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Home My WebLink About222-0571. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 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): 11,459' N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 8,530psi Liner 10,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ZXP Liner Top Pkr; N/A 7,641' MD/ 6,705' TVD; N/A 10,462' 7,530' 7,530' Beaver Creek Beluga Gas 20" 13-3/8" See Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 14BCO 237D Same 6,989'7" ~2164psi 7,838' See Schematic Length December 31, 2025 11,457'3,817' 3-1/2" 10,460' 7,838' Perforation Depth MD (ft): 3,632' 3-1/2" See Schematic 5,750 psi 3,060 psi 3,450 psi 145' 3,548' 145' 2,122' Size 145' 9-5/8"3,632' 2,122' MD Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 7,651' 11,220psi 2,122' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 222-057 50-133-20539-02-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Ryan Lemay, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade: ryan.lemay@hilcorp.com 661-487-0871 Noel Nocas, Operations Manager 907-564-5278 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: m n P s 66 t N 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 Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.12.22 16:56:42 - 09'00' Noel Nocas (4361) 325-772 By Grace Christianson at 7:58 am, Dec 23, 2025 DSR-12/29/25TS 12/23/25 Perform MIT-IA to 2000 psi once job is complete and well has been brought on line, within 30 days of POP. 10-404 BJM 12/30/25JLC 12/30/2025 12/30/25 Well Prognosis Well: BCU-14B Well Name: BCU-14B API Number: 50-133-20539-02-00 Current Status: Producing Gas Well Permit to Drill Number: 222-057 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661) 487-0871 Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2800 psi @ 6363 TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2164 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.63 psi/ft using 12.1 ppg EMW FIT at the 9-5/8 int. casing shoe Shallowest Allowable Perf TVD: MPSP / (0.63 - 0.1) = 2164 psi / 0.53 = 4083 TVD (No plans to perforated above Beluga Gas Pool / PA) Top of Applicable Gas Pool / PA: 6531 MD / 5832 TVD (Beluga) Well Status: Producing Gas Well Currently producing + 150 mcfd / 11 bwpd / 66 psi FTP (As of 12/14/2025) Brief Well Summary In April of 2025, the 3-1/2 x 7 annulus was cemented above the liner top packer and perforations were added in the Beluga 12 & 11 intervals. The well came on production at + 600 mcfd from these intervals. Gas rate declined declined to + 200 mcfd by the start of June 2025. Additional perforations were added in the Bel 10 interval in June of 2025 bringing production back up to + 350 mcfd. Since, the gas production rates have slowly declined and as of 12/14/2025 current well production is + 150 mcfd / 11 bwpd / 66 psi FTP The purpose of this Sundry is to add additional perforations in the Beluga sands. Wellbore Notes: Inclination o Max deviation of 39.6° @ 5,867 MD o Max DLS of 4.98°/ 100 @ 3,714 MD Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,500 psi high 3. RIH and perforate the following sands from bottom up. Below are proposed targeted sands in order of testing (bottom/up), but additional intervals may be added depending on results of these perfs, between the proposed top and bottom perfs Well Sand MD Top MD Bottom TVD Top TVD Bottom Interval BCU-14B BEL 5 ±6,563' ±6,583' ±5,858' ±5,874' ±20' BCU-14B BEL 5 ±6,593' ±6,605' ±5,882' ±5,892' ±12' BCU-14B BEL 5 ±6,614' ±6,626' ±5,899' ±5,909' ±12' BCU-14B BEL 6 ±6,671' ±6,691' ±5,945' ±5,961' ±20' BCU-14B BEL 7 ±6,693' ±6,700' ±5,962' ±5,968' ±7' Well Prognosis Well: BCU-14B BCU-14B BEL 8 ±6,787' ±6,833' ±6,038' ±6,075' ±46' BCU-14B BEL 8B ±6,869' ±6,879' ±6,104' ±6,112' ±10' BCU-14B BEL 9 ±6,966' ±6,980' ±6,183' ±6,195' ±14' BCU-14B BEL 9 ±6,997' ±7,015' ±6,209' ±6,224' ±18' BCU-14B BEL 11 ±7,169' ±7,175' ±6,357' ±6,363' ±6' a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If any current or proposed zones produce sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together. If possible, the CIBP will be set 50 above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50. f. If necessary, use nitrogen or pad gas to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Contingency Procedure: Coiled Tubing Cleanout 1. If throughout the job any current or proposed zones produce sand and / or water that cannot be depressed and pushed away with nitrogen or high-pressure pad gas, a coil tubing unit may be rigged up to clean out fill or fluid blown down as necessary. a. MIRU Fox CTU, PT BOPE to 250 psi low / 2500 psi high i. Provide AOGCC 24hrs notice of BOP test. b. Cleanout wellbore fill and / or blowdown well with nitrogen if necessary. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 4. Standard Well Procedure N2 Operations Updated by DMA 07-14-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390 MD / 10,396 TVD TD = 11,459 MD / 10,462 TVD RKB to GL = 16.0 3-1/8 Otis CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20Conductor 133 K-55 Weld 18.73Surf 145 13-3/8"Surf Csg 68.0 K-55 BTC 12.415Surf 2,122 9-5/8Intermediate Csg 40.0 L-80 BTC 8.835Surf 3,632 TOW 7Intermediate Csg 2 26 L-80 Multiple 6.276Surf 7,838 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.9927,64111,457 3-1/2"Tubing 9.3 L-80 RTS-8 2.992Surf 7,651 2 20 13-3/8 3-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 3,632N/A 9.625Whipstock 2 7,530Cement Retainer (4/11/25) 3 7,641 4.150 5.75 Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2 bullet seal assembly 4 7,965CIBP w/ 48 cement TOC @ 7,917 (3/31/25) 5 8,255CIBP (10/23/24) 6 8,407CIBP (10/22/24) 7 8,445CIBP (10/21/24) 8 9,665CIBP w/35 of cement TOC @ ~9,630 9 9,790CIBP 6/11/24 4 9-5/8 @ 3,632 1BCU 14A (Abandoned) 7 T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8TOC @ Surface (Original BCU 14) 9-5/8" TOC @ Surface (Original BCU 14) 7 3,596 MD TOC CBL 11/6/22 3-1/2 7,636 MD TOC CBL 11/6/22 3-1/2 3,880 MD TOC CBL 4/10/25 BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWF BEL 11 BEL 12Tubing punch 7,510-7,514 4/1/25 BEL 10 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 10 7,085'7,095'6,284'6,293'10'6/20/2025 Open BEL 11 7,157' 7,165' 6,347' 6,354' 8' 4/18/2025 Open BEL 11 7,197' 7,206' 6,383' 6,391' 9' 4/18/2025 Open BEL 11 7,302' 7,312' 6,479' 6,488' 10' 4/18/2025 Open BEL 12 7,393' 7,400' 6,564' 6,570' 7' 4/18/2025 Open PERFORATION DETAIL continued on following page Updated by DMA 07-14-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PERFORATION DETAIL continued from previous page Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolated BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolated BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolated BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolated BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolated BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolated BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolated BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolated BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolated BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolated BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolated BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130 10,150 9,192 9,211 20 11/22/2022 Isolated T7A 10,152 10,172 9,213 9,232 20 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304 10,314 10' 11/21/2022 Isolated Updated by RPL 12/16/2025 SCHEMATIC Proposed Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390 MD / 10,396 TVD TD = 11,459 MD / 10,462 TVD RKB to GL = 16.0 3-1/8 Otis CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20Conductor 133 K-55 Weld 18.73Surf 145 13-3/8"Surf Csg 68.0 K-55 BTC 12.415Surf 2,122 9-5/8Intermediate Csg 40.0 L-80 BTC 8.835Surf 3,632 TOW 7Intermediate Csg 2 26 L-80 Multiple 6.276Surf 7,838 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.9927,64111,457 3-1/2"Tubing 9.3 L-80 RTS-8 2.992Surf 7,651 2 20 13-3/8 3-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 3,632N/A 9.625Whipstock 2 7,530Cement Retainer (4/11/25) 3 7,641 4.150 5.75 Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2 bullet seal assembly 4 7,965CIBP w/ 48 cement TOC @ 7,917 (3/31/25) 5 8,255CIBP (10/23/24) 6 8,407CIBP (10/22/24) 7 8,445CIBP (10/21/24) 8 9,665CIBP w/35 of cement TOC @ ~9,630 9 9,790CIBP 6/11/24 4 9-5/8 @ 3,632 1BCU 14A (Abandoned) 7 T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8TOC @ Surface (Original BCU 14) 9-5/8" TOC @ Surface (Original BCU 14) 7 3,596 MD TOC CBL 11/6/22 3-1/2 7,636 MD TOC CBL 11/6/22 3-1/2 3,880 MD TOC CBL 4/10/25 BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWF BEL 11 BEL 12Tubing punch 7,510-7,514 4/1/25 BEL 10 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 5 ±6,563'±6,583'±5,858'±5,874'±20'Proposed Proposed BEL 5 ±6,593' ±6,605' ±5,882' ±5,892' ±12' Proposed Proposed BEL 5 ±6,614' ±6,626' ±5,899' ±5,909' ±12' Proposed Proposed BEL 6 ±6,671' ±6,691' ±5,945' ±5,961' ±20' Proposed Proposed BEL 7 ±6,693' ±6,700' ±5,962' ±5,968' ±7' Proposed Proposed BEL 8 ±6,787' ±6,833' ±6,038' ±6,075' ±46' Proposed Proposed BEL 8B ±6,869' ±6,879' ±6,104' ±6,112' ±10' Proposed Proposed BEL 9 ±6,966' ±6,980' ±6,183' ±6,195' ±14' Proposed Proposed BEL 9 ±6,997' ±7,015' ±6,209' ±6,224' ±18' Proposed Proposed BEL 10 7,085' 7,095' 6,284' 6,293' 10' 6/20/2025 Open BEL 11 7,157' 7,165' 6,347' 6,354' 8' 4/18/2025 Open BEL 11 ±7,169' ±7,175' ±6,357' ±6,363' ±6' Proposed Proposed BEL 11 7,197' 7,206' 6,383' 6,391' 9' 4/18/2025 Open BEL 11 7,302' 7,312' 6,479' 6,488' 10' 4/18/2025 Open BEL 12 7,393' 7,400' 6,564' 6,570' 7' 4/18/2025 Open PERFORATION DETAIL continued on following page Updated by RPL 12/16/2025 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PERFORATION DETAIL continued from previous page Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolated BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolated BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolated BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolated BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolated BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolated BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolated BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolated BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolated BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolated BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolated BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130 10,150 9,192 9,211 20 11/22/2022 Isolated T7A 10,152 10,172 9,213 9,232 20 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304 10,314 10' 11/21/2022 Isolated STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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 Nitrogen vendor 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 Transport. From:Brooks, Phoebe L (OGC) To:Regg, James B (OGC) Subject:FW: [EXTERNAL] FW: Revised: Hilcorp, Beaver Creek Unit, BC-14B MIT IA Date:Tuesday, August 19, 2025 12:48:39 PM Attachments:BC-14B MIT IA 07-11-25.xlsx BC-14B MIT IA 07-11-2025.xls Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Michael Morgan <mmorgan@hilcorp.com> Sent: Tuesday, August 19, 2025 10:59 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Ryan Lemay <Ryan.Lemay@hilcorp.com>; Chad Johnson <chjohnson@hilcorp.com>; Mike Chivers <mchivers@hilcorp.com> Subject: RE: [EXTERNAL] FW: Revised: Hilcorp, Beaver Creek Unit, BC-14B MIT IA Pheobe, Here is the revised MIT-IA for BC-14B, I’ve also included the Crystal Gauge graph. Thank you, Michael Morgan Beaver Creek Lead Operator Office 907-283-1317 Cell 907-394-8725 mmorgan@hilcorp.com Alternate:Mike Chivers Hilcorp Alaska, LLC From: Michael Morgan <mmorgan@hilcorp.com> Sent: Tuesday, August 19, 2025 9:41 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] FW: Revised: Hilcorp, Beaver Creek Unit, BC-14B MIT IA %HDYHU&UHHN8QLW% 37' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Phoebe, I just came back onshift today, I’ll get this back to you today. Thank you, Michael Morgan Beaver Creek Lead Operator Office 907-283-1317 Cell 907-394-8725 mmorgan@hilcorp.com Alternate:Mike Chivers Hilcorp Alaska, LLC From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Tuesday, August 19, 2025 9:38 AM To: Michael Morgan <mmorgan@hilcorp.com> Subject: [EXTERNAL] FW: Revised: Hilcorp, Beaver Creek Unit, BC-14B MIT IA I was following up on this email. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (OGC) Sent: Tuesday, August 12, 2025 10:42 AM To: Michael Morgan <mmorgan@hilcorp.com> 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. Some people who received this message don't often get email from mmorgan@hilcorp.com. Learn why this is important Subject: RE: Revised: Hilcorp, Beaver Creek Unit, BC-14B MIT IA Michael, Please include all pressures on this MIT report (if not applicable, please include that in the remarks). Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Michael Morgan <mmorgan@hilcorp.com> Sent: Friday, July 11, 2025 2:01 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Chad Johnson <chjohnson@hilcorp.com>; Ryan Lemay <Ryan.Lemay@hilcorp.com> Subject: Revised: Hilcorp, Beaver Creek Unit, BC-14B MIT IA Revised I put the IA test pressures in the tubing column in the first email, corrected to the IA column. Please find the attached MIT IA for Hilcorp Beaver Creek Unit BC-14B. Thank you, Michael Morgan Beaver Creek Lead Operator Office 907-283-1317 Cell 907-394-8725 mmorgan@hilcorp.com Alternate:Mike Chivers Hilcorp Alaska, LLC From: Michael Morgan Sent: Friday, July 11, 2025 1:41 PM To: jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov; chris.wallace@alaska.gov Cc: Chad Johnson <chjohnson@hilcorp.com>; Ryan Lemay <Ryan.Lemay@hilcorp.com> Subject: Hilcorp, Beaver Creek Unit, BC-14B MIT IA Please find the attached MIT IA for Hilcorp Beaver Creek Unit BC-14B. Thank you, Michael Morgan Beaver Creek Lead Operator Office 907-283-1317 Cell 907-394-8725 mmorgan@hilcorp.com Alternate:Mike Chivers Hilcorp Alaska, LLC 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. Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220570 Type Inj N Tubing 309 309 309 310 Type Test P Packer TVD BBL Pump NA IA 10 2060 2052 2045 Interval O Test psi 2000 BBL Return NA OA 0 NA NA NA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska llc Beaver Creek Unit, Pad-1, Well BC-14B Michael Morgan 07/11/25 Notes:BC-14B Performed 30min MIT IA Notes: Notes: Notes: BC-14B Form 10-426 (Revised 01/2017)2025-0711_MITP_BCU-14B 9 9 9 999 9 9 9 -5HJJ *DVSURGXFHU Data Collection Report Chassis Left Scale Right Scale Serial Number 463859 822131 Datatype Lower Units psi Lower -500.0 0.0 500.0 1000.0 1500.0 2000.0 2500.0 psi Elapsed Time hh:mm:ss BC-14B MIT IA - 11-Jul-25, 08:59:34, 1076 psi 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: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP Please include current contact information if different from above. T40659 T40660 T40661 T40662 T40663 T40664 T40664 T40664 T40665 T40665 T40665 T40665 T40666 T40667 T40668 T40669 T40670 T40671 T40672 T40673 BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -08'00' DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : CB L 1 1 - 5 - 2 2 , M u d l o g , L W D ( A G R , P W D , R e s , A L D , C T N ) No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 11 / 2 2 / 2 0 2 2 11 2 2 2 7 5 8 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B 3 . 5 I N MA I N . l a s 37 2 8 8 ED Di g i t a l D a t a DF 11 / 2 2 / 2 0 2 2 76 3 4 3 0 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B 7 I N MA I N . l a s 37 2 8 8 ED Di g i t a l D a t a DF 11 / 2 2 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B S C B L F I N A L . p d f 37 2 8 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 36 3 2 1 1 4 5 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B L W D Fi n a l . l a s 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l M D . c g m 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l T V D . c g m 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B - D e f i n i t i v e S u r v e y Re p o r t . p d f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B - F i n a l S u r v e y s . x l s x 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B _ D S R A c t u a l _ P l a n . p d f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B _ D S R A c t u a l _ V s e c . p d f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B _ D S R - G I S . t x t 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B _ D S R . t x t 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l M D . e m f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l T V D . e m f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l M D . p d f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l T V D . p d f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l M D . t i f 37 3 3 8 ED Di g i t a l D a t a DF 11 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U 1 4 B L W D F i n a l T V D . t i f 37 3 3 8 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 1 o f 1 1 Su p p l i e d b y Op Su p p l i e d b y Op BCU 1 4 B L W D Fi n al. l as 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,459 feet See Schematic feet true vertical 10,462 feet N/A feet Effective Depth measured 7,530 feet 7,641 feet true vertical 7,530 feet 6,705 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7,651' MD 6,810' TVD Packers and SSSV (type, measured and true vertical depth) ZXP Liner Top Pkr; N/A 7,641' MD 6,705' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3,090psi 8,530psi 3,060psi 3,450psi 5,750psi 11,220psi 2,122' 2,122' Burst Collapse 1,050psi 1,950psi Intermediate 2 Production 3,632' 7,838' 3,817' Casing Structural 3,548' 6,989' 3-1/2" 3,632' 7,838' 11,457' 10,460' 145'Conductor Surface Intermediate 1 20" 13-3/8" 145' 2,122' measured TVD 9-5/8" 10,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-057 50-133-20539-02-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA 028083 Beaver Creek / Beluga Gas Beaver Creek Unit (BCU) 14B Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 5 Size 145' 14 5347 0 671 65 Ryan LeMay, Operations Engineer 325-328 Sr Pet Eng: 10,540psi Sr Pet Geo: Sr Res Eng: WINJ WAG 266 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A ryan.lemay@hilcorp.com 661-487-0871 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:24 pm, Jul 14, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.07.14 15:03:20 - 08'00' Noel Nocas (4361) BJM 9/25/25 Page 1/1 Well Name: BCU-014B Report Printed: 7/11/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20539-02-00 Field Name:Beaver Creek State/Province:ALASKA Permit to Drill (PTD) #:222-057 Sundry #:325-328 Rig Name/No: Jobs Actual Start Date:5/23/2025 End Date: Report Number 1 Report Start Date 6/17/2025 Report End Date 6/17/2025 Last 24hr Summary MIRU slickline. PT 250 / 2500 psi - good. Drifted tubing with 20' x 2" Dummy gun to 7280'KB. Bailed from 7280' to 7319'KB Report Number 2 Report Start Date 6/18/2025 Report End Date 6/18/2025 Last 24hr Summary PTW/PJSM, MIRU PWL, PT 250 / 2500 psi - good. Ran 20' x 2" dummy gun SD @ 7264' SLM, work to 7266' SLM (7282' KB). Made (7) 6'x 2" DD bailer runs SD @ 7266' SLM work to as deep as 7306' SLM (7322' KB) last 4 runs lost footage back to 7300' SLM (7316' KB) Report Number 3 Report Start Date 6/19/2025 Report End Date 6/19/2025 Last 24hr Summary PTW/PJSM. Well flowing ran 2.0"x12' DD, SD @ 7284' SLM (7300' KB), work to 7286' SLM 7302' KB Shut in well. Made 7 more 2.0"x12' bailer runs. Bailed from 7284' SLM,(7300' KB) - 7294' SLM (7310' KB) returning full bailers of sand every run. Report Number 4 Report Start Date 6/20/2025 Report End Date 6/20/2025 Last 24hr Summary PTW/PJSM, MIRU AK Eline, PT 250 / 2500 psi - good. Perforate BEL_10 from (7085'-7095'). Report Number 5 Report Start Date 6/21/2025 Report End Date 6/21/2025 Last 24hr Summary PTW/PJSM, Well flowing ran GPT, tag @ 7304', make 2 passes from 6800'-7304' @ 60 fpm. See cooling across Bel 10 & 11 intervals. RDMO E-line. Report Number 6 Report Start Date 7/11/2025 Report End Date 7/12/2025 Last 24hr Summary Perform MIT - IA on 3-1/2" x 7" annulus within 30 days of POP per AOGCC Sundry requirements. Tested to 2000 psi for 30 min - Good test. IA Pre Test Pressure = 10 psi Initial = 2060 psi 15 min = 2052 psi 30 min = 2045 psi Submited MIT-IA test form to AOGCC on 7/11/2025 Updated by DMA 07-14-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390 MD / 10,396 TVD TD = 11,459 MD / 10,462 TVD RKB to GL = 16.0 3-1/8 Otis CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20Conductor 133 K-55 Weld 18.73Surf 145 13-3/8"Surf Csg 68.0 K-55 BTC 12.415Surf 2,122 9-5/8Intermediate Csg 40.0 L-80 BTC 8.835Surf 3,632 TOW 7Intermediate Csg 2 26 L-80 Multiple 6.276Surf 7,838 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.9927,64111,457 3-1/2"Tubing 9.3 L-80 RTS-8 2.992Surf 7,651 2 20 13-3/8 3-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 3,632N/A 9.625Whipstock 2 7,530Cement Retainer (4/11/25) 3 7,641 4.150 5.75 Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2 bullet seal assembly 4 7,965CIBP w/ 48 cement TOC @ 7,917 (3/31/25) 5 8,255CIBP (10/23/24) 6 8,407CIBP (10/22/24) 7 8,445CIBP (10/21/24) 8 9,665CIBP w/35 of cement TOC @ ~9,630 9 9,790CIBP 6/11/24 4 9-5/8 @ 3,632 1BCU 14A (Abandoned) 7 T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8TOC @ Surface (Original BCU 14) 9-5/8" TOC @ Surface (Original BCU 14) 7 3,596 MD TOC CBL 11/6/22 3-1/2 7,636 MD TOC CBL 11/6/22 3-1/2 3,880 MD TOC CBL 4/10/25 BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWF BEL 11 BEL 12Tubing punch 7,510-7,514 4/1/25 BEL 10 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 10 7,085'7,095'6,284'6,293'10'6/20/2025 Open BEL 11 7,157' 7,165' 6,347' 6,354' 8' 4/18/2025 Open BEL 11 7,197' 7,206' 6,383' 6,391' 9' 4/18/2025 Open BEL 11 7,302' 7,312' 6,479' 6,488' 10' 4/18/2025 Open BEL 12 7,393' 7,400' 6,564' 6,570' 7' 4/18/2025 Open PERFORATION DETAIL continued on following page Updated by DMA 07-14-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PERFORATION DETAIL continued from previous page Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolated BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolated BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolated BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolated BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolated BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolated BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolated BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolated BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolated BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolated BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolated BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130 10,150 9,192 9,211 20 11/22/2022 Isolated T7A 10,152 10,172 9,213 9,232 20 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304 10,314 10' 11/21/2022 Isolated DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 12 / 5 / 2 0 2 2 35 0 0 1 1 4 5 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B . l a s 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D a i l y R e p o r t s . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F i n a l W e l l R e p o r t . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g MD 2 i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g MD 5 i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g TV D 2 i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g TV D 5 i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g M D 2i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g M D 5i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g T V D 2i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g T V D 5i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g M D 2i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g M D 5i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g T V D 2i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g T V D 5i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g M D 2i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g M D 5i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g T V D 2i n . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g T V D 5i n . p d f 37 3 5 8 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 2 o f 1 1 BC U - 1 4 B . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g MD 2 i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g MD 5 i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g TV D 2 i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B D r i l l i n g D y n a m i c s L o g TV D 5 i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g M D 2i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g M D 5i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g T V D 2i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B F o r m a t i o n L o g T V D 5i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g M D 2i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g M D 5i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g T V D 2i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B G a s R a t i o L o g T V D 5i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g M D 2i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g M D 5i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g T V D 2i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B L W D C o m b o L o g T V D 5i n . t i f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B S h o w R e p o r t s . p d f 37 3 5 8 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 10 0 2 6 1 1 2 9 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ 0 6 0 - d n . l a s 37 3 8 5 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 3 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 12 / 1 9 / 2 0 2 2 11 2 6 8 9 9 9 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ 0 6 0 - u p . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 10 0 3 0 1 1 2 9 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ 0 9 0 - d n . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 11 2 5 8 9 9 9 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ 0 9 0 - u p . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 10 0 3 0 1 1 3 3 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ 1 2 0 - d n . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 11 2 6 8 1 0 0 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ 1 2 0 - u p . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 10 0 2 6 1 1 3 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ P r o c e s s e d L o g - V 1 . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 0 5 5 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ s t o p - 1 0 0 9 0 . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 0 5 0 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ s t o p - 1 1 2 5 0 . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 0 4 8 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ s t o p - 1 1 3 4 0 . l a s 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 1 4 B _ P P R O F _ 0 8 D E C 2 2 . p d f 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ i m g . t i f f 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ R e p o r t - V 1 . p d f 37 3 8 5 ED Di g i t a l D a t a DF 12 / 1 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U - 14 B _ P P R O F _ 0 8 D E C 2 2 _ V 1 . k e 5 37 3 8 5 ED Di g i t a l D a t a DF 12 / 2 9 / 2 0 2 2 -1 7 1 1 3 3 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : BC U _ 1 4 B _ G P T _ F l u i d S a m p l e _ 2 7 - N o v - 20 2 2 _ ( 4 0 8 7 ) . l a s 37 4 0 1 ED Di g i t a l D a t a DF 12 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B C U _ 1 4 B _ G P T _ F l u i d Sa m p l e _ 2 7 - N o v - 2 0 2 2 _ ( 4 0 8 7 ) . p d f 37 4 0 1 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 10 4 9 2 1 1 3 6 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B 1 1 - 2 1 - 22 G P T 1 . l a s 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 11 3 5 7 1 0 9 5 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B 1 1 - 2 1 - 22 G U N - 1 C O R R E L A T I O N . l a s 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 11 3 2 7 1 1 0 4 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B 1 1 - 2 2 - 22 G U N - 2 C O R R E L A T I O N . l a s 37 4 6 3 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 4 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 1/ 2 4 / 2 0 2 3 10 2 3 3 9 9 6 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B 1 1 - 2 3 - 22 G U N - 3 C O R R E L A T I O N . l a s 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 10 2 5 8 9 9 8 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B 1 1 - 2 3 - 22 G U N - 4 C O R R E L A T I O N . l a s 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 10 2 7 0 1 0 0 2 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B 1 1 - 2 3 - 22 G U N - 5 C O R R E L A T I O N . l a s 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U 1 4 B G P T - P E R F F I N A L . p d f 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U - 1 4 B 1 1 - 2 1 - 2 2 G P T 1 . p d f 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U - 1 4 B 1 1 - 2 1 - 2 2 G U N - 1C O R R E L A T I O N . p d f 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U - 1 4 B 1 1 - 2 2 - 2 2 G U N - 2 CO R R E L A T I O N . p d f 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U - 1 4 B 1 1 - 2 3 - 2 2 G U N - 3 CO R R E L A T I O N . p d f 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U - 1 4 B 1 1 - 2 3 - 2 2 G U N - 4 CO R R E L A T I O N . p d f 37 4 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : B C U - 1 4 B 1 1 - 2 3 - 2 2 G U N - 5 CO R R E L A T I O N . p d f 37 4 6 3 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 11 2 0 0 1 0 9 3 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B G U N - 1 CO R R E L A T I O N L O G T - 1 6 S A N D 5 - 2 2 - 2 4 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 11 0 8 4 1 0 8 0 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B G U N - 2 CO R R E L A T I O N L O G T - 1 4 S A N D 5 - 2 2 - 2 4 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 10 1 4 1 9 8 9 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B G U N - 3 CO R R E L A T I O N L O G T - 5 S A N D 5 - 2 2 - 2 4 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 99 1 9 9 6 8 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B G U N - 4 CO R R E L A T I O N L O G T - 3 S A N D 5 - 2 2 - 2 4 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 10 2 0 8 9 6 2 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B G P T TO F I N D F L U I D L E V E L 6 - 1 1 - 2 4 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 97 5 3 9 5 4 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B T 2 97 1 5 - 9 7 2 9 P E R F C O R R E L A T I O N P A S S 6 - 1 1 - 24 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 97 6 8 9 5 4 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B T 2 97 2 9 ' - 9 7 4 9 ' P E R F C O R R E L A T I O N P A S S 6 - 1 1 - 24 . l a s 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 98 0 9 9 5 9 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U - 1 4 B T 3 PL U G C O R R E L A T I O N P A S S 6 - 1 1 - 2 4 . l a s 39 3 1 0 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 5 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B G U N - 1 CO R R E L A T I O N L O G T - 1 6 S A N D 5 - 2 2 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B G U N - 2 CO R R E L A T I O N L O G T - 1 4 S A N D 5 - 2 2 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B G U N - 3 CO R R E L A T I O N L O G T - 5 S A N D 5 - 2 2 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B G U N - 4 CO R R E L A T I O N L O G T - 3 S A N D 5 - 2 2 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B P E R F F I N A L 5 - 2 2 - 24 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B G P T T O F I N D F L U I D LE V E L 6 - 1 1 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B G P T - P L U G - P E R F FI N A L . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B T 2 9 7 1 5 - 9 7 2 9 P E R F CO R R E L A T I O N P A S S 6 - 1 1 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B T 2 9 7 2 9 ' - 9 7 4 9 ' P E R F CO R R E L A T I O N P A S S 6 - 1 1 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 7/ 3 0 / 2 0 2 4 E l e c t r o n i c F i l e : B C U - 1 4 B T 3 P L U G CO R R E L A T I O N P A S S 6 - 1 1 - 2 4 . p d f 39 3 1 0 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 96 7 0 9 3 7 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 14 B , C O R R E L A T I O N P A S S T O S E T C I B P A T 96 6 5 ' , 8 - 1 1 - 2 0 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 96 1 2 9 3 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 1 C O R R E L A T I O N L O G T O S A N D A T 96 0 2 - 9 6 0 8 F T 8 - 1 4 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 95 1 8 9 2 2 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 2 C O R R E L A T I O N L O G B E L _ 3 3 9 4 6 3 - 94 6 9 & B E L _ 3 2 L 9 3 3 5 - 9 3 4 5 ' 8 - 1 4 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 90 3 8 8 7 4 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 3 C O R R E L A T I O N L O G P E R F 4 B E L _ 2 8 SA N D S 8 - 1 5 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 88 9 5 8 6 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 4 C O R R E L A T I O N L O G P E R F 4 B E L _ 2 8 , 27 , & 2 6 S A N D S 8 - 1 5 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 87 0 6 8 4 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 5 C O R R E L A T I O N L O G P E R F B E L _ 2 5 SA N D 8 - 1 5 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 6 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 9/ 2 7 / 2 0 2 4 86 6 9 8 3 8 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 6 C O R R E L A T I O N L O G P E R F B E L _ 2 4 SA N D 8 - 1 5 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 86 0 5 8 3 7 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 7 C O R R E L A T I O N L O G P E R F B E L _ 2 3 SA N D S 8 5 2 3 - 8 5 3 3 , 8 5 4 1 - 8 5 5 5 8 - 1 5 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 85 1 1 8 2 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B , G U N RU N - 8 C O R R E L A T I O N L O G P E R F B E L _ 2 2 SA N D S 8 5 0 0 - 8 5 0 6 ' , 8 4 8 5 - 8 4 9 1 ' , 8 4 5 2 - 8 4 6 2 ' 8 - 15 - 2 4 . l a s 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , P E R F F I N A L 8 - 1 4 - 24 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G P T F I N A L 8 - 1 4 - 24 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , C O R R E L A T I O N P A S S TO S E T C I B P A T 9 6 6 5 ' , 8 - 1 1 - 2 0 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 1 CO R R E L A T I O N L O G T O S A N D A T 9 6 0 2 - 96 0 8 F T 8 - 1 4 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 2 CO R R E L A T I O N L O G B E L _ 3 3 9 4 6 3 - 9 4 6 9 & BE L _ 3 2 L 9 3 3 5 - 9 3 4 5 ' 8 - 1 4 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 3 CO R R E L A T I O N L O G P E R F 4 B E L _ 2 8 S A N D S 8- 1 5 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 4 CO R R E L A T I O N L O G P E R F 4 B E L _ 2 8 , 2 7 , & 2 6 SA N D S 8 - 1 5 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 5 CO R R E L A T I O N L O G P E R F B E L _ 2 5 S A N D 8 - 15 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 6 CO R R E L A T I O N L O G P E R F B E L _ 2 4 S A N D 8 - 15 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 7 CO R R E L A T I O N L O G P E R F B E L _ 2 3 S A N D S 85 2 3 - 8 5 3 3 , 8 5 4 1 - 8 5 5 5 8 - 1 5 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 7 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 9/ 2 7 / 2 0 2 4 E l e c t r o n i c F i l e : B C U 1 4 B , G U N R U N - 8 CO R R E L A T I O N L O G P E R F B E L _ 2 2 S A N D S 85 0 0 - 8 5 0 6 ' , 8 4 8 5 - 8 4 9 1 ' , 8 4 5 2 - 8 4 6 2 ' 8 - 1 5 - 2 4 . p d f 39 5 9 3 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 82 9 0 8 5 5 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B 1 0 - 2 1 - 24 G P T F L U I D A T 8 4 6 5 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 82 2 3 7 9 0 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B CO R R E A L T I O N L O G B E L 1 9 S A N D 8 2 1 2 - 8 2 2 2 82 2 8 - 8 2 3 8 8 2 4 3 - 8 2 4 9 , 1 0 - 2 4 - 2 0 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 83 8 2 8 0 8 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B CO R R E L A T I O N B E L 2 0 S A N D 8 2 5 9 - 8 2 8 6 - 1 0 - 23 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 83 9 7 8 0 5 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B CO R R E L A T I O N B E L 2 0 S A N D 8 2 9 8 - 8 3 1 2 , 8 3 2 8 - 83 3 8 - 1 0 - 2 3 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 84 3 6 7 8 4 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B CO R R E L A T I O N B E L 2 1 G U N 1 8 4 2 2 - 8 4 2 8 1 0 - 22 - 2 0 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 84 0 3 8 0 2 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B CO R R E L A T I O N S E T P L U G @ 8 4 0 7 1 0 - 2 2 - 20 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 78 0 0 8 2 5 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B G P T 4 10 - 2 4 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 77 9 6 8 4 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B G P T LO G - 2 - 1 0 - 2 3 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 75 0 0 8 2 6 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B G P T LO G 5 1 0 - 2 5 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 82 4 3 7 8 9 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B G U N CO R R E L A T I O N L O G 1 0 - 2 5 - 2 4 P E R F B E L 1 6 L SA N D 8 0 1 5 - 8 0 3 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 82 1 8 7 8 9 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B G U N CO R R E L A T I O N L O G 1 0 - 2 5 - 2 4 S A N D B E L 1 9 BE L 1 8 B E L 1 7 P E R F 8 0 6 1 - 8 0 6 7 , 8 0 8 9 - 8 0 9 5 , 81 2 4 - 8 1 3 0 , 8 1 5 5 - 8 1 6 1 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 82 2 9 7 8 8 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B G U N CO R R E L A T I O N P A S S B E L 1 9 8 1 7 0 - 8 1 7 6 , 8 1 8 0 - 81 9 0 , 8 1 9 3 - 8 2 0 3 1 0 - 2 4 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 84 5 9 8 1 9 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B P L U G CO R R E L A T I O N - S E T A T 8 4 4 5 1 0 - 2 1 - 2 0 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 8 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No DF 1/ 2 8 / 2 0 2 5 82 2 4 8 0 5 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : B C U 1 4 B S E T PL U G - 8 2 5 5 - 1 0 - 2 3 - 2 4 . l a s 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B 1 0 - 2 1 - 2 4 G P T F L U I D AT 8 4 6 5 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B C O R R E A L T I O N L O G BE L 1 9 S A N D 8 2 1 2 - 8 2 2 2 8 2 2 8 - 8 2 3 8 8 2 4 3 - 8 2 4 9 , 10 - 2 4 - 2 0 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B C O R R E L A T I O N B E L 20 S A N D 8 2 5 9 - 8 2 8 6 - 1 0 - 2 3 - 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B C O R R E L A T I O N B E L 20 S A N D 8 2 9 8 - 8 3 1 2 , 8 3 2 8 - 8 3 3 8 - 1 0 - 2 3 - 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B C O R R E L A T I O N B E L 21 G U N 1 8 4 2 2 - 8 4 2 8 1 0 - 2 2 - 2 0 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B C O R R E L A T I O N S E T PL U G @ 8 4 0 7 1 0 - 2 2 - 2 0 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B D O W N H O L E P A S S WI T H 1 9 F O O T G U N F O R F L U I D T A G . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G P T 4 1 0 - 2 4 - 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G P T L O G - 2 - 1 0 - 2 3 - 2 4 2i n . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G P T L O G - 2 - 1 0 - 2 3 - 24 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G P T L O G 5 1 0 - 2 5 - 24 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G P T - P L U G - P E R F FI N A L . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G U N C O R R E L A T I O N LO G 1 0 - 2 5 - 2 4 P E R F B E L 1 6 L S A N D 8 0 1 5 - 80 3 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G U N C O R R E L A T I O N LO G 1 0 - 2 5 - 2 4 S A N D B E L 1 9 B E L 1 8 B E L 1 7 PE R F 8 0 6 1 - 8 0 6 7 , 8 0 8 9 - 8 0 9 5 , 8 1 2 4 - 8 1 3 0 , 8 1 5 5 - 81 6 1 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B G U N C O R R E L A T I O N PA S S B E L 1 9 8 1 7 0- 8 1 7 6 , 8 1 8 0 - 8 1 9 0 , 8 1 9 3 - 82 0 3 1 0 - 2 4 - 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 9 o f 1 1 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 11 / 2 1 / 2 0 2 2 Re l e a s e D a t e : 6/ 2 / 2 0 2 2 DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B P L U G CO R R E L A T I O N - S E T A T 8 4 4 5 1 0 - 2 1 - 2 0 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U 1 4 B S E T P L U G - 8 2 5 5 - 1 0 - 23 - 2 4 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 1/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : G P T 2 I N C H 1 0 - 2 5 . p d f 40 0 2 5 ED Di g i t a l D a t a DF 4/ 2 8 / 2 0 2 5 61 9 3 5 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : BC U _ 1 4 B _ C B L _ 1 0 - A p r i l - 2 0 2 5 _ ( 5 3 9 1 ) . l a s 40 3 2 8 ED Di g i t a l D a t a DF 4/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B C U _ 1 4 B _ C B L _ 1 0 - A p r i l - 20 2 5 _ ( 5 3 9 1 ) . p d f 40 3 2 8 ED Di g i t a l D a t a 1/ 5 / 2 0 2 3 36 3 2 1 1 4 6 0 51 8 3 6 Cu t t i n g s We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 1 0 o f 1 1 M. G u h l 6/ 1 1 / 2 0 2 5 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 3 9 - 0 2 - 0 0 We l l N a m e / N o . BE A V E R C K U N I T 1 4 B Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 11 / 2 1 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 5 7 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 11 4 5 9 TV D 10 4 7 0 Cu r r e n t S t a t u s 1- G A S 6/ 1 1 / 2 0 2 5 UI C No We d n e s d a y , J u n e 1 1 , 2 0 2 5 AO G C C P a g e 1 1 o f 1 1 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 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): 11,459'N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 8,530psi Liner 10,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ZXP Liner Top Pkr; N/A 7,641' MD/ 6,705' TVD; N/A 10,462'7,530'7,530' Beaver Creek Beluga Gas 20" 13-3/8" See Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 14BCO 237D Same 6,989'7" ~2140psi 7,838' See Schematic Length June 10, 2025 11,457'3,817' 3-1/2" 10,460' 7,838' Perforation Depth MD (ft): 3,632' 3-1/2" See Schematic 5,750 psi 3,060 psi 3,450 psi 145' 3,548' 145' 2,122' Size 145' 9-5/8"3,632' 2,122' MD Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 7,651' 11,220psi 2,122' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 222-057 50-133-20539-02-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Ryan Lemay, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade: ryan.lemay@hilcorp.com 661-487-0871 Noel Nocas, Operations Manager 907-564-5278 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: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-328 By Gavin Gluyas at 2:26 pm, May 27, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.05.27 14:19:54 - 08'00' Noel Nocas (4361) Perform MIT-IA to 2000 psi once job is complete and well has been brought on line, within 30 days of POP. A.Dewhurst 02JUN25 10-404 BJM 6/3/25 DSR-6/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.04 08:55:27 -08'00'06/04/25 RBDMS JSB 060525 Well Prognosis Well: BCU-14B Well Name: BCU-14B API Number: 50-133-20539-02-00 Current Status: Producing Gas Well Permit to Drill Number: 222-057 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661) 487-0871 Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2769 psi @ 6293’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2140 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.63 psi/ft using 12.1 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: MPSP / (0.63 - 0.1) = 2140 psi / 0.53 = 4038‘ TVD (Will not perforate above applicable gas pool) Top of Applicable Gas Pool: 6531’ MD / 5832’ TVD (Beluga) Well Status: Producing Gas Well x Currently producing + 300 mcfd / 67 psi FTP as of 5/22/2025 Brief Well Summary In April of 2025, the 3-1/2” x 7” annulus was cemented above the liner top packer and perforations were added in the Beluga 12 & 11 intervals. The well came on production at + 600 mcfd / 78 psi FTP from these intervals. Gas rate has declined to + 300 mcfd / 67 psi FTP as of 5/22/2025. The purpose of this Sundry is to add additional perforations in the Beluga sands. Wellbore Notes: x Inclination o Max deviation of 39.6° @ 5,867’ MD o Max DLS of 4.98°/ 100’ @ 3,714’ MD Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate the following sands from bottom up. Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Well Sand md top md bottom tvd top tvd bottom interval BCU-14B BEL 5 ±6,563' ±6,583' ±5,858' ±5,874' ±20' BCU-14B BEL 5 ±6,593' ±6,605' ±5,882' ±5,892' ±12' BCU-14B BEL 5 ±6,614' ±6,626' ±5,899' ±5,909' ±12' BCU-14B BEL 6 ±6,671' ±6,691' ±5,945' ±5,961' ±20' BCU-14B BEL 7 ±6,693' ±6,700' ±5,962' ±5,968' ±7' BCU-14B BEL 8 ±6,787' ±6,833' ±6,038' ±6,075' ±46' Well Prognosis Well: BCU-14B BCU-14B BEL 8B ±6,869' ±6,879' ±6,104' ±6,112' ±10' BCU-14B BEL 9 ±6,966' ±6,980' ±6,183' ±6,195' ±14' BCU-14B BEL 9 ±6,997' ±7,015' ±6,209' ±6,224' ±18' BCU-14B BEL 10 ±7,085' ±7,095' ±6,284' ±6,293' ±10' a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If any current or proposed zones produce sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together. If possible, the CIBP will be set 50’ above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50’. f. If necessary, use nitrogen or pad gas to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Contingency Procedure: Coiled Tubing Cleanout 1. If throughout the job any current or proposed zones produce sand and / or water that cannot be depressed and pushed away with nitrogen or high-pressure pad gas, a coil tubing unit may be rigged up to clean out fill or fluid blown down as necessary. a. MIRU Fox CTU, PT BOPE to 250 psi low / 2500 psi high i. Provide AOGCC 24hrs notice of BOP test. b. Cleanout wellbore fill and / or blowdown well with nitrogen if necessary. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 4. Standard Well Procedure – N2 Operations Updated by RPL 05-05-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,530’Cement Retainer (4/11/25) 3 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 4 7,965’CIBP w/ 48’ cement – TOC @ 7,917’ (3/31/25) 5 8,255’CIBP (10/23/24) 6 8,407’CIBP (10/22/24) 7 8,445’CIBP (10/21/24) 8 9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 9 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 3-1/2”3,880’ MD TOC CBL 4/10/25 BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWFBEL 11 BEL 12 PERFORATION DETAIL on following page Tubing punch 7,510’-7,514’ 4/1/25 Updated by RPL 05-05-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 11 7,157' 7,165' 6,347' 6,354' 8' 4/18/2025 Open BEL 11 7,197' 7,206' 6,383' 6,391' 9' 4/18/2025 Open BEL 11 7,302' 7,312' 6,479' 6,488' 10' 4/18/2025 Open BEL 12 7,393' 7,400' 6,564' 6,570' 7' 4/18/2025 Open BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolate BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolate BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolate BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolate BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolate BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolate BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolate BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolate BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolate BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolate BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolate BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792’ 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130’ 10,150’ 9,192’ 9,211’ 20’ 11/22/2022 Isolated T7A 10,152’ 10,172’ 9,213’ 9,232’ 20’ 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304’ 10,314’ 10' 11/21/2022 Isolated Updated by RPL 05-05-25 SCHEMATIC Proposed Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,530’Cement Retainer (4/11/25) 3 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 4 7,965’CIBP w/ 48’ cement – TOC @ 7,917’ (3/31/25) 5 8,255’CIBP (10/23/24) 6 8,407’CIBP (10/22/24) 7 8,445’CIBP (10/21/24) 8 9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 9 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 3-1/2”3,880’ MD TOC CBL 4/10/25 BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWFBEL 11 BEL 12 PERFORATION DETAIL on following page Tubing punch 7,510’-7,514’ 4/1/25 Updated by RPL 05-23-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 5 ±6,563' ±6,583' ±5,858' ±5,874' ±20' Proposed BEL 5 ±6,593' ±6,605' ±5,882' ±5,892' ±12' Proposed BEL 5 ±6,614' ±6,626' ±5,899' ±5,909' ±12' Proposed BEL 6 ±6,671' ±6,691' ±5,945' ±5,961' ±20' Proposed BEL 7 ±6,693' ±6,700' ±5,962' ±5,968' ±7' Proposed BEL 8 ±6,787' ±6,833' ±6,038' ±6,075' ±46' Proposed BEL 8B ±6,869' ±6,879' ±6,104' ±6,112' ±10' Proposed BEL 9 ±6,966' ±6,980' ±6,183' ±6,195' ±14' Proposed BEL 9 ±6,997' ±7,015' ±6,209' ±6,224' ±18' Proposed BEL 10 ±7,085' ±7,095' ±6,284' ±6,293' ±10' Proposed BEL 11 7,157' 7,165' 6,347' 6,354' 8' 4/18/2025 Open BEL 11 7,197' 7,206' 6,383' 6,391' 9' 4/18/2025 Open BEL 11 7,302' 7,312' 6,479' 6,488' 10' 4/18/2025 Open BEL 12 7,393' 7,400' 6,564' 6,570' 7' 4/18/2025 Open BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolate BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolate BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolate BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolate BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolate BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolate BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolate BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolate BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolate BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolate BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolate BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792’ 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130’ 10,150’ 9,192’ 9,211’ 20’ 11/22/2022 Isolated T7A 10,152’ 10,172’ 9,213’ 9,232’ 20’ 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304’ 10,314’ 10' 11/21/2022 Isolated STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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 Nitrogen vendor 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 Transport. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Cement Annulus, N2 Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,459 feet See Schematic feet true vertical 10,462 feet N/A feet Effective Depth measured 7,530 feet 7,641 feet true vertical 7,530 feet 6,705 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 7,651' MD 6,810' TVD Packers and SSSV (type, measured and true vertical depth)ZXP Liner Top Pkr; N/A 7,641' MD 6,705' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Ryan LeMay, Operations Engineer 325-087 Sr Pet Eng: 10,540psi Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A ryan.lemay@hilcorp.com 661-487-0871 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 145' 0 00 0 00 0 measured TVD 9-5/8" 10,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-057 50-133-20539-02-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA 028083 Beaver Creek / Beluga Gas Beaver Creek Unit (BCU) 14B Plugs Junk measured Length Production Liner 3,632' 7,838' 3,817' Casing Structural 3,548' 6,989' 3-1/2" 3,632' 7,838' 11,457'10,460' 145'Conductor Surface Intermediate 20" 13-3/8" 145' 2,122' 3,090psi 8,530psi 3,060psi 3,450psi 5,750psi 11,220psi 2,122'2,122' Burst Collapse 1,050psi 1,950psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:00 am, May 07, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.05.06 16:21:31 - 08'00' Noel Nocas (4361) RBDMS JSB 051525 DSR-5/8/25BJM 6/3/25 Page 1/1 Well Name: BCU-014B Report Printed: 4/30/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20539-02-00 Field Name:Beaver Creek State/Province:ALASKA Permit to Drill (PTD) #:222-057 Sundry #:325-087 Rig Name/No: Jobs Actual Start Date:2/10/2025 End Date: Report Number 1 Report Start Date 3/31/2025 Report End Date 4/1/2025 Last 24hr Summary PTW/PJSM. MIRU Fox cement unit and Yellowjacket E-line. P-test PCE and lines to 250/2,500 psi. SITP 250 psi. Bullhead 5 bbl 9.4 ppg NaCl + 64 bbl prod water. Run 2.80" GR/JB to 8,005'. Set CIBP at 7,965'. Dump bail 14.4 gal cement on top of CIBP. Calculated TOC 7,926'. SITP 0 psi. SDFN. Report Number 2 Report Start Date 4/1/2025 Report End Date 4/2/2025 Last 24hr Summary PTW/PJSM. Tubing MIT to 2,450 psi and tag TOC at 7,917', witnessed by AOGCC inspector Sully Sullivan. Perforate tubing from 7,610' - 7,614'. Circulate 330 bbl produced water down tubing, taking returns from the IA. CMIT tbg/IA to 2,500 psi for 5 min - good. RDMO Yellow Jacket E-line and Fox cement unit. Report Number 3 Report Start Date 4/6/2025 Report End Date 4/7/2025 Last 24hr Summary PJSM / PTW. Spot Fox Offshore CTU 9 and support equipment. Pick 1.75" reel & power stand. Stab pipe. N/U BOPE stack. R/U 2" 1502 hardline. Completed BOPE testing 250 psi low / 3000 psi high. AOGCC Jim Regg waived witness 4/6/25. SDFN. Report Number 4 Report Start Date 4/7/2025 Report End Date 4/8/2025 Last 24hr Summary PJSM / PTW. M/U and RIH YJ 2.75" One Trip Retainer. Tagged TOC @ 7,915' ctm / 7,917' MD. PUH to set depth 7,528' ctm / 7530' MD. Load & launch 1/2" ball. Set retainer at 7530' MD and put 7k down. Pressure up CTBS to 500 psi. Circulated 50 bbls of FW w/CI down coil and up IA. Pumped 97 bbls of 15.3 ppg Class G Cement down coil and up IA. Displaced coil w/22.5 bbls of FW. Full 1:1 returns throughout entire cement job. Shut in IA and coil. Sheared off retainer clean 20k and PUH 25'. Monitor Circ & WHP for 15 minutes, stabile @ 540 psi. Retainer shifted closed. Pooh w/BHA pumping PD to maintain 1300 psi on WHP. Layed down YJ setting tool, recovered 1/2" ball. Blow down coil w/N2 and wiper ball. SDFN. WOC. IA Calculated TOC = 3968'. Report Number 5 Report Start Date 4/9/2025 Report End Date 4/10/2025 Last 24hr Summary PJSM / PTW. MIRU YJ Eline/ PT 250 psi low / 2500 psi high. RIH w/1-11/16" SCBL tools and tagged Cmt Retainer @ 7,524'. Logged up to 2800'. Pressure up well 800 psi and logged from 7524' to 2800'. CBL data repeated. Report Number 6 Report Start Date 4/10/2025 Report End Date 4/11/2025 Last 24hr Summary PJSM / PTW. MIRU AK Eline/ PT 250 psi low / 2500 psi high. RIH w/1-11/16" SCBL tools and tagged Cmt Retainer @ 7,525'. Pressure up tubing to 1300 psi. Logged CBL 7525' - 2800' @ 40 fpm. IA TOC estimated 3880'. RDMO AK Eline. CBL results submitted to AOGCC and BLM. Received approval to proceed forward with perforations as per Sundry after CBL submission from Mel Rixse (AOGCC) and Will Maercklein (BLM) on 4/10/2025. Report Number 7 Report Start Date 4/11/2025 Report End Date 4/12/2025 Last 24hr Summary PJSM / PTW. M/U CTC & 2" BDN. RIH w/BHA to 7000' ctm. Blow well dry conventionally w/N2 1150 scfm. Fluid unloaded to 7000' ctm. Swap to reverse circulation w/N2 1150 scfm and RIH. Tagged cement retainer @ 7,520' ctm. Fox offshore N2 pump died and unable to catch prime. Replace N2 pump and continue to reverse N2 to unload last 4.5 bbls of fluid off bottom. Recovered 63 bbls / 64 bbls calculated. Reverse N2 off bottom until straight nitrogen off coil at return tank. Shut in CTBS and Coil. Pooh w/BHA. Pressure up tubing to 2200 psi and trap pressure on well. Total N2 pumped 204,000 scf = 2200 gallons. RDMO Fox CTU 9. Report Number 8 Report Start Date 4/18/2025 Report End Date 4/19/2025 Last 24hr Summary PTW/PJSM, MIRU YJOS, PT lubricator 250 psi low / 3500 psi high - good test. Perforate Bel 12 (7393'-7400'), Bel 11 (7302'-7312')(7197'-7206')(7157'-7165'). Turn well over to production. RDMO YJOS. Report Number 9 Report Start Date 4/28/2025 Report End Date 4/29/2025 Last 24hr Summary Perform MIT - IA on 3-1/2" x 7" annulus. Began pressuring up well ~ 14:30 hrs. Pressure stabilized ~16:00 hrs. Start of test: 16:07 hrs 2177.2 psi 15 min: 16:22 hrs 2157.0 psi 30 min: 16:37 hrs 2138.5 psi Pressure test: Pass (1.8% decline for 30 min test duration) Send crystal gauge data / test report to OE Updated by RPL 05-05-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,530’Cement Retainer (4/11/25) 3 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 4 7,965’CIBP w/ 48’ cement – TOC @ 7,917’ (3/31/25) 5 8,255’CIBP (10/23/24) 6 8,407’CIBP (10/22/24) 7 8,445’CIBP (10/21/24) 8 9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 9 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 3-1/2”3,880’ MD TOC CBL 4/10/25 BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWFBEL 11 BEL 12 PERFORATION DETAIL on following page Tubing punch 7,510’-7,514’ 4/1/25 Updated by RPL 05-05-25 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 11 7,157' 7,165' 6,347' 6,354' 8' 4/18/2025 Open BEL 11 7,197' 7,206' 6,383' 6,391' 9' 4/18/2025 Open BEL 11 7,302' 7,312' 6,479' 6,488' 10' 4/18/2025 Open BEL 12 7,393' 7,400' 6,564' 6,570' 7' 4/18/2025 Open BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolate BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolate BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolate BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolate BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolate BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolate BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolate BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolate BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolate BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolate BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolate BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792’ 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130’ 10,150’ 9,192’ 9,211’ 20’ 11/22/2022 Isolated T7A 10,152’ 10,172’ 9,213’ 9,232’ 20’ 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304’ 10,314’ 10' 11/21/2022 Isolated 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: 4/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025022 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 14B 50133205390200 222057 4/10/2025 AK E-LINE CBL BRU 241-23 50283201910000 223061 4/7/2025 AK E-LINE Perf BRU 241-26 50283201970000 224068 4/12/2025 AK E-LINE CIBP BRU 244-27 50283201850000 222038 4/8/2025 AK E-LINE Perf MPU B-21 50029215350000 186023 4/7/2025 AK E-LINE LDL MPU C-24A 50029230200100 209134 4/6/2025 AK E-LINE CBL MPU J-25 50029232070000 204073 4/5/2025 AK E-LINE JetCut NCIU A-21 50883201990000 224086 4/4/2025 AK E-LINE Perf NCIU A-18 50883201890000 223033 4/5/2025 AK E-LINE Perf PBU Z-235 50029237600000 223055 4/1/2025 READ InjectiojnProfile HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL HVB 18 50231201210000 225001 4/4/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40328 T40329 T40330 T40331 T40332 T40333 T40334 T40335 T40336 T40337 T40338 T40339 BCU 14B 50133205390200 222057 4/10/2025 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:42:09 -08'00' From:McLellan, Bryan J (OGC) To:Scott Warner; Rixse, Melvin G (OGC) Cc:Eli Wilson - (C); Ryan Lemay; Donna Ambruz Subject:RE: [EXTERNAL] RE: BCU-14B Cement Bond Log / Review and Approval to Proceed with Perforations Date:Tuesday, April 15, 2025 1:25:00 PM Scott, It looks like there is good cement outside the 7” casing. Hilcorp has approval to proceed with the perfs in the sundry. The well still must pass an MITIA within 30 days of putting on production. After the MITIA is performed, if additional perfs are added shallower, another MITIA will need to be done within 30 days of putting the new perfs on production. The reason for additional MITIAs is that we won’t know which section of cement is acting as the packer. New perfs that are shallower than existing perfs will invalidate the previous MITIA. It’s the same for any of these cement packers. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, April 15, 2025 12:24 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Eli Wilson - (C) <Eli.Wilson@hilcorp.com>; Ryan Lemay <Ryan.Lemay@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: BCU-14B Cement Bond Log / Review and Approval to Proceed with Perforations Bryan, This job went exactly to plan. We had 1:1 returns throughout the job, pumping 50 bbls CIW up the annulus followed by 97 bbls of 15.3 ppg class G cement, and then the coil volume of 22.5 bbls was displaced with FW. TOC should have been ~+/- 3936’ which lines up well with the TOC showing up around 3880’ MD. It does not make sense that we have great cement on bottom and top with the apparent lack of cement as you mention from 5165-6880’ but I can’t deny what the CBL shows. With that said, we plan to perforate the following intervals still as planned since they are below what appears to have lack of cement. Sand md top md bottom tvd top tvd bottom interval BEL 9 ±6,966'±6,980'±6,183'±6,195'±14' BEL 10 ±7,085'±7,095'±6,284'±6,293'±10' BEL 11 ±7,157'±7,165'±6,347'±6,354'±8' BEL 11 ±7,197'±7,206'±6,383'±6,391'±9' BEL 11 ±7,302'±7,312'±6,479'±6,488'±10' BEL 12 ±7,393'±7,400'±6,564'±6,570'±7' After these intervals are tested, we will selectively perf and target the intervals with the highest chance of success first. The other intervals will be evaluated after the initial intervals are tested to ensure maximum depletion of the pool. Sand md top md bottom tvd top tvd bottom interval BEL 5 ±6,563'±6,583'±5,858'±5,874'±20' BEL 5 ±6,593'±6,605'±5,882'±5,892'±12' BEL 5 ±6,614'±6,626'±5,899'±5,909'±12' BEL 7 ±6,693'±6,700'±5,962'±5,968'±7' Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 14, 2025 5:33 PM 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. To: Ryan Lemay <Ryan.Lemay@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Scott Warner <Scott.Warner@hilcorp.com>; Eli Wilson - (C) <Eli.Wilson@hilcorp.com> Subject: [EXTERNAL] RE: BCU-14B Cement Bond Log / Review and Approval to Proceed with Perforations Ryan, How do you explain the apparent lack of cement from ~5165-6880’ and what are the implications? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <Ryan.Lemay@hilcorp.com> Sent: Thursday, April 10, 2025 3:57 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Scott Warner <Scott.Warner@hilcorp.com>; Eli Wilson - (C) <Eli.Wilson@hilcorp.com> Subject: BCU-14B Cement Bond Log / Review and Approval to Proceed with Perforations Mel / Bryan, Attached is the CBL for BCU-14B. Please review and Hilcorp is requesting to proceed with planned perforations per approved Sundry. Summary of Operations Prior to Cement Job (3/31-4/1/2025) MIRU E-line. PT lubricator 250 low / 2500 high – good test. Bullhead 5 bbl 9.4 ppg NaCl + 64 bbls produced water Set CIBP @ 7965’. Dump bail 14.4 gal cement Tag TOC @ 7917’. MIT plug to 2450 psi – good test. AOGCC Sully Sullivan witnessed on 4/1/2025 Shoot tubing punches from 7610’-7614’ Circulated 330 bbls water with good 1 to 1 returns down 3-1/2” tubing up 3-1/2” x 7” annulus Pressure up tubing / IA to 2500 psi for 5 min to verify tubing punches did not puncture 7” casing – good test RDMO E-line Summary of Operations Cement Job (4/6/25-current) MIRU Fox CTU. PT BOPE 250 psi low / 3000 psi high – good test RIH with one trip cement retainer on coil and set at 7530’ MD Establish circulation through retainer down 3-1/2” tubing and up 3-1/2” x 7” annulus Pump cement job: Pump 50 bbls fresh water with corrosion inhibitor. Pump 97 bbls 15.3 ppg class G cement Displace with 23 bbls fresh water Good 1 to 1 returns throughout entire cement job ETOC in 3-1/2” x 7” annulus ~3,968’ Shear off retainer. Verify retainer holding, POOH holding 1350 psi on 3-1/2” tubing. Cement in place ~18:00 hrs on Monday 4/7/2025. WOC MIRU E-line. PT lubricator 250 psi low / 2500 high – good test. RIH w/ CBL and tag cement retainer at 7,522’ MD. Log well with 1300 psi surface pressure applied TOC Estimated ~3880’ per attached CBL. Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. You don't often get email from ryan.lemay@hilcorp.com. Learn why this is important From:Rixse, Melvin G (OGC) To:Ryan Lemay Cc:Scott Warner; Eli Wilson - (C); McLellan, Bryan J (OGC) Subject:20250410 1823 APPROVAL BCU-14B Cement Bond Log / Review and Approval to Proceed with Perforations Date:Thursday, April 10, 2025 6:25:29 PM Ryan, CBL received. Approved to proceed with planned perforations. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Scott Warner, Eli Wilson, Bryan McLellan From: Ryan Lemay <Ryan.Lemay@hilcorp.com> Sent: Thursday, April 10, 2025 3:57 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Scott Warner <Scott.Warner@hilcorp.com>; Eli Wilson - (C) <Eli.Wilson@hilcorp.com> Subject: BCU-14B Cement Bond Log / Review and Approval to Proceed with Perforations Mel / Bryan, Attached is the CBL for BCU-14B. Please review and Hilcorp is requesting to proceed with planned perforations per approved Sundry. Summary of Operations Prior to Cement Job (3/31-4/1/2025) MIRU E-line. PT lubricator 250 low / 2500 high – good test. Bullhead 5 bbl 9.4 ppg NaCl + 64 bbls produced water Set CIBP @ 7965’. Dump bail 14.4 gal cement Tag TOC @ 7917’. MIT plug to 2450 psi – good test. AOGCC Sully Sullivan witnessed on 4/1/2025 Shoot tubing punches from 7610’-7614’ Circulated 330 bbls water with good 1 to 1 returns down 3-1/2” tubing up 3-1/2” x 7” annulus Pressure up tubing / IA to 2500 psi for 5 min to verify tubing punches did not puncture 7” casing – good test RDMO E-line Summary of Operations Cement Job (4/6/25-current) MIRU Fox CTU. PT BOPE 250 psi low / 3000 psi high – good test RIH with one trip cement retainer on coil and set at 7530’ MD Establish circulation through retainer down 3-1/2” tubing and up 3-1/2” x 7” annulus Pump cement job: Pump 50 bbls fresh water with corrosion inhibitor. Pump 97 bbls 15.3 ppg class G cement Displace with 23 bbls fresh water Good 1 to 1 returns throughout entire cement job ETOC in 3-1/2” x 7” annulus ~3,968’ Shear off retainer. Verify retainer holding, POOH holding 1350 psi on 3-1/2” tubing. Cement in place ~18:00 hrs on Monday 4/7/2025. WOC MIRU E-line. PT lubricator 250 psi low / 2500 high – good test. RIH w/ CBL and tag cement retainer at 7,522’ MD. Log well with 1300 psi surface pressure applied TOC Estimated ~3880’ per attached CBL. Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 33 Township: 7N Range: 10W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 11,459 ft MD Lease No.: FEDA028083 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 145 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 2,122 Feet Csg Cut@ Feet Intermediate: 9-5/8" O.D. Shoe@ 3,632 Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 7,838 Feet Csg Cut@ Feet Liner: 3-1/2" O.D. Shoe@ 11457 Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 7,651 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 7,965 ft 7,917 ft 8.5 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2450 2310 2240 IA 70 70 70 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Trevor Williams Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): This is the initial plug to isolate the current open perfs in the Beluga pool. Wireline dump bailed 48 feet of cement on top of a cast iron bridge plug. Top of cement verified by solid tags at 7,917 ft MD. Successful MIT-T after plug tag. April 1, 2025 Sully Sullivan Well Bore Plug & Abandonment Beaver Creek Unit 14B Hilcorp Alaska LLC PTD 2220570; Sundry 325-087 none Test Data: P Casing Removal: rev. 3-24-2022 2025-0401_Plug_Verification_BCU-14B_ss 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 999 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.05 16:26:56 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Cement Annulus, N2 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): 11,459'N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 8,530psi Liner 10,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ryan.lemay@hilcorp.com 661-487-0871 Noel Nocas, Operations Manager 907-564-5278 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 Ryan Lemay, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 222-057 50-133-20539-02-00 Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 7,651' 11,220psi 2,122' Size 145' 9-5/8"3,632' 2,122' MD 3-1/2" See Schematic 5,750 psi 3,060 psi 3,450 psi 145' 3,548' 145' 2,122' February 27, 2025 11,457'3,817' 3-1/2" 10,460' 7,838' Perforation Depth MD (ft): 3,632' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 14BCO 237D Same 6,989'7" ~2234psi 7,838' See Schematic Length ZXP Liner Top Pkr; N/A 7,641' MD/ 6,705' TVD; N/A 10,462'8,255'7,390' Beaver Creek Beluga Gas 20" 13-3/8" See Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-087 By Gavin Gluyas at 3:26 pm, Feb 18, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.02.18 15:15:58 - 09'00' Noel Nocas (4361) BJM 2/24/25 DSR-2/18/25 Submit 3-1/2" tubing CBL to AOGCC and obtain approval before perforating. Perform MIT-IA to 2000 psi within 30 days of bringing well on line, after perforating is complete. X Pressure test cement plug at ~7930' MD to 2200 psi and tag TOC to verify depth. Provide 24 hrs notice for opportunity to witness PT & Tag. 10-404 A.Dewhurst 27FEB25*&: 2/27/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.27 13:18:29 -09'00' RBDMS JSB 022825 Well Prognosis Well: BCU-14B Well Name: BCU-14B API Number: 50-133-20539-02-00 Current Status: Producing Gas Well Permit to Drill Number: 222-057 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661) 487-0871 Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2891 psi @ 6570’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2234 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.63 psi/ft using 12.1 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.63-0.1) = 2234 psi / 0.53 = 4216‘ TVD (Will not perforate above applicable gas pool) Top of Applicable Gas Pool: 6531’ MD/ 5832’ TVD Well Status: Producing Gas Well x Currently producing + 175 mcfd Brief Well Summary Beaver Creek 14B is a sidetracked gas producer that was drilled and completed in November 2022. Initial perforations were added from T7-T18 and the well came online at 2.2 mmscfd. Additional footage was added in the Tyonek sands in June 2024 which were unsuccessful, bringing in water and ultimately killing the well. In August 2024, the Tyonek pool was plugged, and perforations were added to the Beluga pool (Beluga 22-33 sands). No sustained gas production in perforation intervals. In October 2024, additional perforations were added (Beluga 21-16L sands). The well is currently producing + 175 mcfd The purpose of this Sundry is to plug and isolate current open perforations in Beluga pool, cement 3-1/2” x 7” annulus above liner top packer, and additional production perforations in the Beluga pool. Wellbore Notes: x 3-1/2” liner top packer at 7641’ MD x 7” casing TOC at 3596’. CBL dated 11/6/22 x Inclination o Max deviation of 39.6° @ 5,867’ MD o Max DLS of 4.98°/100’ @ 3,714’ MD Pre – Sundry Slickline Procedure: 1. MIRU slickline unit and pressure control equipment. PT lubricator to 250 psi low / 2,500 psi high 2. RIH with full gauge drift and tag. Verify ability to drift to + 7965’ for CIBP setting depth a. If fill is encountered, bail as necessary to get to plug setting depth. 