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Home My WebLink About222-124Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240419 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 4/5/2024 AK E-Line Perf BRU 242-04 50283201640000 212041 3/20/2024 AK E-Line JB/PProf NCIU A-17 50883201880000 223031 3/27/2024 AK E-Line GPT/Perf PBU 05-02A 50029201440100 201241 4/6/2024 Halliburton PPROF PBU 09-35A 50029213140100 193031 4/9/2024 Halliburton RBT PBU 13-24A 50029207390100 204243 4/5/2024 Halliburton RBT PBU B-14A 50029203490100 209059 4/2/2024 Halliburton RBT PBU D-31B 50029226720200 212168 4/7/2024 Halliburton PERF SRU 222-33 50133207150000 223100 3/27/2024 AK E-Line CIBP/Perf SRU 224-10 50133101380100 222124 3/29/2024 AK E-Line CIBP/Perf SRU 241-33B 50133206960000 221053 4/2/2024 AK E-Line CIBP Please include current contact information if different from above T38718 T38719 T38720 T38721 T38722 T38723 T38724 T38725 T38726 T38727 T38728 SRU 224-10 50133101380100 222124 3/29/2024 AK E-Line CIBP/Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.19 14:54:13 -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: 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 8,350 feet See Schematic feet true vertical 7,500 feet N/A feet Effective Depth measured 6,676 feet 3,010 feet true vertical 6,187 feet 2,971 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 3,019' MD 2,890' TVD Packers and SSSV (type, measured and true vertical depth)Baker HRD-E ZXP LTP; N/A 3,010' MD 2,971' TVD 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: Jake Flora, Operations Engineer 324-094 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 jake.flora@hilcorp.com 907-777-8442 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 30' 65 Size 30' 1,349' 0 651243 0 10760 1477 measured TVD 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-124 50-133-10138-01-00 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: ADL0028405 / ADL0028406 Swanson River / Tyonek Gas Pool Swanson River Unit (SRU) 224-10 Plugs Junk measured Length 30' Production Liner 5,338' Casing Structural 7,498'8,348' 1,349'Conductor Surface Intermediate 22" 13-3/8" 7-5/8" 1,349' 3,222' 10,540psi 2,730psi 6,890psi 10,160psi 3,222'3,178' Burst Collapse 1,130psi 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 11:24 am, Apr 09, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.04.09 10:48:57 -08'00' DSR-4/12/24 RBDMS JSB 041024 Well Name: SRF SRU 224-10 API #:50-133-10138-01-00 Field:Swanson River Start Date:3/28/2024 Permit #:222-124 Sundry #:324-094 End Date: 3/28/2024 3/29/2024 3/30/2024 3/31/2024 4/1/2024 4/2/2024 Activity Report PJSM, Crew travel to location, Pick up injector head and make up reverse nozzle, Run in hole with coil to tag @ 6756' Coil measurement, Calculated: 94 bbls, Actual: 105 bbls actual, Pull out of hole & trap 2000 psi on wellhead, RIg down BOPE & mob to 241-33B PJSM, Crew travel to location, Spot in & rig up, PIck up Run #1 & stab onto well, Pressure test 250/3000-good, Run in hole & perform correlation pass, (Winds Increased) Pull out of hole & secure well, Rig down AK Eline. PJSM, Crew travel to location, Spot in & rig up, Nipple up BOPE, Function test-good, Perform BOPE & Accumilator test 250 low/ 3000 high (no retests), Secure well PJSM, Crew travel to location, Pick up injector head and lube, Make up coil connector & make up BHA, Fill reel, Test stripper-250/3000- good, Run in hole to while pumping to load hole, Clean out from 5110' to 6781', Hard stall at 6871' (unable to pass), Circulate well clean, Pull out of hole circulating, Rig down coil BHA & Injector head, Spot in & rig up AK Eline, Pick up CCL/GR & 2.75" plug, Stab & pressure test 250/3000-good, Run in hole & correlate, Set plug @ 6740', Pull out of hole & secure well, Rig down AK Eline PJSM, Crew travel to location, PIck up Run #1 & stab onto well, Pressure test 250/3000-good, Run in hole & perform correlation pass, Adjust +/-, Shoot run # 1 TY57-8 (6691-6706), Pull out of hole & lay down run #1, Flow well with production, Run #2 CCL/GPT, Fluid level @ 6550', Pull out of hole make up run #3 2.5" plug Run in hole & set @ 6676', Pull out of hole, Pick up run #4 2-1/2" x 15'' & run in the hole, Perf TY56-9 sands (6548-6563), Pull out of hole & lay down gun, Run # 5 CCL/GPT run in, Fluid level @ 6630', Continue to check fluid level while flowing (no change), Pull out of hole & secure well for the night. Daily Operations: PJSM, Rig down & mob to 241-33b Page 1 of 1 Updated by DMA 04-08-24 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status TY 56-9 6,548’6,563’6,089’6,101’15’4/1/24 Open TY 57-8 6,691’6,706’6,199’6,210’15’4/1/24 Isolated TY 61-0 6,745’6,764’6,239’6,254’19’12/28/23 Isolated TY 61-8 6,998’7,021’6,427’6,444’23’12/27/23 Isolated TY_62-3 7,112’7,140’6,515’6,535’28’11/4/23 Isolated TY 62-3 7,112’7,142’6,515’6,538’30’4/3/23 Isolated TY 62-5 7,155’7,175’6,548’6,564’20’1/9/23 Isolated TY 62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY 67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY 68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 6,676’CIBP 4/1/24 4 6,740’CIBP 3/29/24 5 7,090’-2.993”CIBP w/14’ cmt - TOC 7,076’ 12/27/23 6 7,145’-2.993”CIBP 3/31/23 7 7,150’-2.993”CIBP 3/30/23 8 7,177’-2.993”WRP set 2/15/23 9 7,874’-2.993”CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 3,998’ & 4,994’ Short joints 5.8ft @ 5511’ & 4508’ 3 7 6 5 Sand Fill 4 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:Joshua Stephenson - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Jacob Flora Subject:SRU 224-10 BOPE test Date:Friday, March 29, 2024 6:41:11 PM Attachments:SR 224-10 BOPE test 3-28-24.xlsx Please see attached if any issues please let me know. Thanks! Joshua Stephenson 505-386-8853 Joshua.stephenson@hilcorp.com Well Site Supervisor 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. 6ZDQVRQ5LYHU8QLW 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:8 DATE: 3/28/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2221240 Sundry #324-094 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:N/A Valves:250/3000 MASP:2456 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" stripper P Trip Tank NA NA Annular Preventer 0NAPit Level Indicators NA NA #1 Rams 1 1.75" Pipe/Slip P Flow Indicator NA NA #2 Rams 1 Blindshear P Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2-1/16"P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)3100 P Kill Line Valves 2 2-1/16"P Pressure After Closure (psi)2500 P Check Valve 0NA200 psi Attained (sec)3 P BOP Misc 0NAFull Pressure Attained (sec)9 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 1400/4 P No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 17 P Coiled Tubing Only:#2 Rams 14 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/25/2024 @ 1458 Waived By Test Start Date/Time:3/28/2024 12:00 (date) (time)Witness Test Finish Date/Time:3/28/2024 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Terrenace Rias Hilcorp Alaska LLC Joshua Stephenson SRU 224-10 Test Pressure (psi): trais@foxak.com Joshua.stephenson@hilcorp.com Form 10-424 (Revised 08/2022)2024-0328_BOP_Fox8_SRU_224-10 9 9 9 9 9 9 99 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:McLellan, Bryan J (OGC) To:Jacob Flora Cc:Donna Ambruz Subject:RE: SRU 224-10 AOGCC 10-403 324-094 PTD 222-124 - Request for coil cleanout & plug back Date:Thursday, March 14, 2024 2:34:00 PM Attachments:image005.png image006.png image007.png Jake, Hilcorp has approval to add the CT procedure described in your email below to the existing sundry 324-094. CT BOP test pressure = 3000 psi. Provide 24 hrs notice to witness. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Wednesday, March 13, 2024 10:01 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: SRU 224-10 AOGCC 10-403 324-094 PTD 222-124 - Request for coil cleanout & plug back Hello Bryan, This well also has filled up w sand and will require a coil tubing fill cleanout. Hilcorp requests permission to perform the following: 1. Provide 24hrs notice of BOP test 2. MIRU coil tubing unit 3. BOP test to 3000 psi 4. Perform fill cleanout 5. Set CIBP at 6740’ w no cement cap 6. Jet well dry with nitrogen 7. Proceed with perforation program per approved Sundry 324-094 Please let me know if you need anything additional in your review. Thanks, Jake Approved Perf Table Please do not reply to this message as this account is not monitored. 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 namedabove. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of thisemail is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listedabove, 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 andthe recipient should carry out such virus and other checks as it considers appropriate. 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. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,350 N/A Casing Collapse Structural Conductor 1,130psi Surface 4,790psi Intermediate Production 10,540psi 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 Other: N2 jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028405 / ADL0028406 222-124 50-133-10138-01-00 Hilcorp Alaska, LLC Proposed Pools: 30' 30' L-80 TVD Burst 3,019' 10,160psi 3,178' Size 1,349' 3,222' MD See Schematic 2,730psi 6,890psi 1,349'1,349' 3,222' February 27, 2024 3-1/2" 30' 22" 8,348' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit 224-10CO 716A Same 7,498'3-1/2" ~2456 psi 5,338' See schematic Length HRD-E ZXP LTP & N/A 3,010 (MD) 2,971 (TVD) & N/A 7,500 7,076 6,487 Swanson River Tyonek Gas 13-3/8" 7-5/8" See Schematic Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test No Wellbore schematic 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 11:17 am, Feb 20, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.16 09:25:10 - 09'00' Noel Nocas (4361) BJM 2/27/24 DSR-2/21/24 Perforate f 10-404 SFD 2/20/2024($8 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.27 16:25:51 -09'00'02/27/24 RBDMS JSB 022824 Well: SRU 224-10 Well Name: Swanson River 224-10 API Number: 50-133-10138-01-00 Current Status: Gas Producer Permit to Drill Number: 222-124 First Call Engineer: Jake Flora (720) 988-5375 (c) Second Call Engineer: Chad Helgeson (907) 229-4824 (c) Maximum Expected BHP 3,108 psi @ 6,427’ TVD Based on 9.3ppg gradient Maximum Potential Surface Pressure: 2,456 psi 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Current Status: Producing Gas Well 991mcfd, 38bwpd @ 158 psi (1/31/24) Brief Well Summary Swanson River 224-10 is a sidetracked gas producer that was drilled and completed to 8,350ft. The wellbore is completed as a 3-1/2” mono-bore with tieback to surface. April 2023 the Tyonek 62-3 was added bringing the rate above 4MM at 2100 psi. In December 2023 sands were added in the Tyonek 61 with and IP of over 3MM at 1100 psi FTP. The well has continued to decline and the objective of this sundry is to increase productivity by perforating additional Tyonek sands. Notes Regarding Wellbore Condition Current Gross Perf Interval: 6745 - 7021’ MD (6239 - 6444’ TVD) 12/27/23 Set CIBP w 14’ cement top 7090’ MD 12/28/23 Perforated Tyonek 61-8, 61-0 6745 – 6764’, 6998 - 7021’ MD Procedure 1. RU E-line, PT lubricator to 2700 psi 2. Perforate Tyonek sands from the bottom up within the below intervals: ZONE MD TOP MD BOTTOM TVD TOP TVD BOTTOM Top Tyonek Gas Pool 5936 5627 TY 54-4 6145 6213 5787 5838 TY 55-5 6300 6335 5903 5929 TY 56-9 6548 6563 6089 6101 TY 57-8 6691 6706 6199 6210 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. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Nitrogen SOP Updated by DMA 01-12-24 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)FT Date Status TY_61-0 6,745’6,764’6,239’6,254’19 12/28/23 Open TY_61-8 6,998’7,021’6,427’6,444’23 12/27/23 Open TY_62-3 7,112’7,140’6,515’6,535’28’11/4/23 Isolated TY_62-3 7,112’7,142’6,515’6,538’30’4/3/23 Isolated TY_62-5 7,155’7,175’6,548’6,564’20’1/9/23 Isolated TY_62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY_67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY_68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,090’-2.993”CIBP w/14’ cmt - TOC 7,076’ 12/27/23 4 7,145’-2.993”CIBP 3/31/23 5 7,150’-2.993”CIBP 3/30/23 6 7,177’-2.993”WRP set 2/15/23 7 7,874’-2.993”CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 7 6 5 Sand Fill 4 Updated by DMA 02-02-24 PROPOSED Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status TY 54-4 6,145 6,213 5,787 5,838 proposed TY 55-5 6,300 6,335 5,903 5,929 proposed TY 56-9 6,548 6,563 6,089 6,101 proposed TY 57-8 6,691 6,706 6,199 6,210 proposed TY_61-0 6,745’ 6,764’ 6,239’ 6,254’ 19 12/28/23 Open TY_61-8 6,998’ 7,021’ 6,427’ 6,444’ 23 12/27/23 Open TY_62-3 7,112’ 7,140’ 6,515’ 6,535’ 28’ 11/4/23 Isolated TY_62-3 7,112’ 7,142’ 6,515’ 6,538’ 30’ 4/3/23 Isolated TY_62-5 7,155’ 7,175’ 6,548’ 6,564’ 20’ 1/9/23 Isolated TY_62-5 7,179’ 7,199’ 6,567’ 6,582’ 20’ 12/29/22 Isolated TY_67-0 7,777’ 7,789’ 7,020’ 7,030’ 12’ 12/27/22 Isolated TY_68-0 7,915’ 7,930’ 7,128’ 7,140’ 15’ 12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22” Conductor Weld Surf 30’ 13-3/8" Surf Csg 54.5 J-55 8RD 12.415” Surf 1,349’(TOW) 7-5/8” Intermediate Csg 29.7 L-80 BTC 6.276” Surf 3,222’ 3-1/2" Prod Csg 9.3 L-80 Multiple 2.992” 3,010’ 8,348’ 3-1/2” Tubing 9.3 L-80 IBT M 2.992” Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No. Depth ID OD Item 1 1,388’ N/A 12.25” Whipstock (TOW – 1,349’) 2 3,010’ 5.75” Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,090’ - 2.993” CIBP w/14’ cmt - TOC 7,076’ 12/27/23 4 7,145’ - 2.993” CIBP 3/31/23 5 7,150’ - 2.993” CIBP 3/30/23 6 7,177’ - 2.993” WRP set 2/15/23 7 7,874’ - 2.993” CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8” TOC @ Surface (Original 12-15) 7-5/8" Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 7 6 5 Sand Fill 4 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 8,350 feet See Schematic feet true vertical 7,500 feet N/A feet Effective Depth measured 7,076 feet 3,010 feet true vertical 6,487 feet 2,971 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 3,019' MD 2,890' TVD Packers and SSSV (type, measured and true vertical depth)Baker HRD-E ZXP LTP; N/A 3,010' MD 2,971' TVD 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: Jake Flora, Operations Engineer 323-660 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 157 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 jake.flora@hilcorp.com 907-777-8442 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 30' 80 Size 30' 1,349' 0 901382 0 1380 1083 measured TVD 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-124 50-133-10138-01-00 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: ADL0028405 / ADL0028406 Swanson River / Tyonek Gas Pool Swanson River Unit (SRU) 224-10 Plugs Junk measured Length 30' Production Liner 5,338' Casing Structural 7,498'8,348' 1,349'Conductor Surface Intermediate 22" 13-3/8" 7-5/8" 1,349' 3,222' 10,540psi 2,730psi 6,890psi 10,160psi 3,222'3,178' Burst Collapse 1,130psi 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 7:56 am, Jan 17, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.01.16 11:51:16 - 09'00' Noel Nocas (4361) DSR-1/26/24BJM 1/17/24 RBDMS JSB 012324 Page 1/1 Well Name: SRF SRU 224-10 Report Printed: 1/15/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:12/27/2023 End Date: Report Number 1 Report Start Date 12/27/2023 Report End Date 12/28/2023 Operation Travel to Swanson River. PJSM & Permit. Travel to location. MIRU Yellow Jacket E-Line. PT 250 / 3000 PSI. Test good. Production had injected gas down tubing till well broke over. Currently 400 PSI on tbg. RIH w/ GPT. Found FL at 7120'. Tag fill at 7126'. POOH. Sent log to town. OOH. L/D GPT. P/U 3-1/2" (2.75" OD) CIBP. CCL to top of CIBP = 15.5' / CCL to be at 7074.5' to place CIBP at 7090' set depth. RIH w/ 3-1/2" CIBP. Made tie in pass. Set CIBP at 7090'. P/U 6' and hung up. Worked wire a few times & came free. POOH. OOH. L/D Setting Tool. P/U 2.5" x 25' dump bailer loaded w/ 5 gallons cement to = 13.5' in tubing. RIH w/ Dump Bailer. Tag CIBP at 7090'. P/U 10'. Fire dump bailer. POOH. TOC is 7076.5' OOH. L/D Dump Bailer. P/U Gun ONE 23' x 2-3/8" (5SPF/120) to soot TY 61-8 zone 6998' to 7021'. CCL to TS = 11' / CCL to be at 6987' to place TS at 6998'. RIH w/ Gun ONE. Made tie in pass. Sent log to town. Town approved. Position Gun ONE. Fire Gun ONE. POOH. Well built from 1777 to 1844 PSI in 22 minutes. OOH. L/D Gun ONE. Dry end cap. All shots fired. P/U GPT. Production bringing well online to test. Well at 1700 PSI / 672 MCF. RIH w/ GPT.At 5800' got erratic readings off tool. Troubleshoot & reboot. Finished log. Sent to town for evaluation. POOH. OOH. L/D GPT. Secure well & equipment. SDFN. Return to YJ shop. Report Number 2 Report Start Date 12/28/2023 Report End Date 12/29/2023 Operation Travel to Swanson River. PJSM & Permit. Travel to location. MIRU Yellow Jacket E-Line. YJ thawing out grease pump. (-15 ambient). Production pressuring up well to 1700 PSI w/ GL Injection. RIH w/ Gun TWO. 19' x 2-3/8" to shoot TY 61-0 zone at 6745' to 6764'. CCL to TS = 11' / CCL to be at 6734' to place TS at 6745'. Made tie in pass. Sent log to town. Town adjusted +2'. Position Gun TWO. Fire Gun TWO. POOH. Well built from 1700 to 1950 PSI in 15 minutes. OOH. L/D Gun TWO. All shots fired and end cap dry. Production brought on well to flow test. Town in happy w/ results so far and wants to continue flow testing. RDMO YJ. Return to YJ shop. API: 50-133-10138-01-00 Field: Swanson River Sundry #: 323-660 State: Alaska Rig/Service:Permit to Drill (PTD) #:222-124 Updated by DMA 01-12-24 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)FT Date Status TY_61-0 6,745’6,764’6,239’6,254’19 12/28/23 Open TY_61-8 6,998’7,021’6,427’6,444’23 12/27/23 Open TY_62-3 7,112’7,140’6,515’6,535’28’11/4/23 Isolated TY_62-3 7,112’7,142’6,515’6,538’30’4/3/23 Isolated TY_62-5 7,155’7,175’6,548’6,564’20’1/9/23 Isolated TY_62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY_67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY_68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,090’-2.993”CIBP w/14’ cmt - TOC 7,076’ 12/27/23 4 7,145’-2.993”CIBP 3/31/23 5 7,150’-2.993”CIBP 3/30/23 6 7,177’-2.993”WRP set 2/15/23 7 7,874’-2.993”CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 7 6 5 Sand Fill 4 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 T38287 SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,350 N/A Casing Collapse Structural Conductor 1,130psi Surface 4,790psi Intermediate Production 10,540psi 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 HRD-E ZXP LTP & N/A 3,010 (MD) 2,971 (TVD) & N/A 7,500 7,145 6,540 Swanson River Tyonek Gas 13-3/8" 7-5/8" See Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit 224-10CO 716A Same 7,498'3-1/2" ~2456 psi 5,338' See schematic Length December 21, 2023 3-1/2" 30'22" 8,348' Perforation Depth MD (ft): See Schematic 2,730psi 6,890psi 1,349'1,349' 3,222'3,178' Size 1,349' 3,222' MD 50-133-10138-01-00 Hilcorp Alaska, LLC Proposed Pools: 30'30' L-80 TVD Burst 3,019' 10,160psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028405 / ADL0028406 222-124 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Other: N2 chelgeson@hilcorp.com 907-777-8405 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. 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 9:16 am, Dec 12, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.12.11 18:03:26 - 09'00' Noel Nocas (4361) 323-660 SFD 12/13/2023BJM 12/14/23 Perforate 10-407 DSR-12/14/23*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.12.15 09:48:08 -09'00' 12/15/23 RBDMS JSB 121923 Well Work Prognosis Well Name: Swanson River 224-10 API Number: 50-133-10138-01-00 Current Status: Gas Producer Permit to Drill Number: 222-124 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M) Second Call Engineer: Jake Flora (720) 988-5375 (M) Maximum Expected BHP 3,108 psi @ 6,427’ TVD Based on 9.3ppg gradient Maximum Potential Surface Pressure: 2,456 psi @ 6,515’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Swanson River 224-10 is a sidetracked gas producer that was drilled and completed to 8,350ft. The wellbore is completed as a 3-1/2” mono-bore with tieback to surface. The Tyonek 62-5 Sand is depleted and plan to continue perforating up the well for more rate. The purpose of this sundry is to add perforations to the well for more rate and plug back or patch any sands that make water. Notes Regarding Wellbore Condition x 3-1/2” mono-bore completion x Liner/seal assembly @ 3,010’ x A cast iron bridge plug is set at 7,145’ x Shut-in BHP Survey completed on 9/26/23 = 828 psi Procedure: 1. Review all approved COAs 2. RU Eline, PT well to 3000 psi H/250 L 3. RIH and set WRP/CIBP at 7,090’ 4. Pressure up well to ~1800 psi with gas lift 5. Perforate the following Tyonek sands, bottom up, testing each zone individually Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT TY_54-4 ±6,145’ ±6,211’ ±5,787’ ±5,837’ ±66 TY_54-5 ±6,300’ ±6,333’ ±5,903’ ±5,927’ ±33 TY_56-9 ±6,548’ ±6,563’ ±6,089’ ±6,100’ ±14 TY_57-8 ±6,691’ ±6706’ ±6,199’ ±6,210’ ±15 TY_61-0 ±6,745’ ±6,764’ ±6,239’ ±6,254’ ±19 TY_61-0 ±6,772’ ±6778’ ±6,260 ±6,264’ ±6 TY_61-8 ±6,998’ ±7,021’ ±6,427’ ±6,444’ ±23 a. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. b. Record initial and 5/10/15 minute tubing pressures after firing c. Perfs will be shot in the Tyonek Gas Pool governed by CO 716A 6. RD E-Line unit and turn well over to production for testing. E-line Procedure (Contingency) If any zone produces sand and/or water or needs isolated: 1. MIRU Eline and N2 pump truck 2. Pressure test equipment to 3,500 psi High/250 psi Low 3. Eline run PT to find fluid level 4. RU N2 or use gas lift and push fluid below perfs (verify fluid depth with PT tool) 5. PU 4-1/2” CIBP/WRBP or patch Concur. SFD Well Work Prognosis Note: All proposed perforations are in the same Pool / PA. A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. If necessary to cleanout or unload well with coiled tubing, 6. MIRU Fox Coiled Tubing Unit, PT BOPE to 3,500 psi High/250 psi Low 7. Provide AOGCC 24hrs notice of BOP test 8. PU wash nozzle, RIH and cleanout well to below perfs or proposed plug depth 9. PU CT jet nozzle and RIH, unload fluid from the wellbore with nitrogen a. Reverse circ out any fluid if perfs are isolated/plugged back 10. RDMO coil tubing Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil Tubing Fox BOP Diagram 4. Coil Tubing SLB Bop Diagram 5. Standard Nitrogen Operations Updated by DMA 11-09-23 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)FT Date Status TY_62-3 7,112’7,140’6,515’6,535’28’11/4/23 Open TY_62-3 7,112’7,142’6,515’6,538’30’4/3/23 Open TY_62-5 7,155’7,175’6,548’6,564’20’1/9/23 Isolated TY_62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY_67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY_68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’ 5.75” Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,145’-2.993 CIBP 3/31/23 4 7,150’2.993 CIBP 3/30/23 5 7,177’-2.993”WRP set 2/15/23 6 7,874’-2.993 CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer . CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 6 5 4 Sand Fill Updated by CAH 12-6-23 PROPOSED Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)FT Date Status TY_54-4 ±6,145’±6,211’±5,787’±5,837’±66 TBD Proposed TY_54-5 ±6,300’±6,333’±5,903’±5,927’±33 TBD Proposed TY_56-9 ±6,548’±6,563’±6,089’±6,100’±14 TBD Proposed TY_57-8 ±6,691’±6706’±6,199’±6,210’±15 TBD Proposed TY_61-0 ±6,745’±6,764’±6,239’±6,254’±19 TBD Proposed TY_61-0 ±6,772’±6778’±6,260 ±6,264’±6 TBD Proposed TY_61-8 ±6,998’±7,021’±6,427’±6,444’±23 TBD Proposed TY_62-3 7,112’7,140’6,515’6,535’28’11/4/23 Isolated TY_62-3 7,112’7,142’6,515’6,538’30’4/3/23 Isolated TY_62-5 7,155’7,175’6,548’6,564’20’1/9/23 Isolated TY_62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY_67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY_68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 ±7,090’-2.993”WRP/CIBP 4 7,145’-2.993”CIBP 3/31/23 5 7,150’-2.993”CIBP 3/30/23 6 7,177’-2.993”WRP set 2/15/23 7 7,874’-2.993”CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 7 6 5 Sand Fill 4 ~ Coiled Tubing BOP Dressed for 2-3/8” CT Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual 2 1/16 10M Manual 2 1/16 10M Manual 2 1/16 10M Manual 2 1/16 10M Valve, master, WKM, 3 1/8 5M FE, HWO Valve, swab, WKM, 3 1/8 5M FE, HWO SWAB VALVE MASTER VALVE STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 8,350 feet See Schematic feet true vertical 7,500 feet N/A feet Effective Depth measured 7,145 feet 3,010 feet true vertical 6,540 feet 2,971 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 3,019' MD 2,890' TVD Packers and SSSV (type, measured and true vertical depth)Baker HRD-E ZXP LTP; N/A 3,010' MD 2,971' TVD 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: Chad Helgeson, Operations Engineer 323-583 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1977 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 chelgeson@hilcorp.com 907-777-8405 N/A 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 30' 90 Size 30' 1,349' 0 90825 0 2910 90 measured TVD 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-124 50-133-10138-01-00 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: ADL0028405 / ADL0028406 Swanson River / Tyonek Gas Pool Swanson River Unit (SRU) 224-10 Plugs Junk measured Length 30' Production Liner 5,338' Casing Structural 7,498'8,348' 1,349'Conductor Surface Intermediate 22" 13-3/8" 7-5/8" 1,349' 3,222' 10,540psi 2,730psi 6,890psi 10,160psi 3,222' 3,178' Burst Collapse 1,130psi 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 Samantha Carlisle at 10:19 am, Nov 14, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.13 11:44:04 - 09'00' Noel Nocas (4361) Wellname: SRF SRU 224-10 Rig: E-Line API Number: 50-133-10138-00-00 Well Permit Number: 222-124 Start Date: 11/04/23 End Date: 11/04/23 Date Summary 11/04/23 PJSM and PTW Well flowing 1.1MMCFD @ 140psi R/U YJ E-line. Shut in well. SITP rose to 244psi Stab on lubricator and pressure test to 250psi/2500psi - TEST GOOD,Open well and RIH w/ Gamma, weight bar, and 14' x 2.375"OD Geodynamics perf gun, 5spf (CCL to top shot 10.0') Tag at 7,140.5, pull correlation log and send to town. On depth. Pull on depth and perforate TY_62-3 sands from 7,126-7,140' SITP 244psi, no change in 15min. POOH. All shots fired, gun had a little water on the inside. No sand seen,M/U Gamma, weight bar, and 14' x 2.375"OD Geodynamics perf gun, 5spf (CCL to top shot 10.0') Tag at 7,140.5, pull correlation log. On depth. Pull on depth and perforate TY_62-3 sands from 7,112-7,126' SITP 252psi, no change in 15min. POOH. All shots fired, gun had a little water on the inside. No sand seen,Secure well, and turn back over to production. RDMO YJ E-line Hilcorp Alaska, LLC Well Operations Summary Daily Operations Updated by DMA 11-09-23 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281 / TVD = 7,438 TD = 8,350 / TVD = 7,500 RKB to GL = 21.02 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status TY_62-3 7,112 7,140 6,515 6,535 2811/4/23 Open TY_62-3 7,112 7,142 6,515 6,538 304/3/23 Open TY_62-5 7,155 7,175 6,548 6,564 201/9/23 Isolated TY_62-5 7,179 7,199 6,567 6,582 2012/29/22 Isolated TY_67-0 7,777 7,789 7,020 7,030 1212/27/22 Isolated TY_68-0 7,915 7,930 7,128 7,140 1512/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22Conductor Weld Surf 30 13-3/8" Surf Csg 54.5 J-55 8RD 12.415Surf 1,349(TOW) 7-5/8Intermediate Csg 29.7 L-80 BTC 6.276Surf 3,222 3-1/2"Prod Csg 9.3 L-80 Multiple 2.9923,0108,348 3-1/2Tubing 9.3 L-80 IBT M 2.992Surface 3,019 2 22 13-3/8 JEWELRY DETAIL No. Depth ID OD Item 1 1,388N/A 12.25 Whipstock (TOW 1,349) 2 3,010 5.75 Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75 PBR 3 7,145- 2.993 CIBP 3/31/23 4 7,1502.993 CIBP 3/30/23 5 7,177-2.993WRP set 2/15/23 6 7,874- 2.993 CIBP w/ 39 of cement (7,835) OPEN HOLE / CEMENT DETAIL 13-3/8TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2 Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235 MD. 4 7-5/8 1 SRU 12-15 ( Abandoned) TOW 1,349 3-1/2 Notes: RA Tags set @ 4,994 & 3,998 Short joints 5.8ft @ 5511 & 4508 3 6 5 4 Sand Fill 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,350 N/A Casing Collapse Structural Conductor 1,130psi Surface 4,790psi Intermediate Production 10,540psi 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 HRD-E ZXP LTP & N/A 3,010 (MD) 2,971 (TVD) & N/A 7,500 7,145 6,540 Swanson River Tyonek Gas 13-3/8" 7-5/8" 7,112 - 7,142 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit 224-10CO 716A Same 7,498'3-1/2" 177psi 5,338' See schematic Length November 2, 2023 3-1/2" 30' 22" 8,348' Perforation Depth MD (ft): 6,515 - 6,538 2,730psi 6,890psi 1,349'1,349' 3,222' 3,178' Size 1,349' 3,222' MD 50-133-10138-01-00 Hilcorp Alaska, LLC Proposed Pools: 30' 30' L-80 TVD Burst 3,019' 10,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028405 / ADL0028406 222-124 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Other: CT Operations / N2 chelgeson@hilcorp.com 907-777-8405 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. No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:23 am, Oct 26, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.10.25 17:31:06 - 08'00' Noel Nocas (4361) 323-583 X 10-404 BJM 10/27/23 CT BOP test to 3500 psi, if CT contingency is required. SFD 10/26/2023 DSR-11/2/23&': Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.11.03 08:05:11 -08'00'11/03/23 RBDMS JSB 110723 Well Work Prognosis Well Name:Swanson River 224-10 API Number:50-133-10138-01-00 Current Status:Gas Producer Permit to Drill Number:222-124 First Call Engineer:Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M) Second Call Engineer:Jake Flora (720) 988-5375 (M) Maximum Expected BHP 828 psi @ 6,515’ TVD Based on SI static BHP survey 9/26/23 Maximum Potential Surface Pressure: 177 psi @ 6,515’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Swanson River 224-10 is a sidetracked gas producer that was drilled and completed to 8,350ft. The wellbore is completed as a 3-1/2” mono-bore with tieback to surface. The current Tyonek Producing sand has been online since April 2023. The purpose of this sundry is reperforate the existing zone, due to suspected formation sand compaction. Notes Regarding Wellbore Condition x 3-1/2” mono-bore completion x Liner/seal assembly @ 3,010’ x 3-1/2” liner currently filled with 10.2 ppg 6% KCl drilling mud x A cast iron bridge plug is set at 7,145’ x Shut-in BHP Survey completed on 9/26/23 = 828 psi Procedure: 1. Review all approved COAs 2. Ops shut-in well 3. RU Eline, PT well to 2500 psi H/250 L 4. Reperforate the following Tyonek sand Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT TY_62-3 ±7,112’ ±7,145’ ±6,515’ ±6,540’ 33’ a. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. b. Record initial and 5/10/15 minute tubing pressures after firing c. Perfs will be shot in the Tyonek Gas Pool governed by CO 716A 5. RD E-Line unit and turn well over to production for testing. Coil Procedure (Contingency)If Eline is unable to get to bottom for perforations a. MIRU Fox Coiled Tubing Unit, PT BOPE to 3,500 psi High/250 psi Low b. Provide AOGCC 24hrs notice of BOP test c. PU wash nozzle, RIH and cleanout well to 7,177’, using N2 as necessary d. Leave 1000 psi of N2 on well when complete e. Continue with Eline operations Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil Tubing BOP Diagram 4. Standard Nitrogen Operations Updated by DMA 04-05-23 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)FT Date Status TY_62-3 7,112’7,142’6,515’6,538’30’4/3/23 Open TY_62-5 7,155’7,175’6,548’6,564’20’1/9/23 Isolated TY_62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY_67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY_68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,145’-2.993 CIBP 3/31/23 4 7,150’2.993 CIBP 3/30/23 5 7,177’-2.993”WRP set 2/15/23 6 7,874’-2.993 CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 6 5 4 Sand Fill Updated by JLL 10-25-23 PROPOSED Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status TY_62-3 ±7,112’ ±7,145’ ±6,515’ ±6,540’ ±33’ TBD Proposed TY_62-3 7,112’ 7,142’ 6,515’ 6,538’ 30’ 4/3/23 Open TY_62-5 7,155’ 7,175’ 6,548’ 6,564’ 20’ 1/9/23 Isolated TY_62-5 7,179’ 7,199’ 6,567’ 6,582’ 20’ 12/29/22 Isolated TY_67-0 7,777’ 7,789’ 7,020’ 7,030’ 12’ 12/27/22 Isolated TY_68-0 7,915’ 7,930’ 7,128’ 7,140’ 15’ 12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22” Conductor Weld Surf 30’ 13-3/8" Surf Csg 54.5 J-55 8RD 12.415” Surf 1,349’(TOW) 7-5/8” Intermediate Csg 29.7 L-80 BTC 6.276” Surf 3,222’ 3-1/2" Prod Csg 9.3 L-80 Multiple 2.992” 3,010’ 8,348’ 3-1/2” Tubing 9.3 L-80 IBT M 2.992” Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No. Depth ID OD Item 1 1,388’ N/A 12.25” Whipstock (TOW – 1,349’) 23,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,145’ - 2.993 CIBP 3/31/23 4 7,150’ 2.993 CIBP 3/30/23 5 7,177’ - 2.993” WRP set 2/15/23 6 7,874’ - 2.993 CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8” TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 6 5 4 Sand Fill 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. DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : CB L 1 2 - 1 4 - 2 2 , G P T & P e r f L o g s , m u d l o g s , L W D ( G R , N e u , R e s , P W D ) No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 12 / 7 / 2 0 2 2 13 4 8 8 3 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 LW D F i n a l . l a s 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l M D . c g m 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l T V D . c g m 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 - D e f i n i t i v e S u r v e y Re p o r t . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 - F i n a l S u r v e y s . x l s x 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 _ D S R Ac t u a l _ P l a n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 _ D S R Ac t u a l _ V S e c . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 _ D S R . t x t 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 _ D S R _ G I S . t x t 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l M D . e m f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l T V D . e m f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l M D . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l T V D . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l M D . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 7 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D F i n a l T V D . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 12 3 0 8 3 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 . l a s 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D a i l y R e p o r t s . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F i n a l W e l l R e p o r t . p d f 37 3 6 3 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 1 o f 7 Su p p l i e d b y Op Su p p l i e d b y Op SR U 2 2 4 - 1 0 LW D F i n al. l as SR U 2 2 4 - 1 0 . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g M D 2 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g M D 5 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g T V D 2 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g T V D 5 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g M D 2i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g M D 5i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g T V D 2i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g T V D 5i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g M D 2i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g M D 5i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g T V D 2i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g T V D 5i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g MD 2 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g MD 5 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g TV D 2 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g TV D 5 i n . p d f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g M D 2 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g M D 5 i n . t i f 37 3 6 3 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 2 o f 7 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g T V D 2 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 D r i l l i n g D y n a m i c s Lo g T V D 5 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g M D 2i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g M D 5i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g T V D 2i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 F o r m a t i o n L o g T V D 5i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g M D 2i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g M D 5i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g T V D 2i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G a s R a t i o L o g T V D 5i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g MD 2 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g MD 5 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g TV D 2 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 L W D C o m b o L o g TV D 5 i n . t i f 37 3 6 3 ED Di g i t a l D a t a DF 12 / 9 / 2 0 2 2 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 S h o w R e p o r t s . p d f 37 3 6 3 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 70 0 1 8 2 7 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G P T 1. l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 81 5 3 7 4 8 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G U N 1. l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 48 9 4 5 6 4 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 1 - 2 2 G P T RU N 1 . l a s 37 4 6 7 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 3 o f 7 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 1/ 2 4 / 2 0 2 3 82 8 1 7 7 7 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 1 - 2 2 T A G RU N T D @ 8 2 7 4 ' . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 78 9 2 7 5 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 2 - 2 2 S R U 22 4 - 1 0 C I B P C O R R E L A T I O N . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 78 0 3 7 5 3 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 7 - 2 2 S R U 22 4 - 1 0 1 2 ' P E R F C O R R E L A T I O N . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 70 7 8 7 8 4 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 9 - 2 2 G P T RU N F L U I D @ 7 7 6 0 ' . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 73 0 8 7 0 4 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 9 - 2 2 S R U 22 4 - 1 0 2 0 ' T Y _ 6 2 - 5 P E R F # 2 CO R R E L A T I O N . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 73 0 8 7 0 0 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : 1 2 - 2 9 - 2 2 S R U 22 4 - 1 0 2 0 ' T Y _ 6 2 - 5 P E R F C O R R E L A T I O N . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 -2 4 4 7 2 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 GP T . l a s 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T 1 . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T - P E R F FI N A L . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G U N 1 . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 1 - 2 2 G P T R U N 1 . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 1 - 2 2 S R U 2 2 4 - 1 0 G P T FI N A L . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 1 - 2 2 S R U 2 2 4 - 1 0 P L U G - PE R F F I N A L . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 1 - 2 2 T A G R U N T D @ 82 7 4 ' . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 2 - 2 2 G P T R U N F L U I D @ 78 0 0 ' . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 2 - 2 2 S R U 2 2 4 - 1 0 C I B P CO R R E L A T I O N . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 7 - 2 2 S R U 2 2 4 - 1 0 1 2 ' P E R F CO R R E L A T I O N . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 9 - 2 2 G P T R U N F L U I D @ 77 6 0 ' . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 9 - 2 2 S R U 2 2 4 - 1 0 2 0 ' T Y _ 6 2 - 5 P E R F # 2 C O R R E L A T I O N . p d f 37 4 6 7 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 4 o f 7 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 9 - 2 2 S R U 2 2 4 - 1 0 2 0 ' T Y _ 6 2 - 5 P E R F C O R R E L A T I O N . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 9 - 2 2 S R U 2 4 4 - 1 0 G P T FI N A L . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 2 - 2 9 - 2 2 S R U 2 4 4 - 1 0 P E R F FI N A L . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T F I N A L . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T . p d f 37 4 6 7 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 67 4 7 7 8 1 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G P T 1 D N 3 0 . l a s 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 78 1 1 6 7 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G P T 1 U P 3 0 . l a s 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 67 6 0 7 8 1 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G P T 2 D N 3 0 . l a s 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 78 1 0 6 7 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G P T 2 U P 3 0 . l a s 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 72 9 7 6 9 8 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G U N 1 C O R R E L A T I O N . l a s 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 72 9 6 7 0 4 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 G U N 2 C O R R E L A T I O N . l a s 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T 1 D N 3 0 . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T 1 U P 3 0 . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T 2 D N 3 0 . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T 2 U P 3 0 . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G P T - P E R F FI N A L . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G U N 1 CO R R E L A T I O N . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 G U N 2 CO R R E L A T I O N . p d f 37 4 7 2 ED Di g i t a l D a t a DF 1/ 2 6 / 2 0 2 3 82 9 0 2 7 8 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ C B L _ 1 4 - D e c - 2 0 2 2 _ ( 4 1 0 8 ) . l a s 37 4 7 8 ED Di g i t a l D a t a DF 1/ 2 6 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 1 0 _ C B L _ 1 4 - D e c - 20 2 2 _ ( 4 1 0 8 ) . p d f 37 4 7 8 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 5 o f 7 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 2/ 2 2 / 2 0 2 3 68 3 2 7 2 2 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ 0 6 0 - d n . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 71 9 8 6 8 4 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ 0 6 0 - u p . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 68 2 6 7 2 1 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ 0 9 0 - d n . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 71 8 1 6 8 2 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ 0 9 0 - u p . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 68 3 3 7 1 6 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ 1 2 0 - d n . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 72 0 9 6 8 2 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ 1 2 0 - u p . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 68 2 8 7 2 5 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ P r o c e s s e d L o g . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 54 6 5 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ s t o p - 7 1 9 7 . l a s 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 . p d f 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ i m g . t i f f 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ R e p o r t - V 1 . 1 . p d f 37 5 1 1 ED Di g i t a l D a t a DF 2/ 2 2 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 10 _ P P R O F _ 0 3 F E B 2 3 _ V 1 . k e 5 37 5 1 1 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 71 8 4 6 9 8 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 2 - 1 5 - 23 G A U G E R U N . l a s 37 5 7 2 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 71 6 3 6 9 3 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U 2 2 4 - 1 0 2 - 1 5 - 23 R E T . P L U G C O R R E L A T I O N . l a s 37 5 7 2 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 2 - 1 5 - 2 3 G A U G E RU N . p d f 37 5 7 2 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 2 - 1 5 - 2 3 R E T . P L U G CO R R E L A T I O N . p d f 37 5 7 2 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : S R U 2 2 4 - 1 0 P L U G F I N A L . p d f 37 5 7 2 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 71 6 6 7 0 3 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ C I B P _ G P T _ P e r f _ 3 1 - M a r - 2 0 2 3 _ ( 4 2 2 3 ) . l a s 37 6 0 4 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 6 o f 7 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 1 0 1 3 8 - 0 1 - 0 0 We l l N a m e / N o . SW A N S O N R I V U N I T 2 2 4 - 1 0 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 12 / 1 6 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 2 4 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 83 5 0 TV D 75 0 0 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 12 / 1 6 / 2 0 2 2 Re l e a s e D a t e : 10 / 2 0 / 2 0 2 2 DF 4/ 1 7 / 2 0 2 3 71 5 0 5 6 9 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : S R U _ 2 2 4 - 10 _ G P T _ P e r f _ 0 3 - A p r - 2 0 2 3 . l a s 37 6 0 4 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 10 _ C I B P _ G P T _ P e r f _ 3 1 - M a r - 2 0 2 3 _ ( 4 2 2 3 ) . p d f 37 6 0 4 ED Di g i t a l D a t a DF 4/ 1 7 / 2 0 2 3 E l e c t r o n i c F i l e : S R U _ 2 2 4 - 1 0 _ G P T _ P e r f _ 0 3 - A p r - 20 2 3 . p d f 37 6 0 4 ED Di g i t a l D a t a 1/ 5 / 2 0 2 3 32 3 0 8 3 5 0 4 1 8 3 7 Cu t t i n g s Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 7 o f 7 M. G u h l 9 / 2 5 / 2 0 2 3 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 04/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230414 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPF-81 50029229590000 200066 3/29/2023 READ CaliperSurvey MPI-04A 50029220680100 201092 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 3/20/2023 READ CaliperSurvey MPL-12 50029223340000 193011 4/2/2023 READ CaliperSurvey MPU I-27 50029236920000 221013 3/23/2023 READ LeakPointSurvey PBU 09-23A 50029210660100 198044 3/28/2023 READ MultipleArrayProductionProfile PBU L-112A 50029231290100 222138 3/27/2023 READ MemoryRadialCementBondLog END 1-11 50029221070000 190157 3/19/2023 AK E-LINE Perf END 1-29 50029216690000 186181 2/9/2023 AK E-LINE Perf NCI A-08 50883200280000 169063 3/20/2023 AK E-LINE Perf BCU 19RD 50133205790100 219188 4/4/2023 AK E-LINE PPROF SRU 224-10 50133101380100 222124 3/31/2023 AK E-LINE CIBP_GPT_Perf SRU 224-10 50133101380100 222124 4/3/2023 AK E-LINE GPT_Perf SRU 231-33 50133101630100 223008 3/29/2023 AK E-LINE GPT Please include current contact information if different from above. T37595 T37596 T37599 T37599 T37597 T37599 T37598 T37601 T37603 T37600 T37602 T37594 T37604 T37604 T37605 SRU 224-10 50133101380100 222124 3/31/2023 AK E-LINE CIBP_GPT_Perf SRU 224-10 50133101380100 222124 4/3/2023 AK E-LINE GPT_Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 14:10:44 -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: CTU Ops, N2 Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,350 feet See Schematic feet true vertical 7,500 feet N/A feet Effective Depth measured 8,281 feet 3,010 feet true vertical 7,438 feet 2,971 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 3,019' MD 2,890' TVD Packers and SSSV (type, measured and true vertical depth)Baker HRD-E ZXP LTP; N/A 3,010' MD 2,971' TVD 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: 10,540psi 2,730psi 6,890psi 10,160psi 3,222' 3,178' Burst Collapse 1,130psi 4,790psi Production Liner 5,338' Casing Structural 7,498'8,348' 1,349'Conductor Surface Intermediate 22" 13-3/8" 7-5/8" 1,349' 3,222' measured TVD 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-124 50-133-10138-01-00 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: ADL0028405 / ADL0028406 Swanson River / Tyonek Gas Pool Swanson River Unit (SRU) 224-10 Plugs Junk measured Length 30' 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 30' 0 Size 30' 1,349' 0 06425 0 125121 2221 Chad Helgeson, Operations Engineer 323-163 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1011 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 chelgeson@hilcorp.com 907-777-8405 N/A 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 Kayla Junke at 1:26 pm, Apr 06, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.04.06 11:07:41 -08'00' Noel Nocas (4361) Rig Start Date End Date 3/28/23 4/3/23 PTW, JSA with AK E-line. Pick up Lubricator. Make up 3.5" CIBP. Stab on well. PT stack 250/3500 psi. Tie into RAmarkers. Pull correlation pass. Send to town. ON depth. Set CIBP @ 7150' saw weight bobble good set. PU and tag CIBP. POOH to surface. Rig back AK E-line. PTW, JSA with Fox Energy CTU. Spot crane and pick injector head. Make up lubricator and BHA. Stab on well. PT stack 250/3500 psi. RIH. start cooling down N2. 3000' online with N2 at 1200 scf/min. Continue in hole and tag CIBP at 7160'.Increase rate to 1800 scf/min. 63 bbls returned to surface. Start POOH @ 70 ft/min. Continue pumping N2 chasing any remaining fluid up hole. Tagged up at surface. RDMO Fox Energy CTU. 03/31/2023- Friday PTW, JSA with crew. Rig up AK E-line. Make up 3.5" CIBP. Stab on well. PT lubricator 250/3000 psi. RIH with GPT. Found fluid level at 5910' with 1800 psi gas cap on well. (1240' fluid column to top of plug at 7150 or 10 bbls). Log RAmarkers to confirm depth. Bleed WHP from 1800 psi down to 500 psi to look for water influx. Pull GPT pass and found water. Moved up hole to 5830' (80' of movement). Pressure up well to 2300 psi with lease gas. and Log GPT. Fluid didn"t move. Still remains at 5830'. POOH to surface. At surface waiting for 3.5" CIBP hot shot. Make up 3.5" tubing CIBP (2.75" OD). Stab on well. RIH. Tagged at 7144' with 200 lb over pull. Log correlation pass. Set CIBP 7145'. Tag plug. POOH to surface. Lay down equipment. Ensure wellhead and flow line are double isolated to monitor pressure over the weekend. 03/29/2023 - Wednesday PTW, JSA with crew. Fire equipment. Spot YJOS fluid pump. Pick injector head. Make up CC and nozzle. PT stripper and lubricator. 250/3500 psi. RIH. Bring pump online fill reel and well. 7 bbls to fill well bore. Tagged at 7125' Start washing down at 1.4 bbls/min from 7125' until returns were lost at 7184'. @ 7152' regained returns and started bottoms up. Returns dirty. Offline on pump. Waiting on water supply. N2 Transport on location. Transfer N2. 6.3 bbls to fill well. Online with fluid. Wash down to 7186'. Hard tag. Found PBTD. Did not loose returns. Pump bottoms up from depth. 41 bbls. POOH to surface. Continue pulling OOH cool down N2. Shut in well. Blow reel dry with N2. Location walk around complete. Coil crew depart for the night. Move coil crane. AK E line crew PTW, JSA. MIRU. Shut down until following day. 03/30/2023 - Thursday 03/28/2023 - Tuesday PTW, JSA with Fox Energy, Cruz Crane operator, and Hilcorp personnel. MIRU FOX 8 CTU with 1.75" coil. AOGCC witness waived by Jim Regg. Test BOPE 250/3500 psi. Stab coil in injector head. Dress CT end for coil connector. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 224-10 50-133-10138-01-00 222-124 Rig Start Date End Date 3/28/23 4/3/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 224-10 50-133-10138-01-00 222-124 04/03/2023 - Monday Arrive Swanson River office. PJSM and Permits with AK E-Line crew. Travel to location. Fire up equipment. Found some equipment & wire had froze to the ground since previous rig up. Call for heater. Heater arrived. Thawing equipment. Pad Operator on location. Bled tubing down from 2271 to 1632 PSI. Rig up e-line. Pressure test surface equipment 250 / 3000 PSI. Test good. Run in hole with GPT. Tag CIBP at 7142' (Original set depth 7144'). Fluid level at 5870' (5910' previous job post CIBP). 2405 PSI-BHP (2200 PSI desired before perf). Send log to town. POOH. Out of hole. E-line crew working on dropping 3' of shots off of top of existing 33' gun. Pad Op to location to drop tubing PSI 200 to drop BHP from 2405 to 2200 PSI prior to perf gun shoot. Arm 30' x 2" gun. Run in hole w/ 30' x 2" carrier gun. CCL to TS = 13.5' / CCL to bottom shot = 44' / CCL stop at 7098' + 13.5' = 7111.5' TS. Desired perf interval to shoot 7112' to 7142'. Make tie in pass / log. Send log to town for approval. Tie in approved. Stage tools. Fire guns. Successful fire. Pull out of hole. Start PSI 1400 / Initial fire PSI fast build up. / 5 Min 1900 PSI / 10 Min 2000 PSI / 15 Min 2000 PSI / 20 Min 2000 PSI. Out of hole. Confirm guns fired. Rig down AK E-Line. Transport equipment back to shop to prep for Beaver Creek job tomorrow. Updated by DMA 04-05-23 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281 / TVD = 7,438 TD = 8,350 / TVD = 7,500 RKB to GL = 21.02 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status TY_62-3 7,112 7,142 6,515 6,538 304/3/23 Open TY_62-5 7,155 7,175 6,548 6,564 201/9/23 Isolated TY_62-5 7,179 7,199 6,567 6,582 2012/29/22 Isolated TY_67-0 7,777 7,789 7,020 7,030 1212/27/22 Isolated TY_68-0 7,915 7,930 7,128 7,140 1512/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22Conductor Weld Surf 30 13-3/8"Surf Csg 54.5 J-55 8RD 12.415Surf 1,349(TOW) 7-5/8Intermediate Csg 29.7 L-80 BTC 6.276Surf 3,222 3-1/2"Prod Csg 9.3 L-80 Multiple 2.9923,0108,348 3-1/2Tubing 9.3 L-80 IBT M 2.992Surface 3,019 2 22 13-3/8 JEWELRY DETAIL No. Depth ID OD Item 1 1,388N/A 12.25Whipstock (TOW 1,349) 2 3,010 5.75 Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75 PBR 3 7,145-2.993 CIBP 3/31/23 4 7,1502.993 CIBP 3/30/23 5 7,177-2.993WRP set 2/15/23 6 7,874-2.993 CIBP w/ 39 of cement (7,835) OPEN HOLE / CEMENT DETAIL 13-3/8TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2 Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235 MD. 4 7-5/8 1 SRU 12-15 ( Abandoned) TOW 1,349 3-1/2 Notes: RA Tags set @ 4,994 & 3,998 Short joints 5.8ft @ 5511 & 4508 3 6 5 4 Sand Fill 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: 03/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230328 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 2/18/2023 YELLOW JACKET PLUG BCU 18RD 50133205840100 222033 3/9/2023 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 3/2/2023 YELLOW JACKET PERF-GPT-PLUG KBU 11-07 50133205560000 205165 3/3/2023 YELLOW JACKET PERF KBU 11-07 50133205560000 205165 3/1/2023 YELLOW JACKET PLUG KU 14X-6 50133203420000 181092 3/3/2023 YELLOW JACKET CALIPER-SCBL NCI B-02 50883200900100 197210 3/9/2023 AK E-LINE GPT Perf SRU 224-10 50133101380100 222124 2/15/2023 YELLOW JACKET PLUG TBU D-09RD 50733201310100 181080 2/27/2023 AK E-LINE Plug Punch Please include current contact information if different from above. SRU 224-10 50133101380100 222124 2/15/2023 YELLOW JACKET PLUG 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 8,350'NA Casing Collapse Structural Conductor 1,130psi Surface 4,790psi Intermediate Production 10,540psi 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 Tyonek Gas 10,160psi7,498'8,348' 1,349' 3,222' Perforation Depth MD (ft): 5,338' 3-1/2" 13-3/8" 7-5/8" 1,349' 3,222' 2,730psi 6,890psi 1,349' 3,178' Length Size Proposed Pools: 30' 30' TVD Burst PRESENT WELL CONDITION SUMMARY 7,500' 8,281' 7,438' 2,499' See schematic 30' 22" MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028405 / ADL0028406 222-124 50-133-10138-01-00 Tyonek Gas CO 716A Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit 224-10 Other:CT Operations / N2 Operations Swanson River Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.3# L-80 3,019 March 31, 2023 Baker HRD-E ZXP LTP 3,010 (MD) 2,971 (TVD) 7,155 - 7,930 6,548 - 7,140 3-1/2" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson chelgeson@hilcorp.com 907-777-8405 Operations Manager Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov DSR-3/20/23 X 10-404 BJM 3/23/23 MDG 3/21/2023 CT BOP test to 3500 psi GCW 03/23/23JLC 3/23/2023 3/23/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.23 15:18:25 -08'00' RBDMS JSB 032323 Well Work Prognosis Well Name:Swanson River 224-10 API Number:50-133-10138-01-00 Current Status:Gas Producer Rig:Eline & Fox CTU Estimated Start Date:3/31/23 Regulatory Contact:Donna Ambruz (8305)Permit to Drill Number:222-124 First Call Engineer:Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M) Second Call Engineer:Jake Flora (720) 988-5375 (M) Maximum Expected BHP 3,150 psi @ 6,515’ TVD Based on 9.3ppg gradient Maximum Potential Surface Pressure: 2,499 psi @ 6,515’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Swanson River 224-10 is a sidetracked gas producer that was drilled and completed to 8,350ft. The wellbore is completed as a 3-1/2” mono-bore with tieback to surface, the lower zone has been perforated and flowed since 12/31/2022. The purpose of this sundry is to plugback existing zone and add additional Tyonek perfs. The well has been making some water with sand, so its possible a coil cleanout may be necessary. Notes Regarding Wellbore Condition 3-1/2” mono-bore completion Liner/seal assembly @ 3,010’ 3-1/2” liner currently filled with 10.2 ppg 6% KCl drilling mud A wireline retrievable bridge plug is set at 7,177’ Procedure: 1. Review all approved COAs 2. Once well dies, SL to drift and tag for setting CIBP, if WRP is tagged, try to pull with SL. (not required to remove) 3. If fill is above 7,150’ and needs to be cleaned out with coil tubing: a. MIRU Fox Coiled Tubing Unit, PT BOPE to 3,500 psi High/250 psi Low b. Provide AOGCC 24hrs notice of BOP test c. PU wash nozzle, RIH and cleanout well to 7,177’, using N2 as necessary d. Leave 2000 psi of N2 on well when complete 4. RDMO coil tubing 5. RU E-line, PT lubricator to 3000 psi High/250 psi Low 6. Run GPT to verify wellbore is dry. 7. PU CIBP and set at 7,150’ Variance request from Onshore Order #2 III.G.2.iii and 20AAC25.112(c)(1)(E) for placing 35 ft of cement on bridge plug, due to proximity of next perf zone having 10ft between them, not allowing room for cement to be placed on plug. 8. Perforate the following Tyonek sands individually to determine productivity from each sand. Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT TY_54-5 ±6,145’ ±6,211’ ±5,787’ ±5,837’ 50’ TY_55-5 ±6,300’ ±6,331’ ±5,903’ ±5,926’ 31’ TY_56-9 ±6,548’ ±6,563’ ±6,089’ ±6,100’ 15’ TY_57-8 ±6,690’ ±6,703’ ±6,198’ ±6,208’ 13’ TY_61-0 ±6,745’ ±6,763’ ±6,240’ ±6,253’ 18’ TY_61-8N ±6,999’ ±7,020’ ±6,428’ ±6,443’ 21’ TY_62-3 ±7,112’ ±7,145’ ±6,515’ ±6,540’ 33’ I think this is a cut & paste, since the well is flowing.-bjm Well Work Prognosis Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing b. Above perfs will be shot in the Tyonek Gas Pool governed by CO 716A 9. RD E-Line Unit and turn well over to production for testing. 10. Operations to flow well and test zones E-line Procedure (Contingency) If any zone produces sand and/or water or needs isolated: 11. MIRU Eline and N2 pump truck 12. Pressure test equipment to 3,500 psi High/250 psi Low 13. Eline run PT to find fluid level 14. RU N2 and push fluid below perfs (verify fluid depth with PT tool) 15. PU 3-1/2” CIBP or patch a. If a plug is set (it must be set within 50ft of the top perf being plugged back) b. Dump bail 35ft of cement on top of plug (unless it is between the Tyonek 57-8 and 61-0 Sand – Where there is not enough distance between the sands for a plug and 35ft of cement.) 16. If necessary to cleanout or unload well with coiled tubing, RU same coil equipment used in initial completion a. Test BOPs, 3500 psi High/ 250 psi Low b. Cleanout with N2 or foam c. Set 3-1/2” plug or patch (cement as required in Step 18) Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil Tubing BOP Diagram 4. Standard Nitrogen Operations Updated by CAH 3-17-2023 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API:50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status TY_62-5 7,155’ 7,175’ 6,548’ 6,564’ 20’ 1/9/23 Open TY_62-5 7,179’ 7,199’ 6,567’ 6,582’ 20’ 12/29/22 Isolated TY_67-0 7,777’ 7,789’ 7,020’ 7,030’ 12’ 12/27/22 Isolated TY_68-0 7,915’ 7,930’ 7,128’ 7,140’ 15’ 12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22” Conductor Weld Surf 30’ 13-3/8" Surf Csg 54.5 J-55 8RD 12.415” Surf 1,349’(TOW) 7-5/8” Intermediate Csg 29.7 L-80 BTC 6.276” Surf 3,222’ 3-1/2" Prod Csg 9.3 L-80 Multiple 2.992” 3,010’ 8,348’ 3-1/2” Tubing 9.3 L-80 IBT M 2.992” Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No. Depth ID OD Item 1 1,388’ N/A 12.25” Whipstock (TOW – 1,349’) 2 3,010’ 5.75” Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,177’ - 2.993” WRP 4 7,874’ 0” 2.993 CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8” TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 4 Updated by CAH 3-17-2023 PROPOSED Swanson River Unit SRU 224-10 PTD: 222-124 API:50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status TY_54-5 ±6,145’ ±6,211’ ±5,787’ ±5,837’ 50’ Future Proposed TY_55-5 ±6,300’ ±6,331’ ±5,903’ ±5,926’ 31’ Future Proposed TY_56-9 ±6,548’ ±6,563’ ±6,089’ ±6,100’ 15’ Future Proposed TY_57-8 ±6,690’ ±6,703’ ±6,198’ ±6,208’ 13’ Future Proposed TY_61-0 ±6,745’ ±6,763’ ±6,240’ ±6,253’ 18’ Future Proposed TY_61-8N ±6,999’ ±7,020’ ±6,428’ ±6,443’ 21’ Future Proposed TY_62-3 ±7,112’ ±7,145’ ±6,515’ ±6,540’ 33’ Future Proposed TY_62-5 7,155’ 7,175’ 6,548’ 6,564’ 20’ 1/9/23 Isolated TY_62-5 7,179’ 7,199’ 6,567’ 6,582’ 20’ 12/29/22 Isolated TY_67-0 7,777’ 7,789’ 7,020’ 7,030’ 12’ 12/27/22 Isolated TY_68-0 7,915’ 7,930’ 7,128’ 7,140’ 15’ 12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22” Conductor Weld Surf 30’ 13-3/8" Surf Csg 54.5 J-55 8RD 12.415” Surf 1,349’(TOW) 7-5/8” Intermediate Csg 29.7 L-80 BTC 6.276” Surf 3,222’ 3-1/2" Prod Csg 9.3 L-80 Multiple 2.992” 3,010’ 8,348’ 3-1/2” Tubing 9.3 L-80 IBT M 2.992” Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No. Depth ID OD Item 1 1,388’ N/A 12.25” Whipstock (TOW – 1,349’) 2 3,010’ 5.75” Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 ~7,150’ - 2.993 CIBP 4 7,177’ - 2.993” WRP set 2/15/23 5 7,874’ - 2.993 CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8” TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags set @ 4,994’ & 3,998’, GR Indicates currently @ 6,284’ & 7,235’ Short joints 5.8ft @ 5511’ & 4508’ 3 5 4 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. 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): Swanson River Field GL: 319' BF:N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 7-5/8" L-80 3,178' 3-1/2" L-80 7,498' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 099138 0 2/10/2023 24 Flow Tubing 99 1855 N/A18550 N/A 1,349' MD / 1,349' TVD N/A 8,350' MD / 7,500' TVD 7,835' MD / 7,065' TVD 207' FNL, 1844' FWL, Sec 15, T8N, R9W, SM, AK 112' FSL, 2500' FWL, Sec 10, T8N, R9W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 9.3# 3,222' Water-Bbl: PRODUCTION TEST 12/29/2022 Date of Test: Oil-Bbl: Flowing *** Please see attached schematic for perforation detail *** Gas-Oil Ratio: AMOUNT PULLED 349715 350375 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. SRU 224-10November 26, 20222175' FNL, 1092' FWL, Sec 15, T8N, R9W, SM, AK 337' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2492048 SETTING DEPTH TVD 2482359 TOP HOLE SIZE CBL 12-14-22, GPT & Perf Logs, Mud Logs, LWD (GR, Neu, Res, PWD) Tyonek Gas Pool A028406, A028405 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 348941 2480090 50-133-10138-01-00November 14, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 12/16/2022 222-124 / 322-681 N/A PACKER SET (MD/TVD) 9-7/8" 6-3/4" L- 495 sx / T - 175 sx 2,972' L - 495 sx / T - 220 sx Surface 8,348' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 3,010' ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 3,019'3-1/2" SIZE DEPTH SET (MD) 3,010' MD / 2,972' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 11:26 am, Feb 28, 2023 Completed 12/16/2022 JSB RBDMS JSB 031023 GSFD 10/26/2023 DSR-3/14/23BJM 1/16/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval Ty 62-5 7155' 6548' 2409' 2386' 2989' 2952' 3811' 3752' 4185' 4115' 5209' 5056' 5942' 5633' 7085' 6494' 7714' 6971' 7891' 7109' 8313' 7468' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS TY 74-3 Tyonek Ty 62-5 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Authorized Title: Drilling Manager Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Ty 68 MB 39 ST A8 LB 50-6 Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Ty 67 Sterling B TPI (Top of Producing Interval). Authorized Name and Upper Bel Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 2.28.