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Home My WebLink About222-054Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/8/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type BCU 09A 50133204450100 224113 11/13/2024 YELLOWJACKET GPT-PERF BCU 09A 50133204450100 224113 10/30/2024 YELLOWJACKET GPT BCU 11A 50133205210100 224123 11/9/2024 YELLOWJACKET SCBL BCU 25 50133206440000 214132 11/2/2024 YELLOWJACKET SCBL END 2-74 REVISED 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 HVA 10 50231200280000 204186 11/13/2024 YELLOWJACKET GPT-PERF KU 23-07A 50133207300000 224126 11/23/2024 YELLOWJACKET SCBL NCIU A-21 50883201990000 224086 11/29/2024 AK E-LINE CaliperSurvey PAXTON 6 50133207070000 222054 11/7/2024 YELLOWJACKET PERF PBU 01-37 50029236330000 219073 11/23/2024 BAKER MRPM PBU 06-15A 50029204590200 224108 12/26/2024 BAKER MRPM PBU 06-19B 50029207910200 224095 12/10/2024 BAKER MRPM PBU 07-29E 50029217820500 213001 11/26/2024 BAKER SPN PBU 14-31A 50029209890100 224090 11/10/2024 BAKER MRPM PBU 14-41A 50029222900100 224076 11/9/2024 BAKER MRPM SRU 241-33B 50133206960000 221053 11/5/2024 YELLOWJACKET GPT-PERF Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. T40053 T40053 T40054 T40055 T40056 T40057 T40058 T40059 T40060 T40061 T40062 T40063 T40064 T40065 T40066 T40067 PAXTON 6 50133207070000 222054 11/7/2024 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.07 13:25:23 -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: 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: 8,340' Total Depth measured 8,890 feet 8,444 & 8,636 feet true vertical 8,111 feet N/A feet Effective Depth measured 8,340 feet 1,740 feet true vertical 7,582 feet 1,571 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 12.6# / L-80 1,740' MD 1,578' TVD Liner Top Pkr; Packers and SSSV (type, measured and true vertical depth) Baker ONYX 1,740' MD 1,571' TVD 472' MD/471' TVD 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: Scott Warner, Operations Engineer 324-585 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 254 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 Tieback Assy 4-1/2" scott.warner@hilcorp.com 907-564-4506 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 120' 4 01442 0 730 75 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-054 50-133-20707-00-00 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: Private FEE, ADL0384372 Ninilchik / Belugla-Tyonek Gas Paxton 6 Plugs Junk measured Length Production Liner 7,156' Casing Structural 8,106'8,886' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,170' 7,500psi 2,980psi 6,880psi 8,430psi 2,170' 1,913' Burst Collapse 1,410psi 4,790psi 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 4:11 pm, Nov 20, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.11.20 15:56:39 - 09'00' Noel Nocas (4361) Page 1/1 Well Name: NINU Paxton 06 Report Printed: 11/13/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:10/29/2024 End Date: Report Number 1 Report Start Date 11/7/2024 Report End Date 11/8/2024 Last 24hr Summary PTW/PJSM. MIRU Yellow Jacket E-line. P-test to 250/3,000 psi. Perf the T-115 from 8,126' - 8,146' with well flowing. Init FTP: 719 psi, 15 min: 720 psi. SDFN. Report Number 2 Report Start Date 11/8/2024 Report End Date 11/9/2024 Last 24hr Summary PTW/PJSM. Perf the T-100 from 8,030' - 8,050' with well flowing. Init FTP: 719 psi, 15 min: 720 psi. Perf the T-81 from 7,677' - 7,697' with well flowing. Init FTP: 713 psi, 15 min: 715 psi. RDMO E-line. Field: Ninilchik Sundry #: 324-585 State: ALASKA Rig/Service:Permit to Drill (PTD) #:222-054Permit to Drill (PTD) #:222-054 Wellbore API/UWI:50-133-20707-00-00 _____________________________________________________________________________________ Updated by DMA 11-20-24 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 4724713.812 5.590 SSSV- Baker ONYX 2 1,494 1,3903.850 4.800 Chemical Inj Sub 3 1,7401,578 4.875 6.540 Liner hanger / LTP Assembly / Seal Assembly 4 1,9461,735-6.875Whipstock TOW 1,946 / BOW 1,960 5 1,9641,749-7.500Cement Retainer 6 8,3407,582 N/A N/A CIBP (4/16/24) 7 8,4447,682N/A N/A CIBP (4/12/24) 8 8,6367,863N/A N/A CIBP (2/26/24) OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface 36 bbls returned 4-1/2Est. TOC @ ~3,000 MD (CBL) T 146 5 8 PB1 1 3 2 4 PBTD = 8,802 / TVD = 8,027 TD = 8,890 / TVD = 8,111 T 142 - T 145 7 T 140 T 119 T 118 6 T 81 to T 115 RKB to GL = 18 16 9-7/8 hole 7-5/8 6-3/4 hole 4-1/2 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 X-56 Weld 15.01Surf 120 7-5/8"Surf Csg 29.7 L-80 CDC 6.875Surf 2,170 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.9581,7308,886 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958Surf 1,740 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Size Date Status T-81 7,677 7,697 6,941 6,961 20 2-3/4 6 SPF 11/8/24 Open T-100 8,030 8,050 7,283 7,254 20 2-3/4 6 SPF 11/8/24 Open T-115 8,126 8,146 7,376 7,395 20 2-3/4 6 SPF 11/7/24 Open T-118 8,224' 8,238' 7,470' 7,484' 14'2-3/4 6 SPF 4/17/24 Open T-119U 8,252' 8,270' 7,497' 7,515' 18'2-3/4 6 SPF 4/17/24 Open T-119L 8,288' 8,294' 7,546' 7,538' 6'2-3/4 6 SPF 4/16/24 Open T-140 8,359 8,369 7,600 7,610 10 2-3/4 6 SPF 4/12/24 Isolated T-142 8,451' 8,464' 7,689' 7,701' 13'2-3/4 6 SPF 02/27/24 Isolated T-144 8,563' 8,574' 7,797' 7,807' 11'2-3/46 SPF 02/27/24 Isolated T-145 8,615' 8,622' 7,847' 7,854' 7'2-3/46 SPF 02/27/24 Isolated T-146 8,642 8,660 7,873 7,89018 2-3/46 SPF 01/24/23 Isolated T-146 8,670 8,680 7,900 7,90910 2-3/46 SPF 01/24/23 Isolated T-146 8,681 8,744 7,910 7,97163 2-7/86 SPF 08/01/22 Isolated 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): 8,890'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Liner Top Pkr; Baker ONYX 1,740' MD/1,571' TVD; 472' MD /471' TVD 8,111'8,340'7,582' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINILCHIK UNIT PAXTON 6CO 701C Same 8,108'4-1/2" ~2566 psi 7,156' See Schematic Length October 11, 2024 Tieback Assy 4-1/2" 8,886' Perforation Depth MD (ft): See Attached Schematic 2,980psi 6,880psi 120'120' 2,170' Size 120' 2,170' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 1,740' 8,430psi 1,913' 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 Private FEE, ADL0384372 222-054 50-133-20707-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: 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 writte n 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 By Grace Christianson at 3:18 pm, Oct 08, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.10.08 14:44:09 -08'00' 324-585 10-404 SFD 10/8/2024 DSR-10/10/24 Perforate BJM 10/28/24 Perforations above the T-17 are not allowed under this sundry. Shallower perfs will require a cement plug above lower perfs and further approval from AOGCC. JLC 10/28/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.29 03:44:24 -08'00' 10/29/24 RBDMS JSB 102924 Well Prognosis Well: Paxton 6 Well Name: Paxton 6 API Number: 50-133-20707-00-00 Current Status: Producing Gas Well Permit to Drill Number: 222-054 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: 3320 psi @ 7546’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:2566 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.68 psi/ft using 13.1 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.68-0.1) = 2566 psi / 0.58 = 4424‘ TVD Top of Applicable Gas Pool: 1650’ MD/ 1509’ TVD Well Status: Online Gas Producer flowing at 350 mscfd, ~3 bwpd, 70 psi FTP Brief Well Summary Drilled in 2022 targeting the Pearl structure in the southern most portion of the Ninilchik Field and completed in the Tyonek 146 sand. Additional perforations were added in the T-146 in January of 2023 which increased production slightly, but the well has been on steady decline since. Water production began in ~ May of 2023 which increased production decline and ultimately prevented the well from flowing at the end of January 2024. Additional perforations were added in February and April of 2024 which got rate up to ~500 mscfd which has since declined to ~350 mscfd. The purpose of this sundry is to add additional perforations in the Tyonek and Beluga sands. Notes Regarding Wellbore Condition x Inclination o Max deviation of 43.77° @ 2,365’ MD o Max DLS of 7.21°/100’ @ 2,241’ MD x Recent Tags o 4/17/24: AK Eline ran GPT. No FL found at T-119L. Perforate T-119U 8252’ to 8270’. GPT while bleed off N2 from 1600 to 740 PSI. No LEL or FL. Perforate T-118 8224’ to 8238’ o 4/16/24: AK Eline Set CIBP at 8340'. Perforate T-119L Zone 8288’ to 8294’ Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /3,000 psi high 3. RIH and perforate T-115 – Beluga 115 sands from bottom up with 2-3/4” 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 BEL-115 ±4,356 ±4,376 ±3,729 ±3,748 ±20 BEL-115 ±4,386 ±4,394 ±3,758 ±3,766 ±8 T-6 ±5,186 ±5,192 ±4,531 ±4,537 ±6 T-17 ±6,012 ±6,032 ±5,330 ±5,349 ±20 pp Shallowest Allowable Perf TVD: , equivalent to 5075' MD SFD * Per Well Completion Report received 8/22/22, 9-7/8" intermediate hole size, with 7-5/8" intermediate casing. SFD Per calculations above, shallowest allowable perf is ~5,075' MD / 4,424' TVD. SFD MPSP/(0.68-0.1) = 2566 psi / 0.58 = 4424‘ TV * Perforations above the T-17 are not allowed under this sundry. Shallower perfs will require a cement plug above lower perfs and further approval from AOGCC. See attached email from Scott Warner 10/25/24 -bjm Well Prognosis Well: Paxton 6 T-67 ±7,489 ±7,499 ±6,759 ±6,769 ±10 T-81 ±7,677 ±7,697 ±6,941 ±6,961 ±20 T-100 ±8,030 ±8,050 ±7,283 ±7,254 ±20 T-115 ±8,126 ±8,146 ±7,376 ±7,395 ±20 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 DMA 07-05-24 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,740’1,578’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer 6 8,340’7,582 N/A N/A CIBP (4/16/24) 7 8,444’7,682’N/A N/A CIBP (4/12/24) 8 8,636’7,863’N/A N/A CIBP (2/26/24) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 8 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ T 142 - T 145 7 T 140 T 119 T 118 6 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Size Date Status T-118 8,224'8,238'7,470'7,484'14'2-3/4” 6 SPF 4/17/24 Open T-119U 8,252'8,270'7,497'7,515'18'2-3/4” 6 SPF 4/17/24 Open T-119L 8,288'8,294'7,546'7,538'6'2-3/4” 6 SPF 4/16/24 Open T-140 8,359’8,369’7,600’7,610’10’2-3/4” 6 SPF 4/12/24 Isolated T-142 8,451'8,464'7,689'7,701'13'2-3/4” 6 SPF 02/27/24 Isolated T-144 8,563'8,574'7,797'7,807'11'2-3/4”6 SPF 02/27/24 Isolated T-145 8,615'8,622'7,847'7,854'7'2-3/4”6 SPF 02/27/24 Isolated T-146 8,642’8,660’7,873’7,890’18 2-3/4”6 SPF 01/24/23 Isolated T-146 8,670’8,680’7,900’7,909’10 2-3/4”6 SPF 01/24/23 Isolated T-146 8,681’8,744’7,910’7,971’63 2-7/8”6 SPF 08/01/22 Isolated _____________________________________________________________________________________ Updated by SRW 9-27-24 PROPOSED Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,740’1,578’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer 6 8,340’7,582 N/A N/A CIBP (4/16/24) 7 8,444’7,682’N/A N/A CIBP (4/12/24) 8 8,636’7,863’N/A N/A CIBP (2/26/24) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 8 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ T 142 - T 145 7 T 140 T 119 T 118 6 BEL-115 to T 115 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Size Date Status BEL-115 ±4,356 ±4,376 ±3,729 ±3,748 ±20 2-3/4” 6 SPF TBD Proposed BEL-115 ±4,386 ±4,394 ±3,758 ±3,766 ±8 2-3/4” 6 SPF TBD Proposed T-6 ±5,186 ±5,192 ±4,531 ±4,537 ±6 2-3/4” 6 SPF TBD Proposed T-17 ±6,012 ±6,032 ±5,330 ±5,349 ±20 2-3/4” 6 SPF TBD Proposed T-67 ±7,489 ±7,499 ±6,759 ±6,769 ±10 2-3/4” 6 SPF TBD Proposed T-81 ±7,677 ±7,697 ±6,941 ±6,961 ±20 2-3/4” 6 SPF TBD Proposed T-100 ±8,030 ±8,050 ±7,283 ±7,254 ±20 2-3/4” 6 SPF TBD Proposed T-115 ±8,126 ±8,146 ±7,376 ±7,395 ±20 2-3/4” 6 SPF TBD Proposed T-118 8,224'8,238'7,470'7,484'14'2-3/4” 6 SPF 4/17/24 Open T-119U 8,252'8,270'7,497'7,515'18'2-3/4” 6 SPF 4/17/24 Open T-119L 8,288'8,294'7,546'7,538'6'2-3/4” 6 SPF 4/16/24 Open T-140 8,359’8,369’7,600’7,610’10’2-3/4” 6 SPF 4/12/24 Isolated T-142 8,451'8,464'7,689'7,701'13'2-3/4” 6 SPF 02/27/24 Isolated T-144 8,563'8,574'7,797'7,807'11'2-3/4”6 SPF 02/27/24 Isolated T-145 8,615'8,622'7,847'7,854'7'2-3/4”6 SPF 02/27/24 Isolated T-146 8,642’8,660’7,873’7,890’18 2-3/4”6 SPF 01/24/23 Isolated T-146 8,670’8,680’7,900’7,909’10 2-3/4”6 SPF 01/24/23 Isolated T-146 8,681’8,744’7,910’7,971’63 2-7/8”6 SPF 08/01/22 Isolated * Per calculations in application above, shallowest allowable perf is ~5,075' MD / 4,424' TVD. SFD * Perforations above the T-17 are not allowed under this sundry. Shallower perfs will require a cement plug above lower perfs and further approval from AOGCC. -bjm 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 McLellan, Bryan J (OGC) From:Scott Warner <Scott.Warner@hilcorp.com> Sent:Friday, October 25, 2024 10:14 AM To:McLellan, Bryan J (OGC) Cc:Davies, Stephen F (OGC); Donna Ambruz Subject:RE: [EXTERNAL] Paxton 6 (PTD 222-054) perf interval Bryan, Per phone conversaƟon, we will not perforate above the T-17 proposed perfs at 6012-6032 MD (5330-5349 TVD) unƟl a plug is set higher up in the wellbore and 25’ of cement is placed on top. As discussed, it is likely another plug will be needed before we want to perforate above the T-17 anyway and at that point all of the proposed perfs would be within the new shallowest allowable perf depths. Once a new plug is set and cement is dumped I will communicate that further and request approval prior to moving up hole to the T-6 and BEL-115 proposed perfs. Thanks, ScoƩ Warner Kenai – OperaƟons Engineer Oĸce: (907) 564-4506 Cell: (907) 830-8863 To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, October 17, 2024 1:53 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL] Paxton 6 (PTD 222-054) perf interval Scott, When doing the shallowest allowable perf calculations, you need to start with the deepest perf interval above the last zone that was abandoned with cement per 20 AAC 25.112. CIBP’s don’t count unless there is cement on top. In the case of this sundry application, none of the perfs above 4600’ TVD are allowed. If you dump bail cement 25’ of cement on top of plug at 8340’ MD, you could add perfs as shallow as 4400’ TVD, but that still excludes the top two proposed perf intervals. How would you like to proceed? 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. 2 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. 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: 5/10/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240510-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 242-04 50283201640000 212041 3/11/2024 AK E-LINE Perf LRU C-01RD 50283200610100 201168 4/26/2024 AK E-LINE Perf LRU C-02 50283201900000 223057 4/28/2024 AK E-LINE Perf MPU F-65 50029227526000 223121 5/3/2024 AK E-LINE HoistCut MPU L-07 50029220280000 190037 4/26/2024 AK E-LINE Perf NCIU A-17 50883201880000 223031 4/28/2024 AK E-LINE GPT/Perf NCIU B-02 50883200900100 197210 4/29/2024 AK E-LINE PPROF NCIU B-02 50883200900100 197210 5/4/2024 AK E-LINE PPROF PAXTON 6 50133207070000 222054 4/13/2024 AK E-LINE GPT/CIBP/Perf PAXTON 6 50133207070000 222054 4/16/2024 AK E-LINE GPT/CIBP/Perf SRU 14B-27 50133206040000 212089 4/23/2024 AK E-LINE Caliper SRU 32C-15 50133206130000 213070 4/24/2024 AK E-LINE Caliper TBU M-15 50733204220000 190109 4/18/2024 AK E-LINE GPT/Puncher TBU M-23 50733207190000 224018 5/1/2024 AK E-LINE CBL Please include current contact information if different from above. T38780 T38781 T38782 T38783 T38784 T38785 T38786 T38786 T38787 T38787 T38788 T38789 T38790 T38791 PAXTON 6 50133207070000 222054 4/13/2024 AK E-LINE GPT/CIBP/Perf PAXTON 6 50133207070000 222054 4/16/2024 AK E-LINE GPT/CIBP/Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 15:31:19 -08'00' 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: 8,340' Total Depth measured 8,890 feet 8,444 & 8,636 feet true vertical 8,111 feet N/A feet Effective Depth measured 8,340 feet 1,740 feet true vertical 7,582 feet 1,571 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)12.6# / L-80 1,740' MD 1,578' TVD Liner Top Pkr; Packers and SSSV (type, measured and true vertical depth)Baker ONYX 1,740' MD 1,571' TVD 472' MD/471' TVD 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: 7,500psi 2,980psi 6,880psi 8,430psi 2,170'1,913' Burst Collapse 1,410psi 4,790psi Production Liner 7,156' Casing Structural 8,106'8,886' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,170' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-054 50-133-20707-00-00 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: Private FEE, ADL0384372 Ninilchik / Belugla-Tyonek Gas Paxton 6 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 120' 0 0629 0 6330 70 Scott Warner, Operations Engineer 324-055 Sr Pet Eng: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 Tieback Assy 4-1/2" 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 3:05 pm, May 03, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.05.03 13:39:19 -08'00' DSR-5/6/24 RBDMS JSB 051524 Well Name: NINU Paxton 06 API #:50-133-20707-00-00 Field:Ninilchik Start Date:2/26/2024 Permit #:222-054 Sundry #:324-055 End Date:4/17/2024 2/26/2024 2/27/2024 4/12/2024 4/16/2024 4/17/2024 Activity Report PTW, JSA with AK E line and Fox N2 crew. MIRU E-line unit, N2 pump. WHP 1521 psi. Make up tools. Stab on well and pt 250/3000 psi. Run GPT for fluid level and correlate. Found fluid level 8,050'. Cool down N2. Onilne with N2 800 scf/min. Pumped 37,690 scf (405 gallons). Pressure broke over at 1813 psi. Pull GPT pass. Fluid level 8,475'. POOH to surace. Break down tools. Makeu up 4.5" CIBP. Run in hole pull correlation pass. Send to town. Shift +2'. Set CIBP at 8,444. POOH to surface. Make up gun run #1. RIH pull correlation pass for shooting T-140 sands from 8359'-8369' (10') with 2 3/4" gun loaded 6 spf, 60 degree phasing. 