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223-125
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 - 0 2 9 - 2 1 2 8 9 - 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 3 B - 1 6 A Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 3/ 1 4 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 1 2 5 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 79 9 6 TV D 62 6 2 Cu r r e n t S t a t u s WA G I N 1/ 1 3 / 2 0 2 6 UI C Ye s 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 No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 4/ 3 / 2 0 2 4 66 0 0 7 9 9 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : 3 B - 16 A _ R T _ 5 M D _ F i n a l . l a s 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 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 : 3 B - 16 A _ R T _ F i n a l _ A P R u n 1 . l a s 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 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 : 3 B - 16 A _ R T _ F i n a l _ A P R u n 2 . l a s 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 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 : 3 B - 16 A _ R T _ F i n a l _ A P R u n 3 . l a s 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 2 M D _ F i n a l . c g m 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 2 T V D _ F i n a l . c g m 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 5 M D _ F i n a l . c g m 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 5 T V D _ F i n a l . c g m 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ A P _ F i n a l . c g m 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 2 M D _ F i n a l . p d f 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 2 T V D _ F i n a l . p d f 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 5 M D _ F i n a l . p d f 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ 5 T V D _ F i n a l . p d f 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ R T _ A P _ F i n a l . p d f 38 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 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 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 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 6 8 1 ED Di g i t a l D a t a DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 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 6 8 1 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 3 3B - , 16 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 - 0 2 9 - 2 1 2 8 9 - 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 3 B - 1 6 A Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 3/ 1 4 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 1 2 5 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 79 9 6 TV D 62 6 2 Cu r r e n t S t a t u s WA G I N 1/ 1 3 / 2 0 2 6 UI C Ye s 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 4 / 2 0 2 4 Re l e a s e D a t e : 1 / 3 / 2 0 2 4 DF 4/ 3 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 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 6 8 1 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 4 77 7 2 7 6 0 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 : 3 B - 16 A _ P E R F _ 1 8 M A Y 2 4 _ C o r r e l a t i o n . l a s 39 1 6 8 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 4 77 4 1 7 6 9 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 : 3 B - 16 A _ P E R F _ 1 8 M A Y 2 4 _ S h o o t i n g _ 7 7 5 1 - 7 7 3 8 f t . l a s 39 1 6 8 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 4 77 5 6 7 6 8 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : 3 B - 16 A _ P E R F _ 1 8 M A Y 2 4 _ S h o o t i n g _ 7 7 6 5 - 7 7 5 1 f t . l a s 39 1 6 8 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 4 77 6 8 7 7 3 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 : 3 B - 16 A _ P E R F _ 1 8 M A Y 2 4 _ S h o o t i n g _ 7 7 8 5 - 7 7 6 5 f t . l a s 39 1 6 8 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ P E R F _ 1 8 M A Y 2 4 . p d f 39 1 6 8 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 4 E l e c t r o n i c F i l e : 3 B - 1 6 A _ P E R F _ 1 8 M A Y 2 4 _ i m g . t i f f 39 1 6 8 ED Di g i t a l D a t a DF 5/ 2 8 / 2 0 2 5 79 1 2 4 2 0 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 : 4 7 8 6 _ C P A I _ 3 B - 16 A _ C B L _ 1 8 - A p r i l - 2 0 2 4 _ L A S . l a s 40 4 5 1 ED Di g i t a l D a t a DF 5/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : 4 7 8 6 _ C P A I _ 3 B - 1 6 A _ C B L _ 1 8 - Ap r i l - 2 0 2 4 . p d f 40 4 5 1 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 3 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 - 0 2 9 - 2 1 2 8 9 - 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 3 B - 1 6 A Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 3/ 1 4 / 2 0 2 4 Pe r m i t t o D r i l l 22 3 1 2 5 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 79 9 6 TV D 62 6 2 Cu r r e n t S t a t u s WA G I N 1/ 1 3 / 2 0 2 6 UI C Ye s 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 3 o f 3 1/ 1 6 / 2 0 2 6 M. G u h l ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 3B-16 A 50029212890100 2231250 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed: Other:Coiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment Service 6. API Number:Stratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth 7996'feet None feet feetNonefeet6262'true vertical measuredEffective Depth 7996'feet 6580'feet feet5336'feet6262'true vertical Measured depthPerforation depth True Vertical depth 6255' TVD7986' MDL-803-1/2"Tubing (size, grade, measured and true vertical depth) 6580' MDPackers and SSSV (type, measured and true vertical depth) N/A 5336' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/ATreatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Contact Name:Digital Signature with Date: Contact Email: Contact Phone:Authorized Title: 3270'3409' CollapseBurst Production Liner 7835' Casing 6325'7858' 3379' 117'Conductor Surface Intermediate 16" 9-5/8" 85' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-125 50-029-21289-01-00 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: ADL0025 Kuparuk River Field / Kuparuk River Oil Pool KRU 3B-16A Plugs measuredJunk Length 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) ~ Gas-Mcf MD ~ Size 117' ~~~ ~INJECTOR ~ ~ Sr Res Eng:Sr Pet Geo:Sr Pet 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: SLB BluPack SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Senior RWO/ CTD Engineer 7738-7785' 6089-6120' Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 324-253 Kuparuk River Oil Pool -DQ By Grace Christianson at 10:51 am, Jan 10, 2025 JJL 2/7/25 DSR-1/16/25 RBDMS JSB 011525 ADL0025633 SFD SFD 2/7/2025 Perforate DTTMSTART JOBTYP SUMMARYOPS 4/18/2024 SUPPORT OTHER OPERATIONS LOG CORRELATED TO BAKER HUGHES LWD DATED 11-MAR-2024, TAG BOTTOM @ 7878' ELMD, LOG CBL FROM 7850'-4200', TOC FIELD PICK: 6574', POSIBLE CEMENT STRINGERS OR DEBRIS ABOVE 6500', PERFORM LOSS OF WELL CONTROL DRILL W/ CREW & WSL. WAIT FOR APPROVED SUNDRY PRIOR TO PERFORATING. NOTE: SL UNABLE TO GET 2.7" PERF GUN DRIFT PAST 6504' RKB. READY FOR PLAN FORWARD. 4/22/2024 SUPPORT OTHER OPERATIONS RUN KOT & LOCATE ST# 2 GLM @ 6511' RKB TO OBTAIN A CORRECTION FACTOR, FREELY DRIFTED THRU KNOWN TIGHT SPOT @ 6514' RKB & TAG SOLID @ 6569' RKB (BAKER SLEEVE @ 6569' RKB). JOB IN PROGRESS. ***FOUND CEMENT SHEATH IN #2 GLM @ 6511' RKB WAS NOT ABLE TO GET IMPRESSION OF VALVE *** 4/23/2024 SUPPORT OTHER OPERATIONS RAN BRAIDED LINE BRUSH W/ 2.79" GAUGE RING & MADE MULTIPLE PASSES FROM 6460' TO 6660' RKB (TAGGED TD @ 7876' RKB), DRIFTED TBG W/ 2.70" x 23' DMY GUN DRIFT & TAGGED TD @ 7865' RKB (NO SIGNFICANT WEIGHT SWINGS OR TIGHT SPOTS OBSERVED). READY FOR E-LINE. 5/18/2024 SUPPORT OTHER OPERATIONS PERFORATE WITH 2.5" MILLENNIUM II GUNS, 6 SPF, 60 DEGREE PHASE: GUN 1: 7785.5' TO 7765.5', CCL STOP AT 7758.1' GUN 2: 7765.5' TO 7751.5', CCL STOP AT 7744' GUN 3 : 7751.5' TO 7738.5', CCL STOP AT 7730.2' CORRELATE TO BAKER LWD GAMMA LOG DATED 7-MAR-24 5/19/2024 SUPPORT OTHER OPERATIONS INJECTIVITY TEST, PUMPED TOTAL 140 BBLS DIESEL DOWN TBG FOR INJECTIVITY TEST, SEE LOG FOR DETAILS. JOB COMPLETE. 5/24/2024 SUPPORT OTHER OPERATIONS MEASURED SBHP @ 7717' RKB (3411 psi) JOB COMPLETE. 3B-16A Perforations Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 7,877.03B-16A4/23/2024pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added perforations (7738.5' - 7785.5' RKB)3B-16A5/18/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Well sidetracked to 3B-16A March '24. Remaining 3B-16 completion below cut is inaccessible. 5/9/2024spilch Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 32.0 117.0 117.062.50 H-40 WELDED SURFACE 9 5/8 8.92 30.2 3,409.3 3,269.4 36.00 J-55 BTC PRODUCTION 7 6.28 23.7 7,858.4 6,169.