3. RDMO slickline unit. E-line Procedure: 4. RU pump truck and batch mixer. Mix 5 bbls of 9.4 ppg NaCl corrosion inhibited brine (~575’ ft of kill weight fluid). Pump weighted brine into well followed by 64 bbls of produced water to kill well and place original drill weight mud between plugs. 5. MIRU E-line and pressure control equipment. PT lubricator to 250 psi low / 2,500 psi high 6. Make up 3-1/2” CIBP, RIH and set 3-1/2” CIPB plug at + 7965’ MD (50’ above top perforations). Do not set tubing plug across collar (Tubing tally shows collars at + 7958’ MD & + 7989’ MD) a. Tag plug after set and confirm setting depth TOC at 3620' MD -bjm Well Prognosis Well: BCU-14B b. BLM regulations call for plug to be set 50’-100’ of perfs (Top Perf 8015’ MD) 7. RIH and dump bail 35’ of cement on top of plug (planned estimated TOC + 7930’ MD). 8. Pressure test 3-1/2” tubing to 1400 psi with 0 psi on 3-1/2” x 7” annulus. No chart required. a. 3-1/2” x 7” annulus is 8.3 ppg corrosion inhibited drill water 9. MU and RIH with tubing punch. a. Punch 3-1/2” tubing at + 7631’ MD (~10’ above liner top packer). Verify collar depths and do not shoot across collar (tubing tally shows collars at + 7609’ & + 7640’) 10. Establish circulation from 3-1/2” tubing and 3-1/2” x 7” annulus a. If unable to establish circulation, run CBL to see if there are any solids settled. b. Repeat tubing punch ~50 ft shallower if CBL does not indicate solids build up. 11. RDMO E-line 12. Once circulation has been established in both directions, circulate a minimum of 300 bbls of fluid (until returns are clean) a. 3-1/2” x 7” annulus = 202 bbls b. 3-1/2” tubing volume = 67 bbls 13. CMIT tubing and annulus to 2500 psi (no chart required) to verify and ensure tubing punch did not rupture casing. 3-1/2” x 7” Cementing and Coil Tubing Procedure: 14. MIRU CTU and provide 24 hour notice for BOP Test. 15. Conduct BOP test 250 psi low, 3000 psi high. 16. RIH with cement retainer on 1.75” coil tubing and set @ + 7530’ MD. 17. Establish circulation through cement retainer up the 3-1/2” x 7” annulus. 18. RU cement truck, PT lines 250 psi low, 3000 psi high. 19. Mix and pump ~15.3 ppg cement down coil, taking returns up the 3-1/2” x 7” annulus. a. Manage 3-1/2” x 7” back pressure to keep the cement from running away down tubing. 20. Planned TOC in 3-1/2” x 7” annulus = + 4000’ MD a. 96 bbls cement in 3-1/2” x 7” annulus b. 0.9 bbls cement in 3-1/2” tubing below retainer c. Total ~97 bbls cement 21. Displace coil tubing to cement retainer per OE with fresh water. a. Use wiper ball down coil if available. 22. Unstab coil from cement retainer, circulate clean with minimum of 3-1/2” tubing volume (66 bbls) 23. Test cement retainer float (check valve). a. If necessary, trap pressure on the tubing (~1350 psi) with 3-1/2” x 7” annulus at 0 psi to ensure cement doesn’t u-tube. 24. RDMO cementers 25. POOH with coil 26. WOC for a minimum of 24 hours. 27. MIRU E-line and pressure control equipment. PT lubricator 250 psi low / 2500 psi high. 28. RIH, tag cement retainer, and complete CBL (submit CBL to AOGCC and obtain approval prior to perforating). 29. RD E-line 30. MIT 3-1/2” x 7” annulus to 2500 psi for 30 min – charted. 31. RIH with coil tubing, tag retainer, with a nozzle to drift tubing for perf guns. 32. Reverse lift water from wellbore (~66 bbls) 33. Trap N2 pressure on tubing per OE/RE recommendation for perforating. a. ~2100 psi applied trapped pressure = 25% underbalanced 34. RDMO CTU Pressure test plug to 2200 psi. Tag TOC to verify depth. Provide 24 hrs notice for opportunity to witness PT & tag. -bjm Well Prognosis Well: BCU-14B E-line Procedure: 35. MIRU E-line and pressure control equipment. PT lubricator to 250 psi low / 2500 psi high 36. RIH and perforate as directed by reservoir team. Well Sand md top md bottom tvd top tvd bottom interval BCU-14B BEL 5 ±6,563' ±6,583' ±5,858' ±5,874' ±20' BCU-14B BEL 5 ±6,593' ±6,605' ±5,882' ±5,892' ±12' BCU-14B BEL 5 ±6,614' ±6,626' ±5,899' ±5,909' ±12' BCU-14B BEL 6 ±6,671' ±6,691' ±5,945' ±5,961' ±20' BCU-14B BEL 7 ±6,693' ±6,700' ±5,962' ±5,968' ±7' BCU-14B BEL 8 ±6,787' ±6,833' ±6,038' ±6,075' ±46' BCU-14B BEL 8B ±6,869' ±6,879' ±6,104' ±6,112' ±10' BCU-14B BEL 9 ±6,966' ±6,980' ±6,183' ±6,195' ±14' BCU-14B BEL 9 ±6,997' ±7,015' ±6,209' ±6,224' ±18' BCU-14B BEL 10 ±7,085' ±7,095' ±6,284' ±6,293' ±10' BCU-14B BEL 11 ±7,157' ±7,165' ±6,347' ±6,354' ±8' BCU-14B BEL 11 ±7,197' ±7,206' ±6,383' ±6,391' ±9' BCU-14B BEL 11 ±7,302' ±7,312' ±6,479' ±6,488' ±10' BCU-14B BEL 12 ±7,393' ±7,400' ±6,564' ±6,570' ±7' a. Correlate using Open Hole Correlation log provided by Geologist. Send correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. b. Use Gamma / CCL to correlate c. Record tubing pressure before and after each perforating run at 5 min, 10 min, and 15 min intervals post shot and record. 37. Turn well over to operations and flow the well. a. Pending well production, all perforation intervals may not be completed on this Sundry. Post Perforation MIT: 38. Perform MIT on 3-1/2” x 7” annulus to 2000 psi once job is complete and well has been brought online within 30 days. Contingency Procedure: If any perforated zones produce sand and / or water or needs isolated: 1. MIRU E-line and pressure control equipment. PT 250 psi low / 2500 psi high 2. E-line to run PT to find fluid level 3. Use N2 or gas lift to push fluid below perforations (verify fluid level depth with PT tool) 4. PU 3-1/2” CIBP, WRP, or patch a. If a CIBP is set (it must be set within 50’ of the top perforation being plugged back). b. Note 5. If necessary to cleanout or unload the well with coil tubing: a. MIRU CTU (provide 24 hour notice for BOP test witness) b. Test BOP 250 psi low / 3000 psi high. c. Cleanout using water and N2 d. Set 3-1/2” plug or patch e. Blow well dry with coil using N2. Well Prognosis Well: BCU-14B Attachments: 1. Current Schematic 2. Proposed Schematic 3. CTU BOP Diagram 4. Standard Well Procedure – N2 Operations Updated by DMA 11-11-24 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 3 8,255’CIBP (10/23/24) 4 8,407’CIBP (10/22/24) 5 8,445’CIBP (10/21/24) 6 9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 7 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 16L 8,015'8,034'7,159'7,177'19'10/25/2024 Open BEL 17 8,061'8,067'7,203'7,209'6'10/25/2024 Open BEL 18 8,089'8,095'7,230'7,236'6'10/25/2024 Open BEL 18 8,124'8,130'7,264'7,270'6'10/25/2024 Open BEL 19 8,155'8,161'7,294'7,299'6'10/25/2024 Open BEL 19 8,170'8,176'7,308'7,314'6'10/24/2024 Open BEL 19 8,180'8,190'7,318'7,327'10'10/24/2024 Open BEL 19 8,193'8,203'7,330'7,340'10'10/24/2024 Open BEL 19 8,212'8,222'7,348'7,358'10'10/24/2024 Open BEL 19 8,228'8,238'7,364'7,373'10'10/24/2024 Open BEL 19 8,243'8,249'7,378'7,384'6'10/24/2024 Open BEL 20 8,259'8,286'7,394'7,420'27'10/23/2024 Isolated BEL 20 8,298'8,312'7,431'7,445'14'10/23/2024 Isolated BEL 20 8,328'8,338'7,460'7,470'10'10/23/2024 Isolated BEL 21 8,422'8,428'7,551'7,557'6'10/22/2024 Isolated BEL 22 8,452'8,462'7,580'7,590'10'8/16/2024 Isolated BEL 22 8,485'8,491'7,613'7,618'6'8/16/2024 Isolated BEL 22 8,500'8,506'7,626'7,632'6'8/16/2024 Isolated BEL 23 8,523'8,533'7,648'7,658'10'8/16/2024 Isolated BEL 23 8,541'8,555'7,664'7,682'14'8/16/2024 Isolated BEL 24 8,629'8,635'7,751'7,757'6'8/15/2024 Isolated BEL 25 8,655'8,675'7,776'7,795'20'8/15/2024 Isolated BEL 26 8,729'8,735'7,847'7,852'6'8/15/2024 Isolated BEL 27 8,808'8,818'7,923'7,932'10'8/15/2024 Isolated BEL 28 8,879'8,885'7,991'7,997'6'8/15/2024 Isolated BEL 28 8,905'8,911'8,016'8,022'6'8/15/2024 Isolated BEL 28 8,916'8,922'8,026'8,033'6'8/15/2024 Isolated BEL 28L 8,945'8,951'8,055'8,061'6'8/15/2024 Isolated BEL 32L 9,335'9,345'8,428'8,437'10'8/14/2024 Isolated BEL 33 9,463'9,469'8,550'8,556'6'8/14/2024 Isolated T0 9,602'9,608'8,685'8,689'6'8/14/2024 Isolated T2 9,715'9,749'8,792’8,825'34'6/11/2024 Isolated T3 9,798'9,810'8,867'8,883'14'5/22/2024 Isolated T5 10,025'10,039'9,082'9,103'14'5/22/2024 Isolated T7 10,130’10,150’9,192’9,211’20’11/22/2022 Isolated T7A 10,152’10,172’9,213’9,232’20’11/23/2022 Isolated T14 10,941'10,961'9,967'9,986'20'5/22/2024 Isolated T16 11,108'11,118'10,129'10,140'10'5/22/2024 Isolated T18 11,290'11,300'10,304’10,314’10'11/21/2022 IsolatedT18 T14-T16 T7 T3-T5 T2 7 BEL 21 6 CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 BEL 16-19 BEL 19-20 BEL 22-T0 3 4 5 Updated by RPL 02-13-2025 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 + 7,530 Cement Retainer (Proposed) 3 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 4 + 7,965’CIBP w/ 35’ cement – TOC @ + 7,930’ (Proposed) 5 8,255’CIBP (10/23/24) 6 8,407’CIBP (10/22/24) 7 8,445’CIBP (10/21/24) 8 9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 9 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” T18 T14-T16 T7 T3-T5 T2 9 BEL 21 8 CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 3-1/2”TOC + 4,000 MD (Proposed) BEL 16-19 BEL 19-20 BEL 22-T0 5 6 7 3 4 9.4 ppg KWF PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 5 ±6,563' ±6,583' ±5,858' ±5,874' ±20' Proposed BEL 5 ±6,593' ±6,605' ±5,882' ±5,892' ±12' Proposed BEL 5 ±6,614' ±6,626' ±5,899' ±5,909' ±12' Proposed BEL 6 ±6,671' ±6,691' ±5,945' ±5,961' ±20' Proposed BEL 7 ±6,693' ±6,700' ±5,962' ±5,968' ±7' Proposed BEL 8 ±6,787' ±6,833' ±6,038' ±6,075' ±46' Proposed BEL 8B ±6,869' ±6,879' ±6,104' ±6,112' ±10' Proposed BEL 9 ±6,966' ±6,980' ±6,183' ±6,195' ±14' Proposed BEL 9 ±6,997' ±7,015' ±6,209' ±6,224' ±18' Proposed BEL 10 ±7,085' ±7,095' ±6,284' ±6,293' ±10' Proposed BEL 11 ±7,157' ±7,165' ±6,347' ±6,354' ±8' Proposed BEL 11 ±7,197' ±7,206' ±6,383' ±6,391' ±9' Proposed BEL 11 ±7,302' ±7,312' ±6,479' ±6,488' ±10' Proposed BEL 12 ±7,393' ±7,400' ±6,564' ±6,570' ±7' Proposed BEL 16L 8,015' 8,034' 7,159' 7,177' 19' 10/25/2024 Isolate BEL 17 8,061' 8,067' 7,203' 7,209' 6' 10/25/2024 Isolate BEL 18 8,089' 8,095' 7,230' 7,236' 6' 10/25/2024 Isolate BEL 18 8,124' 8,130' 7,264' 7,270' 6' 10/25/2024 Isolate BEL 19 8,155' 8,161' 7,294' 7,299' 6' 10/25/2024 Isolate BEL 19 8,170' 8,176' 7,308' 7,314' 6' 10/24/2024 Isolate BEL 19 8,180' 8,190' 7,318' 7,327' 10' 10/24/2024 Isolate BEL 19 8,193' 8,203' 7,330' 7,340' 10' 10/24/2024 Isolate BEL 19 8,212' 8,222' 7,348' 7,358' 10' 10/24/2024 Isolate BEL 19 8,228' 8,238' 7,364' 7,373' 10' 10/24/2024 Isolate BEL 19 8,243' 8,249' 7,378' 7,384' 6' 10/24/2024 Isolate BEL 20 8,259' 8,286' 7,394' 7,420' 27' 10/23/2024 Isolated BEL 20 8,298' 8,312' 7,431' 7,445' 14' 10/23/2024 Isolated BEL 20 8,328' 8,338' 7,460' 7,470' 10' 10/23/2024 Isolated BEL 21 8,422' 8,428' 7,551' 7,557' 6' 10/22/2024 Isolated BEL 22 8,452' 8,462' 7,580' 7,590' 10' 8/16/2024 Isolated BEL 22 8,485' 8,491' 7,613' 7,618' 6' 8/16/2024 Isolated BEL 22 8,500' 8,506' 7,626' 7,632' 6' 8/16/2024 Isolated BEL 23 8,523' 8,533' 7,648' 7,658' 10' 8/16/2024 Isolated BEL 23 8,541' 8,555' 7,664' 7,682' 14' 8/16/2024 Isolated BEL 24 8,629' 8,635' 7,751' 7,757' 6' 8/15/2024 Isolated BEL 25 8,655' 8,675' 7,776' 7,795' 20' 8/15/2024 Isolated BEL 26 8,729' 8,735' 7,847' 7,852' 6' 8/15/2024 Isolated BEL 27 8,808' 8,818' 7,923' 7,932' 10' 8/15/2024 Isolated BEL 28 8,879' 8,885' 7,991' 7,997' 6' 8/15/2024 Isolated BEL 28 8,905' 8,911' 8,016' 8,022' 6' 8/15/2024 Isolated BEL 28 8,916' 8,922' 8,026' 8,033' 6' 8/15/2024 Isolated BEL 28L 8,945' 8,951' 8,055' 8,061' 6' 8/15/2024 Isolated BEL 32L 9,335' 9,345' 8,428' 8,437' 10' 8/14/2024 Isolated BEL 33 9,463' 9,469' 8,550' 8,556' 6' 8/14/2024 Isolated T0 9,602' 9,608' 8,685' 8,689' 6' 8/14/2024 Isolated T2 9,715' 9,749' 8,792’ 8,825' 34' 6/11/2024 Isolated T3 9,798' 9,810' 8,867' 8,883' 14' 5/22/2024 Isolated T5 10,025' 10,039' 9,082' 9,103' 14' 5/22/2024 Isolated T7 10,130’ 10,150’ 9,192’ 9,211’ 20’ 11/22/2022 Isolated T7A 10,152’ 10,172’ 9,213’ 9,232’ 20’ 11/23/2022 Isolated T14 10,941' 10,961' 9,967' 9,986' 20' 5/22/2024 Isolated T16 11,108' 11,118' 10,129' 10,140' 10' 5/22/2024 Isolated T18 11,290' 11,300' 10,304’ 10,314’ 10' 11/21/2022 Isolated STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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 Nitrogen vendor 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 Transport. 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: 1/28/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240128 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 14B 50133205390200 222057 10/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 232-04 50283100230000 162037 1/8/2025 AK E-LINE TubingPlugCut BRU 241-34S 50283201980000 224077 1/11/2025 AK E-LINE Perf END 2-16 50029218850000 188134 10/6/2024 YELLOWJACKET PERF MPU H-08B 50029228080200 201047 1/9/2025 READ CaliperSurvey MRU M-25 50733203910000 187086 1/2/2025 AK E-LINE Perf PEAR 11 50133207120000 223032 10/2/2024 YELLOWJACKET PLUG-PERF Please include current contact information if different from above. T40025 T40026 T40027 T40028 T40032 T40033 T40035 BCU 14B 50133205390200 222057 10/21/2024 YELLOWJACKET GPT-PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.29 10:55:36 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: N2 Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,459 feet See Schematic feet true vertical 10,462 feet N/A feet Effective Depth measured 8,255 feet 7,641 feet true vertical 7,390 feet 6,705 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 7,651' MD 6,810' TVD Packers and SSSV (type, measured and true vertical depth)ZXP Liner Top Pkr; N/A 7,641' MD 6,705' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 3,090psi 8,530psi 3,060psi 3,450psi 5,750psi 11,220psi 2,122'2,122' Burst Collapse 1,050psi 1,950psi Production Liner 3,632' 7,838' 3,817' Casing Structural 3,548' 6,989' 3-1/2" 3,632' 7,838' 11,457'10,460' 145'Conductor Surface Intermediate 20" 13-3/8" 145' 2,122' measured TVD 9-5/8" 10,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-057 50-133-20539-02-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA 028083 Beaver Creek / Beluga Gas Beaver Creek Unit (BCU) 14B Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 15 Size 145' 1 15225 0 6840 65 Scott Warner, Operations Engineer 324-352 Sr Pet Eng: 10,540psi Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:28 am, Nov 19, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.11.18 14:11:59 - 09'00' Noel Nocas (4361) BJM 6/3/25 RBDMS JSB 112124 DSR-11/21/24 Page 1/1 Well Name: BCU-014B Report Printed: 11/6/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:10/21/2024 End Date: Report Number 1 Report Start Date 10/20/2024 Report End Date 10/21/2024 Last 24hr Summary PTW/PJSM. MIRU Fox N2 equipment. P-test to 4600 psi- pass. Pump 105 mscf nitrogen to push water. Shut down at 4,500 psi. SDFN. Report Number 2 Report Start Date 10/21/2024 Report End Date 10/22/2024 Last 24hr Summary PTW/PJSM. MIRU YJ E-line. SITP 2,985 psi. P-test 250/3,000 psi. Run GPT log. Found fluid level at ~8,275'. RU Fox N2 and pump 32,464 scf N2, SD at 4,000 psi. Check fluid level with GPT - found at 8,465'. RD Fox N2. RIH with CIBP and set at 8445'. SDFN Report Number 3 Report Start Date 10/22/2024 Report End Date 10/23/2024 Last 24hr Summary PTW/PJSM with YJ Eline. (SITP-3476 psi -N2) Rig back on well, draw down to 1775 psi and perforate the BEL_21 sand (8422'-8428'). Gun wet, M/U and set CIBP at 8407'. Shut down operations due to high wind gusts. Secure well. Report Number 4 Report Start Date 10/23/2024 Report End Date 10/24/2024 Last 24hr Summary PTW/PJSM with YJ E-line. (SITP-1725 psi) Rig back on well and perforate the BEL_20 (8328'-8338' & 8298'-8312') with switch guns. Small dip in pressure and guns dry. RIH and perforate the BEL_20 interval 8259'-8286'. Pressure dropped steadily f/1650 psi to1350 psi in 1 hour. Flow back well to 1000 psi, SI 15 min. - pressure continuing to drop 2 psi/min. Draw down to 800 psi, SI 15 min. - pressure decrease at 1 psi/min. RIH with GPT and locate fluid level at 8366' (28' below all open perfs). Draw well down to 500 psi and locate top of fluid at 8320'. RIH with CIBP and set at 8255'. Secure well. SDFN. Report Number 5 Report Start Date 10/24/2024 Report End Date 10/25/2024 Last 24hr Summary PTW/PJSM with YJ E-line. SITP-528 psi, jump gas up to 753 psi. Rig back on well and perforate the BEL_19 intervals (8243-49'), (8228'-38'), (8212'-22') with switch guns. Pressure decreased and gun plug contained greasy fluid. P/U GPT, no fluid detected to plug at 8255'. Draw down to 500 psi. (30 min. shut in 486 psi). No fluid detected after draw down. P/U and RIH with 3 switch guns and perforate the BEL_19 intervals (8193'-8203'), (8180'-8190'), (8170'-8176'). Pressure slowly increased after last shot at 8170'-76'. P/U and RIH with GPT and located fluid top at 8244' (11' above CIBP at 8255'). Secure well. SDFN. Turn well over to production to flow test. Report Number 6 Report Start Date 10/25/2024 Report End Date 10/26/2024 Last 24hr Summary PTW/PJSM with YJ E-line. SITP - 890 psi. P/U GPT and locate fluid level at 8168'(top perf 8170'-8176'). P/U (4) x 6' switch guns and perforate BEL_19 (8155'-61'), BEL_18 (8124'-30'), BEL_18 (8089'-95') and BEL_17 (8061'-67'). Slow decrease in pressure, guns dry. P/U 19' gun and perforate BEL_16L (8015'-34'). Secure well and RDMO E-line. Job complete, turn well over to production. Field: Beaver Creek Sundry #: State: ALASKA Rig/Service:Permit to Drill (PTD) #:222-057Permit to Drill (PTD) #:222-057 Wellbore API/UWI:50-133-20539-02-00 ,pg p( perforate the BEL_19 intervals (8193'-8203'), (8180'-8190'), (8170'-8176'). (4) x 6' switch guns and perforate BEL_19 (8155'-61'),p BEL_18 (8124'-30'), BEL_18 (8089'-95') and BEL_17 (8061'-67'). M/U and set CIBP at 8407'. (p)g RIH and perforate the BEL_20 interval 8259'-8286'. perforate the BEL_19 intervals (8243-49'), (8228'-38'), (8212'-22') pp RIH with CIBP and set at 8255 P/U 19' gun and perforate BEL_16L (8015'-34'). () g p _ perforate the BEL_21 sand (8422'-8428 ,p g RIH with CIBP and set at 8445'. Updated by DMA 11-11-24 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 3 8,255’CIBP (10/23/24) 4 8,407’CIBP (10/22/24) 5 8,445’CIBP (10/21/24) 6 9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 7 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 16L 8,015'8,034'7,159'7,177'19'10/25/2024 Open BEL 17 8,061'8,067'7,203'7,209'6'10/25/2024 Open BEL 18 8,089'8,095'7,230'7,236'6'10/25/2024 Open BEL 18 8,124'8,130'7,264'7,270'6'10/25/2024 Open BEL 19 8,155'8,161'7,294'7,299'6'10/25/2024 Open BEL 19 8,170'8,176'7,308'7,314'6'10/24/2024 Open BEL 19 8,180'8,190'7,318'7,327'10'10/24/2024 Open BEL 19 8,193'8,203'7,330'7,340'10'10/24/2024 Open BEL 19 8,212'8,222'7,348'7,358'10'10/24/2024 Open BEL 19 8,228'8,238'7,364'7,373'10'10/24/2024 Open BEL 19 8,243'8,249'7,378'7,384'6'10/24/2024 Open BEL 20 8,259'8,286'7,394'7,420'27'10/23/2024 Isolated BEL 20 8,298'8,312'7,431'7,445'14'10/23/2024 Isolated BEL 20 8,328'8,338'7,460'7,470'10'10/23/2024 Isolated BEL 21 8,422'8,428'7,551'7,557'6'10/22/2024 Isolated BEL 22 8,452'8,462'7,580'7,590'10'8/16/2024 Isolated BEL 22 8,485'8,491'7,613'7,618'6'8/16/2024 Isolated BEL 22 8,500'8,506'7,626'7,632'6'8/16/2024 Isolated BEL 23 8,523'8,533'7,648'7,658'10'8/16/2024 Isolated BEL 23 8,541'8,555'7,664'7,682'14'8/16/2024 Isolated BEL 24 8,629'8,635'7,751'7,757'6'8/15/2024 Isolated BEL 25 8,655'8,675'7,776'7,795'20'8/15/2024 Isolated BEL 26 8,729'8,735'7,847'7,852'6'8/15/2024 Isolated BEL 27 8,808'8,818'7,923'7,932'10'8/15/2024 Isolated BEL 28 8,879'8,885'7,991'7,997'6'8/15/2024 Isolated BEL 28 8,905'8,911'8,016'8,022'6'8/15/2024 Isolated BEL 28 8,916'8,922'8,026'8,033'6'8/15/2024 Isolated BEL 28L 8,945'8,951'8,055'8,061'6'8/15/2024 Isolated BEL 32L 9,335'9,345'8,428'8,437'10'8/14/2024 Isolated BEL 33 9,463'9,469'8,550'8,556'6'8/14/2024 Isolated T0 9,602'9,608'8,685'8,689'6'8/14/2024 Isolated T2 9,715'9,749'8,792’8,825'34'6/11/2024 Isolated T3 9,798'9,810'8,867'8,883'14'5/22/2024 Isolated T5 10,025'10,039'9,082'9,103'14'5/22/2024 Isolated T7 10,130’10,150’9,192’9,211’20’11/22/2022 Isolated T7A 10,152’10,172’9,213’9,232’20’11/23/2022 Isolated T14 10,941'10,961'9,967'9,986'20'5/22/2024 Isolated T16 11,108'11,118'10,129'10,140'10'5/22/2024 Isolated T18 11,290'11,300'10,304’10,314’10'11/21/2022 IsolatedT18 T14-T16 T7 T3-T5 T2 7 BEL 21 6 CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 BEL 16-19 BEL 19-20 BEL 22-T0 3 4 5 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: 9/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 8/18/2024 YELLOWJACKET PERF BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 9/9/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 8/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 9/14/2024 AK E-LINE CBL END 1-61 50029225200000 194142 9/11/2024 READ CaliperSurvey KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF MPU B-24 50029226420000 196009 9/9/2024 READ CaliperSurvey MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey MPU R-103 50029237990000 224114 9/16/2024 AK E-LINE TubingCut MPU R-103 50029237990000 224114 9/19/2024 AK E-LINE TubingCut MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug NCIU A-19 50883201940000 224026 9/20/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/13/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/15/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/18/2024 AK E-LINE CBL NCIU A-20 50883201960000 224065 9/11/2024 AK E-LINE PPROF NCIU A-20 50883201960000 224065 8/26/2024 READ MemoryRadialCementBondLog PBU 09-27A 50029212910100 215206 9/13/2024 AK E-LINE CBL/TubingPunch PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL PBU 13-24B 50029207390200 224087 8/21/2024 YELLOWJACKET CBL-PERF PBU 13-24B 50029207390200 224087 8/23/2024 YELLOWJACKET CBL PBU 13-26 50029207460000 182074 8/13/2024 YELLOWJACKET CCL PBU NK-26A 50029224400100 218009 7/20/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T39593 T39594 T39595 T39596 T39597 T39598 T39599 T39600 T39601 T39602 T39603 T39603 T39604 T39605 T39605 T39605 T39605 T39606 T39606 T39607 T39608 T39609 T39609 T39610 T39611 BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.27 14:47:28 -08'00' 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. From:McLellan, Bryan J (OGC) To:Scott Warner Cc:Donna Ambruz Subject:RE: BCU-14B AOGCC 10-403 324-352 PTD 222-057 Approved 06-24-24 Date:Monday, September 9, 2024 3:50:00 PM Scott, Hilcorp has approval to add the additional perfs listed below as part of the sundry 324-352. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, September 9, 2024 3:28 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: BCU-14B AOGCC 10-403 324-352 PTD 222-057 Approved 06-24-24 Bryan, This sundry is still open and we are hoping to add the following proposed perforation table to the sundry. Well Sand md top md bottom tvd top tvd bottom interval BCU-14B BEL 16 ±8,015'±8,034'±7,159'±7,177'±19' BCU-14B BEL 17 ±8,061'±8,067'±7,203'±7,209'±6' BCU-14B BEL 18 ±8,089'±8,095'±7,230'±7,236'±6' BCU-14B BEL 18 ±8,124'±8,130'±7,264'±7,270'±6' BCU-14B BEL 19 ±8,155'±8,161'±7,294'±7,299'±6' BCU-14B BEL 19 ±8,170'±8,176'±7,308'±7,314'±6' BCU-14B BEL 19 ±8,180'±8,190'±7,318'±7,327'±10' BCU-14B BEL 19 ±8,193'±8,203'±7,330'±7,340'±10' BCU-14B BEL 19 ±8,212'±8,222'±7,348'±7,358'±10' BCU-14B BEL 19 ±8,228'±8,238'±7,364'±7,373'±10' BCU-14B BEL 19 ±8,243'±8,249'±7,378'±7,384'±6' BCU-14B BEL 20 ±8,259'±8,286'±7,394'±7,420'±27' BCU-14B BEL 20 ±8,297'±8,313'±7,430'±7,446'±16' BCU-14B BEL 20 ±8,328'±8,338'±7,460'±7,470'±10' BCU-14B BEL 21 ±8,422'±8,428'±7,551'±7,557'±6' We have shot all perforations from the open sundry and the well never sustained flow. We will plan to rig up and check for fluid level initially. Pending fluid level, we would either continue to perforate or use N2 to push fluid away, set a plug, and then perforate. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Tuesday, June 25, 2024 8:26 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: BCU-14B AOGCC 10-403 324-352 PTD 222-057 Approved 06-24-24 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 7/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240730 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 5/22/2024 YELLOW JACKET PERF BCU 14B 50133205390200 222057 6/11/2024 YELLOW JACKET GPT-PLUG-PERF BCU 19RD 50133205790100 219188 7/17/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/1/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 7/11/2024 AK E-LINE PressureTemp CLU 16 50133207200000 224021 5/16/2024 YELLOW JACKET SCBL CLU 16 50133207200000 224021 5/31/2024 YELLOW JACKET SCBL END 2-14 50029216390000 186149 5/9/2024 YELLOW JACKET PLUG KU 33-08 50133207180000 224008 5/9/2024 YELLOW JACKET GPT-PLUG-PERF MPU H-08B 5.00292E+13 201047 7/14/2024 READ CaliperSurvey MPU I-40 50029236890000 220071 7/6/2024 AK E-LINE TubingCut MPU R-101 50029237930000 224078 7/16/2024 YELLOW JACKET SCBL MPU S-17 50029231150000 202173 7/12/2024 AK E-LINE TubingCut MPU S-17 5.00292E+13 202173 7/18/2024 READ CaliperSurvey PBU NK-43 50029229980000 201001 6/11/2024 YELLOW JACKET PL PBU PTM P1-13 50029223720000 193074 7/4/2024 YELLOW JACKET PL Pearl 11 50133207120000 223032 7/10/2024 AK E-LINE Plug/Perf Please include current contact information if different from above. T39310 T39310T T39311T T39312T T39312 T39313 T39313 T39314 T39315 T39316 T39317 T39318 T39319 T39319 T39320 T39321 T39322 YELLOW BCU 14B 50133205390200 222057 5/22/2024 JACKET PERF YELLOW BCU 14B 50133205390200 222057 6/11/2024 JACKET GPT-PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.30 13:09:33 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 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): 11,459'N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 8,530psi Liner 10,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 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 Scott Warner, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 222-057 50-133-20539-02-00 Hilcorp Alaska, LLC Proposed Pools: L-80 TVD Burst 7,651' 11,220psi 2,122' Size 145' 9-5/8"3,632' 2,122' MD 3-1/2" See Schematic 5,750 psi 3,060 psi 3,450 psi 145' 3,548' 145' 2,122' July 2, 2024 11,457'3,817' 3-1/2" 10,460' 7,838' Perforation Depth MD (ft): 3,632' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 14B CO 237D Beluga Gas 6,989'7" ~2990psi 7,838' 9790' Length ZXP Liner Top Pkr; N/A 7,641' MD/ 6,705' TVD; N/A 10,462'11,390'10,396' Beaver Creek Tyonek Gas 20" 13-3/8" See Schematic m n P s 66 t N 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 Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.19 13:55:03 - 08'00' Noel Nocas (4361) 324-352 By Grace Christianson at 2:24 pm, Jun 19, 2024 Beluga Perforate New Pool P SFD 6/20/2024 DSR-6/21/24BJM 6/24/24 10-407 *&:JLC 6/24/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.24 15:23:23 -08'00'06/24/24 RBDMS JSB 062524 Well Prognosis Well: BCU-14B Date: 6/18/24 Well Name: BCU-14B API Number: 50-133-20539-02-00 Current Status: Producing Gas Well Permit to Drill Number: 222-057 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 3869 psi @ 8792’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:2990 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.63 psi/ft using 12.1 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.63-0.1) = 2990 psi / 0.53 = 5642‘ TVD (Will not perforate above applicable gas pool) Top of Applicable Gas Pool: 6531’ MD/ 5832’ TVD Well Status: Shut In Gas Producer Brief Well Summary Beaver Creek 14B is a sidetracked gas producer that was drilled and completed in November 2022. Initial perforations were added from T7-T18 and the well came online at 2.2 mmscfd. Additional footage was added in the Tyonek sands in June 2024 which were unsuccessful, bringing in water and ultimately killing the well. The purpose of this sundry is to plug back the Tyonek pool and perforate sands in the lower Beluga pool. Notes Regarding Wellbore Condition x Inclination o Max deviation of 39.6° @ 5,867’ MD o Max DLS of 4.98°/100’ @ 3,714’ MD x Recent Tags/Fish o 6/11/24: M/U and RIH with 2.75" CIBP and set at 9790'. Bleed N2 off well to 2200 psi. Perforate T2 sand 9715'-9749' (34') in two runs w/ 2-3/8” guns. Did not flow. o 5/22/24: RIH and perforated T-16, T-14, T-5, and T-3 w/ 2-3/8” guns. Brought in water and did not flow. o 5/18/24: Tag w/ 2.83” GR at 11,296’. Ran P/T survey, tag again with 2.78” bailer at 11,300’ KB. o 4/9/23: 2” DD bailer tag at 11,340’ KB. Recovered ½ cup of soft sand & soap stick o 1/7/23: 1.75” sample bailer tag at 11,342’ SLM. No sample noted in WSR o 12/31/22: 2.5” DD bailer & tag @ 11,370’ SLM. Fluid level noted at 7,200’ SLM Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /3,000 psi high 3. RIH w/ GPT and ensure fluid level is below planned CIBP set depth of 9,665’ 4. Once fluid level is confirmed below 9,665’, RIH and set CIBP at 9,665’ 5. Dump bail minimum of 35’ cement on top of CIBP to isolate the Tyonek Pool from the Beluga Gas Pool 6. RIH and perforate Tyonek 0 – Beluga 22 sands from bottom up with 2-3/8” 60 deg phased perf guns: Top of Applicable Gas Pool plug back the Tyonek pool 6531’ MD perforate sands in the lower Beluga pool Well Prognosis Well: BCU-14B Date: 6/18/24 Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval BEL 22 ±8,449' ±8,472' ±7,577' ±7,599' ±23' BEL 22 ±8,486' ±8,491' ±7,613' ±7,618' ±5' BEL 22 ±8,500' ±8,506' ±7,626' ±7,632' ±6' BEL 23 ±8,523' ±8,533' ±7,648' ±7,658' ±10' BEL 23 ±8,539' ±8,558' ±7,664' ±7,682' ±19' BEL 24 ±8,629' ±8,635' ±7,751' ±7,757' ±6' BEL 25 ±8,655' ±8,675' ±7,776' ±7,795' ±20' BEL 26 ±8,729' ±8,734' ±7,847' ±7,852' ±5' BEL 27 ±8,808' ±8,818' ±7,923' ±7,932' ±10' BEL 28 ±8,879' ±8,885' ±7,991' ±7,997' ±6' BEL 28 ±8,905' ±8,911' ±8,016' ±8,022' ±6' BEL 28 ±8,915' ±8,922' ±8,026' ±8,033' ±7' BEL 28L ±8,945' ±8,952' ±8,055' ±8,061' ±7' BEL 32L ±9,335' ±9,345' ±8,428' ±8,437' ±10' BEL 33 ±9,463' ±9,469' ±8,550' ±8,556' ±6' T0 ±9,603' ±9,607' ±8,685' ±8,689' ±4' o Note: Top of Tyonek pool is 9678’ MD/ 8757’ TVD- T0 is within the Beluga gas pool a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i.Note: All proposed perforations are in the same Pool / PA after the initial CIBP is set at 9,665’ w/ a 35’ cement cap. A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together in same PA. If possible, the CIBP will be set 50’ above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50’. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 7. RDMO Attachments: Top of Tyonek pool is 9678’ MD/ 8757’ TVD- T0 is within the Belu ga gas pool Well Prognosis Well: BCU-14B Date: 6/18/24 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Updated by DMA 06-12-24 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 3 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status T2 9,715'9,749'8,792’8,825'34'6/11/2024 Open T3 9,798'9,810'8,867'8,883'14'5/22/2024 Isolated T5 10,025'10,039'9,082'9,103'14'5/22/2024 Isolated T7 10,130’10,150’9,192’9,211’20’11/22/2022 Isolated T7A 10,152’10,172’9,213’9,232’20’11/23/2022 Isolated T14 10,941'10,961'9,967'9,986'20'5/22/2024 Isolated T16 11,108'11,118'10,129'10,140'10'5/22/2024 Isolated T18 11,290'11,300'10,304’10,314’10'11/21/2022 Isolated T18 T14-T16 T7 T3-T5 T2 3 Updated by DMA 06-18-24 PROPOSED Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 2A ±9,665’CIBP w/35’ of cement – TOC @ ~9,630’ 3 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 22 ±8,449'±8,472'±7,577'±7,599'±23'Proposed TBD BEL 22 ±8,486'±8,491'±7,613'±7,618'±5'Proposed TBD BEL 22 ±8,500'±8,506'±7,626'±7,632'±6'Proposed TBD BEL 23 ±8,523'±8,533'±7,648'±7,658'±10'Proposed TBD BEL 23 ±8,539'±8,558'±7,664'±7,682'±19'Proposed TBD BEL 24 ±8,629'±8,635'±7,751'±7,757'±6'Proposed TBD BEL 25 ±8,655'±8,675'±7,776'±7,795'±20'Proposed TBD BEL 26 ±8,729'±8,734'±7,847'±7,852'±5'Proposed TBD BEL 27 ±8,808'±8,818'±7,923'±7,932'±10'Proposed TBD BEL 28 ±8,879'±8,885'±7,991'±7,997'±6'Proposed TBD BEL 28 ±8,905'±8,911'±8,016'±8,022'±6'Proposed TBD BEL 28 ±8,915'±8,922'±8,026'±8,033'±7'Proposed TBD BEL 28L ±8,945'±8,952'±8,055'±8,061'±7'Proposed TBD BEL 32L ±9,335'±9,345'±8,428'±8,437'±10'Proposed TBD BEL 33 ±9,463'±9,469'±8,550'±8,556'±6'Proposed TBD T0 ±9,603'±9,607'±8,685'±8,689'±4'Proposed TBD T2 9,715'9,749'8,792’8,825'34'6/11/2024 Isolated T3 9,798'9,810'8,867'8,883'14'5/22/2024 Isolated T5 10,025'10,039'9,082'9,103'14'5/22/2024 Isolated T7 10,130’10,150’9,192’9,211’20’11/22/2022 Isolated T7A 10,152’10,172’9,213’9,232’20’11/23/2022 Isolated T14 10,941'10,961'9,967'9,986'20'5/22/2024 Isolated T16 11,108'11,118'10,129'10,140'10'5/22/2024 Isolated T18 11,290'11,300'10,304’10,314’10'11/21/2022 Isolated T18 T14-T16 T7 T3-T5 T2 3 BEL 22- T0 2A STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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 Nitrogen vendor 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 Transport. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: N2 Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,459 feet N/A feet true vertical 10,462 feet N/A feet Effective Depth measured 11,390 feet 7,641 feet true vertical 10,396 feet 6,705 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 7,651' MD 6,810' TVD Packers and SSSV (type, measured and true vertical depth)ZXP Liner Top Pkr; N/A 7,641' MD 6,705' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 3,090psi 8,530psi 3,060psi 3,450psi 5,750psi 11,220psi 2,122'2,122' Burst Collapse 1,050psi 1,950psi Production Liner 3,632' 7,838' 3,817' Casing Structural 3,548' 6,989' 3-1/2" 3,632' 7,838' 11,457'10,460' 145'Conductor Surface Intermediate 20" 13-3/8" 145' 2,122' measured TVD 9-5/8" 10,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-057 50-133-20539-02-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA 028083 Beaver Creek / Tyonek Gas Beaver Creek Unit (BCU) 14B Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 145' 0 00 0 650 1082 Scott Warner, Operations Engineer 324-278 Sr Pet Eng: 10,540psi Sr Pet Geo:Sr Res Eng: WINJ WAG 334 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:43 am, Jun 17, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.14 14:54:27 - 08'00' Noel Nocas (4361) BJM 6/3/25 RBDMS JSB 061924 DSR-6/17/24 Well Name: BCU-014B API #:50133205390000 Field:Beaver Creek Start Date:5/22/2024 Permit #:204-086 Sundry #:324-278 End Date:6/11/2024 5/22/2024 6/10/2024 6/11/2024 Activity Report YJ E-line PTW and PJSM. MIRU, M/U GPT tool and PCE and PT 250 psi/4000 psi. Run GPT and locate fluid level at 10,004' (~200' below T3 perfs 9798'-9810'). M/U and RIH with 2.75" CIBP and set at 9790'. Bleed N2 off well to 2200 psi. Perforate T2 sand 9715'-9749' (34') in two runs. Turn over to production and flow back well. PJSM, Crew travel to location, Spot in & rig up Yellow jacket Eline, PIck up run #1, Pressure test to 4000 psi-good, Run in hole with run #1, Perf (T-16 11,108 to 11,118), Pull out & lay down, PIck up run #2, Run in hole & perf (T-14 10,941 to 10,961), Pull out of hole & lay down, Pick up run # 3, Run in hole & Perf (T-5 10,025' to 10,039'), Pull out of the hole & lay down, PIck up run #4, Run in hole & perf (T 3 9798- 9810), Pull out of the hole & lay down tools, Rig down & release Yellowjacket Eline. PTW/PJSM. SITP 1340 psi. MIRU Fox N2 unit and transport. P-test lines to 4500 psi. Pump nitrogen at 800-1000 scfm. Pump a total of 135,188 scf. Final SITP 4500 psi. SDFN. Daily Operations: Page 1 of 1 perf (T-14 10,941 to 10,961 Perforate T2 sand 9715'-9749' (34 Perf (T-16 11,108 to 11,118 Perf (T-5 10,025' to 10,039 RIH with 2.75" CIBP and set at 9790'. Updated by DMA 06-12-24 SCHEMATIC Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis CEMENT DETAIL 13-3/8”TOC @ Surface (Original BCU 14) 9-5/8"TOC @ Surface (Original BCU 14) 7”3,596’ MD TOC CBL 11/6/22 3-1/2”7,636’ MD TOC CBL 11/6/22 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 20”Conductor 133 K-55 Weld 18.73”Surf 145’ 13-3/8"Surf Csg 68.0 K-55 BTC 12.415”Surf 2,122’ 9-5/8”Intermediate Csg 40.0 L-80 BTC 8.835”Surf 3,632’ TOW 7”Intermediate Csg 2 26 L-80 Multiple 6.276”Surf 7,838’ 3-1/2"Prod Csg 9.2 L-80 Hyd 533 2.992”7,641’11,457’ 3-1/2"Tubing 9.3 L-80 RTS-8 2.992”Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 3,632’N/A 9.625”Whipstock 2 7,641’4.150”5.75”Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly 3 9,790’CIBP 6/11/24 4 9-5/8” @ 3,632’ 1BCU 14A (Abandoned) 7” PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status T2 9,715'9,749'8,792’8,825'34'6/11/2024 Open T3 9,798'9,810'8,867'8,883'14'5/22/2024 Isolated T5 10,025'10,039'9,082'9,103'14'5/22/2024 Isolated T7 10,130’10,150’9,192’9,211’20’11/22/2022 Isolated T7A 10,152’10,172’9,213’9,232’20’11/23/2022 Isolated T14 10,941'10,961'9,967'9,986'20'5/22/2024 Isolated T16 11,108'11,118'10,129'10,140'10'5/22/2024 Isolated T18 11,290'11,300'10,304’10,314’10'11/21/2022 Isolated T18 T14-T16 T7 T3-T5 T2 3 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 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): 11,459' N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 8,530psi Liner 10,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 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 Scott Warner, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 222-057 50-133-20539-02-00 Hilcorp Alaska, LLC Proposed Pools: L-80 TVD Burst 7,651' 11,220psi 2,122' Size 145' 9-5/8"3,632' 2,122' MD 3-1/2" See Schematic 5,750 psi 3,060 psi 3,450 psi 145' 3,548' 145' 2,122' May 21, 2024 11,457'3,817' 3-1/2" 10,460' 7,838' Perforation Depth MD (ft): 3,632' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 14B CO 237D Same 6,989'7" ~3525psi 7,838' N/A Length ZXP Liner Top Pkr; N/A 7,641' MD/ 6,705' TVD; N/A 10,462' 11,390' 10,396' Beaver Creek Tyonek Gas 20" 13-3/8" See Schematic m n P s 66 t N 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 2:31 pm, May 07, 2024 DSR-5/7/24SFD 5/7/2024 10-404 BJM 5/9/24JLC 5/9/2024 Well Prognosis Well: BCU-14B Date: 5/7/24 Well Name: BCU-14B API Number: 50-133-20539-02-00 Current Status: Producing Gas Well Permit to Drill Number: 222-057 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 4562 psi @ 10369 TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:3525 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.63 psi/ft using 12.1 ppg EMW FIT at the 9-5/8 int. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.63-0.1) = 3525 psi / 0.53 = 6650 TVD Top of Applicable Gas Pool: 9678 MD/ 8757 TVD Well Status: Online Gas Producer flowing at 306 mcfd, 0 bwpd, 65 psi FTP Brief Well Summary Beaver Creek 14B is a sidetracked gas producer that was drilled and completed in November 2022. Initial perforations were added from T7-T18 and the well came online at 2.2 mmscfd. The purpose of this sundry is to perforate additional footage in the Tyonek 2-18 sands to increase production. Notes Regarding Wellbore Condition Inclination o Max deviation of 39.6° @ 5,867 MD o Max DLS of 4.98°/100 @ 3,714 MD Recent Tags/Fish o 4/9/23: 2 DD bailer tag at 11,340 KB. Recovered ½ cup of soft sand & soap stick o 1/7/23: 1.75 sample bailer tag at 11,342 SLM. No sample noted in WSR o 12/31/22: 2.5 DD bailer & tag @ 11,370 SLM. Fluid level noted at 7,200 SLM Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /4,000 psi high 3. RIH and perforate Tyonek 2 - 18 sands while flowing from bottom up with 2-3/8 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval T2 ±9,715' ±9,749' ±8,792' ±8,825' ±34' T3 ±9,793' ±9,810' ±8,867' ±8,883' ±17' T5 ±10,017' ±10,039' ±9,082' ±9,103' ±22' T7A ±10,181' ±10,199' ±9,240' ±9,257' ±18' T7A ±10,216' ±10,231' ±9,273' ±9,288' ±15' 9678 MDTop of Applicable Gas Pool: , equivalent to 7,484' MD SFD Well Prognosis Well: BCU-14B Date: 5/7/24 T7B ±10,282' ±10,286' ±9,336' ±9,340' ±4' T11 ±10,695' ±10,699' ±9,731' ±9,735' ±4' T13 ±10,852' ±10,864' ±9,881' ±9,893' ±12' T13 ±10,873' ±10,878' ±9,901' ±9,906' ±5' T14 ±10,941' ±10,961' ±9,967' ±9,986' ±20' T14 ±10,977' ±10,990' ±10,002' ±10,015' ±13' T14 ±10,995' ±10,999' ±10,019' ±10,023' ±4' T15 ±11,026' ±11,037' ±10,049' ±10,060' ±11' T16 ±11,108' ±11,119' ±10,129' ±10,140' ±11' T16 ±11,146' ±11,151' ±10,166' ±10,171' ±5' T17 ±11,194' ±11,199' ±10,212' ±10,217' ±5' T17 ±11,212' ±11,217' ±10,230' ±10,235' ±5' T18 ±11,344' ±11,355' ±10,358' ±10,369' ±11' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure N2 Operations Updated by CAH 11-26-22 Schematic Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390 MD / 10,396 TVD TD = 11,459 MD / 10,462 TVD RKB to GL = 16.0 3-1/8 Otis PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Tyonek T7 10,130 10,150 9,192 9,211 20 11/22/22 Open Tyonek T7A 10,152 10,172 9,213 9,232 20 11/23/22 Open Tyonek T18 11,290' 11,300' 10,304 10,314 10' 11/21/22 Open CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20 Conductor 133 K-55 Weld 18.73 Surf 145 13-3/8" Surf Csg 68.0 K-55 BTC 12.415 Surf 2,122 9-5/8 Intermediate Csg 40.0 L-80 BTC 8.835 Surf 3,632 TOW 7 Intermediate Csg 2 26 L-80 Multiple 6.276 Surf 7,838 3-1/2" Prod Csg 9.2 L-80 Hyd 533 2.992 7,641 11,457 3-1/2" Tubing 9.3 L-80 RTS-8 2.992 Surf 7,651 2 20 13-3/8 3-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 3,632 N/A 9.625 Whipstock 2 7,641 4.150 5.75 Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2 bullet seal assembly CEMENT DETAIL 13-3/8 TOC @ Surface (Original BCU 14) 9-5/8" TOC @ Surface (Original BCU 14) 7 3,596 MD TOC CBL 11/6/22 3-1/2 7,636 MD TOC CBL 11/6/22 4 9-5/8 @ 3,632 1 BCU 14A (Abandoned) 7 Updated by DMA 05-07-24 PROPOSED Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390 MD / 10,396 TVD TD = 11,459 MD / 10,462 TVD RKB to GL = 16.0 3-1/8 Otis CEMENT DETAIL 13-3/8 TOC @ Surface (Original BCU 14) 9-5/8" TOC @ Surface (Original BCU 14) 7 3,596 MD TOC CBL 11/6/22 3-1/2 7,636 MD TOC CBL 11/6/22 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20 Conductor 133 K-55 Weld 18.73 Surf 145 13-3/8" Surf Csg 68.0 K-55 BTC 12.415 Surf 2,122 9-5/8 Intermediate Csg 40.0 L-80 BTC 8.835 Surf 3,632 TOW 7 Intermediate Csg 2 26 L-80 Multiple 6.276 Surf 7,838 3-1/2" Prod Csg 9.2 L-80 Hyd 533 2.992 7,641 11,457 3-1/2" Tubing 9.3 L-80 RTS-8 2.992 Surf 7,651 2 20 13-3/8 3-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 3,632 N/A 9.625 Whipstock 2 7,641 4.150 5.75 Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2 bullet seal assembly 4 9-5/8 @ 3,632 1 BCU 14A (Abandoned) 7 PERFORATION DETAIL Sands Top MD Btm MD Top TVD Btm TVD FT Date Status T2 ±9,715' ±9,749' ±8,792' ±8,825' ±34' Proposed TBD T3 ±9,793' ±9,810' ±8,867' ±8,883' ±17' Proposed TBD T5 ±10,017' ±10,039' ±9,082' ±9,103' ±22' Proposed TBD T7 10,130 10,150 9,192 9,211 20 11/22/2022 Open T7A 10,152 10,172 9,213 9,232 20 11/23/2022 Open T7A ±10,181' ±10,199' ±9,240' ±9,257' ±18' Proposed TBD T7A ±10,216' ±10,231' ±9,273' ±9,288' ±15' Proposed TBD T7B ±10,282' ±10,286' ±9,336' ±9,340' ±4' Proposed TBD T11 ±10,695' ±10,699' ±9,731' ±9,735' ±4' Proposed TBD T13 ±10,852' ±10,864' ±9,881' ±9,893' ±12' Proposed TBD T13 ±10,873' ±10,878' ±9,901' ±9,906' ±5' Proposed TBD T14 ±10,941' ±10,961' ±9,967' ±9,986' ±20' Proposed TBD T14 ±10,977' ±10,990' ±10,002' ±10,015' ±13' Proposed TBD T14 ±10,995' ±10,999' ±10,019' ±10,023' ±4' Proposed TBD T15 ±11,026' ±11,037' ±10,049' ±10,060' ±11' Proposed TBD T16 ±11,108' ±11,119' ±10,129' ±10,140' ±11' Proposed TBD T16 ±11,146' ±11,151' ±10,166' ±10,171' ±5' Proposed TBD T17 ±11,194' ±11,199' ±10,212' ±10,217' ±5' Proposed TBD T17 ±11,212' ±11,217' ±10,230' ±10,235' ±5' Proposed TBD T18 11,290' 11,300' 10,304 10,314 10' 11/21/2022 Open T18 ±11,344' ±11,355' ±10,358' ±10,369' ±11' Proposed TBD T18 T14-T17 T11-T13 T7 T2-T5 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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 Nitrogen vendor 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 Transport. Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/24/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230124 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 11/21/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/17/2022 YELLOW JACKET GPT CLU 10RD 50133205530100 222113 10/26/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/28/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 12/2/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 11/25/2022 YELLOW JACKET PLUG CLU 13 50133206460000 214171 11/29/2023 YELLOW JACKET PERF PBU W-26B 50029219640200 222151 12/30/2022 YELLOW JACKET SCBL SRU 224-10 50133101380100 222124 12/19/2022 YELLOW JACKET GPT SRU 224-10 50133101380100 222124 12/16/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/21/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/29/2022 YELLOW JACKET GPT-PERF Please include current contact information if different from above. By Meredith Guhl at 9:59 am, Jan 24, 2023 T37463 T37464 T37464 T37464 T37464 T37464 T37465 T37466 T37467 T37467 T37467 T37467 BCU 14B 50133205390200 222057 11/21/2022 YELLOW JACKET GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.24 10:05:13 -09'00' F1i1rnrrp A1aAa_ 1.1.