. Tbg=125 PSI IA=125 PSI OA=600 PSI OOA=0 PSI 6,929.0 6,929.0 3/1/2024 11:30 3/1/2024 12:00 0.50 DEMOB, MOVE SVRG P Service Breaks on top drive. *** Rig Released @ 12:00 noon 3/1/24 6,929.0 6,929.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 1/1 2A-10 Report Printed: 3/21/2024 Cement Cement Details Description Production String 1 Cement Cementing Start Date 2/25/2024 00:45 Cementing End Date Wellbore Name 2A-10A Comment Cement Stages Stage # 1 Description Production String 1 Cement Objective Top Depth (ftKB) 6,385.0 Bottom Depth (ftKB) 7,150.0 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? No Q Pump Init (bbl/m… 560 Q Pump Final (bbl/… 680 Q Pump Avg (bbl/… 3 P Pump Final (psi) 1,860.0 P Plug Bump (psi) 2,380.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 20 Bbls 11.5 PPG Tuned Pime Spacer 25 Bbls 15.3 PPG Primary Cement w/ BridgeMaker II int the middle 10 Bbls at 5 lb/bbl. Displaced w/ 9.8 PPG brine. Plug bumped on time. Cement Fluids & Additives Fluid Fluid Type Primary Cement Type 1 Fluid Description Estimated Top (ftKB) 5,659.0 Est Btm (ftKB) 7,150.0 Amount (sacks) 135 Class *NOT IN LIBRARY Volume Pumped (bbl) 25.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) Density (lb/gal) 15.30 Plastic Viscosity (cP) Thickening Time (hr) 5.13 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Production String 1 Cement ! 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Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7260' None Casing Collapse Conductor Surface Production Intermediate Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Adam Klem adam.klem@conocophillips.com (907) 263-4529 CTD/RWO Engineer Tubing Grade: Tubing MD (ft): Packer: 6744'MD/5813'TVD 6897'MD/5939'TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-80 TN-110SS 6760' 6900' 3/24/2024 Packer: HES TNT Packer Packer: HES TNT Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025570 223-092 P.O. Box 100360, Anchorage, AK 99510 50-103-20056-01-00 ConocoPhillips Alaska, Inc. KRU 2A-10A Kuparuk Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Length Size Proposed Pools: 106' 106' TVD Burst PRESENT WELL CONDITION SUMMARY 71' 16" 6242' 6897' 5939' None MD 2773' 6133' 5799' 2863' 7130' 6690' 9-5/8" 5-1/2" 2828' 7095' Perforation Depth MD (ft): 7"6655' 6801-6856', 6909-6919', 6934-6965' 5859-5905', 5949-5957', 5970-5995' 3-1/2" 3-1/2" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:07 am, Mar 05, 2024 A.Dewhurst 18MAR24 CDW 03/13/2024 3/24/2024 DSR-3/5/24VTL 03/20/2024 10-404X JLC 3/20/2024 Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). Section 2 Plat 20 AAC 25.283 (2)(A) Plat 1: Wells within 1/2 mile Table 1: Wells within 1/2 miles (2)(C) 2A-10A Frac Sundry Well Intersect Tract Buffer Field Name API * Well Name Status Symbology KUPARUK RIVER UNIT 501032002300 2A-01 PA Plugged and Abandoned KUPARUK RIVER UNIT 501032002301 2A-01A ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032002400 2A-02 PA Plugged and Abandoned KUPARUK RIVER UNIT 501032002500 2A-03 ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032002600 2A-04 ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032003000 2A-05 ACTIVE Oil KUPARUK RIVER UNIT 501032002800 2A-06 PA Plugged and Abandoned KUPARUK RIVER UNIT 501032002900 2A-07 PA Plugged and Abandoned KUPARUK RIVER UNIT 501032004900 2A-08 ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032005900 2A-09 ACTIVE Oil KUPARUK RIVER UNIT 501032005600 2A-10 SUSP Suspended KUPARUK RIVER UNIT 501032005700 2A-11 ACTIVE Oil KUPARUK RIVER UNIT 501032005800 2A-12 ACTIVE Oil KUPARUK RIVER UNIT 501032003900 2A-13 ACTIVE Oil KUPARUK RIVER UNIT 501032004000 2A-14 ACTIVE Oil KUPARUK RIVER UNIT 501032004100 2A-15 ACTIVE Oil KUPARUK RIVER UNIT 501032004200 2A-16 ACTIVE Oil KUPARUK RIVER UNIT 501032019300 2A-17 ACTIVE Oil KUPARUK RIVER UNIT 501032022000 2A-18 ACTIVE Oil KUPARUK RIVER UNIT 501032019700 2A-19 PA Plugged and Abandoned KUPARUK RIVER UNIT 501032019701 2A-19A ACTIVE Oil KUPARUK RIVER UNIT 501032019600 2A-20 ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032019200 2A-21 ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032022100 2A-22 PA Plugged and Abandoned KUPARUK RIVER UNIT 501032022101 2A-22A ACTIVE Oil KUPARUK RIVER UNIT 501032022160 2A-22AL1 ACTIVE Oil KUPARUK RIVER UNIT 501032019400 2A-23 ACTIVE Injector Miscible Water Alternating Gas KUPARUK RIVER UNIT 501032019500 2A-24 ACTIVE Oil KUPARUK RIVER UNIT 501032023900 2A-25 ACTIVE Oil KUPARUK RIVER UNIT 501032057500 2A-26 ACTIVE Oil KUPARUK RIVER UNIT 501032057560 2A-26L1 ACTIVE Oil KUPARUK RIVER UNIT 501032057561 2A-26L1-01 ACTIVE Oil KUPARUK RIVER UNIT 501032060400 2A-27 PA Plugged and Abandoned SECTION 3 FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), That portions of the aquifers on the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field. SECTION 4 PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) The surface casing is cemented and tested in accordance with 20 AAC 25.030. The 5-1/2 casing was cemented and a CBL run, showing top of cement at 6385MD/5545TVD which is 415 MD/312 TVD above top of reservoir. It is our assessment that this cement height will provide adequate isolation for stimulation operations. See Wellbore schematic for casing details. SECTION 6 ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 9-5/8 casing cement pump report on 2/2/1986 shows that the original job pumped as designed. The cement job was pumped with 810 sx of class 3 cement and 310 sx of class 2 tail cement. The plug was bumped. The 5-1/2 casing cement report on 2/25/24 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 25 barrels of 15.3ppg primary cement with LCM in the middle 10 bbls. The plug was bumped and the floats held. A cement bond log indicates competent cement with a cement top @ 6,385 MD (5,545TVD). Summary All casing is cemented and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 2/3/1986 the 9-5/8 casing was pressure tested On 2/29/2024 the 3-1/2 tubing was pressure tested to 3,050 psi. Good Test On 2/29/2024 the 5-1/2 casing by 3.5 tubing annulus was pressure tested to 3,300 psi. Good Test AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,500 Annulus pressure during frac 3,000 Annulus PRV setpoint during frac 3,100 5-1/2" Annulus pressure test 3,300 3-1/2" Tubing pressure Test 3,050 Electronic PRV 6,650 Highest pump trip 6,050 SECTION 8 PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight, ppf Grade API Burst, psi API Collapse, psi 9-5/8 36 J-55 3,520 2,020 5-1/2 17 L-80 7,740 6,390 5-1/2 15.5 L-80 7,000 4,990 3-1/2 9.3 L-80 10,160 10,540 3-1/2 9.3 TN-110 12,700 12,570 Table 2: Wellbore pressure ratings Stimulation Surface Rig-Up Stinger Tree Saver SECTION 9 DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, within the Kuparuk Oil Pool, are the Kuparuk A3 and A4 sands, starting at 5829 TVDSS (6908 MD) in the 2A-10A well and have an average gross thickness of 80 TVD. The Kuparuk Oil Pool is comprised of multiple stacked reservoirs of very fined grained, quartz rich sandstones separated by laterally continuous shale beds, in this area the main reservoirs are the Kuparuk C4 sand and A3 and A4 reservoirs. The gross thickness of the Kuparuk interval here is ~200 TVD. The estimated fracture pressure for the Kuparuk A3 and A4 is 13.1 ppg. The overlaying confining interval for the Kuparuk is the Kalubik and HRZ shales, totaling approximately 350 TVD. The top of the confining interval starts at 5390 TVDSS (6335 MD) The estimated fracture pressure of the Kalubik and HRZ ranges from 16-17 ppg. The underlying confining zone is the Miluveach shale, extending ~500 feet below the reservoir with an estimated fracture pressure of 15.5 ppg. The estimated formation pressure in the A3 and A4 sands is 2590 psi. SECTION 10 LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2A-03: 7 casing cement pump report on 4/27/1984 shows that job was pumped as designed. The cement job was pumped with 350 sx 15.8ppg of Class G cement displaced with 10.1ppg brine. The plug bumped and full returns were seen throughout the job. The CBLs ran in 1984 and 2014 show adequate cement for isolation. 