The URL can be used to link to this page

Home My WebLink About222-0241. 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): 7,550 N/A Casing Collapse Structural Conductor Surface 670psi Intermediate 2,090psi Production 4,320psi 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 1/24/2026 7,550'3,810' 4-1/2" 5,359' Baker ZXP & Baker ONYX-R5E TRSSSV 3,740 (MD) 3,192 (TVD) & 351 (MD) 351 (TVD) 4,010' Perforation Depth MD (ft): 2,587' 6,180 - 7,347 4,010' 4 1/2" 4,435 - 5,194 3,388'7" 30" 16" 386' 10 3/4"2,587' 631' MD 3,580psi 1,640psi 386' 631' 2,371' 386' 631' Length Size Proposed Pools: L-80 TVD Burst 3,740 4,980psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 222-024 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20029-01-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-09A AOGCC USE ONLY 16,176psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager 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 North Cook Inlet Tertiary System Gas Same 5,360 7,343 5,191 161psi N/A 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 14:21:58 - 09'00' Dan Marlowe (1267) 326-020 By Grace Christianson at 2:39 pm, Jan 09, 2026 MGR09JAN2025 TS 1/12/25 10-404 * BOPE pressure test to 3000 psi. 48 hour notice to AOGCC. DSR-1/16/26 01/20/26 Fill Clean Out and Perf Well: North Cook Inlet Unit A-09A Well Name:NCIU A-09A API Number:50-883-20029-01 Current Status:Online, Gas Well Leg:Leg #2 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:222-024 First Call Engineer:Eric Dickerman (907) 564-4061 Second Call Engineer:Dan Marlowe (907) 283-1329 Maximum Expected BHP:692 psi at 5,317 tvd 0.13 psi/ft NCIU A-01A, 11/10/2021 SBHP survey Max. Potential Surface Pressure: 161 psi MPSP -0.1 psi/ft gas grad. to surface Field/Pool: North Cook Inlet Unit, Tertiary System Gas Pool Applicable Frac Gradient: 0.78 psi/ft using 15.1 ppg EMW 6/19/2022 LOT after exiting 7 casing. Shallowest Allowable Perf TVD: MPSP/(Frac grad. Gas grad.) = 161 psi / (0.78 0.1 psi/ft) = 237 tvd Brief Well Summary: A-09A was drilled in 2022, targeting the Beluga formation within the North Cook Inlet field. The Beluga A/B/D/E/F sands were perforated and the well came online at a peak production rate of 5.6 MMCFD. In March 2024 slickline tagged at 6,579 which means the bottom 150 of perforations were covered by fill. Infill add perfs were identified and a coiled tubing cleanout was successfully performed in March 2025 however eline was not able to reach all of the target intervals, and only perforated two of the target intervals. Objective: Coiled tubing fill cleanout. Add Beluga perforations. Wellbore information: North Cook Inlet Unit, Tertiary System Gas Pool top = Top of Sterling sands, at 3,787 md / 3,226 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-09A 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 drift/cleanout BHA. Drift to PBTD at ± 7,468. Perform fill cleanout as necessary. Deepest target perforation is 7,497 (corrected to the open hole logs)*. a. *The bottom target perf interval is 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 deepest target interval 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. MU memory GR/CCL, perform correlation log. a. Tie in to attached log (LWD open hole logs). 5. Perforate the following intervals with 2 or 2.5 guns. All runs will be fully lubricated. Interval Perf Depths Perf Length #1 7480 7497* *The perf interval is close to PBTD, depending on actual tag depth the perf may not be accessible or may have to be shortened to target what is accessible. 17 #2 7370 7375 5 #3 6537 6557 20 6. 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-09A Correlation Log: Target perf intervals Updated by JLL 04/21/25 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: NCI A-09A PTD: 222-024 API: 50-883-20029-01-00 Completed: 8/18/22 PBTD:7,468MD / 5,292 TVD TD: 7,550 MD / 5,360 TVD 30 RKB: 126.6 2 10-3/4 4-1/2 7 Window @ 4,010 MD Beluga A 16 NCIU A-09 Motherbore Beluga B Beluga D Beluga E Beluga F TOC @ 3,995 per CBL 8/6/22 Tag @ 7,343 SLM 3/25/25 1 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30 28.500 Surf 386 16 65 H-40 15.250 Surf 631 10-3/4 45.5 J-55 BTC 9.950 Surf 2,587 7 26 J-55 BTC 6.276 Surf 4,010 4-1/2 12.6 L-80 DWC 3.870 3,740 7,550 4-1/2 12.6 L-80 IBT-M 3.958 Surf 3,740 Notes: Short joints of 4-1/2 casing @ 4549 (8), 5549 (8), 6592 (8) RA Tag @ 7052 & 6592 Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 351 351 3.870 5.970 Baker ONYX-R5E TRSSSV 2 3,740 3,192 3.958 Baker ZXP liner hanger packer assy & Seal Assembly (6/30/22) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Bel Aa 6,180 6,190 4,435 4,440 10 01/31/25 Open Bel-A Upper 1 6,197 6,207 4,444 4,449 10 08/20/22 Open Bel-A Upper 2 6,211 6,221 4,451 4,456 10 08/20/22 Open Bel-A Mid 6,231 6,251 4,461 4,471 20 08/20/22 Open Bel-A Lower 1 6,266 6,281 4,478 4,485 15 08/20/22 Open Bel-A Lower 2 6,302 6,312 4,495 4,500 10 08/20/22 Open Bel Ba 6,397 6,410 4,451 4,547 13 01/31/25 Open Bel-B Upper 1 6,423 6,443 4,553 4,563 10 08/20/22 Open Bel-B Upper 2 6,463 6,472 4,572 4,577 9 08/20/22 Open Bel-B Upper 3 6,517 6,527 4,599 4,604 10 08/20/22 Open Bel-B Mid 1 6,553 6,565 4,617 4,623 12 08/20/22 Open Bel-B Mid 2 6,586 6,600 4,634 4,642 14 08/19/22 Open Bel-B Mid 3 6,6186,628 4,651 4,657 10 08/19/22 Open Bel-B Lower 6,678 6,691 4,686 4,694 13 08/19/22 Open Bel-D Lower 7,007 7,027 4,918 4,934 20 08/19/22 Open Bel-E Upper 7,036 7,046 4,941 4,950 10 08/19/22 Open Bel-E Mid 1 7,069 7,074 4,968 4,972 5 08/19/22 Open Bel-E Mid 2 7,141 7,147 5,027 5,032 6 08/19/22 Open Bel-E Mid 3 7,165 7,170 5,046 5,050 5 08/18/22 Open Bel-E Mid 4 7,176 7,181 5,055 5,059 3 08/18/22 Open Bel-E Lower 7,207 7,227 5,080 5,096 20 08/18/22 Open Bel-F Upper 7,257 7,267 5,121 5,129 10 08/18/22 Open Bel-F Mid 1 7,271 7,285 5,132 5,144 14 08/18/22 Open Bel-F Mid 2 7,3277,347 5,178 5,194 20 08/18/22 Open Updated by JLL 01/09/26 PROPOSED North Cook Inlet Unit Tyonek Platform Well: NCI A-09A PTD: 222-024 API: 50-883-20029-01-00 Completed: 8/18/22 PBTD:7,468MD / 5,292 TVD TD: 7,550 MD / 5,360 TVD 30 RKB: 126.6 2 10-3/4 4-1/2 7 Window @ 4,010 MD Beluga A 16 NCIU A-09 Motherbore Beluga B Beluga D Beluga E Beluga F TOC @ 3,995 per CBL 8/6/22 Beluga G Beluga H 1 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30 28.500 Surf 386 16 65 H-40 15.250 Surf 631 10-3/4 45.5 J-55 BTC 9.950 Surf 2,587 7 26 J-55 BTC 6.276 Surf 4,010 4-1/2 12.6 L-80 DWC 3.870 3,740 7,550 4-1/2 12.6 L-80 IBT-M 3.958 Surf 3,740 Notes: Short joints of 4-1/2 casing @ 4549 (8), 5549 (8), 6592 (8) RA Tag @ 7052 & 6592 Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 351 351 3.870 5.970 Baker ONYX-R5E TRSSSV 2 3,740 3,192 3.958 Baker ZXP liner hanger packer assy & Seal Assembly (6/30/22) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Bel Aa 6,180 6,190 4,435 4,440 10 01/31/25 Open Bel-A Upper 1 6,197 6,207 4,444 4,449 10 08/20/22 Open Bel-A Upper 2 6,211 6,221 4,451 4,456 10 08/20/22 Open Bel-A Mid 6,231 6,251 4,461 4,471 20 08/20/22 Open Bel-A Lower 1 6,266 6,281 4,478 4,485 15 08/20/22 Open Bel-A Lower 2 6,302 6,312 4,495 4,500 10 08/20/22 Open Bel Ba 6,397 6,410 4,451 4,547 13 01/31/25 Open Bel-B Upper 1 6,423 6,443 4,553 4,563 10 08/20/22 Open Bel-B Upper 2 6,463 6,472 4,572 4,577 9 08/20/22 Open Bel-B Upper 3 6,517 6,527 4,599 4,604 10 08/20/22 Open Bel Be ±6,537' ±6,557' ±4,609' ±4,619' ±20' Future Proposed Bel-B Mid 1 6,553 6,565 4,617 4,623 12 08/20/22 Open Bel-B Mid 2 6,586 6,600 4,634 4,642 14 08/19/22 Open Bel-B Mid 3 6,6186,628 4,651 4,657 10 08/19/22 Open Bel-B Lower 6,678 6,691 4,686 4,694 13 08/19/22 Open Bel-D Lower 7,007 7,027 4,918 4,934 20 08/19/22 Open Bel-E Upper 7,036 7,046 4,941 4,950 10 08/19/22 Open Bel-E Mid 1 7,069 7,074 4,968 4,972 5 08/19/22 Open Bel-E Mid 2 7,141 7,147 5,027 5,032 6 08/19/22 Open Bel-E Mid 3 7,165 7,170 5,046 5,050 5 08/18/22 Open Bel-E Mid 4 7,176 7,181 5,055 5,059 3 08/18/22 Open Bel-E Lower 7,207 7,227 5,080 5,096 20 08/18/22 Open Bel-F Upper 7,257 7,267 5,121 5,129 10 08/18/22 Open Bel-F Mid 1 7,271 7,285 5,132 5,144 14 08/18/22 Open Bel-F Mid 2 7,3277,347 5,178 5,194 20 08/18/22 Open Bel Gb ±7,370 ±7,375' ±5,213' ±5,217' ±5' Future Proposed Bel Hb ±7,480'±7,497' ±5,302' ±5,316' ±17' 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. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 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 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): 7,550 N/A Casing Collapse Structural Conductor Surface 670psi Intermediate 2,090psi Production 4,320psi 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: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 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 9/20/2024 7,550'3,810' 4-1/2" 5,359' Baker ZXP Liner Hanger Packer & Baker ONYX-R5E TRSSSV 3,740 (MD) 3,192 (TVD) & 351 (MD) 351 (TVD) 4,010' Perforation Depth MD (ft): 2,587' 6,197 - 7,347 4,010' 4 1/2" 4,444 - 5,194 3,388'7" 30" 16" 386' 10 3/4"2,587' 631' MD 3,580psi 1,640psi 386' 631' 2,371' 386' 631' Length Size Proposed Pools: L-80 TVD Burst 3,741 4,980psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 222-024 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20029-01-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-09A AOGCC USE ONLY 16,176psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager 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 North Cook Inlet Tertiary System Gas Same 5,360 7,468 5,292 1,818psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:20 pm, Sep 05, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.09.05 11:09:38 - 08'00' Dan Marlowe (1267) 324-505 DSR-9/5/24 Weekly BOP test approved for continuous CT operations on this leg only. BOP test required on first well of campaign on this leg of this platform. BJM 9/9/24 10-404 A.Dewhurst 10SEP24 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.11 18:40:27 -05'00'09/11/24 RBDMS JSB 091624 Cleanout + Perf Well: NCIU (Tyonek) A-09A Well Name:NCIU (Tyonek) A-09A API Number:50-883-20029-01-00 Current Status:Online gas well Leg:Leg #2 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:222-024 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,338 psi @ 5,194’ TVD 0.45psi/ft to deepest perf Max. Potential Surface Pressure: 1818 psi Using 0.1 psi/ft Brief Well Summary Gas producer A-09A was sidetracked to its current bore in 2022. The well was completed in the Upper Beluga portion of the Tertiary System Gas Pool. The well IP’d strong at >5MMCFD. In January-2024 the production had naturally declined to 1.7MM. The well then took an abrupt step change down to 1.0MM gas and hasn’t recovered since. Th rate is now <0.5MM. SL tags have indicated an obstruction around the BEL-B sand. This intervention aims to restore production to January-2024 rates, and add some additional sands. All planned perforations below are within the Tertiary System Gas Pool as defined by CO 68A. The goal of this project is to cleanout the well and add infill perfs to improve rate Pertinent wellbore information: - 3/5/24: SL drift o Tag at 6446' and works down to 6474' MD o Didn't make much more hole (6579' is corrected). o Minimal fill in bailers, but clay on tools. - 7/4/23: Flowing drift attempt couldn’t make it past 4350’ MD. Elected not to SI well and try for deeper - 8/20/22: initial perforations o 2-7/8” guns perf’d as deep as 7347’ MD o Perfs from 6586 – 6600 and 6553 – 6565’ caused the largest FTP increases when shot o GPT run on morning of 8/19. Showed fluid level at 7300’ - 8/14/22: CT blowdown post-drilling. Made it to PBTD at 7440’ CTMD’ with a 3.72” JSN (no issues) - 2022: o Sidetracked to current location o TRSSSV installed and functional o Inclination Max = 70 degrees at 5020’ MD Inclinations above 60 degrees from 4500 – 6500’ MD Cleanout + Perf Well: NCIU (Tyonek) A-09A Coiled Tubing Procedure 1. MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high a. Multiple wells planned for CT intervention on this leg (#2) b. Hilcorp requests a weekly CT BOP test requirement while on this leg, instead of each well 3. MU cleanout BHA 4. RIH and clean / mill out to PBTD or as deep as practical a. Working fluid will be freshwater (8.33ppg) or heavier b. If necessary, add foam and nitrogen for the cleanout 5. Once hole is clean, lift well to production with nitrogen 6. RDMO CT E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. RIH and perforate from ±6,108’ - ±7,468’ MD (±4,436’ - ±5,292’ TVD) per RE/Geo a. All proposed perfs within Tertiary System Gas Pool b. Bottom pool is below PBTD c. Top pool is at top Sterling sands (Far above top proposed perfs) 4. RDMO EL CONTINGENCY plug/patch: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and PT lines to 2000psi (or higher if needed) 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2000psi high 5. Set 4-1/2” isolation plug or patch per OE 6. RDMO Nitrogen and EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing (Fox energy) 4. Nitrogen procedure Weekly CT BOP test approved for work on this leg only. -bjm Updated by JLL 01/30/24 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: NCI A-09A PTD: 222-024 API: 50-883-20029-01-00 Completed: 8/18/22 PBTD:7,468’MD /5,292’TVD TD: 7,550’ MD / 5,360’ TVD 30” RKB: 126.6’ 2 10-3/4” 4-1/2” 7” Window @ 4,010’ MD Beluga A 16” NCIU A-09 Motherbore Beluga B Beluga D Beluga E Beluga F TOC @ 3,995’ per CBL 8/6/22 1 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 386’ 16” 65 H-40 Surf 631’ 10-3/4” 45.5 J-55 BTC Surf 2,587’ 7” 26 J-55 BTC Surf 4,010’ 4-1/2” 12.6 L-80 DWC 3.870 3,740’ 7,550’ 4-1/2” 12.6 L-80 IBT-M 3.958” Surf 3,741’ Notes: Short joints of 4-1/2” casing @ 4549’ (8’), 5549’ (8’), 6592’ (8’) RA Tag @ 7052’ & 6592’ Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 351’ 351’ 3.870” 5.970” Baker ONYX-R5E TRSSSV 2 3,740’ 3,192’ 3.958” Baker ZXP liner hanger packer assy & Seal Assembly (6/30/22) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Bel-A Upper 1 6,197’ 6,207’ 4,444’ 4,449’ 10 08/20/22 Open Bel-A Upper 2 6,211’ 6,221’ 4,451’ 4,456’ 10 08/20/22 Open Bel-A Mid 6,231’ 6,251’ 4,461’ 4,471’ 20 08/20/22 Open Bel-A Lower 1 6,266’ 6,281’ 4,478’ 4,485’ 15 08/20/22 Open Bel-A Lower 2 6,302’ 6,312’ 4,495’ 4,500’ 10 08/20/22 Open Bel-B Upper 1 6,423’ 6,443’ 4,553’ 4,563’ 10 08/20/22 Open Bel-B Upper 2 6,463’ 6,472’ 4,572’ 4,577’ 9 08/20/22 Open Bel-B Upper 3 6,517’ 6,527’ 4,599’ 4,604’ 10 08/20/22 Open Bel-B Mid 1 6,553’ 6,565’ 4,617’ 4,623’ 12 08/20/22 Open Bel-B Mid 2 6,586’ 6,600’ 4,634’ 4,642’ 14 08/19/22 Open Bel-B Mid 3 6,618’6,628’ 4,651’ 4,657’ 10 08/19/22 Open Bel-B Lower 6,678’ 6,691’ 4,686’ 4,694’ 13 08/19/22 Open Bel-D Lower 7,007’ 7,027’ 4,918’ 4,934’ 20 08/19/22 Open Bel-E Upper 7,036’ 7,046’ 4,941’ 4,950’ 10 08/19/22 Open Bel-E Mid 1 7,069’ 7,074’ 4,968’ 4,972’ 5 08/19/22 Open Bel-E Mid 2 7,141’ 7,147’ 5,027’ 5,032’ 6 08/19/22 Open Bel-E Mid 3 7,165’ 7,170’ 5,046’ 5,050’ 5 08/18/22 Open Bel-E Mid 4 7,176’ 7,181’ 5,055’ 5,059’ 3 08/18/22 Open Bel-E Lower 7,207’ 7,227’ 5,080’ 5,096’ 20 08/18/22 Open Bel-F Upper 7,257’ 7,267’ 5,121’ 5,129’ 10 08/18/22 Open Bel-F Mid 1 7,271’ 7,285’ 5,132’ 5,144’ 14 08/18/22 Open Bel-F Mid 2 7,327’7,347’ 5,178’ 5,194’ 20 08/18/22 Open Updated by JLL 09/05/2024 PROPOSED North Cook Inlet Unit Tyonek Platform Well: NCI A-09A PTD: 222-024 API: 50-883-20029-01-00 Completed: 8/18/22 PBTD: 7,468’ MD / 5,292’ TVD TD: 7,550’ MD / 5,360’ TVD 30” RKB: 126.6’ 2 10-3/4” 4-1/2” 7” Window @ 4,010’ MD Beluga A 16” NCIU A-09 Motherbore Beluga B Beluga D Beluga E Beluga F TOC @ 3,995’ per CBL 8/6/22 1 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 386’ 16” 65 H-40 Surf 631’ 10-3/4” 45.5 J-55 BTC Surf 2,587’ 7” 26 J-55 BTC Surf 4,010’ 4-1/2” 12.6 L-80 DWC 3.870 3,740’ 7,550’ 4-1/2” 12.6 L-80 IBT-M 3.958” Surf 3,741’ Notes: Short joints of 4-1/2” casing @ 4549’ (8’), 5549’ (8’), 6592’ (8’) RA Tag @ 7052’ & 6592’ Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 351’ 351’ 3.870” 5.970” Baker ONYX-R5E TRSSSV 2 3,740’ 3,192’ 3.958” Baker ZXP liner hanger packer assy & Seal Assembly (6/30/22) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga ±6,108' ±7,468' ±4,436' ±5,292' ±1,360' Future Proposed Bel-A Upper 1 6,197’ 6,207’ 4,444’ 4,449’ 10 08/20/22 Open Bel-A Upper 2 6,211’ 6,221’ 4,451’ 4,456’ 10 08/20/22 Open Bel-A Mid 6,231’ 6,251’ 4,461’ 4,471’ 20 08/20/22 Open Bel-A Lower 1 6,266’ 6,281’ 4,478’ 4,485’ 15 08/20/22 Open Bel-A Lower 2 6,302’ 6,312’ 4,495’ 4,500’ 10 08/20/22 Open Bel-B Upper 1 6,423’ 6,443’ 4,553’ 4,563’ 10 08/20/22 Open Bel-B Upper 2 6,463’ 6,472’ 4,572’ 4,577’ 9 08/20/22 Open Bel-B Upper 3 6,517’ 6,527’ 4,599’ 4,604’ 10 08/20/22 Open Bel-B Mid 1 6,553’ 6,565’ 4,617’ 4,623’ 12 08/20/22 Open Bel-B Mid 2 6,586’ 6,600’ 4,634’ 4,642’ 14 08/19/22 Open Bel-B Mid 3 6,618’6,628’ 4,651’ 4,657’ 10 08/19/22 Open Bel-B Lower 6,678’ 6,691’ 4,686’ 4,694’ 13 08/19/22 Open Bel-D Lower 7,007’ 7,027’ 4,918’ 4,934’ 20 08/19/22 Open Bel-E Upper 7,036’ 7,046’ 4,941’ 4,950’ 10 08/19/22 Open Bel-E Mid 1 7,069’ 7,074’ 4,968’ 4,972’ 5 08/19/22 Open Bel-E Mid 2 7,141’ 7,147’ 5,027’ 5,032’ 6 08/19/22 Open Bel-E Mid 3 7,165’ 7,170’ 5,046’ 5,050’ 5 08/18/22 Open Bel-E Mid 4 7,176’ 7,181’ 5,055’ 5,059’ 3 08/18/22 Open Bel-E Lower 7,207’ 7,227’ 5,080’ 5,096’ 20 08/18/22 Open Bel-F Upper 7,257’ 7,267’ 5,121’ 5,129’ 10 08/18/22 Open Bel-F Mid 1 7,271’ 7,285’ 5,132’ 5,144’ 14 08/18/22 Open Bel-F Mid 2 7,327’7,347’ 5,178’ 5,194’ 20 08/18/22 Open KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary 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. 