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Home My WebLink About222-0131. 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 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): 7,944 N/A Casing Collapse Structural Conductor 670psi Surface 2,090psi Intermediate 3,270psi Production Liner 10,959psi 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: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 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 Other: CTCO& N2 Operations CO 68A N Cook Inlet Tertiary System Gas Same 5,563 7,854 5,473 166psi N/A 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: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 16,176psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 222-013 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20031-02-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-11A Length Size Proposed Pools: 380' 380' L-80 TVD Burst 7,941 MD 4,360psi 1,640psi 3,580psi 621' 2,488' 3,047' 621' 2,745' 380' 30" 16" 10-3/4" 621' 7"3,520' 2,745' Perforation Depth MD (ft): 3,520' 6,923 - 7,637 4-1/2" 4,657 - 5,269 1/26/2026 7,941'4,658' 4-1/2" 5,560' Baker ZXP & Baker ONYX-R5E TRSSSV 3,283 (MD) 2m874 (TVD) & 357 (MD) 357 (TVD) No 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 Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2026.01.09 14:35:16 - 09'00' Dan Marlowe (1267) 326-021 By Grace Christianson at 2:44 pm, Jan 09, 2026 DSR-1/16/26 10-404 MGR09JAN2025 TS 1/12/26 * BOPE pressure test to 3000 psi. 48 hour notice to AOGCC for opportunity to witness. 01/20/26 Fill Clean Out and Perf Well: North Cook Inlet Unit A-11A Well Name:NCIU A-11A API Number:50-883-20031-02 Current Status:Online, Gas Well Leg:Leg #2 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:222-013 First Call Engineer:Eric Dickerman (907) 564-4061 Second Call Engineer:Dan Marlowe (907) 283-1329 Maximum Expected BHP:717 psi at 5,515 tvd 0.13 psi/ft NCIU A-01A, 11/10/2021 SBHP survey Max. Potential Surface Pressure: 166 psi MPSP -0.1 psi/ft gas grad. to surface Field/Pool: North Cook Inlet Unit, Tertiary System Gas Pool Applicable Frac Gradient: 0.77 psi/ft using 14.9 ppg EMW 7/16/2022 LOT after exiting 7 casing. Shallowest Allowable Perf TVD: MPSP/(Frac grad. Gas grad.) = 166 psi / (0.77 0.1 psi/ft) = 248 tvd Brief Well Summary: A-11A was drilled and completed in August 2022, targeting the Beluga formation. The Beluga A, B, C, D, E, and F sands were initially perforated. In July 2023, fill was tagged at 7625 in the deepest perf interval and a fluid level was found at 7,200. In April 2024, slickline tagged fill at 7,559 which puts the bottom two perf intervals below fill. A fluid level was logged at 7,225 putting the bottom 91 of perforations below fluid level. Recent add perf success on NCIU A-06A indicates potential for bypassed pay opportunities in NCIU A-11A close to PBTD. Objective: Coiled tubing fill cleanout. Add Beluga perforations. Wellbore information: North Cook Inlet Unit, Tertiary System Gas Pool top = Top of Sterling sands, at 3,890 md / 3,276 tvd. North Cook Inlet Unit, Tertiary System Gas Pool Bottom = Base of Beluga sands (below TD). Fill Clean Out and Perf Well: North Cook Inlet Unit A-11A Coiled Tubing Cleanout: 1. MIRU Fox Offshore Coiled Tubing Unit #9 and pressure control equipment. 2. Pressure test BOP and PCE to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48hr witness notification for BOP test. 3. MU cleanout BHA. Dry tag top of fill, then cleanout to PBTD ± 7,854. a. * The bottom two target perf intervals are close to PBTD and may or may not be accessible depending on final corrected depths. Plan to clean out as deep as possible then determine if the target intervals can be perforated after reviewing the correlation log. b. Working fluid will be 6% KCl (8.6 ppg). c. Take returns to surface from the coiled tubing backside. d. Add foam and nitrogen as necessary to carry solids to surface. 4. RIH and blow well dry with nitrogen. 5. RDMO CTU. Slickline drift: 6. MIRU Slickline. PT PCE to 250 psi low / 3,000 psi high. 7. Dummy perf gun drift for eline. 8. RDMO. Eline Perforate: 9. MIRU Eline. 10. Pressure test PCE to 250 psi low / 3,000 psi high. 11. Perforate the target intervals per the perf table below. All perforations are within the North Cook Inlet Unit, Tertiary gas pool. Tie in to the attached correlation log. Sand Interval Perforation Top (MD) Perforation Bottom (MD) Perforation Interval Footage (ft.) Beluga_Gb 7746 7749 3 Beluga_Ha 7821 7831 10 Beluga_Hb* 7858 7869 11 Beluga_Hc* 7884 7894 10 * bottom two intervals are close to PBTD and may not be accessible depending on final depth correction to the open hole logs. 12. RDMO Eline. 13. Hand well over to Operations to flow test. If new perf intervals bring in unwanted solids or water execute the CONTINGENCY Eline plug and/or coil cleanout. CONTINGENCY Eline plug/patch: (if any zone makes unwanted solids or water) 14. RU Nitrogen to tubing and pressure test treating iron to 250 psi low / 3,000 psi high. 15. Pressure up on tubing to displace water back into formation. Fill Clean Out and Perf Well: North Cook Inlet Unit A-11A 16. MIRU Eline. 17. Pressure test PCE to 250 psi low / 3,000 psi high. 18. Set 4-1/2 CIBP or patch to shut off unwanted interval per Operations Engineer. a. If a 4-1/2 CIBP is set, dump bail 25 of cement on top of plug. 19. RDMO Eline and Nitrogen. CONTINGENCY Coiled Tubing Cleanout: (if any zone brings in excessive fill and needs to be cleaned out) 20. MIRU Fox Offshore Coiled Tubing Unit #9 and pressure control equipment. 21. Pressure test BOP and PCE to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48 hr witness notification for BOP test. 22. MU cleanout BHA. Dry tag top of fill, then begin cleaning out to target depth per Operations Engineer. a. Working fluid will be 6% KCl (8.6 ppg). b. Take returns to surface from the coiled tubing by 4-1/2 annulus. c. Add foam and nitrogen as necessary to carry solids to surface. 23. RIH and blow well dry with nitrogen. 24. RDMO CTU. Attachments: 1. Correlation log 2. Current Wellbore Schematic 3. Proposed Wellbore Schematic 4. CT BOP Drawing 5. Nitrogen procedure Fill Clean Out and Perf Well: North Cook Inlet Unit A-11A Correlation Log: Target perf intervals Updated by JLL 01/09/26 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: NCI A-11A PTD: 222-013 API: 50-883-20031-02-00 Completed: 7/26/22 JEWELRY DETAIL Item Depth MD Depth TVD ID OD Description 1 357 357 3.870 5.970 Baker ONYX-R5E TRSSSV 2 3,283 2,874 3.940 6.390 Baker ZXP Liner Hanger / Packer & Seal Assy. PBTD:7,854 MD /5,473 TVD TD: 7,944 MD / 5,563 TVD 30 RKB: MSL = 126.6 1 10-3/4 4-1/2 7 Window @ 3,520 MD 16 NCIU A-11 Motherbore RA 6,948 RA 7,444 2 Beluga A TOC3,590 w/ CBL on 8-15-22 Beluga B Beluga C Beluga D Beluga E Beluga F CASING & TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30 28.500 Surf 380 16 65 H-40 15.250 Surf 621 10-3/4 45.5 & 51 J-55 BTC 9.850 Surf 2,745 7 26 J-55 BTC 6.276 Surf 77 7 23 J-55 BTC 6.366 77 3,520 (TOW) 4-1/2 12.6 L-80 IBT-M 3.958 Surf 3,290 4-1/2 12.6 L-80 DWC 3.958 3,283 7,941 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status Beluga A Lower 6,923'6,957' 4,657 4,680' 34' 8/27/22 Open Beluga B Upper 1 6,974' 6,994' 4,693 4,708' 20' 8/25/22 Open Beluga B Upper 2 7,022' 7,034' 4,729 4,738' 12' 8/25/22 Open Beluga B Lower 7,133' 7,139' 4,817 4,822' 6' 8/24/22 Open Beluga C Upper 7,173' 7,190' 4,851 4,865' 17' 8/24/22 Open Beluga D Upper 7,317' 7,326' 5,976 4,984' 9' 8/24/22 Open Beluga D Mid 7,356' 7,370' 5,010 5,023' 14' 8/24/22 Open Beluga D Lower 7,410' 7,440' 5,059 5,087' 30' 8/24/22 Open Beluga E Upper 7,451' 7,469' 5,097 5,113' 18' 8/24/22 Open Beluga F Upper 7,597 7,603' 5,231 5,237' 6' 8/24/22 Open Beluga F Mid 7,623' 7,637 5,256 5,269' 14' 8/24/22 Open Updated by JLL 01/09/26 PROPOSED North Cook Inlet Unit Tyonek Platform Well: NCI A-11A PTD: 222-013 API: 50-883-20031-02-00 Completed: 7/26/22 JEWELRY DETAIL Item Depth MD Depth TVD ID OD Description 1 357 357 3.870 5.970 Baker ONYX-R5E TRSSSV 2 3,283 2,874 3.940 6.390 Baker ZXP Liner Hanger / Packer & Seal Assy. PBTD: 7,854 MD / 5,473 TVD TD: 7,944 MD / 5,563 TVD 30 RKB: MSL = 126.6 1 10-3/4 4-1/2 7 Window @ 3,520 MD 16 NCIU A-11 Motherbore RA 6,948 RA 7,444 2 Beluga A TOC 3,590 w/ CBL on 8-15-22 Beluga B Beluga C Beluga D BelugaE Beluga F Beluga G Beluga H CASING & TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30 28.500 Surf 380 16 