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 7,986.3 Set Depth … 6,255.1 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) 25.5 25.5 0.00 Hanger 10.844 Tubing Hanger 7 1/16" - Gen3 FMC - 3 1/2" EUE lift threads H-BPV FMCGen 3 2.950 2,468.0 2,455.7 17.15 Mandrel – GAS LIFT 4.724 3.5" x 1" BGLO-1.0RCT, Vam Top Box by Pin (#2) SN# 12165-02 (2500') Baker BGLO- 1.0 RCT 2.818 6,511.3 5,293.8 52.70 Mandrel – GAS LIFT 4.724 3.5" x 1" BGLO-1.0RCT, Vam Top Box by Pin (#1) SN#12165-01 BakerBGLO- 1.0 RCT 2.818 6,569.8 5,329.8 51.49 Sleeve - Sliding 5.880 3 1/2" HP Defender - 4K Burst Disc - Vam Top Conn SN#108270600-SN2 Hydraulically shifted closed 03/27/24 HD Defende r H81032 0020 2.813 6,580.2 5,336.3 51.28 Packer 5.999 SLB BluPack 3.5" by 7" - Vam Top Box x Pin SN#103058459 SLB BluePac k 2.885 6,598.9 5,348.0 50.90 Nipple - Profile 4.506 NIPPLE,LANDING,3 1/2",X,2.813",HY563,BXP Halliburt on 2.813 X/Nipple 2.813 7,887.0 6,188.6 47.55 Collar - Landing 4.280 3.5" H563 Landing Collar SN#73517 -1 Baker4512404 030 2.867 7,951.4 6,231.7 48.02 Collar - Float 3.500 3.5" H563 Float Collar SN#4524020849-00004-1 2.931 7,984.1 6,253.7 48.02 Shoe 4.255 3.5" H563 Float Shoe SN#4524020849-00003-2 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) 2,468.02,455.7 17.15 1 GAS LIFT DMY BGLO 5.513/13/2024 Side pocke t Mandr el Baker BGLO- 1RCT 1.000 6,511.3 5,293.8 52.70 2 GAS LIFT DMY BGLO - 1RCT 5.52 3/13/2024 When makin g drifts for e- line perfs we found ceme nt sheat h in GLM BakerBGLO- 1RCT 1.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,738.5 7,785.5 6,089.1 6,120.4 5/18/2024 6.0 IPERF 2.5" MILLENNIUM GUNS, 6 SPF, 60 DEGREE PHASE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,569.5 7,986.3 5,329.66,255.1 Primary – Full Bore Pump 30 BBLS 12 PPG spacer, 47 BBLS 15.3 PPG cement 3/13/2024 7,238.0 7,456.0 5,761.3 5,903.9 Cement Squeeze 31 BBLS 15.8 PPG CEMENT PUMPED THROUGH RETAINER AND INTO THE C-SANDS. 8/18/2023 3B-16A, 1/7/2025 5:30:50 PM Vertical schematic (actual) Collar - Float; 7,951.4 Collar - Landing ; 7,887.0 PRODUCTION; 23.7-7,858.4 IPERF; 7,738.5-7,785.5 Cement Squeeze; 7,238.0 ftKB Primary – Full Bore; 6,569.5 ftKB CUT; 6,632.0 WHIPSTOCK; 6,610.8 Nipple - Profile; 6,598.9 Packer; 6,580.2 Sleeve - Sliding; 6,569.8 Mandrel – GAS LIFT; 6,511.2 SURFACE; 30.2-3,409.3 Mandrel – GAS LIFT; 2,468.0 CONDUCTOR; 32.0-117.0 Hanger; 25.5 KUP INJ KB-Grd (ft) 35.98 RR Date 4/7/1985 Other Elev… 3B-16A ... TD Act Btm (ftKB) 7,996.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128901 Wellbore Status INJ Max Angle & MD Incl (°) 54.45 MD (ftKB) 6,398.39 WELLNAME WELLBORE Annotation Last WO: End Date 3/14/2024 H2S (ppm)DateComment MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3B-16A KUPARUK RIV UNIT 3B-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 3B-16A 50-029-21289-01-00 223-125-0 W SPT 5336 2231250 1500 2700 2700 2700 2700 280 280 280 280 INITAL P Sully Sullivan 6/3/2024 Initial MIT -IA after RWO 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3B-16A Inspection Date: Tubing OA Packer Depth 1120 1810 1780 1780IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240604105431 BBL Pumped:0.5 BBL Returned:0.5 Thursday, July 25, 2024 Page 1 of 1 Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 2C-12 50-029-21222-00 909383030 Kuparuk River Correlation Record Field- Final 1-Jul-24 0 1 2 2H-03 50-103-20031-00 n/a Kuparuk River Plug Setting Record Field- Final 13-May-24 0 1 3 2P-432 50-103-20420-00 909422477 Kuparuk River Plug Setting Record Field- Final 30-Jun-24 0 1 4 2W-01 50-029-21273-00 n/a Kuparuk River Patch Setting Record Field- Final 20-May-24 0 1 5 2X-05 50-029-20985-00 909358554 Kuparuk River Multi Finger Caliper Field & Processed 28-May-24 0 1 6 2X-05 50-029-20985-00 909358554 Kuparuk River Patch Setting Record Field- Final 29-May-24 0 1 7 2Z-06 50-029-20957-00 n/a Kuparuk River Plug Setting Record Field- Final 23-May-24 0 1 8 3B-16A 50-029-21289-01 909336135 Kuparuk River Perforation Record Field- Final 18-May-24 0 1 9 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 22-Jun-24 0 1 10 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 24-Jun-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39162 T39163 T39164 T39165 T39166 T39166 T39167 T39168 T39169 T39169 184-206 184-070 202-091 185-010 183-107 183-077 223-125 209-103 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:26:17 -08'00' 3B-16A 50-029-21289-01 909336135 Kuparuk River Perforation Record Field- Final 18-May-24 0 1 T39168 223-125 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Apr 03, 2024 AOGCC Attention: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 3B-16A Kuparuk River API #: 50-029-21289-01-00 Permit No: 223-125 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: Hampton, Jerissa Jerissa.Hampton@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com 223-125 T38681 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.03 13:52:40 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7996' None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5/1/2024 3-1/2" Packer: SLB BluPack Packer SSSV: None Perforation Depth MD (ft): L-80 3379' None 7835' None 7" Perforation Depth TVD (ft): 117' 3409' 6325'7858' 16" 9-5/8" 85' 7986' MD 117' 3270' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025633 223-125 P.O. Box 100360, Anchorage, AK 99510 50-029-21289-01-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6580' MD and 5336' TVD N/A Elliott Tuttle Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: elliott.tuttle@conocophillips.com (907) 263-4742 Senior RWO/CTD Engineer KRU 3B-16A 6262' 7245' 5806' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2024.04.29 16:05:13-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle By Grace Christianson at 7:52 am, Apr 30, 2024 DSR-4/30/24VTL 5/6/2024 SFD 5/6/2024 X 10-404 JLC 5/6/2024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 25, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to perforate KUP Producer 3B-16A (PTD# 223-125). Well 3B-16A was recently rotary sidetracked from 3B-16. After post-rig logging of CBL (attached) and checking formation depths with gamma ray for the new cemented 3.5" liner, perforation depths were confirmed. If you have any questions or require any further information, please contact me at +1-907-252-3347. The plan is to perforate 3B-16A in the A2 Kuparuk sands only. A3 Sand is of interest as well but will be perforated later on after an injection test is performed on the A2 sand. Post-rig CBL of the cemented 3.5" liner confirms adequate TOC of the 3.5" liner. Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle @conocophillips.com Reason: I am approving this document Location: Date: 2024.04.29 16:05:38-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 3B-16A Perforating Procedure Kuparuk Injector PTD #223-125 Page 1 of 1 Well Work 1. RU eline. a. RIH to desired depths ~ 7738.5 MD (6005.7 TVDSS) to ~7785.3 MD (6036.8 TVDSS) and perforate A2. MD to N7ES. b. RD eline. 3B-16A Final RWO-ST Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 117 117 16 15.06 62.5 H-40 Welded Welded Surface 3409 3270 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 7858 6325 7 6.276 26 J-55 BTC BTC Liner/ Tubing 7986 3.5 2.99 9.3 L-80 Hyd563 Hyd563 Depths Corrected to 7ES RKB from ORKB ORKB= 35.98', 7ES RBK= 25.48', -10.5' COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface (2 Each) 3-1/2" Baker BGLO-1.0RCT Monotrip GLM @ 2468', 6511' 3 1/2" HP Defender @ 6570' RKB (2.813" ID) 3.5" x 7.0" Packer @ 6580' RKB (4" ID) 3-½" X landing nipple at 6599' RKB (2.813" min ID) 3-1/2" Landing Collar (PBTD @ ~7877' RKB) 3 1/2" Float Collar 3 1/2" Float Shoe Btm @ 7986' RKB REMAINING COMPLETION LEFT IN HOLE Stump found @ 6630' RKB - 3/7/24 3.5" x 7.0" Packer (7224' RKB) GLM Blast Rings GLM 3.5" x 7.0" Packer (7460' RKB) 2.75" D-Nipple (7472' RKB) WLEG Surface Casing Production Casing Conductor A-sand perfs C-sand Perfs Gamma Marker found @ 6436' RKB (6442' ORKB) KOP @ 6608' MD (5357' TVDSS) 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: 55.4 Total Depth:3392' FSL, 4221' FEL, Sec 21, T12N, R9E, 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-40 117' 9-5/8"J-55 3270' 7"J-55 6325' 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/14/2024 223-125 50-029-21289-01-00 KRU 3B-16A ADL 0025633 ALK 2566 3/9/2024 7996'MD/6262'TVD N/A 83.4' P.O. Box 100360 Anchorage, AK 99510-0360 518231 5991349 3494' FSL, 4058 FEL, Sec. 21, T12N, R9E, UM 3/11/2024229' FSL, 802' FEL, Sec 16, T12N, R9E, UM 5989327 1565'MD/1565'TVD SETTING DEPTH TVD 5989225 TOP HOLE SIZE AMOUNT PULLED 514985 