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 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): 7,550 N/A Casing Collapse Structural Conductor Surface 670psi Intermediate 2,090psi Production 4,320psi 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: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 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 North Cook Inlet Tertiary System Gas Same 5,360 7,468 5,292 2,223psi 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 / ADL0037831 222-024 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20029-01-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-09A Length Size Proposed Pools: L-80 TVD Burst 3,741 4,980psi MD 3,580psi 1,640psi 386' 631' 2,371' 386' 631' 3,388'7" 30" 16" 386' 10 3/4"2,587' 631' Perforation Depth MD (ft): 2,587' 6,197 - 7,347 4,010' 4 1/2" 4,444 - 5,194 Other: N2 Operations CO 68A 2/14/2024 7,550'3,810' 4-1/2" 5,359' Baker ZXP Liner Hanger Packer & Baker ONYX-R5E TRSSSV 3,740 (MD) 3,192 (TVD) & 351 (MD) 351 (TVD) 4,010' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-044 By Kayla Junke at 9:26 am, Feb 02, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.02.01 06:31:40 - 09'00' Dan Marlowe (1267) 10-404 Perforate BJM 2/5/24 SFD 2/5/2024 DSR-2/12/24*&:JLC 2/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.13 10:47:24 -06'00'02/13/24 RBDMS JSB 021324 Perfs Well: NCIU A-09A Well Name:NCIU A-09A API Number:50-883-20029-01-00 Current Status:Online gas well Leg:Leg #2 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:222-024 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,752 psi @ 5,292’ TVD 0.52psi/ft to PBTD Max. Potential Surface Pressure: 2223 psi Using 0.1 psi/ft Brief Well Summary NCIU A-09A was sidetracked in 2022 and has been an online gas producer from the Upper Beluga ever since. The well has infill perf opportunity. All existing and proposed perforations below are within the Tertiary System Gas Pool. The goal of this project is to add infill perfs Pertinent wellbore information: - TRSSSV installed - Inclination: Increases to 70 degrees at 5,020’ MD, then rolls back over to 60 degrees - 7/4/23 P/T survey attempt o SL can’t drift below 4975’ MD with a 2” bailer (no roller boogies attempted) o Tools coated in fine sand o Well was flowing ~2MM at the time of drift E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. RIH and perforate sands from ±6,180 - ±7,468’ MD (±4,436’ - ±5,292’ TVD) per RE/Geo 4. RDMO EL CONTINGENCY: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and PT lines to 2500psi 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2500psi high (higher if needed due to N2 pressure) 5. Set 4-1/2” CIBP or patch per OE 6. RDMO Nitrogen and EL Attachments: 1. Proposed Wellbore Schematic 2. Nitrogen procedure Updated by JLL 01/30/24 PROPOSED North Cook Inlet Unit Tyonek Platform Well: NCI A-09A PTD: 222-024 API: 50-883-20029-01-00 Completed: 8/18/22 PBTD:7,468’MD /5,292’TVD TD: 7,550’ MD / 5,360’ TVD 30” RKB: 126.6’ 2 10-3/4” 4-1/2” 7”Window @ 4,010’ MD Beluga A 16” NCIU A-09 Motherbore Beluga B Beluga D Beluga E Beluga F TOC @ 3,995’ per CBL 8/6/22 1 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 386’ 16” 65 H-40 Surf 631’ 10-3/4” 45.5 J-55 BTC Surf 2,587’ 7” 26 J-55 BTC Surf 4,010’ 4-1/2” 12.6 L-80 DWC 3.870 3,740’ 7,550’ 4-1/2” 12.6 L-80 IBT-M 3.958” Surf 3,741’ Notes: Short joints of 4-1/2” casing @ 4549’ (8’), 5549’ (8’), 6592’ (8’) RA Tag @ 7052’ & 6592’ Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 351’ 351’ 3.870” 5.970” Baker ONYX-R5E TRSSSV 2 3,740’ 3,192’ 3.958” Baker ZXP liner hanger packer assy & Seal Assembly (6/30/22) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga ±6,180' ±7,468' ±4,436' ±5,292' ±1,288' Future Proposed Bel-A Upper 1 6,197’ 6,207’ 4,444’ 4,449’ 10 08/20/22 Open Bel-A Upper 2 6,211’ 6,221’ 4,451’ 4,456’ 10 08/20/22 Open Bel-A Mid 6,231’ 6,251’ 4,461’ 4,471’ 20 08/20/22 Open Bel-A Lower 1 6,266’ 6,281’ 4,478’ 4,485’ 15 08/20/22 Open Bel-A Lower 2 6,302’ 6,312’ 4,495’ 4,500’ 10 08/20/22 Open Bel-B Upper 1 6,423’ 6,443’ 4,553’ 4,563’ 10 08/20/22 Open Bel-B Upper 2 6,463’ 6,472’ 4,572’ 4,577’ 9 08/20/22 Open Bel-B Upper 3 6,517’ 6,527’ 4,599’ 4,604’ 10 08/20/22 Open Bel-B Mid 1 6,553’ 6,565’ 4,617’ 4,623’ 12 08/20/22 Open Bel-B Mid 2 6,586’ 6,600’ 4,634’ 4,642’ 14 08/19/22 Open Bel-B Mid 3 6,618’6,628’ 4,651’ 4,657’ 10 08/19/22 Open Bel-B Lower 6,678’ 6,691’ 4,686’ 4,694’ 13 08/19/22 Open Bel-D Lower 7,007’ 7,027’ 4,918’ 4,934’ 20 08/19/22 Open Bel-E Upper 7,036’ 7,046’ 4,941’ 4,950’ 10 08/19/22 Open Bel-E Mid 1 7,069’ 7,074’ 4,968’ 4,972’ 5 08/19/22 Open Bel-E Mid 2 7,141’ 7,147’ 5,027’ 5,032’ 6 08/19/22 Open Bel-E Mid 3 7,165’ 7,170’ 5,046’ 5,050’ 5 08/18/22 Open Bel-E Mid 4 7,176’ 7,181’ 5,055’ 5,059’ 3 08/18/22 Open Bel-E Lower 7,207’ 7,227’ 5,080’ 5,096’ 20 08/18/22 Open Bel-F Upper 7,257’ 7,267’ 5,121’ 5,129’ 10 08/18/22 Open Bel-F Mid 1 7,271’ 7,285’ 5,132’ 5,144’ 14 08/18/22 Open Bel-F Mid 2 7,327’7,347’ 5,178’ 5,194’ 20 08/18/22 Open 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. DATA SUBMITTAL COMPLIANCE REPORT API No. 50-883-20029-01-00Well Name/No. N COOK INLET UNIT A-09A Completion Status 1-GASCompletion Date 8/18/2022 Permit to Drill 2220240 Operator Hilcorp Alaska, LLC MD 7550 TVD 5360 Current Status 1-GAS 4/21/2023 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:CBL 8-6-22, LWD NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 7/20/20223990 7550 Electronic Data Set, Filename: NCIU A-09A LWD Final.las 36817ED Digital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final MD.cgm36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final TVD.cgm36817EDDigital Data DF 7/20/2022 Electronic File: NCI A-09A - Definitive Survey Report.pdf 36817ED Digital Data DF 7/20/2022 Electronic File: NCI A-09A - DSR Actual - Plan.pdf 36817ED Digital Data DF 7/20/2022 Electronic File: NCI A-09A - DSR Actual - VSec.pdf 36817ED Digital Data DF 7/20/2022 Electronic File: NCI A-09A - Final Surveys.xlsx36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A_DSR.txt36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A_GIS.txt36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final MD.emf36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final TVD.emf36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final MD.pdf36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final TVD.pdf36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final MD.tif36817EDDigital Data DF 7/20/2022 Electronic File: NCIU A-09A LWD Final TVD.tif36817EDDigital Data DF 9/22/20222812 2559 Electronic Data Set, Filename: NCIU_A- 09A_Drift_CBL_06-Aug-2022_(3894).las 37030ED Digital Data DF 9/22/2022 Electronic File: NCIU_A-09A_Drift_CBL_06-Aug- 2022_(3894).pdf 37030ED Digital Data Friday, April 21, 2023AOGCCPage 1 of 2 NCIU A-09A LWD Final.las DATA SUBMITTAL COMPLIANCE REPORT API No. 50-883-20029-01-00Well Name/No. N COOK INLET UNIT A-09A Completion Status 1-GASCompletion Date 8/18/2022 Permit to Drill 2220240 Operator Hilcorp Alaska, LLC MD 7550 TVD 5360 Current Status 1-GAS 4/21/2023 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:8/18/2022 Release Date:3/16/2022 DF 11/9/20227428 6994 Electronic Data Set, Filename: NCI_A- 09A_Perf_20-Aug-2022_(3917).las 37247ED Digital Data DF 11/9/2022 Electronic File: NCI_A-09A_Perf_20-Aug- 2022_(3917).pdf 37247ED Digital Data Friday, April 21, 2023AOGCCPage 2 of 2 M. Guhl 4/21/2023 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/8/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221108 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 241-01 502832018400 221076 8/14/2022 AK E-Line GPT/Plug/Perf IRU 241-01 502832018400 221076 8/31/2022 AK E-Line GPT/Plug/Perf IRU 41-01 502832008800 192109 9/9/2022 AK E-Line GR/Perf IRU 241-01 502832018400 221076 8/25/2022 AK E-Line Perf IRU 241-01 502832018400 221076 8/22/2022 AK E-Line Plug/GR MPU S-34 500292317100 203130 9/4/2022 AK E-Line Cut Tubing NCI A-09A 508832002901 222024 8/20/2022 AK E-Line Perf NCI A-10B 508832003002 222025 8/23/2022 AK E-Line Perf Please include current contact information if different from above. T37244 T37244 T37245 T37244 T37244 T37246 T37247 T37248 NCI A-09A 508832002901 222024 8/20/2022 AK E-Line Perf Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.09 11:47:34 -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-09A 50883200290100 222024 8/6/2022 AK E-Line 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 5,360' 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 Rate361 June 27, 2022 June 18, 2022 ADL 17589 / ADL 37831 N/A N/A 4,010' MD / 3,388' TVD99 351' MD / 351' TVD 7,550' MD / 5,360' TVD CBL 8-6-22, Logging While Drilling Logs Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 004233 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/A4233 Flowing *** Please see attached schematic for perforation detail *** 0 Water-Bbl: PRODUCTION TEST 8/18/2022 Date of Test: 33 8/25/2022 24 Flow Tubing 0 12.6# 7,550' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) 3,740' / 3,192' PACKER SET (MD/TVD) CASING WT. PER FT.GRADE 329163 328299 TOP SETTING DEPTH MD 3,740' SETTING DEPTH TVD 2583986 BOTTOM TOP 3,192' HOLE SIZE AMOUNT PULLED 50-883-20029-01-00 NCIU A-09A 332040 2586667 1744' FSL, 1822' FEL, Sec 1, T11N, R10W, SM, AK CEMENTING RECORD 2584485 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/18/2022 1312' FNL, 1022' FWL, Sec 6, T11N, R9W, SM, AK 1232' FSL, 2600' FWL, Sec 1, T11N, R10W, SM, AK 222-024 / 322-438 / 322-373 Tertiary System Gas Pool 126.6' 7,468' MD / 5,292' 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" 440 sx 3,741'4-1/2" 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 8:33 am, Aug 31, 2022 Completed 8/18/2022 JSB RBDMS JSB 090122 GDSR-9/1/22WCB 4/20/2023 G 222-024 / 322-438 / 322-373 SFD 11/8/2022 NCIU A-09A Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval 6,197' Bel A 4,444' 6,176' 4,434' 6,335' 4,511' 6,720' 4,711' 6,828' 4,783' 7,033' 4,939' 7,233' 5,102' 7,382' 5,223' 7,429' 5,261' 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 8.30.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.08.30 15:44:13 -08'00' Monty M Myers Updated by CJD 08-30-22 SCHEMATIC North Cook Inlet Unit TyonekPlatform Well: NCI A-09A PTD: 222-024 API: 50-883-20029-01-00 Completed: 8/18/22 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30”Surf 386’ 16”65 H-40 Surf 631’ 10-3/4”45.5 J-55 BTC Surf 2,587’ 7”26 J-55 BTC Surf 4,010’ 4-1/2”12.6 L-80 DWC 3.870 3,740’7,550’ 4-1/2”12.6 L-80 IBT-M 3.958”Surf 3,741’ Notes: Short joints of 4-1/2” casing @ 4549’(8’), 5549’ (8’), 6592’(8’) RA Tag @ 7052’ & 6592’ Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 351’351’3.870”5.970”Baker ONYX-R5E TRSSSV 2 3,740’3,192’3.958”Baker ZXP liner hanger packer assy & Seal Assembly (6/30/22) PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Bel-A Upper 1 6,197’6,207’4,444’4,449’10 08/20/22 Open Bel-A Upper 2 6,211’6,221’4,451’4,456’10 08/20/22 Open Bel-A Mid 6,231’6,251’4,461’4,471’20 08/20/22 Open Bel-A Lower 1 6,266’6,281’4,478’4,485’15 08/20/22 Open Bel-A Lower 2 6,302’6,312’4,495’4,500’10 08/20/22 Open Bel-B Upper 1 6,423’6,443’4,553’4,563’10 08/20/22 Open Bel-B Upper 2 6,463’6,472’4,572’4,577’9 08/20/22 Open Bel-B Upper 3 6,517’6,527’4,599’4,604’10 08/20/22 Open Bel-B Mid 1 6,553’6,565’4,617’4,623’12 08/20/22 Open Bel-B Mid 2 6,586’6,600’4,634’4,642’14 08/19/22 Open Bel-B Mid 3 6,618’6,628’4,651’4,657’10 08/19/22 Open Bel-B Lower 6,678’6,691’4,686’4,694’13 08/19/22 Open Bel-D Lower 7,007’7,027’4,918’4,934’20 08/19/22 Open Bel-E Upper 7,036’7,046’4,941’4,950’10 08/19/22 Open Bel-E Mid 1 7,069’7,074’4,968’4,972’5 08/19/22 Open Bel-E Mid 2 7,141’7,147’5,027’5,032’6 08/19/22 Open Bel-E Mid 3 7,165’7,170’5,046’5,050’5 08/18/22 Open Bel-E Mid 4 7,176’7,181’5,055’5,059’3 08/18/22 Open Bel-E Lower 7,207’7,227’5,080’5,096’20 08/18/22 Open Bel-F Upper 7,257’7,267’5,121’5,129’10 08/18/22 Open Bel-F Mid 1 7,271’7,285’5,132’5,144’14 08/18/22 Open Bel-F Mid 2 7,327’7,347’5,178’5,194’20 08/18/22 Open Activity Date Ops Summary 6/5/2022 Construction finish drilling holes In Rotary sub base. Remove planking. Work boat-receive bops & Misc. supplies. Start N/U BOPs inside rotary sub while waiting on crane rigging for the 800 crane removal.;Shut down N/U operations due to 800 crane removal. Still waiting on 800 crane body removal, Top landing pedestal, Lower landing R/D. Simop- replacing cables on spartan starboard crane.;Skid Rig out over rotary sub, jack and shim rotary sub for bolt up t/rig floor. Simop-c/o whip line on starboard crane.;Torque rotary sub bolts t/rig floor. Simop-c/o head block line on starboard crane. Un-bolt rig floor from cantilever.;Skid cantilever back and leave rig package on the platform. Jack rig up and remove shims from bolt up on rotary sub. 6/6/2022 Skid rig towards Leg 2 & set up scaffolding. Torque bolts on Rot sub & Continue to install C plates.;Work on safe out handrails on 151 pipe deck. Install cat walk from 151 to Tyonek platform; simop-Tyonek still Demob 800 crane landings.;Hook up drain lines on Spartan cantilever and fire fighting deluge system; simop- Tyonek still Demob 800 crane landings.;Skid rig toward leg #2, swap side with jacks to push and continue jacking over well A-09A. Work boat.;Secure rot. base, scope in rams and roll up hyd. unit. decision made to traverse rig package 4" north when rig is powered up.;Cont. working on fire fighting deluge, sea H2O systems on Spartan. Work boat-unload HAK rack base beams and spot same, unload Sperry unit. 6/7/2022 take on potable water and fuel. Install hurricane clamps on rot.sub base to deck. Bolt up Hak rack base t/spreaders w/C-clamp bolts.;Modify jack links t/fit Hak rack base and install jacks t/skid same. Change out head block on port crane. Pull blind flanges off mud pits on Spartan.;Install mud feed/return hoses from pits/pumps t/ beaver slide. Assist welders installing ST-80 socket for pedestal-firewatchs x3. Re-install new bolts on C-clamps on rot. sub used for Hak rack.;Install centrifuge feed pump under centrifuge unit. Build bracket and move satellite dish for internet in OIM office. Ready decks and back load for boat.;Unload Hak rack section from boat and set on deck, re-rig for 2 crane pick and set in place, while working boat w/Spartan crane.;Pick 2nd Hak rack section and set into place, secure both sections to Hak rack base section. Cont. working boat w/Spartan crane. 6/8/2022 Secure HAK rack end sections to base and skid HAK rack into place. Continue to work on ST-80 socket install.;Install service catwalk from 151 to Tyonek platform and lay down rubber matting. Install catwalk from 151 to HAK rack on Tyonek platform.;Work on handrails and landings to 151 pipe deck.;Unpack and layout gas alarm equipment with Tyonek electrician. Begin laying cables in service catwalk from 151 to platform.;Work boat- unload and set-middle Hak rack deck, 2ea. 8 x30ft mats for new shaker tank. Install hand rails on Hak deck. Unload shaker tank and set same.;Unload and set-stairs; unload the rest of equipment. Set centrifugal pumps x2 and headers.;M/u centrifugal pumps and headers t/shaker tank, simop-install service line brackets and install service lines. Set shaker roof. 6/9/2022 Work on gas alarm installation. Fabricate/install stairs, landings, and handrails around shaker tank and from HAK rack deck to 151. Coil, secure and plug in electrical service connections to rig from jack up.;cont. install ST-80 socket and fit beaver slide extension.;Cont. fabricate/install stairs, landings, and handrails around shaker tank and from HAK rack deck to 151. Coil, secure and plug in electrical service connections to rig from jack up.;Begin welding out beaver slide extension. Work boat-off load mud product, vacuum unit, spot mud shack and misc. equipment.;Cont. fabricate/install stairs, landings, and handrails around shaker tank and from HAK rack deck to 151. Coil, Secure and plug in electrical service connections to rig from jack up.;Welding out beaver slide extension. Pulling power cords from shaker tank t/bang board under Hak rack. Install cement line from rig t/Spartan. 