2A-07: This well has been P&Ad 2A-09: 5 liner casing cement pump report on 2/19/1986 shows that job was pumped as designed. The cement job was pumped with 200 sx 15.8ppg of Class G cement. The CBL ran in 1986 shows adequate cement for isolation. 2A-10: This well has been P&Ad 2A-18: 3.5 liner casing cement pump report on 10/9/1995 shows that job was pumped as designed. The cement job was pumped with 306 sx 15.8ppg of Class G cement. The CBL ran in 1995 shows adequate cement for isolation. SECTION 11 LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that five faults transect the Kuparuk Oil Pool reservoir within one half mile radius of the 2A-10A wellbore, as shown in Plat. The 2A-10A wellbore did not intersect any of the mapped faults during drilling. The majority of the faults in the area have less than 40 of interpreted throw and terminate in the overburden confining zones, the Kalubik and HRZ. One large fault running NNE-SSW directly to the east of the wellbore has down to the east throw greater than 100. This fault extends up into the overburden and offsets the Kalubik and HRZ confining interval ultimately terminating in the Torok. If there is any indication that a fracture has intersected any mapped faults (or any other faults unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. SECTION 12 PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2A-10A was completed in 2024 as a slant producer in the Kuparuk A and C formations. The well was completed with a 3-1/2 tubing upper completion and a 5-1/2 longstring with A and C sand perfs. A selective completion isolates the C sand and only the A sand will be fracd as a single stage. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000 TVD. 3. Pressure test the treesaver to 10,000 psi. 4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 1-2 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with enough 100º F seawater required for breakdown, maximum pad and displacement. (450 bbls usable volume per tank). 6. MIRU HES Frac Equipment. 7. PT Surface lines to 10,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Bring up pumps and increase annulus pressure from 2,500 psi to 3,000 psi as the tubing pressures up. 10. Pump the single stage Frac job by following attached HES schedule @ ~25bpm with a maximum expected treating pressure of 5,500 psi. 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep and flowback Stage Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- Length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 95,000 6,909 5,954 210 200 0.189 Disclaimer Notice: KRU 2A-10 This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results SECTION 13 POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will be turned over to production for initial clean up production. Hydraulic Fracturing Fluid Product Component Information Disclosure 2024-02-28 Alaska HARRISON BAY 50-103-20056 CONOCOPHILLIPS 2A 10 -150.0196 70.3034 NAD83 none Oil 6,248 72610 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone SEAWATER (SG 8.52) Halliburton Base Fluid Water 7732-18-5 100.00%84.10186%618638 Density = 8.52 Halliburton BA-20 BUFFERING AGENT Halliburton Buffer Listed Below Listed Below 0 BC-140 X2 Halliburton Initiator Listed Below Listed Below 0 BE-6(TM) Bactericide Halliburton Microbiocide Listed Below Listed Below 0 CAT-3 ACTIVATOR Halliburton Activator Listed Below Listed Below 0 CL-28M CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0 LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA LVT-200 Baker Hughes Additive Listed Below Listed Below 0 NA MO-67 Halliburton pH Control Listed Below Listed Below 0 OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Listed Below 0 OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Listed Below 0 WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below Listed Below 0 Ceramic Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA SAND, COMMON BROWN 100 MESH Halliburton Proppant Listed Below Listed Below 0 NA Calcium Chloride Customer Salt Solution Listed Below Listed Below 0 NA Ingredients Listed Above Listed Above 0.00%0.00000%0 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00075%6 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00001%1 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00150%11 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00002%1 Acetic acid 64-19-7 30.00%0.00375%28 Ammonia 7664-41-7 1.00%0.00011%1 Ammonium acetate 631-61-8 100.00%0.01249%92 Ammonium chloride 12125-02-9 5.00%0.00057%5 Ammonium persulfate 7727-54-0 100.00%0.02221%164 Borate salts Proprietary 60.00%0.10737%790 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 C.I. pigment Orange 5 3468-63-1 1.00%0.00002%1 Calcium Chloride 10043-52-4 100.00%1.35947%10000 Calcium magnesium carbonate 16389-88-1 1.00%0.00179%14 Corundum 1302-74-5 65.00%8.04126%59150 Crystalline silica, quartz 14808-60-7 100.00%0.55014%4047 Distillates (petroleum), hydrotreated light 64742-47-8 100.00%0.94075%6920 EDTA/Copper chelate Proprietary 30.00%0.00340%26 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ethanol 64-17-5 60.00%0.04501%332 Ethylene glycol 107-21-1 30.00%0.00414%31 Gluteraldehyde 111-30-8 1.00%0.00179%14 Guar gum 9000-30-0 100.00%0.29609%2178 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.02250%166 Inorganic mineral 1317-65-3 5.00%0.00895%66 Inorganic mineral Proprietary 1.00%0.00179%14 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Magensium chloride 7786-30-3 0.01%0.00002%1 Magnesium nitrate 10377-60-3 0.01%0.00002%1 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00018%2 Monoethanolamine borate 26038-87-9 100.00%0.01381%102 Mullite 1302-93-8 45.00%5.56703%40950 Naphthalene 91-20-3 5.00%0.00375%28 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02250%166 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxyalkylated phenolic resin Proprietary 10.00%0.00750%56 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxylated phenolic resin Proprietary 30.00%0.00666%50 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00375%28 Polymer Proprietary 1.00%0.00179%14 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Potassium chloride 7447-40-7 5.00%0.00895%66 Sodium bisulfate 7681-38-1 0.10%0.00018%2 Sodium chloride 7647-14-5 5.00%4.20581%30938 Sodium hydroxide 1310-73-2 30.00%0.02147%158 Water 7732-18-5 100.00%0.19815%1458 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3 All component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administrations (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: Tr e a t m e n t CU S T O M E R Co n o c o P h i l l i p s FA L S E AP I BF D (l b / g a l ) 8. 5 4 LA T 70 . 3 0 3 4 1 4 9 4 TR U E LE A S E 2A - 1 0 SA L E S O R D E R BH S T (° F ) LO N G -1 5 0 . 