514822 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 6608'MD/5354'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 35' 32' 3409' 62.5# 36# 117' 35'7858'Lead: 47bbls of 15.8ppg Class G Tail: 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 7986'3.5" 12-1/4"30' 8-1/2" 30' 32' 26# Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. Flow Tubing Sr Res EngSr Pet GeoSr Pet Eng None Oil-Bbl:Water-Bbl: 6580'MD/5336'TVD Directional Survey Water-Bbl: PRODUCTION TEST N/A - Injection Well Date of Test:Oil-Bbl: PACKER SET (MD/TVD) J G s d 1b 10 D A 2 p and Bot ;Perfor L s (atta Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Completed 3/14/2024 JSB RBDMS JSB 050124 Received 4/12/2024 G JJL 12/02/24 DSR-5/6/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface Base of Permafrost 1565 1565 C4 7470 5913 7674 6046 7736 6088 7996 6261 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Elliott Tuttle Digital Signature with Date:Contact Email:elliott.tuttle@cop.com Contact Phone:907-263-4742 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: 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 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. Total Depth (Miluveach) TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Top of Productive Interval (Kuparuk A2) A3 Authorized Title: CTD/RWO 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. N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips , CN=Elliott Tuttle, E=elliott.tuttle@conocophillips.com Reason: I am approving this document Location:Date: 2024.04.29 13:00:34-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 3B-16A Final RWO-ST Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 117 117 16 15.06 62.5 H-40 Welded Welded Surface 3409 3270 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 7858 6325 7 6.276 26 J-55 BTC BTC Liner/ Tubing 7986 3.5 2.99 9.3 L-80 Hyd563 Hyd563 Depths Corrected to 7ES RKB from ORKB ORKB= 35.98', 7ES RBK= 25.48', -10.5' COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface (2 Each) 3-1/2" Baker BGLO-1.0RCT Monotrip GLM @ 2468', 6511' 3 1/2" HP Defender @ 6570' RKB (2.813" ID) 3.5" x 7.0" Packer @ 6580' RKB (4" ID) 3-½" X landing nipple at 6599' RKB (2.813" min ID) 3-1/2" Landing Collar (PBTD @ ~7877' RKB) 3 1/2" Float Collar 3 1/2" Float Shoe Btm @ 7986' RKB REMAINING COMPLETION LEFT IN HOLE Stump found @ 6630' RKB - 3/7/24 3.5" x 7.0" Packer (7224' RKB) GLM Blast Rings GLM 3.5" x 7.0" Packer (7460' RKB) 2.75" D-Nipple (7472' RKB) WLEG Surface Casing Production Casing Conductor A-sand perfs C-sand Perfs Gamma Marker found @ 6436' RKB (6442' ORKB) KOP @ 6608' MD (5357' TVDSS) Page 6/12 3B-16 Report Printed: 4/4/2024 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) 3/8/2024 15:00 3/8/2024 16:00 1.00 SLOT, WHPST WPST P Set the TOWS at 324 degrees at 6608' with the BOWS at 6621'. Shear anchor at 15K, pulled 10K over to confirm set./ Shear out sheer bolt at 47K and pull free. 6,629.0 6,608.0 3/8/2024 16:00 3/8/2024 18:00 2.00 SLOT, WHPST DISP P Pump 30 bbl Hi vis sweep. Then displace seawater with 11.5 ppg LSND mud. 6,608.0 6,608.0 3/8/2024 18:00 3/8/2024 19:45 1.75 SLOT, WHPST MILL P TIH, ROT=80 rpm, off bottom torque=3,700 ft/lbs, On bottom torque=4,762 ft/lbs, pumping 1,843 psi/58 spm pump #1, 64 spm pump #2, Total SPM=122, Flow in 295 gal/min, WOB= 6,608.0 6,613.0 3/8/2024 19:45 3/8/2024 20:00 0.25 SLOT, WHPST MILL P PUH, back ream, PUW=127k, SOW=99k, BOBM, ROT=80 rpm, off bottom torque=3,700 ft/lbs, On bottom torque=4,762 ft/lbs, pumping 1,843 psi/58 spm pump #1, 64 spm pump #2, Total SPM=122, Flow in 295 gal/min, WOB=2-3k 6,613.0 6,613.0 3/8/2024 20:00 3/9/2024 00:00 4.00 SLOT, WHPST MILL P PUW=127k, SOW=99k, BOBM, ROT=80 rpm, off bottom torque=3,700 ft/lbs, On bottom torque=5,562 ft/lbs, pumping 1,843 psi/58 spm pump #1, 64 spm pump #2, Total SPM=121, Flow in 295 gal/min, WOB=4-5k, pump 20 bbl sweep to clean hole 6,613.0 6,624.0 3/9/2024 00:00 3/9/2024 01:30 1.50 SLOT, WHPST MILL P BOBM, ROT=100 rpm, off bottom torque=3,700 ft/lbs, On bottom torque=4,790 ft/lbs, pumping 1,898 psi/57 spm pump #1, 63 spm pump #2, Total SPM=120/7 bpm, Flow in 288 gal/min, WOB=6-8 k 6,624.0 6,662.0 3/9/2024 01:30 3/9/2024 02:45 1.25 SLOT, WHPST REAM P 6,662', TD rat hole, PUH 105 k, ROT=81 rpm, Off bottom torque=5,600 ft/lbs, pumping 1,895 psi/122 spm/7 bpm, back ream casing exit x 3 while circulating sweep around, lower pump rate to 2 bpm, drift casing exit (clean) 6,662.0 6,600.0 3/9/2024 02:45 3/9/2024 03:15 0.50 SLOT, WHPST OWFF P Stand back 1 stand, blow down TOP Drive due to ambient temp -31° F, Check well for flow 6,600.0 6,600.0 3/9/2024 03:15 3/9/2024 03:30 0.25 SLOT, WHPST TRIP P KBU, Pump Dry Job 14.4 ppg/15 bbl, blow down TOP Drive 6,600.0 6,572.0 3/9/2024 03:30 3/9/2024 08:30 5.00 SLOT, WHPST TRIP P TOOH standing back stands in derrick on elevators. UWT 120K DWT 95K 6,572.0 432.0 3/9/2024 08:30 3/9/2024 11:00 2.50 SLOT, WHPST BHAH P LD window milling BHA. Upper watermelon mill in gauge at 6.151". Lower watermelon mill in gauge at 5.875". Window mill under gauge at at 5.8" (started at 6.125") 432.0 0.0 3/9/2024 11:00 3/9/2024 11:30 0.50 SLOT, WHPST SVRG P Service and inspect top drive. 0.0 0.0 3/9/2024 11:30 3/9/2024 12:00 0.50 SLOT, WHPST OTHR P M/U Johnny Wack Stick, jet BOPE of metal from milling operations 0.0 3/9/2024 12:00 3/9/2024 15:00 3.00 PROD1, DRILL BHAH P MU Drilling BHA #4 Orient tool and scribe as per Baker hand. 0.0 341.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 7/12 3B-16 Report Printed: 4/4/2024 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) 3/9/2024 15:00 3/9/2024 16:30 1.50 PROD1, DRILL TRIP P TIH on stands F/341' T/2258'. Shallow test MWD tools at 2258' 341.0 2,258.0 3/9/2024 16:30 3/9/2024 19:30 3.00 PROD1, DRILL TRIP P TIH on stands F/2,258' T/6,600' Orient TF 45° LOHS, continue through casing exit (clean) 2,258.0 6,611.0 3/9/2024 19:30 3/9/2024 23:00 3.50 PROD1, DRILL DDRL P Obtain drilling parameters. 6 bpm, off bottom pressure=1,894 psi on bottom pressure=2,370 psi,PUW=115k.,SOW=98k, stall out x 2 6,662', PUH, ROT 15 RPM @ 30 fpm ROP, TQ=5,000 ft/lbs, ROTW=100k F/6,662' T/6,668', Slide F/6,668' T/6,710', connection. ROTTQ=4,900 ft/lbs, ROT=40 rpm, ROTW=98k, ROT F/6,710' T/6,766', shoot check shot 6,611.0 6,766.0 3/9/2024 23:00 3/10/2024 00:00 1.00 PROD1, DRILL DDRL P Slide F/6,766' T/6,800' 6,766.0 6,800.0 3/10/2024 00:00 3/10/2024 01:45 1.75 PROD1, DRILL DDRL P Connection @ 6,802', ROTW=95k, Rot=55 rpm, ROTQ off bottom=4,800 ft/lbs ROTQ on bottom=5,500 ft/lbs, pumping 6 bpm/2,540 psi, WOB=15k, AVG ROP=50 fph 6,800.0 6,871.0 3/10/2024 01:45 3/10/2024 03:45 2.00 PROD1, DRILL DDRL P Hard spot, ROP slowed to 35 fph, ROT=50 rpm, ROTQ=5,200 ft/lbs, ROW=90k, pumping 6 bpm/2,584 psi, increase ROT=60 rpm, WOB=17k, AROP=35 fph, ECD 13.3 ppg 6,871.0 6,898.0 3/10/2024 03:45 3/10/2024 04:15 0.50 PROD1, DRILL DDRL P Connection @ 6,897', PUW=117k, SOW=95k, Slide 20', pumping 6 bpm/2,880 psi 6,898.0 6,918.0 3/10/2024 04:15 3/10/2024 06:00 1.75 PROD1, DRILL DDRL P PUW=117k, SOW=95k, ROTW=95k, Rot=60 rpm, ROTQ off bottom=4,950 ft/lbs ROTQ on bottom=5,700 ft/lbs, pumping 6 bpm/2,540 psi, WOB=10 k, AVG ROP=80 fph 6,918.0 6,993.0 3/10/2024 06:00 3/10/2024 06:15 0.25 PROD1, DRILL DDRL P Connection @ 6,993, PUW=117k, SOW=95k, pumping 6.9 bpm/2,600 psi 6,993.0 6,993.0 3/10/2024 06:15 3/10/2024 06:30 0.25 PROD1, DRILL DDRL P DRLG ahead F/6993 T/6997 PUW=117k, SOW=95k, ROTW=95k, Rot=60 rpm, ROTQ off bottom=4,950 ft/lbs ROTQ on bottom=5,700 ft/lbs, pumping 6 bpm/2,540 psi, WOB=11 k, AVG ROP=40 fph 6,993.0 6,997.0 3/10/2024 06:30 3/10/2024 07:45 1.25 PROD1, DRILL DDRL P DRLG ahead F/6997 T/7022 W/Mud pump 2 down for a valve rocking noise. Blew it down and took the caps off and could not find a problem. Put it back to gether and everything runs great. Must have been a rock in there under a valve causing the rocking noise. DRLG w/only one pump #1 running for 25'. Slide from 6995' -7025'. 6,997.0 7,022.0 3/10/2024 07:45 3/10/2024 08:45 1.00 PROD1, DRILL DDRL P Connection @ 7090', PUW=120k, SOW=87K, ROT on bottom 5.7K, ROTQ off bottom5K. RPM 60. ECD 13.2 Pumping 6 bpm at 2500 psi. 7,022.0 7,090.0 3/10/2024 08:45 3/10/2024 12:00 3.25 PROD1, DRILL DDRL P DRLG ahead F/7090 T/7185' Connection @ 7090'. WOB 10-15K, Pumping 6.7 bpm @2500 psi, TQ on bottom 5700 TQ off bottom 5K.UWT 130K, DWT 85K, RWT 95, RPM 60. Slide from 7091'-7116'. 7,090.0 7,185.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 8/12 3B-16 Report Printed: 4/4/2024 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) 3/10/2024 12:00 3/10/2024 13:00 1.00 PROD1, DRILL DDRL P DRLG ahead F/7185 to T/7210' Connection @ 7185'. WOB 10-15K, Pumping 6.7 bpm @2539 psi, TQ on bottom 5300, TQ off bottom 5K.UWT 120K, DWT 87K, RWT 103, RPM 60 Slide from 7185'-7210' 7,185.0 7,210.0 3/10/2024 13:00 3/10/2024 18:00 5.00 PROD1, DRILL DDRL P DRLG ahead F/7,210 to T/7,386'' Geo = K1 marker 7,318' Connection @ 7,282'. 