6/10/2022 Continue to fabricate/install stairs, landings, and handrails. Continue hook up service lines. Continue hook up gas detection system . Power up rig and test same. Rig up overboard line from shakers. Rig up secondary BOPE panel and install 80gal accumulator bottle on rig.;Continue to fabricate/install stairs, landings, and handrails. Secure HAK rack green iron to deck with clamps. Offload boat, take on fuel and water. Weld flange on flow line. Install flow line to shakers. 6/11/2022 Continue to fabricate/install stairs, landings, and handrails. Continue and finish fabricate of flow line . Install ST-80 pipe handler and work on plumbing for same. Continue work on beaver slide sling access walk way. install test pump on rig floor. House cleaning;Continue install and test gas detection system. Start r/up of Pason rig watch system. Boat unable to Load pipe and needed equipment @ dock due to wind and seas;Set beaver slide w/ sling access walkway and catwalk in position. Finish installation of stairs over green iron on HAK rack base. Route service lines away from stair base and clear walkway. Clear decks for drill pipe.;Hold PJSM and stage tools and equipment in BOPE deck and cellar. ND dry hole tree and NU 11" 3M tubing spool.;Dress upper and lower rams with 2- 7/8" x 5" VBRs. Dress middle rams with blind rams. NU high pressure riser. 6/12/2022 Continue nipple up Bopes . House clean all work areas and prep loads for boat . Still no boat or chopper weather in. Re-work beaver slide sling access . Continue r/ up Pason rig watch system . Finish testing gas detection system.;House clean all work areas and prep deck for boat. Straighten landings and stairs. Continue to rig up Pason system. Grease choke manifold valves.;Work Boat: Offload short high pressure riser, pipe bucket and pipe stanchions. Offload 250 jts of 4" DP, 14 jts of 4" HWDP, 9 DC, MWD tools, and mud product. Take on drill water from boat and transfer fuel from platform. Install short high-pressure riser. Nipple up BOPE stack. Torque bolts 6/13/2022 Continue to nipple up BOPE. Make up choke and kill lines to stack and XO to Spartan 15M equipment. Make up remainder of high-pressure mud line and route hoses over the top of the shaker tank.;Fill lines and tanks with water. Walk through lines and check connections for leaks. Verify operation of shakers and agitators on shaker tank. Repair leaks on feed pump lines on shaker tank transfer pumps. Calibrate tank volumes with Pason system. Install clamps and secure high pressure mud line.;Continue to fix leaks on transfer tank lines and Pit 1. Change saver sub and top drive dies from CDS40 to XT39. Build test joint assemblies. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-09A North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00030 NCIU A-09A Drilling Spud Date: 6/14/2022 Continue and finish weld out of 3'x3' Patch on port side of Jack up Mud tank #1. Continue repair leaks on jack up tanks HP isolation valve , 10" and couple 8" butterfly butter fly valve & repair leaks on scalper tank transfer pump #1 suction line . Change out bell guide Held pre-spud meeting.;Welders continue and finished beaver slide pipe bucket re-work and install. Re flood test Jack up Pit # 1 Still leaking drain same and install 2nd 2' x2' patch.;Continue and finish 2nd patch on mud tank #1 and re flood test same good. Reassemble scalping tank transfer pump #1 Suctions line and flood test good and trouble shoot Pumps poor performance Impeller good motor wrong rpm for application chase new motor. Function test bopes install 4";test jt and exercise annular element flood stack and retighten riser and r/up test equipment and shell test Bope t/ 250/3000 psi on chart good.;Good shell test and test on tubing spool break - 250- 3500 psi for 5/5 charted min. Pull lower test plug. Make up and install upper test plug with 4" test joint. Test with upper rams, flange between HCR and manual valve on Choke side leaking - tighten and re-test good.;Work Boat: Offload cement pods and air compressor. Transfer cement to silos on rig and backload pods. Take on fuel and water to platform.;Continue to test BOPE with 4" test joint. Work and re-test Choke HCR and Manual valves good. Perform drawdown test: 25 sec to 200 psi, 140 sec to full pressure. Annular closed in 24 sec. 6/15/2022 Still working two men short on one crew . Finish Pre- BOPE test with 4" test joint. 250L /3000H 5/5 on chart .R/dn test equipment. Install flow nipple and work on rig acceptance chk list. Flood test trip tank and flow nipple good. Flood test Jack up shaker tanks and lines and repair leaks.;Set test plug and r/up test equipment . Test Bop as per regulations 250L / 3000H 5/5 on chart witnessed by AOGCC inspector Austin McLeod;Work boat - Offload 3 cement pods and transfer 440 sks of tail cement to rig silo. Loadout empty pods and take on drill water.;Rig down test equipment, pull test plug. Secure stack in cellar. Re-Torque all bolts on BOP stack. Fabricate new mounting plate for transfer pump motor and install motor. Install mouse hole and 3-1/2" handling equipment.;Strap, pick up and make up nine 4-3/4" drill collars and rack back in the derrick. Verify ST-80 make up torque and rig tongs read the same on first connection running in. Change handling equipment for 4". 6/16/2022 Chg out crown -o- madic and test same. r/up test auto driller and set block height. install wear ring. PTSM Crew chg and short change New crew walk dn rig and Platform & orientation of both. flood test jack up shaker tanks and lines . Pump out stack and finish setting wear ring .;P/up rabbit and strap 14 jts of 4" HWDP. Cut and slip drill line and install directional drillers screen at drillers station.;Pick up, drift and strap 1100' of 4" Drill Pipe. Run power to directional driller screen at driller's station.;Work Boat: offload cement pod with weighted spacer, 4 iso's of fuel and 80' of 4" mud return hose. Install XT39 saver sub in top and verify function. Install 4" mud return line and commission primary mud return transfer pump (~16 bbl/min). Start building mud in pits. Check top drive make up torque.;Continue to pick up, drift and strap 4" drill pipe. Continue to build mud in pits. 6/17/2022 Running 2 men short. Continue to pick up, drift and strap 4" 14# S-135 XT39 drill pipe f/ 1533' t/ 2130' while monitoring well on trip tank for proper displacement. Continue to build LNSD WBM;Remove test pump from rig floor and install new cable for crown saver bell system and test same. Finish dressing #3 Mp. Continue to build LNSD WBM system;Resume p/up 4" 14# S-135 XT-39 DP f/ 2130' t/ t/ 2413' while monitoring well on trip tank for proper displacement . Continue to build LNSD WBM system;Pooh and rack back f/ 2413' t/ 430' P/up and m/up jars and rack back in derrick and Commission derrick and finish rig acceptance chk list and accept rig @ 1300 hrs;P/up Drift / c/out bha #1 = 6-1/8" bit + 7" scraper + Bit sub w/ float + 6-1/8" string mill + (9) 4-3/4" Dc's + XO + (2) jts HWDP + 4-3/4" jars + (12) jts HWDP = 750.09'. Continue to build LNSD WBM system;Resume p/up 4" 14# S-135 XT-39 DP f/ 745' t/1781' while monitoring well on trip tank for proper displacement. Continue to build LNSD WBM system;Continue to build LNSD WBM system. Install tarps around scalper deck shakers. Re-install rubber under high pressure mud line over scalper roof and secure mud line. Clean cellar area around BOP stack. Re-route and secure drain from rig floor.;Continue to build LNSD WBM system. Resume p/up 4" 14# S-135 XT-39 DP f/ 1781' t/ 3764' while monitoring well on trip tank for proper displacement.;Continue to build LNSD WBM system. Pull and rack back DP f/ 3764' t/ 2637' while monitoring well on trip tank for proper displacement.;Continue to build LNSD WBM system. Resume p/up 4" 14# S-135 XT-39 DP f/ 2637' t/ 4022' while monitoring well on trip tank for proper displacement. Tag cement at 4022' w/ 10 Klbs. 6/18/2022 Drain sand traps to Pit #2 (short system water ) Rack back 3 std and p/up 9 more jts of dp for total 6700' of DP in derrick and on hook and re tag @ 4022' w/ 10k. Continue to build LNSD WBM system;Polish off cmt f/ 4022' t/ 4031' & circ btm/up. Continue to build LNSD WBM system;Prime and test and trouble shoot MP#3 power issue. Continue to build LNSD WBM system;Pooh rack back f/ 4031' t/ 787'. Continue to build LNSD WBM system;Joint Platform / Jack up drill gas alarm on platform, secured well all reported to proper muster area all accounted for. Then abandon platform all went to proper Brucker and Debriefing;Open well resume pooh f/ 787' inspect and l/dn Bha #1 (ok). Continue to build LNSD WBM system;P/up bha #2 w/ WIS 5-3/8" Whip stock assy shallow hole test MWD ok, P/up M/up. Continue to build LNSD WBM system;Trip in the hole with Whipstock and milling assembly at 120sec/std to 4010'. Monitoring well on trip tank.;Make up top drive and orient whipstock with MWD. Set whipstock at 55 deg ROH and shear off with top of whipstock at 4010'. Bolt sheared at 40 Klbs.;Transfer water from platform shaker tank to Pit #2 on jack-up and prep pits for displacement to LSND. Hold PJSM with rig crew and Mud Engineer.;Displace well to 8.9 ppg LSND at 205 gpm, 600 psi, taking all returns to scalper tank.;Discharge water in scalper tank overboard and rig up to pressure test casing.;Pressure test 7" casing to 2200 psi for 30 charted min. Good test.;Mill 7" window per WIS representative f/ 4010' t/ 4017' 113 rpm, 5-7 Kft-lbs Torque, 236 gpm, 685 psi Set whipstock at 55 deg ROH and shear off with top of whipstock at 4010'. yp py ;Trip in the hole with Whipstock and milling assembly at 120sec/std to 4010'.p p gy ppg gp p g p ;Pressure test 7" casing to 2200 psi for 30 charted min. Good test.;Mill 7" window Whipstock set @4010'. -WCB 6/19/2022 Continue Mill window in 7" csg per WIS representative f/ 4017' t/ 4020' Mill formation t/ 4041' . Ream and wash and dress window and Drift window with out Pump or rotation (Clean, no drag) Continue mill formation f/ 4041' t/ 4051' @ 240 gpm @ 750 psi, 90 rpm 5-7k TQ, up/dn/rot = 100/90/95k;Pull into shoe @ 4005' circ btm and even MW @ 9,0 ppg flush choke and kill line to clear any metal shaving build up,;R/up to preform F.I.T. Applied 1080 psi w/ 2.2 bbls pump and achieved 15.12 EMW w/ TVD of 3390' and 9.0 ppg mud weight (see test sheet);Rih t/ 4051' Pump around 30 bbl high vis sweep w/ No increases of Iron shavings w/ total of 39# of iron recovered;Pump dry job and Had troubles braking out of Top drive and damaged saver sub and l/dn damaged jt;Pooh and rack back in derrick f/ 4051' and lay down mills. Mills look good. Lead mill 1/16" under-gauge, both dress-off mills in-gauge. TOW = 4010', BOW = 4020';Change out saver sub and grabber dies on top drive. Pull, repair and re-install derrick board winch. Change out leaking fittings on ST-80. Remove nozzles from 2 gun lines in scalper tank to help with equalizing flow in and flow to rig shakers.;Modify stairs leading from top of scalper tank to deck under HAK rack to eliminate hazard created by large step over green iron.;Make up BHA #3, 1.5° motor assembly t/ 480'. Surface test MWD - good.;Trip in the hole with BHA #3 f/ 480' t/ 4051' while monitoring the well on the trip tank. Orient motor, no drag observed running through window w/ pumps off. MW in/out = 9.0 ppg LSND;Drill per DD f/ 4051' t/ 4155' (104' at 26 fph ave rop) 268 GPM, 1200 PSI, 60 RPM, 3-4 Kft-lbs Torque PU 100 Klbs, SO 90 Klbs, ROT 95 Klbs. MW in/out = 9.0 ppg LSND Max gas - 21 units;Inlet Water Used Daily (bbl): 581 Inlet Water Used Cumulative (bbl): 581 Discharge Daily (bbl): 330 Discharge Cumulative (bbl): 330 Metal Recovered Daily (lbs): 39 Metal Recovered Cumulative (lbs): 39 6/20/2022 Continue Directional Drilling 6-1/8" hole per DD f/ 4155' t/ 4252' @ 268 GPM, 1200 PSI, 60 RPM, 3-4 Kft-lbs Torque. PU 100 Klbs, SO 90 Klbs, ROT 95 Klbs. MW in/out = 9.0 ppg LSND. Max gas - 58 units, Slow pump rates;Circ. high vis sweep around while rotating and reciprocating pipe @ 40 rpm, 3k TQ, 272 gpm @ 1250 psi. Sweep back on time w/ 10 % increase. Flow chk static . pump dry job;Pooh wet and rack back in derrick f/ 4252' t/ Bha w/ proper displacement;L/dn and inspect Bha #3 re-run bit graded 1-1-ingage;Clear and clean floor and full service rig and continue trouble shoot mud pump #3 power issue only running one man short;P/up Bha #4, 6-1/8" Hybrid bit, 1.5 deg AKO motor and triple combo t/ 542' per DD and MWD. Upload to MWD, shallow test tools and load sources.;Trip in the hole with BHA #4 f/ 542' t/ 3985', monitoring well with trip tank, proper displacement. Orient toolface to 57 deg ROH prior to running through window - no drag noted. Continue to trip in t/ 4252';Drill per DD f/ 4252' t/ 4593' (341' at 45.5 fph ave rop) 296 GPM, 1580 PSI, 80 RPM, 6 Kft-lbs Torque PU 100 Klbs, SO 90 Klbs, ROT 95 Klbs. MW in/out = 9.0 ppg LSND Max gas - 256 units Distance to wp05: 24.67', 21' Low, 12' Left;Inlet Water Used Daily (bbl): 28 Inlet Water Used Cumulative (bbl): 609 Discharge Daily (bbl): 22 Discharge Cumulative (bbl): 352;Downhole Losses Daily (bbl): 0 Downhole Losses Cumulative (bbl): 0 Metal Recovered Daily (lbs): 13 Metal Recovered Cumulative (lbs): 52;Casing pressures at 00:00: 10-3/4" x 7": 190 psi 16" x 10-3/4": 3.5 psi Continue Directional Drilling 6-1/8" hole per DD f/ 4155' t/ 4252' @ @ ppg Applied 1080 psi w/ 2.2 bbls pump and achieved 15.12 EMW w/ TVD of 3390' and 9.0 ppg mud weight Continue mill formation f/ 4041' t/ 4051' Continue Mill window in 7" csg per WIS representative f/ 4017' t/ 4020'Mill formation t/ 4041' p Milled window @4020'. Milled into formation to 4051'. Performed FIT to 15.12 EMW. gg ;Drill per DD f/ 4051' t/ 4155' pp ;R/up to preform F.I.T. Drilling liner hole. -WCB pgg ;Drill per DD f/ 4252' t/ 4593' 6/21/2022 Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 4593' t/ 4854' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 took 30 bbl loss @ 4651-4686' slowed pump rate drill through pumped 15 bbl high sweep around while drilling @ 4798';Back on time w/ 15% increase 261' at 34.8 fph ave rop) MW in/out = 9.0 ppg LSND 293 GPM, 1658 PSI, 80 RPM, 6-7 Kft-lbs Torque, WOB 5-7k PU 105 Klbs, SO 90 Klbs, ROT 95 Klbs. Max Gas = 85 units;Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 4854' t/ 5064' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 210' at 46.6' fph ave rop) MW in/out = 9.0 ppg LSND 286 GPM, 1550 PSI, 80 RPM, 5-6 Kft-lbs Torque, WOB 5-7k PU 100 Klbs, SO 90 Klbs, ROT 95 K;Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 5064' t/ 5111' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 210' at 46.6' fph ave rop) MW in/out = 9.0 ppg LSND 286 GPM, 1550 PSI, 80 RPM, 5-6 Kft-lbs Torque, WOB 5-7k PU 110 Klbs, SO 90 Klbs, ROT 95 K;Rig hand noticed a counter sunk bolt holding the cover plate for the dog knot on the draw works was backed out and bent and had damaged the drill line. Kept bolck high enough to keep 10+ wraps past the damaged line and circ. B/U.;Hung off blocks and top drive and slipped/cut 700 plus ft of drill line. Replaced draw work dog knot cover bolt, torqued and lock tight in.;Back ream 1 std. Pulled 180k to break over, 110k up wt, 90 dwn wt, 260gpm, 25.5% flow, 1180psi std pipe, 75rpm, 8k trq off btm. pump 25bbl, 10.5ppg dry job. POOH on elevators f/4973' t/3935'. 