0 1 9 6 5 7 3 60 FO R M A T I O N Ku p a r u k DA T E M a x P r e s s u r e ( p s i ) 24 P r o p S l u r r y D e s i g n C l e a n D e s i g n C l e a n D e s i g n S l u r r y D e s i g n P r o p S t a g e I n t e r v a l C L - 2 8 M L o s u r f - 3 0 0 D M O - 6 7 W G - 3 6 O P T I F L O - I I I O P T I F L O - I I B E - 6 7 Tr e a t m e n t St a g e F l u i d S t a g e P r o p p a n t C o n c R a t e V o l u m e V o l u m e V o l u m e T o t a l T i m e T i m e Cr o s s l i n k e r S u r f a c t a n t B u f f e r In t e r v a l N u m b e r D e s c r i p t i o n D e s c r i p t i o n D e s c r i p t i o n (p p g ) ( b p m ) ( g a l ) ( b b l ) ( b b l ) ( l b s ) ( h h : m m : s s ) ( h h : m m : s s ) (g p t ) ( g p t ) ( g p t ) ( p p t ) ( p p t ) ( p p t ) ( p p t ) 1 1 - 1 S h u t - I n S h u t - I n 1 : 3 1 : 5 4 1 1 - 2 F r e e z e P r o t e c t P r i m e U p P r e s s u r e T e s t 5 1 , 0 0 0 2 4 2 4 0 : 0 4 : 4 6 1 : 3 1 : 5 4 1 1 - 3 S h u t - I n S h u t - I n 1 : 2 7 : 0 9 1 1 - 4 3 0 # L i n e a r D F I T 1 5 1 , 6 8 0 4 0 4 0 0 : 0 2 : 4 0 1 : 2 7 : 0 9 1 . 0 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 5 S h u t - I n S h u t - I n 1 : 2 4 : 2 9 1 1 - 6 3 0 # L i n e a r S t e p R a t e T e s t 1 5 3 , 3 6 0 8 0 8 0 0 : 0 5 : 2 0 1 : 2 4 : 2 9 1 . 0 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 7 3 0 # H y b o r G M i n i f r a c - E s t a b l i s h F l u i d 1 5 8 , 4 0 0 2 0 0 2 0 0 0 : 1 3 : 2 0 1 : 1 9 : 0 9 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 8 3 0 # H y b o r G M i n i f r a c - T r e a t m e n t 2 5 8 , 3 5 0 1 9 9 1 9 9 0 : 0 7 : 5 7 1 : 0 5 : 4 9 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 9 3 0 # L i n e a r M i n i f r a c - F l u s h 2 5 2 , 7 1 0 6 5 6 5 0 : 0 2 : 3 5 0 : 5 7 : 5 2 1 . 0 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 0 S h u t - I n S h u t - I n 0 . 4 1 0 : 5 5 : 1 7 1 1 - 1 1 3 0 # H y b o r G E s t a b l i s h S t a b l e F l u i d 1 5 8 , 4 0 0 2 0 0 2 0 0 0 : 1 3 : 2 0 0 : 5 5 : 1 7 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 2 3 0 # H y b o r G P a d 2 5 1 2 , 7 0 0 3 0 2 3 0 2 0 : 1 2 : 0 6 0 : 4 1 : 5 7 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 3 3 0 # H y b o r G C o n d i t i o n i n g P a d 1 0 0 M 1 . 0 0 2 5 4 , 0 0 0 9 5 1 0 0 4 , 0 0 0 0 : 0 3 : 5 9 0 : 2 9 : 5 1 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 4 3 0 # H y b o r G P r o p p a n t L a d e n F l u i d W a n l i 1 6 / 2 0 C e r a m i c 2 . 0 0 2 5 3 , 2 0 0 7 6 8 3 6 , 4 0 0 0 : 0 3 : 2 0 0 : 2 5 : 5 2 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 5 3 0 # H y b o r G P r o p p a n t L a d e n F l u i d W a n l i 1 6 / 2 0 C e r a m i c 3 . 0 0 2 5 3 , 3 0 0 7 9 8 9 9 , 9 0 0 0 : 0 3 : 3 4 0 : 2 2 : 3 2 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 6 3 0 # H y b o r G P r o p p a n t L a d e n F l u i d W a n l i 1 6 / 2 0 C e r a m i c 4 . 0 0 2 5 3 , 6 0 0 8 6 1 0 1 1 4 , 4 0 0 0 : 0 4 : 0 3 0 : 1 8 : 5 8 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 7 3 0 # H y b o r G P r o p p a n t L a d e n F l u i d W a n l i 1 6 / 2 0 C e r a m i c 5 . 0 0 2 5 3 , 7 0 0 8 8 1 0 8 1 8 , 5 0 0 0 : 0 4 : 2 0 0 : 1 4 : 5 5 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 8 3 0 # H y b o r G P r o p p a n t L a d e n F l u i d W a n l i 1 6 / 2 0 C e r a m i c 6 . 0 0 2 5 3 , 7 0 0 8 8 1 1 2 2 2 , 2 0 0 0 : 0 4 : 2 9 0 : 1 0 : 3 5 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 1 9 3 0 # H y b o r G P r o p p a n t L a d e n F l u i d W a n l i 1 6 / 2 0 C e r a m i c 7 . 0 0 2 5 2 , 8 0 0 6 7 8 7 1 9 , 6 0 0 0 : 0 3 : 3 1 0 : 0 6 : 0 6 2 . 0 0 1 . 0 0 0 . 8 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 2 0 3 0 # L i n e a r F l u s h 2 5 2 , 7 1 0 6 5 6 5 0 : 0 2 : 3 5 0 : 0 2 : 3 5 1 . 0 0 3 0 . 0 0 2 . 0 0 0 . 2 5 0 . 1 5 1 1 - 2 1 S h u t - I n S h u t - I n 30 0 7 73 , 6 1 0 1 , 7 5 3 1 , 8 5 4 9 5 , 0 0 0 De s i g n T o t a l (g a l ) De s i g n T o t a l (l b s ) CL - 2 8 M L o s u r f - 3 0 0 D M O - 6 7 W G - 3 6 O P T I F L O - I I I O P T I F L O - I I B E - 6 62 , 1 5 0 9 1 , 0 0 0 (g a l ) ( g a l ) ( g a l ) ( l b s ) ( l b s ) ( l b s ) ( l b s ) 10 , 4 6 0 4 , 0 0 0 I n i t i a l D e s i g n M a t e r i a l V o l u m e 1 2 4 . 3 7 2 . 6 4 9 . 7 2 , 1 7 8 . 3 1 4 5 . 2 1 8 . 2 1 0 . 9 - 1, 0 0 0 - W h o l e U n i t s t o b e o r d e r e d - - C L - 2 8 M L o s u r f - 3 0 0 D M O - 6 7 W G - 3 6 O P T I F L O - I I I O P T I F L O - I I B E - 6 - (g p m ) ( g p m ) ( g p m ) p p m p p m p p m p p m - M a x A d d i t i v e R a t e 2 . 1 1 . 1 0 . 8 3 1 . 5 2 . 1 2 . 1 0 . 2 - M i n A d d i t i v e R a t e 1: 3 1 : 5 4 Interval 1 @ - ft - °F Pr o p p a n t T y p e Wa n l i 1 6 / 2 0 C e r a m i c 10 0 M -- - Fl u i d T y p e 30 # H y b o r G 30 # L i n e a r Se a w a t e r Fr e e z e P r o t e c t --- - Li q u i d A d d i t i v e s D r y A d d i t i v e s 50 - 1 0 3 - 2 0 0 5 6 Co n o c o P h i l l i p s - 2 A - 1 0 P l a n n e d D e s i g n 1 1 Dewhurst, Andrew D (OGC) From:Klem, Adam <Adam.Klem@conocophillips.com> Sent:Monday, March 18, 2024 07:53 To:Dewhurst, Andrew D (OGC) Cc:Loepp, Victoria T (OGC); Roby, David S (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Wallace, Chris D (OGC) Subject:RE: [EXTERNAL]KRU 2A-10A Frac Sundry 324-139 (PTD 223-092): Questions Here you go: Would you please send a copy of the geologic tops for this well. Im looking in particular for the picks for Kuparu C, A4, Kalubik, HRZ, etc. Basically, any top mentioned in the application. Surface X Y TVDSS MD HRZ 1637332.13 5958160.85 -5391.24 6334.08 Kalubik 1637314.79 5957970.2 -5592.25 6611.8 Kuparuk_C4 1637318.99 5957852.74 -5740.26 6800.88 Kuparuk_A4 1637319.24 5957793.13 -5829.85 6908.45 Kuparuk_A3 1637319.34 5957778.82 -5851.43 6934.34 Miluveach 1637319.98 5957718.42 -5943.13 7044.15 Also, what is the base of the upper confining zone (definition plus MD/TVD)? The upper confining zone is the Kalubik, so the base would be the top of the Kuparuk, which is the C4 pick here, - 5740 TVDSS/6801MD. Do you have an estimated depth for the base of the lower confining zone? How is that depth estimated (seismic, offset tops, etc.)? This is estimated from offset wells, 2F-20 is a nearby well that penetrates the entire Miluveach, at that well the Miluveach is ~450 thick TVD, so similar estimates at 2A-10 would place base Miluveach at -6393 TVDSS. Regarding the largest of the 5 faults, I see that is has a throw of greater than 100 ft. Would you provide a maximum throw? Do you have an estimate for the offset at the top of the upper confining zone? Im trying to get a sense of the minimum shale-on-shale contact across the fault within the AOR. The maximum throw at the top of the Kuparuk on the largest fault is ~108 as measured from seismic. The offset at the top of the HRZ (the top of the upper confining zone) is ~70. From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Friday, March 15, 2024 4:37 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL]KRU 2A-10A Frac Sundry 324-139 (PTD 223-092): Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Adam, I am reviewing the KRU 2A-10A frac sundry and have a few ques ons for you: Would you please send a copy of the geologic tops for this well. Im looking in par cular for the picks for Kuparu C, A4, Kalubik, HRZ, etc. Basically, any top men oned in the applica on. Also, what is the base of the upper con ning zone (de ni on plus MD/TVD)? Do you have an es mated depth for the base of the lower con ning zone? How is that depth es mated (seismic, o set tops, etc.)? Regarding the largest of the 5 faults, I see that is has a throw of greater than 100 . Would you provide a maximum throw? Do you have an es mate for the o set at the top of the upper con ning zone? Im trying to get a sense of the minimum shale-on-shale contact across the fault within the AOR. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conserva on Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n C h e c k l i s t KR U 2 A - 1 0 A ( P T D N o . 