7,372' WOB 10-15K, Pumping 6.5 bpm @ 2277 psi, TQ on bottom 5795, TQ off bottom 5K.UWT 120K, DWT 87K, RWT 98, RPM 59 Slide from 7185'-7210' 7,210.0 7,386.0 3/10/2024 18:00 3/10/2024 23:00 5.00 PROD1, DRILL DDRL P PUW=125k, SOW=95k, ROTW=91k, Rot=60 rpm, ROTQ off bottom=4,950 ft/lbs ROTQ on bottom=6,160' ft/lbs, pumping 6.5 bpm/2,664 psi, WOB=15- 20 k, AVG ROP=20-30 fph 7,386.0 7,464.0 3/10/2024 23:00 3/11/2024 00:00 1.00 PROD1, DRILL DDRL P DRLG ahead F/7,464' to T/ Rotating WOB 16-20K, Pumping 6.5 bpm @ 2,665 psi, TQ on bottom 7,200, TQ off bottom 5K.UWT 124K, DWT 87K, RWT 105, RPM 59 *** Note: Rate increase to 90-100 fph @ 7,480', @ 7,500' brought a little gas to surface, PUH, recep pipe rotating circulate BU, go back drilling ahead. 7,464.0 7,505.0 3/11/2024 00:00 3/11/2024 01:30 1.50 PROD1, DRILL DDRL P DRLG ahead F/7,505' to T/7,565', Rotating Connection @ 7,565''. WOB 5K, Pumping 6.4 bpm @2300 psi, TQ on bottom 7,000 fr/lbs, TQ off bottom 5K.UWT 120K, DWT 87K, RWT 103, RPM 60, holding 13.4 ECD. 7,505.0 7,565.0 3/11/2024 01:30 3/11/2024 02:30 1.00 PROD1, DRILL CIRC P Gas in returns, shut down pump 5 mins, returns deminishing, bring pump online, get returns, PUH=150k, slack off, attempt to rotate, no luck, stack back out, rotate free, 60 rpm, PUH=110k, recep while circulating BU. ECD 13.4 ppg. Confer with TE, weight up from 11.7 ppg to 11.8 ppg 7,565.0 7,565.0 3/11/2024 02:30 3/11/2024 02:48 0.30 PROD1, DRILL DDRL P DRLG ahead F/7,565' to T/7,575', Rotating Connection @ 7,565''. WOB 5K, Pumping 6.4 bpm @2300 psi, TQ on bottom 7,000 fr/lbs, TQ off bottom 5K.UWT 120K, DWT 87K, RWT 103, RPM 60, holding 13.4 ECD. 7,565.0 7,575.0 3/11/2024 02:48 3/11/2024 03:00 0.20 PROD1, DRILL DDRL P Drilling ahead F/7,575' T/7,625' Sliding, WOB 5K, Pumping 6.4 bpm @2300 psi, , holding 13.4 ECD. 7,575.0 7,625.0 3/11/2024 03:00 3/11/2024 11:30 8.50 PROD1, DRILL DDRL P DRLG ahead F/7,625' to T/7851', Rotating WOB 5K, Pumping 5.7 bpm @3000 psi, TQ on bottom 6.8K, TQ off bottom 6K.UWT 134K, DWT 90K, RWT 109, RPM 60, holding 13.5 ppg ECD. At 08:00 brought mud weight up from 11.8 to 11.9ppg. 7,625.0 7,850.0 3/11/2024 11:30 3/11/2024 12:00 0.50 PROD1, DRILL SVRG P Service washpipe. 7,850.0 7,850.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 9/12 3B-16 Report Printed: 4/4/2024 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) 3/11/2024 12:00 3/11/2024 13:00 1.00 PROD1, DRILL DDRL P Drilling ahead F/7850' T/7996' Rotating WOB 16K, Pumping 6 bpm @ 2700 psi, TQ on bottom 6.4K TQ off bottom 6K. UWT 134K, DWT 90K, RWT 109, RPM 60, holding 13.5 ppg ECD. 7,850.0 7,996.0 3/11/2024 13:00 3/11/2024 14:30 1.50 PROD1, CASING CIRC P Pump 2 sweeps with 2 BU maintaining 13.4 ppg ECD. 7,996.0 7,996.0 3/11/2024 14:30 3/11/2024 18:45 4.25 PROD1, CASING TRIP P TOOH on stands to window at 6608' maintaining 13.4 ECD and 60 FPM pulling speed, PUW=145 k, tight hole 7,370'-7,384', pull free 7,996.0 6,590.0 3/11/2024 18:45 3/11/2024 19:30 0.75 PROD1, CASING CIRC P Circulate BU, stand back 1 stand 6,590.0 6,509.0 3/11/2024 19:30 3/11/2024 20:00 0.50 PROD1, CASING OWFF P Observe well for flow 6,509.0 6,509.0 3/11/2024 20:00 3/12/2024 00:00 4.00 PROD1, CASING TRIP P TOOH, on elevators, w/continuous hole fill on. MW=11.9 ppg 6,509.0 2,800.0 3/12/2024 00:00 3/12/2024 03:00 3.00 PROD1, CASING TRIP P Continue TOOH F/2,800', continuous hole fill. 2,800.0 342.0 3/12/2024 03:00 3/12/2024 04:00 1.00 PROD1, CASING TRIP P TIH with DP out of the derrick 342.0 1,737.0 3/12/2024 04:00 3/12/2024 05:15 1.25 PROD1, CASING TRIP P TOOH sideways 1,737.0 342.0 3/12/2024 05:15 3/12/2024 05:45 0.50 PROD1, CASING OWFF P Observe well for flow while clean and clear the floor. 342.0 342.0 3/12/2024 05:45 3/12/2024 06:00 0.25 PROD1, CASING SFTY P PJSM to L/D and inspect drilling BHA. 342.0 342.0 3/12/2024 06:00 3/12/2024 08:00 2.00 PROD1, CASING BHAH P Lay down drilling BHA. 342.0 0.0 3/12/2024 08:00 3/12/2024 08:45 0.75 PROD1, CASING CLEN P Pull wear ring, RU johnny wacker to clean the cuttings from the stack. 0.0 0.0 3/12/2024 08:45 3/12/2024 09:00 0.25 COMPZN, RPCOMP SFTY P PJSM to MU completion. 0.0 0.0 3/12/2024 09:00 3/12/2024 10:30 1.50 COMPZN, RPCOMP RURD P RU GBR tongs, RU to fill each joint and RU 3.5" elevators. 0.0 0.0 3/12/2024 10:30 3/12/2024 11:30 1.00 COMPZN, RPCOMP PUTB P MU shoe track, 2 centralizers per joint, Baker lock first three connections and fill pipe to ensure floats hold. 0.0 224.0 3/12/2024 11:30 3/12/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Grease the Draw works 224.0 224.0 3/12/2024 12:00 3/13/2024 00:00 12.00 COMPZN, RPCOMP PUTB P RIH W/3 1/2" TBG as per detail F/224' T/7,362' 80K UP 65K DN TQ turn HYD 563 connections, M/U TQ = 2900 FT/LBS Installing one centralizer with stop ring in middle of every joint 1 - 41 Fill pipe every 15 JTS 224.0 7,362.0 3/13/2024 00:00 3/13/2024 00:30 0.50 COMPZN, RPCOMP PUTB P RIH W/3 1/2" TBG as per detail F/7,362' T/7,478' 85K UP 65K DN TQ turn HYD 563 connections, M/U TQ = 2900 FT/LBS Fill pipe every 15 JTS At 7,478' set DN 10K twice, pick up see 5-10K over, set down 15K pick up see 5- 10K over Pick up to 7,457' - L/D JT to rig up head pin on it 7,362.0 7,457.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 10/12 3B-16 Report Printed: 4/4/2024 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) 3/13/2024 00:30 3/13/2024 01:15 0.75 COMPZN, RPCOMP WASH P Make up head pin and circulating hose Break circulation Pump down F/7,457' T/7,478' 1-3 BPM 375/680 PSI Set DN 10-15K with no luck 7,457.0 7,478.0 3/13/2024 01:15 3/13/2024 02:45 1.50 COMPZN, RPCOMP CIRC P Circulate @ 3 BPM 820 PSI 4 BPM 820 PSI Work pipe F/7,454' T/7,478' Tag up at 7,478' set DN 15K no over pull Circulated a bottoms up and slow start making footage and having cleaner pick up weights with no over pull T/7,484' Shut down pump, break out head pin, X/over and circulating hose to pick up another JT Note: Build lube/bead pill 7,478.0 7,484.0 3/13/2024 02:45 3/13/2024 04:00 1.25 COMPZN, RPCOMP WASH P Make up X/over and screw in with top drive Washing DN F/7,484' T/7,579' Work thru tight spots as need with 4 BPM and 10 - 15K DN, no pump PSI increase when setting DN and see 0-5K over when picking up Pump @ 4 BPM 775 PSI 85K UP 65K DN From 7,516' T/7,579' clean didn't take any weight DN 7,484.0 7,579.0 3/13/2024 04:00 3/13/2024 05:00 1.00 COMPZN, RPCOMP PUTB P RIH W/3 1/2" TBG F/7,579' T/8,000' 88K UP 65K DN TQ turn HYD 563 connections, M/U TQ = 2900 FT/LBS Fill pipe every 15 JTS 7,579.0 8,000.0 3/13/2024 05:00 3/13/2024 05:30 0.50 COMPZN, RPCOMP HOSO P Tag bottom with 10K DN, P/U 10', slack off confirm tag depth with 1-2K DN L/D 3 JTS F/8,000' T/7,920' M/U 5.83' pup JT, JT #249, hanger and landing JT T/7,952' 8,000.0 7,986.0 3/13/2024 05:30 3/13/2024 06:15 0.75 COMPZN, RPCOMP THGR P Land out hanger in well head RILDS 88K UP 65K DN Packer depth 6580' MD/5336' TVD 14' off bottom 7,952.0 7,986.0 3/13/2024 06:15 3/13/2024 08:00 1.75 COMPZN, RPCOMP CIRC P R/U to landing joint and IA to take returns up secondary line to gas buster to pits Circulate condition mud for CMT job 3 BPM 600 PSI 7,986.0 7,986.0 3/13/2024 08:00 3/13/2024 09:00 1.00 COMPZN, CEMENT RURD P RU cement head to top drive with XO to landing joint. MU cement manifold. 7,986.0 7,986.0 3/13/2024 09:00 3/13/2024 09:30 0.50 COMPZN, CEMENT SFTY P Safety meeting with crews to go over cement job. 7,986.0 7,986.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 11/12 3B-16 Report Printed: 4/4/2024 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) 3/13/2024 09:30 3/13/2024 12:00 2.50 COMPZN, CEMENT CMNT P Pressure test cement lines from cementer to cement head 4500 psi, (Good Test) Pump CMT, CMT wet at 10:15 HRS Pump 30 BBLS 12 PPG s[acer at 3 BPM Pump 47 BBLS 15.3 PPG Class G lead CMT Cement going down pipe @ 3 BPM/690 PSI Chase with 11.9 PPG mud Slow pump to 1 BPM 670 PSI F/bump plug @ 1101 stks, PSI up 500 over FCP T/1100 PSI, hold 5 min, bleed pressure floats are holding CIP @ 12:21 HRS 7,986.0 7,986.0 3/13/2024 12:00 3/13/2024 13:00 1.00 COMPZN, CEMENT CMNT P Flush lines from trucks, Blow down surface lines, Blow down top drive and line to tiger tank. LD cement line. 7,986.0 7,986.0 3/13/2024 13:00 3/13/2024 14:00 1.00 COMPZN, RPCOMP PACK P RU head pin and cement line. PT and set packer 3500 psi for 30 minutes. PSI up to 4000 PSI with mud pumps, PSI up to 4300 with test pump to burst disk to open sliding sleeve. 