65 H-40 15.250 Surf 621 10-3/4 45.5 & 51 J-55 BTC 9.850 Surf 2,745 7 26 J-55 BTC 6.276 Surf 77 7 23 J-55 BTC 6.366 77 3,520 (TOW) 4-1/2 12.6 L-80 IBT-M 3.958 Surf 3,290 4-1/2 12.6 L-80 DWC 3.958 3,283 7,941 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status Beluga A Lower 6,923'6,957' 4,657 4,680' 34' 8/27/22 Open Beluga B Upper 1 6,974' 6,994' 4,693 4,708' 20' 8/25/22 Open Beluga B Upper 2 7,022' 7,034' 4,729 4,738' 12' 8/25/22 Open Beluga B Lower 7,133' 7,139' 4,817 4,822' 6' 8/24/22 Open Beluga C Upper 7,173' 7,190' 4,851 4,865' 17' 8/24/22 Open Beluga D Upper 7,317' 7,326' 5,976 4,984' 9' 8/24/22 Open Beluga D Mid 7,356' 7,370' 5,010 5,023' 14' 8/24/22 Open Beluga D Lower 7,410' 7,440' 5,059 5,087' 30' 8/24/22 Open Beluga E Upper 7,451' 7,469' 5,097 5,113' 18' 8/24/22 Open Beluga F Upper 7,597 7,603' 5,231 5,237' 6' 8/24/22 Open Beluga F Mid 7,623' 7,637 5,256 5,269' 14' 8/24/22 Open Bel Gb ±7,746' ±7,749' ±5,373' ±5,376' ±3' Future Proposed Bel Ha ±7,821' ±7,831' ±5,445' ±5,455' ±10' Future Proposed Bel Hb ±7,858' ±7,869' ±5,480' ±5,491' ±11' Future Proposed Bel Hc ±7,884' ±7,894' ±5,505' ±5,515' ±10' Future Proposed STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 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 - 8 8 3 - 2 0 0 3 1 - 0 2 - 0 0 We l l N a m e / N o . N C O O K I N L E T U N I T A - 1 1 A Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 8/ 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 79 4 4 TV D 55 6 3 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : CB L 8 - 1 5 - 2 2 , L W D : D G R / E W R / A L D / C T N No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 5/ 1 0 / 2 0 2 2 37 0 2 3 3 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 : N C I _ A - 1 1 A _ P l u g Ce m e n t _ 2 4 - A p r - 2 0 2 2 _ ( 3 7 5 2 ) . l a s 36 5 6 6 ED Di g i t a l D a t a DF 5/ 1 0 / 2 0 2 2 E l e c t r o n i c F i l e : N C I _ A - 1 1 A _ P l u g C e m e n t _ 2 4 - A p r - 20 2 2 _ ( 3 7 5 2 ) . p d f 36 5 6 6 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 35 1 2 7 9 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : N C I U A - 1 1 A LW D F i n a l . l a s 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l M D . c g m 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l T V D . c g m 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A - D e f i n i t i v e S u r v e y Re p o r t . p d f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A - F i n a l S u r v e y s . x l s x 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A _ D S R Ac t u a l _ P l a n . p d f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A _ D S R Ac t u a l _ V S e c . p d f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A _ D S R . t x t 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A _ D S R _ G I S . t x t 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l M D . e m f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l T V D . e m f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l M D . p d f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l T V D . p d f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l M D . t i f 36 8 3 8 ED Di g i t a l D a t a DF 7/ 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : N C I U A - 1 1 A L W D F i n a l T V D . t i f 36 8 3 8 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 1 o f 3 NC I U A - 1 1 A LW D F i n al. l as DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 8 8 3 - 2 0 0 3 1 - 0 2 - 0 0 We l l N a m e / N o . N C O O K I N L E T U N I T A - 1 1 A Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 8/ 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 79 4 4 TV D 55 6 3 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : 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 : 8 / 2 4 / 2 0 2 2 Re l e a s e D a t e : 2/ 1 1 / 2 0 2 2 DF 9/ 2 2 / 2 0 2 2 17 9 6 1 4 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 : N C I _ A - 11 A _ R B T _ 1 5 A U G 2 2 _ F r e e P i p e . l a s 37 0 3 3 ED Di g i t a l D a t a DF 9/ 2 2 / 2 0 2 2 78 1 6 2 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 : N C I _ A - 11 A _ R B T _ 1 5 A U G 2 2 _ M a i n P a s s . l a s 37 0 3 3 ED Di g i t a l D a t a DF 9/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : N C I _ A - 1 1 A _ R B T _ 1 5 A U G 2 2 . p d f 37 0 3 3 ED Di g i t a l D a t a DF 9/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : N C I _ A - 11 A _ R B T _ 1 5 A U G 2 2 _ F r e e P i p e . d l i s 37 0 3 3 ED Di g i t a l D a t a DF 9/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : N C I _ A - 11 A _ R B T _ 1 5 A U G 2 2 _ i m g . t i f f 37 0 3 3 ED Di g i t a l D a t a DF 9/ 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : N C I _ A - 11 A _ R B T _ 1 5 A U G 2 2 _ M a i n P a s s . d l i s 37 0 3 3 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 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 - 8 8 3 - 2 0 0 3 1 - 0 2 - 0 0 We l l N a m e / N o . N C O O K I N L E T U N I T A - 1 1 A Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 8/ 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 79 4 4 TV D 55 6 3 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No Co m p l i a n c e R e v i e w e d B y : Da t e : Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 3 o f 3 M. G u h l 9/ 2 2 / 2 0 2 3 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/07/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230207 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPE-17 50029226870000 196115 1/17/2023 YELLOW JACKET LDL CLU 10RD 50133205530100 222113 2/3/2023 YELLOW JACKET GPT-PERF BCU 04RD 50133202390100 219011 1/27/2023 YELLOW JACKET PERF BCU 04RD 50133202390100 219011 2/2/2023 YELLOW JACKET PERF BCU 05RD2 50133202620200 218068 1/26/2023 YELLOW JACKET PERF BCU 12A 50133205300100 214070 2/1/2023 YELLOW JACKET PLUG Please include current contact information if different from above. By Meredith Guhl at 9:51 am, Feb 07, 2023 T37492 T37492 T37493 T37494 T37495 T37496 CLU 10RD 50133205530100 222113 2/3/2023 YELLOW JACKET GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.07 10:08:10 -09'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/21/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220921 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # HVB B-16A 50231200400100 222070 8/5/2022 YellowJacket CBL Paxton 6 50133207070000 222054 7/23/2022 AK E-Line CBL NCIU A-09A 50883200290100 222024 8/6/2022 AK E-Line CBL NCIU A-11A 50883200310200 222013 8/15/2022 Halliburton CBL NCIU A-10B 50883200300200 222025 8/16/2022 Halliburton CBL Please include current contact information if different from above. T37029 T37031 T37030 T37033 T37032 NCIU A-11A 50883200310200 222013 8/15/2022 Halliburton CBL Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.22 13:28:56 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): North Cook Inlet Unit GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 4-1/2" L-80 5,561' 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 Rate206 July 23, 2022 July 16, 2022 ADL 17589 N/A N/A 3,520' MD / 3,047' TVD99 357' MD / 357' TVD 7,944' MD / 5,563' TVD CBL 8-15-22, Logging While Drilling Logs Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 003883 Oil-Bbl: suspension, or abandonment, 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 if necessary N/A3883 Flowing *** Please see attached schematic for perforation detail *** 0 Water-Bbl: PRODUCTION TEST 8/24/2022 Date of Test: 18 9/7/2022 24 Flow Tubing 0 12.6# 7,941 Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) 3,283' MD / 2,874' TVD PACKER SET (MD/TVD) CASING WT. PER FT.GRADE 332335 332374 TOP SETTING DEPTH MD 3,283' SETTING DEPTH TVD 2591486 BOTTOM TOP 2,874' HOLE SIZE AMOUNT PULLED 50-883-20031-02-00 NCIU A-11A 332041 2586677 2193' FNL, 1253' FWL, Sec 31, T12N, R9W, SM, AK CEMENTING RECORD 2591062 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/24/2022 1302' FNL, 1023' FWL, Sec 6, T11N, R9W, SM, AK 1769' FNL, 1286' FWL, Sec 31, T12N, R9W, SM, AK 222-013 / 322-416 / 322-443 Tertiary System Gas Pool 126.6' 7,854' MD / 5,473' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6-1/8" 540 sx 3,290'4-1/2" Tieback SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:27 pm, Sep 21, 2022 Completed 8/24/2022 JSB RBDMS JSB 101222 LWD: DGR/EWR/ALD/CTN MDG 10/13/2022 G 222-013 G NCIU A-11A SFD 11/14/2022 DSR-4/24/23BJM 11/9/23 Development Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval 6,923' Bel A 4,657' 6844' 4604' 6966' 4687' 7169' 4847' 7273' 4937' 7452' 5098' 7597' 5231' 7700' 5329' 7752' 5379' Bel H 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: 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. 