5,10,15 minute post perf readings 1214 starting, 1315 psi, 1443 psi, 1640 psi. Bull nose of gun was dry. Lay down E-line equipment. MIRU FOX N2. MIRU AK E-Line. PT 250/3000 PSI. Test good. GPT while N2 injecting to push water away. Broke over at 2500 PSI. 169,900 scf’s / 1824 gallons N2 total. Set CIBP. P/U 20' then go back down and tag CIBP at 8340'. Perforate T-119L Zone 8288’ to 8294’. SDFN. Plan Forward: GPT / Perforate T-119U Zone PJSM. SITP: 633 psi. MIRU AK E-line and Fox N2. P-test WL lubricator to 250/3000 psi - good. Pump N2 to push fluid level down. Ran GPT logging tools. Fluid level at 8686' and hard tag at 8690'. GIH with 3.75" gauge ring to 8642'. Set 10K CIBP at 8636'. LD tools and lubricator. Secure well. SITP 2300 psi. SDFN. PTW, PJSM. Rig AK E-line back on well (SITP 2333 psi), perforate the T-145 interval (8615'-8622'), draw tubing down to 1500 psi (no LEL). Run GPT (no fluid detected). RU Fox N2 and pressure tubing to 2980 psi, perforate the T-144 interval (8563'-8574') 50 psi pressure decrease. RIH and perforate the T-142 interval (8451'-8464'). Pressure dropped from 2900 psi to 2400 psi in 30 minutes. Secure well, RDMO E-line and N2. Flow back well to 1500 psi (no LEL). Hand over to production to continue flow testing. MIRU FOX N2. MIRU AK E-Line. GPT. No FL found at T-119L. Perforate T-119U 8252’ to 8270’. GPT while bleed off N2 from 1600 to 740 PSI. No LEL or FL. Perforate T-118 8224’ to 8238’. RDMO. Plan Forward: Flow test well. Daily Operations: Page 1 of 1 _____________________________________________________________________________________ Updated by SRW 05-03-24 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,740’1,578’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer 6 8,340’7,582 N/A N/A CIBP (4/16/24) 7 8,444’7,682’N/A N/A CIBP (4/12/24) 8 8,636’7,863’N/A N/A CIBP (2/26/24) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 8 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ T 142 - T 145 7 T 140 T 119 T 118 6 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Size Date Status T-118 8,224'8,238'7,470'7,484'14'2-3/4” 6 SPF 4/17/24 Open T-119U 8,252'8,270'7,497'7,515'18'2-3/4” 6 SPF 4/17/24 Open T-119L 8,288'8,294'7,546'7,538'6'2-3/4” 6 SPF 4/16/24 Open T-140 8,359’8,369’7,600’7,610’10’2-3/4” 6 SPF 4/12/24 Open T-142 8,451'8,464'7,689'7,701'13'2-3/4” 6 SPF 02/27/24 Isolated T-144 8,563'8,574'7,797'7,807'11'2-3/4”6 SPF 02/27/24 Isolated T-145 8,615'8,622'7,847'7,854'7'2-3/4”6 SPF 02/27/24 Isolated T-146 8,642’8,660’7,873’7,890’18 2-3/4”6 SPF 01/24/23 Isolated T-146 8,670’8,680’7,900’7,909’10 2-3/4”6 SPF 01/24/23 Isolated T-146 8,681’8,744’7,910’7,971’63 2-7/8”6 SPF 08/01/22 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: 5/1/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240501 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-13 50231200320000 207151 4/10/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 3/27/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 4/1/2024 YELLOW JACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/22/2024 YELLOW JACKET GPT-PERF KU 33-08 50133207180000 224008 4/30/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/23/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/11/2024 AK E-LINE GPT/Perf/CIBP MPU F-30A 50029226230100 213188 4/12/2024 READ CaliperSurvey MPU S-13 50029230930000 202114 4/16/2024 READ Caliper Survey NCI A-17 50883201880000 223031 3/22/2024 AK E-LINE Perf Paxton 6 50133207070000 222054 4/14/2024 AK E-LINE GPT/Perf PBU PTM P1-13 50029223720000 193074 4/8/2024 YELLOW JACKET CBL SRU 232-15 50133207140000 223091 3/28/2024 YELLOW JACKET GPT-PLUG-PERF SRU 232-15 50133207140000 223091 4/22/2024 YELLOW JACKET PLUG-PERF SRU 241-33B 50133206960000 221053 4/12/2024 YELLOW JACKET GPT-PERF SRU 241-33B 50133206960000 221053 4/4/2024 YELLOW JACKET GPT-PERF Please include current contact information if different from above. T38745 T38746 T38746 T38746 T38747 T38748 T38748 T38749 T38750 T38751 T38752 T38753 T38754 T38754 T38755 T38755 Paxton 6 50133207070000 222054 4/14/2024 AK E-LINE GPT/Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.05.13 09:32:35 -08'00' 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: 3/20/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240320 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/2/2024 AK E-LINE Perf CLU 14 50133206840000 219078 12/11/2023 AK E-LINE Perf IRU 41-01 50283200880000 192109 11/15/2023 AK E-LINE PERF KBU 22-06Y 50133206500000 215044 12/29/2023 AK E-LINE PERF MPU C-14 50029213440000 185088 3/4/2024 AK E-LINE Whipstock MPU L-62 50029236850000 220059 3/3/2024 AK E-LINE TubingPunch NCIU A-17 50883201880000 223031 12/13/2024 AK E-LINE GPT /Plug /Perf Paxton 6 50133207070000 222054 2/27/2024 AK E-LINE Plug/Perf PBU BORE V-109 50029231200000 202202 2/13/2024 AK E-LINE TubingPunch Please include current contact information if different from above. T38657 T38658 T38659 T38660 T38661 T38662 T38663 T38664 T38665 Paxton 6 50133207070000 222054 2/27/2024 AK E-LINE Plug/Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.21 13:14:02 -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: Install Cap String, 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): 8,890'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Liner Top Pkr; Baker ONYX 1,740' MD/1,571' TVD; 472' MD /471' TVD 8,111'8,802'8,027' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINILCHIK UNIT PAXTON 6CO 701C Same 8,108'4-1/2" ~3507 psi 7,156' N/A Length February 24, 2024 Tieback Assy 4-1/2" 8,886' Perforation Depth MD (ft): See Attached Schematic 2,980psi 6,880psi 120'120' 2,170' Size 120' 2,170' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 1,740' 8,430psi 1,913' 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 Private FEE, ADL0384372 222-054 50-133-20707-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: 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: m n P s 66 t 2 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 Samantha Coldiron at 11:06 am, Feb 07, 2024 324-055 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.06 17:37:36 - 09'00' Noel Nocas (4361) Perforate BJM 2/14/24 10-404 DSR-2/13/24SFD 2/8/2024 2710 psi -bjm *&:JLC 2/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.14 16:25:08 -06'00' RBDMS JSB 021524 Well Prognosis Well: Paxton 6 Date: 2/1/24 Well Name: Paxton 6 API Number: 50-133-20707-00-00 Current Status: Producing Gas Well Permit to Drill Number: 222-054 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) Max. Expected BHP: ~ 3507 psi @ 7,971’ TVD Based on .44 psi/ft gradient to bottom perf Max. Potential Surface Pressure ~ 2710 psi Based on 0.1 psi/ft gas gradient to surface Well Status: Shut in Gas Producer Well Summary Drilled in 2022 targeting the Pearl structure in the southern most portion of the Ninilchik Field and completed in the Tyonek 146 sand. Additional perforations were added in the T-146 in January of 2023 which increased production slightly, but the well has been on steady decline since. Water production began in ~ May of 2023 which increased production decline and ultimately prevented the well from flowing at the end of January 2024. The purpose of this sundry is to perforate additional footage in the Tyonek 55-145 sand to get the well flowing and increase production. Notes Regarding Wellbore Condition 08/01/2022 Perforated T-146 sand from: 8681 – 8744’ with 2-7/8” guns 01/23/2023 Perforated T-146 sand from: 8642-8680’ with 2-3/4” guns 01/30/2024 D&T w/ 2.5” to 8705’ MD. D&T w/ 3.5” blind box to find FL @ 6007’ MD Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,000 psi high 3. RU N2 unit, pressure up well to 2500 psi with N2 4. Run GPT to ensure fluid is pushed away, below 8632’ 5. RIH and set plug at 8632’ 6. RIH and perforate Tyonek 55- 145 sands from bottom up: Sand Top MD Btm MD Top TVD Btm TVD Interval T-55 ±7290' ±7297' ±6567' ±6573' ±7' T-67 ±7479' ±7499' ±6749' ±6769' ±20' T-67 ±7502' ±7509' ±6772' ±6779' ±7' T-80 ±7642' ±7647' ±6907' ±6912' ±5' T-81 ±7677' ±7699' ±6941' ±6963' ±22' T-91 ±7926' ±7931' ±7182' ±7187' ±5' T-98 ±7958' ±7967' ±7213' ±7222' ±9' T-100 ±8031' ±8050' ±7284' ±7302' ±19' T-115 ±8120' ±8154' ±7370' ±7403' ±34' T-118 ±8208' ±8243' ±7455' ±7489' ±35' T-119 ±8252' ±8295' ±7497' ±7539' ±43' T-119 ±8303' ±8308' ±7546' ±7551' ±5' T-140 ±8359' ±8369' ±7600' ±7610' ±10' T-142 ±8451' ±8464' ±7689' ±7701' ±13' Well Prognosis Well: Paxton 6 Date: 2/1/24 T-144 ±8546' ±8552' ±7780' ±7786' ±6' T-144 ±8563' ±8574' ±7797' ±7807' ±11' T-145 ±8615' ±8622' ±7847' ±7854' ±7' 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 h. Frac Calcs: using 13.1 ppg EMW FIT at the surface casing shoe (0.68 psi/ft) frac gradient i. Shallowest Allowable Perf TVD = MPSP/ (0.68-0.1) = 2710 psi / 0.58 = 4672’ TVD 7. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating i. RU Cap String Truck ii. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 2500 psi iii. RIH with 3/8” capillary string to ±8300’ MD a. Set cap string as deep as practical in fluid iv. Install slips and connect tubing to chemical injection pump v. Set spool of remaining line near well vi. RD cap string Unit, and turn well over to production Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Only the erfs between 7290 -8615' MD are permitted with this sundry without further approval. -bjm Shallowest Allowable Perf TVD = MPSP/ (0.68-0.1) = 2710 psi / 0.58 = 4672’ TVD _____________________________________________________________________________________ Updated by DMA 02-01-24 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,740’1,578’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Size Date Status T-146 8,642’ 8,660’ 7,873’ 7,890’18 2-3/4” 6 SPF 01/24/23 Open T-146 8,670’ 8,680’ 7,900’ 7,909’10 2-3/4” 6 SPF 01/24/23 Open T-146 8,681’ 8,744’ 7,910’ 7,971’63 2-7/8” 6 SPF 08/01/22 Open _____________________________________________________________________________________ Updated by SRW 02-06-24 PROPOSED Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,740’1,578’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer 6 ±8,632’±7,863’N/A N/A CIBP OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 6 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ T 55-T 145 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Size Date Status T-55 ±7,290'±7,297'±6,567'±6,573'±7'2-3/4” 6 SPF Proposed TBD T-67 ±7,479'±7,499'±6,749'±6,769'±20'2-3/4” 6 SPF Proposed TBD T-67 ±7,502'±7,509'±6,772'±6,779'±7'2-3/4” 6 SPF Proposed TBD T-80 ±7,642'±7,647'±6,907'±6,912'±5'2-3/4” 6 SPF Proposed TBD T-81 ±7,677'±7,699'±6,941'±6,963'±22'2-3/4” 6 SPF Proposed TBD T-91 ±7,926'±7,931'±7,182'±7,187'±5'2-3/4” 6 SPF Proposed TBD T-98 ±7,958'±7,967'±7,213'±7,222'±9'2-3/4” 6 SPF Proposed TBD T-100 ±8,031'±8,050'±7,284'±7,302'±19'2-3/4” 6 SPF Proposed TBD T-115 ±8,120'±8,154'±7,370'±7,403'±34'2-3/4” 6 SPF Proposed TBD T-118 ±8,208'±8,243'±7,455'±7,489'±35'2-3/4” 6 SPF Proposed TBD T-119 ±8,252'±8,295'±7,497'±7,539'±43'2-3/4” 6 SPF Proposed TBD T-119 ±8,303'±8,308'±7,546'±7,551'±5'2-3/4” 6 SPF Proposed TBD T-140 ±8,359'±8,369'±7,600'±7,610'±10'2-3/4” 6 SPF Proposed TBD T-142 ±8,451'±8,464'±7,689'±7,701'±13'2-3/4” 6 SPF Proposed TBD T-144 ±8,546'±8,552'±7,780'±7,786'±6'2-3/4”6 SPF Proposed TBD T-144 ±8,563'±8,574'±7,797'±7,807'±11'2-3/4”6 SPF Proposed TBD T-145 ±8,615'±8,622'±7,847'±7,854'±7'2-3/4”6 SPF Proposed TBD T-146 8,642’8,660’7,873’7,890’18 2-3/4”6 SPF 01/24/23 Isolated T-146 8,670’8,680’7,900’7,909’10 2-3/4”6 SPF 01/24/23 Isolated T-146 8,681’8,744’7,910’7,971’63 2-7/8”6 SPF 08/01/22 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. DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:+PB1, Mudlogs, CBL 7/19/22 & 7/23/22, Perf Logs NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 7/22/202240 8890 Electronic Data Set, Filename: Paxton 6 LWD Final.las 36822ED Digital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final MD.cgm36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final TVD.cgm36822EDDigital Data DF 7/22/2022 Electronic File: Paxton #6_DSR.txt36822EDDigital Data DF 7/22/2022 Electronic File: Paxton #6_DSR_GIS.txt36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 - Definitive Survey Report.pdf 36822ED Digital Data DF 7/22/2022 Electronic File: Paxton 6 - Final Surveys.xlsx36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6_DSR Actual_Plan.pdf36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6_DSR Actual_VSec.pdf36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final MD.emf36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final TVD.emf36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final MD.pdf36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final TVD.pdf36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final MD.tif36822EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 LWD Final TVD.tif36822EDDigital Data DF 7/22/202240 2650 Electronic Data Set, Filename: Paxton 6 PB1 LWD Final.las 36823ED Digital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final MD.cgm36823EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.cgm 36823ED Digital Data Tuesday, April 18, 2023AOGCCPage 1 of 8 PB1 Supplied by Op Supplied by Op Paxton 6 LWD Final.las Paxton 6 PB1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No DF 7/22/2022 Electronic File: Paxton #6 PB1_DSR.txt36823EDDigital Data DF 7/22/2022 Electronic File: Paxton #6 PB1_DSR_GIS.txt36823EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 PB1- Definitive Survey Report.pdf 36823ED Digital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final MD.emf36823EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.emf 36823ED Digital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final MD.pdf36823EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.pdf36823EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final MD.tif36823EDDigital Data DF 7/22/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.tif36823EDDigital Data DF 7/25/202210 8990 Electronic Data Set, Filename: Paxton 6.las36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Daily Reports.pdf36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Final Well Report.pdf36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log MD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log MD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log TVD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log TVD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log MD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log MD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log TVD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log TVD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log MD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log MD 5in.pdf 36824ED Digital Data Tuesday, April 18, 2023AOGCCPage 2 of 8 Paxton 6.las DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log TVD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log TVD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log MD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log MD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log TVD 2in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log TVD 5in.pdf 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log MD 2in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log MD 5in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log TVD 2in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Drilling Dynamics Log TVD 5in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log MD 2in.tif36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log MD 5in.tif36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log TVD 2in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Formation Log TVD 5in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log MD 2in.tif36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log MD 5in.tif36824EDDigital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log TVD 2in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Gas Ratio Log TVD 5in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log MD 2in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log MD 5in.tif 36824ED Digital Data Tuesday, April 18, 2023AOGCCPage 3 of 8 DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log TVD 2in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 LWD Combo Log TVD 5in.tif 36824ED Digital Data DF 7/25/2022 Electronic File: Paxton 6 Show Reports.pdf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6_DSR Actual_Plan.pdf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6_DSR Actual_VSec.pdf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final MD.emf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final TVD.emf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final MD.pdf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final TVD.pdf36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final MD.tif36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final TVD.tif36824EDDigital Data DF 10/5/202240 8890 Electronic Data Set, Filename: Paxton 6 LWD Final.las 36824ED Digital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final MD.cgm36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 LWD Final TVD.cgm36824EDDigital Data DF 10/5/2022 Electronic File: Paxton #6_DSR.txt36824EDDigital Data DF 10/5/2022 Electronic File: Paxton #6_DSR_GIS.txt36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 - Definitive Survey Report.pdf 36824ED Digital Data DF 10/5/2022 Electronic File: Paxton 6 - Final Surveys.xlsx36824EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1- Definitive Survey Report.pdf 36825ED Digital Data DF 10/5/2022 Electronic File: Paxton #6 PB1_DSR.txt36825EDDigital Data DF 10/5/2022 Electronic File: Paxton #6 PB1_DSR_GIS.txt36825EDDigital Data DF 10/5/202240 2650 Electronic Data Set, Filename: Paxton 6 PB1 LWD Final.las 36825ED Digital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final MD.cgm36825EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.cgm 36825ED Digital Data DF 10/5/2022 Electronic File: Paxton #6 PB1_DSR.txt36825EDDigital Data Tuesday, April 18, 2023AOGCCPage 4 of 8 Paxton 6 LWD Final.las Paxton 6 PB1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No DF 10/5/2022 Electronic File: Paxton #6 PB1_DSR_GIS.txt36825EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1- Definitive Survey Report.pdf 36825ED Digital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final MD.emf36825EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.emf 36825ED Digital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final MD.pdf36825EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.pdf36825EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final MD.tif36825EDDigital Data DF 10/5/2022 Electronic File: Paxton 6 PB1 LWD Final TVD.tif36825EDDigital Data DF 9/7/202210 2690 Electronic Data Set, Filename: Paxton 6 PB1.las36825EDDigital Data DF 9/7/2022 Electronic File: Paxton 6 Daily Reports.pdf36825EDDigital Data DF 9/7/2022 Electronic File: Paxton 6 Final Well Report.pdf36825EDDigital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Drilling Dynamics Log MD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Drilling Dynamics Log MD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Drilling Dynamics Log TVD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Drilling Dynamics Log TVD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Formation Log MD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Formation Log MD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Formation Log TVD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Formation Log TVD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Gas Ratio Log MD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Gas Ratio Log MD 5in.pdf 36825ED Digital Data Tuesday, April 18, 2023AOGCCPage 5 of 8 : Paxton 6 PB1.las DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No DF 9/7/2022 Electronic File: Paxton 6-PB1 Gas Ratio Log TVD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 Gas Ratio Log TVD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 LWD Combo Log MD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 LWD Combo Log MD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 LWD Combo Log TVD 2in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6-PB1 LWD Combo Log TVD 5in.pdf 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Drilling Dynamics Log MD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Drilling Dynamics Log MD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Drilling Dynamics Log TVD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Drilling Dynamics Log TVD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Formation Log MD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Formation Log MD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Formation Log TVD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Formation Log TVD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Gas Ratio Log MD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Gas Ratio Log MD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Gas Ratio Log TVD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 Gas Ratio Log TVD 5in.tif 36825ED Digital Data Tuesday, April 18, 2023AOGCCPage 6 of 8 DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No DF 9/7/2022 Electronic File: Paxton 6 PB1 LWD Combo Log MD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 LWD Combo Log MD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 LWD Combo Log TVD 2in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 PB1 LWD Combo Log TVD 5in.tif 36825ED Digital Data DF 9/7/2022 Electronic File: Paxton 6 Show Reports.pdf36825EDDigital Data DF 9/22/20228736 -18 Electronic Data Set, Filename: PAXTON_6_CBL_19-Jul-2022_(3864).las 37031ED Digital Data DF 9/22/2022 Electronic File: PAXTON_6_CBL_19-Jul- 2022_(3864).pdf 37031ED Digital Data DF 11/22/20228820 1446 Electronic Data Set, Filename: PAXTON 6 CBL MAIN PASS.las 37291ED Digital Data DF 11/22/2022 Electronic File: PAXTON 6 CBL FINAL.pdf37291EDDigital Data DF 11/29/20228780 8527 Electronic Data Set, Filename: PAX-6 GUN 1 CORRELATION.las 37310ED Digital Data DF 