{ Date: 01/OS/2023 Kyle Wiseman Hilcorp Alaska, LLC Geo technician 3800 CenterPoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: kyle.wiseman@hilcorp.com To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99SO1 DATA TRANSMITTAL BCU-14B (PTD 222-057) (API 50-133-20539-02-00) Washed and Dried Well Samples (11/2/2022) A Set (5 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) BCU-14B BOX 1 OF 5 3632' - 5160' MD BCU-14B BOX 2 OF 5 5160' - 6660' MD BCU-14B BOX 3 OF 5 6660' - 8460' MD BCU-14B BOX 4 OF 5 8460' - 10170' MD BCU-14B BOX 5 OF 5 10170' - 11460' MD (11459' TD) Total Dry Bag Count: 260 Please include current contact information if different from above. a�'a - (Ds T 193co RECEIVED JAN 0 6 2023 ACGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Recei d►� By;/1 � /�`i� Date: Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 11/27/2022 AK E-LINE GPT Fluid Sample BRU 214-13 50283201870000 222117 11/9/2022 AK E-LINE Perf GPT BRU 214-13 50283201870000 222117 12/2/2022 AK E-LINE Perf BRU 222-34 50283201860000 222039 11/13/2022 AK E-LINE GPT BRU 233-23 50283201360100 222050 11/10/2022 AK E-LINE GPT Plug Perf BRU 244-27 50283201850000 222038 11/13/2022 AK E-LINE GPT Please include current contact information if different from above. By Meredith Guhl at 9:22 am, Dec 29, 2022 T37401 T37402 T37402 T37403 T37404 T37405 BCU 14B 50133205390200 222057 11/27/2022 AK E-LINE GPT Fluid Sample Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.29 09:31:43 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/19/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221219 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU Z-34 50029234690000 212061 12/5/2022 HALLIBURTON WFL-TMD3D PBU W-08A 50029219060100 202090 12/12/2022 HALLIBURTON WFL-TMD3D PBU_L-221 50029233850000 208031 12/13/2022 HALLIBURTON WFL-TMD3D BCU-14B 50133205390200 222057 12/8/2022 HALLIBURTON PPROF BRU 222-34 50283201860000 222039 12/11/2022 HALLIBURTON PPROF PBU 09-41 50029220540000 190074 11/30/2022 READ Multi-Array-Pprof Please include current contact information if different from above. By Meredith Guhl at 1:47 pm, Dec 19, 2022 T37385 T37386 T37387 T37388 T37389 T37390 BCU-14B 50133205390200 222057 12/8/2022 HALLIBURTON PPROF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.19 13:56:07 -09'00' 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): Beaver Creek Unit GL: 141' BF: 141' 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 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 7" P-110 6,987' 3-1/2" L-80 10,467' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 00281 0 12/5/2022 24 Flow Tubing 0 1470 N/A14700 2127' FSL, 1727' FWL, Sec 34, T7N, R10W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 29# 9.2# 7,838' Water-Bbl: PRODUCTION TEST 11/25/2022 Date of Test: Oil-Bbl: Flowing *** Please see attached schematic for perforation detail *** Gas-Oil Ratio: AMOUNT PULLED 317206 317512 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. PACKER SET (MD/TVD) 8-1/2" BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2431849 SETTING DEPTH TVD 2432036 TOP HOLE SIZE CBL 11-5-22, Mudlog, LWD (AGR, PWD, Res, ALD, CTN) N/A 3,632' MD / 3,548' TVD N/A 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 314368 2430071 50-133-20539-02-00October 19, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 11/21/2022 222-057 / 322-642 / 322-606 N/A BCU-14BNovember 1, 2022113' FSL, 1390' FEL, Sec 33, T7N, R10W, SM, AK 159' Tyonek GP & Beluga GP A028083 11,459' MD / 10,470' TVD 11,390' MD / 10,396' TVD 1935' FSL, 1423' FWL, Sec 34, T7N, R10W, SM, AK 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 6" L - 145 sx / T - 490 sx 6,796' 570 sx Surface 3-1/2" SIZE DEPTH SET (MD) 7,636' MD / 6,796' TVD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 7,636' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7,651' 11,457' WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment RECEIVED BY JAMES BROOKS ON 12/9/2022 3:16 pm Completed 11/21/2022 JSB RBDMS JSB 122322 G DSR-1/3/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval T7 10,130' 9,191' 3,864' 3,731' 4,556' 4,282' 5,285' 4,854' 6,423' 5,745' 6,490' 5,799' 7,202' 6,387' 8,318' 7,451' 9,524' 8,609' 9,687' 8,765' 9,904' 8,973' 10,104' 9,166' 11,223' 10,179' 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 Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 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: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. T2 Sterling A Sterling D7 Beluga Tyonek Sterling C Sterling B Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. INSTRUCTIONS T 18 Mid Beluga Lower Beluga T5 T7 T18 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 12.15.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.12.15 09:59:31 -09'00' Monty M Myers Updated by CAH 11-26-22 Schematic Beaver Creek Unit BCU-14B PTD: 222-057 API: 50-133-20539-02-00 PBTD = 11,390’ MD / 10,396’ TVD TD = 11,459’ MD / 10,462’ TVD RKB to GL = 16.0’ 3-1/8” Otis PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Tyonek T7 10,130’ 10,150’ 9,192’ 9,211’ 20’ 11/22/22 Open Tyonek T7A 10,152’ 10,172’ 9,213’ 9,232’ 20’ 11/23/22 Open Tyonek T18 11,290' 11,300' 10,304’ 10,314’ 10' 11/21/22 Open CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 133 K-55 Weld 18.73” Surf 145’ 13-3/8" Surf Csg 68.0 K-55 BTC 12.415” Surf 2,122’ 9-5/8” Intermediate Csg 40.0 L-80 BTC 8.835” Surf 3,632’ TOW 7” Intermediate Csg 2 26 L-80 Multiple 6.276” Surf 7,838’ 3-1/2" Prod Csg 9.2 L-80 Hyd 533 2.992” 7,641’ 11,457’ 3-1/2" Tubing 9.3 L-80 RTS-8 2.992” Surf 7,651’ 2 20” 13-3/8” 3-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 3,632’ N/A 9.625” Whipstock 2 7,641’ 4.150” 5.75” Flex-Lock V Liner Hanger HRD-E ZXP Liner top packer w/ 5-1/2” bullet seal assembly CEMENT DETAIL 13-3/8” TOC @ Surface (Original BCU 14) 9-5/8" TOC @ Surface (Original BCU 14) 7” 3,596’ MD TOC CBL 11/6/22 3-1/2” 7,636’ MD TOC CBL 11/6/22 4 9-5/8” @ 3,632’ 1 BCU 14A (Abandoned) 7” Activity Date Ops Summary 10/13/2022 Remove windwalls from pits, scope down derrick, wrap up TD HPU hoses, Cover flanges on all BOPE, Lay over and remove MGS, Continue rigging down pits, Continue pressure washing throughout entire rig. Scope derrick down, Remove centrifuge from pits, lay over MGS and remove from footprint. Continue;disconnecting all modules in preparation for move. Continue moving equipment to Beaver Creek.;Remove BOPE stack from cellar and place on trailer for transport to BC-14B. Continue welding on pipe skate, Hang blocks, Unspool drilling line from draworks, Cut 84' of drilling line (18 wraps), Tie lines up in derrick, P/U service loop and hang off, Hang off drilling line. Continue pressure washing;Throughout entire rig, PJSM, lay over derrick, continue scrubbing and pressure washing in and around mud pits, pumps and derrick.;Lay felt and liner over well. Pressure wash derrick, clean and organize all buildings, Remove pins from derrick cylinders, Lower pit roofs, Cont. to blowdown and disconnect lines. Disconnect drive line and break handle;Set rig mats on well, Finish lowering pit roofs and securing lines, hoses, and electrical. Perform derrick inspection, Remove light from buildings and lower hand rails. R/D Pason and comms cables 10/14/2022 Remove choke house, Iron roughneck and V-Door wind wall with crane while bed trucks tear down backyard and position MP#1 , Mud Tanks 1 and 2 on side of location for next trip, Take Boiler, Generator skids, MP #2 skid to Beaver Creek. Come back and grab MP #1, Electrical;shop. Crane lays down derrick board windwalls. Both cranes connect to Mast and remove it from draworks skid and place on trailer, tie down and disconnect cranes, load drilling line spool on trailer and secure, transport to Beaver Creek.;Connect cranes to draworks skid, remove from subbase and set on containment and tail roll on trailer and leave location. Connect cranes to subbase and lift off of pony subs, tail roll mechanic shop and remove from location, tail roll mud tank 2 and remove from location, Cranes set subbase on drop;deck trailer, secure and take to Beaver Creek. Pick and set pony subs on trailer, secure and take to Beaver Creek. Mobe Cranes to Beaver Creek to assemble rig over well BCU-14B.;Spot pony subs over well, crane in sub base, draw works skid, derrick. Prep tp raise derrick, spot and raise dog house, Raise derrick, Spot top drive HPU, mud tanks 1-3, Mud pumps 1 and 2, boiler house. Raise roofs on mud tanks, Install stairs and hand rails, R/U electrical cables;Power up generators, R/U mud pump high pressure lines. Pick up rig mats, liner and felt on CLU 10 well, clean up location CCI rig mover released @ 2100hrs;Complete R/U of pits and mud pumps, Spot Generator #3, Spool line on draw works and prep to raise derrick. R/U Pason system and all electrical lines. Lay out liner for Catwalk 10/15/2022 Prep to scope up derrick, perform derrick inspection, Spot and R/U choke house, Scope up derrick, prep to P/U top drive. Install wind walls on mud pits, install iron roughneck. 24hr notice for BOP test given to AOGCC @ 8:04.;Cont R/U pit system and electrical lines. Install handy berm around rig. Tie back bridal lines. R/U and P/U top drive. Hook up hyd. lines to top drive and shin top drive extend frame. Lay liner for gas buster and R/U same. Update given to BLM and AOGCC @ 15:09.;Check Nitrogen pre-charge in Koomey bottles filling as needed. Change gear oil on top drive gear box/swivel, Install saver sub, bails and M/U kelly hose on top drive. Fill boilers with water, R/U rig tongs and handling equipment/Subs.;AOGCC (Jim Regg) waived witness @ 19:29.;Remove single gate from stack and install DSA, Remove tree and install test dart, N/U BOP's and tight flanges. R/U kill and choke lines Bring boiler to full pressure and circulate steam thru rig. Install lines going to gas buster. 10/16/2022 Rig accepted @ 06:00. Install tarps and turn steam on to all heaters throughout rig, Install accumulator Lines. Function test blind rams, Choke and Kill HCRs. M/U 2-7/8" test joint and install, Function test Annular and VBRs. Good function test. Shell test T/ 3000psi. good test.;Test BOPE 250/ 3000psi 5/10as per BLM and AOGCC regulations with BLM representative Quinn Sawyer witnessing test.;R/D testing equipment, Blow down choke and kill lines, Line up well control equipment, break down test joint, Pull blanking plug from hanger as per wellhead representative, Clean and clear rig floor.;Wellhead Tech Pull BPV with dry rod. R/U parker casing equipment. M/U landing jt and screw into hanger, BOLDS and pull hanger to floor. P/U 40K S/O 38K. L/D landing jt and hanger.;POOH 2 7/8" EUE tubing F/~ 3700' to surface, L/D 117 jts and 7' cut jt.;R/D casing equipment and clear rig floor.;Set BPV, bleed down accumulator, Remove Koomey lines , Remove choke and kill hoses, remove BOP from well, Install single gate on BOP's . Remove DSA and tubing head from well head. N/U BOP's . 10/17/2022 Continue assembling flow box assembly, Test run 5-1/2" test joint, open LPR door and mark pipe for hole, POOH and take to shop and drill hole in joint. Start building 300 BBLs KCL mud, Function test new top drive hpu pump, Replace air compressor motor.;Wellhead tech Install TWC with dry rod, Install 5-1/2" test joint, Close LPR with 5-1/2" fixed rams and purge system with water and test 250psi for 5 minutes and 3000psi for 10 minutes, Good test. Pull 5-1/2" test joint and install 4-1/2" test joint close UPR 2-7/8" x 5" VBRs purge system and test.;VBRs, Mezz kill valve, CV 1, 2, and 3 to 250/ 3000 psi for 5/ 10 minutes testing all components that were broke for the re-install F/ the 7-1/16" head T/ 11" head. Good test.;R/D test equipment, Blow down choke and kill lines, L/D test joint, Clear and clean rig floor.;PJSM, R/U E-Line and RIH with jet cutter and CCL. RIH and tag 2-7/8" tubing stub at 3711' WLM, Locate 5-1/2" coupling at 3689' and jet cut 5-1/2" liner at 3700' WLM. POOH and R/D E-Line equipment.;R/U casers and equipment to pull 5-1/2" liner. P/U landing joint and pull pack-off as per wellhead tech, Pull hanger to floor with 150K to unseat hanger and 100K P/U guiding hanger through bope stack.;R/U and circulate well clean with 400 GPM and SPP of 550psi. Flow check well: Static, Blow down top drive, P/U 80K, S/O 80K.;POOH laying down 5 1/2" casing from 3700' to surface (89 jts, 10'cut jt.) recovered 5 bow spring and 17 solid centralizers.;R/D casing equipment, clean and clear rig floor, Change out bell nipple on stack.;M/U running tool and set 9" ID wear bushing.;Load BHA on rig floor, strap and tally DP.;M/U scraper BHA.;TIH picking up DP with Scraper BHA F/ surface T/3704' - worked thru tight spots from 3650 ' to 3704'. P/U 77K, S/O 72K.;CBU 400gpm@ 390 psi. 10/18/2022 Flowcheck well, Static POOH with 9-5/8" scraper assembly F/ 3704' T/ 40' P/U 77K, S/O 72K.;Iron Rough Neck Ram Leaking, Change ram.;Service rig and top drive, grease crown and draw works.;RIH P/U 4.5'' DP f/ 40' t/ 2544' POOH standing Back DP in Derrick t/ Surface, P/U 18 jts of HWDP and Rack back in the derrick.;Spot in yellow Jacket Eline truck and rig up, RIH w/ CIBP t/ 3704' set down log up find collar @ 3668' set CIBP @ 3663' WLM POOH R/D Eline.;R/U and Test Casing t/ 3000 psi f/ 10 min 3.3 bbls pumped 2.8 bbls bled back.;Pull wear ring and set test plug. Open LPR's and change rams to 7". Measure test jt. X/O and check clearance on rams. X/O to long for ram closure.;Service top drive, blocks crown, draw works, and iron roughneck.;Wait on new test jt. - perform derrick inspection, clean choke house, Prep whipstock BHA.;R/U 7" test jt. and equipment. Pressure test to 3000 high/ 250 low. Test failed. Fluid leaking out of Mud seal weep hole.;Change out mud seals on LPR.;R/U 7" test jt and test equipment. Pressure test LPR to 250psi/5 min and 3000psi /10 min. R/D test equipment. pull test plug and set wear bushing.;PJSM, P/U and M/U whipstock BHA. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: BCU-014B Beaver Creek Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00074 BCU-14B Drilling Spud Date: 10/19/2022 M/U Whipstock BHA as per DD/MWD and WIS rep Shallow test MWD, M/U Slide RIH t/ 3630'.;Displace well w/ 6 % KCL Polymer mud system Orient slide 30 right of High side.;Set down on CIBP trip anchor, Shear bolt w/ 29k down weight TOW 3632' BOW 3646' Mill window and 20' of new hole to 3667'. Top of window @ 3632', bottom of window @ 3647' 400 gpm 80 rpm 3-5k WOB 880 psi, P/U 87K, S/O 85K. 204lbs total metal recovered.;Circulate and condition while working thru window multiple times (2xCBU). Shut down pumps and rotation and work thru window with no drag. MW in 9.0, MW out 9.0.;R/U and perform FIT - 9.0 ppg mud. TVD - 3576', test pressure 580 psi. EMW = 12.1. Volume pumped 27.4 gal, Volume returned 23.5 gal. R.D test equipment and blow down choke/kill/ top drive. flow check well - static.;POOH F/ 3667 T/ surface. L/D BHA. upper mill 1/16", mid mid 1/8", lower mill 1/8" under gauge.;Clean and clear rig floor, flush Stack and prep drilling BHA.;Grease and check oils on rig equipment, clean suction screens on mud pumps.;P/U drilling BHA and trip in hole T/1500'.;Hauled: 1 bbl Solids to KGF G&I Cumulative: 27 bbl Hauled: 374 bbl Fluid to KGF G&I Cumulative: 608 bbl 10/20/2022 RIH f/ 1500' t/ 3623' fill pipe, orient to high side slide through window, tag bottom @ 3667' no fill.;Drill Ahead f/ 3667' t/ 3879' 488 gpm 1441 psi SPP 50 RPM 5k tq on bottom 3k WOB 92k PUW 85k SOW 87k ROT.;CBU obtain survey and SPR's, Flow check, blow down top drive.;POOH f/ 3877' t/ 114' flow check well static.;Change out drilling BHA L/D TM M/U ADL and CTN and TM Upload MWD and Shallow Test, Load Sources, RIH w/ remaining BHA out of the derrick t/ 730'.;RIH P/U 4.5'' DP from rack 40 jts continue RIH out of the derrick T/3746' filling pipe every 2000'. No issues thru window.;Wash down F/ 3746' T/ 3877' 460 GPM, SPP 1200, RPM 20, TQ - 5.3k.;Drill ahead F/3879' T/ 3988' P/U - 97K. S/O - 85K, ROT - 91K, GPM 490, SPP 1400, RPM - 50, TQ - 5K, WOB- 4K. SPR's= MP#1 46 SPM, 221psi / MP#2 46 SPM / 215psi.;Drill ahead F/3988' T/ 4392' P/U - 92K. S/O - 85K, ROT - 93K, GPM 490, SPP 1440, RPM - 55, TQ - 5.5K, WOB- 4K.;Hauled: 4 bbl Solids to KGF G&I Cumulative: 31 bbl Hauled: 76 bbl Fluid to KGF G&I Cumulative: 684 bbl Daily Metal: 20 lbs Cumulative: 224 lbs 10/21/2022 Continue Drilling Ahead 8 1/2'' Hole Section f/ 4392' t/ 4855' 490 gpm 1450 psi 70 rpm 6.3k tq on bottom 3k WOB 110k PUW 90k SOW 100k ROT Max gas 20 units.;Continue Drilling Ahead 8 1/2'' Hole Section f/ 4855' t/ 5042' 500 gpm 1620 psi 70 rpm 7k tq on bottom 4k WOB 118k PUW 94k SOW 105k ROT Max gas 23 units Distance to plan 4.72' 1.61' High 4.44' Right.;Circulate bottoms up 500 gpm 1510 psi Obtain SPR's and Survey Flow check well static.;POOH f/ 5042' t/ 3985' with no hole issues observed.;Service rig and top drive, grease crown and draw works, iron rough neck and break linkage.;RIH f/ 3985' t/ 5042' wash last stand to bottom no fill or hole issues.;Continue Drilling Ahead 8 1/2'' Hole Section f/ 5042' t/5599'. P/U 127K. S/O 96K, ROT 108K, SSP 1680, GPM 480, RPM 70, TQ 7.9K, WOB 5K. Pumped hi-vis sweep @ 5042' - back on time w/ 50% increase in cuttings.;Continue Drilling Ahead 8 1/2'' Hole Section f/ 5042' t/6029'. P/U 140K. S/O 108K, ROT 118K, SSP 11775, GPM 480, RPM 70, TQ 8.3K, WOB 4K.;Hauled: 104 bbl Solids to KGF G&I Cumulative: 135 bbl Hauled: 216 bbl Fluid to KGF G&I Cumulative: 900 bbl Daily Metal: 4 lbs Cumulative: 228 lbs 10/22/2022 Drill Ahead 8 1/2'' Hole Section F/ 6029' t/ 6523' 480 gpm 1970 psi 70 rpm 10 ktq on bottom 155k PUW 100k SOW117k ROT Max Gas 694.;CBU, obtain survey and SPR's, Flow check well slight loss.;POOH f/ 6523' t/ 5040' No hole Issues.;Service rig grease top drive and blocks, crown and drawworks.;RIH f/ 5040' t/ 6523' Set down 6412' work through tight spot with rotary and pump Wash to bottom.;Drill Ahead 8 1/2'' Hole Section f/ 6523' t/7015', P/U 160k, S/O 108k, ROT 124k, SPP 2090, GPM 480,l RPM 70, TQ 10.1, WOB 7K. Pumped sweep @ 6523' - returned on time with 25% increase in cuttings.;Drill Ahead 8 1/2'' Hole Section f/ 7015' t/ 7230', P/U 1170k, S/O 113k, ROT 130k, SPP 2150, GPM 480,l RPM 70, TQ 10.7, WOB 7K.;Hauled: 128 bbl Solids to KGF G&I Cumulative: 263 bbl Hauled: 192 bbl Fluid to KGF G&I Cumulative: 1092 bbl Daily Metal: 3 lbs Cumulative: 331 lbs 10/23/2022 Continue Drilling Ahead 8 1/2'' Hole Section f/ 7230' t/ 7572' 480 gpm 2250 psi 70 rpm 12.7k torque on bottom, MW 9.3 ppg ECD 9.78 ppg, 180k PUW 110k SOW 135k ROT, Max Gas 230 Units;Continue Drilling Ahead 8 1/2'' Hole Section f/ 7572' t/ 7858' 480 gpm 2250 psi 70 rpm 11.8k torque on bottom, MW 9.3 ppg ECD 9.82 ppg, 185k PUW 115k SOW 137k ROT, Max Gas 255 Units;Circulate bottoms up 480 gpm 2123 psi, Obtain survey and SPR's, Flow check Well slight loss dropped 10'' in riser in 10 min;POOH f/ 7858' t/ 7123'. multiple tight spot with 25K overpulls, Ream from 7123' to 6465' with consistent TD stalls and overpulls (SPP-2079, GPM 480, RPM 30 -70, TQ - 8-17K, ROT 118K, S/O 95K, P/U 150K;Ream from 6465'' to 6280' with consistent TD stalls and overpulls. Varied RPM, pump rates. No increase in diff psi or pack-offs. Worked pipe free in multiple spots using jars.;Hauled: 104 bbl Solids to KGF G&I Cumulative: 367 bbl Hauled: 216 bbl Fluid to KGF G&I Cumulative: 1308 bbl Daily Metal: 0 lbs Cumulative: 331 lbs 10/24/2022 BROOH f/ 6280' Stalling rotary if over 1-4 ft per min, continue work out of the hole t/ 6141' pump lube pill around background torque dropped off still unable to pull, 6080' acted like obstruction disappeared able to pull without pumps or rotary, Trip out of the hole t/ 2940' 5k drag at window.;POOH f/ 2940' t/ 107' stand back BHA, L/D sources, download MWD, L/D remaining BHA Bit graded 1-2 in gauge, no scaring on bit or BHA.;Clean and clear floor L/D BHA components.;M/U Clean out BHA as per DD RIH t/683'.;Slip and cut 86' of drill line.;Cont to TIH F/ 683' T/ 7858' ( set dn 25 K @ 6665' washed and reamed to 6697'). Tagged fill @ 7838' washed and reamed to bottom.;Pump hi-vis sweep and condition hole. Sweep back on time w/ 20% in cuttings. SPP 1900, GPM 520, RPM 70, TQ 7k.;POOH F 7858' T/ 3329 with no issues.;Hauled: 8 bbl Solids to KGF G&I Cumulative: 375 bbl Hauled: 72 bbl Fluid to KGF G&I Cumulative: 1380 bbl Daily Metal: 2 lbs Cumulative: 233 lbs 10/25/2022 Continue POOH f/ 3328' t/ Surface, L/D Jars and Flex Collars, L/D stab and bit sub, break bit.;Pull wear ring, R/D flow line, R/D flow box and riser remove air boot assembly f/ top of annular, Install spilt riser and flow line. hook up hole fill and center and chain stack.;Service rig and top drive.;R/U casing equipment, P/U and M/U shoe track and check floats.;Cont. RIH w/ 7" 29# P-110 LTC casing F/161-T/3622' (TOW).;Circ. 1.5 BU. GPM-111 SPP-628 psi Flow 14% MW-9.35 ppg. Gave HES cmt's 4 hr. notice.;Resumed RIH w/ 7" casing F/3622'-T/5140'. Casing displacement- Cal= 45.6 bbls Act= 36.0 bbls Diff= -9.6 bbls P/U-150K S/O-117K.;Crew change, held PTSM. Cont. RIH w/ 7" casing F/5140-T/5735'.;CBU- P/U-165K S/O-125K GPM-213 SPP-315 psi Flow-21% Max gas 18 units. Blew down TDS.;Resumed RIH w/ 7" casing F/5735' to current depth of 7091' at 30 fpm.;Hauled: 8 bbl Solids to KGF G&I Cumulative: 383 bbl Hauled: 72 bbl Fluid to KGF G&I Cumulative: 1482 bbl Daily Metal: 0 lbs Cumulative: 233 lbs 10/26/2022 Continue RIH w/ 7'' 29# LTC casing f/ 7091' t/ 7842' Tag fill, M/U circ head, wash down f/ 7842' t/ 7852' Stage pumps t/ 230 gpm 840 psi, reciprocate string, M/U buddy bails and spot in cementers and R/U, thaw and load cement head with plugs, Spot 90 bbls Inhibited 9.3 ppg Brine in pipe.;R/U cement head and lines to Halliburton, string out mud hose from pits.;PJSM, Fill Lines with water cement head leaked on collar shut down and tighten, pump 5 bbls water, PT lines 500/4500 psi, drop bottom plug, pump 30 bbls 10.5 ppg spacer, 60 bbls 145 sx 12 ppg lead @ 4 bpm 390 psi, pump 105 bbls 490 sx 15.3 ppg tail cement @ 4 bpm 170 psi, drop top plug, pump;10 bbls water, followed by 278.7 bbls mud, slowed pumps t/ 2 bpm t/ bump, bumped plugs @ 1000 psi pressured up t/ 1800 psi and held f/ 5 min, bleed off and check floats held bled back 1.5 bbls, CIP 14:55 R/D and wash up cementers, released cementers, flow check well static.;Drain stack, open lower ram doors, remove 7'' rams and close doors, remove split riser and flow line, N/D choke and kill lines, unchain stack. N/D stack from well head, P/U BOP stack 1.5' w/ BOP hoist cylinder lines. Pulled 7' casing in tension (140K) installed & set E-slips.;Cut off 7" casing stick up and L/D same (18.46' of cut off). Handed off BOP's to bridge canes, tailed out of the way of well head. N/U B section to well head while N/D rig 169's single gate from BOP's stack and N/U rig 147's single gate. Tested B section void T/4000 psi for 15 min (Good test).;Crew change, held PTSM. N/U BOP's to B section. Installed bell nipple/flow riser, catch can, and flow line. Installed VBR's in LPR. Ran in test plug on 4.5" test jt. Confirmed rams wouldn't make contact on 4.5" and 3.5" up set on test jt. connection. Finished hooking up remainder of koomey lines.;Energized koomey. Flooded stack w/ water. Actuated rams and HCR's to purge out air. Service centrifuge and shaker bed (changed out rubber).;Currently performing shell test T/5000 psi and checking for leaks.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 383 bbl Hauled: 230 bbl Fluid to KGF G&I Cumulative: 1712 bbl Daily Metal: 0 lbs Cumulative: 233 lbs 10/27/2022 Attempt Shell test of BOP's fix multiple leaks, continue chasing leaks.;Test BOP's w/ 4.5'' Test jt t/ 250 low f/ 5 min 5000 High f/ 10 min, State and BLM Waived witness, FP on Inside Kill Manual, FP on HCR Choke, FP on LPR Bonnet Seals, Repair Bonnet Seal and 2 1/16'' Valve and resume testing. Finished tests w/ 4.5" test jt. w/ other issues.;Pulled 4.5" test jt. & plug and L/D same. Drained stack, P/U and ran in 3.5" test jts & plug. Flooded stack, purged out air. Tested 3.5" on annular and UPR w/ no issues. Functioned tested LPR on 3.5" test jt. Found weep hole on HYD side of rams leaking (ODS). Changed out ram shaft seal and finish;up BOP test on LPR (ok). Pulled 3.5" test jt. & plug and L/D same. Quadco came out and bump tested gas alarm system (ok).;Crew change, held PTSM. R/U testing equip. to test 7" casing. Purged air out of system. Performed casing test T/4800 psi on chart for 30 min (good test). Pumped in 4.5 bbls Bled back 3.7 bbls.;R/D testing equip, blew down choke manifold, mud cross, mud gas separator, and mud lines. Installed short mouse hole. Drained stack, installed 9" wear ring, RILD's, closed annulus valve. Greased choke manifold & mud cross. Obtained RKB's.;Serviced rig- Greased crown, blocks, TD, DWKS, brake linkage, drive shaft, and IR. Checked pulsation dampeners on MP's. Checked gap on weight indicator.;P/U 6" directional BHA #6. 5 bladed PDC bit, 1.5 mud motor w/ 166.44 off set. M/U MWD tools. Currently uploaded data to MWD tools.