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). 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, 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. Formation at total depth: Bel D Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. Signature w/Date: 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. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Bel H Bel E Bel B Bel C Bel A This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Bel F Bel G Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment For Monty MyersDigitally signed by Cody Dinger (2323) DN: cn=Cody Dinger (2323), ou=Users Date: 2022.09.21 11:17:31 -08'00' Cody Dinger (2323) Updated by CJD 09-21-22 Schematic North Cook Inlet Unit Tyonek Platform Well: NCI A-11A PTD: 222-013 API: 50-883-20031-02-00 Completed: 7/26/22 JEWELRY DETAIL Item Depth MD Depth TVD ID OD Description 1 357’357’3.870”5.970”Baker ONYX-R5E TRSSSV 2 3,283’2,874’3.940”6.390”Baker ZXP Liner Hanger / Packer & Seal Assy. CASING & TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30”Surf 380’ 16”65 H-40 Surf 621” 10-3/4”45.5 & 51 J-55 BTC Surf 2,745’ 7”26 J-55 BTC Surf 77’ 7”23 J-55 BTC 77’3,520’ (TOW) 4-1/2”12.6 L-80 IBT-M 3.958”Surf 3,290’ 4-1/2”12.6 L-80 DWC 3,283’7,941’ PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status Beluga A Lower 6,923'6,957'4,657’4,680'34'8/27/22 Open Beluga B Upper 1 6,974'6,994'4,693’4,708'20'8/25/22 Open Beluga B Upper 2 7,022'7,034'4,729’4,738'12'8/25/22 Open Beluga B Lower 7,133'7,139'4,817’4,822'6'8/24/22 Open Beluga C Upper 7,173'7,190'4,851’4,865'17'8/24/22 Open Beluga D Upper 7,317'7,326'5,976 4,984'9'8/24/22 Open Beluga D Mid 7,356'7,370'5,010’5,023'14'8/24/22 Open Beluga D Lower 7,410'7,440'5,059’5,087'30'8/24/22 Open Beluga E Upper 7,451'7,469'5,097’5,113'18'8/24/22 Open Beluga F Upper 7,597’7,603'5,231’5,237'6'8/24/22 Open Beluga F Mid 7,623'7,637’5,256’5,269'14'8/24/22 Open Activity Date Ops Summary 7/14/2022 Skid rig from A-10B and center over NCIU A-11A. Secure rig. Fabricate and install stairs and landing. Modify flow line and work on rig acceptance chk list .;Remove dry hole tree. Install tbg spool and riser. Continue work rig acceptance chk list. Work boat. Clean pits and continue w/ flow line modification;Nipple up 13-5/8" 5M riser and BOPE stack. Continue work rig acceptance chk list. Clean pits and continue w/ flow line modification;Nipple up bell nipple and pollution pan. Install fill-up line and bleed off line. Check pre-charge on accumulator bottles. Continue work rig acceptance chk list.;Rig up to test BOPE. Make up test assemblies. Install test plug and fill stack with water. Flush Kill line and choke manifold. Continue work rig acceptance chk list.;Test BOPE per AOGCC/Hilcorp policy - 250/3000 psi for 5/5 charted min. Test upper rams, lower rams and annular with both 4" and 4.5" test joint.;Drilling - Inlet Water Use and Discharge Summary (bbls) Inlet Water Used Today: 0 Inlet Water Used Cumulative: 0 Discharge Today: 0 Discharge Cumulative: 0 Daily down hole loss: 0 Total down hole loss: 0;Metals Recovery (lbs) Today: 0 Cumulative: 0 7/15/2022 Continue and finish Testing BOPE per AOGCC/Hilcorp policy - 250/3000 psi for 5/5 charted min. Test upper rams, lower rams and annular with both 4" and 4.5" test joint. and build mud continue working rig acceptance check list;Preform accumulator draw down test continue build mud;R/dn test equipment. inspect and re-chk accumulator bottles pre charge, check for any leaking Shrader valves all good and continue build mud;Change out pop-off on koomey unit and install new annular regulator and inspect saver sub (good) and continue build mud;Level derrick (remove one 1/2" shim on ODS leg ) House clean all work areas and continue build mud;Install wear ring and M/up BHA #1 Clean out drift run. Continue build mud and work boat;RIH with BHA #1 f/ 292' t/ 765', picking up 4" drill pipe joints (12). Monitor well on trip tank - good displacement. Continue build mud, work boat and off-load cement pods;Cont. to RIH with BHA #1, cleanout assembly, f/ 765' and tag CIBP at 3539'. Monitor well on trip tank - good displacement. Continue build mud, work boat and off-load cement pods;Open and inspect suctions on mud pumps prior to beginning displacement to LSND. Continue to work boat and off-load cement pods;Displace well to 9.0 ppg LSND. 7.5 bpm, 700 psi. Wash and tag top of CIBP while displacing.;POOH with BHA #1, standing back drill pipe. Lay down bit, and scraper assembly. Monitor well on trip tank. Clean and clear rig floor.;Slip and cut drill line - cut 130' of 1-3/8" drill line. Remove and replace hose from load cell to weight indicator. Service top drive, drawworks and rig floor equipment.;Pressure test 7" casing to 2100 psi for 30 charted min.;Make up Whipstock / window milling assembly per WIS representative. Shallow test MWD tools and make up mills to whipstock. 7/16/2022 Finish Make up Whipstock / window milling assembly per WIS representative.;Rih slow 3 min std w/ whip stock assy on 4" dp out derrick t/ 3485' and fill pipe, monitoring well on trip tank w/ proper displacement;Brk circ @ 250 gom @ 850 psi and orient rih and trip and set whipstock off CIBP @ 3539' @ 21R HS and shear off. Up/Dn 103/98k;Calibrate flow sensor and align surface equipment for milling operations;Mill window in 7" as per WIS rep f/ 3520' t/ 3530' + 31' of new hole to 3561' at 250 gpm, 800 psi, 100 rpm, 3-5k Torque;Circulate 30 bbl High-vis sweep at 250 gpm, 800 psi. MW in/out = 9.0 ppg;Rig up and perform FIT. Top of window at 3520' MD, 3047' TVD, MW in/out = 9.0 ppg. Pressure up to 935 psi for an FIT 14.9 ppg EMW . Monitor OA during FIT - No pressure.;Rig down test equipment, flow check well - static and pump slug for pulling out of the hole.;Pull out of the hole and lay down milling assembly f/3520'. Lead mill 1/8" under, follow mill 1/8" under, and gage mill 1/16" under.;Make up stack flushing tool and flush stack, choke and kill lines.;Clean and clear rig floor. Service top drive and rig floor equipment.;Make up BHA #3, 6-1/8" drilling assembly per DD / MWD. 6-1/8" Smith X516, 1.5° Motor, and slimmed down MWD tool suite (DM, GM and TM HOC) to 528'. Shallow test MWD tools - good. Perform kick while tripping drill with rig crew - well secured at 1min 55 sec.;Trip in the hole with BHA #3 on 4" drill pipe stands out of the derrick f/528' to top of window. Orient motor at 3500' prior to exiting window. Slide through window with no issues.;Drill 6-1/8" hole per DD and wp04 f/ 3561' t/ 3625' (64' at 32 fph ave ROP) 254 gpm, 919 psi, 80 rpm, 5k tq, 95k up, 90k dn, 95k rot MW in/out = 9.0 ppg;Drilling - Inlet Water Use and Discharge Summary (bbls) Inlet Water Used Today: 254 Inlet Water Used Cumulative: 630 Discharge Today: 2 Discharge Cumulative: 2 Daily down hole loss: 0 Total down hole loss: 0;Metals Recovery (lbs) Today: 51.5 Cumulative: 51.5 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-11A North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00028 NCIU A-11A Drilling Spud Date: ;Rig up and perform FIT. p pp Slide through window with no issues.;Drill 6-1/8" hole per DD and wp04 f/ 3561' t/ 3625' ff ;Mill window in 7" as per WIS rep f/ 3520' t/ 3530' + 31' of p new hole to 3561' gp p p q g p gp p Top of window at 3520' MD, 3047' TVD, MW in/out = 9.0 ppg. Pressure up to 935 psi for an FIT 14.9 ppg EMW . ppg Monitor OA during FIT - No pressure. gp p pyppp rih and trip and set whipstock off CIBP @ 3539' @ 21R HS and fpp @@g shear off. 7/17/2022 Drill 6-1/8" directional hole per DD and wp04 f/ 3625' t/ 3896' (271' at 45.1fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 258 gpm, 980 psi, 80 rpm, 5k tq, 103k up, 95k dn, 98k rot MW in/out = 9.0 ppg;Drill 6-1/8" directional hole per DD and wp04 f/ 3896' t/ 4113' (217' at 36.2fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas. 258 gpm, 980 psi, 80 rpm, 5k tq, 103k up, 95k dn, 98k rot. MW in/out = 9.0 ppg. Max gas = 7 units;Pump 20 bbl high vis sweep around while drilling @ 4040' back 10 late w/ no increase. started notice seepage losses @ 4013' pump around 15 bbl 60 ppb LCM pill;Drill 6-1/8" directional hole per DD and wp04 f/ 4113' t/ 4394' (281' at 