2k over pull when stabilizer went thru the window, no other issues.;Re-check bolts on Deadman and draw works dog knot cover. Service/Grease rig.;RIH on elevators t/5111', no issues.;Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 5111' t/xxxx control drilling @ 65FPH max, mad passing slides and back reaming connection X2 . Pump hi-vis sweep @ 5130';Distance to well plan-6.78ft 1.15ft low 6.68ft right;Inlet Water Used Today (bbl): 47 Inlet Water Used Cumulative (bbl): 656 Discharge Today (bbl): 411 Discharge Cumulative (bbl): 763;Downhole Losses Daily (bbl): 0 Downhole Losses Cumulative (bbl): 0 Metal Recovered Daily (lbs): 13 Metal Recovered Cumulative (lbs): 52;Casing pressures 10-3/4" x 7": 200 psi 16" x 10-3/4": 3.5 psi 6/22/2022 Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 5226' t/ 5723' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 w/ no losses noticed. Haliburton Transferred Tune spacer from transport to silo and preformed maintenance on unit;flooded lines and tested high pressure cement line t/ rig floor 250L/5000H ok and finish drifting 4-1/2" csg . and went over recent incidents w/ crews at PTSM.;Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 5723' t/6008' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 w/ no losses noticed. shoot survey.;226gpm, 1350psi, 75spm, 4-5k trq, 3-4k wob, p/u wt.115k, s/o wt.90k, rot wt.100k. Distance to wp05= 16.31' 8.45' LOW, 13.95' Left.;Monitor for loss's before POOH f/bit run. 0.25 loss per/hr+-.;Circulate B/U; 261gpm, 1450psi,. Spot 50bbls LCM pill w/Steelseal and Baracarb on bottom@6008'. get SPR's.;SPR pump#1 -20spm/500psi, 30spm/575psi, 40spm/600psi. SPR pump #2-20/500, 30/575, 40/680. @6005MD, 4328TVD, 9.1ppg LSND.;POOH f/6008 t/3930', monitoring fill on the TT. no issue pulling thru the window @4010'. Cont. POOH f/3930' t/BHA.;Service BHA as per DD/MWD, c/o bit.;Inlet Water Used Today (bbl): 80 Inlet Water Used Cumulative (bbl): 736 Discharge Today (bbl): 48.3 Discharge Cumulative (bbl): 811.3;Downhole Losses Daily (bbl): 0 Downhole Losses Cumulative (bbl): 0 Metal Recovered Daily (lbs): 13 Metal Recovered Cumulative (lbs): 52;Casing pressures 10-3/4" x 7": 360 psi at 2300hrs w/pumping 16" x 10-3/4": 5 psi Distance to well plan-6.78ft 1.15ft low 6.68ft right 6/23/2022 Work bha #4 as per DD/MWD, c/o bit and graded same 1-1- in P/up M/up new bit and re-run Bha #4 triple combo for Bha #5.;RIH w/ Bha # 5 Rih slow t/ 2806' went to kelly up and during torque sequence. Top drive starting spinning backwards at high rate of speed and tongs caught and slapped a floor hand in elbow and knocking him down before he could get out of the way.;Took hand to medic and safety stand down while Mechanic, electrician and tool pusher trouble shoot TDS system and attempt to re-create issue . unable to recreate scenario electrically, Mechanically or human error and discuss issue w/ town.;Resumed rih t/ 3936' and service rig.;Chg out saver sub, while electricians trouble shoot Top Drive electrical panel. monitor well on T.T.;exit window ok. RIOH slow t/ +- 5600' brk circ and wash and ream thru LCM pill t/ Btm @ 6008'.;Continue Drill 6-1/8" directional hole per DD and wp#5 f/6008' t/6350' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 w/ no losses noticed. shoot survey.;230gpm, 1450psi, 2-5k wob, 78rpm, 4-5k trq, 118k p/u wt, 90k s/o wt, 100k rot wt., 20.9% flow.;Inlet Water Used Today (bbl): 12 Inlet Water Used Cumulative (bbl): 748 Discharge Today (bbl): 121.3 Discharge Cumulative (bbl): 932.6;Downhole Losses Daily (bbl): 0 Downhole Losses Cumulative (bbl): 0 Metal Recovered Daily (lbs): Metal Recovered Cumulative (lbs): 52;Casing pressures 10-3/4" x 7": 210 psi at 0000hrs w/pumping 16" x 10-3/4": 5 psi Distance to well plan-19.97ft 16.16ft low 11.17ft right Drilling liner hole. -WCB q ;Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 5064' t/ 5111' pp ;Continue Drill 6-1/8" directional hole per DD and wp#5 f/6008' t/6350' Rig hand hurt from top drive malfunction. Drilling liner hole. -WCB ;Continue Drill 6-1/8" directional hole per DD and wp#5 f/ 4854' t/ 5064' gp ;Continue Drill 6-1/8" directional hole per g DD and wp#5 f/ 5723' t/6008' Continue Drill 6-1/8"directional hole per DD and wp#5 f/ 4593' t/ 4854' Drilling liner hole. -WCB Continue Drill 6-1/8"directional hole per DD and wp#5 f/ 5226' t/ 5723' pp p Top drive starting spinning backwards at high rate of speed and tongs caught and slapped a floor hand inyp g q q p gp g g p g g pp elbow and knocking him down before he could get out of the way.;Took hand to medic and safety stand down while Mechanic, electrician and tool pusher ggy y p trouble shoot TDS system and attempt to re-create issue . unable to recreate scenario electrically, Mechanically or human error and discuss issue w/ town.; Drill 6-1/8" directional hole per DD and wp#5 f/ 5111' t/xxxx 6/24/2022 Continue Drill 6-1/8" directional hole per DD and wp#5 f/6350' t/6592' control drilling @ 65FPH max, mad passing slides and back reaming connection X2 w/ no losses noticed.;Drill 6-1/8" directional hole per DD and wp#5 f/6592' t/6800' control drilling, loss's encountered @6649' and since approx. 25bph and slowing. Slowed pumps f/230gpm t/200gpm and adding LCM to mitigate. Losses stopped at 0430hrs, approx. 185bbl loss.;200gpm, 1300psi, 18.3% flow, 10-15wob, 78rpm, 5-7 k torq, 120=p/u wt, 90k=s/o wt, 102k=rot wt. Distance to WP#05: 44.04' Projected to bit: 43.01' high / 9.49' left;Inlet Water Used Today (bbl): 97 Inlet Water Used Cumulative (bbl): 845 Discharge Today (bbl): 98.4 Discharge Cumulative (bbl): 1031 Daily down hole loss (bbl): 107 Total down hole loss (bbl): 125.6;metal collected=1#, total metal collected=54# Ann. pressure's: 16"x 10-3/4" / 10-3/4"x 7" 1500hr=5psi / 310psi 2000hr=4psi / 320psi 2330hr=5psi / 300psi 6/25/2022 Continue Drill 6-1/8" directional hole per DD and wp#5 f/6800' t/6885'. Plugged jet cleared. Very streaky and slow drilling w/ weight stacking while sliding, added lube +- 1% by volume. Mad passing slides and back reaming connection X2 . Pumping LCM sweeps around to manage losses;247 GPM @ 1781 psi , WOB 2-25k @ 80 rpm @ 5k TQ Up wt @ 118k, Dn wt @ 90k , Rot wt @ 105k Max gas @ 20 units ECD Max @ 10.27 , Annulus 7" x10-3/4" @ 340 psi. MW @ 9.1 ppg and 44 vis, K-revs @542.;Continue Drill 6-1/8" directional hole per DD and wp#5 f/6885' t/6950'. Very streaky and slow drilling w/ weight stacking while sliding, added lube +- 1% by volume. Mad passing slides and back reaming connection X2 . Pumping LCM sweeps around to manage losses.;Shoot survey and Circ btm up while mad passing slide and spot 55 bbl LCM pill monitor static hole w/ slight seepage.;Pooh on elevators wet f/ 6950' t/3940' inside the window, pump out T.T., monitor well-slight seepage.;Cont. POOH f/3940 t/114'. Monitor well on T.T.;Clean floor f/wet trip, hold pre-job f/BHA, unloading radio- active sources and down load tools. monitor well on the T.T.;Cont. BHA, POOH t/ bit and c/o same; (Bit grade: pdc 1-1-wt-a-x-1-bu-bha / roller cone 2-1-cd-1-f-1- pn-bha. ) c/o TM/HOC, up load tools and shallow pulse test. Load radio-active sources. monitor well on the T.T. Run in HWDP.;P/U 18jts. 4" XT-39 DP.;Distance to well plan: 63.03' Projected to bit: 61.92' High / 11.77' Left;3# metal recovered from magnets today, total 57# recovered. Ann. Pressures: 1300hrs-16"x 10-3/4"=5psi, 10-3/4"x 7"=330psi 2300hrs-16"x 10-3/4"=5psi, 10-3/4"x 7"=135psi;Inlet Water Used Today (bbl): 409 Inlet Water Used Cumulative (bbl): 1,254 Discharge Today (bbl): 12.2 Discharge Cumulative (bbl): 1043.2 Daily down hole loss (bbl): 285.5 Total down hole loss (bbl): 411.1 6/26/2022 Continue RIH and P/U 18jts. 4" XT-39 DP and repair failed Brake cooling sea water line.;Rih slow out of derrick t/ 3934' and fill pipe @ 2901'.;Service rig. Grease traveling equipment and install new bolts in drill line cover plate on DWK drum and lock tight same. Install ST-80 extend plate while monitoring losses on trip tank @ 1/2 BPH.;Resume RIH on elevators Slow f/ 3934' w/ no issues @ window t/set dn @ 4649' unable to work by same kelly up and wash and ream t/ 4680' resume rih on elevators took weight @ 6011', 6053' and 6191 and wipe all clean continue Rih t/ 6483' w/ no issue.;Wash and ream and stage up pump rate and warm mud f/ 6483' t/ 6950' w/ high gas of 103 units and high ECD of 10.7.;Continue Drill 6-1/8" directional hole per DD and wp#5 f/6950' t/7480' control drilling @ 65FPH max, mad passing slides and back reaming connection X2. 240gpm, 1500psi, 2-5k wob, 72 rpm, 5-7k torq, 120k P/U wt, 90k S/O wt, 105k Rot wt.;Distance to well plan: 39.55' Projected to bit: 38.38' High / 9.54' Left;total 57# metal recovered. Ann. Pressures: 1800hrs-16"x 10-3/4"=5psi, 10-3/4"x 7"=130psi 2300hrs-16"x 10-3/4"=5psi, 10-3/4"x 7"=230psi;Inlet Water Used Today (bbl): 52 Inlet Water Used Cumulative (bbl): 1,304 Discharge Today (bbl): 15.9 Discharge Cumulative (bbl): 1059.1 Daily down hole loss (bbl): 57.9 Total down hole loss (bbl): 469 6/27/2022 Continue Drill 6-1/8" directional hole per DD and wp#5 f/7480' t/TD @ 7550' control drilling @ 65FPH max, mad passing slides and back reaming connection X2. 240gpm, 1500psi, 2-5k wob, 72 rpm, 5-7k torq, 120k P/U wt, 90k S/O wt, 105k Rot wt.;Pump flagged sweep around Back 10 bbls late. Lost DWK power trouble shoot same bring Gen #7 on line and stand alone SCR and restored power back to DWK, shoot TD survey.;Pooh on elevators slow t/ 3941' with no issues w/ 7.3 bbls over calculated displacement. found bad box and l/dn and replace joint ( will chk pin on way in hole).;Service rig and trouble shoot DWK power issue (found bad crimp w/ burnt wire), cut and re crimp same while monitoring hole on trip tank w/ 1/2 BPH loss rate.;Rih slow t/ 6012' w/ no issue chk pin from previous bad box & l/dn jt and replace same and fill pipe. Continue Rih slow tag btm @ 7550' w/ no issues.;Brk circ and stage up pump rate & circ btm /up w/ high gas of 75 units and high ECD of 10.64. Pump 55bbl lcm pill and and over displace +- 300' off btm.;L/dn single to chg brks. Pooh slow w/ no issue t/4567' drop steel1.91" drift w/100' wire tail. Monitor well on TT f/15min @3900'.;Cont. pooh slow w/ no issue t/550' , monitoring fill on the TT.;BHA, stand back HWDP, retrieve steel rabbit, L/D flex collars, retrieve radioactive sources, Down load data from MWD/LWD, rinse motor out x2.;Distance to well plan: 19.21' Projected to bit: 17.94' High / 6.86' Left;total 57# metal recovered. 0#'s today. Ann. Pressures: 2300hrs-16"x 10-3/4"=4psi, 10-3/4"x 7"=110psi;Inlet Water Used Today (bbl): 56 Inlet Water Used Cumulative (bbl): 1,360 Discharge Today (bbl): 22.5 Discharge Cumulative (bbl): 1081.6 Daily down hole loss (bbl): 50.6 Total down hole loss (bbl): 519.6 Continue Drill 6-1/8"directional hole per DD and wp#5 f/6800' t/6885'. TD'd liner hole @7550'. -WCB gpp ;Continue Drill 6-1/8" directional hole per DD and wp#5 f/6950' t/7480' Continue Drill 6-1/8"directional hole per DD and wp#5 f/7480' t/TD @ 7550' p@ @ @ g@ ;Continue Drill 6-1/8" directional hole per DD and wp#5 f/6885' t/6950'. V gp Continue Rih slow tag btm @ 7550' w/ no issues. Continue Drill 6-1/8"directional hole per DD and wp#5 f/6350' t/6592' ;Drill 6-1/8" directional hole per DD and wp#5 f/6592' t/6800' p p Drilling liner hole. -WCB Drilling liner hole. -WCB Drilling liner hole. -WCB 6/28/2022 Chg out TDS pipe handler and test and set sequence.;P/up m/up 4-1/2" test jt set test test plug Attempt r/up testing equipment found mis- marked XO.;Chase correct XO and weathered in. Simop- clean rig floor and under beaver slide area from wet trips. Transfer mud and clean pit #3. R/U casing fill up line.;XO arrived on helo, cont. r/u test assy, fill stack w/fresh water. Test annular, top and bottom 2-7/8 x 5 variable rams t/300psi/3000psi for 5minuts each on chart. As per AOGCC and Hilcorp test procedure, all test passed w/no issues.. R/D test equipment.;R/U Weatherford casing equipment- slips, elevators, and 4.5" handling equipment. Set Baker tool box, centralizers and pup jts on rig floor.;P/U shoe track as per detail on tally, baker lock connections and check float equipment function-good. P/U and run 4.5" 12.6# L-80 DWC-C/HT liner as per detail running order w/ RA tag @ 500/1000" and pup jts every 1000', f/surface t/3832'. TIW on floor and functioning.;Monitoring displacement on the trip tank, filling every jt. and topping off every 10jts.;P/U 5"x 7" L-80 HRD-E Liner setting Sleeve, as per Baker rep.;Kelly up on first std and circ. 1.5 liner vol. Attempt to get rot wt., top drive issues-Kelly valve hoses crossed and bell guide rubbing. c/o bell guide at report time.;Distance to well plan: 19.21' Projected to bit: 17.94' High / 6.86' Left;total 57# metal recovered. 0#'s today. Ann. Pressures: 1300hrs-16"x 10-3/4"=4psi, 10-3/4"x 7"=25psi;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 1,360 Discharge Today (bbl): 0 Discharge Cumulative (bbl): 1081.6 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 519.6 6/29/2022 Trouble shoot IBOP open/close position. Actuating backwards, check all connections and swap supply/return lines to correct issue.;Change dies in die carrier, re- adjust grabber lift cylinder stop block for proper grabber box spacing. Simop-P/U and M/U cement head and torque XO's for 4"DP. R/U cement wash up line, clean and clear rig floor.;TIH f/3814' t/6544' @ 2-3min. std. Monitor displacement on TT. Good.;Circ. B/U, staging up pumps from 1-4bpm. No Losses.;Cont. TIH f/6544' t/7201' @2-3min. std. Monitor displacement on TT.;Dies broke in grabber. C/O grabber die blocks on Top drive T/4", Install new dies and bell guide.;Cont. TIH f/7201' t/7550' @2-3min. std. Monitor displacement on TT. Tag TD at 7557' .;Circ. B/U staging up pumps from 1-4bpm. Reciprocating pipe. No Losses.;R/U Baker cement head assy. Break circ. w/rig pumps. Line up t/Halliburton and break circ., test lines to 250-5000psi-good.;Cement 4.5" 12.6# L-80 DWC-C/HT liner at 7550' as per plan. pump 25bbl 10.5# spacer, followed by 95bbl 15.3# ( 440 SX) cement, dropped plug, flushed lines w/10bbl water and displace with 97bbl of 9.2# mud. Did not bump. Discuss with DE.;Because we saw the latch 3 bbl late we decided to Pumped shoe track plus 1 bbl. Bumped plug at 100.5 BBL.Held 500 over. Bled down & Checked floats-good. bled back 3/4bbl.;Set down t/50k, pressure up t/4500psi w/Halliburton, bleed off and p/u t/75k-free. Line up t/pump w/rig, pressure up t/1000psi, p/u 16'-seals out, catch pressure drop with rig pumps @800psi, pull up above liner and circ. out cement and 1400psi, 462gpm.;Spacer back at 1000stks, overboard 29.4bbl spacer, 21bbl cement and 21.7bbl contaminated mud. 30 BBL Losses during cmt job calculated.;L/D cement equipment. Flush surface surface equipment.;Hang off string on test plug and R/U test equipment for BOP full test. Shell test @2345hrs.;Test BOPE and choke manifold to 250/ 3000 psi w/4.5" and 4" jts t/300-3000psi.;Distance to well plan: 19.21' Projected to bit: 17.94' High / 6.86' Left;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 1,360 Discharge Today (bbl): 93.1 (20 bbl wash up, 29.4 bbl Spacer, 21 bbl cement slurry, 22.7 bbl contaminated mud) Discharge Cumulative (bbl): 1,174.7 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 519.6 6/30/2022 Test 13-5/8 5k BOPE and choke manifold to 250/ 3000 psi w/4.5" and 4" jts t/300-3000psi, 4" dart and floor valves, accumulator draw down, H2S and gas LEL detection system.;Verify pre-charge on bottles. Function test BOP's f/driller remote emergency station and accumulator. as per AOGCC and Hilcorp policy, test witnessed by Guy Cook.;R/D test equipment and unhang string from test plug.;POOH f/3747' , L/D liner running tool as per Baker Rep.. Monitoring fill on TT.;P/u wear ring running tool and set wear ring, P/U Liner polish mill and XO, as per Baker rep. RIH w/ Polish mill assy. t/3640' kelly up and wash down t/TOL @3747', up wt=80k, dwn wt=80k, rot wt=82k, 71gpm, 98psi, 30rpm, 3.7k trq.;Reciprocate and Polish on liner top as per Baker Rep., up wt=80k, dwn wt=80k, rot wt=82k, 71gpm, 88psi, 30rpm, 3.7k trq. ; Circ. B/U at 226gpm, 283psi, 23rpm, 3.7k trq.;POOH w/ polish mill assy. f/TOL 3737' t/ surface, L/D assy as per Baker Rep.. Monitor fill on TT.;P/U ZXP liner top packer as per Baker rep.;Service rig, R/U fill up line for filling pipe on TIH.;Distance to well plan: 19.21' Projected to bit: 17.94' High / 6.86' Left;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 1,360 Discharge Today (bbl): 0 Discharge Cumulative (bbl): 1,174.7 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 549.6 7/1/2022 RIH with baker seal assembly on 4'' Dp T/ 3726.;M/U TD & sting in to liner. Saw good indication of all seals engagement with 8 K Drag total. Set 10K dn wt. Pressure up down tubing to 1000 psi. Good. Pull out of seals and break connection to drop setting ball. Pump down at 2 bpm and ball on seat at 300 psi.;Bleed down pressure and sting in to seals with good seal drag. Set 10K down. Pressure up to 2500 psi and hole. Good. Pressure up to 3700 psi and saw ball seat shear. Pressure up to 4500 and hold for 5 min. Good.;Bleed down using choke and pull 10 k over on slips. Good. Set down to 65K and rot 20 turns to the right. 3K TQ. P/U and we are free of packer. Pull seals out of packer and free. Test liner lap and tubing to 2000 psi for 10 min good. Bleed down.;Displace well to FIW with sweep in front. Flush kill, Choke and clean trip tank. Dump interface.;POOH from 3700' T/ surface and L/D running tool. Inspect same and looked good. L/D jar stand. Jars to be sent in. Pull Wear bushing.;R/U Parker Csg service- power tongs and 4.5" handling equipment. M/U TIW valve on Csg swedge and hold pre-job w/all company's involved.;M/U seal assy on 1st jts, as per Baker Rep. and RIH P/U 4.5" 12.6# L-80 IBTM tbg f/surface t/33376'. R/U control line t/SCSSV and function test-good with Pollard Wireline. cont. RIH w/4.5" tbg t/3677'. Monitoring displacement on the TT.;P/U 2jts off deck and space out f/3677', t/3683', P/U and L/D 2jts. and install 5.68' pup below first jt under the hanger. P/U wt=75k, S/O wt=72k (Blocks=42k).;M/U landing jt, simop-terminating control line into hanger and re-pressurize line. Kelly up w/TD and slack off t/land out Hanger @3683' set dwn to Block wt of 42k, pressure up with mud pump t/260psi and P/U 9' and see seal pressure bleed off as per Baker Rep.;Spot 8.9+ KCL inhibited brine in the 4.5" x7" annulus, pump 135bbl at 160gpm, 90psi.;S/O 9' and Land Hanger on Talley depth @3683'md. R/U test chart recorder, test tbg t/1500psif/30min.