11/29/20228761 8546 Electronic Data Set, Filename: PAX-6 GUN 2 CORRELATION.las 37310ED Digital Data DF 11/29/20228760 8522 Electronic Data Set, Filename: PAX-6 GUN 3 CORRELATION.las 37310ED Digital Data DF 11/29/20228763 8539 Electronic Data Set, Filename: PAX-6 GUN 4 CORRELATION.las 37310ED Digital Data DF 11/29/2022 Electronic File: PAX-6 GUN 1 CORRELATION.pdf 37310ED Digital Data DF 11/29/2022 Electronic File: PAX-6 GUN 2 CORRELATION.pdf 37310ED Digital Data DF 11/29/2022 Electronic File: PAX-6 GUN 3 CORRELATION.pdf 37310ED Digital Data DF 11/29/2022 Electronic File: PAX-6 GUN 4 CORRELATION.pdf 37310ED Digital Data DF 11/29/2022 Electronic File: PAX-6 PERF FINAL.pdf37310EDDigital Data DF 2/6/20238780 8492 Electronic Data Set, Filename: Paxton 6_Perf_24-Jan-2023_(4145).las 37487ED Digital Data Tuesday, April 18, 2023AOGCCPage 7 of 8 DATA SUBMITTAL COMPLIANCE REPORT API No. 50-133-20707-00-00Well Name/No. NINILCHIK UNIT PAXTON 6 Completion Status 1-GASCompletion Date 8/1/2022 Permit to Drill 2220540 Operator Hilcorp Alaska, LLC MD 8890 TVD 8111 Current Status 1-GAS 4/18/2023 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:8/1/2022 Release Date:6/14/2022 DF 2/6/2023 Electronic File: Paxton 6_Perf_24-Jan- 2023_(4145).pdf 37487ED Digital Data 9/8/20222160 2650 Paxton 6 PB111812Cuttings 9/8/20221946 8890 Paxton 6 mainbore61813Cuttings Tuesday, April 18, 2023AOGCCPage 8 of 8 M. Guhl 4/18/2023 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU C-07 50029212660000 185002 1/20/2023 AK E-LINE Perf Paxton 6 50133207070000 222054 1/24/2023 AK E-LINE Perf TBF A-07 50733200360000 167046 1/13/2023 AK E-LINE CBL TBF A-18 50733201430000 168076 1/22/2023 AK E-LINE Tubing Punch TBU D-09RD 50733201310100 181080 1/18/2023 AK E-LINE LDL Please include current contact information if different from above. By Meredith Guhl at 11:24 am, Feb 06, 2023 T37486 T37487 T37488 T37489 T37490 Paxton 6 50133207070000 222054 1/24/2023 AK E-LINE Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.06 11:33:21 -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: ______________________ 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 8,890 feet N/A feet true vertical 8,111 feet N/A feet Effective Depth measured 8,802 feet 1,740 feet true vertical 8,027 feet 1,578 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 12.6# / L-80 1,740' MD 1,578' TVD Packers and SSSV (type, measured and true vertical depth) Liner Top Pkr; N/A 1,740' MD 1,578' 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: 7,500psi 2,980psi 6,880psi 8,430psi 2,170' 1,913' Burst Collapse 1,410psi 4,790psi Production Liner 7,156' Casing Structural 8,106'8,886' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,170' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-054 50-133-20707-00-00 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: Private FEE, ADL0384372 Ninilchik / Belugla-Tyonek Gas Paxton 6 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 120' 0 06363 0 8330 832 Jake Flora, Operations Engineer 323-011 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 6390 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 jake.flora@hilcorp.com 907-777-8442 N/A Tieback Assy 4-1/2" p k ft t Fra O s O 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 Meredith Guhl at 3:04 pm, Jan 27, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.01.27 14:57:55 -09'00' Noel Nocas (4361) Rig Start Date End Date E-Line 1/24/23 1/24/23 01/24/2023 - Tuesday AKE-line obtain PTW and hold PJSM. Discuss Simops with Pad expansion crew and scope of work. Spot WL truck and crane. Begin RU. MU (Gun #1) - 2-3/4" OD x 10' perf gun (6spf/60D) with 3-1/8" Gun Gamma Ray/CCL. Move tools and lubricator to well head. PT 250/3000 psi. Pass. FTP - 822psi @ 6037 mcfd. Open swab, RIH. Tag PBTD at 8788' and log correlation pass. Confirm tie-in on depth with RE. Position gun and shoot T- 146 add perfs at 8670'-8680'. POOH. OOH. MU (Gun #2) 2-3/4" x 18' gun. FTP - 830 psi @ 6698 mcfd. Open swab and RIH. Log tie-in pass, confirm, position and shoot T-146 add perfs at 8642'-8660'. POOH. OOH. Secure well and RD. Turn well over to production. Final FTP - 832 psi @ 6935 mcfd (12 bbls fluid) Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 6 50-133-20707-00-00 222-054 _____________________________________________________________________________________ Updated by DMA 01-27-23 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 4724713.812 5.590 SSSV- Baker ONYX 2 1,494 1,3903.850 4.800 Chemical Inj Sub 3 1,7401,578 4.875 6.540 Liner hanger / LTP Assembly / Seal Assembly 4 1,9461,735-6.875Whipstock TOW 1,946 / BOW 1,960 5 1,9641,749-7.500Cement Retainer OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface 36 bbls returned 4-1/2 Est. TOC @ ~3,000 MD (CBL) T 146 5 PB1 1 3 2 4 PBTD = 8,802 / TVD = 8,027 TD = 8,890 / TVD = 8,111 RKB to GL = 18 T 146 16 9-7/8 hole 7-5/8 6-3/4 hole 4-1/2 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 X-56 Weld 15.01Surf 120 7-5/8"Surf Csg 29.7 L-80 CDC 6.875Surf 2,170 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.9581,7308,886 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958Surf 1,740 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status T-146 8,642 8,660 7,873 7,89018 2-3/4 6 SPF 01/24/23 Open T-146 8,670 8,680 7,900 7,90910 2-3/4 6 SPF 01/24/23 Open T-146 8,681 8,744 7,910 7,97163 2-7/8 6 SPF 08/01/22 Open 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,890'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,430psi8,108'8,886' 120' 2,170' Perforation Depth MD (ft): 7,156'4-1/2" 16" 7-5/8" 120' 2,170' 2,980psi 6,880psi 120' 1,913' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 8,111'8,802'8,027'~2,589psi N/A MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Private FEE, ADL0384372 222-054 50-133-20707-00-00 Ninilchik Beluga/Tyonek Gas Same CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Paxton 6 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 12.6# / L-80 1,730' January 25, 2023 Liner Top Pkr; N/A 1,740' MD/1,571' TVD; N/A See Schematic See Schematic Tieback Assy 4-1/2" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 m n P s t _ 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 2:03 pm, Jan 11, 2023 323-011 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.01.11 10:45:02 -09'00' Noel Nocas (4361) SFD 1/11/2023BJM 1/17/23 DSR-1/12/23 10-404 Brett W. Huber, Sr. GCW 01/17/23 JLC 1/17/2023 1/17/23 RBDMS JSB 011923 Well Prognosis Well Name: Paxton 6 API Number: 50-133-20707-00-00 Current Status: Gas Producer Permit to Drill Number: 222-054 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum Expected BHP: ~3479 psi @ 7909’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~2689 psi (Max expected BHP - gas to surface) Well Status: Online Producer making 6500 mcfd at 850 psi Brief Well Summary Drilled in 2022 targeting the Pearl structure in the southern most portion of the Ninlichik Field and completed in the Tyonek 146 sand. The purpose of this sundry is to perforate additional footage in the Tyonek 146 sand to determine if the increased height will also increase productivity. Notes Regarding Wellbore Condition: 08/01/2022 Perforated T-146 sand from: 8681 – 8744’ with 2-7/8” guns Procedure 1. RU E-line, PT lubricator to 3000 psi 2. Perforate below Tyonek sands from the bottom up: Top Tyonek 146 8640’ MD 7871’ TVD Bottom Tyonek 146 8680’ MD 7909’ TVD a) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic _____________________________________________________________________________________ Updated By: JMF 01/11/23 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,730’1,570’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer T 146 5 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Size Date Status T-146 8,681 8,744 7,910 7,971 63 2-7/8” 6 SPF 08/01/22 Open _____________________________________________________________________________________ Updated By: JMF 01/11/23 PROPOSED Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,730’1,570’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’-7.500”Cement Retainer OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 PB1 1 3 2 4 PBTD = 8,802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ RKB to GL = 18’ T 146 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Size Date Status T-146 8,640 8,680 7,871 7,909 planned T-146 8,681 8,744 7,910 7,971 63 2-7/8” 6 SPF 08/01/22 Open Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PAXTON 6 50133207070000 222054 8/1/2022 Yellowjacket PERF BCU-7A 50133202840100 214060 8/2/2022 Yellowjacket GPT-PERF KBU 43-07Y 50133206250000 214019 8/3/2022 Yellowjacket PERF KBU 22-06Y 50133206500000 215044 8/4/2022 Yellowjacket GPT-PERF SRU 32A-33 50133101640100 191014 8/21/2022 Yellowjacket GPT-PERF HVB 16A 50231200400100 222070 8/23/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/26/2022 Yellowjacket PERF HVB-16A 50231200400100 222070 8/27/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/29/2022 Yellowjacket PERF KALOTSA 4 50133206650000 217063 9/1/2022 Yellowjacket GPT-PERF KALOTSA 4 50133206650000 217063 9/6/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:26 am, Nov 29, 2022 T37305 T37306 T37306 T37307 T37307 T37308 T37309 T37310 T37311 T37311 T37312 PAXTON 6 50133207070000 222054 8/1/2022 Yellowjacket PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:43:24 -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: 11/22/2022 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 PAXTON 6 50133207070000 222054 7/23/2022 AK E-Line CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.22 13:28:54 -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: 10/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL **** REVISED/RE-ISSUE **** The Logs for Paxton 6 and Paxton 6PB1 were revised due to a recently identified calibration error with the CTN tool. The tool was recalibrated and the affected curve data was reprocessed. PAXTON 6 + PAXTON 6PB1 - PTD 222-054 - API 50-133-20707-00-00 + 50-133-20707-70-00 FINAL LWD FORMATION EVALUATION LOGS (06/24/2022 to 07/08/2022) AGR, EWR-M5, DGR, ADR, PCG, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Main Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. PTD:222-054 Paxton 6: T36822 Paxton 6 PB1: T36823 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 09:27:32 -08'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/21/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220921 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # HVB B-16A 50231200400100 222070 8/5/2022 YellowJacket CBL Paxton 6 50133207070000 222054 7/23/2022 AK E-Line CBL NCIU A-09A 50883200290100 222024 8/6/2022 AK E-Line CBL NCIU A-11A 50883200310200 222013 8/15/2022 Halliburton CBL NCIU A-10B 50883200300200 222025 8/16/2022 Halliburton CBL Please include current contact information if different from above. T37029 T37031 T37030 T37033 T37032 Paxton 6 50133207070000 222054 7/23/2022 AK E-Line CBL Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.22 13:28:56 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL:148.5' BF:148.5' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" X-56 120' 7-5/8" L-80 1,913' 4-1/2" L-80 8,108' 4-1/2" L-80 1,577' 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 Rate1490 July 8, 2022 June 24, 2022 Private FEE, ADL 384372 LOCI 04-007 N/A 1,946' MD / 1,735' TVDN/A 472' MD / 471' TVD 8,890' MD / 8,111' TVD Logging while drilling logs+PB1, Mudlogs, CBL 7/19/22 & 7/23/22, Perf Logs Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 009803 Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A9803 Flowing 8,714' - 8,719' MD / 7,942' - 7,947' TVD 2-7/8" 6 SPF 8/1/22 8,681' - 8,744' MD / 7,910' - 7,971' TVD 2-7/8" 6 SPF 8/1/22 0 Water-Bbl: PRODUCTION TEST 8/2/2022 Date of Test: 0 8/11/2022 24 Flow Tubing 0 84# 29.7# 120' 1,730' 8,886' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 12.6# 1,740' 1,571' Surface DEPTH SET (MD) PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 12.6# 203912 203887 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 2228750 BOTTOM TOP 6-3/4" 36 bbls Surface 9-7/8" HOLE SIZE AMOUNT PULLED 50-133-20707-00-00 Paxton 6 206366 2230578 2537' FNL, 94' FEL, Sec 14, T1S, R14W, SM, AK CEMENTING RECORD 2228794 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/1/2022 784' FNL, 2960' FEL, Sec 13, T1S, R14W, SM, AK 2581' FNL, 118' FEL, Sec 14, T1S, R14W, SM, AK 222-054 / 322-388 Ninilchik Field / Beluga/Tyonek Gas Pool 166.5' 8,802' MD / 8,027' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Driven Surface 2,170' L - 255 sx / T - 157 sx Driven L - 540 sx / T - 95 sx Surface SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Tieback Assy.Tieback TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks on 8.22.2022 Completed 8/1/2022 JSB RBDMS JSB 083022 GDSR-9/1/22DLB 09/16/2022 Paxton 6 WCB 04/17/2023 222-054 / 322-388 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval T-146 8714' 7942' 721' 714' 1042' 1014' 1927' 1751' 3678' 3087' 4676' 4028' 4759' 4119' 5170' 4515' 6489' 5790' 7603' 6869' 7972' 7226' 8094' 7344' 8348' 7589' 8624' 7855' T 150 8841' 8064' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). T-100 T-110 T-140 T-146' Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. T-80 Formation at total depth: Bel 88 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys + PB1, Csg and Cmt Reports. Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME T-40 Bel 136 Bel A Bel 30 ST 3 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Tyonek T-10 Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 8.22.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.08.22 13:39:27 -08'00' Monty M Myers _____________________________________________________________________________________ UpdatedBy: CJD 8/22/22 SCHEMATIC Ninilchik Unit Paxton 6 PTD: 222-054 API: 50-133-20707-00-00 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 472’471’3.812 5.590 SSSV- Baker ONYX 2 1,494 1,390’3.850 4.800 Chemical Inj Sub 3 1,730’1,570’4.875”6.540”Liner hanger / LTP Assembly / Seal Assembly 4 1,946’1,735’-6.875”Whipstock TOW 1,946’ / BOW 1,960’ 5 1,964’1,749’--Cement Retainer OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface 36 bbls returned 4-1/2”Est. TOC @ ~3,000’ MD (CBL) T 146 5 PB1 1 3 2 4 PBTD = 8802’ / TVD = 8,027’ TD = 8,890’ / TVD = 8,111’ RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 2,170’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,730’8,886’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,740’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Size Date Status T-146 8,714 8,719 7,942 7,947 5 2” 6 SPF 08/01/22 Open T-146 8,681 8,744 7,910 7,971 63 2-7/8” 6 SPF 08/01/22 Open 7-5/8"Surf Csg 4-1/2”Est. TOC @ ~3,000’ MD (CBL) 2,170’ 7-5/8"TOC @ Surface 36 bbls returned Activity Date Ops Summary 6/15/2022 Check on Paxton 6 and confirm needs to be leveled. Contact grader and said later today. CCI gather up matting boards from there yard and take to Paxton pad along with there loader. Gather up all small equipment;at Beaver Creek Pad and take to Paxton Pad. After all current crew members arrive at Drilling Warehouse and individuals confirmed that are going to Rig 147. We do not have the personnel to break tours today.;Button up and seal TD unit for an on location install of drive motor. Continue working projects at drilling warehouse. Remove 2000 gallons from fuel tank at Beaver Creek and bring it back to Drilling warehouse tank.;Work on removing triplex from skid at Drilling Warehouse. Bend tubing for new auxiliary diesel tank for Rig 169. Update from grader operator that they will not be on Paxton Pad until tomorrow morning. Break for day and let crew rest. 6/16/2022 PJSM with rig crew for moving the rig. Prepared rig modules to be moved. Trucks arrived at 07:00hrs. Moved all rig modules off of the matting boards except the derrick and sub base and staged on pad for loading. Load out loads and began moving rig modules to Paxton pad.;Cranes arrived and spotted to double pick the derrick and sub base. At Paxton pad observed that well#5 tree was still in place. Contacted town and production that tree and flowline needed to be nippled down. Began to level pad for the rig.;Received rig modules from Beaver Creek and offloaded on the Paxton pad.;Double Picked the derrick and sub base with cranes and loaded out same. Trucks returned to Beaver Creek and were loaded out with rig modules and sent to Paxton Pad. Pulled up matting boards and stacked on a trailer. Folded up rig underlayment and secured same.;Wireline arrived at Paxton 5. Set a sleeve and prong in the WR-SSSV. Pressure tested prong with passing results. Removed the electrical components from the flowline. Set a BPV in the tubing hanger. N/D the tree and flowline.;Loads remaining at Beaver Creek: BOP, HPU, Wind walls,1 Mud pit unit, 3 office and living quarter units, breakroom and change house. Will continue to move tomorrow morning. Release crews for rest will break tours tomorrow. 6/17/2022 Remove Cellar containment boards from Paxton 5 and continue with pad prep for Paxton 6. Lay 12' X 8" X 1" steel plate on top of cellar box at well #5 and blend in with pad prep area. Prep modules by installing hand rails and lights.;Continue with pad prep as scheduled to level everything out. Prep and move Break shack, Crew shack and generator shack from Beaver Creek to Susan Dion pad. Continue working on projects at drilling warehouse.;Prep and rig down DSM, TP and Sleeper modules and transport to Susan Dion pad. Continue leveling pad for rig. Lay Felt, Liner and install matting boards. Mark spot on where center of well #5 is located to ensure crane downriggers;do not set in this area when lifting and installing Draworks skid and Derrick. Continue working on projects at the drilling warehouse. Complete laying matts and set pony subs. 6/18/2022 Set HPU inside pony subs and crib in area above well # 5 for setting pit modules. PJSM with Rig Move Coordinator and full Parker crews and discuss hazards associated with rigging up along with communication expectations;Bring sub base onto rig matts and position cranes. Lift and set sub base. Bring in Draworks skid and set on matts, Lift with cranes and set on sub base. Bring in trailer with derrick, remove drilling spool and set on draworks skid..;Lift derrick and attach to sub base. Lift derrick board wind walls and secure pins. Set pit module # 1, Lift iron roughneck and pin into position on rig floor. Set pi module #2. Connect all lines as modules are set.;Re-adjust pit module #2 to accept jig and set. Raise mast to half derrick. Set mud pump #1 skid. Crane choke house and pin to sub base. Set HPU skid. Set mud pump #2 skid, Set genset #1 & #2 skid. Set pit module #3, Set boiler module.;Set accumulator/ water tank module. Lay felt, liner and matts for catwalk. Bring catwalk close to position and lower to ground with bed truck. Lift catwalk skid with crane and set in place. Continue hooking up all modules as they are .;placed. Set MGS skid. Set up DSM, Toolpusher and sleeper camps with generator. Set up crew change shack, break room, generator trailer, mechanic shop and electrician shop. 6/19/2022 Set Generator #3 module, Rig up Mud Gas Separator, Move catwalk over with loader for correct alignment, Continue working on communication lines including Pason and Gai-Tronic system. Cleaning out all grease from mud pumps;and pull equipment to dress pumps with 5-1/2" liners. Wellhead technician and welders complete permits and install starting head on conductor. Rig up air, water and fuel lines.;Clean out dirt work from end of catwalk to allow traffic to get on drillers side of rig. Level catwalk and MGS. Start spooling drill line on main drum.;Complete spooling on drill line to main drum. Complete installation of starting head. Secure upper section of torque tube. Perform derrick inspection. Check all generators and sync. Confirm ESD's are working as designed.;Continue dressing mud pumps with 5-1/2" liners. PJSM, Review derrick scoping procedure and raise top section of derrick. Install T-Bar for torque tube.;Continued to dress the pumps with 5 1/2" liners. Function tested the Iron Roughneck. C/O the leaking air fittings on the air tank on the drawworks skid. Installed the lighting and and wind sock on the pipe skate control unit. Installed stairs on the shaker house landings.;Installed a gasket in the choke line at the drill floor connection. Installed the crown-o-matic and installed the weight indicator sensor to the dead line. Observed the electrical plug for the sensor needs repair. Installed a light on the Generator#3 module.;Hooked up the water supply line to the boiler. Installed the shaker screen gaskets on the shakers.;Performed the derrick inspection and dressed out the derrick board. Synced the generators. Installed a dresser sleeve on the equitization line between pit modules 1 and 2. Removed the shipping beams from the subbase. Cleaned and organized the choke house. Rigged up the boiler. 