46.8fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 254 gpm, 975 psi, 80 rpm, 4k tq, 2-3k wob, 110k up, 99k dn, 105k rot MW in/out = 9.0 ppg Max gas = 13 units;Drill 6-1/8" directional hole per DD and wp04 f/ 4394' t/ 4665' (271' at 45.2fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 258 gpm, 1053 psi, 80 rpm, 5-6k tq, 2-3k wob, 110k up, 95k dn, 105k rot MW in/out = 9.0 ppg Max gas = 39 units;F/ 4400' t/ 4485': dynamic loss rate increased to 4.5 bph. Did not treat and losses healed after 4485'. Swap from MP #2 to MP #1 at 4501' - swab on MP #2. Pump 20 bbl high-vis sweep at 4522': 4 bbls late with 5-10% increase in cuttings. Distance to wp04, 10.44' (8.26' High, 6.39' Right);Drilling - Inlet Water Use and Discharge Summary (bbls) Inlet Water Used Today: 314 Inlet Water Used Cumulative: 944 Discharge Today: 65 Discharge Cumulative: 67 Daily down hole loss: 20 Total down hole loss: 20;Metals Recovery (lbs) Today: 49.5 Cumulative: 101 CSG pressures at 11:30: IA = 110 psi, OA = 0 psi CSG pressures at 23:30: IA = 120 psi, OA = 0 psi 7/18/2022 Continue Drill 6-1/8" directional hole per DD and wp04 f/ 4665'' t/ 4768' (103' at 34.3fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 258 gpm, 1053 psi, 80 rpm, 5-6k tq, 2-3k wob, 112k up, 98k dn, 105k rot MW in/out = 9.0 ppg Max gas = 39 units;Circ btm up 250 gpm @ 1020 psi while rotating and reciprocating pipe full std and spot 36 bbl pill of 60 ppb LCM just out of bit to cover +- 989' open hole;Flow chk well static Pooh short trip wet on elevators f/ 4768' t/ 3452' just in side window w/ no issues monitoring well on trip tank for w/ proper displacement;Service traveling equipment clean and chk flow paddle and recalibrate same. Chg out shaker screens on platform shakers and adjust actuator arms for TDS IBOP shifting sleeve. while monitoring static well w/ 3 bph loss rate;Rih slow short trip on elevators w/ no issues wash last std to btm @ 4768' and stage up pump rate and warm mud;Resume Drilling 6-1/8" directional hole per DD and wp04 f/ 4768' t/ 5149' (381' at 40.1fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 250 gpm, 1050 psi, 80 rpm, 4k tq, 2-3k wob, 113k up, 100k dn, 105k rot MW in/out = 9.0 ppg Max gas = 35 units;4860' Trouble getting survey with MWD, Swap to MP3. Troubleshoot MP1 & MP2 and clean suction headers.;Resume Drilling 6-1/8" directional hole per DD and wp04 f/ 5149' t/ 5420' (271' at 45.2fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 254 gpm, 1152 psi, 80 rpm, 6.5k tq, 2-6k wob, 115k up, 100k dn, 105k rot MW in/out = 9.0 ppg Max gas = 76 units;Distance to wp04, 0.21' (0.18' High, 0.11' Left);Drilling - Inlet Water Use and Discharge Summary (bbls) Inlet Water Used Today: 16 Inlet Water Used Cumulative: 960 Discharge Today: 28 Discharge Cumulative: 95 Daily down hole loss: 15.5 Total down hole loss: 35.5;Metals Recovery (lbs) Today: 8.5 Cumulative: 109.5 CSG pressures at 8:00: IA = 100 psi, OA = 0 psi CSG pressures at 23:15: IA = 120 psi, OA = 0 psi Continue Drill 6-1/8"directional hole per DD and wp04 f/ 4665'' t/ 4768' Drill 6-1/8"directional hole per DD and wp04 f/ 3625' t/ 3896' started notice seepage losses @ 4013' pump aroundg 15 bbl 60 ppb LCM pill; losses healed after 4485'. spot 36 bbl pill of 60 ppb LCM just out of bit to cover +- g 989' open hole; ;Resume Drilling 6-1/8"gggy directional hole per DD and wp04 f/ 5149' t/ 5420' gp p ;Resume Drilling 6-1/8"directional hole per DD and wp04 f/ 4768' t/ 5149' pq p ;Drill 6-1/8" directional hole per DD and wp04 f/ 3896' t/ 4113' g ;Drill 6-1/8" directional hole per DD and wp04 f/ 4394' t/ 4665' pg p g@ ;Drill 6-1/8" directional hole per DD and wp04 f/ 4113' t/ 4394' ; 7/19/2022 Resume Drilling 6-1/8" directional hole per DD and wp04 f/5420' t/5589' (169' at 28.1fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 250 gpm, 1190 psi, 80 rpm, 6.5k tq, 2-6k wob, 120k up, 100k dn, 108k rot. Added lube @ 1% MW in/out = 9.0 ppg Max gas = 71 units;Resume Drilling 6-1/8" directional hole per DD and wp04 f/5589' t/5712' (169' at 28.1fph ave ROP) control drilling @ 65fph max back reaming conn x2 and slide areas 250 gpm, 1190 psi, 80 rpm, 6.5k tq, 2-6k wob, 120k up, 100k dn, 108k rot MW in/out = 9.0 ppg Max gas = 59 units;Pumped 20 bbl Hi-Vis sweep. 250 gpm, 1100 psi. Sweep returned on time with 5% increase in cuttings. Spot 60bbl 40ppb LCM pill on bottom;POOH F/5712' T/3358' didn't have any tight area's on the way out of the hole monitored well at shoe.;Pumped 20bbl 2ppg over Dry job;POOH F/3358' T/93' monitored well @ HWDP;LD BHA#3 As per DD. DD graded bit and determined it was in gauge and good to run back in hole.;PU and MU BHA#4 Halliburton Triple Combo Drilling assy T/115' shallow hole test tools with 250gpm 800 psi good test. Load Radioactive Sources .;RIH F/115' T/1146' w/BHA#4 pu 65k sow 65k;Distance to wp04, = 9.07' (8.47' High, 3.24' Left);Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 16 Inlet Water Used Cumulative: 976 Discharge Today: 31.5 Discharge Cumulative: 126.5 Daily down hole loss: 15 Total down hole loss: 50.5;Metals Recovery (lbs) Today: 3 Cumulative: 112.5 CSG pressures at 8:00: IA = 100 psi, OA = 0 psi CSG pressures at 23:15: IA = 120 psi, OA = 0 psi 7/20/2022 Cont. RIH w/6-1/8" Triple combo BHA#3 f/1146' t/5672', wash down last std t/5712'. No issues going thru the window or other wise.;Drill/Slide as per wp04/DD f/5712' t/5781', double backream each std and sweep hole every 500' or as needed. p/u=120k, s/o=100k, rot=108k, 80rpm, 5k trq, 250gpm, 1190psi, 3-4k wob.;Drill/Slide as per wp04/DD f/5781 t/6070', double backream each std and sweep hole every 500' or as needed. p/u=120k, s/o=100k, rot=108k, 80rpm, 5k trq, 250gpm, 1190psi, 3-4k wob.;Drill/Slide as per wp04/DD f/6070' t/6328', double backream each std and sweep hole every 500' or as needed. p/u=125k, s/o=100k, rot=105k, 80rpm, 5k trq, 250gpm, 1550psi, 3-4k wob.;Drill/Slide as per wp04/DD f/6328' t/6572', double backream each std and sweep hole every 500' or as needed. p/u=130k, s/o=98k, rot=108k, 80rpm, 5k trq, 250gpm, 1550psi, 3-4k wob.;Annulus pressures @ 0930hrs= OA=0psi, IA=110psi Annulus pressures @ 2300hrs= OA=0psi, IA=160psi;Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 25 Inlet Water Used Cumulative: 1001 Discharge Today: 46 Discharge Cumulative: 172.5 Daily down hole loss: 15 Total down hole loss: 65.5;Metals Recovery (lbs) Today: 5 Cumulative: 117.5 7/21/2022 Cont. drill/slide as per wp04/DD f/6572’ t/6673’ , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=135k, s/o wt=105k, rot wt=112k, 250gpm, 1550psi, 80rpm, 5k trq, 3k WOB.;Cont. drill/slide as per wp04/DD f/6673’ t/6894' , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=135k, s/o wt=105k, rot wt=112k, 250gpm, 1550psi, 80rpm, 5k trq, 3k WOB. Increase lube to 2% to help with slides.;Pumped 20bbl high vis sweep came back 100 stks early and 0% increase at shakers. obtained SPR's, Spot 30bbl LCM pill on bottom and chased w/ 10bbls;Monitored well for 10mins Short Trip POOH on elevators F/6874' to 5700' max over pull was 20k and it fell right off.;RIH F/5700' t /6800' puw =135k sow=100k washed last stand to bottom no fill;Cont. drill/slide as per wp04/DD f/6894’ t/7080' , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=138k, s/o wt=108k, rot wt=115k, 250gpm, 1700psi, 80rpm, 5-6k trq, 1-2k WOB. Increase lube to 2% to help with slides.;Annulus pressure @ 11:30hrs: OA=0psi, IA= 120psi;Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 48 Inlet Water Used Cumulative: 1049 Discharge Today: 42 Discharge Cumulative: 214.5 Daily down hole loss: 32.3 Total down hole loss: 97.8;Metals Recovery (lbs) Today: 0 Cumulative: 117.5 qp Spot 30bbl LCM pill on bottom and chased w/ 10bbls; p sweep hole every 500' or as needed. p sweep hole every 500' or as needed. ;Drill/Slide as per wp04/DD f/6070' t/6328', gp sweep hole every 500’ or as needed, g ;Resume Drilling 6-1/8" directional hole per DD and wp04 f/5589' t/5712' Spot 60bbl 40ppb LCM pill on g bottom; p sweep hole every 500’ or as needed, Cont. drill/slide as per wp04/DD f/6572’ t/6673’ ;Cont. drill/slide as per wp04/DD f/6894’ t/7080' , p sweep hole every 500' ;Drill/Slide as per wp04/DD f/5781 t/6070', ;Drill/Slide as per wp04/DD f/5712' t/5781', or as needed. ;Drill/Slide as per wp04/DD f/6328' t/6572', Resume Drilling 6-1/8" directional hole per DD and wp04 f/5420' t/5589' p ;Cont. drill/slide as per wp04/DD f/6673’ t/6894' 7/22/2022 Cont. drill/slide as per wp04/DD