7,986.0 7,986.0 3/13/2024 14:00 3/13/2024 15:30 1.50 COMPZN, RPCOMP CMNT P Displace cement above sliding sleeve out of the hole with 11.9 ppg mud, not going over 1500 psi to prevent closing the sliding sleeve. 7,986.0 7,986.0 3/13/2024 15:30 3/13/2024 17:00 1.50 COMPZN, RPCOMP DISP P Displace 11.9 ppg mud above sliding sleeve out of the hole with 8.6 ppg CI, pump 230 BBLS not going over 1500 psi to prevent closing the sliding sleeve. 7,986.0 7,986.0 3/13/2024 17:00 3/13/2024 17:30 0.50 COMPZN, RPCOMP PRTS P R/U Test IA and TBG T/2500 PSI F/30 Min 7,986.0 7,986.0 3/13/2024 17:30 3/13/2024 18:00 0.50 COMPZN, RPCOMP RURD P B/D and R/D cement lines, R/D landing JT 7,986.0 0.0 3/13/2024 18:00 3/13/2024 18:30 0.50 COMPZN, RPCOMP MPSP P Drain stack set BPV 0.0 0.0 3/13/2024 18:30 3/13/2024 19:00 0.50 COMPZN, RPCOMP RURD P Rig up to test BPV from below Prime mud pumps with water for test 0.0 0.0 3/13/2024 19:00 3/13/2024 19:15 0.25 COMPZN, RPCOMP MPSP P Test BPV T/1000 PSI F/10 min 0.0 0.0 3/13/2024 19:15 3/13/2024 19:30 0.25 COMPZN, RPCOMP RURD P B/D and R/D all lines 0.0 0.0 3/13/2024 19:30 3/13/2024 20:00 0.50 COMPZN, RPCOMP OWFF P Flow check 30 min SimOps clean rig floor of drilling mud, clean pits 0.0 0.0 3/13/2024 20:00 3/13/2024 22:30 2.50 COMPZN, WHDBOP RURD P R/U super sucker, pull riser, install drip pan plug Clean rig floor of drilling mud Clean out drip pan, under rig floor mats Clean mud pits 0.0 0.0 3/13/2024 22:30 3/14/2024 00:00 1.50 COMPZN, WHDBOP RURD P Change out saver sub from XT 39 to HT38 Lay down all 4" handling equipment and bring up 3 1/2" equipment Clean pits 0.0 0.0 3/14/2024 00:00 3/14/2024 01:30 1.50 COMPZN, WHDBOP RURD P Change out saver sub from XT 39 to HT38 Lay down all 4" handling equipment Clean pits 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 12/12 3B-16 Report Printed: 4/4/2024 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) 3/14/2024 01:30 3/14/2024 10:00 8.50 COMPZN, WHDBOP NUND P Change out lower pipe rams to 7" solid body N/D BOP stack N/U Tree and PT to 5000 psi Clean pits 0.0 0.0 3/14/2024 10:00 3/14/2024 11:45 1.75 COMPZN, WHDBOP MPSP P Pull test dart and BPV with FMC rep. 0.0 0.0 3/14/2024 11:45 3/14/2024 12:00 0.25 COMPZN, WHDBOP RURD P Warm up lines to Kill tank with LRS diesel. 0.0 0.0 3/14/2024 12:00 3/14/2024 13:15 1.25 COMPZN, WHDBOP FRZP P Start pumping warm diesel FP into IA taking returns up tubing to Tiger tank. Pumped 70 bbls at 1.5 BPM with pressures between 300 and 500 psi. U-tube TBG and IA until balanced 0.0 0.0 3/14/2024 13:15 3/14/2024 18:00 4.75 DEMOB, MOVE RURD P Cleaning pits. Secure well head and tree. Secure rig floor for bridal up. Unpin top drive and bridal up. Final pressures on well T/IA/OA = 0/0/120 PSI Rig Release: 18:00 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/14/2024 Page 1/1 3B-16 Report Printed: 4/8/2024 Cement Cement Details Description Production String 1 Cement Cementing Start Date 3/13/2024 09:30 Cementing End Date 3/13/2024 12:00 Wellbore Name 3B-16A Comment Pump 30 BBLS 12 PPG spacer, 47 bbls Lead cement class G 15.3 ppg cement, bumped plug at 63.5 BBLS, floats hold Cement Stages Stage # <Stage Number?> Description Cement Squeeze Objective Top Depth (ftKB) 7,238.0 Bottom Depth (ftKB) 7,456.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) 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 31 BBLS 15.8 PPG CEMENT PUMPED THROUGH RETAINER AND INTO THE C-SANDS. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Primary – Full Bore Objective Top Depth (ftKB) 6,569.5 Bottom Depth (ftKB) 7,986.3 Full Return? No Vol Cement … 7.0 Top Plug? No Btm Plug? Yes Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 3 P Pump Final (psi) 690.0 P Plug Bump (psi) 690.0 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 Pump 30 BBLS 12 PPG spacer, 47 BBLS 15.3 PPG cement Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 6,569.0 Est Btm (ftKB) 7,986.0 Amount (sacks) 226 Class G Volume Pumped (bbl) 47.0 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) 5.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Production String 1 Cement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"3*3 +.*6) 7+-+*3) !+)*++ !"")*-7+."*) )766"7.)+*)6 "7#)-7"+3*+6 * "*." =$!& ("0 7)6-*+. .*). +*3 7)36* !#.*3" !"++*+7+6)*- )766"7.6*) "7#)-7""-*)- *-3 ")+*#3 =$!& ("0 7#6-*+. *# ++*3 7#3* !3#*-. !"33*37)--*- )766"7.*.- "7#)-7.-)*)6 *"6 "6"* =$!& ("0 736-*+. )*. +)*" 73#*3" !6*6. !"*6)7#-.*" )766"7..)*-6 "7#)-7.+6*.) *+" "* =$!& ("0 7-6-*+. 3*3 +)*. 7-)*6 !""*)# !)+*#73#6*-6 )766.76-3*"+ "7#)-7..-*36 *3. 3)*+" =$!& ("0 766-*+. .*)- +)* 76+.*# !"*6 !6-*).7-)3* )766.76##*## "7#)376#+*#" *-# *3) =$!& ("0 7.6-*+. *+3 +)*3 7.)*6 !")+*-6 !+#*3#76+"*66 )766.76++*)6 "7#)376"#*+. *6. 3#*+ =$!& ("0 7"6-*+. #*#. +#*. 7".3*# !"3-*# !66*"67.*-# )766.76"*". 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(234 0 1 * 5 !"# $ 7 9 789 < 789 546&. 7 9 516& 7 9 (- 7 9 (- 7 9 10 7 9 4 0 7 9 - 7 9 , 786=9 (1+ )76-*+. +6*3 )*+) +7)"*" !-3#*+) !"73#)*6)+7++3*6" )766.7"6*3 "7#)#7+66*.3 .*+6 "76#*33 =$!& ("0 )76-*+. +6*- +*#. +7)6)*-- !6.* !"7--*)+7)"*+- )766.7"3)*-" "7#)#7+#*# .*## 7.6*." =$!& ("0 )7+6-*+. +6*-. *) +7##.*+" !6#)*") !"7-6.*.+7)33*." )766.7".*3 "7#)#73+*6) .*6# 7"")*"6 =$!& ("0 )7)6-*+. +6*# *) +73)*.3 !"7.".*)6 !"76)"*)3+7#+"*#3 )766.7.-)*") "7#)#7"*36 .*" 7"6"*" =$!& ("0 )7#6-*+. +6*3 *3 +73-6*33 !"7.))*-" !7."*6#+73.#*3 )766.7.6*36 "7#)#7)*) .*"6 7#3*" =$!& ("0 )736-*+. +6*+3 *- +7-)+*)- !"7"..*-" !7.3+*+.+733"*"- )76-6766+*#) "7#)#7"6"*. .*3 7+*" =$!& ("0 )7-6-*+. +6*33 *6 +76"6*3 !"7"+)*3 !7")*6+7-)*63 )76-676+6*#. "7#)#7"6*3- .*" 7+"6*.6 =$!& ("0 )766-*+. ).* *3 +76-*#) !"7"6.*6+ !7"63*3#+76..*) )76-676.+*+ "7#)#7.#-*.# .*+- 7+6)*+3 =$!& ("0 #7.6-*+. )"*3 *) )7.+#*6 !"7#*6# !7#.*.++76#*) )76-67-)-*.3 "7#)#7..)*-6 "*.- 7)3*#) =$!& ("0 #7"6-*+. )*#) *.3 )7".-*)+ !"7-+*" !7*"")7.)*"+ )76-67-".*3# "7#))76+*6+ "*+. 7#)"*"" =$!& ("0 #76-*+. )*6 *-. )7"#-* !"7*++ !7-3*.-)7.-+*6 )76-673#*. "7#))7-36*". "*6 73.*6 =$!& ("0 #76-*+. )+*+) *3 )7#*-+ !"7-"*)" !7+)"*#+)7"+*++ )76-673"*.- "7#))7-"+*## .*) 7-""*#) =$!& ("0 #7+6-*+. )*63 *) )7-#*. !"7+.*+ !7)")*#6)7.*# )76-67##+*." "7#))73).*3+ "*+6 7-6"*-3 =$!& ("0 #7)6-*+. ).*6. *#3 )7+3*#3 !"7+3-*# !7)3-*)7#+*3 )76-67#"#*.+ "7#))7#--* *.3 763.* =$!& ("0 #7#.-*.. ).*6. *#3 )7)*3 !"7+-*33 !7)-+*"))73.* )76-67#""*)" "7#))7#-*+" .*.. 7633*# *) &5 (0 #7-.)*. )"*36 .*"- )7+33*. !"7)--*# !7#6)*))76*-. )76-67).)*+. "7#))7)3"*)3 +*6# 7"3*- *) &5 (0 #7-*. )"*## *+3 )7+6+*#" !"7#.)*"6 !73.6*-)7+""*" )76-67+--*-. "7#))7))3*.) #*+" 7"+-*6 *) &5 (0 #766*#- )"*+ *6. )7))+*)# !"7##.* !73#"*+#)7+3"*"# )76-67+*## "7#))7).)*)+ "*"6 7"*- *) &5 (0 37.*- +3*3+ #*6+ )7#"+*6) !"73".*." !7-""*6)7)"*)) )76-67-*3) "7#))7+))*" +*#3 76.*6 *) &5 (0 37""6*.+ +#*6. "* )7#-.*"6 !"73)#*- !7-#)*#)7)6#*36 )76-673*# "7#))7+."*-- *+# 7#.*3+ *) &5 (0 37"*6" +3*.# )*++ )73++*6 !"7363*#+ !76"*.")7##"*) )76-676)*-3 "7#))7+#* *"- 7+6*- *) &5 (0 37""*)# +6*+ )*3 )7-".*.- !"7--*3+ !76-"*.)73#*#- )76-67)+*# "7#))7-#*+ *+ 7).*+- *) &5 (0 37+.3*)) +6*)6 #*#+ )7-3*) !"7-36*" !7.+"*)-)73-6*" )76-67"*6 "7#))7)*63 .*-" 7)3)* *) &5 (0 37+6-*. ).*." #*." )76"*". !"76"3*3+ !7.66*3)7-+3*3. )76-67"3)*) "7#))7"#-*- .*3. 7#++*#" *) &5 (0 37)6*+ +-*#3 3*6) )766*.6 !"76)3*.3 !7")6*3#)76.6*#6 )76-67")*-- "7#))7".3*66 *.6 73"#*3) *) &5 (0 37#--*.6 +-*) -*"- #7.))*#6 !"766+*# !7.*.)763*6 )76-67.6-*"6 "7#))7.+3*- .*+ 73-3*3) *) &5 (0 373-+*#. +-*" -*+. #7""6*-" !7.*)+ !7-"*-#7.#*+" )76-67.#.*" "7#)+76-#*)# .*# 7-)6*-- *) &5 (0 37--.*+- +3*+- -*# #7"-+*"# !7.#6*-" !7+"*6"#7"..*3# )76-67.*3 "7#)+76#*" .*3# 76.*6# *) &5 (0 376.*3 +-*. 3*6 #7"3*3" !7.-6*+) !73*"-#7"+*" )76-67..*." "7#)+7-6+*6" "*-. 76#3*-6 *) &5 (0 3766#*.. +-*. 3*6 #7#"*#. !7"")*3+ !7+"+*-#7"3-*. )76--763#*# "7#)+7-)*-- .*.. +7."#*#3 AC4$4 $ 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 Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3B-16A Conoco Phillips Alaska, Inc. Permit to Drill Number: 223-125 Surface Location: 229' FSL, 802' FEL, Sec. 16, T12N, R9E, UM Bottomhole Location:188' FNL, 4230' FEL, Sec. 21, T12N, R9E, UM Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this 3 day of January 2024. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.03 15:24:14 -09'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 8003' TVD: 6264' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property:14.Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 85' 15. Distance to Nearest Well Open Surface: x-518231 y- 5991349 Zone-4 to Same Pool:2100' (3B-15) 16. Deviated wells: Kickoff depth:6613'feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle:54.08 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6.125" 3-1/2" 9.3# L-80 Hyd563 8003' 8003' 6264' Surface Surface 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): None TVD 117' 3270' 6325' 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: Elliott Tuttle Contact Email: elliott.tuttle@conocophillips.com Senior CTD/RWO Engineer Contact Phone: (907) 263-4742 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 KRU 3B-16A Kuparuk River Field/ Kuparuk River Oil Pool 1/15/2024 30480' 5919-5958', 6047-6077', 6093-6123' Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2049 psi 1667' FNL, 3890' FEL, Sec. 21, T12N, R9E, UM 188' FNL, 4230' FEL, Sec. 21, T12N, R9E, UM ALK2566 P.O. Box 100360, Anchorage, AK 99510 ConocoPhillips Alaska, Inc. 229' FSL, 802' FEL, Sec. 16, T12N, R9E, UM ADL0025633 2560 18. Casing Program: Top - Setting Depth - BottomSpecifications 3419 psi Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) 270 sx 15.3 ppg Class G plus Adds 6851' 5514' Conductor/Structural 16"85' 7878'6342' LengthCasing 6851', 7238', 7245' Authorized Title: Authorized Signature: 375 sx Class G, 250 sx AS IProduction Liner 7835' Intermediate Authorized Name: 7385-7432', 7538-7574', 7592-7627' Commission Use Only See cover letter for other requirements. 7858'7" 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 3379' 265 sx PF "C' 117' 3409'9-5/8" 920 sx AS III, 360 SX Class G Effect. Depth MD (ft): Effect. Depth TVD (ft): Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 12/18/2023 Digitally signed by Elliott TuttleDN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN= Elliott Tuttle, E=elliott.tuttle@conocophillips.com Reason: I am the author of this document Location: Date: 2023.12.18 15:46:37-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle By Grace Christianson at 8:43 am, Dec 19, 2023 DSR-12/19/23 223-125 BOP test to 3000 psig Annular preventer test to 2500 psig VTL 01/03/2024 1,850' X A.Dewhurst 03JAN24 VTL 1/3/242827 -A.Dewhurst 03JAN23 see emails 50-029-21289-01-00 55.4' 1,130' to ADL 025632 ($8JLC 1/3/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.03 15:24:59 -09'00' 01/03/24 01/03/24 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 18, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 2M-24A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore, slot recovery to reacquire the Kuparuk formation, sidetracking out of the existing 3B-16 well, from the existing 3B pad in Kuparuk. The intended spud date for this well is 1/15/24. It is intended that Nabors 7ES be used to drill the well. 3B-16A will sidetrack out of the existing 7” intermediate casing in the 3B-16 wellbore. A 6-1/8” hole will be drilled to the planned TD, and a 3-1/2” liner will be run and cemented back into the 7” casing, with the top planned 890’MD or 575’TVD above the top of the Kuparuk resevoir. The well will be completed as an injector with a high pressure breakdown of the A Sand, Kuparuk formation. 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) 7. ¼ mile review of surrounding wells 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 Elliott Tuttle at 907-252- 3347(Elliott.tuttle@conocophillips.com) or Jonathan Coberly at 265-1013. Sincerely, Elliott Tuttle Drilling Engineer Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN= Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.12.18 15:47:14 -09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 1 of 7 Printed: 18-Dec-23 3B-16A 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)) ......................................... 2 3. Proposed Drilling Program ...................................................................................... 3 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 4 5. MASP Calculations ................................................................................................... 4 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 5 7. Casing and Cementing Program ............................................................................. 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 6 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 (Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 6 14. Drilling Hazards Summary ....................................................................................... 6 15. Proposed Completion Schematic ........................................................................... 7 Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 2 of 7 Printed: 18-Dec-23 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 3B-16A 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 229‘ FSL, 802‘ FEL, SEC 16, T12N, R9E, UM NAD 1927 Northings: 5991349 Eastings: 518231 RKB Elevation 85’ AMSL Pad Elevation 49’ AMSL Location at Sidetrack KOP 1254' FNL, 3390' FEL , S21 T12N R9E, UM NAD 1927 Northings: 5989861 Eastings: 515650 Measured Depth, RKB:6613’ Total Vertical Depth, RKB:5361’ Total Vertical Depth, SS:5276’ Top of Productive Horizon 1667' FNL, 3890' FEL , S21 T12N R9E, UM NAD 1927 Northings: 5989446 Eastings: 515152 Measured Depth, RKB:7458’ Total Vertical Depth, RKB:5899’ Total Vertical Depth, SS:5814’ Total Depth 1888' FNL, 4230' FEL, S21 T12N R9E, UM NAD 1927 Northings: 5989225 Eastings: 514814 Measured Depth, RKB:8003’ Total Vertical Depth, RKB:6264’ Total Vertical Depth, SS:6179’ Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 3 of 7 Printed: 18-Dec-23 3. Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. Completed Pre-Rig Work 1. Perform Tubing Punch at 7240’ to 7243’ RKB (8/4/2023) 2. Perform Injectivity test at 1.6BPM at 1375psi, set Retainer at 7198’ RKB and pump cement to suspend 3B-16 (8/18/23) 3. Tag TOC at 6647’ SLM, MIT-T 2500psi, Passed (9/6/23) 4. Get a SBHP on 3B-15 Remaining Pre-Rig Work 5. Pull DV in Station 9 at 6348’ RKB 6. Perform tubing cut at 6632’ RKB (once sundry is approved) 7. Ready well within 48Hrs on rig arrival Rig Work MIRU 1. MIRU Nabors 7ES on 3B-16. Circulate well over to 8.5ppg seawater. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30- minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve Tubing, Set whipstock 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to cut (~6632’ RKB). 6. Set Whipstock at 6613’ RKB TOWS oriented high side. 1. Mill window in 7” casing. 2. Drill 6-1/8” hole to TD, 210’ RKB below the A2-Kuparuk Formation. 7. Circulate hole clean and pull out of hole with drilling BHA. 8. Run 3.5” long string to TD. Land in tubing hanger and cement down tubing up through IA valve. a. Pressure test hanger seals to 5,000 psi. 9. Cement liner, bringing cement above packer and circulation sub (HP Defender). On plug bump, set packer, rupture circulation sub and circulate cement out of hole from above top of liner packer. 10. Perform pressure test on 7” casing / 3-1/2” liner to 2000. 11. Circulate in 8.6 ppg/ 8.6ppg CI as needed, close circulation sub with absolute pressure. 12. Test tubing to 3500 psi, chart test. 13. Test IA to 3,000 psi, chart test. Drop tubing pressure and shear SOV. 14. Install BPV and test to 1000 psi in the direction of flow. 15. Nipple down BOP. 16. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 4 of 7 Printed: 18-Dec-23 17. Freeze protect down annulus through SOV, RU TxIA cross, let u-tube. 18. 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 6613 / 5361 14.9 2439 1890 3.5 7373/ 5814 15.5 3419 2049 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) 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 = [(14.9 x 0.052) – 0.1] x 5361 = 3617 psi OR ASP = FPP – (0.1 x D) = 2425 – (0.1 x 5361) = 1890 psi Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 5 of 7 Printed: 18-Dec-23 Drilling 6-1/8” hole to top of Reservoir ASP = [(FG x 0.052) – 0.1] D = [(15.5 x 0.052) – 0.1] x 5814 = 4104 psi OR ASP = FPP – (0.1 x D) = 2630 – (0.1 x 5814) = 2049 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)) A FIT to 12.5 EMW at the surface casing shoe (3409’ RKB/ 3270’ TVD) was performed on original drill on 4/3/1985. Additionally, the CBL of the 7” from 4/12/1985 shows estimated TOC near 6301’ RKB, which is above planned KOP. 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 3.5 6.125 9.3 L-80 Hyd563 Cemented liner – 5.5” OD Centralizers planned Cementing Calculations 3-1/2” production tubing/ liner run to 7876’ MD / 6179’ TVD Top of slurry is designed to be at ~6560’ MD, the top of the 3-1/2” liner, which is 813’MD / 490’ TVD above the top of the Kuparuk interval. Assume 20% excess annular volume. Tail slurry from 7876’ MD to 6560’ MD with 15.3 ppg Class G + Add's Total Volume = 218ft3 => 270 sx of 15.3 ppg Class G + Add's @ 1.237 ft3/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Production Hole Size in. 6.125 Casing Size in. 3.5 Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 6 of 7 Printed: 18-Dec-23 Density PPG 11.5-12.5 PV cP 10 YP lb./100 ft2 10 - 15 Funnel Viscosity s/qt. 40 - 50 Initial Gels lb./100 ft2 6 10 Minute Gels lb./100 ft2 8 API Fluid Loss cc/30 min. 4.0 HPHT Fluid Loss cc/30 min. 10.0 pH 9.0 – 9.5 The interval will be drilled with a water-based mud (LSND) weighted to 11.5-12.5 ppg. Fluid hydraulic modeling has been performed. Range of fluid weights are due to shale stability above the Kuparuk. Base plan is to use 11.5ppg LSND. 