6/20/2022 Checked bottles in Accumulator room and replaced two shrader valves. Functioned ESD's again and observe air line leaking. Repaired air line for ESD kill on rig motors. Repaired Pason plug, Cable and pit sensor. Continue troubleshooting Pason system. Pick up Top Drive and torque bushing. Connected;accumulator hoses to Accumulator skid. Begin connecting up top drive. Receive equipment for diverter Tee, Knife valve, Vent line, drill pipe and HWDP. Install Handy Berm around entire rig.;Complete connecting top drive and torque bushing. Crane in and install clamshell for iron roughneck. Crane in feed pump, centrifuge and control panel. Connect lines for centrifuge. Receive and spot MWD, Geo-Log and Mud man shacks. Spot all third party shacks.;Connected the water line from well to water tank, installed a valve on the water tank and begin to fill the rig water tank. Installed shaker screens. Measured from the rig floor to the lockdowns 19.9' and rig floor to GL 17.8'.;N/U 21 1/4" Diverter T and diverter. Had to N/D the DSA on the bottom of the T to orient the run of the diverter line.;Continued to N/U the Diverter, knife valve and diverter line to end of catwalk. Connect koomey lines and function test. Installed the bell nipple. Installed the flow line. Chained down the diverter. Continued to work the rig acceptance check list. 18 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Paxton 06 Ninilchik Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: 221-00072 Job Name:221-00072 Paxton 6 Drilling Spud Date: 6/21/2022 Prepare Top Drive and Drive motor for installation, Transferred fluid through pits, Installed drive motor on Top Drive, Recalibrated all centrifuge switches, Offloaded mud product and organized same, Laid out and tallied HWDP and drill pipe. Production bring in two 500 bbl tanks and spot.;Continue to work through crossover subs at rig tenders.;Change oil in gearbox on Top Drive, Function test centrifuge, Install swivel packing, Connect service lines and mud pump line on Top Drive, Complete Diverter vent line. Change out leaky hydraulic fitting on Top Drive. Installing Pit 1 sensor, Function test Top Drive. Install bales and elevators.;Installed the saver sub on the top drive. Changed the dies in the top drive grabber box. Adjusted the load collar for the bales on the top drive. Adjusted the turnbuckles on the torque tube. Secured the bridal lines. Ran the wear bushing.;P/U 16 jnts 37PPF CDS40 HWDP and racked back in the derrick(broke in all recut connections as per recommended break-in procedure). P/U 4 12/" 16.5ppf S-135 CDS40 DP.;Cont. to P/U 4 1/2" DP total 60jnts racked back in the derrick. Organized and cleaned the parts containers. Organized the sub rack. Organized subs on the rig floor. Work the rig acceptance check list. Organize bits and handling tools. 6/22/2022 Continue building stands of 4-1/2" Drill Pipe, Fill pits with water and start mixing KCL mud. At 08:35 send notification to AOGCC of intent to function Diverter on 6/24/2022 at 09:00 hours. AOGCC Jim Regg waives witness on diverter function test at 09:17 hours.;Held meeting on Hand placement, Line of fire and overhead hazards. Walked through rig in teams of two identifying situations that could harm individuals and what the mitigations would be.;Continue building stands of 4-1/2" Drill Pipe, Continue organizing and cleaning rig. Start a new Rig Acceptance checklist.;Discuss recent incidents in industry and perform hazard hunts in teams of two and discuss hand positions, Line of fire and Overhead hazards.;Receive 58 joints of 7-5/8" 29.7# Casing and remove thread protectors and drift same. Continue with rig acceptance checklist. Clean and organize around rig, Build two more stands of drill pipe and tag bottom at 109'. Make up drilling jar stand and stand back. Total DP in derrick is 118 jts.;Tallied the 7 5/8" 29.7# L-80 USS-CDC casing and installed the thread protectors. Cleaned and organized around the rig. Continued building 300bbls 6%KCL mud. Surface checked the MWD tools on location.;Continued to organize the rig sub rack. Cleaned and organized around the rig. Wash the rig floor area, pit modules, generator modules, and HPU. Increased the mud pump 1 pulsation dampener to 600psi. Tightened the fan belts on Generator 2. Painted and plumbed the mud tank weigh station.;Continued to surface check the MWD tools on location. 6/23/2022 Begin building 8.8 ppg spud mud, Gyro data personnel arrived on location and confirmed that we are set up with Halliburton UBHO sub on location. Laid out BHA #1 on catealk. Prepped handling tools, tongs and iron roughneck for assembly of BHA. Repaired exhaust fans in hopper rooms, filled boiler with;water, continue cleaning, Inspected fall ascent equipment and replaced two carabiners and took one SALA block out of service. Built 100 BBLs of 8.8 ppg spud mud.;Continue building 8.8 ppg spud mud. Verify BHA #1 with Sperry DD/ MWD. Inspect handling equipment for BHA. Check all high pressure connections on mud lines. Fire up boiler and bring up to operating pressure. Receive cement to upright on location.;Continued to clean and organize around the rig. Continued to build spud mud 337bbls total. Fluid packed the mud lines and mud pumps. Pressure tested the mud lines and checked for leaks. No leaks. Located the bushing saver and brought to the rig floor. Completed the rig acceptance checklist.;Checked oil level in the agitator gear boxes and added where needed. Installed the crank valve for the gas analyzer. Picked up the e-kelly for testing the diverter system.;Tested the 21 1/4" diverter and knife valve OK. Witness waved by Jim Reg AOGCC. Filled the hole w/18bbls spud mud and checked for leaks, No leaks. Tested Rig PVT alarms. Table top diverter drill with all of the rig hands and all 3rd party hands on location.;Begin to install and test the rig gas alarms. Rig accepted at 06:00hrs 06/24/2022. 6/24/2022 Rig accepted at 0600 hours. Continue installing gas alarms and test same.;Gather essential personnel and hold pre spud meeting talking through anti collision plan and ensure are aware of all hazards to keep an eye on when spudding the well.;Load mud motor in skate and bring up to V-Door. Confirm Non Ported plunger float installed in top of motor. Pick up mud motor and make up 9-7/8" PDC 5 rib bit. M/U crossover and 1 stand of 4-1/2" HWDP and RIH T/ 95'. M/U another stand and M/U Top Drive. Wash & Ream F/ 95' T/ 129' @ 347 GPM W/ 354psi;while rotating at 30 RPM. Observe torque at 129' Observe clean gravel at surface from bottoms up.;POOH and stand back HWDP and break off crossover sub and make up BHA #1 MWD tools from bottom stabilizer to UBHO sub, M/U crossover and make up Top Drive. P/U and upload data to MWD tools.;Continue to upload data to MWD tools and shallow pulse test tools. PJSM and load sources.;M/U stand of 4-1/2" HWDP and drill ahead F/ 129'. Wash pipe on Top Drive leaking. Shut down pump and stand back HWDP lower Top Drive to floor and change out wash pipe assembly.;Drill ahead F/ 129' T/ 233' GPM 450, SPP 1120psi, Diff 160psi, RPM 30, Torque 3.5K, WOB 3-5K, PUW 26K, SOW 26K, ROT 26K.;POOH F/ 233' T/ 108' PUW 26K, SOW 26K.;PJSM with e-line crew and Gyro hand. R/U wireline sheaves for Gyro runs.;P/U and M/U flex collars and RIH. M/U stand of HWDP and wash down to bottom at 233'.;Run Gyro and calibrate Gyro tool set tool face for drilling assembly at 190°. POOH with Gyro and continue drilling ahead @ 233' and drill T/ 250 at 460 GPM, SPP 1080psi, Diff 113psi, RPM 30, Torque 3.5K, WOB 3-5K, PUW 26K, SOW 26K, ROT 26K.;Drill ahead F/250' to 294' 450GPM, SPP 1010psi, Diff 110psi, RPM 45, WOB 2-3K, P/U 30K, SOW 30K ROT 30K.;Run Gyro survey. Slide drill F/294' to 324' MTR RPM 139. Rotary drill F/324' to 356'. 450 GPM, 1100psi, Diff 120psi, RPM 45, TQ 3K, WOB 2-3K, PUW 34K,SOW 33K,ROT 34K B/R stand out and MAD pass back to TD. Gyro on e-line survey @ 241'.;Slide drill F/356' to 386' MTR RPM 139. Rotary drill F/386' to 415' 450GPM, 1100psi, Diff100psi, RPM 50, TQ 3K, WOB 2-3, PUW 34K, SOW 33K, ROT 34K B/R stand out and MAD pass back to TD. Gyro survey on e-line @ 300'.;Slide drill F/415' to 445' MTR RPM 139. Rotary drill F/445' to 476' 450GPM, 1100psi, Diff 50psi, RPM50RPM, TQ 3K, WOB 2-3K, PUW 34K, SOW 33K, ROT 34K B/R the stand out and MAD pass back to TD. Gyro survey on e-line @ 361.;Pull 2 stand and rack back. M/U jar stand and RIH to 476'.;Rotary drill 476' to 481'. Run Gyro survey on e-line @ 361', Slide drill 481' to 511' MTR RPM 139. Rotary drill 511' to 541'. 450GPM, 1150psi, Diff 25psi. 55RPM, TQ 3.5K, WOB 2-3K, PUW 34K, SOW 33K, ROT 34K B/R stand out and MAD pass back to TD. Gyro survey on e-line@ 424'.;Slide drill 541' to 571' MTR RPM 139. Rotary drill 571' to 601 '. 450GPM, 1200psi, Diff 25psi. 50RPM, TQ 3.5K, WOB 2-3K, PUW 34K, SOW 33K, ROT 34K B/R stand out and MAD pass back to TD. Run Gyro survey on e-line @ 485'.;Slide drill 601' to 636'MTR RPM 139. Rotary drill 636' to 662'. 450GPM, 1200psi, Diff 50psi, 50RPM TQ 3.5K, WOB 2-3K, PUW 40, SOW 40,ROT 40. B/R stand out and MAD pass back to TD. Flow check well static. Run Gyro survey on e-line @ 547' .;Slide drill 662' to 692' MTR RPM 139. Rotary drill 692' to 724'. 450GPM,1250psi, Diff, 50psi, 50RPM, TQ 3.5K, WOB 2-3K, PUW 43K, SOW 43K,ROT 43K. B/R stand out and MAD pass back to TD. Run Gyro survey on e- line @ 607'.;Slide drill 724' to 754' MTR RPM 139. Rotary drill 754' to 784' 450GPM,1250psi, Diff, 50psi, 50RPM, TQ 3.5K, WOB 2-3K, PUW 43K, SOW 43K,ROT 43K. B/R stand out and MAD pass back to TD. Run Gyro survey on e-line @ 668'.;Slide drill 784-814'MTR RPM 139. Rotary drill 814' to 847' 450GPM,1300psi, Diff, 100psi, 50RPM, TQ 3.5K, WOB 2-3K, PUW 43K, SOW 43K,ROT 43K. B/R stand out and MAD pass back to TD. Run Gyro survey on e- line @ 729'. Distance to well plan 10.10' 2.73' high 9.73' right.;Avg ROP today 168 ft/hr. Slide hrs 1.32 Rotate hrs 2.52.;Hauled solids to G&I 80bbl Hauled to G&I cumulative 80bbl Hauled fluid to G&I 80bbls Hauled to G&I cumulative 80bbls Hauled cement to G&I 0bbls Cumulative cement to G&I 0bbls Rotary drill F/386'to 415' ;Drill ahead F/250' to 294' ;Drill ahead F/ 129' T/ 233' Rotary drill F/445'to 476' Rotary drill F/324' to 356'. Rotary drill 692' to 724'. Rotary drill 571' to 601 '. continue drilling ahead @ 233' and drill T/ 250g Rotary drill 511' to 541' Rotary drill 636'to 662'. Rotary drill 754' to 784' Rotary drilly 814' to 847' 6/25/2022 Drill ahead in 9-7/8" Surface hole F/ 847' T/ 909' MW in at 8.8+ with 190 Vis, MW out at 8.8+ with 177 Vis, 460GPM, SPP 1350psi, ECD at 9.19 Diff 45psi, RPM 60, WOB 1K, PUW 43K, SOW 43K ROT 43K. Run Gyro to 793' ( Drilled depth at 909' md) and receive co-ordinates, MWD reading with no interference;have Gyro standby until we get to 1000' Continue drilling F/ 909' T/ 974' with same parameters and continue to Mad Pass slides of +/- 30' per stand. Sperry MWD notified DSM that the surface equipment needs upgrading. POOH T/ 909' and stand back one stand of drill pipe.;Remove Gyro Tool from E-Line and Rig Down E-Line services.;Service Top Drive, Draworks, Crown, Traveling Blocks, Right Angle drive and Brake Linkage.;Wash down F/ 909' T/ 974' at 450 GPM with 1335 psi. pump pressure. Continue Drilling F/ 974' T/ 1127' MW in at 8.8+ with 147 Vis, MW out at 8.9 with 163 Vis, 460GPM, SPP 1350psi, ECD at 9.35 Diff 30psi, RPM 60, WOB 1K, PUW 52K, SOW 48K ROT 49K.;Sent 48 hour notification for running surface and cementing 7-5/8" surface casing by e-mail to AOGCC.;Continue Drilling 9-7/8" Surface hole F/ 1127' md T/ 1590' md Sliding 15' to 30' per stand MW in at 9+ with 140 Vis, MW out at 9.1 with 200 Vis, 515GPM, SPP 1760psi, ECD at 9.60 Diff 66psi, RPM 60, WOB 1-3K, TQ 4-6K, PUW 52K, SOW 48K ROT 49K. Mad Passing slides.;CBU@ 1590' . 515GPM, 1800psi, RPM 60, TQ 4K , P/U 60K, S/O 48K, ROT 53K. Flow check , slight seepage loss. P/U 62K S/O 50K w/no pumps.;POOH to 108'. Hole in good condition. No gain or loss on trip.;Service the rig, Top drive, IR, Blocks, crown, washpipe, Monitor the well on trip tank, slight seepage loss.;RIH to 1590'. Tight spot at 1017, slack off 10K X 2 and could not pass. Orient the motor HS and wash down. Continue to RIH on elevators to 1530'. Wash down last stand to 1590' with full drilling parameters. No gain or loss on trip.;Pump 20bbl high vis sweep w/nut plug while drilling ahead. Sweep came back 2300sks Theoretical is 1950sks.;Drill ahead Rotating and sliding as necessary to maintain direction. 1590' to 2022' '. MW in at 9.2ppg with 146 Vis, MW out at 9.3 with 181 Vis, 515GPM, SPP 1950psi, ECD at 9.60 Diff 66psi, RPM 60, WOB 5-6K, TQ 4-6K, PUW 63K, SOW 51K ROT 55K.;Slide intervals 1652'-1677', 1714'-1726', 1775'- 1787', 1961-1973'. At 1988' 6.07' to well plan 6.06' high .36' left.;Hauled solids to G&I 80bbl Hauled to G&I cumulative 80bbl Hauled fluid to G&I 120bbls Hauled to G&I cumulative 200bbls Hauled cement to G&I 0bbls Cumulative cement to G&I 0bbls Daily down hole losses 0bls Cumulative losses 0bbls Daily metal 0lbs Cumulative metal 0lbs 6/26/2022 Continue drilling ahead F/ 2022' T/ 2175' md 1904' tvd MW in at 9.2+ with 114 Vis, MW out at 9.3 with 93 Vis, 515GPM, SPP 2000psi, ECD at 9.84 Diff 168psi, RPM 60, WOB 1-3K, TQ 5-6K, PUW 73K, SOW 49K ROT 59K. CBU Last Survey on bottom showed that we are 9.59' Center to Center F/ WP 06 8.24' high.;Last Survey on bottom showed that we are 9.59' Center to Center F/ WP06, 8.24' high and 4.90' Left.;Flow Check well, static. Short trip F/ 2175' T/ 1560' with no overpulls and correct displacement.;Service Top Drive, Blocks, Draworks, Crown, Iron Roughneck, Right angle drive, Brake linkage and brake bands.;RIH with 9-7/8" drilling assembly F/ 1560' T/ 2175' with no set downs and correct pipe displacement.;Pump sweep with 25% increase in cuttings and circulate clean.;Flow check well, static. POOH for 7-5/8" casing F/ 2175' T/ 725' standing back 4-1/2" Drill Pipe with correct displacement and no overpulls.;PJSM, Stand back 5 stands of 4-1/2" HWDP, Lay down 1 joint of HWDP and Drilling jar, Stand back 3 stands of HWDP, Lay down 6-3/4" flex collars, Remove sources, Download MWD tools and lay down remaining components. Bit graded 1-1-WT-A-X-I-NO-TD.;Clean and Clear rig floor, Drain stack and pull wear ring. Change elevators to 7-5/8" and Dummy run with Cactus wellhead tech and mark landing joint. Prep rig floor for upcoming surface casing run.;Rig up to run 7-5/8" surface casing. Bring centralizers, Power Tongs, Slips, Drive sub for 7-5/8" to rig floor and prepare equipment.;PJSM, Pick up, Fill and make up shoe track with Baker-Lok and confirm floats are working properly. Good. Continue running 7-5/8" surface casing as per running tally to 160' . Check X/O for floor valve/top drive OK. Submit notice to AOGCC for BOPE test at 18:26 hours.;Continue to Run 7 5/8" 29.7ppf L-80 USS-CDC casing F/160' to 2170' P/U 78K S/O 50K. P/U hanger and landing joint and M/U same. Landed on the hanger.;Staged up the pumps to 5 BPM 100psi and monitored flow. No losses. Conditioned the mud for cementing . Max trip gas 100 units. Held a PJSM for cementing with the rig crew and all 3rd party personnel on the rig. Rigged up Halliburton cement lines.;R/D the drive sub and loaded the top plug in the cement head and loaded the bottom plug in the casing. R/U the cement head and M/U the cement lines. Pumped 5bbls water ahead and tested lines to 500psi low 4000psi high OK.;Halliburton pumped 60bbls 10.5ppg tuned spacer 5BPM 125psi. Pumped 108bbls 255sxs 12ppg lead slurry at 5BPM 120psi. Tailed in with 33bbls 165 sxs 15.8ppg tail slurry.;Dropped the top plug and displaced with 10bbls water and 85.5bbls (.5bbls early) of 9.3ppg spud mud and bumped the plug with 1472psi 900psi over last displacement pressure. Displacement pumped by pump truck. Bled back .75bbls and floats held OK. CIP @02:25hrs.;60bbls spacer and 36bbls cement to surface. No losses observed through out the cement job.;Flushed the stack, flowline and shakers with retarded water. Released the hanger running tool and L/D the landing joint and hanger running tool. M/U the packoff running tool and installed the packoff and tested same to 3000psi OK. N/D the diverter line.;Emptied and began to clean the mud pits that had spud mud in them.;Hauled solids to G&I 80bbl Hauled to G&I cumulative 280bbl Hauled fluid to G&I 170 bbls Hauled to G&I cumulative 370 bbls Hauled cement to G&I 0 bbls Cumulative cement to G&I 0 bbls Daily down hole losses 0 bbls Cumulative losses 0 bbls Daily Metal0lbs Cumulative 0lbs Landed on the hanger. y( Continue drilling F/909' T/ 974' p Continue Drilling F/ 974' T/ 1127' g loss.;RIH to 1590'. Tight spot at 1017, g pg pp g p pg ;Drill ahead Rotating and sliding as necessary to maintain direction. 