f/7080' t/7234' , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=139k, s/o wt=105k, rot wt=115k, 258gpm, 1800psi, 80rpm, 5-6k trq, 4k WOB. 9.1ppg in/out, 43vis, 10.36ECD. Preformed MAD pass through each slide @250fph Function tested all BOPE but B.R;Cont. drill/slide as per wp04/DD f/7234' t/7300' , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=139k, s/o wt=105k, rot wt=115k, 258gpm, 1800psi, 80rpm, 5-6k trq, 4k WOB. 9.1ppg in/out, 43vis, 10.36ECD. Preformed MAD pass through each slide @250fph;Cont. drill/slide as per wp04/DD f/7234' t/7300' , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=139k, s/o wt=105k, rot wt=115k, 258gpm, 1800psi, 80rpm, 5-6k trq, 4k WOB. 9.3ppg in/out, 43vis, 10.36ECD. Preformed MAD pass through each slide @250fph;Cont. drill/slide as per wp04/DD f/7515' t/7690' , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=140k, s/o wt=110k, rot wt=122k, 250gpm, 1900psi, 80rpm, 5-6k trq, 3k WOB. 9.1ppg in/out, 42vis, 10.31ECD. Preformed MAD pass through each slide @250fph;Dumped 200bbl of 9.3ppg mud overboard and diluted the system with 145bbls of new 8.6ppg new mud to get the ECD's and mud weight back down.;Annulus psi @09:30hrs: IA=175psi, OA=0psi Annulus psi @23:00hrs: IA=160psi, OA=0psi Metals Recovery (lbs) Today: 8 Cumulative: 125.5;Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 50 Inlet Water Used Cumulative: 1099 Discharge Today: 66.6 Discharge Cumulative: 281.1 Daily down hole loss: 30 Total down hole loss: 127.8 7/23/2022 Cont. drill/slide as per wp04/DD f/7690' t/7944'TD , dbl backream stds and sweep hole every 500’ or as needed, p/u wt=160k, s/o wt=112k, rot wt=122k, 250gpm, 1810psi, 80rpm, 6-7k trq, 4k WOB. 9.1ppg in/out, 41vis, 10.68ECD. Preformed MAD pass through each slide @250fph;Circ. B/U, pump 26bbl Hi-vis sweep w/walnut marker, came back 60stks late(1%).;Monitor well f/10 min.- static. POOH f/7944' t/ TOW 3520'.;clean rig floor up from wet trip.;Service Rig TD, DW, crown, ST-80, and inspect handling equip;RIH F/3501' T/ 4200';Preform MAD pass F/4200' to 5700' @ 360fph , 250 gpm, 1550 psi , 50 rpm,;RIH on elevators F/5700 T/7944'. washing last stand down noticed fill at 7926' PUW=160 SOW=115;Circ BUS, pump sweep w/marker, Drop steel rabbit w/100’ wire tail PUW=160k SOW=115k RTW=122k;Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 70 Inlet Water Used Cumulative: 1169 Discharge Today: 232 Discharge Cumulative: 513.1 Daily down hole loss: 14 Total down hole loss: 141.8;Metals Recovery (lbs) Today: 0 Cumulative: 125.5 7/24/2022 cont. circ. hi-vis sweep around with walnut marker, sweep came back on strokes.;Monitor well f/10min.-static. Drop 1.875" steel rabbit w/100' wire tail. Pooh f/7944" t/3409'. no issues. monitoring fill on TT.;Monitor well f/10min.-static. Pump slug and Pooh f/3409' t/115', monitoring fill on the TT.;Pre-job and un-loading radio-active sources, down load MWD data. Break down smart tools as per Haliburton MWD/DD and l/d same.;Clean and clear rig floor. P/u cement head and install XO's and pup jts, lay down same.;P/u Parker casing 4.5" liner handling tools and r/u floor , m/u floor valve on liner XO.;PU and MU shoe track and baker lock shoe track connections, RIH w/ 4.5'' liner t/3493' Filling pipe on the fly going in the hole;Circ BUS @ 3493';RIH w/ 4.5'' liner f/3493' t/4610' Filling pipe on the fly going in the hole;PU and MU Baker setting sleeve as per Baker rep. CO elevators and MU first stand of 4'' DP;circ 1.5X string volume @ 210 gpm and 440 psi;RIH w/ 4'' DP f/4737' t/7500';Annulus pressure@ 10:00hrs: OA=0psi, IA=170psi;Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 0 Inlet Water Used Cumulative: 1169 Discharge Today: 0 Discharge Cumulative: 513.1 Daily down hole loss: 0 Total down hole loss: 141.8;Metals Recovery (lbs) Today: 0 Cumulative: 125.5 7/25/2022 Cont. run 4.5” liner as per wp04/Baker rep. f/7500’ t/7938’. monitoring displacement on the TT.;p/u cement head, manifold and HP hoses and r/u same. Monitoring on TT..;Break circ. and stage up t/5bpm, 1120psi attempt to work pipe with no success, confer with Engineer-decision made to circ./condition mud while working pipe, until 9.3ppg in/out and cement at current depth of 7938'.;Hold pre-job w/cementers and cement liner as per wp04/Haliburton cementers; flood lines and PT t/5k psi-good, pmp approx.. 25bbl 10.5# spacer @5bpm, pmp 117bbl 15.3# cement @5bpm, shut dwn /wash up and drop plug.;Displace cement @5bpm 107bbl 9.3# mud, plug latched @37bbl (+3bbl), recalculated displacement t/107.5bbls, plugged bumped at 107bbl @3bpm. Pressure up t/4200psi, check floats-good. (cement in place @1240hrs);Line up t/rig pumps and release f/setting sleeve as per Baker Rep.. P/U 30’+- w/800psi catch pressure as it bleeds off and circ. b/u x2…no cement or spacer t/surface. Flow had dropped off slightly during the whole job f/7.1% t/6.6%, approx. 45bbl estimated loss.;R/D cement head and manifold, L/D same, wash thru all lines.;POOH f/3273' t/37', L/D running tool. monitoring fill on the TT.;service rig;P/U polish mill as per Baker Rep. and TIH t/3230';Kellyed up @ 3230' washed down to 3317' tagged on no go. Polish the seal bore assy as per baker rep. f3317' t/ TOL @ 3308'. gpm=175, psi=300, rpm=30 Picked up to 3275' and circ'd BUS;POOH with Polish mill assy;Wait on weather. High winds of 52 MPH not allowing for crane use to PU the LTP tools. Cleaned and serviced rig while waiting on weather.;Drilling - Inlet Water Use and Discharge Summary (bbl) Inlet Water Used Today: 0 Inlet Water Used Cumulative: 1169 Discharge Today: 46.5 Discharge Cumulative: 559.6 Daily down hole loss: 0 Total down hole loss: 141.8;Metals Recovery (lbs) Today: 0 Cumulative: 125.5 OA=0psi IA=120psi @ 23:00 ppg p p j p p pmp approx.. 25bbl 10.5# spacer @5bpm, pmp 117bbl 15.3# cement @5bpm, shut dwn /wash up and drop plug.;Displace cement p g pppp p @ p pp @ p @5bpm 107bbl 9.3# mud, plug latched @37bbl (+3bbl), recalculated displacement t/107.5bbls, plugged bumped at 107bbl Cont. run 4.5” liner as per wp04/Baker rep. f/7500’ t/7938’. Cont. drill/slide as per wp04/DD f/7690' t/7944'TD circ. b/u(p@)pgpp gp p pp x2…no cement or spacer t/surface. Flow had dropped off slightly during the whole job f/7.1% t/6.6%, approx. 45bbl estimated loss. gg RIH w/ 4.5'' liner t/3493' Filling pipe on the fly going in the hole; sweep hole every 500’ or as needed, p p q ppg ;Cont. drill/slide as per wp04/DD f/7515' t/7690' sweep hole every 500’ or as needed, gg Polish the seal bore assy as per baker rep. sweep hole every 500’ or as needed, No liner cement returns to surface. They estimated 45 bbls were lost. Cont. drill/slide as per wp04/DD f/7080' t/7234' @p ;Cont. drill/slide as per wp04/DD f/7234' t/7300' backream stds and sweep hole every 500’ or as needed, ;RIH w/ 4.5'' liner f/3493' t/4610' Filling pipe on the fly going in the hole; TD'd @7944' MD. -WCB 7/26/2022 Continue to wait on weather. High winds not allowing for crane use to PU the LTP tools. Cleaned and serviced rig while waiting on weather.;Make up Baker ZXP LTP packer and running tool assembly and run in the hole on stands of 4" drill pipe to 3262'. Monitor well on trip tank while running in.;Make up top drive and tag LTP no-go on liner top at 3317' (9' of seal assembly puts LT on depth at 3308'). Pressure up to 200 psi and pick up. Pressure dropped off at 3308'. Drop 1" setting ball and pump down to seat - landed at 313 stks. Slack off to no-go and pressure up to set LTP.;LTP set at 2787 psi and neutralized and ball sheared at 3843 psi. Bleed off pressure and set down 20k lbs. Rotated 15 turns to the right with no torque. Pick up and verify off LTP. Pressure test LTP to 2150 psi for 10 min - good test. Rig down test equipment.;Pull out of the hole and lay down liner running tool. Monitor well on trip tank while pulling out.;Pull wear ring.;R/U Parker casing tools to run 4.5" 12.6# L-80 IBT completion tbg. M/U Floor valve on XO's f/tbg. Pre-job.;P/U seal assy w/no-go, run 4.5" 12.6# IBT tbg f/surface t/ 2921', P/U Baker S-5 SSSV (1800psi open pressure) and M/U same, Pollard install control line and test t/5k-good, confirm open/close function.;Cont. Run 4.5" 12.6# tbg w/ control line f/2940' t/3286', land out on No-Go, re-confirmed. pulled up 4 jts and spaced out for 2' off the No-go (p/u 4 pup jts 1.35, 5.93, 9.47, 9.75=26.5') and last jt #13 before the hanger.;Installed hanger, control line thru same and test t/4200psi-good, verify valve opens @2600psi. Slack off and sting into seals. (note 12ea. stainless bands installed on control line);Pressure up tbg t/500psi and pull up on seals until pressure dropped at circ. ports approx. 