2 2 3 - 0 9 2 ; S u n d r y N o . 3 2 4 - 1 3 9 ) Pa r a g r a p h Su b -Pa r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 1 M a r c h 1 8 , 2 0 2 4 (a ) A p p l i c a t i o n f o r Su n d r y A p p r o v a l (a ) ( 1 ) A f f i d a v i t Pr o v i d e d w i t h a p p l i c a t i o n . A. D e w h u r s t 15 M A R 2 4 ( a ) ( 2 ) P l a t Pr o v i d e d w i t h a p p l i c a t i o n . A. D e w h u r s t 15 M A R 2 4 ( a ) ( 2 ) ( A ) W e l l l o c a t i o n Pr o v i d e d w i t h a p p l i c a t i o n . We l l l i e s i n S e c t i o n 14 of T 11 N, R8 E , U M . A. D e w h u r s t 15 M A R 2 4 ( a ) ( 2 ) ( B ) E a c h w a t e r w e l l w i t h i n ½ m i l e No n e : Ac c o r d i n g t o t h e W a t e r E s t a t e m a p a v a i l a b l e t h r o u g h DN R s A l a s k a M a p p e r a p p l i c a t i o n , t h e r e a r e n o w e l l s a r e us e d f o r d r i n k i n g w a t e r p u r p o s e s a r e k n o w n t o l i e w i t h i n ½ mi l e o f t h e s u r f a c e l o c a t i o n o f K R U 2 A - 1 0 A . T h e r e a r e n o su b s u r f a c e w a t e r r i g h t s o r t e m p o r a r y s u b s u r f a c e w a t e r ri g h t s w i t h i n ~ 1 4 m i l e s o f t h e s u r f a c e l o c a t i o n o f K R U 2 A - 10 A . A. D e w h u r s t 15 M A R 2 4 (a ) ( 2) (C ) I d e n t i f y a l l w e l l t y p e s w i t h i n ½ mi l e Li s t p r o v i d e d w i t h a p p l i c a t i o n . A. D e w h u r s t 15 M A R 2 4 (a ) ( 3 ) F r e s h w a t e r a q u i f e r s : g e o l o g i c a l na m e ; m e a s u r e d a n d t r u e v e r t i c a l d e p t h No n e . Th e r e i s a n E P A A q u i f e r E x e m p t i o n f o r t h e K R U . Fo r a n o u t l i n e o f t h e A r e a , s e e t h e E P A s A l a s k a O i l & G a s Aq u i f e r E x e m p t i o n s I n t e r a c t i v e M a p a v a i l a b l e o n l i n e u n d e r th e P e r m i t s s e c t i o n o f E P A R e g i o n 1 0 s w e b p a g e . A. D e w h u r s t 15 M A R 2 4 ( a ) ( 4 ) B a s e l i n e w a t e r s a m p l i n g p l a n No n e r e q u i r e d . A. D e w h u r s t 15 M A R 2 4 ( a ) ( 5 ) C a s i n g a n d c e m e n t i n g i n f o r m a t i o n Pr o v i d e d w i t h a p p l i c a t i o n . Pr o p o s e d s c h e m a t i c a t t a c h e d , a s bu i l t n o t g e n e r a t e d t o d a t e . CD W 3/ 1 1 / 2 4 (a ) (6 ) Ca s i n g an d ce m e n t i n g op e r a t i o n as s e s s m e n t 9-5/ 8 su r f a c e c a s i n g ce m e n t ed w i t h 81 0 s x CS I I I a n d , 31 0 sx C S I I . J o b w e n t t o p l a n w i t h c e m e n t t o s u r f a c e n o t CD W 3/ 1 1 / 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n C h e c k l i s t KR U 2 A - 1 0 A ( P T D N o . 2 2 3 - 0 9 2 ; S u n d r y N o . 3 2 4 - 1 3 9 ) Pa r a g r a p h Su b -Pa r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 2 M a r c h 1 8 , 2 0 2 4 re p o r t e d (2 / 3 / 1 9 8 6 ) . Ca s i n g s h o e / c e m e n t d r i l l e d o u t a n d FI T p e r f o r m e d . 5- 1 / 2 s i d e t r a c k c a s i n g c e m e n t e d a s d e s i g n e d . C B L r u n a n d CP A I e s t i m a t e d T O C a t 6 3 8 5 f t . CB L s h o w s v e r y g o o d b o n d i n a r e a o f t h e i n t e n d e d p e r f / f r a c in t e r v a l s . N o i s s u e s w i t h c e m e n t f o r t h e u p c o m i n g st i m u l a t i o n . 5- 1 / 2 c a s i n g w a s p r e s s u r e t e s t e d t o 3 3 0 0 p s i . (a ) ( 6 ) ( A ) C a s i n g c e m e n t e d b e l o w lo w e r m o s t f r e s h w a t e r a q u i f e r a n d co n f o r m s t o 2 0 A A C 2 5 . 0 3 0 No f r e s h w a t e r a q u i f e r s p r e s e n t . ( S e e S e c t i o n ( a ) ( 3 ) , a b o v e . ) A. D e w h u r s t 15 M A R 2 4 (a ) ( 6 ) ( B ) E a c h h y d r o c a r b o n z o n e i s is o l a t e d Ye s : Se e a b o v e f o r TO C f o r 5 -1/ 2 p r o d u c t i o n c a s i n g ac r o s s Ku p a r u k r e s e r v o i r . No o t h e r H C z o n e i d e n t i f i e d . A. D e w h u r s t 15 M A R 24 / Dr l g E n g (a ) (7 ) Pr e s s u r e t e s t : i nf o r m a t i o n a n d pr e s s u r e - t e s t p l a n s f o r c a s i n g a n d t u b i n g in s t a l l e d i n w e l l Pr o v i d e d w i t h a p p l i c a t i o n . 3 3 0 0 p s i M I T I A 2 / 2 9 / 2 0 2 4 , 3 0 5 0 ps i M I T T 2 / 2 9 / 2 0 2 4 . CD W 3/ 1 1 / 2 4 (a ) ( 8 ) P r e s s u r e r a t i n g s a n d s c h e m a t i c s : we l l b o r e , w e l l h e a d , B O P E , t r e a t i n g h e a d Pr o v i d e d w i t h a p p l i c a t i o n . 1 0 K p s i tr e e s a v e r . ma x . f r a c . Pr e s s u r e e s t i m a t e d a s 5 5 0 0 p s i . P u m p k n o c k o u t 6 0 5 0 p s i an d G O R V 6 6 5 0 p s i . , l i n e s t e s t 1 0 , 0 0 0 p s i . CD W 3/ 1 1 / 2 4 (a ) (9 ) (A ) Fr a c t u r i n g a n d c o n f i n i n g zo n e s : li t h o l o g i c d e s c r i p t i o n f o r e a c h z o n e (a ) ( 9 ) ( B ) G e o l o g i c a l n a m e o f e a c h z o n e (a ) ( 9 ) ( C ) a n d ( a ) ( 9 ) ( D ) M e a s u r e d a n d t r u e Up p e r c o n f i n i n g z o n e s : Th e up p e r co n f i n i n g z o n e c o n s i s t s o f Ka l u b i k a n d H R Z s h a l e s t h a t h a v e a t h i c k n e s s g r e a t e r t h a n 35 0 T V T . T h e e s t i m a t e d f r a c t u r e g r a d i e n t o f t h e u p p e r co n f i n i n g z o n e i s 0 . 8 3 - 0 . 8 8 p s i / f t ( 1 6 p p g - 1 7 p p g E M W ) . Th e t o p o f t h e u p p e r c o n f i n i n g z o n e i s 6 , 3 3 5 M D ( 5 , 5 0 9 A. D e w h u r s t 18 M A R 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n C h e c k l i s t KR U 2 A - 1 0 A ( P T D N o . 2 2 3 - 0 9 2 ; S u n d r y N o . 3 2 4 - 1 3 9 ) Pa r a g r a p h Su b -Pa r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 3 M a r c h 1 8 , 2 0 2 4 ve r t i c a l d e p t h s (a ) ( 9 ) ( E ) F r a c t u r e p r e s s u r e f o r e a c h z o n e TV D ) a n d e x t e n d s t o t h e t o p o f t h e K u p a r u k r e s e r v o i r a t 6, 9 0 8 M D ( 5 , 9 4 8 T V D ) . Fr a c t u r i n g Z o n e : T h e K u p a r u k A 3 a n d A 4 s a n d s a t K R U 2 A - 10 A h a s a g r o s s t h i c k n e s s o f a p p r o x i m a t e l y 8 0 T V D , w i t h t h e to p o f t h e f o r m a t i o n a t 6 , 9 0 8 M D ( 5 , 9 4 8 T V D ) . I t i s co m p r i s e d o f mu l t i p l e s t a c k e d r e s e r v o i r s o f v e r y f i n e d gr a i n e d , q u a r t z r i c h s a n d s t o n e s s e p a r a t e d b y l a t e r a l l y co n t i n u o u s s h a l e b e d s . I n t h i s a r e a , t h e m a i n r e s e r v o i r s a r e th e K u p a r u k C 4 , A 3 , a n d A 4 . T h e e s t i m a t e d f r a c t u r e g r a d i e n t fo r t h e K u p a r u k A 3 a n d A 4 r e s e r v o i r s i s a p p r o x i m a t e l y 0 . 6 8 ps i / f t ( 1 3 . 1 p p g E M W ) . Lo w e r c o n f i n i n g z o n e s : T h e l o w e r c o n f i n i n g z o n e c o n s i s t s o f Mi l u v e a c h s h a l e t h a t i s a p p r o x i m a t e l y 5 0 0 T V T . T h e es t i m a t e d f r a c t u r e g r a d i e n t f o r t h e l o w e r c o n f i n i n g z o n e i s 0. 8 1 p s i / f t ( 1 5 . 