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.02.28 11:12:12 -09'00' Monty M Myers Updated by CJD 2-28-2023 SCHEMATIC Swanson River Unit SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 PBTD = 8,281’ / TVD = 7,438’ TD = 8,350’ / TVD = 7,500’ RKB to GL = 21.02’ Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)FT Date Status TY_62-5 7,155’7,175’6,548’6,564’20’1/9/23 Open TY_62-5 7,179’7,199’6,567’6,582’20’12/29/22 Isolated TY_67-0 7,777’7,789’7,020’7,030’12’12/27/22 Isolated TY_68-0 7,915’7,930’7,128’7,140’15’12/16/22 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 22”Conductor Weld Surf 30’ 13-3/8"Surf Csg 54.5 J-55 8RD 12.415”Surf 1,349’(TOW) 7-5/8”Intermediate Csg 29.7 L-80 BTC 6.276”Surf 3,222’ 3-1/2"Prod Csg 9.3 L-80 Multiple 2.992”3,010’8,348’ 3-1/2”Tubing 9.3 L-80 IBT M 2.992”Surface 3,019’ 2 22” 13-3/8” JEWELRY DETAIL No.Depth ID OD Item 1 1,388’N/A 12.25”Whipstock (TOW – 1,349’) 2 3,010’5.75”Flex-Lock V Liner Hanger, HRD-E ZXP LTP w/ 5.75” PBR 3 7,177’-2.77”CIBP 4 7,874’0”2.993 CIBP w/ 39’ of cement (7,835’) OPEN HOLE / CEMENT DETAIL 13-3/8”TOC @ Surface (Original 12-15) 7-5/8"Pumped 213 bbls (495 sx) of 12 ppg lead cement followed by 33 bbls (175 sx) of 15.8 ppg tail, bumped plug, 40 bbls of lead returned at surface, TOC @ Surface 3-1/2” Pumped 208 bbls (495 sx) of 12 ppg lead followed by 47 bbls of 15.3 ppg tail, bumped plug, lost 104 bbls, returned 8 bbls of 30 bbl 10.6 ppg spacer. CBL TOC @ ~3,235’ MD. 4 7-5/8” 1 SRU 12-15 ( Abandoned) TOW 1,349’ 3-1/2” Notes: RA Tags 4,994’ & 3,998’ Short joints 5.8ft @ 5511’ & 4508’ 3 4 Activity Date Ops Summary 11/7/2022 Continue evacuating all fluids from mud pumps and removing equipment from rig floor. Button up Generator 3 and prep for move. Remove torque tube bushing for top drive extension, bring TD carrier to rig floor and remove top drive from blocks and set in carrier.;R/U and move Top Drive from rig floor to catwalk. Travel to Swanson to evaluate location. Prepare lower section of torque tube to travel down catwalk when scoping derrick down. Remove T-Bar from torque tube. Loader prepping location at SRU 224-10 for setting up rig footprint.;Remove Generator 3 and set on trailer along with fuel tank. Take down Centrifuge tent and remove windwalls from pits with crane. Connect bridle lines and scope derrick down to half-mast laying lower torque tube on catwalk. Prepare derrick for laying over, hang blocks, unspool drilling line and;cut 9 wraps, lay over mud gas separator, wrap and tie up kelly hose and service loop, break over exhaust pipe on HPU, remove brake linkage, unpin A legs and lay over mast on headache rack. Remove clamshell, centrifuge with crane. Lay over V-Door onto catwalk;Rig crew traveled to SRU 224-10 and laid felt, liner, and spotted rig mats.;Lower roof top on mud pits. Removed Handy berming around the rig. Prepped derrick to be removed from carrier. Secured misc. items through out the rig for travel. Circulating boiler water to cool down. Finish unplugging Pason cables, cameras, Gai tronics, and all electrical wires through out;the rig. Scoped in and lowered dog house in water tank. Removed all light from module roofs. Folded up walk ways, removed stairs, and cont. removing snow through out the rig.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 0 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 0 bbl Hauled: 0 bbls of cmt to KGF G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 11/8/2022 Circulated water in boilers to bring temperature down and evacuate water. CCI picking all three pit modules, mud pump #2 module, accumulator/ water tank/ doghouse module transporting to Swanson River. Set up crane and remove iron roughneck, choke house and lay over v-door windwall and lower derrick;windwalls. 48 hour notice given to AOGCC and BLM for diverter test.;When trucks arrive back remove mud pump #1 module, generator module, Rig HPU and boiler house module. Set cranes and remove mast from draworks module and set on trailer and secure, move drilling line spool to same trailer and secure.;Load and transport Draworks skid, and mud pump, gen skid, pony sub and mats to Swanson river, clear snow and ice from mats and liner;Set remaining mats on liner, set pony subs over well, install lights on buildings prep f/ rig movers to set rig, transport remaining equipment from beaver creek to Swanson river 11/9/2022 Evaluate loader incident and ensure loader operator is good. Make notifications as per policy for incident. Rigging ordered to retrieve loader from ditch. Cranes rig up on pad, bring subbase and set on pony subs with cranes. Receive notification that the draworks skid was dropped 3' last night when;moved to staging pad from beaver creek. Observe damage to draworks skid and arrange to ship to CCI shop for complete evaluation and repair.;Retrieve loader from ditch and set upright on road. Decision was made to stand down for the rest of the day and have meeting on events and communication of the plan forward and expectations before work continues.;Crews cleaning up Beaver creek pad, prep to move offices, work on draworks skid, wait on inspectors in morning, hold safety stand down with all crews. 11/10/2022 Continue with Safety standown. DSM, Tool Pusher and Hilcorp Safety attend meeting with CCI support crew to discuss recent events and plan forwards to avoid any more incidents. Meet at Swanson River operations office with Key personnel and agree to action items to be implemented.;Travel to rig site and restart spotting mud pit modules #1 and #2, Place jig in place and bring in mud pit module #3, Place Mud Pump #2 in place first due to tight location, Place mud pump #1, Set up cranes and install draworks skid on sub, set HPU, Hoist derrick and install on draworks skid.;Set choke house and raise wind wall, set IR in, Spot water tank/doghouse, spot in gen skid, hook up interconnects get gens fired up and get lights up, get air compressor, pump hydralic oil into rig HPU, function and bleed air out of system, raise pit rooves, raise doghouse into drilling position.;Prep and raise mast, hook up rig floor and pit systems, continue hooking up modules, install drive shaft and break linkage, install lights around rig, lay felt liner and mats for catwalk, haul in equipment for rig up and stage for crane, prep derrick to scope up 11/11/2022 Continue to rig mud tanks, pumps, Generator #3 and set windwalls for pits. Install tarps across rig. Crane set in centrifuge and rig up same. Set in boiler house and replace bad lines and connect air heater to warm up system. Spool up drilling line and slip on 9 wraps. R/D camps at BCU. Secure upper;torque tube to mast. 1-1/2 gallon antifreeze spill from bed truck at staging pad with failure to hose.;Continue rigging up boilers, spot mud gas separator with crane and rig up. Continue rigging up mud tanks, inspect derrick and prepare to scope up, Spot and rig up catwalk with assistance from crane. Spot camps and connect electrical lines and receive comms at 19:00 hours. Hook up Pason, Install;stairs on safety shack. Spot mechanical building and hook up electrical lines.;Raise gas buster and hook up , Scope up Derrick Pin torque tube and Prep t/ P/U top drive, P/U top drive and remove from cradle, spot in third party shacks, build mud docks, build steam pressure staging up, take on water to rig tank.;M/U torque bushing, R/U top drive service loop and kelly hose, function test top drive, install saver sub and clamp, install bales and elevators, change oil on top drive gear box, work on rig acceptance checklist. 11/12/2022 Continue bringing mud and equipment from staging pad and get location ready for operations, Change oil in Top Drive swivel, Gear box. Oil and filters on right angle drive and floor motor. Change out Hydraulic IBOP on Top Drive. Function test MP #1 and MP #2, Change agitator in pit #5.;Pressure test all surface lines and stand pipe, Blow down all lines. Continue offloading mud products from staging area and set on docks. Continue working on rig acceptance checklist. Remove wellhead with wellhead rep., install new wellhead, test plug and 2' spacer spool. Spacing too short for vent;line wellhead rep travel to shop for another spool. Building 6% KCL 9ppg mud.;N/U diverter assembly, N/U spacer spools, DSA and Diverter T assembly, set annular tighten bolts, install knife valve and joint of vent line, set line anchors, M/U koomey lines and set in riser, riser wouldn't fit needs 6'' cut off it, take out riser and send to weld shop.;Charge koomey unit, get test joints and DP to location from staging pad, set test joint M/U to test plug, Perform Function test of Diverter system. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: SRF SRU 224-10 Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00107 SRU 224-10 Drilling Spud Date: 11/13/2022 Perform Diverter test, Knife valve opens in 2 seconds, 21-1/4" Annular Preventer closes on 4-1/2" test joint in 40 seconds. Vent Line 156', Outlet F/ subbase 144', Closest ignition source 86'. Move crew safety meeting camps, electrician shop & mechanic shop away to clear regulation restrictions.;from end of vent line. Riser taken to CCI shop to get trimmed. Contact Swanson control room to get flair pilot distinguished. Pilot has been shut off. Complete 600 BBLs of 6% KCL 9.0ppg WBM. Rig accepted at 06:00.;Pull test plug and install 15-1/2" wear ring and RILDS (2). Rack and tally 4-1/2" CDS40 HWDP, install bell nipple returned from welding shop, install flow line and secure.;P/U and RIH with stack washer sub with HWDP T/ 548', POOH and stand back HWDP., break off stack washer.;RIH w/ stack washer P/U DP singles f/ surface t/ 1211' POOH standing back DP in derrick, clear floor.;Get scraper BHA to floor, get OD's and ID's and lengths on all equipment, load racks w/ DP.;M/U scraper BHA and 12.25'' Bit, Bit sub and crossover, RIH P/U DP Tag cement @ 1365' POOH Stand back DP, RIH P/U DP singles t/ 1250'. 11/14/2022 Displace well with 6% KCL 9.0ppg WBM at 1364', Stop and screen down F/ 140's T/ 120's for higher flow rate Circulate at 8BPM with 300psi. continue circulating until good mud returned.;Washed and reamed at 40 RPM and TQ 6K, clean out F/ 1365' T/ 1387' when torque increased stopped and let it mill off. P/U and CBU at 1384' until returns cleaned up GPM 380, SPP 390psi. Slack off and verify 15K down at 1387'. P/U 42K S/O 40K.;POOH with 13-3/8" scraper assembly standing back drill pipe and L/D scraper assembly.;P/U and M/U 6-1/2" spiral drill collars and stand back in derrick.;PJSM on picking up and assembling 13-3/8" whipstock assembly, load all components to rig floor, P/U Tri-Mill assembly and set in hole. P/U and M/U 6-5/8" Flex Joint, XO, UBHO, XO and lift sub. POOH and scribe mill assembly with BOLT hole lower in hole, Lower back in hole and confirm scribe.;B/O lift sub and Gyro hand orient UBHO sub with scribe. M/U lift sub and stand mill assembly back in derrick. P/U whipstock and unable to get the shipping pins drove out of the anchor assembly. Lay down and P/U backup whipstock.;P/U back up Whip stock Pull pins and, M/U to Mill assembly, install 35k shear bolt as per WIS rep, RIH w/ BHA f/ derrick t/ 1383' fill pipe blow down top drive.;R/U Yellow Jacket Eline Hoisting GyroData tools RIH, orient whip stock t/ 3.02 POOH R/D ELine.;M/U Stand, Slack off and set down 1388' set down 19k to shear trip anchor, verify set, set down 41k to shear bolt on whip stock TOW 1349' BOW 1371' , get pumps up to speed and establish parameters.;Mill window f/ 1349' t/1357' 550 gpm 560 psi 86 rpm 6.7k tq on bottom 6k WOB time drill 1 ft per hour 550 lbs of metal recovered.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 0 bbl Hauled: 165 bbl Fluid to KGF G&I Cumulative: 165 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 0 lbs 11/15/2022 Cont milling window from 1357' to BOW at 1371', then 20' new formation to 1391'. Rot wob 15K, 534 gpm-639 psi, 85 rpm-4784 ft/lbs on bott torque, 5 to 9 ft/hr ROP, MW 9.0/vis 61, BGG 3 units. At 1391' worked mills through window rotating/pumping, pumping with no rotation, then no pump or rotary.;Window good and clean. Flow checked well 10 minutes after CBU, then blew down topdrive and surface lines. Total metal recovered at this point is 957 lbs.;POOH from TOW at 1349' to 891', LD two joints HWDP and racked back remainder, LD eight joints drill collars, UBHO, flex joint and mills. Starter mill 1/4" under, follow mill 1/8" under, dress mill 1/32" under gauge. Set cement silo and received 495 sx lead cement.;Cleaned and cleared rig floor, loaded all whipstock tools in baskets and prepped for shipping out. Gyro hand on location for next BHA, updated e-line rep. Staged Sperry tools for PU.;MU directional BHA, M/U TM DM and UBHO obtain offset and M/U Bit, RIH P/U flex collars and Jars, RIH f/ Derrick t/ 1347'.;R/U eline sheave in derrick, RIH w/ Gyro orient tools Run through window without issues.;Drill Ahead f/ 1391' t/ 1595' 540 gpm 1550 psi 50rpm 4.2k tq on bottom 3-6k WOB 80 diff, taking gyro surveys every stand until MWD surveys clean up.;Hauled: 16 bbl Solids to KGF G&I Cumulative: 16 bbl Hauled: 74 bbl Fluid to KGF G&I Cumulative: 239 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 957 lbs Cumulative: 957 lbs 11/16/2022 Drilled 9 7/8 hole from 1595 to 1719 taking gyro surveys each stand. Rot wob 3-4K, 542 gpm-1587 psi, 55 rpm-4599 ft/lbs on bott torque, 100 ft/hr ROP. Sliding wob 1-3K, 543 gpm-1600 psi, 120 psi diff, 86 ft/hr ROP, MW 9/vis 61, BGG 13 units, max gas 40 units. Last two surveys good and clean.;CBU at 534 gpm-1535 psi, 70 rpm-4500 ft/lbs off bott torque while RD e-line unit and gyro, released same. Shut down and flow checked 10 minutes, well static.;POOH on elevators from 1718' with no issue, up wt 57K. Racked back HWDP, jars, NM flex DC's, LD TM-HOC, pulled motor and bit through table for inspection, Bit graded a 0-0 in gauge.;TIH and PU EWR-M5, ALD, CTN collars. Scribed with an RFO of 2.13, MU TM HOC and MU topdrive. Shallow pulse tested tools, blew down topdrive, held PJSM and loaded sources. Cont TIH with NM flex DC's, jars and HWDP for a total BHA length of 723.79'. Cont TIH on DP to 1587'.;Slacked off on 4 way chains on diverter stack, loosened clamp on bluie line from choke house to pits, raised offside of sub base and shimmed to level up derrick. Tightened 4 way chains.;MU topdrive and filled pipe. Mad Passed wellbore from 1590' to 1617' at 225 ft/hr. 520 gpm-1368 psi, 55 rpm-4246 ft/lbs off bott torque. At 1617' Sperry lost comm's with EWR-M5 tool. Swapped to B mode and shut down 10 minutes for hard reset of tool. Tool working again. Cont mad pass 1617' to 1719';Cont drilling 9 7/8" surface hole from 1719' to 2204', 520 gpm 1475 psi, 55 rpm 4.1k tq on bottom 68k PUW 68k SOW 68K ROT;Continue Drilling 9 7/8'' Surface hole from 2204' to 2611' 535 gpm 1620 psi 55 RPM 4200 tq on bottom 74k PUW 73k SOW 74k ROT, Distance from Plan 13.71' 13.49' Above 2.45' Right;Hauled: 64 bbl Solids to KGF G&I Cumulative: 80 bbl Hauled: 96 bbl Fluid to KGF G&I Cumulative: 335 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs p ;Mill window f/ 1349' t/1357' 550 11/17/2022 Cont drilling surface hole from 2611' to 2702'. Rot wob 1-3K, 536 gpm-1572 psi, 55 rpm-4500 ft/lbs on bott torque, 120 ft/hr ROP, MW 9.1/vis 63, BGG 25 units, max gas 123 units.;CBU twice for wiper trip. 535 gpm-1590 psi, 55 rpm-3765 ft/lbs off bott torque. Flow check shows slight seepage over 10 minutes.;Pulled up hole on elevators from 2700', up wt 80K and parked string at 1770', jars inside window. Calculated hole fill = 6.4 bbls, actual hole fill = 8.5 bbls. No issue pulling up hole.;Serviced rig and topdrive, greased crown, adjusted kelly hose.;TIH from 1770' to 2639', dwn wt 65K. Filled pipe and washed last stand to bottom at 2702'. No sign of fill, no issue TIH.;CBU one time at 531 gpm-1592 psi, 50 rpm-4345 ft/lbs off bott torque. Had no increase in cuttings at bottoms up.;Cont drilling 9 7/8" surface hole from 2702' to TD at 3230' md/3186' tvd. Rot wob 2-3K, 539 gpm-1659 psi, 55 rpm-4404 ft/lbs on bott torque, 120 ft/hr ROP. Sliding wob 2-3K, 538 gpm-1610 psi, 134 psi diff, 180 ft/hr ROP. MW 9.0/vis 57, ECD's at 9.2 ppg, BGG 27 units, max gas 313 units.;Circulate hole clean and bump MW up to 9.2ppg;Make wiper trip f/ 3230' t/ 1791' No hole issues;Service rig and top drive;RIH f/ 1791' t/ 3230' No hole issues;Pump Hi Vis Sweep and Circulate around, Back on time w/ 5% increase in cuttings, flow check static, Blow down top drive;POOH on elevators f/ 3230' t/ 730' Rack back BHA and unload sources, down load MWD, L/D BHA as per DD/MWD, Break Bit Graded 1-1 in gauge, clean and clear floor, send down all BHA subs;Hauled: 128 bbl Solids to KGF G&I Cumulative:208 bbl Hauled: 192 bbl Fluid to KGF G&I Cumulative: 527 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/18/2022 Drained BOP stack, PU run tool and retrieved wear ring. PU landing joint/hanger and dummy ran for RKB of 24.54'. LD landing jnt. RU casing tongs and elevators, staged casing on rack, held PJSM with rig crew and casing crew,;Inspect, PU and MU shoe track filling and Baker Lok each joint. Checked that float equipment operational (OK). Cont PU single in hole with 7 5/8" 29.7# L-80 BTC surface casing, top filling on the fly, topping off every 10 jnts, torqued to 7500 ft/lbs. TIH to 1577', no issue exiting window.;At 1577' MU circ swedge and topdrive, broke circ and CBU at 3 bpm. Blew down topdrive. Sent AOGCC notification for upcoming BOP test, witness waived by Jim Regg at 13:40. Updated BLM, no response. Notified Quadco Rep for upcoming BOP test.;Cont PU single in hole from 1577' to 3192' with no issue, MU circ swedge and topdrive, broke circ at 3 bpm while installing buddy bails and staging landing joint, MU circ swedge in landing joint, PU and MU same in string, MU topdrive and washed down at 3 bpm landing hanger with no issue. Up wt 105K,;down wt 98K. Calc displacement = 34.5 bbls, actual = 32.1 bbls. Removed casing tongs from rig floor.;Cont to stage pump rate up to 5 bpm-213 psi, lay out liner for pump truck and staged cementer trucks. Work pipe occasionally with no issue. Stage plug launcher on rig floor.;MU plug launcher and cement hose, Halliburton flushed then loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 325 psi low 3900 psi high, good tests. Halliburton pumped 58.8 bbls 10.5 ppg Tuned Spacer at 4 bpm- 94 to 115 psi, dropped bottom plug and pumped 213;bbls (495 sx) of 12 ppg Type I II lead cement at 5 bpm- 109 to 106 psi, followed by 33 bbls (175 sx) of 15.8 ppg Type I II tail cement at 2.5 bpm- 52 to 0 psi. Halliburton dropped top plug, then displaced with 9.2 ppg 6% KCL Mud at 4 bpm- 40 to 800 psi. Slowed pump to 2 bpm with 14 bbls to go. Did;bump the plug 143.3 bbls into displacement (calculated 144 bbls). Held 1550 psi (FCP of 800 psi) for 3 minutes, bled off and floats held. Bled back 1 bbls back to truck. Had 58.8 bbls of Spacer returns to surface and 40 bbls lead cement to surface. Added LCM to lead cement at 2.4 pps (Bridge Maker).;Mix water temp 71.5 deg. Pumped 50% excess on lead and 50% tail. Lost 0 bbls throughout the job. Did reciprocate string until lead cement well on its way up backside. Up wt 110K, dwn wt 105K. CIP at 21:00, 11/18/2022. RD and released Halliburton.;Flush stack with black water, L/D casing elevators and buddy bails.;Install Pack Off and RILDS, test seals t/ 5000 pai d/ 10 min good,;N/D diverter vent pipe, remove anchors, N/D riser and annular pull T and spacer spools, break top cap of annular and clean out behind elements, pull element and grease reinstall cap and remove from cellar, Clean and prep to install B section and spacer spool;Hauled:43 bbl Solids to KGF G&I Cumulative:251 bbl Hauled: 272 bbl Fluid to KGF G&I Cumulative: 799 bbl Hauled: 43 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/19/2022 Work B section and spacer spools into cellar. Set B section with spacer spools and NU on wellhead. Folded back beaver slide, brought in CCI crane and BOP cradle.;Staged crane and cradle, transferred BOP stack to cellar bridge cranes. Released crane, set BOP stack on wellhead, hammered up all connections. Installed drip pan, flow riser and flow line, installed choke and kill lines, obtained RKB measurements. Installed koomey lines and function test rams/HCR's;Installed 4 way chains. BLM Rep Allie Schoessler waived witness of BOP test at 11:32 via email. AOGCC Rep Jim Regg waived witness at 13:40 on 11-18-22 via email.;Set test joint, flooded surface equipment. RU test equipment, purged air, performed draw down test, attempted shell test on stack, door seal leaked, opened door, replaced gasket, sealed door, filled stack and performed shell test. Quadco Rep arrived at 15:30 and tested audio and visual gas alarms.;Set pipe racks and rack/tally 4 1/2" DP;Tested all BOPE at 250/3000 for 5 min low, 10 min high. Tested with 3 1/2" and 4 1/2" test joints. Had 2 FP Electric choke had to function and retest passed Manual choke had to function and grease retest pass;R/D BOP test equipment Pull test plug set wear ring, R/U to Test Casing;Test 7 5/8'' Casing t/ 3000 psi f/ 30 min, Sensor not pumped up bleed off and pump up, gland nuts leaking tighten and retest Pass Pumped 1.58 bbls in got 1.54 bbls back;Blow down lines and clear floor, Prep to P/U DP;RIH P/U 4.5'' DP off racks t/ 2011';Hauled:0 bbl Solids to KGF G&I Cumulative:251 