6ft. Displace well w/clean FIW @6.5bpm and 400psi until clean fluid back, approx. 525bbl. Displace well w/inhibited drill H2O @6.5bpm and 350psi,126bbl.;Simop- r/u to pump out stack and test annulus.;Metals Recovery (lbs) Today: 0 Cumulative: 125.5 Annulus pressure@2300hrs: IA-130psi, OA=0psi;Inlet Water Used Today: 425 Inlet Water Used Cumulative: 1594 Discharge Today: 0 Discharge Cumulative: 559.6 Daily down hole loss: 0 Total down hole loss: 141.8 7/27/2022 Pump out stack and land hanger. Run in all lock down screws per Vault rep. Line up and pressure test tubing to 2190 psi for 30 min monitoring open IA during test. Line up and pressure test 7" x 4-1/2" IA to 2100 psi for 30 charted min - good tests;Rig down test equipment. Back out and lay down landing joint. Install TWC per Vault rep. Clean and clear rig floor of all tubing handling equipment.;Niple down bell nipple, 13-5/8" BOPE stack and high pressure riser. Pull 13-5/8" 5M x 11" 3M DSA off of high pressure riser.;N/U tree and re-configure valves and bonnet per Productions request. Fill and test void t/300psi low and 5000psi high for 5min. each-good. Fill tree with and test same t/300psi low and 5000psi high f/5min.each-good.;clean and clear well room of test equipment and tools, Vault Rep.- pull TWC and install tree cap and secure tree. Rig released f/A-11A @0000hrs.;Inlet Water Used Today: 200 Inlet Water Used Cumulative: 1,794 Discharge Today: 772 Discharge Cumulative: 1,331.6 Daily down hole loss: 0 Total down hole loss: 141.8 Liner hanger set. pp g p gp g Line up and pressure test 7" x 4-1/2" IA to 2100 psi for 30 charted min - good tests; Pick up and verify off LTP.p Pressure test LTP to 2150 psi for 10 min - good test. ( Run 4.5" 12.6# tbg w/ control line ;Make up Baker gg ZXP LTP packer and running tool assembly and run in the hole on stands of 4" drill pipe to 3262'. tag LTP no-go on liner top at 3317' (9' of seal assembly puts LT on depth at 3308'). pgy pp Drop 1" setting ball and pump down to seat - landed at 313 stks. Slack off to no-go and gg p ( yp p pppp pp pressure up to set LTP.;LTP set at 2787 psi and neutralized and ballp sheared at 3843 psi.p pg Activity Date Ops Summary 8/6/2022 Move unit from A-09A and RU on A-11A. Pressure test Lube 200L/2500H, pass Open TRSSSV. RIH with 3.7" GR drift. Set down at 5,634'. Try to work tools deeper, but unsuccessful. POOH w tools, find gouge marks on GR.,RU slim tool string, Max OD 2-1/8". Sit down at 6150, 6180, 6225, 6295, 6360, 7550, 7560, 7597'. Final depth 7595. POOH, RDEL. 8/13/2022 Morning safety meeting. PTW. Unstab pipe. Restage equipment for A-11A. Stab pipe. Transfer drilling fluids to ISO tanks. MU riser and BOPs on well. Function test each set of rams and perform full body test to 250 psi and 3000 psi. MU BHA - .5'x1.75" CTC, .7'x1.69" DFCV, 1.753"x5.76" stinger, .7'x2.18" XO, 1.1"x3.72" JSN. OAL - 8.76'. MU lubricator and stab on well.,Open well and RIH. Transfer 240 bbls of drilling mud from OTT to 2 ISO tanks. Tag at 7557'. Jet down to 7567'. PUH to 7450' and shut down pump. Dry tag at 7586'. PUH 20' and circulate until drilling mud seen at the OTT. Shut down pump and transfer completion fluid from OTT to production. RIH and dry tag at 7620'. PUH to 7590' and come online with the pump. Jet down taking small bites to 7830', hard tag.,PUH to 7800' and circulate 15 bbls. POOH jetting to surface. Secure tree, lay down lubricator/injector and SDFN. 8/14/2022 Morning safety meeting. SLB crew loaned to Ivan River for some urgent pumping needs. Left at 0630 and returned at 1700. Crew that stayed fueled equipment, greased equipment and did general upkeep on tools etc.,Picked up injector head and 28' of lubricator. MU Yellowjacket 2-7/8" external grapple coiled tubing connector. Pull tested to 25k and PT to 3000 psi. Stabbed on the well. SDFN 8/15/2022 Morning safety meeting. PTW. Breakoff lub from BOPs. MU CBL BHA - 2-7/8" x .75' ctc, 2-7/8" x 1.2' DFCV, .5' XO, 26' HES CBL tools 1.69" x 26'. OAL - 28.5'. MU lubricator to BOPs. Fluid pack and pressure test. Open well and RIH. Stacked ~1000-1500 surface weight several time between 3500-7000'. Pumping down the CT seemed to help tools slide easier RIH. RIH to 7780'. Stopped for 5 min for time/depth log.,Transfer 160 bbls to ISO tanks from OTT. POOH at 45 fpm to 3000'. Pull to surface and break off HES tools. Verified good data. MU 3.72" JSN on YJ MHA. OAL - 6'. RIH for nitrogen blowdown. Tag at 7810'. OTT volume at 47 bbls. Begin pumping nitrogen at 1200 scfm. 162 bbls returned. This is near the expected amount (115 bbls). POOH. Pump OTT volume, ~160 bbls, to Tyonek.,Close the well. Break off and lay down lubricator. Break off tools except CTC. Lay down injector head. Install night cap on BOPs. SDFN. 8/24/2022 AK E-line conduct JSA and approve PTW. MU gun #1 and PT lubricator to 250/1500 psi.,RIH with Gun #1 (2-7/8" x 14'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga F Mid: 7623-7637'. Well is shut-in. Initial tubing pressure = 142 psi, 5 min = 165 psi, 10 min = 168 psi, 15 min = 167 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #2 (2-7/8" x 6'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga F Upper: 7597-7603''. Well is shut-in. Initial tubing pressure = 163 psi, 5 min = 163 psi, 10 min = 163 psi, 15 min = 162 psi. All shots fired. Bull plug was damp with a little sand.,RIH with Gun #3 (2-7/8" x 18'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga E Upper: 7451-7469'. Well is shut-in. Initial tubing pressure = 155 psi, 5 min = 155 psi, 10 min = 154 psi, 15 min = 154 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #4 (2-7/8" x 30'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga D Lower: 7410-7440'. Well is shut-in. Initial tubing pressure = 146 psi, 5 min = 146 psi, 10 min = 146 psi, 15 min = 146 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #5 (2-7/8" x 14'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga D Mid: 7356-7370'. Well is shut-in. Initial tubing pressure = 140 psi, 5 min = 140 psi, 10 min = 140 psi, 15 min = 139 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #6 (2-7/8" x 9'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga D Upper: 7317-7326'. Well is shut-in. Initial tubing pressure = 134 psi, 5 min = 133 psi, 10 min = 133 psi, 15 min = 133 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #7 (2-7/8" x 17'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga C Upper: 7173-7190'. Well is shut-in. Initial tubing pressure = 125 psi, 5 min = 188 psi, 10 min = 254 psi, 15 min = 278 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #8 (2-7/8" x 6'). Send correlation data to RE/GEO and confirm on depth. Perforate Beluga B Lower: 7133-7139'. Well is shut-in. Initial tubing pressure = 272 psi, 5 min = 274 psi, 10 min = 276 psi, 15 min = 276 psi. All shots fired. Bull plug on gun was dry.,Laydown lubricator and install night cap on wireline valves. Hand well over to production to test. SDFN. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-11A North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00028 NCIU A-11A Completion Spud Date: 8/25/2022 AK E-line hold TBT and approve PTW. Pick up lubricator and MU gun #9.,RIH with Gun #9 (2-7/8" x 12'). Send correlation data to RE/GEO, shift log 1' down. Perforate Beluga B Upper 2: 7022-7034'. Well is flowing. Initial tubing pressure = 246 psi, pressure dropped to 240 psi after shooting. All shots fired. Bull plug on gun was dry.,RIH with Gun #10 (2-7/8" x 20'). Send correlation data to RE/GEO, on depth. Perforate Beluga B Upper 1: 6974-6994'. Well is flowing. Initial tubing pressure = 249 psi, pressure increased to 253 psi after shooting.,After perforating with Gun #10, E-line became stuck while POOH at 6800'. Attempt to work wire with well flowing and shut-in up to 80% of weak point at 2650#, no success. Work wire up to 3500# and moved a total ~ 60'. Pump 3 bbls of methanol down well while shut-in.,Standby while E-line crew runs Gyro survey for Rig 151.,Start flowing well at ~ 2.4 MM scf/d and work wire. Toolstring came free. Having weight fluctuations and eventually lost all weight of toolstring ~ 3300'. Continue to POOH and recover all wire except for ~ 60'. Close SSSV, close swab, laydown lubricator and install night cap on wireline valves. E-line crew moved to Rig 151 