1590' to 2022' g Fill and make up ggp gppqpp shoe track with Baker-Lok and confirm floats are working properly. Good. Continue running 7-5/8" surface casing as per running tally to 160' ;Continue Drilling 9-7/8"Surface hole F/ 1127' md T/ 1590' md Drill ahead in 9-7/8" Surface hole F/ 847' T/ 909' Surface casing run and cemented, with 36 bbls cement returns to surface. -WCB pg g ;Halliburton pumped 60bbls 10.5ppg tuned spacer 5BPM 125psi. p ppg pp ppg pp Pumped 108bbls 255sxs 12ppg lead slurry at 5BPM 120psi. Tailed in with 33bbls 165 sxs 15.8ppg tail slurry.;Dropped the top plug and displaced with 10bblsp ppg y p ppg y pp p p g p water and 85.5bbls (.5bbls early) of 9.3ppg spud mud and bumped the plug with 1472psi 900psi over last displacement pressure. Displacement pumped by ( y) ppg p p p g p p p p pppy pump truck. Bled back .75bbls and floats held OK. CIP @02:25hrs.;60bbls spacer and 36bbls cement to surface. No losses observed through out the cementp job.; p ;Rig up ggg to run 7-5/8" surface casing. g hours.;Continue to Run 7 5/8" 29.7ppf L-80 USS-CDC casing F/160' to 2170' ggpgy Continue drilling ahead F/ 2022' T/ 2175' md 6/27/2022 Continue to Nipple down Annular Preventer, Remove Knife valve, Riser and flow line. Start changing liners in mud pumps to 5" Liners. Continue cleaning mud pits.;Remove DSA and Install wellhead "B", Cleaning mud pits 1 and 3, Continue working on Mud Pump 1. Received another tub of DS40 Drill Pipe for a total of 219 joints on location.;Lower catwalk slide, Have crane remove 21-1/4" Annular Preventer and bring 11" BOPE stack to cellar so that cellar winches can connect. Raise catwalk slide back up to floor, Finish tightening bolts for wellhead and test wellhead T/ 3000psi. Good test.;Clean and inspect all BOPE flanges, Install all jewelry onto mud cross, Set BOPE onto wellhead. Finish cleaning Pits 1, 2 , 3, Pill pit and trip tank. Start building an additional 200 bbls of 6% KCL mud. Continue changing liners in mud pumps.;Continue to torque BOPE flanges to spec., Install choke line, Install bell nipple, Install flow box, Install flowline, Open ram doors, Install 2-7/8" x 5" VBRs and Blind Rams, Connect hydraulic accumulator lines, continue building 6% KCL drilling mud and changing mud pump liners.;Make up 4-1/2" Test joint, Make up Dart valve, TIW, Fill stack and all equipment to be tested, Function test from drillers console. AOGCC Jim Regg waived witness.;Shell test BOP 250/3500 psi. Stem was leaking on the choke HCR. Greased and function the choke line HCR and test OK. Completed mixing KCL mud at 18:30hrs. Clean the mud pit area.;Performed BOP test to 250/3500psi 5/5 min as per AOGCC regulations. Test #1 OK. On test#2 the upper pipe rams were leaking. Trouble shot upper ram leak. Open the upper ram doors and inspected the rams. No obvious problem wit the 2 7/8" X 5" variable rams.;C/O upper rams to 4.5" rams. Tested OK. Test#3 failed and found the manual kill line valve was leaking. Greased the valve functioned and retested OK. Continued to test BOPE with no other failures. Quadco tested the gas alarms OK.;Performed the accumulator drawdown test OK. Tested the rig PVT OK.;Ran wear bushing, Blew down choke. P/U 4 1/2" DP and boke in any recut connections.;Hauled solids to G&I 73bbl Hauled to G&I cumulative 353bbl Hauled fluid to G&I 391bbls Hauled to G&I cumulative 761bbls Hauled cement to G&I 36bbls Cumulative cement to G&I 36bbls Daily down hole losses 0 bbls Cumulative losses 0 bbls Daily Metal0 lbs Cumulative 0 lbs 6/28/2022 Continue P/U and Rack Back Back Stands in derrrick, Make and break all recut jts inspect and redope threads make up to full tq, 60 stands total stood back.;R/U and Perform Casing test t/ 3500 psi f/ 30 min (good test) R/D and blow down lines, Pumped in 1.28 bbls returned 1.2 bbls (Table top Kick While tripping drill with all crew members discuss rolls and responsibilities).;Load Racks and stage BHA, P/U BHA as per DD /MWD, Upload MWD and shallow test tools , load sources continue P/U BHA, install corrosion ring on top of flex collars, M/U stand of HWDP RIH.;Service rig and top drive, tighten loose JIC fittings on top drive.;RIH P/U Remainder of BHA Jar stand, HWDP and 40 jts of DP t/ 1969' breaking and redoping threads and making up to full torque. Washed down from 1969' to 2087' and tag TOC inside casing. P/U 65K S/O 45K ROT 53K, GPM 255, 1700psi, TQ 4.8K, RPM 30.;Drilled out float collar at 2089', shoe track and shoe to 2170'. Cleaned rat hole to 2175'. Drilled 20' new hole to 2195'. P/U 65K S/O 45K ROT 53K, GPM 255, 1700psi, TQ 4.8K, RPM 30, WOB 5K.;Circulate B/U and work BHA through the shoe and float collar several times OK. Pull bit above shoe and shut down pumps. Cleaned under shakers, lined up to displace to 6% KCL PHPA mud.;RIH and wash down to 2195'. Pump spacer and displace spud mud to 8.9ppg 6%KCL PHPA mud. Circulate 3 B/U 8.9ppg in and 8.9ppg out.;R/U test pump lines to go down the kill line and down the drill string . Perform FIT test. Maximum pressure observed was 320psi 12.1 EMW. Repeated the FIT with the same results and confirmed no surface leaks. Pumped in 12.7gal and bled back 4.6gal.;Discussed options with office. Serviced the top drive, blocks, drawworks, pac rim, drive chain, crown, and checked the torque on the drive line bolts. Fluid packed the lines and performed the FIT for the third time with the same results. Cleaned and organize around the rig.;Waiting on orders to proceed.;Hauled: 35 bbls solids to KGF G&I Cumulative: 388 bbls Hauled: 140 bbls fluid to KGF G&I Cumulative: 901 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 6/29/2022 Wait on orders, clean and service rig components organize parts house, Decision made to POOH L/D BHA and cement.;R/D Test equipment POOH F/ 2195' t/ 425'.;Standby on Laying down BHA Wait on orders, decision made to RIH and drill ahead t/ 2650' getting logs across points of interest.;RIH f/ 425' t/ 2195' Wash last stand down.;Drill Ahead f/ 2195' t/ 2650' 255 gpm 1440 psi 40 rpm 5500 tq on bottom 6k WOB MW 9.0ppg, PUW 55k SOW 45k ROT 47k.;CBU, obtain survey, SPR's and flow check well static.;POOH f/ 2650' t/ 737' Standing back DP, Stand back HWDP.;PJSM L/D BHA. Removed corrosion ring, rack back flex collars, remove sources from logging tools, Download MWD data. Bit graded 1,1,WT,A,X,1,NO,HP.;Clean and clear rig floor and prep for running the cement retainer while wait on cement retainer to arrive to location.;PJSM. M/U the cement retainer. RIH to 1966. P/U 62K S/O 44K. BHA#4 cement retainer, 4 1/2" HWDP, 4 1/2" DP.;Set cement retainer 1964'(top of retainer). Sting in and out of retainer 2 times OK. M/U pump-in sub and TIW valve to the drill string.;R/U cement line and reverse hose. PJSM for the injectivity test and the cement job.;Broke circulation with Halliburton pump 1BPM 85psi, 2BPM 120psi. Closed the annular and test the retainer to 1500psi/5min OK. Opened the annular and sting into the retainer. Injected mud 1BPM 600 psi max and dropped to 414 psi after injecting 2bbls.;Increased to 2BPM 470psi initial and dropped to 430psi after 10bbls total mud away. Increased to 3BPM initial 500psi and dropped to 490psi after 15bbls total mud away. Shut in and test the cement line to 2900psi 5min OK. Pumped 5bbls water ahead at 2BPM 400psi.;Pumped 100sx 15.8ppg squeeze cement 20.5bbls at 2BPM 400psi. Followed with 10bbls water 2BPM 48psi. Pumped 13.75bbls 8.9ppg mud 2BPM 430psi FCP. Pumped a total of 23.75bbls displacement. CIP at 02:30hrs.;P/U and unsting from the retainer and close the annular. Reversed out 30bbls(DP volume 25bbls) mud 5BPM 153psi. Open the annular and circulate the long way 2 B/U 10BPM 480psi.;POOH and L/D the retainer running tool.;Organized and clean the rig floor. Broke down the pups, TIW, and pump in T used for the squeeze job.;Hauled: 34 bbls solids to KGF G&I Cumulative: 422 bbls Hauled: 136 bbls fluid to KGF G&I Cumulative: 1037 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs g p Fluid packed the lines and performed thep FIT for the third time with the same results. yg ;Drill Ahead f/ 2195' t/ 2650' gp g p q A Wait on orders, decision made to RIH and drill ahead t/ 2650' getting logs across points of interest. gp q ;Drilled out float collar at 2089', shoe track and shoe to 2170'. ppp ;Pumped 100sx 15.8ppg squeeze cement 20.5bbls g Drilled 20' new hole to 2195'. pppg Perform FIT test. Maximum pressure observed was 320psi 12.1ppg ppg p p g EMW. Repeated the FIT with the same results and confirmed no surface leaks. ;Set cement retainer 1964'(top of retainer). FIT testing gave only 11.2 ppg, not the planned / req'd 16.5 ppg. They emailed, asking permission to drill ahead 300' to get correlation logs, plug back with a retainer and cement, and set a whipstock @ ~2070 in a more competent formation. Mel approved. -WCB 6/30/2022 M/U 6.75 roller cone bit, bit sub and cross over RIH w/ HWDP from derrick and DP t/ top of retainer @ 1964'.;Circulate and condition mud 220 gpm 180 psi 35 rpm 4400 tq.;POOH f/ 1964' t/ 614'.;Slip and cut drilling line 62', service rig.;POOH f/ 614' t/ surface L/D Clean Out Assembly, clean and clear floor.;Wait on whip stock being shipped from slope, Perform EAM's and maintenance on rig, clean and organize around rig, change out SRL on crown and perform derrick inspection, Change out start stop switch for roughneck and plug on plug board for mix pump.;P/U Whip Stock BHA #5 and and RIH M/U whip stock anchor to mills w/ 35k shear bolt anchor set to shear w/ 14k, M/U MWD and orient to whip stock , shallow pulse test tools RIH to 1940'.;Oriented the whipstock to 52R of high side. RIH and tag the retainer at 1965' and set down w/14K to set the anchor. Work pipe and shear off the bolt w/38K down.;Milled the window 1946' to 1960' P/U 60K, S/O 43K, Rot 50K, 265GPM, 850psi, WOB 3/8, K, RPM-80/85, TQ 5-8K,;Drilled formation1960' to 1980' 265GPM, 850psi, WOB 3/10, K, RPM-80/85, TQ 4.8-5.5K, 70# metal recovered on magnets. P/U 60K, S/O 43K Rot 50K. Circulated a 20bbls sweep around and worked the mills through the window several times. Window in very good condition.;R/U test pump to pump down kill line and drill pipe. Performed FIT. Achieved a 14.1ppg EMW. MW 9.2ppg Max pressure 446 TVD 1746'. R/D test equipment and lines.;Hauled: 16bbls solids to KGF G&I Cumulative: 438bbls Hauled: 64 bbls fluid to KGF G&I Cumulative: 1101bbls Hauled: 0bbls cement to KGF G&I Cumulative: 36bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 70 lbs Cumulative: 70 lbs 7/1/2022 R/D Test equipment Blow down lines.;POOH f/ 1943' t/ surface L/D Mills Upper mill in Gauge, Clean and clear floor.;M/U Directional Only BHA #6 RIH t/ 1840' Orient tools slide through the window without issue, wash to bottom.;Drill Ahead f/ 1980' t/ 2180' 250 gpm 1311 psi SPP, 40 RPM 5 k tq on bottom, 7k WOB, PUW 60k SOW 45k ROT 50k MW 9.2 ppg.;Circulate and condition mud 260 gpm 1200 psi.;POOH f/ 2180' t/ Surface check Bit L/D TM DM collars, Bit Grade 1,1,WT,A,X,1,NO,BHA.;Clean and clear rig floor. Serviced the rig while changing the internals on the DM Collar. Changed seal on the TD hydraulics. Serviced Blocks, TD, Swivel packing, drawworks and IR, Prep floor for upcoming BHA.;PJSM. M/U Directional BHA #7 as per DD/MWD. Uploaded tools, shallow hole tested OK. Installed sources. P/U the flex collar and RIH surface to 185'.;RIH 185' to 2100'.(C/O jars on trip and orient BHA through window 1946-1960' window in good condition).;RIH to 2180 and washed the last stand down. Drill ahead 6 3/4" directional hole 2180' to 2525' MAD passing all of the slide areas. 258GPM 1400-1500psi Diff pressure 221psi 58RPM, TQ 5600, ECD 10.18ppg, in MW9.2ppg Vis 50 out MW 9.2ppg Vis 51 P/U 69 K S/O 45K ROT 55K.;At 2403' Rotate 2.0HRS Slide 1.76HRS Distance to line 19.7', 13.51' low 14.34' right.;Hauled: 16 bbls solids to KGF G&I Cumulative: 438 bbls Hauled: 64 bbls fluid to KGF G&I Cumulative: 1101 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 6 lbs Cumulative: 76 lbs 7/2/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/ 2525' t/3022' 282 gpm 2020 psi 60 rpm 5200 tq on bottom, 8k WOB, 78k PUW 52k SOW 64k ROT Max gas 80 units MW 9.2 ppg ECD 10.55 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 3022' t/3208' 280 gpm 1980 psi 60 rpm 6100 tq on bottom, 8k WOB, 86k PUW 53k SOW 65k ROT Max gas 151 units MW 9.2 ppg ECD 10.60 ppg EMW.;Obtain Survey and SPR's, CBU and flow check well static.;POOH f/ 3208' t/ 2155' on elevators seen minor over pulls worked through and gone, Hole took correct fill Cal 6.9 bbls Act 7.5 bbls.;Service top drive and crown, Change oil in floor motor, set drilling torque, service draw works and iron roughneck.;RIH f/ 2155' t/ 3208' No hole issues wash down last stand no fill 286 units of gas on bottoms up.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 3208' t/3611 280 gpm 1950psi on bottom 1500psi off bottom 60 rpm 6100 tq on bottom, 8k WOB, 86k PUW ,53k SOW ,65k ROT, Max gas 144 units, MW 9.2 ppg, ECD 10.60 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/3611' to 3948' 280 gpm 1750 psi off bottom 2100 psi on bottom 60 rpm 7800 tq on bottom, 8k WOB, 92k PUW 55k SOW 69k ROT Max gas 209 units MW 9.2 ppg ECD 10.95 ppg EMW.;At 3887' Rotate 7.90HRS Slide 3.35HRS Distance to line 6.06', 1.9' low 5.75' left.;Hauled: 74.5 bbls solids to KGF G&I Cumulative: 512.5 bbls Hauled: 90.5 bbls fluid to KGF G&I Cumulative: 1191.5 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 76 lbs 7/3/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/ 3948' t/4259 285 gpm 2075 psi 75 rpm 8100 tq on bottom, 8k WOB, 111k PUW 57k SOW 75k ROT Max gas 168 units MW 9.2 ppg ECD 10.93 ppg EMW.;Obtain Survey and SPR's CBU.;POOH f/ 4259' t/ 3208' Work through tight spots f/ 3378'-3299' 30k over.;Service Rig and Top Drive, Grease crown and Iron Roughneck.;RIH f/ 3208' t/ 4259' No hole Issues.;Circulate Hi Vis Sweep around back 100 stks early and 25% increase in cuttings 1467 units of gas on bottoms up.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 4259' t/4507' 285 gpm 2075 psi 75 rpm 8100 tq on bottom, 8k WOB, 105k PUW 57k SOW 75k ROT 615 Max gas units MW 9.2 ppg ECD 10.74 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 4507' t/4928' 285 gpm 2200 psi 60 rpm 9000 tq on bottom, 8k WOB, 121k PUW 63k SOW 83k ROT 213 Max gas units MW 9.43+ppg ECD 10.9ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 4928' t/5123' 285 gpm 2200 psi 75 rpm 10250 tq on bottom, 6k WOB, 140k PUW 65k SOW 90k ROT Max gas 239units MW 9.2+ ppg ECD 10.74 ppg EMW.;Difficulty sliding from 5,000'. Pumped a 20bbl hi-vis sweep around and it returned 200sks early. Added 165 gal of NXS lubricant and 50 gal of drill and slide lubricant to the active system.;At 5061' rotate 9.99hrs slide 2.18hrs distance to line 6.68' 3.86' high 5.45' left .;Hauled: 96 bbls solids to KGF G&I Cumulative: 608.5 bbls Hauled: 144 bbls fluid to KGF G&I Cumulative: 1335.5 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 76 lbs M/U 6.75 roller cone bit, bit sub and cross over RIH w/ HWDP from derrick and DP t/ top of retainer @ 1964'.; g qg ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 3208' t/3611 gp ;Continue Drilling Ahead 6pp q 3/4'' Hole Section f/ 4928' t/5123' (j p Drill ahead 6 3/4" directional hole 2180' to 2525' qp pp g Orient tools slide through the window without issue, wash to bottom.;Drill Ahead f/ 1980' t/ 2180' Work through tight spots f/ 3378'-3299' Continue Drilling Ahead 6 3/4'' Hole Section f/ 2525' t/3022' ppq ;Continue Drilling Ahead 6 3/4'' Hole Section f/3611' to 3948' Continue Drilling Ahead 6 3/4'' Hole Section f/ 3948' t/4259 gp p p q ;Difficulty sliding from 5,000'. Pumped a 20bbl hi-vis sweep around and it g ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 4259' t/4507' p g Performed FIT. Achieved a 14.1ppg EMW. MW 9.2ppg Max pressure 446 TVD 1746'. gp p p q ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 3022' t/3208' gg p ;P/U Whip Stock BHA #5 and and RIH M/U whip stock anchor to pg p gpgpg ppp p mills w/ 35k shear bolt anchor set to shear w/ 14k, M/U MWD and orient to whip stock , shallow pulse test tools RIH to 1940'.;Oriented the whipstock to 52R of pp p high side. RIH and tag the retainer at 1965' and set down w/14K to set the anchor. Work pipe and shear off the bolt w/38K down.;Milled the window 1946' to gg pp 1960' P/U 60K, S/O 43K, Rot 50K, 265GPM, 850psi, WOB 3/8, K, RPM-80/85, TQ 5-8K,;Drilled formation1960' to 1980' 2 7/4/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/ 5123' t/5309' 285 gpm 2200 psi 60 rpm 10250 tq on bottom, 8k WOB, 142k PUW 70k SOW 95k ROT Max gas 185 units MW 9.2+ ppg ECD 10.81 ppg EMW.;Obtain surveys and SPR's Circulate bottoms up 280 gpm 2205 psi SPP, Flow Check Well Static.;Make Wiper Trip f/ 5309' t/ 4193' No Hole Issues seen 10k drag off bottom and wiped through minor over pulls but they cleaned right up.;Service rig and top drive, C/O Iron Roughneck Dies.;RIH f/ 4193' t/ 5309' With No Issues.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 5309' t/5500' 285 gpm 2200 psi 60 rpm 10300 tq on bottom, 6k WOB, 142k PUW 70k SOW 95k ROT Max gas 185 units MW 9.2+ ppg ECD 10.81 ppg EMW. Pumped High Vis Sweep 20% increase back 200 stks late 211 units of gas on bottoms up.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 5500' t/5804' 285 gpm 2200 psi 65/75 rpm 11200 tq on bottom, 6/8k WOB, 150 k PUW 76k SOW 100k ROT Max gas 424 units MW 9.3 ppg ECD 10.85 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 5804' t/6130' 285 gpm 2250 psi 65/75 rpm 12100 tq on bottom, 6/8k WOB, 160k PUW 80k SOW 105k ROT Max gas 854units MW 9.3 ppg ECD 10.81 ppg EMW. Flow check at 5804' well static. Added 150gal of drill and slide lubricant at 6020'.;At 6000' rotate 8.86hrs slide 3.72hrs . Distance to line 2.59', 2.53' high .55' right .;Hauled: 119.5 bbls solids to KGF G&I Cumulative: 728 bbls Hauled: 135.5 bbls fluid to KGF G&I Cumulative: 1471 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 76 lbs 7/5/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/ 6130' t/6359' 280 gpm 2090 psi 60 rpm 13500 tq on bottom, 6/8k WOB, 160k PUW 80k SOW 105k ROT Max gas 783 units MW 9.3 ppg ECD 10.81 ppg EMW.;Obtain Surveys and SPR's Circulate two bottoms ups, Flow check well static slight seepage dropped 8'' in riser in 10 min.;POOH f/ 6359' t/ 3192' Pulling tight unable to work through Kelly up and CBU, Continue Pulling tight BROOH f/ 3192' t/ 2180' pull BHA into the window t/ 1903'.;Service rig, Grease top drive and draw works, grease crown and iron roughneck, Set drilling torque on top drive t/ 16500 ft/lbs.;RIH f/ 1903' t/ 3485' P/U 50 jts of new DP breaking in threads. Window in good condition. No gain or loss.;RIH with stands from derrick f/3485 ' to 6462'. Had to work through tight spots 5183' to 5216' and 5300' to 5340'. From 5340' to 6462' had to pull over or slack off 20K to break free at the connections. Kelly up at 6246' and wash and ream down to 6332' and CBU .Trip gas 1787 units.;Wash last stand down 6332'-6359'. 1bbl loss for trip in.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 6359' t/6565' 280 gpm 2300/2000 psi 75 rpm 12,500 tq on bottom, 4/10k WOB, 182k PUW 78k SOW k 111ROT Max gas 583 units MW 9.3 ppg ECD 10.55 ppg EMW. Pumped a 20bbl hi-vis sweep, returned on time. Added 330gal Baralube at 6393'.;At 6515' last 24 hrs rotate 5.63hrs slide .6hrs . Distance to line 5.79', 4.79'high .18'left .;Hauled: 72 bbls solids to KGF G&I Cumulative: 800 bbls Hauled: 88 bbls fluid to KGF G&I Cumulative: 1559 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 76 lbs 7/6/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/ 6565' t/6855' 280 gpm 2520 psi 75 rpm 14,100 tq on bottom, 8k WOB, 175k PUW 85k SOW k 115k ROT Max gas 456 units MW 9.3 ppg ECD 10.51 ppg EMW. Add Half tote of Baralube.