-good, bleed off pressure and test 4.5" x 7" annulus t/2000psi f/30min.-good. R/D test equipment and L/D landing jt.;Inlet Water Used Today (bbl): 238 Inlet Water Used Cumulative (bbl): 1598 Discharge Today (bbl): 130.2 Discharge Cumulative (bbl): 1304.6 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 549.6 Pressure up down tubing to 1000 psi. Good. Pull out of seals and break connection to drop setting ball. Cleaned up liner top. -WCB g install 5.68' pup below first jt under the hanger. gg pg P/U Liner polish mill and XO, as per Baker rep. RIH w/ Polish mill assy. p p pull up above liner and circ. out cementpp p gp p p p p p gp p@ p p p and 1400psi, 462gpm.;Spacer back at 1000stks, overboard 29.4bbl spacer, 21bbl cement and 21.7bbl contaminated mud. 30 BBL Losses during cmt jobp calculated. p L/D liner running tool as per Baker Rep.g Installed ZXP liner hanger and seal assy. Tested liner lap. Installed tubing. Passing MIT-T & MIT-IA. -WCB ppj y ;P/U 5"x 7" L-80 HRD-E Liner setting Sleeve, as per Baker rep.; ;Reciprocate and Polish on liner top as per Baker Rep. pp y pp p Good. Pressure up to 3700 psi and saw ball seatpggg pp pp shear. Pressure up to 4500 and hold for 5 min. Good.;Bleed down using choke and pull 10 k over on slips. Good. Set down to 65K and rot 20 turns to the right.p 3K TQ. P/U and we are free of packer. ggpg ;M/U seal assy on 1st jts, as per Baker Rep. and RIH qp g qp p ;P/U shoe track as per detail on tally, baker lock connections and check float equipment qp ppj g p function-good. P/U and run 4.5" 12.6# L-80 DWC-C/HT liner as per detail running order w Test liner lap and tubing to 2000 psi for 10 min good. pp p Land Hanger on Talley depth @3683'md. p ;POOH w/ polish mill assy. f/TOL 3737' t/ surface, L/D assy as per Baker Rep.. pp p j ;M/U landing jt, RIH with baker seal assembly on 4'' Dp T/ 3726.;M/U TD & sting in to liner. Saw good indication of all seals engagement wyp g g Liner cement plug didn't bump at first, with the planned 97 bbls of mud - bumped after pumping 3.5 extra bbls mud. 21 bbls cement returned. Estimate of 30 bbls of cement losses. -WCB Running in the liner and the Baker HRDE liner setting tool. -WCB @ p gg ;Cont. TIH f/7201' t/7550' @2-3min. std. Monitor displacement on TT. Tag TD at 7557' ;R/U Baker cement head assy. @ ppgpp ;Cement 4.5" 12.6# L-80ygp p p pg DWC-C/HT liner at 7550' as per plan. pump 25bbl 10.5# spacer, followed by 95bbl 15.3# ( 440 SX) cement, dropped plug, flushed lines w/10bbl water and y pp p p p y ( ) pp pg displace with 97bbl of 9.2# mud. Did not bump. Discuss with DE.;Because we saw the latch 3 bbl late we decided to Pumped shoe track plus 1 bbl. Bumped pp plug at 100.5 BBL.Held 500 over. Bled down & Checked floats-good. pp gp p test tbg t/1500psif/30min.-good, bleed off pressure and test 4.5" x 7" annulus t/2000psi f/30min.-good. g ;POOH from 3700' T/ surface and L/D running tool. pgp g 7/2/2022 Break out TDS from landing joints, break down and L/D same. Vault Rep. install BPV.;Pump out Brine from stack and riser, N/D bell nipple and service lines. Remove koomey lines f/BOP's, Break bolts on choke /kill lines, DSA t/well and BOP riser.;Remove Remove kill line from stack and secure BOP out of the way f/skidding. Remove 13-5/8" riser and L/D on Hak Deck.;P/U and M/U tree t/well head, install TWC. Test hanger void t/5k psi f/30min.-good. Un-able to get a test on the tree below the bottom master valve, TWC believed to be leaking by, Consulted w/Hilcorp well head rep. and Day Co.Man-;decision made t/proceed with move to A-10B and test tree off line tomorrow, with new TWC valve.;R/D flow line, install skidding jacks and skid west towards A-10B, suspend beaver slide and walk way to floor above Hak deck for lateral skidding. North/south jacks at rail end, leap frog jack to move rig north 8ft.;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 1598 Discharge Today (bbl): 156.7 Discharge Cumulative (bbl): 1461.3 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 549.6 Activity Date Ops Summary 8/5/2022 Move over from NCIU A-10B, Stab on well, MU tool string, PT 250L/1500H Open TRSSSV. RIH and sat down at liner hanger @ 3,730', work tools through Sit down at 4,862', work tools, continuously sit down 6,400-7,400, tag at 7408,PU to 6,000', RIH to 7,408 Clean drift. POOH, 1000lb overpull at liner top. POOH and SDFN. Prep tools for CBL 8/6/2022 Morning meeting, PJSM, PTW Pick up wire and lube Open Swab, RIH with CBL tool string.,Free Pipe Cal at 2804'. Tag at 7,408' Log up find TOC at 4000'. Rig Down and move to A-11A. 8/10/2022 Mobilize crew and equipment to the Tyonek Platform. PTW and PJSM. Pick CTU equipment and stage on deck. Rigup and prep as possible. 2 of 3 boats arrived today. Last boat scheduled for tomorrow afternoon. 8/11/2022 Morning safety meeting. PTW. BOP test 250 psi low / 3000 psi high testing the full body, blind/shear rams, pipe/slip rams, and accumulator. MU riser and BOPs to the well. Stab pipe. 3rd and final boat loaded and on its way with fluid pump, Yellowjacket tools, and other misc. equipment. MU CTC and pull test to 10k. Secure equipment for the night. LDFN. 8/12/2022 Morning safety meeting. PTW. Finish staging and rigging up equipment that was delivered last night. PT N2 hardline to 250 psi and 3500 psi. MU lubricator.,Prime and fluid pack triplex. PT lines. Pickup injector. 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'. RIH to 7440' ctmd. Circulate 26 bbls of completion fluid to OTT. Attempt to send fluid to production, minimal fluid transferred. Continue circulating drilling mud out of well.,Bring on N2 with ~140 bbls in the OTT pumping at 1000-1200 scfm. Started POOH when we had 243 bbls in the OTT. Lay down injector, secure well. SDFN. CT work completed for A-09A. 8/13/2022 PTW. PJSM. Rig down BOPs and riser from A-09A and move over to A-11A. 8/18/2022 Morning safety meeting. PTW. Position EL unit and equipment. MU riser and lubricator. All guns are 2-7/8" HSC 6 spf and 60 deg phasing.,MU 20' gun. PT to 1500 psi. Open well and RIH. Pull correlation log, send to town. Make 8' shift per Geo making 7130' equal to 7138'. Perforate the Bel F mid 2 from 7327'-7347'. POOH. Pressure - 307 psi, no change. Lay down guns, all shots fired. Gun was clean and dry.,MU 14' gun. Arm and RIH. Pull correlation pass, send to town, on depth. Perforate the Bel F mid 1 from 7271'-7285'. POOH. WHP 307 - no change. Gun was clean and dry. All shots fired.,MU 10' gun. Arm and RIH. Pull correlation pass, send to town, on depth. Perforate the Beluga F upper from 7257'-7267'. POOH. WHP 307 - no change. Gun was clean and dry. All shots fired.,MU 20' gun. Arm and RIH. Pull correlation pass, send to town, on depth. Perforate the Bel E lower from 7207'-7227'. POOH. WHP 306 - no change. Gun was clean and dry. All shots fired.,MU 5' gun. Arm and RIH. Pull correlation pass, send to town, on depth. Perforate the Bel E mid 4 from 7176-7181'. POOH. WHP 305 - no change. Gun was clean and dry. All shots fired.,MU 5' gun. Arm and RIH. Pull correlation pass, send to town, on depth. Perforate the Bel E mid 3 from 7165-7170'. POOH. WHP 304 - no change. Gun was clean and dry. All shots fired. Install night cap. Notify production that EL is done for the day. SDFN. 8/19/2022 Safety meeting. PTW. Pickup lubricator and MU GPT. Well is flowing at 1.25 mmscfd and 135 psi. RIH and find fluid level at 7300' and some cooling signatures across the perforations. POOH. Send log to town.,MU 2-7/8" x 6' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga E mid 2 from 7141'-7147'. POOH. All shots fired. Gun was clean and dry. Pressures - 136,140,126,100. Flow rate stabilized at 1491 mcf and 196 psi.,MU 2-7/8" x 5' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Bel E mid 1 from 7069-7074'. POOH. Gun was clean and dry. All shots fired. Pressures - 194,195,173,159. Flow rate stabilized at 1882 mcf and 199 psi.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Bel E upper from 7036-7046'. POOH. Gun was clean and dry. All shots fired. Pressures - 196, 205, 186,171. Flow rate stabilized at 1909 mcf and 242 psi.,MU 2-7/8" x 20' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Bel D lower from 7007-7027'. POOH. Gun was dry, small amount of sand in the bullplug (sample collected). All shots fired. Pressures - 232, 250, 256,242. Flow rate stabilized at 1710 mcf and 260 psi.,MU 2-7/8" x 13' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B lower from 6678'-6691'. POOH. Gun was dry. All shots fired. Pressures - 257, 260, 257, 263. Flow rate stabilized at 1712 mcf and 260 psi.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B mid 3 from 6618'- 6628'. POOH. Gun was dry. All shots fired. Pressures - 256, 255, 255, 256. Flow rate stabilized at 1673 mcf and 256 psi.,MU 2-7/8" x 14' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B mid 2 from 6586'-6600'. POOH. Gun was dry. All shots fired. Pressures - 256, 491, 489, 479. Flow rate stabilized at 2288 mcf and 455 psi. Secure the tree. Turn well over to production to flow overnight. SDFN. n (LAT/LONG): evation (RKB): 50-883-20029-01-00API #: Well Name: Field: County/State: NCIU A-09A North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00030 NCIU A-09A Completion Spud Date: Prep tools for CBL Perforate the Beluga B mid 2 from 6586'-6600'. POOH. RIH with CBL tool string.,Free Pipe Cal at 2804'. Tag at 7,408' Log up find TOC at 4000'. gg Perforate the Beluga E mid 2p from 7141'-7147'. POOH. CBL shows TOC at ~4020'. -WCB Perforate the Bel F mid 2 from 7327'-7347'.p POOH. Perforate the Bel E upper from 7036-7046'. POOH. Perforate the Beluga B mid 3 from 6618'- 6628'. POOH. G 221-00030 NCIU A-09A Completion g Perforate the Bel E mid 4 from 7176-7181'. POOH. y Perforate the Bel E mid 1 from 7069-7074'. POOH. pgyg Perforate the Bel F mid 1 from 7271'-7285'. POOH. W g Perforate the Bel E lower from 7207'-7227'. Well is flowing at 1.25 mmscfd and 135 psi. Position EL unit and equipment. MU riser and lubricator. All guns are 2-7/8" HSC 6 spf and 60 deg phasing.,MU 20' gun. p gp g g g Perforate the Beluga F upper from 7257'-7267'. Perforate the Bel D lower from 7007-7027'. POOH. Perforate the Bel E mid 3 g from 7165-7170'. POOH. Perforate the Beluga B lower from 6678'-6691'. POOH. 8/20/2022 Morning safety meeting. PTW. Fire up equipment. Pickup lubricator and remove night cap. All perforations fired with the well flowing. Well is currently flowing at 1713 mcf and 434 psi.,MU 2-7/8" x 12' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B mid 1 from 6553'-6565'. POOH. Gun was clean and dry. All shots fired. Pressures - 551, 549, 549, 549. Flow rate stabilized at 1899 mcf and 549 psi.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B upper 3 from 6517'-6527'. POOH. Gun was clean and dry. All shots fired. Pressures - 553 - no change. Flow rate stabilized at 1902 mcf and 552 psi.,MU 2-7/8" x 9' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B upper 2 from 6463'-6472'. POOH. Gun was clean and dry. All shots fired. Pressures - 551, 558, 561, 562. Flow rate stabilized at 2007 mcf and 562 psi.,MU 2-7/8" x 20' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B upper 1 from 6423'-6443'. POOH. Gun was clean and dry. All shots fired. Pressures - 564 - no change. Flow rate stabilized at 1982 mcf and 564 psi.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A lower 2 from 6302'-6312'. POOH. Gun was clean and dry. All shots fired. Pressures - 564 - no change. Flow rate stabilized at 2011 mcf and 564 psi.,MU 2-7/8" x 15' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A lower 1 from 6266'-6281'. POOH. Gun was clean and dry. All shots fired. Pressures - 572, 574, 574, 575. Flow rate stabilized at 2032 mcf and 575 psi.,MU 2-7/8" x 20' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A mid from 6231'-6251'. POOH. Gun was clean and dry. All shots fired. Pressures - 577, 580, 580, 580. Flow rate stabilized at 2018 mcf and 580 psi.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A upper 2 from 6211'- 6221'. POOH. Gun was clean and dry. All shots fired. Pressures - 580 - no change. Flow rate stabilized at 2018 mcf and 580 psi.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A upper 1 from 6197'-6207'. POOH. Gun was clean and dry. All shots fired. Pressures - 582, 586, 588, 590. Flow rate stabilized at 2020 mcf and 591 psi. Secure the tree. Turn well over to production. SDFN. g Perforate the Beluga A upper 1 from 6197'-6207'. POOH. g Perforate the Beluga A lower 1 from 6266'-6281'. POOH. Perforate the Beluga A mid from 6231'-6251'. POOH. Perforate the Beluga B upper 3 from 6517'-6527'. POOH. Perforate the Beluga B upper g 2 from 6463'-6472'. POOH. Perforate the Beluga B upper 1 from 6423'-6443'. POOH. Perforate the Beluga A upper 2 from 6211'- 6221'. POOH. gyg Perforate the Beluga B mid 1 from 6553'-6565'. POOH. g Perforate the Beluga A lower 2 from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enjamin Hand Digitally signed by Benjamin Hand Date: 2022.07.06 16:10:28 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.07.06 16:26:17 -08'00' TD Shoe Depth: PBTD: Jts. 1 1 1 7 1 11 1 24 24 19 1 1 Yes X No X Yes No Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Lead 440 1.34 5 7.96 6,600.10 6,592.14 5x7HRD-E liner setting sleeve 5 3/4 Hyd521 4.5 liner pup jt 4 1/2 12.6 L-80 DWC-C/HT 7,052.70 4.5 liner jts 4 1/2 12.6 L-80 DWC-C/HT 452.60 7,052.70 6,600.10 7,384.90 7,094.23 4.5 liner w/RA tag in collar 4 1/2 12.6 L-80 DWC-C/HT 41.53 7,094.23 82.88 7,467.78 7,384.90 4.5 liner jts 4 1/2 12.6 L-80 DWC-C/HT 290.46 4.5 liner/baker locked 4 1/2 12.6 L-80 DWC x BTC 7,468.91 Landing Collar 5 BTC Baker 1.13 7,468.91 7,467.78 7,509.23 7,507.72 4.5 liner/baker locked 4 1/2 12.6 L-80 BTC 38.81 7,507.72 38.96 7,548.19 7,509.23 Float Collar 5 BTC Baker 1.51 4.5 liner/baker locked 4 1/2 12.6 L-80 BTC L-80 Weatherford 5" HRD-E Liner Setting Sleeve: comm no.H295-51-011 www.wellez.net WellEz Information Management LLC ver_04818br 1-centralizer on every full jt including shoe track=91 total. Tag Btm @ 7557'md x2. hyd521/DWC 3,764.12 3,762.99 3,746.99 LSND 15.3 95 Type of Shoe:Baker Casing Crew: CBL Bump Plug? 20:50 7/29/2022 3995' 7,550.007,550.00 CEMENTING REPORT Csg Wt. On Slips: 2100 21 CMT Bump press 9.2 4 87 1100 FI R S T S T A G E 10.5Tuned 25 100.5/97 Csg Wt. On Hook:120,000 Type Float Collar:Baker No. Hrs to Run:12 5,549.53 4,556.96 7.73 4,556.96 4,549.23 3,762.99 992.57 16.00 4.5 liner jts 4 1/2 12.6 L-80 DWC-C/HT 1.13 3,764.125 4.5 liner jts 4 1/2 12.6 L-80 4,549.23 7.74 L-80 DWC-C/HT 5,557.27 DWC-C/HT 785.11 4 1/2 12.6 4 1/2 12.6 L-80 DWC-C/HT 4 1/2 12.6 L-80 DWC-C/HT 6,550.794 1/2 12.6 L-80 DWC-C/HT 993.52 BTC Baker 1.81 7,550.00 7,548.19 5,557.27 5,549.53 41.35 6,592.14 6,550.79 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Shane Hauck Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NCIU A-09A Date Run 29-Jun-22 7,509.00 Floats Held LSND CASING RECORD County State Alaska Supv. Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 7550 FC @ Top of Liner 3747 4.5 liner pup jt 4.5 liner pup jt XO 5"Hyd 521-pin x 4.5"DWC pin Casing (Or Liner) Detail Float Shoe 4.5 liner w/RA tag in collar 4.5 liner jts 5 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW)ULGD\$XJXVW30 7R0LFKDHO+LEEHUW& &F5HJJ-DPHV%2*& 6XEMHFW5(%23(7HVW)RUP7\RQHN$$ $WWDFKPHQWV6FKOXPEHUJHU[OV[ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĂĚĚŝŶŐƚŚĞdĞƐƚdŝŵĞŽĨϱŚŽƵƌƐ;ďĂƐĞĚŽŶƚŚĞ^ƚĂƌƚͬ&ŝŶŝƐŚƚŝŵĞƐͿĂŶĚĐŚĂŶŐŝŶŐŽŶƚƌŽů ^ǇƐƚĞŵZĞƐƉŽŶƐĞdŝŵĞĨŝĞůĚƐƚŽϬ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉŝĞƐ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗DŝĐŚĂĞů,ŝďďĞƌƚͲ;ͿфDŝĐŚĂĞů͘,ŝďďĞƌƚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕ƵŐƵƐƚϭϰ͕ϮϬϮϮϱ͗ϮϴWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ŚĂĚ,ĞůŐĞƐŽŶфĐŚĞůŐĞƐŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗KWdĞƐƚ&ŽƌŵͲdǇŽŶĞŬͲϬϵͲϴͬϭϭͬϮϮ ,ĞůůŽ͕ ,ĞƌĞŝƐƚŚĞƚĞƐƚĨŽƌŵĨŽƌƚŚĞKWƚĞƐƚƉĞƌĨŽƌŵĞĚŽŶƚŚĞdǇŽŶĞŬǁĞůůͲϬϵŽŶϴͬϭϭͬϮϮ͘ >ĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͘ dŚĂŶŬƐ͕ DŝĐŚĂĞů,ŝďďĞƌƚ tĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌ ,ŝůĐŽƌƉůĂƐŬĂ ϵϬϳͲϵϬϯͲϱϵϵϬ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 1RUWK&RRN,QOHW8QLW$$ 37' 7KHLQIRUPDWLRQFRQWDLQHGLQWKLVHPDLOPHVVDJHLVFRQILGHQWLDODQGPD\EHOHJDOO\SULYLOHJHGDQGLVLQWHQGHGRQO\IRUWKHXVHRIWKHLQGLYLGXDORUHQWLW\QDPHG DERYH,I\RXDUHQRWDQLQWHQGHGUHFLSLHQWRULI\RXKDYHUHFHLYHGWKLVPHVVDJHLQHUURU\RXDUHKHUHE\QRWLILHGWKDWDQ\GLVVHPLQDWLRQGLVWULEXWLRQRUFRS\RIWKLV HPDLOLVVWULFWO\SURKLELWHG,I\RXKDYHUHFHLYHGWKLVHPDLOLQHUURUSOHDVHLPPHGLDWHO\QRWLI\XVE\UHWXUQHPDLORUWHOHSKRQHLIWKHVHQGHU VSKRQHQXPEHULVOLVWHG DERYHWKHQSURPSWO\DQGSHUPDQHQWO\GHOHWHWKLVPHVVDJH :KLOHDOOUHDVRQDEOHFDUHKDVEHHQWDNHQWRDYRLGWKHWUDQVPLVVLRQRIYLUXVHVLWLVWKHUHVSRQVLELOLW\RIWKHUHFLSLHQWWRHQVXUHWKDWWKHRQZDUGWUDQVPLVVLRQ RSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQG WKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:1 DATE: 8/11/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2220240 Sundry #322-438 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:NA Valves:250/3000 MASP:17 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 N/A NA Pit Level Indicators NA NA #1 Rams 1 1.75" BS P Flow Indicator NA NA #2 Rams 1 1.75" PS P Meth Gas Detector NA NA #3 Rams 0 N/A NA H2S Gas Detector NA NA #4 Rams 0 N/A NA MS Misc 0NA #5 Rams 0 N/A NA #6 Rams 0 N/A NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 N/A NA System Pressure (psi)2950 P Kill Line Valves 2 2"P Pressure After Closure (psi)2200 P Check Valve 0 N/A NA 200 psi Attained (sec)4 P BOP Misc 0 N/A NA Full Pressure Attained (sec)10 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer NA NA #1 Rams 10 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 0 NA Repair or replacement of equipment will be made within NA days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/9/22 1500 Waived By Test Start Date/Time:8/11/2022 9:00 (date) (time)Witness Test Finish Date/Time:8/11/2022 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger Donavan Thibeaux Hilcorp Alaska Michael Hibbert NCIU A-09A Test Pressure (psi): Michael.Hibbert@Hilcorp.com Dthibeaux2@slb.com Form 10-424 (Revised 08/2022) 2022-0811_BOP_Schlumberger1_NCIU_A-09A 9 9 9 99 9 9 9 9 9 MEU -5HJJ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________N COOK INLET UNIT A-09A JBR 08/18/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:5 4" and 4.5" test joints used for testing. Visual gas alarms found as yellow (methane) and red (H2S) is reverse what normal for Alaska rigs - not a regulatory reqt. Suggested they consider switching colors. The audible and visual alarms in the camp didn't work. The visuals were fixed and the camp audible and visual alarms were replaced with components that work with their current gas alarms system. HCR kill failed. The valve was cycled and flushed and passed the retest. Control systemr response times were checked and were as follows: Annular - 14.7 seconds, UPR - 10.5 seconds, LPR - 10 seconds, Blinds (simulated with UPR) 14.7 seconds, HCR kill - 1.5 seconds, HCR choke - 1.5 seconds. All (15) 11-gallon charge bottles were checked for their precharge pressures. Nine bottles were below required precharge pressure. All nine bottles ranged from 825 psi to 875 psi. All were increased to 1000 psi. The remaining 6 bottles were within compliance. The two 80 gallon charge bottles that are located on the roof of the rig floor were found to be inoperative and were taken out of service. It appeared that both had damaged bladders. Test Results TEST DATA Rig Rep:D. Boyd/B. LeFluerOperator:Hilcorp Alaska, LLC Operator Rep:S. Sotherland/S. Dambacker Rig Owner/Rig No.:Enterprise 151 PTD#:2220240 DATE:6/30/2022 Type Operation:DRILL Annular: 250/3000Type Test:BIWKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopGDC220707103856 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 18.7 MASP: 1793 Sundry No: CLOSURE TIME (sec) Time/Pressure P/F Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 13 PNo. Valves 1 PManual Chokes 2 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000"P #1 Rams 1 2 7/8"x5" VB P #2 Rams 1 Blinds P #3 Rams 1 2 7/8"x5" VB P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 FP Kill Line Valves 3 6" 10K (1) 3"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3125 Pressure After Closure P1950 200 PSI Attained P22 Full Pressure Attained P127 Blind Switch Covers:PAll Stations Nitgn Btls# &psi (avg)P16@2337 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator FP FPMeth Gas Detector FP FPH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 9 FP FP FP FP FP The audible and visual alarms in the camp didn't work. HCR kill failed.Control systemr response times were checked and were as follows: Annular - 14.7 seconds, UPR - 10.5 seconds, LPR - 10 seconds, Blinds (simulated with UPR) 14.7 seconds, HCR kill - 1.5 seconds, HCR choke - 1.5 seconds. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________N COOK INLET UNIT A-09A JBR 07/29/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Initial to 3000psi due to wellhead psi limits. 4" joint. Gas detection visual FP-found communication issue for pass. Choke line flange leak-tighten for a pass. Test Results TEST DATA Rig Rep:Bruce HebertOperator:Hilcorp Alaska, LLC Operator Rep:Shane Hauck Contractor/Rig No.:Enterprise 151 PTD#:2220240 DATE:6/15/2022 Type Operation:DRILL Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSAM220621092430 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 1793 Sundry No: Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 13 PNo. Valves 1 PManual Chokes 2 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8 P #1 Rams 1 2-7/8x5 P #2 Rams 1 Blind P #3 Rams 1 2-7/8x5 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 3 3-1/16&3-1/8 P Check Valve 0 NA BOP Misc 1 Flange FP System Pressure P3100 Pressure After Closure P1850 200 PSI Attained P28 Full Pressure Attained P129 Blind Switch Covers:PAll stations Nitgn. Bottles (avg):P16@2350 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator FP PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9999 9 FP FP 3000psi due to wellhead psi limits.Gas detection visual FP-Choke line flange leak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цϳ͕ϱϬϬΖ aaSVL 1$ 3 W V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Anne Prysunka at 4:29 pm, Jul 25, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH '/% ; &7 %23 WHVW WR SVL 6XEPLW &%/ ORJ WR $2*&& IRU DSSURYDO SULRU WR SHUIRUDWLQJ ; '65%-0 GWV -/& 5%'06 -6% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗E/hͲϬϵW/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϬϮϵͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌ>ĞŐ͗>ĞŐηϮ^ŽƌŶĞƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϴͬϯͬϮϮZŝŐ͗ůŝŶĞΘdhηϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϮϮͲϬϮϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐ>ĂƵŐŚůŝŶ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W ϱϬϬƉƐŝΛϰ͕ϴϯϭ͛dsĂƐĞĚŽŶŽĨĨƐĞƚͲϬϯ/ŶŝƚŝĂů,WϭϭͬϮϬϮϭ DĂǆŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ΕϭϳƉƐŝΛϰ͕ϴϯϭ͛dshƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚϮϬϮϱ͘ϮϴϬ;ďͿ;ϰͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ E/hͲϬϵŝƐĂƐŝĚĞƚƌĂĐŬĞĚŐĂƐƉƌŽĚƵĐĞƌǁĂƐĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶ:ƵŶĞϮϬϮϮ͘dŚŝƐƐƵŶĚƌǇŝƐƚŽƌƵŶ Ă>͕ũĞƚǁĞůůĚƌǇǁŝƚŚEϮĂŶĚƉĞƌĨŽƌĂƚĞƚŚĞǁĞůů͘ dŚĞǁĞůůďŽƌĞŝƐĐŽŵƉůĞƚĞĚĂƐĂϰͲϭͬϮ͟ŵŽŶŽͲďŽƌĞǁŝƚŚƚŝĞďĂĐŬ͕ƚŚĞǁĞůůďŽƌĞƉƌĞƐƐƵƌĞƚĞƐƚĞĚĂŶĚ ĚŝƐƉůĂĐĞĚǁŝƚŚǁĂƚĞƌ͘ WƌŽĐĞĚƵƌĞ͗ ϭ͘ZĞǀŝĞǁĂůůĂƉƉƌŽǀĞĚKƐ Ϯ͘D/ZhͲůŝŶĞ͕ůŽŐ>͕ƐƵďŵŝƚƚŽƚŚĞK' ϯ͘WƌŽǀŝĚĞK'ϮϰŚƌƐŶŽƚŝĐĞŽĨKWƚĞƐƚ;ZĞƋƵĞƐƚƉƌŽƉŽƐĂůĨŽƌǁĞĞŬůǇƚĞƐƚŝŶŐŽĨKWƐĨŽƌϯǁĞůůƐ ŽŶƚŚĞdǇŽŶĞŬƉůĂƚĨŽƌŵͲϬϵ͕ͲϭϬ͕ΘͲϭϭͿ ϰ͘D/Zh^>ŽŝůĞĚdƵďŝŶŐhŶŝƚηϭ͕WdKWƚŽϯϬϬϬƉƐŝ,ŝϮϱϬ>Žǁ dŚĞKWƚĞƐƚŝŶŐǁŝůůĨŽůůŽǁƚŚĞĨŽůůŽǁŝŶŐƌĞƋƵŝƌĞŵĞŶƚƐĂŶĚĚŽĐƵ ŵĞŶƚŝŶĚĂŝůǇƌĞƉŽƌƚ͗ x/ŶŝƚŝĂůũŽďŽƌǁĞĞŬůǇĚƵƌŝŶŐĐŽŶƚŝŶƵŽƵƐũŽďƐ o&ƵůůKWƚĞƐƚŽĨďŽĚǇ͕ďůŝŶĚĂŶĚƐŚĞĂƌƌĂŵƐ͕ƉŝƉĞĂŶĚƐůŝƉƌĂŵƐ ͕ĂĐĐƵŵƵůĂƚŽƌ x^ƵďƐĞƋƵĞŶƚũŽďƐŶŽƚƚŽĞǆĐĞĞĚϳĚĂǇƐĨƌŽŵƉƌĞǀŝŽƵƐƚĞƐƚ o&ƵůůďŽĚǇͬƐŚĞůůƚĞƐƚǁŝůůďĞƉĞƌĨŽƌŵĞĚ o&ƵŶĐƚŝŽŶƚĞƐƚŝŶŐŽĨĞĂĐŚƌĂŵǁŝůůďĞƉĞƌĨŽƌŵĞĚƚŽĞŶƐƵƌĞƚŚĂƚĂůůŚǇĚƌĂƵůŝĐ ŚŽƐĞƐĂƌĞƉƌŽƉĞƌůǇĐŽŶŶĞĐƚĞĚ xǆĐĞƉƚŝŽŶƐ o/ĨĂŶǇƌĂŵĐŽŵƉŽŶĞŶƚƐŚĂǀĞďĞĞŶĐŚĂŶŐĞĚ͕ĨƵŶĐƚŝŽŶͲƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞĐŚĂŶŐĞĚ ĐŽŵƉŽŶĞŶƚƐ o/ĨƵƐĞĚĨŽƌǁĞůůĐŽŶƚƌŽůƉƵƌƉŽƐĞƐŽƌǁŚĞŶƌŽƵƚŝŶĞƵƐĞŽĨƚŚĞĞƋ ƵŝƉŵĞŶƚŵĂǇ ŚĂǀĞĐŽŵƉƌŽŵŝƐĞĚŝƚƐĞĨĨĞĐƚŝǀĞŶĞƐƐ͕ĨƵŶĐƚŝŽŶͲƉƌĞƐƐƵƌĞƚĞƐƚĂůůĐŽŵƉŽŶĞŶƚƐƵƐĞĚƉƌŝŽƌƚŽ ŶĞǆƚǁĞůůďŽƌĞĞŶƚƌǇ o/ĨŶĞǁĞƋƵŝƉŵĞŶƚŝƐĂĚĚĞĚ͕ĨƵŶĐƚŝŽŶͲƉƌĞƐƐƵƌĞƚĞƐƚǁŚĂƚŝƐŶĞǁ ϱ͘Z/,͕ƵŶůŽĂĚĨůƵŝĚĨƌŽŵƚŚĞǁĞůůďŽƌĞǁŝƚŚŶŝƚƌŽŐĞŶ͕ŶŽƉƌĞƐƐƵƌĞůĞĨƚŽŶǁĞůů;ĨĂĐŝůŝƚǇĐĂŶƉƌĞƐƐƵƌĞ ƵƉǁŝƚŚŐĂƐĨƌŽŵƉůĂƚĨŽƌŵĨŽƌĚĞƐŝƌĞĚƵŶĚĞƌďĂůĂŶĐĞ͘Ϳ ϲ͘ZDKĐŽŝůƚƵďŝŶŐ ϳ͘ZhͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϭϱϬϬƉƐŝ ϴ͘WĞƌĨŽƌĂƚĞǁŝƚŚϲϬĚĞŐƉŚĂƐĞĚŚŽůůŽǁĐĂƌƌŝĞƌƉĞƌĨŐƵŶƐ ^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&d ĞůͲhƉƉĞƌϭцϲ͕ϭϵϳ͛цϲ͕ϮϬϳ͛цϰ͕ϰϰϰ͛цϰ͕ϰϰϵ͛цϳ ĞůͲhƉƉĞƌϮцϲ͕Ϯϭϭ͛цϲ͕ϮϮϭ͛цϰ͕ϰϱϭ͛цϰ͕ϰϱϲ͛цϭϬ ĞůͲDŝĚцϲ͕Ϯϯϭ͛цϲ͕Ϯϱϭ͛цϰ͕ϰϲϭ͛цϰ͕ϰϳϭ͛цϮϬ ĞůͲ>ŽǁĞƌϭцϲ͕Ϯϲϲ͛цϲ͕Ϯϴϭ͛цϰ͕ϰϳϴ͛цϰ͕ϰϴϱ͛цϭϱ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ ^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&d ĞůͲ>ŽǁĞƌϮцϲ͕ϯϬϮ͛цϲ͕ϯϭϮ͛цϰ͕ϰϵϱ͛цϰ͕ϱϬϬ͛цϭϬ ĞůͲhƉƉĞƌϭцϲ͕ϰϮϯ͛цϲ͕ϰϰϯ͛цϰ͕ϱϱϯ͛цϰ͕ϱϲϯ͛цϭϬ ĞůͲhƉƉĞƌϮцϲ͕ϰϲϯ͛цϲ͕ϰϳϮ͛цϰ͕ϱϳϮ͛цϰ͕ϱϳϳ͛цϵ ĞůͲhƉƉĞƌϯцϲ͕ϱϭϳ͛цϲ͕ϱϮϳ͛цϰ͕ϱϵϵ͛цϰ͕ϲϬϰ͛цϭϬ ĞůͲDŝĚϭцϲ͕ϱϱϯ͛цϲ͕ϱϲϱ͛цϰ͕ϲϭϳ͛цϰ͕ϲϮϯ͛цϭϮ ĞůͲDŝĚϮцϲ͕ϱϴϱ͛цϲ͕ϲϬϬ͛цϰ͕ϲϯϰ͛цϰ͕ϲϰϮ͛цϭϱ ĞůͲDŝĚϯцϲ͕ϲϭϴ͛цϲ͕ϲϮϴ͛цϰ͕ϲϱϭ͛цϰ͕ϲϱϳ͛цϭϬ ĞůͲ>ŽǁĞƌцϲ͕ϲϳϴ͛цϲ͕ϲϵϭ͛цϰ͕ϲϴϲ͛цϰ͕ϲϵϰ͛цϭϯ ĞůͲ>ŽǁĞƌцϳ͕ϬϬϳ͛цϳ͕ϬϮϳ͛цϰ͕ϵϭϴ͛цϰ͕ϵϯϰ͛цϮϬ ĞůͲhƉƉĞƌцϳ͕Ϭϯϲ͛цϳ͕Ϭϰϲ͛цϰ͕ϵϰϭ͛цϰ͕ϵϱϬ͛цϭϬ ĞůͲDŝĚϭцϳ͕Ϭϲϵ͛цϳ͕Ϭϳϰ͛цϰ͕ϵϲϴ͛цϰ͕ϵϳϮ͛цϱ ĞůͲDŝĚϮцϳ͕ϭϰϭ͛цϳ͕ϭϰϴ͛цϱ͕ϬϮϳ͛цϱ͕ϬϯϮ͛цϳ ĞůͲDŝĚϯцϳ͕ϭϲϱ͛цϳ͕ϭϳϬ͛цϱ͕Ϭϰϲ͛цϱ͕ϬϱϬ͛цϱ ĞůͲDŝĚϰцϳ͕ϭϳϲ͛цϳ͕ϭϴϭ͛цϱ͕Ϭϱϱ͛цϱ͕Ϭϱϵ͛цϯ ĞůͲ>ŽǁĞƌцϳ͕ϮϬϳ͛цϳ͕ϮϮϳ͛цϱ͕ϬϴϬ͛цϱ͕Ϭϵϲ͛цϮϬ ĞůͲ&hƉƉĞƌцϳ͕Ϯϱϳ͛цϳ͕Ϯϲϳ͛цϱ͕ϭϮϭ͛цϱ͕ϭϮϵ͛цϭϬ ĞůͲ&DŝĚϭцϳ͕Ϯϳϭ͛цϳ͕Ϯϴϱ͛цϱ͕ϭϯϮ͛цϱ͕ϭϰϰ͛цϭϰ ĞůͲ&DŝĚϮцϳ͕ϯϮϳ͛цϳ͕ϯϰϳ͛цϱ͕ϭϳϴ͛цϱ͕ϭϵϰ͛цϮϬ ĞůͲ&>ŽǁĞƌцϳ͕ϯϲϴ͛цϳ͕ϯϳϱ͛цϱ͕Ϯϭϭ͛цϱ͕Ϯϭϳ͛цϳ DĂŬĞĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƐĞŶĚůŽŐŝŶƚŽKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ͕Z ĞƐĞƌǀŽŝƌŶŐŝŶĞĞƌĂŶĚƚŚĞ'ĞŽůŽŐŝƐƚ͘ D 5HFRUGLQLWLDODQGPLQXWHWXELQJSUHVVXUHVDIWHUILULQJ ď͘ŽŶƐƵůƚǁŝƚŚZͬ'ĞŽ;ŚƌŝƐ<ĂŶǇĞƌͬĂŶŝĞůzĂŶĐǇͿďĞƚǁĞĞŶĞĂĐŚƉĞ ƌĨŝŶƚĞƌǀĂů Đ͘ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞEŽƌƚŚŽŽŬ/ŶůĞƚ͕dĞƌƚŝĂƌǇ'ĂƐWŽŽů͘ ϵ͘ZͲ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϭϬ͘dĞƐƚ^s^ĂƐƉĞƌϮϬϮϱ͘Ϯϲϱ͘ ĂͿEŽƚŝĨǇK'ϰϴŚƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚŝŶŐ^s^ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘ŽŝůdƵďŝŶŐKWŝĂŐƌĂŵ ϯ͘^ƚĂŶĚĂƌĚEŝƚƌŽŐĞŶKƉĞƌĂƚŝŽŶƐ hƉĚĂƚĞĚǇ͗,ϬϳͬϭϵͬϮϮ WZKWK^ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗E/ͲϬϵ Wd͗ϮϮϮͲϬϮϰ W/͗ϱϬͲϴϴϯͲϮϬϬϮϵͲϬϭͲϬϬ ŽŵƉůĞƚĞĚ͗ϲͬϯϬͬϮϮ &DVLQJ 7XELQJ'HWDLO 6,=(:7*5$'(&2110,1,'723%700' ´6XUI¶ ´+6XUI¶ ´-%7&6XUI¶ ´-%7&6XUI¶ ´/':&¶¶ ´/,%70´6XUI¶ 1RWHV 6KRUWMRLQWVRI´FDVLQJ#¶¶¶ ¶¶¶ 5$7DJ#¶ ¶ -HZHOU\'HWDLO ,WHP'HSWK0''HSWK79','2''HVFULSWLRQ ¶¶´´%DNHU21<;5(756669 ¶¶´%DNHU=;3OLQHUKDQJHUSDFNHUDVV\ 6HDO $VVHPEO\ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ĞůͲhƉƉĞƌϭцϲ͕ϭϵϳ͛цϲ͕ϮϬϳ͛цϰ͕ϰϰϰ͛цϰ͕ϰϰϵ͛цϳdWƌŽƉŽƐĞĚ ĞůͲhƉƉĞƌϮцϲ͕Ϯϭϭ͛цϲ͕ϮϮϭ͛цϰ͕ϰϱϭ͛цϰ͕ϰϱϲ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲDŝĚцϲ͕Ϯϯϭ͛цϲ͕Ϯϱϭ͛цϰ͕ϰϲϭ͛цϰ͕ϰϳϭ͛цϮϬdWƌŽƉŽƐĞĚ ĞůͲ>ŽǁĞƌϭцϲ͕Ϯϲϲ͛цϲ͕Ϯϴϭ͛цϰ͕ϰϳϴ͛цϰ͕ϰϴϱ͛цϭϱdWƌŽƉŽƐĞĚ ĞůͲ>ŽǁĞƌϮцϲ͕ϯϬϮ͛цϲ͕ϯϭϮ͛цϰ͕ϰϵϱ͛цϰ͕ϱϬϬ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲhƉƉĞƌϭцϲ͕ϰϮϯ͛цϲ͕ϰϰϯ͛цϰ͕ϱϱϯ͛цϰ͕ϱϲϯ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲhƉƉĞƌϮцϲ͕ϰϲϯ͛цϲ͕ϰϳϮ͛цϰ͕ϱϳϮ͛цϰ͕ϱϳϳ͛цϵdWƌŽƉŽƐĞĚ ĞůͲhƉƉĞƌϯцϲ͕ϱϭϳ͛цϲ͕ϱϮϳ͛цϰ͕ϱϵϵ͛цϰ͕ϲϬϰ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲDŝĚϭцϲ͕ϱϱϯ͛цϲ͕ϱϲϱ͛цϰ͕ϲϭϳ͛цϰ͕ϲϮϯ͛цϭϮdWƌŽƉŽƐĞĚ ĞůͲDŝĚϮцϲ͕ϱϴϱ͛цϲ͕ϲϬϬ͛цϰ͕ϲϯϰ͛цϰ͕ϲϰϮ͛цϭϱdWƌŽƉŽƐĞĚ ĞůͲDŝĚϯцϲ͕ϲϭϴ͛цϲ͕ϲϮϴ͛цϰ͕ϲϱϭ͛цϰ͕ϲϱϳ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲ>ŽǁĞƌцϲ͕ϲϳϴ͛цϲ͕ϲϵϭ͛цϰ͕ϲϴϲ͛цϰ͕ϲϵϰ͛цϭϯdWƌŽƉŽƐĞĚ ĞůͲ>ŽǁĞƌцϳ͕ϬϬϳ͛цϳ͕ϬϮϳ͛цϰ͕ϵϭϴ͛цϰ͕ϵϯϰ͛цϮϬdWƌŽƉŽƐĞĚ ĞůͲhƉƉĞƌцϳ͕Ϭϯϲ͛цϳ͕Ϭϰϲ͛цϰ͕ϵϰϭ͛цϰ͕ϵϱϬ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲDŝĚϭцϳ͕Ϭϲϵ͛цϳ͕Ϭϳϰ͛цϰ͕ϵϲϴ͛цϰ͕ϵϳϮ͛цϱdWƌŽƉŽƐĞĚ ĞůͲDŝĚϮцϳ͕ϭϰϭ͛цϳ͕ϭϰϴ͛цϱ͕ϬϮϳ͛цϱ͕ϬϯϮ͛цϳdWƌŽƉŽƐĞĚ ĞůͲDŝĚϯцϳ͕ϭϲϱ͛цϳ͕ϭϳϬ͛цϱ͕Ϭϰϲ͛цϱ͕ϬϱϬ͛цϱdWƌŽƉŽƐĞĚ ĞůͲDŝĚϰцϳ͕ϭϳϲ͛цϳ͕ϭϴϭ͛цϱ͕Ϭϱϱ͛цϱ͕Ϭϱϵ͛цϯdWƌŽƉŽƐĞĚ ĞůͲ>ŽǁĞƌцϳ͕ϮϬϳ͛цϳ͕ϮϮϳ͛цϱ͕ϬϴϬ͛цϱ͕Ϭϵϲ͛цϮϬdWƌŽƉŽƐĞĚ ĞůͲ&hƉƉĞƌцϳ͕Ϯϱϳ͛цϳ͕Ϯϲϳ͛цϱ͕ϭϮϭ͛цϱ͕ϭϮϵ͛цϭϬdWƌŽƉŽƐĞĚ ĞůͲ&DŝĚϭцϳ͕Ϯϳϭ͛цϳ͕Ϯϴϱ͛цϱ͕ϭϯϮ͛цϱ͕ϭϰϰ͛цϭϰdWƌŽƉŽƐĞĚ ĞůͲ&DŝĚϮцϳ͕ϯϮϳ͛цϳ͕ϯϰϳ͛цϱ͕ϭϳϴ͛цϱ͕ϭϵϰ͛цϮϬdWƌŽƉŽƐĞĚ ĞůͲ&>ŽǁĞƌцϳ͕ϯϲϴ͛цϳ͕ϯϳϱ͛цϱ͕Ϯϭϭ͛цϱ͕Ϯϭϳ͛цϳdWƌŽƉŽƐĞĚ &RLOHG7XELQJ%23 6:$%9$/9( 0$67(59$/9( ^dEZt>>WZKhZ E/dZK'EKWZd/KE^ ϬϵͬϮϯͬϮϬϭϲ &/E>ǀͲŽĨĨƐŚŽƌĞ WĂŐĞϭŽĨϭ ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Ϯ͘Ϳ EŽƚŝĨǇ&ĂĐŝůŝƚǇKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘ ϯ͘Ϳ WĞƌĨŽƌŵ WƌĞͲ:Žď ^ĂĨĞƚǇ DĞĞƚŝŶŐ͘ ZĞǀŝĞǁ ŽƉĞƌĂƚŝŶŐ ƉƌŽĐĞĚƵƌĞƐĂŶĚ ĂƉƉƌŽƉƌŝĂƚĞ ^ĂĨĞƚǇ ĂƚĂ ^ŚĞĞƚƐ;ĨŽƌŵĞƌůǇD^^Ϳ͘ ϰ͘Ϳ ŽĐƵŵĞŶƚ ŚĂǌĂƌĚƐ ĂŶĚ ŵŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ĂŶĚ ĐŽŶĨŝƌŵ ĨůŽǁ ƉĂƚŚƐ͘ /ŶĐůƵĚĞ ƌĞǀŝĞǁ ŽŶ ĂƐƉŚǇǆŝĂƚŝŽŶĐĂƵƐĞĚ ďǇ ŶŝƚƌŽŐĞŶĚŝƐƉůĂĐŝŶŐŽǆǇŐĞŶ͘DŝƚŝŐĂƚŝŽŶŵĞĂƐƵƌĞƐŝŶĐůƵĚĞĂƉƉƌŽƉƌŝĂƚĞ ƌŽƵƚŝŶŐŽĨĨůŽǁůŝŶĞƐ͕ĂĚĞƋƵĂƚĞǀĞŶƚŝŶŐĂŶĚĂƚŵŽƐƉŚĞƌŝĐŵŽŶŝƚŽƌŝŶŐ͘ ϱ͘Ϳ ^ƉŽƚWƵŵƉŝŶŐhŶŝƚĂŶĚEŝƚƌŽŐĞŶdĂŶŬ͘ŽŶĨŝƌŵůŝƋƵŝĚEϮǀŽůƵŵĞƐŝŶƚƌĂŶƐƉŽƌƚ͘ ϲ͘Ϳ ZŝŐƵƉůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚƚŽƚŚĞǁĞůůĂŶĚƌĞƚƵƌŶƐƚĂŶŬ͘^ĞĐƵƌĞůŝŶĞƐǁŝƚŚǁŚŝƉ ĐŚĞĐŬƐ͘ ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ EŝƚƌŽŐĞŶŵĂǇĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘ ϴ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůǇŵĞĂƐƵƌĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘ ϵ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƵƉƐƚƌĞĂŵĂŶĚĚŽǁŶƐƚƌĞĂŵŽĨĂŶǇĐŚĞĐŬǀĂůǀĞƐ͘ ϭϬ͘Ϳ tĞůůƐŝƚĞDĂŶĂŐĞƌƐŚĂůůǁĂůŬĚŽǁŶǀĂůǀĞĂůŝŐŶŵĞŶƚƐĂŶĚĞŶƐƵƌĞǀĂůǀĞƉŽƐŝƚŝŽŶŝƐĐŽƌƌĞĐƚ͘ ϭϭ͘Ϳ ŶƐƵƌĞƉŽƌƚĂďůĞϰͲŐĂƐĚĞƚĞĐƚŝŽŶĞƋƵŝƉŵĞŶƚŝƐŽŶƐŝƚĞ͕ĐĂůŝďƌĂƚĞĚ͕ĂŶĚďƵŵƉƚĞƐƚĞĚƉƌŽƉĞƌůǇƚŽ ĚĞƚĞĐƚ>>ͬ,Ϯ^ͬKϮͬKϮůĞǀĞůƐ͘ŶƐƵƌĞƐƵƉƉůŝĞƌŚĂƐĂǁŽƌŬŝŶŐĂŶĚĐĂůŝďƌĂƚĞĚĚĞƚĞĐƚŽƌĂƐǁĞůů ƚŚĂƚŵĞĂƐƵƌĞƐKϮůĞǀĞůƐ͘ ϭϮ͘Ϳ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƵƉƐƚƌĞĂŵŽĨǁĞůůƚŽĂƉƉƌŽǀĞĚƐƵŶĚƌǇƉƌĞƐƐƵƌĞŽƌDW^W;DĂǆŝŵƵŵWŽƚĞŶƚŝĂů ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞͿ͕ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘dĞƐƚůŝŶĞƐĚŽǁŶƐƚƌĞĂŵŽĨǁĞůů;ĨƌŽŵǁĞůůƚŽƌĞƚƵƌŶƐƚĂŶŬͿ ƚŽϭ͕ϱϬϬƉƐŝ͘WĞƌĨŽƌŵǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶĨŽƌĂŶǇůĞĂŬƐ͘ ϭϯ͘Ϳ ůĞĞĚŽĨĨƚĞƐƚƉƌĞƐƐƵƌĞĂŶĚƉƌĞƉĂƌĞĨŽƌƉƵŵƉŝŶŐŶŝƚƌŽŐĞŶ͘ ϭϰ͘Ϳ WƵŵƉŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdĂŶŬ͘ 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 or fax to 907 564-4422. Received By: Date: Date: 07/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: NCIA-09A PTD: 222-024 API: 50-883-20029-01-00 FINAL LWD FORMATION EVALUATION LOGS (06/18/2022 to 06/27/20212) x ROP, 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. PTD:222-024 T36817 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.20 13:20:32 -08'00' 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU5XQ7XELQJ 2SHUDWRU1DPH&XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ"<HV 1R 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU)LHOG3RROV 7RWDO'HSWK0'IW7RWDO'HSWK79'IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363SVL 3OXJV0' -XQN0' 1$ &DVLQJ &ROODSVH 6WUXFWXUDO &RQGXFWRU 6XUIDFH SVL ,QWHUPHGLDWH SVL 3URGXFWLRQ /LQHU 3DFNHUVDQG66697\SH3DFNHUVDQG66690'IWDQG79'IW $WWDFKPHQWV3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU :HOO6WDWXVDIWHUSURSRVHGZRUN &RPPHQFLQJ2SHUDWLRQV2,/ :,1- :'63/6XVSHQGHG 9HUEDO$SSURYDO'DWH *$6 :$* *6725 63/8* $2*&&5HSUHVHQWDWLYH*,1-2S6KXWGRZQ $EDQGRQHG &RQWDFW1DPH&KDG+HOJHVRQ2SHUDWLRQV(QJLQHHU &RQWDFW(PDLOFKHOJHVRQ#KLOFRUSFRP &RQWDFW3KRQH $XWKRUL]HG7LWOH &RQGLWLRQVRIDSSURYDO1RWLI\$2*&&VRWKDWDUHSUHVHQWDWLYHPD\ZLWQHVV 6XQGU\1XPEHU 3OXJ,QWHJULW\%237HVW 0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 2WKHU 3RVW,QLWLDO,QMHFWLRQ0,75HT G"<HV 1R 6SDFLQJ([FHSWLRQ5HTXLUHG"<HV 1R 6XEVHTXHQW)RUP5HTXLUHG $33529('%< $SSURYHGE\ &200,66,21(5 7+($2*&& 'DWH &RPP &RPP 6U3HW(QJ 6U3HW*HR 6U5HV(QJ цϳ͕ϱϬϬΖ a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y Samantha Carlisle at 8:46 am, Jun 28, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH DLB 06/30/2022 BOP test to 3500 psig Annular preventer test to 2500 psig Victoria Loepp 6/30/22 VTL 6/30/22 X 10-404 X DSR-6/29/22 X dts 7/1/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.07.01 11:05:00 -08'00' RBDMS JSB 070522 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗E/hͲϬϵW/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϬϮϵͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌ>ĞŐ͗>ĞŐηϮ^ŽƌŶĞƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϲͬϮϵͬϮϬϮϮZŝŐ͗^ƉĂƌƚĂŶϭϱϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϮϮͲϬϮϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐ>ĂƵŐŚůŝŶ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿͿ Current Bottom Hole Pressure: 2,536psi @ 5,359 TVD 9.1 ppg current mud weight Maximum Potential Surface Pressure: 2,000 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌǇ E/hͲϬϵŝƐĂĞůƵŐĂƉƌŽĚƵĐĞƌƚŚĂƚŝƐĐƵƌƌĞŶƚůǇďĞŝŶŐĚƌŝůůĞĚ͘dŚŝƐƐƵŶĚƌǇŝƐƚŽƌƵŶƚƵďŝŶŐǁŝƚŚƚŚĞ ĚƌŝůůŝŶŐƌŝŐĂĨƚĞƌƚŚĞůŝŶĞƌŝƐĐĞŵĞŶƚĞĚŝŶƉůĂĐĞ͘ůůƉƌŽƉŽƐĞĚǁŽƌŬǁŝůůďĞǁŝƚŚƚŚĞůŝŶĞƌƐĞƚŝŶƉůĂĐĞ͘ WƌŽĐĞĚƵƌĞ͗ ϭ͘ΎΎΎdĂŬĞŽǀĞƌŽƉĞƌĂƚŝŽŶƐĨƌŽŵƚŚĞƌŝůůŝŶŐ^ŝĚĞƚƌĂĐŬWƌŽŐƌĂŵWdϮϮϮͲϬϮϰ^ƚĞƉϭϴΎΎΎ Ϯ͘dĞƐƚKW͛ƐĞǀĞƌǇϭϰĚĂǇƐĐŽŶƚŝŶƵĞĚĨƌŽŵůĂƐƚƚĞƐƚĚĂƚĞ xdĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϱϬϬƉƐŝŚŝŐŚͬϮ͕ϱϬϬƉƐŝĂŶŶƵůĂƌ͘;EŽƚĞ͗EŽƚŝĨǇK'ϰϴŚŽƵƌƐ ŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ϯ͘ŽŵƉůĞƚŝŽŶĨůƵŝĚǁŝůůďĞ<>͘KW͛ƐǁŝůůďĞĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽ ĐŝƌĐƵůĂƚĞƚŚĞǁĞůů ϰ͘WhϰͲϭͬϮ͟ƐĞĂůĂƐƐĞŵďůǇĂŶĚZ/,ǁͬϰͲϭͬϮ͟/dϭϮ͘ϲηƚƵďŝŶŐ ϱ͘/ŶƐƚĂůůdZ^^^sĂƉƉƌŽǆŝŵĂƚĞůǇĂƚϰϬϬ͛͘ZhĐŽŶƚƌŽůůŝŶĞƐƉŽŽůĞƌĂŶĚŝŶƐƚĂůůƐŝŶŐůĞĐŽŶƚƌŽůůŝŶĞ ϲ͘EŽͲŐŽƚŝĞďĂĐŬƐĞĂůĂƐƐĞŵďůǇŝŶůŝŶĞƌWZĂŶĚŵĂƌŬƉŝƉĞ͘WhƉƵƉƐƚŽƐƉĂĐĞŽƵƚ ϳ͘WhŚĂŶŐĞƌĂŶĚƚĞƌŵŝŶĂƚĞĐŽŶƚƌŽůůŝŶĞƚŚƌŽƵŐŚŚĂŶŐĞƌ͘>ĂŶĚƐƚƌŝŶŐ͕ŶŽƚĞĚŝƐƚĂŶĐĞŽĨƐĞĂůƐ ĨƌŽŵŶŽͲŐŽ ϴ͘/ŶƐƚĂůůƉĂĐŬŽĨĨĂŶĚƚĞƐƚŚĂŶŐĞƌǀŽŝĚ ϵ͘WƌĞƐƐƵƌĞƚĞƐƚĐĂƐŝŶŐƚŽϭ͕ϱϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶ ϭϬ͘WƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚŽϮ͕ϬϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶ ϭϭ͘/ŶƐƚĂůůWs ϭϮ͘EKW͕EhdƌĞĞĂŶĚƚĞƐƚ ϭϯ͘ZDKĂŶĚŵŽǀĞƚŽͲϭϬ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ hƉĚĂƚĞĚǇ͗,ϬϲͬϮϳͬϮϮ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗E/ͲϬϵ Wd͗ϮϮϮͲϬϮϰ W/͗ϱϬͲϴϴϯͲϮϬϬϮϵͲϬϭͲϬϬ ŽŵƉůĞƚĞĚ͗&ƵƚƵƌĞ -HZHOU\'HWDLO ,WHP'HSWK 0' 'HSWK 79','2''HVFULSWLRQ %DNHU21<;5(756669 ¶´%DNHU=;3OLQHUKDQJHUSDFNHUDVV\ &DVLQJ 7XELQJ'HWDLO 6,=(:7*5$'(&2110,1,'723%700' ´ 6XUI ¶ ´ +6XUI¶ ´-%7&6XUI¶ ´-%7&6XUI¶ ´ /':&¶¶ ´ /,%70´6XUI ¶ 1RWHV 6KRUWMRLQWVRI´FDVLQJ#¶¶ 5$7DJ#¶ ¶ 1 Guhl, Meredith D (OGC) From:Loepp, Victoria T (OGC) Sent:Thursday, June 30, 2022 8:11 PM To:Chad Helgeson Cc:Rixse, Melvin G (OGC); McLellan, Bryan J (OGC); Loepp, Victoria T (OGC) Subject:NCIU A-09A (PTD# 222-024) Running tubing APPROVAL Chad, Approvalisgrantedtoproceedasoutlinedinthesubmittedsundry.SundryapprovalisexpectedJuly1,2022. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From:ChadHelgeson<chelgeson@hilcorp.com> Sent:Thursday,June30,20224:04PM To:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:FW:[EXTERNAL]RE:NCIUAͲ09A(PTD#222Ͳ024)Runningtubing Victoria, BelowistheemailIreceivedfromMelonMondayandattachedistheSundrythatwesubmittedforrunningthetubing onthenewdrillwell. AsImentionedonthephone,therigisfinishingaBOPtest,willbemakingapolishmillrunto~3700ftandthenwewill berunningtubinginthemorning. Ifwecangetaverbalapprovalorhavethesundrysentoverifitwasapproved,itwouldbemuchappreciated. Thanks ChadHelgeson From:ChadHelgeson Sent:Thursday,June30,20223:56PM To:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> You don't often get email from chelgeson@hilcorp.com. Learn why this is important 2 Cc:DonnaAmbruz<dambruz@hilcorp.com>;SeanMcLaughlin<Sean.Mclaughlin@hilcorp.com>;SloanSunderland <ssunderland@hilcorp.com> Subject:RE:[EXTERNAL]RE:NCIUAͲ09A(PTD#222Ͳ024)Runningtubing Mel, WewillberunningthetubingonTheTyonekAͲ09Awellbymorning,dowehaveapprovaltorunthetubingas submitted,eitherwiththeapprovedSundryreturnedorwithVerbalapprovalfollowingtheproposedprocedure? Chad From:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Sent:Monday,June27,20222:59PM To:ChadHelgeson<chelgeson@hilcorp.com> Subject:[EXTERNAL]RE:NCIUAͲ09A(PTD#222Ͳ024)Runningtubing Chad, HasBryanbeenrequestingawitnessedMITforproducers?Iseenoreasonwewouldrequirethatifthisisgoingtobe aproducer. MelRixse SeniorPetroleumEngineer(PE) AlaskaOilandGasConservationCommission 907Ͳ793Ͳ1231Office 907Ͳ297Ͳ8474Cell CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission(AOGCC), StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,useor disclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwardingit, and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactMelRixseat(907Ͳ793Ͳ1231)or(Melvin.Rixse@alaska.gov). From:ChadHelgeson<chelgeson@hilcorp.com> Sent:Monday,June27,20222:25PM To:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Cc:SeanMcLaughlin<Sean.Mclaughlin@hilcorp.com>;DonnaAmbruz<dambruz@hilcorp.com> Subject:NCIUAͲ09A(PTD#222Ͳ024)Runningtubing Mel, Aswediscussedonthephone,wewillbelookingforaquickturnaroundtoa10Ͳ403wewillsubmitthisforrunning tubingonawellwejustcompleteddrillingontheTyonekAͲ09A. Step#18inthePTDsaysaseparatecompletionsundrywillbesubmittedforrunningthetubing.Belowistheprocedure thatwewillincludeintheSundryandschematic.WewillalsosubmitanotherSundryforthecoilandperforating portionofthiswellwork,oncetheGeoteamfinishesourplansforperforatingthewell.ThisworkwilloccurafterRig 151finishesdrilling2morewellsonthislegoftheplatform. Step18inthePTDshouldbe: 1. PU4Ͳ1/2”sealassemblyandRIHw/4Ͳ1/2”IBT12.6#tubing 2. InstallTRSSSVapproximatelyat400’.Rucontrollinespoolerandinstallsingle¼”controlline. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 3. NoͲgotiebacksealassemblyinlinerPBRandmarkpipe.PUpupstospaceout. 4. PUhangerandterminatecontrollinethroughhanger.Landstring,notedistanceofsealsfromnoͲgo 5. Installpackoffandtesthangervoid 6. Pressuretestcasingto1,500psiandchartfor30min 7. Pressuretesttubingto2,000psiandchartfor30min (Provide48hrnoticetowitnessMITͲTandMITͲIA) 8. InstallBPV 9. NDBOPE,NUTreeandtest 10. RDMOandmovetoAͲ10B SeeattachedProposedSchematicforthetubingonthewell. Pleasegivemeacallifyouhaveanyquestionsorneedanyadditionalinformation,Sundrywillbesubmittedassoonas wegetalloursignatures,etc. ChadHelgeson KENOperationsEngineer HilcorpAlaskaLLC chelgeson@hilcorp.com 907Ͳ777Ͳ8405(O) 907Ͳ229Ͳ4824(C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:McLellan, Bryan J (OGC) To:Sean McLaughlin Cc:Regg, James B (OGC); Monty Myers Subject:NCIU A-09A (PTD 222-024) Initial BOP test pressure Date:Wednesday, March 23, 2022 12:17:00 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 Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Cook Inlet Field, Tertiary Gas Pool, NCIU A-09A Hilcorp Alaska, LLC Permit to Drill Number: 222-024 Surface Location: 1312' FNL, 1022' FWL, Sec. 6, T11N, R9W, SM, AK Bottomhole Location: 1225' FSL, 2576' FW L, Sec. 1, T11N, R1OW, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment of this 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 March, 2022. Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.16 11:09:26 -08'00' P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Contractor RepresentativeWell Permit to Drill # 2220240 Sundry Approval # NAOperation Inspection LocationWorking Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure PP Flow Rate Sensor P Operating Pressure PP Mud Gas Separator P Fluid Level/Condition PP Degasser P Pressure Gauges PP Separator Bypass P Sufficient Valves PP Gas Detectors P Regulator Bypass PFP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections PBlind Ram Handle CoverPP Reserve Pits NA Control Panel, Driller PP Trip Tank P Control Panel, Remote PPFirewallPP2 or More Pumps PP Kelly or TD Valves PIndependent Power SupplyPP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment PP Flow Monitor PFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes PHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line NAFAILURES:1CORRECT BY:COMMENTSAustin McLeod6/15/2022This rig inspection was done in conjunction with their initial BOPE test after the rig had been down since summer 2021. Rig up similar to previous years. Multiple pit locations on both rig and platform. Gas detection at all pit/shaker locations. Their gas detection visual alarms are separate and distinct but differ from the "accepted" colors for both H2S and LEL. The H2S is red with LEL being amber. They wanted to keep them the same as the platform's visuals. They do have laminated signs stating the set points and colors of each alarm. Gas detection testing was a FP (Fail/Pass). No bypass line on choke manifold (designated line to shakers). Two lines exiting manifold are to "poor boy" gasbuster (vents up the derrick) and the panic line. BOP stack was not anchored at first but remedied. Rig/jack up looked to be in good order.INSPECT DATEAOGCC INSPECTORDoneEnterprise 151Enterprise Offshore DrillingHilcorp Alaska LLCMISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOORALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsBruce HerbertShane HauckLocking Devices, RamsBOP STACKCHOKE MANIFOLDCook Inlet-Tyonek PlatformMUD SYSTEMNCIU A-09ADrillingCLOSING UNIT2022-0615_Rig_Enterprise151_NCIU_A-09A_amrev. 5-8-1899999ggGas detection at all pit/shaker locations. Their gas detection visualyggalarms are separate and distinct but differ from the "accepted" colors for both H2S and LEL. The H2S is red with LEL being amber. gThey wanted to keep them the same as the platform's visuals. They do have laminated signs stating the set points and colors of each yalarm. Gas detection testing was a FP (Fail/Pass). (gBOP stack was not anchored James B. ReggDigitally signed by James B. Regg Date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y Samantha Carlisle at 12:59 pm, Feb 22, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV 1RWLI\ $2*&& LI SUHVVXUH FRPPXQLFDWLRQ WR 2$ LV REVHUYHG GXULQJ ),7 EHIRUH GULOOLQJ VLGHWUDFN 6)''65 ,QLWLDO %23 WHVW RI VHDVRQ WR 5:3 SVL SVL DQQXODU 6XEVHTXHQW WHVWV WR SVL SVL DQQXODU %-0 dts 3/16/2022 3/16/22 Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.16 11:09:40 -08'00' $$'ULOOLQJ3URJUDPIRU37' 'R1RW3RVWRQ5LJ 7\RQHN 6HDQ0F/DXJKOLQ 5HYLVLRQ )HEUXDU\ NCI A-09A PTD Rev 0 &RQWHQWV :HOO6XPPDU\ 0DQDJHPHQWRI&KDQJH,QIRUPDWLRQ 7XEXODU3URJUDP 'ULOO3LSH,QIRUPDWLRQ ,QWHUQDO5HSRUWLQJ5HTXLUHPHQWV &XUUHQW:HOOERUH6FKHPDWLF 3UH6LGHWUDFN6FKHPDWLF 3ODQQHG:HOOERUH6FKHPDWLF 'ULOOLQJ6XPPDU\ 0DQGDWRU\5HJXODWRU\&RPSOLDQFH1RWLILFDWLRQV %2318DQG7HVW 3UHSDUDWRU\:RUNDQG0XG3URJUDP 'HFRPSOHWH6HW:KLSVWRFN0LOO:LQGRZ 'ULOO´+ROH6HFWLRQ 5XQ´3URGXFWLRQ/LQHU &HPHQW´3URGXFWLRQ/LQHU &OHDQRXW/73 37 5XQ&RPSOHWLRQ$VVHPEO\ 5' %236FKHPDWLF :HOOKHDG6FKHPDWLFFXUUHQW $QWLFLSDWHG'ULOOLQJ+D]DUGV -DFNXSSRVLWLRQ ),73URFHGXUH &KRNH0DQLIROG6FKHPDWLF &DVLQJ'HVLJQ,QIRUPDWLRQ ´+ROH6HFWLRQ0$63 3ORW1$'*RYHUQPHQWDO6HFWLRQV 6ORW'LDJUDP 'LUHFWLRQDO3URJUDPZS$WWDFKHGVHSDUDWHO\ 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 :HOO6XPPDU\ :HOO1&,$$ 'ULOOLQJ5LJ5LJ /HJ 'LUHFWLRQDOSODQZS 3DG 2OG:HOO'HVLJQDWLRQ6LGHWUDFNRIH[LVWLQJZHOO$37' 3ODQQHG&RPSOHWLRQ7\SH´/LQHU´7XELQJ*/&RPS 7DUJHW5HVHUYRLUV%HOXJD$* .LFNRIISRLQW¶0'¶79'ZS±VHW72:6DW¶0' 3ODQQHG:HOO7'0'79'¶0'¶79' 3%7'0'¶0' 6XUIDFH/RFDWLRQ*RYHUQPHQWDO )1/ ):/6HF715:60$. 6XUIDFH/RFDWLRQ1$'; < 6XUIDFH/RFDWLRQ1$' 7RSRI3URGXFWLYH+RUL]RQ *RYHUQPHQWDO )6/ )(/6HF715:60$. 73+/RFDWLRQ1$'; < 73+/RFDWLRQ1$' %+/*RYHUQPHQWDO )6/ ):/6HF715:60$. %+/1$'; < %+/1$' $)(1XPEHU $)('D\V $)('ULOOLQJ$PRXQW :RUN6WULQJ´6&'6 5.%±$06/¶ 06/WR0/¶ 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 0DQDJHPHQWRI&KDQJH,QIRUPDWLRQ 'DWH )HEUXDU\ 6XEMHFW &KDQJHVWR$SSURYHG3HUPLWWR'ULOO )LOH 1&,$$'ULOOLQJ3URJUDP 6LJQLILFDQWPRGLILFDWLRQVWR'ULOOLQJ3URJUDPIRU37'ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQ DSSURYHG37'ZLOOEHFRPPXQLFDWHGDQGDSSURYHGE\WKH$2*&&SULRUWRFRQWLQXLQJIRUZDUGZLWKZRUN 6HF3DJH'DWH3URFHGXUH&KDQJH$SSURYHG%\ $SSURYDO 'ULOOLQJ0DQDJHU 'DWH 3UHSDUHG (QJLQHHU 'DWH 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 7XEXODU3URJUDP +ROH 6HFWLRQ 2'LQ:WIW&RXSO 2' ,' LQ 'ULIW LQ *UDGH&RQQ7RS%RWWRP ´´´´/-)( %($5 ¶¶ 0LQLPXPRI¶RYHUODSUHTXLUHGEHWZHHQFDVLQJVWULQJV 'ULOO3LSH,QIRUPDWLRQ +ROH 6HFWLRQ 2'LQ,'LQ7-,' LQ 7-2' LQ :W IW *UDGH&RQQ%XUVW SVL &ROODSVH SVL 7HQVLRQ NOEV ´´´´6&'6N 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 ,QWHUQDO5HSRUWLQJ5HTXLUHPHQWV )LOORXWGDLO\GULOOLQJUHSRUWDQGFRVWUHSRUWRQ:HOOH] x5HSRUWFRYHUVRSHUDWLRQVIURPDPWRDP x&OLFNRQRQHRIWKHWDEVDWWKHWRSWRVDYHGDWDHQWHUHG,I\RXFOLFNRQRQHRIWKHWDEVWRWKH OHIWRIWKHGDWDHQWU\DUHD±WKLVZLOOQRWVDYHWKHGDWDHQWHUHGDQGZLOOQDYLJDWHWRDQRWKHUGDWD HQWU\WDE x(QVXUHWLPHHQWU\DGGVXSWRKRXUVWRWDO x7U\WRFDSWXUHDQ\RXWRIVFRSHZRUNDV1377KLVKHOSVODWHUZKHQDJJUHJDWLQJHQGRIZHOO UHSRUWV $IWHUQRRQ8SGDWHV x6XEPLWDVKRUWRSHUDWLRQVXSGDWHHDFKZRUNGD\WRPP\HUV#KLOFRUSFRP FGLQJHU#KLOFRUSFRPVHDQPFODXJKOLQ#KLOFRUSFRP (+6,QFLGHQW5HSRUWLQJ x1RWLI\(+6ILHOGFRRUGLQDWRU L7\OHU3UXLWW& x6SLOOV L.HHJDQ)OHPLQJ& LL0RQW\0\HUV2& LLL6HDQ0FODXJKOLQ x6XEPLW+LOFRUS,QFLGHQWUHSRUWWRFRQWDFWVDERYHZLWKLQKUV &DVLQJ7DOO\ x6HQGILQDO³$V5XQ´&DVLQJWDOO\WRVHDQPFODXJKOLQ#KLOFRUSFRPDQGFGLQJHU#KLOFRUSFRP &DVLQJDQG&PWUHSRUW x6HQGFDVLQJDQGFHPHQWUHSRUWIRUHDFKVWULQJRIFDVLQJWRVHDQPFODXJKOLQ#KLOFRUSFRPDQG FGLQJHU#KLOFRUSFRP 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 &XUUHQW:HOOERUH6FKHPDWLF 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 3UH6LGHWUDFN6FKHPDWLF 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 3ODQQHG:HOOERUH6FKHPDWLF 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 'ULOOLQJ6XPPDU\ $$LVDVKXWLQJDVZHOOZLWKDOORSSRUWXQLWLHVH[KDXVWHG:HOOSODQQHGWREHVLGHWUDFNHGWRGRZQVSDFH WKHSURGXFLQJ%HOXJDIRUPDWLRQV $IWHUSOXJJLQJSDUHQWWKH´WXELQJZLOOEHFXWDQGSXOOHGSULRUWRUXQQLQJD´ZKLSVWRFN7KHSDUHQW ZHOOERUHZLOOEHVLGHWUDFNHGDQGQHZZHOOERUHGULOOHGWR¶$´/SURGOLQHUZLOOEHUXQ FHPHQWHGDQGSHUIRUDWHGEDVHGRQGDWDREWDLQHGZKLOHGULOOLQJWKHLQWHUYDO 7KHZHOOZLOOEHFRPSOHWHGZLWKD´JDVOLIWWLHEDFNFRPSOHWLRQ 'ULOOLQJRSHUDWLRQVDUHH[SHFWHGWRFRPPHQFHDSSUR[LPDWHO\0D\ $OOZDVWH PXGJHQHUDWHGGXULQJGULOOLQJDQGFRPSOHWLRQRSHUDWLRQVZLOOEHKDXOHGWRWKH.HQDL*DV)LHOG * ,IDFLOLW\IRUGLVSRVDOEHQHILFLDOUHXVHGHSHQGLQJRQWHVWUHVXOWV $VHSDUDWHVXQGU\QRWLFHZLOOEHVXEPLWWHGIRUWKH$SOXJJLQJDQGUXQQLQJWKHFRPSOHWLRQ DVVHPEO\ *HQHUDOVHTXHQFHRIRSHUDWLRQVSHUWDLQLQJWRWKLVGULOOLQJRSHUDWLRQ 5LJ 5LJZLOO0,58RYHU$ 18%23(DQGWHVWWRSVL0$63SVL 3XOOKDQJHUDQG/'a¶RI´WXELQJ 0DNH%LWDQGVFUDSSHUUXQWRWXELQJVWXE 6HW´ZKLSVWRFNDW¶DQG56ZDSZHOOWRSSJ/61'PXG 0LOOZLQGRZZLWK¶RIQHZIRUPDWLRQ 3HUIRUP),7WRSSJ(0: 38´PRWRUGULOOLQJDVVHPEO\DQG7,+WRZLQGRZ 'ULOO´SURGXFWLRQKROHWR¶0'SHUIRUPLQJVKRUWWULSVDVQHHGHG 322+ZGLUHFWLRQDOWRROV 5,+Z´OLQHU6HWOLQHUDQGFHPHQW&LUFZHOOERUHFOHDQ 3HUIRUP&OHDQRXWUXQWRSROLVKERUH 5XQDQGVHWOLQHUWRSSDFNHU 3HUIRUPOLQHUODSWHVWWRSVL 5XQ´FRPSOHWLRQ&RYHUHGXQGHUVHSDUDWHVXQGU\ /DQGKDQJHUDQGWHVW 1'%23(18WUHHDQGWHVWYRLG 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 0DQGDWRU\5HJXODWRU\&RPSOLDQFH1RWLILFDWLRQV 5HJXODWRU\&RPSOLDQFH (QVXUHWKDWGULOOLQJDQGFRPSOHWLRQRSHUDWLRQVFRPSO\ZLWKWKHEHORZ$2*&&UHJXODWLRQV,I DGGLWLRQDOFODULW\RUJXLGDQFHLVUHTXLUHGRQKRZWRFRPSO\ZLWKDVSHFLILFUHJXODWLRQGRQRWKHVLWDWHWR FRQWDFWWKH$QFKRUDJH'ULOOLQJ7HDP x%23VVKDOOEHWHVWHGDWZHHNLQWHUYDOVGXULQJWKHGULOOLQJ(QVXUHWRSURYLGH$2*&&KUV QRWLFHSULRUWRWHVWLQJ%23V x7KHLQLWLDOWHVWRI%23HTXLSPHQWZLOOEHWRSVL VXEVHTXHQWWHVWVRIWKH%23HTXLSPHQW ZLOOEHWRSVLIRUPLQDQQXODUWRUDWHG:3SVLRQWKHKLJKWHVWIRULQLWLDO DQGVXEVHTXHQWWHVWVConfirm that these test pressures match those specified on the APD. o7KHKLJKHVWUHVHUYRLUSUHVVXUHH[SHFWHGLVSVLLQWKH%HOXJD*VDQG 79'0$63LV SVLZLWKSVLIWJDVLQWKHZHOOERUH o$FDVLQJWHVWWRSVLLVSODQQHGDVSDUWRIWKHSUHULJZRUN x0LQLPXPUHTXLUHG5DWHG:RUNLQJ3UHVVXUH5:3WKH%23(DQGZHOOKHDGPXVWPHHWRUH[FHHG SVL7KHZHOOKHDGLVUDWHGWRSVL xIf the BOP is used to shut in on the well in a well control situation, ALL BOP components utilized for well control must be tested prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x$OO$2*&&UHJXODWLRQVZLWKLQ$$&³3ULPDU\ZHOOFRQWUROIRUGULOOLQJGULOOLQJIOXLG SURJUDPDQGGULOOLQJIOXLGV\VWHP´ x$OO$2*&&UHJXODWLRQVZLWKLQ$$&³6HFRQGDU\ZHOOFRQWUROIRUSULPDU\GULOOLQJDQG FRPSOHWLRQEORZRXWSUHYHQWLRQHTXLSPHQWDQGGLYHUWHUUHTXLUHPHQWV´ x5HYLHZDOOFRQGLWLRQVRIDSSURYDORIWKH37'RQWKHIRUP(QVXUHWKDWWKHFRQGLWLRQVRI DSSURYDODUHFDSWXUHGLQVKLIWKDQGRYHUQRWHVXQWLOWKH\DUHH[HFXWHGDQGFRPSOLHGZLWK x(QVXUH$2*&&DSSURYHGGULOOLQJSHUPLWLVSRVWHGRQWKHULJIORRUDQGLQ&R0DQRIILFH ,I WKLV LV WKH LQLWLDO %23 WHVW IRU 6SDUWDQ LQ LQLWLDO WHVW LV WR 5:3 SVL SVL DQQXODU 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 6XPPDU\RI%23(TXLSPHQWDQG7HVW5HTXLUHPHQWV +ROH6HFWLRQ(TXLSPHQW 7HVW3UHVVXUHSVL ´ x´6KDIIHU0DQQXODU x´06KDIIHU6/'RXEOHJDWH x%OLQGUDPLQERWWRPFDYLW\ x0XGFURVV x´06KDIIHU6/VLQJOHJDWH x´0&KRNH0DQLIROG x6WDQGSLSHIORRUYDOYHVHWF ,QLWLDO7HVW $QQXODUSVL 6XEVHTXHQW7HVWV $QQXODUSVL x3ULPDU\FORVLQJXQLW0DVFRVWDWLRQERWWOHSVLFORVLQJXQLWZLWKWZRDLUSXPSVDWULSOH[ HOHFWULFGULYHQSXPS 5HTXLUHG$2*&&1RWLILFDWLRQV x:HOOFRQWUROHYHQW%23VXWLOL]HGWRVKXWLQWKHZHOOWRFRQWUROLQIOX[RIIRUPDWLRQIOXLGV xKRXUVQRWLFHSULRUWRIXOO%23(WHVW x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ev 0 %2318DQG7HVW 1'7UHHDQGDGDSWHU7:&LQVWDOOHGDVSDUWRISUHULJZRUN 18WR´0WXELQJVSRRO 18´[0%23DVIROORZVWRSGRZQ x´[06KDIIHUDQQXODU%23 x´6KDIIHU7\SH³6/´'RXEOHUDP´;´9%5LQWRSFDYLW\EOLQGUDPLQEWP FDYLW\ x´PXGFURVV x´6KDIIHU7\SH³6/´VLQJOHUDP´;´9%5 x18SLWFKHUQLSSOHLQVWDOOIORZOLQH x,QVWDOOPDQXDOYDOYHVRQNLOOVLGHRIPXGFURVV0DQXDOYDOYHXVHGDVLQVLGHRU³PDVWHU YDOYH´ x,QVWDOOPDQXDOYDOYHRQFKRNHVLGHRIPXGFURVV,QVWDOODQ+&5RXWVLGHRIWKHPDQXDO YDOYH x´0DGDSWHUUHTXLUHG 7HVW%23( x7HVW%23WRSVLIRUPLQ7HVWDQQXODUWRSVLIRUPLQ x(QVXUHWROHDYH³$´VHFWLRQVLGHRXWOHWYDOYHVRSHQGXULQJ%23WHVWLQJVRSUHVVXUHGRHVQRW EXLOGXSEHQHDWKWKH7:&&RQILUPWKHFRUUHFWYDOYHVDUHRSHQHG x7HVW9%5VRQ´WHVWMRLQWSVL x7HVW$QQXODURQ´WHVWMRLQWSVL x(QVXUHJDVPRQLWRUVDUHFDOLEUDWHGDQGWHVWHGLQFRQMXQFWLRQZ%23( 3XOO7:& 3UHSDUDWRU\:RUNDQG0XG3URJUDP 0L[:%0PXGIRU´KROHVHFWLRQ ´OLQHUVLQVWDOOHGLQPXGSXPSDQGSXPS3=¶V x*DUGQHU'HQYHU3=¶V3XPSVDUHUDWHGDWSVLZLWK´OLQHUVDQGFDQGHOLYHU JSPDWVSP x3XPSUDQJHIRUGULOOLQJZLOOEHJSP7KLVFDQEHDFKLHYHGZLWKRQHRUERWKSXPSV 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 ´3URGXFWLRQKROHPXGSURJUDPVXPPDU\ x3ULPDU\ZHLJKWLQJPDWHULDOWREHXVHGIRUWKHKROHVHFWLRQZLOOEHEDULWHWRPLQLPL]HVROLGV (QVXUHHQRXJKEDULWHLVRQORFDWLRQWRZHLJKWXSWKHDFWLYHV\VWHPSSJDERYHKLJKHVW DQWLFLSDWHG0:LQWKHHYHQWRIDZHOOFRQWUROVLWXDWLRQ x3DVRQ397ZLOOEHXVHGWKURXJKRXWWKHGULOOLQJDQGFRPSOHWLRQSKDVH5HPRWHPRQLWRULQJ VWDWLRQVZLOOEHDYDLODEOHDWWKHGULOOHU¶VFRQVROH&R0DQRIILFHDQG7RROSXVKHURIILFH System Type: /16':%0 Properties: 0'0XG :HLJKW9LVFRVLW\3ODVWLF 9LVFRVLW\<LHOG3RLQWS++3+7 ¶7' System Formulation: 2% KCL/BDF-976/GEM GP 3URGXFW&RQFHQWUDWLRQ :DWHU .