5 p p g E M W ) . T h e t o p o f t h e u n d e r l y i n g co n f i n i n g z o n e i s 7 , 0 4 4 M D ( 6 , 0 6 1 T V D ) w i t h a b a s e es t i m a t e d ( f r o m t h e o f f s e t w e l l K R U 2 F - 2 0 ) t o b e a t - 6 , 3 9 3 TV D S S . (a ) ( 1 0 ) L o c a t i o n , o r i e n t a t i o n , r e p o r t o n me c h a n i c a l c o n d i t i o n o f e a c h w e l l CP A I ha s p r o v i d e d t a b l e s h o w i n g o v e r 3 0 w e l l s a t 2 A p a d wi t h i n t h e ½ m i l e r a d i u s . CD W 3/ 1 3 / 2 0 2 4 (a ) ( 1 1 ) S u f f i c i e n t i n f o r m a t i o n t o d e t e r m i n e we l l s w i l l n o t i n t e r f e r e w i t h c o n t a i n m e n t wi t h i n ½ m i l e CP A I h a s p r o v i d e d c e m e n t i n g i n f o r m a t i o n o n 5 w e l l s t h a t tr a n s e c t t h e c o n f i n i n g z o n e s . No i s s u e s i d e n t i f i e d . CD W 3/ 1 3 / 2 0 2 4 A. D e w h u r s t 18 M A R 2 4 (a ) ( 1 1 ) F a u l t s a n d f r a c t u r e s , L o c a t i o n , or i e n t a t i o n Op e r a t o r h a s i d e n t i f i e d 5 f a u l t s w i t h i n a ½ m i l e r a d i u s o f KR U 2 A - 1 0 A . D e t a i l s p r o v i d e d i n a p p l i c a t i o n . Th e l a r g e s t f a u l t o f f s e t s t h e t o p o f t h e ~ 3 5 0 t h i c k u p p e r co n f i n i n g z o n e b y a p p r o x i m a t e l y 7 0 . A. D e w h u r s t 18 M A R 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n C h e c k l i s t KR U 2 A - 1 0 A ( P T D N o . 2 2 3 - 0 9 2 ; S u n d r y N o . 3 2 4 - 1 3 9 ) Pa r a g r a p h Su b -Pa r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 4 M a r c h 1 8 , 2 0 2 4 (a ) ( 1 1 ) F a u l t s a n d f r a c t u r e s , S u f f i c i e n t in f o r m a t i o n t o d e t e r m i n e n o i n t e r f e r e n c e wi t h c o n t a i n m e n t w i t h i n ½ m i l e (a ) ( 1 2 ) P r o p o s e d p r o g r a m f o r f r a c t u r i n g op e r a t i o n Pr o v i d e d w i t h a p p l i c a t i o n . CD W 3/ 1 1 / 2 4 ( a ) ( 1 2 ) ( A ) E s t i m a t e d v o l u m e Pr o v i d e d w i t h a p p l i c a t i o n . 18 5 4 bb l t o t a l d i r t y v o l . 95 K lb to t a l p r o p p a n t CD W 3/ 1 1 / 2 4 (a ) ( 1 2 ) ( B ) A d d i t i v e s : n a m e s , p u r p o s e s , co n c e n t r a t i o n s Pr o v i d e d w i t h a p p l i c a t i o n . CD W 3/ 1 1 / 2 4 (a ) ( 1 2 ) ( C ) C h e m i c a l n a m e a n d C A S nu m b e r o f e a c h Pr o v i d e d w i t h a p p l i c a t i o n . Ha l l i b u r t o n di s c l o s u r e p r o v i d e d . Pr o p r i e t a r y c h e m i c a l s o n f i l e a t A O G C C . CD W 3/ 1 1 / 2 4 (a ) ( 1 2 ) ( D ) I n e r t s u b s t a n c e s , w e i g h t o r vo l u m e o f e a c h Pr o v i d e d w i t h a p p l i c a t i o n . CD W 3/ 1 1 / 2 4 (a ) ( 1 2 ) ( E ) M a x i m u m t r e a t i n g p r e s s u r e w i t h su p p o r t i n g i n f o t o d e t e r m i n e ap p r o p r i a t e n e s s f o r p r o g r a m Max s u r f a c e p r e s s u r e 55 0 0 ps i . M a x p r e s s u r e i s 60 5 0 ps i t o Pu m p s h u t d o w n , 6 6 5 0 p s i E l e c t r o n i c P R V . W i t h 3 0 0 0 p s i ba c k p r e s s u r e I A ( I A p o p o f f s e t 3 1 0 0 p s i ) , m a x t u b i n g di f f e r e n t i a l s h o u l d b e 2 5 0 0 p s i . CD W 3/ 1 1 / 2 4 (a ) ( 1 2 ) ( F ) F r a c t u r e s h e i g h t , l e n g t h , M D an d T V D t o t o p , d e s c r i p t i o n o f f r a c t u r i n g mo d e l Pr o v i d e d w i t h a p p l i c a t i o n . Th e a n t i c i p a t e d h a l f -le n g t h o f th e i n d u c e d f r a c t u r e s i s 2 1 0 a c c o r d i n g t o t h e O p e r a t o r s co m p u t e r s i m u l a t i o n . S i m u l a t i o n i n d i c a t e s t h e a n t i c i p a t e d he i g h t o f t h e i n d u c e d f r a c t u r e s w i l l b e 2 0 0 ( t o p T V D o f ab o u t 6 , 9 0 9 , s o i n d u c e d f r a c t u r e s w i l l l i k e l y p e n e t r a t e i n t o , bu t n o t t h r o u g h , t h e o v e r l y i n g c o n f i n i n g K a l u b i k a n d H R Z sh a l e s t h a t a r e a b o u t 3 5 0 t h i c k . A. D e w h u r s t 15 M A R 2 4 (a ) ( 1 3 ) P r o p o s e d p r o g r a m f o r p o s t - fr a c t u r i n g w e l l c l e a n u p a n d f l u i d r e c o v e r y We l l c l e a n o u t a n d f l o w b a c k p r o c e d u r e p r o v i d e d wi t h ap p l i c a t i o n . N o d i s p o s a l i d e n t i f i e d CD W 3/ 1 1 / 2 4 (b ) T e s t i n g o f c a s i n g or i n t e r m e d i a t e ca s i n g Te s t e d > 1 1 0 % o f m a x a n t i c i p a t e d p r e s s u r e 30 0 0 p s i b a c k p r e s s u r e , a n n u l u s t e s t e d t o 3 3 0 0 p s i , p o p o f f se t a s 3 1 0 0 p s i CD W 3/ 1 1 / 2 4 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n C h e c k l i s t KR U 2 A - 1 0 A ( P T D N o . 2 2 3 - 0 9 2 ; S u n d r y N o . 3 2 4 - 1 3 9 ) Pa r a g r a p h Su b -Pa r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 5 M a r c h 1 8 , 2 0 2 4 (c ) F r a c t u r i n g s t r i n g (c ) ( 1 ) P a c k e r > 1 0 0 b e l o w T O C o f pr o d u c t i o n o r i n t e r m e d i a t e c a s i n g 3. 5 t u b i n g w i l l b e a n c h o r e d w i t h a p a c k e r s e t a t a p p r o x . . 67 4 4 f t a n d 6 8 9 7 f t w i t h p e r f o r a t i o n s p l a n n e d f o r 6 8 0 1 - 6 8 5 6 (C - S a n d ) a n d 6 9 0 9 - 6 9 6 5 f t ( A - S a n d ) . 9 - 5 / 8 s u r f a c e c a s i n g ce m e n t e d t o s u r f a c e . TO C i n 9 - 5 / 8 c a s i n g a t s u r f a c e . TO C i n 5 - 1 / 2 c a s i n g a t 6 3 8 5 f t b y C B L . Go o d c e m e n t a t a r e a o f i n t e r e s t s o n o c e m e n t c o n c e r n s . CD W 3/ 1 1 / 2 4 (c ) ( 2 ) T e s t e d > 1 1 0 % o f m a x a n t i c i p a t e d pr e s s u r e d i f f e r e n t i a l Tu b i n g t e s t o f 30 5 0 ps i . M a x p r e s s u r e d i f f e r e n t i a l i s es t i m a t e d a s 2 5 0 0 p s i ( 5 5 0 0 w i t h 3 0 0 0 p s i b a c k p r e s s u r e ) s o te s t o f 3 0 5 0 p s i s a t i s f i e s 1 1 0 % CD W 3/ 1 1 / 2 4 (d ) P r e s s u r e r e l i e f va l v e Li n e p r e s s u r e < = t e s t p r e s s u r e , r e m o t e l y co n t r o l l e d s h u t - i n d e v i c e 10 , 0 0 0 p s i l i n e pr e s s u r e t e s t , p u m p kn o c k o u t 60 5 0 ps i w i t h ma x . g l o b a l k i c k o u t 6 6 5 0 p s i . I A P R V s e t a s 3 1 0 0 p s i . CD W 3/ 1 1 / 2 4 (e ) C o n f i n e m e n t Fr a c f l u i d s c o n f i n e d t o a p p r o v e d fo r m a t i o n s Pr o v i d e d w i t h a p p l i c a t i o n . CD W 3/ 1 1 / 2 4 (f ) S u r f a c e c a s i n g pr e s s u r e s Mo n i t o r e d w i t h g a u g e a n d p r e s s u r e r e l i e f de v i c e IA P R V s e t a t 31 00 p s i . S u r f a c e a n n u l u s o p e n . F r a c p r e s s u r e s co n t i n u o u s l y m o n i t o r e d . CD W 3/ 1 1 / 2 4 (g ) A n n u l u s pr e s s u r e mo n i t o r i n g & no t i f i c a t i o n 50 0 p s i c r i t e r i a Du r i n g h y d r a u l i c f r a c t u r i n g o p e r a t i o n s , a l l a n n u l u s p r e s s u r e s mu s t b e c o n t i n u o u s l y m o n i t o r e d a n d r e c o r d e d . I f a t a n y ti m e d u r i n g h y d r a u l i c f r a c t u r i n g o p e r a t i o n s t h e a n n u l u s pr e s s u r e i n c r e a s e s m o r e t h a n 5 0 0 p s i g a b o v e t h o s e an t i c i p a t e d i n c r e a s e s c a u s e d b y p r e s s u r e o r t h e r m a l tr a n s f e r , t h e o p e r a t o r s h a l l : CD W 3/ 1 1 / 2 4 ( g ) ( 1 ) N o t i f y A O G C C w i t h i n 2 4 h o u r s ( g ) ( 2 ) C o r r e c t i v e a c t i o n o r s u r v e i l l a n c e ( g ) ( 3 ) S u n d r y t o A O G C C (h ) S u n d r y R e p o r t (i ) R e p o r t i n g ( i ) ( 1 ) F r a c F o c u s R e p o r t i n g (i ) ( 2 ) AO G C C R e p o r t i n g : p r i n t e d & el e c t r o n i c 20 A A C 2 5 . 2 8 3 H y d r a u l i c F r a c t u r i n g A p p l i c a t i o n C h e c k l i s t KR U 2 A - 1 0 A ( P T D N o . 2 2 3 - 0 9 2 ; S u n d r y N o . 