for Gyro surveys *** Fish in hole ***Perforating BHA left in well with ~ 60' of wire *** 8/26/2022 Pollard slickline conduct JSA and approve PTW. Spot slickline equipment on deck. MU toolstring with 3.5" LIB. PU lubricator and wireline valves and stab onto E-line wireline valves. PT lubricator to 250/1500 psi.,RIH with 3.5" LIB and tag top of fish at 3298' slmd. POOH and LIB has impression of rope socket with wire attached. RIH with 3.73" blind box and push fish down to 4385'. Beat down to cut wire on top of rope socket and fish moved to 4389'. POOH. RIH with 3.5" LIB and tag top of fish at 4389'. POOH and LIB has clean rope socket with no wire.,RIH with overshot and latch fish at 4387' slmd. POOH and recover lost perforating BHA, but no wire. RIH with full gauge wire finder and spear. Tag at liner. POOH and recover 45' of wire. RIH with 3.79" gauge ring, having to work through tights spots, can't get deeper than 4211'. POOH. SDFN. 8/27/2022 Pollard slickline and AK E-line hold TBT and approve PTW. SL pick up lubricator and MU 3.75' gauge ring. Stab onto well.,Slickline set down at 7670' slmd with 3.75" gauge ring. POOH. Laydown toolstring and lubricator. RDMO.,AK E-line pick up lubricator and MU perforating toolstring (rope socket, gun gamma/ccl, shock sub, xo, firing head assembly, gun, bullnose).,RIH with Gun #11 (2-7/8" x 20'). Send correlation data to RE/GEO confirm on depth. Perforate Beluga A Lower: 6937-6957'. Well is shut-in. Initial tubing pressure = 754 psi, 5 min = 727 psi, 10 min = 707 psi, 15 min = 699 psi. All shots fired. Bull plug on gun was dry.,RIH with Gun #12 (2-7/8" x 14'). Send correlation data to RE/GEO confirm on depth. Perforate Beluga A Lower: 6923-6937. Well is shut-in. Initial tubing pressure = 692 psi, 5 min = 692 psi, 10 min = 691 psi, 15 min = 691 psi. All shots fired. Bull plug on gun was dry.,Hand well over to production to flow. RD E-line equipment. Depart platform. ! "## $%%&&## '() *) "+ ) ,- ) ) .) ./) 0+) !! "#$%$& 1) /)'() 0 ) "#$%$& ) * ( 0 *) 2 *) '( 03) * *) + ,#-./0 1 ,#-. 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Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: XO Hyd521 x DWC-C/HT Liner Top Packer Casing (Or Liner) Detail Shoe joints pup jt 5L-80 Rotate Csg Recip Csg Ft. Min. PPG9.3 Shoe @ 7941 FC @ Top of Liner 33087,853.00 Floats Held2150 Mud CASING RECORD County State Alaska Supv.Steve Dambacher Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NCIU A-11A Date Run 25-Jul-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Baker 1.80 7,941.00 7,939.20 3,325.31 3,324.10 3,618.38 6,948.44 3,330.06 3,330.064 1/2 12.6 L-80 DWC-C/HT 4.75 DWC-C/HT 4 1/2 12.6 L-80 DWC-C/HT Baker 3,325.31 4 1/2 12.6 L-80 1.21 5 x 7HRDE liner setting sleeve 5 3/4 L-80 DWC-C/HT 3,324.10 3,308.23 24.45 3,308.23 3,283.78 15.87 Csg Wt. On Hook:140 Type Float Collar:Baker No. Hrs to Run:12.5 9.2 5 82 477 FI R S T S T A G E 10.5Spacer 25 104/104 4200 0 Cement Unit 15.3 117 Bump press CBL Bump Plug? 12:40 7/25/2022 3,590 7,941.007,944.00 7,854.00 CEMENTING REPORT Csg Wt. On Slips: LSND Type of Shoe:Round nose float shoe Casing Crew:Parker Baker/5" HRD-E Liner Setting Sleeve www.wellez.net WellEz Information Management LLC ver_04818br 5 3 on shoe track, 1 every joint 107 and 1 on each of 2 RA jts=112 un-able too move string once we stopped and rigged up cement equipment @ 7941'. joint 4 1/2 12.6 L-80 BTC 41.43 7,939.20 7,897.77 Float Collar 5 L-80 BTC Baker 1.49 7,897.77 7,896.28 joint 4 1/2 12.6 L-80 BTC 41.44 7,896.28 7,854.84 Landing Collar 5 l-80 BTC Baker 1.07 7,854.84 7,853.77 joint 4 1/2 12.6 L-80 BTC X DWC 41.42 7,853.77 7,812.35 joints 4 1/2 12.6 L-80 DWC-C/HT 327.28 7,812.35 7,485.07 RA 4 1/2 12.6 L-80 DWC-C/HT 41.47 7,485.07 7,443.60 joints 4 1/2 12.6 L-80 DWC-C/HT 454.50 7,443.60 6,989.10 RA 4 1/2 12.6 L-80 DWC-C/HT 40.66 6,989.10 6,948.44 Type I / II 540 1.24 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW0RQGD\$XJXVW30 7R6KDQH+DXFN &F5HJJ-DPHV%2*& 6XEMHFW5(>(;7(51$/@$2*&&,QVSHFWLRQ)RUP&RQILUPDWLRQ(PDLO $WWDFKPHQWV(QWHUSULVH[OV[ ^ŚĂŶĞ͕ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĐŚĂŶŐŝŶŐƚŚĞƌŝŐŶĂŵĞƚŽƌĞĨůĞĐƚŶƚĞƌƉƌŝƐĞϭϱϭ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. 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Phone:907-776-7945 Rep.: E-Mail Well Name: PTD #22220130 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250 / 3000 Annular:250 / 3000 Valves:250 / 3000 MASP:1843 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5" 5M P Flow Indicator PP #2 Rams 1 Blind 5M P Meth Gas Detector PP #3 Rams 1 2-7/8" x 5" 5M P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/8" 5M P Inside Reel valves 0NA HCR Valves 2 3-1/8" 5M P Kill Line Valves 3 16" 10M & (1)3-1/P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3100 P CHOKE MANIFOLD:Pressure After Closure (psi)1800 P Quantity Test Result 200 psi Attained (sec)20 P No. Valves 13 P Full Pressure Attained (sec)184 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 2P Nitgn. Bottles # & psi (Avg.): 16 @ 2325 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:7.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7/13/22 9:29 AM Waived By Test Start Date/Time:7/15/2022 0:30 (date) (time)Witness Test Finish Date/Time:7/15/2022 8:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Enterprise All tests performed with 4" & 4.5" test joint. With no issues all gas heads tested good Check Pre-Charge: 15ea @15gal/bottle: 12 @1000 psi, 3 @990 psi = 998 psi ave Closing times: Annular 11 sec, Upper Rams 10 sec, Blind Rams 11 sec, Lower Rams 10 sec, HCR Choke 1 sec, HCR Kill 2 sec. Brian lafluer Hilcorp Hauck / Anderson NCIU A-11A Test Pressure (psi): shauck@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0715_BOP_Enterprise151_NCIU_A-11A +LOFRUS$ODVND//& 9 9 9 9 999 9 9 9 MEU - 5HJJ Closing times: Annular 11 sec, Upper Rams 10 sec, Blind Rams 11 sec, Lower Rams 10 sec, HCR Choke 1 sec, HCR Kill 2 sec. DATE:RIG # 151 TIME: Test #Low PSI High PSI Pass/ Fail 1 260 3050 Pass 2 270 3080 Pass 3 280 3140 Pass 4 310 3100 Pass 5 330 3150 Pass 6 300 3100 Pass 7 350 3100 Pass 8 305 3120 Pass 9 310 3120 Pass 10 2000 Pass Manifold Annular 1575 1080 1420 1140 20 184 12:30 AM HILCORP REP: S. Hauck / B. Anderson END TIME: 8:00 AM RIG SUPERVISOR: B. LaFlure / B. McGehee TEST TIME: 7.50 EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. 11 2 7/8''X5" Upper RamsFinal Pressure 200 psi Re-charge 3100 1800 10 10 Blind Rams 11 D. Durham 13-5/8" 5M Preventer Type Closing Time Lower Pipe Rams, IBOP 5 / 5 Choke step down test - Choke #12, 10, 9 (manual) 5 / 5 5 / 5 5 / 5 Upper Pipe Rams, IBOP, Kill HCR, Choke HCR CMV #11, 13, 14, 15, Body test #9, 10, 12 Upper Pipe Rams, Lower Kelly valve, Kill HCR, CMV #5, 6, 7, 8, 16 Upper Pipe Rams, FOSV #W530-2253, Kill Manual CMV #2, 4, 6, 7 4" Test Joint Lower Pipe Rams, FOSV #W530-2255 5 / 5 Contract Testing Representative Signature:Hilcorp Representative Signature: Rig Supervisor Signature: HILCORP BOP TEST SHEET TESTING COMPANY: DP SIZES:Enterprise 4" & 4.5" 7/15/2022 RIG CONTRACTOR: WELL NAME: 5 / 5Annular, Upper Kelly valve, Kill Valve #17,18 Minutes Held (Low/High) 00:30 - 08:00 NCIU A-11A Enterprise Offshore TYPE OF OPERATION - (DRILLING / WORKOVER / OTHER): Drilling Components Tested BOP SIZE & RATING:SUPERINTENDENT: AOGCC WITNESS: Waived by Jim Regg START TIME: Blind Rams, Kill Valve #18, CMV #3, 4, 7 4.5" Test Joint Annular, IBOP #W529-1826, Kill HCR, CMV #1 5 / 5 5 / 5 5 / 5 2 7/8''X5" Lower Rams16 @ 2325NO2 Bottle Avg. Full Recovery Upper Pipe Rams, IBOP, Kill HCR, Choke Manual Accumulator Test Accumulator Initial Pressure 13-5/8'' Annular -5HJJ HILCORP BOP TEST NOTES %23(7HVW (QWHUSULVH 1&,8$$ 37' -5HJJ %23(7HVW (QWHUSULVH 1&,8$$ 37' -5HJJ COMBUSTIBLE GAS DETECTION SYSTEMRig and Mud Pits - State Compliance TestingFACILITY NAME: Tyonek Platform Rig 151ROOM DESIGNATION: Rig, Shakers, Well RoomInstructions: Use this form to record combustible gas detector calibration data and alarm tests. Cal Gas Cal Gas Verify Gas-Free Applied Gas-Free Applied Sensativity Alarms atSensor Tag Name Faulted? Reading Reading Reading Reading With 50% 20 and 40%Or Location (%LEL) (%LEL) (%LEL) (%LEL) Gas Applied YES NORig Gas Detectors20 40 Yes20 40 Yes20 40 Yes20 40 Yes20 40 Yes20 40 YesYES NORIG H2S DETECTORS10 20 Yes10 20 Yes10 20 Yes10 20 Yes10 20 Yes10 20 YesNote: Comb gas used 50% LELH2S gas used 50ppm Conditions As LeftConditions As FoundVerifyAlarms at 10Cal Gas Cal GasNo000000NoFaulted?and 20 ppmGas-FreeReadingAppliedReadingGas-FreeReadingAppliedReadingNOTES:TECHNICIAN: Huntre lamb STATE INSPECTOR: Waived Date: Thurs 7/14/22 (PPM) (PPM) (PPM) (PPM)Rig Floor (Ch. 13)Well Room (Ch. 14)NoNoNoNoNoWell Room (Ch. 7)151 Pits (Ch. 8)Tyonek Shakers H2S (Ch.11)Rig Cellar (Ch.12)151 Pits (Ch. 1)151 Shakers (Ch. 3)Tyonek Shakers (Ch. 4)Rig Cellar (Ch. 5)Rig Floor (Ch.6)151 Shakers (Ch.10)No050%50%50%50%50%0 50%0000050%50%50%50%50%0 50%0000NoNoNoNo50%50% 050%50%50%50%50%0000050%50%50%50%50%-5HJJ David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: NCIA-11A PTD: 222-013 API: 50-883-20031-02-00 FINAL LWD FORMATION EVALUATION LOGS (07/16/2022 to 07/24/2022) x DGR, SLIM EWR-4, ALD, CTN (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. 