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 6855' t/7204' 286 gpm 2360 psi 75 rpm 13,000 tq on bottom, 8k WOB, 180k PUW 85k SOW k 120k ROT Max gas 918 units MW 9.4 ppg ECD 10.58 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 7204' t/7628' 286 gpm 2450 psi 80 rpm 13,500 tq on bottom, 7/8k WOB, 191k PUW 93k SOW k 123k ROT Max gas 1001 units MW 9.4 ppg ECD 10.65 ppg EMW..At 7204' added 165gallons of Baralube lubricant.;Flow checked at 7450 hole static. At 7505' added110 gal Baralube gold seal lubricant.;CBU X 2 280GPM 2035 psi 75 RPM 12500/13500 TQ MW 10.4ppg ECD 35units gas. Flow checked well ,static.;POOH on elevators f/7628' to 7140'. Tight at 7140' B/R F/7195' to 7133'. Cont. to POOH on elevators f/7133' to 6300' worked through tight spots at 7108', 6925', 6905', 6689', 6454'. Lost 1.5bbls mud to the hole on the trip out.;Serviced the rig: greased the crown, blocks, top drive, drawworks, brake linkage, drive shaft, and Iron roughneck,, Checked the saver sub threads OK. Adjusted the bail clamps on top drive. Function the BOP stack, OK. Monitored the well on trip tank 1bbl/hr static losses.;Check the pulsation dampeners MP1=600psi MP2= 800psi. Clean mud pump screens #1, clean MP2= suction 25% discharge 50% packed off.;RIH f/6300' to 7628'. Washed last stand down.;At 7628'' last 24 hrs rotate 14.67hrs slide 0hrs . Distance to line 10.94', 10.91' low .75'left .;Hauled: 84 bbls solids to KGF G&I Cumulative: 884 bbls Hauled: 156 bbls fluid to KGF G&I Cumulative: 1715 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 36 bbls Daily down hole losses: 0 bbls Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 76 lbs gp p pq ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 5804' t/6130' g ppg ppg ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 5500' t/5804' yp ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 6359' t/6565' pq Added 150gal of drill and slide lubricant at 6020'. ppg y p g p gpp Pulling tight unable to work through Kelly up and CBU, Continue Pulling tight BROOH f/ 3192' t/2180' pull BHA into the window t/ 1903'.; gp p ;Continue Drilling Ahead 6 3/4''pq Hole Section f/ 7204' t/7628' Continue Drilling Ahead 6 3/4'' Hole Section f/ 5123' t/5309' g worked through tight spots at 7108', 6925',6905', 6689', 6454'. Continue Drilling Ahead 6 3/4'' Hole Section f/ 6130' t/6359' pq ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 6855' t/7204' Had to work through tight spots jg gg 5183' to 5216' and 5300' to 5340'. From 5340' to 6462' had to pull over or slack off 20K to break free at the connections. pg p y ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 5309' t/5500' Continue Drilling Ahead 6 3/4'' Hole Section f/ 6565' t/6855' 7/7/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/ 7628' t/ 7946' 280 gpm 2350 psi 75 rpm 14,600 tq on bottom, 8k WOB, 200 k PUW 95k SOW k 134 k ROT Max gas 1545 units MW 9.4 ppg ECD 10.47 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 7946' t/ 8220' 280 gpm 2440 psi 65 rpm 15,500 tq on bottom, 8k WOB, 200 k PUW 95k SOW k 134 k ROT Max gas 1545 units MW 9.4 ppg ECD 10.47 ppg EMW.;Continue Drilling Ahead 6 3/4'' Hole Section f/ 8220' t/8479 ' 280 gpm 2440 psi 70 rpm 15,800 tq on bottom, 8k WOB, 217K PUW 100k SOW 137k ROT Max gas 1287 units MW 9.35 ppg ECD 10.45 ppg EMW. High torque and diff pressure at 8241' and 8266'.;Due to high toque above 16,500 at 8479' added 83gal of NXS lubricant and circulated , rotated and reciprocated until there was a reduction in TQ.;Continue Drilling Ahead 6 3/4'' Hole Section f/8479 ' t/8670 ' 280 gpm 2440 psi 70 rpm 16,000/17,100 tq on bottom, 7/9k WOB, 220K PUW 102k SOW 142k ROT Max gas 1110 units MW 9.35 ppg ECD 10.45 ppg EMW. Due to high drilling toque at 8557'added 165 gallons of NXS lubricant to the mud system.;Reduced torque from 17,100 ft-lbs to 16,000 ft-lbs Drilled with the top drive in high torque mode from 8556'.;At 8586' last 24 hrs rotate 14.75hrs slide 1.51hrs . Distance to line 17.82', 9.55' low 15.05'left .;Hauled: 85 bbl solids to KGF G&I Cumulative: 969 bbl Hauled: 245 bbl fluid to KGF G&I Cumulative: 1960 bbl Hauled: 0 bbl cement to KGF G&I Cumulative: 36 bbl Daily down hole losses: 0 bbl Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 76 lbs 7/8/2022 Continue Drilling Ahead 6 3/4'' Hole Section f/8670 ' t/8890 ' 280 gpm 2513 psi 60 rpm 16,600tq on bottom, 12k WOB, 225K PUW 107k SOW 145k ROT Max gas 502 units MW 9.4 ppg ECD 10.41ppg EMW. Due to high drilling torque 165 gallons of NXS lubricant.;Pump Hi Vis Sweep around, sweep back on time no change in cuttings, circulate clean, obtain SPR's and Survey.;BROOH f/ 8890' t/ 2120' 283 gpm 2000/1575 psi 65 RM 9/4.5k tq. ECD 10.3-10.4ppg EMW. Dropped a 2.4" drift with 32 stands drill pipe in the hole. Pulled into the window at 1960' . Window smooth, no drag observed.;Lined up on the trip tank(hole static). Slipped and cut drill line. Serviced the rig. The Rieneer motor failed on the topdrive while screwing out of the stump. Hydraulic oil leaking out of the hydraulic relief valve when functioning the link tilt on the topdrive.;Trouble shot the topdrive. Located the Rieneer motor at the Hilcorp warehouse.;Remove the failed Rainer motor from the topdrive. and replaced and tested the motor OK. Secured bolts with wire ties.;Rotating time 6.29hrs. At TD 35.44' from the line .63' high 35.44' left.;Hauled: 56 bbl solids to KGF G&I Cumulative: 1,025 bbl Hauled: 24 bbl fluid to KGF G&I Cumulative: 1,984 bbl Hauled: 0 bbl cement to KGF G&I Cumulative: 36 bbl Daily down hole losses: 16 bbl Cumulative: 16 bbl Daily Metal: 0 lbs Cumulative: 76 lbs 7/9/2022 Continue testing top drive function, Tie wire bolts on top drive.;Continue POOH f/ 1904' t/ 737' L/D BHA cleaning and vacuuming pipe dry, unload sources, download MWD, continue L/D BHA Bit graded a 1-3, 1/16 under gauge clear floor L/D all BHA components.;R/U casing equipment t/ run liner, load racks, hold PJSM.;RIH w/ 4.5'' Liner as per detail, Baker lock and M/U float equipment, check floats good, RIH w/ 4.5'' liner installing centralizers every other jt f/ total of 85' t/4400'.;Cont. to RIH 4.5" 12.6ppf L-80 DWC/C-HT liner f/4400' to 7118' total 173 jnts M/U TQ 6,000 ft-lbs.;P/U Baker liner hanger/Packer tool and M/U the liner wiper plug and M/U to the top liner joint. P/U 150K S/O 62K. Begin to RIH and had to work past 7168'. M/U top drive and circulate and reciprocate. 163GPM 385psi. Circulate a B/U max gas 1065 units. P/U 120K S/O 65K with pumps on at 165GPM.;Rotate 20RPM 4-8K TQ. Work area 7165 to 7230' while circulating, reciprocating and rotating. Area sticky.;RIH with liner on drill pipe to 8104' and fill pipe. Continue to RIH with liner on drill pipe to 8840'.;Washed 4 1/2" liner down f/8840' to 8886' and tagged. Reciprocated liner and attempted to rotate but could not rotate with 8,000 ft-lbs. Circulated and condition mud for cementing at 255GPM(6BPM) 885psi while reciprocating. Max gas 321units.P/U 165 S/O 75 with 6BPM.;PJSM for the cement job with all rig hands and 3rd party hands on location. R/U the Baker plug dropping head.;Pumped 5bbls water ahead. PT cement lines to 245psi low 4400psi high 5min OK. Mixed and pumped 30bbls 10.5ppg tuned prime spacer 4 BPM 500psi. Mixed and pumped 540sx to yield 227bbls 12.0ppg lead slurry at 6 BPM w/570 psi.;Mixed and pumped 95sx to yield 19bbls 15.3ppg tail slurry 3BPM w/220psi. Shut down and wash out the cement lines to the cutting tank. Dropped the drill pipe wiper dart.;Displaced with 10bbls water and 118.5bbls mud. DP wiper dart latched the liner wiper plug with 23.5bbls away. Bumped the plug with1722psi 727 psi over the last displacement pressure of 995 psi. Bumped 2.7bbls early. CIP at 05:23 hrs.;Held 1700psi for 5 min and bled back .75bbls. Floats held OK. Lost all returns 86bbls into the displacement. No cement to surface during displacement.;Pressured up to 2500psi. Slack off string wt to confirm hanger set and pressured up to 4000psi set liner top packer and release setting tool. Liner hanger running tool did not release hydraulically. P/U to 45K and put in one turn to the left. Set down string wt.;P/U to 50K and released the running tool mechanically.;Hauled: 5 bbl solids to KGF G&I Cumulative: 1,030 bbl Hauled: 85 bbl fluid to KGF G&I Cumulative: 2,069 bbl Hauled: 0 bbl cement to KGF G&I Cumulative: 36 bbl Daily down hole losses: 0 bbl Cumulative: 16 bbl Daily Metal: 0 lbs Cumulative: 76 lbs p RIH w/ 4.5'' liner No returns to surface during liner cementing. -WCB Continue Drilling Ahead 6 3/4'' Hole Section f/ 7628' t/ 7946' py Mixed and pumped 30bblspg ppg p p p g pp 10.5ppg tuned prime spacer 4 BPM 500psi. Mixed and pumped 540sx to yield 227bbls 12.0ppg lead slurry at 6 BPM w/570 psi.;Mixed and pumped 95sx to ppg p p yield 19bbls 15.3ppg tail slurry gp p p q ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 7946' t/ 8220' Floats held OK. Lost all returns 86bbls into the displacement. No cement to surface during displacement. Continue Drilling Ahead 6 3/4'' Hole Section f/8670 ' t/8890 ' gq g ;Continue Drilling Ahead 6 3/4'' Hole Section f/8479 ' t/8670 gp p pq ;Continue Drilling Ahead 6 3/4'' Hole Section f/ 8220' t/8479 ' ggg ;RIH w/ 4.5'' Liner as per detail, Baker lock and M/U float equipment, check floats good, Continue to RIH with liner on drill pipe to 8840'.;Washed 4 1/2" liner pg g y pp pp pp down f/8840' to 8886' and tagged. Reciprocated liner and attempted to rotate but could not rotate with 8,000 ft-lbs. Circulated and condition mud for cementing gg p at 255GPM(6BPM) 885psi while reciprocating. pgpppp p p DP wiper dart latched the liner wiper plug with 23.5bbls away. Bumped the plug with1722psi 727 psi over the last p pppp displacement pressure of 995 psi. Bumped 2.7bbls early. CIP at 05:23 hrs.pp pp y 7/10/2022 Break circulation circulate cement returns out of hole, 440 gpm 443 psi , over board spacer and cement returns, stand back stand and drop wiper ball circulate another surface to surface.;POOH f/ 1677' t/ surface L/D Liner running tools.;Clear floor M/U Polish mill assembly RIH t/ top of liner @ 1730' work up and down through liner top 4 times, confirm no go, rotate 40 rpm and pump 168 gpm.;Displace well t/ CI Fresh Water.;POOH L/D DP f/ 1724' t/ Surface L/D polish mills.;P/U Diffuser RIH w/ DP f/ derrick POOH L/D DP in groups of 25 stands.;Wash out stack with Johnny Wacker. Clean out flow box. M/U X/O on single for wear bushing puller.;Serviced the rig. Greased the crown, blocks, top drive, drawworks, Drive shaft, brake linkage, and iron roughneck.;Back out lockdown screws and pull the wear bushing. R/D the cement head. R/U test equipment to test the 4.5" liner lap. Flood and purge the lines.;Test the 7 5/8" X 4.5" liner lap to 3000psi/30 min OK. Lost 15 psi in first 15 min and 8 psi in second 15 min. Pumped in 2.0 bbls and bled back 1.8 bbls.;R/U casing running tools and injection line running sheaves and run chemical injection line through the sheaves.;Run 4 1/2" 12.6ppf L-80 IBT-M tubing for the upper completion. Seals, 7 joints of 54 total joints and chemical injection mandrel run at report time at 250'.;Hauled: 65 bbl solids to KGF G&I Cumulative: 1,095 bbl Hauled: 565 bbl fluid to KGF G&I Cumulative: 2,634 bbl Hauled: 0 bbl cement to KGF G&I Cumulative: 36 bbl Daily down hole losses: 99 bbl Cumulative: 115 bbl Daily Metal: 0 lbs Cumulative: 76 lbs 7/11/2022 RIH w/ 4 1/2" 12.6ppf L-80 IBT-M Tie back completion to 250' and installed the chemical injection mandrel. Install injection line and test to 1000psi for 15 min OK. Held 1000psi on the line while RIH with the completion. Continued to RIH to 1260' and install the SSSV.;Install the control line and pressured up to 5000psi. Confirmed the valve opened at 2200 psi. Bled off pressure and confirmed the valve closed. Held 5000psi on the line while continued to RIH to 1742'. P/U 35K S/O 35K S/O 35K and confirmed the no go at 1730'.;Observed 5K S/O as the seals entered the seal bore. Set 10K down to confirm tag on the no go. Spaced out the tubing string. L/D joint#54 and P/U and M/U 1-9' pup and 1-2' pup into the string.;M/U the hanger and landing joint and ran the control lines through the hanger. Pressure tested the control lines OK. Landed out the hanger and ran in the lockdown screws. R/D the tubing running equipment. L/D subs from the rig floor.;R/U to test the tubing and the IA. Purge air. Test each to 3000psi for 30 min. R/D test equipment. Flushed all lines with Baraclean and blew down the lines.;Set a BPV. N/D the BOP. Pulled chains and binders. Removed the flow nipple, flow line, flow box, choke and kill lines. Installed the bridge crane beam. R/U the trolly cranes to stack. Unbolted stack and lifted. Trolleyed the stack to a position where it can be crane lifted.;Brought the dry hole tree into the sub base and N/U the tree. Tested the hanger void and seals to 250/5000psi OK. Tested the tree to 250 psi/5000psi OK. R/D the pump room and went through mud pumps. Continued to clean pits and prep for move. R/D the top drive.;Disconnected the the service loop and kelly hose. Broke out the saver sub. R/D and L/D the torque bushing. Brought the cradle to the rig floor and pin it to the top drive . Unpinned the blocks from the top drive. Rigged up to lay down the top drive.;Bridled up to scope down derrick. Removed T-bar from torque tube. Unplugged the lights and heater from the derrick house. Unplugged upper section of the derrick. Disconnected the Pason cable. from crown and coiled up. Scoped derrick to half mast.;Removed the lower section of the torque tube and laid down to catwalk. Continued working on the pumps and pump room. Continued rigging down pits and cleaning. Rigged down the mud gas separator.;Hung off the blocks, unspooled the drilling line from the drum. Cut off 7 wraps, 30' of drilling line. Installed the shipping beams. Secured the torque tube to the derrick. Hung off the kelly hose and service loop and secured in the derrick. Dogged in derrick . R/D the torque tube turnbuckles.;Lowered the roofs on the mud tanks. R/D the steam and water lines. Laid over the derrick.;Rig released from Paxton#6 at 06:00hrs 7/12/2022.;Hauled: 7 bbl solids to KGF G&I Cumulative: 1,102 bbl Hauled: 343 bbl fluid to KGF G&I Cumulative: 2,977 bbl Hauled: 0 bbl cement to KGF G&I Cumulative: 36 bbl Daily down hole losses: 0 bbl Cumulative: 115 bbl Daily Metal: 0 lbs Cumulative: 76 lbs g ;R/U to test the tubing and the IA. Purge air. Test each to 3000psi for 30 min. R/D test equipment. MIT-T and MIT-IA to 3000 psi. -WCB p gg .;Run 4 1/2" 12.6ppf L-80 IBT-M tubing for the upper completion. RIH w/ 4 1/2" 12.6ppf L-80 IBT-M Tie back completion to 250' and installed the chemical injection mandrel. ;Test the 7 5/8" X 4.5" liner p lap to 3000psi/30 min OK. p ;Observed 5K S/O as the seals entered the seal bore. Set 10K down to confirm tag on the no go. Spaced g ggp out the tubing string. L/D joint#54 and P/U and M/U 1-9' pup and 1-2' pup into the string.;M/U the hanger and landing joint and ran the control lines through the hanger. Activity Date Ops Summary 7/17/2022 Fox coil and Cruz crane hold PJSM and approve PTW. MIRU coil equipment.,Test coil BOPE to 250 psi low / 3000 psi high. (Jim Regg with AOGCC waived witness at 23:51 on 7/16/22).,Spot supply tank and start filling with water. Spot return tank and drop trailer with pump on location. SDFN. 7/18/2022 Fox coil and Cruz crane hold PJSM and approve PTW. MU lubricator, 1.75" DFCV's, weight bar, JSN. PT out to choke skid and inner reel valve to 250/3000 psi.,Open well and RIH. Tag at 8771' ctmd. Online with pump displacing drilling mud. Pump rate = 1.5 bpm @ 3200 psi. Stay on bottom pumping until 80 bbls above coil. Start POOH at 50 ft/min while pumping. Stop pumping and POOH once returns at surface clear up and no more drilling mud at surface. Total returns of 180 bbls.,Laydown cleanout BHA and lubricator. Install night cap to secure well. SDFN. 7/19/2022 AK E-line arrive, hold PJSM and approve PTW. MU 1-11/16" CBL toolstring.,RIH to 1200' and calibrate CBL to free pipe. Continue to RIH and toolstring showing high voltage swings at ~ 6500'. Continue to RIH to PBTD, but tool not functioning properly. PUH above 6500' and tool voltage is steady. POOH to change out CBL's.,Swap out 1-11/16" CBL for 2-3/4" CBL.,RIH with 2-3/4" CBL toolstring. Calibrate free pipe at 1200'. Toolstring starting to have high voltage swings at ~ 6500'. Tag PBTD at 8740' (corrected to tubing tally). Log up to 7800' for repeat pass, tool still having some voltage swings. RIH to tag TD. Start logging up and tool having less voltage swings than repeat pass. Once tool is above ~ 6500', very little voltage swings. Log up to surface at 60 ft/min.,RDMO. 7/20/2022 Fox coil arrive at location. Hold PJSM and approve PTW. Cruz crane unable to boom in/out.,Correlation of 2.75” CBL indicated that milling was required to reach zone of interest. Corrected depth = 8724’. Haul fluids for milling, rig down pump and prepare to swap out for another. Crane was not able to boom in/out. Troubleshoot crane, but unable to fix. Crane specialist flying down from Anchorage to troubleshoot crane. 7/22/2022 Cruz crane arrives at wellsite. Fox Energy arrives on site. PTW and PJSM. MU lubricator. PT MHA to 3500 psi. Yellowjacket BHA - 2.88" CTC, 2.88" DFCV, 2.88" BiDi jars, 2.88" Disco, 2.88" Circ sub, 2.88" motor, 3.50" junk mill (OAL - 24.97'). RIH.,Dry tag at 8764' CTM. PUH 20'. Begin pumping at 1.6 bpm @ 4100 psi. Begin milling. As slick water gets into the coil the circ pressure reduce. Milled consistently down to 8821', got a good tag/stall. PUH to 8750' and tagged again at 8821'. POOH pumping at 1.75 bpm @ 2400 psi. Shut down pump. Lay down tools, lubricator and injector head. Install night cap and SDFN. 7/23/2022 Yellowjacket EL arrive on location. PTW and PJSM. MU grease-head and 2-3/4" CBL tools. RIH. Tag uncorrected depth 8818'. Log from tag to surface. Rig down EL. Send uncorrected log to town. RDMO.,Fox Energy arrive on location. PTW and PJSM. Pickup injector head and lubricator. MU roll on CTC, DFCV, weight bar/stinger and 2-1/8" JSN. Rigup nitrogen pump. PT hardline to 3500 psi. RIH and start pumping nitrogen at 4500' at 1500 scf/min. RIH and tag at 8822' ctmd. POOH. Recovered expected amount of fluid from the wellbore and coiled tubing (~165 bbls). Pinch in choke and build WHP. WHP at 1775 psi. RDMO. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Paxton 06 Ninilchik Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: Job Name:221-00072 Paxton 6 Completion Spud Date: gp p p ggg RIH to tag TD. Start logging up and tool having less voltage swings than repeat pass. Once tool is above ~ 6500', very little voltage swings. Log up to surface at g 60 ft/min.,RDMO. Yellowjacket EL arrive on location. PTW and PJSM. MU grease-head and 2-3/4" CBL tools. RIH. Tag uncorrected depth 8818'. Log from tag to surface. Rig downj EL. Send uncorrected log to town. MIRU coil equipment., yppg ppg Stop pumping and POOH once returns at surface clear up and no more drilling mud at surface. pp MU 1-11/16" CBL toolstring.,RIH to 1200' and calibrate CBL to free pipe. AK E-line arrive, 8/1/2022 PJSM and PTW SITP 1760psi of N2,R/U YJ E-line Pressure test lubricator to 250psi/3,000psi - test good,M/U and RIH w/ weight bars, gun gamma, and 5ft 2"OD 6spf 6.5g Geodynamics gun (CCL to top shot 8.5ft) Tag at 8,800.5ft Pull correlation log and send to town - On depth,Pull on depth and perforate T-146 sands from 8,714-8,719ft @ 13:28hrs. POOH, All shots fired, Gun is a little damp, no sand SITP 0min - 1768psi 5min - 1928psi 10min - 2045psi 15min - 2199 30min - 2310psi 60min - 2551psi,M/U and RIH w/ gun gamma, and 23ft 2-7/8"OD 6spf 15g Geodynamics gun (CCL to top shot 10.0ft) Pull correlation log and send to town - On depth,Pull on depth and perforate T-146 sands from 8,721-8,744ft @ 16:21hrs. POOH, All shots fired, Gun is a little damp, no sand SITP - 2717psi No pressure change in 15min,M/U and RIH w/ gun gamma, and 20ft 2-7/8"OD 6spf 15g Geodynamics gun (CCL to top shot 8.5ft) Pull correlation log - On depth,Pull on depth and perforate T-146 sands from 8,701-8,721ft @ 18:26hrs. POOH, All shots fired, Gun is a little damp, no sand SITP - 2732psi No pressure change in 15min,M/U and RIH w/ gun gamma, and 20ft 2-7/8"OD 6spf 15g Geodynamics gun (CCL to top shot 10.0ft) Pull correlation log - On depth,Pull on depth and perforate T-146 sands from 8,681-8,701ft @ 20:32hrs. POOH, All shots fired, Gun is a little damp, no sand SITP - 2740psi No pressure change in 15min,Secure well RD YJ E-line SDFN ! "# "#$% &'' "() *) +, ) -. ) ) /) /0) 1 ,)!"" #$%& '()*&+,- 2) 0)./0 1 ) #$%& '()*&+,- ) 1 / 1 *) 3 *) "( 14) * *) &23,*4 - &23,* ..- 5)+ ! 61 667 / /" 2 ,) ,) 52) 2) 657+/ 67+ "! 3 ,) )')) )')) 3 38) (,9'39 3) 8 '29 &+9'()/ ,5))')) )'() ):(;+('(38 &(&:8 ;8&' 9&1 /0 89: ;, 2 8-: * 2 89: 1,*12 <= >3,>3)33 &8'2) ,3'2& (+ 232'8))))))) " ).) ,) 2 &') / . ) ;*8-.: 8 : 67+ 8 : 89: 657+/ 8 : -< )& 23)'9, 383'())')))'))&9')) ;* 8 : "2* -* 8/0: - 8 : ,>&&>3)33 8?@#@?6 )+2@AB6C 6 )')) ,28')) @7 6* $&-) >& >3)33 8?!10<=&0!0 6 )&)!AB<=7D"# 0 69 2'+ & 23)'9, !10<=&0!0 6*&-* $) >& >3)33 8?!10<=&0!0 6 )&)!AB<=7D"# 0 6& 2+ ')) 9 93 '(9 !10<=&0!0 6*8-* -),>)(>3)33 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 : -. 8 : -. 8 : 1 2 8: 1 52 8: . 8: 897?: -* &9')) )')) )')) &9')) )')) )'))#&+9'() 3 38) (,9'39 3) 8 '29 )')) )')) 4=<4 )')) )')2 329',, )')) )')3 #)')8#&) '() 3 38) (,9'8) 3) 8 '2( )'3& )')& 8?@#@?6*&- && ')) )'88 8'22 && ')) )'3) #)') #()'() 3 38) (,9'+9 3) 8 '28 )'(+ #)')9 8?@#@?6*&- &,,')) )'+3 &,')) &,,')) )'(2 )')3&)'() 3 38) (,9'9, 3) 8 ,')3 )'3) #)'8, 8?@#@?6*&- 3+&')) )'(9 3&,'3+ 3+&')) )'(( #)'&&,+'() 3 38) (,9'9+ 3) 8 '92 &'(+ #)'3( 8?@#@?6*&- 8))')) 3'8( 3&&'() 322'29 #)',3 #)'23&88'+9 3 38) (,,'(2 3) 8 ')+ 8')& &'& 8?@#@?6*&- 8 &')) +'3& 3&,'99 8 )'9, #8'(( #3'2(&2+'8, 3 38) (,+'9) 3) 8 8'2( 8'&) +'() 8?@#@?6*&- +3+')) '38 3&,'8 +38' & #9')2 # '++3(,'&& 3 38) (,)'8( 3) 8 )'8+ 8'3& &)')+ 8?@#@?6*&- +9(')) 9')9 3&&'2+ +9+'&8 #&+'8 #&)',38&,' 8 3 38) ( +'&9 3) 8(('2& 8'38 &,'3( 8?@#@?6*&- (+ ')) 2' 9 3)8'(& (++'+) #33',) #&(')88,,'2) 3 38) ((('2( 3) 8(&'+) 8'8, 3(',( 8?@#@?6*&- ),')) &&'2( &29')2 )+'83 #88'+& #&2')++8,'93 3 38) (+('8+ 3) 8+,'&8 +'), 8('++ 8?@#@?6*&- 2')) &+'( &2 '98 +' #+ '2, #38'32+29'& 3 38) (8&'92 3) 8+3'(( +'3+ +,'), 8?@#@?6*&- "() *) +, ) -. ) ) /) /0) 1 ,)!"" #$%& '()*&+,- 2) 0)./0 1 ) #$%& '()*&+,- ) 1 / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 : -. 8 : -. 8 : 1 2 8: 1 52 8: . 8: 897?: -* ,8)')) & '(& &2,'&8 ,38'+8 # 3' ) #39') (( '28 3 38) (& '89 3) 88,'+) 8'3) )'8, 8?