3 2 4 - 1 3 9 ) Pa r a g r a p h Su b -Pa r a g r a p h Se c t i o n Co m p l e t e ? AO G C C P a g e 6 M a r c h 1 8 , 2 0 2 4 (j ) P o s t -fr a c w a t e r sa m p l i n g p l a n No t r e q u i r e d ( s e e S e c t i o n ( a ) ( 3 ) , a b o v e ) A. D e w h u r s t 15 M A R 2 4 (k ) C o n f i d e n t i a l in f o r m a t i o n Cl e a r l y m a r k e d a n d s p e c i f i c f a c t s su p p o r t i n g n o n d i s c l o s u r e No c o n f i d e n t i a l m a t e r i a l i d e n t i f i e d . A. D e w h u r s t 15 M A R 2 4 (l ) V a r i a n c e s re q u e s t e d Mo d i f i c a t i o n s o f d e a d l i n e s , r e q u e s t s f o r va r i a n c e s o r w a i v e r s No p l a n f o r p o s t f r a c t u r e w a t e r w e l l a n a l y s i s . C o m m i s s i o n m a y r e q u i r e t h i s d e p e n d i n g o n p e r f o r m a n c e o f t h e f r a c t u r i n g o p e r a t i o n . Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 12 Z Ͳ16 5 0 Ͳ02 9 Ͳ21 3 6 3 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲFe b Ͳ24 0 1 23 B Ͳ10 5 0 Ͳ02 9 Ͳ21 3 6 8 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 9 ͲNo v Ͳ23 0 1 33 F Ͳ14 5 0 Ͳ02 9 Ͳ21 5 0 0 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲFe b Ͳ24 0 1 43 H Ͳ13 A 5 0 Ͳ10 3 Ͳ20 0 8 9 Ͳ01 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 1 1 ͲJa n Ͳ24 0 1 53 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 1 0 ͲDe c Ͳ23 0 1 63 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 1 0 ͲDe c Ͳ23 0 1 72 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 n / a K u p a r u k R i v e r R a d i a l B o n d R e c o r d F i e l d & P r o c e s s e d 2 6 ͲFe b Ͳ24 0 1 83 K Ͳ17 5 0 Ͳ02 9 Ͳ21 6 4 2 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 ͲDe c Ͳ23 0 1 93 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 9 ͲDe c Ͳ23 0 1 10 3 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲJa n Ͳ24 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 8 0 T5 8 5 9 1 T3 8 5 9 0 T5 8 5 9 1 T3 8 5 8 9 T3 8 5 8 9 T3 8 5 8 8 T3 8 5 8 7 T3 8 5 8 6 T3 8 5 8 5 18 5 - 1 0 9 18 5 - 1 1 4 18 5 - 2 9 2 19 6 - 1 9 7 20 9 - 1 0 3 22 3 - 0 9 2 18 6 - 1 5 2 19 8 - 2 4 9 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h Gu h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 5 0 : 3 7 - 0 9 ' 0 0 ' 2A Ͳ10 A 22 3-09 2 Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 11 B Ͳ16 A 5 0 Ͳ02 9 Ͳ22 4 5 7 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 7 ͲDe c Ͳ23 0 1 21 D Ͳ13 0 5 0 Ͳ02 9 Ͳ22 8 1 5 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲDe c Ͳ23 0 1 31 D Ͳ14 1 A 5 0 Ͳ02 9 Ͳ22 9 6 7 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲDe c Ͳ23 0 1 41 H Ͳ10 2 5 0 Ͳ02 9 Ͳ23 5 8 0 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 4 ͲJa n Ͳ24 0 1 51 Y Ͳ06 A 5 0 Ͳ02 9 Ͳ20 9 5 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 0 ͲFe b Ͳ24 0 1 62 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 9 0 9 1 7 6 6 9 3 K u p a r u k R i v e r P e r f o r a t i o n R e c o r d F i e l d Ͳ Fi n a l 2 6 ͲFe b Ͳ24 0 1 72 C Ͳ12 5 0 Ͳ02 9 Ͳ21 2 2 2 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲDe c Ͳ23 0 1 82 F Ͳ15 5 0 Ͳ02 9 Ͳ21 0 4 8 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲFe b Ͳ24 0 1 92 U Ͳ05 5 0 Ͳ02 9 Ͳ21 2 8 1 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d & P r o c e s s e d 8 ͲDe c Ͳ23 0 1 10 2 W Ͳ01 5 0 Ͳ02 9 Ͳ21 2 7 3 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲDe c Ͳ23 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 7 5 T3 8 5 7 6 T3 8 5 7 7 T3 8 5 7 8 T3 8 5 7 9 T3 8 5 8 0 T3 8 5 8 1 T3 8 2 8 2 T3 8 5 8 3 T3 8 5 8 4 21 8 - 1 5 5 19 7 - 1 8 3 20 8 - 0 1 6 21 7 - 0 9 7 19 7 - 1 3 4 22 3 - 0 9 2 18 4 - 2 0 6 18 3 - 1 7 2 18 5 - 0 1 8 18 5 - 0 1 0 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h G u h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 1 9 : 5 8 - 0 9 ' 0 0 ' 22 3-09 2 62 A Ͳ10 A T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Mar 01, 2024 AOGCC Attention: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 2A-10A Kuparuk River API #: 50-103-20056-01-00 Permit No: 223-092 Rig: Nabors 7ES The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com 223-092 T38545 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.01 14:00:14 -09'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov $GDP .OHP 'ULOOLQJ Engineer Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 2A-10A Conoco Phillips Alaska, Inc. Permit to Drill Number: 223-092 Surface Location: 3953' FNL, 53' FEL, Sec 14, T11N, R8E, UM Bottomhole Location: 1433'FNL, 1142'FEL, SEC 23, T11N, R8E, UM Dear Mr..OHP: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCCreserves 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 AOGCCspecifically 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 AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of November 2023. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.27 15:30:21 -09'00' 27 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 7082'TVD:6113' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 10/26/2023 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2560 3771' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 123' 15. Distance to Nearest Well Open Surface: x- 5960748 y- 498341 Zone-4 88' to Same Pool:60' @ Surface 16. Deviated wells: Kickoff depth: 6100' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 46 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 24" 16" 62.5 H-40 Weld 71' 35' 35' 106' 106' 12.25" 9-5/8" 36 J-55 BTC 2828' 35' 35' 2863' 2773' 8.5" 7" 26 L-80 TCII 2101' 25' 25' 2126' 2116' 8.5" 7" 26 L-80 TCII 6655' 35' 35' 6690' 5799' 7" 5.5" 17 & 15.5 L-80 HYD 563 & HYD 521 982' 6100' 5210' 7082' 5990' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): 6931' TVD 106' 2773' 2116' 5799' 6240' Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Adam Klem Adam Klem Contact Email:Adam.klem@conocophillips.com Drilling Engineer Contact Phone:907-263-4529 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 106' 2863'9-5/8" 810 sx CS III/310 sx CS II Effect. Depth MD (ft): Effect. Depth TVD (ft): MD Plugs (measured): Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2828' 310 sx CS IIConductor/Structural 16"71' 7260'6248' LengthCasing 6220' 6390'Cement VolumeSize Authorized Title: Authorized Signature: 5" 2126' 200 sx Class G/175 sx CS I 140 sx Class G Production Liner 2101' 6655' 813' Production 7" tieback w/patc Authorized Name: 6783-6837' 6892-6902' 6918-6950' (including stage data) 310 sx CS II 810 sx CS III/310 sx CS II 6897' 5966' 118 sx of 15.3ppg Class G 200 sx Class G/175 sx CS I 18. Casing Program: Top - Setting Depth - BottomSpecifications 2803psi Cement Quantity, c.f. or sacks Total Depth MD (ft): Total Depth TVD (ft): 5952180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2204psi 1315' FNL, 1133'FEL, SEC23, T11N, R8E, UM 1433'FNL, 1142'FEL, SEC 23, T11N, R8E, UM 86-2 P.O. Box 100360 Anchorage, AK 99510 ConocoPhillips Alaska, Inc. 3953' FNL, 53' FEL, Sec 14, T11N, R8E, UM ADL 0025570 KRU 2A-10A Kuparuk River Field/ Kuparuk River Oil Pool 5874-5918' 5962-5969' 5982-6007' Commission Use Only See cover letter for other requirements. 6690'7" 7" 7250' 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Adam Klem Digitally signed by Adam Klem Date: 2023.10.02 14:28:42 -08'00' By Grace Christianson at 8:32 am, Oct 04, 2023 6690' 5960747.8 223-092 VTL 11/27/2023 BOP test to 3500 psig Annular preventer to 2500 psig A.Dewhurst 19OCT23 50-103-20056-01-00 498340.7 X DSR-10/5/23*&:JLC 11/27/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.27 15:30:38 -09'00'11/27/23 11/27/23 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 29, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 2A-10A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore, development producer well into the Kuparuk A and C formations, sidetracking out of the existing 2A-10 well, from the existing 2A pad in Kuparuk. The intended spud date for this well is 10/26/23. It is intended that Nabors 7ES be used to drill the well. 2A-10A will sidetrack out of the existing 7” intermediate casing in the 2A-10 wellbore. A 7” hole will be drilled to the planned TD 6-1/8” bit with 7” bicenter underreamer, and a 5-1/2” longstring casing will be run to surface and cemented back to the 7”casing window, with the top planned at 6000’MD (814’ MD or 618’TVD above the top of the Kuparuk C interval). The well will be completed as a fracture stimulated Producer with a single stage frac job planned in the Kuparuk A sand formation with non stimulated perforations in the Kuparuk C sand. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Adam Klem at 263-4529 (adam.klem@conocophillips.com) or Jonathan Coberly at 265-1013. Sincerely, Adam Klem RWO Engineer Adam Klem Digitally signed by Adam Klem Date: 2023.10.02 14:28:06 -08'00' Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 1 of 7 Printed: 29-Sep-23 2A-10A Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2))Error! Bookmark not defined. 3. Proposed Drilling Program ...................................................................................... 2 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 3 5. MASP Calculations ................................................................................................... 3 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 4 7. Casing and Cementing Program ............................................................................. 4 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 4 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 5 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 5 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 5 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 5 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 5 (Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 5 14. Drilling Hazards Summary ....................................................................................... 5 15. Proposed Completion Schematic ........................................................................... 7 Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 2 of 7 Printed: 29-Sep-23 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 2A-10A 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 3953' FNL, 53' FEL, S14 T11N R8E, UM NAD 1927 Northings: 5960747.76 Eastings: 498340.70 RKB Elevation 123.0’ AMSL Pad Elevation 88.0’ AMSL Location at Sidetrack KOP 861' FNL, 1048' FEL, S23 T11N R8E, UM NAD 1927 Northings: 5958560.68 Eastings: 497346.23 Measured Depth, RKB: 6100’ Total Vertical Depth, RKB: 5333’ Total Vertical Depth, SS: 5210’ Top of Productive Horizon 1315' FNL, 1133' FEL, S23 T11N R8E, UM NAD 1927 Northings: 5958106.41 Eastings: 497261.52 Measured Depth, RKB: 6814’ Total Vertical Depth, RKB: 5873’ Total Vertical Depth, SS: 5750’ Total Depth 1433' FNL, 1142' FEL, S23 T11N R8E, UM NAD 1927 Northings: 5957987.91 Eastings: 497252.64 Measured Depth, RKB: 7082’ Total Vertical Depth, RKB: 6113’ Total Vertical Depth, SS: 5990’ 3. Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. Pre Rig: 1. Slickline: Pull plug and BHP guage 2. Coil tubing: set retainer ~6,335ft KB; pump 25 bbls across/into perfs; un-sting and lay in 2 bbls to ~6,100ft KB 3. Slickline: pressure test; tag TOC, pull GLV 4. Circ in SW to surface 5. Eline: Cut tubing ~6,180ft KB Nabors 7ES: 1. MIRU Nabors 7ES on 2A-10A. 2. Install and test BOPE to 250 psi low / 3500 psi high (2500 psi annular) 3. Pull and lay down existing tubing (pre-rig cut at ~6180’). 4. Run casing scraper down to 6100’. 5. Set plug at ~600’and PT 6. ND BOP, NU new casing head for 5.5” casing. NU BOP. 7. Set whipstock at 6100’, oriented 30° LOHS. 8. Perform pressure test on 7” casing to 2000 psi. 9. Mill window in 7” casing. 10. Drill 6-1/8” hole to TD, 150’ MD below planned perforations. Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 3 of 7 Printed: 29-Sep-23 11. Circulate hole clean and pull out of hole with drilling BHA. 12. Run 5.5” longstring to TD. 13. Cement casing, bringing cement into window. 14. WOC. Run CBL log from TD to 5900’ MD. 15. Perforate the Kuparuk A and C sands 16. Run 3.5” upper completion. Circulate in CI brine 17. Set packers 18. Pressure test hanger seals to 5,000 psi. 19. Test tubing to 3500 psi, chart test. 20. Test IA to 3500 psi, chart test. 21. Install BPV and test to 2500 psi. 22. Nipple down BOP. 23. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 24. Freeze protect down tubing and annulus. 25. Secure well. Rig down and move out. 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP schematics on file for Nabors 7ES. As this well is a sidetrack below the surface casing, no diverter will be used. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Casing/Window Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 7 6100 / 5210 17.9 2295 4328 5.5 7082 / 5990 16.4 2803 2204 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 4 of 7 Printed: 29-Sep-23 Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling 6-1/8” hole out of 7” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(17.9 x 0.052) – 0.1] x 5210= 4328 psi OR ASP = FPP – (0.1 x D) = 2803– (0.1 x 5990) = 2204 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) FIT to 12.5 ppg was performed on surface shoe during initial drilling of 2A-10. No FIT/LOT is planned as part of this sidetrack. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 5.5 7 17#& 15.5 L-80 Hyd563 & Hyd521 Cemented liner Tail slurry from 7082’ MD to 6000’ MD with 15.3 ppg Class G Total Volume = 145.9ft3 => 118 sx of 15.3 ppg Class G 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Cementing Calculations 5-1/2” production casing run to 7082’ MD / 5990’ TVD Top of slurry is designed to be at 6000’ MD, 100’ above the window out of the 7”, which is 814’MD / 618’ TVD above the top of the Kuparuk interval. Assume 30% excess annular volume. Current plan is to use 15.3ppg Class G cement, however at this time a lighter weight cement slurry is also being evaluated to minimize chances of losses during cementing. Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 5 of 7 Printed: 29-Sep-23 Production Hole Size in. 7 Casing Size in. 5.5 Density PPG 9.5-11.2 PV cP 19 YP lb./100 ft2 12-18 Funnel Viscosity s/qt. 40 - 50 Initial Gels lb./100 ft2 8-15 10 Minute Gels lb./100 ft2 8-15 API Fluid Loss cc/30 min. <10 HPHT Fluid Loss cc/30 min. <10 pH 9.5 – 10.0 The interval will be drilled with a water-based mud (LSND) weighted to 9.5-11-2 ppg. Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A – No abnormally pressured formations expected 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A – No seismic to be performed, drilling in well developed area. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well 2A-10A will be injected into a permitted annulus on 1B pad. 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 7” Hole / 5.5” Casing - Slant Production Hole Event Risk Level Mitigation Strategy Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 6 of 7 Printed: 29-Sep-23 Lost circulation Med Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, planned lost circulation material prior to entering formation Hole swabbing on trips Med Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: No collision risks exist in the planned 2A-10A wellbore. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Lost returns are possible if weaker than expected formations or stringers are encountered. LCM material will be available to seal in losses if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Application for Permit to Drill, «Well_Name» Saved: 29-Sep-23 2A-10A APD Page 7 of 7 Printed: 29-Sep-23 15. Proposed Completion Schematic 2 ADL025570 T1 1 N R 9 E T1 1 N R 8 E 26 25 14 23 13 24 2A 2T-36 2T - 4 2T - 4 2 T - 1 5 2T- 1 0 L 1 - 0 1 2T- 1 7 2 H - 1 2 2M-25 2T - 1 4 2A-02 2H-0 3 2A-11 2T-1 62T-37 2A - 1 8 2M-2 0 2T-21 2M - 2 1 2T-37L1-01 2 A - 0 3 2H - 1 7 2 A - 1 2 2H-05 2A - 1 0 2H-15 2A- 0 1 2A- 0 1 A 2A-14 2 H - 0 9 2H - 0 2 2A-07 2A-27 2T - 3 7 L 1 2A-06 2A - 2 6 2A- 2 7 A 2 A - 0 4 2M - 2 1 L 1 2A-13 2A- 1 5 2H - 1 6 2H-0 6 2A- 0 8 2A - 0 9 2M - 2 1 L 1 - 0 1 2A- 0 5 2 A - 2 6 L 1 2A-26 L 1 - 0 1 2A-24 2 A - 1 6 2A-19A 2A-19 2A-17 2A-21 2A-25 2A-20 2A-23 2A-22 2A-22A 2A-22AL1 Document Path: S:\ANC\Longterm\AK GIS\GKA\DM\GKA_Wells_AD01\CPF_2_Wells\Well_2A-10A\2A-10A Well.aprx 10/18/2023 2A-10A PTD 2A - 1 0 A Main Trajectory Perforated Interval Proposed P+A Well Active Well 2 Well Pad Roads and Pads Kuparuk PA Unit Boundary ADNR Section ADNR Township CPAI Lease 00.450.23 Miles ADL025569 ADL025571 ADL025587 ! " # $ $ % & $ ' ($ #) * * ! " #$% &%+,) * ' ( &* ! 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B B ? /B /B / ? /B /4B /4 1 ? /B /4B /4 1 ? 4 - 3 - $ . 1 Dewhurst, Andrew D (OGC) From:Klem, Adam <Adam.Klem@conocophillips.com> Sent:Wednesday, October 18, 2023 13:13 To:Dewhurst, Andrew D (OGC) Cc:Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL]KRU 2A-10A (PTD 223-092) - Questions Attachments:LK6201D30-Current.pdf; 2A-10A_PTD_Final.pdf Ithinkthisistheplatandsurveyyourequested.Letmeknowifyouneedanythingelse From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Monday,October16,20231:15PM To:Klem,Adam<Adam.Klem@conocophillips.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]KRU2AͲ10A(PTD223Ͳ092)ͲQuestions Adam, SƟllnotopening.Notsure.Ihadacolleaguetryontheircomputeranditgaveanerror.IwouldbeĮnewitha.jpgor .pngimageoftheplatifneedbe. Thanks, Andy From:Klem,Adam<Adam.Klem@conocophillips.com> Sent:Monday,October16,202313:01 To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]KRU2AͲ10A(PTD223Ͳ092)ͲQuestions Hmm,odd.Tryingagainforthepdfs: From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Monday,October16,202312:59PM To:Klem,Adam<Adam.Klem@conocophillips.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]KRU2AͲ10A(PTD223Ͳ092)ͲQuestions Adam, Forsomereason,IamunabletoopentheĮrstPDFyousent(CompassPlotsandReports).Butyes,thesurveyistheasͲ builtofthepadwiththelocaƟonsoftheconductors,withasignedsurveyor’sstamp(unsignedexamplebelow). 2 Andy From:Klem,Adam<Adam.Klem@conocophillips.com> Sent:Monday,October16,202312:41 To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]KRU2AͲ10A(PTD223Ͳ092)ͲQuestions x WouldyoupleaseprovideaplatshowingthewellpathandleaseinformaƟon? o SeeaƩached x WouldyouconĮrmthatthe2ApadisanH2Spad?ThemostrecentreportIhaveis50ppmat2AͲ19(04JAN23). IsthereanyotherperƟnentH2SinformaƟon? o Yes.RecentH2Son2AͲ10was100ppmon12/19/17,historicalhighonpadwas650ppmbackon6/7/94. x Doyouhaveacopyofthelatestsurveyforthe2Apad?Wedon’tneedtoseethesurveyforeverywellonapad. Butwouldyoueitherprovideacopyofthelatest,orreferencewhichwell(orPTDnumber)itwaspreviously submiƩedwith? o Workingonthis.Whatalldoyouneed? From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Monday,October9,20231:53PM To:Klem,Adam<Adam.Klem@conocophillips.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:[EXTERNAL]KRU2AͲ10A(PTD223Ͳ092)ͲQuestions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adam, IamcompleƟngmyreviewoftheKRU2AͲ10APTDapplicaƟonandIhaveafewquesƟons: x WouldyoupleaseprovideaplatshowingthewellpathandleaseinformaƟon? x WouldyouconĮrmthatthe2ApadisanH2Spad?ThemostrecentreportIhaveis50ppmat2AͲ19(04JAN23). IsthereanyotherperƟnentH2SinformaƟon? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 x Doyouhaveacopyofthelatestsurveyforthe2Apad?Wedon’tneedtoseethesurveyforeverywellonapad. Butwouldyoueitherprovideacopyofthelatest,orreferencewhichwell(orPTDnumber)itwaspreviously submiƩedwith? Thanks, Andy AndrewDewhurst SeniorPetroleumGeologist AlaskaOilandGasConservaƟonCommission 333W.7thAve,Anchorage,AK99501 andrew.dewhurst@alaska.gov Direct:(907)793Ͳ1254 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 no greater 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. KUPARUK RIVER X KUPARUK RIV OIL POOL 223-092 KRU 2A-10A W E L L P E R M I T C H E C K L I S T Co m p a n y Co n o c o P h i l l i p s A l a s k a , I n c . We l l N a m e : KU P A R U K R I V U N I T 2 A - 1 0 A In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t 11 1 6 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 0 9 2 0 KU P A R U K R I V E R , K U P A R U K R I V O I L - 4 9 0 1 0 0 NA 1 Pe r m i t f e e a t t a c h e d Ye s AD L 0 0 2 5 5 7 0 2 Le a s e n u m b e r a p p r o p r i a t e Ye s 3 Un i q u e w e l l n a m e a n d n u m b e r Ye s KU P A R U K R I V E R , K U P A R U K R I V O I L - 4 9 0 1 0 0 - g o v e r n e d b y 4 3 2 E 4 We l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 We l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 We l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 Su f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 If d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 Op e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 Op e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 Pe r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 Pe r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 Ca n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 We l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r NA 15 Al l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 Pr e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 No n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) NA 18 Co n d u c t o r s t r i n g p r o v i d e d NA 19 Su r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s NA 20 CM T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g NA 21 CM T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s 22 CM T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 23 Ca s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s 24 Ad e q u a t e t a n k a g e o r r e s e r v e p i t Ye s PT D 1 8 6 - 0 0 2 , S u n d r y 3 2 3 - 3 2 9 25 If a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s 26 Ad e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d NA 27 If d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s Ma x f o r m a t i o n p r e s s u r e i s 2 8 0 3 p s i g ( 8 . 8 p p g E M W ) ; w i l l d r i l l w / 9 . 5 - 1 1 . 2 p p g E M W 28 Dr i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s 29 BO P E s , d o t h e y m e e t r e g u l a t i o n Ye s MP S P i s 2 2 0 4 p s i g ; w i l l t e s t B O P s t o 3 5 0 0 p s i g 30 BO P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s 31 Ch o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 Wo r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n Ye s 33 Is p r e s e n c e o f H 2 S g a s p r o b a b l e No 34 Me c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No We l l s o n 2 A - P a d a r e H 2 S b e a r i n g . H 2 S m e a s u r e s r e q u i r e d . 35 Pe r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s Ex p e c t e d r e s e r v o i r p r e s s u r e i s 8 . 8 p p g E M W . 36 Da t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 Se i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 Se a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 Co n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 10 / 1 9 / 2 0 2 3 Ap p r VT L Da t e 11 / 2 7 / 2 0 2 3 Ap p r AD D Da t e 10 / 9 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *&: JL C 1 1 / 2 7 / 2 0 2 3