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)) The Kuparuk C Sand formation at 3B-16 is abnormally pressured to 11.1ppg EMW, with a neighboring, 3B-15, well recently measuring 11.2ppg. 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 3B-16A will be injected into a permitted annulus on 1B pad. 14.¼ Mile review (Requirements of 20 AAC 25.402) No wellbores fall within a ¼ mile of the top-most planned perforation in 3B-16A, See attachments for map of area. o 11.1ppg EMW, w Application for Permit to Drill, 3B-16A Saved: 8/24/202318-Dec-23 3S-24B APD Page 7 of 7 Printed: 18-Dec-23 15. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 6.125” Hole / 3.5” Liner - Slant Production Hole Event Risk Level Mitigation Strategy Lost circulation Med Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material 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 (Known) 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 3B-16A 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. 16. Proposed Completion Schematic - Attached 3B-16 Proposed RWO-ST Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 117 117 16 15.06 62.5 H-40 Welded Welded Surface 3409 3270 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 7858 6325 7 6.276 26 J-55 BTC BTC Liner/ Tubing 8003 6264 3.5 2.99 9.3 L-80 Hyd563 Hyd563 PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface (2 Each) 3-1/2" Baker BGLO-1.0RCT Monotrip GLM @ TBD 3 1/2" HP Defender @ XXXX RKB (2.813" ID) 3.5" x 7.0" Packer @ ~6560' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Landing Collar 3 1/2" Float Collar 3 1/2" Float Shoe WP03 planned TD @ 8003' RKB REMAINING COMPLETION LEFT IN HOLE Planned tubing cut @ 6632' RKB 3.5" x 7.0" Packer (7224' RKB) GLM Blast Rings GLM 3.5" x 7.0" Packer (7460' RKB) 2.75" D-Nipple (7472' RKB) WLEG Surface Casing Production Casing Conductor A-sand perfs C-sand Perfs KOP @ 6613' MD (5357' TVDSS) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,641.0 3B-16 9/13/2011 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Cmt Retainer/Pump 33 bbls 15.8 ppg Cement. 3B-16 8/18/2023 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 7/7/2010 ninam 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 32.0 117.0 117.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.2 3,409.3 3,269.8 36.00 J-55 BTC PRODUCTION 7 6.28 23.7 7,858.4 6,325.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.7 Set Depth … 7,480.6 Set Depth … 5,998.6 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD 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) 23.7 23.7 0.01 HANGER 8.000 FMC GEN III TUBING HANGER PARKE R 141 3.500 1,827.5 1,827.4 1.74 SAFETY VLV 5.937 CAMCO TRDP-1A CAMCO TRDP- 1A 2.810 1,848.8 1,848.7 2.30 GAS LIFT 5.620 MERLA TMPD 2.937 3,066.1 2,998.5 32.49 GAS LIFT 5.620 MERLA TMPD 2.937 4,060.7 3,717.3 46.76 GAS LIFT 5.620 MERLA TMPD 2.937 4,614.7 4,089.3 48.72 GAS LIFT 5.620 MERLA TMPD 2.937 4,937.6 4,299.0 50.07 GAS LIFT 5.620 MERLA TMPD 2.937 5,250.4 4,500.8 49.69 GAS LIFT 5.620 MERLA TMPD 2.937 5,572.7 4,709.0 49.68 GAS LIFT 5.620 MERLA TMPD 2.937 5,880.9 4,908.6 49.71 GAS LIFT 5.620 MERLA TMPD 2.937 6,348.5 5,198.4 54.18 GAS LIFT 5.620 MERLA TMPD 2.937 6,821.0 5,494.0 47.03 GAS LIFT 5.620 MERLA TMPD 2.937 7,170.0 5,747.0 39.29 GAS LIFT 5.620 MERLA TPDX 2.937 7,215.3 5,782.4 38.05 SBR 4.000 OTIS SEAL BORE RECEPTACLE OTIS 3.000 7,224.3 5,789.5 37.83 PACKER 5.980 OTIS RRH RETRIEVABLE PACKER OTIS RRH 2.969 7,373.3 5,909.8 34.92 BLAST RING 3.500 BLAST RINGS (2) 2.992 7,456.3 5,978.3 33.72 LOCATOR 5.060 OTIS STRAIGHT SLOT TYPE LOCATOR OTIS 3.000 7,456.9 5,978.8 33.71 PACKER 6.156 OTIS WD PERMANENT PACKER OTIS WD 4.000 7,460.2 5,981.6 33.66 SBE 3.500 OTIS SEAL BORE EXTENSION OTIS 3.000 7,471.9 5,991.3 33.49 NIPPLE 4.520 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,479.4 5,997.6 33.38 WLEG 4.000 OTIS WIRELINE ENTRY GUIDE OTIS 3.000 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) 7,170.0 5,747.1 39.29 LEAK - TUBING Found tbg leak w/ Relay LDL 11/28/21 11/28/2021 0.000 7,195.0 5,766.5 38.57 CEMENT RETAINER SET 3.5" FH-1 CEMENT RETAINER AT 7195' RKB FH1 005- 2725- 500 8/18/2023 0.000 7,240.0 5,802.0 37.44 TUBING PUNCH 3 FT OF TUBING PUNCHES (4 SPF) 8/4/2023 2.992 7,245.0 5,805.9 37.31 RBP Set RBP (OAL 9.03') TTS CPP3 5281/ CPEQ 35001 11/4/2021 0.000 7,245.0 5,805.9 37.31 OTHER Set 3.5" TTS pulling tool w/ Multiple Fish G-Necks (Top Fish neck is 2.31" & Bottom Fish neck 1.81") 19" OAL 2/4/2022 0.000 7,255.0 5,813.9 37.07 PATCH 21.5' Merla TBG PATCH; Set across GLM #12 on 11/30/95/ w/ AVA Nipple 4' Below Top of GLM 11/30/1995 2.313 7,260.9 5,818.6 36.92 SLEEVE-O 2.31" AVA CIC SLEEVE (OAL=13") 9/13/2011 1.860 7,328.0 5,872.8 35.56 PATCH 21.5' Merla TBG PATCH; Set across GLM #13 on 11/30/95 11/30/1995 2.375 7,471.9 5,991.3 33.49 NIPPLE REDUCER Set Nipple Reducer w/ 1.81" D Profile; Set on 11/29/95 11/29/1995 1.813 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) 1,848.8 1,848.7 2.30 1 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 3,066.1 2,998.5 32.49 2 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 4,060.7 3,717.3 46.76 3 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 4,614.7 4,089.3 48.72 4 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 4,937.6 4,299.0 50.07 5 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 5,250.4 4,500.8 49.69 6 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 5,572.7 4,709.0 49.68 7 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 5,880.9 4,908.6 49.71 8 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 6,348.5 5,198.4 54.18 9 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 6,821.0 5,494.0 47.03 1 0 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000 7,170.0 5,747.0 39.29 1 1 GAS LIFT DMY RM 1 1/2 0.0 11/8/2021 0.000 7,260.9 5,818.6 36.92 1 2 INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000 7,332.9 5,876.8 35.49 1 3 INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000 7,436.8 5,962.2 34.01 1 4 INJ DMY RM 1 1/2 0.0 11/15/1995 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,385.0 7,432.0 5,919.4 5,958.2 C-3, C-2, C-1, 3B-16 5/18/1985 12.0 IPERF 5" Scalloped Csg Gun; 120 deg. ph7,538.0 7,574.0 6,046.8 6,077.3 A-4, A-3, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph 7,592.0 7,627.0 6,092.6 6,122.6 A-2, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,851.0 7,245.0 5,514.6 5,805.9 Cement Plug 30 BBLS 15.8 PPG CEMENT PUMPED THROUGH RETAINER. INTO C-SANDS. 8/17/2023 7,238.0 7,456.0 5,800.4 5,978.1 Cement Squeeze 30 BBLS 15.8 PPG CEMENT PUMPED THROUGH RETAINER AND INTO THE C-SANDS. 8/18/2023 3B-16, 8/18/2023 5:12:49 PM Vertical schematic (actual) PRODUCTION; 23.7-7,858.4 FLOAT SHOE; 7,856.8-7,858.4 FLOAT COLLAR; 7,768.3-7,769.8 IPERF; 7,592.0-7,627.0 IPERF; 7,538.0-7,574.0 WLEG; 7,479.4 NIPPLE REDUCER; 7,471.9 NIPPLE; 7,471.9 SBE; 7,460.2 PACKER; 7,456.9 LOCATOR; 7,456.3 INJECTION; 7,436.8 IPERF; 7,385.0-7,432.0 PATCH; 7,328.0 INJECTION; 7,332.9 PATCH; 7,255.0 INJECTION; 7,260.9 SLEEVE-O; 7,260.9 RBP; 7,245.0 OTHER; 7,245.0 TUBING PUNCH; 7,240.0 Cement Squeeze; 7,238.0 ftKB PACKER; 7,224.3 SBR; 7,215.3 CEMENT RETAINER; 7,195.0 GAS LIFT; 7,170.0 LEAK - TUBING; 7,170.0 Cement Plug; 6,851.0 ftKB GAS LIFT; 6,821.0 GAS LIFT; 6,348.5 GAS LIFT; 5,880.9 GAS LIFT; 5,572.7 GAS LIFT; 5,250.4 GAS LIFT; 4,937.6 GAS LIFT; 4,614.7 GAS LIFT; 4,060.7 SURFACE; 30.2-3,409.3 FLOAT SHOE; 3,407.7-3,409.3 FLOAT COLLAR; 3,319.0-3,320.6 GAS LIFT; 3,066.1 GAS LIFT; 1,848.8 SAFETY VLV; 1,827.5 CONDUCTOR; 32.0-117.0 HANGER; 30.2-35.1 HANGER; 23.7 KUP INJ KB-Grd (ft) 35.98 RR Date 4/7/1985 Other Elev… 3B-16 ... TD Act Btm (ftKB) 7,878.