&O &DXVWLF %$5$=$1' '(;75,'/7 3$&/ %') *(0*3 %$5$&$5% 67((/6($/ %$52),%5( %$52752/3/86 62/7(; %$52,' $/'$&,'(* EEO SSE SSES+ SSEDVUHTXLUHG<3 SSE SSE SSE E\YROXPH SSESSERIHDFK SSESSERIHDFK SSE SSE ±SSE DVQHHGHG SSE 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 3URJUDPPXGZHLJKWVDUHJHQHUDWHGE\UHYLHZLQJGDWDIURPSURGXFLQJ VKXWLQRIIVHWZHOOVHVWLPDWHG %+3¶VIURPIRUPDWLRQVFDSDEOHRISURGXFLQJIOXLGVRUJDVDQGIRUPDWLRQVZKLFKFRXOGUHTXLUHPXG ZHLJKWVIRUKROHVWDELOL]DWLRQ $JXLGLQJSKLORVRSK\ZLOOEHWKDWLWLVOHVVULVN\WRZHLJKWXSDORZHUZHLJKWPXGWKDQEHRYHUEDODQFHG DQGKDYHWKHFKDOOHQJHWRPLWLJDWHORVWFLUFXODWLRQZKLOHGULOOLQJDKHDG 'HFRPSOHWH6HW:KLSVWRFN0LOO:LQGRZ x%237HVWLQWHUYDOIRUWKLVVHFWLRQLVGD\V7RFRPSO\ZLWKVWDWHUHJXODWLRQVUHFRUGPXGZHLJKWVLQDQGRXW DQGHQVXUH%23(IXQFWLRQWHVWDUHUHFRUGHGLQ:HOO(=EHIRUHWKHGD\GHDGOLQH 2SHUDWLRQ6WHSV 3XOOKDQJHUDQG/'a¶RI´WXELQJ x´(8(UGKDQJHUWKUHDGV x´(8(UGWXELQJ 6HWZHDUEXVKLQJLQZHOOKHDG(QVXUH,'RIZHDUEXVKLQJ!´ 38FOHDQRXWDVVHPEO\ELWDQGVFUDSHUDQG'3WRWXELQJVWXE 0DNHXSWKH%270HFKDQLFDOVHW:KLSVWRFN 7,+ZLWK'3WRWKHZKLSVWRFNVHWWLQJGHSWK([HUFLVHFDXWLRQZKHQ5,+VHWWLQJVOLSVZLWKZKLSVWRFN DVVHPEO\ ¾)LOOWKHGULOOSLSHDPLQLPXPRIHYHU\VWDQGVRQWKHWULSLQWKHKROHZLWKWKHZKLSVWRFNDVVHPEO\ ¾$YRLGVXGGHQVWDUWVDQGVWRSVZKLOHUXQQLQJWKHZKLSVWRFN ¾5HFRPPHQGUXQQLQJLQWKHKROHDWDPD[LPXPRIVHFRQGVSHUVWDQGWDNLQJFDUHQRWWRVSXGRUFDWFK WKHVOLSV(QVXUHUXQQLQJVWULQJLVVWDWLRQDU\SULRUWRLQVHUWLRQRIWKHVOLSVDQGWKDWVOLSVDUHUHPRYHGVORZO\ ZKHQUHOHDVLQJWKHZRUNVWULQJWR5,+7KHVHSUHFDXWLRQVDUHUHTXLUHGWRDYRLGDQ\ZHDNHQLQJRIWKH ZKLSVWRFNVKHDUPHFKDQLVPVDQGRUWRDYRLGSDUWSUHVHWRQWKHSDFNHU 2ULHQWZKLSVWRFNDVGLUHFWHGE\WKHGLUHFWLRQDOGULOOHU7KHGLUHFWLRQDOSODQVSHFLILHVGHJ52+6 6HWWKHWRSRIWKHZKLSVWRFNDWa¶0' x´&ROODUVORFDWHGDW¶DQG¶ x5HIORJ1&,8$8OWUDVRQLF,PDJHU-8/ &LUFXODWH PXG LQWR WKH ZHOO DQG WKHQ SUHVVXUH WHVW FDVLQJ WR SVL EHIRUH PLOOLQJ ZLQGRZ EMP 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 0LOOZLQGRZSOXV¶¶RIQHZKROH'2127(;&(('¶2)1(:+2/(%()25(5811,1* 7+(3/$11('),7/27 ¾8VHGLWFKPDJQHWVWRFROOHFWWKHPHWDOVKDYLQJV&OHDQUHJXODUO\ ¾(QVXUHDQ\SHUVRQQHOZRUNLQJDURXQGPHWDOVKDYLQJVZHDUSURSHU33(LQFOXGLQJJRJJOHVIDFHVKLHOGDQG .HYODUJORYHV ¾:RUNWKHXSSHUPLOOWKURXJKWKHZLQGRZWRFRQILUPWKHZLQGRZPLOOLQJLVFRPSOHWHDQGFLUFXODWHZHOOFOHDQ FLUFXODWHDPLQLPXPRIERWWRPVXS3XPSDKLJKYLVVXSHUVZHHSWRUHPRYHPHWDOVKDYLQJVDQG PDNHHYHU\HIIRUWWRUHPRYHDOORIWKHVXSHUVZHHSSLOOIURPWKHPXGV\VWHPDVLWLVFLUFXODWHGWRVXUIDFH 3XOOVWDUWHUPLOOLQWRFDVLQJDERYHWRSRIZKLSVWRFNIORZFKHFNWKHZHOOIRUPLQXWHVDQGFRQGXFWD ),7WRSSJ ¾$VVXPLQJWKHNLFN]RQHLVDW7'D),7RISSJ(0:JLYHVDQXQOLPLWHG.LFN7ROHUDQFHYROXPHZLWK SSJPXGZHLJKW ¾0RQLWRUWKH2$GXULQJ),7DQGUHSRUWDQGFKDQJHLQSUHVVXUH 322+DQG/'PLOOLQJDVVHPEO\ ¾2QFHRXWRIWKHKROHLQVSHFWPLOOJDXJHDQGUHFRUG ¾)ORZFKHFNZHOOIRUPLQXWHVWRFRQILUPQRIORZ ¾%HIRUHSXOOLQJRIIERWWRP ¾%HIRUHSXOOLQJWKH%+$WKURXJKWKH%23( )OXVKWKHVWDFNOLQHVWRUHPRYHPHWDOGHEULVWKDWPD\KDYHVHWWOHGRXWLQWKHVHDUHDV(QVXUH%23 HTXLSPHQWLVRSHUDEOH 'ULOO´+ROH6HFWLRQ 38¶RI´&'6'ULOOSLSHIRUGULOOLQJ´KROHVHFWLRQ 38´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ev 0 3URGXFWLRQVHFWLRQZLOOEHGULOOHGZLWKDPRWRU0XVWNHHSXSZLWKGHJ'/6LQWKHEXLOGDQG GURSVHFWLRQVRIWKHZHOOERUH 3ULPDU\ELWZLOOEHWKH%DNHU+XJKHV.\PHUD´.0(QVXUHWRKDYHDEDFNXS3'&ELW DYDLODEOHRQORFDWLRQ 7,+WRZLQGRZ6KDOORZWHVW0:'RQWULSLQ 7,+WKURXJKZLQGRZHQVXUH%DNHU+XJKHV0:'VHUYLFHUHSRQULJIORRUGXULQJWKLVRSHUDWLRQ &LUFXODWHZHOOZLWKSSJ/16'WRZDUPXSPXGXQWLOJRRGSSJLQDQGRXW 'ULOODSSUR[¶UDWKROHWRDFFRPPRGDWHWKHGULOOLQJDVVHPEO\5HDPVKRHDVQHHGHGWRDVVXUH WKHUHLVOLWWOHRUQRGUDJ$IWHUUHDPLQJVKXWRIISXPSVDQGURWDU\LIKROHFRQGLWLRQVDOORZDQG SDVVWKURXJKVKRHFKHFNLQJIRUGUDJ &LUFXODWH%RWWRPV8SXQWLO0:LQ 0:RXW 'ULOO´KROHWR¶0'XVLQJPRWRUDVVHPEO\ x3XPSVZHHSVDQGPDLQWDLQPXGUKHRORJ\WRHQVXUHHIIHFWLYHKROHFOHDQLQJ x8WLOL]H,QOHWH[SHULHQFHWRGULOOWKURXJKFRDOVHDPVHIILFLHQWO\&RDOVHDPORJZLOOEH SURYLGHGE\+LOFRUS*HRWHDPWU\WRDYRLGVOLGLQJWKURXJKFRDOVHDPV:RUNWKURXJKFRDO VHDPVRQFHGULOOHG x.HHSVZDEDQGVXUJHSUHVVXUHVORZZKHQWULSSLQJ x6HHDWWDFKHGPXGSURJUDPIRUKROHFOHDQLQJDQG/&0VWUDWHJLHV x(QVXUHVROLGVFRQWUROHTXLSPHQWIXQFWLRQLQJSURSHUO\DQGXWLOL]HGWRNHHS/*6WRD PLQLPXPZLWKRXWH[FHVVLYHGLOXWLRQ x$GMXVW0:DVQHFHVVDU\WRPDLQWDLQKROHVWDELOLW\ x(QVXUHPXGHQJLQHHUVHWXSWRSHUIRUP+7+3IOXLGORVV x0DLQWDLQ$3,IOXLGORVV x7DNH0:'VXUYH\VHYHU\VWDQGGULOOHG x0LQLPL]HEDFNUHDPLQJZKHQZRUNLQJWLJKWKROH $W7'SXPSDVZHHSDQGDPDUNHUWREHXVHGDVDIOXLGFDOLSHUWRGHWHUPLQHDQQXOXVYROXPHIRU FHPHQWFDOFXODWLRQV&%8DQGSXOODZLSHUWULSEDFNWRWKHZLQGRZ 72+ZLWKGULOOLQJDVVHPEO\KDQGOH%+$DVDSSURSULDWH 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 5XQ´3URGXFWLRQ/LQHU 58%DNHU´OLQHUUXQQLQJHTXLSPHQW x(QVXUH´&'6FURVVRYHURQULJIORRUDQG08WR)269 x58ILOOXSOLQHWRILOOOLQHUZKLOHUXQQLQJ x(QVXUHDOOOLQHUKDVEHHQGULIWHGDQGWDOO\YHULILHGSULRUWRUXQQLQJ x%HVXUHWRFRXQWWKHWRWDORIMRLQWVEHIRUHUXQQLQJ x.HHSKROHFRYHUHGZKLOH58FDVLQJWRROV x5HFRUG2'¶V,'¶VOHQJWKV61¶VRIDOOFRPSRQHQWVZYHQGRU PRGHOLQIR 38VKRHMRLQWYLVXDOO\YHULI\QRGHEULVLQVLGHMRLQW &RQWLQXH08 WKUHDGORFNLQJVKRHWUDFNDVV\FRQVLVWLQJRI x6KRHMRLQWZVKRHEXFNHGRQ WKUHDGORFNHGFRXSOLQJDOVRWKUHDGORFNHG x-RLQWZLWKIORDWFROODUEXFNHGRQSLQHQG WKUHDGORFNHGFRXSOLQJDOVRWKUHDGORFNHG x/DQGLQJFROODUSXSEXFNHGXS x&HQWUDOL]HUVZLOOEHUXQRQ´OLQHU x(QVXUHSURSHURSHUDWLRQRIIORDWVKRH )& 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 &RQWLQXHUXQQLQJ´SURGXFWLRQOLQHUWR7' x6KRUWMRLQWUXQHYHU\¶ x)LOOOLQHUZKLOHUXQQLQJXVLQJILOOXSOLQHRQULJIORRU x8VH³$3,0RGLILHG´WKUHDGFRPSRXQG'RSHSLQHQGRQO\ZSDLQWEUXVK x8WLOL]HDFROODUFODPSXQWLOZHLJKWLVVXIILFLHQWWRNHHSVOLSVVHWSURSHUO\ (QVXUHWRUXQHQRXJKOLQHUWRSURYLGHDWOHDVW¶RYHUODSLQVLGH´FDVLQJ(QVXUHVHWWLQJVOHHYHZLOO QRWEHVHWLQD´FRQQHFWLRQ %HIRUHSLFNLQJXS%DNHUVHWWLQJVOHHYHFRXQWWKHRIMRLQWVRQWKHSLSHGHFNWRPDNHVXUHLWFRLQFLGHV ZLWKWKHSLSHWDOO\ 5,+RQHVWDQGDQGFLUFXODWHDPLQLPXPRIRQHOLQHUYROXPH1RWHZHLJKWRIOLQHU 5,+ZOLQHURQ'3QRIDVWHUWKDQPLQVWDQG:DWFKGLVSODFHPHQWFDUHIXOO\DQGDYRLGVXUJLQJWKH KROH6ORZGRZQUXQQLQJVSHHGLIQHFHVVDU\ 08WRSGULYHDQGILOOSLSHZKLOHORZHULQJVWULQJHYHU\VWDQGV 6HWVORZO\LQDQGSXOOVORZO\RXWRIVOLSV &LUFXODWHGULOOSLSHDQGOLQHUYROXPHDW´ZLQGRZSULRUWRJRLQJLQWRRSHQKROH6WDJHSXPSVXS VORZO\DQGPRQLWRUIRUORVVHV &RQWLQXHWRILOOWKHVWULQJHYHU\MRLQWVZKLOHUXQQLQJOLQHULQRSHQKROH'RQRWVWRSWRILOOFDVLQJ 38WKHFPWVWDQGDQGWDJERWWRPZLWKWKHOLQHUVKRH38¶RIIERWWRP1RWHVODFNRIIDQGSLFNXS ZHLJKWV5HFRUGURWDWLQJWRUTXHYDOXHVDW USP 6WDJHSXPSUDWHVXSVORZO\WRFLUFXODWLQJUDWHWRFRQGLWLRQPXGZLWKWKHOLQHURQERWWRP5HGXFHWKH ORZHQGUKHRORJ\RIWKHGULOOLQJIOXLGE\DGGLQJZDWHUDQGWKLQQHUV 5HFLSURFDWH URWDWHVWULQJLIKROHFRQGLWLRQVDOORZ&LUFXQWLOKROHDQGPXGLVLQJRRGFRQGLWLRQIRU FHPHQWLQJ &HPHQW´3URGXFWLRQ/LQHU +ROGDSUHMREVDIHW\PHHWLQJRYHUWKHXSFRPLQJFPWRSHUDWLRQV $WWHPSWWRUHFLSURFDWHWKHFDVLQJGXULQJFPWRSHUDWLRQVXQWLOKROHJHWVVWLFN\ 3XPSEEOVSSJVSDFHU 7HVWVXUIDFHFPWOLQHVWRSVL 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev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ev 0 %XPSWKHSOXJ'RQRWRYHUGLVSODFHE\PRUHWKDQEEOV 3UHVVXUHXSWRSVLWRUHOHDVHWKHUXQQLQJWRRO+5'(IURPWKHOLQHU %OHHGSUHVVXUHWR]HURWRFKHFNIORDWHTXLSPHQW 38YHULI\VHWWLQJWRROLVUHOHDVHG 3UHVVXUHXSGULOOSLSHWRSVLDQGSLFNXSWRUHPRYHWKH56SDFNRIIEXVKLQJIURPWKH56QLSSOH %XPSXSSUHVVXUHDVUHT¶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³ZRUN´WKHWRUTXHGRZQWRWKH VHWWLQJWRRO $IWHUVFUHZVKDYHVKHDUHGWKHWRSVXEDQGERG\RIWKHVHWWLQJWRROZLOOWXUQWXUQ7KHQSURFHHG VODFNLQJRIIVHWGRZQZHLJKWWRVKHDUVHFRQGVHWRIVKHDUVFUHZV7KHWRSVXEZLOOGURSLQFKHV$W WKLVSRLQWWKHERWWRPVXEQRORQJHUVXSSRUWVWKHFROOHWILQJHUV3LFNVWUDLJKWXSZLWKZRUNVWULQJWR UHOHDVHFROOHWIURPWKHSURILOH Ensure to report the following on Wellez: x3UHIOXVKW\SHYROXPHEEOV ZHLJKWSSJ x&HPHQWVOXUU\W\SHOHDGRUWDLOYROXPH ZHLJKW x3XPSUDWHZKLOHPL[LQJESPQRWHDQ\VKXWGRZQGXULQJPL[LQJRSHUDWLRQVZLWKDGXUDWLRQ 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 x3XPSUDWHZKLOHGLVSODFLQJQRWHZKHWKHUGLVSODFHPHQWE\SXPSWUXFNRUPXGSXPSVZHLJKW W\SH RIGLVSODFLQJIOXLG x1RWHLIOLQHULVUHFLSURFDWHGRUURWDWHGGXULQJWKHMRE x&DOFXODWHGYROXPHRIGLVSODFHPHQWDFWXDOGLVSODFHPHQWYROXPHZKHWKHUSOXJEXPSHG EXPS SUHVVXUHGRIORDWVKROG x3HUFHQWPXGUHWXUQVGXULQJMRELILQWHUPLWWHQWQRWHWLPLQJGXULQJSXPSLQJRIMRE)LQDOFLUFXODWLQJ SUHVVXUH x1RWHLISUHIOXVKRUFHPHQWUHWXUQVDWVXUIDFH YROXPH x1RWHWLPHFHPHQWLQSODFH x1RWHFDOFXODWHGWRSRIFHPHQW x$GGDQ\FRPPHQWVZKLFKZRXOGGHVFULEHWKHVXFFHVVRUSUREOHPVGXULQJWKHFHPHQWMRE Note: Send Csg & cmt report + “As-Run” liner tally to sean.mclaughlin@hilcorp.com &OHDQRXW/73 37 3HUIRUPDFOHDQRXWUXQWRGUHVVVHWWLQJVOHHYHDQGFDVLQJIRUWKH/73DQGVHDOVWHP,QFOXGHSROLVKPLOO DQG´VWULQJPLOORUFDVLQJVFUDSHU 08%DNHUOLQHUWRSSDFNHUDQGVHDODVVHPEO\5,+(QVXUHWKH/73ZLOOQRWEHVHWDFURVVD´ FRQQHFWLRQ $VVXUHVHDOVWHPLWLQVHWWLQJVOHHYHZLWKHLWKHUSUHVVXUHRUIORZ 5RWDWHVORZO\DQGVODFNRIINGRZQKROHWRVHWWKH/73 3UHVVXUHXSWRSVLWRUHOHDVHWKHUXQQLQJWRRO+5'(IURPWKH/73 7HVWOLQHUODSWRSVLEXUVWRI´DIWHUFHPHQWKDVUHDFKHGSVLFRPSUHVVLYHVWUHQJWK 5XQ&RPSOHWLRQ$VVHPEO\ 5XQ´WXELQJFRPSOHWLRQDVVHPEO\DVSHUVHSDUDWH$SSURYHG&RPSOHWLRQ6XQGU\ 5' x,QVWDOO%39LQZHOOKHDG5,/'V RVHWWKH/73 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 x1'%23(18WUHHWHVWYRLG x5LJ'RZQ %236FKHPDWLF 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 :HOOKHDG6FKHPDWLFFXUUHQW 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 $QWLFLSDWHG'ULOOLQJ+D]DUGV /RVW&LUFXODWLRQ 'ULOOGHSOHWHGUHVHUYRLUPD\FDXVHORVVFLUFXODWLRQHYHQWVDVVHHQLQWKHSURJUDPRQ$$DQG $$ x0DLQWDLQVXIILFLHQWYROXPHVZKLOHGULOO x0DLQWDLQDELOLW\WRWDNHRQ),:GXULQJGULOOLQJSKDVH x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x.HHSWKHGULOOSLSHLQWHQVLRQWRSUHYHQWDZKLSSLQJHIIHFWZKLFKFDQGLVWXUEFRDOVHFWLRQV x8VHDVSKDOWW\SHDGGLWLYHVWRIXUWKHUVWDELOL]HFRDOVHDPV x,QFUHDVHIOXLGGHQVLW\DVUHTXLUHGWRFRQWUROUXQQLQJFRDOV x(PSKDVL]HJRRGKROHFOHDQLQJWKURXJKK\GUDXOLFV523DQGV\VWHPUKHRORJ\ x0LQLPL]HVZDEDQGVXUJHSUHVVXUHV x0LQLPL]HEDFNUHDPLQJWKURXJKFRDOVZKHQSRVVLEOH +6 +6LVQRWSUHVHQWLQWKLVKROHVHFWLRQ $QWLFROOLVLRQ 1RFORVHDSSURDFKHV 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 -DFNXSSRVLWLRQ 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 ),73URFHGXUH )RUPDWLRQ,QWHJULW\7HVW),7DQG /HDN2II7HVW/273URFHGXUHV 3URFHGXUHIRU),7 'ULOO RIQHZIRUPDWLRQEHORZWKHFDVLQJVKRHWKLVGRHVQRWLQFOXGHUDWKROHEHORZWKHVKRH &LUFXODWHWKHKROHWRHVWDEOLVKDXQLIRUPPXGGHQVLW\WKURXJKRXWWKHV\VWHP38LQWRWKHVKRH &ORVHWKHEORZRXWSUHYHQWHUUDPRUDQQXODU 3XPSGRZQWKHGULOOVWHPDWWRESP 2QDJUDSKSORWWKHIOXLGSXPSHGYROXPHRUVWURNHVYVGULOOSLSHSUHVVXUHXQWLODSSURSULDWHVXUIDFH SUHVVXUHLVDFKLHYHGIRU),7DWVKRH$GGFDVLQJSUHVVXUHWHVWGDWDWRJUDSKLIUHFHQWDQGDYDLODEOH 6KXWGRZQDWUHTXLUHGVXUIDFHSUHVVXUH+ROGIRUDPLQLPXPPLQXWHVRUXQWLOWKHSUHVVXUHVWDELOL]HV 5HFRUGWLPHYVSUHVVXUHLQPLQXWHLQWHUYDOV %OHHGWKHSUHVVXUHRIIDQGUHFRUGWKHIOXLGYROXPHUHFRYHUHG 7KHSUHGHWHUPLQHGVXUIDFHSUHVVXUHIRUHDFKIRUPDWLRQLQWHJULW\WHVWLVEDVHGRQDFKLHYLQJDQ(0:DW OHDVWSSJKLJKHUWKDQWKHHVWLPDWHGUHVHUYRLUSUHVVXUHDQGDOORZLQJIRUDQDSSURSULDWHDPRXQWRINLFN WROHUDQFHLQFDVHZHOOFRQWUROPHDVXUHVDUHUHTXLUHG :KHUHUHTXLUHGWKH/27LVSHUIRUPHGLQWKHVDPHIDVKLRQDVWKHIRUPDWLRQLQWHJULW\WHVW,QVWHDGRI VWRSSLQJDWDSUHGHWHUPLQHGSRLQWVXUIDFHSUHVVXUHLVLQFUHDVHGXQWLOWKHIRUPDWLRQEHJLQVWRWDNHIOXLG DWWKLVSRLQWWKHSUHVVXUHZLOOFRQWLQXHWRULVHEXWDWDVORZHUUDWH7KHV\VWHPLVVKXWLQDQGSUHVVXUH PRQLWRUHGDVZLWKDQ),7 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 &KRNH0DQLIROG6FKHPDWLF 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 &DVLQJ'HVLJQ,QIRUPDWLRQ 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 ´+ROH6HFWLRQ0$63 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A PTD Rev 0 6ORW'LDJUDP 3DJH5HYLVLRQ)HEUXDU\ NCI A-09A 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 233.65° (550 usft/in)NCI A-09A wp04 Tgt135004000450050005500600065007000A-094 1/2" x 6 1/8"3500400045005000550060006500700075007596NCI A-09A wp05KOP: 12º/100' : 4050' MD, 3417.19'TVD : 60° RT TFEnd Dir : 4063' MD, 3426.48' TVDStart Dir 5º/100' : 4083' MD, 3440.68'TVDEnd Dir : 4489.95' MD, 3677.26' TVDStart Dir 4º/100' : 6173.81' MD, 4418.92'TVDEnd Dir : 6770.61' MD, 4784.22' TVDTotal Depth : 7595.61' MD, 5416.21' TVDTop Beluga BHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: NCIU A-09Water Depth: 99.00+N/-S +E/-W Northing EastingLatitudeLongitude0.00 0.00 2586667.35 332040.44 61° 4' 35.768 N150° 56' 54.681 WSURVEY PROGRAMDate: 2022-02-10T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool103.23 2453.23 N COOK INLET UNIT A-09 Gyrodata Survey (NCI A-09) 3_Gyro-CT_Csg+Cent2506.23 4050.00 N COOK INLET UNIT A-09 Eastman SS Gyro (NCI A-09) 3_CB-Film-GSS4050.00 4400.00 NCI A-09A wp05 (NCIU A-09A)3_MWD_Interp Azi+Sag4400.00 7595.61 NCI A-09A wp05 (NCIU A-09A) 3_MWD+AX+SagFORMATION TOP DETAILSTVDPathTVDssPath MDPath Formation4531.634405.00 6395.66 Top Beluga BREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well NCIU A-09, True NorthVertical (TVD) Reference:NCI A-09 @ 126.63usft (Spartan 151)Measured Depth Reference:NCI A-09 @ 126.63usft (Spartan 151)Calculation Method:Minimum CurvatureProject:North Cook InletSite:North Cook Inlet UnitWell:NCIU A-09Wellbore:NCIU A-09ADesign:NCI A-09A wp05CASING DETAILSTVD TVDSS MD Size Name5416.21 5289.58 7595.61 4-1/2 4 1/2" x 6 1/8"SECTION DETAILSSecMD Inc Azi TVD +N/-S +E/-W Dleg TFace VSectTargetAnnotation1 4050.00 43.99 227.99 3417.19 -1237.43 -1294.75 0.00 0.00 1776.24 KOP: 12º/100' : 4050' MD, 3417.19'TVD : 60° RT TF2 4063.00 44.77 229.92 3426.48 -1243.40 -1301.60 12.00 60.00 1785.30 End Dir : 4063' MD, 3426.48' TVD3 4083.00 44.77 229.92 3440.68 -1252.47 -1312.38 0.00 0.00 1799.35 Start Dir 5º/100' : 4083' MD, 3440.68'TVD4 4489.95 63.87 238.66 3677.26 -1441.74 -1580.86 5.00 23.11 2127.77 End Dir : 4489.95' MD, 3677.26' TVD5 6173.81 63.87 238.66 4418.92 -2228.01 -2872.02 0.00 0.00 3633.73 Start Dir 4º/100' : 6173.81' MD, 4418.92'TVD66395.61 55.00 239.00 4531.60 -2326.78 -3035.25 4.00 178.19 3823.74 NCI A-09A wp04 Tgt17 6770.61 40.00 239.00 4784.22 -2468.77 -3271.56 4.00 180.00 4098.23 End Dir : 6770.61' MD, 4784.22' TVD8 7595.61 40.00 239.00 5416.21 -2741.90 -3726.12 0.00 0.00 4626.23 Total Depth : 7595.61' MD, 5416.21' TVD -2800-2625-2450-2275-2100-1925-1750-1575-1400-1225-1050-875-700-525South(-)/North(+) (350 usft/in)-4025 -3850 -3675 -3500 -3325 -3150 -2975 -2800 -2625 -2450 -2275 -2100 -1925 -1750 -1575 -1400 -1225 -1050 -875West(-)/East(+) (350 usft/in)NCI A-09A wp04 Tgt1A -0 9 4 1/2" x 6 1/8"27503000325035003750 4 0 0 0 4 2 5 0 4 5 0 0 4 7 5 0 5 0 0 0 5 2 5 0 5 4 1 6 NCI A-09A wp05KOP: 12º/100' : 4050' MD, 3417.19'TVD : 60° RT TFEnd Dir : 4063' MD, 3426.48' TVDStart Dir 5º/100' : 4083' MD, 3440.68'TVDEnd Dir : 4489.95' MD, 3677.26' TVDStart Dir 4º/100' : 6173.81' MD, 4418.92'TVDEnd Dir : 6770.61' MD, 4784.22' TVDTotal Depth : 7595.61' MD, 5416.21' TVDCASING DETAILSTVDTVDSS MDSize Name5416.21 5289.58 7595.61 4-1/2 4 1/2" x 6 1/8"Project: North Cook InletSite: North Cook Inlet UnitWell: NCIU A-09Wellbore: NCIU A-09APlan: NCI A-09A wp05WELL DETAILS: NCIU A-09Water Depth: 99.00+N/-S +E/-WNorthingEastingLatitudeLongitude0.00 0.002586667.35 332040.44 61° 4' 35.768 N 150° 56' 54.681 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well NCIU A-09, True NorthVertical (TVD) Reference: NCI A-09 @ 126.63usft (Spartan 151)Measured Depth Reference:NCI A-09 @ 126.63usft (Spartan 151)Calculation Method:Minimum Curvature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eparation Factor4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750Measured Depth (500 usft/in)A-09B-03No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: NCIU A-09 NAD 1927 (NADCON CONUS) Alaska Zone 04Water Depth:99.00+N/-S+E/-W NorthingEastingLatitudeLongitude0.000.00 2586667.35 332040.44 61° 4' 35.768 N150° 56' 54.681 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well NCIU A-09, True NorthVertical (TVD) Reference:NCI A-09 @ 126.63usft (Spartan 151)Measured Depth Reference:NCI A-09 @ 126.63usft (Spartan 151)Calculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name5416.21 5289.58 7595.61 4-1/2 4 1/2" x 6 1/8"SURVEY PROGRAMDate: 2022-02-10T00:00:00 Validated: Yes Version: Depth From Depth ToSurvey/PlanTool103.23 2453.23 N COOK INLET UNIT A-09 Gyrodata Survey (NCI A-09)3_Gyro-CT_Csg+Cent2506.23 4050.00 N COOK INLET UNIT A-09 Eastman SS Gyro (NCI A-09) 3_CB-Film-GSS4050.00 4400.00 NCI A-09A wp05 (NCIU A-09A)3_MWD_Interp Azi+Sag4400.00 7595.61 NCI A-09A wp05 (NCIU A-09A) 3_MWD+AX+Sag0.0040.0080.00120.00160.00200.00Centre to Centre Separation (80.00 usft/in)4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750Measured Depth (500 usft/in)A-09NO GLOBAL FILTER: Using user defined selection & filtering criteria4050.00 To 7595.61Project: North Cook InletSite: North Cook Inlet UnitWell: NCIU A-09Wellbore: NCIU A-09APlan: NCI A-09A wp05Ladder/S.F. Plots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±JRYHUQHGE\&2$ :HOOORFDWHGLQDGHILQHGSRRO<HV 5XOH:HOO6SDFLQJ7KHUHVKDOOEHQRUHVWULFWLRQVDVWRZHOOVSDFLQJZLWKLQWKHSRROH[FHSW :HOOORFDWHGSURSHUGLVWDQFHIURPGULOOLQJXQLWERXQGDU\<HV WKDWQRSD\VKDOOEHRSHQHGLQDZHOOZLWKLQ¶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