@#@?6*&- ,28')) &9'(9 &22' + ,98'+2 #9)' & #8+'), & '22 3 38) +29'(8 3) 88)'2( 8'() , '&) 8?@#@?6*&- 9 2'+ 3&' 3 3)&'82 9(('32 #&)('3) #+8'8& 99',2 3 38) +,+'& 3) 83&'&3 +')( 29'+) 8?!10<=&0!0 6*3- 283'2& 33'23 3) '+) 2&+')& #&3,'& #(8'),,+,'(& 3 38) +(3'+( 3) 8&)'98 8' 3 &&2'(& 8?!10<=&0!0 6*3- 228',2 38'9) 3&3' 2 2'2& #&+9'&3 # +'2,9)8'+& 3 38) +8&',2 3) 329'+8 +'83 &+&',& 8?!10<=&0!0 6*3- & )( ')3 3('& 3&,'28 & )3 '(( #& 2'&8 #,2'999 )')( 3 38) +&&'&( 3) 398')& +'&8 & '88 8?!10<=&0!0 6*3- & &&,'92 3,' , 33+'&9 & )9&'2, #&92'9& #2,'292&('+, 3 38) 82)'2& 3) 3 +'+& ')( &28'39 8?!10<=&0!0 6*3- & &9)'(3 8)'28 33,'92 & &8 '(9 #3&&')+ #&3)') 2,)')9 3 38) 8,)'38 3) 3+&'9& ('2 338',8 8?!10<=&0!0 6*3- & 3+3')+ 88'+, 383',( & &99' + #38&'23 #&+('8&& )33'&+ 3 38) 8+2'2, 3) 3& '), ('92 3( '+ 8?!10<=&0!0 6*3- & 8)+'9+ 8('&, 38 '82 & 3+)'(& #3(3'+& #&,+'& & ),+')& 3 38) 88)'&9 3) &9 ',8 +'3+ 32&'98 8?!10<=&0!0 6*3- & 8 ('9 8,'(( 382')& & 392' ( #3,&',3 #3)+',+& &38'&( 3 38) 8&&' 3 3) &((' 2 +' 83,'9+ 8?!10<=&0!0 6*3- & +3,' & 89'+2 3+)' ( & 889'8) #32)'98 #38,' 3& &,&'9) 3 38) 328'83 3) &33'8( 3'38 8 ('( 8?!10<=&0!0 6*3- & +92'38 82'8) 3++'83 & 89 '3, #8)9' 2 #3,&'28& 3&2',, 3 38) 3, '8) 3) )9,' 3 8'2 +)8' ( 8?!10<=&0!0 6*3- & (()'23 82'98 3+('2+ & +88'93 #83('3& #8),'(9& 3 ,'83 3 38) 3 )' 3) )(&'(9 &'99 ++&'22 8?!10<=&0!0 6*3- & &3' 3 +&'83 3+ '(9 & +9)' 2 #8+&'8 #8++'8&& 8&+'&2 3 38) 3+('+) 3) )&+'+ 3'(& +9)'2, 8?!10<=&0!0 6*3- & ,8'2 82',8 3+ ')9 & (3,'8& #8(,'8 #89)'93& 8 )'9& 3 38) 38)'8) 3)( 2,,'(9 3' ( (&2' , 8?!10<=&0!0 6*3- & ,8(' 8 82'3 3+(')9 & (,+'2) #8,8'(, #+& '(8& +)9'+) 3 38) 3&+'2 3)( 2+&'+9 &'39 ((,'9, 8?!10<=&0!0 6*3- & ,2,') 82',& 3+ '8& & 33'8& #892' ( #+(3'&8& +(('9& 3 38) &22',( 3)( 2)('() &'+, (2('2) 8?!10<=&0!0 6*3- & 9(2'( +&'3( 3+ ' + & 2'9( #+)('9+ #+92'88& ()8'8( 3 38) &9+'+, 3)( 9 ,'23 3'+2 8('3, 8?!10<=&0!0 6*3- & 23)'9, +)'(& 3+ '( & ,& '3& #+3&',9 #(3 '& & (+2',& 3 38) & 2'++ 3)( 98)',& &'3& ,+'&2 8?!10<=&0!0 6*3- & 2+ ')) +)' ( 3+ '8( & ,8('32 #+39'8& #(+&'&+& ( 9',2 3 38) & 8'3, 3)( 9&('(, )',9 2)')( 8?!10<=&0!0 6*8- & 299', +)'+) 3+2'8& & , ,'9) #+89',2 #( '9,& )&'8) 3 38) &(8'+3 3)( ,92' ) +'(+ ,& '9+ 8?!10<=&0!0 6*8- 3 )+9'38 8,'9& 3(8' , & 9&8'2( #+()',8 # )3'+)& +,'+( 3 38) &+3'8( 3)( ,(8',2 '8( ,(3'8) 8?!10<=&0!0 6*8- 3 &)2'(9 8 '(( 3(9'+2 & 9 3'9+ #+(2' # 89'8 & 2 '8+ 3 38) &8+'32 3)( ,&,' 3 ('&, ,9 '3, 8?!10<=&0!0 6*8- 3 &++',& 8 ',+ 3(9' 9 & 92&')8 #+ 8'9& # (9'2&& ,3+'(8 3 38) &8)' + 3)( 2 '29 )' 8 9)('&) 8?!10<=&0!0 6*8- 3 &,2'8) 8 ' & 3(+'2, & 2&9',, #+ 9'(3 # ,2')3& ,(3'3, 3 38) &3 '+8 3)( , ', '+3 938'23 8?!10<=&0!0 6*8- 3 3+&' 82',2 3+2'93 & 2 ,',2 #+9)'38 #,&(',8& 9)&'32 3 38) &&(' & 3)( 82',9 ,'3& 9 )'&, 8?!10<=&0!0 6*8- 3 8)8')8 +&')9 3+(')9 3 )&+'(& #+2('(& #,(3'+(& 9+9')& 3 38) &)&'3+ 3)( )3' 2 ('+8 929' & 8?!10<=&0!0 6*8- 3 8 +',& +8',, 3+)'33 3 ) )')( #(&+' ( #,92'8,& 928'(( 3 38) )98')) 3)( ( ('83 '9, 282'(+ 8?!10<=&0!0 6*8- 3 +39')2 +8'( 389'( 3 &)('2) #(8 '28 #93,')8& 282'+) 3 38) ) &' + 3)( (3,'&8 &'9+ 293'22 8?!10<=&0!0 6*8- 3 +92',, +3' & 3+)'(& 3 &()'2+ #((9'32 #9 8'88& 29+'++ 3 38) )+&'&, 3)( +2)'8& 3' ( & )3+'9) 8?!10<=&0!0 6*8- 3 ((&' 3 +&' 2 3+8'3& 3 &2 '9) #(,,'9, #922'233 )8)'8) 3 38) )33'+9 3)( +(8'3 8'32 & ) (',+ 8?!10<=&0!0 6*8- 3 &+')8 +&')2 3+ ',2 3 3+8' 8 #(2('8& #28,'8)3 ),,'&8 3 38) ))('2 3)( +&('+ 8'2& & &) ')3 8?!10<=&0!0 6*8- 3 ,('23 +&'33 3+,'++ 3 32)'38 # &&'&( #2,+'983 &38',8 3 332 22&')+ 3)( 8,,'(, )',3 & &+('+8 8?!10<=&0!0 6*8- 3 ,8,',3 +&'+& 3+ '+ 3 88 ' ( # 3,'&8 #& )&3'8,3 &,)'&( 3 332 2,('29 3)( 882' ( &')2 & &9+'2+ 8?!10<=&0!0 6*8- 3 ,22'38 +&'(9 3++',& 3 893',3 # +8'2, #& )+2'+93 3& '33 3 332 2 )')( 3)( 8)3'&+ &'2& & 33+' 8 8?!10<=&0!0 6*8- 3 9 )' , +&'8) 3+ '( 3 +39',9 # )',( #& )9 '(&3 3 3'39 3 332 2++'&9 3)( 3 +',& 3')+ & 3 +'38 8?!10<=&0!0 6*8- 3 238' & +&'+3 3+('32 3 +, ')3 # ,,',& #& &3+'+93 8)2'(3 3 332 239'&+ 3)( 33 '8+ &'8( & 8)+' 9 8?!10<=&0!0 6*8- 3 29 ' ( +)'9, 3+9'8( 3 (38'() # 2+')+ #& & 3' )3 8(,')) 3 332 2&3',+ 3)( &9,'98 8'8& & 8++'9 8?!10<=&0!0 6*8- 8 )+9',& +)',( 3+,'+9 3 (,)'+, #,)2'32 #& 3))'&93 +)8'2, 3 332 929'+3 3)( &+2'92 )'2+ & 898'2 8?!10<=&0!0 6*8- "() *) +, ) -. ) ) /) /0) 1 ,)!"" #$%& '()*&+,- 2) 0)./0 1 ) #$%& '()*&+,- ) 1 / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 : -. 8 : -. 8 : 1 2 8: 1 52 8: . 8: 897?: -* 8 &)9'89 89' 3+ '(, 3 & '89 #,3+'& #& 38('393 ++2'99 3 332 99+'+) 3)( &&+'++ 8' + & +3)'9( 8?!10<=&0!0 6*8- 8 &,3'32 89'2 3+('(& 3 '&9 #,+)'+8 #& 3,&'993 +22' 9 3 332 9 2')8 3)( ),,'+ &'&+ & +(2',2 8?!10<=&0!0 6*8- 8 388'38 89') 3+('(& 3 ,&8'9 #,( '& #& 8) '+&3 (+,'8 3 332 9(+'&( 3)( )+3'(( &'+9 & +2 ', 8?!10<=&0!0 6*8- 8 32('+9 89')9 3+8'2+ 3 , 3'9, #,,3'(+ #& 8+&'&33 (2 '8, 3 332 989' & 3)( )),'+ &'( & (8+'39 8?!10<=&0!0 6*8- 8 8((',( 8('+3 3+3'+2 3 9&&'& #,99',9 #& 8,8'8&3 ++' 3 332 938'& 3)+ 2,+'99 +' + & ( 2',) 8?!10<=&0!0 6*8- 8 +&,'9( 88'&& 3+)'22 3 9 3'+9 #9)('83 #& +)+'&&3 2('29 3 332 9),'89 3)+ 2+8' 2 8'2 & )+'3) 8?!10<=&0!0 6*8- 8 +9)'&3 88')3 3+8'), 3 2&+' , #93&'3( #& +8+'&&3 ,+9'&, 3 332 ,23'&9 3)+ 2&8'8& &'98 & 8,',) 8?!10<=&0!0 6*8- 8 (+3' , 8)'83 3+3'+& 3 2 ,'2) #98 '32 #& + 8'8&3 9)&'+) 3 332 ,,,'9 3)+ 998', +'8( & ,)')3 8?!10<=&0!0 6*8- 8 )+'+8 39'++ 3+3'38 8 )3&',& #9()'8 #& +2)'&+3 9(('3& 3 332 , +'++ 3)+ 9( '(2 8')( & 22'9, 8?!10<=&0!0 6*8- 8 ('(, 3('2) 3+&'+ 8 ), '&) #9 8'(8 #& (&+',(3 2)2' ) 3 332 ,(&'99 3)+ 98&' +'&2 & ,3,'+3 8?!10<=&0!0 6*8- 8 ,3,')) 3+'(9 3+)'(3 8 &8&' #9, '33 #& (8,' 3 2 ('& 3 332 ,82',( 3)+ 9)9'+( 3'3( & ,(8'83 8?!10<=&0!0 6*8- 8 ,99')) 33'9& 38,' 8 8 &9,'(3 #999'9) #& ((9',)8 )3&')3 3 332 ,3,' 2 3)+ ,9,'&3 8'+, & ,,,' 8?!10<=&0!0 6*8- 8 9+9'9+ 3)'(( 388'8) 8 3++') #2)&'() #& (,,'338 ),,'( 3 332 ,&('++ 3)+ , 9'32 +'(( & 9))')2 8?!10<=&0!0 6*8- 8 2&)' 2 &9' ) 33 ',( 8 8)3'8+ #2&+',( #& (28'&&8 &8('9+ 3 332 ,)3'(9 3)+ ,(3')9 +',+ & 93)', 8?!10<=&0!0 6*8- 8 2,8',2 &9'98 338'38 8 8 3'&) #232') #& ),'+38 &2(' ) 3 332 99' 3 3)+ ,8,'+8 &'98 & 9+)'98 8?!10<=&0!0 6*8- + )8('9+ &,',2 33('3+ 8 +3&')& #2+8')8 #& 3&')&8 3(+'(& 3 332 ,+'22 3)+ ,38'() &'2 & 9 )'&& 8?!10<=&0!0 6*8- + )2 '2& &('22 33('9+ 8 +,2'+( #2(('+ #& 88' ,8 8&3'2( 3 332 3'9, 3)+ ,&)'(+ 3'2 & 9,,',3 8?!10<=&0!0 6*8- + &(2'88 &(' ) 333',( 8 (82'(& #2 ,' & #& +('(88 8,8')& 3 332 (&')& 3)+ 29'82 &'+2 & 92+'(+ 8?!10<=&0!0 6*8- + 3&,'88 &('8& 3&2' 9 8 (2('+& #2,2'38 #& ((',38 +39'2& 3 332 82' + 3)+ 9,'23 &'() & 2)2' 2 8?!10<=&0!0 6*8- + 398'2+ &('8+ 333'+) 8 (2' #223'(& #& ,'3,8 +28'& 3 332 3 ' ( 3)+ , ')( &')9 & 23 '2+ 8?!10<=&0!0 6*8- + 8+('33 &('++ 333'(9 8 ,&9',+ #& ))+'() #& ,9'3 8 ((3'3+ 3 332 &+'28 3)+ +',, )'&9 & 2+3'2( 8?!10<=&0!0 6*8- + +)9'(+ &('22 33)',, 8 ,,2' 2 #& )&,'8& #& 92' 8 &8'&2 3 332 )3'+) 3)+ (8'), &'& & 2(2',2 8?!10<=&0!0 6*8- + +,)'&2 &('32 33('2, 8 982') #& )32'82 #& ,)&')(8 ,3'( 3 332 (2)' ) 3)+ +&'82 3'(+ & 2, '&2 8?!10<=&0!0 6*8- + (8&'2 &8'32 338'(8 8 929'23 #& )+)'3) #& ,&&',28 ,83'+3 3 332 (9)')( 3)+ 8)'89 8'89 & 22&'32 8?!10<=&0!0 6*8- + (28'88 &8'() 33&',& 8 2(9' 3 #& )()' , #& ,3&'+38 ,23'&3 3 332 ( 2'98 3)+ 3)'() )',, 3 ))('8) 8?!10<=&0!0 6*8- + (+'8& &8'93 33&'&, + )&,'9, #& ) &'+ #& ,8)'2(8 9(&'8, 3 332 ((2'3, 3)+ &)',& )'( 3 )&2'+8 8?!10<=&0!0 6*8- + ,& '++ &+'88 333')9 + ),9'&+ #& ),3',( #& ,+)'298 2&&' + 3 332 (+9'33 3)+ ))'+) )'92 3 )8+'3, 8?!10<=&0!0 6*8- + ,,,'32 &+'(2 333'3( + &8,') #& )9+')3 #& ,(&'&98 2,)'( 3 332 (8,'3& 3)+ (92'28 )'+8 3 )+2'33 8?!10<=&0!0 6*8- + 982'&3 &('&) 33&' 9 + &2 '98 #& )2('9) #& , &',9+ )8)'88 3 332 (3(' 2 3)+ (,2') )'9 3 ) +',2 8?!10<=&0!0 6*8- + 2))',& &('(+ 33&'28 + 3( '38 #& &),'28 #& ,,3' 3+ )92',8 3 332 (&8'98 3)+ ( ,'23 )',3 3 )9)',9 8?!10<=&0!0 6*8- + 2 8'32 & '3) 33)'29 + 8& '+3 #& &3)',( #& ,98'2(+ &+2'23 3 332 ()&'39 3)+ (( '39 &'&8 3 )2,'(, 8?!10<=&0!0 6*8- ( )3+'(, & ' ) 33&'+2 + 8,('3& #& &88', #& ,2('8 + 3)9',& 3 332 +99'(( 3)+ (++'( )' 2 3 &&+'(+ 8?!10<=&0!0 6*8- ( )9 '(3 &+'98 33)'33 + +8+'9+ #& &+ '+( #& 9) '8++ 3 9'8+ 3 332 +, '&+ 3)+ (88'39 3'2& 3 &8)'29 8?!10<=&0!0 6*8- ( &+,', &(')) 3&9'+( + +2+')3 #& &(9' + #& 9& '88+ 83,'(3 3 332 + +'3) 3)+ (33'22 )',2 3 &+ '83 8?!10<=&0!0 6*8- ( 3)2'++ &+'92 33&' + ((8' & #& &,)'9& #& 93 '( + 89,'&& 3 332 +(3'39 3)+ (&3'+, &'8( 3 & &'9( 8?!10<=&0!0 6*8- ( 3 2' 2 &(') 33,'3, + &&'93 #& &9&'2) #& 98,'+(+ ++('83 3 332 ++&'+( 3)+ ()&'8& 3'+3 3 &,,'3( 8?!10<=&0!0 6*8- ( 88+')( &('32 332',, + ,8'2+ #& &28') #& 9()'),+ (),'++ 3 332 +8)' & 3)+ +99'+3 &')9 3 &2+')( 8?!10<=&0!0 6*8- ( 82(',8 &(',( 38&'&3 + ,88'8, #& 3)8'(, #& 9 3'9)+ ( '9, 3 332 +3)'+& 3)+ +,('++ )'2( 3 3&)'(+ 8?!10<=&0!0 6*8- ( +(,'&2 &(' ) 33 '99 + ,23'(+ #& 3&+'+( #& 9,('88+ 3 ')+ 3 332 +)2'9+ 3)+ + 3' ( &'99 3 33,'&& 8?!10<=&0!0 6*8- ( (&9'(3 &+'8( 33)'( + 9(&',2 #& 33('9 #& 99 '32+ 9('32 3 332 829',) 3)+ +(&'+3 8'8( 3 3+3',( 8?!10<=&0!0 6*8- "() *) +, ) -. ) ) /) /0) 1 ,)!"" #$%& '()*&+,- 2) 0)./0 1 ) #$%& '()*&+,- ) 1 / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 : -. 8 : -. 8 : 1 2 8: 1 52 8: . 8: 897?: -* ( (9)'(( &+'&) 3&,'9) + 2&&'23 #& 38,' , #& 92('23+ ,+('+3 3 332 89,'&3 3)+ ++&'() &'&, 3 3(,'(9 8?!10<=&0!0 6*8- ( +&'29 &+'3& 33&'+( + 2,&'+2 #& 3+2'3+ #& 2)('()+ 9)+'22 3 332 8,('9) 3)+ +8&' ( &'+ 3 3,3'33 8?!10<=&0!0 6*8- ( ,)8'89 &+'88 338'&2 ( )8)'22 #& 3 )'+8 #& 2&(' 2+ 9 +'+2 3 332 8 +'9 3)+ +3&'&2 )',8 3 39,'&& 8?!10<=&0!0 6*8- ( , ('8 &+' + 338') ( )2&')) #& 3,&',+ #& 23 '39+ 23+'() 3 332 8(8'9) 3)+ +&)'83 )'() 3 8)3'+& 8?!10<=&0!0 6*8- ( 939'(9 &+' ( 338'99 ( &(3'&, #& 398'8+ #& 28,'39+ 29(' , 3 332 8+3'+9 3)+ 822')+ )'88 3 8&9'&2 8?!10<=&0!0 6*8- ( 92)') &+' 3 338'9 ( 3&&' ( #& 32+'(+ #& 2+9')+( )+('&( 3 332 88&'(+ 3)+ 899')& )')( 3 888'(( 8?!10<=&0!0 6*8- ( 2(&'29 &+'9+ 338' ( ( 3,&'(+ #& 8)('2& #& 2(9'28( &)(')+ 3 332 83)'++ 3)+ 8, '9( )'8, 3 8+2'&& 8?!10<=&0!0 6*8- )&+'38 &+'2, 333'(( ( 88&',) #& 8&,' ) #& 2 2'9,( & ('3) 3 332 8)2')3 3)+ 8 (' 3 )'() 3 8 +'2& 8?!10<=&0!0 6*8- ),('9& &('+2 333'8) ( 82&'&& #& 832'(+ #& 29)',9( 33+' & 3 332 32,'8( 3)+ 8(+'+3 )'9( 3 89)'9+ 8?!10<=&0!0 6*8- &8 ' + &(' ) 33&'22 ( ++2',3 #& 8+&' 8 #& 22&',3( 398'33 3 332 39('(8 3)+ 8+8'3) )'38 3 82 '9, 8?!10<=&0!0 6*8- &22'2& &('98 33)'3) ( (&)' 3 #& 8(+'(( #3 ))3'29( 8++'&3 3 332 3,3'92 3)+ 88&' 3 )'9( 3 +&8' , 8?!10<=&0!0 6*8- 3 &'+8 &(')( 33&'(8 ( ( 2'23 #& 8 '28 #3 )&8',)( +)8'+3 3 332 3 )',, 3)+ 83)' & &'82 3 +32',& 8?!10<=&0!0 6*8- 8&9'&& &('8+ 333'39 ( 3+' 3 #& 8,,'22 #3 )38' 3( +(9'&3 3 332 3+2'2 3)+ 8&)'+3 )' 3 3 +++'8& 8?!10<=&0!0 6*8- 8(+'98 &('82 33)'9 ( )')8 #& 89('3, #3 )8)'),( +28'(8 3 332 3+3'9+ 3)+ 8)8',2 &')8 3 +(8'9 8?!10<=&0!0 6*8- +& ')8 &+'89 33&'&8 ( ,&2'&, #& 82,'&8 #3 )+)'82( ((3' , 3 332 38&'38 3)+ 328'3) &' ( 3 + 2'3, 8?!10<=&0!0 6*8- +, '2, &+'+, 33)'++ ( ,,9'&2 #& +)9' 8 #3 )()'8)( &&' 2 3 332 3&2'29 3)+ 398')) )'83 3 +9+'&8 8?!10<=&0!0 6*8- (82'9, &+'38 33)'(+ ( 982'&8 #& +3)'+2 #3 ) )'+3( ,3' 8 3 332 3)9'8, 3)+ 3,3'(2 )'89 3 +22'89 8?!10<=&0!0 6*8- ))'28 &8'9 33)'() ( 929'8 #& +8&',( #3 ),)')(( ,8&'9 3 332 &2,'8+ 3)+ 3 3',) )' & 3 (&8'99 8?!10<=&0!0 6*8- 3'2+ &8'( 33)') ( 2(9' & #& ++3'2 #3 ),2'((( ,23'&& 3 332 &9 '8, 3)+ 3(3'23 )'(& 3 (39'3+ 8?!10<=&0!0 6*8- ,3+'3( &8' 33)' 8 )&9'3) #& +(8'2 #3 )99'92( 9(&',) 3 332 &,(' ) 3)+ 3+8'83 )'3, 3 (+3'8+ 8?!10<=&0!0 6*8- ,9 '39 &8'22 333'+8 ),9'+8 #& + (')( #3 )29',3( 2&&'28 3 332 & +',( 3)+ 388'33 )'9, 3 (( '92 8?!10<=&0!0 6*8- 9+9'2( &8'2+ 338') &82'3( #& +, '& #3 &)9'22( 2,3',( 3 332 &(8'2) 3)+ 333' 2 )'3 3 (,&'9) 8?!10<=&0!0 6*8- 2&)'39 &8' 2 333'2) &29'9) #& +9 '9, #3 &&9'2, )83'8) 3 332 &+8'+8 3)+ 3&3'+( )'+& 3 (9 '3+ 8?!10<=&0!0 6*8- 2,&',+ &8',, 338'&+ 3(9'(& #& +2,'(+ #3 &39'23 )23')& 3 332 &88')& 3)+ 3)3'3+ )'& 3 ))' 8 8?!10<=&0!0 6*8- , )88',+ &+')& 338'(9 8&9' 2 #& ()9'8 #3 &82'&+ &(3'&2 3 332 &33'++ 3)+ &2&', )'+3 3 &('88 8?!10<=&0!0 6*8- , )2+'9+ &+'8 333'9) 8,,'28 #& (&2'3, #3 &+2'82 3&&'+8 3 332 &&&',9 3)+ &9&'3( )' ( 3 8)'&) 8?!10<=&0!0 6*8- , &( ',( &+'29 333'+2 +8,'93 #& (8)'9& #3 & )')& 3,&'83 3 332 &))'(& 3)+ &,)'8( &')& 3 +('(( 8?!10<=&0!0 6*8- , 3&9'28 &+',9 33&'2 +2,'23 #& (+3' 8 #3 &,)',+ 88&'+3 3 332 )99'2( 3)+ &(2'8+ )'82 3 &'3 8?!10<=&0!0 6*8- , 39&'&, &+',9 33&'(+ ((9'&) #& ((+'+9 #3 &9&'8& 82&' ) 3 332 ),,'8 3)+ &+9'+9 )'&, 3 , '9 8?!10<=&0!0 6*8- , 8+3'22 &+' 9 33&'( &,'92 #& ( '3+ #3 &2&',+ +(&'82 3 332 ) ('9 3)+ &8,',, )'& 3 23'32 8?!10<=&0!0 6*8- , +)+'9& &+'9& 33&'( ,,' , #& (,9')& #3 3)3'&9 (&&'&, 3 332 )(+'8+ 3)+ &3,')( )'3& 3 ,),',+ 8?!10<=&0!0 6*8- , + '(& &+'(2 333' ,8,'8( #& (92' 8 #3 3&3' 9 (,)'9( 3 332 )+3'29 3)+ && '3, )'(9 3 ,38'&+ 8?!10<=&0!0 6*8- , (39'+8 &+'3( 33&', ,2,'83 #& )&')( #3 338')+ 8)'93 3 332 )8&'93 3)+ &)(' + )' 3 ,89'8& 8?!10<=&0!0 6*8- , (9 ' + &+'8& 333')2 9(8',8 #& &&',8 #3 383' 8 9,'38 3 332 )3&'8, 3)+ )2(',2 )'&, 3 ,(3'+3 8?!10<=&0!0 6*8- , (3',( &+'(2 33&'9& 2&,',( #& 3+')) #3 3+8' ,(&'3( 3 332 ))2'89 3)+ )9+'+ )'++ 3 , 9' + 8?!10<=&0!0 6*8- , ,&8'(3 &+' 33&') 2, '(( #& 8('() #3 3(8'9& 9&)')( 3 339 229'&3 3)+ ),+')8 )'88 3 ,98',) 8?!10<=&0!0 6*8- , ,, ')8 &+' ) 3&2'2 , )8,')8 #& +,'(& #3 3 +'), 9,)'(8 3 339 29 '8, 3)+ ) 8'+2 )'+( 3 ,22'&+ 8?!10<=&0!0 6*8- , 989')8 &+'++ 3&2'3) , )2,')( #& (2'+2 #3 3,8'2, 28)'(( 3 339 2,+' + 3)+ )(8'32 )'+) 3 9&+'32 8?!10<=&0!0 6*8- , 922' & &8'29 3&9'9, , &( ',( #& ,&'38 #3 398'+2 22)'3( 3 339 2 8'&8 3)+ )+8'+2 )', 3 932')) 8?!10<=&0!0 6*8- , 2 &',8 &+'+) 3& ' 3 , 3& '2, #& 98'3, #3 323'9&, )()'+, 3 339 2(&'83 3)+ )88'99 &'&3 3 9+8',3 8?!10<=&0!0 6*8- "() *) +, ) -. ) ) /) /0) 1 ,)!"" #$%& '()*&+,- 2) 0)./0 1 ) #$%& '()*&+,- ) 1 / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 : -. 8 : -. 8 : 1 2 8: 1 52 8: . 8: 897?: -* 9 )33'93 &(')& 3&2',( , 3, ') #& 2('+( #3 8)3'+), &)2'( 3 339 282'89 3)+ )3+')) &' + 3 9(9',+ 8?!10<=&0!0 6*8- 9 )9+'+( &+'9) 33)')+ , 88(' 3 #& ,),' & #3 8&3'(,, & 2'&3 3 339 23,'+, 3)+ )&8'(+ )'8 3 9,+'3& 8?!10<=&0!0 6*8- 9 &+,'83 &+' , 3&,'+& , 82 '+3 #& ,3)')9 #3 833'(,, 332'23 3 339 2&('3+ 3)+ ))8'3+ &')9 3 992',+ 8?!10<=&0!0 6*8- 9 3)9'9+ &('+3 33&'&3 , +(('9+ #& ,83'+8 #3 883' 9, 392'8+ 3 339 2)8'&+ 3)8 223'98 &'29 3 2)('39 8?!10<=&0!0 6*8- 9 3,)'2) & ')2 3&2'8( , (&('( #& ,+('8) #3 8+8'( , 8+2') 3 339 92)'(( 3)8 29&' + &'88 3 23&',+ 8?!10<=&0!0 6*8- 9 883'92 & '&) 3&9'23 , (,('&3 #& ,(9' 8 #3 8(+'+&, +)9' 3 3 339 9,,'+9 3)8 2,)'+, )'&2 3 289'+ 8?!10<=&0!0 6*8- 9 828', &(' 2 3& '9 , 88' , #& ,,&',9 #3 8 +' (, + ,'&, 3 339 9 +'(9 3)8 2(2'2& &'&( 3 2(+'(2 8?!10<=&0!0 6*8- 9 +( ' + &('88 3&+'+9 , 2+'3 #& ,9('++ #3 8,+'+(, (3,', 3 339 9(&'&, 3)8 2+2',9 &'& 3 2,)' 9 8?!10<=&0!0 6*8- 9 (&,',9 &('+, 3&+')8 , ,(8'3) #& ,29'9 #3 898'(2, (9 ',) 3 339 98,'29 3)8 2+)'83 )'8) 3 29 '&) 8?!10<=&0!0 6*8- 9 (,2'+, &('9) 3&8'3( , 9&3' & #& 9&3',) #3 823'9), + '&& 3 339 93+'8 3)8 28)',, )' 8 8 ))&'9+ 8?!10<=&0!0 6*8- 9 +&'), & ')3 3&)' , 9,&'9( #& 93,')3 #3 +)&',8, ,)('8( 3 339 9&)'3 3)8 23&'+2 &'3& 8 )&,' + 8?!10<=&0!0 6*8- 9 ,)8'&3 & '&9 3)2'(8 , 28&'+, #& 9+&'2& #3 +&)'8 , , +'2, 3 339 ,2('(2 3)8 2&3'(& )'(, 8 )88'(( 8?!10<=&0!0 6*8- 9 , (')& &('2, 3)2' + , 22)'2+ #& 9( '9& #3 +&9'93, 93+'++ 3 339 ,9)'2) 3)8 2)8' 2 )'8+ 8 )+2'88 8?!10<=&0!0 6*8- 9 93 '(9 &(' 8 3),'3, 9 )()'&9 #& 9,&'(( #3 +3 '9&, 998' 9 3 339 , '8 3)8 92('8+ &'&9 8 ) +' + 8?!10<=&0!0 6*8- 9 92)')) &(' 8 3),'3, 9 &&&'3 #& 99 ',8 #3 +8+' +, 2++', 3 339 ,(&'8, 3)8 99,'&+ )')) 8 )9)'&) .E4/4/ 7$B7$B B Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.07.14 15:10:55 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.07.15 09:09:00 -08'00' ! 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9:; 768,0 9 ; 78, 9 ; ./ 9 ; ./ 9 ; 2 3 9; 2 63 9; / 9; 9:8@; .+ ,8)')) " '(" "2,'"8 ,38'+8 % 3' ) %39') (( '28 3 38) (" '89 3) 88,'+) 8'3) )'8, 8?@%@?6*"- ,28')) "9'(9 "22' + ,98'+2 %9)' " %8+'), " '22 3 38) +29'(8 3) 88)'2( 8'() , '") 8?@%@?6*"- 9 2'+ 3"' 3 3)"'82 9(('32 %")('3) %+8'8" 99',2 3 38) +,+'" 3) 83"'"3 +')( 29'+) 8?# 10<="0# 0 6*3- 283'2" 33'23 3) '+) 2"+')" %"3,'" %(8'),,+,'(" 3 38) +(3'+( 3) 8")'98 8' 3 ""2'(" 8?# 10<="0# 0 6*3- 228',2 38'9) 3"3' 2 2'2" %"+9'"3% +'2,9)8'+" 3 38) +8"',2 3) 329'+8 +'83 "+"'," 8?# 10<="0# 0 6*3- " )( ')3 3('" 3",'28 " )3 '(( %" 2'"8%,2'999 )')( 3 38) +""'"( 3) 398')" +'"8" '88 8?# 10<="0# 0 6*3- " "",'92 3,' , 33+'"9" )9"'2, %"92'9" %2,'292"('+, 3 38) 82)'2" 3) 3 +'+" ')( "28'39 8?# 10<="0# 0 6*3- " "9)'(3 8)'28 33,'92 " "8 '(9 %3""')+ %"3)') 2,)')9 3 38) 8,)'38 3) 3+"'9" ('2 338',8 8?# 10<="0# 0 6*3- " 3+3')+ 88'+, 383',( " "99' + %38"'23 %"+('8"" )33'"+ 3 38) 8+2'2, 3) 3" '), ('92 3( '+ 8?# 10<="0# 0 6*3- " 8)+'9+ 8('", 38 '82 " 3+)'(" %3(3'+" %",+'" " ),+')" 3 38) 88)'"9 3) "9 ',8 +'3+ 32"'98 8?# 10<="0# 0 6*3- " 8 ('9 8,'(( 382')" " 392' ( %3,"',3 %3)+',+" "38'"( 3 38) 8""' 3 3) "((' 2 +' 83,'9+ 8?# 10<="0# 0 6*3- " +3,' " 89'+2 3+)' ( " 889'8) %32)'98 %38,' 3" ","'9) 3 38) 328'83 3) "33'8( 3'38 8 ('( 8?# 10<="0# 0 6*3- " +92'38 82'8) 3++'83 " 89 '3, %8)9' 2 %3,"'28" 3"2',, 3 38) 3, '8) 3) )9,' 3 8'2 +)8' ( 8?# 10<="0# 0 6*3- " (()'23 82'98 3+('2+ " +88'93 %83('3" %8),'(9" 3 ,'83 3 38) 3 )' 3) )("'(9 "'99 ++"'22 8?# 10<="0# 0 6*3- " "3' 3 +"'83 3+ '(9 " +9)' 2 %8+"'8 %8++'8"" 8"+'"2 3 38) 3+('+) 3) )"+'+ 3'(" +9)'2, 8?# 10<="0# 0 6*3- " ,8'2 82',8 3+ ')9 " (3,'8" %8(,'8 %89)'93" 8 )'9" 3 38) 38)'8) 3)( 2,,'(9 3' ( ("2' , 8?# 10<="0# 0 6*3- " ,8(' 8 82'3 3+(')9 " (,+'2) %8,8'(, %+" '(8" +)9'+) 3 38) 3"+'2 3)( 2+"'+9 "'39 ((,'9, 8?# 10<="0# 0 6*3- " ,2,') 82'," 3+ '8" " 33'8" %892' ( %+(3'"8" +(('9" 3 38) "22',( 3)( 2)('() "'+, (2('2) 8?# 10<="0# 0 6*3- " 9(2'( +"'3( 3+ ' + " 2'9( %+)('9+ %+92'88" ()8'8( 3 38) "9+'+, 3)( 9 ,'23 3'+2 8('3, 8?# 10<="0# 0 6*3- " 23)'9, +)'(" 3+ '( " ," '3" %+3"',9 %(3 '" " (+2'," 3 38) " 2'++ 3)( 98)'," "'3" ,+'"2 8?# 10<="0# 0 6*3- " 298'83 +)'9 3+ ')+ " , 8'( %+89'"+%( 8'+8" (2,') 3 38) "(8'29 3)( ,28')( )',9 ,"8',3 8?# 10<="0# 0 6*3- 3 )++'+" +"'2) 3+('"2" 9)2'+) %+(+'93 % ))'3"" +3'2) 3 38) "89'3" 3)( ,(('99 "'28 ,(8')( 8?# 10<="0# 0 6*3- 3 ")('9 +8'() 3++'+( " 9(+'( %+,3'(( % 8,'23" 99') 3 38) "3"'+) 3)( ,",',( 3',8 ,28',, 8?# 10<="0# 0 6*3- 3 "8,'9, ++'8, 3++' " " 9,,' " %+93'")% (,'2," ,""'"" 3 38) ""3'8+ 3)( 2,'+, 3',+ 9"('+2 8?# 10<="0# 0 6*3- 3 ", '99 +('"" 3++'), " 2)('83 %+28'22 % 93',3" ,89'93 3 38) ")"')( 3)( ,3'++ 3'"8 9+3'8 8?# 10<="0# 0 6*8- 3 3+"')+ + ')8 3+3'3+ " 2()'3+ %("+' 9 %,38' )" ,98',+ 3 38) )9"'8 3)( 8"'), 3'+2 99,'82 8?# 10<="0# 0 6*8- 3 8)8'8" +,'3) 3+"'+2 " 228')" %(8 ')8 %, 8'()" 93 '(" 3 38) ) "')) 3)( (2)' 3'), 283')+ 8?# 10<="0# 0 6*8- 3 8 (',8 +,',, 3+)'9+ 3 )8('"2%((9'33 %9)8'9)" 9 9' 2 3 38) )82'9) 3)( (+2'98 "'"2 2,,'(3 8?# 10<="0# 0 6*8- 3 +3 '23 +9'(8 3+)')" 3 ), ')3 %(9)'," %9+8'++" 2)2'(3 3 38) )"9'3, 3)( ()2' ( "' ) " )33' , 8?# 10<="0# 0 6*8- 3 +99'), +9'9" 382')" 3 "" '+) % )+')" %998')"" 2+2'2) 3 332 22('2+ 3)( + 2'(8 "'8" " ) 9'3+ 8?# 10<="0# 0 6*8- 3 (("'3) +2'83 389'88 3 "(,', % 39'9" %238',(" 22"'3 3 332 2,3'"+ 3)( +39'3) "'"(" ""(' ( 8?# 10<="0# 0 6*8- 3 "+'82 +2'(2 38,'( 3 "29'9+ % (+'8) %2 +'++3 )83'8+ 3 332 2+,' ( 3)( 89 '2) "')3 " " 8'+ 8?# 10<="0# 0 6*8- 3 ()')) +2'(2 38,'( 3 33"'23 % 9'9+ %29,'883 )(('+3 3 332 288' , 3)( 8 8' , )')) " "2)'+ .E4/4/ 7!B7!B B Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.07.14 15:12:22 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.07.15 09:03:05 -08'00' TD Shoe Depth: PBTD: Jts. 2 51 Yes X No X Yes No 6 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?: 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?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: 255 2.4 157 1.16 5 2.00 19.90 17.90Wellhead 18 5/8 Cactus 21.37 Hanger 16 CDC 1.47 21.37 19.90 2,089.42 23.74 Hanger pup 7 5/8 29.7 L-80 CDC USS 2.37 23.74 1.33 2,090.75 2,089.42 7 5/8" Casing Joints 7 5/8 29.7 L-80 CDC USS 2,065.68 Float collar 7 5/8 29.7 L-80 CDC Innovex 2 on Joint#1, 1 on joint#2, 1 on joint#3, 1 on every other joint to 350' below surface. Total 25 centralizers. 7 5/8" CSG Joints 7 5/8 29.7 L-80 CDC USS 78.15 2,168.90 2,090.75 www.wellez.net WellEz Information Management LLC ver_04818br 5 Type of Shoe:Innovex Bullnose Casing Crew:Weatherford 12 108 2,170.412,175.00 CEMENTING REPORT Csg Wt. On Slips: Spud mud 2:25 6/27/2022 0 15.8 33 Bump press Visual Bump Plug? 95.5/96 1470 36 Cement unit FI R S T S T A G E 10.5Tuned 60 9.3 5 100 570 Csg Wt. On Hook: Type Float Collar:Innovex No. Hrs to Run:5.5 CDC Innovex 1.51 2,170.41 2,168.90 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Paxton 06 Date Run 26-Jun-22 CASING RECORD County State AK Supv.Jay Murphy 2,089.00 Floats Held Mud Rotate Csg Recip Csg Ft. Min. PPG Shoe @ 2175 FC @ Top of Liner Casing (Or Liner) Detail Float shoe 7 5/8 29.7 L-80 TD Shoe Depth: PBTD: Jts. 1 2 171 Yes X No X Yes No 40 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface? 