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 383 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 1712 bbl Daily Metal: 0 lbs Cumulative: 233 lbs 10/28/2022 Upload MWD, Shallow test tools 220 gpm 1250 psi, Load Sources, Continue RIH w/ BHA f/ Derrick, RIH P/U 110 Jts of DP f/ Racks t/ 4185' filling pipe every 2000'.;RIH out of the derrick F/4185'-T/7576'.;Slip & cut drill line and adjusted brake handle height. Cut 9 wrap for a total of 44'.;Cont. RIH F/7576'- T/7704'.;Washed & reamed F/7704'-T/7750'. Tagged cmt @ 7750'. Drilled cmt F/7750'-T/7754', started seeing black rubber from top plug back at the shakers @ 7754'. P/U-185K S/O-105K ROT-125K GPM-205 SPP-1670 psi RPM-30 WOB-1/2K Diff-12/15 psi MW-9.35 ppg ECD-10.8 ppg.;Noticed fluid come from gear box bleeder on TD. Call rig superintendent, decision was made to change out HYD Rineer motor. CBU, flow checked well, racked back 5 stds. Changed out Rineer motor on TD w/ same. while monitoring well on TT.;Crew change, held PTSM. Finished changing over Rineer motor on TD. Function tested motor (ok). Static loss rate= 0.;RIH on elevators F/7451'-T/7704'. M/U TD, washed down to 7754'. P/U-175K S/O-100K ROT-125K GPM-212 SPP-1760 psi RPM-30 MW- 9.35 ppg ECD-10.8 ppg.;Resumed drilling up plugs, shoe track, and 20' of new formation F/7754'. Current depth of 7865'. P/U-185K S/O-105K ROT-125K GPM- 202 SPP-1795 psi RPM-54 TQ-11.6K WOB-5.3K Diff-166 psi MW-9.4 ppg ECD-10.8 ppg.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 383 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 1712 bbl Daily Metal: 0 lbs Cumulative: 233 lbs 10/29/2022 Drill Float equipment and rathole drill 20' of new hole t/ 7878' 200 gpm 1710 psi 50 rpm 12.5 k tq 6 k WOB, 175k PUW 100k SOW 120k ROT, CBU.;R/U and perform FIT t/ 13.09 ppg EMW pressure up t/ 1362 psi, TVD 6999' Blow down R/D test equipment 1.5 bbls pumped in 1.4 bbls returned.;Drill Ahead 6'' Production section f/ 7878' t/ 8075' 280 gpm 2940 psi, 70 rpm 12.5k, 8k WOB, 182k PUW 100k SOW, 125k ROT, Distance to plan 11.18' 1.79' Low 11.041' Left.;Drill Ahead 6'' Production section f/ 8075' t/ 8568' 280 gpm 2800 psi, 60 rpm 11.5k, 8k WOB, 182k PUW 100k SOW, 125k ROT.;Cont. directional drilling 6" Production section F/8568'-T/8942'. P/U-200K S/O-100K ROT-130K GPM-275 SPP-3050 psi RPM-60 TQ-12.9K WOB-8K Diff-350 psi ROP-120 MW-10.0 ppg Max gas- 381 units @ 8699' ECD-12.31 ppg.;Crew change, held PTSM. Cont. directional drilling 6" Production section F/8942'-T/9004'. P/U-200K S/O-100K ROT-130K GPM-277 SPP-3006 psi RPM-80 TQ-12.6K WOB-5K Diff-175 psi ROP-99 MW-10.0 ppg Max gas- 293 units @ 8985' ECD-12.57 ppg.;Circ. till shakers cleaned up. GPM-277 SPP-2816 psi RPM-80 TQ-12.5K. Shot on bottom survey. Obtained new SPR's. Flow checked well (static).;POOH on elevators F/9004'-T/7847' w/ no issues, had 5-10K drag during the trip. P/U-210K S/O-105K Had calculated hole fill during the trip.;Service rig while monitoring well on TT. Greased crown, blocks, TD, DWKS, brake linkage, drive shaft, and IR. Cleaned suction screen on MP's. Checked pulsation dampeners and gap on weight indicator (good).;RIH on elevators F/7884' w/ no issues, washed last std down, had 5' of fill on bottom.;CBU GPM-271 SPP-2674 psi RPM-82 TQ-12.9K MW- 10.15 ppg ECD-12.02 ppg Max gas 60 units.;Cont. directional drilling 6" Production section F/9004' to current depth of 9020'. . P/U-210K S/O-105K ROT-130K GPM-283 SPP-2876 psi RPM-80 TQ-13K WOB-6.7K Diff-200psi MW-10.15 ppg Max gas- 60 units ECD-12.5 ppg Distance to well plan: 12.43' 10.69' Low 6.35' Left.;Hauled: 96 bbl Solids to KGF G&I Cumulative: 479 bbl Hauled: 144 bbl Fluid to KGF G&I Cumulative: 1856 bbl Daily Metal: 0 lbs Cumulative: 233 lbs 10/30/2022 Drill Ahead 6'' Hole Section f/ 9020' t/ 9330' 266 gpm 3090 psi 70 rpm 13.5k tq on botom, 190k PUW 102k SOW 133k Rot WOB 6k Sweep back on time 10% increase in cuttings.;Cont. directional drilling 6" Production section F/9330'-T/9680'. P/U-195K S/O-120K ROT-140K GPM-260 SPP-2950 psi RPM-70 TQ-12.8K WOB-6K Diff-250 psi ROP-100 MW-10.4 ppg Max gas- 329 units @ 9678' ECD-12.8 ppg.;Cont. directional drilling 6" Production section F/9680'-T/9927'. P/U- 200K S/O-120K ROT-142K GPM-260 SPP-2950 psi RPM-70 TQ-13.2K WOB-6K Diff-250 psi ROP-100 MW-10.45 ppg Max gas- 448 units @ 9926' ECD-12.89 ppg.;Crew change, held PTSM and weekly safety meeting w/ rig crew. Cont. directional drilling 6" Production section F/9927'-T/10133'. P/U-195K S/O-120K ROT- 145K GPM-260 SPP-2930 psi RPM-73 TQ-13K WOB-6K Diff-170 psi ROP-100 MW-10.4 ppg Max gas- 416 units @ 10,131' ECD-12.52 ppg.;Distance to well plan: 4.52' 4.41' Low .98' Right.;Hauled: 64 bbl Solids to KGF G&I Cumulative: 543 bbl Hauled: 96 bbl Fluid to KGF G&I Cumulative: 1952 bbl Daily Metal: 2 lbs Cumulative: 235 lbs 10/31/2022 Drill 6'' Hole Section f/ 10,133' t/ 10,172' 260 gpm 2950 psi 70 rpm 14.5k tq on bottom 5-8k WOB Gas 420 units 195k PUW 120k SOW 145k Rot.;Circulate hole clean, Obtain survey and SPR's, Flow check well static.;POOH f./ 10,172' t/ 9488' unable to pull through, M/U top drive and back ream through tight spot, Continue POOH w/ pumps t/ 9147'.;Service rig and top drive, grease blocks and crown, clean m,ud pump screens, electrician worked on service loop wires f/ float switch, mechanic changed sensor on intake on floor motor.;RIH f/ 9174' t/ 10,172' no issues 20' of fill on bottom wash to bottom, pump Hi Vis sweep around.;Drill Ahead f/ 10,172' t/ 10,356' 271 gpm 3079 psi 70 rpm 12.1k tq on bottom 5-7k WOB 12.63 ppg ECD MW 10.4ppg.;Cont. directional drilling 6" Production section F/10,356'-T/10,614'. P/U-190K S/O-125K ROT-155K GPM-270 SPP-3129 psi RPM-70 TQ-12.5K WOB-5K Diff-250 psi ROP-90 MW-10.35 ppg Max gas- 424 units @ 10,541' ECD-12.64 ppg.;Crew change, held PTSM. Cont. directional drilling 6" Production section F/10,614'-T/10,782'. P/U-195K S/O- 125K ROT-155K GPM-247 SPP-2875 psi RPM-70 TQ-13K WOB-10K Diff-250 psi ROP-70 MW-10.4 ppg Max gas- 91 units @ 10,641' ECD-12.33 ppg.;Distance to well plan: 3.79' 2.02' High 3.20' Right.;Hauled: 96 bbl Solids to KGF G&I Cumulative: 639 bbl Hauled: 144 bbl Fluid to KGF G&I Cumulative: 2096 bbl Daily Metal: 0 lbs Cumulative: 235 lbs 11/1/2022 Continue Drilling 6'' Production Hole Section F/ 10,784' T/ 10,976' GPM 248, SPP 2720 psi, Diff 370psi, RPM 70, TQ 13.8K, WOB 10K, ECD 12.62, Max Gas 500 units, P/U 202K, S/O 130K, ROT 159K.;Continue Drilling 6'' Production Hole Section F/ 10,976' T/ 11,156' GPM 236, SPP 2842 psi, Diff 200psi, RPM 70, TQ 14.5K, WOB 10K, ECD 12.34, Max Gas 101 units, P/U 200K, S/O 135K, ROT 160K. Pump Hi-Vis sweep @ 11,112' with 10% increase of cuttings.;Cont. directional drilling 6" Production section F/11,156'-T/11,287'. P/U-200K S/O-135K ROT-160K GPM-236 SPP-3023 psi RPM-70 TQ-12.7K WOB-10K Diff-300 psi ROP-25/50 MW-10.45 ppg Max gas- 359 units @ 11,193' ECD-12.34 ppg.;At 11,223' had issues pumping up survey. Attempted multiple time w/ both MP's w/ no luck. Discussed issue w/ drilling engineer. Decision was made to drill ahead. Attempted again to obtain survey after drilling next std down (good survey).;Crew change, held PTSM. Cont. directional drilling 6" Production section F/11,287' to purposed TD of 11,459'. P/U-205K S/O-137K ROT-165K GPM-244 SPP-2681 psi RPM-70 TQ-15.5K WOB-6K Diff-170 psi ROP-40 MW-10.55 ppg Max gas- 118 units @ 11,316' ECD-12.34 ppg.;Currently CBU. GPM-244 SPP-2712 RPM- 70 TQ-15.5K Distance to well plan: 12.89' 12.88' Low .49' Right.;Hauled: 96 bbl Solids to KGF G&I Cumulative: 735 bbl Hauled: 144 bbl Fluid to KGF G&I Cumulative: 2240 bbl Daily Metal: 8 lbs Cumulative: 243 lbs 11/2/2022 CBU GPM 262, SPP 2890psi. while rotating and reciprocating pipe. RPM 75, TQ 12.6K, ECD 12.34ppg, Max Gas 97 units, Survey, SPRs @ 11,459' MD, 10,470' TVD. MW 10.5ppg, MP #1 46 SPM 910psi., MP #2 46 SPM 907psi. B/D Top Drive. Flow check well: Static. Sent BLM Notification for cementing liner.;POOH on elevators F/ 11,469' T/ Tight spot @ 10,776'. M/U Top Drive and pump through tight spot at coal seam and continue POOH on elevators F/ 10,776' MD T/ 10,100' MD. P/U 225K, S/O 133K. Calculated disp. 8.14 BBLs, Act Disp. 9.6 BBLs, Difference of 1.46 BBLs.;Grease Crown, Blocks, Top Drive, Draworks, Brake Linkage, Drive Shaft, Iron Roughneck. Pulsation dampeners MP #1 600psi, MP #2 600psi. Calibrate weight indicator.;RIH F/ 10,100' T/ 11,459' Wash and ream F/ 11,079' T/ 11,459' through 17' of fill. P/U 225K, S/O 135K, ROT 165K. Max Gas 800 units. Received response from BLM representative Quinn Sawyer and wants to witness Cementing of Liner.;Pump Hi-Vis sweep @ 11,459'. Reciprocate and circulate out of hole. Sweep came back on time with no increase in cuttings. Flow check well: Static.;POOH on elevators F/ 11,459' T/ 7,766' P/U 250K, S/O 125K, ROT 165K, GPM 245, SPP 2779psi, TQ 15K, ECD 12.59ppg. Dropped hollow 2.375" drift with slickline connected at 9311' MD.;Finish building 13.0 ppg dry job and pump. Sent 48 hour notice for MIT testing to BLM.;POOH on elevators F/7766'-T/989'.;Cont. POOH F/989' L/D 8 jts of DS-40 DP, HWDP, jar std, and flex collars T/124'.;Held PJSM on removing sources, removed sources. Down loaded MWD data. L/D MWD tools. Bit graded 1-1 engage. Off line gave Parker casing crew & BOT hand 2 hr. notice.;Serviced rig- Greased TD, blocks, DWKS, IR, brake linkage, drive shaft, and crown. Performed weekly BOP function of rams. Monitored well on TT (static).;R/U Parker liner handling equip. Loaded racks w/ shoe track & 3.5" liner tubulars. R/U liner fill up line. Held PJSM w/ Parker liner hand on running liner.;M/U shoe track w/ BakerLok, M/U IBT-M x CDS-40, pumped through shoe track to check floats (ok). Cont. RIH w/ 3.5" L-80 9.2# IBT-M liner as per run tally. Current depth of 599'.;Hauled: 32 bbl Solids to KGF G&I Cumulative: 767 bbl Hauled: 48 bbl Fluid to KGF G&I Cumulative: 2288 bbl Daily Metal: 0 lbs Cumulative: 243 lbs 11/3/2022 Cont. RIH w/ 3.5" N-80 Range II 9.2# IBT-M liner as per run tally F/ 599' T/ 3785' M/U TQ. 3500 ft/ lbs.;P/U and M/U Baker ZXP Liner Top Hanger and RIH. Confirm shear screws and install pal mix into Liner hanger. P/U 47K, S/O 45K.;P/U and M/U 1 stand of drill pipe and circulate liner volume @ 158 GPM W/ 300psi. B/D Top Drive.;Continue RIH with 3-1/2" Liner running 4-1/2" Drill Pipe from derrick F/ 3900' T/ 4528' Remove casing tongs and air slips from rig floor. Continue RIH with 3-1/2" Liner running 4-1/2" Drill Pipe from Derrick F/ 4528' T/ 11,415, 122 stds. filling pipe every 20 stands. P/U-165K S/O-115K.;P/U E- Kelly, M/U TD, broke circ. Washed down F/11,145'-T/11,445' w/ no fill. CBU GPM-178 SPP-1809 psi Max gas 1098 units MW-10.5 ppg.;P/U Baker cmt head, washed to bottom. P/U 2' of bottom. Held PJSM w/ cmt hands. Shut down MP. Installed cmt lines, blew down TD. Halliburton pumped 10 bbls water to flush and fill lines. Shut in at Baker cement head and PT lines at 450 psi low 4500 psi high.;Lined up Baker cement head to Halliburton, pumped 30 bbls 12 ppg spacer at 3 bpm-1270-1396 psi, followed with 124 bbls ( 570 sx) 15.3 ppg Type I II Tail cement at 3 bpm, 1180 to 113 psi, Added no LCM to tail cement. Baker released dart, Halliburton then displaced with 10.5 ppg 6% KCL mud at 65 bpm-;65 ICP. 56 bbls into displacement caught pressure chasing cement. Reduced rate with 12 bbls to pump, 2 bpm- 2136 psi and bumped plug/landing collar 135.5 bbls into displacement (calculated at 137.3 bbls). FCP 2270 psi. Halliburton increased to and held 3057 psi (787 over fcp) for 1 minute.;Slacked off on blocks from 175K to 90K, giving us a good indication hanger was set. Bled back 1.5 bbl to truck and floats held. CIP at 00:47 on 11-4-22. Lost 0 bbls throughout the job. Applied 4500 psi and held 3 minute to shift HRD-E and release run tool. Bled off and PU to 200K three times, run;tool not released. S/O to 100K and applied 4710 psi and held 5 minutes. Bled off, PU to 150K, lost weight, cont. to PU at 150K, run tool released. PU 6 to clear dogs from hanger top, rotated at 20 rpm, 8,600 ft/lbs torque, S/O and set down to 50K (50K applied) three times,;to ensure weight transfer to set packer. Top of liner hanger at 7636, top of landing collar at 11,389. LD Baker cement head, MU topdrive. Pressured up to 500 psi on drill string and PU 10 slowly. Once psi started dropping, rig started pumping and did one full circ at 318 gpm- 1800 psi.;Had 30 bbls of spacer to surface, and 10.5 bbls of cement. Shut down pump, L/D E-Kelley, installed 2 wiper balls in drill string, MU topdrive and pumped second circulation at 375 gpm- 1985 psi. Flow checked well (static).;POOH w/ liner hanger running tool on DP F/7584' to current depth fo 3929'. P/U-148K S/O-146K.;Hauled: 33 bbl Solids to KGF G&I Cumulative: 800 bbl Hauled: 127 bbl Fluid to KGF G&I Cumulative: 2415 bbl Hauled: 10 bbls of cmt to KGF G&I Cumulative: 10 bbls Daily Metal: 0 lbs Cumulative: 243 lbs 11/4/2022 POOH w/ liner hanger running tool on DP F/ 3929' to surface, Break and L/D running tool. P/U-76K S/O-72K. Continue building 300 BBLs of Corrosion Inhibited Drill Water. Clean centrifuge.;Wash stack with blackwater, Blow down surface lines and Top Drive. P/U and break down Baker cement head.;P/U and M/U Polish mill assembly and RIH F/ surface T/ 4954' filling pipe every 2000'. P/U 90K, S/O 60K.;Slip and Cut 104' of drilling line. Total of 22 wraps, Adjust break linkage, Grease and service the draworks.;Continue RIH with Polish mill assembly F/ 4954' T/ 7590' P/U 125K, S/O 100K. Hole displacement was .5 BBL light.;Attempt to reach depth of LTP and would not go past 7590' MD. CBU 220 GPM 520psi SPP and nothing seen on returns with no increase in PH.;Monitor Well, Static. POOH with Polish Mill assembly F/ 7590' T/ Surface. Look over drill pipe tally to confirm and observe discrepancy in numbers. Continue to pull to surface and observe mill. Mill shows signs of milling on Liner Top.;Service Rig, Grease crown, Top Drive, Blocks, Iron Roughneck and clean the rig floor.;RIH with polish mill assembly to obtain correct depth of liner top. F/ surface T/ 7651' filling pipe every 20 stands. P/U 125K, S/O 105K. Located Liner Top at 7641' MD with PBR mill at 7651'.;Polish PBR and Liner Top as per Baker representative. GPM 205, SPP 900, RPM 40. CBU.;Displace 10.5ppg WBM with 8.3ppg Corrosion Inhibited drill water. GPM 282, SPP 1620psi.;Hauled: 68 bbl Solids to KGF G&I Cumulative: 868 bbl Hauled: 492 bbl Fluid to KGF G&I Cumulative: 2907 bbl Hauled: 0 bbls of cmt to KGF G&I Cumulative: 10 bbls Daily Metal: 0 lbs Cumulative: 243 lbs 11/5/2022 Line up on trip tank and confirm good no flow negative test for 30 minutes. No Flow observed.;POOH with polish mill assembly laying down CDS40 drill pipe F/ 7632' T/ 2114' P/U 150K S/O 115K. Sucking wiper balls through pipe, cleaning and re-doping connections, installing thread protectors. Worked on hauling off drilling mud and clean pits.;RIH with remaining CDS40 in derrick F/ 2114' T/ 5081' filling drill pipe every 20 stands. P/U 80K S/O 65K.;Circulate drill pipe volume to remove WBM from drill pipe @ 112 GPM 89psi SPP.;Continue L/D CDS40 drill pipe while POOH with PBR and Liner Top mill assembly F/ 5081' T/ 2114', Continue L/D DS40 drill pipe F/ 2114' T/ polish mill assembly at surface and L/D mill assembly. Sucking wiper balls through pipe, cleaning and re-doping connections, installing thread protectors.;R/U testing equip. Performed liner lap test T/3000 psi on chart for 10 min (good test). Pumped in 3.42 bbls Bled back 3.35 bbls. R/D testing equip. and blew down same. Cont. w/ pit cleaning.;R/U Yellow Jacket E-line, CBL tools- rope socket, Titan CCL, centralizer, DAT 8 Titan SCBL with IE Temp, centralizer, and 1-11/16" Titan Gamma Ray. Total length= 22.63' OD= 1.69". Held PJSM. RIH and tagged up @ 11,225' WLM. Performed CBL's on 3.5" liner & 7" casing. R/D and released;Yellow Jacket E-line unit @ 02:00 hrs. DST . Gave Parker casing hands 2 hr. notice @ 00:30 hrs. and BOT rep 1 hr. notice @ 01:30 hrs. Finished cleaning pit module 1 & 2, flushed all lines and hopper manifolds w/ Barakleen pill and blew down same.;Pulled 9" wear ring and L/D same. R/U Parker casing equip. Loaded Tie back jts. on catwalk racks. Held PJSM on running tie back.;M/U Tie back seals as per BOT Rep (9.60' to locator No-Go). RIH w/ 3.5" L-80 9.3# RTS-8 as per run tally. Current depth of 1678'. P/U-30K S/O-27K.;Hauled: 56 bbl Solids to KGF G&I Cumulative: 924 bbl Hauled: 504 bbl Fluid to KGF G&I Cumulative: 3411 bbl Hauled: 0 bbls of cmt to KGF G&I Cumulative: 10 bbls Daily Metal: 0 lbs Cumulative: 243 lbs 11/6/2022 Continue RIH w/ 3.5" L-80 9.3# RTS-8 as per run tally. F/ 1678' and locate PBR and No-Go. Tag twice and confirm. Lay down joints 245 & 244 locate and P/U 28.23' of pup joints and M/U hanger and land Tie-Back at 7653.65' MD 2' off of No-Go. P/U 79K S/O 63K.;Perform MIT on Tbg/ Liner to 3000psi. for 30 charted minutes Pressure up T/ 3175psi. 15 minutes 3150psi. 30 minutes 3140psi. Good Test with 0 psi on IA and OA pump 49.45 gallons to pressure up and bled off 46 gallons.;R/U and pressure up on 3-1/2" x 7" IA T/ 5000psi. 15 minutes 4975psi. 30 minutes 4930psi. 45 minutes 4925psi. Good Test. 460psi. on tubing and 0psi on OA. Took 163 gallons to pressure up and bled back 157 gallons.;WHR installed TWC. Opened up UPR, Blind ram, and LPR doors, cleaned & serviced rams and cavities. Removed VBR's from LPR. De-energized koomey. R/D Koomey lines on stack. R/D and removed choke & kill lines, catch can, and flow line. Pumped Barakleen through all mud lines and blew down same.;Finished cleaning mud tanks. Replaced blow down valve on boiler #1. Separated rig 147's single gate from stack, trolleyed out stack. Picked stack w/ crane, M/U 169's single gate on bottom of stack.;Crew change, held PTSM and weekly safety w/ rig crew. Cont. w/ R/D. Removed old BOP lifting plate and installed modified lifting plate on stack and set in newly designed BOP cradle w/ crane. Stored away koomey line in tray on sub. WHR N/U dry hole tree.;Tested void, hanger neck seals, and tree to lower master valve T/5000 psi for 15 min (ok). Loaded out MWD/DD & Geo-Log shack. Cont. w/ R/D in the pits.;Replaced keepers and screws on shaker beds along w/ installing some new deck rubbers on shakers. Tore down MP's, serviced, and reassembled. Installed shipping beams. Removed XO, subs, slips, and elevators from rig floor.;Final report for BCU-14B, releasing rig @ 06:00 hrs this morning and moving to SRU 224-10 AFE.;Hauled: 3 bbl Solids to KGF G&I Cumulative: 927 bbl Hauled: 258 bbl Fluid to KGF G&I Cumulative: 3669 bbl Hauled: 0 bbls of cmt to KGF G&I Cumulative: 10 bbls Daily Metal: 0 lbs Cumulative: 243 lbs Activity Date Ops Summary 11/12/2022 PJSM and PTW SITP 0psi,Spot Fox coil tubing unit, Cruz crane. Build containment and spot rain for rent tanks and mud pump. NU BOPES, build hardline, and flowback iron.,Test BOPES to 250psi/4,500psi - Test Good. Witness waived by AOGCC, Jim Regg at 13:37 via Email. One F/P on choke valve #3, the valve was greased and cycled then passed on the 2nd test.,Secure well and SDFN 11/13/2022 PJSM and PTW, warm up equipment SITP 0psi,Load supply tank with 200BBL fresh water Pick up lubricator. M/U YJ 2.25"OD External grapple CTC for 1.75"OD coil, pull test to 25k, pressure test to 3500psi. MU YJ DFCV, Jars, Dico, Circ sub, 2.125" motor and 2.75"OD tri-cone rock bit. Stab on well and pressure test pump iron and lubricator to 250psi/4500psi - Test good,Open well and RIH dry tag at 11,290ft. Pump at 1BPM and clean down to 11,390ft. (PBTD 11,390'). One cement stringer was seen @ 11,381ft, otherwise very little motor work until we stalled out on the landing collar at 11,390' Assume we were just cleaning settled-out mud, not cement. Circulate 100BBL, returns were very clean after 75BBL pumped. Reciprocate pipe across the bottom 300ft of the wellbore while circulating.,Drop ball and pump 30BBL, open circulating sub. RU N2 unit. Pressure test to 250/5000psi - Test Good Come online with N2 at 1200scfm Jet well dry 98BBL recovered (expected volume 99BBL). POOH Trap 3570psi of N2 on the well (265,600SCF pumped),Secure well. Break down YJ tools, and lay down the lubricator. SDFN 11/14/2022 PJSM and PTW SITP 3500psi,RDMO Coil tubing and support equipment 11/21/2022 PJSM and PTW SITP 3150psi of N2,Spot equipment, R/U YJ E-line M/U 1-11/16" OD GPT tool. Stab on well Pressure test to 250psi/4500psi - TEST GOOD,Open well to RIH, tools will not fall. Call for tungsten weight bars and bleed well pressure to 2540psi.,M/U tungesten weight bars and 1-11/16" OD GPT tool, RIH Fluid level observed at 10,720ft, SITP 2540psi, Bottom perf 11,300ft. (5.7BBL of water left after N2 lift) Tag PBTD at 11,364ft, POOH.,Bleed SITP to 2250psi M/U and RIH with gun gamma and 10ft, 2" OD Geodynamics gun, 6.5gm, 6SPF (CCL to top shot 10.5ft) Pull correlation log and send to town. On depth.,Pull on depth and perforate Tyonek T18 11,290-11,300ft. POOH, All shots fired, bull plug full of water. (we were in fluid when we shot) SITP - 2268psi No pressure change seen in 15min,Lay down lubricator, secure well and SDFN 11/22/2022 Notify Yellow Jacket E-line to load strip guns. Yellow Jacket return to shop and load strip guns.,Yellow Jacket arrive on location. Conduct JSA and approve PTW. MU 2 x 1-11/16" weight bars and 1-11/16" GPT toolstring. Open well and RIH. Find fluid level = 10,720' with tubing pressure = 2206 psi. POOH.,MU and RIH with 2-1/8" x 10' strip gun. Send correlation data to RE/GEO and confirm on depth. Re-perf T18 zone from 11,290 - 11,300'. Tubing pressure = 2182 psi. Pressure did not change after perforating. POOH. Confirm all shots fired.,Secure well with night cap on wireline valves. SDFN. 11/23/2022 Yellow Jacket E-line arrive at location. Conduct JSA and approve PTW. MU GR/CCL and strip gun. Stab lubricator onto wireline valves. Open well and RIH.,RIH with 2-1/8" x 10' strip gun. GR/ CCL to top shot = 9.0'. Send correlation data to RE/GEO and confirm on depth. Perforate T7 zone from 10,140 - 10,150'. Initial pressure = 2164 psi, 5 min = 2174 psi, 10 min = 2175 psi, 15 min = 2174 psi.,RIH with 2-1/8" x 10' strip gun. GR/ CCL to top shot = 9.0'. Send correlation data to RE/GEO and confirm on depth. Perforate T7 zone from 10,130 - 10,140'. Initial pressure = 2174 psi, 5 min = 2174 psi, 10 min = 2145 psi, 15 min = 2174 psi.,Flow well from 2174 psi to 1500 psi. No gas, only N2. Run GPT and find fluid level at 10,348; fluid level come up 282. Tubing pressure = 1550 psi.,RIH with 2" x 20' hollow carrier perf gun. GR/ CCL to top shot = 10.5'. Send correlation data to RE/GEO and confirm on depth. Perforate T7A zone from 10,152 - 10,172'. Initial pressure = 1647 psi, 5 min = 1653 psi, 10 min = 1654 psi, 15 min = 1655 psi. All shots fired. Bull plug on gun is dry.,RDMO n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: BCU-014B Beaver Creek Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00074 BCU-14B Completion Spud Date: 11/27/2022 ELine arrive in Field, Complete JSA MIRU, PT to 2500H and 250L,RIH w/ GPT Find fluid level at approx 11,300 (T-18 sand) PU fluid sampler, RIH and collect fluid sample from ~11,300. RDMO well !"# $#% &#''&'( !)* * $" * +, * * -* -* ! ./"*"## $%&'(()*&+ 0*! *,-./ , . * $%&'(()*&+ / * 0 . . * 1 * !) .2* * &12)34 + , &12), -,-,+ 5( " 60 66 - -! 0 "* "* 30* /0* 435$- 45$ ! 1 "* ('(( ('(( 1 7( (2'7*( 7 7*8'88 '((-/"3*('(( ('%( *(978:%'%88, %91:7'2((&0 - 678 9" 0/ 6+8 0 678 ! .".0 ;< (=1(=1(11 '*1 27'% %% 1*('2((((((( !/*,* "* 0! 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AEA A Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.11.02 12:10:13 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.11.02 16:59:21 -08'00' TD Shoe Depth: PBTD: Jts. 2 191 Yes X No X Yes No 10 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?: Yes X 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? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Float Shoe 7 3/4 Rotate Csg Recip Csg Ft. Min. PPG9.45 Shoe @ 7848.19 FC @ Top of Liner7,765.68 Floats Held 6% KCL Polymer Mud CASING RECORD County State Alaska Supv.Josh Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.BCU-014B Date Run 26-Oct-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC 1.52 7,848.19 7,846.67 Csg Wt. On Hook: Type Float Collar: No. Hrs to Run: 9.45 5 99 1000 FI R S T S T A G E 10.5Tune Prime 30 288.7/288.2 1800 0 Halliburton 15.3 105 Bump press CBL Bump Plug? 14:55 10/26/2022 3,596' 7,848.007,858.00 CEMENTING REPORT Csg Wt. On Slips: 6% KCL Polymer Mud 12 60 Type of Shoe: Casing Crew:Parker www.wellez.net WellEz Information Management LLC ver_04818br 4 7'' LTC Casing Jts 7 29.0 L-80 BTC 79.59 7,846.67 7,767.08 Float Collar 7 3/4 BTC 1.40 7,767.08 7,765.68 7'' LTC Casing Jts 7 29.0 P-110 LTC 7,765.68 7,765.68 l ll 145 2.39 l ll 490 1.24 4 TD Shoe Depth: PBTD: Jts. 1 2 117 Yes X No Yes X No 60 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? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Type I II 570 1.24 7,661.95 Hanger 5 3/4 IBT-M Baker 26.01 7,661.95 7,635.94 11,387.34 7,671.74 Pup 3 1/2 9.2 L-80 IBT-M 9.79 7,671.74 1.50 11,388.84 11,387.34 Liner 3 1/2 9.2 L-80 IBT-M 3,715.60 Pup 3 1/2 9.2 L-80 BTC x IBT-M 11,390.65 Landing Collar 3 1/2 BTC Baker 1.81 11,390.65 11,388.84 11,423.45 11,392.38 Pup 3 1/2 9.2 L-80 IBT-M x BTC 1.73 11,392.38 1.22 11,424.67 11,423.45 Liner 3 1/2 9.2 L-80 BTC 31.07 Float Collar 4 1/2 BTC Frontier Ran 56 solid body centralizers. Liner 3 1/2 9.2 L-80 BTC 31.08 11,455.75 11,424.67 HRD-E HD ZXP liner packer/Flex-Lock V liner hanger www.wellez.net WellEz Information Management LLC ver_04818br 3 Type of Shoe:Frontier Casing Crew:Parker 11,457.0011,459.00 11,388.84 CEMENTING REPORT Csg Wt. On Slips:35,000 6% KCL PHPA 0:47 11/4/2022 7,636' 15.3 124 Bump press CBL Bump Plug? 134.5/137 3057 360 HES FI R S T S T A G E 12Tune 30 10.5 4 100 2270 Csg Wt. On Hook:175,000 Type Float Collar:Frontier No. Hrs to Run:16 BTC Frontier 1.25 11,457.00 11,455.75 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.BCU-014B Date Run 3-Nov-22 CASING RECORD County State Alaska Supv.Jay Murphy 11,423.45 Floats Held3000 6% KCL PHPA Rotate Csg Recip Csg Ft. Min. PPG10.5 Shoe @ 11457 FC @ Top of Liner 7635.94 Casing (Or Liner) Detail Shoe 4 1/2 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 14B - PTD 222-057 - API 50-133-20539-02-00 MUDLOGS - EOW DRILLING REPORTS (10/19/2022 to 11/02/2022) 1. FINAL EOW REPORT 2. DAILY REPORTS 3. SHOW REPORTS 4. DIGITAL DATA (LAS) 5. MUDLOG PRINTS (2” and 5” MD and TVD COLOR PRINTS – TIFF AND PDF FORMATS) Formation Log LWD Combo Log Gas Ratio Log Drilling Dynamics Log SFTP Transfer - Data Folders: Please include current contact information if different from above. By Meredith Guhl at 7:43 am, Dec 05, 2022 222-057 T37358 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.05 07:44:02 -09'00' David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/29/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 14B - PTD 222-057 - API 50-133-20539-02-00 FINAL LWD FORMATION EVALUATION LOGS (10/19/2022 to 11/02/2022) EWR-M5, AGR, PCG, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Folder Contents: Please include current contact information if different from above. By Meredith Guhl at 1:35 pm, Nov 29, 2022 222-057 T37338 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 13:38:11 -09'00' 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: [EXTERNAL] RE: BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22 Date:Friday, November 18, 2022 11:31:00 AM Jake, Approval granted to add these perfs, which are between two other sets of proposed perfs authorized under Sundry 322-642. 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 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, November 15, 2022 8:21 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Fwd: [EXTERNAL] RE: BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22 Good Morning Bryan, Please see below table which includes a zone we would like to add: Tyonek-12: 10,761-10,791’ md Thanks Jake Begin forwarded message: From: Sarah Frey <sarah.frey@hilcorp.com> Date: November 14, 2022 at 5:09:10 PM AKST To: Jacob Flora <Jake.Flora@hilcorp.com>, Meredyth Richards <Meredyth.Richards@hilcorp.com> Subject: RE: [EXTERNAL] RE: BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22 Hi Jake. I’m pretty sure the only interval we discussed that wasn’t included in the sundry was the coal. It is added and is in grey in the following table: Well Name Zone Name Top Perf Depth MD Bottom Perf Depth MD Top Perf Depth TVD Bottom Perf Depth TVD Gun Length Gun Order Sundry Interval Name Sundry MD Top Sundry MD BASE BCU-14B Tyonek T18 11,290 11,300 10,305 10,314 10 1 Tyonek T18 11,290 11,338 BCU-14B Tyonek T15 11,025 11,036 10,048 10,059 11 8 Tyonek T15 11,025 11,055 BCU-14B Tyonek T14 10,977 10,989 10,001 10,013 12 7 Tyonek T14 10,939 11,000 BCU-14B Tyonek T12 10,761 10,791 9,794 9,823 30 9 Tyonek T12 10,761 10,791 BCU-14B Tyonek T7A 10,182 10,201 9,240 9,258 19 4 Tyonek T7 10,130 10,230 BCU-14B Tyonek T7A 10,152 10,172 9,212 9,231 20 3 BCU-14B Tyonek T7 10,130 10,150 9,190 9,200 20 2 BCU-14B Tyonek T5 10,017 10,040 9,082 9,104 23 5 Tyonek T5 10,012 10,040 BCU-14B Tyonek T2 9,714 9,748 8,791 8,824 34 6 Tyonek T2 9,714 9,748 I also updated the “Gun order” to reflect what I thought were our conclusions from the perf discussion today. Please let me know if you need anything else. I will be able to check my email most days but likely wont’ be able to do much more log and depth work until I get back next Friday. Thanks! Sarah From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Monday, November 14, 2022 4:34 PM To: Sarah Frey <sarah.frey@hilcorp.com>; Meredyth Richards <Meredyth.Richards@hilcorp.com> Subject: Fwd: [EXTERNAL] RE: BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22 Bryan needs these new depths tomorrow am if possible Sent from my iPhone Begin forwarded message: From: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Date: November 14, 2022 at 4:08:12 PM AKST To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] RE: BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22 Best to send these over by first thing in the morning if it’s urgent. I’m tied up tomorrow afternoon and Wednesday. 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 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Monday, November 14, 2022 3:53 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22 Hi Bryan, Our geo wants to add a couple more target zones to this Sundry. I will be sending these over tomorrow and wanted to give you a heads up. Thanks, Jake 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 thisemail 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 therecipient 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 havereceived 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 virusand other checks as it considers appropriate. 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Wednesday, November 23, 2022 1:59 PM To:Jay Murphy - (C) Cc:Regg, James B (OGC) Subject:RE: BCU-14B MIT Attachments:MIT BCU-14B 11-06-22 Revised.xlsx Jay, Attached is a revised report removing the well name Pearl 8 and replacing with 14B and included additional remarks. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907 793 1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From:Jay Murphy (C) <Jay.Murphy@hilcorp.com> Sent:Sunday, November 6, 2022 7:04 PM To:Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject:BCU 14B MIT Thank You and Best Regards, Jay Murphy/DSM Hilcorp Alaska, LLC HAK Rig 169 Office: 907 283 1369 Cell: 907 715 9211 Jay.Murphy@Hilcorp.com 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. revised report 2 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. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220570 Type Inj N Tubing 0 3175 3150 3140 Type Test P Packer TVD 6815 BBL Pump 1.2 IA 0 0 0 0 Interval O Test psi 3000 BBL Return 1.0 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220570 Type Inj N Tubing 0 460 455 450 445 Type Test P Packer TVD 6815 BBL Pump 3.9 IA 0 5000 4975 4930 4925 Interval O Test psi 4800 BBL Return 3.7 OA 0 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Rig MIT-IA per 322-606. Witness waived. Notes: Notes: Hilcorp Beaver Creek Unit, Pad #2A, BCU-14B Jay Murphy 11/06/22 Notes:Rig MIT-T per 322-606. Witness waived. Notes: Notes: Notes: BCU 14B BCU 14B Form 10-426 (Revised 01/2017)2022-1106_MITP_BCU-14B_2tests David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122 Log Print Files and Log Data Files: Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-14B 50133205390200 222057 11/5/2022 Yellowjacket SCBL HVB-16A 50231200400100 222070 7/30/2022 Yellowjacket SCBL NCI B-03A 50883200950100 222048 9/22/2022 AK E-Line CBL PAXTON 6 50133207070000 222054 7/23/2022 AK E-Line CBL S MGS Unit 6 (DI-06) 50733200420000 167052 10/6/2022 AK E-Line CBL SRU 12-15 50133101380000 160022 09/25/2022 AK E-Line CBL Please include current contact information if different from above. By Meredith Guhl at 12:59 pm, Nov 22, 2022 T37288 T37289 T37290 T37291 T37292 T37293 BCU-14B 50133205390200 222057 11/5/2022 Yellowjacket SCBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.22 13:28:54 -09'00' From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:BCU-14B (PTD 222-057) wellfile Date:Friday, November 18, 2022 11:32:36 AM Attachments:RE EXTERNAL RE BCU-14B AOGCC 10-403 PTD 222-057 Submitted 11-08-22.msg Please add the attached email to the wellfile in association with sundry 322-642 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 1 Regg, James B (OGC) From:Karson Kozub - (C) <kkozub@hilcorp.com> Sent:Wednesday, November 16, 2022 12:36 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Donna Ambruz; Juanita Lovett Subject:Fox 8 CTU 11-12-22 Attachments:Fox 8 CTU 11-12-22.xlsx Good Afternoon, Attached is the BOPE test report for Fox CTU 8 (Sundry 322‐642) (PTD 222‐057) Regards, Karson Kozub Mobile: +1 (907) 570-1801 kkozub@hilcorp.com 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. 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. Beaver Creek Unit 14BPTD 2220570 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:8 DATE:11/12/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2220570 Sundry #322-642 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/4500 Annular:N/A Valves:250/4500 MASP:4120 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Other Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 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 NA H2S Gas Detector NA NA #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA System Pressure (psi)2950 P Kill Line Valves 2 2"P Pressure After Closure (psi)2400 P Check Valve 0 NA 200 psi Attained (sec)4 P BOP Misc 0 NA Full Pressure Attained (sec)7 P Blind Switch Covers:All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA NA No. Valves 5 FP ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 23 P Coiled Tubing Only:#2 Rams 20 P Inside Reel valves 1 P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:3.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice YES Date/Time 11/11/22 7:33hrs Waived By Test Start Date/Time:11/12/2022 13:00 (date)(time)Witness Test Finish Date/Time:11/12/2022 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Choke valve #3 F/P. The valve was greased and cycled then passed on the second test. Accumulator system 4 bottles at 1400psi. Test fluid 60/40 Methanol/Water blend Terence Rais Hilcorp Alaska Karson Kozub BCU 14B Test Pressure (psi): Trais@FoxEnergyAK.com kkozub@hilcorp.com Form 10-424 (Revised 08/2022)2022-1112_BOP_Fox8_BCU-14B           jbr J. Regg; 12/27/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Fox CTU 8 Date:Tuesday, December 27, 2022 11:44:23 AM Attachments:2022-1112_BOP_Fox8_BCU-14B.pdf Beaver Creek Unit 14B (PTD 2220570) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 1 Regg, James B (OGC) From:Joshua Riley - (C) <jriley@hilcorp.com> Sent:Friday, October 28, 2022 9:22 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:Rig 169 BOPE Test 10/28/22 Attachments:Rig 169 BCU-14B 10-28-22.xlsx Here is the BOPE test for 169 Beaver Creek BCU‐14B Josh Riley Hilcorp DSM: 907-283-1369 Cell: 907-252-1211 Hilcorp Alaska, LLC 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. 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. Beaver Creek Unit 14B PTD 2220570 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:169 DATE:10/28/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2220570 Sundry # Operation:Drilling:x Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:x Other: Rams:250/5000 Annular:250/2500 Valves:250/5000 MASP:4604 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11'' P Pit Level Indicators P P #1 Rams 1 2 7/8'' x 5'' VBR P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2 7/8'' x 5'' VBR FP H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8'' P Time/Pressure Test Result HCR Valves 2 2 1/16'' & 3 1/8'' FP System Pressure (psi)3050 P Kill Line Valves 1 2 1/16''FP Pressure After Closure (psi)1650 P Check Valve 0 NA 200 psi Attained (sec)22 P BOP Misc 0 NA Full Pressure Attained (sec)87 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4@2460 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 21 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:3 Test Time:16.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/25/22 03:35 Waived By Test Start Date/Time:10/27/2022 7:30 (date)(time)Witness Test Finish Date/Time:10/28/2022 0:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested w/ 3.5'' and 4.5'' Test jts 250 low f/ 5 min and 5000 high f/ 10 min Annular tested 250 low 5 min 2500 high 10 min, FP on LPR bonnet seals replace seals and retest good, FP 2 1/16'' Manual Kill Valve Replace and retest good, FP HCR choke grease and function retest good, Quadco Tested Gas alarms all tested good Brandon Davis Hilcorp Josh Riley BCU-14B Test Pressure (psi): jriley@hilcorp.com Form 10-424 (Revised 08/2022)2022-1028_BOP_Hilcorp169_BCU-14B Alaska LLC             jbr J. Regg; 11/28/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp 169 Date:Monday, November 28, 2022 12:21:27 PM Attachments:2022-1028_BOP_Hilcorp169_BCU-14B.pdf Beaver Creek Unit 14B (PTD 2220570) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage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y Anne Prysunka at 10:12 am, Oct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essie L. Chmielowski Digitally signed by Jessie L. 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Procedure Rev 3 6SLGHU3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH9HUVLRQ2FWREHU BC-14B Drilling Procedure Rev 3 ¶5DGLXVIRU6669 3DJH9HUVLRQ2FWREHU BC-14B Drilling Procedure Rev 3 'LUHFWLRQDO3URJUDPZS$WWDFKHG 6WDQGDUG3URSRVDO5HSRUW 2FWREHU 3ODQ%&8%ZS +LOFRUS$ODVND//& %HDYHU&UHHN8QLW %HDYHU&UHHN8QLW3DG$ 3ODQ%HDYHU&.8QLW 5LJ%&8% 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000True Vertical Depth (1000 usft/in)0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 Vertical Section at 57.00° (1000 usft/in) BCU-14 wp01 Tgt1 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 800 0 8 500 900 0 9 3 6 1 BCU 14 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 0 00 9 4 5 0 BCU-14A 9 5/8" TOW 7" x 8-1/2" 4 1/2" x 6-1/8" 4 0 0 0 4 50 0500 055 006 00 0 650 07 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 0 0 0 9 5 0 0 1 0 0 0 0 1 0 5 0 0 11 0 0 0 11 4 5 9 BCU 14B wp03 KOP : Start Dir 12.3º/100' : 3660' MD, 3570.24'TVD : 30° RT TF End Dir : 3677' MD, 3583.78' TVD Start Dir 3º/100' : 3697' MD, 3599.51'TVD End Dir : 4385.57' MD, 4146.6' TVD Start Dir 3º/100' : 6787.41' MD, 6033.13'TVD End Dir : 7530.42' MD, 6689.95' TVD Total Depth : 11459.44' MD, 10462.58' TVD Sterling B Beluga B5 Lower Beluga Tyonek T12 Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: Beaver CK Unit 14 Ground Level: 141.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.002430071.360 314368.188 60° 38' 51.1588 N 151° 2' 3.7009 W SURVEY PROGRAM Date: 2022-05-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 161.00 3660.00 BCU 14 (BCU 14) 3_MWD+AX+Sag 3660.00 4060.00 BCU 14B wp03 (Rig: BCU-14B) 3_MWD_Interp Azi+Sag 4060.00 8000.00 BCU 14B wp03 (Rig: BCU-14B) 3_MWD+IFR1+MS+Sag 8000.00 11459.44 BCU 14B wp03 (Rig: BCU-14B) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 4865.49 4706.49 5300.83 Sterling B 5885.29 5726.29 6599.18 Beluga B5 7459.90 7300.90 8332.29 Lower Beluga 9762.58 9603.58 10730.42 Tyonek T12 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Beaver CK Unit 14, True North Vertical (TVD) Reference:BCU 14B @ 159.00usft (169) Measured Depth Reference:BCU 14B @ 159.00usft (169) Calculation Method:Minimum Curvature Project:Beaver Creek Unit Site:Beaver Creek Unit Pad 1A Well:Plan: Beaver CK Unit 14 Wellbore:Rig: BCU-14B Design:BCU 14B wp03 CASING DETAILS TVD TVDSS MD Size Name 3570.24 3411.24 3660.00 9-5/8 9 5/8" TOW 7140.84 6981.84 8000.00 7 7" x 8-1/2" 10462.58 10303.58 11459.44 4-1/2 4 1/2" x 6-1/8" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 3660.00 36.33 30.51 3570.24 389.38 217.25 0.00 0.00 394.27 KOP : Start Dir 12.3º/100' : 3660' MD, 3570.24'TVD : 30° RT TF 2 3677.00 38.15 32.20 3583.78 398.16 222.60 12.30 30.00 403.55 End Dir : 3677' MD, 3583.78' TVD 3 3697.00 38.15 32.20 3599.51 408.62 229.19 0.00 0.00 414.76 Start Dir 3º/100' : 3697' MD, 3599.51'TVD 4 4385.57 38.24 65.92 4146.60 678.46 540.45 3.00 103.17 822.78 End Dir : 4385.57' MD, 4146.6' TVD 5 6787.41 38.24 65.92 6033.13 1285.11 1897.59 0.00 0.00 2291.37 Start Dir 3º/100' : 6787.41' MD, 6033.13'TVD 6 7530.42 16.22 57.65 6689.95 1436.38 2198.99 3.00 -173.92 2626.53 End Dir : 7530.42' MD, 6689.95' TVD 7 10730.42 16.22 57.65 9762.58 1914.67 2954.10 0.00 0.00 3520.32 BCU-14 wp01 Tgt1 8 11459.44 16.22 57.65 10462.58 2023.63 3126.13 0.00 0.00 3723.94 Total Depth : 11459.44' MD, 10462.58' TVD 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Tyonek and Beluga Gas Pools, BCU-14B Hilcorp Alaska, LLC Permit to Drill Number: 222-057 Surface Location: 113' FSL, 1388' FEL, Sec 33, T7N, R10W, SM, AK Bottomhole Location: 2136' FSL, 1739' FWL, Sec 34, T7N, 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 AOGCC within 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 June, 2022. 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Procedure Rev 0 'LUHFWLRQDO3URJUDPZS$WWDFKHG 6WDQGDUG3URSRVDO5HSRUW 0D\ 3ODQ%&8%ZS +LOFRUS$ODVND//& %HDYHU&UHHN8QLW %HDYHU&UHHN8QLW3DG$ 3ODQ%HDYHU&.8QLW 3ODQ%&8% 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000True Vertical Depth (1000 usft/in)0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 Vertical Section at 57.00° (1000 usft/in) BCU-14 wp01 Tgt1 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 800 0 8 500 9000 9 3 6 1 BCU 14 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 00 0 9 4 5 0 BCU-14A 7" x 8-1/2" 4 1/2" x 6-1/8" 4 0 0 0 4 5 0 0 50 0 0 550060 0 0 65007 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 0 0 0 9 5 0 0 1 0 0 0 0 1 0 5 0 0 1 1 0 0 0 11 4 7 7 BCU-14B wp02 End Dir : 3897' MD, 3761.13' TVD Start Dir 3º/100' : 3917' MD, 3776.97'TVD End Dir : 4683.86' MD, 4386.3' TVD Start Dir 3º/100' : 6768.64' MD, 6003.87'TVD End Dir : 7548.03' MD, 6689.95' TVD Total Depth : 11477.05' MD, 10462.58' TVD Sterling B Beluga B5 Lower Beluga Tyonek T12 Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: Beaver CK Unit 14 Ground Level:141.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2430071.36 314368.19 60° 38' 51.159 N 151° 2' 3.701 W SURVEY PROGRAM Date: 2022-05-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 161.00 3880.00 BCU 14 (BCU 14) 3_MWD+AX+Sag 3880.00 4280.00 BCU-14B wp02 (Plan: BCU-14B) 3_MWD_Interp Azi+Sag 4280.00 11477.05 BCU-14B wp02 (Plan: BCU-14B) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 4865.49 4706.49 5301.46 Sterling B 5885.29 5726.29 6615.82 Beluga B5 7459.90 7300.90 8349.90 Lower Beluga 9762.58 9603.58 10748.02 Tyonek T12 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Beaver CK Unit 14, True North Vertical (TVD) Reference:BCU 14B @ 159.00usft (169) Measured Depth Reference:BCU 14B @ 159.00usft (169) Calculation Method:Minimum Curvature Project:Beaver Creek Unit Site:Beaver Creek Unit Pad 1A Well:Plan: Beaver CK Unit 14 Wellbore:Plan: BCU-14B Design:BCU-14B wp02 CASING DETAILS TVD TVDSS MD Size Name KOP: 12.3º/100' : 3880' MD, 3747.51'TVD : 30° RT T)52.29 8693.29 9800.00 7 7" x 8-1/2" 10462.58 10303.58 11477.05 4-1/2 4 1/2" x 6-1/8" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 3880.00 35.82 29.72 3747.51 501.95 282.86 0.00 0.00 510.61 KOP: 12.3º/100' : 3880' MD, 3747.51'TVD : 30° RT TF 2 3897.00 37.64 31.43 3761.13 510.70 288.03 12.30 30.00 519.71 End Dir : 3897' MD, 3761.13' TVD 3 3917.00 37.64 31.43 3776.97 521.13 294.40 0.00 0.00 530.73 Start Dir 3º/100' : 3917' MD, 3776.97'TVD 4 4683.86 39.11 68.83 4386.30 812.23 646.81 3.00 101.36 984.83 End Dir : 4683.86' MD, 4386.3' TVD 5 6768.64 39.11 68.83 6003.87 1287.26 1873.25 0.00 0.00 2272.13 Start Dir 3º/100' : 6768.64' MD, 6003.87'TVD 6 7548.03 16.22 57.65 6689.95 1436.38 2198.99 3.00 -172.16 2626.53 End Dir : 7548.03' MD, 6689.95' TVD 7 10748.03 16.22 57.65 9762.58 1914.67 2954.10 0.00 0.00 3520.32 BCU-14 wp01 Tgt1 8 11477.05 16.22 57.65 10462.58 2023.63 3126.13 0.00 0.00 3723.94 Total Depth : 11477.05' MD, 10462.58' TVD 35052570087510501225140015751750192521002275245026252800South(-)/North(+) (350 usft/in)175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 2625 2800 2975 3150 3325 3500West(-)/East(+) (350 usft/in)BCU-14 wp01 Tgt137504000425045004750500052505500575060006250650077508 5 0 0 BCU 145 2505 5 0 05750600062506500675070007250775082508871BCU-14A7" x 8-1/2"4 1/2" x 6-1/8"4 2 5 0 4 5 0 0 4 7 5 0 5 0 0 0 5 2 5 0 5 5 0 0 5 7 5 0 6 0 0 0 6 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 0 7 5 0 0 7 7 5 0 8 0 0 0 8 2 5 0 8 5 0 0 8 7 5 0 9 0 0 0 9 2 5 0 9 5 0 0 9 7 5 0 1 0 0 0 0 1 0 2 5 010463 BCU-14B wp02KOP: 12.3º/100' : 3880' MD, 3747.51'TVD : 30° RT TFEnd Dir : 3897' MD, 3761.13' TVDStart Dir 3º/100' : 3917' MD, 3776.97'TVDEnd Dir : 4683.86' MD, 4386.3' TVDEnd Dir : 7548.03' MD, 6689.95' TVDTotal Depth : 11477.05' MD, 10462.58' TVDCASING DETAILSTVDTVDSS MDSize Name8852.29 8693.29 9800.00 7 7" x 8-1/2"10462.58 10303.58 11477.05 4-1/2 4 1/2" x 6-1/8"Project: Beaver Creek UnitSite: Beaver Creek Unit Pad 1AWell: Plan: Beaver CK Unit 14Wellbore: Plan: BCU-14BPlan: BCU-14B wp02WELL DETAILS: Plan: Beaver CK Unit 14Ground Level: 141.00+N/-S +E/-W Northing Easting Latitude Longitude0.00 0.002430071.36 314368.1960° 38' 51.159 N 151° 2' 3.701 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Beaver CK Unit 14, True NorthVertical (TVD) Reference: BCU 14B @ 159.00usft (169)Measured Depth Reference:BCU 14B @ 159.00usft (169)Calculation Method:Minimum Curvature 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 79'5HIHUHQFH 6LWH +LOFRUS$ODVND//& %HDYHU&UHHN8QLW %HDYHU&UHHN8QLW3DG$ 6WDQGDUG3URSRVDO5HSRUW :HOO :HOOERUH 3ODQ%HDYHU&.8QLW 3ODQ%&8% 6XUYH\&DOFXODWLRQ0HWKRG0LQLPXP&XUYDWXUH %&8%#XVIW 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RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: Beaver CK Unit 14 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 141.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002430071.36314368.19 60° 38' 51.159 N151° 2' 3.701 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Beaver CK Unit 14, True NorthVertical (TVD) Reference: BCU 14B @ 159.00usft (169)Measured Depth Reference:BCU 14B @ 159.00usft (169)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-05-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool161.00 3880.00 BCU 14 (BCU 14) 3_MWD+AX+Sag3880.00 4280.00 BCU-14B wp02 (Plan: BCU-14B) 3_MWD_Interp Azi+Sag4280.00 11477.05 BCU-14B wp02 (Plan: BCU-14B) 3_MWD+IFR1+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600Measured Depth (800 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 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