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Plug Cement 04/24/2022 Please include current contact information if different from above. PTD:222-013 T36566 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.10 10:09:14 -08'00' From:McLellan, Bryan J (OGC) To:Sean McLaughlin Cc:Regg, James B (OGC); Monty Myers Subject:NCIU A-11A (PTD 222-013) Initial BOP test pressure Date:Wednesday, March 23, 2022 12:18:00 PM Sean, As you pointed out, the Initial BOP test pressure specified on the PTD Conditions of Approval for this well exceeds the rated working pressure of the wellhead equipment. The required BOP test pressures associated with this permit are reduced to 3000 psi (2500 psi for the annular) for both initial and subsequent tests. Thanks for catching that. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manger Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Cook Inlet Field, Tertiary Gas Pool, NCIU A-11A Hilcorp Alaska, LLC Permit to Drill Number: 222-013 Surface Location: 1302' FNL, 1023' FWL, Sec 6, T11N, R9W, SM, AK Bottomhole Location: 1772' FNL, 1284' FWL, Sec 31, T12N, R9W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of February, 2022. 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OHDVWSSJKLJKHUWKDQWKHHVWLPDWHGUHVHUYRLUSUHVVXUHDQGDOORZLQJIRUDQDSSURSULDWHDPRXQWRINLFN WROHUDQFHLQFDVHZHOOFRQWUROPHDVXUHVDUHUHTXLUHG :KHUHUHTXLUHGWKH/27LVSHUIRUPHGLQWKHVDPHIDVKLRQDVWKHIRUPDWLRQLQWHJULW\WHVW,QVWHDGRI VWRSSLQJDWDSUHGHWHUPLQHGSRLQWVXUIDFHSUHVVXUHLVLQFUHDVHGXQWLOWKHIRUPDWLRQEHJLQVWRWDNHIOXLG DWWKLVSRLQWWKHSUHVVXUHZLOOFRQWLQXHWRULVHEXWDWDVORZHUUDWH7KHV\VWHPLVVKXWLQDQGSUHVVXUH PRQLWRUHGDVZLWKDQ),7 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 &KRNH0DQLIROG6FKHPDWLF 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 &DVLQJ'HVLJQ,QIRUPDWLRQ 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 ´+ROH6HFWLRQ0$63 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 6ORW'LDJUDP 3DJH5HYLVLRQ-DQXDU\ NCI A-11A PTD Rev 0 'LUHFWLRQDO3URJUDPZS$WWDFKHGVHSDUDWHO\ !"" # ! # !$ $ 3025330035753850412544004675495052255500True Vertical Depth (550 usft/in)825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225 5500 5775 6050Vertical Section at 3.00° (550 usft/in)NCI A-11A wp04 top Beluga35004000450050005500600065007000A-117" Casing TOW4 1/2" x 6 1/8"3500400045005000550060006500700075007944NCI A-11A wp04KOP 12.3º/100' : 3500' MD, 3032.04'TVD : 15° RT TFEnd Dir : 3517' MD, 3044.4' TVDStart Dir 4º/100' : 3537' MD, 3058.7'TVDEnd Dir : 4048.75' MD, 3356.62' TVDStart Dir 4º/100' : 6478.37' MD, 4418.57'TVDEnd Dir : 7744.46' MD, 5374' TVDTotal Depth : 7944.46' MD, 5568.52' TVDTop Beluga BBase Beluga HHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: NCIU A-11Water Depth: 99.00+N/-S +E/-W Northing EastingLatitudeLongitude0.00 0.00 2586677.01 332041.75 61° 4' 35.863 N150° 56' 54.657 WSURVEY PROGRAMDate: 2021-08-18T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool103.33 1053.33 NCIU A-11 2008 Gyro (NCI A-11) 3_Gyro-CT_Csg+Cent1109.63 3500.00 N COOK INLET UNIT A-11 (NCI A-11) 3_CB-Film-GSS3500.00 3900.00 NCI A-11A wp04 (NCI A-11A) 3_MWD_Interp Azi+Sag3900.00 7944.46 NCI A-11A wp04 (NCI A-11A) 3_MWD+AX+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation4609.63 4483.00 6830.44 Top Beluga B5384.63 5258.00 7755.39 Base Beluga HREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: NCIU A-11, True NorthVertical (TVD) Reference:NCIU A-11 @ 126.63usftMeasured Depth Reference:NCIU A-11 @ 126.63usftCalculation Method: Minimum CurvatureProject:North Cook InletSite:North Cook Inlet UnitWell:Plan: NCIU A-11Wellbore:NCI A-11ADesign:NCI A-11A wp04CASING DETAILSTVD TVDSS MD Size Name3032.04 2905.41 3500.00 7 7" Casing TOW5568.52 5441.89 7944.46 4-1/2 4 1/2" x 6 1/8"SECTION DETAILSSecMD Inc Azi TVD +N/-S +E/-W Dleg TFace VSectTargetAnnotation1 3500.00 42.35 358.15 3032.04 1389.74 -64.39 0.00 0.00 1384.46 KOP 12.3º/100' : 3500' MD, 3032.04'TVD : 15° RT TF2 3517.00 44.37 358.92 3044.40 1401.40 -64.68 12.30 15.00 1396.10 End Dir : 3517' MD, 3044.4' TVD3 3537.00 44.37 358.92 3058.70 1415.39 -64.95 0.00 0.00 1410.05 Start Dir 4º/100' : 3537' MD, 3058.7'TVD4 4048.75 64.08 5.82 3356.62 1827.64 -44.77 4.00 17.99 1822.79 End Dir : 4048.75' MD, 3356.62' TVD5 6478.37 64.08 5.82 4418.57 4001.63 176.76 0.00 0.00 4005.40 Start Dir 4º/100' : 6478.37' MD, 4418.57'TVD66830.44 50.00 6.00 4609.63 4294.73 207.06 4.00 179.43 4299.68 NCI A-11A wp04 top Beluga7 7744.46 13.44 6.00 5374.00 4764.59 256.44 4.00 180.00 4771.48 End Dir : 7744.46' MD, 5374' TVD8 7944.46 13.44 6.00 5568.52 4810.82 261.30 0.00 0.00 4817.90 Total Depth : 7944.46' MD, 5568.52' TVD 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 South(-)/North(+) (400 usft/in)-1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 West(-)/East(+) (400 usft/in) NCI A-11A wp04 top Beluga A-11 7" Casing TOW 4 1/2" x 6 1/8" 2750 300 0 3250 3500 3750 4000 4250 4500 4750 5000 5250 55005569 NCI A-11A wp04 KOP 12.3º/100' : 3500' MD, 3032.04'TVD : 15° RT TF End Dir : 3517' MD, 3044.4' TVD Start Dir 4º/100' : 3537' MD, 3058.7'TVD End Dir : 4048.75' MD, 3356.62' TVD Start Dir 4º/100' : 6478.37' MD, 4418.57'TVD End Dir : 7744.46' MD, 5374' TVD Total Depth : 7944.46' MD, 5568.52' TVD CASING DETAILS TVD TVDSS MD Size Name 3032.04 2905.41 3500.00 7 7" Casing TOW 5568.52 5441.89 7944.46 4-1/2 4 1/2" x 6 1/8" Project: North Cook Inlet Site: North Cook Inlet Unit Well: Plan: NCIU A-11 Wellbore: NCI A-11A Plan: NCI A-11A wp04 WELL DETAILS: Plan: NCIU A-11 Water Depth: 99.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2586677.01 332041.75 61° 4' 35.863 N 150° 56' 54.657 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: NCIU A-11, True North Vertical (TVD) Reference:NCIU A-11 @ 126.63usft Measured Depth Reference:NCIU A-11 @ 126.63usft Calculation Method:Minimum Curvature % & " ' ()* ' + +, - .# ! 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" # !! $ $ $ $$ " # !! " # !! $ " # !! $ " # !! $ $ $ " # !! $ $ " # !!%%% $$ $$ " # !!% & & $$ $$ " # !!# "' $ ! " # !!# "' $ $ $$ $ " # !! =. )0@. )0 -C! -@ () *(!+," (%- . (/01(" 2, + $ . (/01,3, + )!" ## # '( ! -! !!!4 5)""! "!6 4 ! "7."!! 4 !!" !4 8 ! " 91! "%."# 8!:;1! "%."# 8! ! "<1! "%."" !!6! +6"! "7.".7 " !! " " !. 4 4!"+6/"-4-4 5 4 -6 0.001.002.003.004.00Separation Factor3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250Measured Depth (500 usft/in)A-05A-11A-05A-11No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: Plan: NCIU A-11 NAD 1927 (NADCON CONUS) Alaska Zone 04Water Depth:99.00+N/-S+E/-W NorthingEastingLatitudeLongitude0.000.002586677.01332041.7561° 4' 35.863 N 150° 56' 54.657 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: NCIU A-11, True NorthVertical (TVD) Reference: NCIU A-11 @ 126.63usftMeasured Depth Reference:NCIU A-11 @ 126.63usftCalculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name3032.04 2905.41 3500.00 7 7" Casing TOW5568.52 5441.89 7944.46 4-1/2 4 1/2" x 6 1/8"SURVEY PROGRAMDate: 2021-08-18T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool103.33 1053.33 NCIU A-11 2008 Gyro (NCI A-11) 3_Gyro-CT_Csg+Cent1109.63 3500.00 N COOK INLET UNIT A-11 (NCI A-11) 3_CB-Film-GSS3500.00 3900.00 NCI A-11A wp04 (NCI A-11A) 3_MWD_Interp Azi+Sag3900.00 7944.46 NCI A-11A wp04 (NCI A-11A) 3_MWD+AX+Sag0.0040.0080.00120.00160.00200.00Centre to Centre Separation (80.00 usft/in)3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250Measured Depth (500 usft/in)A-11A-11A-11GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference3500.00 To 7944.46Project: North Cook InletSite: North Cook Inlet UnitWell: Plan: NCIU A-11Wellbore: NCI A-11APlan: NCI A-11A wp04Ladder/S.F. 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