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 4 1/2 12.6 L-80 Rotate Csg Recip Csg Ft. Min. PPG9.3 Shoe @ 8886 FC @ Top of Liner 17308,841.00 Floats Held Mud CASING RECORD County State AK Supv.Josh Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Paxton 06 Date Run 9-Jul-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top DWC/C-HT Baker 1.78 8,886.00 8,884.22 Csg Wt. On Hook:125,367 Type Float Collar:Baker No. Hrs to Run:14.5 9.3 6 995 FI R S T S T A G E 10.5Tuned prime 30 128.5/131.2 1722 0 Cement Unit 15.3 19 Bump press CBL Bump Plug? 5:30 7/10/2022 ~3,000' 8,886.008,890.00 CEMENTING REPORT Csg Wt. On Slips: Mud 12 227 Type of Shoe:Baker Casing Crew:Parker Wellbore Baker Flex-lock liner hanger HRDE ZXP liner packer www.wellez.net WellEz Information Management LLC ver_04818br 3 1 centralizer per float equipment joint and 1 centralizer every other joint to the liner hanger. 85 centralizers total. 4 1/2" Liner Joint 4 1/2 12.6 L-80 DWC/C-HT USS 41.42 8,884.22 8,842.80 Float collar 4 1/2 12.6 L-80 DWC/C-HT USS 1.46 8,842.80 8,841.34 4 1/2" Liner Joints 4 1/2 12.6 L-80 DWC/C-HT USS 40.99 8,841.34 8,800.35 Landing collar 4 1/2 12.6 L-80 DWC/C-HT USS 1.05 8,800.35 8,799.30 4 1/2" Liner Joints 4 1/2 12.6 L-80 DWC/C-HT USS 7,031.53 8,799.30 1,767.77 Flexlock liner hanger/pkr 7 12.6 L-80 DWC/C-HT Baker 38.21 1,767.77 1,729.56 540 2.39 95 1.24 6 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: 09/06/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 6PB1 (REVISED DUE TO API # ERROR) - PTD 222-054 - API 50-133-20707-70-00 MUDLOGS - EOW DRILLING REPORTS (06/30/2022 to 07/08/2022) 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 - Main Folders: Sub-Folder Contents: Please include current contact information if different from above. (REVISED DUE TO API # ERROR) PTD:222-054 T36825 Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.07 09:54:09 -08'00' 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 Date: 09/08/2022 To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 6 P B 1 - PTD 222-054 - API 50-133-20707-70-00 Washed and Dried Well Samples (06/30/2022) B Set (1 Box) : WELL I BOX SAMPLE INTERVAL (FEET / MD) PAXTON 6PB1 I BOX 1 OF 1 2160' — 2650' MD PAXTON 6 - PTD 222-054 - API 50-133-20707-00-00 Washed and Dried Well Samples (07/08/2022) B Set (6 Boxes): WELL BOX SAMPLE INTERVAL (FEET i MD) PAXTON 6 BOX 1 OF 6 1946' - 3210' MD PAXTON 6 BOX 2 OF 6 3210' - 4500' MD PAXTON 6 BOX 3 OF 6 4500' - 5700' MD PAXTON 6 BOX 4 OF 6 5700' - 7050' MD PAXTON 6 BOX 5 OF 6 7050' - 8190' MD PAXTON 6 BOX 6 OF 6 8190' - 8890' MD (TD) Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received � �� /I Date: � / I aa)--05q � 00 RECEIVED SEP 0 8 2022 AOGCC 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:Jacob Flora Subject:RE: Paxton 6 CBL July-23-2022 (PTD 225-054) (Sundry_322-388) Date:Tuesday, July 26, 2022 9:08:00 AM Jake, Cement looks good across the entire sundried perf interval. You have approval to proceed with perforating per Sundry 322-388. Regards Bryan 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, July 25, 2022 3:40 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Paxton 6 CBL July-23-2022 (PTD 225-054) (Sundry_322-388) Hello Bryan, Please see attached CBL, we had to pick up a mill and clean out the shoe track to see all of the bottom target sand, the current CBL was run after cleaning out. We are planning on shooting the T-146 (8681’ to 8744’ MD) as the first and primary target. Please advise if you see any issues, Thanks, Jake Jake Flora | Kenai Ops Engineer | Hilcorp Alaska | 720-988-5375 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 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 07/25/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 6 + PAXTON 6PB1 - PTD 222-054 - API 50-133-20707-00-00 + 50-133-20707-70-00 MUDLOGS - EOW DRILLING REPORTS (06/30/2022 to 07/08/2022) 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 - Main Folders: Sub-Folder Contents: Please include current contact information if different from above. PTD:222-054 Paxton 6: T36824 Paxton 6PB1: T36825 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.25 13:48:37 -08'00' 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: 7/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 6 + PAXTON 6PB1 - PTD 222-054 - API 50-133-20707-00-00 + 50-133-20707-70-00 FINAL LWD FORMATION EVALUATION LOGS (06/24/2022 to 07/08/2022) AGR, EWR-M5, DGR, ADR, PCG, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Main Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. PTD:222-054 Paxton 6: T36822 Paxton 6PB1: T36823 Kayla Junke Digitally signed by Kayla Junke Date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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:8 DATE: 7/17/22 Rig Rep.: Rig Phone: 208-553-6699 Operator: Op. Phone:907-777-8300 Rep.: E-Mail Well Name: PTD #22220540 Sundry #322-388 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:NA Valves:250/3000 MASP:2668 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75 B/S P Flow Indicator NA NA #2 Rams 1 1.75 P/S P Meth Gas Detector NA NA #3 Rams 0 NA NA H2S Gas Detector NA NA #4 Rams 0 NA NA MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA Quantity Test Result Choke Ln. Valves 2 2"P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2"P Check Valve 0 NA NA ACCUMULATOR SYSTEM: BOP Misc 0 NA NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2450 P Quantity Test Result 200 psi Attained (sec)5 P No. Valves 5P Full Pressure Attained (sec)16 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): NA NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:2.0 Hours Repair or replacement of equipment will be made within NA days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7/16/22 11:19 Waived By Test Start Date/Time:7/17/2022 12:00 (date) (time)Witness Test Finish Date/Time:7/17/2022 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Accumulator precharge pressure 1400 psi Landry Lynn Hilcorp Brad Gathman Paxton 6 Test Pressure (psi): brad.gathman@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0717_BOP_Fox8_Ninilchik_Paxton-6 999 9 9 9999 9 9 MEU -5HJJ 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:Rixse, Melvin G (OGC) To:Sean McLaughlin Cc:McLellan, Bryan J (OGC) Subject:FW: Paxton 6 FIT (222-054) Date:Wednesday, June 29, 2022 12:18:00 PM Attachments:Paxton #6 7.625"" Casing Fit test 6-28-22.xls Sean, I could go to 12.1 FIT as stated on your spreadsheet. Approved to drill 300’, cement, then set a whipstock in more competent formation. 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). From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Wednesday, June 29, 2022 10:41 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Paxton 6 FIT (222-054) Mel, The FIT obtained on Paxton 6 was much lower than expected. A 16.5# FIT was planned to drill to TD of 9,266’. A 11.1# FIT was obtained. We are seeing a dramatic increase in sand/reservoir quality out of our shoe than we expected based on offset wells. This could be leading to the poorer overall LOT. Additionally, we may have crossed a fault that separates Paxton from Pearl and have the Beluga 45 sand higher in section than anticipated. The plan is to drill ahead 300’ to 2500’ MD to get logs across this area to help corelate our position. I calculate the KTV is unlimited at 2500’ MD. The well will then be plugged back with a retainer and cement. A whipstock will then be set around 2070’ in a more competent formation. After milling window we will perform an FIT and send to the AOGCC within 24 hrs as written in the well program. At this time there is no change to our casing plan, only the sidetrack addition, which is due to geology. Regards, sean Sean McLaughlin Hilcorp Alaska, LLC Drilling Engineer Sean.McLaughlin@hilcorp.com Cell: 907-223-6784 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 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. 5HJJ-DPHV%2*& )URP-D\0XUSK\&-D\0XUSK\#KLOFRUSFRP! 6HQW7XHVGD\-XQH$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& 6XEMHFW+LOFRUS $WWDFKPHQWV+LOFRUS[OV[ dŚĂŶŬzŽƵĂŶĚĞƐƚZĞŐĂƌĚƐ͕ :ĂǇDƵƌƉŚǇͬ^D +LOFRUS$ODVND//& ,<ZŝŐϭϲϵ KĨĨŝĐĞ͗ϵϬϳͲϮϴϯͲϭϯϲϵ Ğůů͗ϵϬϳͲϳϭϱͲϵϮϭϭ :ĂǇ͘DƵƌƉŚǇΛ,ŝůĐŽƌƉ͘ĐŽŵ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:169 DATE: 6/28/22 Rig Rep.: Rig Phone: 907-283-1390 Operator: Op. Phone:907-283-1369 Rep.: E-Mail Well Name: PTD #22220540 Sundry #N/A Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2880 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 4 1/2"FP Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 1 2 7/8" x 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"p Inside Reel valves 0NA HCR Valves 2P Kill Line Valves 2 2 1/16 FP Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3100 P CHOKE MANIFOLD:Pressure After Closure (psi)1650 P Quantity Test Result 200 psi Attained (sec)24 P No. Valves 15 P Full Pressure Attained (sec)97 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 @ 2525 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:2 Test Time:9.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6-26-2022 18:26 Waived By Test Start Date/Time:6/27/2022 19:30 (date) (time)Witness Test Finish Date/Time:6/28/2022 4:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Upper 2 7/8" X 5" VBRs failed. Changed out to 4 1/2" fixed rams, tested OK. Manual inside kill line valve failed. Greased, functioned and retested OK. All tests conducted with a 4-1/2" test joint. Annular Preventer closed in 23 seconds during drawdown test. Davis/ Deshotel Hilcorp Alaska, LLC Murphy/ Lawson Paxton 6 Test Pressure (psi): Jay.Murphy@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0628_BOP_Hilcorp169_Ninilchik_Paxton-6 9 9 9 9 9 9 9 9 9 9 9 9 MEU -5HJJ FP FP Upper 2 7/8" X 5" VBRs failed. Changed out to 4 1/2" fixed rams,Manual inside kill line valve failed. 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ate: 6/24/2022 Development: X Exploratory: Drlg Contractor: Rig No. 169 AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.: 2220540 Rig Phone: Rig Email: MMISCEL L ANEOUS:DIVERTER SYSTEM: Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice: P Vent line Below Diverter? P AACCUMUL ATOR SYSTEM:Diverter Size: 21 1/4 in. Systems Pressure: 2975 psig P Hole Size: 9 7/8 in. Pressure After Closure: 1500 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time: 25 Seconds P Vent Line(s) Length: 115 ft. P Full Recharge Time:113 Seconds P Closest Ignition Source: 75.5 ft. P Nitrogen Bottles (Number of): 4 Outlet from Rig Substructure: 97 ft. P Avg. Pressure: 2500 psig P Accumulator Misc: NA Vent Line(s) Anchored: P MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: P Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: Flow Monitor: P P Annular Closed Time: 40 sec P Mud System Misc: 0 NA Knife Valve Open Time: 4 sec P Diverter Misc: NA GGAS DETECTORS:Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA Total Test Time: 1.5 hrs Non-Compliance Items: 0 Remarks: Submit to: SSTATE OF AL ASK A AAL ASK A OIL AND GAS CONSERVATION COMMISSION DDi v er t er Sys t em s In s p ec t i o n Rep o r t GGENERAL INFORMATION WaivedHilcorp **Al l Di verter rep o r t s ar e d u e t o t h e ag en c y w i t h i n 5 d ays o f t est i n g * Jay.Murphy@hilcorp.com TTEST DATA Brandon Davis phoebe.brooks@alaska.gov Hilcorp Alaska, LLC 0 Jay Murphy 0 907-283-1369 TTEST DETAIL S jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov Ninilchik/ Paxton/ Well 6 Form 10-425 (Revised 05/2021)2022-0624_Diverter_Hilcorp169_Ninilchik_Paxton-6 9 9 9 9 9 -5HJJ 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: Ninilchik Field, Beluga/Tyonek Gas Pool, Paxton 6 Hilcorp Alaska, LLC Permit to Drill Number: 222-054 Surface Location: 784' FNL, 2960' FEL, Sec 13, T1S, R14W, SM, AK Bottomhole Location: 2635' FNL, 214' FEL, Sec 14, T1S, R14W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of June, 2022. Jeremy Price Digitally signed by Jeremy Price Date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¶)1/¶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y Samantha Carlisle at 2:24 pm, May 10, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV '65 6)'%-0 %23 WHVW WR SVL DQQXODU WHVW WR SVL 6XEPLW ),7/27 UHVXOWV ZLWKLQ KUV RI SHUIRUPLQJ WHVW 3URYLGH KUV QRWLFH IRU $2*&& WR ZLWQHVV 0,770,7,$ JLC 6/10/2022 dts 6/14/2022 6/14/22 Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.14 11:43:25 -08'00' 3D[WRQ 'ULOOLQJ3URJUDP 1LQLOFKLN8QLW 0D\ &RQWHQWV :HOO6XPPDU\ 0DQDJHPHQWRI&KDQJH,QIRUPDWLRQ 7XEXODU3URJUDP 'ULOO3LSH,QIRUPDWLRQ ,QWHUQDO5HSRUWLQJ5HTXLUHPHQWV 3ODQQHG:HOOERUH6FKHPDWLF 'ULOOLQJ&RPSOHWLRQ6XPPDU\ 0DQGDWRU\5HJXODWRU\&RPSOLDQFH1RWLILFDWLRQV 58DQG3UHSDUDWRU\:RUN 18´&RQGXFWRU 'ULOO´+ROH6HFWLRQ 5XQ´6XUIDFH&DVLQJ &HPHQW´6XUIDFH&DVLQJ %2318DQG7HVW 'ULOO´+ROH6HFWLRQ 5XQ´3URGXFWLRQ/LQHU &HPHQW´3URGXFWLRQ/LQHU ´/LQHU7LHEDFN3ROLVK5XQDQG&OHDQRXW5XQ ´7LHEDFN5XQ 5'02 %236FKHPDWLF :HOOKHDG6FKHPDWLF 'D\V9V'HSWK *HR3URJ $QWLFLSDWHG'ULOOLQJ+D]DUGV +LOFRUS5LJ/D\RXW ),7/273URFHGXUH &KRNH0DQLIROG6FKHPDWLF &DVLQJ'HVLJQ,QIRUPDWLRQ ´+ROH6HFWLRQ0$63 6SLGHU3ORW*RYHUQPHQWDO6HFWLRQV ¶5DGLXVIRU6669 6XUIDFH3ODW$V%XLOW1$' 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 :HOO6XPPDU\ :HOO3D[WRQ 3DG 2OG:HOO'HVLJQDWLRQ3D[WRQ3DGJUDVVURRWVZHOO 3ODQQHG&RPSOHWLRQ7\SH´&HPHQWHG3URGXFWLRQ/LQHU 7DUJHW5HVHUYRLUV%HOXJD7\RQHN*DV6DQGV 3ODQQHG:HOO7'0'79'¶0'¶79' 3%7'0'79'¶0'¶79' 6XUIDFH/RFDWLRQ*RYHUQPHQWDO¶)1/¶)(/6HF765:60$. 6XUIDFH/RFDWLRQ1$'; 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DWWKLVSRLQWWKHSUHVVXUHZLOOFRQWLQXHWRULVHEXWDWDVORZHUUDWH7KHV\VWHPLVVKXWLQDQGSUHVVXUH PRQLWRUHGDVZLWKDQ),7 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 &KRNH0DQLIROG6FKHPDWLF 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 &DVLQJ'HVLJQ,QIRUPDWLRQ 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 ´+ROH6HFWLRQ0$63 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 6SLGHU3ORW*RYHUQPHQWDO6HFWLRQV 3ULYDWH 6)' $'/ 6)' 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 ¶5DGLXVIRU6669 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 6XUIDFH3ODW$V%XLOW1$' 3DJH9HUVLRQ'HFHPEHU PAXTON 6 Drilling Procedure Rev 0 !"# -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750True Vertical Depth (1500 usft/in)-750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 Vertical Section at 232.50° (1500 usft/in) Paxton 6 wp02 Tgt2 16" Casing 7 5/8" Casing 4 1/2" Casing 5 0 0 1 0 0 0 15002000250030003 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 8 0 0 0 8 5 0 0 9 0 0 0 9 2 6 6 Paxton #6 wp06 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 450' MD, 449.63'TVD End Dir : 1595.55' MD, 1473.95' TVD Start Dir 3º/100' : 3118.93' MD, 2617.04'TVD End Dir : 4066.27' MD, 3447.08' TVD Total Depth : 9266.27' MD, 8469.9' TVD Base Glacial Drift BEL_20 BEL_50 BEL_110 Top Tyonek Unconformity T-6 T65 T-140 T-146 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: Paxton #6 Ground Level: 148.50 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2230578.28 206366.98 60° 5' 45.523 N 151° 36' 31.681 W SURVEY PROGRAM Date: 2022-05-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 2163.00 Paxton #6 wp06 (Paxton #6) 3_MWD+IFR1+MS+Sag 2163.00 9266.27 Paxton #6 wp06 (Paxton #6) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 195.50 29.00 195.50 Base Glacial Drift 1622.50 1456.00 1793.51 BEL_20 2065.50 1899.00 2383.90 BEL_50 3431.50 3265.00 4050.13 BEL_110 3797.50 3631.00 4429.05 Top Tyonek Unconformity 4152.50 3986.00 4796.58 T-6 6632.50 6466.00 7364.06 T65 7628.50 7462.00 8395.20 T-140 7846.50 7680.00 8620.89 T-146 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Paxton #6, True North Vertical (TVD) Reference:As-Built @ 166.50usft (147) Measured Depth Reference:As-Built @ 166.50usft (147) Calculation Method: Minimum Curvature Project:Ninilchik Unit Site:Paxton Well:Plan: Paxton #6 Wellbore:Paxton #6 Design:Paxton #6 wp06 CASING DETAILS TVD TVDSS MD Size Name 97.00 -69.50 97.00 16 16" Casing 1900.00 1733.50 2163.34 7-5/8 7 5/8" Casing 8469.89 8303.39 9266.27 4-1/2 4 1/2" Casing SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 3 450.00 6.00 190.00 449.63 -10.30 -1.82 3.00 190.00 7.71 Start Dir 4º/100' : 450' MD, 449.63'TVD 4 900.00 23.72 205.23 882.96 -116.23 -44.84 4.00 20.00 106.33 5 1595.55 41.38 247.29 1473.95 -335.88 -322.02 4.00 71.59 459.94 End Dir : 1595.55' MD, 1473.95' TVD 6 3118.93 41.38 247.29 2617.04 -724.65 -1250.95 0.00 0.00 1433.60 Start Dir 3º/100' : 3118.93' MD, 2617.04'TVD 7 4066.27 15.00 222.00 3447.08 -941.09 -1629.62 3.00 -166.57 1865.78 End Dir : 4066.27' MD, 3447.08' TVD 8 8566.27 15.00 222.00 7793.75 -1806.62 -2408.94 0.00 0.00 3010.95 Paxton 6 wp02 Tgt2 9 9266.27 15.00 222.00 8469.90 -1941.26 -2530.17 0.00 0.00 3189.09 Total Depth : 9266.27' MD, 8469.9' TVD -2100-1950-1800-1650-1500-1350-1200-1050-900-750-600-450-300-1500South(-)/North(+) (300 usft/in)-2700 -2550 -2400 -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 -750 -600 -450 -300 -150 0West(-)/East(+) (300 usft/in)Paxton 6 wp02 Tgt216" Casing7 5/8" Casing4 1/2" Casing25050075010001 2 5 0 1 5 0 0 1 7 5 0 2 0 0 0 2 2 5 0 2 5 0 0 2 7 5 0 3 0 0 0 3250350037504000425045004750500052505500575060006250650067507000725075007750800082508470Paxton #6 wp06Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4º/100' : 450' MD, 449.63'TVDEnd Dir : 1595.55' MD, 1473.95' TVDStart Dir 3º/100' : 3118.93' MD, 2617.04'TVDEnd Dir : 4066.27' MD, 3447.08' TVDTotal Depth : 9266.27' MD, 8469.9' TVDCASING DETAILSTVDTVDSS MDSize Name97.00 -69.50 97.00 16 16" Casing1900.00 1733.50 2163.34 7-5/8 7 5/8" Casing8469.89 8303.39 9266.27 4-1/2 4 1/2" CasingProject: Ninilchik UnitSite: PaxtonWell: Plan: Paxton #6Wellbore: Paxton #6Plan: Paxton #6 wp06WELL DETAILS: Plan: Paxton #6Ground Level: 148.50+N/-S +E/-WNorthingEastingLatitudeLongitude0.00 0.002230578.28 206366.98 60° 5' 45.523 N 151° 36' 31.681 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Paxton #6, True NorthVertical (TVD) Reference:As-Built @ 166.50usft (147)Measured Depth Reference:As-Built @ 166.50usft (147)Calculation Method:Minimum Curvature $ % & ' ()* 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'(** ,567!"!6 ! 8 9 1 23)& 1 :&0 1 1 $ &0 ; $#< $) =& 8 :: & 1 18691901 2 1 9& 0.001.002.003.004.00Separation Factor550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured Depth (1100 usft/in)Paxton #10No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: Plan: Paxton #6 NAD 1927 (NADCON CONUS) Alaska Zone 04Ground Level: 148.50+N/-S+E/-W NorthingEastingLatitude Longitude0.000.002230578.28 206366.98 60° 5' 45.523 N 151° 36' 31.681 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Paxton #6, True NorthVertical (TVD) Reference: As-Built @ 166.50usft (147)Measured Depth Reference:As-Built @ 166.50usft (147)Calculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name97.00 -69.50 97.00 16 16" Casing1900.00 1733.50 2163.34 7-5/8 7 5/8" Casing8469.89 8303.39 9266.27 4-1/2 4 1/2" CasingSURVEY PROGRAMDate: 2022-05-04T00:00:00 Validated: Yes Version: Depth From Depth ToSurvey/PlanTool18.00 2163.00 Paxton #6 wp06 (Paxton #6) 3_MWD+IFR1+MS+Sag2163.00 9266.27 Paxton #6 wp06 (Paxton #6) 3_MWD+IFR1+MS+Sag0.0030.0060.0090.00120.00150.00Centre to Centre Separation (60.00 usft/in)550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured Depth (1100 usft/in)Paxton #1Paxton #2 SurveysPaxton #3 SurveysPaxton #4Paxton #5Paxton #7Paxton #8Paxton #9GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.00 To 9266.27Project: Ninilchik UnitSite: PaxtonWell: Plan: Paxton #6Wellbore: Paxton #6Plan: Paxton #6 wp06Ladder/S.F. 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