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 799 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs ggp single in hole with 7 5/8" 29.7# L-80 BTC surface casing, p ppppp g p Did;bump the plug 143.3 bbls into displacement (calculated 144 bbls) Lost 0 bbls throughout the job. )p( 40 bbls lead cement to surface. )pp p bled off and floats held. Bled p ppgg pp dropped bottom plug and pumped 213;bbls (495 sx) of 12 ppg Type I II lead cement at 5 bpm- 109 to 106 psi, ppg p p p pp followed by 33 bbls (175 sx) of 15.8 ppg Type I II tail cement p ;Test 7 5/8'' Casing t/ 3000 psi f/ 30 min, 11/20/2022 Cont PU single in hole with CDS-40 DP from 2011' to 2287'.;POOH racking back stands from 2287' to surface.;Serviced rig and topdrive, while staging BHA on catwalk and racking an additional 64 joints DP.;PU 4 3/4" motor and MU 6 3/4" HDBS PDC, MU DM, PCG, ADR, ALD, CTN, PWD, and TM collars. MU topdrive, plugged in and down loaded MWD. RFO of 127.50. Shallow pulse tested tools 3 times and DM collar failed.;Pulled up hole from 125' and swapped out DM collar with backup tool. Scribed with an RFO of 271.50. RIH to TM collar at 125' and MU topdrive. Plugged in and downloaded MWD, shallow pulse tested with no issues, held PJSM and loaded sources. PU NM Flex DC's, HWDP and jars, BHA = 740.92'.;Cont TIH from 740' PU singles. Filled pipe at 1354'. Singled in hole from 1354' to 2720', turned elevators and TIH to 3090' on stands. At 3090' filled pipe. Increased to 208 gpm-1071 psi,30 rpm-3856 ft/lbs off bott torque, eased down and tagged wiper plugs at 3134'.;Drill Plugs and float equipment f/ 3134' t/ 3222' drill cement t/ 3230' Drill 20' of new hole t/ 3250' 5k WOB 214 gom 1300 psi 40 RPM 3-4k tq;Circulate and condition f/ FIT, Rack Back stand and R/U t/ FIT;R/U and Perform FIT t/ 12.67 ppg EMW, 14.95 gal pumped in 9.2 gals returned, R/D test Equipment blow down;Drill Ahead 6 3/4'' hole Section f/ 3250' t/ 3750' 281 gpm 1700 psi 53 RPM 4400 tq on Bottom , PUW 85k SOW 77k ROT 82k , MW 9.2 ppg ECD 10.01 Max Gas 313 units Distance to Plan 9.52' 8.26' Low 4.74' left;Hauled:0 bbl Solids to KGF G&I Cumulative:251 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 799 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/21/2022 Cont drilling 6 3/4 production hole from 3750 to 4263. Rot wob 2K, 282 gpm-1752 psi, 60 rpm-5200 ft/lbs on bott torque, 120 ft/hr ROP. Sliding wob 1K, 284 gpm- 1740 psi, 104 psi diff, 180 ft/hr ROP. MW 9.3/vis 53, ECDs at 10.1 ppg, BGG 15 units, max gas 629 units at 3800.;At 4263 CBU one time, 280 gpm-1707 psi, 60 rpm-4626 ft/lbs off bott torque. Obtained SPR's and survey, racked one stand back. flow check shows slight seepage, blew down topdrive. Hilcorp HSE Rep Leonard Dickerson did walkthrough of rig and location. Two minor issues immediately resolved.;Pulled wiper trip up hole to 3397 with no issue. Up wt 103K. Parked at 3460'. Calc hole fill = 5.5 bbls, actual hole fill = 6.4 bbls.;Serviced rig and topdrive, clean mud pump suction screens.;RIH on elevators from 3460', down wt 80K, MU topdrive at 4201' and filled pipe, washed last stand to bottom and made hook.;Started 20 bbl hi-vis nutplug sweep down drill string, once sweep exited the bit, cont drilling production hole from 4263' to 4393', rot wob 2-3K, 280 gpm-1882psi, 60 rpm-5100 ft/lbs on bott torque, 120 ft/hr ROP. MW 9.3/vis 53, ECD's at 10.3 ppg, BGG 12 units, max gas 117 units.;Cont drilling from 4393' to 4758' 200 gpm 1899 psi 60 RPM 4800 tq on bottom, Max gas 381 MW 9.35 ppg PUW 105k SOW 89k ROT 96k;Cont drilling from 4758' to 5065' 282 gpm 1820 psi 60 RPM 5200 tqon bottom, Max gas 205 units MW 9.3 ppg PUW 110K SOW 92k ROT 101k, Distance to plan 13.11 11.61' Above 6.10' Left;Hauled:85 bbl Solids to KGF G&I Cumulative:336 bbl Hauled: 155 bbl Fluid to KGF G&I Cumulative: 954 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/22/2022 Cont drilling 6 3/4" hole from 5065' to 5250'. Rot wob 1-3K, 282 gpm-1922 psi, 55 rpm-5260 ft/lbs on bott torque, 90 to 120 ft/hr ROP. Sliding wob 4-5K, 277 gpm- 1885 psi, 189 psi diff, 100 to 134 ft/hr ROP. MW 9.3/vis 60, ECD's at 10.2 ppg, BGG 17 units, max gas 158 units. Start CBU while mad pass.;CBU twice at 281 gpm-1871 psi, 54 rpm-5171 ft/lbs off bott torque. (1st CBU while making mad pass of slide interval);Obtained SPR's and survey on bottom, 10-minute flow check shows slight seepage. Pulled up hole 3 stands and blew down topdrive. Cont pull up hole on elevators to 4195', up wt 122K, parked at 4257'. Calc hole fill = 7.6 bbls, actual hole fill = 9.5 bbls.;Serviced rig and topdrive, greased crown, cleaned mud pump suction screens. Monitored well on trip tank, .4 bph loss rate.;TIH on elevators from 4257' to 5192' with no issues. Down wt 90K. Calc displacement 18.3 bbls, actual displacement 15.2 bbls. MU topdrive on last stand.;Filled pipe and washed to bottom at 5250'. Pumped a 20 bbl hi-vis nutplug sweepp around at 282 gpm-1912 psi, 80 rpm-5500 ft/lbs off bott torque. Sweep back 4 bbls early and had a 50% increase in cuttings.;Resumed drilling ahead from 5250' to 5499', sliding 30' intervals to turn to 36.74 and mad passing slide intervals. Rot wob 2-3K, 282 gpm-2012 psi, 70 rpm-5880 ft/lbs on bott torque, 100 to 120 ft/hr ROP. Sliding wob 3-9K, 278 gpm-1983 psi, 250 psi diff, 50 to 140 ft/hr ROP.;MW 9.3+/vis 61, ECD's at 10.4 ppg, BGG 11 units, max gas 787 units at 5498'.;Cont drilling from 5499' to 5745' , sliding 30' intervals to turn to 36.74 and mad passing slide intervals. Rot wob 2-3K, 282 gpm-2012 psi, 70 rpm-5880 ft/lbs on bott torque, 100 to 120 ft/hr ROP. Sliding wob 3-9K, 278 gpm-1983 psi, 250 psi diff, 50 to 140 ft/hr ROP.;Pump hi-vis walnut sweep around and circulate out. Sweep came back 11bbl early with a 25% increase in cuttings.;Resume drilling ahead f/5745' t/5807' Rot wob 2-3K, 282 gpm-2012 psi, 70 rpm-5880 ft/lbs on bott torque, 100 to 120 ft/hr ROP. Sliding an average of ~30' a stand 3-9k wob 300 psi diff 120'-200'/hr.;Cont Drilling ahead f/5807' t/6071' Rot wob 3-5K, 278 gpm-1950 psi, 70 rpm-5.8-6.9k ft/lbs on bott torque, 100 to 120 ft/hr ROP. Sliding an average of ~30' a stand 3-9k wob 300 psi diff 120'-200'/hr.;Hauled: 96 bbl Solids to KGF G&I Cumulative:432 bbl Hauled: 144 bbl Fluid to KGF G&I Cumulative: 1098 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs Perform FIT t/ 12.67 ppg EMW, 11/23/2022 Cont drilling 6 3/4" hole from 6071' to 6239', rot wob 4-5K 285 gpm-2140 psi, 80 rpm-6700 ft/lbs on bott torque, 100 ft/hr ROP. Sliding wob 3K, 283 gpm-2031 psi, 117 psi diff, 28 to 90 ft/hr ROP. MW 9.4/vis 61, ECD's at 10.6 ppg, BGG 31 units, max gas 388 units at 6239'.;CBU at 282 gpm-1956 psi, 80 rpm-6700 ft/lbs off bott torque. Obtained survey and SPR's. 10 minute flow check = slight seepage.;Pulled up hole for wiper trip from 6239' 5 stands and blew down topdrive. Cont pull up hole on elevators, up wt 140K to 3397' with no issues. Parked with smart tools outside surface shoe. Calc hole fill = 20.2 bbls, actual hole fill = 22.3 bbls.;Serviced rig and topdrive, greased crown, cleaned suction screens, found one suction valve stem guide on pump #2 out of place, reset same.;RIH on elevators slow from 3397' to 4940', filled pipe, cont RIH slow, down wt 90K. Set down twice at 5540' (claystone/siltstone), worked twice and went through to 6179', no issues through coals or slides. MU topdrive and filled pipe, washed to bottom and started sweep around.;Calculated displacement = 54.9 bbls, actual displacement = 52.2 bbls.;Pumped 20 bbl hi-vis nutplug sweep around at 279 gpm-1944 psi, 80 rpm-6726 ft/lbs off bott torque. Had 100% increase in cuttings at bottoms up, max of 234 units gas. Sweep back on time with an additional 50% increase in cuttings, worked full stand.;Resumed drilling 6 3/4" hole from 6239' to 6301', sliding wob 5-6K, 277 gpm-2180 psi, 255 psi diff, 140 ft/hr ROP. Rot wob 2-3K, 278 gpm-2233 psi, 60 rpm-6551 ft/lbs on bott torque, 115 to 120 ft/hr ROP. MW 9.3+/vis 63, ECD's at 10.7 ppg, BGG 30 units, max gas 148 units.;Cont. directional drilling 6-3/4" production hole and mad passing all slides greater than 20' F/6301'-T/6675'. P/U-130K S/O-98K ROT-115K GPM-278 SPP-2380 psi RPM-60 TQ-7K WOB-3/6K Diff-260 psi MW-9.45 ppg ECD-10.83 ppg Max gas- 679 units @ 6549'.;Crew change, held PTSM. Cont. directional drilling 6-3/4" production hole and mad passing slides. Pumped 20 bbl Hi-Vis sweep w/ walnut @ 6735', sweep came back 5 bbls early w/ a 20% increase in cuttings. Current depth of 6883'.;P/U-140K S/O-100K ROT-115K GPM-285 SPP-2044 psi RPM-60 TQ-7K WOB-3/6K Diff-140 psi MW-9.5 ppg ECD-10.96 ppg Max gas-628 units @ 6796'. Distance to well plan: 15.83' 15.83' Low .18' Right.;Hauled:132 bbl Solids to KGF G&I Cumulative:564 bbl Hauled: 198 bbl Fluid to KGF G&I Cumulative: 1288 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/24/2022 Cont slide drilling from 6883' to 6930', continuous mudmotor stalling, added NXS lube to 1% in active and slightly better, pumped a 20 bbl nutplug condet sweep which came back 9 bbls early and had a 10% increase in cuttings. Sliding improved considerably after sweeping hole, saw a good;amount of pea and nickle size coal chunks at shakers. Sliding wob 4-5K, 279 gpm-2074 psi, 50 to 500 psi diff, 0-32 ft/hr ROP. Rot wob 1-2K, 281 gpm-2164 psi, 60 rpm-7634 ft/lbs on bott torque, 25-100 ft/hr ROP. MW 9.5/vis 62, ECD's 10.8 pgg, BGG 21 units, max gas 75 units.;Cont directional drilling from 6930' to 7168', sliding wob 3-7K, 277 gpm-2200 psi, 270 psi diff, 1 to 80 ft/hr ROP. Rot wob 8K, 279 gpm-2336 psi, 60 rpm-7498 ft/lbs on bott torque. MW 9.5/vis 61, ECDs at 10.8 ppg, BGG 33 units, max gas 1483 units at 7168', start wt up to 9.6 ppg.;Cont. directional drilling 6-3/4" production hole as per wp07 F/7168'-T/7229'. Bumped MW up to 9.6 ppg due to connection gas. P/U-145K S/O-105K ROT-120K GPM-278 SPP-2400 psi RPM-60 TQ-8K WOB-5/9K Diff-350 psi ECD-10.89 ppg MW-9.6 ppg Max gas 357 units @ 7168'.;CBU X2, GPM-275 SPP-2087 psi RPM-60 Max gas 457 units ECD-1084 ppg. Shot on bottom survey, obtained new SPR's, flow checked well (static).;Performed 1000' wiper trip F/7229'-T/6179' w/ no issues. Had calculated hole fill for the trip. P/U-160K S/O-115K;Serviced rig while monitoring well on TT (static). Greased crown, blocks, TD, wash pipe, IR, DWKS, brake linkage, and drive line.;RIH on elevators F/6238'-T/7229' w/ no issues or fill on bottom. Had calculated pipe displacement for the trip. P/U-140K S/O-105K;Broke circ. Pumped tandem sweeps- 20 bbl low vis/ low weight w/ walnut sweep, followed by 20 bbl Hi-Vis/ Hi-weight w/ walnut sweep. Seen 100% increase in cuttings on BU (quarter size coal chunks). Sweep came back on time a 25% increase in cuttings (super fines). GPM-284 SPP-2302 RPM-80 Max gas 573;Cont. directional drilling 6-3/4" production hole as per wp07 F/7229' to current depth of 7434'. Cont. to maintain 1% by volume on NXS lube in the mud system. P/U-150K S/O-105K ROT-123K GPM-278 SPP-2457 psi RPM-60 TQ-8K WOB-5/9K Diff-280 psi ECD- 10.89 ppg MW-;9.65 ppg Max gas 279 units @ 7293'. Distance to well plan: 5.34' 4.04' Low 3.50' Left;Hauled: 64 bbl Solids to KGF G&I Cumulative:628 bbl Hauled: 96 bbl Fluid to KGF G&I Cumulative: 1384 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/25/2022 Cont drilling 6 3/4" hole from 7434' to 7628'. Rot wob 6-7K, 279 gpm-2339 psi, 60 rpm-9000 ft/lbs on bott torque, 30-40 ft/hr ROP. Sliding wob 4K, 278 gpm-2374 psi, 116 psi diff, 20-40 ft/hr ROP. MW 9.7/vis 59, ECD's 10.8 ppg, BGG 40 units, max gas 232 units.;Cont drilling from 7628' to 7726'. Rot wob 7K, 275 gpm- 2462 psi, 60 rpm-9266 ft/lbs on bott torque, 30-70 ft/hr ROP. MW 9.6+/vis 63, ECD's at 10.8 ppg, BGG 47 units, max gas 164 units.;Obtained survey and SPR's, pumped a 40 bbl tandem sweep around at 283 gpm-2416 psi, 80 rpm-8800 ft/lbs off bott torque. Sweep back on time with 100% increase in cuttings (pea size coal and fines).;Cont drilling from 7726' to 7793', rot wob 8K, 276 gpm-2513 psi, 60 rpm- 8758 ft/lbs on bott torque, 40 to 100 ft/hr ROP. Sliding wob 7-8K, 278 gpm-2513 psi, 253 psi diff, 40 ft/hr ROP. MW 9.6+/vis 62, ECD's at 10.9 ppg, BGG 46 units, max gas 104 units.;Cont. directional drilling 6-3/4" production hole as per wp07 F/7793'-T/8006'. P/U-165K S/O-108K ROT-133K GPM-280 SPP-2600 psi RPM-60 TQ-9/10K WOB-9K Diff-350 psi ECD-11.06 ppg MW-9.7 ppg Max gas 219 units @ 7858'.;Crew change, held PJSM. Cont. directional drilling 6-3/4" production hole as per wp07 F/7793' to current depth of 8180'. P/U-170K S/O-109K ROT-130K GPM-285 SPP-2421 psi RPM-60 TQ-9K WOB-5/9K Diff-202 psi ECD-10.95 ppg MW-9.7 ppg Max gas 277 units @ 8055'.;Distance to well plan: 12.60' 2.99' Low 12.24' Left;Hauled: 49 bbl Solids to KGF G&I Cumulative:677 bbl Hauled: 201 bbl Fluid to KGF G&I Cumulative: 1585 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/26/2022 Cont drilling 6 3/4" hole from 8180' to 8284', rot wob 7K, 283 gpm-2580 psi, 60 rpm-8700 to 10,000 ft/lbs on bott torque, 20-60 ft/hr ROP, sliding wob 6-8K, 283 gpm-2640 psi, 320 psi diff, 30-40 ft/hr ROP. MW 9.7/vis 57, ECD's at 10.9 ppg, BGG 75 units, max gas 354 units.;CBU twice at 281 gpm-2345 psi, 80 rpm-8100 to 9700 ft/lbs off bott torque, MW 9.7+/vis 59, ECD's at 11.1 ppg, BGG 30 units at shut down. Obtained on bottom survey and SPR's. Well flowing at 4.3 bph over 15 minutes.;Cont circulating at 273 gpm-2200 psi, 70 rpm-9400 to 10,400 ft/lbs off bott torque, increased MW from 9.7+ to 9.8+, had a max of 960 units gas at bottoms up. Circulated until 9.8+ in/out, ECD's at 10.9 ppg. 15 min flow check was static. Obtained new SPR's.;Pulled up hole on elevators from 8280' slow, up wt 185K, pulled 5 stands and blew down topdrive, cont pull up hole to 7164' with no issue. S/O and parked at 7228'. Calculated hole fill = 7.2 bbls, actual hole fill 5.7 bbls.;Monitored well on trip tank 30 minutes during rig service, well static. Serviced rig and topdrive, built tandem sweep.;TIH on elevators from 7228' to 8106' with no issue. At 8106' we set down three times (top of a slide), MU topdrive, filled pipe, washed/reamed stand down and saw nothing. Cont TIH to 8219' and MU topdrive.;Filled pipe then pumped 40 bbl tandem sweep at 278 gpm-2482 psi, 70 rpm-9000 to 10,800 ft/lbs off bott torque. Had a max of 3044 units at 3100 strokes (BU = 3628 stks) and hole started unloading pea to quarter size coal chunks. Sweep back 10 bbls late, gas still dropping at 737 units.;Had 100% increase in cuttings/coal just prior to bottoms up and another 100% of fines with sweep to surface. Gas down to 89 units at shut down and shakers cleaned up good. Received centralizers for liner run. Baker Rep was out to check tools and get liner tally.;Cont. directional drilling 6-3/4" production hole as per wp07 F/8284' to called TD by Geologist @ 8350'. P/U-190K S/O-111K ROT-135K GPM-278 SPP-2800 psi RPM-60 TQ-8/9K WOB-7.5K Diff-350 psi ECD-11.15 ppg MW-9.85 ppg Max gas 224 units @ 8324'.;Performed flow check, well was flowing at .31 bph. Circulated hole clean and weighted up mud system from 9.85 ppg to 10.0 ppg. P/U-170K S/O-111K ROT-136K GPM-277 SPP-2513 psi RPM-70 TQ-9K ECD-11.32 ppg Max gas 201 units.;Crew change, held PTSM. Circulated 10.0 ppg mud all the way around. Flow checked well (static). B/D TDS.;Pulled 5 std wiper trip F/8350'-T/8034' w/ no issues. Had calculated hole fill for the trip. P/U-180K S/O-120K;RIH on elevators F/8034'-T/8284', washed last std to bottom w/ no issues or fill on bottom. GPM-112 SPP-715 psi;Pumped tandem sweeps- 20 bbls Low-Vis/Low weight followed by 20 bbl Hi-Vis/Hi-weight. Had 50% increase in cuttings on BU (coal). Sweeps came back 10 bbls early w/ a 75% increase in cutting (mostly fines). GPM-283 SPP-2683 psi RPM-70 TQ-10.5K MW-10.0 ppg ECD-11.32 ppg Max gas 481 units;Flow checked well on TT for 30 min (slight seepage).;CBU. GPM-280 SPP-2621 psi RPM-70 TQ-9.7K MW-10.0 ppg ECD-11.21 ppg Max gas-80 units. Flow check well (static). Obtained new SPR's. Blew down TDS.;POOH on elevators. Current depth of 8284'.;Distance to well plan: 14.01' 4.40' Low 13.30' Left;Hauled: 48 bbl Solids to KGF G&I Cumulative: 725 bbl Hauled: 112 bbl Fluid to KGF G&I Cumulative: 1697 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 11/27/2022 Pulled up hole from 8350', up wt 185K, to 7362'. Hole fill short by 2 bbls. Monitored well 5 minutes, well static. TIH from 7362' to 8284', down wt 110K. MU topdrive and filled pipe, washed down to bottom at 8350' with no issue.;CBU at 284 gpm-2498 psi, 30 rpm-9100 to 10,100 ft/lbs off bott torque. Had a max of 1795 units at bottoms up with a 25% increase in fine cuttings, ECD's at 11.3 ppg. Cont to circulate and increase mud weight from 10.0 to 10.2 ppg, ECD's increased to 11.4 ppg. Shut down pump.;Monitored well 15 minutes, well static, obtained SPR's. Pulled up hole five stands at 30 ft/min to 8007', 1.87 bbl hole fill (calc 2.3). Pulled five more stands at 50 ft/min and hole fill right on the money at 2.3 bbls. Cont to POOH with no issue in hole conditions or hole fill to 3216'.;Eased into surface casing with BHA, no issues and did flow check. Well static. Parked at 3031' for rig service. Hole fill at this point calcualted at 39.10 bbls, actual hole fill 37.88 bbls.;Installed TIW on stump, MU topdrive and hung off blocks. Cut and slipped 130' drill line. Monitoring well on trip tank, hole taking 1.2 bph.;Broke off topdrive, removed TIW from stump, MU topdrive and pumped 20 bbl dry job, then dropped 2 3/8" hollow drift with wire.;Cont. POOH F/3031' T/BHA at 740'. Hole fill- Cal- 63.6 bbls Act- 63.4 bbls Diff- +.1 bbls Baker tool hand arrived on location.;Racked back 8 stds on HWDP, L/D jar std, and flex collars. Gave Parker casing hands 2 hr. notice. Held PJSM, removed sources and down loaded MWD data. L/D remainder of MWD tools, mud motor, and B/O PDC bit. Bit grade- 1/8" under gauge, DBR (1-8-RO-SG-X-2-PN-TD), and one plugged jet.;Serviced rig- Greased crown, TD, IR, blocks, wash pipe, brake linkage, DWKS, drive shaft, and changed oil filters on DWKS motor.;Cleaned & cleared rig floor. Prepped to run 3.5" liner. R/D drilling elevators. Static loss rate= .5 bph;Crew change, held PTSM. Cont. R/U Parker handling equip. Loaded out racks w/ 3.5" liner. Held PJSM on running liner w/ all parties involved.;P/U, BakerLok, and M/U 3.5" shoe track. Tested floats (ok). Cont. running 3.5" liner as per run tally F/68' to current depth of 2115'. P/U-30K S/O-30K;Hauled: 16 bbl Solids to KGF G&I Cumulative: 741 bbl Hauled: 64 bbl Fluid to KGF G&I Cumulative: 1761 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs well was flowing at .31 bph. p ppg weighted up mud system from 9.85 ppg 11/28/2022 Cont PU single in hole with 3 1/2" 9.3# L-80 liner from 2115' to 3200', filling on the fly, topping off every ten jnts and stopped just above surface shoe.;MU circ swedge and topdrive. CBU at 3 bpm-170 psi. Broke off and blew down topdrive.;Cont PU single in open hole with liner from 3200' to 5306'. Ran a total of 173 full length joints of liner that included shoe track and RA marker joints. Torqued RTS-8 at 3375 ft/lbs, H563 at 2900 ft/lbs and H533 at 3400 ft/lbs.;MU topdrive and circulated at 3 bpm-275 psi, removed air slips from rig floor, staged Baker liner hanger on catwalk, RU to PU hanger assembly, blew down topdrive.;Worked hanger assembly to rig floor, PU and MU same. Mixed and poured xanplex. Up wt 60K, dwn wt 51K. PU and MU single jnt CDS-40 DP and XO, S/O and MU topdrive. Shipped out cement silo and all HDBS bits.;Circulated 2 liner volumes at 3 bpm-300 psi and blew down topdrive. Did not rotate as we will not be rotating string due to MU torque of 2900 ft/lbs on the H563 liner connections. Up wt 60K, dwn wt 55K. Removed casing tongs from rig floor, released Parker casing crew.;Moved HWDP in derrick and resumed TIH on stands from 5384', top filling stands. Trip speed 30 ft/minute. At 6260' we set down 3 times (middle of a slide, small coal). MU topdrive and washed stand down at 3 bpm-395 psi to 6307'. Cont TIH on stands to 6871' with no issue.;At 6871' MU topdrive and CBU staging up to 205 gpm-821 psi. Max of 166 units gas at bottoms up. Shut down, blew down. Cementers on location at 18:30 staging trucks on liner. Had some issue getting pump started but worked through it. Temp at 3.;Cont. TIH on DP stands F/6871' to bottom at 8350'. P/U-105K S/O-80K Pipe displacement- Cal= 21.1 bbls Act= 19.8 bbls Diff= 1.3 bbls BLM Rep Quinn Sawyer on location at 20:00 hrs.;Circ. & conditioned mud for cement job. GPM-210 SPP-876 psi Max gas- 955 units;Blew down TDS, P/U Baker cement head.;Crew change, held PTSM. Cont. R/U HES cement liners. Halliburton pumped 15 bbls water to flush and fill lines. Shut in at Baker cement head to PT lines. Found leak on 1502 hammer union, replaced rubber seal on hammer union. Retested cement lines to;278 psi low and 4600 psi high (ok). Lined up Baker cement head to Halliburton, pumped 30 bbls 10.6 ppg spacer at 4 bpm- 675-650 psi, followed with 208 bbls (495 sx) 12 ppg Type I II lead cement at 4.5 bpm, 545 to 190 psi, followed with 47 bbls (220 sx) 15.3 ppg Type I II Tail;cement at 3.7 bpm, 190 to 124 psi, Added 2 pps of LCM to lead cement. Baker released dart, Halliburton then displaced with 10.2 ppg 6% KCL mud at 4.5 bpm- 113 ICP. 23 bbls into displacement caught pressure chasing cement. Reduced rate at 42 bbls into displacement;due to packing off to 1.5 bpm- 620-1380 psi and bumped plug/landing collar 85 bbls into displacement (calculated at 87 bbls). FCP 1380 psi. Halliburton increased to and held 2167 psi (787 over fcp) for 2 minute. Bled back .75 bbl to truck and floats held.;CIP at 03:56 on 11-29-22. Lost 104 bbls throughout the job. Pressured up to 2643 psi, S/O F/ 105K to 30K, confirmed hanger was set. Brought pressure up to 3109 psi, seen packer set, held for 3 min. Staged up pressure to 3706 to shift HRD-E and release running tool. Bled off;pressure, P/U to 73K and released from hanger. LD Baker cement head, MU topdrive. Pressured up to 900 psi on drill string and PU 10 slowly. Once psi started dropping, rig started pumping and did one full circ. at 279 gpm, SPP-384 psi. Had 8 bbls of spacer to surface,;and 0 bbls of cement. Shut down pump, L/D single, installed 2 wiper balls in drill string, MU topdrive and pumped second circulation at 282 gpm, SPP-373 psi.;Currently blowing down the TD.;Hauled: 6 bbl Solids to KGF G&I Cumulative: 747 bbl Hauled: 174 bbl Fluid to KGF G&I Cumulative: 1935 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs 11/29/2022 Flow check well: Static. POOH F/ 2860' T/ Baker Liner running tool. P/U 57K;Break apart and L/D Baker Liner running tool. M/U swizzle stick and wash stack. P/U and break down cement head, clean and clear rig floor.;P/U PBR Polish Mill assembly and RIH with 4-1/2" drill pipe from derrick T/ 3021' and polish top of PBR as per baker representative at 30 RPM, 3 BPM with 200psi SPP. P/U 55K S/O 55K. Top of liner at 3013'.;Circulating WBM while building corrosion inhibited water for displacement. Circulating at 3BPM with 130psi SPP.;Displace well with 20 BBLs of spacer and 120 BBLs of corrosion inhibited water at 177 GPM with ICP at 410psi SPP and FCP at 81psi SPP.;Perform 30-minute negative flow check with well on trip tank. Good no flow test. BLM Allie Schoessler waived witness for MIT tests.;POOH L/D 4.5" DP singles F/2990'-T/331'. P/U-55K S/O-55K Vacuumed wiper balls through pipe, re-dope threads, and installed thread protectors on tight. Cont. hauling drilling mud to KGF G&I and clean tank tops.;RIH out of the derrick w/ 5 stds of 4.5" DP and 8 stds of 4.5" HWDP F/331'- T/1225'.;POOH L/D 4.5" HWDP and 4.5" DP singles F/1225'-T/Baker polishing mills.;RIH out of the derrick w/ 4.5" DP F/21'-T/2988'. (48 stds) P/U-55K S/O- 55K;Crew change, held PTSM. Serviced rig- Greased TD, blocks, crown, wash pipe, IR, DWKS, brake linkage, and drive shaft. Checked pulsation dampeners MP #1= 600 psi MP #2= 800 psi;Circ. pipe volume GPM-258 SPP-145 psi. Blew down TDS.;POOH L/D 4.5" DP singles F/2988'-T/ Baker polishing mills. Vacuumed wiper balls through pipe, re-dope threads, and installed thread protectors on tight.;RIH out of the derrick w/ 4.5" DP F/21'-T/1720'. (27 stds) P/U-44K S/O-44K;Circ. pipe volume GPM-258 SPP-103 psi. Blew down TDS.;POOH L/D 4.5" DP singles F/1720' to current depth of 859'. Gave Parker casing hands and Baker tool hand 3 hr. notice for running 3.5" tie back.;Hauled: 49 bbl Solids to KGF G&I Cumulative: 796 bbl Hauled: 616 bbl Fluid to KGF G&I Cumulative: 2551 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs )p Lost 104 bbls throughout the jo 3 1/2" 9.3# L-80 liner followed with 208 ppg()p p p ppg p p bbls (495 sx) 12 ppg Type I II lead cement at 4.5 bpm, 545 to 190 psi, followed with 47 bbls (220 sx) 15.3 ppg Type I II Tail;cement at p floats held.;C pp g Had 8 bbls of spacer to surface,;and 0 bbls of cement. 