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128900 Wellbore Status INJ Max Angle & MD Incl (°) 54.45 MD (ftKB) 6,400.00 WELLNAME WELLBORE3B-16 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 6300 6700 6700 6725 6725 7200 7200 7800 7800 8000 3B-16A wp03 Plan Summary 3B-16A RST Project 3B-10 3B-13 3B-13L1 3B-13L1 3B-143B-15 3B-16 0 8 Do g l e g S e v e r i t y 6300 6600 6900 7200 7500 7800 Measured Depth 7" Production Liner 3-1/2" Conductor Casing 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 3B-16 5000 6000 Tr u e V e r t i c a l D e p t h 2700 2925 3150 3375 3600 3825 4050 Vertical Section at 238.27° 3B-16 3B-16A wp03 0 125 250 Ce n t r e t o C e n t r e S e p a r a t i o n 6250 6500 6750 7000 7250 7500 7750 Measured Depth 3B-16 Equivalent Magnetic Distance DDI 5.726 SURVEY PROGRAM Date: 2023-06-06T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 100.00 6300.00 3B-16 (3B-16)GCT-MS 6300.00 8003.00 3B-16A wp03 (3B-16A RST Project) r.5 MWD OWSG Surface Location North / 5991348.87 East / 518230.79Ground / 0.00 CASING DETAILS TVD MD Name 5184.69 6325.00 7" Production Liner 6264.27 8003.00 3-1/2" Conductor Casing Mag Model & Date: BGGM2023 01-Oct-23 Magnetic North is 14.50° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.68° 57245.94nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 6300.00 53.92 232.80 5169.92 -1332.43 -2387.06 0.00 0.00 2731.04 Start DLS 1.03 TFO -177.25 2 6613.00 50.70 232.60 5361.26 -1482.50 -2584.07 1.03 -177.25 2977.52 Start DLS 13.00 TFO -45.00 3 6649.00 54.08 228.51 5383.23 -1500.63 -2606.07 13.00 -45.00 3005.77 Start 40.00 hold at 6649.00 MD 4 6689.00 54.08 228.51 5406.70 -1522.09 -2630.34 0.00 0.00 3037.69 Start DLS 4.00 TFO -100.00 5 6849.00 53.23 220.64 5501.62 -1613.73 -2720.70 4.00 -100.00 3162.74 Start DLS 4.00 TFO 118.02 6 7190.86 47.88 236.98 5719.61 -1787.55 -2917.12 4.00 118.02 3421.22 Start 604.48 hold at 7190.86 MD 7 7795.34 47.88 236.98 6125.00 -2031.91 -3293.07 0.00 0.00 3869.49 Start 207.66 hold at 7795.34 MD 8 8003.00 47.88 236.98 6264.27 -2115.85 -3422.23 0.00 0.00 4023.49 TD at 8003.00 FORMATION TOP DETAILS No formation data is available By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by 3B-16 @ 85.00usft (3B-16) Pl a n V i e w Pr o j e c t : K u p a r u k R i v e r U n i t _ 2 Si t e : K u p a r u k 3 B P a d We l l : 3 B - 1 6 We l l b o r e : 3 B - 1 6 A R S T P r o j e c t De s i g n : 3 B - 1 6 A w p 0 3 -9 0 0 0 -6 0 0 0 -3 0 0 0 0 South(-)/North(+) (1500 usft/in) -4 5 0 0 - 3 0 0 0 - 1 5 0 0 0 1 5 0 0 We s t ( - ) / E a s t ( + ) ( 7 5 0 u s f t / i n ) 3B - 1 6 A T 1 . 2 1 3 2 1 f t 3 B -1 0 3B -13 3B -13 L 1 3B-13 L 1 wp0 4 3B-14 3 B-15 3 B-16 626 4 3 B -16A w p 0 3 50 0 0 55 0 0 60 0 0 65 0 0 True Vertical Depth (250 usft/in) 20 0 0 2 5 0 0 3 0 0 0 3 5 0 0 4 0 0 0 4 5 0 0 Ve r t i c a l S e c t i o n a t 2 3 8 . 2 7 ° ( 2 5 0 u s f t / i n ) 3 B - 1 6 / 3 B - 1 6 7" P r o d u c t i o n L i n e r 3- 1 / 2 " C o n d u c t o r C a s i n g 64 00 6600 68 00 70 0 0 7 2 0 0 7 4 0 0 76 0 0 7 8 0 0 80 0 0 3B - 1 6 / 3 B - 1 6 A w p 0 3 St a r t D L S 1 . 0 3 T F O - 1 7 7 . 2 5 St a r t D L S 1 3 . 0 0 T F O - 4 5 . 0 0 St a r t 4 0 . 0 0 h o l d a t 6 6 4 9 . 0 0 M D St a r t D L S 4 . 0 0 T F O - 1 0 0 . 0 0 St a r t D L S 4 . 0 0 T F O 1 1 8 . 0 2 St a r t 6 0 4 . 4 8 h o l d a t 7 1 9 0 . 8 6 M D St a r t 2 0 7 . 6 6 h o l d a t 7 7 9 5 . 3 4 M D TD a t 8 0 0 3 . 0 0 Se c t i o n V i e w Pr o j e c t : K u p a r u k R i v e r U n i t _ 2 Si t e : K u p a r u k 3 B P a d We l l : 3 B - 1 6 We l l b o r e : 3 B - 1 6 A R S T P r o j e c t De s i g n : 3 B - 1 6 A w p 0 3 ! 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B 9 % B 0 Pr o j e c t : Ku p a r u k R i v e r U n i t _ 2 Si t e : K u p a r u k 3 B P a d We l l : 3B - 1 6 Qu a r t e r M i l e P l a n V i e w We l l p l a n : 3 B - 1 6 A w p 0 3 -9 0 0 0 -6 0 0 0 -3 0 0 0 0 South(-)/North(+) (1500 usft/in) -6 0 0 0 - 3 0 0 0 0 3 0 0 0 6 0 0 0 We s t ( - ) / E a s t ( + ) ( 1 5 0 0 u s f t / i n ) 3B - 1 6 A 1 3 2 0 f t 3B - 1 6 A T 1 . 1 3B -1 4 3 B -1 0 3B -13 3B-13 L 1 2 3 / 8 " 3B-13L1 wp0 4 16 " C o n d u c t o r C a s i n g 7" P r o d u c t i o n L i n e r 3B -1 6 3B-15 16 " C o n d u c t o r C a s i n g 9- 5 / 8 " S u r f a c e C a s i n g 3B - 1 6 A w p 0 3 1 Dewhurst, Andrew D (OGC) From:Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent:Wednesday, January 3, 2024 08:55 To:Dewhurst, Andrew D (OGC); Hobbs, Greg S Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL]KRU 3B-16A (PTD 223-125) - Questions Attachments:3B-16A_PTD.pdf Andrew, Please see aƩached plat showing 3B-16A proposed sidetrack. 3B-16A wp03 Property Designation: Acres in Property:* Distance to Nearest Property†: Distance to Nearest Well Open to Same Pool‡: ADL025633 2560 1130' to ADL025632 1850' to 3B-15 2700' to 3B-14 † based on BHL ‡ based on wells' open intervals 3,000' to 3B-01 From: Tuttle, Elliott Sent: Tuesday, January 2, 2024 3:03 PM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]KRU 3B-16A (PTD 223-125) - Questions Andrew, Please Įnd the aƩached as built you requested as well as my answers to your quesƟons below. The plat will take a few days and I didn’t want to wait any longer to provide an update, thank you. Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 668 Some people who received this message don't often get email from elliott.tuttle@conocophillips.com. Learn why this is important 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 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, December 27, 2023 1:25 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]KRU 3B-16A (PTD 223-125) - 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. EllioƩ, I am compleƟng the review of the KRU 3B-16A PTD and have a few quesƟons: x This PTD applicaƟon doesn’t have a copy of the “as-built” survey. We have on record the original one from 1985 (PTD 185-026). It matches the SHL. I’m just checking to see if there a newer survey exists. If so, please send me a copy. AƩached x The ground/pad elevaƟon was leŌ blank on the 10-401. Would you please conĮrm the pad elevaƟon and KRB? I do see the 85’ KB. - KB to Ground is 35.98’. 49’ ground elevaƟon x Would you also please send a plat with the well path and lease boundaries marked? Forthcoming x What is the prognosed depth of the Kuparuk C for the redrill? - Top of Kuparuk C Sand prognosed at 7485’ RKB, 5832’ TVDSS x Would you please conĮrm the presence of H2S at the 3B pad? Please provide a recent and maximum reading. - Highest reading was 600ppm, read on 3B-11 – 9/23/00, most recent reading on pad was 3B-03 at 90ppm and was taken 12/24/23. x Are you planning on pre-producing this injector? - No plan to pre-produce this well. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 15 21 16 22 3A -17 A J-01 A-17 A L 1 W - 1 2 3 B - 0 3 3A- 1 7 A L 2 3A- 1 7 A L 2 - 0 1 3A-12 2W - 1 4 2 W - 1 0 2W-0 2 L 1 3F-06 2 W - 0 9 L 1 3B - 1 4 3F-02 3A-05 3A-18 3A- 0 1 3F-02L 1 3B-07 3F- 0 5 3B- 1 0 3B-01 3B-08 3 B - 0 4 3B-09 3B-16 3 A - 1 8 L 1 3B- 0 5 3B-0 6 3B - 1 3 3B - 1 1 3 B - 0 2 3 B - 1 2 3 A - 1 8 L 1 - 0 1 3B- 1 5 3B - 1 3 L 1 ADL025643 ADL025633 ADL025631 ADL025632 ADL025642 ADL025630 3B Document Path: S:\ANC\Longterm\AK GIS\GKA\DM\GKA_Wells_AD01\CPF_3_Wells\Well_3B-16A\Well_3B-16A.aprx k1/2/2024 Document Path: S:\ANC\Longterm\AK GIS\GKA\DM\GKA_Wells_AD01\CPF_3_Wells\Well_3B-16A\Well_3B-16A.aprx k1/2/2024 3B-1 6 A 3B-16A PTD 00.20.40.1 Miles Main Trajectory Perforated Interval Suspended Well P+A Well Active Well Roads and Pads Kuparuk PA Unit Boundary CPAI Lease ADNR Township ADNR Section Well Pad 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. 223-125 KUPARUK RIVER KRU 3B-16A X KUPARUK RIVER OIL POOL 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 3 B - 1 6 A In i t i a l C l a s s / T y p e SE R / 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 SE R 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 1 2 5 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 2 5 6 3 3 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 Ye s Ar e a I n j e c t i o n O r d e r N o . 2 C - K u p a r u k R i v e r U n i t 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 Ye s 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 ) No 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 Ce m e n t e d p r o d u c t i o n l i n e r 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 5 - 0 2 6 , S u n d r y 3 2 3 - 6 6 4 & 3 2 3 - 3 3 3 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 r e s e r v o i r p r e s s u r e i s 3 4 1 9 p s i g ( 1 2 . 2 p p g E M W ) ; w i l l d r i l l w / 1 1 . 5 - 1 2 . 5 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 8 8 2 p s i g ; w i l l t e s t B O P s t o 3 0 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 Ye s no o t h e r w e l l s i n A O R 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 H2 S m e a s u r e s r e q u i r e d . M a x r e a d i n g 6 0 0 p p m a t 3 B - 1 1 ( 2 0 0 0 ) 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 Ma x p o r e p r e s s u r e o f 1 1 . 1 p p g E M W a n t i c i p a t e d i n K u p a r u k C 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 1/ 3 / 2 0 2 4 Ap p r VT L Da t e 1/ 3 / 2 0 2 4 Ap p r AD D Da t e 1/ 3 / 2 0 2 4 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *& : JL C 1 / 3 / 2 0 2 4