11/30/2022 POOH L/D 4.5" DP singles F/ 859' and L/D PBR Mill assembly.;Pull wear ring, R/U and perform operational assurance test against blind rams of liner lap T/ 3000psi. for 10 charted minutes. Passing test. Submit 24-hour notice to AOGCC of upcoming MIT tests.;R/D test equipment, B/D Choke and mud cross, R/U casing equipment, PJSM with all personnel involved in running 3-1/2" 9.2# L-80 IBT-Mod Range II tubing Tie-Back string as per approved tally. AOGCC Jim Regg waived witness of MIT test for SRU 224-10 @ 08:39am.;RIH with Bullet Seal assembly P/U 3-1/2" 9.2# L-80 IBT-Mod Range II tubing as per approved tally and locate PBR. Mark No-Go and confirm by pulling seals and 15' and locate No-Go again on same mark. L/D 2 jts. M/U 4 pup jts, hanger and landing jt. Land hanger, RILDS and remove landing joint.;Bottom of Seal Assembly @ 3019'. 1.34' off of No-Go. Finished hauling off drilling mud and cleaning out tank bottoms.;R/D Parker casing equip. B/O and L/D landing Jt. R/U testing equip. Filled IA w/ 1.97 bbls of diesel for 58' of coverage (freeze protect). Filled tubing w/ .4 bbls of diesel for 47' of coverage. Flooded stack to blind rams w/ diesel and purged out all air. Flushed entire pit system w/ Barakleen pill;Perform MIT-T T/3000 psi on chart for 30 min (ok). Pumped in .79 bbls Bled back .77 bbls. R/U testing equip to IA, Performed MIT-IA T/3000 psi on chart for 30 min (ok). Pumped in 1.4 bbls Bled back 1.4 bbls. R/D testing equip. Vacuumed out diesel from stack. WHR installed TWC.;Crew change, held PTSM. Flushed MP's, pop offs, Bleeders, TD, low/high pressure lines, choke manifold, gas buster, and BOP's w/ Barakleen pill and blow down same. Filled pit #10 w/ fresh water and repeated same. Cleaned and sent XO's & subs off rig floor. Filled pit #10;again, added 1 drum of Baracore 100 corrosion inhibitor, and flushed through same.;Cont. w/ flushing on pit system. De-energized koomey, opened up all ram doors, removed ram. Cleaned out residual material from cavities. Prepped BOP internals for stack out, closed ram doors. N/D riser, flow line, and flow box. Installed trolley beams.;Currently hooking up bridge cranes to BOP stack.;Hauled: 2 bbl Solids to KGF G&I Cumulative: 798 bbl Hauled: 498 bbl Fluid to KGF G&I Cumulative: 3049 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 12/1/2022 Remove BOPE stack from well and move near V-door. Remove adapter spool and spacer spool from well. Install dry hole tree and test hanger void, hanger neck seals and tree T/ 5000psi for 15 minutes each. All good tests. Pull TWC and secure well. Continue cleaning pits and disassemble;mud cross choke and kill components.;Continue prepping equipment for stack out. Install shipping beams in sub, remove adapter and spacer spools from cellar and bring BOPE stack into cellar to break double gate from mud cross, inspect ring gasket and install new API ring and re-torque. Tear down fluid end on MP #2 and pickle same.;Continue thoroughly cleaning pits. Place mud cross assemblies in hot box for warming and cleaning. Continue to haul third party vendor equipment to town. Rig down, clean and disassemble pull tongs. Molly mist all pins while re-assembling tongs.;Steam cleaned IR, and TD. Cont. w/ cleaning in pit tanks and shakers. Molly misted all ram blocks and stored away. Loaded out MWD shack and tool box. Gathered up misc. well head equip and banded to pallet.;Crew change, held PTSM. Cleaned & oil rotary table bushings & gears. Removed gauges and sensators from stand pipe, cleaned and pumped up sensators. Cont. w/ cleaning in the pits and prepped MP #1 & MP #2 for stack out. Loaded out remainder of mud product.;Started breaking down mud docks. Clean out bird baths and check on wood under matting (ok). Power washed rig floor. Gathered up and put Quadco gas alarm sensors in doghouse. Removed GeoLog shack from perimeter of rig. R/D choke/Gas buster lines.;Inspected suction line for MP's. Repaired HYD pressure washer in choke house.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 798 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 3049 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 12/2/2022 Install saver sub on top drive and check bearing end play/ back lash, Install new fuel filter housing on generator #2, Continue cleaning mud tanks, Disconnect TD HPU lines/ Kelly hose, Rig down and lay out torque bushing, Lower TD in cradle and lower down to catwalk. Disconnect;accumulator lines. Remove T-Bar from torque tube.;Shovel snow around handy berm, Cleaning mud pumps, Draining two drums of gear oil out of #2 mud pump, Packing up TD HPU module, Rigging down equalizer lines between all mud tanks, R/D pop off lines from mud pumps to mud tanks, Re-sealing gear end cover on MP #2 gear end,;Change out agitator and electric motor on mud tank #6, Torque the rebuilt dart valve, Molly mist and cover all mud line connections, Cover electrical and hydraulic connections and rig down S pipe on standpipe.;R/D gen #3 and mud lab. Cleaned cuttings box and removed shaker cuttings slides. Applied per lube 19 on catwalk cables, degasser cables, all accessible cables in the derrick, and doghouse cables. R/D degasser in mud pits and lowered into pit #4. R/D gas buster hard line;to shaker. Pressure washed mezz deck, and sub base/cellar area. Loaded out gen #3 and hauled to Tyler pad.;Crew change, held PTSM. Lower gas buster, opened side port and inspected for scale. Cleaned & organized lube room. Sorted through oily waste and prepped for disposal. Disconnected Pason throughout the rig. Loaded out mud man shack and hauled to Tyler pad along w/;pipe racks. Hauled Handy berm conex to location. Moved trailer around on Tyler pad to stake grassroots well. Emptied hot house of hoses & straps.;Hauled: 6 bbl Solids to KGF G&I Cumulative: 804 bbl Hauled: 529 bbl Fluid to KGF G&I Cumulative: 3578 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs pg qp 3-1/2" 9.2# L-80 IBT-Mod Range II tubing Tie-Back string py p Performed MIT-IA T/3000 psi on chart for 30 min (ok) 12/3/2022 Remove, Rebuild and re-install 4" valves on MP#1 and MP#2. Remove 4" standpipe valve and prepare to rebuild. Finish removing debris from MGS. Remove and inspect high pressure hoses and hard lines on MP#1 and MP#2 for washouts. Complete rigging down TD HPU.;Unplug all electrical for pit 1,2 and 3 except lights and heaters. Replace agitator #6 on pit module 2. Disconnect and store CCTV cameras. Quadco rep remove all gas alarm equipment from rig and take to Anchorage. Continue cleaning and organizing throughout rig.;Remove Pason PVT sensors out of pit module #1, Rebuild 4" standpipe valve on rig floor, Finish installing agitator on pit #6, Cleaning pump rooms, Lube room, Loading out miscellaneous equipment around rig, Continue working on cold stack list. Scrubbing the outside walls of the mud pumps, TD HPU,;Boiler house and chipping ice around sub and MGS skid.;Scrubbed and power washed the outside of all the mud pits. Palletized & banded handling equip, T-bar, and tongs to be sent in for inspection. Changed out light bulbs on crown. Removed Pason PVT sensors off pit module #2. Cleaned choke house. R/D Geronimo line.;Crew change, held PTSM. Disposed of metal cutting in metal dumpster. Rebuilt blind ram blocks w/ new rubbers. Cleaned gen house, MCC room, VFR room, and air compressor room. Performed EAM's on MP #1 & 2 and floor motor. Organized and inventoried C- can.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 804 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 3578 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 12/4/2022 Continue moving dry equipment to pad 12-27 for stack out. Dispose of used oil containers as per Swanson River Hydrocarbon Recycle in Alaska waste guide after discussing with SRU Production Foreman. Rebuild manual choke. Troubleshoot 37 pin TD communication cable.;Repair CCTV camera, Prep derrick for scoping down, Continue working on cold stack list.;Pressure wash top of all pit modules. Shovel out windwall basket. PJSM, Scope in derrick, Layout bottom section of torque tube, Remove turnbuckles from upper torque tube section, Hang off blocks, Tie up cables, Strap service loop and kelly hose to derrick, Remove tarps from V-Door,;Unspool drill line and cut off 8 wraps, remove drill line from dead man, Hang drill line in mast with #2 winch line.;Laid over beaver slide. Pressure washed tarps, folded, and stored away. R/D power & HYD to catwalk. Hun off Kelley hose, service loop, climb assist in derrick. R/D break linkage. Worked on EAM's. Cont. working through stack out list. Secured loose equip. on top of mud tanks;for travel. R/D and stored away lights from top of MP's. Load out extra rig mats onto floats to send to CCI's yard.;Crew change, held PTSM and weekly safety meeting w/ rig crew.;Finished removing remainder of the lights from module roof tops. Greased choke manifold valves. Prepped mud tanks to remove wind walls and lower roof tops. Removed Sala block from derrick for inspection.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 804 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 3578 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 12/5/2022 Shut down boiler and B/D boiler and heater lines. B/D all water lines. R/D steam, water and air lines. Crane pick clam shell, Pick mud tank wind walls. Lay over mast onto headache rack, Remove pins from lifting rams and prepare mast for rig move. Crane pick Iron Roughneck off of floor.;Crane pick centrifuge, feed pump and control panel from pits. Crane pick choke house from rig floor. Cover all piping in pits to lower roofs. Crane pick BOPE stack from cellar move over and set on plywood and hold with crane while removing lifting plate, Move BOPE to carrier and secure on stand,;Unbolt Annular Preventer cap and rotate so that pad eyes will be 90 from hose fittings and directly over gates on double and single gates. Unbolt Annular Preventer, Replace API ring and re-torque flange connection. Lay over V-Door windwall with crane.;Shovel snow from with in rig foot print. Plowed snow from pad. Folded roof flaps between roofs of pits. L/D roofs on all three pit modules. R/D electrical to pit lights.;Crew change, held PTSM. Blew down & R/D camp water. Disconnected remainder of electrical on rig. Scoped in and lower dog house in water tank. Hauled Handy berm conex to staging pad 12-27. Stored away hoses in hot house. Loaded out 2 Tioga heater and a light plant,;R/D and loaded out CCI's conex w/ choke house. Hauled both trailers to Tyler pad.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 804 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 3578 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 43 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 957 lbs 12/6/2022 Remove 55 BBLs of water from boiler and freeze protect same, Remove 2307 gallons fuel from auxiliary tank and rig tank. Burned total today is 220 gallons. Tie up all lines in derrick, remove lights from remaining modules, secure tools and place miscellaneous items in accumulator room and lube room.;PJSM, Tail Roll Accumulator/ Water Tank module, Generator #1 & #2 module and stage for transport. Move empty auxiliary fuel tank and mud dock matting boards and stage for placement. Pull boiler module away from footprint. Tail Roll Top Drive HPU module and stage for transport.;Position and secure grasshopper on top of Mud Pump #1 with forklift and stinger. Tail Roll Mud Pump #1 module and Mud Pump #2 module and stage for transport. Remove walkway jig with forklift. Leaving monkey board windwalls up for storm gate repair. Tail Roll Mud Tank #3 and stage for;placement on containment. Tail Roll Mud Tanks #1 & #2 and stage for transportation. Remove derrick with two cranes and secure on trailer, Move drilling line spool to same trailer and secure. Move derrick and stage for containment. Connect cranes to draworks skid and place on trailer for transport.;Tail Roll boiler module and stage for containment placement. Pull stairway from subbase with forklift. Lift subbase with cranes and swing out of way. Forklift grab pony subs and spot them in containment on pad 12-15. Grab subbase with bed truck and spot subbase next to pony subs.;Tail roll catwalk and set onto opposite edge of matts from the pony subs. Bring in derrick on trailer and spot next to catwalk. Tail roll boiler module and set next to subbase. Tail roll mud tank #3 and set on containment between derrick and boiler. Set MGS, Auxiliary fuel tank, 11" BOPE stack with;skid and Diverter Annular Preventer on containment.;P/U remaining matts and take to pad 12-27. P/U Liner and what felt we could get. Travel to CCI yard and lay felt, liner and matts for modules to be worked on.;Break Tour so that both crews will be on daylights only. 12/7/2022 Plow snow on location, Electrician and crew repair wires in the derrick for derrick heater, Remove terminated conduit from derrick, Load out Iron roughneck HPU to go to drilling warehouse, Crew at CCI yard complete laying rig matts and receive rig modules to set in containment.;Assist wellhead representative install production tree on 224-10.;Complete containment barrier at 12-15 pad Swanson River. Set following modules on containment at CCI yard, Accumulator/ Water tank module, Generator, Draworks, Top Drive HPU, Mud Pump #1 and Mud Pump #2. Electrician install new 37 pin pigtail on service loop for top drive.;Rig support returns and P/U remaining modules and take to CCI yard. Position all dumpster's and porta potty's for pick-up. Pull felt that we could get loose and let production know that we will be back in the spring to get remaining felt.;Shut down crews as we are all on daylight tour. Rig released from SRU 224-10 at 06:00 on 12/08/2022. Activity Date Ops Summary 12/9/2022 Fox CT and Cruz crane arrive on location. PTW and PJSM. MIRU. Spot supply and return tanks. Flange up BOPs. AOGCC BOP test witness waived per Jim Regg on 12/8/22 @ 1236. BOP test 250 psi low / 3500 psi high. Good tests. Drive man-lift from the Plant to the wellsite. Stage YJ fluid pump. Install night cap on BOPs. SDFN. 12/10/2022 Fox, YJ toolhand, and Cruz arrive on location. PTW and PJSM. Pickup lubricator. Circulate warm FW into CT. MU CT BHA - CTC 2.13"x.75', DFCV 2.13"x.94, BiDi jars 2.13"x5.6', Disco 2.13"x1.58', Circ sub 2.13"x1.1', motor 2.13"x10.5', XO 2.42"x.48', tricone bit 2.75"x.25', OAL - 21.2'. Pull test to 25k and pressure test BHA. Stab on.,Test motor in lubricator, good. RIH. Bring on pump at 1.2 bpm at 7000'. See motor work between 8264' and 8295' ctmd, hard tag at 8295'. Circulate bottoms up plus 30 bbls and begin POOH.,AK EL arrive on location. CT at surface. Cut off YJ BHA. Lay down lubricator. Blowdown reel. Haul away fluids. Lay down injector. Mobe fluid pump back to YJ.,MIRU AK EL above Fox BOPs. MU and RIH with 1-11/16" CBL with 2 bow-spring centralizers. Tag high at 2715'. Repeated tags at same depth. No overpulls. POOH. MU junk basket with 2.78" gauge ring. RIH and tag at 2715'. RIH at 100 fpm, 200 fpm, 400 fpm and 500 fpm. No change in tag depth, and no over-pulls. POOH. Nothing in junk basket. RDMO. Install night cap. SDFN. 12/11/2022 Yellowjacket EL arrive on location. PTW and PJSM. Arrive on wellsite. MIRU. Cross-over to Fix's BOPs was needed from Pollard. Cross-over and additional tools were retrieved from YJ and Pollard shops.,MU and RIH with 1.75" drift toolstring. Made it to 2715' and sat down. After working toolstring, were able to drift clean down to 3000'. Went through problem area 3-4 times each time seeing a weight bobble going in and out of hole. POOH. MU and RIH with 2.75" gauge ring. Sat down at 2715', clean pick-up weights an no overpulls. POOH. Small piece of rubber stuck in gauge ring (1.5" long and 3/8" wide - soft black rubber).,RDMO YJ EL. Leave crossover to Fox's BOP stack on location. 12/12/2022 Assess weather/road conditions. Field advises that Swanson River Rd is not suitable for non-essential travel. Field roads and pads essentially inaccessible. Coordinate plans for Pollard SL and Fox CT crew to come out to location tomorrow morning depending on road conditions. 12/14/2022 Pollard slick line and Cruz crane operator arrive on location. PTW, JSA. Remove snow from location. Spot in and rig up slick line unit.,RIH w/ 2.0 gauge ring to 2690' slm. Bobble through, continue to 2730'. POOH to 2690' slm. RIH to 2719' slm, before bobbling through. POOH,RIH w/ 2.70 3-pronged internal wire grab to 2713' slm, w/ obstruction to 2727' slm. W/t, POOH w/ extra weight. (175 lbs). Foam wiper ball recovered. Drilling report indicated they dropped 2 wiper balls. Only 1 recovered.,RIH w/ same to 5195' and sat down weight. Work down to 5220' SLM. POOH to surface. Nothing in wire grab.,RIH w/ same to 8253' slm, w/ no issues. Pooh, Make a few passes from 5175'-5230' slm for obstruction. None found, POOH. Close master and swab. Rig down Pollard wireline.,AK E-line arrive on location. PTW, JSA. Spot in unit and Rig up. PT lubricator 250/3500 psi.,Perform CBL log from 8270' to cement top at 3240'. Field copy with additional passes sent to town to correlate. Final Log will be adjusted and resubmitted. 12/15/2022 PTW, JSA with Fox CTU , Cruz Crane operator and Hilcorp rep. Fire equipment and warm up. Pick injector head. Make up coil connector.,Stab on well. PT stack 250/3500 psi. RIH with 1.75" CTU. Start cooling down N2 @ 3500'. 5000' Online down CT at 1200 scf/min. Tag PBTD @ 8274' CTMD. PIck up 2' and blow well dry.,72 bbls recovered from wellbore. Increase rate to 1500 scf/min. Well mostly dry. POOH to surface. 5000' shut down N2. No fluid at return tank. Tagged up at surface. Close master and swab.,Production will pressure up tubing with 2200 lbs of gas from facility prior to perforating. Rig down Fox energy CTU. 12/16/2022 YJ Eline check in at office, Sign PTW & PJSM. Drive to location.,Spot in unit and support equipment. Ops on location installing flowline and pressuring up on wellbore with lift gas to 2200. Flowline installed.,Pick up lubricator and GPT toolstring. Establish circulation down the slobber hose. PT lubricator to 250/3000 psi. Pass,WHP = 2155 psi. RIH w/ 21' x 1.69" WB, 8.5' x 1.69" GPT w/ CCL. Tag TD @ 8269'. Did not find any fluid. POOH.,SITP = 2114. RIH w/ 6' x 1.69" GR/CCL, 2' x 1.69" shock sub, 15' x 2" Geo Razor guns (6 spf). CCL to top shot = 15.5'. Pull correlation pass from 8200' - 7500'. On depth. CCL stop depth 7899.5'. Shoot the TY_68-0 from 7915'-7930'. SITP = 2116, 5 min = 2112, 10 min = 2111, 15 min = 2111. POOH. All shots fired, bull plug is dry.,Turn over to ops to flow well. Starting tubing pressure of 2101 psi. Bleed down well to 1498 psi in 25 minutes. SI well for pressure build up. Begin to rig down Eline, RDMO and secure well. 45 minute pressure build up from 1498 to 1512 (14 psi). Ops flows well down to 987 psi with no sustained flow in 30 minutes. SI well for the night. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: SRF SRU 224-10 Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00107 SRU 224-10 Completion Spud Date: 12/19/2022 YJ E-line crew meeting at SRF office, sign in, obtain PTW and hold PJSM. Discuss location, sub-zero hazards and scope of work. Mobilize to location.,Spot equipment, MU PCE and GPT tool string (3x 1.69" wt. bars, GPT tool). Move all to wellhead and PT 250psi/3000 psi. Good test. 470 psi SITP.,Open swab, RIH logging down pass searching for fluid level. Observed FL at 4120' RKB. (3795' above perfs) TY68-0 perforations: 7915'-30' Notified RE and received orders to push fluid downhole with lift gas. Pulled tools OOH into lubricator.,Contacted production operator, mobilized and RU hoses for gas lift jumper. 12:15 pm - Opened 2600 psi GL to well bore. Trending online. 14:00 pm - Well bore equalized to GL @ 2569 psi. PU lubricator and MU 2" x 2' bailer section on bottom of GPT. Stab back on well.,Open swab (2570 psi SITP). RIH to locate fluid level and collect sample. 15:20 pm - Observed fluid at 4515'. 15:50 pm - Observed fluid at 4565' Informed town of approximate fluid push rate of 100'/ hr. Received orders to POOH, rig back and allow production to continue gas lift push. 17:00 pm - Last fluid check - 4650'. POOH.,OOH. Close swab. Secured well and rigged back. Communicated with night operations regarding lift gas/H2O push operations procedure. Leave location. 12/21/2022 Sign in at SRF office, obtain PTW and hold PJSM. Discuss scope of work and proactive spill containment. Early morning power outage negated 36-hour lift gas operation to push fluid back into open perforations at 7915'-7930'. Mobilize equipment to location. SITP - 1090 psi,Spot methanol pup trailer, fuel triplex and trunk heater, MIRU YJ E-line. MU tool string with wt. bars, GPT and fluid sample catcher. Move PCE and tool string to well head. PT 250 psi / 3000 psi.,SITP -1120 psi. Open swab and RIH. Located fluid level at 5495'. Continued downhole and tagged PBTD at 8274'. BHP @ perfs (7915'-30') 2105psi POOH. Contact Fox Energy for N2 transport, pump and crew.,Wait on N2 services to rig down off CLU-10 job and mobilize to Swanson River location.,Fox Energy crew and equipment arrive. Add service and personnel to PTW, hold PJSM and approval from operations to continue. MU hard line from N2 pump to WL pump in sub,1502 Low torque valve. Allow for cool down and PT 500 psi / 4000 psi w/ N2. Open swab and begin coming on-line at 400 - 600 - 800 then 1000 scfm. Pumped for 50 minutes until WHP reached 4000 psi. Total = 50,000 scf. Come off-line and monitor WHP pressure.,After 2 hours off-line well bled down to 3550 psi. Came back on-line at 1000 scfm to 4000 psi WHP. (Additional 9,000 scf). Shut in and secure well. Rig back for the night. Contact production to monitor WHP through the night. 12/22/2022 Sign in, obtain PTW and hold PJSM with YJ E-line crew. Address the PTW and JSA documents and cover well site hazards. Mobe to location.,SITP - 3120 psi. MU (2)1-11/16" wt. bar, (1) 2" tungsten wt. bar, GPT, 1-11/16" setting tool and 2.75" CIBP. PU lubricator and tool string and move to well head. (CCL to plug = 17.5') PT 250psi/4000psi. Pass Fox Energy (N2) arrives on location.,Open swab and RIH w/ GPT to locate fluid level after trapping N2 pressure on well bore overnight. Fluid level at 7100'. Add Fox Energy to PTW and hold PJSM. E-line stationary in hole above fluid level.,Equalize and open lo-torque and roll on N2 pump to 1000scfm and begin pressuring up well bore to 4000 psi. Go offline and allow well to drop in pressure to 3800 psi and bump back up to 4000K. Run log pass every 30 minutes to follow fluid level. Repeat process for 6 hours until fluid moved to 7800' depth. Shut down pump operations. RDMO Fox N2.,Run GPT fluid level check down pass log and correlation up pass for CIBP setting log. (7300'-7850'). Send to engineers, wait for confirmation. Confirmed tie-in and positioned 2.75" CIBP to set at 7874'. Set plug, tagged and POOH.,OOH. LD tools and lubricator. Night cap and secure well. SDFN. Production to bleed well down to 2500 psi overnight. 12/23/2022 Sign in, obtain PTW and hold PJSM. Discuss scope of work, weather conditions and manlift operations. Travel to well site.,Production worked on thawing flow line then bled well down to 2520 psi. PTW approval. MU 2-1/2" x 30' dump bailer, CCL and wt. bar. Hold on site JSA to discuss wind/work conditions. PU lubricator and tool string and position bailer vertically in well cellar. Mix 6.5 gallons of 15.8# cement and fill dump bailer through bailer top using manlift. Move to well, PT 250 psi / 2520 psi.,Open swab and RIH. Tag CIBP at 7874'. PU 10' and dump cement. Witnessed small weight loss. Wait 15 minutes. POOH.,OOH. Bottom bailer cap had shot off. Re-armed again w/ new bailer bottom. Mixed next batch of cement, attempted to fill bailer but would not take cement. LD tool string and determined cement had bridged off and was setting up in bailer. Wind gusts increased to 30-40 mph. Made call to shut down cementing operations due to tool and weather conditions. Secure well. RDMO. 12/27/2022 YJ E-line - sign in, obtain PTW and hold PJSM. Discuss importance of JSA documentation and scope of work. Mobe equipment to location.,Spot equipment and RU. MU 2" x 30' cement dump bailer w/ wt. bar and CCL. PU lubricator and tool string and arm bailer bottom. Mix 4.5 gal. of 15.8# cement and fill bailer. Stab on and MU to wellhead. PT 250/3000 psi. Pass WHP - 2500 psi.,Open swab and RIH. Tag CIBP at 7874'. PU 10' and fire bailer squib, dump cement. POOH. At surface, mix and fill bailer w/ 4.5 gal. cement, fill bailer and RIH with Run #2. Dump cement 10' above plug at 7864'. Repeat for Run #3. Final fill volume = 13.5 gal. and 39' above plug to 7835'. POOH.,OOH. LD dump bailer. MU 2" x 12' (6spf/60Deg.) HSC perf gun with 1-11/16" gun gamma ray/CCL. (12.5' CCL to top shot). RIH and draw well pressure down to 2060 psi. Correlate and confirm tie-in with town. Position and fire gun at 7777'-7789' (TY67-0 interval). Initial pressure - 2059 psi 5 min. - 2060 psi 10 min. - 2055 psi 20 min. - 2050 psi OOH. Final WHP 2042 psi.,LD spent gun. No fluid observed in gun bull plug. Secure well. SDFN and turn over to production to flowback. 12/29/2022 YJ E-line. Sign in, obtain PTW and hold PJSM. Discuss scope of work and JSA accordingly. Travel to well site.,RU and MU GPT tool string. Move lubricator and tools to wellhead and PT 250/3000 psi. Pass WHP - 2500 psi (Injected lift gas).,Open swab and RIH. Observed fluid level at 7760' (17' above open perfs at 7777'-7789'). Tagged PBTD at 7838'. POOH.,OOH. MU 2" x 20' (6spf/60D) RTG perf gun w/ 1-11/16" gun gamma ray/CCL. (10.5' CCL to top shot). Run correlation pass from 7300'-7000'. Send tie-in log to town. Bleed well pressure down to 1800 psi. Confirm tie-in and position gun to shoot 7179' - 7199' (TY62-5 sand). Fire gun. POOH. Initial - 1763 psi 5 min. 1770 psi 10 min.- 1780 psi 15 min.- 1796 psi.,OOH. WHP at 1830 psi. Gun bull pug dry. Turn well over to production to flow test. Initial - 1900 psi @ 1MMCFD Continue drawing down well at same rate, stabilized at 1525 psi. Decision from RE to reshoot same zone.,LD spent gun. Hot check, arm and PU second 2" x 20' perf gun. Open swab and RIH with well flowing at 1.0 MMCFD. Correlate, confirm tie-in and shoot gun again at 7179'-7199'. Initial - 1725 psi. Gradual increase in pressure to 1835 psi, tools at surface.,Secure well. RDMO E-line and turn well over to production to flow back. 1/9/2023 YJ EL arrive at Office. PTW and PJSM. MIRU on well. PT lubricator to 250 psi and 3000 psi. MU 1-11/16" pressure/temp tools. RIH. Well flowing at 2.2 mmscf and 1465 psi. Log from 6800' down to 7800' and back up to 6800'. Find fluid level at ~7182'. POOH. Send logs to town.,MU 10' HSC 2" gun. RIH and correlate, send to town, on depth. Perforate from 7155'-7165'. POOH. All shots fired. Pressure and flow rate data: no change in rate or pressure after shooting.,PU 1-11/16" pressure/temp tool and RIH. Log up and down passes from 6800' to 7800'. POOH. Fluid level showed no movement from earlier, 7182'. Pulling heavy at 80', likely ice.,Pump methanol down pump-in-sub. Heater arrives on location. Tools came free prior to tarping lubricator. Bumped up and shut swab valve with full turns. Lay down lubricator and tarp for the night. Install night cap. SDFN. 1/10/2023 YJ EL arrived at the office. PJSM and PTW. Warm-up equipment and pickup lubricator. MU 20' HSC 2" gun. Well flowing at 3.3 mmscf at 1076 psi. RIH, correlate, send to town, on depth. Perforate from 7155'-7175'. POOH. Pressure/flow data (mmscf/psi): Initial - 3.365/1076 5 min - 3.441/1100 10 min - 3.478/1112 15 min - 3.524/1123,Lay down gun. All shots fired. Gun was damp. Lay down lubricator. Install tree cap. RDMO. 2/5/2023 HES - SL crew arrive on location. PTW. PU lubricator, de-ice bailer, and rebuild packoffs. Bail sand @ ~7230'. Discrepancies between digital and mechanical counters. Made 2 bailer runs. Painted a flag on wire at 7234'. Digital counter was off 18' when toolstring got to surface. Mechanical counter stopped working. LD lubricator. Leave equipment partially rigged up. Will return in AM to continue bailing sand with SL unit. 2/15/2023 Arrive at SRF office, obtain PTW and hold PJSM. Travel to location.,Spot and RU equipment. Shut in well at 0800. MU tool string ( R.S., 2 x 5' weight bars, GR/CCL and junk basket w/ 2.80" gauge ring). Move tools and lubricator to well and PT 250/3000 psi. Pass.,Open swab and RIH. Observed fluid level at 6450'. Tagged PBTD at 7183' (correlated). Tagged bottom 3 times to confirm fill depth. POOH. TY-65 perfs: 7155' - 7175' & 7179' - 7199'.,OOH. Junk basket infused with sand. MU Baker #10 setting tool with setting sleeve and WRP (2.77" OD) x 1.5'. (16' CCL to mid-element). Open swab and RIH. Correlated. confirmed set depth and set plug at 7177'. POOH. Fluid level observed at 6140'.,OOH. Secured well and turned over to production. RDMO. ! "# $%&'( !)$% &%**%%*+% ',- - $( - #. - - !"# /- /- $% 01(-&'"'" " $%())*+%%"! 2-$%-,-. , 0 -$%())*+%%"! 1 - / " 0 - 3 - ', 04- - 0*123 "4 , 0*1, -,-,4 5%$ & 6/! 66 ! / /' 2 (- (- 52- 12- "! 657$/ 67$ '! "! "! "!3 (- "! 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Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: l ll 495 2.44 l ll 175 1.16 5 25.67 Hanger 10 3/4 BTC 1.13 25.67 24.54 3,136.57 28.81 7 5/8'' Pup Jt 7 5/8 29.7 L-80 BTC 3.14 28.81 1.44 3,138.01 3,136.57 7 5/8'' Casing Jts 7 5/8 29.7 L-80 BTC 3,097.76 Float Shoe 8 5/8 BTC 7 5/8'' Casing Jts 7 5/8 29.7 L-80 BTC 82.85 3,220.86 3,138.01 www.wellez.net WellEz Information Management LLC ver_04818br 2.5 Type of Shoe:Frontier Bullnose Casing Crew:Parker 12 213 3,222.003,230.00 CEMENTING REPORT Csg Wt. On Slips: 6% KCL Polymer Mud 21:00 11/18/2022 0 15.8 33 Bump press Visual Bump Plug? 143.2/144.8 1550 40 Halliburton FI R S T S T A G E 10.5Tuned Prime 60 9.2 4 100 800 Csg Wt. On Hook: Type Float Collar:Frontier Float Collar No. Hrs to Run:8 BTC 1.60 3,222.46 3,220.86 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.SRF SRU 224-10 Date Run 18-Nov-22 CASING RECORD County State Alaska Supv.R Pederson / J Riley 3,136.00 Floats Held 6% KCL Polymer Mu Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 3222 FC @ Top of Liner Casing (Or Liner) Detail Float Shoe 8 5/8 TD Shoe Depth: PBTD: Jts. 1 1 52 23 16 2 15 16 2 31 Yes X No X Yes No 30 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Liner Liner Liner Casing (Or Liner) Detail Shoe Liner Liner RA Jts 4 1/2 Rotate Csg Recip Csg Ft. Min. PPG10.2 Shoe @ 8348 FC @ Top of Liner 3010.068,315.19 Floats Held3000 6% KCL PHPA mud CASING RECORD County State Alaska Supv.R Pederson / J Richardson Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.SRF SRU 224-10 Date Run 28-Nov-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Innovex 1.46 8,348.00 8,346.54 4,965.44 4,514.28 481.21 5,505.48 5,024.27 5,024.273 1/2 9.3 L-80 533 X IBT X HYD Tenaris 58.83 HYD 533 3 1/2 9.3 L-80 HYD 533 Tenaris Tenaris 4,965.44 533 x IBT x HYD Tenaris 58.94 3 1/2 9.3 3 1/2 9.3 L-80 Liner RA Jts 3 1/2 9.3 L-80 4,028.08 Tenaris 451.16 L-80 HYD 533 Tenaris Pup Jt 3 1/2 9.3 L-80 HYD 563 L-80 928.94 3,969.143 1/2 4,514.28 4,508.45 480.37 4,508.45 4,028.08 3,040.20 5.83 30.14 Csg Wt. On Hook:105,000 Type Float Collar:Innovex No. Hrs to Run:19.5 10.2 1.5 63 1380 FI R S T S T A G E 10.6Tuned 30 85/87 2167 342 Halliburton 15.3 47 Bump press CBL Bump Plug? 3:56 11/29/2022 ~3,235' 8,348.008,350.00 8,279.65 CEMENTING REPORT Csg Wt. On Slips:32,000 6% KCL PHPA mud 12 208 HYD 533 Tenaris9.3 3,969.14 3,040.20 3,010.06 Type of Shoe:Innovex Casing Crew:Parker Flex-Lock V hanger, HDR-E ZXP liner Packer www.wellez.net WellEz Information Management LLC ver_04818br 3.7 Ran 85 bow spring style centralizers Liner 3 1/2 9.3 L-80 BTC Tenaris 31.35 8,346.54 8,315.19 Float Collar 4 1/2 BTC Innovex 1.18 8,315.19 8,314.01 Liner 3 1/2 9.3 L-80 BTC Tenaris 31.34 8,314.01 8,282.67 Landing Collar XO 4 1/2 BTC 1.26 8,282.67 8,281.41 Landing collar 4 1/2 BTC Baker 1.76 8,281.41 8,279.65 Liner 3 1/2 9.3 L-80 RTS-8 Tenaris 1,629.19 8,279.65 6,650.46 XO 3 1/2 9.3 L-80 IBT x HYD 563 Tenaris 5.87 6,650.46 6,644.59 Liner 3 1/2 9.3 L-80 HYD 533 Tenaris 1,133.31 6,644.59 5,511.28 Pup Jt 3 1/2 9.3 L-80 HYD 563 Tenaris 5.80 5,511.28 5,505.48 Liner Top Packer 6 5/8 HYD 563 Baker Type I II 495 2.39 Type I II 220 1.24 4.5 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Cody Dinger To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] FW: SRU 224-10 and SRU 12-15 10-407s Date:Friday, March 10, 2023 7:51:46 AM Attachments:image001.png Hi James, Looks like I mistyped that one, TPI y coordinate should be: 2482048. Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Friday, March 10, 2023 7:48 AM To: Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] FW: SRU 224-10 and SRU 12-15 10-407s Hi, Can you take a look at the tpi Y coordinate as it is off. thanx From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Tuesday, February 28, 2023 11:22 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: SRU 224-10 and SRU 12-15 10-407s From: Cody Dinger <cdinger@hilcorp.com> Sent: Tuesday, February 28, 2023 11:20 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: SRU 224-10 and SRU 12-15 10-407s 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. Hello, Attached are the 10-407s for SRU 224-10 and SRU 12-15. Thank you! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 02/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230221 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 1/29/2023 HALLIBURTON PPROF END 1-69 50029220200000 190029 2/4/2023 HALLIBURTON COILFLAG END 1-69 50029220200000 190029 2/11/2023 HALLIBURTON PERF KU 14X-06 50133203420000 181092 1/27/2023 HALLIBURTON TEMP SRU 224-10 50133101380100 222124 2/3/2023 HALLIBURTON PPROF TBU D-09RD 50733201310100 181080 2/8/2023 READ LeakPointSurvey Please include current contact information if different from above. SRU 224-10 50133101380100 222124 2/3/2023 HALLIBURTON PPROF 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Wednesday, February 1, 2023 2:38 PM To:Michael Hibbert - (C) Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: BOP Test Form - SRU 224-10 - 12/9/22 Attachments:Fox 8 12-09-22 Revised.xlsx Thank you. I’ve attached a revised report with the change. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Michael Hibbert ‐ (C) <Michael.Hibbert@hilcorp.com> Sent: Wednesday, February 1, 2023 9:20 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: BOP Test Form ‐ SRU 224‐10 ‐ 12/9/22 Hi Phoebe, I just double checked our test chart and my notes and we did not have any failures. So yes, the FP was a typo. Do you need me to send an updated Fom? Thanks! Michael Hibbert Wellsite Supervisor Hilcorp Alaska 907‐903‐5990 From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Monday, January 30, 2023 10:57 AM To: Michael Hibbert ‐ (C) <Michael.Hibbert@hilcorp.com> Subject: [EXTERNAL] RE: BOP Test Form ‐ SRU 224‐10 ‐ 12/9/22 Michael, There was a #2 Rams “FP” listed, but no remarks and the Number of Failures was listed as “0”; was this a typo? Please advise. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Swanson River Unit 244-10PTD 2221240 2 Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Michael Hibbert ‐ (C) <Michael.Hibbert@hilcorp.com> Sent: Wednesday, December 14, 2022 7:48 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: BOP Test Form ‐ SRU 224‐10 ‐ 12/9/22 Hello, Here is the test form for the BOPE test performed on well SRU 224‐10 on 12/9/22. Let me know if you have any questions. Thanks, Michael Hibbert Wellsite Supervisor Hilcorp Alaska 907‐903‐5990 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:8 DATE:12/9/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221240 Sundry #322-681 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:Valves:250/3500 MASP:2471 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Other Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA 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 0 NA #5 Rams 0 NA NA #6 Rams 0 NA NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA NA System Pressure (psi)3000 P Kill Line Valves 2 2"P Pressure After Closure (psi)2550 P Check Valve 0 NA NA 200 psi Attained (sec)3 P BOP Misc 0 NA NA Full Pressure Attained (sec)19 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):N/A NA No. Valves 5 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 15 P Coiled Tubing Only:#2 Rams 15 P Inside Reel valves 1 P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/8/2022 / 12:30 Waived By Test Start Date/Time:12/9/2022 13:00 (date)(time)Witness Test Finish Date/Time:12/9/2022 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Test Fluid: Methanol. Bottle Precharge: 1400 psi. Landry Lynn Hilcorp Alaska Michael Hibbert SRU 224-10 Test Pressure (psi): trais@foxenergyak.com michael.hibbert@hilcorp.com Form 10-424 (Revised 08/2022)2022-1209_BOP_Fox8_SRU_224-10      jbr J. Regg; 4/27/2023  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: 01/26/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230126 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# TBU M-10 50733205880000 209154 12/30/2022 AK E-LINE Perf CLU 10RD 50133205530100 222113 12/29/2022 AK E-LINE GPT_Plug_Perf NCI A-14 50883201250000 208096 11/6/2022 AK E-LINE Perf BRU 214-13 50283201870000 222117 12/19/2022 AK E-LINE PPROF BRU 233-23 50283201360100 222050 12/21/2022 AK E-LINE PPROF SRU 224-10 50133101380100 222124 12/14/2022 AK E-LINE CBL Please include current contact information if different from above. By Meredith Guhl at 2:54 pm, Jan 26, 2023 T37473 T37474 T37475 T37476 T37477 T37478SRU 224-10 50133101380100 222124 12/14/2022 AK E-LINE CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.26 15:02:03 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230125 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 13 50133206460000 214171 1/6/2023 YELLOW JACKET PERF MPU F-62A 50029226090100 220066 1/12/2023 YELLOW JACKET RCT CUT SRU 224-10 50133101380100 222124 1/9/2023 YELLOW JACKET GPT-PERF Please include current contact information if different from above. By Meredith Guhl at 1:56 pm, Jan 25, 2023 T37470 T37471 T37472SRU 224-10 50133101380100 222124 1/9/2023 YELLOW JACKET GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.25 14:00:32 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/24/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230124 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 11/21/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/17/2022 YELLOW JACKET GPT CLU 10RD 50133205530100 222113 10/26/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/28/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 12/2/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 11/25/2022 YELLOW JACKET PLUG CLU 13 50133206460000 214171 11/29/2023 YELLOW JACKET PERF PBU W-26B 50029219640200 222151 12/30/2022 YELLOW JACKET SCBL SRU 224-10 50133101380100 222124 12/19/2022 YELLOW JACKET GPT SRU 224-10 50133101380100 222124 12/16/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/21/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/29/2022 YELLOW JACKET GPT-PERF Please include current contact information if different from above. By Meredith Guhl at 9:59 am, Jan 24, 2023 T37463 T37464 T37464 T37464 T37464 T37464 T37465 T37466 T37467 T37467 T37467 T37467 SRU 224-10 50133101380100 222124 12/19/2022 YELLOW JACKET GPT SRU 224-10 50133101380100 222124 12/16/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/21/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/29/2022 YELLOW JACKET GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.24 10:05:13 -09'00' aa�izy Kyle Wiseman Hilcorp Alaska, LLC Geo technician 3800 CenterPoint Drive, Suite 1400 3 Anchorage, AK 99503 Tele: (907) 564-4558 Nil-wi, kla,ka. 1.1.1 E-mail: kyle.wiseman@hilcorp.com Date: 01/05/2023 To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 224-10 (PTD 222-124) (API 50-133-10138-01-00) Washed and Dried Well Samples (11/27/2022) A Set (4 Boxes): WELL BOX SAMPLE INTERVAL (FEET i MD) SRU 224-10 BOX 1 OF 4 3230' - 4580' MD SRU 224-10 BOX 2 OF 4 4580' - 5930' MD SRU 224-10 BOX 3 OF 4 5930' - 7310' MD SRU 224-10 BOX 4 OF 4 7310' - 8350' MD (TD) Total Dry Bag Count: 171 Please include current contact information if different from above. RECEIVED JAN 0 5 2023 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By Date: 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Friday, December 16, 2022 1:29 PM To:Jay Murphy - (C) Cc:Regg, James B (OGC) Subject:RE: Hilcorp 169 11-13-2022 (SRU 12-15 Diverter Test) Attachments:Diverter Hilcorp 169 11-13-22 Revised.xlsx Jay, Attached is a revised report changing the well name to 224‐10 based on PTD #2221240, adding 0 to the Non‐Compliance Items for Hilcorp 169. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Jay Murphy ‐ (C) <Jay.Murphy@hilcorp.com> Sent: Monday, November 14, 2022 10:16 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Hilcorp 169 11‐13‐2022 (SRU 12‐15 Diverter Test) Thank You and Best Regards, Jay Murphy/ DSM Hilcorp Alaska, LLC HAK Rig 169 Office: 907‐283‐1369 Cell: 907‐715‐9211 Jay.Murphy@Hilcorp.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Swanson River Unit 224-10PTD 2221240 Date: 11/13/2022 Development:X Exploratory: Drlg Contractor:Rig No.169 AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.:2221240 Rig Phone: Rig Email: MISCELLANEOUS: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 ACCUMULATOR SYSTEM:Diverter Size:21 1/4 in. Systems Pressure:3000 psig P Hole Size:9 7/8 in. Pressure After Closure:1550 psig P Vent Line(s) Size:16 in.P 200 psi Recharge Time:16 Seconds P Vent Line(s) Length:156 ft.P Full Recharge Time:95 Seconds P Closest Ignition Source:86 ft.P Nitrogen Bottles (Number of):4 Outlet from Rig Substructure:144 ft.P Avg. Pressure: 2500 psig P Accumulator Misc:NA Vent Line(s) Anchored:P MUD SYSTEM:Visual Alarm Turns Targeted / Long Radius:NA 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: 2 sec P Diverter Misc:NA GAS DETECTORS:Visual Alarm Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:0 NA Total Test Time:1 hrs Non-Compliance Items:0 Remarks: Submit to: Jay.Murphy@hilcorp.com TEST DATA Jon Van-Evera phoebe.brooks@alaska.gov Hilcorp 0 Jay Murphy 0 (907)283-1369 TEST DETAILS jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov Swanson River Unit / SRU 224-10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report GENERAL INFORMATION WaivedHilcorp *All Diverter reports are due to the agency within 5 days of testing* Form 10-425 (Revised 05/2021)2022-1113_Diverter_Hilcorp169_SRU_224-10   Alaska LLC   J. Regg; 12/27/2022 J. Regg; 12/27/2022 SRU 224-10 (PTD 2221240) 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:Chad Helgeson Cc:Donna Ambruz Subject:RE: SRU 224-10 (PTD# 222-124) Sundry # 322-681 Date:Thursday, December 15, 2022 4:10:00 PM Hilcorp has approval to proceed with perforating per sundry 322-681 and to perf the additional interval requested in the email below. This additional interval is between two other approved intervals in the same pool. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, December 15, 2022 4:02 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: SRU 224-10 (PTD# 222-124) Sundry # 322-681 Bryan, Please find attached the CBL for SRU 224-10. The log looks very good, better than we expected towards the top of the well. TOC is 3,240’. The liner top is at 3,010’. Please let us know if we have approval to perforate the Tyonek T-68 Sand (1st zone in the sundry). Our reservoir team also found another sand they would like to add to the Sundry if this can be approved via email. We would like to add: Well Name Zone Top MD Bottom MD Top TVD Bottom TVD TOTAL SRU224-10 TY_67-0 7777 7789 7020 7029 12 Please let me know if we have approval to shoot 1st zone on sundry based on the CBL, we would like to shoot this tomorrow. If you can approve the next sand, we may want to shoot this on Monday or Tuesday if the 1st sand isn’t fruitful. Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notifiedthat 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 theonward 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. David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/08/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 MUDLOGS - EOW DRILLING REPORTS (11/15/2021 to 11/26/2021) 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) a. Formation Log b. LWD Combo Log c. Gas Ratio Log d. Drilling Dynamics Log Folder Contents: Please include current contact information if different from above. By Meredith Guhl at 7:33 am, Dec 09, 2022 222-124 T37363 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.09 07:34:19 -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: 12/07/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 224-10 PTD: 222-124 API: 50-133-10138-01-00 FINAL LWD FORMATION EVALUATION LOGS (11/15/2022 to 11/26/2022) EWR-M5, AGR, PCG, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. By Meredith Guhl at 1:17 pm, Dec 07, 2022 222-124 T37363 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.07 13:18:12 -09'00' Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2221240 Type Inj N Tubing 0 3100 3090 3090 Type Test P Packer TVD 2994 BBL Pump 0.8 IA 0 50 50 50 Interval O Test psi 3000 BBL Return 0.8 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2221240 Type Inj N Tubing 0 310 310 310 Type Test P Packer TVD 2994 BBL Pump 1.4 IA 0 3100 3100 3100 Interval O Test psi 3000 BBL Return 1.4 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Rig MIT-T. AOGCC witness waived. Notes: Hilcorp Alaska LLC Swanson River Unit / Beluga & Tyonek Gas Pool / SRU 224-10 Jay Murphy 11/30/22 Notes: Notes: Notes: Notes: SRU 224-10 SRU 224-10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Rig MIT-IA. AOGCC witness waived. Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-1130_MITP_SRU_224-10_2tests              J. Regg; 4/13/2023 1-Gas Producer 1-Gas Producer RBDMS JSB 120222 1 Regg, James B (OGC) From:Rance Pederson - (C) <rpederson@hilcorp.com> Sent:Sunday, November 20, 2022 12:32 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:Hilcorp Rig 169 BOP Test Results Attachments:Hilcorp 169 11-19-22.xlsx Please see the attached initial BOP test results for SRU 224‐10. Rance Pederson Drilling Foreman Swanson River Unit 907‐283‐1369 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Swanson River Unit 224-10 PTD 2221240 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:169 DATE:11/19/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221240 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2565 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5" vbr P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2 7/8" x 5" vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 2 1/16" & 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 1 2 1/16"P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)23 P BOP Misc 0 NA Full Pressure Attained (sec)91 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2525 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 FP Hydraulic Chokes 1 FP Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 23 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:5.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/18/22 10:44 Waived By Test Start Date/Time:11/19/2022 18:00 (date)(time)Witness Test Finish Date/Time:11/19/2022 23:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with both 3 1/2" and 4 1/2" test joints at 250 psi low, 3000 psi high, 5 min low, 10 min high as per BLM regulations. Quadco Rep tested audio and visual gas alarms with no issues at 15:30 on 11-19-22. Had F/P on Electric Choke, Functioned choke retest for a pass. F/P on Manual Choke, Functioned greased and retest for a pass. Van Evera / Trick Hilcorp Alaska, LLC Pederson / Riley SRU 224-10 Test Pressure (psi): jvan-evera@hilcorp.com rpederson@hilcorp.com Form 10-424 (Revised 08/2022)2022-1119_BOP_Hilcorp169_SRU_224-10          jbr J. Regg; 12/27/2022  From:Brooks, James S (OGC) on behalf of AOGCC Reporting (CED sponsored) To:AOGCC Records (CED sponsored) Subject:FW: BOP - Hilcorp 169 Date:Wednesday, December 28, 2022 9:31:25 AM Attachments:2022-1119_BOP_Hilcorp169_SRU_224-10.pdf James Brooks research analyst II | alaska oIl and Gas conservatIon commIssIon department of commerce, communIty and economIc development 907-793-1241|James.Brooks@alaska.Gov From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, December 27, 2022 3:12 PM To: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov> Subject: BOP - Hilcorp 169 Swanson River Unit 244-10 (PTD 2221240) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 0RQW\0\HUV 'ULOOLQJ0DQDJHU +LOFRUS $ODVND//& &HQWHUSRLQW'U6XLWH $QFKRUDJH$. 5H 6ZDQVRQ5LYHU)LHOG7\RQHNDQG%HOXJD*DV3RRO658 +LOFRUS $ODVND//& 3HUPLWWR'ULOO1XPEHU 6XUIDFH/RFDWLRQ¶)1/¶):/6HF715:60$. %RWWRPKROH/RFDWLRQ ¶)6/¶):/6HF715:60$. 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7KHIROORZLQJOHVVRQVZHUHOHDUQHGIURPH[WHQVLYHH[SHULHQFHGULOOLQJFRDOVHDPVLQ&RRN,QOHW7KH QHHGIRUJRRGSODQQLQJDQGGULOOLQJSUDFWLFHVLVDOVRHPSKDVL]HGDVDNH\FRPSRQHQWIRUVXFFHVV x.HHSWKHGULOOSLSHLQWHQVLRQWRSUHYHQWDZKLSSLQJHIIHFWZKLFKFDQGLVWXUEFRDOVHFWLRQV x8VHDVSKDOWW\SHDGGLWLYHVWRIXUWKHUVWDELOL]HFRDOVHDPV x,QFUHDVHIOXLGGHQVLW\DVUHTXLUHGWRFRQWUROUXQQLQJFRDOV x(PSKDVL]HJRRGKROHFOHDQLQJWKURXJKK\GUDXOLFV523DQGV\VWHPUKHRORJ\ +6 +6LVQRWSUHVHQWLQWKLVKROHVHFWLRQ 1RDEQRUPDOWHPSHUDWXUHVDUHSUHVHQWLQWKLVKROHVHFWLRQ 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev A +LOFRUS5LJ/D\RXW 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev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rilling Procedure Rev A &KRNH0DQLIROG6FKHPDWLF 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev A &DVLQJ'HVLJQ,QIRUPDWLRQ 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev A ´+ROH6HFWLRQ0$63 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev A 6SLGHU3ORW*RYHUQPHQWDO6HFWLRQV 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev A ¶5DGLXVIRU6669 3DJH9HUVLRQ$6HSWHPEHU SRU 224-10 Drilling Procedure Rev A 3URSRVHG'LUHFWLRQDO3ODQZS$WWDFKHG 6WDQGDUG3URSRVDO5HSRUW 6HSWHPEHU 3ODQ658ZS +LOFRUS$ODVND//& 6ZDQVRQ5LYHU8QLW 65)763DG 6ZDQVRQ5LY8QLW 3ODQ658 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000True Vertical Depth (1000 usft/in)-1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section at 33.02° (1000 usft/in) SRU N-well wp01 tgt 1 SRU N-well wp04 tgt 2 1000 1500 2000 2500 3000 3500 4000 4500 5000 550 0 6000 650 0 700 0 7500 8000SRU 12-15 13 3/8" TOW 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 1 5 0 0 2 0 0 0 2 5 0 0 3 0 0 0 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 600065007 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 8 6 4 6 SRU 224-10 wp06 KOP : Start Dir 12º/100' : 1400' MD, 1399.92'TVD : 0° RT TF End Dir : 1417' MD, 1416.91' TVD Start Dir 3º/100' : 1437' MD, 1436.9'TVD End Dir : 1808.7' MD, 1804.57' TVD Start Dir 3º/100' : 4401.91' MD, 4327.3'TVD End Dir : 5869.26' MD, 5567.14' TVD Start Dir 3º/100' : 6484.01' MD, 6028.32'TVD End Dir : 7096.24' MD, 6496.47' TVD Start Dir 3º/100' : 7846.24' MD, 7071'TVD Total Depth : 8646.24' MD, 7772.21' TVD 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: Swanson Riv Unit 12-15 Ground Level: 319.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2480090.800 348941.057 60° 47' 8.5831 N 150° 50' 43.1923 W SURVEY PROGRAM Date: 2022-09-13T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 210.00 1400.00 SRU12-15 Inc Only (SRU 12-15) 3_INC-Only 1400.00 1700.00 SRU 224-10 wp06 (Plan: SRU 224-10) 3_MWD_Interp Azi+Sag 1700.00 3209.00 SRU 224-10 wp06 (Plan: SRU 224-10) 3_MWD+IFR1+MS+Sag 3209.00 8646.24 SRU 224-10 wp06 (Plan: SRU 224-10) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS No formation data is available REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Swanson Riv Unit 12-15, True North Vertical (TVD) Reference:SRU 12-15RD @ 337.00usft Measured Depth Reference:SRU 12-15RD @ 337.00usft Calculation Method:Minimum Curvature Project:Swanson River Unit Site:SRF TS 2-15 Pad Well:Swanson Riv Unit 12-15 Wellbore:Plan: SRU 224-10 Design:SRU 224-10 wp06 CASING DETAILS TVD TVDSS MD Size Name 1399.92 1062.92 1400.00 13-3/8 13 3/8" TOW 3167.00 2830.00 3209.19 7-5/8 7 5/8" x 9 7/8" 7772.21 7435.21 8646.24 4-1/2 4 1/2" x 6 3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 1400.00 0.20 0.00 1399.92 12.52 0.00 0.00 0.00 10.49 KOP : Start Dir 12º/100' : 1400' MD, 1399.92'TVD : 0° RT TF 2 1417.00 2.24 0.00 1416.91 12.88 0.00 12.00 0.00 10.80 End Dir : 1417' MD, 1416.91' TVD 3 1437.00 2.24 0.00 1436.90 13.66 0.00 0.00 0.00 11.45 Start Dir 3º/100' : 1437' MD, 1436.9'TVD 4 1808.70 13.39 0.95 1804.57 64.10 0.72 3.00 1.14 54.14 End Dir : 1808.7' MD, 1804.57' TVD 5 4401.91 13.39 0.95 4327.30 664.45 10.71 0.00 0.00 562.97 Start Dir 3º/100' : 4401.91' MD, 4327.3'TVD 6 5190.63 37.00 5.00 5036.00 996.92 33.23 3.00 6.07 854.01 SRU N-well wp01 tgt 1 7 5869.26 41.39 36.74 5567.14 1384.21 186.87 3.00 90.39 1262.48 End Dir : 5869.26' MD, 5567.14' TVD 8 6484.01 41.39 36.74 6028.32 1709.94 430.06 0.00 0.00 1668.11 Start Dir 3º/100' : 6484.01' MD, 6028.32'TVD 9 7096.24 40.00 65.00 6496.47 1957.41 732.07 3.00 105.04 2040.18 End Dir : 7096.24' MD, 6496.47' TVD 10 7846.24 40.00 65.00 7071.00 2161.15 1168.99 0.00 0.00 2449.10 SRU N-well wp04 tgt 2 Start Dir 3º/100' : 7846.24' MD, 7071'TVD 11 8646.24 16.00 65.00 7772.21 2318.72 1506.90 3.00 180.00 2765.35 Total Depth : 8646.24' MD, 7772.21' TVD 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 2625 2800 South(-)/North(+) (350 usft/in)-525 -350 -175 0 175 350 525 700 875 1050 1225 1400 1575 1750 West(-)/East(+) (350 usft/in) SRU N-well wp04 tgt 2 SRU N-well wp01 tgt 1 SRU 12-15 13 3/8" TOW 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 1750 2250 2750 3250 375 0 4250 4500 4750 5000 5250 5500 5750 600 0 6 2 5 0 650067507000725075007772SRU 224-10 wp06KOP : Start Dir 12º/100' : 1400' MD, 1399.92'TVD : 0° RT TF End Dir : 1417' MD, 1416.91' TVD Start Dir 3º/100' : 1437' MD, 1436.9'TVD End Dir : 1808.7' MD, 1804.57' TVD Start Dir 3º/100' : 4401.91' MD, 4327.3'TVD End Dir : 5869.26' MD, 5567.14' TVD Start Dir 3º/100' : 6484.01' MD, 6028.32'TVD End Dir : 7096.24' MD, 6496.47' TVD Start Dir 3º/100' : 7846.24' MD, 7071'TVD Total Depth : 8646.24' MD, 7772.21' TVD CASING DETAILS TVD TVDSS MD Size Name 1399.92 1062.92 1400.00 13-3/8 13 3/8" TOW 3167.00 2830.00 3209.19 7-5/8 7 5/8" x 9 7/8" 7772.21 7435.21 8646.24 4-1/2 4 1/2" x 6 3/4" Project: Swanson River Unit Site: SRF TS 2-15 Pad Well: Swanson Riv Unit 12-15 Wellbore: Plan: SRU 224-10 Plan: SRU 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8000True Vertical Depth (1000 usft/in)-1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section at 33.02° (1000 usft/in) SRU 224-10 wp06 Tgt1 SRU 244-10 wp06 Tgt2 1000 1500 2000 2500 3000 3500 4000 4500 5000 550 0 6000 650 0 700 0 7500 8000SRU 12-15 13 3/8" TOW 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 1 5 0 0 2 0 0 0 2 5 0 0 3 0 0 0 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 600065007 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 8 6 4 6 SRU 224-10 wp07 KOP : Start Dir 12º/100' : 1400' MD, 1399.92'TVD : 0° RT TF End Dir : 1417' MD, 1416.91' TVD Start Dir 3º/100' : 1437' MD, 1436.9'TVD End Dir : 1808.7' MD, 1804.57' TVD Start Dir 3º/100' : 4401.91' MD, 4327.3'TVD End Dir : 5869.26' MD, 5567.14' TVD Start Dir 3º/100' : 6484.01' MD, 6028.32'TVD End Dir : 7096.24' MD, 6496.47' TVD Start Dir 3º/100' : 7846.24' MD, 7071'TVD Total Depth : 8646.24' MD, 7772.21' TVD 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: Swanson Riv Unit 12-15 Ground Level: 319.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2480090.800 348941.057 60° 47' 8.5831 N 150° 50' 43.1923 W SURVEY PROGRAM Date: 2022-09-13T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 210.00 1400.00 SRU12-15 Inc Only (SRU 12-15) 3_INC-Only 1400.00 1700.00 SRU 224-10 wp07 (Plan: SRU 224-10) 3_MWD_Interp Azi+Sag 1700.00 3209.00 SRU 224-10 wp07 (Plan: SRU 224-10) 3_MWD+IFR1+MS+Sag 3209.00 8646.24 SRU 224-10 wp07 (Plan: SRU 224-10) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS No formation data is available REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Swanson Riv Unit 12-15, True North Vertical (TVD) Reference:SRU 12-15RD @ 337.00usft Measured Depth Reference:SRU 12-15RD @ 337.00usft Calculation Method:Minimum Curvature Project:Swanson River Unit Site:SRF TS 2-15 Pad Well:Swanson Riv Unit 12-15 Wellbore:Plan: SRU 224-10 Design:SRU 224-10 wp07 CASING DETAILS TVD TVDSS MD Size Name 1399.92 1062.92 1400.00 13-3/8 13 3/8" TOW 3167.00 2830.00 3209.19 7-5/8 7 5/8" x 9 7/8" 7772.21 7435.21 8646.24 4-1/2 4 1/2" x 6 3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 1400.00 0.20 0.00 1399.92 12.52 0.00 0.00 0.00 10.49 KOP : Start Dir 12º/100' : 1400' MD, 1399.92'TVD : 0° RT TF 2 1417.00 2.24 0.00 1416.91 12.88 0.00 12.00 0.00 10.80 End Dir : 1417' MD, 1416.91' TVD 3 1437.00 2.24 0.00 1436.90 13.66 0.00 0.00 0.00 11.45 Start Dir 3º/100' : 1437' MD, 1436.9'TVD 4 1808.70 13.39 0.95 1804.57 64.10 0.72 3.00 1.14 54.14 End Dir : 1808.7' MD, 1804.57' TVD 5 4401.91 13.39 0.95 4327.30 664.45 10.71 0.00 0.00 562.97 Start Dir 3º/100' : 4401.91' MD, 4327.3'TVD 6 5190.63 37.00 5.00 5036.00 996.92 33.23 3.00 6.07 854.01 7 5869.26 41.39 36.74 5567.14 1384.21 186.87 3.00 90.39 1262.48 End Dir : 5869.26' MD, 5567.14' TVD 8 6484.01 41.39 36.74 6028.32 1709.94 430.06 0.00 0.00 1668.11 Start Dir 3º/100' : 6484.01' MD, 6028.32'TVD 9 7096.24 40.00 65.00 6496.47 1957.41 732.07 3.00 105.04 2040.18 End Dir : 7096.24' MD, 6496.47' TVD 10 7846.24 40.00 65.00 7071.00 2161.15 1168.99 0.00 0.00 2449.10 Start Dir 3º/100' : 7846.24' MD, 7071'TVD 11 8646.24 16.00 65.00 7772.21 2318.72 1506.90 3.00 180.00 2765.35 Total Depth : 8646.24' MD, 7772.21' TVD 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 South(-)/North(+) (300 usft/in)-300 -150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 West(-)/East(+) (300 usft/in) SRU 244-10 wp06 Tgt2 SRU 224-10 wp06 Tgt1 SRU 12-15 13 3/8" TOW 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 175 0 2000 2250 2500 2750 300 0 325 0 3500 375 0 4000 4250 4500 4750 5000 5250 5500 5750 600 0 6 2 5 0 650067507000725075007772SRU 224-10 wp07KOP : Start Dir 12º/100' : 1400' MD, 1399.92'TVD : 0° RT TF End Dir : 1417' MD, 1416.91' TVD Start Dir 3º/100' : 1437' MD, 1436.9'TVD End Dir : 1808.7' MD, 1804.57' TVD Start Dir 3º/100' : 4401.91' MD, 4327.3'TVD End Dir : 5869.26' MD, 5567.14' TVD Start Dir 3º/100' : 6484.01' MD, 6028.32'TVD End Dir : 7096.24' MD, 6496.47' TVD Start Dir 3º/100' : 7846.24' MD, 7071'TVD Total Depth : 8646.24' MD, 7772.21' TVD CASING DETAILS TVD TVDSS MD Size Name 1399.92 1062.92 1400.00 13-3/8 13 3/8" TOW 3167.00 2830.00 3209.19 7-5/8 7 5/8" x 9 7/8" 7772.21 7435.21 8646.24 4-1/2 4 1/2" x 6 3/4" Project: Swanson River Unit Site: SRF TS 2-15 Pad Well: Swanson Riv Unit 12-15 Wellbore: Plan: SRU 224-10 Plan: SRU 224-10 wp07 WELL DETAILS: Swanson Riv Unit 12-15 Ground Level: 319.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2480090.800 348941.057 60° 47' 8.5831 N 150° 50' 43.1923 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Swanson Riv Unit 12-15, True North Vertical (TVD) Reference:SRU 12-15RD @ 337.00usft Measured Depth Reference:SRU 12-15RD @ 337.00usft Calculation Method:Minimum Curvature 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 79'5HIHUHQFH 6LWH +LOFRUS$ODVND//& 6ZDQVRQ5LYHU8QLW 65)763DG 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eparation Factor1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125 7500 7875 8250 8625Measured Depth (750 usft/in)SRU 12-15SRU 32A-15SRU 432-15SRU 211-15SRU 34-10No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Swanson Riv Unit 12-15 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 319.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002480090.800348941.05760° 47' 8.5831 N150° 50' 43.1923 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Swanson Riv Unit 12-15, True NorthVertical (TVD) Reference: SRU 12-15RD @ 337.00usftMeasured Depth Reference:SRU 12-15RD @ 337.00usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-09-13T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool210.00 1400.00 SRU12-15 Inc Only (SRU 12-15) 3_INC-Only1400.00 1700.00 SRU 224-10 wp07 (Plan: SRU 224-10) 3_MWD_Interp Azi+Sag1700.00 3209.00 SRU 224-10 wp07 (Plan: SRU 224-10) 3_MWD+IFR1+MS+Sag3209.00 8646.24 SRU 224-10 wp07 (Plan: SRU 224-10) 3_MWD+IFR1+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125 7500 7875 8250 8625Measured Depth (750 usft/in)SRU 32A-15SRU 432-15GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference1400.00 To 8646.24Project: Swanson River UnitSite: SRF TS 2-15 PadWell: Swanson Riv Unit 12-15Wellbore: Plan: SRU 224-10Plan: SRU 224-10 wp07CASING DETAILSTVD TVDSS MD Size Name1399.92 1062.92 1400.00 13-3/8 13 3/8" TOW3167.00 2830.00 3209.19 7-5/8 7 5/8" x 9 7/8"7772.21 7435.21 8646.24 4-1/2 4 1/2" x 6 3/4" 5LJDQG'LYHUWHU6WDFN *URXQG/HYHO Annular 0 7RVKDNHU '6$ ϮϭϭͬϰΗΗϮD 0 :(//3(50,7&+(&./,67&RPSDQ\+LOFRUS$ODVND//&:HOO1DPH6:$16215,981,7,QLWLDO&ODVV7\SH'(93(1'*HR$UHD8QLW2Q2II6KRUH2Q3URJUDP'(9)LHOG 3RRO:HOOERUHVHJ$QQXODU'LVSRVDO37'6:$16215,9(57<21(.*$6 6:$16215,9(5%(/8*$*$1$ 3HUPLWIHHDWWDFKHG<HV 6XUI/RF 7RS3URG,QWOLHLQ)('$7'OLHVLQ)('$ /HDVHQXPEHUDSSURSULDWH<HV 5HGULOORI658 8QLTXHZHOOQDPHDQGQXPEHU<HV 6ZDQVRQ5LYHU%HOXJD*DV 7\RQHN*DV3RROVERWKJRYHUQHGE\&2$ :HOOORFDWHGLQDGHILQHGSRRO<HV :HOOORFDWHGSURSHUGLVWDQFHIURPGULOOLQJXQLWERXQGDU\1$ 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